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Home My WebLink About100-2421a. Well Status: GINJ Oil 1b. Well Class: Exploratory Service 5 Hilcorp North Slope, LLC 14. Permit to Drill Number/Sundry 100-242 6/18/1973 6/23/1973 GL PRUDHOE BAY, PRUDHOE 4a. Surface: Top of Productive Interval: Total Depth: 750' FNL, 1047' FEL, Sec. 11, T10N, R14E, UM 750' FNL, 1047' FEL, Sec. 11, T10N, R14E, UM 750' FNL, 1047' FEL, Sec. 11, T10N, R14E, UM Surface: x- y- Zone -685969 5939848 ASP 4 11. Gas SPLUG 5Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 6/16/2020 15. 50-029-21821-00-00 16. PBU OWDW-C Well Name and Number: Surface / Surface 40.90 17. TPI:y- Zone -685969 ASP 4x-5939848 Total Depth: x-y-Zone -685969 ASP 45939848 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: 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# 173 N-80 Surface Surface 215 cu ft AS 25. GRADE PACKER SET (MD/TVD) 26. 2-7/8" 6.5# L-80 1982' 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: 1905' - 1910' 1945' 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 2250 12-1/4"4200 sx PF II, 160 sx PF IISurface2250 1917' / 1917' 13 Bbls Cement Surface Tubing Punch 47 Bbls Class 'G', 1 Gal 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 320-117 Other 12. SSSV Depth (MD/TVD): Ref Elevations BF Surface (attached) 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 Drive, 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.) 5 Submit within 30 days of Completion, Suspension, or Abandonment DIL, BHC Sonic, Comp NEU GR, Comp Fm Den GR, 4-arm caliper G By Jody Colombie at 3:52 pm, Jul 15, 2020 Abandonment Date 6/16/2020 HEW RBDMS HEW 7/17/2020 xGMGR22JUL2020SFD 7/17/2020 SFD 7/17/2020 DSR-7/20/2020 Undefined WDSP 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 14:13:43 -08'00' Carrie Janowski (4185) ACTIVITYDATE SUMMARY 3/22/2020 T/I = 100/4. Temp = SI. WHPs (LTSI). Flowline disconnected. SV, WV, SSV = C. MV = O. IA = OTG. 15:30 5/22/2020 ***WELL S/I ON ARRIVAL*** (Plug & Abandonment) STAND-BY FOR SNOW REMOVAL ***JOB CONTINUED ON 23-MAY-2020*** 5/23/2020 ***CONTINUE JOB FROM 22-MAY-2020***(plug & abandonment) DRIFTED W/ 20' x 1.75" BAILER TO 2,004' SLM RAN NORTHERN SOLUTIONS BALL TEST TOOL TO XN NIPPLE @ 1,945' MD PERFORMED A 10 MINUTE PRESSURE TEST ON TUBING TO 550 PSI (see log for details) RUN SLB EFIRE AND 5' PERF GUNS, PERF FROM 1905'-1910' MD. CONFIRMED TxIA COMMUNICATION WITH TRIPLEX. ***WELL TURNED OVER TO DSO*** 5/25/2020 Job Scope: Cement injection line. (Plug & Abandon) Pumped 1.3 gallons of SqueezeCrete (D-163) ultra fine cement @ 14 PPG down 1/4" injection line. Note: Need to pressure test lines 72 hours after cement placement. DS6O notified and tag hung on injection point. ***Job Complete*** 5/30/2020 Job Scope: Test post cementing of injection lines (Plug & Abandon) Single 1/4" line pressed to 2500 psi with a loss 20 psi ***Job Complete** 5/31/2020 SLB Fullbore Pumping Crew Job Scope: Reservoir Plug and Abandonment. Bullhead Injection test and surfactant wash of TBG & IA, 5 bbls 50/50, 10 bbls hot fresh water + surfactant (2gal/mgal F103 and 2 gal/mgal U067), Take returns from the IA when 8 bbls of surfactant are away, 40 bbls 9.8 ppg brine (taking returns from IA), 10 bbls 9.8 ppg brine (bullhead into perfs) Bullhead Reservoir Cement Abandonment Plug , 5 bbls 60/40, 10 bbls fresh water (ensure IA is fluid packed before going to cement to avoid cement going into tubing punch holes). 13 bbls total cement. , At 12 bbls cement away drop 4" foam ball followed by 1.86" OD steel ball with 4" foam wiper ball behind. Pump last bbl of cement behind wiper ball. (this cement volume will sqz ~10 bbls behind casing)., 2 bbls FW 6 bbls gel pill Slow rate to 0.5 bpm @ 3 bbls gel away to bump ball. Ball bumped 1 bbl past calculated volume Presure testt for five mins started at 382 psi ended at 372 psi = 2.62% leak off. Start circlation of remaining bbl of cement to surface taking returns from IA and flush excess cement out @ ~3 bpm with FW until returns cleaned up. Maintained ~300 psi on choke to keep ball seated. Closed choke traping 350 psi on well. UCA showing 31 hours until 500 psi comprssive strength. Cement in place is 15.8 ppg.Class G Cement 2 7/8:" TBG from 1945' MD to TT @ 1982' MD 5 1/2" Liner 1982 MDto 2030' MD ***Job Complete*** 6/1/2020 T/IA= 20/20. LRS unit 42. Freeze Protection (PLUG AND ABANDONMENT) Circulate 39 bbls of 50/50 Meoh into the TBG with IA returns to OTT. Maintained 100 psi on the IA with the choke. Freeze protect the surface lines with 1 bbl of Meoh. Final T/I= 140/140. SV, SSV WV closed. MV open. IA OTG. ***Job Complete*** Daily Report of Well Operations PBU OWDW-C Daily Report of Well Operations PBU OWDW-C 6/2/2020 T/I = 7/9. Temp = SI AOGCC Witnessed CMIT-TxIA (P&A) AOGCC rep Lou Laubenstein. AOGCC witnessed CMIT-TxIA PASSED to 1,629/1,620 psi. Max Pressure = 1,650 psi, Target pressure = 1500 psi. Used 0.4 bbls of 50/50 to pressure T/IA up to 1,672/1,665psi. First 15min T/IA lost 26/25psi, second 15min lost 17/20psi, for a total loss of 43/45psi. Bled back to 0 psi (0.4 bbls). Hung tags. Final WHPs = 0/0. SV, WV, SSV = C. MV = O. IA = OTG. ***Job Complete*** 6/3/2020 SLB Fullbore Pumping Crew Job Scope: Surface cement TBG & IA mono bore. Pump 5 bbls fresh water down TBG followed by 47 bbls of 15.8 ppg class G cement. Tags hung on all valves DSO notified. UCA- 1000psi compressive strength at 144hr 28min. Cement in place is 15.8 ppg.Class G Cement 2 7/8:" TBG from Surface to 1910' MD 5 1/2" Liner from 1910 'MD to Surface. 6/16/2020 OWDW-C P&A: (Group Excavation) Pad elevation at 41.9' and Tundra elevation 37.4'. Cut wellhead at 10.0' below pad grade. Leaving well 5.5' below Tundra level. AOGCC Adam Earl witnessed cut prior to top off. Tubing had 5.6' void. Filled with 1 gallon of AS1 cement. Cement tops and Marker plate installation witnessed by AOGCC Guy Cook. ***Back fill excavation*** MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �1 �� w DATE P. I. Supervisor FROM: Guy Cook SUBJECT Petroleum Inspector 6/16/2020 Surface Abandon PBU OWDW-C ' BPXA _ PTD 1002420; Sundry 320-117 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. The casing was confirmed to be cut off at 5.5 feet below tundra level. I then inspected the identification plate once it was installed. The welds 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_0WD W-C_gc. docx Page 1 of 3 Y O 0 U U 3 0 K U O pti� I U 3 0 �� M a. �"� O M � � N Q W �I t,U, 1� ', b m O O N O N MEMORANDUM TO: Jim Regg 7) ep 6 vzezti P.I. Supervisor I` FROM: Lou Laubenstein Petroleum Inspector Section: Drilling Rig: Operator Rep: 11 Township: NA Rig Elevation: Daniel Scarpella Casing/Tubing Data (depths are MD) Conductor: 13-3/8" O.D. Shoe@ Surface: O.D. Shoe@ Intermediate: O.D. Shoe@ Production: 5-1/2" O.D. Shoe@ Liner: O.D. Shoe@ Tubing: 2-7/8" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 2, 2020 SUBJECT: Plug Verification PBU OWDW-C BP Exploration (Alaska), Inc. PTD 100-242; Sundry 320-117 Tvpe Pluq Founded on De th Btm De th To MW Above 10N Range: 14E Meridian: Umiat NA Total Depth: 2250 ft MDQ Lease No.: ADL 028311 Suspend: P&A: Yes Casing Removal: 100 Feet Csg Cut@ Feet Feet Csg Cut@ Feet Feet Csg Cut@ Feet 2250 - Feet Csg Cut@ Feet Feet Csg Cut@ Feet 1982 Feet Tbg Cut@ Feet Tvpe Pluq Founded on De th Btm De th To MW Above Verified Fullbore Balanced 1946 It MD Brine Initial 15 min 30 min 45 min Result Tubing 1665 1640 1620, IA 1672 1646 1627 P OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Plug tag not required - wiper plug landed in XN nipple at 1945 ft MD. I witnessed a combo MIT-TxIA on the first cement plug in the well'ss abandonment process. Daniel Scarpella was on location as the company Rep. for this test. This test passed without issue or concern. Attachments: none rev. 11-28-18 2020-0602_Plug_Verification_PBU_OWDW-C_II THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Travis Montgomery Intervention and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission Re: Prudhoe Bay Field, Prudhoe Undefined WDSP Pool, PBU OWDW-C Permit to Drill Number: 100-242 Sundry Number: 320-117 Dear Mr. Montgomery: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.a0gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, y OC _ J sie�lowski Commissioner DATED this Iq day of March, 2020. RBDMSLI�/ APR 0 7 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED 114. 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ 'v""Bpda&nAWX.wn ❑ Suspend ❑ Perforate Oa -s 3/011/7-0 P ❑ Other Stimulate ❑ Pull Tubing ❑ Chanop,EpQrQvrpgram ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Oth l`.=1 (V'1U ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 100-242 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stmtigraphic ❑ Service 0 6. API Number: 50-029-21821-00-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? B. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU OWDW-C 9. Property Designation (Lease Number): 10. Field/Pools: s ADL 028311 • PRUDHOE BAY, PRUDHOE UNDEFINED WDSP 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (R): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 2250 2250 2214 2214 None 2071 Casing Length Size MD TVD Burst Collapse Structural Conductor 84 13-3/8" 16-100 16-100 4930 2670 Surface Intermediate Production 2234 5-1/2" 16-2250 16-2250 7740 6280 Liner Perforation Depth MD (ft): Pertoretion Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2006-2030 2006 - 2030 1 19-1982 Packers and SSSV Type: 2-7/8" Otis BWD Perm Packer Packers and SSSV MD (ff) and TVD (ft): 1917/1917 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: March 22, 2020 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ElAbandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Montgomery, Travis J be deviated from without prior written approval. Contact Email: Travis.Montgomery0lop.com Authorized Name: Montgomery, Travis J Contact Phone: +1 907 564 4127 Authorized Title: Interventions 8 Integrity Engineer Authorized Signature: Date: .3112120,20 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 19 O 111r Plug Int e rity 11 BOP Test ❑ Mechanical Integnty Test m�Location Clearance Other: T L �,* - o`-5 �,tLe—u �C III�� c 1A...e "4 ' RBDMS Post Initial Injection MIT Req'd? Yes ❑ No ❑ APR 0 7 2020 / Spacing Exception Required? Yes ❑ No &l Subsequent Form Required: 1 � — 5/ � V APPROVED BYTHE Approved by I, COMMISSIONER COMMISSION Date: / ORIGINAL . Submit Forth and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approvalAttachments in Duplicate -�3e�ry _4:5�-8 oa ZAD OWDW-C P&A Sundry Intervention Engineer Travis Montgomery (907) 564-4127 / (918) 281-9663 Reviewed by Aras Worthington (907) 564-4102 History: OWDW-C was originally drilled to monitor temperatures in the permafrost for testing in 1973, one of 5 wells drilled at Pad 3. It began use as a disposal well in 2014. The well was completed with 5-1/2" casing and currently has 2-7/8" tubing with perforations just under the permafrost. The well has been permitted as an EPA Class I disposal well since 2014. With the Pad 3 facility closing down, the wells are no longer required. All wells at Pad 3 will be plugged and abandoned (OWDW-NW, OWDW-C, OWDW-SE). Last Pressure Test: MIT -IA to 1559 psi, 6/18/19. Witnessed by EPA Top of DPZ 1 @ 1882' MD. Objective: Perform a full P&A on the well by placing cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker plate. The P&A is designed to conform with BP Practice 100221: Zonal Isolation and BP Alaska's deviation captured in eMOC 10439. Procedural Steps: Note recording requirements in RP: Through Tubing Abandonments (section 5.9) that must be documented in A WGRS and the Wellfile. AOGCC Witness: All AOGCC witnessed operations require a minimum of 24 hour notice to AOGCC inspectors of the timing of the operation so they can be available. EPA Permitted Well: Requires EPA Sundry Approval as well as AOGCC. EPA Requires 45 day notice prior to execution. 1) Slickline A. D&T to top of fill and for wiper dart 2) DHD A. Attempt to purge and cement 3/8" control line • 3/8" line has dual check valves on the end and does not terminate into SSSV. B. Wait on cement C. Pressure test control lines to 2500 psi 3) Eline A. Punch 2-7/8" Tbg @ 1910' MD OWDW-C P&A Sundry.docx 4) Fullbore A. Bullhead Injection Test with Brine B. Bullhead Reservoir Cement Abandonment Plug • Bullhead —12 bbls of Class G Cement (10 of the 12 bbls will be squeezed into perforations). • Land wiper dart in XN nipple. • Cement from 2030' MD — 1945' MD C. Wait on Cement and Pressure Test Reservoir Abandonment Cement Plug • CMIT TxIA to 1500 psi. Max pressure for CMIT 1750psi. AOGCC and or EPA Witnessed • Stop point if CMIT Fails. pr\t� o�rSA Inc c w^x ru� W �v wce gi/�Srion s b�. D. Circulate Upper Wellbore with Brine and Surfactant Wash E. Circulate Upper Wellbore Cement Plug / • Circulate —46 bbls of Class G Cement down tubing and up the IA to surface. • Cement from 1910' MD to surface. Cement Type/weight: Class G 15.8 ppg mixed on the fly or batch mixed. Field blend to be =lab ppg +/_ 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 20-100cc/30 min Compressive Strength: 2000 psi Thickening Time: Minimum 3 hours 5) DHD A. Assist Fullbore with cement job and pump N2 across the wellhead to remove excess cement from the valves. This will allow valves to be opened prior to the wellhead removal to check for pressure. 6) Special Projects A. Excavate and cut off all casings and wellhead 3' below original tundra level. Top job the conductor x 13-3/8" annulus, all other annuli and tubing with cement as needed. Photo document cement in all tubing and all casing strings B. AOGCC witness cement toos in all annuli and inctallatinn of markar can nn nuformnc4 the marker plate onto the casing string Photo document welded marker plate C. Bead weld marker cap on outermost casing string (Conductor Pipe) to read as follows: OWDW-C P&A Sundry.docx BP Exploration Alaska, Inc. OWDW-C PTD # 100-242 API # 50-029-21821-00 OWDW-C P&A Sundry.docx Original Wellbore Diagram Tf7ff= '.BHANCE OFLV YD WBlFAD=- FM -IES AND FMXE""4G SPBD7020AMANDOWDW SOD BAKERC FLUIDS TO 15OT-VLY WASTE DISPOSAL WELL. OIB.BEV= 56.5' COMACTC FREE N0MMMDRTODON('ANY OF. ALV= _'COFDl1CrO:i ? ®D0W?*UI.EWOfM. LOWM FLANGE ON CSG SPOOL M. Angle= 0 - _-.._ 0 RATTO 2000 PSIONLY-3.1?OTSff TRCAP Max „. iCalum kD- ...-- 0 DatumWD= _8800' SS I I I I IOPBIE1 w/Cl KVLVS Minimum ID =1.791" @ 1945' 2-3/8" HES XN NIPPLE 0=2.750• D - 2.00' D=2.00' akD Tf HDT LOGE® PEFFOMMNSLRWRY REP LOG: OND0070014 ANGLE AT TOP PBTF: 0' @ 2008' Nle: Refer m Raducfi n OB for historical pert data SIZE I SPF I WERVAL OpNS7 SHOT SO2 7 fi 20W-2030 O 02111/74 NOJD COFR6CI®PBTdAMFEFW BO PERIAT No:/7002420 LATE REV BY CONAMS DATE REV BY COMAENTS PR CIDEBAY UNT 06123M HMLCDkFLEIION 02/17/14 DWIJkD FlA.L PAKInPPB]LHF BAR( WELL OWDN-C 12/1BV98 Sl na ec LASTTAGDATE 03PoN14 NOJD COFR6CI®PBTdAMFEFW BO PERIAT No:/7002420 1213W73 614 RWO 07121/15 CYJAD CORABCI®TBG BPF API No.; 50-029.21821-00 01/O8r14 Jho DNLG tq CORRECTDFS 03NSr17 CYAD UDATEDCONPACPNSAFErYNOTE65E011,T10N, R14F 648'FFL8104 FEL 01/14114 CRJkD FNALODEAPPROVAL BP Capbratlon (Alaska) 07117/14 lR/JRD ADDED LOW. SLOT C63rdS SLB OWDW-C P&A Sundry.docx 4 Proposed P&A Diagram TNff= BLNDRANGEON-Y n.-Ev= 5B ELEV-- F'— i Angle = omAii= Minimum ID =1- 791" @ 1945' 2-38" HES XN IPPLE Tubing Punches 1910'-1911'M 2 -TM- TBG. S.W, L-30 aRD w DOPE .0058 Opf, 0 = 2.00• Wiper Plug landed in XN Nipple PHKORATI NSU#WRY FEF LOG: _ ON)DU=14 ANGLEATTOPPEW: 0' 2D06' PMe: rifer W Production DB for h' Wal pert data SIZE I SPF I INTERVAL I OpNSq� SHOT SOZ 13/6' 6 2006-2(130 O 02/11/14 BP Fspioratbn(ALa ka) Or - D W—CSAFETY NOTE EDGES AND RB)IXE YRLI NJG SPED 2WMMAND FLUIDS TO ISOT—OLY WASTE DISPOSAL WELL. CONTACT CARMEJANOWSM PRIOR TO DOING ANY I DATE 02/17/14 03/04114 07M/151 0308'17 I FEV BY I cohama /S I F LI FOE BAY UNIT qN/JAU ft1LL PAMIOPP6Dp13SBARf WELL: OWONGC MAID COW/ECfEO FMA DD R3iF B0 FBUAT Pb: e1002420 CYJAL COPo�I®TBG BPF AR No.: 50-029-21821-00 CWAL U-OATEDCO TAACFNSAFEFYNDT6SEC11,T10R Rt4F 848'FN-&1D18'FEL J 0&2373 NIIWLCDW fU4 DOWNHDLEWOR(. LOWERRANGEON(SG SPOOL Is 12J30113 614 RWO 01/08/14 JAL DRLGNOMFIRMTI@s RATED TO 2000 PSI ONLY •-112. OTs TREE CAP WNN87 — CWJAL RNAL- O AHR VAL VLVS Upper Wellbore Cement Plug from 1910'MD to Surface 1.920• fiAL TT Nor LOGc® Reservoir Abandonment Cement Plug from 1945'-2030'MD w/^10 bbls squeezed behind pipe OWDW-C P&A Sundry.docx 5 I DATE 02/17/14 03/04114 07M/151 0308'17 I FEV BY I cohama /S I F LI FOE BAY UNIT qN/JAU ft1LL PAMIOPP6Dp13SBARf WELL: OWONGC MAID COW/ECfEO FMA DD R3iF B0 FBUAT Pb: e1002420 CYJAL COPo�I®TBG BPF AR No.: 50-029-21821-00 CWAL U-OATEDCO TAACFNSAFEFYNDT6SEC11,T10R Rt4F 848'FN-&1D18'FEL DATE REV BY I COKUHM 0&2373 NIIWLCDW fU4 12119/9& sucKL £ LASTTAGd1TE 12J30113 614 RWO 01/08/14 JAL DRLGNOMFIRMTI@s 01/14114 CWJAL RNAL- O AHR VAL BP Fspioratbn(ALa ka) 01/17/14 AB/JAL ADDED LONG SLOT DEBRIS SLB OWDW-C P&A Sundry.docx 5 TYPE LOG Northwest Well Dftwn: GL = as OWDW-C P&A Sundry.docx �-. ro 8. o (, f).. M� R M E 0 t3 G R ,-I TT,-s,,-Ivr �t' R n a 1900 Base Permafro Confuting Zone r . Arresting Zone Continuous 2000. sand _ y . Perforations 1980'- 2005' and 2032',- 2093'_nnd 2100 OWDW-C P&A Sundry.docx Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com> Sent: Tuesday, January 14, 2020 10:26 AM To: AK, OPS EOC Specialists; Ak, OPS FS3 Field PTL; AK, OPS FS3 OSM; AK, OPS FS2 Pad 3; Wallace, Chris D (CED); AK, OPS Prod Controllers Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Lau, Jack Subject: NOT OPERABLE: Injector OWDW-C (PTD #1002420) EPA permit expired with no plans for renewal -1 All, Disposal injector OWDW-C (PTD #1002420) was shut in on 12/06/19 as the injection permit expired 12/07/19. There are no plans for renewal of the injection permit. The well is now classified as NOT OPERABLE and will remain shut in. The well has also been added to the quarterly AOGCC injection report. Please call with any questions or concerns. Ryan Holt Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-5102 BP EXPLORATION ALASKA INC. 900 E BENSON BLVD ANCHORAGE ALASKA, 99508 Correction to OWDW Well Coordinates ,RECEIVE® MW 08 ,Mjq AOGCC XcC- 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 cut off 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. Karl H. Kyzer, PLS Lead Surveyor, BP Exploration Alaska Inc. May 7, 2019 11 DRILL SITE 6 ' MON. 6-D � p zg n 1-z wg N� DRILL SITE 6 OWDW-NW ■ . OWOW-NE (ABDN) OWDW—C ■ OWDW-SE GRAPHIC SCALE LEGEND 0 15 30 60 AS—BUILT CONDUCTOR ( IN FEET) ■ EXISTING WELL 1 inch - 30 ft. 0 CONTROL MONUMENT 01111*9 1. ALASKA STATE PLANE ODORDINATES ARE ZONE 4, NAD27. 2. GEODETIC POSITIONS ARE NAD27. 3. BEARINGS AND DISTANCES SHOWN ALASKA STATE PLANE GRID. 4. BASS OF VERTICAL CONTROL IS DRILL SITE 6, 2010 WELL BORE SUBSIDENCE STUDY, MONUMENT 6—D, ELEVATION, EL 35.30. S DRILL SITE 06 AVERAGE SCALE FACTOR IS: 0.9999388, 6. DATE O SURVEY. SEPTEMBER 19-20, 2018. 7. REFERENCE FIELD BOOK: NS18-33 PP. 45-50. & ESTIMATED RELATIVE ACCURACY (THIRD ORDER): BASELINE DISTANCE 1:24,403' BASELINE AZIMUTH: *&4' AVERAGE RELATIVE ACCURACY: *0.01' DRILL SITE kIi Li iM'6_1' * VICINITY MAP SCALE 1'= 1000' I SEC I SEC 2 1 SEC SEC 11 I 12 I l JI I PAD 3 1 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS—BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF SEPTEMBER 20, 2018 LOCATED WITHIN PROTRACTED SECTION 11, T. 10 N., R. 14 E., UMIAT MERIDIAN, ALASKA WELLA.S.P. CON LCL: BASIS OF CONTROL: S. NAD27 COORDINATES DERIVED USING TRIMBLE BUSINESS GEODETIC GEODETIC CENTER—HCE, VER. 3.92. DRILL SITE 6 MONUMENT 6—D 10. GEODETIC COORDINATES DERIVED USING AUTODESK AUTOCAD CIVIL Y- 5,942,094.02 N- 7,31&55 ELEVATION: 35.30' MLLW NO. X� 685,136.(12 E= 3,945.53 3D 208, VER. 120.8420. NAD27, ASP, ZONE 4 PAD 3 PLANT 11. BASE FLANGE ELEVATION SHOWN PER PAD 3 WELL BORE DESCRIPTION: FROST FREE MONUMENT IN r DIA STEEL CASING, 2.7FT* SUBSIDENCE STUDY 2018. ABOVE TUNDRA GRADE, 365FT* NORTH OF DRILL 97E 6 PAD. MONUMENT IS OWDW—C IN FAIR CONDITION. LOCATED WITHIN PROTRACTED SECTION 11, T. 10 N., R. 14 E., UMIAT MERIDIAN, ALASKA WELLA.S.P. PLANT GEODETIC GEODETIC SECTION PAD CELLAR BASE NO. COORDINATES COORDINATES IPOSITION(DMS)IPOSITION(D.DD)l OFFSETS ELEVATION BOX EL. IFLANGE EL. OWDW—C Y= 5,939,847.50 N= 5,007.34 7014'26.225" 70.2406181' 4,529' FSL N/A N/A 40.97'. X= 685,968.76 E= 4,577.12 148'29'53.070" 148.4980749' 1,047' FEL Hall Wal b RAPER p ogre a9 z9 a �•I ERB16 PIAT (R 9 EU.. CDA# PRUDHOE BAY, ALASKA ,,wAg,MWE AECC562 EOA DS6/PAD 3, WELL OWDW—C I• - 3W CONDUCTOR AS—BUILT No. DAIS N. B1' aK [� l)F�) 0 by North America - ALASKA - BP PBUSAT OWDW OWDW-C - Slot C OWDW-C 500292182100 Design: OWDW-C Final Survey Report 10 January, 2019 r ae Company: North America - ALASKA - BP Protect: PBUSAT Site: OWDW Well: OWDW-C Wellbore: OWDW-C Design: OWDW-C BP Final Survey Report Local Coordinate Reference: Well OWDW-C - Slot C TVD Reference: - KB @ 56.50usft (1 : C 6/18/1973 00:00) MD Reference: KB @ 56.50usft (1 : C 6/18/1973 00:00) North Reference: - True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Project PBUSAT, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones System Datum: Mean Sea Level Geo Datum: NAD27' OGP-Usa AK [4267'15864] Using Well Reference Point Map Zone: NAD27'OGP-Usa AK/ Alaska zone 4[26734'1586, Using geodetic scale factor Site OWDW, TR -10-14 Site Position: From: Map Position Uncertainty: 0.00 usft Well OWDW-C - Slot O, OWDW-C Well Position NI -S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 Usti Wellbore OWDW-C Magnetics Model Name Sample Date bggm2007 4/17/2000 Design OWDW-C Audit Notes Northing: Eastinq: Slot Radius: Northing: Eastinq: Wellhead Elevation: Declination V) 27 15 Version: 1 Phase ACTUAL Vertical Section: Depth From (TVD) +N/ -S (usft) (usft) 56.50 0 00 Survey Program Date 1/10/2019 From To (usft) (usft) Survey (Wellbore) 100.00 2,200.00 Survey #1 (OWDW-C) Tool Name BLIND 5,937,242.500 usft 683,394.810 usft 0.000 in 5,939,847.500usft - 685,968.760 usft usft Latitude: Longitude: Grid Convergence: Latitude: Longitude: Ground Level: Dip Angle Field Strength (nT) 80.79 57,474 Ti. On Depth: 56.50 +E/ -W Direction (usft) (1) 0 00 0 00 Description Blind drilling 70114' 1.231 N 1481 31' 9.716 W 1.39 ' 70° 14'26.225 N 148" 29'53.070 W 0.00 usft 1/102019 8:51:18PM Page 2 COMPASS 5000.1 Build 810 by BP Final Survey Report Company: North America- ALASKA - BP Project: PBUSAT Local Coordinate Reference: Well OWDW-C -SlotC Site: OWDW TVD Reference: KB @ 56.50usft (1 : C 6/18/1973 00:00) Well: OWDW-C MD Reference: KB @ 56.50usft (1 : C 6/18/1973 00:00) Wellbore: OWDW-C North Reference: True Design: OWDW-C Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS (usft) (°) (°) (usft) (usft) 1 (usft) usft Northing Fasting DLe9 V. Sec 56.50 0.00 0.00 56.50 0.00 (usft) 1 (usft) (usft) (°1100usft) (weft) 100.00 0.00 0.00 100.00 0.00 0.00 5,939,847.500 685,968.760 0.00 0.00 I 2,200.00 0.00 0.00 2,200.00 43.50 0.00 0.00 5,939,847.500 685,988.760 0.00 0.00 2,250.00 0.00 0.00 2,250.00 2,143.50 0.00 0.00 5,939,847.500 885,968.780 0.00 0.00 2,193.50 0.00 0.00 5,939,847.500 885,968.760 0.00 - - _ - - - _ - - - - - _ 0.00 1/102019 8:51:18PM Page 3 COMPASS 5000.1 Build 81D • CERTIFIED MAIL # 7016 0910 0001 1049 8887 April 24, 2018 Mr. Edward J. Kowalski Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue OCE -101 Seattle, WA 98101 Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West Ph Avenue Ste 100 Anchorage, AK 99501-3192 Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 by 41111111�' -416 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 U.� °!'i t t RE: Mechanical Integrity Test Notifications Pad 3 Iniection Wells, UIC Permit AK -1 1004-B. Wastewater Disposal Permit No 201 ODB0001-0021 Grind and Iniect Iniection Wells, UIC Permit AK -1 1008-B. Area Injection Order No 4G. General Wastewater, Permit No. 201ODBO01-0012 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following revision to notification of well surveillance activities to satisfy demonstration of mechanical integrity requirements for the Class I UIC permits mentioned above: 1) SAPT (Standard Annulus Pressure Test) also called MITIA (Mechanical Integrity Test of the Inner Annulus) 2) approved fluid movement tests 3) tubing inspection tests or logs (known as caliper logs). This notification was submitted on with letter dated April 3, 2018. 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. Evan Osborne of the Environmental Protection Agency (EPA) to maximize efficiencies associated with the travel arrangements of the EPA Mechanical Integrity Test Noation April 24, 2018 Page 2 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. If you have any questions, please contact me at (907) 564-5056 or omar.ramirez@bp.com Sincerely, ,111 A4W Omar Ramirez Regulatory and Permitting Advisor-Waste/UIC Attachment cc: Evan Osborne, EPA Region 10 Mechanical Integrst Notification • April 24, 2018 ie Page 3 Certification Statement Mechanical Integrity Test Notification 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. 16 1 - - -- , q R onsible o pang Official Date Wendy Bosmans East Area Operations Manager BP Exploration Alaska) Inc. Printed Name Title Company s • Certified Mail # 7016 0910 0001 1049 8948 BP Exploration (Alaska) Inc. 900 East Benson Boulevard April 24, 2018 P,O. Box 196612 Anchorage, Alaska 99519-6612 UIC Manager, Ground Water Protection Unit (907) 561-5111 U.S. Environmental Protection Agency (OCE -101) 1200 Sixth Avenue, Suite 155 Seattle, WA 98101 RE: First Quarter 2018 — Pad 3 Injection Well Monitoring Report UIC Class I Permit AK — 11004-B Dear UIC Manager: This report is being submitted to fulfill the first quarter 2018 (January - March) reporting obligations for the above referenced permit. Enclosed are two 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 were no permit exceedances of the 1400 psig injection pressure limitation or 150 psig annulus pressure limitation on the Class I wells during this calibration. Please see attached emails for descriptions of any data anomaly events, if applicable. 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. If you need any clarification or additional information concerning these reports, please contact me at (907) 564-5056 or Omar. Ramirez@bp.com. Sincerely, /** I 44;n Omar Ramirez Waste and UIC Compliance Advisor Attachments cc: Evan Osborne, EPA Chris Wallace, AOGCC Marc Bentley, ADEC UIC Manager April 24, 2018 Page 2 Certification Statement First Quarter 2018 — Pad 3 Injection Well Monitoring Report 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. s !- r 4V ke46nsi a147 pany Official Date Wendv Bosmans East Area Operations Manaaer BP Exploration (Alaska) Inc, Printed Name Title Company AlkIIS 0 A Mr AMiOle .1 US Environmental Protection Agency Form 7520-8 STEP 1. Copy this template in macro -enabled xism version using "Save As". Include Well name, Yr and Qtr with current file name. STEP 2. Fill in the highlighted cells with relevant information. Do not enter n/a in any cell. Fields(*) are mandatory. STEP 3. Enable macro. Press <Ctrl><Shift><A> to run the macro and check data in Dbtable worksheet. Save file and submit. Important: Please do not change the position of any cell below. Do not copy/paste cells or insert/delete row or column. OPERATOR NAME* WELL* YEAR* PERMIT* Prudhoe Bay Unit, Pad 3 OWDW-NW 2018 AK -11004-8 REPORTING MONTH* JAN FEB MAR INJ PRESSURE (MIN), PSI 0 2 283 INJ PRESSURE (AVG), PSI 631 590 596 INJ PRESSURE (MAX), PSI 2005 908 902 INJ RATE (MIN), GPM 39 2 12 INJ RATE (AVG), GPM 82 68 73 INJ RATE (MAX), GPM 143 212 131 ANNULAR PRESSURE (MIN), PSI 2 64 66 ANNULAR PRESSURE (AVG), PSI 75 73 72 ANNULAR PRESSURE (MAX), PSI 205 88 88 TOTAL INJ VOL (MONTH), GAL 1,699,463 975,883 927,167 ANNUAL INJ VOL (CUM), GAL 1,699,463 2,675,346 3,602,513 TEMPERATURE (MIN), OF 35 35 35 TEMPERATURE (AVG), °F 50 50 50 TEMPERATURE (MAX), OF 130 130 130 pH (MIN) 2.1 2.1 2.1 pH (AVG) 7 7 7 pH (MAX) 12.4 12.4 12.4 (mm/dd/yyyy) SUBMITTED ON:* ��4/24/2018 • US Environmental Protection Agency Form 7520-8 STEP 1. Copy this template in macro -enabled xlsm version using "Save As". Include Well name, Yr and Qtr with current file name. STEP 2. Fill in the highlighted cells with relevant information. Do not enter n/a in any cell. Fields(*) are mandatory. STEP 3. Enable macro. Press <Ctrl><Shift><A> to run the macro and check data in Dbtable worksheet. Save file and submit. Important: Please do not chanee the position of anv cell below. Do not copy/paste cells or insert/delete row or column. OPERATOR NAME* WELL* YEAR* PERMIT* Prudhoe Bay Unit, Pad 3 OWDW-SE 2018 AK -11004-B REPORTING MONTH* JAN FEB MAR INJ PRESSURE (MIN), PSI 0 14 289 INJ PRESSURE (AVG), PSI 437 531 546 INJ PRESSURE (MAX), PSI 2017 938 897 INJ RATE (MIN), GPM 0 0 12 INJ RATE (AVG), GPM 24 71 73 INJ RATE (MAX), GPM 155 225 147 ANNULAR PRESSURE (MIN), PSI 1 7 6 ANNULAR PRESSURE (AVG), PSI 15 13 10 ANNULAR PRESSURE (MAX), PSI 201 24 19 TOTAL INJ VOL (MONTH), GAL 365,864 998,962 893,399 ANNUAL INJ VOL (CUM), GAL 365,864 1,364,826 2,258,225 TEMPERATURE (MIN), °F 35 35 35 TEMPERATURE (AVG), °F 50 50 50 TEMPERATURE (MAX), °F 130 130 130 pH (MIN) 2.1 2.1 2.1 PH (AVG) 7.0 7.0 7.0 PH (MAX) 12.4 12.4 12.4 SUBMITTED ON:* 4/24/2018 (mm/dd/yyyy) 0 US Environmental Protection Agency Form 7S20-8 STEP 1. Copy this template in macro -enabled xism version using "Save As". Include Well name, Yr and Qtr with current file name. STEP 2. Fill in the highlighted cells with relevant information. Do not enter n/a in any cell. Fields(*) are mandatory. STEP 3. Enable macro. Press <Ctrl><Shift><A> to run the macro and check data in Dbtable worksheet. Save file and submit. Important: Please do not change the position of any cell below. Do not copy/paste cells or insert/delete row or column. OPERATOR NAME* WELL* YEAR* PERMIT* Prudhoe Bay Unit, Pad 3 OWDW-C 2018 AK -11004-B REPORTING MONTH* JAN FEB MAR INJ PRESSURE (MIN), PSI 0 0 0 INJ PRESSURE (AVG), PSI 22 4 9 INJ PRESSURE (MAX), PSI 1206 18 95 INJ RATE (MIN), GPM 0 0 0 INJ RATE (AVG), GPM 0 0 0 INJ RATE (MAX), GPM 0 0 0 ANNULAR PRESSURE (MIN), PSI 20 75 76 ANNULAR PRESSURE (AVG), PSI 81 80 81 ANNULAR PRESSURE (MAX), PSI 108 87 89 TOTAL INJ VOL (MONTH), GAL 0 0 0 ANNUAL INJ VOL (CUM), GAL 0 0 0 TEMPERATURE (MIN), °F 35 35 35 TEMPERATURE (AVG), °F 50 50 50 TEMPERATURE (MAX), °F 130 130 130 pH (MIN) 2.1 2.1 2.1 pH (AVG) 7 7 7 pH (MAX) 12.4 12.4 12.4 SUBMITTED ON:* 1 4/24/2018 (mm/dd/yyyy) • 0 r i PAD3 - West Pit bp Composition Summary 11112018 to 313112018 North Slope Technical Services By Exemption, By Component Equipment Services Group Component Cubic yards Barrels Exempt BOILERBLOWDOWN 24.00 SCALECORROSIONINHIBITOI 300 CRUDEOIL 1,38023 CRUDEOIL 2085 CUTTINGS 13.30 DIESEL 1,381.14 DIESELWATERGEL 1,610.19 DOMESTICWATER 1,359.00 DRI LLI NGMUD 2,925, 76 FRACSAND 1870 FRESHWATER 18,070.38 FRESHWATER 226.00 GLYCOL 55.50 GRAVELSAND 1.27 METHANOL 2,706.13 METHANOL 0.50 CEMENT RINSATE 53800 RINSATE (RINSE FLUIDS) 32,303.00 ORANGE SOL 2.99 AQUEOUS WASTE BASIC 22.00 USED OIL 260 GLYCOL 14.00 SNOWMELT OR RAINWATER 1,45300 SPILL CLEANUP WASTE 21800 BLEED TRAILER FLUIDS 338.00 contam pill 54.00 testing rinsate 55.00 CAUSTIC 72.50 CHEM CLEAR (Commercial by 054 Printed on Sunday, Ap Page 1 of 2 Component Cubic yards Barrels MINERAL OIL 263,65 Tank Vessel Fluids 1 481,00 SURFACTANTS 184.00 Parts washer fluid 22,00 PARTS WASHING FLUIDS 24,22 SUMP WASTES 18,52575 TANKNESSEL SOLIDS 0,20 WELL CELLAR FLUIDS 1,103,00 WELL RETURNS 5900 CHEMICALS AND REAGENTS 3.55 INSULATION FLUIDS 1100 SOAP (Non -hazardous deterge. 200.03 FREEZE PROTECTION FLUID 67,50 HYDROTEST FLUIDS 1,106,00 MUD RINSATE 7600 RINSATE (RINSE FLUIDS) 650,00 Other 1.00 KITCHEN GREASE / OIL 0,01 PRODUCEDWATER 5,212.16 PRODUCEDWATER 3465 SEAWATERBRINEKCI 30,592,45 SNOW 12530 CEMENTCONTAMINATE 1,210,55 Total Exempt Volume 125,625,00 Total Volume: 125,525.00 Printed on Sunday, Ap Paye 2 of 2 Pad 3 Monthly Manifest & Data Review Monthly Manifest & Data Review Period: 1 Q 2018 Reviewed By: William E Drake III Date: 4/1/2018 Yes/No Initial/Date Were wastes manifested accurately? Yes IWED 4/1/18 Were wastes approved for disposal by appropriate a ? IYes IWED 4/1/18 Were lab results reviewed? IYes IWED 4/1/18 Cnmments: Nothing in my review indicates any miss -injection during 4Q. 0 0 50000 N L 30000 m 20000 10000 n Total Well Volumes \,tiO CO \`y4 \IP 01 \tp \,tiO \OP \`tiO 10<P \tip Days 0 is 2500 2000 1500 �N a 1000 500 0 Maximum Injection Pressure Days **Ib ,,Ib —NW Well SE Well — C Well 0 0 250 200 150 CL 100 50 0 Maximum Annular Pressure �� h$ R� R$ �� ti$ +�`� h�' ►�$ ►�� ti`s ti� ti� ►�� R$ Ory0 OrO Days Well SE Well C Well • Total Well Volumes 50000 45000 40000 35000 30000 ` 25000 e� 00 20000 15000 10000 5000 —Total Volume Injected (NW, C and SE) 0 N N RN "�� ►�� ►Np ti1b tit Nb \gyp \gyp \,gyp \gyp \gyp \gyp 4\P\ryp \,P\� h\gyp 4p `,tip \rp Days • • Maximum Injection Pressure 1600 1400 1200 1000 CL 800 600 400 200 0 'b oNb o'`o oNt oNb oN"b oNb oN1b oN'b oN1b o',Ib o'`,' oNt oNq) Days W _. Well — SE Well C Well n U • Maximum Annular Pressure 160 140 120 100 CL 80 60 40 20 0 rL� ti� ti4 rLp efl tp rL \ rL�\ `L�` tib\ �Cb\ '`h\'�, tiR�\ �'`�\ ��` \ � \\ � \ e r e e ti �� ti� 41 Days NW Well SE Well C Well 0 45000 40000 35000 30000 25000 L m 20000 15000 10000 5000 0 Total Well Volumes 4 'b 3 I bP I 34' 1 4ry 3V 3`L ISP Days Total Volume Injected (NW, C and SE) Pad 3 • n LJ i Maximum Injection Pressure 1600 i 1400 I 1200 -- — E I 1000 800 I 600 4— s 400 -- i 200 1 0 I Days NNW Well —SE Well --C Well 0 160 140 120 100 CL 80 60 40 20 0 Maximum Annular Pressure Days NW Well SE Well C Well • r1 U Garney, Hilary (SLR) UM From: AK, OPS FS2 G&I-Pad3 Facilities Supervisor Sent: Monday, January 08, 2018 6:34 AM To: AK, HSSEE Env Adv Central; Janowski, Carrie Cc: AK, OPS FS2 COTU G&I PAD3 OTL; AK, OPS FS2 Pad 3 Subject: FW: SE well tubing The weather is extremely cold up here -20. We are actively monitoring well house temperature and tubing pressure to catch tubing from freezing as well as brainstorming, future preventive measures. Thanks, GNI / PAD 3 Supervisor Timothy Dushkin/ alt-Kemane Wright AES O&M Harmony 3381/6018 Desk: 907-659-8947 / Cell: 907-306-2986 Prudhoe Bay, AK 99734 One Crew, One Journey Honoring the values of our founders as we develop the future. "`I G 5 ;A A8RC Er4ER y SEFivices PI?3 From: AK, OPS FS2 Pad 3 Sent: Monday, January 08, 2018 5:03 AM To: Janowski, Carrie Cc: AK, OPS FS2 G&I-Pad3 Facilities Supervisor; AK, OPS FS2 Pad 3 Subject: SE well tubing Carrie Last night we seen the SE well tubing pressure spiked to above 120OPSIG a few times. walk downs from the PZ discharge to the well heads were done and all associated gauges show 500PSIG. The problem was a frozen 3/8" instrument tubing at the well head tubing rose mount gauge. Charleton and I bleed off the pressure and we worked on the 3/8" instrument tubing ice plug. All other gauges on the well tubing read 500PSIG. We placed a heater trunk in the well house and thawed the ice plug. All is back to normal. DAMEL SUCH PAD 3 B59 5533,,/%Stt#675 One Crew, One Journey Honoring the values of our founders as we develop the future. .° a ASAC ENERGY BERvices � rwAlwrt M hwle � Mwms.r� Grrm+alssr. 4 � �4N`+ Garney, Hilary (SLR) From: AK, OPS FS2 Pad 3 Sent: Thursday, February 01, 2018 3:15 PM To: Janowski, Carrie Cc: AK, HSSEE Env Adv Central Subject: January 2018 Pressure anomalies on OWDW wells There were 3 high injection pressure anomalies recorded in the OWDW wells during January 2018. See notes below: 1-7-18 OWDW- SE high injection pressure of 1406 psi was due to a frozen Rosemount surface gauge, not an injection pressure. 1-10-18 OWDW-SE high injection pressure of 2017 psi & OWDW-NW high injection pressure of 2005 psi were from annual periodic maintenance work, not injection pressures. Thanks, 6*7arlOi2 C-Terrn(ra Pad 3 Operator 907-659-5533 H# 6143/ 6756 Prudhoe Bay, Alaska 99734 M±�> ASPIC EENER93Y SERVICES #� ;* + w.bWusw a wrear ter Cw»vaAr`rwr. 1 Garney, Hilary (SLR) From: AK, OPS FS2 Pad 3 Sent: Wednesday, January 10, 2018 11:22 AM To: Janowski, Carrie Cc: AK, HSSEE Env Adv Central Subject: Pad 3 NW / SE Well High Annulus Tubing Pressures 01/10/2018 Carrie, Between approximately 10:00 AM and 11:00 AM on 01/10/2018, CH2MHill Instrument Technicians performed Pad 3 Annual Well Pressure Monitoring Periodic Maintenance (PM) work on OWDW NW / OWDW SE Wells. Well high annulus/tubing pressure readings for this time frame resulted from performing PM work, and no injection occurred during PM performance on Pad 3 OWDW NW/SE Wells. Thanks Carrie, Matthew Morris Pad 3 Facility Operator (907)659-5533 Harmony #6757 Alt. Marc McInnis Garney, Hilary (SLR) From: AK, OPS FS2 Pad 3 Sent: Wednesday, January 17, 2018 5:47 AM To: Janowski, Carrie; AK, HSSEE Env Adv Central Cc: AK, OPS FS2 G&I-Pad3 Facilities Supervisor; AK, OPS FS2 Pad 3 Subject: SE well ALL Below Is the original EMAIL I sent back on 01/08/2018 about a SCADA DATA RECORDING on 01/07/2018. It was asked me to send out a little more detail. After looking at the SCADA DATA the actual recorded instrumentation reading was 1406PSIG. This is false. We were not injecting down the well when this reading came in. The actual gauge on the tubing at the well head read 50OPSIG as well as all other tubing gauges. The false reading was caused from a ice plug in the Rosemount gauge tubing the small space rose in pressure as the well house heated up(thermal expansion. Pad 3 operators immediately bleed the little bit off. Last night we seen the SE well tubing pressure spiked to above 120OPSIG a few times. walk downs from the PZ discharge to the well heads were done and all associated gauges show 500PSIG. The problem was a frozen 3/8" instrument tubing at the well head tubing rose mount gauge. Charleton and I bleed off the pressure and we worked on the 3/8" instrument tubing ice plug. All other gauges on the well tubing read 500PSIG. We placed a heater trunk in the well house and thawed the ice plug. All is back to normal. Thank You DARREL SUCH PAD S 65-5538757 One Crew, One Journey Honoring the values of our founders as we develop the future. ABAC ENERGY SERVICED - : _;,` • -bwory e1 ,wwk ale" 11.so Ce.s+r+wn Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main RECEIVED OCT 2 0 2017 AOGCC (907)273-4760fax Delivered to: �'IMakanaK Bender Natural Resources Technician II Alaska Oil & Gas Conservation Commission 333W 7'Ave. Suite 100 Anchorage, AK 99501 2"-" l 2,% f TRANSMITTAL DATE • • ■ TRANSMITTAL # • DATA LOGGED �O /2"11201-1 M.K BENDER Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the -- X '� package have been verified to match the media noted above. The Print Name Signature Date specific content of the CDs and/or hardcopy prints may or may Please send signed transmittal to BP via email or post. not have been verified for correctness or quality level at this gancpdc@bp.com point. BP PDC 1-112-1, 900 E Benson Blvd, Anchorage, AK 99508 SLB Auditor - '�T IJ SCANNED 6' EB 2 8 z SERVICE ORDER SEWCr NAME F -35A __WKLL 50-029-21843-01 DODJ-00046 J& PRUDHOE BAY • WIL • • Thrubit Rev2 �� FINAL FIELD • • 11 -May -17 COLOR -1: 1 1 1-5-12A 50-029-21694-01 DQMD-00012 LISBURNE Memory PPROF FINAL FIELD 11 -Jul -17 1 1 GNI-02A 50-029-22851-01 DUZF-00007 PRUDHOE BAY WL IPROF FINAL FIELD 17 -Jul -17 1 1 OWDW-SE 50-029-21818-00 DODJ-00069 PRUDHOE BAY WL RST FINAL FIELD 2 -Aug -17 1 1 OWDW-NW 50-029-21819-00 DTBP-00025 PRUDHOE BAY WL RST FINAL FIELD 3 -Aug -17 1 1 OWDW-C 50-029-21821-00 DTBP-00026 PRUDHOE BAY WL RST FINAL FIELD 4 -Aug -17 1 1 09-19 50-029-20260-00 DQMD-00013 PRUDHOE BAY Memory SCMT FINAL FIELD 6 -Aug -17 1 1 03-25A 50-029-21021-01 DQMD-00014 PRUDHOE BAY Memory SCMT FINAL FIELD 15 -Aug -17 1 1 11-18 50-029-21607-00 DTBP-00039 PRUDHOE BAY WL LDL FINAL FIELD 5 -Sep -17 1 1 a Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the -- X '� package have been verified to match the media noted above. The Print Name Signature Date specific content of the CDs and/or hardcopy prints may or may Please send signed transmittal to BP via email or post. not have been verified for correctness or quality level at this gancpdc@bp.com point. BP PDC 1-112-1, 900 E Benson Blvd, Anchorage, AK 99508 SLB Auditor - '�T IJ SCANNED 6' EB 2 8 z l0oz4zc Regg, James B (DOA) From: Brooks, Phoebe L (DOA) Sent: Monday, September 11, 2017 1:52 PM To: AK, GWO Projects Well Integrity a Cc: Regg, James B (DOA) Subject: RE: August 2017 MIT Forms for BPXA Attachments: MIT PBU AGI Pad 08-05-17 Revised.xlsx; MIT PBU OWDW-C-NW-SE 08-01-17 Revised.xlsx; MIT PBU AGI -09 08-05-17 Revised.xlsx; MIT PBU NGI-12 08-16-17 Revised.xlsx; MIT PBU WGI-07 08-16-17 Revised.xlsx Attached are revised reports as follows: • MIT PBU AGI Pad 08-05-17 — AGI -01A test data has been combined into one entry as this was one continuous test (the same was done with AGI -04) with additional data being included in the remarks. ✓• MIT PBU OWDW-C-NW-SE 08-01-17 — The name was removed from the AOGCC Rep field (as witness was waived). • MIT PBU AGI -09 08-05-17, MIT PBU NGI-12 08-16-17, & MIT PBU WGI-07 08-16-17 —The packer TVD was changed to match our records. Please review and update your copies or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission SCANNED r-,Ri 92M Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC, is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooksnalaska.gov. From: AK, GWO Projects Well Integrity[ma ilto:AKDCProjectsWelllntegrityEnginee r@bp.comj Sent: Sunday, September 03, 2017 1:49 PM To: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; Regg, James B (DOA) <jim.regg@alaska.gov>; Wallace, Chris D (DOA) <chris.waIlace @alaska.gov>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov> Cc: AK, GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Subject: August 2017 MIT Forms for BPXA All, Attached are the AOGCC MIT forms for test performed by BP in August 2017. Please note the multiple entries for individual wells on AGI pad represent holding the test out for additional time due to thermal stabilization. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 z Well: PTD: Notes: L-e'OWDW-C 1002420 Passed MIT -IA to 1711psi on 8/1/2017 (EPA) OWDW-NW 1002400 Passed MIT -IA to 1697psi on 8/1/2017 (EPA) OWDW-SE 1002390 Passed MIT -IA to 1698psi on 8/1/2017 (EPA) P1 -G1 1921130 Passed MIT -IA to 2861psi on 8/2/2017 AGI -01 2091640 Passed MIT -IA to 2605psi on 8/5/2017 AGI -02 1921200 Passed MIT -IA to 2413psi on 8/5/2017 AGI -03 1921350 Passed MIT -IA to 2490psi on 8/5/2017 AGI -04 1921460 Passed MIT -IA to 2730psi on 8/5/2017 AGI -06 1930090 Passed MIT -IA to 2450psi on 8/5/2017 AGI -09 1930350 Passed MIT -IA to 2468psi on 8/5/2017 03-37 2091390 Passed MIT -IA to 2355psi on 8/15/2017 04-20 1831190 Passed MIT -IA to 2444psi on 8/15/2017 NGI-12 1770810 Passed MIT -IA to 2339psi on 8/16/2017 WG 1-07 1900400 Passed MIT -IA to 2487psi on 8/16/2017 LPC -02 1930250 Passed MIT -IA to 2456psi on 8/18/2017 13-35 1940410 Passed MIT -IA to 2261psi on 8/28/2017 Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 z STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regg(Malaska.gov; AOGCC.Insoectors(cDalaska.gov; ohoebe.brooksoalaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bav / PBU / OWDW 08/01/17 DATE: OPERATOR REP: AOGCC REP: Michael Zimmer chris.wallace0alaska. goy Well OWDW-C Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1002420 - Type Inj W Tubing 26 17 18 16 Type Test P Packer TVD 1917 HBI -Pump 2.1 IA 0 1757 1726 ' 1711 Interval 0 Test psi 1500 BBL Return 0.6 OA I Result P / Notes: EPA test to target pressure of 1500 psi, EPA witness Evan Osborne and Jason Selitsch. AOGCC waived by Guy Cook. OA - N/A Well OWDW-NW Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD 1002400 Type Inj W Tubing 357 353 352 352 Type Test P Packer TVD 1896 BBI -Pump 3.1 IA 55 1765 1715 1697 Interval 0 Test psi 1500 BBL Return 0.5 OA Result P Notes: EPA test to target pressure of 1500 psi, EPA witness Evan Osborne and Jason Selitsch. AOGCC waived by Guy Cook. OA - N/A Well OWOW-SE Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1002390 Type Inj W Tubing 48 49 49 49 Type Test P Packer TVD 1885 BBI -Pump 2.3 IA 0 1750 1715 1698 Interval 0 Test psi 1500 BBL Return 1.4 OA Result P Notes: OA - N/A Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval —i— Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BEL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes W = Water G = Gas S = Slurry I = Industrial Wastewater N = Not Injecting TYPE TEST Codes INTERVAL Codes P = Pressure Test I = Initial Test O = Other (describe in Notes) 4 = Four Year Cycle V = Required by Variance 0 = Other (describe In notes) Form 10-426 (Revised 01/2017) MIT PBU OWOW-C-NW-SE 08-01-17 Revised Result Codes P = Pass F = Fail I = Inconclusive 0 RECEIVEA AUG 3 1.2.017 AOGW August 29, 2017 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 40 BP Exploration (Alaska) lnc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 56 1 -5 111 SC001EV HP 0 5 201?r 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 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. A tubing inspection log in well OWDW-SE was conducted July 28, 2017. The annulus pressure tests, also known as Mechanical Integrity Tests (MIT-IAs) were performed in wells OWDW-SE, OWDW-NW and OWDW-C on August 1, 2017. The fluid movement logging requirement was satisfied with borax -RST logs that were run by service company Schlumberger in well OWDW-SE on August 2, 2017, in OWDW-NW on August 3, 2017 and in OWDW-C on August 4, 2017. There was no indication of a loss of mechanical integrity in any of these activities. EPA representatives Jason Selitsch and Evan Osborne, witnessed the annulus pressure tests and the fluid movement logs. The enclosed descriptive and interpretive report contains the results for the following mechanical integrity test and logs: Tubing Inspection Log on OWDW-SE, July 28, 2017 Mechanical Integrity Tests on OWDW-C,-SE,-NW, August 1, 2017 OWDW Southeast Borax PNL Survey Results, August 2, 2017 OWDW Northwest Borax PNL Survey Results, August 3, 2017 OWDW Center Borax PNL Survey Results, August 4, 2017 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. It BPXA understands thaA EPA will notify BPXA of the acceptabo 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 Carrie Janowski, Intervention & Integrity Specialist at (907) 564-5273. Sincerely, Wendy Bos ns East Area Operating Manager Attachments: Memory Multi -Finger Caliper Log Results Summary OWDW-SE August 2, 2017 OWDW Surveillance Procedure Summary OWDW Southeast Borax PNL Survey Results OWDW Northwest Borax PNL Survey Results OWDW Center Borax PNL Survey Results Mechanical Integrity Test Forms Cc: Letter and report with log copies: Evan Osborne, EPA Region 10 Chris Wallace, AOGCC Jim Regg, AOGCC Marc Bentley, ADEC • froudhoe Bay Unit, EPA Permit: AK-1I004-B OWDW Surveillance Procedure Summary Background EPA permit AK- 1I004 -B effective December 08, 2009 requires an annual fluid movement test, Part II C 3 b (2). The procedure used was very similar 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 pressure 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. In the last 6 month period, daily average injection pressures were: 556 psi for the NW well, 464 psi for the SE well, and 469 psi for the C well. Pumping unit pressures were at or above 1000 psi during the high rate pumping (4.5 -5 barrels per minute) of borax solution. The injection rate was reduced to less than 1 bpm 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 2.0" in the lined 2- 7/8"). The general survey procedure involved the following steps: run baseline temperature pass and baseline RST pass pump 100 barrels hot water at high pump rate run RST baseline pass at minimum pump rate pump 30 barrels hot borax -water solution at high pump rate run RST pass at minimum pump rate pump 30 barrels hot borax -water solution at high pump rate run RST pass at minimum pump rate pump 15 barrels hot water at low rate to flush wellbore run final RST pass, minimum pump rate wait one hour, run optional shut-in temperature pass 1 wait one hour, run optional shut-in temperature pass 2 Carrie Janowski, Intervention & Integrity Specialist August 15, 2017 Page 1 of 1 • • Prudhoe Bay Unit, EPA Permit: AK -1I004 -B OWDW Southeast (Pad -3 SE) Borax-PNL Survey Procedure - On 07/28/17, slick line operations verified access in the SE well to 1983' feet slickline measured depth (slm) / —1991' feet measured depth (MD). - This is near the middle of the perforations and assured sufficient interval was available to perform the survey. - OWDW-SE injected normally during the previous six months. During the last six months, the average injection pressure was 464 psi. Pumping unit pressures during logging were around 1000 psi. Borax-PNL Survey Results - reference OWDW-SE Schlumberger Reservoir Saturation Log, -2- August-2017. The log includes pertinent individual sigma passes. Each sigma pass was run from the fill level to about 1400' 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). • "Baseline pass 1 and baseline 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 at approximately 5 bpm. This overlay indicates areas of increased sigma from that baseline. There is a significant increase in borehole sigma due to the borax solution in the wellbore below the tubing tail. The formation sigma increase seen in the overlay indicates injection is taking place potentially up to 1952'MD. • "Baseline pass 2 and baseline overlay". A second stage of boron laden fluid was pumped prior to running this pass. There is no increase in formation sigma from the previous pass. • "Sigma baseline 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 near baseline levels indicating the boron laden fluid had been flushed from the wellbore and there is no indication of upward movement beyond approximately 1952'MD. The absence of any significant increase in formation sigma after pumping a large amount of boron laden solution indicates there is no evidence of upward movement of injected fluids above the approved injection zone. Page 1 of 2 0 • Prudhoe Bay Unit, EPA Permit: AK -1I004 -B OWDW Southeast (Pad -3 SE) Overall Conclusions There is no indication of fluid movement above the base of the confining zone. 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 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 7/30/2017 indicate the tubing, casing and the exterior part of the well are hydraulically sound. Carrie Janowski, Intervention & Integrity Specialist August 8, 2017 Page 2 of 2 Prudhoe Bay Unit, EPA Permit: AK -1I004 -B OWDW Northwest (Pad -3 NW) Borax-PNL Survey Procedure - On 07/29/17, slick line operations verified access in the NW well to 1972' feet slickline measured depth (slur) / —2021' feet measured depth (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 the last six months, the average injection pressure was 556 psi. Pumping unit pressures during logging were around 1000 psi. Borax-PNL Survey Results — reference OWDW-NW Schlumberger Reservoir Saturation Log, 3 - August -2017. 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 about 1400 feet 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). • "Borax pass 1 and baseline overlay". This overlay shows the change in tool response between a baseline pass and the pass run after pumping the first stage of borax solution at approximately 5 bpm. This overlay indicates areas of increased sigma from that baseline. There is a significant increase in borehole sigma due to the borax solution in the wellbore below the tubing tail. There is no significant increase in formation sigma related to the injected borax indicating the injection is going into the perforations below. • "Borax pass 2 and baseline overlay". A second stage of boron laden fluid was pumped prior to running this pass. There is no significant increase in formation sigma from the previous pass. • "Sigma baseline overlay". This overlay compares the tool response after flushing the boron laden solution from the wellbore with water at low pump rates. The borehole sigma returned to near baseline levels indicating the boron laden fluid had been flushed from the wellbore and there is no indication of upward movement from the perforations. The absence of any significant increase in formation sigma after pumping a large amount of boron laden solution indicates there is no evidence of upward movement of injected fluids above the approved injection zone. Page 1 of 2 • • Prudhoe Bay Unit, EPA Permit: AK -1I004 -B OWDW Northwest (Pad -3 NW) Overall Conclusions There is no indication of fluid movement above the base of the confining zone. 2. Most, if not all, of the fluid pumped during the test was confined near the top of the perforated intervals. 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 07/30/2017 indicate the tubing, casing above the packer and the exterior part of the well are hydraulically sound. Carrie Janowski, Interventions & Integrity Specialist August 8, 2017 Page 2 of 2 • Prudhoe Bay Unit, EPA Permit: AK -1I004 -B OWDW Center (Pad -3 C) Borax-PNL Survey Procedure On 07/29/17, slick line operations verified access in the C well to 2025'slickline measured depth (slm) / — 2057' measured depth ( MD). This is below the perforations and assured sufficient interval was available to perform the survey. While OWDW-C was perforated in February, 2014, it has essentially been used as a back-up well with minimal use over the last six months. During the last six months, the average injection pressure was 469 psi. Pumping unit pressures during logging were around 1000 psi. Borax-PNL Survey Results - reference OWDW-C Schlumberger Reservoir Saturation Log, 4 - August -2017. Note: depths referenced below refer to the reservoir saturations log 9-21-14, which reference Kelly bushing (RKB). The log includes pertinent individual sigma passes. Each sigma pass was run from the fill level to about 1400' 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). • "Borax pass 1 and baseline overlay". 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 approximately 5 bpm. This overlay indicates areas of increased sigma from that baseline. There is a significant increase of borehole sigma due to the borax solution is in the wellbore below the tubing tail. There is no significant increase in formation sigma related to the injected borax indicating the injection is going into the perforations below. • "Borax pass 2 and baseline overlay". A second stage of boron laden fluid was pumped prior to running this pass. There is no significant increase in formation sigma observed from the previous pass. • "Sigma baseline overlay". This overlay shows the tool response after flushing the boron laden solution from the wellbore at low pump rates. The borehole sigma returned to near baseline levels indicating the boron laden fluid had been flushed from the wellbore and there is no indication of upward movement beyond approximately 1978'MD. The absence of any significant increase in formation sigma after pumping a large amount of boron laden solution indicates there is no evidence of upward movement of injected fluids above the approved injection zone. Page 1 of 2 • Prudhoe Ba Unit EPA Perm' Y � it. AK -1I004 -B OWDW Center (Pad -3 C) Overall Conclusions There is no indication of fluid movement above the base of the confining zone. 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 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 07/30/17 indicate the tubing, casing and the exterior part of the well are hydraulically sound. Carrie Janowski, Intervention and Integrity Specialist August 8, 2017 Page 2 of 2 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 August 1, 2017. 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: 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 -1 I004 -B, Part II, C 3 b (1). Annulus pressures were observed on a recording digital test gauge. During each test period, the tubing pressure was essentially constant. The pressure decline observed in these wells may be the result of shrinkage due to cooling of the well fluids during the test. The testing was witnessed by EPA representatives Jason Selitsch and Evan Osborne. I conclude from the successful MIT's that the casing, tubing and packer in the SE, NW and C 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. Carrie Janowski August 8, 2017 Tubing Pressure Annulus Pressure psi 1st Half 2nd Half Test Pad 3 Well Start / End Start 15 Min 30 Min Decline Decline Result Center 18/16 1757 1726 1711 31 15 Passed Northwest 353/352 1765 1715 1697 50 18 Passed Southeast 48/49 1748 1587 1543 161 44 Failed Southeast 49/49 1750 1715 1698 35 17 Passed 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 -1 I004 -B, Part II, C 3 b (1). Annulus pressures were observed on a recording digital test gauge. During each test period, the tubing pressure was essentially constant. The pressure decline observed in these wells may be the result of shrinkage due to cooling of the well fluids during the test. The testing was witnessed by EPA representatives Jason Selitsch and Evan Osborne. I conclude from the successful MIT's that the casing, tubing and packer in the SE, NW and C 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. Carrie Janowski August 8, 2017 CERTIFIED MAIL # 7016 0910 0001 1040 7001 April 13, 2017 Mr. Edward J. Kowalski Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501-3192 Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 APR 13 2017 ,rs,, GCC BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 USA NED APR 2 0 2017 RF: Mechanical Integrity Test Notifications Pad 3 Infection Wells UIC Permit AK -1 1004-B, Wastewater DisposaL Permit No. 201 0DB0001 -0021 Grind and Infect Iniection Wells UIC Permit AK -1 1008-A, Area Iniection Order No, 4G General Wastewater Permit No. 2010DB001-0012 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notification of well surveillance activities to satisfy demonstration of mechanical integrity requirements for the Class 1 UIC permits mentioned above: 1) SAPT (Standard Annulus Pressure Test) 2) Fluid movement tests 3) Tubing inspection logs. 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. Evan Osborne 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. Mechanical Integrity Te*tification • April 13, 2017 Page 2 A summary of the proposed annual testing is presented in the attached table. If you have any questions, please contact me at (907) 564-4613 or tom.harvey@bp.com Sincerely, Thomas J Harvey, CHMM Regulatory and Permitting Advisor-Waste/UIC Attachment cc: Evan Osborne, EPA Region 10 Mechanical Integrity Te-40tification April 13, 2017 Page 3 Certification Statement Mechanical Integrity Test Notification 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. Respo ibl Company Official Wendy Bosmans Printed Name 0 I r �- Date East Area Operations Manager BP Exploration Alaska) Inc. Title Company Mechanical Integrity Te*tification April 13, 2017 Page 4 bcc (hard copy, with enclosure): Pad 3 File [1007.01.26] Grind & Inject File [1007.02.01 bcc (electronic, enclosure): Carrie Janowski AK, HSSEE Env Adv Central Proposed Schedule for 2017 Demonstration of Mechanical Integrity Activities Class I UIC Wells Class I Well (s) Activity Next Deadline /Requirement 2017 Proposed test date Notes Pad 3 — Caliper 8/24/18 7/27/17 OWDW-NW & C OWDW-NW, C OWDW-SE (every 2 years) wells have lined and SE Wells tubing Borax -RST 8/31/18 OWDW-SE 7/31/17 Order which wells logging (every 2 years) OWDW-NW 8/1/17 are tested could OWDW-C 8/2/17 change SAPT 8/30/17 8/3/17 Plan to test (Standard (annually, 3 month OWDW-NW, -C, & - annulus grace period at Director SE wells on same pressure discretion) day testing) BP calls MITIA Grind & Inject Tag fill & 2017 GNI-02A 6/3/17 Order which wells — GNI-02A, - temperature (each calendar year) GNI-03 6/16/17 are tested could 03, and -04 survey GNI-04 6/28/17 change. Tag fill, memory temperature / pressure logs and Caliper will be run Caliper 2017 GNI-02A 6/3-6/4/17 on same Slickline (annually, no monthly GNI-03 6/16-6/17/17 rig up if possible. requirement) GNI-04 6/28-6/29/17 SAPT 8/29/17 7/28/17 Plan to test GNI- (Standard (required annually, one 02A, -03, -04 wells annulus month grace period) on same day pressure testing) BP calls MITIA Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main NOV 0 4 2015 (9(17)273-4760 fax 0GC,C Delivered to: Makana K Bender -% Natural Resources Technician II Alaska Oil & Gas Conservation Commission 333 W. 711% Ave. Suite 100 Anchorage, AK 99501 X00 -2-q2. 2-:1 G C� 5 DATA LOGGED K. BENDER WELL NAME API # ORDERSERVICE # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATELOGGED PRINTS CID OWDW-SE 50-029-21818-00 DMKL-00245 PRUDHOE BAY WL RST REV1 FINAL FIELD 31 -Aug -16 1 1 OWDW-C 50-029-21821-00 DNHF-00006 PRUDHOE BAY WL RST REV1 FINAL FIELD 1 -Sep -16 1 1 OWDW-NW 50-029-21819-00 DNHF-00007 PRUDHOE BAY WL RST REV1 FINAL FIELD 2 -Sep -16 1 1 B-18 50-029-20702-00 D4AQ-00110 PRUDHOE BAY WL Pulsed Neutron eXtreme FINAL FIELD 10 -Oct -16 1 1 16-17A 50-029-21441-01 DM29-00022 PRUDHOE BAY Memory PPROF FINAL FIELD 13 -Oct -16 1 1 B-06 50-029-20279-00 DOP9-00001 PRUDHOE BAY WL Pulsed Neutron eXtreme FINAL FIELD 21 -Sep -16 1 1 17-20 50-029-22300-00 CQ1G-00083 PRUDHOE BAY WL LDL FINAL FIELD 1 -Apr -16 1 1 04-43 50-029-22443-00 DNHF-00008 PRUDHOE BAY WL RST-WFL FINAL FIELD 24 -Sep -16 1 1 J-29 50-029-23486-00 DNHF-00012 PRUDHOE BAY WL Pulsed Neutron eXtreme FINAL FIELD 1 -Oct -16 1 1 09-34A 50-029-21329-01 DK26-00045 PRUDHOE BAY Memory CBL-SCMT FINAL FIELD 6 -Oct -16 1 1 Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The Print Name Sig ature Date specific content of the CDs and/or hardcopy prints may or may Please send signed transmittal to BP via email or post. not have been verified for correctness or quality level at this gancpdc@bp.com point. BP PDC LR2-1, 900 E Benson Blvd, Anchorage, AK 99508 SLB Auditor - J k► SCANNED DEC 0 12016 • 0 0 Certified Mail # 70151520 0000 9081 5819 October 26, 2016 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 ()0-- . [Z REMEIVED by OCT 3 12016 AOG(;C BP Exploration (Alaska) Inc. P.O. Box 196612 900 E Benson Boulevard Anchorage, AK 99519-6612 USA RE; Third Quarter 2016 — Pad 3 Injection Well Monitoring Report UIC Class I Permit AK —11004-B Dear UIC Manager: This report is being submitted to fulfill the third quarter 2016 (July - September) reporting obligations for the above referenced permit. Enclosed are two 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 were no permit exceedences of the 1400 psig injection pressure limitation or 150 psig annulus pressure limitation on the Class I wells during this calibration. Data anomalies occurred on August 30, 2016, see attached email for descriptions of this event. 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. If you need any clarification or additional information concerning these reports, please contact me at (907) 564-4267 or Tom.Barrett@bp.com. Sincerely, Tom Barrett Environmental Team Lead Attachments cc: Evan Osborne, EPA SCANNED APR 3 0 2013 Chris Wallace, AOGCC Marc Bentley, ADEC UIC Manager October 26, 2016 Page 2 Certification Statement Third Quarter 2016 — Pad 3 Injection Well Monitoring Report 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. "M t4w"+ — e ponsible C m an Oficial p Y Kurt Horst Printed Name ZS-ocr II% Date Onshore Site Manager BP Exploration (Alaska) Inc.. Title Company UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT Year 2016 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum July August September 176 166 163 188 176 243 488 557 276 Injection Rate (Gal/111111n) 1. Minimum 2. Average 3. Maximum 0 0 0 0 0 0 0 0 0 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 58 9 70 60 61 79 68 80 107 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 0 0 0 0 0 0 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) 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 C Well ADEC2otsommi EPA Well Permit No. AK -110048 Name and Official Title Kurt Horst Onshore Site Manager ES2 Signature I I�-V-t/,V�1 Date Signed LgrocT Ib EPA Form 752" (2-94) 'The values provided darhe the non - hazardous range and are not measured values. See Waste Analysis Plan. Values in parentheses ( ) ars actual values for permit compliance 1- Ww"i 'The values Provided donne the non - hs=rftn range end aro not inessund values . ase Wnw Analysla ftn . Values in Psis ( ) we actual values for permit compliarros UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT Ypr 2016 MONTH MONTH MONTH Injection Pressure (P31) 1. Minimum 2. Average 3. Maximum Ju 73 16 5 617 609 431 987 1,011 1,005 injection Rale (Gal/Min) 1. Minimum 2. Average 3. Maximum 80 0 0 97 82 44 146 139 132 Annular Prseeum (Psi) 1. Minimum 2. Average 3. Maximum 37 0 0 43 45 59 57 58 108 Injection Volume (Gal) 1. Monthly Total 2. Yowly Cumulative 2,109.257 2174 319 818.080 14,500,714 16,675.033 17,493.113 Temperaturs (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. Mordhy Average Injection Volume (Gallons/Day) 2. Maximum Daily Injection Volume Gallo 68,040 70,140 27.271 128.188 129.507 79,435 _ None and Address of Psneigee Permit Number BP EXPLORATION (ALASKA, INC.) NW Well 900 E. BENSON BLVD. ADEC20ioDs i P.O. BOX 196612 EPA Well Permit No. ANCHORAGE , AK . 99519 - 6612 line Name and OAIchd Title Kurt Horst Onshore Site Manager FS2 Signature Dab 34*d 1- Ww"i 'The values Provided donne the non - hs=rftn range end aro not inessund values . ase Wnw Analysla ftn . Values in Psis ( ) we actual values for permit compliarros UNITED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, D.C. 20460 EPA INJECTION WELL MONITORING REPORT Year 2016 MONTH MONTH MONTH Injection Pressure (PSI) 1. Minimum 2. Avers" 3. Maximum July August r 320 0 198 649 626 638 1,079 1,336 1,217 Ir4actlon Rate (GNtMin) 1. Minimum 2. Average 3. Maximum 61 0 0 97 84 46 140 139 140 Annular Pressure (PSI) 1. Minimum 2. Averege 3. Maximum 36 0 15 44 41 27 70 72 92 Injection Volume (Gal) 1. Monthly Total 2. Yqarly Cumulative 2,467,731 2,062,276 1,933,697 10,352,954 12,415,230 14,348,926 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 Gallony 79,503 66,524 18,564 161,641 116,424 104.580 Name and Address of Permittee BP EXPLORATION (ALASKA, INC.) 900 E. BENSON BLVD. P.O. BOX 196612 ANCHORAGE, AK. 99519-0812 Permit Number SE Well ADEC2oteoeoom EPA Well Permit No. AK -11004B Name and Ofllelal Title Kurt Horst Onshore Site Manager FS2 Signature 4 Date Signed `LV(T� I VD crwrurm ra[u-e 14-041 The values provided define the norrhmrdous range and ore not measured values. Sae Waste Analp" plan. The values in po wale la ( ) an actual values for oompuenm purposes, • PAD3 - Class I Inject Composition Summary 7/1/2016 to 913012016 By Exemption, By Component • by North Slope Technical Services Equipment Services Group 0 Component Cubic yards Barrels Exempt BOILERBLOWDOWN 77.00 CEMENTCONTAMINATE 2,522-19 CRUDEOIL 5,728.89 CUTTINGS 75.50 DIESEL 11001.15 DIESELWATERGEL 53691 DRILLINGMUD 23,711.36 FRACSAND 14.50 FRESHWATER 58,116.43 GLYCOL 131 60 METHANOL 88485 NRDC 2.90 WATER (Fresh or Seewater) 98.60 WELL CELLAR FLUIDS 5,677.00 SNOWMELT OR RAINWATER 60,602 21 WELL RETURNS 70.00 FREEZE PROTECTION FLUID 23200 PURGE WATER (See SOURCE 3.00 WASH BAY FLUIDS 580.00 DRILLING MUD 70.20 GLYCOL 1,00 PRODUCTION FACILITY FLUII 1060 SNOW / ICE 56.00 TURBINE WASH WATER 3.00 ASH 103.80 OIL, HYDRAULIC OR LUBRIC/ 10.00 SPILL CLEANUP WASTE 3,267,00 WELL CASING FILINGS/CUTT 5.00 BLEED TRAILER FLUIDS 17.00 Printed on Thursday, C Page 1 of 3 0 • SNOW Component Cubic yards Barrels PRODUCED WATER 27.00 5.00 RINSATE (RINSE FLUIDS) GLYCOL 18,008.80 SOAP (Non -hazardous detergei 5.80 32.75 SUMP WASTES WASH BAY FLUIDS 8,473.00 TANKNESSEL SOLIDS 29000 40600 BIOCIDE/ORILLING MUD MIXT PIGGING SOLIDS 120 MINERAL OIL 3.00 22140 Other WELL CELLAR FLUIDS 4.60 METHANOL AND METHANOL/ 3,700.00 339.30 PIGGING SOLIDS 1,845.05 PRODUCEDWATER 7,962.98 RESERVEFLARERELIEFPITW 1,852.80 SEAWATERSRINEKCI 31,540.94 SCALECORROSIONINHIBiTOI 80.45 SOURCEWATER 2940 ACID 10.00 Total Exempt Volume 234,204.36 Non -Exempt, Non -Hazardous Waste Stream CEMENTCONTAMINATE 348.90 SNOW 52.20 DOMES71CWATER 2,00 DRILLINGMUD 27.00 FRESHWATER 8,015.94 GLYCOL 36.80 GRAVELSAND 5.80 METHANOL 2.30 WASH BAY FLUIDS 36900 WATER (Fresh or Seawater) 29000 CHEMICALS AND REAGENTS 15.00 PIGGING SOLIDS 145.00 SPILL CLEANUP WASTE 3.00 SUMP WASTES 2,900.00 WELL CELLAR FLUIDS 20.00 GLYCOL 3,700.00 Printed on Thursday, C Page 2 of 3 Component Cubic yards Barrels SNOWMELT OR RAINWATER 6,527,00 SOAP (Non -hazardous daterpe 5.41 CORROSION INHIBITOR 3.24 METHANOL AND METHANOL/ 1.02 RINSATE (RINSE FLUIDS) 1,953,00 MINERAL OIL 1 00 SEAWATERBRINEKCI 1,060.79 DIESEL 8.00 Total Mon-ExemPt, Non-Hazarr 257,686.76 Total Volume: Printed on Thursday, C 267,696.76 Page 3 of 3 Pad 3 Monthly Manifest & Data Review Monthly Manifest & Data Review Period: 3Q 2016 Reviewed By. David Dawley & Aaron Assmann Date: 10/9/16 Were wastes manifested accurately? Were wastes approved for disposal by appropriate Were lab results reviewed? Comments: No UIC compliance issues noted. Some minor NS manifest completion issues Yes/No Initial/Date Yes DMD Yes DMD • Yes DMD 120000 80000 7, 60000 w in M Total Well Volumes b�r bib bnb bib ' ° +pro b+r� fl"*b bNCO ©NCO bNCO bNCO bNCO ©NCO b„ CO b�6 .�\NO \\'t\�T �\"a\� � �\�' �,��\�'�\,��\` t\`�` �,�A\`f, q\`Z Al":\ \",�\`� \fit\`� \�.� \T41 \b�K A 1 � A 1 Days • 1600 1400 1200 1000 'ro 800 CL 600 400 200 0 Days Maximum Injection Pressure Well —SE Well C Well ---Limit • 0 160 140 120 100 Irs IL so 60 40 20 X Maximum Annular Pressure 4b ��,;o �Z;,fo ,,ro fiaNib ro Nb ro N No 41, Days 0 120,000 60,000 40,000 20,000 L11 Total Well Volumes N1b Nb N1 b N�> Nb ,b N\rp 4rp 4p\rim 4p 4P Days —Total Volume Injected' (NW, C and SE) 0 • 2500 2000 1500 'n a 1000 500 0 ey4 �C3 O O 4 q Q 4 4 © O O O Cs Q d 4 "40 4 Days Maximum Injection Pressure 1 --NW Well —SE Well C Well Limit 0 250 200 150 a fL 100 0 q�q q�q q�q q�q q�q q`q q"q q"q qti�° q,�to q'��O gtity q�q q�q q�q gtiq q\�``l. q��ti $\��• $�1`1` �1g1� �'��\(1` �"*'��• �'��t1' �++'��r`►' ,�q\`�• ��,�1`�' ��`��`�, �}c��`� ry��`y �yg\`�' 3"��`�• Eb Ra 45 q q 4a q q� 4�t Rai 4� Maximum Annular Pressure Days =-NW Well SE Well --C Well Limit E 70000 60000 50000 a 40000 m L W m 30000 20000 10000 0 Total Well Volumes �,,0 Cjn,b QACo O,6 Oar Nb ©Nb �Nro Nb �� pNCO QNB p qNb Q, b ONo C 4 Days Total Volume Injected (NW, C and SE) Pad 3 0 • 1600 1400 1200 1000 800 600 400 200 0 Maximum Injection Pressure O;"O &�O &�O ro &CO e Nb Nb Nb NCO Nb 541, 411CP , 03 Cp Cb\N CP C;\v CP CP 41 Days Well SE Well ,—C Well —Limit L_ E 0 160 140 120 100 8 CL 0 60 40 20 0 Maximum Annular Pressure r OrbNb NCO Nz N�b ro ro 0 �lti 4\ qP 4hl 4ti CA CP CiP Cb\T Days ==-ffw-- Well —SE Well —C Well =—Limit 0 0 Salter, Dane (ORION ENGINEERING) From: AK, L&I Utilities PAD 3 Sent: Friday, October 14, 2016 12:09 PM To: AK, HSSEE Env Adv Central Cc: Janowski, Carrie Subject: High Annulus/Tubing Pressure 08/30/2016 Pad 3 OWDW NW Well Attachments: Pad 3 Daily Report 08_30_2016.pdf Follow Up Flag: Follow up Flag Status: Flagged Trey, While preparing the Pad 3 OWIF 3`d Quarter Injection Report, a high annulus/tubing pressure was discovered for OWDW NW Well on 08/30/2016. The SCADA report shows an annulus pressure reading of 205 psi, and a tubing pressure reading of 2002 psi for 08/30/2016. As Pad 3 was shut down for MIT / Well Surveillance and no fluid was injected, I think that we can attribute these readings to aforementioned well work. I am attaching a copy of the Pad 3 Daily Report which reflects MIT/Well Surveillance operations in the Operator Notes, and that no fluid was received or injected at Pad 3 OWIF on 08/30/2016. Thanks for your help with this, Matthew Morris Pad 3 Facility Operator (907)659-5533 Harmony #6757 Alt. Marc McInnis Operator Tools Page 1 of 1 Date 00/30/2016 -_�; I Generate Report Main Report Daily Report : 08/30/2016 Pad3 Plant Daily Activities Plant Foreman Day: JAY RUTLEDGE Plant Foremen Night MARC MCINNIS Total Injection: 0 Facility Received: 0 Down Well Wall Barrels YTD 0WOW-SE 0 297153 OMW-NW 0 395695 OWDW-C 0 0 OWDW-SW o D TIO Pressure Readings Tuesday, 1:27 Handover Acknovdodged by incoming Operator, 9ennalley. Ivan 8P1M3E123Y Well Reading Well Data Slat Temp TBG IA OA Pilot Pilot Safety UA Engineering Notes Comments Tuesday, 610 Reuttna Ort -Pad P,pag and daily HSE to tons perfarmeo too cork ds:ereparces SP10AV176 Stat Type Sys OK Stat OWE) 0 0 0 0 O DW OWD WSW 0 0 0 0 N EPA clss 1 permit found Continua the shut in for MIT Tuesday 71 ikt Hltndnvnr Arknowledged by mrommg Oparalor McInnis, Marc Suspended P&A Tuesday. 21 05 Routine OmPod Ptpmg and ds =:y H$' ,nspeuwng petfun ted Ivo nuN d.,34jopor; es found F4€Ary SuM OuAri "pr Mt 1'g Senlumtlarar wt;l tha 8P11MCINMA s0ning ,rp nrl SE well aner nudnnJhl tot MITiA wt EPA Q 0700 'Alockod On COW aauvng and VTA waahoad cut tie Own W -NW 0 0 0 0 O DW Field Log Book Tuesday, 1:27 Handover Acknovdodged by incoming Operator, 9ennalley. Ivan 8P1M3E123Y Tuesday, 0 05 1landovat ALkiuwivdyuU by iinuuting Opetalur . Dews, Mlkel SPIWAVUd Tuesday, 606 Handover Acknowledged by Incoming Operator Davis Mkel 13PI1DAV476 Tuesday, 610 Reuttna Ort -Pad P,pag and daily HSE to tons perfarmeo too cork ds:ereparces SP10AV176 lamd POC44y pan aria !woos. are good are snug ddwn fes tAjf`A fW 3 days. Jay and i oo mg our Facitzty today and gOn 99 0`0 043W sea lot smrcdss mon we came tack an Tuesday, 6.13 Handover Ackrowledged by Inmmmg Operator Rutledge Jay (ASRC) BPIIRUTLJ3 Tuesday, 6 14 Routine On -Pao Piping and daily HSE inspections performed No new dtscreparlaas 13PitRUTLJ3 found Continua the shut in for MIT Tuesday 71 ikt Hltndnvnr Arknowledged by mrommg Oparalor McInnis, Marc SPIWCINMA Tuesday. 21 05 Routine OmPod Ptpmg and ds =:y H$' ,nspeuwng petfun ted Ivo nuN d.,34jopor; es found F4€Ary SuM OuAri "pr Mt 1'g Senlumtlarar wt;l tha 8P11MCINMA s0ning ,rp nrl SE well aner nudnnJhl tot MITiA wt EPA Q 0700 'Alockod On COW aauvng and VTA Generated 1011412016 Page 1 of 1 http://operatortools.bpweb.bp.com/WDF/Reports/Pad3Report.aspx 10/14/2016 id o ... 2q Z RELIVED SEP 29 2016 AOGCC BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard Certified Mail: 7016 0750 0000 4951 8847 Anchorage, AK 99519-6612 USA September 23, 2016 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 SCANNED APR 3 0 2018 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 Il, 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. A tubing inspection log in well OWDW-SE was conducted August 24, 2016. The annulus pressure tests, also known as Mechanical Integrity Tests (MITs) were performed in wells OWDW-SE, OWDW-NW and OWDW-C on August 30, 2016. The fluid movement logging requirement was satisfied with borax -RST logs that were run by service company Schlumberger in well OWDW-SE on August 31, 2016, in OWDW-C on September 1, 2016 and in OWDW-NW on September 2, 2016. There was no indication of a loss of mechanical integrity in any of these activities. EPA representatives Jason Selitsch and Tim Mayers, witnessed the annulus pressure tests and the fluid movement logs. Detailed information regarding the results of the tubing inspection log, the MITs and the borax -RST logs are contained in the attachments. They include descriptive and interpretive analyses along with copies of the following: Tubing Inspection Log on OWDW-SE, August 24, 2016 Mechanical Integrity Tests on OWDW-C,-SE,-NW, August 30, 2016 OWDW Southeast Borax PNL Survey Results, August 31, 2016 OWDW Center Borax PNL Survey Results, September 1, 2016 OWDW Northeast Borax PNL Survey Results, September 2, 2016 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 thewill notify BPXA of the acceptabilitye mechanical integrity demonstration withis days of receipt of the results of the anical 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 Carrie Janowski, Intervention & Integrity Specialist at (907) 564-5273. Sincerely, Chris Fortenberry East Area Engineering Team Lead Attachments: Memory Multi -Finger Caliper Log Results Summary OWDW-SE August 24, 2016 Mechanical Integrity Test Results Mechanical Integrity Test Forms OWDW Surveillance Procedure Summary OWDW Southeast Borax PNL Survey Results OWDW Northwest Borax PNL Survey Results OWDW Center Borax PNL Survey Results Enclosures: 2 copies each of the following Schlumberger logs: - OWDW-SE Schlumberger Reservoir Saturation Log, August 31, 2016 - OWDW-NW Schlumberger Reservoir Saturation Log, September 2, 2016 - OWDW-C Schlumberger Reservoir Saturation Log, September 1, 2016 - OWDW-SE Multi -Finger Caliper Log August 24, 2016 Cc: Letter and report with log copies: Evan Osborne, EPA Region 10 Chris Wallace, AOGCC Jim Regg, AOGCC Marc Bentley, ADEC Prue Bay Unit, EPA Permit: AK -1100 O W Surveillance Procedure Summary Background EPA permit AK- 11004-B effective December 08, 2009 requires an annual fluid movement test, Part II C 3 b (2). The procedure used was very similar 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 -1I004 -B requires a fluid movement test "... be conducted at an injection pressure 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. - In that 6 month period, daily average and maximum daily injection pressures did not exceed 572 and 1121 psi respectively for the NW well, 504 and 1050 psi respectively for the SE well, and there was no injection into the Center well since logging in 2015. Pumping unit pressures were at or above 1000 psi during the high rate pumping (4.5 -5 barrels per minute) of borax solution. - The injection rate was reduced to less than 1 bpm 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 2.0" in the lined 2- 7/8"). - The general survey procedure involved the following steps: run baseline temperature and first baseline RST pass pump 100 barrels hot water at high pump rate run second RST baseline pass at minimum pump rate pump 30 barrels hot borax -water solution at high pump rate run RST pass at minimum pump rate pump 30 barrels hot borax -water solution at high pump rate run RST pass at minimum pump rate pump 15 barrels hot water at low rate to flush wellbore run final RST pass, minimum pump rate wait one hour, run shut-in temperature pass 1 wait one hour, run shut-in temperature pass 2 Carrie Janowski, Intervention & Integrity Specialist September 12, 2016 Page 1 of 1 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 August 30, 2016. 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: Tubing Pressure Pad 3 Well Start / End Southeast 443/442 Northwest Center 517/517 152/171 Annulus Pressure psi 1 st Half 2nd Half Test Start 15 Min 30 Min Decline Decline Result 1671 1555 1523 116 22 Passed 1673 1533 1508 140 25 Passed 1725 1595 1573 130 22 Passed 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 -1 I004-13, Part II, C 3 b (1). Annulus pressures were observed on a recording digital test gauge. During each test period, the tubing pressure was essentially constant. The pressure decline observed in these wells may be the result of shrinkage due to cooling of the well fluids during the test. The testing was witnessed by EPA representatives Jason Selitsch and Tim Mayers. I conclude from the successful MIT's that the casing, tubing and packer in the SE, NW and C 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. Carrie Janowski September 6, 2016 Prue Bay Unit, EPA Permit: AK -1I000 OWDW Center (Pad -3 C) Borax-PNL Survey Procedure - On 08/24/16, slick line operations verified access in the C well to 2065 feet MD. This is well below the perforations and assured sufficient interval was available to perform the survey. While OWDW-C was perforated in February, 2014, there has only been 4 days of disposal injection in the well to date. There was no injection into this well since the last Borax-PNL Survey on 9-19-15. To be consistent with the previous logging, the pumping unit pressures during logging were above 1000 psi. Borax-PNL Survey Results - reference OWDW-C Schlumberger Reservoir Saturation Log, 1 - September -2016. The log includes pertinent individual sigma passes. Each sigma pass was run from the fill level to about 1400' 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 baseline overlay" A baseline sigma was run prior to pumping any fluid with methanol -water in the well. A second baseline sigma pass was run after pumping about 110 barrels of hot KCL water. The two baseline passes were overlayed to show the statistical variation in the formation sigma of up to 3 capture units. One of the baseline passes was used for comparison to subsequent passes. - "Borax pass 1 and baseline overlay". 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 approximately 5 bpm. This overlay indicates areas of increased sigma from that baseline. There is a significant increase of borehole sigma due to the borax solution is in the wellbore below the tubing tail. The largest formation sigma increase seen in the overlay was approximately 6 capture units around 2000'MD. - "Borax pass 2 and baseline overlay". A second stage of boron laden fluid was pumped prior to running this pass. There was an increase in formation sigma of up to about 11 capture units in the same area as the previous pass, and an indication of borax as high as 1994'MD. - "KCL flush and baseline overlay". This overlay shows the tool response after flushing the boron laden solution from the wellbore at low pump rates. The borehole sigma returned to near baseline levels. There is an indication of borax up to 1988'MD. - "Pressure Temperature Baseline Down at 60 fpm". The baseline temperature pass was run after the well had been shut in for an excess of 12 hours to provide a basis for comparison with temperature log after borax solution was flushed from the wellbore. The post pumping temperature passes confirm the effects of injection are seen as high as 1988'MD. The absence of any significant increase in formation sigma after pumping a large amount of boron laden solution indicates there is no evidence of upward movement of injected fluids above the approved injection zone. Page 1 of 2 Pr4e Bay Unit, EPA Permit: AK -1I000 OWDW Center (Pad -3 C) Overall Conclusions 1. There is no indication of fluid movement above the base of the confining zone. 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 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 08/30/16 indicate the tubing, casing and the exterior part of the well are hydraulically sound. Carrie Janowski, Intervention and Integrity Specialist September 12, 2016 Page 2 of 2 United States Environmental Protection Agency Region 10 'w 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well I Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-Center 1002420 Injector MIT Type Test Type Test Date Class 1 T X IA Std. Annular Pressure Test (SAPT) 30 -Aug -16 Req'd Test Fluid Type(s) used to Packer Depth: Test Interval /Comments Presssure (psi) test MD / TVD 1,500 Diesel 1900.79 TVD I 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 START TIME: RECORDED PRESSURES (PSI) RESULT E 11:25 AM PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN S TUBING 120 152 170 171 PASS T INNER ANNULUS OUTER ANNULUS 0 1,725 1,595 1,573 N/A N/A N/A N/A 1 LOSS 130 22 COMMENTS: Well SI since earl • august 2016. 2.5bbl Ambient Diesel req. to PSI up annulus (401) T E S T START TIME: RECORDED PRESSURES (PSI) PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ FAIL TUBING INNER ANNULUS OUTER ANNULUS 2 LOSS COMMENTS: G A Manufacturer Type Calibration Date U TUBING Nvision Digital, 0-10k 7/3/2016 G INNER ANNULUS Nvision Digital, 0-10k 7/3/2016 E OUTER ANNULUS S OTHER COMMENTS: Dual input gauge, Well does not have an OA OTHER COMMENTS: Criteria 1 = 8.81% Criteria 2 = 14.47% NOTE: Pressure must shop+ stabilizing tendency: Criteria 1) Total loss must be less than 10%at the end of a 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on-site decision per Inspector). Evan Osborne 206-553-1747 osbome.evan@epa.gov Tim Mayers 907-271-34I0 mayers.timothy@epa.gov son Selitsch 907-317-4774 j.selitsch@.denalienvironmental.us EPA Rep:, AOGCC Rep: Operator Rep: T. Mayers / J. eli6;/i_' Waived; Guy Cook Josh Murphy Pruo Bay Unit, EPA Permit: AK -1I000 OWDW Northwest (Pad -3 NW) Borax-PNL Survey Procedure - On 08/25/16 slick line operations verified access in the NW well to 2020 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 this injection period, average and maximum daily injection pressures were 572 psi and 1121 psi respectively. Pumping unit pressures during the logging were at or above 1000 psi. Borax-PNL Survey Results — reference OWDW-NW Schlumberger Reservoir Saturation Log, 2 - September -2016. 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 about 1400 feet 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 baseline overlay". A baseline sigma was run prior to pumping any fluid with methanol -water in the well. A second baseline sigma pass was run after pumping about 100 barrels of hot KCL water. The two baseline passes were overlayed to show the statistical variation in the formation sigma of up to 3 capture units. One of the baseline passes was used for comparison to subsequent passes. "Borax pass 1 and baseline overlay". This overlay shows the change in tool response between a baseline pass and the pass run after pumping the first stage of borax solution at approximately 5 bpm. This overlay indicates areas of increased sigma from that baseline. There is a significant increase in borehole sigma due to the borax solution in the wellbore below the tubing tail. There was no significant increase in formation sigma related to the borax that was injected into the perforations below. - "Borax pass 2 and baseline overlay". A second stage of boron laden fluid was pumped prior to running this pass. There is no increase in formation sigma from the previous pass. - "KCL flush and baseline 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 near baseline levels indicating the boron laden fluid had been flushed from the wellbore and there is no indication of upward movement. - "Pressure Temperature Baseline Down at 60 fpm". The baseline temperature pass was run after the well had been shut in for an excess of 12 hours to provide a basis for comparison with temperature log after borax solution was flushed from the wellbore. The post pumping temperature passes confirm the conclusions above. The absence of any significant increase in formation sigma after pumping a large amount of boron laden solution indicates there is no evidence of upward movement of injected fluids above the approved injection zone. Page 1 of 2 Pru4wBay Unit, EPA Permit: AK -1I000 OWDW Northwest (Pad -3 NW) Overall Conclusions 1. There is no indication of fluid movement above the base of the confining zone. 2. Most, if not all, of the fluid pumped during the test was confined near the top of the perforated intervals. 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 08/30/16 indicate the tubing, casing above the packer and the exterior part of the well are hydraulically sound. Carrie Janowski, Interventions & Integrity Specialist September 14, 2016 Page 2 of 2 United States Environmental Protection Agency Region 10 ` 1200 Sixth Avenue, Suite 900 - Seattle, WA 98101 MECHANICAL INTEGRITY TEST (MIT) FORM Facility I Well Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-NW AK- 11004-A 1002400 Injector MIT Type Test Type I Test Date Class 1 T X IA Std. Annular Pressure Test (SAPT) 30 -Aug -16 Req'd Test Presssure (psi) Fluid Type(s) used to test Packer Depth: MD / TVD Test Interval / Comments 1,500 Diesel 1896 TVD 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 START TIME: RECORDED PRESSURES `MI) RESULT E S T 9:31 AM PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN TUBING 517 517 517 517 PASS INNER ANNULUS VAC 1,673 1,533 1,508 OUTER ANNULUS N/A N/A N/A 1 LOSS 140 25 COMMENTS: Well SI since august 27 2016.2.5bbl Ambient Diesel req. to PSI up annulus (40'f) T E 5 T START TIME: RECORDED PRESSURES (PSI) PRE MIT I INITIAL -T 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ FAIL TUBING INNER ANNULUS 2 OUTER ANNULUS LOSS COMMENTS: G A U G E Manufacturer Type Calibration Date TUBING Nvision Digital, 0-10k 12/23/2015 INNER ANNULUS Nvision Digtta( 0-10k 12/23/2015 OUTER ANNULUS S OTHER COMMENTS: IDual input gauge, Well does not have an OA OTHER COMMENTS: Well has performed similarly in 2014 & 2015 Criteria 1 = 9.86% Criteria 2 = 15.15% iNu i r;: rressure must snow stabilizing tendency: Criteria 1) Total loss must be less than le%at the end of a 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on-site decision per Inspector). Evan Osborne 206-553-1747 osbome.evan@epa.gov Tim Mayers 907-271-3410 mayers.timothy@epa.gov Jason Selitsch 907-317-4774 j.selitsch@denalienvironmental.us t EPA Rep; i T. Ma ers / J. elits AOGCC Rep: Waived; Guy Cook Operator Rep: Josh Murphy ?J� Awpit Prue Bay Unit, EPA Permit: AK -1I000 OWDW Southeast (Pad -3 SE) Borax-PNL Survey Procedure - On 08/31/16, slick line operations verified access in the SE well to 1991 feet MD. This is near the top of the perforations and assured sufficient interval was available to perform the survey. - OWDW-SE injected normally during the previous six months. During that period, average and maximum daily injection pressures were 504 and 1050 psi respectively. Pumping unit pressures during the logging were at or above 1000 psi. Borax-PNL Survey Results - reference OWDW-SE Schlumberger Reservoir Saturation Log, 31 - August -2016. The log includes pertinent individual sigma passes. Each sigma pass was run from the fill level to about 1400' 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 Baseline Overlay" A baseline sigma was run prior to pumping any fluid with methanol -water in the well. A second baseline sigma pass was run after pumping about 100 barrels of hot KCL water. The two baseline passes were overlayed to show the statistical variation in the formation sigma of up to about 3 capture units. One of the baseline passes was used for comparison to subsequent passes. - "Baseline pass 1 and baseline 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 at approximately 5 bpm. This overlay indicates areas of increased sigma from that baseline. There is a significant increase in borehole sigma due to the borax solution in the wellbore below the tubing tail. The largest formation sigma increase seen in the overlay was up to 6 capture units, potentially up to 1955'MD. - "Baseline pass 2 and baseline overlay". A second stage of boron laden fluid was pumped prior to running this pass. There is no increase in formation sigma from the previous pass. - "KCL flush and baseline 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 near baseline levels indicating the boron laden fluid had been flushed from the wellbore and there is no indication of upward movement beyond 1952'MD. - "Pressure Temperature Baseline Down at 60 fpm". The baseline temperature pass was run after the well had been shut in for an excess of 12 hours to provide a basis for comparison with temperature log after borax solution was flushed from the wellbore. The post pumping temperature passes confirm the conclusions above. The absence of any significant increase in formation sigma after pumping a large amount of boron laden solution indicates there is no evidence of upward movement of injected fluids above the approved injection zone. Page 1 of 2 Pruo Bay Unit, EPA Permit: AK -1I0040 OWDW Southeast (Pad -3 SE) Overall Conclusions 1. There is no indication of fluid movement above the base of the confining zone. 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 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 30 -August -16 indicate the tubing, casing and the exterior part of the well are hydraulically sound. Carrie Janowski, Intervention & Integrity Specialist September 14, 2016 Page 2 of 2 Demonstration of Mechanical Integrity Prudhoe Bay Unit Pad 3 Well OWDW-SE EPA permit AK -1 1004-B effective December 8, 2009 requires a tubing inspection log in Prudhoe Bay Unit pad 3 Class I wells once every two years. Approved tubing inspection logs (Part II C 3 b (3)) include pipe analysis logs, caliper logs or other equivalent tests. Below are the results of a caliper log run in active Pad 3 well OWDW-SE. Tubing Inspection Logs A memory caliper log was run in well OWDW-SE on August 24, 2016. The log was run on slickline using a memory 24 arm caliper logging tool supplied by service company PDS (Proactive Diagnostic Services) to inspect the interior surface of the tubing. The inspection indicated the tubing in OWDW-SE to be in fair to poor condition due to erosion and isolated pitting corrosion. The SE well tubing was installed in 1985. Enclosed is a copy of the PDS Memory Multi -Finger Caliper Log Results Summary for the well. Below are the maximum wall penetration and the maximum cross sectional metal loss as measured by this log. OWDW Well Date SE Tubing 08/24/16 Overall Conclusions Max Wall Penetration Max Cross -Sectional Wall Loss 52% 39% The OWDW-SE calliper log indicates the tubing has erosion/corrosion damage, but is suitable for continued injection. Carrie Janowski, Intervention and Integrity Specialist September 12, 2016 • United States Environmental Protection Agency i a Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 MECHANICAL INTEGRITY TEST (MIT) FORM Facility Well Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-SE AIL -1I004-7 1002390 Injector MIT Type Test Type Test Date Class 1 T X IA Std. Annular Pressure Test (SAPT) 30 -Aug -16 Req'd Test Fluid Type(s) used to Packer Depth: TUBING 443 1 443 443 442 PASS INNER ANNULUS 0 1,671 1.555 1,523 OUTER ANNULUS N/A N/A N/A N/A Presssure (psi) test MD / TVD Test Interval /Comments 1,500 Diesel 1885 TVD 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 RECORDED PRESSURES (PSI) RESULT 10:27 AM PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN TUBING 443 1 443 443 442 PASS INNER ANNULUS 0 1,671 1.555 1,523 OUTER ANNULUS N/A N/A N/A N/A LOSS 116 22 COMMENTS: Well SI since august 27 2016. 2.4bbl Ambient Diesel req. to PSI up annulus (401) T E S START TIME: RECORDED PRESSURES (PSI) PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ TUBING T INNER ANNULUS FAIL 2 OUTER ANNULUS LOSS COMMENTS: A U G E 5 Manufacturer Tyke Calibration Date TUBING Nvision Digital, 0-10k 12/23/2015 INNER ANNULUS Nvision Digital, 0-10k 12/23/2015 OUTER ANNULUS OTHER COMMENTS: Dual input gauge, Well does not have an OA OTHER COMMENTS: Criteria 1 = 8.26% Criteria 2 = 15.94% NOTE: Pressure must show stabilizing tendency: Criteria 1) Total loss must be less than 10%at the end of a 30 minute test 2) Pressure loss in last 15 minutes must be less than 33% of total loss Extend test duration to 60 minutes, if necessary, to eliminate thermal effects (on-site decision per Inspector). Evan Osborne 206-553-1747 osbome.evan@epa.gov Tim Mayers 10 907-271-3410 mayers.timothy@epa.gov Jason Selitsch f 907-317-4774 j.selitsch@denalienvironmental.us {EPA Rep: s T. Mayers / J.,"*Vtoqb ,t L �f AOGCC Rep: Waived; Guy Cook Operator Rep: Josh Murphy Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main IDelIwredtQ iii Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, October 04, 2015 8:14 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC EPA form included Prudhoe Bay Cc: AK, D&C Well Integrity Coordinator Subject: September 2015 AOGCC MIT forms Attachments: September 2015 MIT Forms.zip SCANNED All, Please find the attached MIT forms for September 2015: Well: GNI-02A GNI-03 OWDW-C OWDW M OWDW-SE 09-11 09-22 B-17 NGI-13A P-13 PSI -01 V-219 X-33 Thank you, PTD #: Notes: 2061190 EPA form included 1971890 EPA form included 2071170 EPA form included 1002420 witness w orm include 02400 witness waived/EPA form inc TM—de- 1002390 witness waived/EPA form included Whitney Pettus 1760840 1831730 1790280 2071140 1901110 2021450 2081420 1961440 (Allerrrute. Kevin Parks) BP Alaska - Well Integrity Coordinator GW non -witnessed WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com 1 11 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: iim.regg(Walaska.gov; AOGCC.Inspectors(ci7alaska.gov; phoebe.brooks(calaska.gov chrismallace( alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay/PBU/Pad 3 L 09/21/15 Kevin Parks Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I = Industrial Wastewater Well OWDW-C Tye In'. I N TVD I 1,917 Tubin - 696 '700 696 695 1 Interval 0 P.T.D. 1002420 Type test P Test si 1500 Casin 17 ' 1,675 1,555 1,536 P/F P Notes: Annual EPA MIT -IA witnessed by Thor Cutler and OA 1 Jason Selitsch, pumped 2 bbls ambient diesel I VVelI10WDVV-NVV1 Type In'. I N I TVD 1,896' Tubing 613 614 613 613 1 Interval 0 P.T.D. 1002400 I Type test I P I Test psi 1 1500 Casing 1,552 1,5321 1 P Notes: Annual EPA MIT -IA witnessed by Thor Cutler and OA Jason Selitsch, pumped 3.75 bbls ambient diesel _4__1,671 Well OWDW-SE I Type Inj.1 N I TVD 1 1,885Tubing 120 142 120 120 Interval 0 P.T.D. 1002390 Type test P Test psi 1500 Casin 28 1,676 1,556 1,530J P/F P Notes: Annual EPA MIT -IA witnessed by Thor Cutler and OA Jason Selitsch, pumped 2.4 bbls ambient diesel Weill I Typelnj.1 TVDTJbn Interval P.T.D. Type test Test psi C P/F Notes: Well I Typ.Inj.1 I ND I Tubing Interval P.T.C.1 Type test I Test psil Casing P/F Notes: OA TYPE ]NJ 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 11/2012) MIT PBU OWDW-C, OWDW-NW, OWDW-SE 09-21-15.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance 0 = Other (describe in notes) • CERTIFIED MAIL # 7015 1730 0000 6058 3491 April 26, 2016 Mr. Edward J. Kowalski Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501-3192 Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 i• AWEIVED A , ,2 9 2016 SCAMAD BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 USA RE: Mechanical Integrity Test Notifications Pad 3 Infection Wells, UIC Permit AK -1 1004-B, Wastewater Disposal Permit No 201 ODB0001-0021 Grind and lniect Infection Wells, UIC Permit AK -1 1008-A, Area Infection Order No 4E General Wastewater, Permit No. 2010DB001-0012 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notifications: 1) 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-B and 2) 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. 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) Mechanical IntegrityT�otification • April 26, 2016 Page 2 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 will be sent under separate cover or by e-mail. If you have any questions, please contact me at (907) 564-4267 or Tom.Barrett@bp.com Sincerely, Tom Barrett Environmental Team Lead Attachment cc: Thor Cutler, EPA Region 10 Mechanical Integrity T otification • April 26, 2016 Page 3 Certification Statement Mechanical Integrity Test Notification 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. Respo5lAlfi Compa fficial Gary Crawford Printed Name Date Logistics/Infrastructure Manager BP Exploration Alaska) Inc. Title Company Proposed Schedule for 2016 Mechanical Integrity Testing Class I Well (s) MIT Deadline Proposed MIT test date Flexibility in test date? Fluid Movement Logs Planned after MIT? Pad 3 — By Mid -September 2016 Yes Borax -RST logs OWDW-NW, C September for each well and SE Wells 21, 2016 for scheduled with NW, C and MIT's SE wells Caliper log in OWDW-SE in (Logging summertfall may be 2016 extended up to 3 months with Director approval Grind and Inject By Mid -September 2016 Yes Shut -In — GNI-02A, September Temperature GNI-03 and 20, 2016 for Logs and/or GNI-04 GNI-02A, Water Flow Logs GNI-03 and planned for GNI-04. summertfall 2016 (May be extended 1 Caliper logs in month or at summer/fall Director 2016 discretion CERTIFIED MAIL # 7011 2970 0001 9243 3630 April 28, 2015 Mr. Edward J. Kowalski Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle, WA 98101 Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501-3192 Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage, AK 99501 BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 USA r r f RE: Mechanical Integrity Test Notifications Pad 3 Iniection Wells, UIC Permit AK -1 1004-B, Wastewater Disposal Permit No 201 ODB0001-0021 Grind and Infect Infection Wells, UIC Permit AK -1 1008-A, Area Iniection Order No 4E, General Wastewater, Permit No. 2010DB001-0012 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notifications: 1) 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-B and 2) 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. 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) Mechanical Integrity Notification • April 28, 2015 Page 2 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 will be sent under separate cover or by e-mail. If you have any questions, please contact me at (907) 564-4838 or Darren Mulkey at 564- 5229. Sincerely, Alison Cooke UIC Compliance Advisor Attachment cc: Thor Cutler, EPA Region 10 Mechanical Integrity Notification April 28, 2015 Page 3 Certification Statement Mechanical Integrity Test Notification 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. Responsib a Compa ficial Gary Crawford Printed Name Z -//W Date Logistics/Infrastructure Manager BP Exploration Alaska) Inc. Title Company 10 • Proposed Schedule for 2015 Mechanical Integrity Testing Class 1 Well (s) MIT Deadline Proposed MIT test date Flexibility in test date? Fluid Movement Logs Planned after MIT? Pad 3 — By Mid -September 2015 Yes Borax -RST logs OWDW-NW, C September for each well and SE Wells 18, 2015 for scheduled with NW, C and MIT's SE wells. Caliper log in OWDW-SE in (Logging summer/fall may be 2015 extended up to 3 months with Director approval) Grind and Inject By Mid -September 2015 Yes Shut -In — GNI-02A, September Temperature GNI-03 and 20, 2015 for Logs and/or GNI-04 GNI-02A, Water Flow Logs GNI-03 and planned for GNI-04. summer/fall 2015 (May be extended 1 Caliper logs in month or at summertfall Director 2015 discretion) Certified # 7011 2970 0001 9242 8681 October 30, 2014 lot, O�V � c� a I- by BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 UIC Manger, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 SCANNED NOVO 7 2014 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 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 wells OWDW-SE, OWDW-NW and OWDW-C on September 22, 2014. All wells 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 on September 18, 2014, in OWDW-NW September 20 and in OWDW-C September 21. There was no indication of fuid movement behind the casing above the approved injection interval in the 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. UIC Manager, Ground Water Protection Unit Pad 3 Demonstration of Mechanical Intengrity October 30, 2014 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, Gary Crawford Logaistics and Infrastructure Manager Attachments Cc: Letter and report w/o log copies: Thor Cutler, EPA Region 10 Chris Wallace, AOGCC Jim Regg, AOGCC Marc Bentley, ADEC UIC Manager, Ground Water Protection Unit Pad 3 Demonstration of Mechanical Intengrity October 30, 2014 Attachments: Mechanical Integrity Test Results Mechanical Integrity Test Forms OWDW Surveillance Procedures OWDW Southeast Borax PNL Survey Results OWDW Northwest Borax PNL Survey Results OWDW Center Borax PNL Survey Results Enclosures: 2 copies each of the following Schlumberger logs: - OWDW-SE Schlumberger Reservoir Saturation Log w/ Borax, 18 -September -2014 - OWDW-NW Schlumberger Reservoir Saturation Log w/ Borax, 20 -September -2014 - OWDW-C Schlumberger Reservoir Saturation Log w/ Borax, 21 -September -2014 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 22, 2014. 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: 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 -B, Part 11, C 3 b (1). Annulus pressures were observed on a recording digital test gauge. During each test period, the tubing pressure was essentially constant. The pressure decline observed in these wells 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 Jason Selitsch. I conclude from the successful MIT's that the casing, tubing and packer in the SE, NW and C 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 September 23, 2014 Tubing Pressure Annulus Pressure psi 1 st Half 2nd Half Test Pad 3 Well Start / End Start 15 Min 30 Min Decline Decline Result Southeast 446/445 1595 1500 1473 95 27 Passed Northwest 470/469 1620 1500 1480 120 20 Passed Center 202/202 1651 1515 1493 136 22 Passed 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 -B, Part 11, C 3 b (1). Annulus pressures were observed on a recording digital test gauge. During each test period, the tubing pressure was essentially constant. The pressure decline observed in these wells 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 Jason Selitsch. I conclude from the successful MIT's that the casing, tubing and packer in the SE, NW and C 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 September 23, 2014 United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553-1673 a -mai L• cutler.thor@epa.gov MECHANICAL, INTEGRITY TEST (MIT) FORM Facility I Well Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-SI? AK -1I004 -A 1 1002390 ��Cnjie-clso_ir MIT Type Test Type Test Date T X IA I Std. Annular Pressure Test (SAPT) 9/22/2014 Req'd Test Presssure (psi) Fluid Type(s) used to test Packer Depth (ft, 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: 9:57 AM PRE M1'1' RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT PIF S TUBING 445 446 445 445 PASS T INNER ANNULUS 276 1595 1500 1473 OUTER ANNULUS 0 0 0 0 1 COMMENTS. SI, 2 bbls ambient diesel total..5 bbls to MIT Crystal gauge calibration 06/30/14 T E S START TIME: PRE MITI RECORDED PRESSURES (PSI) INITIALI 15 MIN I 30 MIN I 45 MIN 60 MIN RESULT PASS/ TUBING T INNER ANNULUS FAIT. OUTER ANNULUS 2 COMMENTS: T E S START TIME: RECORDED PRESSURES (PSI) PRE MIT INITIAL. 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ TUBING T INNER ANNULUS FAIL OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: 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). D -- E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler Chuck Scheve Laurie Climer / Ryan Hayes United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553-1673 e-mail: cutlenthor@Depa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility I 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 1 T X IA I Std. Annular Pressure Test (SAPT) 1 9/22/2014 Req'd'l'est Presssure (psi) Fluid Type(s) used to test Packer Depth (ft, TVD) Test Interval / Comments 1,500 Diesel 1,896' 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 START TIME: 10:37 AM PRI'. MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT P(F PASS TUBING 469 470 470 469 T INNER ANNULUS 192 1620 1500 1480 OUTER ANNULUS 1 COMMENTS: SI, 3 bbls total ambient diesel, 25 bbls for MIT crystal gauge calibration 9/11/14 T E S START TIME: PRF. MIT RECORDED PRESSURES (PSI) INITIAL, 15 MIN 30 MIN 45 MIN 60 MIN RESULT PASS/ TUBING T INNER ANNULUS FAIL OUTER ANNULUS 2 COMMENTS: T E START TIME: PRE MITI RECORDED PRESSURES (PSI) INI'T'IAL 1 15 MIN 1 30 MIN 45 MIN 60 MIN RESULT S T TUBING PASSI FAIL. INNER ANNULUS OUTER ANNULUS 3 COMMENTS: MISC COMMENTS: 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% oftotal 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). �—J o-- E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler Chuck Scheve Laurie Climer / Ryan Hayes United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 Seattle, WA 911101 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 Ray Unit, PAD 3 OWDW-C AK -11004-A 1002420 Injector MIT Type I Test Type Test Date Class I T X lA I Std. Annular Pressure Test (SAPT) 1 9/22/2014 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval /Comments Presssure (psi) test TVD) INNER ANNULUS 1,500 Diesel 1,917' One Year Cycle Record all Wellhead Pressures before and during "rest 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 START TIME: 12:57 PM PRE MIT RECORDED PRESSURES (PSI) INPTIAL I 15 MIN 30 MIN 45 MIN 60 MIN RESULT P/F PASS TUBING 202 202 202 202 T INNER ANNULUS 1 1651 1515 1493 OUTER ANNULUS 0 0 0 0 1 COMMENTS: SI, 2 25 bbls total, .25 bbls for MIT_ monobore, Crystal gauge calibration 06/30/14 T E START TIME: PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT S TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 2 COMMENTS. T E START TIME: PRE MPT RECORDED PRESSURES (PSI) INITIAL 1S MIN 30 MIN 45 MIN 60 MIN RESULT S TUBING PASS/ T INNER ANNULUS FAIL. OUTER ANNULUS 3 COMMENTS: RISC COMMENTS: DOTE: 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 NET 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). �—J -- E-mail this MIT Test Data Form to EPA Region 10 - Tbor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler Chuck Scheve Laurie Climer / Ryan Hayes Prudhoe Bay Unit, EPA Permit: AK -1I004 -A OWDW Center (Pad -3 C) _Borax-PNL Survey Procedure - On 09/15/14, slick line operations verified access in the C well to 2065 feet MD. This is below the perforations and assured sufficient interval was available to perform the survey. - While OWDW-C was perforated in February, 2014, there has been no disposal injection in the well to date. Pumping unit pressures were at or above 1350 psi Borax-PNL Survey Results - reference OWDW-C Schlumberger Reservoir Saturation Log w/ Borax, 21 -September -2014. The log includes pertinent individual sigma passes. Each sigma pass was run from the fill level to above 1400' 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). - "Baseline and KCL Overlay" A baseline sigma was run prior to pumping any fluid with methanol -water in the well. A second baseline sigma pass was run after pumping about 100 barrels of hot water. The two baseline passes overlayed well showing the statistical variation in the formation sigma of up to 1 chart division. One of the baseline passes was used for comparison to subsequent passes. - "Baseline KCL and Borax 1 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 at 5 bpm. During this pass borax solution was being pumped at minimum rate to minimize tool drag. Yellow shading on each overlay indicates areas of increased sigma from that baseline. Below the packer, there is a significant increase in borehole sigma due to the borax solution in the wellbore. Above the packer, there is a small shift in wellbore sigma (up to 1 chart division) due to the small volume of borax solution surrounding the tool while it is in the tubing (lined tubing I13=2.0", 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 2to 4 chart divisions or 5 to 12 capture units. As anticipated, the largest formation sigma increase seen in the overlay was 5 chart divisions across and immediately above the perforated interval (up to 1992' MD), well below the packer. There was no indication of upward movement above this point. A decrease of up to 1-1/2 chart division was noted in in the formation sigma from this point to near the packer. This is believed to an artifact of the processing algorithm. - "Baseline KCL Sigma and Borax 2 Overlay". A second stage of boron laden fluid was pumped prior to running this pass. Borax was noted across and immediately above the perforated interval as in the previous pass. - "Baseline and Flush Overlay". This overlay shows the tool response after flushing boron laden solution from the wellbore with water at low pump rates. The wellbore sigma returned to near baseline levels. Borax was still evident in and immediately above the perforated interval to 1990' MD. The 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 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 Prudhoe Bay Unit, EPA Permit: AK -1I004 -A OWDW Center (Pad -3 C) Baseline Temperature Survey_— shown on Log trace "Baseline Pass Down at 200 FPM", reference OWDW-C Schlumberger Reservoir Saturation Log w/ Borax, 21 -September -2014. - The baseline temperature pass was run in this shut in well to provide a basis for comparison should additional passes be necessary. This baseline is similar in character to the baseline temperature surveys run earlier this year. These logs show significant permafrost warming due to vertical and radial heat transfer from injection operations. - Shut In temperature passes were not required due to the results from the Borax -RST passes. Overall Conclusions 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 below about 1990' MD, within about 15 feet of 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 09/22/14 indicate the tubing, casing and the exterior part of the well are hydraulically sound. Michael L. Bill, P.E. September 23, 2014 Page 2 of 2 Prudhoe Bay Unit, EPA Permit: AK -1I004 -A OWDW Northwest (Pad -3 NW) Borax-PNL Survey Procedure - On 09/15/14 slick line operations verified access in the NW well to 2024 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 until 08/05/14 when the well was shut in for facility maintenance. During that injection period, average and maximum daily injection pressures were 516 and 1022 psi respectively. Pumping unit pressures during pumping were at or above 1200 psi. Borax-PNL Survey Results — reference OWDW-NW Schlumberger Reservoir Saturation Log w/ Borax, 20 -September -2014. 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 1400 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). - "Baseline and KCL Overlay". A baseline sigma was run prior to pumping any fluid with methanol -water in the well. A second baseline sigma pass was run after pumping about 100 barrels of hot water. The two baseline passes overlayed showing the statistical variation in the formation sigma of up to about 1 chart division. One of the baseline passes was used for comparison to subsequent passes. - "Baseline and Borax 1 Overlay". This overlay shows the change in tool response between a baseline pass and the pass run after pumping the first stage of borax solution at 5 bpm. During this pass borax solution was being pumped at minimum rate to minimize tool drag. Yellow shading on the overlay indicates areas of increased sigma. Below the packer, there is a significant increase in borehole sigma due to the borax solution in the wellbore. Above the packer there is a small shift in wellbore sigma (up to 1 chart division) due to the small volume of borax solution surrounding the tool while it is in the tubing (Tubing liner ID=2.0", 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. Typically, the increase in formation sigma due to the displacement of formation fluids adjacent to the wellbore with borax solution is 2 to 4 chart divisions or 5 to 12 capture units. - "Baseline and Borax 2 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. - "Baseline and Flush 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 near baseline levels indicating 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 Prudhoe Bay Unit, EPA Permit: AK -1I004 -A OWDW Northwest (Pad -3 NW) Baseline Temperature/Pressure Survey - shown on log trace "Baseline Pass Down at 200 FPM", reference OWDW-NW Schlumberger Reservoir Saturation Log w/ Borax, 20 -September -2014. - The baseline temperature pass was run after the well had been shut in for about 45 days to provide a basis for comparison should additional passes be necessary. The baseline temperature surveys in past years were typically run after a period of 12-24 hours of shut-in time. The 2014 baseline 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. - 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. There is no indication of fluid movement above the base of the confining zone. 2. Most, if not all, of the fluid pumped during the test was confined near the perforated interval. 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 9/22/14 indicate the tubing, casing above the packer and the exterior part of the well are hydraulically sound. Michael L. Bill, P.E. September 23, 2014 Page 2 of 2 Prudhoe Bay Unit, EPA Permit: AK -1I004 -A OWDW Southeast (Pad -3 SE) Borax-PNL Survey Procedure - On 09/15/14, slick line operations verified access in the SE well to 1978 feet MD. This is near the top of the perforations and assured sufficient interval was available to perform the survey. - OWDW-SE injected normally during the previous six months until 09/18/14 when the facility was shut in for maintenance. During that period, average and maximum daily injection pressures were 554 and 1204 psi respectively. Pumping unit pressures during the logging were at or above 1500 psi Borax-PNL Survey Results - reference OWDW-SE Schlumberger Reservoir Saturation Log w/ Borax, 18 -September -2014. The log includes pertinent individual sigma passes. Each sigma pass was run from the fill level to about 1400' 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). - "Baseline and KCL Overlay" A baseline sigma was run prior to pumping any fluid with methanol -water in the well. A second baseline sigma pass was run after pumping about 100 barrels of hot water. The two baseline passes were overlayed to show the statistical variation in the formation sigma of 0-2 chart divisions. One of the baseline passes was used for comparison to subsequent passes. - "Baseline KCL and Borax 1 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 at 5 bpm. During this pass borax solution was being pumped at minimum rate to minimize tool drag. Yellow shading on each overlay indicates areas of increased sigma from that baseline. Below the packer, there is a significant increase in borehole sigma due to the borax solution in the wellbore. Above the packer, there is a small shift in wellbore sigma (up to 1 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 to 4 chart divisions or 5 to 12 capture units. The largest formation sigma increase seen in the overlay was up about 2 chart divisions at 1876-78' MD, above the packer. There was no indication of upward movement from the perforated interval. A decrease of up to 2 chart division was noted in most of the formation sigma below the tubing tail. This is believed to an artifact of the processing algorithm. "Baseline KCL Sigma and Borax 2 Overlay". A second stage of boron laden fluid was pumped prior to running this pass. There is no increase in formation sigma above the previous pass due to an accumulation of borax solution exterior to the casing. "Baseline and Flush Overlay". This overlay shows the tool response after flushing boron laden solution from the wellbore with water at low pump rates. The wellbore sigma returned to near baseline levels. The formation sigma overlay shows a small amount of sigma increase, but it is believed to be within the statistical variation of the tool. 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 from the perforations upward. Page 1 of 2 Prudhoe Bay Unit, EPA Permit: AK -1I004 -A OWDW Southeast (Pad -3 SE) Baseline Temperature Survey— shown on Log trace "Baseline Pass Down at 200 FPM", reference OWDW-SE Schlumberger Reservoir Saturation Log w/ Borax, 18 -September -2014. - The baseline temperature pass was run after the well had been shut in for about 1 day to provide a basis for comparison should additional passes be necessary. The baseline temperature surveys in past years were typically run after a period of 12-24 hours of shut-in time. The 2014 baseline 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. - Shut In temperature passes were not required due to the results from the Borax -RST passes. Overall Conclusions 1. 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 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 09/22/14 indicate the tubing, casing and the exterior part of the well are hydraulically sound. Michael L. Bill, P.E. September 23, 2014 Page 2 of 2 Prudhoe Bay Unit, EPA Permit: AK -1I004 -B OWDW Surveillance Procedures Background EPA permit AK- 11004-B effective December 08, 2009 requires an annual fluid movement test, Part II C 3 b (2). Notice of the proposed test schedule was sent via email to Thor Cutler, EPA Region 10. The procedure used was very similar 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 pressure 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. - In that 6 month period, daily average and maximum daily injection pressures did not exceed 517 and 1022 psi respectively for the NW well and 554 and 1204 psi respectively for the SE well. There has been no injection in the Center well. Pumping unit pressures were 1200 psi or above for the NW well, 1500 psi or above for the SE well and 1350 psi or above for the C well during the high rate pumping (5 barrels per minute) of borax solution. - The injection rate was reduced to less than 1 bpm 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 2.0" in the lined 2- 7/8"). - The general survey procedure involved the following steps: run baseline temperature and first baseline RST pass pump 100 barrels hot water at high pump rate run second RST baseline pass at minimum pump rate pump 30-40 barrels hot borax -water solution at high pump rate run RST pass at minimum pump rate pump 30-40 barrels hot borax -water solution at high pump rate run RST pass at 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 -B OWDW Surveillance Procedures Optional Pump -in Temperature Survey Procedure Considerations To provide additional data if needed, an optional procedure was included 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 not run due to clear results with the Borax-PNL surveys. Michael L. Bill, PE September 23, 2014 Page 2 of 2 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main Delivered to: RECEIVED � MakanaK Bender • Natural Resources Technician II OU 10 s'* Alaska Oil & Gas Conservation Commission AO t 333 W T- Ave, Suite 100 Anchorage, AK 9950: �,00- 2`4 2 TRANSMITTAL DATE, • IF TRANSMITTAL# • =� DATA LOGGED to /Z1 /201J1 M. K. BENDER Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package N T. 5 >: 1i�� X have been verified to match the media noted above. The specific Date content of the CDs and/or hardcopy prints may or may not have been Print Name Sgftre verified for correctness or quality level at this point. Please return via courier or sign/scan and email a copy to Schlumberger. - _•l AlaskaPTSPrintCenter@slb.com (907) 561-8317 fax WRVICE • • WELL 03-16A r CFMH-00089 r NAMjj SERVICE PRUDHOE BAY DESCRIPTION,_JbDELIVERABLE WL DESCRIPTION IPROF DATA FINAL FIELD _DATE• r 29 -Sep -14 1 r 1 07-08B CV61-1-00046 PRUDHOE BAY MEMORY GR/CCL FINAL FIELD 30 -Sep -14 1 1 09-15A CV61-1-00051 PRUDHOE BAY MEMORY GR/CCL FINAL FIELD 6 -Oct -14 1 1 11-30 CBOO-00085 PRUDHOE BAY WL LDL FINAL FIELD 30 -Sep -14 1 1 A -24A CV61-1-00048 PRUDHOE BAY MEMORY GR/CCL FINAL FIELD 2 -Oct -14 1 1 MPC -15 CV61-1-00045 MILNE POINT MEMORY IPROF FINAL FIELD 25 -Sep -14 1 1 OWDW-C CODG-00070 PRUDHOE BAY WL RST BORAX *REV 1* FINAL FIELD 21 -Sep -14 1 1 OWDW-SE CODG-00072 PRUDHOE BAY WL RST BORAX *REV 1* FINAL FIELD 18 -Sep -14 1 1 OWDW-NW CODG-00071 PRUDHOE BAY WL RST BORAX *REV 1* FINAL FIELD 20 -Sep -14 1 1 Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package N T. 5 >: 1i�� X have been verified to match the media noted above. The specific Date content of the CDs and/or hardcopy prints may or may not have been Print Name Sgftre verified for correctness or quality level at this point. Please return via courier or sign/scan and email a copy to Schlumberger. - _•l AlaskaPTSPrintCenter@slb.com (907) 561-8317 fax MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re DATE: Thursday, September 25, 2014 gg IU�b�� P.I. Supervisor � f SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC OWDW-C FROM: Chuck Scheve PRUDHOE BAY UNIT OWDW-C Petroleum Inspector Src: Inspector Reviewed By.:, P.I. Supry 'Jgk NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT OWDW-C API Well Number 50-029-21821-00-00 Inspector Name: Chuck Scheve Permit Number: 100-242-0 Inspection Date: 9/22/2014 Insp Num: mitCS140922141714 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min PTD OWDW-c 'Type Inj N TVD 1917 Tubing 202 • 2oz —202 zoz - ell - iooza2oype Test SPT Test psi 1500 IA 1 1651 1515 ' 1493' - - IntervallOTHER- P/F P OA Notes: Annual MIT, Thor Cutler with EPA also witnessed. Pressure dropped slightly below minimum test pressure,Mr Cutler accepted results so I did not require retest. 0-1&%:r— waC SCANNED OCT 3 0 2014 Thursday, September 25, 2014 Page 1 of I Corine Barrera Data Manager Schlumberger Oilfield Services WIRELINE 2525 Gambell St, Ste. 400 Anchorage, AK 99503 Office: (907) 273-1709 z -A t%G DATE: 04 June 2014 TRANS#: 6952 DATA LOGGED Makana K B ender G� fc. /2014 -y Natural Resources Technician II M K BENDER Alaska Oil & Gas Conservation Commission 333 W- 711, Ave, Suite 100 Anchorage, AK 09501 t (007) 793-1335 -m a k.arta. Deziderc' alask 1. _ ^7�- X Please return a signed copy to: BP PDC LR2-1 900 E Benson Blvd Anchorage AK 99508 SCAWO OCT 0 2 2014 X Please return a signed copy to: Wireline 2525 Gambell St, Suite 400 Anchorage AK 99503 NWE ORD—E-A-4- - - DIST _DIST - 61ST DIST LOGGED PRINTS PRINTS C -15A CFGK-00067 X MEMORY PPROF 13 -May -14 1 1 18-16B CFGK-00068 X MEMORY PPROF 15 -May -14 1 1 02-18C CY89-00007 X MEMORY CNL 23 -Apr -14 I 1 1 02-12D CFGK-00066 X MEMORY PPROF W/ GHOST 9 -May -14 1 1 L2-33 CYCD-00003 X LDL 19 -Apr -14 1 1 03-29 CODG-00026 X RST BORAX 14 -May -14 1 1 02-16C CY89-00010 X MEMORY PPROF 28 -Apr -14 1 1 OWDW-C CBOO-00058 X RST 25 -Feb -14 1 1 Z-15 ClSD-00112 X MEMORY LDL 27 -Apr -14 1 1 NK -43 C4W7-00118 X PPROF W/ DEFT 4 -Apr -14 1 1 NK -43 CFMH-00076 X BORAX SPINNER 17 -May -14 1 1 02-33B CY89-00012 X IMEMORY PPROF 30 -Apr -14 1 1 05-11A CY89-00013 X MEMORY PPROF 3 -May -14 1 1 1-21/K-25 C1SD-00114 X MEMORY LDL 1 -May -14 1 1 X Please return a signed copy to: BP PDC LR2-1 900 E Benson Blvd Anchorage AK 99508 SCAWO OCT 0 2 2014 X Please return a signed copy to: Wireline 2525 Gambell St, Suite 400 Anchorage AK 99503 Certified Mail #7012 2920 0001 8307 7113 May 20, 2014 Mr. Edward Kowalski Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue Seattle WA 98101 Mr. Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501-3192 Mr. Marc Bentley Department of Environmental Conservation 555 Cordova St. Anchorage, Alaska 99501 Mechanical Integrity Test Notifications Milne Point Iniection Well UIC Permit AK -11005-A. General Wastewater Disposal Permit No. 201ODB0001-0001 Northstar Class I Iniection Wells UIC Permit AK -11002-6 General Wastewater Disposal Permit No. 2001 OB0001 -0020 Liberty Proiect UIC Permit AK -11013-A General Wastewater Disposal Permit No. 20010B0001-0025 `uc--)-2L4-2 by f'b MAY 2 2 2014 aid OMBP Exploration (Alaska) Inc. PO Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 USA Pad 3 Iniection Wells UIC Permit AK -11004-8 General Wastewater Disposai Permit No. 2010-DB0001-0021 Grind and Iniect Iniection Wells UIC Permit AK -1 1008-A Area Iniection Order No. 4E General Wastewater Disposal Permit No. 20010B0001-0012 gafggo OCT 02 2014 MIT Notification May 20, 2014 Page 2 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notifications: 1) the MIT and fluid movement tests at the Northstar NS10 and NS32, Class I wells to meet the annual permit requirement in UIC Permit AK -11002-B; 2) the MIT and fluid movement tests at the Pad 3 Class I wells in the Prudhoe Bay Unit to meet the annual permit requirement in UIC Permit AK - 11004 -13; 3) 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; 4) the MIT and fluid movement test that is required every three years at the Milne Point Class I well to meet the permit requirement in UIC Permit AK -11005-A; and 5) the MIT and fluid movement tests at the Liberty Class I well to meet the annual 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 is 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 I 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 or alison.cooke@bp.com Sincerely, Alison D. Cooke UIC Compliance Advisor Attachment cc: Thor Cutler, EPA Region 10 Wn� Proposed Schedule for 2014 Mechanical Integrity Testing Class I Well (s) MIT Proposed MIT test Flexibility in Fluid Deadline date test date? Movement Logs Planned after MIT? Milne Point By July 28, Approximately July 22- Coordinate with Yes, fluid MPB-50 2014 25, 2014. Northstar test movement logs date. are required at Milne Point every three years and are ,Zo �- 25ao required in 2014. Calliper log PO(n+ planned for summer 2014. Northstar NS10 By July 28, Approximately July 25- Coordinate with Yes, all required 2014 29, 2014. Milne test date. logs will be 20 (May be scheduled with the MIT. n extended up to 3 months with Director approval) Northstar NS32 By July 28, Approximately July 25- Coordinate with Yes, all required 2014 29, 2014.. Milne test date. logs will be 0 scheduled with (May be the MIT. extended up to 3 months with Director approval) Liberty CRI Well N/A The Liberty CRI well All logs required will not be drilled in to complete the 2014. well would be scheduled with the MIT. �tAAK,u Ra.� �ieA MIT Notification May 20, 2014 Page 2 Class I Well (s) MIT Deadline Proposed MIT test date Flexibility in test date? Fluid Movement Logs Planned after MIT? Pad 3 — By Mid to Late September Yes Borax -RST logs OWDW-NW, September 2014 for each well SE, and C Wells 21, 2014 for scheduled with NW and SE MIT's in 2014. wells. oo Caliper logs in early summer 100 23 � (Logging (target June, may be 2014). ((Do 2� ZO extended up to 3 months with Director approval) Grind and Inject By Mid to Late September Yes Shut -In — GNI-02A, September 2014 Temperature GNI-03, and 23, 2014 for Logs and/or GNI-04 GNI-02A, Water Flow Logs GNI-03 and planned for GNI-04. summer 2014. 16 Iffl (May be Pressure falloff 1c(7 1 S I o extended 1 tests and step month or at rate tests in 201 11-10 Director early to mid discretion) summer (target is June -July, 2014). RECEIVED J��DsrgT� UNITED STATES ENVIRONMENTAL PROTECTION AGENCY MAY 12 2014 3m s REGION 10 1200 Sixth Avenue, Suite 900 AOGCC Seattle, Washington 98101-3140 it Pnolsr' OFFICE Or- COMPI.IANCE AND ENFORCEMENT Reply To: OCE -127 CER'll'IFIED MAIL - RETURN RECEIPT REQESTIA) QQj1D*0f:- RAIZ Ft EL -r) Mr. Gary Crawford Logistics and Inli'astructure Manager BP Exploration (Alaska) Inc. (BPXA) 900 East Benson Boulevard Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit Pad 3 Disposal Facility Underground Injection Control (UIC) Program Class I Well Oily Waste Disposal Well -Northwest (OWDW-C) under Permit AK11004-B, Final Approval to Inject into UIC Class 1 well OWDW-C PT- D 100;'+20 Dear Mr. Crawford: The U.S. Environmental Protection Agency, Region 10 (EPA) has received and reviewed the Completion Report of the workover completed on March 24, 2014 for Class ,l Well OWDW-C. Based on the review, the EPA grants final approval to BPXA, under EPA UIC Permit number AK -1 1004-B to commence injection at Pad 3 Well OWDW-C. The EPA looks forward to receiving the future quarterly and annual reports required by the permit. If you have any questions regarding the final approval to commence injection into well OWDW-C, please contact Thor Cutler of my staff at (206) 553-1673, or email at cutler.thor(cJepa.gay. y Edward J. Kowalski Director cc: vChris Wallace Alaska Oil and Gas Conservation Commission Marc Bentley Alaska Department of Environmental Conservation SMIAED OCT 0 - 2014. aPrinfed on Recycled Paper Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWellintegrityCoordinator@bp.com] Sent: Friday, April 11, 2014 5:56 PM To: Regg, James B (DOA); Wallace. Chris D (DOA) Subject: RE: OPERABLE: Disposal Well OWDW-C (PTD #1002420) Approval to Operate Jim and Chris, Correction to my earlier email - the rig workover was to run tubing, as there was none in the well at the time. The rig did not remove corroded tubing on OWDW-C. I apologize for any confusion in the matter. Regards, Laurie Climer BP Alaska - Well Integrity Coordinator Ci ;;'V SCpNNEi3 OCT 0 2014, WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Friday, April 11, 2014 2:41 PM To: 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; Daniel, Ryan; Bill, Michael L (ASRC); 'chris.wallace@alaska.gov'; 'jim.regg@alaska.gov' Cc: AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer Subject: OPERABLE: Disposal Well OWDW-C (PTD #1002420) Approval to Operate All, Disposal Well OWDW-C (PTD #1002420) has had recent rig wellwork to repair corroded tubing. The well passed an AOGCC witnessed MIT -IA to 1,800 psi on March 24, 2014 indicating competent downhole barriers. Per the EPA permit requirements, a Borax log was run on Feb 25, 2014, and the EPA has given interim approval for injection. At this time, the well has been reclassified as Operable, and may be used for injection as needed. Use caution when during start-up, as the annuli will be fluid packed. A copy of the interim approval as well as a wellbore schematic have been included for reference. Please call with any questions. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator G Y 11 GlooWl Wells prgani22ttui WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@BP.com IINE=. BLIMRAN13EQLY Minimum D =1.781' 01945' 2-W FES XN NPPLE Dm2 M1' A bd. D -=P FE RFUMI l SUM RW MFLOQ OKXKDWM AMMEATXWR3RP. 0-02OW MAw Rdtr b Rn& -A- M for l , Im bd di SES SW NFOWAL Opd by MDT BM 34' 6 2M-2WO O MMlfl4 16-1Q CM In N406 := W. o -4AW I OWDW-C "MM *TMYOOF6 M - RMM= I3AICDIUM"wQ wwm�ms S m lorpmc LY YIRM OM08AL MBL A" IEWML MRT0 MMAW DOMDUE E K- LOVkBt RAIN13EEON CBG SRIOL E fi1T®TO M ONLY !3 -WF OTB TRECIIPOOIiMH7K11 ' ENDED wX*lECK VLVS D- 2.750' . JOW H2 -7W LAID a1D1RNt'RLDOC�1 FRE FMERY LNf WELL O A3R-C FERMWNor � AFI Noy MOMS" SE 11. Tftt 4 ME 6D FNL A 1063 FEL O IE Mf BY COLIAM OM FM IV OQIE1EBAs71 06Cl, m E#EWCOiERaDN M7tM R&LB M3MFF DWMR 12MM S+rJeME LASTTA IRIE 031067% E8■D CCMIMM®FERMNMFEW 1� D614 � .OWWH JD MA HD ODRiEDLOB OIRRM I Q6aD FMLMEAARMAL l E3�io�ado� (AIrd1 lovaml IDIiD wm SAT oiB BL8 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg�E� DATE: Thursday, April 10, 2014 P.1. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC OWDW-C FROM: Bob Noble PRUDHOE BAY UNIT OWDW-C Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv, NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT OWDW-C API Well Number 50-029-21821-00-00 Inspector Name: Bob Noble InSp Num: mitRCN140324133421 Permit Number: 100-242-0 Inspection Date: 3/24/2014 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min OWDW-C Type Inj N- TVD 1917 IA 0 1800 1673 1655 1002420 Type Test SPT Test psi lsoo OA OTHER P/F P Tubing 185 185. 185 - 185. Notes: Post RWO on class 1 well. SC&*M OCT 0 2 2014, Thursday, April 10, 2014 Page 1 of l ,C)U - 24-�2 RECEIVED `��,�jEosrr�s UNITED STATES ENVIRONMENTAL PROTECTION AGENCY APR 0 1 2014 REGION 10 /� n r 1200 Sixth Avenue. Suite 900 AC Seattle, Washington 981 01-31 40 VAPR 2 6 2014 Reply To: OCE -127 CERTIFIED MAIL - RETURN RI:CI IP'I' REQUESTED Mr. Gary Crawford SCANNED OCT 0 2 2014 Logistics and Infrastri►cture Manager BP Exploration (Alaska) Inc. (BPXA) 900 East Benson Boulevard Anchorace. Alaska 99519-6612 Re: Prudhoe Bay Unit Pad 3 Disposal Facility Under2r01.111c1 Injection Control (UIC) Program Class I Well Oily Waste Disposal Well -Center (OWDW-C) under Permit AKII004-B. Interim Approval to Iniect into UIC Class I well OWDW-C Dear Mr. Crawford: The U.S. Environmental Protection Aoe:ncy. Region 10 (EPA) has witnessed portions of the workover on-site and telephonically witnessed the well mechanical integrity tests (MIT) conducted on December 29, 2013 and February 25. 2014 for Class I Well OWDW-C. Based on the on-site review and the MIT, the EPA grants interim approval to BPXA, under EPA UIC Permit number AK -1 1004-B to commence injection at Pad ; Well OWDW-C. After the permit requirements are fulfilled including the submittal of the completion information with file `'Completion Form For Wells (EPA Form 7520-9)" per permit Part 1.1 C. I., then EPA will make an adequacy cletermination for final approval for injection into UIC Class I well OWDW-C. If you have any questions regarding the interim approval to commence injection into well OWDW-C. please contact Thor Cutler of my staff at (206) 553-1673, or email at cutler.tllor@epa.-o".. cc Director ✓Chris Wallace Alaska Oil and Gas Conservation Commission Marc Bentley Alaska Department of Environmental Conservation 4 Printed on Recycled Paper E9 10 � -24� Certified Mail #7013 0600 0000 8040 0247 March 25, 2014 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 RECEIVED MAR 2 6 2014 AOGGG 0 BP Exploration (Alaska) Inc. P. O. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 USA SAU [U 022014, Re: Completion Report and Demonstration of Mechanical Integrity Prudhoe Bay Pad 3 Disposal Facility, Well OWDW-C UIC Class I Permit AK -1 1004-B Dear UIC Manager, BP Exploration (Alaska), Inc. (BPXA) operator of the Prudhoe Bay Pad 3 Disposal Facility has recently installed tubing and packer in well OWDW-C. This letter is to submit the Completion Report for Injection Wells, EPA Form 7520-9 to document the new completion in this well. This form is submitted as required in Part II, C.1.a of EPA UIC Class I permit AK11004-B. This information will provide an update to information in UIC Class I Permit Renewal Applications submitted June 2009 and February 1999. Also attached are the results of an annulus pressure test also known as a Mechanical Integrity Test (MIT) and a fluid movement log. OWDW-C MITs were conducted in compliance with the permit requirements in Part II C.3.b on December 29, 2013 and on March 24, 2014. The first test was monitored by an EPA representative and the second test was witnessed by an AOGCC representative. The well passed both MITs. The fluid movement logging requirement was satisfied with a borax -RST log on February 25, 2014. Detailed information regarding the results of the MIT and the log is contained in the enclosed descriptive and interpretive analyses of the tests. EPA representative Thor Cutler monitored the placement of the packer in the well, verifying that it met the requirement in Part II A.2 of the permit. Final approval for injection will be based on this Completion Report. 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. Completion Report and Demonstration of Mechanical Integrity Prudhoe Bay Pad 3 Disposal Facility, Well OWDW-C March 25, 2014 If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564-4692. Sincerely, Gary Crawford Logistics and Infrastructure Manager Attachments: Completion Form for Injection Wells, EPA Form 7520-9 Update to Form 7520-9 Attachment II 1, II 3 and II 5 Mechanical Integrity Test Result Report EPA Mechanical Integrity Test (MIT) Form, December 29, 2013 AOGCC Mechanical Integrity Test (MIT) Form, March 24, 2014 OWDW Surveillance Procedures OWDW Center Borax RST Survey Results EPA Permit Requirements Checklist OWDW-C Wellbore Diagram AOGCC Report of Sundry Well Operations, Form 10-404 OWDW-C Schlumberger Reservoir Saturation Log, 25 -February -2014 Cc: Thor Cutler, EPA Region 10 Chris Wallace, AOGCC Marc Bentley, ADEC A. D. Cooke MB 3-3 M. L. Bill MB 7-1 cc w/o enclosures: R. Daniel MB 7-1 J. Disbrow/L. Climer PRB 24 A. Reyes/G. Kany PRB 42 OMB No. 2040-0042 Approval Expires 11/30/2014 United States Environmental Protection Agency EPAWashington, DC 20460 Completion Form For Injection Wells Administrative Information 1. Permittee BP Exploration (Alaska) Inc. Address (Permanent Mailing Address) (Street, City, and ZIP Code) 900 E Benson Blvd. Anchorage, AK 99508 2. Operator BP Exploration (Alaska) Inc. Address (Street, City, State and ZIP Code) 900 E. Benson Blvd. Anchorage, AK 99508 3. Facilitv Name Telephone Number Prudhoe Bay Pad 3 Disposal Facility 907-659-5893 (Environmental Advisor) Address (Street, City, State and ZIP Code) c/o Environmental Advisor Central BP Exploration (Alaska) Inc. P.O. Box 196612, Anchorage, AK 99516 4. Surface Location Description of Injection Well(s) State County Alaska North Slope Borough Surface Location Description SW 1/4 of N W 1/4 of NE 'I/4 of NE 1/4 of Section I I Township I ON Range 14E Locate well in two directions from nearest lines of quarter section and drilling unit Surface Location 651 ft. frm (NIS).N Line of quarter section and 10N21 ft. from (E/W) N Line of quarter section. Well Activity Well Status Type of Permit X Class I _ Operating X Individual Class II X Modification/Conversion Area : Number of Wells _ Brine Disposal Proposed Enhanced Recovery Hydrocarbon Storage _ Class III Other Lease Number ADL 028311 Well Number OWDW-C Submit with this Completion Form the attachments listed in Attachments for Completion Form. 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.) am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment (Ref. 40 CFR 144.32) Name and Official Title (Please type or print) Signature ,' Date Signed Gary Crawford, Logistics & Infrastructure Manager j/iS� I/ EPA Form 7520-9 (Rev. 12.11) V Prudhoe Bay Unit, OWDW-C Workover to Replace Tubing December 2013 A workover was performed in Class I disposal well OWDW-C to install tubing. The well had never been perforated or been used for disposal. All other well specific information contained in the June 2009 Class I UIC permit application and Supplemental Information submitted 06/30/09 was unchanged. The following information is submitted to satisfy Completion Form for Injection Wells, EPA Form 7520-9, Attachments II 1 and I13. Old tubing None Old packer: None Well Fluid: Glycol New tubing: 2-7/8" OD, 6.5 #/ft, L-80, lined with Polycore HDPE New Packer: 5-1/2" HES BWD set at 1917' MD RKB (rig measurement) Annulus Fluid: Diesel The packer placement was within the interval specified in UIC Class I Permit AK -11004-B, Part 11, A.2, as clarified by the OWDW-C Checklist dated 12/04/13. The packer was set on 12/27/13 at 1917 ft RKB as measured by the workover rig. The packer placement was verified by EPA representative Thor Cutler. An annulus pressure test to 2150 psi was performed on 12/29/13 after the tubing was run as specified in the permit Part II C.3.c. This test was witnessed telephonically by EPA representative Thor Cutler. Attached is a copy of the Alaska Oil and Gas Conservation Commission, Report of Sundry Well Operations (Form 10-404) containing the details of the workover operations and an updated wellbore schematic. The annulus pressure test was repeated on 03/24/14 prior to initiating disposal injection. EPA and AOGCC were notified of the repeat test. A complete report on this work is included with this report. Mechanical Integrity Test Results Prudhoe Bay Unit, OWDW-C UIC Class I Permit AK -1I004-13, Part II C.3.b (1) states: "In order to demonstrate there is no significant leak in the casing, tubing or packer, the tubing/casing annulus (inner annulus) will be pressure tested upon initial completion to at least 1500 pounds per square inch gauge (psig) for not less than 30 minutes. Pressure must show a stabilizing tendency.... This initial standard annulus pressure test (SAPT) will be required upon completion of the well and prior to the well first being placed on injection...." An annulus pressure test (aka mechanical integrity test, MIT) was performed on Class I Pad 3 disposal well OWDW-C on December 29, 2013 after the tubing and packer were installed. The test was performed in accordance with the above stipulations. The tubing/casing annulus was fluid packed with diesel. The annulus was then pressured to above 1500 psi with diesel and observed for 30 minutes. The test was conducted while the subject well was shut in and the workover rig was still on the well. The test was witnessed telephonically by EPA representative Thor Cutler. The results of the test were as follows: Tubing Pressure Pad 3 Well Start / End OWDW-C 1410/1410 Annulus Pressure psi 1 st Half 2nd Half Start 15 Min 30 Min Decline Decline 2150 2020 2000 130 20 Test Result Passed A second MIT was conducted on March 24, 2014 prior to starting disposal injection. The test was performed in accordance with the above stipulations. The tubing/casing annulus was fluid packed with diesel. The annulus was then pressured to above 1500 psi with diesel and observed for 30 minutes. The test was witnessed by AOGCC Inspector Bob Noble. The results were: Tubing Pressure Annulus Pressure psi 1 st Half 2nd Half Test Pad 3 Well Start / End Start 15 Min 30 Min Decline Decline Result OWDW-C 185/185 1800 1673 1655 127 18 Passed In both tests, 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 -B, Part II, C 3 b (1). Annulus pressures were observed on a test gauge and chart. During the test period, the tubing pressure was essentially constant in both tests. I conclude from the successful MIT that the casing, tubing and packer in well OWDW-C are in sound mechanical condition. Michael L. Bill, PE March 24, 2014 (: 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 I Permit No. PTD No. BP Alaska - Prudhoe Bay Unit, PAD 3 OWDW-Center 1002420 Injector MIT Type Test Type Test Date Class I T X IA I Std. Annular Pressure Test (SAPT) 12/29/2013 Req'd Test Fluid Type(s) used to Packer Depth (ft, Test Interval /Comments Presssure (psi) test TVD) 0 1,500 Diesel 1,900.79' 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: PRE MITI RECORDED PRESSURES (PSI) INITIAL 1 15 MIN 30 MIN 45 MIN 1 60 MIN RESULT P S TUBING 0 2250 2100 2080 T INNER ANNULUS 0 90 90 90 OUTER ANNULUS 1 COMMENTS: Pre Injection Tubing Test performed on rig T E START TIME: PRE MITI RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 45 MIN 60 MIN RESULT S T TUBING 1200 1410 1425 1410 P INNER ANNULUS 0 2150 2020 2000 OUTER ANNULUS 2 COMMENTS: Pre Injection Casing Test performed on rig Bled tubing from 2080 to 1200 psi for IA MIT. T E START TIME: PRE MIT RECORDED PRESSURES (PSI) INITIAL 15 MIN 30 MIN 1 45 MIN 1 60 MIN RESULT S TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 3 COMMENTS: RISC COMMENTS: Depths are correlated to Reservoir Saturation Log performed on 04/22/2012. .09 bbls to pressure up tubing/.1 bbls total bled back .28 bbls to pressure up IA/ .3 bbls bled back total 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) loss exceeds 10% 2) Loss during last 15 minute period = or > 50% of loss during first 15 minute period then extend the test 30 minutes to demonstrate stabilization (thermal effects). 0 0 — E-mail this MIT Test Data Form to EPA Region 10 - Thor Cutler EPA Rep: AOGCC Rep: Operator Rep: Thor Cutler Mike Alexander STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(@alaska.goy AOGCC.Insoectors(aalaska.gov; phoebe brooksc alaska.gov chris.wallace(cbalaska.aov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay/PBU/Pad 3 DATE: 03/24/14 OPERATOR REP: Jack Disbrow AOGCC REP: Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well OWDW-C I Type Inj. I N TVD 1,917' Tubing 185 185 185 185 Interval D P.T.D. 1002420 I Type test I P Test psi 1500 Casing 0 1,800 1,673 1,655 P/F P Notes: Post RWO OA Pumped 21 gals of diesel 0958 Well I I Type Inj. I I TVD Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA Well I Type Inj. TVD Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA Well Type Inj. I TVD Tubing Interval P.T.D Type test Test psi Casing P/F Notes: OA Weil Type Inj. TVD I Tubing Interval P.T.D. Type test Test psi I Casing —4—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 11/2012) MIT PBU OWDW-C 03-24-13.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance 0 = Other (describe in notes) Fluid Movement Logging Procedure Prudhoe Bay Unit, OWDW-C Background EPA permit AK- 11004-B (Part II C 3 b (2)) effective December 08, 2009 requires: "... Fluid movement/confinement logs will be run initially upon completion of the well and prior to initiation of injection at start-up....". The procedure used was very similar to that used in previous tests in the other OWDW wells. 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 is present 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 -1I004 -B requires a fluid movement test "... be conducted at an injection pressure at least equal to the average continuous injection pressure observed in the previous 6 months ...". Since there has been no disposal injection into OWDW-C, a typical maximum injection pressure in the other OWDW wells was used to set the target of 1000 psi for this test. Wellhead pressures exceeded 1000 psi well during the high rate pumping (5 barrels per minute) of borax solution. - The injection rate was reduced to less than 1 bpm 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 (2.0" ID in 2-7/8" tubing with Polycore liner). - The general survey procedure involved the following steps: run baseline temperature and first baseline RST log pump 100 barrels hot water at high pump rate run second RST baseline pass at minimum pump rate pump 30-40 barrels hot borax -water solution at high pump rate run RST pass at minimum pump rate pump 30-40 barrels hot borax -water solution at high pump rate run RST pass at minimum pump rate pump 15 barrels hot water at low rate to flush wellbore run final RST pass, minimum pump rate Fluid Movement Logging Results Prudhoe Bay Unit, OWDW-C Borax-PNL Survey Procedure On 0211/14 slick line operations verified access in the Center well to 2034 feet MD. This is below the perforations and assured sufficient interval was available to perform the survey. Borax-PNL Survey Results — reference OWDW-C Schlumberger Reservoir Saturation Log, 25 - February -2014. The depths referenced below refer to the Borax -RST log. The log trace includes pertinent individual passes. Each pass was run from above the perforations to above 1400 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 (CCL), formation sigma (capture units), borehole sigma (capture units). - "Baseline 1 / Baseline 2 Sigma Overlay". A baseline sigma was run prior to pumping any fluid with diesel in the well. A second baseline sigma pass was run after pumping about 100 barrels of hot water. The two baseline passes overlayed well showing the statistical variation in the formation sigma of up to about 1 chart division. Baseline Pass 2 was used for comparison to subsequent passes. - "Baseline 2 / Borax 1 Sigma Overlay". This overlay shows the change in tool response between a baseline pass and the pass run after pumping the first stage of borax solution at 5 bpm. 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 (IA to % chart division) due to the small volume of borax solution surrounding the tool while it is in the tubing (Tubing with Liner ID=2.0", 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 be 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. No significant upward movement of borax solution exterior to the wellbore was noted. - "Baseline 2 and Borax 2 Sigma 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. - "Baseline 2 / Flush Pass Sigma 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 near baseline levels indicating the boron laden fluid had been flushed from the wellbore. There is no significant change in the formation sigma. 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 upward movement of injected fluids above the bottom of the logged interval. Baseline Temperature/Pressure Survey - shown on log trace "Baseline Temp / Press Pass", reference OWDW-C Schlumberger Reservoir Saturation Log, 25 -February -2014. - The baseline temperature pass was run about 11 days after an injectivity test to provide a basis for comparison should additional temperature passes be necessary. - Shut In temperature passes were not required due to the clear results from the Borax -RST passes. Overall Conclusions 1. There is no indication of channeling upward 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 surveillance in the other active OWDW wells 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 tests indicate the tubing, casing above the packer, and the exterior part of the well are hydraulically sound. Michael L. Bill, P.E. March 24, 2014 OWDW-C Class I Disposal Well Completion Checklist (Draft, November 4, 2013) Completion Checklist Witness Date Documentation 1 Injection Zone: Identify top from available logs Thor Cutler 12/15/ Schlumberger (reference Type Log Northwest Well, Datum = GL, Exhibit 1-8A Pad 3 Class 1 2013 Compensated Application, June 2009, based on Schlumberger Gamma Ray CCL log 07/31/73) Neutron Log OWDW-C correlative depth: 1924' MD RKB, Schlumberger Compensated 06/20/73 Neutron Log 06/20/73 2 Injection Casing: Verify casing condition and cement across injection zone to base Thor Cutler 12/15/ PDS Caliper Log of confining zone. Caliper and MSIP casing inspection logs, and USIT and CBL 2013 04/17/12, cement bond logs submitted to EPA 10/08/13. Per EPA correspondence Kowalski Schlumberger MSIP to Fontaine dated 10/23/13, "... EPA has determined well OWDW-C meets the Log 04/23/12, casing and cementing requirements per the permit (Part Il A.1.)." Schlumberger USIT Log 04/23/12, US1/CBL Evaluation 3 Injection Packer Depth: Set no shallower than ,100 feet MD above injection zone Thor Cutler 12/28/ 1916.79 drill pipe 2013 measurement 1900.79 log set depth (md RKB) 4 Internal Mechanical Integrity Test (Tubing/Casing/Packer) > 1500 psig Thor Cutler 12/29/ (will also test tubing hanger seals) 2013 5 External Mechanical Integrity Test (Fluid Movement Test) Thor Cutler 03/05/ Schlumberger Borax 2014 Lo Indicators to Assist Communications — OWDW-C Rig Workover, UIC Class I Permit AK -1I004 -B 1: Injection Zone: Identify top from available logs (Part II C 4) Top of the injection zone has been determined from open hole electric line log Schlumberger Compensated Neutron Log 06/20/73 by correlation with OWDW-NW logs and Exhibit 1-8A Type Log Northwest Well from the Pad 3 Waste Disposal Class I Renewal Application dated June 2009. Top of injection zone (base of confining zone) is 1924' MD RKB. 2. Injection Casing: Verify casing condition and cement across injection zone to base of confining zone. (Part II A 1) and Schlumberger's MSIP ultrasonic tool (04/23/12). Logs submitted to EPA on 10/08/13 showed a short interval of axial Casing condition was inspected using PDS 24 arm memory caliper log (04/17/13)displacement at about 1000 feet, but otherwise good casing condition . The axial displacement has not affected casing pressure integrity. Cement quality was determined by the USIT and CBL bond logs, also submitted to EPA on 10/08/13. Schlumberger's analysis of the bond logs shows intervals of zonal isolation (good cement bond) across the injection and confining zones to 1861' MD, above the top of the confining zone. Per EPA correspondence Kowalski to Fontaine dated 10/23/13, "... EPA has determined well OWDW-C meets the casing and cementing requirements per the permit (Part II A.1.). Acceptance criteria are defined by the following: • 50 ft of bonded cement, not necessarily continuous but containing one zone of continuous bond 15 ft or more from the 5-1/2" casing shoe -to the top of the confining zone. (Top of confining zone is 1868' MD). • USIT cement parameters set for 15.0 lb/gal Permafrost II Cement, in place since 1973. • `Bonded Cement' is defined as any interval which demonstrates an Impedance (Z) value greater than 2.6 Mrayls. Any degree of shading, as represented by the USIT log by comparing the Impedance (Z) values, will be considered to have cement bond capable of providing zonal isolation • USIT tests can be run with casing pressure but casing pressure should not exceed 1000 psi. the 4/23/13 log was run with zero psi casing pressure. 3. Injection Packer Depth: Set no shallower than 100 feet MD above injection zone (Part II A 2) Injection packer setting location will be confirmed by the tubing tally. The packer is to be placed no shallower than 100 feet MD above the top of the permitted injection interval. Top of injection zone (base of confining zone) is 1924' MD RKB. Target packer depth will be 1906' MD RKB. 4. Internal Mechanical Integrity Test (Tubing/Casing/Packer) >1500 psig (Part II C 3 b (1)) Acceptance criteria is defined as a positive pressure test of the 2-7/8" tubing x 5-1/2" casing annulus to above 1500 psi for 30 minutes Pressure shall show a stabilizing tendency. During the test period, the pressure shall not decline more than 10% and shall experience less than 1/3 of its total loss in the last half of the test period. If the total loss exceeds 10% or if the loss during the second 15 minute period is equal to or greater than one half of the loss during the first 15 minutes, the test period may be extended for an additional 30 minutes to demonstrate stabilization. At the time of the test, the tubing pressure shall be significantly lower than the annulus pressure. 5. External Mechanical Integrity Test (Fluid Movement Test) (Part II C 3 b (2)) Acceptance criteria is defined as an approved fluid movement tests which reveal no fluid movement above the top of the injection zone (base of confining zone) at 1924' MD RKB. Movement above the base of the confining zone may indicate a failure to demonstrate external mechanical integrity, requiring additional diagnostics and/or alternate logs or procedures. Approved fluid movement tests include, but are not limited to, tracer surveys, temperature logs, noise logs, oxygen activation/water flow logs (WFL), borax pulse neutron logs (PNL), or other logs. The survey must be at the maximum injection pressure anticipated during injection activities or the maximum rate and pressure obtained by pumping equipment available on site. (Injection pressures during normal injection activities are estimated to be 1000 psi or less.) The above list has been prepared to enhance communication between EPA and BPXA. It does not modify permit number AK -1I008 - A, nor does it relieve BPXA of its obligation to comply with all terms and conditions of the permit. TREE = BLIND FLANGE ONLY WELLHEAD = FMC - -- — _._._v_._.E2_ ACTUATOR= BAKHC OKB- ELEV = 56.5' BF. ELEV = OprVSgz SHOT 0 Max Angle = 0 Detum MD = ------M _ 0 DetumTVD= - -- 8800' SS j__" CONDUCTOR, I--� ? 13-3/8' CSG, 72#, N-80, D = 12.347' 1 100' Minimum ID = 1.791" @ 1945' 2-3/8" HES XN NIPPLE OWDW-C SAFETY NOTE "POLY CORE TBG - RESTRICT SHARP EDGES AND REDUCE RLMNG SPEED TO 200'/MN AND FLUIDS TO 150'F"OLY WASTE DISPOSAL WELL. CONTACT MI<E BLL PRIOR TO DOING ANY DOWNHOLE WORK LOWER FLANGE ON CSG SPOOL IS RATED TO 2000 PSI ONLY "' 3-1/2" OTIS TRS CAP CONNECTION — 564' -13/8' CONTROL LINES, OPEN ENDED w /CHECK V LV S 1864' 1-12-3/8" HES X NP, ID = 1.875" 1918' -SEAL LOC SUB, D = 2.441" 1917' 5-1/2' X 2-3/4' HES BWD PKRw/2.75' 2-718' TBG, 6 5#, L-80 8RD w /HDPE 1928' j SEA LBORE, D= 2 750" 0058 bpf, D = 2.00'1928' 2-7/8' SEALSTEM w /WLEG, D = 1.920" 2-7/8" TBG, 6.5#, L-80 8RD,1--tj949' - 1980' .0058 bpf, ID = 2.441" 2-7/8" TBG, 6.5#. L-80 8RD w /HDPE 198T 0058 bpf, D = 2.00' PERFORATION SUMMARY Rff LOG- ON XX/XX/14 ANGLE AT TOP PERF- 0-@2006' Note. Refer to Production DB for historical pert data SIZE I SPF INTERVAL OprVSgz SHOT SQZ 3-318" 6 2006-2030 O 02/11/14 PBTD 2214' 5-1/2" CSG, 17#, "0, 0232 bpf, D = 4 892' 225W 1945' —12-3/8' HES XN NP, D = 1.791" 1946 - 194T 2-7/8" LONG SHOT DEBRIS SUB 1982' —j2 -7/6 -WL ELMD TT NOT LOGGED 2071' —1 PERF BAR AND FRED GUNS (02/11/14) PRUDHOE BAY UNIT WELL: OWDW-C PERPAT No 1002420 API No. 50-029-21821-00 SEC 11, T10R R14E, 646 PTL 8 1048' PTL DATE REV BY COMMENTS DATE REV BY CONMENTS 06/23/73 INITIAL COMPLETION 02/17/14 DW/JMD PULL PXNDROPPED PERF BAR (0 12/19/98 SLICKLNE LAST TAG DATE i 03/06/14 M3/JMD CORRECTED PBTD/ADD PERF BOX 12/30113 D-14 RWO 01/08/14 JMD DRLG HO CORRECTIONS 01/14/14 CR/JMD 1FTWLODE APPROVAL BP Exploration (Alaska) 01/17/14 MB/JMD I ADDED LONG SLOT DEBRIS SUB STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ® Perforate ® Re -Enter Suspended Well ❑ Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate -Other ❑ Time Extension Run Tubing 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service 100-242 3. Address: 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519-6612 50.029-21821-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 028311 PBU OWDW-C 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field/ Pool(s): Prudhoe Bay / Prud Undefined WDSP 11. Present well condition summary: Total depth: measured 2250' feet Plugs: (measured) None feet true vertical 2250' feet Junk: (measured) 2071' feet Effective depth: measured 2147' feet Packer: (measured) 1917' feet true vertical 2147' feet Packer: (true vertical) 1917' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 13-3/8" 100' 100' 4930 2670 Surface 2250' 5-1/2" 2250' 2250' 7740 6280 Intermediate Production Liner Perforation Depth: Measured Depth: 2006'- 2030' feet True Vertical Depth: 2006'- 2030' feet Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 1982' 1982' Packers and SSSV (type, measured and true vertical depth): 5-1/2" x 2-3/4" HES BWD Packer 1917' 1917' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description 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: ❑ Copies of Logs and Surveys run 15. Well Class after work: El [IStratigraphic ❑ Development ® Service ® Daily Report of Well Operations 16. Well Status after work: ❑ Oil El Gas ® WDSPL ® Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ 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: Cody Rymut, 564-4398 Email: Cody.Rymut@bp.com 313-502 Printed Name: Joe Lastufka Title: Drilling Technologist Signature: Phone: 564-4091 Date: Form 10-404 Revised 10/2012 Submit Original Only -PREP PITS FOR RECIEVING FLUID. "SIMOPS: WORK ON MP -2'S AS EQUIPMENT 'IS BEING PUT BACK TOGETHER. -RIG ACCEPTED AT 03:00 12/25/2013. 03:00 - 10:00 7.00 RIGD N WAIT PRE WAIT ON ADAPTER FLANGE. -WORK ON MP -2 WORK ORDERS. -PERFORM TABLE TOP CAMP EVACUATION i 'DRILL. -NO ADAPTER FLANGE WAS LOCATED ON THE SLOPE. DECISION TO MAKE ONE WAS MADE BY TOWN AND FIELD SUPPORT. *FMC DEVELOPING PLAN ON TURNING A GEN IV ADAPTER FLANGE INTO A DSA FOR 2M --- ---------- -- - - - -- ____' WELLHEAD. -------- - ---- - ------ 10 00 - 14:00 4.00 RIGU P PRE YEAR END DISCUSSION. -GATHER UP CREW AND DISCUSS END OF YEAR PERFORMANCE OF RWO TEAM (HELD DISCUSSION WITH BOTH CREWS). � 1 i -CONDUCT CHRISTMAS GATHERING AT RIG CAMP TO ALLOW RIG PERSONNEL TIME TO - -- ____ _..__---_ __.----------------.- - CONTACT FAMILY. Printed 2/24/2014 11.4715AM North America - ALASKA - BP Page 1 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: 0,670,000.00 ) Project: Prudhoe Bay (various) Site: PB OWDW Rig Name/No.: DOYON 14 Spud DateMme: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. UWL 500292182100 Active datum: 1 : C 5/1811973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs —Task Code NPT NPT Depth Phase Description of Operations - - --- - - -- - (hr) - - - -- --- --- - (usft) - --- --- ----- - - -- - -- 12/24/2013 • 19:00 - 20:00 1.00 RIGD P PRE SKID RIG FLOOR INTO MOVING POSITION. _PJSM. -SKID RIG FLOOR INTO MOVING POSITION. 120:00 - 21:00 1.00 RIGID P PRE 'MOVE RIG OFF OF WELL. -PJSM. -PLACED ALL SPOTTERS INTO POSITION. -MOVE RIG OFF OF OWDW-NW WELL. '21:00 - 22:00 1.00 RIGID P PRE MOVE RIG ONTO NEW WELL. -PJSM. -MOVE RIG ONTO OWDW-C WELL. `FUNCTION ESD ON MOVING SYSTEM BEFORE FINAL PLACEMENT. ESD 'FUNCTIONED PROPERLY. 22:00 - 23:00 1.00 RIGID P PRE SHIM RIG. -PJSM. -SHIM AND LEVEL RIG. 23:00 - 00:00 1.00 RIGID P PRE SKID RIG INTO POSITION. -PJSM. -SKID RIG INTO DRILLING POSITION. 12/25/2013 00:00 - 01:00 1.00 RIGU P PRE RIG UP AROUND RIG. -SECURE RIG. -COVER WELL CELLAR WITH BOARDS. -PUT UP HAND RAILS AND ANTI-SKID PLATES AROUND RIG. — 101:00 - 03:00 2.00 RIGU P PRE RIG UP. -PJSM. -RIG UP HIGH PRESSURE LINES UNDER RIG 'FLOOR. -RIG UP AIR, STEAM AND WATER LINES TO RIG FLOOR. -RIG UP BEAVER SLIDE. -RIG UP CHOKE MANIFOLD ON RIG FLOOR. -SPOT ROCKWASHER AND RIG UP. -SPOT LUNCH SHACK. -PREP PITS FOR RECIEVING FLUID. "SIMOPS: WORK ON MP -2'S AS EQUIPMENT 'IS BEING PUT BACK TOGETHER. -RIG ACCEPTED AT 03:00 12/25/2013. 03:00 - 10:00 7.00 RIGD N WAIT PRE WAIT ON ADAPTER FLANGE. -WORK ON MP -2 WORK ORDERS. -PERFORM TABLE TOP CAMP EVACUATION i 'DRILL. -NO ADAPTER FLANGE WAS LOCATED ON THE SLOPE. DECISION TO MAKE ONE WAS MADE BY TOWN AND FIELD SUPPORT. *FMC DEVELOPING PLAN ON TURNING A GEN IV ADAPTER FLANGE INTO A DSA FOR 2M --- ---------- -- - - - -- ____' WELLHEAD. -------- - ---- - ------ 10 00 - 14:00 4.00 RIGU P PRE YEAR END DISCUSSION. -GATHER UP CREW AND DISCUSS END OF YEAR PERFORMANCE OF RWO TEAM (HELD DISCUSSION WITH BOTH CREWS). � 1 i -CONDUCT CHRISTMAS GATHERING AT RIG CAMP TO ALLOW RIG PERSONNEL TIME TO - -- ____ _..__---_ __.----------------.- - CONTACT FAMILY. Printed 2/24/2014 11.4715AM Panted 2,24/2014 11:47:15AM North America - ALASKA - BP Page 2 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00 ) Site: PB OWDW Project: Prudhoe Bay (various) Rig Name/No.: DOYON 14 Spud Datefrime: 6/18/1973 12:00:00AM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. UW: 500292182100 Active datum: 1 : C 6/18/1973 00:00 (M56.50usR (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations _ - -i-4:6-0 shr) -- ------ ---------�use�- -_.—. _------ — -- - - 23:00--- 9.00 RIGU N WAIT PRE WAIT ON ADAPTER FLANGE. -WORK ON MP -2 WORK ORDERS. -PREP FOR NIPPLE DOWN AND BOP TEST. 'DSA PLAN APPROVED AND SENT TO BAKER --- - -- ----- --------�-- - - MACHINE. 23:00 - 00:00 1.00 RIGU P PRE PERFORM RIG H2S EVAC DRILL. -PERFORM H2S EVACUATION DRILL. -CONDUCTED AFTER ACTION REVIEW WITH ALL HANDS. -DISCUSSED THE PARTICULARS ON THE WELL WITH THE RIG CREW. 'BAKER MACHINE FINISHING DSAAS PER DRAWING FROM FMC. 12/26/2013 00:00 - 02:00 2.00 RIGU N WAIT PRE WAIT ON ADAPTER FLANGE. -PREP FOR BOP TESTING. -READY 2 7/8" TEST JOINT, FOSV, DART VALVE. -WORK ON MP -2'S. -LOAD PIPE SHED WITH 2 7/8" TUBING FOR DRIFT/TALLY. 'BAKER MACHINE FINISHING DSAAS PER __ DRAWING FROM FMC. 02:00 02:30 0.50 RIGU P PRE PERFORM RIG H2S EVAC DRILL. -PERFORM H2S EVACUATION DRILL. -CONDUCTED AFTER ACTION REVIEW WITH ALL HANDS. -DISCUSSED THE PARTICULARS ON THE WELL WITH THE RIG CREW. *7-1/16"5M X 7-1/16"2M DOUBLE STUDDED ADAPTER ARRIVED ON LOCATION. 02:30 - 04:00 1.50 WHSUR P WHDTRE NIPPLE DOWN TREE. -PJSM. -BLEED PRESSURE OFF OF HANGER VOID -NO PRESSURE. -NIPPLE DOWN DRY HOLE TREE. -CHECK THREADS ON CROSSOVER FOR PULLING HANGER -9 FULL TURNS. ,04:00 - 07:30 3.50 BOPSUR P PRE NIPPLE UP 13-5/8"5M BOPE. -PJSM. -NIPPLE UP 7-1/16" 5M X 7-1/16" 2M DOUBLE STUDDED ADAPTER. -NIPPLE UP 7-1116" 5M X 13-5/8" 5M SPOOL. j -NIPPLE UP BOPE STACK CONFIGURED WITH 2-7/8" FIXED RAMS IN UPPER PIPE RAMS AND 2-7/8"X 5" VBR IN LOWER PIPE RAM. i -CENTER STACK WITH TURNBUCKLES. - — —- 07:30 - 09:30 2.00 BOPSUR P PRE i RIG UP TO TEST BOP'S. -RIG UP 2-718" TEST JOINT, 2-7/8" FOSV AND DART TO TEST. -FILL STACK -TEST MGS FOR FILL -TOOK 6 BBLS. -TEST RIG ESD SYSTEM. i 09:30 - 14:30 5.00 BOPSUR P PRE i TEST BOPE. I -PJSM. -TEST BOPE TO 250 PSI LOW, 2000 PSI HIGH FOR 5 MINUTES EACH. -TEST WITH 2-7/8" TEST JOINT. -ALL TESTS CHARTED -SEE ATTACHED BOP TEST CHARTS. -TEST WITNESS WAIVED BYAOGCC REP. LOU GRIMALDI. Panted 2,24/2014 11:47:15AM North America - ALASKA - BP Operation Summary Report Page 3 of 10 Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00 ) Project: Prudhoe Bay (various) Site: PB OWDW Rig NameMo.: DOYON 14 Spud DateRme: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 14:30 - 15:00 0.50 BOPSUR P PRE RIG DOWN FROM TESTING BOPE. -BLOW DOWN CHOKE AND CHOKE MANIFOLD. -BLOW DOWN KILL LINE. -RIG DOWN TESTING TOOLS. -CLEAR RIG FLOOR OF ALL TOOLS NOT NEEDED FOR UPCOMING OPETATIONS. 15:00 - 15:30 0.50 RIGU P PRE INSTALL BALES ON TOP DRIVE. --~15:30 - 16:30 16:30 -- 19:30 19:30 - 21:00 -PJSM. -PICK UP AND INSTALL SHORT BALES ON TOP DRIVE. 1.00 RIGD P PRE INSTALL DUTCH RISER. -PJSM. -PICK UP AND INSTALL DUTCH RISER FOR BPV LUBRICATOR INSTALLATION. 3.00 RIGD N SFAL PRE FRONT END LOADER PROBLEMS. HYDRAULICS ON FRONT END LOADER FROZE UP. -COVERED UP WITH TARP AND APPLIED HEAT WITH AIR HEATER TO TRY TO THAW OUT HYDRAULICS. -NOT SUCCESSFUL -SECURED FRONT END LOADER FROM CAMP AND USE IT. 1.50 RIGD P PRE PICK UP AND RIG UP LUBRICATOR. -PJSM. -PICK UP TWC RETRIEVAL TOOLS AND LUBRICATOR FROM GROUND THRU BEAVER SLIDE. -BRING UP EXTENSIONS AND CONTROL LINES FOR LUBRICATOR. -RIG UP ON DUTCH RISER WITH 21 00 - 21 30 0.50 RIGD P PRE PRESSURE TEST LUBRICATOR -PRESSURE TEST LUBRICATOR TO 250 PSI LOW/2000 PSI HIGH FOR 5 MINUTES EACH, 21 30 - 22.30 1.00 WHSUR P WHDTRE PULL TWC. -PJSM. -CHECK FOR PRESSURE UNDER TWO WAY CHECK WITH IA VALVES -NO PRESSURE. -PULL TWO WAY CHECK VALVE INTO BOP STACK. -ENSURE NO PRESSURE ON WELL BEFORE PULLING LUBRICATOR -NO PRESSURE. -PICK UP AND PULL LUBRICATOR. -CLOSE BLIND RAMS TO SECURE WELL. 22 30 - 00:00 1.50 WHSUR P WHDTRE RIG DOWN LUBRICATOR -RIG DOWN LUBRICATOR AND EXTENSIONS. -MOBILIZE SAME OFF OF RIG FLOOR. -RIG DOWN DUTCH RISER. 12/27/2013 00:00 - 01:00 1.00 PULL P DECOMP 'PULL HANGER. -RIG UP LANDING JOINT TO HANGER. -BACK OUT LOCKDOWN BOLTS. -PULL HANGER AND INSPECTED (SINGLE PORT). 01:00 - 02:00 1.00 PULL P DECOMP RIG UP TONGS FOR 2-7/8" PAC PIPE. -PJSM. -PICK UP 2-7/8" TONGS TO RIG FLOOR THRU BEAVER SLIDE. -PICK UP HANDLING EQUIPMENT TO RIG FLOOR THRU BEAVER SLIDE. -MAKE UP AND TEST POWER TONGS. Pnnted 2/24/2014 11:47:15AM Printed 2/24/2014 11:47-15AM North America - ALASKA - BP Page 4 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type. WORKOVER (WO) Start Date: 12/24/2013 End Date. 12/29/2013 X3 -0140Q -C: (1,670,000.00 ) Project: Prudhoe Bay (various) Site: PB OWDW Rig Name/No.: DOYON 14 Spud Date/Time: 6/18/1973 12:00 OOAM Rig Release: 12/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) ----- - ----- ------------ ----_...-------------- Date From - To Hrs Task Code NPT NPT Depth Phase --------------------- Description of Operations 02:00 - 02:30 0.50 PULL P DECOMP MAKE UP RBP RETRIEVAL HEAD. -PJSM. -PICK UP AND MAKE UP RSP RETRIEVAL HEAD. 02:30 - 03:30 1.00 PULL P DECOMP RIH WITH RBP RETRIEVAL TOOL ON 2-7/8 HT -PAC PIPE. -RUN IN HOLE ON ELEVATORS WITH STANDS FROM THE DERRICK. -PICK UP SINGLE FROM PIPE SHED, ATTACH FOSV TO TOP, THEN ATTACH SECOND JOINT 03:30 - 04:00 0.50 PULL P DECOMP PULL BAKER 5.5" RBP. -ESTABLISH PARAMETERS AT 495': PUW= 62K, SOW --58K. -TAG RBP AT 538'. -EQUALIZE ACROSS RBP BY SETTING DOWN 3K AND SHEARING EQUALIZING SLEEVE. -MONITOR FOSV AND WELL FOR FLOW -NO FLOW OBSERVED. -PULL UP V AND SHEAR KEEPERS ON DOGS. -WAIT 15 MINUTES FOR ELEMENTS TO RELAX/FLOWCHECK WELL -NO FLOW OBSERVED. -POOH 6' THEN SLACK BACK OFF PAST TAG POINT. ALL INDICATIONS ARE THAT THE PLUG IS ON THE RETRIEVAL TOOL. 04:00 0430 0.50 PULL P DECOMP POOH WITH RBP. -PJSM. -POOH ON ELEVATORS STANDING BACK DRILL PIPE WITH RETRIEVABLE BRIDGE PLUG. -POOH FROM 538' TO SURFACE. LAY DOWN RBP AND RETRIEVAL TOOL. 04:30 - 07:00 2.50 CLEAN P DECOMP MAKEUP CLEANOUT ASSEMBLY. -PICK UP AND MAKE UP CLEAN OUT ASSEMBLY WITH 4-3/4" MILL AND 5-1/2 _ _ _ ----...------------- -- ! -._ _ ..__ ------:C ASINGSCRAPER. 07:00 - 07:30 0.50 CLEAN P DECOMP RIH WITH CLEANOUT BHA ON 2-7/8 HT -PAC PIPE. -SCRAPE FROM 1880' TO 1,930' WITH 5-1/2" SCRAPER, PUW= 73K SOW= 75K. -RUN IN HOLE TO 214T.- 14T.07:30 07 30- 08:30 1.00 CLEAN P DECOMP ATTEMPT TO WASH DOWN PAST 2,147'. -PUW= 73K, SOW --75K, ROT WT=75K AT 6BM WITH 750 PSI. BEGIN MILLING OPERATIONS. -BEGIN MILLING WITH 40 RPM AND 1K TORQUE AND 5K WOB. -NOT MILLING OFF 'SIM -OPS -DISPLACE WELL WITH 8.5 SEAWATER. MONITOR WELL BEFORE POOH -WELL - ---- —=- STATIC. Printed 2/24/2014 11:47-15AM Printed 2/24/2014 114715AM North America - ALASKA - BP Page 5 of to Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 1 2/2 912 01 3 X3 -0140Q -C: (1,670,000.00) Projed: Prudhoe Bay (various) Site: PB OWDW Rig Name/No.: DOYON 14 Spud DateRme: 6/18/1973 12:00:00AM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations ------------- -- -�hr) _ -- -._.. - -- - �usft) - - ----—-------- -. ----- - - 08:30 - 11:30 3.00 CLEAN P DECOMP PJSM ON POOH AND LAYING DOWN 2-7/8". -BLOW DOWN TOP DRIVE. -POOH AND UD 2-7/8" DP FROM 2,147' TO 1,929'. -POOH AND STAND BACK 2-7/8" DP FROM 1,929' TO SURFACE. -MONITOR WELL BEFORE PULLING NONSHEARABLES THROUGH STACK WELL STATIC. 'SENT NOTICE TO MIT TUBING AND ANNULUS TO AOGCC AT 10:26 AM ON 12/27/2013. 11:30 - 12:00 0.50 CLEAN P DECOMP PJSM LAY DOWN CLEAN OUT ASSEMBLY. -BEAVERSLIDE OPERATIONS. 12:00 - 13:00 1.00 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR FROM CLEAN OUT BHA. "SPILL DRILL. 13 00 - 15:00 2.00 PERF P RUNCMP PJSM LOAD SLB PERF GUNS INTO PIPESHED. -BEAVERSLIDE OPERATIONS- PICK UP RUNNING EQUIPMENT TO RIG FLOOR. 15:00 - 17:30 2.50 PERF P RUNCMP MAKE UP PERF GUNS AND PACKER ASSY. -5-1/2" X 2-3/4" HES BWD PACER. -3.36" HSD PERF GUNS, SXAR-BA EXPLOSIVE AUTOMATIC RELEASE SYSTEM. -HDFBHF HYDRAULIC REDUNDANT FIRING SYSTEM. 17:30 - 19:30 2.00 PERF P RUNCMP RIH WITH PERF GUNS AND PACKER ASSY. - PJSM, RIH WITH PERF GUNS,'XN' NIPPLE WITH PXN PLUG (10' SLUGGITS DUMPED ON TOP OF PXN PLUG, TOP OF SLUGGITS C 1936), AND PACKER ASSY ON 2-7/8" PAC 19:30 - 20:30 1.00 PERF P RUNCMP SET HES 5-1/2" X 2-3/4" BWD PACKER. - PJSM, PU ONE JOINT OF PAC PIPE, MU XO TO TOP DRIVE. -PRESSURE UP TO 500 PSI AND ALLOW TO STABALIZE. -PRESSURE UP TO 2200 PSI, OVER PULL 8K TO SHEAR OFF, PICK UP 15'. -PRESSURE UP TO 3100 PSI TO SHEAR BALL SEAT. -CLEAR RIG FLOOR OF SLB TOOLS WHILE MONITORING WELL FOR FLOW. -TOP OF PACKER Q 1916.79' (DRILL PIPE MEASUREMENT), 1900.79' (LOG SET DEPTH). *PERF INTERVAL=2022' TO 2046' (DRILL PIPE MEASUREMENT), 2006' TO 2030 (LOG SET DEPTH) AT 6 SHOTS/FT. •'WHEN PERFORATION GUNS ARE FIRED AND RELEASED WLEG WILL BE AT 1982' (DRILL PIPE MEASUREMENT & 1966' LOG DEPTH -REFERENCE RESERVIOR - SATURATION LOG 4/22/2013) 20:30 - 23:30 3.00 PERF P RUNCMP l POOH WITH HES RUNNING TOOL ON 2-7/8" 1 PAC PIPE. -REMOVE TOP DRIVE AND XO AND BLOW DOWN SAME. -MOUSE HOLE ONE JOINT 2-7/8" PAC PIPE. -POOH WITH 2-7/8" PAC DRILL PIPE AND LAY DOWN TO PIPE SHED. Printed 2/24/2014 114715AM North America - ALASKA - BP Page 6 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00 ) Project: Prudhoe Bay (various) Site: PB OWDW Rig Name/No.: DOYON 14 Spud DateRme: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. UWI: 500292182100 Ac_t_ive datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level)_ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations --- — ---- jhq - 23:30 - 00:00 0.50 PERF P RUNCMP CLEAR RIG FLOOR - PJSM, RIG DOWN CASING TONGS -CHANGE OUT ELEVATORS TO 4" DP ELEVATORS 12/28/2013 -00:00 - 00:30 0.50 RUNCOM P RUNCMP RIG SERVICE. -LUBRICATE RIG. 00:30 - 02:00 1.50 RUNCOM P RUNCMP CLEAR RIG FLOOR. -PJSM ON LAY DOWN 4" DRILL PIPE IN THE MOUSE HOLE. 02:00 - 03:30 1.50 RUNCOM P RUNCMP RIG UP TO RUN 2-7/8" COMPLETION. 03:30 - 06:00 2.50 06:00 - 06:30 -RIG DOWN TOOLS AND EQUIPMENT. -MOBILIZE HANGER TO RIG FLOOR, DOUBLE CHECK PIPE TALLY. -MAKE UP LANDING JOINT ASSY, MOBILIZE SLB CONTROL LINE SPOOLER TO RIG - - ------ .._ - - - - - --------FLOOR_ - RUNCOM P RUNCMP RUN 2-7/8" 6.5# L-80 EUE POLYCORE TUBING AND SEAL ASSY. -PJSM. -RIH WITH 2-7/8" COMPLETION, MAKE UP SEAL ASSEMBLY AND "X" NIPPLE FROM SURFACE TO 1,380'. 0.50 RUNCOM P RUNCMP . INSTALL SLB CONTROL LINE (NTH 2 EA. 5 PSI CHECK VALVES) FROM MID JOINT ON JOINT #42. -3/8" CONTROL LINE SECURED WITH 3 STAINLESS STEEL BANDS. 06:30 - 07:30 1.00 RUNCOM P RUNCMP RUN 2-7/8"6.5# L-80 EUE POLYCORE TUBING AND SEAL ASSEMBLY. -RIH FROM 1,380' TO 1,928' INSTALLING CANNON CLAMP ON EVERY JOINT W/ 3/8" CONTROL LINE. 07:30 - 08:30 1.00 RUNCOM P RUNCMP 'OBTAIN PARAMETERS. PUW--63K, SOW-- 66K, CIRCULATE 1/2 BBL MINUTE WITH 40 PSI. -RIH, PRESSURE INCREASE TO 500 PSI WHEN ENTERED THE SEAL BORE AT 1921'. -SEALS ENGAGED WITH NO LEAKS. -PUMPS OFF, PRESSURE BLED OFF. -RIH TO NO-GO, CONFIRM NO-GO AGAIN 1931' (WLEG ON SEAL ASSEMBLY DEPTH). -TOP OF NO-GO AT 1919.64'. ,'SEE ATTACHED WORKBOOK FOR TUBULAR SUMMARY. 08:30 - 10:30 2.00 RUNCOM P RUNCMP SPACE OUT COMPLETION.. -BLOW DOWN TOP DRIVE. -LAY DOWN JOINT # 60, 59 & 58. -PICK UP & MAKE UP JOINT# 59. -MAKE UP HANGER. -SLB AND HES REP MAKE UP CONTROL LINE TO HANGER. -CONTROL LINE PORT ON TUBING HANGER TESTED TO 5000 PSI. -CONTROL LINE PORT ON HANGER IS 1/4. 3/8" CONTROL LINE WAS ASSEMBLED WITH REDUCER BUSHING TO HANGER. *TOTAL OF 17 CANNON CLAMPS W/ 34 PINS i RAN PLUS 3 SS BANDS. North America - ALASKA - BP Page 7 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00 ) Project: Prudhoe Bay (ou varis) Site: PB OWDW --- ...- - - --- - ----- - -- Rig Name/No.: DOYON 14 Spud DateTme: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. LIN: 500292182100 Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations Printed 2/24/2014 11AT15AM (usft) I_ _ ____ RUNCMP CLEAN UP TOOLS AND EQUIPMENT USED FOR COMPLETION AND LAY DOWN THE BEAVER SLIDE. -LITTLE RED SERVICE -SPOTTING INTO POSITION. RUNCMP RIG UP TO REVERSE CIRCULATE WELL WITH DIESEL. -LOWER COMPLETION STRING WITH HANGER BELOWANNULAR PREVENTER. -CLOSE ANNULAR PREVENTER. -RIG UP LRS. RUNCMP REVERSE CIRCULATE WELL WITH DIESEL. -PRESSURE TEST ALL LINES 250 PSI LOW/ 2500 PSI HIGH. -LINE UP TO REVERSE CIRCULATE, RETURNS AFTER PUMPING 1.5 BELS. -PUMP 45 BBLS AT 1.5 BPM WITH 250 PSI, 250 PSI MAX SEEN DURING REVERSE CIRC OUT, RUNCMP LAND TUBING HANGER. -VERIFY ZERO PRESSURE. -OPEN ANNULAR PREVENTER. -LAND HANGER WITH BOTTOM OF WLEG ON SEAL ASSEMBLY AT 1928.15' RKB AND 1912' LOG DEPTH. -FINAL PUW=63K, SOW --66K, DOYON 14 BLOCK WEIGHT=50K. -FMC RUN IN LOCK DOWN SCREWS. '-350 FT POUND TORQUE ON LOCK DOWNS AND GLAND NUTS. RUNCMP TEST 2-7/8" TUBING WITH RIG PUMPS. -PJSM, RIG UP TEST TUBING. -TEST TUBING 250 PSI LOW FOR 5 MINUTES = .4 BBLS. -TEST TUBING 2000 PSI HIGH FOR 30 MINUTES =1.1 BBLS. -BLEED PRESSURE TO 1000 PSI, FLUID RECOVERED -1/4 BBL. RUNCMP TEST INNER ANNULUS. -ATTEMPT TO LINE UP LRS TO TEST ANNULUS, -LINE FROM LRS TRUCK TO IA WAS FROZEN DUE TO SEAWATER IN HOSE FROM HANGER LANDING OPERATIONS AND NOT EVACUATING HOSE AFTER HANGER WAS LANDED. -PJSM WITH LRS AND CREW ON THAWING FROZEN HARDLINE. -BLOW DOWN CEMENT LINE, CALLED FOR SECOND HEATER AND WRAPPED HOSE TO LRS TRUCK. -CLEAR RIG FLOOR OF CASING TOOLS, CONTROL LINE SPOOLER. -LINE THAWED AND DISCONNECTED, LRS CIRCULATE LINE WITH METHANOL AND DIESEL TO THEIR TRUCK. - y*FIRE DRILL. t 0:30 - 12:00 1.50 RUNCOM P 12:00 - 13:00 — 1.00 -- RUNCOM - - p 13:00 14:30 1.50 RUNCOM P 14 30 - 15:00 0.50 RUNCOM P 15:00 - 17:00 2.00 RUNCOM P 17:00 - 00:00 7.00 RUNCOM N SFAL Printed 2/24/2014 11AT15AM (usft) I_ _ ____ RUNCMP CLEAN UP TOOLS AND EQUIPMENT USED FOR COMPLETION AND LAY DOWN THE BEAVER SLIDE. -LITTLE RED SERVICE -SPOTTING INTO POSITION. RUNCMP RIG UP TO REVERSE CIRCULATE WELL WITH DIESEL. -LOWER COMPLETION STRING WITH HANGER BELOWANNULAR PREVENTER. -CLOSE ANNULAR PREVENTER. -RIG UP LRS. RUNCMP REVERSE CIRCULATE WELL WITH DIESEL. -PRESSURE TEST ALL LINES 250 PSI LOW/ 2500 PSI HIGH. -LINE UP TO REVERSE CIRCULATE, RETURNS AFTER PUMPING 1.5 BELS. -PUMP 45 BBLS AT 1.5 BPM WITH 250 PSI, 250 PSI MAX SEEN DURING REVERSE CIRC OUT, RUNCMP LAND TUBING HANGER. -VERIFY ZERO PRESSURE. -OPEN ANNULAR PREVENTER. -LAND HANGER WITH BOTTOM OF WLEG ON SEAL ASSEMBLY AT 1928.15' RKB AND 1912' LOG DEPTH. -FINAL PUW=63K, SOW --66K, DOYON 14 BLOCK WEIGHT=50K. -FMC RUN IN LOCK DOWN SCREWS. '-350 FT POUND TORQUE ON LOCK DOWNS AND GLAND NUTS. RUNCMP TEST 2-7/8" TUBING WITH RIG PUMPS. -PJSM, RIG UP TEST TUBING. -TEST TUBING 250 PSI LOW FOR 5 MINUTES = .4 BBLS. -TEST TUBING 2000 PSI HIGH FOR 30 MINUTES =1.1 BBLS. -BLEED PRESSURE TO 1000 PSI, FLUID RECOVERED -1/4 BBL. RUNCMP TEST INNER ANNULUS. -ATTEMPT TO LINE UP LRS TO TEST ANNULUS, -LINE FROM LRS TRUCK TO IA WAS FROZEN DUE TO SEAWATER IN HOSE FROM HANGER LANDING OPERATIONS AND NOT EVACUATING HOSE AFTER HANGER WAS LANDED. -PJSM WITH LRS AND CREW ON THAWING FROZEN HARDLINE. -BLOW DOWN CEMENT LINE, CALLED FOR SECOND HEATER AND WRAPPED HOSE TO LRS TRUCK. -CLEAR RIG FLOOR OF CASING TOOLS, CONTROL LINE SPOOLER. -LINE THAWED AND DISCONNECTED, LRS CIRCULATE LINE WITH METHANOL AND DIESEL TO THEIR TRUCK. - y*FIRE DRILL. North America - ALASKA - BP Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date. 12/29/2013 X3 -0140Q -C: (1,670,000.00 ) Project: Pruoe Bay (various) Site: PB OWDW dh Rig Name/No.: DOYON 14 Spud Date/Time: 6/18/1973 12:DO:OOAM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. UN: 500292182100 Active datum: 1 C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT -00:00 _ r 12/29/2013 - 00:30 0.50 RUNCOM P 00:30 - 01:00 -' 0.50 RUNCOM P - — 01:00 - 02:30 -1.50 - RUNCOM P 02:30 i - 03:30 RUNCOM P 1.00 i i 03 30 - 04:00 0.50 RUNCOM P 04:00 - 04:30 0.50 WHSUR P I 04:30 - 05:00 0.50 WHSUR P Pnnted 2/24/2014 11:47:115AM Page 8 of 10 NPT Depth Phase Description of Operations --ys1. - -�-- - -- RUNCMP •THAWHARDLINE -LRS FLUSHING WATER FROM HARDLINE -TEST BREAK 250 PSI LOW FOR 5 MINUTES, 2500 PSI HIGH FOR 5 MINUTES *AOGCC REP LOU GRIMALDI WAIVED RE -WITNESS TO MIT AT 12:30 AM 12/29/2013 ;VIA PHONE CALL. RUNCMP PRETEST ON TUBING AND IA -PRESSURE UP TUBING TO 2000 PSI FOR 5 MINUTES, BLEED DOWN TO 1000 PSI. PRESSURE UP TATO 2000 PSI FOR 5 MINUTES. -BLEED DOWN 1A, THEN TUBING TO 0 PSI FOR MIT. RUNCMP PERFORM TUBING MIT. -PRESSURE UP TUBING TO 300 PSI (A BELS), HELD FOR 5 MINUTES -NO PRESSURE LOSS. -INCREASED TUBING PRESSURE TO 2250 PSI (.9 BBLS TOTAL). -HELD PRESSURE FOR 30 MINUTES -15 MINUTE LOSS WAS 150 PSI (2100 PSI), 2ND 15 MINUTE LOSS WAS 20 PSI (2080 PSI) FOR A TOTAL LOSS OF 170 PSI. -BLED TUBING BACK TO 1100 PSI IN PREPARATION FOR IA MIT (.3 BBLS BLED BACK). _ RUNCMP RFORM IA MIT. STARTING PRESSURES- IA=O PSI, TUBING=1200 PSI. -PRESSURE UP IA TO 450 PSI WITH LRS (DIESEL). TUBING =1200 PSI -HELD FOR 5 MINUTES WITH NO PRESSURE LOSS. -PRESSURE UP IS TO 2150 PSI. TUBING = 1410 PSI. -HELD PRESSURE FOR 15 MINUTES-IA=2020 PSI (130 PSI LOSS), TUBING=1425 PSI. -HELD PRESSURE FOR ADDITIONAL 15 MINUTES (30 MINUTES TOTAL)- IA=2000 PSI (20 PSI LOSS), TUBING=1410 PSI. -TOTAL LOSS=150 PSI. RUNCMP BLEED DOWN IAAND TUBING. -BLEED DOWN INNER ANULLUS AND TUBING TO 0 PSI. -WAIT ON APPROVAL FROM TOWN BEFORE PROCEEDING FORWARD. *CONTACTED THOR CUTLER W/ EPA FOR APPROVAL=APPROVAL GRANTED AT 03:30 AM 12/29/2D13 VIA PHONE CALL. *CONTACTED WTI_ RICHARD BURNETT FOR APPROVAL=APPROVAL GRANTED AT 03:45 AM 12/29/2013 VIA PHONE CALL RUNCMP ! INSTALL TWC. -RIG DOWN AND BLOW DOWN CEMENT LINE. !-PULLANDRIG DOWN LANDING JOINT. ;-MAKE UP T -BAR FOR TWO WAY CHECK. -DRY ROD IN TWO WAY CHECK RUNCMP PRESSURE TEST TWO WAY CHECK PRESSURE TEST TWO WAY CHECK FROM ABOVE TO 250 PSI LOW AND 1200 PSI HIGH FOR 5 MINUTES EACH. I -TEST PASSED. Printed 2/24/2014 11:47:15AM North America - ALASKA - SP Page 9 of 10 Operation Summary Report -NIPPLE DOWN BOPE AND SECURE BACK IN Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) 4.50 Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00) i Project: Prudhoe Bay (various) -PJSM. Site: PB OWDW Rig Name/No.: DOYON 14 Spud DateTme: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. --------. — -- -- UWI: 500292182100 -- — ---- - - - - -- -- Active datum: 1 : C_6/1811973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations MINUTES, 2000 PSI HIGH FOR 30 MINUTES - 05:00 - 06:00 1.00 BOPSUR P RUNCMP FLUSH BOP STACK. RUNCMP 'TEST TREE. -RIG UP STACK WASHER ON DRILL PIPE. -PJSM. -FLUSH BOP STACK FREE OF DEBRIS AND - - - ----- - - --- _ ._. __ ---- _06:00 06:00 - 07:30 1.50 BOPSUR P RUNCMP SUCK OUT ROPE STACK RUNCMP RU LUBRICATOR AND TEST. -BLOW DOWN CHOKE & KILL LINES -PJSM. -BLOW DOWN HOLE FILL AND BLEEDER -RIG UP LUBRICATOR WITH QUICK TEST SUB. LINES 07:30 - 09:30 2.00 BOPSUR P RUNCMP SWAP OUT UPPER RAMS AND 2000 PSI HIGH FOR 5 MINUTES -PJSM 'EACH -TEST GOOD. 20:00 23:00 3.00 -SWAP RAMS FROM 2-7/8" SOLID TO 3-1/2" X RUNCMP PULL TWC AND INSTALL BPV. 09:30 - 12:30 3.00 BOPSUR P RUNCMP NIPPLE DOWN BOPE. Printed 2/24/2014 11:47:15AM -PJSM -NIPPLE DOWN BOPE AND SECURE BACK IN CELLAR ON STUMP. 12:30 - 17:00 4.50 WHSUR P RUNCMP NIPPLE UP TREE. -PJSM. -INSTALL ADAPTER FLANGE. -TERMINATE CONTROL LINE IN HANGER. -TEST HANGER VOID TO 250 PSI LOW FOR 5 MINUTES, 2000 PSI HIGH FOR 30 MINUTES - TEST GOOD. 17:00 - 18:00 1.00 WHSUR P RUNCMP 'TEST TREE. -PJSM. -TEST TREE TO 250 PSI LOW AND 2000 PSI HIGH FOR 5 MINUTES EACH -TEST GOOD. 18:00 - 20:00 2.00 WHSUR P RUNCMP RU LUBRICATOR AND TEST. -PJSM. -RIG UP LUBRICATOR WITH QUICK TEST SUB. -TEST LUBRICATOR AND QTS TO 250 PSI LOW AND 2000 PSI HIGH FOR 5 MINUTES 'EACH -TEST GOOD. 20:00 23:00 3.00 WHSUR P RUNCMP PULL TWC AND INSTALL BPV. -PJSM. -PULL TWO WAY CHECK. -INSTALL BACK PRESSURE VALVE. WHILE INSTALLING, THE BPV DID NOT SEEM TO GO RIGHT. -PULLED BACK PRESSURE VALVE AND INSPECTED. NO APPARENT PROBLEMS FOUND. -INSTALLED NEW BACK PRESSURE VALVE. THIS ONE SEATED FINE. 123:00 - 23:30 0.50 RIGD P RUNCMP RIG DOWN LUBRICATOR AND SECURE TREE. -PJSM -SECURE TREE WITH GAUGES AND CHECK PRESSURES -TUBING PRESSURE=O PSI, IA PRESSURE=O PSI. -RIG DOWN AND LAY DOWN LUBRICATOR, QUICK TEST SUB AND CROSSOVER THRU --- - — — -------------- __. BEAVERSLIDE. Printed 2/24/2014 11:47:15AM Pnnted 2/24/2014 11:47:15AM North America - ALASKA - BP Page 10 of 10 Operation Summary Report Common Well Name: OWOW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X301400 -C (1 .670,000.00 ) ------------ Project: Prudhoe Bay (various) --- ---- - -- - -- --- i Site: PB OWDW -, Rig Name/No.: DOYON 14 Spud DateRme: 6118/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00.00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations -------- --.._----- ----.. - - - -- -- LLQ— __ 23:30 - 00:00 0.50 RIGD P RUNCMP SECURE CELLAR, RIG DOWN FOR DEMOBE -PJSM. -SECURE CELLAR. -PREP RIG FLOOR FOR SKIDDING. -RIG DOWN CHOKE LINE, GAS BUSTER U -TUBE, SERVICE LINES, HAND RAILS, STACKS, BRACES, SECURE BEAVER SLIDE, BLOW DOWN STEAM AND WATER. -RIG RELEASED FROM ODWD-C @ 0000 12/30/2013 MORNING. Pnnted 2/24/2014 11:47:15AM OWDW-C, Well History (Post -Rig Workover) Date Summary 02/11/14 PULLED 2-3/8 PXN PLUG BODY FROM 1908' SLM / 1945' MD. DROPPED SLB 1.25" PERF BAR TO FIRE TCP PERFORATING GUNS. DRIFTED W/ 1.75" CENT. & 2" JDC, TAGGED TD @ 2034' SLM / 2071' MD. **PERFORATING GUNS CONFIRMED FIRED / PERF BAR LEFT IN HOLE** (picture in well file). 02/14/14 T/1=78/Vac Temp=S/I, Injectivity Test (Inject) Performed injectivity test, Pumped a 5 bbls meth spear and 10 bbls ambiant diesel @ 1 bpm @ 402 psi Pumped 90 bbls ambiant diesel @ 5 bpm Final injectivity test 5 bpm @ 1309 psi Final WHP's 558/-25 SV,WV,SSV=closed MV,IA=open DSO notified on departure. Page 1 of 1 WELLHEAD= FAC; ACTUATOR= BAIijkC OKB E..EV INTERVAL BF ELEV = _56.5' SOZ 6 7 PAax Angle = 0 Datum ?,b 0 _.._____..._..._.__.._....._............_.. Datum TVD= _ 8800'SS i 3-3/8" CSG, 72#, N-80, D = 12.347" 100' Minimum ID = 1.791" @ 1945' 2-3/8" HES XN NIPPLE 2-718" TBG, 6.5#. L-80 8RD w /HDPE —J. ' 1928' ........................... .0058 bpf, ID = 2.00" 12-718" TBG, 6.5#, L-80 8RD, 949' - 19$0' ,0058 bpf, ID = 2.441= 11-1 2-718" TBG, 6.5#, L-80 8RD w /HDPE. 1982„ 0058 bpf, D = 2.00' PERFORAT)ONSLUV1ARY RI -F LOG` ON XXIXX/14 ANGLE AT TOP PERF: 0'@2006' Nate: Refer to Production DB for historical pert data SIZE SPF INTERVAL OprJSgz SHOT SOZ 6 7 2006-2030 O 02111/14 PBTD 2214' 5-1/2" CSG, 17#, N-80, .0232 bpf, ID = 4.892" 14 2250' SAFETY NOTE —POLY CORE TBG - RESTRICT SHARP EDGES AND REDUCE RL"4NG SPS TO 2007MN AND FLUIDS TO 150"F'`OLY WASTE DISPOSAL WELL. CONTACT WE BILL PF40R TO DOING ANY DOWNHOLE WORK . LOWER FLANGE ON CSG SPOOL IS RATED TO 2000 PSI ONLY "'• 3-112" OTIS TRE= CAP OONWCTIDN "' 564' 1318' CONTROL LINES, OPEN ENDED w /CHECK V LV S 1864' —�2-318' HES X NIP. tD = 1.875" BAY UNIT WELL: OWT7+N-C PERMT No: 1002420 API No.: 50-029-21821-00 SEC 11, T10N, R14E, 648' FhL 8 1048' FEL SEAL LOC Still, D = 2.441" 191$" 06/23/73 INITIAL COMB. ETION 02/17/14 DW/JM7 PULL PXN1DI20PF PERF BAR (0 191T 5-112" X 2-314' HES BWD PKR w12.75" 12!30/13 D-14 MO SEALBORE K)=2.750* 192$71�]2-718_ SEALSTEM w /VVLEG, D = 1.920' 1946' —�2-318^ HES XN NP, D = 1.79'Y 19 2-7/8" LONG SHOT DEBRIS SUES { 1982' —12-718' WLEG, D = 2.00" �— E3_MD TT NOT LOGGED 2071' 1—i PERF BAR AND FIRED GUNS (02111/14) 101117/141 BAY UNIT WELL: OWT7+N-C PERMT No: 1002420 API No.: 50-029-21821-00 SEC 11, T10N, R14E, 648' FhL 8 1048' FEL DATE REV BY CONMENTS DATE REV BY CON ENTS IPRUDHOE 06/23/73 INITIAL COMB. ETION 02/17/14 DW/JM7 PULL PXN1DI20PF PERF BAR (0 12119/58 SLIC KLINE LAST TAG DATE 03106/14 M3/JM) CORRECTED PBTD/ADD PERF BOX 12!30/13 D-14 MO 01/08/14 JM} DRLG HO COR£2ECTIONiS 09/14/14 CT�IJMD FINAL ODEAPPROVAL BP Exploration (Alaska) M31JMD JADDED LONG SLOT DEBRIS SUE STATE OF ALASKA A. AKA OIL AND GAS CONSERVATION CG,_._,,ISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED MAR 0 6 201 1. Operations Performed: AUUUU ❑ Abandon ❑ Repair Well ❑ Plug Perforations ® Perforate ® Re -Enter Suspended Well ❑ Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Run Tubing 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service • 100-242 3. Address: 6. API Numbe - P.O. Box 196612, Anchorage, Alaska 99519-6612 50.029-21821-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 028311 PBU OWDW-C 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field/ Pool(s): Prudhoe Bay/ Prud Undefined WDSP 11. Present well condition summary: Total depth: measured 2250' feet Plugs: (measured) None feet true vertical 2250' feet Junk: (measured) 2071' feet Effective depth: measured 2214' feet Packer: (measured) 1917' feet true vertical 2214' feet Packer: (true vertical) 1917' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 13-3/8" 100' 100' 4930 2670 Surface 2250' 5-1/2" 2250' 2250' 7740 6280 Intermediate Production Liner MWED AUG 1 4 2094 Perforation Depth: Measured Depth: 2006'- 2030' feet True Vertical Depth: 2006'- 2030' feet Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 1982' 1982' Packers and SSSV (type, measured and true vertical depth): 5-1/2"x2-3/4" HES BWD Packer 1917' 1917' r 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDM MAY 13 2014 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: ❑ Copies of Logs and Surveys run 15. Well Class after work: [I Exploratory [I Stratigraphic ❑ Development ® Service ® Daily Report of Well Operations 16. Well Status after work: ❑ Oil El Gas ® WDSPL ® Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ 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: Cody Rymut, 564-4398 Email: Cody.Rymut@bp.com 313-502 Printed Name: Joe Lastufk Title: Drilling Technologist SAO I) Signature: hone: 564-4091 Date: Form 10-404 Revised 10/2012 Submit Original Only North America - ALASKA - BP Page 1 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013X3 -0140Q -C: (1,670,000.00 ) Project: Prudhoe Bay (various) Site: PB OWDW Rig Name/No.: DOYON 14 Spud DateMme: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) P PRE SKID RIG FLOOR INTO MOVING POSITION. 12/24/2013 19:00 20:00 1.00 RIGD -PJSM. -SKID RIG FLOOR INTO MOVING POSITION. 20:00 - 21:00 1.00 RIGD P PRE MOVE RIG OFF OF WELL. -PJSM. -PLACED ALL SPOTTERS INTO POSITION. -MOVE RIG OFF OF OWDW-NW WELL. 21:00 - 22:00 1.00 RIGD P PRE MOVE RIG ONTO NEW WELL. -PJSM. -MOVE RIG ONTO OWDVV-C WELL. *FUNCTION ESD ON MOVING SYSTEM BEFORE FINAL PLACEMENT. ESD FUNCTIONED PROPERLY. 22:00 - 23:00 1.00 RIGID P PRE SHIM RIG. -PJSM. -SHIM AND LEVEL RIG. 23:00 - 00:00 1.00 RIGD P PRE SKID RIG INTO POSITION. -PJSM. -SKID RIG INTO DRILLING POSITION. 12/25/2013 00:00 - 01:00 1.00 RIGU P PRE RIG UP AROUND RIG. -SECURE RIG. -COVER WELL CELLAR WITH BOARDS. -PUT UP HAND RAILS AND ANTI-SKID PLATES AROUND RIG. 01:00 - 03:00 2.00 RIGU P PRE RIG UP. -PJSM. -RIG UP HIGH PRESSURE LINES UNDER RIG FLOOR. -RIG UP AIR, STEAM AND WATER LINES TO RIG FLOOR. -RIG UP BEAVER SLIDE. -RIG UP CHOKE MANIFOLD ON RIG FLOOR. -SPOT ROCKWASHER AND RIG UP. -SPOT LUNCH SHACK. -PREP PITS FOR RECIEVING FLUID. **SIMOPS: WORK ON MP -2'S AS EQUIPMENT IS BEING PUT BACK TOGETHER. ***RIG ACCEPTED AT 03:00 12/25/2013. WAIT ON ADAPTER FLANGE. 03:00 - 10:00 7.00 RIGU N WAIT PRE -WORK ON MP -2 WORK ORDERS. -PERFORM TABLE TOP CAMP EVACUATION DRILL. -NO ADAPTER FLANGE WAS LOCATED ON I I THE SLOPE. DECISION TO MAKE ONE WAS MADE BY TOWN AND FIELD SUPPORT. *FMC DEVELOPING PLAN ON TURNING A GEN IV ADAPTER FLANGE INTO A DSA FOR 2M WELLHEAD. 10:00 - 14:00 4.00 RIGU P PRE YEAR END DISCUSSION. -GATHER UP CREWAND DISCUSS END OF YEAR PERFORMANCE OF RWO TEAM (HELD DISCUSSION WITH BOTH CREWS). -CONDUCT CHRISTMAS GATHERING AT RIG CAMP TO ALLOW RIG PERSONNEL TIME TO CONTACT FAMILY. Printed 2/24/2014 11:47:15AM North America - ALASKA - BP Operation Summary Report Page 2 of 10 Common Well Name: OWDW-C - 02:30 0.50 RIGU AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 - 04:00 X3 -0140Q -C: (1,670,000.00 ) Project: Prudhoe Bay (various) Site: PB OWDW PRE P PRE P Rig Name/No.: DOYON 14 Spud Date/Time: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 23:00 9.00 RIGU N WAIT PRE WAIT ON ADAPTER FLANGE. 23:00 - 00:00 1.00 RIGU 12/26/2013 00:00 - 02:00 2.00 RIGU 02:00 - 02:30 0.50 RIGU 02:30 - 1430 5.00 WHSUR - 04:00 1.50 04:00 - 07:30 3.50 BOPSUR 07.30 - 09:30 2.00 BOPSUR 0930 - 1430 5.00 BOPSUR Printed 2/24/2014 11:47:15AM P PRE I i N WAIT PRE P PRE P WHDTRE P PRE P PRE P PRE -WORK ON MP -2 WORK ORDERS. -PREP FOR NIPPLE DOWN AND BOP TEST. *DSA PLAN APPROVED AND SENT TO BAKER MACHINE. PERFORM RIG H2S EVAC DRILL. -PERFORM H2S EVACUATION DRILL. -CONDUCTED AFTER ACTION REVIEW WITH ALL HANDS. -DISCUSSED THE PARTICULARS ON THE WELL WITH THE RIG CREW. *BAKER MACHINE FINISHING DSAAS PER DRAWING FROM FMC. WAIT ON ADAPTER FLANGE. -PREP FOR BOP TESTING. -READY 2 7/8" TEST JOINT, FOSV, DART VALVE. -WORK ON MP -2'S. -LOAD PIPE SHED WITH 2 7/8" TUBING FOR DRIFT/TALLY. *BAKER MACHINE FINISHING DSAAS PER DRAWING FROM FMC. PERFORM RIG H2S EVAC DRILL. -PERFORM H2S EVACUATION DRILL. -CONDUCTED AFTER ACTION REVIEW WITH ALL HANDS. -DISCUSSED THE PARTICULARS ON THE WELL WITH THE RIG CREW. *7-1/16" 5M X 7-1/16" 2M DOUBLE STUDDED ADAPTER ARRIVED ON LOCATION. - NIPPLE DOWN TREE. PJ SM, -BLEED PRESSURE OFF OF HANGER VOID -NO PRESSURE. -NIPPLE DOWN DRY HOLE TREE. -CHECK THREADS ON CROSSOVER FOR PULLING HANGER -9 FULL TURNS. NIPPLE UP 13-5/8"5M BOPE. -PJSM. -NIPPLE UP 7-1/16" 5M X 7-1/16" 2M DOUBLE STUDDED ADAPTER. -NIPPLE UP 7-1/16" 5M X 13-5/8" 5M SPOOL. -NIPPLE UP BOPE STACK CONFIGURED WITH 2-7/8" FIXED RAMS IN UPPER PIPE RAMS AND 2-7/8" X 5" VBR IN LOWER PIPE RAM. -CENTER STACK WITH TURNBUCKLES. RIG UP TO TEST BOP'S. -RIG UP 2-7/8" TEST JOINT, 2-7/8" FOSV AND DART TO TEST. -FILL STACK. -TEST MGS FOR FILL -TOOK 6 BBLS. -TEST RIG ESD SYSTEM. TEST BOPS. -PJSM. -TEST BOPE TO 250 PSI LOW, 2000 PSI HIGH FOR 5 MINUTES EACH. -TEST WITH 2-7/8" TEST JOINT. -ALL TESTS CHARTED -SEE ATTACHED BOP TEST CHARTS. -TEST WITNESS WAIVED BYAOGCC REP. LOU GRIMALDI. Common Well Name. OWDW-C Event Type: WORKOVER (WO) Rig Name/No.: DOYON 14 Rig Contractor. DOYON DRILLING INC. Active datum: 1 : C 6/18/1973 00:00 @56.50us DateFrom -To Hrs (hr) 14:30 - 15:00 0.50 15:00 - 15:30 0.50 15:30 - 16:30 1.00 North America - ALASKA - BP Operation Summary Report Page 3 of 10 AFE No Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00) Site: PB OWDW Spud Dateffime: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 UWL 500292182100 ve Mean Sea Level) Task Code NPT NPT Depth Phase Description of Operations BOPSUR P PRE RI DOWN FROM TESTING BOPE -BLOW DOWN CHOKE AND CHOKE MANIFOLD. -BLOW DOWN KILL LINE. -RIG DOWN TESTING TOOLS. -CLEAR RIG FLOOR OF ALL TOOLS NOT NEEDED FOR UPCOMING OPETATIONS. RIGU P PRE INSTALL BALES ON TOP DRIVE. -PJSM. -PICK UP AND INSTALL SHORT BALES ON TOP DRIVE. RIGID P PRE INSTALL DUTCH RISER. PJSM. -PICK UP AND INSTALL DUTCH RISER FOR BPV LUBRICATOR INSTALLATION. oir_n r.i ��i � PRE FRONT END LOADER PROBLEMS. -HYDRAULICS ON FRONT END LOADER FROZE UP. -COVERED UP WITH TARP AND APPLIED HEAT WITH AIR HEATER TO TRY TO THAW OUT HYDRAULICS. -NOT SUCCESSFUL -SECURED FRONT END LOADER FROM CAMP AND USE IT. i PRE 'PICK UP AND RIG UP LUBRICATOR. -PJSM. -PICK UP TWC RETRIEVAL TOOLS AND LUBRICATOR FROM GROUND THRU BEAVER SLIDE. -BRING UP EXTENSIONS AND CONTROL LINES FOR LUBRICATOR. -RIG UP ON DUTCH RISER WITH LUBRICATOR. PRE PRESSURE TEST LUBRICATOR -PRESSURE TEST LUBRICATOR TO 250 PSI LOW/2000 PSI HIGH FOR 5 MINUTES EACH. WHDTRE PULLTWC. -PJSM. -CHECK FOR PRESSURE UNDER TWO WAY CHECK WITH IA VALVES -NO PRESSURE. -PULL TWO WAY CHECK VALVE INTO BOP STACK. -ENSURE NO PRESSURE ON WELL BEFORE PULLING LUBRICATOR -NO PRESSURE. -PICK UP AND PULL LUBRICATOR. -CLOSE BLIND RAMS TO SECURE WELL. 21:00 - 21:30 0.50 RIGID P 21:30 - 22:30 1.00 WHSUR P 22:30 - 00:00 1.50 WHSUR P WHDTRE RIG DOWN LUBRICATOR -RIG DOWN LUBRICATOR AND EXTENSIONS. -MOBILIZE SAME OFF OF RIG FLOOR. -RIG DOWN DUTCH RISER. 12/27/2013 00:00 - 01:00 ! 1.00 PULL P DECOMP PULL HANGER. -RIG UP LANDING JOINT TO HANGER. -BACK OUT LOCKDOWN BOLTS. -PULL HANGER AND INSPECTED (SINGLE - -----I PORT). 01:00 - 02:00 1.00 PULL P DECOMP RIG UP TONGS FOR 2-7/8" PAC PIPE. -PJSM. PICK UP 2-7/8" TONGS TO RIG FLOOR THRU BEAVER SLIDE. -PICK UP HANDLING EQUIPMENT TO RIG FLOOR THRU BEAVER SLIDE. -MAKE UP AND TEST POWER TONGS. Printed 2/24/2014 11:47:15AM Printed 2/24/2014 11:47:15AM North America - ALASKA - BP Page 4 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00 ) i Project: Prudhoe Bay (various) --- Site: PB OWDW Rig Name/No.: DOYON 14 Spud DateMme: 6/18/1973 12:00:00AM Rig Release: 12/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292182100 Active datum 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 0200 - 02:30 (hr) 0.50 — PULL (usft) P DECOMP — !MAKE UP RBP RETRIEVAL HEAD. -PJSM. -PICK UP AND MAKE UP RBP RETRIEVAL HEAD. P DECOMP 02:30 03:30 1.00 PULL RIH WITH RBP RETRIEVAL TOOL ON 2-7/8 I HT -PAC PIPE. -RUN IN HOLE ON ELEVATORS WITH STANDS FROM THE DERRICK. -PICK UP SINGLE FROM PIPE SHED, ATTACH FOSV TO TOP, THEN ATTACH SECOND JOINT P DECOMP 03:30 - 04:00 0.50 PULL PULL BAKER 5.5" RBP. -ESTABLISH PARAMETERS AT 495': PUW= 62K, SOW --58K. -TAG RBP AT 538'. -EQUALIZE ACROSS RBP BY SETTING DOWN 3K AND SHEARING EQUALIZING SLEEVE. -MONITOR FOSV AND WELL FOR FLOW -NO FLOW OBSERVED. -PULL UP 6' AND SHEAR KEEPERS ON DOGS. -WAIT 15 MINUTES FOR ELEMENTS TO RELAX/FLOWCHECK WELL -NO FLOW OBSERVED. -POOH 6' THEN SLACK BACK OFF PAST TAG POINT. ALL INDICATIONS ARE THAT THE PLUG IS ON THE RETRIEVAL TOOL. 04:00 - 04:30 0.50 PULL P DECOMP POOH WITH RBP. -PJSM. -POOH ON ELEVATORS STANDING BACK DRILL PIPE WITH RETRIEVABLE BRIDGE PLUG. POOH FROM 538' TO SURFACE. -LAY DOWN RBP AND RETRIEVAL TOOL. 04:30 - 07:00 2.50 CLEAN P DECOMP (MAKE UP CLEANOUT ASSEMBLY. -PICK UP AND MAKE UP CLEAN OUT 'ASSEMBLY WITH 4-314" MILL AND 5-1/2 CASING SCRAPER. 07:00 - 07:30 0.50 CLEAN P DECOMP RIH WITH CLEANOUT BHA ON 2-7/8 HT -PAC PIPE. -SCRAPE FROM 1880' TO 1,930' WITH 5-1/2" SCRAPER, PUW= 73K SOW= 75K. — RUN IN HOLE TO 2147'. 1.00 CLEAN 07:30 - 08:30 P DECOMP ATTEMPT TO WASH DOWN PAST 2,147'. -PUW= 73K, SOW=75K, ROT Wi=75KAT6BM WITH 750 PSI. BEGIN MILLING OPERATIONS. -BEGIN MILLING WITH 40 RPM AND 1 K TORQUE AND 5K WOB. -NOT MILLING OFF *SIM -OPS -DISPLACE WELL WITH 8.5 SEAWATER. MONITOR WELL BEFORE POOH -WELL STATIC. Printed 2/24/2014 11:47:15AM North America - ALASKA - BP Page 5 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00 ) Project: Prudhoe Bay (various) Site: PB OWDW Rig Name/No.: DOYON 14 Spud DateMme: 6/18/1973 12:00:00AM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) 1 UWL 500292182100 Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 11:30 3.00 CLEAN P DECOMP PJSM ON POOH AND LAYING DOWN 2-7/8". -BLOW DOWN TOP DRIVE. POOH AND L/D 2-7/8" DP FROM 2,147' TO 1,92Y. -POOH AND STAND BACK 2-7/8" DP FROM 1,929' TO SURFACE. -MONITOR WELL BEFORE PULLING NONSHEARABLES THROUGH STACIE WELL STATIC. 'SENT NOTICE TO MITTUBING AND ANNULUS TO AOGCC AT 10:26 AM ON 12/27/2013. 11 30 - 12:00 0.50 CLEAN P DECOMP PJSM LAY DOWN CLEAN OUT ASSEMBLY. -BEAVE_RSLIDE OPERATIONS. 12:00 - 13:00 1.00 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR FROM CLEAN OUT BHA. 'SPILL DRILL. 13:00 - 15:00 2.00 PERF P RUNCMP PJSM LOAD SLB PERF GUNS INTO PIPESHED. -BEAVERSLIDE OPERATIONS- PICK UP RUNNING EQUIPMENT TO RIG FLOOR. 15:00 - 17:30 2.50 PERF P RUNCMP MAKE UP PERF GUNS AND PACKER ASSY. -5-1/2" X 2-3/4" HES BWD PACER. -3.38" HSD PERF GUNS, SXAR-BA EXPLOSIVE AUTOMATIC RELEASE SYSTEM. -HDFBHF HYDRAULIC REDUNDANT FIRING SYSTEM. 17:30 - 19:30 2.00 PERF P RUNCMP RIH WITH PERF GUNS AND PACKER ASSY. PJSM, RIH WITH PERF GUNS,'XN' NIPPLE WITH PXN PLUG (10' SLUGGITS DUMPED ON TOP OF PXN PLUG, TOP OF SLUGGITS @ 1935'), AND PACKER ASSY ON 2-7/8" PAC + PIPE. — 19.30 - 20 30 Loo PERF P RUNCMP SET HES 5-1/2" X 2-3/4" BWD PACKER. - PJSM, PU ONE JOINT OF PAC PIPE, MU XO TO TOP DRIVE. -PRESSURE UP TO 500 PSI AND ALLOW TO STABALIZE. -PRESSURE UP TO 2200 PSI, OVER PULL 8K TO SHEAR OFF, PICK UP 15'. -PRESSURE UP TO 3100 PSI TO SHEAR BALL SEAT. -CLEAR RIG FLOOR OF SLB TOOLS WHILE MONITORING WELL FOR FLOW. 1 *TOP OF PACKER @ 1916.79' (DRILL PIPE MEASUREMENT), 1900.79' (LOG SET DEPTH). !'PERF INTERVAL=2022' TO 2046' (DRILL PIPE MEASUREMENT), 2006' TO 2030 (LOG SET DEPTH) AT 6 SHOTS/FT. "WHEN PERFORATION GUNS ARE FIRED AND RELEASED WLEG WILL BE AT 1982' (DRILL PIPE MEASUREMENT & 1966' LOG DEPTH -REFERENCE RESERVIOR SATURATION LOG 4/22/2013) 20:30 - 23:30 3.00 PERF P RUNCMP POOH WITH HES RUNNING TOOL ON 2-7/8" PAC PIPE. -REMOVE TOP DRIVE AND XO AND BLOW DOWN SAME. -MOUSE HOLE ONE JOINT 2-7/8" PAC PIPE. -POOH WITH 2-7/8" PAC DRILL PIPE AND LAY DOWN TO PIPE SHED. Printed 2/24/2014 11:47:15AM North America - ALASKA - BP Operation Summary Report Page 6 of 10 Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00) Project: Prudhoe Bay (various) Site: PB OWDW Rig Name/No.: DOYON 14 Spud Date/Time: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) __ ---- _(usft) 23:30 - 00:00 0.50 PERF P RUNCMP CLEAR RIG FLOOR PJSM, RIG DOWN CASING TONGS -CHANGE OUT ELEVATORS TO 4" DP -- - — ELEVATORS 12/28/2013 100:00 - 00:30 0.50 RUNCOM P RUNCMP RIG SERVICE. -LUBRICATE RIG. 00:30 - 02:00 1.50 RUNCOM P RUNCMP CLEAR RIG FLOOR. -PJSM ON LAY DOWN 4" DRILL PIPE IN THE MOUSE HOLE. 02:00 - 03:30 1.50 RUNCOM P RUNCMP RIG UP TO RUN 2-7/8" COMPLETION. -RIG DOWN TOOLS AND EQUIPMENT. -MOBILIZE HANGER TO RIG FLOOR, DOUBLE CHECK PIPE TALLY. -MAKE UP LANDING JOINT ASSY, MOBILIZE SLB CONTROL LINE SPOOLER TO RIG FLOOR. 103:30 - 06:00 2.50 RUNCOM P RUNCMP RUN 2-7/8" 6.5# L-80 EUE POLYCORE TUBING AND SEAL ASSY. -PJSM. -RIH WITH 2-7/8" COMPLETION, MAKE UP SEAL ASSEMBLY AND "X" NIPPLE FROM SURFACE TO 1,380'. 0600 - 0630 0.50 RUNCOM P RUNCMP INSTALL SLB CONTROL LINE (WITH 2 EA. 5 PSI CHECK VALVES) FROM MID JOINT ON JOINT #42. -3/8" CONTROL LINE SECURED WITH 3 _ STAINLESS STEEL BANDS. 06:30 - 07:30 1.00 RUNCOM P RUNCMP RUN 2-7/8" 6.5# L-80 EUE POLYCORE TUBING AND SEALASSEMBLY. -RIH FROM 1,380' TO 1,928' INSTALLING CANNON CLAMP ON EVERY JOINT W/ 3/8" _ CONTROL LINE. 07:30 08:30 1.00 I RUNCOM P RUNCMP OBTAIN PARAMETERS. -PUW=63K, SOW= 66K, CIRCULATE 1/2 BBL MINUTE WITH 40 PSI. RIH, PRESSURE INCREASE TO 500 PSI WHEN ENTERED THE SEAL BORE AT 1921'. SEALS ENGAGED WITH NO LEAKS. -PUMPS OFF, PRESSURE BLED OFF. RIH TO NO-GO, CONFIRM NO-GO AGAIN 1931(MEG ON SEAL ASSEMBLY DEPTH). -TOP OF NO -GOAT 1919.64'. 'SEE ATTACHED WORKBOOK FOR TUBULAR SUMMARY. 08:30 - 10:30 2.00 RUNCOM P RUNCMP SPACE OUT COMPLETION.. -BLOW DOWN TOP DRIVE. -LAY DOWN JOINT# 60,59 & 58. -PICK UP & MAKE UP JOINT # 59. -MAKE UP HANGER. -SLB AND HES REP MAKE UP CONTROL LINE TO HANGER. -CONTROL LINE PORT ON TUBING HANGER TESTED TO 5000 PSI. -CONTROL LINE PORT ON HANGER IS 1/4". 3/8" CONTROL LINE WAS ASSEMBLED WITH i REDUCER BUSHING TO HANGER. 'TOTAL OF 17 CANNON CLAMPS W/ 34 PINS RAN PLUS 3 SS BANDS. Printed 2/24/2014 11:47:15AM Printed 2/24/2014 11.47:15AM North America - ALASKA - BP Page 7 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/2412013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00 ) Project: Prudhoe Bay (various) Site: PB OWDW Rig Name/No.: DOYON 14 Spud Date/Time: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor: DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 12:00 1.50 RUNCOM P RUNCMP CLEAN UP TOOLS AND EQUIPMENT USED FOR COMPLETION AND LAY DOWN THE BEAVER SLIDE. -LITTLE RED SERVICE -SPOTTING INTO POSITION. 12:00 - 13:00 1.00 RUNCOM P RUNCMP RIG UP TO REVERSE CIRCULATE WELL WITH DIESEL. -LOWER COMPLETION STRING WITH HANGER BELOW ANNULAR PREVENTER. -CLOSE ANNULAR PREVENTER. -RIG UP LRS. 1300 - 1430 1.50 RUNCOM P RUNCMP REVERSE CIRCULATE WELL WITH DIESEL. -PRESSURE TEST ALL LINES 250 PSI LOW/ 2500 PSI HIGH. -LINE UP TO REVERSE CIRCULATE, RETURNS AFTER PUMPING 1.5 BBLS. -PUMP 45 BBLS AT 1.5 BPM WITH 250 PSI, 250 PSI MAX SEEN DURING REVERSE CIRC OUT. 14:30 - 15:00 0.50 RUNCOM I P RUNCMP LAND TUBING HANGER. i VERIFY ZERO PRESSURE. -OPEN ANNULAR PREVENTER. -LAND HANGER WITH BOTTOM OF WLEG ON SEAL ASSEMBLYAT 1928.15' RKB AND 1912' LOG DEPTH. -FINAL PUW=63K, SOW -66K, DOYON 14 BLOCK WEIGHT=50K. -FMC RUN IN LOCK DOWN SCREWS. -350 FT POUND TORQUE ON LOCK DOWNS AND GLAND NUTS. 15:00 - 17:00 2.00 RUNCOM P RUNCMP TEST 2-7/8" TUBING WITH RIG PUMPS. -PJSM, RIG UP TEST TUBING. -TEST TUBING 250 PSI LOW FOR 5 MINUTES = .4 BBLS. -TEST TUBING 2000 PSI HIGH FOR 30 MINUTES =1.1 BBLS. -BLEED PRESSURE TO 1000 PSI, FLUID RECOVERED= 1/4 BBL. 17:00 - 00:00 7.00 RUNCOM N SFAL RUNCMP TEST INNER ANNULUS. -ATTEMPT TO LINE UP LRS TO TEST ANNULUS, -LINE FROM LRS TRUCK TO IA WAS FROZEN DUE TO SEAWATER IN HOSE FROM HANGER LANDING OPERATIONS AND NOT EVACUATING HOSE AFTER HANGER WAS LANDED. -PJSM WITH LRS AND CREW ON THAWING FROZEN HARDLINE. -BLOW DOWN CEMENT LINE, CALLED FOR SECOND HEATER AND WRAPPED HOSE TO LRS TRUCK. -CLEAR RIG FLOOR OF CASING TOOLS, CONTROL LINE SPOOLER. LINE THAWED AND DISCONNECTED, LRS CIRCULATE LINE WITH METHANOL AND DIESEL TO THEIR TRUCK. *FIRE DRILL. Printed 2/24/2014 11.47:15AM North America - ALASKA - BP Page 8 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X3-0140Q-C: (1,670,000.00 ) Project: Prudhoe Bay (various) Site: PB OWDW Rig Name/No.: DOYON 14 Spud Date/Time: 6/18/1973 12:00:OOAM 1 Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usR) 12/29/2013 00:00 - 00:30 0.50 RUNCOM P RUNCMP THAW HARDLINE -LRS FLUSHING WATER FROM HARDLINE -TEST BREAK 250 PSI LOW FOR 5 MINUTES, 2500 PSI HIGH FOR 5 MINUTES •AOGCC REP LOU GRIMALDI WAIVED RE-WITNESS TO MIT AT 12:30 AM 12/29/2013 VIA PHONE CALL. 00:30 - 01:00 0.50 RUNCOM P RUNCMP PRETEST ON TUBING AND IA. -PRESSURE UP TUBING TO 2000 PSI FOR 5 MINUTES, BLEED DOWN TO 1000 PSI. -PRESSURE UP IA TO 2000 PSI FOR 5 MINUTES. -BLEED DOWN IA, THEN TUBING TO 0 PSI FOR MIT. 01:00 - 02:30 1.50 RUNCOM P RUNCMP PERFORM TUBING MIT. -PRESSURE UP TUBING TO 300 PSI (.4 BBLS), HELD FOR 5 MINUTES-NO PRESSURE LOSS. -INCREASED TUBING PRESSURE TO 2250 PSI (.9 BBLS TOTAL). -HELD PRESSURE FOR 30 MINUTES-15 MINUTE LOSS WAS 150 PSI (2100 PSI), 2ND 15 MINUTE LOSS WAS 20 PSI (2080 PSI) FOR A TOTAL LOSS OF 170 PSI. -BLED TUBING BACK TO 1100 PSI IN PREPARATION FOR IA MIT (.3 BBLS BLED BACK). 02.30 - 03.30 1.00 RUNCOM P RUNCMP PERFORM IA MIT. -STARTING PRESSURES- IA=O PSI, TUBING=1200 PSI. -PRESSURE UP IA TO 450 PSI WITH LRS (DIESEL). TUBING =1200 PSI -HELD FOR 5 MINUTES WITH NO PRESSURE LOSS. -PRESSURE UP IS TO 2150 PSI. TUBING = 1410 PSI. -HELD PRESSURE FOR 15 MINUTES-IA=2020 PSI (130 PSI LOSS), TUBING=1425 PSI. HELD PRESSURE FOR ADDITIONAL 15 MINUTES (30 MINUTES TOTAL)- IA=2000 PSI (20 PSI LOSS), TUBING=1410 PSI. -TOTAL LOSS=150 PSI. _ 0330 - 04.00 0.50 RUNCOM P RUNCMP BLEED DOWN IAAND TUBING. I -BLEED DOWN INNER ANULLUS AND TUBING I TO 0 PSI. -WAIT ON APPROVAL FROM TOWN BEFORE PROCEEDING FORWARD. 'CONTACTED THOR CUTLER W/ EPA FOR APPROVAL=APPROVAL GRANTED AT 03:30 AM 12/29/2013 VIA PHONE CALL. ('CONTACTED WTL RICHARD BURNETT FOR APPROVAL=APPROVAL GRANTED AT 03:45 AM 12/29/2013 VIA PHONE CALL_ . 0400 - 0430 0.50 WHSUR P RUNCMP INSTALL TWC. j -RIG DOWN AND BLOW DOWN CEMENT LINE. -PULL AND RIG DOWN LANDING JOINT. -MAKE UP T-BAR FOR TWO WAY CHECK. -DRY ROD IN TWO WAY CHECK. 04:30 - 05:00 0.50 WHSUR P RUNCMP PRESSURE TEST TWO WAY CHECK. -PRESSURE TEST TWO WAY CHECK FROM ABOVE TO 250 PSI LOW AND 1200 PSI HIGH FOR 5 MINUTES EACH. -TEST PASSED. Printed 2/24/2014 11:47:15AM North America - ALASKA - BP Operation Summary Report Page 9 of 10 Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 X3 -0140Q -C: (1,670,000.00 ) Project: Prudhoe Bay (various) Site: PB OWDW Rig Name/No.: DOYON 14 Spud DateTme: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00:00 (d56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 06:00 1.00 BOPSUR P RUNCMP : FLUSH BOP STACK. -RIG UP STACK WASHER ON DRILL PIPE. -FLUSH BOP STACK FREE OF DEBRIS AND -- -- - DIESEL. +_..---- 06:00 - 07:30 1.50 BOPSUR P RUNCMP SUCK OUT BOPE STACK -BLOW DOWN CHOKE & KILL LINES i -BLOW DOWN HOLE FILL AND BLEEDER LINES 07:30 - 09:30 2.00 BOPSUR P RUNCMP SWAP OUT UPPER RAMS -PJSM -SWAP RAMS FROM 2-7/8" SOLID TO 3-1/2" X 6" VBR'S 09:30 - 12:30 3.00 BOPSUR P RUNCMP NIPPLE DOWN BOPE. -PJSM -NIPPLE DOWN BOPE AND SECURE BACK IN CELLAR ON STUMP. 12:30 - 17:00 4.50 WHSUR P RUNCMP NIPPLE UP TREE. -PJSM. -INSTALL ADAPTER FLANGE. -TERMINATE CONTROL LINE IN HANGER. -TEST HANGER VOID TO 250 PSI LOW FOR 5 MINUTES, 2000 PSI HIGH FOR 30 MINUTES - TEST GOOD. 17:00 - 18:00 1.00 WHSUR P RUNCMP TESTTREE. -PJSM. -TEST TREE TO 250 PSI LOW AND 2000 PSI HIGH FOR 5 MINUTES EACH -TEST GOOD. 18:00 - 20:00 2.00 WHSUR P RUNCMP RU LUBRICATOR AND TEST. -PJSM. -RIG UP LUBRICATOR WITH QUICK TEST SUB. -TEST LUBRICATOR AND QTS TO 250 PSI LOW AND 2000 PSI HIGH FOR 5 MINUTES EACH -TEST GOOD. 20:00 - 23:00 3.00 WHSUR P RUNCMP PULL TWC AND INSTALL BPV. -PJSM. -PULL TWO WAY CHECK. -INSTALL BACK PRESSURE VALVE. WHILE INSTALLING, THE BPV DID NOT SEEM TO GO RIGHT. PULLED BACK PRESSURE VALVE AND INSPECTED. NO APPARENT PROBLEMS FOUND. -INSTALLED NEW BACK PRESSURE VALVE. THIS ONE SEATED FINE. 2300 - 2330 0.50 RIGD P RUNCMP RIG DOWN LUBRICATOR AND SECURE TREE. -PJSM -SECURE TREE WITH GAUGES AND CHECK ;PRESSURES -TUBING PRESSURE=O PSI, IA PRESSURE=O PSI. -RIG DOWN AND LAY DOWN LUBRICATOR, QUICK TEST SUB AND CROSSOVER THRU BEAVER SLIDE. Printed 2/24/2014 11-.47:15AM Printed 2/24/2014 11:47:1 SAM North America - ALASKA - BP Page 10 of 10 Operation Summary Report Common Well Name: OWDW-C AFE No Event Type: WORKOVER (WO) Start Date: 12/24/2013 End Date: 12/29/2013 �_- X3 -0140Q -C: (1,670,000.00 ) ---------- Projed: Prudhoe Bay (various) --- .Site: PB OWDW Rig Name/No.: DOYON 14 Spud Date/Time: 6/18/1973 12:00:OOAM Rig Release: 12/29/2013 Rig Contractor. DOYON DRILLING INC. UWI: 500292182100 Active datum: 1 : C 6/18/1973 00:00 @56.50usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations --- __ (hr) - -- (usft) 23:30 - 00:00 0.50 RIGD P RUNCMP SECURE CELLAR, RIG DOWN FOR DEMOBE -PJSM. -SECURE CELLAR. -PREP RIG FLOOR FOR SKIDDING. -RIG DOWN CHOKE LINE, GAS BUSTER U -TUBE, SERVICE LINES, HAND RAILS, STACKS, BRACES, SECURE BEAVER SLIDE, BLOW DOWN STEAM AND WATER. 'RIG RELEASED FROM ODWD-C @ 0000 12/30/2013 MORNING. Printed 2/24/2014 11:47:1 SAM OWDW-C, Well History (Post -Rig Workover) Date Summary 02/11/14 PULLED 2-3/8 PXN PLUG BODY FROM 1908' SLM / 1945' MD. DROPPED SLB 1.25" PERF BAR TO FIRE TCP PERFORATING GUNS. DRIFTED W/ 1.75" CENT. & 2" JDC, TAGGED TD @ 2034' SLM / 2071' MD. —PERFORATING GUNS CONFIRMED FIRED / PERF BAR LEFT IN HOLE" (picture in well file). 02/14/14 T/1=78/Vac Temp=S/I, Injectivity Test (Inject) Performed injectivity test, Pumped a 5 bbls meth spear and 10 bbls ambiant diesel @ 1 bpm @ 402 psi Pumped 90 bbls ambiant diesel @ 5 bpm Final injectivity test 5 bpm @ 1309 psi Final WHP's 558/-25 SV,WV,SSV=closed MV,IA=open DSO notified on departure. Page 1 of 1 VVELLHEAD= FMC ACTUATOR BAKER C ... ................................................................................ OKB� ELEV = ......- 565 BO. L = ... ............. .. ...... ..— KOO'=' . ... ...... ... . .. ... .... ... .. 0'' Mtex Angle = 0 �tumMU=_ 13-31W CSG, 72#, N-80, 1) =12,347" I Minimum ID = 1-791" @ 19451 12-3/8- HES XN NIPPLE 5.5#, L-80 8RD w IHDPF_-28' --F 19 2,00" 2-7/8" TSG, 6,5#, L-80 8RD, 1-� 1949' - 1980* .0058 bpf, ID = 2.441" 2-718'TSG, 6,5#,L-808RD w/HDPF- 1982' ,0058 bpf, ID = ZOO* PERFORATION SUMMARY REF LOG: ON)WXXJ14 ANGLE AT TOP PERE 0* @ 2006' Nate: Refer to Production DB for historical perf data SIZE AL I OprVSqz I SHOT I 3-3/8' 1 6 12006 - 20301 0 102M1/141 I PBTD 5-1/2- CSG, 17#, N-80,.0232 bpf, 11) = 4,892- 2214' F 225W SAl'. NOTE -POLY CORE TBG - RESTRICT SHARP EDGES AND REDUCE RUNNING SPEED TO 2007MNAND FLUIDS TO 150'F**OILY WASTE DISPOSAL WELL. ODNTACT MIKE BILL PRIOR TO DOING ANY DOWNHOI F WORK. LOWERR.ANGEONCSG SPOOL IS RATEDTO 564' 1318- CONTROL LINES. OPEN ENDED w /CHECK V LV S 1864' J--32-318-HES XNIP, ICD =1.875- 1918* -ISEAL LOC SLJB, ID= 2.441* 1917' 1928' -425718- SEALSTEM . MEE, D = 1,920- 1946' -{2-318- HES XN NF, V=1.791" 19+411' 1.791- 1946' - 1947' 2-718' LONG SHOT DWRS SUB 1982' -12-718- WLEG, ID = 2,00- 2071' 1�PERFBARANDFFNEDGMS (02111/14) PRUDHOE BAY UNIT WELL OWDW_C PERMIT No: 1002420 API Nn.: 50-029-21821-00 SEC 11, TIOR R14F_ 648' FNL 81048' F EL BP Exploration (Alaska) 0-017 !� Ini RVA :11%malrAguell 0 4 Y'A If IF 2 0 11501 z Its_.i X41 9 f: VV 45-.1t PRUDHOE BAY UNIT WELL OWDW_C PERMIT No: 1002420 API Nn.: 50-029-21821-00 SEC 11, TIOR R14F_ 648' FNL 81048' F EL BP Exploration (Alaska) � o c� • 2 �2 -. ��(EDST qT UNITED STATES ENVIRONMENTAL PROTECTION AGENCY 2�J FSYJ REGION 10 Z 1200 Sixth Avenue, Suite 900 i Q Seattle, Washington 98101-3140 o= q< PR OCT OCT 2 3 2013 OFFICE OF COMPLIANCE AND ENFORCEMENT Reply To: OCE -127 CERTIFIED MAIL - RETURN RECEIPT REQUESTED SCANNED APR 0 1 M4 Ms. Katherine Fontaine Logistics and Infrastructure Manager BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit Pad 3 Disposal Facility Underground Injection Control (UIC) Class I Permit AKI1004-B, wells: Oily Waste Disposal Well -Center (OWDW-C) and (OWDW-NW) Receipt of notification (Part 1 E.10); 30 day notice (Part II C.3.c (3); casing inspection; cement bond log; baseline log; and EPA approval to forego requirements to perform step rate test (SRT) (Part II C.1. c) on well OWDW-C and approval to forego requirements to perform periodic tubing inspection (Part II C. b. (3)) on well OWDW-C and well OWDW-NW with tubing liners. Dear Ms. Fontaine: The U.S. Environmental Protection Agency (EPA) has reviewed your letter "Notice of Rig Workovers and Demonstration of Mechanical Integrity Request for Waiver to Permit Requirements Prudhoe Bay Unit Pad 3, UIC Class I Permit AK -1I004 -B" dated October 8, 2013, that EPA received on October 18, 2013. It is noted that Alaska Oil and Gas Conservation Commission has approved an application for sundry approval to re-enter a suspended well (OWDW-C) and approved an application for sundry approval to repair, casing patch, and pull tubing of a well (OWDW-NW). Based on the information you submitted and a review of your letter by a member of my staff, EPA has determined well OWDW-C meets the casing and cementing requirements per the permit (Part II A.1.). EPA concurs with your conclusion that a step rate test (SRT) on OWDW-C will not provide useful data due to the well OWDW-C proximity (21 feet) to well OWDW-NW and well OWDW-SE. Per director's discretion, EPA waives the requirement to perform the initial step rate test (Permit AK1I004-B Part II C.l.c) on well OWDW-C. EPA acknowledges the construction addition of a tubing liner. To protect the liner integrity EPA waives the requirement to perform periodic tubing inspections (AK1I004-B Part II C.3.b (3)) on wells OWDW-C and OWDW-NW with tubing liners. Following the workover of the wells, interim described in the permit AK1I0904-B Part II C.3. to inject in wells OWDW-NW and OWDW-C aPrinted on Recycled Paper E After the workovers of wells OWDW-C and OWDW-NW are completed and permit requirements are fulfilled including the submittal of the completion information with the "Completion Form For Wells (EPA Form 7520-9)" per permit Part II C.1.), then EPA will make an adequacy determination for final approval for injection into UIC Class I well OWDW-NW and well OWDW-C. If you have any questions regarding the workover and completion of well OWDW-C or the workover of well OWDW-NW, please contact Thor Cutler of my staff at (206) 553-1673, or email at cutler.thor@cpa.gov. Sincerel , Edward J Kowalski Director cc: Chris Wallace Alaska Oil and Gas Conservation Commission Marc Bentley Alaska Department of Environmental Conservation THE STATE Alaska Oil and Gas o, 1LAV KAConservation CommiSS GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 SCli1� NED NOV I � qo�� Main: 907.279.1433 J�.l Fax: 907.276.7542 Dave Bjork Engineering Team Leader 1 ©o � a� c�►• BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Undefined WDSP, PBU OWDW-C Sundry Number: 313-502 Dear Mr. Bjork: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair, Commissioner DATED this X of October, 2013. Encl. STATE OF ALASKA ALASPOIL AND GAS CONSERVATION COMM ION �o,�S l APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 SEP 'rckZ•0136A_ 1. Type of Request: A0GOC ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ® Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ® Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ® Other Run Tubing 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service 100-242 3. Address: 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519-6612 50.029-21821-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU OWDW-C Will planned perforations require a Spacing Exception? ❑ Yes 0 No 9. Property Designatior 10. Field/ Pool(s): ADL 028311 Prudhoe Bay / Prud Undefin WDSP 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' ' 2250' 1 2214' 1 2214' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 13-3/8" 100' 100' 4930 2670 Surface 2250' 5-1/2" 2250' 2250' 7740 6280 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None Packers and SSSV Type: None Packers and SSSV None MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑Exploratory ❑Stratigraphic [I Development ®Service ❑ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: November 25, 2013 ❑ Oil ❑ WINJ ® WDSPL ❑ Plugged ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned 16. Verbal Approval: Date ❑ WAG ❑ SPLUG ❑ Suspended Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Rymut, 564-4398 Printed Name: Dave Bjork Title: Engineering Team Leader Email: Cody. Rymut bp.com Signature: Phone: 564-5683 Date: Q q / �� Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness S k3 _ 5 O 2— Sundry Number: ❑ Plug Integrity t]'BOP Test 'KI Mechanical Integrity Test ❑ Loeation Clearance Other: �(i %p �� G y �U 1-25 ) 01 14s" �r Spacing Exception Required? ❑ Yes E'No Subsequent Form Required: APPROVED BY P Date:, Approved By: COMMISSIONER THE COMMISSION Form 10-403 Revised 107012OfftioiflAt Submit In Duplicate A rov onths from the date of approval VLAtdl�/, l3 pp RBED M 8 OCT 16 2n1 by 4D Sundry Request To Run Tubing And Perforate Well: OWDW-C Date: 9/11/2013 Engineer: Cody Ry mu MASP: 1135 psi Well Type: Injector (Disposal) Estimated Start date: November 25th, 2013 History: OWDW-C was drilled and completed with 13-3/8" conductor and 5-1/2" casing to 2250' MD in 1973 as part of a 5 well permafrost test. The well has no tubing, packer or perforations and is currently considered Suspended with AOGCC. The well is not currently permitted with EPA as a Class I disposal well but it will be considered as a replacement for OWDW-SW. The 5-1/2 casing was / 15�n inspected with a caliper log on 4/17/12 and a USIT/CBL on 4/23/12. The casing passed an MIT to 2 0 psi. The cement bond is good across the potential perforation interval and to the top of the confining �s ` zone. A dryhole tree was installed on the well 3/30/12. Scope of Work: Remove tree, NU BOPE, perform drift run, run TCP guns and completion packer, set packer, run 2-7/8" completion, freeze protect, MIT -T & IA, set TWC, install tree, set BPV, RD MO. Pre Rig Prep Work: f O Install Cellar F MIT -T to 2 si. 15 -Cc S O Pull well- ouse, flow -line, pre0 pad for the rig. Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 2- 7/a" x 5" VBRs, blind shears, mud cress and 2-7/8" x 5" VBRs). Test the VBRs to 3*psi and the annular to 35,66 -psi 15-00 p15 2. Perform 5-172" clean up and drift run ! �� 5 3. Run —25' of TCP guns below 5-1/2" completion packer from 2006-2030'md 4. Set packer at—1906'md 5. Run 2-7/8" completion 6. Set TWC 7. ND BOPE, NU Tree 8. Pull TWC 9. Set BPV host riq vvorK F I Fire Perforation Guns F I MIT -IA O Install Wellhouse from P&A well OWDW-SW, install instrumentation E Run GR -CCL Tie-in to E Run Borax RST • Proposed 13-3/8" CSG, 72#, N-80, D = 12.347" Minimum ID =1.719" @ 1926' 2-3/8" HES XN NIPPLE 2-7/8" TBG, 6.5#, L-80 8RD w /HDPE feed tubing, D = 2.0" PERFORATION SUMMARY REF LOG: CNL ON O6/20f73 ANGLE AT TOP PERF: 0 @ 2006' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2-718" 6 2006-2030 PBTD 5-1/2" CSG, 17#, N-80, D = 4.892" OWDW-C IPFEfY NOTE OILY WASTE DISPOSAL WELL CONTACT MIB BLL PRIOR TO DOING ANY DOW*lOLE WORK . SOME LOGS ARE MEASURED FROM GROUND LEVEL. —2006 RWO: DEMIS ARE TO RIB, RIB TO GL = 27.5' —LOWER FLANGE ON CSG SPOOL IS RATED TO 2000 PSI ONLY. —3-1/7 OTIS WEE CAP CONNECTION" 318" CONTROL LINES, OPEN ENDED w /CHECK V LV S 1892' I—i 2-318" FES X NIPD =1.875" 1906' 15-1/2' x 2-7/8" HES BWD packer w/2.75" seabore 1926' I --j 2-3/8" FES XN NIPD =1.791" 1940' J l 1�0• 2-7/8" WLEG, D=2.441" ELMD TT NOT LOGO 2210 I 1 2260' 1 TREE = BLIND FLANGE ONLY WELLHEAD = FMC ACTUATOR = KB. ELEV = 56.5' BF. E KOP Max, Dates Dates 0 0 OWDW-C DATE REV BY COMMENTS DATE REV BY COMMENTS 06/23/73 ORIGINAL COMPLETION 05/31/06 DTM WELLHEAD CORRECTIONS 12/19/98 LAST TAG DATE 11/09/00 SIS-SLT CONVERTED TO CANVAS 03/03/01 SIS -MD FINAL 109/19/011 RN/KAK I CORRECTIONS 09/27/01 MB/KAK I CORRECTIONS PRUDHOE BAY UNIT WELL: OWDW-C PERMIT No: 100-242 API No.: 50-029-21821-00 SEC 11, T10N, R14E, FEL, FNL BP Exploration (Alaska) 1 RIG FLOOR 33.7 ' AGL 13 5/8', 50M PSI, HYDRIL ANNULAR BOP, STUDDED TOP/FLANGED BOTTOM -� FLANGED TOP 13 5/8', 5000 PSI, 10' MPL OPERATORS, HYDRIL PIPE RMI 3 1/8' 5000 PSI SIDE OUTLET 13 5/8', 5000 PSI, 14' MPL OPERATORS, 3' CHOKE UNE HYDRL BUND SHEAR RMI STUDDED BOTTOM B% 180 3 1/8' 5000 FSI HCR VALVE KILL LINE /2' 3 1/8' 5000 PSI HCR VALVE) / I 3 1/8' 5000 PSI GATE VALVE 3 1/8' 5000 PSI GATE VALVE) BOP STACK ELEVATION 150 PSI HPDR. RATED KNIFE GATE VALVE E 'LG'O VENT UNE C SURFACE DIVERTER CONFIGURATION SINGLE 13 5/8', 5000 PSI, 10' MPL OPERATORS. HYDRIL PIPE RMI STUDDED BOTTOM/RANGED TOP B% 180 ACCUMULATOR MANIFOLD FLANGE 21 1/4', 2000 PSI, MSP HYDRIL BOP/DNERTER STUDDED TOP/RANGED BOTTOM FLANGE/FLANGE R% 73 18 BOTTLES, 10 GALLONS EACH NITROGEN BACKUP BOTTLES UPW BOP SLACK UPWTE ROP %XX X CHOWAQL M UI0WE OOP 5T X OR" TO MUIq'M oEwwlnx REMOTE PANEL IN DOGHOUSE AND UTILITY MODULE BOP SYSTEM AND CONTROL T1• 9 Ferguson, Victoria L (DOA) • From: Rymut, Cody D <Cody. Rymut@ bp.com > Sent: Friday, October 11, 2013 5:10 PM To: Ferguson, Victoria L (DOA) Subject: Re: PBU OWDW-C (PTD 100-242, Sundry 313-502) Follow Up Flag: Follow up Flag Status: Flagged We'll take the BOP's to 1500psi as well. From: Ferguson, Victoria L (DOA)[mailto:victoria.ferguson@alaska.aov] Sent: Friday, October 11, 2013 07:32 PM To: Rymut, Cody D Subject: RE: PBU OWDW-C (PTD 100-242, Sundry 313-502) The BOP test pressure listed on the sundry is 3500 psi. Do you want to test the BOPs to 1500 psi or 2000 psi? From: Rymut, Cody D fmaiIto: Cody. Rymut@bp.com1 Sent: Friday, October 11, 2013 4:08 PM To: Ferguson, Victoria L (DOA) Subject: RE: PBU OWDW-C (PTD 100-242, Sundry 313-502) Victoria, I've attached a few pictures but the well head is limited to a spool with a blanking flange on top, with a whitie valve on the blanking flange. FMC is currently trying to figure out what hanger/pack-off will fit in the wellhead, but once the spool was dug out they noted the spool was rated to 2000psi. The PE for this well Micheal Bill is asking for an MIT of 1500psi. I submitted the Sundry listing an MIT to 2000psi but after discussion with Micheal we only need to go to 1500psi. The well is currently not completed and just has 5-1/2" casing cemented to surface. Let me know if you need anything else. Have a great weekend, Cody Rymut C: 907-230-3594 From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson alaska.gov] Sent: Friday, October 11, 2013 11:46 AM To: Rymut, Cody D Subject: PBU OWDW-C (PTD 100-242, Sundry 313-502) Cody, What type of wellhead is on this well and what are the components pressure rating? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska 1 E NC3 ca — 2L -I2 by RECEIVED OCT 10 2013 AOGCC BP Exploration (Alaska) Inc. P. O. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 USA October 8, 2013 CERTIFIED MAIL: 7012 2920 0001 8307 7298 UIC Manager, Ground Water Protection Unit U.S. Environmental Protection Agency (OCE -127) SCANNED OCT 0 2 2014. 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Re: Notice of Rig Workovers and Demonstration of Mechanical Integrity Request for Waiver to Permit Requirements Prudhoe Bay Unit Pad 3, UIC Class I Permit AK -1 1004-B Dear UIC Manager: BP Exploration (Alaska) Inc. (BPXA), operator of the Prudhoe Bay Unit Pad 3 Disposal Facility is planning to perform a rig workover in an existing disposal well and a second workover to equip another well as a replacement disposal well. This letter is to meet the notification requirements of Permit AK -11004-B, Part I E.10 and Part II C.3.c (3) and also submits casing inspection, cement bond and baseline logs run in the replacement disposal well. In addition, BPXA requests a waiver from the initial step rate test (Part II C.1.c) and the periodic tubing inspection (Part II C.3.b (3)) requirements in the permit. Notification The workover in existing Class I disposal well OWDW-NW is currently anticipated to begin in mid-November 2013, but the exact timing is uncertain. The workover in replacement disposal well OWDW-C will follow the NW well work. Both workovers will include a pressure test of the casing, new tubing and packer. BPXA will notify your staff when a better estimate of the timing is known. The workover in existing well OWDW-NW will remove and replace corrosion damaged tubing and the packer. This well has been in Class I disposal service since 1989 and had a similar workover in 2006. The OWDW-C work will equip the well as a replacement for plugged and abandoned well OWDW-SW by installing new tubing and a packer. This well was drilled in 1973 but it has never been permitted or used for Class I disposal. It has no tubing or packer and it has never been perforated. The permit authorizes utilizing "up to three Class I injection wells at the Prudhoe Bay Unit Pad 3 disposal facility ...". The possibility of equipping OWDW-C as a replacement well was noted in the BPXA Pad 3 Class I UIC Permit Renewal Application (June 2009) and in the U.S. Environmental Protection Agency Pad 3 Class I Wells Fact Sheet dated July 24, 2009. The construction history for OWDW-C was included in correspondence dated June 30, 2009 responding to a request for supplemental information to the permit application. In both wells, new lined tubing will be installed and a new packer will be set not more than 100 feet measured depth up the casing from the top of the permitted injection interval (Part II A.2). A demonstration of mechanical integrity of the tubing, casing and packer in the form of an annulus pressure test will take place in each well after the new tubing is installed (Part II C.3.b (1)). After perforating, a demonstration of mechanical integrity will be performed in OWDW-C to verify there are no vertical channels adjacent to the wellbore (Part II C.3.b (2)). The same log was run in OWDW-NW on September 19, 2013 verifying there are no channels adjacent to the wellbore in this well. Attached for your information and review are copies of the Applications for Sundry Approvals submitted to Alaska Oil and Gas Conservation Commission (AOGCC) for the rig workovers. These applications contain additional detail about the planned work. The completions in these wells will be very similar to the current completion in OWDW-NW. Several logs and tests were performed in OWDW-C prior to proposing the well as a replacement disposal well. A cement evaluation log (Ultrasonic and Cement Bond Log) was run in on April 23, 2012 to verify the well's cement quality. The log shows intervals of good cement over the injection and confining zones. The tool was also run in casing inspection mode. No areas of metal loss were observed. A RST sigma and temperature log was run in OWDW-C the same day to provide baseline data for comparison to future logs. A RST log with borax as a tracer is typically used to demonstrate there are vertical channels adjacent to the wellbore in the OWDW wells. A caliper log was run in the casing on April 17, 2012 showing no significant metal loss on the interior of the casing. An area of casing axial displacement (buckling) was indicated at 1014-1024' MD. The well passed a casing pressure test to 2000 feet and this level of damage is not believed to be significant. Copies of these logs are attached. Waiver Requests BPXA requests a waiver to the requirement for an initial step rate test for OWDW-C (Part II C.1.c). It is very likely that a step rate test in this well will provide no useful data. The OWDW-C well is located between and in close proximity to the other active wells (OWDW- NW and OWDW-SE) and inactive disposal wells on the pad. OWDW-C is located only 21 feet from each of the other wells and it will be perforated in the same disposal interval. The long term disposal of a variety of waste materials into the offset wells has significantly damaged the formation surrounding OWDW-C. The disposal mechanism at Pad 3 is believed to be horizontal fracturing. Fracturing of the injection zone is authorized in the permit (Part II C.5.ii). A step rate test typically provides insight into the fracture initiation pressure and other baseline formation properties by observing the character of matrix injection mechanism and the change to a fracture injection mechanism as the injection rate is increased. With significant formation damage, it is likely there will be no matrix injection component in the step rate test data. Routine injection monitoring will provide fracture injection data. Step rate tests for the existing wells were waived in the permit (Part II C.1.c). In addition, a step rate test in OWDW-C would require shutting in the offset active wells for several days, resulting in disruption and additional cost with no benefit. The new tubing strings to be installed in each well will be lined with HDPE (high density polyethylene) to mitigate corrosion damage. The permit requires internal tubing inspection logs to be run once every two years (Part II C.3.b.3). The most definitive log to monitor tubing corrosion in OWDW wells has been the use of a 24 arm memory caliper log. BPXA requests the Director or an authorized representative use their discretion to waive the requirement for a periodic tubing inspection log since the tubing will be protected from internal corrosion and the caliper log tool could damage the lining of the new tubing. The tubing size and the properties of the liner preclude using other tubing inspection tools. 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. If you have questions, please contact Michael Bill, Sr. Staff Engineer at (907) 564-4692. Sincerely, Katharine Fo taine Logistics and Infrastructure Manager Attachments: Application for Sundry Approval for OWDW-NW, submitted to AOGCC 09/06/13 Application for Sundry Approval for OWDW-C, submitted to AOGCC 09/16/13 OWDW Log Copies: Ultrasonic and Cement Bond Log, CCL/GR/USIT/MSIP, 23 April -2012, Schlumberger Reservoir Saturation Log, CCL/GR/Press/Temp/RST Sigma, 23 -April -2012, Schlumberger Memory Multi -Finger Caliper, Log Results Summary, April 17, 2012, PDS Cc: Thor Cutler, EPA Region 10 Chris Wallace, AOGCC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ® Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ® Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ® Other Run Tubing 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 100-242 3- Address: ❑ Development ® Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519-6612 50.029-21821-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU OWDW-C Will planned perforations require a Spacing Exception? ❑ Yes N No 9. Property Designatior10. Field / Pool(s): ADL 028311 Prudhoe Bay/ Prud Undefin WDSP 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): 2250' Total Depth TVD (ft): 2250' Effective Depth MD Mi. 1 2214' Effective Depth TVD (ft): 2214' Plugs (measured): None Junk (measured). None Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 13-3/8" 100' 100' 4930 2670 Surface 2250' 5-1/2" 2250' 2250' 7740 L 6280 Intermediate Production Liner Perforation Depth MD (ft)Perforation Depth TVD (ft): Tubing Size. Tubing Grade: Tubing MD (ft): None None Packers and SSSV Type: None Packers and SSSV None IMD (ft) and TVD-(ft).- 12. VD-(ft) 12. Attachments. 13 Well Class after proposed work ® Description Summary of Proposal ® BOP Sketch ❑ [I Exploratory ❑Stratigraphic [I Development ®Service Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation November 25, 2013 ❑ Oil ❑ WINJ ® WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contac: Cody Rymut, 564-4398 Printed Name: Dave /Bjork Title: Engineering Team Leader Email• Cody.Rymut@bp,com Signature: //y+� Phone: 5645683 Date-- Commission ate:Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ❑ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Spacing Exception Required? ❑ Yes ❑ No Approved Subsequent Form Required: APPROVED BY COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 10/2012 Approved application is valid for 12 months from the date of approval Submit In Duplicate Sundry Request To Run Tubing And Perforate Well: OWDW-C Date: 9/11/2013 Engineer: Cody Rymut MASP: 1135 psi Well Type: Injector (Disposal) Estimated Start date: November 25"', 2013 History: OWDW-C was drilled and completed with 13-3/8" conductor and 5-1/2" casing to 2250' MD in 1973 as part of a 5 well permafrost test. The well has no tubing, packer or perforations and is currently considered Suspended with AOGCC. The well is not currently permitted with EPA as a Class I disposal well but it will be considered as a replacement for OWDW-SW. The 5-1/2" casing was inspected with a caliper log on 4/17/12 and a USIT/CBL on 4/23/12. The casing passed an MIT to 2000 psi. The cement bond is good across the potential perforation interval and to the top of the confining zone. A dryhole tree was installed on the well 3/30/12. Scope of Work: Remove tree, NU ROPE, perform drift run, run TCP guns and completion packer, set packer, run 2-7/8" completion, freeze protect, MIT -T & IA, set TWC, install tree, set BPV, RD MO. Pre Rig Prep Work: Tia 0Install Cellar F MIT -T to 2000 psi. O Pull well -house, flow -line prep pad for the rig - Proposed RWO Procedure! 1. MIRU Doyon 14. ND tree- NU and test BOPE with four preventers configured top down (annular, 2- 7/8" x 5" VBRs, blind shears, mud cross and 2-'/8" x 5" VBRs). Test the VBRs to 3500 psi and the annular to 3500 -psi 2. Perform 5-1/2" clean up and drift run 3. Run —25' of TCP guns below 5-1/2" completion packer from 2006-2030'md 4. Set packer at—1906'md 5. Run 2-7/8" completion 6. Set TWC 7. ND BOPE, NU Tree 8. Pull TWC 9. Set BPV Post rW Work F Fire Perforation Guns F MIT -IA O Install Wellhouse from P&A well OWDW-SW, install instrumentation E Run GR -CCL Tie-in log E Run Borax RST owDw-c Proposed 13-3/8' CSG, 72#, W80, D = 12.34r H 100' Minimum ID =1.719" @ 1926` 2-3/8" HES XN NIPPLE 2-7/8' TBG, 6.5#, L-80 8 R w 4-10FT Eyed tubhg, 1940' D=2.0' PERFORATION SL&"RY FU LOG: CN_ ON 06!20/73 ANGLEATTOPPEW 002006' Note: PlEfer to Production DB for hisborical perf data SIZE SPF 14TERVAL OprUSgz E NUE 2-7/8' 6 2006 - 2030 1 5-12' CSG, 17#, N-80. ID - 4.882' I SAFETY NOTT'_ OLY WASTE DISPOSAL WEL CONTACT MFT— BLL PF IOR TO DOM ANY DOWNHOLE WORK . SOME LOGS ARE MEASURED FROM GRDLIND LEVEL "2006 RWO: DEPTHS ARE FU 8130 ED TO Fes, RKB TO GL = 27.5' " LOVVER FLANGE ON CSG SPOOL IS RATED TO 2000 PSI ONLY. "3-1/2' OTISTREE CAP COMELTION'e 500 H3/5' CONTROL LNES, OPEN ENDED w /CFECK V LV S 1892' H 2-3/8' HES X NP, D = 1.875' 1906' 5-12- x 2-7/8' HES BWD packer w 2.75' seabore 1926' H 2-3/r HES XN W. D = 1.791' { 1940• H. 2-71V VAEG, D = 2441 HJbO TT NOT LOOG(� TREE= BLIND FLANGE ONLY WELLHEAD = FMC ACTUATOR = KB. ELEV = 56.5' BF. E KOP MaxmDatui SAFETY NOTES: SOME LOGS ARE OWDW-C I MEASURED FROM GROUND LEVEL. DATE REV BY COMMENTS DATE REV BY COMMENTS 06/23/73 ORIGINAL COMPLETION 05/31/06 DTM WELLHEAD CORRECTIONS 12/19/98 LAST TAG DATE 11/09/00 SIS-SLT CONVERTED TO CANVAS 03/03/01 SIS -MD FINAL 09/19/01 RN/KAK CORRECTIONS 09127/01 MB/KAK CORRECTIONS PRUDHOE BAY UNIT WELL: OWDW-C PER W No: 100-242 API No.: 50-029-21821-00 SEC 11, T1 ON, R1 4E, FEL, FNL BP Exploration (Alaska) J 1/1' 5000 F 5 1/8' 5000 RIG FLOOR 33.7 ' ACL BOP STACK ELEVATION ISO Ps IN•I. WED R•E GTE VALVE LC'O VENT LINE 13 5/8'. 5000 PSA MOPR ANNULAR BW. STLIOOID TDP/FVIIGM 90-rcM FLANGED TOP 15 5/9', SONO PSI, 10' IPL OPERATORS. Pl'ONL PIPE RAN 13 5/f'. 5OD0 PSI, 11' NPL OPERATORS. HIM SHEAR RAP STIgDED BOTTOM Bn ISO 5 1/5' 500D PSI HCR VALVE -- 27 PILL LINE 5 1/8' 5000 PSI GATE VALVE SINGLE 1J 5/f', 5000 PSI. 10' MR OPERATORS. HTOML PTE ILAY SHOOED 3OTtd1/F1AN¢O TOP BR Ifo SURFACE DIVFRTER CONFIGURATION Py P/OATRDR IA N ED BOTTOM RS 73 ACCUMULATOR: NL SHAFFER, 180 GAL, 6 STATION TRI FT( PUMP: 575 VAC, 30 HP AIR PUMP: 1, NIL SHAFFER ACCJMULATORMANIFOI—D 18 BOTTLES, 10 GALLONS EACH VALVE LEGEND 1 BYPASS 2 KILL 3 (:HOKE 4 BOTTOM RAMS 5 BLIND RAMS 6 TOP PIPE RAMS 7 ANNULAR 000 �' PAss • • • • 1500 Am f • :7�LCi1�7J7��17fr�P1�FY! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ® Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ® Other Casing Patch 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc.100-240 ❑Exploratory ❑ Stratigraphic ❑ Development ® Service 3. Address: 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519-6612 50.029-21819-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU OWDW-NW Will planned perforations require a Spacing Exception? ❑ Yes D9 No 9. Property Designatior 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) Effective Depth TVD (ft): Plugs (measured): Junk (measured) 2253' 2253' 1 2130' 2130' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 13-3/8" 100' 100' 4930 2670 Surface 2200' 5-1/2" 2200' 2200' 7740 6280 Intermediate Production Liner Perforation Depth MID (ft7T erforation Depth TVD (fty _T Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8", 6.5# L-80 1935' Packers and SSSV Type: 5-1/2" Baker'F1' Production Packer Packers and SSSV 1900'/ 1900' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch []Exploratory❑ Stratigraphic ❑Development ®Service [I Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work. Commencing Operation. November 7, 2013 ❑ Oil ❑ WINJ ® WDSPL ❑ Plugged ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned 16. Verbal Approval: Date Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sean McLaughlin, 564-4387 Printed Name: Dave Bjork Title: Engineering Team Leader Email: Sean.Mr-Laughrin@bp.com Signature: s%r�� ` Phone: 564-5683 Date:Cc c11- Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ❑ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Spacing Exception Required? ❑ Yes ❑ No Subsequent Form Required: APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 10/2012Submit In Duplicate Approved application is valid for 12 months from the date of approval by Sundry Request: Tubing repair on an injector Well: OWDW-NW Date: 09/02/2013 0 Engineer: Sean McLaughlin MASP: 1137 psi Well Type UIC Class I Disposal Estimated Start date: November 7", 2013 History: OWDW-NW was drilled and completed with 13-3/8" conductor and 5-1/2" casing to 2200' MD in 1973 as part of a 5 well permafrost test. 2-3/8" injection tubing was run in 1985, the well was perforated and disposal injection began that year. The well was permitted as a Class I disposal well in 1989. Cumulative disposal injection to date is 10.1 MMB. The tubing string was replaced with a 2-718" string in 11/06 due to corrosion after a 20 year life. A new tree was also installed at that time. A tubing caliper log was run on 6/06/13 showing 46% maximum wall penetration and 17% maximum cross sectional metal loss. A casing caliper run from the fill level to the tubing tail showed 86% maximum wall penetration and 12% maximum cross sectional metal loss. There is no indication of tubing or packer leak based on annulus pressure monitoring. Another caliper run 6/04/12 showed 51 % max wall penetration on the tubing. Scope of Work. Pull 2-7/8" tubing, Mill and Retrieve Packer, Run 5-1/2" casing patch, Run 2-7/8" Pofycore lined tubing. Pre FUg Prep Work: S 1 Run SBHPS, Set PXN plug at 1,922', Drift for 2-7/8" Jet Cutter F 2 MIT -IA to 2,000 E 3 Jet cut 2-7/8" tubing @ 1,848'. Reference tubing tally 2/19/06. Cut desired to be 3' from top of first full joint above the X nipple leave a —28tubing stub). F 4 Circulate well through the cut with seawater and diesel freeze protect to 2000' MD. Post cut CMIT-TxlA to 2000 psi. V 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaks check one at a time). PPPOT-T & IC. V 6 Set BPV. V 7 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 2- 7/8" x 5" VBR's, blind shears, mud cross' and 2-7/8" x 5" VBR's). Test the VBR's and annular to 3,500 psi. Pull TWC. 2. Pull and lay down 2-7/8" tubing string to the jet cut_ 3. Fish seal assembly from the packer 4. Change out IC packoff 5. Mill and retrieve packer from 1,900'. 6. Scrape 5-1/2" casing and cleanout to 2,130'. 7. Install 5-1/2" casing patch from 1900'- 1975' 8. Run 5-1/2" x 2-7/8" HES BWD packer and tailpipe. MIT -IA to 2000 psi. (EPA Witness) 9. Run new 2-7/8" Polycore lined tubing with 2 x 1/4" control lines. MIT -T & MIT -IA to 2000 psi 10. Set a BPV and RDMO. Pos rig Work M 1 1 Pull BPV S 1 2 1 Pull PXN Tae` = ' CAK43M CTUATOR RAC ACTUATOR OWDW—NW CTIAT= KBELBI= 57.E Proposed BF. EEV = KOP = 0 o Max Angle = 0 Datum MD = 0 Datum TVD = 8800' SS 13-3/8- CSq 72#, "0. D = 12.347- H 100 - Minimum ID = 1.781" @ xxxx' 2-3/8" HES XN NIPPLE 2-718" TBG, 6.5#, L-80 8RD w/ HDPE lined tubing, ID = 2.0" PERFORATION SUMMARY REF LOG: SPIOL ON 06/0893 ---ANGLEAT-TOPPF#: 0 a 1980' - Note: Wfer to Production DB for historical pert data SIZE SPF WT9RVAL Opn/Sgz DATE 4-1/4' 4 1980- 2005 O 01106/85 4-1/4' 4 2032 -2052 O 08/16176 4-1/4- 4 2052 -2062 O 0V1896 4-114' 4 2062- 2073 O 11/0995 4-1/4' 4 2073 -2093 O 01118!78 IP�MH rte' 5-112' CSG, 17If, N -W. D = 4.892- 2200• SAFETY NOTE IDLY WASTE OISFOSAL VVE-L CONTACT LIKE BLL PRIOR TO DOING ANY DOVft DLE WORK, SOME LOGS ARE MEASURED FROM GROUND L IEL- -2006 RVVQ DEP`F}15 ARE FFE ENCED TO RfB, RB TO GL = 27.5' "LOWER FLANGE ON CSG SF OOL Is RATED TO 2000 PSI ONLY. "3117 OTIS TRff CAP CONNEL-TK*r 2 x 3/8" control lines, open ended w/check valves to 500' 2-3/8" X NIP, ID = 1.875" 5-112" x 2-718'' HES BWD packer w/ 2.75" sealbore at 1890' 2-3/8" XN NIP, ID = 1 791" End of Tubing at 1965' Wfd XSpan 5-1/2" casing patch, 1900'- 1975', ID= 4.0" DATE REV BY CGW(TSDATE FIEV BY COMMEM 1103"T-3ONGlNAL COM PLETI IN DU07ETFS LAST WOl NMER 11112Ms1N Me MO0224106 DWM-H DWGDRAFTC0ME1-11D16 10/22/07 JIYPJC SAFETY NOTE= TFEECAP PFaDIVE BAY LINIT VVELL• OVYDN-NW FOW-'1002400 AR No.: 50029-21819-M SEC 11. TION. R14E F EI- FTL BP Otploratlon (Alaska) IP'�!�I VVB JFAD = FMC ACTUATOR = Nobe: Refer to Roduction DB for historical pert data KB. BFI/ = 57.9' BF. BEI/ = Opn/Sgz DATE KOP= 0 Max Angle = 0 Datum MD = 0 Datum TVD= 8800'SS OWDW-NW 13-3/8' CSC, 729, N$D, D = 12.347' 100' Minimum IQ = 2.205" @ 1992' 2-7/8" HES XN NIPPLE 6.50, L-80 ORD, .0058 bpi, 0=2."V H 1935' PERFORATFON SULOMRY REF LOG: SPFDL ON 06/08173 ANIGLF AT TOP FEW 0 IM 1980' Nobe: Refer to Roduction DB for historical pert data SIZE I SPF I NTH41/AL Opn/Sgz DATE 4-114" 4 1960-2005 O 01!08/85 4-1/4' 4 2032-2052 O 08/1676 4-114" 4 2052- 2062 O 01/18/76 4-1/4" 4 2062- 2073 O 11/09/15 4-1/4" 4 2073- 2093 O 01/18/78 15-1/2' CSG, 17X, N-80, D = 4.892. 1 �C00F.--T-q SAFELY NOTE OLY WASTE DISFOSAL VVELL CONTACT MFS BLL PF40R TO DOING ANY DOVVN IDLE WORK . SONE LOGS ARE MEASURED FRDMGRO(W LEVEL "2006 RIND DFT'TFiS ARE Rff6EMUD TO RKB, RKB TO GL = 27.5'—LOWER FLANGE ON CSG SPOOL IS RATED TO 2000 PSI ONLY. "3-1/2' OTISTREECAP CON ECTK*r 3B' CONTROL LINES, OF$V ENOlD w /CHECK VLV S 1886' I—i2-718' Ifs X NP, D = 2.313' 189T I -SEAL LOC SUB, D = 2.441' 1898' BKR G3H-22 LOC SEAL ASSY, D = 2.370' 1900' 5-112' BKR F1 PROD FiO2 w / SEALBORE EXY. D = 3.00" 1927 H2-7/8" 1 ES XN NP, D = 2205' j 1935' 1-12-718' WILG, D = 2.441' t3MD TT NCfT lOG(� DATE REV BY COM EM DATE Fel/ BY OON90113M M2113 ORdlAL COMPLETION 01w - M LAST WORIOVBt MOM Dig IM 9224006 CITMA DRLG DRAFT OORREL l4 1022-07 J[2PJC JsAFETY NOT& TFEE cAP PRLDFDEBAY UNIT VVH.L- OWDVIFNW PERWT:'1W2400 APF No.: 50-029-21819-M SED 11, T10K R14E, FEL, FN_ BP Btpbratim (Alaska) 3 1/!• 5000 1 3 i/a• boa RIG FLOOR 33.7 ' AGL BOP STACK ELEVATION 13 5/8•, 5000 PL, HTOaI "Num BOP. mean TOP/RAMaT1 aorta RAWX0 3W 13 5/6', mm P% IO' MPL OPEMRa15. ff"L PPE RAM 13 5/9'. 5000 PSL 14' MPL OPEIAMIS. HMaK SUMO 9*" PMI SRIOOED SOROM 911 160 3 1/a• mm P51 11[II VALUE - 2' PAL LAE 3 1/6. 5000 PSI CAFE WLVE 51WEE 13 5/8-, WW P51, IO' MPL OP66AATURS. KMRL PPE PAM snxm BOTTOMinANCm TOP Mt 160 iql 21 1/A'. 2000 P9, 150 KMSP 4YM BOP/OOFAT[AEOUWKWE GYE VAL*511100m MP/ Lgdom BMW EUMQ/EIMCE RA 73 RC'D VEr UME SURFACE DIVE9TER CON FI URATIQ ACCUMUjQ$ NL SHAFFER. 180 GAL, 6 STATION TRIM EX PLILLO: 575 VAC, 30 HP AIR PUMP1 1, NL SHAFFER ACCUMULATOR MMIFQ 18 BOTTLES, 10 GALLONS EACH VALVE LEGEND 1 BYPASS 2 KILL 3 CHOKE 4 BOTTOM RAMS 5 BLIND RAMS 6 TOP PIPE RAMS 7 ANNULAR I ,--x *- Mxqj Company: BP Exploration (Alaska), Inc. Log Date: April 17, 2012 Log No.: 10213 Run No.: 1 Pipe Description: 5.5 inch 17 Ib. N-80 Pipe Use: Casing Memory Multi -Finger Caliper Log Results Summary Well: Field. State: API No. Top Log Interval: Bottom Log Interval. Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into surface at 0 feet (Driller's Depth). OWDW-C Prudhoe Bay Alaska 50-029-21821-00 Surface 2,110 Ft. (MD) This log was run to assess the condition of the casing with respect to corrosive and mechanical damage The caliper recordings indicate the 5.5 inch casing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. Although no significant I.D. restrictions are recorded, the caliper recordings indicate slight buckling from surface to -✓1,890 feet, and axial displacement from -1,014 feet to 1,024 feet. A 3-D log plot overlay of the centered and off -center caliper recordings across the casing logged is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 10%) are recorded throughout the casing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded throughout the casing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the casing logged. E. Gustin C. Waldrop J. Perl F�Zid Fngineegs; 'P':tgers(es) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, T X 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalvsis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 C6 PDS Multifinger Caliper 3D Log Plot Company : BP Exploration (Alaska), Inc. Field : Prudhoe Bay Well: OWDW-C Date : April 17, 2012 Description Overlay of Centered and Off -Center Caliper Recordings Across 5.5" Casing Logged .- I.D. 4.5 inches 5,5 RadiusMinimum Maximum ------------------------ 2.25 inches 2.75 Minimum Radius --------------- Nominal I.D. 4.5 inches 5.5 ■■ ■ 50.0 � �■■ -tea ' >� � ■!!! �E ■■■ ■®■■■ _ 150.0200.0 ■ ! ■■■. ■o a, ■ ■■■ ■! ■' ■ ■■ MEW 0.0 ■■ ■■■ ■� MEN MI W, ■�—MM ■ ■ 300.0 ■ ■■ ■ ■■0 91 ■■■ 350.0 ■o a's ■■■ ■ ■■ ■�!!�KE1� ■■■ ■■ ,�■■■ ■■MWINE ■■■ ■■■ I ■■■ -Amp"% -K s, •.cam""_.. Well: OWDW-C Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Tubinp� _ 5.5 ins 17 ppf N-80 Tubing: Nom.OD Weight Grade & Thread - —5.5 ins —_ -17 Ppf N-80 - --_ i j Penetration(% wall) 0 --- I i 0 to 20 to 40 to over 20%n 40% 85% 85% j Number of joints analysed (total = 54) y 54 0 0 0 Damage Configuration ( body) i I I I I' Iwlated General Line Other Hole Pitting corrosion Corrosion Damage Pos. Hole I I Number of' in I = 0 0 0 0 0 PDS Report Overview Body Region Analysis Survey Date: April 17, 2012 Tool Type: UW MFC XR 40 No. 217958 Tool Size: 2.75 No. of Fingers: 40 Analyst: C. Waldrop Nom.ID Nom.Upset Upper len. Lower len. 4.892 ins 5.5 ins 6.0 ins 6.0 ins _ Damage Profile (% wall) i Penetration body Metal loss body 0 50 0 — — i— I of j 10 i 20 i I I i i I I I I i i 30 I ! I 40 I I i I I i I I I I I I 50 i l Bottom of Survey = 53 PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 17.0 ppf N-80 Well: OWDW-C Body Wall: 0.304 in Field: Prudhoe Bay Upset Wall: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 4.892 in Country: USA Survey Date: April 17, 2012 joint jt. Depth j ?e.'. Pen. Pen. ;Metal j Min. Damage Profile No. (Ft.) Opset Body % Loss j 1. D. Comments (% wall) ! Sli t Buckling. !ns.) (Ins.) �35 36 % j (Ins.) 0 50 100 01 __-� -0 ---- - G. -- 0.03- 10 - 2 - -- - 4.85.1_ Ptd - --- - _____ 1 -- -17 _ -__0 0.02. 8 _ 2 4.86 -Slight Buckling. -- 2 -3 57 0 0.03 10 4 4.87 1-- 0 97 0 0.02 7 3__- 4.85 1j j 1 _ 4 136 0 0.02 7 2 4.88 1 5 176- 0 ;_ 0.02 ___ 7 -_2_ _ 4.87 Sli ht Bucklin - �_ 6 _ 216 0 0.02 _ 7 _ 2 4.88---- - ----- 7 _ _. 2561-0 - 0.03 - -103 0 4.88 ! -- ---- - - - -- 8 _ 295 .-- ---0 -' -0.02 - 7 - 2 4.86---- --------- -- --- - 9 - - - 335_ - -0 -0-02 _' _ 7 -__2_ _ ._. 4.88 __ Slight.Buckling. 10 374 _ 0 0.03 8 3 4.88 11 414---------0 1722- 0.02 7 3 - 4.89 - --- - -- -- _ ------------- _ _ - - --- 12 ---- 454 ----- 0 -------- 0.02 6 --_ 2_.__.4.87 ---------------------- ---- _13 493 0 _0.02 __i _`_2 4.84 _4.89 Slight Buckling. -- - 14 533 0 0.02 7 2 4.87 15__-572 7 0 0.02-7 _ 3 4.86 -- ------ 612 0 ! 7 3 4.88__;_ --116 - 17 -- 6520 _ ' 0.02 7 3 4.8 7 ! Slight Buckling-- -- -- -- j 1 18 691 0 0.03 9 3 4.87 19 731 0 0.02 6 2 4.90' j i! 20 771 0 0.03 8 ! 3 4.87 I !i � 21 810 0 0.02 7 3 4.90 Sli t Buckling.I " 22 850 0 10.02 8 2 4.89 23 889 0 .0.02 7 3 4.87 24 929 0 0.02 7 3 4.87 25 969 0 i 0.02 7 3 4.86 Slight Buckling, 26 1008 0 0.02 i 8 I 2 4.86 ! Axial Displacement. ! i 27 1048 0 0.03 8 3 4.87 1088 00.02 7 2 4.88 _28 29 1127 0 0.02 7 �- 3 4.88 30 1167 0 0.02 1_ : 2 4.87 i Slight Buckling, 31 1207_ 00 0 J I 2 4.87 32_ 1246 0 0.02 t 8 1 3 1 4.87 vt I i ?Ar' In n ni R 1 'A I a R7 34-- 1326 0 1 0.03 ' 8 ' 4 4.84 ! Sli t Buckling. �35 36 1365 1405 0 0 0.02 ! 0.02 7 7 2 3 4.85 4.86 1 37 1444 0 0.02 7 3 4.86 38 1484 0 10.03 8 2 4.85 Sli ht Buckling, 39 1524 0 0.02 7 3 4.85 l i 40 1563 0 0.02 7 2 4.87 ------------------�--------- I i! 41 1603 0 0.03 8 2 4.84 Slight Buckling. i 42 1643 0 0.03 10 3 4.85 43 1682 0 0.02 7 3 4.86 ! 44 1722- 0 0.02 8 1 3 4.86 45 1761 0 0.03 9 3 4.84 Slight Buckling. 46' 1801 0 0.02 7 2 4.86 47 1841 0 0.03 10 1 3 4.86 1 48 1880 0 0.03 8 2 4.88 Sli t Buckliny 49 1 1920 0 1 0.02 7 ' 2 1 4.86 Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 17.0 ppf N-80 Well: OWDW-C Body Wall: 0.304 in Field: Prudhoe Bay Upset Wall: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 4.892 in Country: USA Survey Date: April 17, 2012 Joint ' )t. Depth 'Fri. Pen. Pen. Metal Min. No. (Ft.) Upset Body % Loss I.D. i Ons.) (Ins.) I % ; (Ins.) ;n 195Q 1 n m -- a ; 4 R7 Page 2 Damage Profile Comments (% wall) 0 50 100' -- ----- - — - — I — --- Penetration Body Metal Loss Body Memory Multi -Finger Caliper Log Results Summary ji S_ h Company: BP Exploration (Alaska), Inc. Well: OWDW-C Log Date: April 17, 2012 Field: Prudhoe Bay Log No. 10213 State: Alaska Run No.: 1 API No. 50-029-21821-00 Pipe Description: 5.5 inch 17 Ib. N-80 Top Log Interval: Surface Pipe Use: Casing Bottom Log Interval: 2,110 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into surface at 0 feet (Driller's Depth). This log was run to assess the condition of the casing with respect to corrosive and mechanical damage The caliper recordings indicate the 5.5 inch casing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. Although no significant I.D. restrictions are recorded, the caliper recordings indicate slight buckling from surface to -1,890 feet, and axial displacement from 1,014 feet to 1,024 feet. A 3-D log plot overlay of the centered and off -center caliper recordings across the casing logged is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 10%) are recorded throughout the casing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded throughout the casing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the casing logged. E. Gustin C. Waldrop J. Perl ProAct'sve Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysisarnemoryloo-tan Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 PDS Multifinger Caliper 3D Log Plot Company: BP Exploration (Alaska), Inc. Field : Prudhoe Bay Well: OWDW-C Date : April 17, 2012 Description : Overlay of Centered and Off -Center Caliper Recordings Across 5.5" Casing Logged. 0.0 50.0 100.0 150.0 NEE i MEN 250.0 Image Map (Off -Center) 3-D Log (Centered) Image Map (Centered) ELL I 0° 90°' 180° 270° 00 0° 0° 90° 180° 270° 0° 1�Nwl A2'2'_M7 350.0 s_ 400.0 Maximum I.D. Depth 3-D Log (Of 4.5 inches 5 5 1ft 800ft 0. Minimum I.D. 4 5 inches 5.5 ------------------------------- Maximum Radius 2.25 inches 2.75 Minimum Radius ------------------------------ 2.25 inches 2.75 ..............................................................: Nominal I.D. 4.5 inches 5.5 0.0 50.0 100.0 150.0 NEE i MEN 250.0 Image Map (Off -Center) 3-D Log (Centered) Image Map (Centered) ELL I 0° 90°' 180° 270° 00 0° 0° 90° 180° 270° 0° 1�Nwl A2'2'_M7 350.0 s_ 400.0 : PA 44 �- s --m 60 40 20 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 54) 54 0 0 0 Damage Configuration body Isolated General Line Other Hole Pitting Corrosion Corrosion Damage Pos. Hole 0 0 0 0 0 1 Penetration body Metal loss body 0 50 100 0 10 2011i Bottom of Survey = 53 30 PDS Report Overview Body Region Analysis Well: OWDW-C Survey Date: April 17, 2012 Field: Prudhoe Bay Tool Type: UW MFC XR 40 No. 217958 50 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing-______ 5.5 'ins 17-ppf -N-80 Analyst-, C. Waldrop Tubing: Nom.OD Weight Grade & Thread NomJD Nom.Upset Upper len. Lower len. 5.5 ins 17-ppf N-80 4.892 ins 5.5 ins 6.0 ins 6.0 ins __ _ Penetration(% wall) Damage Profile (% wall) 60 40 20 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 54) 54 0 0 0 Damage Configuration body Isolated General Line Other Hole Pitting Corrosion Corrosion Damage Pos. Hole 0 0 0 0 0 1 Penetration body Metal loss body 0 50 100 0 10 2011i Bottom of Survey = 53 30 40 50 Damage Profile (% wall) 0 50 100, 1 PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 17.0 ppf N-80 Well: OWDW-C Body Wall: 0.304 in 57 Field: Prudhoe Bay Upset Wall: 0.304 in 4 Company: BP Exploration (Alaska), Inc. Nominal I.D.: 4.892 in 0 Country: USA 3 4.85 Survey Date: April 17, 2012 Joint jt. Depth -1 Pen. Pen. Pen. Metal: Min. - No. (Ft.) Upset Body % Loss 1. D. Comments 176 (Ills.) % (Ins.) 2 --003 )m in 2 48 C D 216 Damage Profile (% wall) 0 50 100, 1 17 0 0.02 ' 8- 2 4.86 u Slight Buckling. 2 57 0 I -10.03 I 10 4 4.87 3 97 0 0.02 1 7 3 4.85 4 136 0 0.02 1 7 2 4.88 5 176 0 0.02 7 2 4.87 Slight BuckLing 216 —0 0.02 7 2--.4.-88 7 256 0 0.03 10 3 488 80 0 0.02 7 2 4.86 9 ---.-335 0.02 7 2 4.88 Slight Buckling._ 0 0.03 8 3 4.88 11 414 00.02 7 3 4.89 12 ---- 4541 0 0.02 6 2 4.87 1-3 4 93 0.02 7 _2_.__-4.89 Slight Buckling-_ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 17.0 ppf N-80 Well: OWDW-C Body Wall: 0.304 in Field: Prudhoe Bay Upset Wall: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 4.892 in Country: USA Survey Date: April 17, 2012 Joint Jt. Depth Pen. Pen. Pen. Metal i Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % ; (Ins.) !0 50 100 50 1959 0 _ -1 _ 003 3 -8 --3 ' 4.87 I 51 1999 0 0.03 8 2 4.87 i 52 2039 0 0.02 17 3 4.85 _ 53 2079 0 1 0.03 L 9--1 3 4.79_Lt. Deposits. Penetration Body Metal Loss Body Page 2 'TREE = BLIND FLANGE ONLY WELLHEAD = FMC ACTUATOR = KB. ELEV = 56.5' BF. E -- -K—Op Max, Dates Datui OWDW-C I MEASURED FROM GROUND LEVEL. DATE REV BY COMMENTS DATE REV BY COMMENTS 06/23/73 ORIGINAL COMPLETION 05/31/06 DTM WELLHEAD CORRECTIONS 12/19/98 LAST TAG DATE 11/09/00 SIS-SLT CONVERTEDTO CANVAS 03/03/01 SIS -MD FINAL 09/19/01 RN/KAK I CORRECTIONS 09/27/01 MB/KAK I CORRECTIONS PRUDHOE BAY UNIT WELL: OWDW-C PERMIT No: 100-242 API No.. 50-029-21821-00 SEC 11, T10N, R14E; FEL, FNL BP Exploration (Alaska) Stephanie Pacillo Data Manager Schiumberger WHO Services WIRELINE 2525 Gambell St, Ste. 400 Anchorage, AK 99503 9: Office: (907) 273-1770 DATE: 3 -Jul -13 TRANS#: 6149 3 \ C.) (-;) - 24-k-2 Makana K Bender Natural Resources Technician II Alaska Oil & Gas Conservation Commission 333 W_ 711' Ave, Suite 100 Anchorage, AIS 99501 (907 ) 793-1225 makana . benderkalask LU --Dy, WELL NAME.;,: , 02-06C SERVICE CEYC-00063 OH RESERV CNL X MECH LOG• MCNL DACOLOR PRtNTS 7 -May -13 PRINTS 1 CD's 1 CD 04-37 C5XI-00084 X jo MEMORY LEAK DETECT LOG 23 -May -13 1 1 CD L-210 C5XI-00102 X V9 MEMORY IPROF 30 -Jun -13 1 1 CD K -02D C5XI-00076 X MEMORY PPROF w/ GHOST 21 -Apr -13 1 1 CD • 11-2-24A C1 UB -00023 I lq5-- X LDWG EDIT OF RST 29 -Jun -12 1 CD • 04-30 C4W7-00027 IA5 089 X LDWG EDIT OF RST 1 -Jul -12 h1A 1 CD 05-31 B CBAF-00040 — © X LDWG EDIT OF RST 4 -Feb -13 1 CD B -29A BUTT -00061 X LDWG EDIT OF MCNL 25 -Feb -12 1 1 CD C -12C C600-00009 X LDWG EDIT OF MCNL 30 -May -12 1 1 CD E -01A BJGT-00100 Q X LDWG EDIT OF RST 8 -Apr -12 1 1 CD N-17 BG41-1-00122 X LDWG EDIT OF RST 26 -Mar -12 1 1 CD 15-09B C600-00002 X LDWG EDIT OF MCNL 28 -Apr -12 1 1 CD C -35B C4W7-00003 X LDWG EDIT OF RST 7 -Apr -12 1 1 CD 18-15C BCRC-00170 X LDWG EDIT OF MCNL 11 -Mar -12 1 1 CD G -09B BD88-00204 elo X LDWG EDIT OF MCNL 22 -Mar -12 1 1 CD F -29B BAUJ-00112 X LDWG EDIT OF MCNL 27 -Feb -12 1 1 CD OWDW-C C2JC-00013 — LDWG EDIT OF RST 22 -Apr -12 1 1 CD M-25 C2JC-00008 X LDWG EDIT OF RST 29 -Mar -12 1 1 CD M-15 BINC-00092 Q X LDWG EDIT OF RST 10 -Jan -12 1 1 CD F -31A BUTT -00063 X LDWG EDIT OF MCNL 28 -Mar -12 1 1 CD X X Please return a signed copy to: lea a signe pffieqa5� 47 BP PDC LR2-1 eline 2525 Gam ell St, 900 E Benson Blvd 5ED OCT 02 2014 Anchorage AK 3 Anchorage AK 99508<? `�L<� Stephanie Pacillo Data Delivery Services Technician Schlumberger Oilfield Services Data & Consulting Services 2525 Gambell St, Ste. 400 Anchorage, AK 99503 W: Office: (907) 273-1770 DATE: 17 -May -12 TRANS#: 5955 ,)�MakanaK Bender ,+ Natural Resources Technician II Alaska Oil & Gas Conservation Cominission WELL SERVICE OH RESERV CNL MECH LOG DESCRIPTION DATE B/W COLOR ELECTRONIC N002 DIST DIST DIST LOGGE1111- MPB-20 C4W7-00008 X WATERFLOW RST LOG 30 -Apr -12 1 1 G -09B BD88-00204 X MEMORY PPROF W GHOST 20 -Mar -12 1 1 G -09B BD88-00204 X MEMORY CNL BORAX IPROF 22 -Mar -12 1 1 16-22 BX69-00028 X PPROF W GHOST DEFT 22 -Feb -12 1 1 P2-39 BYS4-00024 X USIT 26 -Mar -12 1 1 OWDW-C C2JC-00013 X USIT W CBL 23 -Apr -12 1 1 1 J-26 C2JC-00015 X LEAK DETECT LOG 7 -May -12 1 1 X Please return a signed copy to: BP PDC LR2-1 900 E Benson Blvd Anchorage AK 99508 SCMIAEt) OCT 0 2 2014 X Please return a signed copy to: DCS 2525 Gambell St, Suite 400 Anchorage AK 99503 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/27/10 Inspector: Bob Noble Well Name: PBU OWDW-C PTD No.: 100-242 Location Verified? No If Verified, How? ier (specify in commei Onshore / Offshore: Onshore Suspension Date: 06/23/73 Sundry No.: N/A Well Pressures (psi): Tubing ? IA ? OA ? Operator: BPX Oper. Rep: Ryan Holt Oper. Phone: 659-5766 Oper. Email: Date AOGCC Notified: 08/26/10 Type of Inspection: Initial Wellbore Diagram Avail.? No Photos Taken? Yes Condition of Wellhead: Wellhead was a spool piece sticking out of the ground It had a tapped flange on the top with a needle valve and a flange at i flange at ground level with a tap and needle valve in the spool below Both needle valves were opened and found not to have on them There were no markings on well. I only went by Ryan Holt telling me that it is the well. There was no barrier around v Condition of Surrounding Surface The ground around was in good clean condition around the well. Location: Follow Up Actions The location of this well verified with a plot plan and sign. I would like to see a well schematic Needed The well needs proper sign It needs a barrier to protect it Note: Well never completed; transferred to AOGCC as part of UIC Class II oversight ' Attachments: Photo (1) A REVIEWED BY: Insp. Suprva L0L Comm PLB 08/2010 2010-0827_Suspend_PBU_OWDW-C_bn.xis 0 0 Suspended Well Inspection — PBU OWDW-C PTD 100-242 Photos by AOGCC Inspector B. Noble 8-27-2010 PBU OWDW-C Suspended Well Inspection 8-27-10 bn • • z WED ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS333 W. 7th AVENUE, SUITE 100 CONSERTATION C01101ISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Preble Data Management Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 0 0 Re: Prudhoe Bay Field, Prudhoe Bay Pool, OWDW-C Sundry Number: 310-291 Dear Mr. Preble: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy. . Foerster Commissioner DATED this k day of September, 2010. Encl. • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 September 8, 2010 • *� r"" -fir F: r> 7010 Mr. Daniel Seamount, Chairman rpr ;;tsson Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well OWDW-C (PTD #1002420) Suspended Well Inspection Report (10-404) Application for Renewal of Existing Suspension (10-403) Dear Mr. Seamount, BP Exploration (Alaska) Inc. (BPXA) completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well OWDW-C on 8/27/10. Enclosed is a Report of Sundry Well Operations (10-404) with attachments documenting the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). Recent well events from this well indicate that this well is mechanically sound. Specific attachments include: • Suspended Well Site Inspection form documenting the well pressures and site condition • Wellbore diagram illustrating the current configuration of the well • Pad map and aerial photo showing well location and other wells within one- quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Prudhoe Bay Unit well OWDW-C was suspended on 6/23/73. It is located on a pad with active service wells. Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10- 403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Prudhoe Bay Unit well OWDW-C is mechanically sound and secure and will meet the requirements for renewal of suspended status. • If you require any additional information, please contact me at 564-5637, Torin Roschinger/Jerry Murphy at 659-5102 or Chris Stone 564-5518. Sincerely, R. Steven Rossberg BPXA, Wells Operations Manager Attachments: Report of Sundry Operations (Form 10-404) with attachments: Suspended Well Site Inspection form Wellbore Schematic Well location plat and aerial photo Pictures of wellhead and location Application for Sundry Approval (Form 10-403) with attachment: Technical Justification Cc: Roschinger/Murphy Harry Engel Mike Bill Chris Stone Gary Preble 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AArl 9a 901) 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re-enter Susp. Well ❑ Stimulate[] Alter Casing ❑ Other. RENEW SUSPENSION ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑, 100-2420- 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-21821-00-00 - 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 El Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028311 PRUDHOE BAY Field / PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 2250- 2250 2214 2214 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 100 13-3/8"72# N-80 SURFACE 100 SURFACE 100 4930 2670 Surface 2250 5-1/2" 17# N-80 SURFACE 2250 SURFACE 2250 7740 6280 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE- - NONE Packers and SSSV TVDe: NONE Packers and SSSV MD and TVD (ft): 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program R1 BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑✓ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/13/2010 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 Gary Preble Printed Name ary Preble Title Data Management Engineer Signature Phone Date 564-4944 fPrepared Zd by Gary Preble 564-4944 COMMISSION USE ONLY Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ s 4 z,"`' Other: ) �ouuC Z5- � �'vs is Subsequent Form Required: 'j- APPROVED BY Y Approved by: �`s �"_ COMMISSIONER THE COMMISSION ;1 Date:? -2-7 ID '.0 — 1IvuTS qtr z 8 cuiu , �j Submit in Duplicate Prudhoe Bay Oil Pool well OWDW-C Technical Justification for Application for Renewal of Suspension Status September 8, 2010 Well Status Prudhoe Bay Unit well OWDW-C (PTD #1002420) was drilled, cased and cemented and then suspended on 6/23/73. The well was drilled to 2250' MD as the center well of a 5 -spot pattern of a test to determine the effects of thawing and re -freezing permafrost on casing. Hot glycol circulated using an open ended tubing string and the thawed region and casing strain was monitored in the offset wells. The well was never perforated and currently has no tubing or tree. It is located between, but within 25 feet of active Class I disposal wells OWDW-NW, SW and SE. The well has been used in the past to observe temperatures in the disposal zone and the permafrost near the disposal wells. In the event one of the active disposal wells became unusable, OWDW- C could be completed and perforated as a replacement well. The well is mechanically sound. It will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe, and not a threat to public health. The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of the Wellhead and Surface Location Prudhoe Bay Unit well OWDW-C is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. During the inspection, it was discovered the well sign was missing. A new sign will be ordered and placed at the well. The well pressure readings showed zero on the casing and lower flange needle valve. Request BPXA requests approval for renewal of the existing suspension status for OWDW-C. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other 0 INSPECT Performed: Alter Casing ❑ Pull Tubing[] Perforate New Pool ❑ Waiver[:] Time Extension ❑ WELL Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re-enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ 100-2420 Stratigraphic❑ Service ❑� 3. Address: P.O. Box 196612 6. API Numbed Anchorage, AK 99519-6612 50-029-21821-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028311 OWDW-C 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 2250 feet Plugs (measured) None feet true vertical 2250 feet Junk (measured) None feet Effective Depth measured 2214 feet Packer (measured) true vertical 2214 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 100 13-3/8" 72# N-80 SURFACE - 100 SURFACE - 100 4930 2670 Surface 2250 5-1/2" 17# N-80 SURFACE - 2250 SURFACE - 2250 7740 6280 Intermediate Production Liner - Liner Perforation depth: Measured depth: NONE - True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) NONE 0 Packers and SSSV (type, measured and true vertical depth) NONE 20111 12. Stimulation or cement squeeze summary: Intervals treated (measured):_4$Si0g 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: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ qp4lopment ❑ Service ❑✓ 16. Well Status after we USPENDED Oil 0 Gas Lj WDSPL Daily Report of Well Operations X GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signaturenr%�S SEP (4-4944 Date 9 f b • : • - - - - :: _ is .'3%IL�.yr.. . . Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT OWDW-C Field/Pool: PRUDHOE BAY 1 PRUDHOE UNDEFINED WDSP Permit # (PTD): 100-242 API Number: 50029218210000 Operator: BP EXPLORATION (ALASKA) INC Date Suspenc 6/23/1973 Surface Location: Section: 11 Twsp: 10N Range: 14E Nearest active pad or road: Prudhoe Bay Pad -3 / Drillsite #6 Take to Location Digital carnera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None -- Pits condition: N/A -- Surrounding area condition: Good Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): 4; Wellhead and site 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: Good / spool piece / no yate valves Cellar description, condition, fluids: Dry gravel _ Rat Hole: None ---- Wellhouse or protective barriers: No barriers _ Well identification sign: No sign Tubing Pressure (or casing if no tubing): 0 psi upper flange needle valve Annulus pressures: 0 psi lower flange needle valve Wellhead Photos taken (# and description): 4; Wellhead and site Work Required: Excavate lower flange in cellar / put up sign and barrier Operator Rep (name and signature): AOGCC Inspector: Bob Noble Inspection Date: 8/27/2010 Time of arrival: 10:30 AM Site access method: Drive Je Other Observers: AOGCC Notice Date: Time of Departure: Holt 1010 10:45 AM ' TREE = BLIND FLANGE ONLY WELLHEAD = FMC ACTUATOR= KB. ELEV = 56.5' BF. E KOP Max Datur Datur OWDW-C DATE REV BY COMMENTS DATE REV BY COMMENTS 06/23/73 ORIGINAL COMPLETION 05/31/06 DTM WELLHEAD CORRECTIONS 12/19/98 LAST TAG DATE 11/09/00 SIS-SLT CONVERTED TO CANVAS 03/03/01 SIS -MD FINAL 09/19/01 RN/KAK CORRECTIONS 09/27/01 MB/KAK CORRECTIONS PRUDHOE BAY UNIT WELL: OWDW-C PERMIT No: 100-242 API No.: 50-029-21821-00 SEC 11, T10N, R14E, FEL, FNL BP Exploration (Alaska) Enter/Exit 1261' V 17, 4� of 0 275' C� 240' � O � I 23 16 2 22 3 15 � 21 14 4 20 13 5 N �19 �12 L6 18 11 7 17 10 8 9 a icades an west 4854 k 4955 Tanks l Pit 39-1901 I1 / 39-1902 Edstl TannTr adi `.�` _ : ' 4952 Pit / °admLO 9/ �I t Ta 9 Area �. i - Drum Enter/ nk38.1g06 tore =_= 4953 Area 9e Exit " 4952 n I ' cell J U cel/1 n _ u WELL PRODUCER■ TADATE WELL INJECTOR :01/06/2009 SCALE: 1" = 275' MAP DATE: 2007 PBU - DS6 WELL SLOT W/CONDUCTOR bsl4495.dgn pS-6&Pad 3 July 14, 2009 Approximate Scale: 1"=300' 2009-19c-8-14 AMM -MEW -a sk gle v,. - 44,tr FA 9Ai a tom+- 5 # t Av NEEL ax � , a _ _._ �, 1 e�, ,� ,'. •.. __._ . `� W . ,\ , � ,�, �_� a V'A I / t rr t a sA h - , _ r . r.. ,`: . �. .,. i �. »... _^«.. _ tet, '• :.. -.: �., a - b ' f ' y a :740 imp ti ,t �, • - .,,� •. ,yi Ilk i Y•. r _ vw .a •�.' ••' pre � • a . F^ • - rr • "''�4" e . z .iib 41, m Wig, . •> . , ,. • # °y + +7 �s ^- fin' ^' �` q • ,4 •' 4 • mi � " • ;y �aiy�.r i � ir . 3 � * : i ,.. , r ,✓ a. ., w F w ( �y a . f �i3w... —++ All , ,• .�,. O � tla94w. > � �5 a i I r SARAH PALIN, GOVERNOR LSSA 0611) AND %A 333 W 7th AVENUE, SUITE 100 CGIMERVA ON COMMSSIGY ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 29, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7004 1160 00013621 1878 Harry Engel BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Request for Verification of Suspended, Shut -In and Observation Well Information Dear Mr. Engel: SCANNED APR 0 x. 2014 This letter supersedes our correspondence of January 28, 2009. Enclosed are lists of suspended, long term shut-in and observation wells operated by BP Exploration Alaska Inc. and BP Alaska Inc. For each list, please verify the information for each well, and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, P/1710� Cathy7.Foerster Commissioner Enclosures w MAILT. RECEIPT cO (DomesticCERTIFIED rq ni For delivery. At l f i KE W 9951 -bt 12'` `, u m Postage $ $0.59 Qg PO? E3 C3 O Certified Fee Return Reciept Fee $2.70 J 2 (Endorsement Required) $2,40 0 9 O C3 Restricted Delivery Fee (Endorsement Required) $0.00 S O� r q Total Postage & Fees $ $5.49 9 N 01/ G 9g50 O O f� Sent To '�•----------- ------ Street or PO Box No. / (� City, State, Z/P+4 ---------------------- PS Form:r0 June 2002 ■ Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: /-M rry Z/ -?9 e / 9PX/-;1 /00/H 9'614/2 X /%G L. / ' " � q 51511/ A. Signatu X KAgent ❑ Addressee B. Re eiv by (Printed Name) C. Date of Delivery D. Is delivery a�-dress diffefent from item 19 ❑ 6i If YES, enter delivery address below: ❑ No 3.,SS ce Type ZQS.CertPied Mail ❑ Express Mail ❑ Registered,Lalleturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (transfer from service label) _ ?004 116 0 0001 3621 18 7 8 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator Suspended, Shut In and Observation Wells BP ALASKA INC Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... PRUDHOE BAY 169-068-0 50-029-20036-00-00 PUT RIV 01-10-14 OBSW 9/19/1975 555 FNL 710 FEL Sec 11 T 10 N R 14E UM 169-069-0 50-029-20037-00-00 PUT RIV 02-10-14 OBSW 9/19/1975 555 FNL 820 FEL Sec 11 T 10 N R 14E UM 169-070-0 50-029-20038-00-00 PUT RIV 11-10-14 OBSW 9/19/1975 555 FNL 930 FEL Sec 11 T 10 N R 14 E UM 169-059-0 50-029-20033-00-00 PUT RIV 13-10-14 OBSW 9/19/1975 650 FSL 555 FWL Sec 13 T 10 N R 14E UM 169-062-0 50-029-20034-00-00 PUT RIV 14-10-14 OBSW 9/19/1975 430 FSL 555 FWL Sec 13 T 10 N R 14 E UM 169-081-0 50-029-20043-00-00 PUT RIV 17-10-15 OBSW 9/19/1975 755 FNL 600 FEL Sec 19 T 10 N R 15E UM Thursday, January 29, 2009 Operator Suspended, Shut In and Observation Wells BP EXPLORATION (ALASKA) INC Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... *EXPLORATORY 198-252-0 50-089-20027-00-00 RED DOG 1 SUSP 4/2/1999 1682 FSL 4508 FEL Sec 34 T 10 N R 21 E UM ENDICOTT 196-022-0 50-029-22644-00-00 DUCK IS UNIT MPI 1-59/024 SUSP 2/21/1996 3083 FSL 2202 FEL Sec 36 T 12 N R 16E UM MILNE POINT 196-009-0 50-029-22642-00-00 MILNE PT UNIT KR B-24 SUSP 3/3/1996 827 FSL 4289 FEL Sec 18 T 13 N R 11 E UM 199-091-0 50-029-21373-01-00 MILNE PT UNIT KR C -12A SUSP 7/13/2003 496 FSL 2027 FEL Sec 10 T 13 N R 10E UM 185-110-0 50-029-21364-00-00 MILNE PT UNIT KR C-16 SUSP 10/27/1993 610 FSL 2063 FEL Sec 10 T 13N R 10E UM 196-032-0 50-029-22650-00-00 MILNE PT UNIT KR K-25 SUSP 3/23/1996 3592 FSL 2078 FEL Sec 3 T 12 N R 11 E UM 197-080-0 50-029-22766-00-00 MILNE PT UNIT KR L-34 SUSP 12/1/2008 3285 FSL 5106 FEL Sec 8 T 13 N R 10E UM 201-109-0 50-029-22768-01-00 MILNE PT UNIT KR L -35A SUSP 10/12/2002 3177 FSL 4937 FEL Sec 8 T 13 N R 10E UM 201-075-0 50-029-23012-00-00 MILNE PT UNIT SB I-13 SUSP 8/19/2001 2346 FSL 1253 FWL Sec 33 T 13 N R 10E UM NORTHSTAR 200-211-0 50-029-22996-00-00 NORTHSTAR UNIT NS -26 SUSP 2/1/2001 1298 FSL 648 FEL Sec 11 T 13 N R 13E UM 206-138-0 50-029-23325-00-00 NORTHSTAR UNIT NS -33 SUSP 4/26/2007 1369 FSL 650 FEL Sec 11 T 13 N R 13 E UM PRUDHOE BAY 174-006-0 50-029-20133-00-00 E BAY ST 1 OBSW 10/6/1986 1536 FNL 635 FWL Sec 15 T 11 N R 15E UM 175-059-0 50-029-20177-00-00 GETTY STATE 1 OBSW 5/11/1980 1388 FSL 887 FWL Sec 2 T 10 N R 13E UM 180-092-0 50-029-20504-00-00 PBU MP 11-33-11-12 1 SUSP 4/29/1981 1966 FNL 1380 FEL Sec 33 T 11 N R 12 E UM 198-035-0 50-029-22866-00-00 PRUDHOE BAY UN BORE 02-01 SUSP 4/22/1998 453 FSL 4553 FWL Sec 19 T 12 N R 11 E UM 205-010-0 50-029-23245-00-00 PRUDHOE BAY UN BORE I-100 SUSP 4/17/2006 3219 FSL 3945 FEL Sec 20 T 12 N R 11 E UM 189-075-0 50-029-21959-00-00 PRUDHOE BAY UN LIS 1-3-01 SUSP 9/13/1994 287 FNL 550 FWL Sec 22 T 11 N R 15E UM 189-104-0 50-029-21978-00-00 PRUDHOE BAY UN LIS 1-4-02 SI 12/8/1994 2426 FSL 2176 FEL Sec 24 T 11 N R 15E UM 202-002-0 50-029-22789-01-00 PRUDHOE BAY UN NIA NK -11A SUSP 2/22/2002 1312 FSL 1021 FEL Sec 36 T 12 N R 15E UM 206-031-0 50-029-22668-01-00 PRUDHOE BAY UN NIA NK -14A SUSP 5/4/2007 1358 FSL 944 FEL Sec 36 T 12 N R 15 E UM 197-158-0 50-029-22778-01-00 PRUDHOE BAY UN NIA NK -41A SUSP 11/2/1997 1474 FSL 717 FEL Sec 36 T 12N R 15E UM 202-052-0 50-029-23072-00-00 PRUDHOE BAY UN NWE 04-01 SUSP 4/7/2002 3203 FSL 4003 FEL Sec 20 T 12N R 11 E UM Thursday, January 29, 2009 • I Operator Suspended, Shut In and Observation Wells BP EXPLORATION (ALASKA) INC Field Permit API Number Well Name Current Date of Status Status Surface Location__ . . ............................. Lease(s)................................... 201-222-0 50-029-23054-00-00 PRUDHOE BAY UN ORIN V-201 SUSP 1/25/2008 4838 FSL 1775 FEL Sec 11 T 11 N R 11 E UM 191-037-0 50-029-22146-00-00 PRUDHOE BAY UN PTM 12 SUSP 4/30/1991 1359 FSL 980 FEL Sec 16 T 12N R 14E UM 192-082-0 50-029-22283-00-00 PRUDHOE BAY UN PTM P2-55 SUSP 10/12/1992 565 FNL 4052 FEL Sec 14 T 12N R 14E UM 176-034-0 50-029-20208-00-00 PRUDHOE BAY UN WBH WBST-03 SUSP 7/26/1976 70 FSL 2000 FWL Sec 25 T 12N R 14E UM 170-040-0 50-029-20076-00-00 PRUDHOE BAY UNIT 01-05 SUSP 5/25/2007 547 FNL 1420 FWL Sec 8 T ION R 15E UM 200-126-0 50-029-22202-02-00 PRUDHOE BAY UNIT 02-30B SUSP 7/6/2007 154 FNL 774 FWL Sec 36 T 11 N R 14 E UM 195-024-0 50-029-20096-01-00 PRUDHOE BAY UNIT 04-04A SUSP 4/17/1995 916 FNL 382 FEL Sec 34 T 11 N R 15E UM 187-082-0 50-029-21744-00-00 PRUDHOE BAY UNIT 07-27 SUSP 9/4/1994 952 FNL 497 FWL Sec 34 T 11 N R 14 E UM 182-207-0 50-029-20878-00-00 PRUDHOE BAY UNIT 13-98 OBSW 1/17/1983 1405 FSL 361 FWL Sec 13 T ION R 14E UM 201-148-0 50-029-20764-01-00 PRUDHOE BAY UNIT A -25A SUSP 11/22/2001 2651 FNL 1703 FEL Sec 35 T 11 N R 13E UM 178-054-0 50-029-20321-00-00 PRUDHOE BAY UNIT B-10 SUSP 4/10/2008 2070 FNL 1611 FEL Sec 31 T 11N R 14 E UM 204-139-0 50-029-20654-02-00 PRUDHOE BAY UNIT E -18B SUSP 5/2/2008 1853 FNL 501 FEL Sec 6 T 11 N R 14 E UM 200-163-0 50-029-20600-01-00 PRUDHOE BAY UNIT G -13A SUSP 10/6/2008 2224 FNL 2368 FEL Sec 12 T 11 N R 13E UM 197-190-0 50-029-20487-01-00 PRUDHOE BAY UNIT H -10A SUSP 11/24/1997 1982 FNL 1264 FEL Sec 21 T 11 N R 13E UM 180-067-0 50-029-20484-00-00 PRUDHOE BAY UNIT H-12 SUSP 7/22/1994 1762 FNL 1264 FEL Sec 21 T 11N R 13E UM 181-061-0 50-029-20591-00-00 PRUDHOE BAY UNIT H-15 SUSP 10/22/2004 1432 FNL 1265 FEL Sec 21 T 11 N R 13 E UM 169-046-0 50-029-20026-00-00 PRUDHOE BAY UNIT J-04 OBSW 9/19/1975 970 FNL 1245 FEL Sec 9 T 11 N R 13 E UM 100-242-0 50-029-21821-00-00 PRUDHOE BAY UNIT OWDW-C SUSP 6/23/1973 651 FNL 1048 FEL Sec 11 T ION R 14E UM 194-144-0 50-029-22522-00-00 PRUDHOE BAY UNIT R-36 SUSP 11/1/2000 782 FSL 3629 FEL Sec 32 T 12 N R 13 E UM 191-123-0 50-029-20765-01-00 PRUDHOE BAY UNIT S -10A SUSP 11/6/1991 1644 FNL 1745 FWL Sec 35 T 12 N R 12E UM 204-071-0 50-029-20804-01-00 PRUDHOE BAY UNIT S -14A SUSP 12/18/2007 1651 FNL 2185 FWL Sec 35 T 12 N R 12 E UM 180-108-0 50-029-20511-00-00 PRUDHOE BAY UNIT TR 18-11-12 SUSP 12/24/1980 809 FSL 3893 FEL Sec 7 T 11 N R 12 E UM 180-066-0 50-029-20483-00-00 PRUDHOE BAY UNIT TR 3-10-12 SUSP 10/11/1980 1993 FNL 1479 FEL Sec 33 T 11 N R 12E UM 169-104-0 50-029-20047-00-00 PRUDHOE BAY UNIT TR PR 33-12-13 SUSP 12/20/1969 683 FNL 755 FEL Sec 33 T 12N R 13 E UM 178-102-0 50-029-20356-00-00 PRUDHOE BAY UNIT TW -C SUSP 4/25/1979 1320 FSL 1321 FEL Sec 3 T 11 N R 12E UM 192-011-0 50-029-22244-00-00 PRUDHOE BAY UNIT U-01 SUSP 3/16/1992 5134 FNL 2498 FEL Sec 18 T 11N R 13E UM 204-102-0 50-029-21947-01-00 PRUDHOE BAY UNIT W -09A SUSP 8/7/2006 1437 FNL 1194 FEL Sec 21 T 11 N R 12E UM 179-031-0 50-029-20369-00-00 PRUDHOE BAY UNIT WGI-01 SUSP 8/28/2006 258 FNL 1209 FEL Sec 11 T 11 N R 14E UM 188-115-0 50-029-21558-01-00 PRUDHOE BAY UNIT Y -22A SUSP 10/29/1988 1394 FNL 132 FEL Sec 33 T 11 N R 13E UM 208-140-0 50-029-21883-01-00 PRUDHOE BAY UNIT Y -25A SUSP 11/14/2008 1403 FNL 169 FEL Sec 33 T 11 N R 13E UM 202-046-0 50-029-22403-01-00 PRUDHOE BAY UNIT Y -37A SUSP 3/31/2002 1425 FNL 276 FEL Sec 33 T 11 N R 13E UM Thursday, January 29, 2009 Operator Suspended, Shut In and Observation Wells BP EXPLORATION (ALASKA) INC Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... 169-014-0 50-029-20011-00-00 SAG DELTA 31-11-16 186-056-0 50-029-20138-01-00 W BEACH ST 1-A PT THOMSON 196-008-0 50-089-20026-00-00 SOURDOUGH 3 Thursday, January 29, 2009 SUSP 4/28/1969 1102 FNL 1743 FEL Sec 31 T 11 N R 16 E UM SUSP 5/6/1986 70 FSL 1880 FWL Sec 25 T 12 N R 14 E UM SUSP 4/24/1996 2245 FSL 5068 FEL Sec 29 T 9N R 24 E UM \o0- 2�2 t 14 SARAH PALIN, GOVERNOR SHA OIL AND GAS� 333W 7thAVENUE, SUITE 100 CONSECONSERVATION CQ�MMSSION � ANCHORAGE ALASKA 99501-3539 RVATION LL i� l� 1•L1�1� lei' !� PHONE (907) 279-1433 FAX (907) 276-7542 .January 28, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001. 2499 5951 Karry Engel BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Engel: SCANNED APR® 12014 Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are a list of suspended wells and a list of long term shut-in wells operated by BP Exploration Alaska Inc. For each list, please verify the information for each well, and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, A/ 0�7;�C� Cathy P. oerster Commissioner Enclosures It ■ Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. • Print your name and address on the reverse so that we can return the card to you. e Attach this card to the back of the mailpiece, or on the front if soace permits. 1. Article Addressed to: Harry Engel BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 A. Sig X agent ` 0 Addressee B. Re ed bame) Cate of Delp ery D. Is delivery address different from item 1? Oyes It YES, enter delivery address below: 0 No rvice Type Certified Mail 0 Express Mail ❑ Registered -&Return Receipt for Merchandise ❑ Insured Mail 0 C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) 7005 1520 0001 2499 5951 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Postal CERTIFIED MAIL— RECEIPT LII Er Domestic h1ail Only:Provided.) Ln C 166,61A ru Aotw. = $0.59 d VS',as Q diidr'" $2.70 q Q O ReW w,. + f Wr D $2.28 �" a y ';otaj posl�gs & F�� l� $5.19 a - -- o Harry Engel 0 r 3i;;WIA 1 N6.;_., BP Exploration Alaska Inc. aP08001 z PO Box 196612 Anchorage AK 99519-6612 )per$tor Suspended and Shut In Wells BP EXPLORATION (ALASKA) INC Field Current Date of Permit API Number Well Name Status Status Surface Location. ..... .. ...... . Lease(s)................................ 198-252-0 50-089-20027-00-00 RED DOG 1 SUSP 4/2/1999 1682 FSL 4508 FEL Sec 34 T 10 N R 21 E UM ADL0377013 ENDICOTT 196-022-0 50-029-22644-00-00 DUCK IS UNIT MPI 1-59/024 SUSP 2/21/1996 3083 FSL 2202 FEL Sec 36 T 12 N R 16E UM ADL0312828 MILNE POINT 196-009-0 50-029-22642-00-00 MILNE PT UNIT KR B-24 SUSP 3/3/1996 827 FSL 4289 FEL Sec 18 T 13N R 11 E UM ADL0047432 199-091-0 50-029-21373-01-00 MILNE PT UNIT KR C -12A SUSP 7/13/2003 496 FSL 2027 FEL Sec 10 T 13N R 10E UM ADL0047434 185-110-0 50-029-21364-00-00 MILNE PT UNIT KR C-16 SUSP 10/27/1993 610 FSL 2063 FEL Sec 10 T 13N R 10E UM ADL0047437 196-032-0 50-029-22650-00-00 MILNE PT UNIT KR K-25 SUSP 3/23/1996 3592 FSL 2078 FEL Sec 3 T 12 N R 11 E UM ADL0375133 197-080-0 50-029-22766-00-00 MILNE PT UNIT KR L-34 SUSP 12/1/2008 3285 FSL 5106 FEL Sec 8 T 13N R 10E UM ADL0025514 201-109-0 50-029-22768-01-00 MILNE PT UNIT KR L -35A SUSP 10/12/2002 3177 FSL 4937 FEL Sec 8 T 13N R 10E UM ADL0025514 201-075-0 50-029-23012-00-00 MILNE PT UNIT SB 1-13 SUSP 8/19/2001 2346 FSL 1253 FWL Sec 33 T 13N R 10E UM ADL0025517 NORTHSTAR 200-211-0 50-029-22996-00-00 NORTHSTAR UNIT NS -26 SUSP 2/1/2001 1298 FSL 648 FEL Sec 11 T 13N R 13E UM ADL0312799 206-138-0 50-029-23325-00-00 NORTHSTAR UNIT NS -33 SUSP 4/26/2007 1369 FSL 650 FEL Sec 11 T 13N R 13E UM ADL0321798 PRUDHOE BAY 180-092-0 50-029-20504-00-00 PBU MP 11-33-11-12 1 SUSP 4/29/1981 1966 FNL 1380 FEL Sec 33 T 11N R 12E UM ADL0047452 198-035-0 50-029-22866-00-00 PRUDHOE BAY UN BORE 02-01 SUSP 4/22/1998 453 FSL 4553 FWL Sec 19 T 12N R 11E UM ADL0047446 205-010-0 50-029-23245-00-00 PRUDHOE BAY UN BORE 1-100 SUSP 4/17/2006 3219 FSL 3945 FEL Sec 20 T 12N R 11E UM ADL0047446 189-075-0 50-029-21959-00-00 PRUDHOE BAY UN LIS 1-3-01 SUSP 9/13/1994 287 FNL 550 FWL Sec 22 T 11N R 15 E UM ADL0034631 189-104-0 50-029-21978-00-00 PRUDHOE BAY UN LIS 1-4-02 SI 12/8/1994 2426 FSL 2176 FEL Sec 24 T 11N R 15E UM ADL0028323 202-002-0 50-029-22789-01-00 PRUDHOE BAY UN NIA NK -11A SUSP 2/22/2002 1312 FSL 1021 FEL Sec 36 T 12 N R 15 E UM ADL0034629 206-031-0 50-029-22668-01-00 PRUDHOE BAY UN NIA NK -14A SUSP 5/4/2007 1358 FSL 944 FEL Sec 36 T 12 N R 15E UM ADL0034625 197-158-0 50-029-22778-01-00 PRUDHOE BAY UN NIA NK -41A SUSP 11/2/1997 1474 FSL 717 FEL Sec 36 T 12N R 15 E UM ADL0312827 202-052-0 50-029-23072-00-00 PRUDHOE BAY UN NWE 04-01 SUSP 4/7/2002 3203 FSL 4003 FEL Sec 20 T 12 N R 11E UM ADL0047446 201-222-0 50-029-23054-00-00 PRUDHOE BAY UN ORIN V-201 SUSP 1/25/2008 4838 FSL 1775 FEL Sec 11 T 11N R 11E UM ADL0028240 191-037-0 50-029-22146-00-00 PRUDHOE BAY UN PTM 12 SUSP 4/30/1991 1359 FSL 980 FEL Sec 16 T 12N R 14 E UM ADL0375136 Wednesday, January 14. 2009 ADL0034630 ADI -0047447 Operator Suspended and Shut In 'Fells BP EXPLORATION (ALASKA) INC Field Permit API Number Well Mame Current Date of Status Status Surface Location .................................................... Lease(s)................................... 192-082-0 50-029-22283-00-00 PRUDHOE BAY UN PTM P2-55 SUSP 10/12/1992 565 FNL 4052 FEL Sec 14 T 12 N R 14 E UM ADL0034622 176-034-0 50-029-20208-00-00 PRUDHOE BAY UN WBH WBST-03 SUSP 7/26/1976 70 FSL 2000 FWL Sec 25 T 12 N R 14 E UM ADL0034627 170-040-0 50-029-20076-00-00 PRUDHOE BAY UNIT 01-05 SUSP 5/25/2007 547 FNL 1420 FWL Sec 8 T 10 N R 15E UM ADL0028328 200-126-0 50-029-22202-02-00 PRUDHOE BAY UNIT 02-30B SUSP 7/6/2007 154 FNL 774 FWL Sec 36 T 11 N R 14E UM ADL0028308 195-024-0 50-029-20096-01-00 PRUDHOE BAY UNIT 04-04A SUSP 4/17/1995 916 FNL 382 FEL Sec 34 T 11 N R 15E UM ADL0028324 187-082-0 50-029-21744-00-00 PRUDHOE BAY UNIT 07-27 SUSP 9/4/1994 952 FNL 497 FWL Sec 34 T 11 N R 14 E UM ADL0028309 201-148-0 50-029-20764-01-00 PRUDHOE BAY UNIT A -25A SUSP 11/22/2001 2651 FNL 1703 FEL Sec 35 T 11 N R 13E UM ADL0028286 178-054-0 50-029-20321-00-00 PRUDHOE BAY UNIT B-10 SUSP 4/10/2008 2070 FNL 1611 FEL Sec 31 T 11 N R 14 E UM ADL0028313 204-139-0 50-029-20654-02-00 PRUDHOE BAY UNIT E -18B SUSP 5/2/2008 1853 FNL 501 FEL Sec 6 T 11 N R 14 E UM ADL0028304 200-163-0 50-029-20600-01-00 PRUDHOE BAY UNIT G -13A SUSP 10/6/2008 2224 FNL 2368 FEL Sec 12 T 11 N R 13E UM ADL0028304 197-190-0 50-029-20487-01-00 PRUDHOE BAY UNIT H -10A SUSP 11/24/1997 1982 FNL 1264 FEL Sec 21 T 11 N R 13E UM ADL0028283 180-067-0 50-029-20484-00-00 PRUDHOE BAY UNIT H-12 SUSP 7/22/1994 1762 FNL 1264 FEL Sec 21 T 11 N R 13E UM ADL0028283 181-061-0 50-029-20591-00-00 PRUDHOE BAY UNIT H-15 SUSP 10/22/2004 1432 FNL 1265 FEL Sec 21 T 11 N R 13E UM ADL0028283 100-242-0 50-029-21821-00-00 PRUDHOE BAY UNIT OWDW-C SUSP 6/23/1973 651 FNL 1048 FEL Sec 11 T 10 N R 14 E UM ADL0028311 194-144-0 50-029-22522-00-00 PRUDHOE BAY UNIT R-36 SUSP 11/1/2000 782 FSL 3629 FEL Sec 32 T 12 N R 13E UM ADL0028279 191-123-0 50-029-20765-01-00 PRUDHOE BAY UNIT S -10A SUSP 11/6/1991 1644 FNL 1745 FWL Sec 35 T 12N R 12E UM ADL0028257 204-071-0 50-029-20804-01-00 PRUDHOE BAY UNIT S -14A SUSP 12/18/2007 1651 FNL 2185 FWL Sec 35 T 12N R 12 E UM ADL0385193 180-108-0 50-029-20511-00-00 PRUDHOE BAYJJNIT TR 18-11-12 SUSP 12/24/1980 809 FSL 3893 FEL Sec 7 T 11 N R 12E UM ADL0028262 180-066-0 50-029-20483-00-00 PRUDHOE BAY UNIT TR 3-10-12 SUSP 10/11/1980 1993 FNL 1479 FEL Sec 33 T 11 N R 12E UM ADL0047454 169-104-0 50-029-20047-00-00 PRUDHOE BAY UNIT TR PR 33-12-13 SUSP 12/20/1969 683 FNL 755 FEL Sec 33 T 12 N R 13E UM ADL0028278 178-102-0 50-029-20356-00-00 PRUDHOE BAY UNIT TW -C SUSP 4/25/1979 1320 FSL 1321 FEL Sec 3 T 11 N R 12E UM ADL0028261 192-011-0 50-029-22244-00-00 PRUDHOE BAY UNIT U-01 SUSP 3/16/1992 5134 FNL 2498 FEL Sec 18 T 11 N R 13E UM ADL0028283 204-102-0 50-029-21947-01-00 PRUDHOE BAY UNIT W -09A SUSP 8/7/2006 1437 FNL 1194 FEL Sec 21 T 11 N R 12E UM ADL0047453 179-031-0 50-029-20369-00-00 PRUDHOE BAY UNIT WGI-01 SUSP 8/28/2006 258 FNL 1209 FEL Sec 11 T 11 N R 14 E UM ADL0028302 188-115-0 50-029-21558-01-00 PRUDHOE BAY UNIT Y -22A SUSP 10/29/1988 1394 FNL 132 FEL Sec 33 T 11 N R 13E UM ADL0028288 208-140-0 50-029-21883-01-00 PRUDHOE BAY UNIT Y -25A SUSP 11/14/2008 1403 FNL 169 FEL Sec 33 T 11 N R 13E UM ADL0028287 ADL0028288 202-046-0 50-029-22403-01-00 PRUDHOE BAY UNIT Y -37A SUSP 3/31/2002 1425 FNL 276 FEL Sec 33 T 11 N R 13E UM ADL0028287 ADL0047471 169-014-0 50-029-20011-00-00 SAG DELTA 31-11-16 SUSP 4/28/1969 1102 FNL 1743 FEL Sec 31 T 11 N R 16E UM ADL0028343 186-056-0 50-029-20138-01-00 W BEACH ST 1-A SUSP 5/6/1986 70 FSL 1880 FWL Sec 25 T 12 N R 14E UM ADL0034628 PT THOMSON Wedhesday. Japuapy Operator Suspended and Shut In Wells BP EXPLORATION (ALASKA) INC Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... 196-008-0 50-089-20026-00-00 SOURDOUGH 3 SUSP 4/24/1996 2245 FSL 5068 FEL Sec 29 T 9 N R 24 E UM ADL0343112 Wednesday, January 14, 2009 ARCO SUSPENDED WELLS PRIOR TO 1980 AS OF AUGUST 1994 WELL WELL STATUS PERMIT API NUMBER WELL NAME CLASS STATUS DATE SECT TWP RNG MER 00-0242-0 029-21821-00 PRUDHOE BAY UNIT OWDW-C SER SUSP 6/23/73 11 ION 014E U 68-0095-0 029-20004-00 DELTA ST 1 EXP SUSP 2/27/69 10 ION 016E U 69-0036-0 029-20017-00 PUT RIV ST 1 EXP SUSP 7/01/69 07 ION 014E U 73-0027-0 179-20004-00 KAVIK UNIT 3 DEV SUSP 5/02/74 08 03N 023E U 74-0056-0 029-20150-00 DELTA ST 2 EXP SUSP 5/17/75 35 11N 016E U 74-0057-0 029-20151-00 GULL IS ST 1 EXP SUSP 4/01/76 28 12N 015E U 76-0013-0 029-20195-00 GULL IS ST 2 EXP SUSP 4/22/77 28 12N 015E Ti 76-0017-0 029-20199-00 HIGHLAND ST 1 DEV SUSP 4/12/76 24 11N 011E U 76-0034-0 029-20208-00 W BEACH ST 3 EXP SUSP 7/26/76 25 12N 014E U 78-0017-0 029-20278-00 W MIKKELSEN ST 1 EXP SUSP 11/11/78 32 ION 019E U 0 ARCO SUSPENDED WELLS SINCE 1980 AS OF AUGUST 1994 WELL WELL STATUS PERMIT API NUMBER WELL NAME CLASS STATUS DATE SECT TWP RNG MER 60-0041-0 133-10142-00 SWANSON RIV UNIT 34-15 DEV SUSP 8/21/91 15 08N 009W S 82-0038-0 029-20727-00 KUPARUK RIV UNIT 1F1-05 DEV SUSP 5/18/82 33 12N OIOE U 82-0218-0 029-20888-00 RAVIK ST 1 EXP SUSP 4/03/83 32 09N 009E U 83-0181-0 029-21056-00 HEMS SPRINGS ST 1 EXP SUSP 4/03/84 12 ION 011E U 84-0156-0 029-21181-00 PRUDHOE BAY UNIT DSIS-11 DEV SUSP 9/17/84 19 11N OISE U 84-0205-0 029-21221-00 PRUDHOE BAY UNIT DS11-15 DEV SUSP 2/14/91 33 11N OISE U 86-OOS6-0 029-20138-01 W BEACH ST 1-A SER SUSP 5/06/86 25 12N 014E U 89-0013-0 029-21912-00 PT MCINTYRE P1-03 EXP SUSP 4/26/89 16 12N 014E Ti 89-0041-0 029-21937-00 PT MCINTYRE P3-01 DEV SUSP 7/03/89 22 12N 014E U 90-0036-0 029-22027-00 KUPARUK RIV UNIT 1L-20 DEV SUSP 3/31/91 29 11N OIOE U 91-0069-0 029-22173-00 KUPARUK RIV UNIT 1L-26 DEV SUSP 6/09/91 32 11N OIOE U 92-0065-0 029-22261-01 PT MCINTYRE P2 -50A DEV SUSP 8/30/92 14 12N 014E U 93-0174-0 029-22419-00 KUPARUK RIV UNIT 2E-17 DEV SUSP 4/25/94 36 IIN 009E U 93-0179-0 029-22423-00 KUPARUK RIV UNIT 2E-05 DEV SUSP 4/25/94 36 11N 009E U 94-0043-0 029-20614-01 PRUDHOE BAY UNIT DS12-13A DEV SUSP 4/03/94 18 ION OISE U ALASKA INDIVIDUAL WELL PRODUCTION AS OF 10/23/96 ******** NO PRODUCTION FOUND FOR WELL: PRUDHOE BAY UNIT OWDW-C WITH API #: 0292182100 ARCO Alaska, Inc. __ Post Office Box 100 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 31, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston, Re: Suspended Well Update ARCO Alaska Inc. ("ARCO") has compiled data pertaining to the 25 suspended wells described in your August 19, 1994, letter. Any additional suspended wells which were discovered during our research are also included in this update. I have attached an update on each well and grouped the wells by geographic area. If you have any questions, please call the ARCO Contact indicated for each geographical area or me at 265-6914. Sincerely, James R. Winearner, CPL `Senior Land m e f JRW:hb Enclosures cc: M. L. Bill ATO 1528 L. D. Brown LAO 466 H. R. Engel ATO 1918 R. M. Lance ATO 1420 T. W. McKay ATO 1202 G. K. Phillips ATO 496 M. J. Reisterer ATO 1439 ARCO Alaska, Inc. Is a Subsidiary of Atlantic Richfield Company RECEIVED APR 14 1995 Alaska Oil & Gas Cons. Commission Anchora. PRUDHOE BAY UNIT (EOA) (ARCO Contact: Mike Bili 263-4254) ARCO hereby requests extensions of "suspended" status for the following wells. Additionally, an exception to the surface plug requirement of AOGCC 20AAC25.110(c) is requested. All of these wells are located in safe and accessible locations on producing drill sites that are monitored daily. The individual status of each well is detailed below. DS 18-11, API # 50-029-21181-00, Permit # 84-0156 - Drilled as ARCO/Exxon Tract Well 19-11-15 - Suspended 9/17/84, TD 4509' MD, cement plug across surface casing shoe, location inspected 9/4/86 - Name Change approval 87-538 - Deepened to TD 11927' MD 3/88, Permit # 87-0087 - Located on an active producing well pad - Active producing well currently shut in pending well work DS 11-15. A P I # 50-029-21221-00, Permit # 84-0205 - Original completion 1/8/85, TD 12412' MD - Plugged and Abandon - approval # 90-074 - Report of Sundry Operations filed 3/20/91 documents P&A - Located on an active producing well pad DS 12-13A, Sidetrack Permit # 94-043 API# 50-029-20614-01 - Original completion 9/5/81, TD 10548' MD, API # 50-029-20614-00, Permit #81-0087 - Sidetrack found high water saturation, plugged back to 8625' MD by cementing through a retainer above milled window, approval # 94-093 Well has master valve & tree cap, no tubing, no exposed perforations - � c 1\J Evaluating additional sidetrack operations, 1, i:. - Located on an active producing well pad r 4 199 OWDW C. API# 50-029-21821-00, Permit # 00-0242 - Drilled as art of a permafrost well test TD 2250' MD o►�aska Ui18� Gas Cons�Commis51on p p Anchora - Does not penetrate any freshwater sources or hydrocarbon intervals - Never perforated, no tubing in well - Surface equipment: casing flange at ground level with a 3.5' flanged pup joint with a swab cap and needle valve to monitor casing pressure - Located on active disposal well pad West Beach State 1 A. API# 50-029-20138-00, Permit # 86-0056-0 This well was Certified Capable of Producing in Paying Quantities on March 13, 1977. Suspended with 7" liner cemented and not perforated. The 9 5/8" has a 150' surface plug. This well drilled and cored the Initial Participating Area Gas Cap and may be used as an injection well. East Bav State #1. API # 50-029-20133-00, Permit # 74-0006-0 This well was Certified Capable of Producing in Paying Quantities. It is currently classified as an Observation Well and the perforated interval was temporarily abandoned by placing a cement plug across the perforations on 6/25/93,(10-404 Report 8/2/93, approval 93-108). We request the well be maintained in "Observation Well" ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 10036r -lchorage, AK 99510' March 24, 1995 Transmittal #: OWDW Data, 1 Blueline, 1 Film Karla Zuspan/ATO-1515D 265-6547 Bob Crandall, AOGCC RECEIVED MAR 2 C5 1995 Alaska Oil & Gas Cons. Commission Anchorage Please retain one copy and return a signed copy as receipt of data. OQ- )LqA 0 o -x.,41 00--1,4o (3U -z 3q on - Xie Well Number Log Date (M -D -Y) Tool Type Contractor I OWDW-C 06-20-73 DIL Sch 06-20-73 BHC Sonic Sch 06-20-73 Comp Fm Den GPI -k Sch 06-20-73 Comp Neut GR Sch 06-21-73 4 -Arm Caliper 4-' Sch -NE 06-16-73 DIL E Sch 08-01-73 GR Neutron --r Sch 06-16-731 4 -Arm Caliper Sch -NW 06-08-73 4 -Arm Caliper --r Sch 06-08-73 DIL Sch 07-31-73 GR Neutron Sch -SE 06-29-73 4 -Arm Caliper v I Sch 06-29-73 DIL I 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 AtlanticRlchfleldCompany A A WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS 3001 PORCUPINE DRIVE CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 19, 1994 David Sutter, Land Manager ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Suspended Wells Compliance with regulations Dear Mr. Sutter: ARCO Alaska Inc. has 25 suspended wells as shown on the attached lists: ARCO SUSPENDED WELLS PRIOR TO 1980 and ARCO SUSPENDED WELL SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as required by 20 AAC 25.110(e), must have well site inspections this year prior to snow covering the locations. encls c: Blair Wondzell bew/11arsusp printed on JL/ PRUDHOE BAY OPERATIONS ENGINEERING PAD 3 OILY WASTE DISPOSAL WELL (OWDW) INFORMATION WELL NAME: OWDW CENTER SURFACE LOCATION: fFeFn NV cc; ~�,�— Sec 11, T10N, R14E0 UM BOTTOM HOLE LOCATION: Straight Hole SPUD DATE: 2000 hrs 6-18-73 RIG RELEASE DATE: 1000 hrs 6-23-73 COMPLETION: No Tubing in Well Casing set to TD T D : 2250' MD PBTD: 2214' MD LOGS RUN: SP/DIL, FDC, GR/BRCS SPN Neutron, 4 -arm caliper PERFORATION: NODE DATE WELL BEGAN DISOPOSAL SERVICE: Never used for disposal CURRENT STATUS: Suspended. No current plans for service. Mac.OWDW Info Form (3/5/88) i�. 5> a MJt ; PAD 3 OILY WASTE DISPOSAL WELL LOG OF EVENTS OWDW CENTER .EVENT 06-18-73 Spud well 06-20-73 Ran DIL, BHCS, FDC, CNL,SNP Neutron 06-22-73 Ran 4 -arm caliper, GR to 2250' MID 06-23-73 Ran 56 jts 5 1/2" 17# N-80 csg to 2217' MID TD=2250' MID 06-23-73 Released rig 07-15-87 Ran bailer. Sent sample to lab. 07-16-87 Log Temp/gauge ring to 2114' MID 08-26-87 Log ARCO Sonic tool to 2127' MD 09-21-87 Tiltmeter test Ei � int mei ARCO Aiaska, Inc. \��~�� P.U. 8ox i8O36O Anchorage, Aiaska 995i0 DATE: Juiy 24, 1987 REFERENCEARCO Cased Hoie Finai ** %PECIAL DI%TRIBUTION ** Pad 3 -Center Weii 7-16-87 TEMP/CR/CCL Run 1, 5" %ch Piease sign and ret hec-cdw��as receipt of data. Received By_____ HAVE A NICE DAY! \~� Rosanne Peek ATO -i529 TRANS .'r TR Approved___- __�� ..,b X5 'FRI RVI -ION Centrai F�ies Chevron D&M � Extension Expioration # Exxon Marathon Mobii Phiiiips PB Weii Fi|es R&D 41: %ohio U)f.Aiaska Texaco - ARCO Alaska, Inc. Post Office ,4360 -► Anchorage. Alaska 99510-0360 Telephone 907 276 1215, COIK,±M' RE R EPdG SFi EldG _ October 31, 1986 SRENG SR G� L Blair Wondzel 1 SR GEOL - EPJG,gS�=l= Alaska Oil and Gas Conservation Commission (AOGCC) EIJQ,SST 3001 Porcupine Drive STAT TECF=j Anchorage, Alaska 99501-3192 TA- T--T-�E-C. Subject: Prudhoe Bay Unit Oily Waste Disposal Wells (Pad 3) FELE: . Dear Mr. Wondzell: 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), Sty' (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, //%z ;�4 Mark A. Major Operations Coordinator Prudhoe Bay Operations MAM/plw:073 Attachments RECE(VE: D NOV 0 S iggg Alaska Oil & Gas Cons. Commission Anchorage ARCC- Alas. Inc. v r Sw s-diar• c' AtlanlicWchf c—: Company 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:073.4 10-29-86 OWDW C ADL 28311 /, FN L, /og8 'FEz.. e+ Sec 11, T10N, R14E, UM Straight hole 2000 Hrs 06-18-73 1000 Hrs 06-23-73 N/A 2250' MD 2250' TVD 2214' Thaw subsidence test well 5 Service N/A; well unused since thaw test Suspended None Not used for this purpose None V'(000e, NOV 0 5 1966 Opt & G3�Commissioc� Anchorage 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:073.4 10-29-86 OWDW C ADL 28311 3292'S & 1593'E from NW corner of Sec 11, T10N, R14E, UM Straight hole 2000 Hrs 06-18-73 1000 Hrs 06-23-73 N/A 2250' MD 2250' TVD 2214' Thaw subsidence test well Service N/A; well unused since thaw test Suspended None Not used for this purpose None E E IV°E NOV 0 5 1986 ► ; pu Gas Co M. GOmm►ssiar' WELL STATUS CENTER 13-3/8" @ 72' CMT. W/ 21S CU.FT . OF DOWELL ARCTIC SET PSTO 2214' S -1/20V, 170 N-80• BTC TO 2250' CMT. W/4200 SX PERMAFROST II NEAT CMT, (TOP JOB 160 SX PERMAFROST II) TO; (-Hoyle H. Hamilton Chairman Thru: Lonnie C. Smith Commissioner OIL AND GAS CONSERVATION COMMISSION FROM: Ben LeNorman Petroleum Inspector 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. 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. o yr .. wr.; `�.ws.a�:�.r•�rres rv.-.mv - • at .a.hw .. a 11 'W20 2 A�*r PAD 860' • �t+C 2,*rI014,R14-c, U. tit.' 66 17 f M r �bA K x 3s.7 .: t' -VON , Q ° . Q' 14 11-10-14 PAD _:+t, ..._... x 33.1 3'1:4 IUN PRA 0 0 t l.i N xti WW -- G rJ L 374 �.,, ,.. b 5A x 124. 4cafe : 1* = 7.00' 712 LG'ca+t'f D s Leca��br� ._ --- 93s' //� 0 • Ai- 3TA 5VID t,OCAMOry 0 S- L bOdArrION welts. Je GE6. W W 110t r_'14t R Y�i,y� �j•�Q"i'� Q!?.•EQ..s'� j,►"tQ•.� SHEET Me CHK. M r'`. AND ......,....,. A I acts k a na. DATI t `- ��btidi�rr of >M,InntiC riic�4teizi rom�vny 1 .t00 "` taOfi'ri, SUPE '+3-PRUD14CE CAY f APPEMIX I - PRUDI K FIVE SPOT HIAA SUBSIDENCE 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 S -spot pattern ' to produce a thaw of approximately 3S' 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 ' 13P'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 S -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.: i 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 I-1 ■ PERMAFROST THAW TEST FIGURE 1-1 APPROXIMATE 18 MONTH THAW ZONE AT 1000' O'TEMPEnATURE HOLES E-5 d E-6 LEGEND SIX 15' MONITOR RODS S SIX 30' MONITOR RODS > THREE 100' MONITOR WIRES FOUR 150' MONITOR WIRES �., TWO 250' MONITOR WIRES THREE 400' TEMERATURE HOLES SUBSIDENCE MONITOR & TEMPERATURE HOLE 'PATTERN _77__ SCALE I "= 10'