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200-109
RECEIVED • • FEB 2 7018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas SPLUG ❑ . Other ❑ Abandoned Q - Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ❑ WAGE') WDSPL❑ No.of Completions: Service 2. Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 12/19/2017 200-109/316-475 • 3.Address: 7.Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 8/15/2000 50-029-22966-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2327'FSL,3666'FEL,Sec.33,T13N, R10E, UM 8/20/2000 MILNE PT UNIT 1-10 . Top of Productive Interval: 9.Ref Elevations: KB: 62.35 17. Field/Pool(s): 2043'FSL,4241'FEL,Sec.32,T13N, R10E, UM GL: 34.6 BF: MILNE POINT/SCHRADER BLUFF OIL' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2027'FSL,4671'FEL,Sec.32,T13N,R10E, UM Surface ADL0025517 ` 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.DNR Approval Number: Surface: x- 551705 y- 6009444 Zone-ASP4 8,302'/4,000' N/A TPI: x- 545853 y- 6009121 Zone-ASP4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 545422 y- 6009102 Zone-ASP4 N/A 1,800'(Approx.)/1,738' 5. Directional or Inclination Survey: Yes U (attached) No 0 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 (ft MSL) N/A 22. 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 DIR,GR, PWD,RES&SCMT SCANNED F - , 1 5 201Fi 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 94 H-40 27' 107' 27' _ 107' 30" 260 sx 5-1/2" 17 L-80 28' 8,291' 28' 3,996' 7-7/8" 1,170 sx 24.Open to production or injection? Yes ❑ No ❑i 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 2-7/8" 7,180' 7,140'/3,609' AA- Oc)J O 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes 0 No ❑✓ t1-1‘,0,10- Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED I,I, 7,115'-7,116' Tubing Punch 6,708'-6,709' Tubing Punch Surface-7,140' 173 bbls Class G Surface-7,140' 46 Gal.Arctic Set Lite,6 Gal.Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .. * Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate ,...► ?AaAmp? xi - -le 4e (0d Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 RbDi°�� L� --'' i -'�13 Submit ORIGINIAL only • • 28.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1,800' 1,738' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval information,including reports,per 20 AAC 25.071. Schrader Bluff NA 7,348' 3,677' Schrader Bluff NB 7,433' 3,706' Schrader Bluff NC 7,530' 3,738' Schrader Bluff NE 7,579' 3,754' Schrader Bluff NF 7,731' 3,804' Schrader Bluff OA 7,843' 3,842' Schrader Bluff OB 8,042' 3,910' Formation at total depth: Schrader Bluff 31. List 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. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Contact Phone: 777-8412 Signature: ` Date:2/1/2018 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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 la: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange 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 19: Report the Division of Oil&Gas/Division of Mining Land and Water:Plan of Operations(LO/Region YY-123),Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.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. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-10 None 50-029-22966-00-00 200-109 12/12/17 12/20/17 Daily Operations: 12/12/2017-Tuesday MIRU excavation equipment. Begin excavation. 12/13/2017 -Wednesday Remove cement from around outer annulus to new excavation point. 12/14/2017-Thursday No activity to report. 12/15/2017- Friday No activity to report. 12/16/2017-Saturday No activity to report. 12/17/2017 -Sunday Set trench box. Install wach saw. Cut casing at 4' below original tundra level. 12/18/2017- Monday Inspector onsite.Take photos of casing stub. Weld marker plate on well.Take photos of marker plate. GPS location: 70° 26.1761N 149° 34.895'W / 12/19/2017-Tuesday Backfill location. Rig down. 12/20/2017-Wednesday Demobe equipment. 1111 4111 n° �' , „....i.0.4—1;i" ' YEe +� � Zif ° - x ,41a a+ : 'a a� axis s h� �' � ,it jYx2,$ a a � { •,..-'..,.."';',--'-'1=z-,'''.-'• i d V e X '44 _ "^Y R, x,11 „'e� Y Y„ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggIz(7�z,1i 7 DATE: 12/18/2017 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector MPU 1-10 , Hilcorp Alaska LLC PTD 2001090 12/18/2017: I traveled to Hilcorp's Milne Point Unit to inspect the final surface abandonment of MPU 1-10. Hilcorp reps Konrad Schruff and Micky Townsend met me on location with the information that I had requested. This well was previously abandoned (casing cut; marker plate installed) by BPXA on October 31, 2013 but the casing cutoff was not at the required depth below tundra. The October 31, 2013 effort was classified by AOGCC as a suspended well. I inspected the marker plate and it had the proper well name, oil company name, PTD, and API numbers. The plate diameter was 20 inches; thickness was '/2-inch. I then inspected the cut off pipe and it was found full of good hard cement. The two inner casing string annuli had a darker colored cement but it was hard. The well was cut off a good 4+ feet below tundra level. The marker plate was placed on the well with no overhang. I witnessed them weld the plate to the casing stub. This represents the final surface abandonment for MPU 1-10. Attachments: Photos (2) SCANNED , trt 4 2017-1218_Surface_Abandon_fmal_MPU_I-10_bn.docx Page 1 of 2 • • Surface Abandonment (Final) — MPU 1-10 PTD 2001090 Photos by AOGCC Inspector B. Noble 12/18/2017 • k ♦� y .. 'rRSr tiF 4 lor F 1. .4 • f r migc e 2017-1218 Surface Abandon final MPU I-10 bn.docx Page 2 of 2 OF � • • ":\l//// s), THE STATE Alaska Oil and Gas �•�•;"� 7 of e T ® cKA Conservation Commission � 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 7,051T7 Q. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York SAW FE I SZCI Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-10 Permit to Drill Number: 200-109 Sundry Number: 316-475 Dear Mr. York: 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, PI;4c..-W-t . Cathy Pf. Foerster Chair DATED this 4-4 day of September, 2016. RBDMS LV SEP 2 6 2016 • •• STATE OF ALASKA SEP 1 1 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC . 20 AAC 25.280 1.Type of Request: Abandon Q Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Treatment❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development ❑ 200-109 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic D Service Q, 6.API Number. Anchorage Alaska 99503 50-029-22966-00-00 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05/ t Will planned perforations require a spacing exception? Yes ❑ No ❑ ,/ MILNE PT UNIT SBI-10 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 • MILNE POINT/SCHRADER BLUFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,302' 4,000' Surface Surface 0 Surface N/A Casing Length Size MD TVD Burst Collapse Conductor 107' 20" 107' 107' N/A N/A Production 8,291' 5-1/2" 8,291' 3,996' 7,740psi 6,390psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 EUE 8rd 7,179 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): S-3 Permanent Packer and N/A 7,140MD/3,609TVD and N/A 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development ❑ Service ❑ • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/30/2016 OILWINJ ❑ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Ei . 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola S Email sporholaahilcorp.com Printed Name Bo York Title Operations Manager Signature " / Phone 777-8345 Date 9/13/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ` _ Ler S Plug Integrity E BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: ,K Ph fe: i@c,Lc.-+•.4.J- e_0,s ja .f--c:� .� f L✓t �Y/� 1 G Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes 0 No EZ Subsequent Form Required: /d_ q 07 RBDMS L V SEP 2 6 2016 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date -2.4.1� 1 a 11141g, '''‘947116 ).:4?... i". t/6, Ria l,1 V L� Submitsn Form and Form 10-403 Revised 11/2015 r V EEEE7777 c I n���444NaMttt���sssr 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: MPU 1-10 Hilcora Alaska,LL Date:9/12/2016 Well Name: MPU 1-10 API Number: 50-029-22966-00 Current Status: Suspended Pad: I-Pad Estimated Start Date: September 30th, 2016 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 200-109 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE`Number: 111 011 AohsYe: . ,. ufac P��Ik ti Current Bottom Hole Pressure: 0 psi (Plugged to Surface) Maximum Expected BHP: 0 psi (Plugged to Surface) MPSP: 0 psi (0.10 psi/ft gas gradient) Brief Well Summary: The Milne Point 1-10 was plugged back to surface in October 2013. However, the well abandonment marker was installed 4' below the surface of the gravel pad. Therefore, the well has remained in a suspended status since 2013. Notes Regarding Wellbore Condition • Plugged back to surface in 2013. • Well capped at 4' below gravel pad. Objective: Finalize the surface abandonment of the well. Surface Procedure: 1. Notify AOGCC inspectors 24 hrs prior to cutoff of wellhead and welding marker plate. 2. Excavate cellar, cut off wellhead and casing 3' below natural GL(9.3'below pad level). a. If cement fell back, bring cement top to level of cut. 3. Photograph casing stub before setting marker plate. 4. Set marker plate, collect GPS coordinates. ___ peA 2-6 4.4 L-a•/ 5. Photograph casing stub after setting marker plate. 6. Backfill cellar, close out location. Attachments: 1. As-built Schematic • • Wellhead cut off 4'below pad grade.Will MPU I - 10i Orig. DF elev. = 62.30' (Doyon 141) cut off 3'below original ground level Orig. GL. elev.= 34.6' (Pad=33.2',OGL=26.9'). RT to 5.5" csg. hng. = 26.7' 20"91.1 ppf, H-40 107' D Tam port collar 990' KOP @ 400' I HES X-Nipple 2.313" id 2,591' Max. hole angle = 76 deg. l 2500'-4700' 70 deg.to 76 deg. I WELLS TUBING,IA WAS CEMENTED ON Hole angle through perfs = 70 deg. 9/28/13 5.5", 17 ppf,L-80,Btrc-mod. (0 -4,122') 5.5", 17 ppf, L-80,IBT-mod.(4,164' - shoe) (drift ID =4.892", cap. = 0.0232 bpf) 2 7/8" 6.5 ppf, L-80, 8rd EUE-Mod tbg. ( drift ID = 2.347",cap. = 0.0058 bpf) Split Shot 9/15/13 6707.5-6709 (t -. s 1 _._J Split Shot 9/15/13 7114.5'-7116' —1 4 Minimum tubing restriction = 2.205" 'XN' profile @ 7,167' I HES X-Nipple 2.313" id 7,127' -, Baker KBH-22 Anchor seal assy. k A Baker S-3 Permanent Packer 7140' i li2 7/8" HES 'XN' npl. 7167 (w/2.313" packing bore & 2.205" no-go) XXN Plug set 11/10/12 Perforation Summary 2 7/II"WLEG 7179' Ref log:SWS CBL 24 Aug, 2000 Size SPF Interval (TVD) OA sand ' — 2" 4 7,845'-7,865' 3,842'-3,849' 2" 4 7,912'-7,932' 3,865'-3,871' BOT IBP set to isolate the OB sands OB sand ISOLATED _ on 3/8110, Top of IBP @ 7980',Element @ 7987' 2" 4 8,042'-8,062' 3,910'-3,917' ' 2" 4 8,087'-8,107' 3,926'-3,932' — I — — 5.5"float collar(PBTD) 8,208' L. 5.5" casing shoe 8,291' DATE REV.BY COMMENTS 8,2f,00 Marc teMedand Completed Deyonidt MILNE POINT UNIT 0,10/00 M.under Initial OB pen. WELL I-1 Oi 11/15/00 MDO Initial OA Perforations 3/8/10 Hulme IBP set to isolate OB sands API NO: 50-029-22966-00 12/12/12 B.Bixby Correct API Number 08/27/13 BILL.K Added XXN plug set 11/10/12 09/16/13 BILL.K E-Line punched Split holes 9-15-13 ' HILCORP ALASKA LLC 09/29/13 BILL. K WELL CEMENTED FOR PA • WELL LOG TRANSMITTAL DAVGED M K BENDER To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 October 14, 2013 Anchorage, Alaska 99501 J NED DE( 20 i RE: Leak Detection Log: MPI-10 SCAN Run Date: 9/24/2013 The technical data listed below is being submitted herewith. concerns to the attention of th. Please address any problems or Matthew Cool,Halliburton Wireline&Perforating 6900 Arctic Blvd.,Anchorage, AK 99518 MPI 10 Digital Log Image files 50-029-22966-00 1 CD Rom Leak Detection Log S0-029-22966-00 1 Color Log PLEASE ACKNOWLEDGE RECEIPT By SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn:Matthew Cook 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook @halliburton.corn Date: Signed: ARA. s-10 • Ti) zoolo'o Reg§, James B (DOA) From: Daniel, Ryan [Ryan.Daniel @bp.com] Sent: Wednesday, September 25, 2013 2:34 PM t i f Z71(3 To: Regg, James B (DOA) Subject: RE: MPI-10 (2001090) P&A operation Attachments: MPI-10 Subsidence timelapse.pptx; MPI-10a.pdf Hello Jim, I have attached the MPI-10 well bore schematic for your reference, and a time-lapse log highlighting the subsidence damage casing area.The note below was received from MPU site OSM early this morning.The small qty of"pooling" fluid has frozen is situ and will be removed by SRT. Engineering work to continue the P&A will resume shortly. MPU Field staff providing contingent fluid "containment and collection" mitigations once pumping the upper cement plug through tubing commences. Rgds Ryan 4 3 ,61'. salvo D "At approx. 1:42 AM this morning, SRT was paged out for a potential Code Black response. In preparation for a P&A planned for 1-10 well, E-line (Halliburton/Little Red)pumped approx.. 160 bbls of dead crude down the casing and up the tubing using a Temperature Log to try and identify the location of a potential PC or packer leak. The Temp. log indicated a change around 150'down from the surface. Warm water(no LEL's detected) started surfacing approx. two well houses down behind the MPI-9 well house. Shortly afterwards, the bubbling stopped with a couple of small pooled up areas, all water and no indication of hydrocarbons. Notifications were made. 1-10 well is a monobore completion, with suspected shallow subsidence damage to the PC at approx. 135'. There is a packer set at 7,140'and an XXN Plug set at 7,167'. Current status: SRT stood down at approx. 3:20AM. A vac truck and Support Tech employee is on man-watch and water pooling appears to be starting to freeze. e4'"�m a•" ................. Alaska Region Wells Integrity and Compliance BP Exploration Alaska 900 E. Benson Blvd Anchorage, Alaska Tel +1 907 564 5430 Mob: +1 907 748 1140 ryan.daniel aC�bp.com From: Regg, James B (DOA) [mailto:jim.recg alaska.gov] Sent: Wednesday, September 25, 2013 1:18 PM To: Daniel, Ryan Subject: RE: MPI-10 (2001090) P&A operation 1 [an | getasumnnaryofeventsauyouexp|ainedthisnmorning? Jim Regg AOGCC S33vv.7th Ave,Suite 1OO Anchorage,AK 99501 907'7934236 From: Daniel, Ryan [mailto:Ryan.Daniel@bp.coni] Sent: Wednesday, September 2S 2013 11:49 AM To: Regg, James B (DOA) Cc: Bill, Michael L (Natchiq) Subject: MPI-10 (2001090) P&A operation Good Morning Jim, Following up from our call this AM, We are planning to move ahead with the through tubing P&A for this well (with surface fluid return mitigations in place). R Alaska Region Wells Integrity and Compliance BP Exploration Alaska 900 E Benson Blvd Anchorage Alaska Tel +i 907 564 5430 Mob +1 907 748 1140 n/an.danie| bp.com 2 4 • • Q 0 b , . . N 2 1B N 1 Q of 3 VJ b s L ^ W N r L "°" C C • e e i. ,1 U COZ (,�5 i genres •. w , U J tyj C N T m Q N u� y b W co V/ CO d = U V• O t ,.. O J N G .. e § o 0 Co N 0 R o O M b d' I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 1 1 1 1 1 1 1 1 1 1 4.1 1 1 1 1 1 1 1 1 1 1 1 1 1 0 Tree: 29/16"-5M • • M • Wellhead: 11" 5M FMC Gen. 6 PU I - 10i Orig. DF elev. = 62.30' (Doyon 141) w/6"x 2-7/8" FMC Tbg. Hng.,4.250 Orig. GL. elev.= 34.6' LH acme lift thds. . bottom 2 7/8" mod. RT to 5.5" csg. hng. = 26.7' api up tbg.,2.5" CIW "H" BPV profile 20" 91.1 ppf, H-40 107' 40 Tam port collar 990' KOP @ 400' HES X-Nipple 2.313" id 2,591' Max. hole angle= 76 deg. �� 2500'-4700' 70 deg.to 76 deg. Hole angle through perfs = 70 deg. 1 5.5", 17 ppf,L-80,Btrc-mod. (0 4,122') 5.5", 17 ppf, L-80,IBTmod.(4,164' -shoe) (drift ID =4.892", cap. = 0.0232 bpf) 2 7/8" 6.5 ppf, L-80, 8rd EUE-Mod tbg. I (drift ID = 2.347", cap. =0.0058 bpf) Split Shot 9/15/13 6707 5 6709' I I' Split Shot 9/15/13 7114.5' 7116' '< 1► Minimum tubing restriction = 7127' HES X-Nipple 2.313" id 2.205" 'XN' profile @ 7167' Baker KBH-22 Anchor seal assy. -- Baker S-3 Permanent Packer 7140' 2 7/8" HES 'XN' npl. 7,167 ( (w/2.313" packing bore & 2.205" no-go) XXN Plug set 11/10/12 2 7/8"WLEG 7,179' Perforation Summary Ref loci: SWS CBL 24 Aug, 2000 Size SPF Interval (TVD) OA sand — 2" 4 7,845'-7,865' 3,842'-3,849' 2" 4 7,912'-7,932' 3,865'-3,871' '- BOT IBP set to isolate the OB sands OB sand ISOLATED — on 3/8/10. 2" 4 8,042'-8,062' 3,910'-3,917' Top of IBP @ 7980',Element @ 7987' 2" 4 8,087'-8,107' 3,926'-3,932' - 5"float collar(PBTD) 8,208' J 5.5.5' casing shoe 8,291' DATE REV.BY COMMENTS MILNE POINT UNIT 8/28/00 MDO Drilled and Completed Doyon 141 9/10/00 M.Linder O6 pert. WELL I -10i 11/15/00 MDO Initial OA Perforations 3/8/10 Hulme IBP set to isolate OB sands API NO: 50-029-22966-00 12/12/12 B.Bixby Correct API Number 08/27/13 BILL.K Added XXN pl g set 11/10/12 09/16/13 BILL.K E-Line punched Split holes 9-15-13 BP EXPLORATION (AK) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 " " Anchorage, Alaska 99519 -6612 0 December 30, 2011 zoiz Mr. Tom Maunder log Alaska Oil and Gas Conservation Commission a � 3 t 10 33 West 7 Avenue v4 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI -02 1900910 50029220660000 Sealed coductor NA NA NA NA NA MPI-03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI-04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI-05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 MPI-08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 '- ) MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 MITE OF ALASKA ALASKA OIL AND aws CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other 0 MBE TREATMENT Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived: Time Extension ❑ 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 ❑ • 200 -1090 3. Address: P.O. Box 196612 Stratigraphic Service al 6. API Number: Anchorage, AK 99519 -6612 ■ 50- 029 - 22966 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 025517 . MPI -10 10. Field /Pool(s): MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 8302 feet Plugs (measured) 7980 feet true vertical 4000.17 feet Junk (measured) None feet Effective Depth measured 8208 feet Packer (measured) 7141 feet true vertical 3967.38 feet (true vertical) 3610 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.1# H -40 27 - 107 27 - 107 Surface Intermediate Production 8265' 5 -1/2" 17# L -80 26 - 8291 26 - 3995 7740 6280 Liner Liner .ot.. _ Lr. 53 Ztitt Perforation depth: Measured depth: SEE ATTACHED - — _ — True Vertical depth: _ — — — — Tubing: (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 25 - 7180 25 - 3623 Packers and SSSV (type, measured and true vertical depth) Baker S -3 Packer 7141 3610 ECF NE 12. Stimulation or cement squeeze summary: Nov ���� Intervals treated (measured): N Treatment descriptions including volumes used and final pressure: Alaska Oil & Gas Cons. Commission 13. Representative Daily Average Production or Injectibn Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 403 584 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service` 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ a WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exemp . 311 -292 Contact Joe Lastufka Printed Na e Lastufka Title Petrotechnical Data Technologist ),\, Signatur i Phone 564 -4091 Date 11/22/2011 B ®MS NOV 2 3 Zin es.„ fird-7 . - /f- - . ri Form 10 -404 Revised 10/2010 4 Submit Original Only MPI -10 1 . 200 -109 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI -10 9/9/00 PER 8,086.4 8,106.4 3,925.49 3,932.36 MPI -10 11/13/00 PER 8,042. 8,062. 3,910.21 3,917.1 MPI -10 11/15/00 APF 7,845. 7,865. 3,842.92 3,849.74 MPI -10 11/15/00 PER 7,912. 7,932. 3,865.76 3,872.57 MPI -10 7/19/01 FIL 8,099. 8,106.4 3,929.82 3,932.36 MPI -10 9/12/01 FIL 8,097. 8,099. 3,929.13 3,929.82 MPI -10 3/8/10 BPS 7,980. 8,106.4 3,888.92 3,932.36 MPI -10 4/24/10 SPS 7,968. 7,980. 3,884.83 3,888.92 AB ABANDONED PER PERF APF ADD PERF RPF REPERF _ BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • MPI -10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/31/201 j ** *Thermatek Treatment * ** Pre Thermatek injection test - -Pump 5 bbl's 60/40 meth, 125 bbl's PW, 9.8 bbl's K -max gel, chased gel to perfs with PW. Saw gel hit perfs at ''56 bbl's, continue pumping 76 bbl's of PW, freeze protect surface lines with 4 bbl's =meth. ** *Thermatek treatment * ** Pump 3 bbl's pw, 2 bbl's x -link k -max gel, 5 bbl's :Thermatek, 2 bbl's x- linked k -max gel, 3 bbl's Thermatek, 2 bbl's x- linked k -max gel, 25 bbl's PW, 28.2 bbl's diesel. . Spot treatment with 2 bbl's x- linked k -max gel left in `liner, thermatek flush with perfs. Will perform post thermatek injection test in AM. Secure location. ** *Thermatek Treatment complete * ** 11/1/2011 Thermatek Treatment * ** Post Thermatek Treatment injectivity test - -Pump 60/40 meth down tbg at 0.4 bpm well taking some injection, at 1500 psi pump trip kicked out. Flow well back to return tank and inject into perforations several times untill the well started taking steady injection at 0.5 bpm, 985 psi. ** *Job complete * ** FLUIDS PUMPED BBLS 76 PW 29 DIESEL 27 60/40 METH 8 THERMATEK 15.8 K -MAX GEL X- LINKED 155.8 TOTAL • • Tree: 2- 9/16" - 5M M P U I - 10i Orig. DF elev. = 62.30' (Doyon 141) Wellhead: 11" 5M FMC Gen. 6 w /6" x 2 -7/8" FMC Tbg. Hng., 4.250 Orig. GL. elev.= 34.6' LH acme lift thds. . bottom 2 7/8" mod. I RT to 5.5" csg. hng. = 26.7' api up tbg.,2.5" CIW "H" BPV profile 20" 91.1 ppf, H -40 107' O Tam port collar 990' KOP @ 400' I HES X- Nipple 2.313" id 2,591' Max. hole angle = 76 deg. 2500'- 4700' 70 deg. to 76 deg. Hole angle through perfs = 70 deg. 5.5 ", 17 ppf,L- 80,Btrc -mod. (0 - 4,122) 5.5 ", 17 ppf, L- 80,IBT- mod.(4,164` - shoe) ( drift ID = 4.892 ", cap. = 0.0232 bpf ) 2 7/8" 6.5 ppf, L -80, 8rd EUE -Mod tbg. , . ( drift ID = 2.347 ", cap. = 0.0058 bpf ) Minimum tubing restriction = 7 127' 2.205" 'XN' profile @ 7,167' HES X Nipple 2.313" id — Baker KBH -22 Anchor seal assy. Baker S -3 Permanent Packer 7,140' 2 7/8" HES 'XN' npl. 7,167' (w/ 2.313" packing bore & 2.205" no -go) II 2 7/8" WLEG 7,179' Perforation Summary Ref Ioq: SWS CBL 24 Aug, 2000 Size SPF Interval (TVD) OA sand 2" 4 7,845'- 7,865' 3,842' -3,849 2" 4 7,912'- 7,932' 3,865'- 3,871' BOT IBP set to isolate the 06 sands OB sand ISOLATED " "`` on 3/8/10. 2" 4 8,042' - 8,062' 3,910'- 3,917' Top of IBP @ 7980', Element @ 7987 2" 4 8,087' - 8,107' 3,926'- 3,932' r ./ 5.5" float collar (PBTD) 8,208' 5.5" casing shoe 8,291' DATE REV. BY COMMENTS MILNE POINT UNIT 8/28/00 MDO Drilled and Completed Doyen 141 9/10/00 M. Linder initial 08 parr. WELL I -101 11/15/00 MDO Initial OA Perforations API NO: 50 -029- 22971 -00 3/8/10 Hulme IBP set to isolate OB sands BP EXPLORATION (AK) • • • (01[F A[LAs SEAN PARNELL, GOVERNOR ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Lopez Petroleum Engineer BP Exploration (Alaska), Inc. _ % w� . 0 ZJ I P.O. Box 196612 rr�� , a - t 0 Anchorage, AK 99519 -6612 G Re: Milne Point Field, Schrader Bluff Oil Pool, MPI -10 Sundry Number: 311 -292 Dear Mr. Lopez: 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, 6/ Daniel T. Seamount, Jr. Chair DATED this 4 `dday September, 2011. Encl. • STATE OF ALASKA (� ALASKA AND GAS CONSERVATION COMMISSIOO 0.- APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: MBE TREATMENT M 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 200 - 1090 — 3. Address: P.O. Box 196612 Stratigraphic ❑ Service isi _ 6. API Number: Anchorage, AK 99519 -6612 50 029 - 22966 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: - Spacing Exception Required? Yes ❑ No ❑ MPI - 10 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 025517. MILNE POINT Field / SCHRADER BLUFF 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): 8302 - 4000.17 - 8208 3967.38 7980 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.1# H -40 27 107 27 107 Surface Intermediate Production Liner 8265' 5 -1/2" 17# L -80 26 8291 26 3995 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 2 -7/8" 6.5# L -80 25 7180 Packers and SSSV Tvoe: Baker S -3 Packer Packers and SSSV MD and TVD (ft): 7141 3610 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/10/2011 Oil ❑ Gas ❑ WDSPL p Suspended ❑ 16. Verbal Approval: Date: WINJ 0 • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact KEITH LOPEZ Printed Name KEITH LOPEZ Title PE Signature ,�r / / Phone Date /�/ ,[ 564 -5718 9/26/2011 Prepared by Joe Lastufka 564 -4091 i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 l \ - a a Plug Integrity BOP Test Mechanical Integrity Test Location Clearance 9 9 Y❑ ❑ 9 Y ❑ ❑ RE'cEIVED° Other: SEP 2 6 am Alaska Oil & Gas Cons. Convnisshn Subsequent Form Required: la — y o y Anchorage Anchorage &�� 4 ,' APPROVED BY � fi Approved by: COMMISSIONER THE COMMISSION Date: f Form 10 -403 Revised 1 /201 s SEP 3 0 2011 ORIGINAL i./ 74 Submit in Duplicate 1 MPI -10 200 -109 _ PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI -10 9/9/00 PER 8,086.4 8,106.4 3,925.49 3,932.36 MPI -10 11/13/00 PER 8,042. 8,062. 3,910.21 3,917.1 MPI -10 11/15/00 APF 7,845. 7,865. 3,842.92 3,849.74 MPI -10 11/15/00 PER 7,912. 7,932. 3,865.76 3,872.57 MPI -10 7/19/01 FIL 8,099. 8,106.4 3,929.82 3,932.36 MPI -10 9/12/01 FIL 8,097. 8,099. 3,929.13 3,929.82 MPI -10 3/8/10 BPS 7,980. 8,106.4 3,888.92 3,932.36 MPI -10 4/24/10 SPS 7,968. 7,980. 3,884.83 3,888.92 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • by To: Mark O'Malley /Rob Handy Date: September 20, 2011 MPU Ops Team Leaders From: Keith Lopez, MPU Schrader Pad Engineer 907 - 564 -5718 Subject: MPI -10 MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPI -10. 2 F Bullhead treatment down MPI -10 (OA sand). Keep well and offset producers and injectors shut in for minimum of's and flow producers to a tank before returning to production if necessary. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is seen. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPI -10 is an unregulated injector in the OA and OB sands supporting MPI -06 and MPI -17. This well has a Matrix Bypass Event in the OA zone with MPI -06. The ESP in MPI -06 failed in 2010 and has not been brought back online due to the MBE raising the water cut of the well to 100 %. This treatment will ensure that MPI -10 provides MPI -17 effective support and may give the opportunity to • begin producing MPI -06 again. The purpose of this treatment is to block the preferential path to re- establish matrix water flooding. PROCEDURE Stage 1. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. ' • • 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post job assessment meeting to capture learnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. . . , it ' ■ • • Tree: 2-9115" - 5M We need M 11 5M FMC PU 1 - 101 Orig. DF elev. = 62.30' (Doyon 141) ; " Gen. 6 w!6" x 2-78" FMG Tbg.11-Ing., 4.250 Ong. GL. elev.= 34.6' LH acre lift thdc. . bottom 2 718" mod.I 4 I FIT to 5 . 5 " cog- hog- = 28 - 7 ' api up tbg.,2.5" CIW "H" BPV profile 20" 91.1 pot 1-1-40 I 107' I 0 Tarn port mita: OW 111: KOP 6 400' HES X-Nipple 2.313" Id I 2,591" Max. hole angle = 78 deg. 2500'- 4700' 70 deg. to 76 deg. Hole angle through perfc = 70 deg. 5.5", 17 ppf,L-130,BIns-mod. (0- 4,122) 5.5", 17 ppf, L-130,10T-mod.(4,164" - - ice) ( drift 11) = 4J92", cap. = 0.0232 Oaf ) 2 718" 6.5 ppf, L-80, 8rd EUE-Mod ibg. ( drift ID = 2347", cap. = 0_005131)0 I .°, Minimum tubing restriction = ii HES X-Nipple 2313 id I 7,127' 2.205" XN profile 0 7,16'7' -=---- Baker KBH-M. Anchor seal assy_ - - ..._. Baker S-3 Perroartertt Packer' 7 I LI 111 2 Mt" HES 'XN' npl. I 7,167' I I 2.. (vii 205 2..31 n 4" packing bore & ) 2 718" WLEG I 7 Perforation Summary Ref leg SWS GBL 24 Aug, 2000 Size SPF Interval MID) OA swirl 2" 4 7,845"-7,865" 3,842'-3,849' C / 2" 4 7,912'4,937 3,966"-3,871" BOT IBP set MI Isola* the 08 sands OS sand ISOLATED ° Top or MP ei7980', Element GI 73417' 2" 4 8,04Z-6,062" 3,916-3,917' r 4 8,097"-£1,107 3,9215`- 3,932' I I fioat collar (PBTD) I 8,°-'08' I lk 5.5' casing once I $3,W)1' I DATE REV. BY COWENTE MILNE POINT UNIT L.22Ce ken Dread end Combing Cpyart 141 &inac IC Lnnir trige CO part WEU_ 1 -101 rinses moo inft&E OA Partorabors; API NO: 50-029-22971-00 111113 Heine IBP set to Isolae 06 sands BP EXPLORATION (AK) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS f2ECEIVED MAY 2 O~ z010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ ~~~~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension S E'T Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ i(j P 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: ~ Name: Development ^ Exploratory ^ 2.i 200-1090 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50-029-22966-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: \ ADLO-025517 MPI-10 10. Field/Pool(s): ,` MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 8302 feet Plugs (measured) 7980/ 3/9/10 feet true vertical 4000.17 feet Junk (measured) None feet Effective Depth measured 8208 feet Packer (measured) 7141' true vertical 3697 feet (true vertical) 3610' Casing Length Size MD TVD Burst Collapse Structural Conductor 107 20" 91.1# H-40 SURFACE - 107 SURFACE - 107 1490 470 Surface Intermediate Production Liner 8263 5-1/2" 17# L-80 SURFACE - 8291 SURFACE - 3995 7740 6280 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 2-7/8" 6.5# LL-80 SURFACE - 7180 SURFACE - 3623 7 P P k d SSSV i 141' ~ P~ie 3610' ac ers an (type, measured and true vert cal depth) BAKER S-3 PERMANENT PKR 7 - 12. Stimulation or cement squeeze summary: Intervals treated measured : ~, ~ ~°~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 477 593 Subsequent to operation: 603 577 14. Attachments: Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-387 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 5/20/2010 . fo I rVllll IV-'YVY RCVIJCU //LVV.7 -. "'~ "~~~ IY. {/ (~ /J ~J JU Vlllll VIIVII I /I}IJIY MPI-10 200-109 PFRF ATTA[:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI-10 9/9/00 PER 8,086.4 8,106.4 3,925.49 3,932.36 MPI-10 11/13/00 PER 8,042. 8,062. 3,910.21 3,917.1 MPI-10 11/15/00 APF 7,845. 7,865. 3,842.92 3,849.74 MPI-10 11/15/00 PER 7,912. 7,932. 3,865.76 3,872.57 MPI-10 7/19/01 FIL 8,099. 8,106.4 3,929.82 3,932.36 MPI-10 9/12/01 FIL 8,097. 8,099. 3,929.13 3,929.82 MPI-10 3/9/10 BPS 7,980. 7,981. 3,888.92 3,889.27 MPI-10 4/23/10 SPS 7,968. 8,042. 3,884.83 3,910.21 MPI-10 4/26/10 SPS 7,987. 8,042. 3,891.32 3,910.21 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • MPU-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/7/2010 CTU #9 w/1.50" OD CT. Job scope - MIRU, SBG, log, set IBP. Move to MPI -10. I ; RU. Test BOPE......Continued on WSR 03/08/2010 3/8/2010 CTU #9 w/1.5" OD CT. Job scope - Schmoo, log, set Baker IBP. «< Interact publishing »> Continued from WSR 03/07/2010. RIH w/2"od JSN, jetting Iw/SBG. Tagged up 8114'. Washed from 7800' - 8050' x 2. Painted flag at 8064'. POOH. MU PDS MEM logging tools and RIH. Tag TD @ 8114' ctmd, logged from 8110' to 7600' Flag at 8069' and POOH. Good data correct depth +8.5', MU 2.125" IBP. IBP snagged on stabbing deck and sheared the tool. LD IBP and WO another done to get here. MU IBP and RIH to flag and correct depth to mid element. PUH to X7987' (middle of joint) to set IBP Launch 1/2" steel ball. Set IBP. POOH. I ....Continued on WSR 03/09/2010. ~. 3/9/2010CTU #9 w/1.50" OD CT. Job scope - RDMO. Continued from WSR 03/08/2010. ;Finish POOH. Recovered ball. RDMO. (Top of IBP at 7,980'.) *****Job complete. 4/22/2010`***WELL S/I ON ARRIVAL"*" (dump sluggits) RIG UP SWCP 5 ~**"WSR CONT ON 4/23/10*** 1 ,_ 4/22/2010~T/I/0=500/0 Freeze protect Tbg. Pump 2 bbls Neat meth and 13 bbls 60/40 meth down Tbg. Hang Tag. Swab, Wing, Ssv closed. Mst., IA open. Notify operator. FW HP=750/0. BRUSH & FLUSH TO OUT WLEG @ 7175' SLM W/ 2 7/8" BRUSH, 1.90" GAUGE RING. ILRS PUMP 35 BBLS 90 DEGREE DIESEL. RAN KJ, 3'x 1 1/2" STEM, 2.15" CENT, TEL, S. BAILER. LOC TT @ 7,145' SLM (7,179' MD) 34' CORRECTION. COULD NOT GET PAST 7,921' SLM (7,955' MD). REC 1 TBSP OF SANDY/SHMOO. RAN KJ, 10' x 2.0" DUMP BAILER (empty), 1-1/2" K-JAR, 2.05" cent, 2.14" cent. DRIFTED TO 7,934' SLM (7,968' MD). MADE SEVERAL RUNS W/ KJ. 10' x 2.0" DUMP BAILER (full of sluggits plus), 1- _ _ __ 1/2" K-JAR, 2.05" cent, 2.14" cent. DUMPED TOTAL OF 5-1/4 GALLONS @ 7,934' SLM 7,968' MD~~ _ 4/23/2010'T/I=650/0 Assist S-Line Brush & Flush Pumped 45 bbls 90* diesel down Tbg. DSO notified slb s-line on well upon LRS departure. FWHP's=650/0 4/23/2010*'"*WSR CONT FROM 4/22/10*** (dump sluggits) • • 4/24/2010 4/25/2010 4/26/2010 **"CONT'D FROM 3-23-10***(dump bail) MADE 3 RUNS W/ KJ, 10' x 2.0" DUMP BAILER (full of sluggits plus), 1-1/2" K- JAR, 2.05" cent, 2.14" cent. DUMPED ADDITIONAL 3.5 gal @ 7,934' SLM (7,968' MD). I JOB POSTPONED, WILL RETURN. WELL LEFT S/I, TURN OVER TO DSO. **" JOB NOT COMPLETED"** **"WELL S/I ON ARRIVAL**~ _ _ .~_...._ RAN 2.13" CENT, T.E.L., 1.5" SAMPLE BAILER. WAS UNABLE TO LOCATE T.T. RECOVERED 1/4 CUP OF SLUGGITS AND WHAT LOOKS LIKE A FINGER FROM A CALIPER. **"CONT'D ON 4-26-10""* ***CONT'D FROM 4-25-10"**(dump sluggits) RAN 2.246" GAUGE RING. TAGGED XN NIPPLE @ 7133' SLM (7167' MD, -34' CORR.). MADE SEVERAL RUNS W/ KJ, 2.13" CENT, 10' x 2" DUMP BAILER(full of sluggits), 1-1/2" K-JAR, 2.06" CENT, 1.843" CENT. DUMPED TOTAL OF 7 GALLONS OF SLUGGITS ON IBP @ 7987' MD """CONT'D ON 4-27-10*** 4/27/2010"'`'`CONT'D FROM 4-26-10*'""(dump sluggits) =MADE 2 RUNS W/ KJ, 10' x 2.0" DUMP BAILER (full of sluggits plus), 1-1/2" K- JAR, 2.05" cent, 1.84" cent, 2.14" cent. DUMPED 2.5 GALLONS OF SLUGGITS. WELL S/I ON DEP, TURNED OVER TO DSO. I '"""JOB COMPLETE"** I 1 "*"**"**********''TOTAL OF 20 GALLONS OF SLUGGITS ON IBP @ 7,980' FLUIDS PUMPED BBLS 137 60/40 METH 60 1 % KCL XS 255 SCHMOO B GONE 2 NEAT MEOH 45 DIESEL 499 Total • MPU-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ~ 3/7/2010 CTU #9 w/1.50" OD CT. Job scope - MIRU, SBG, log, set IBP. Move to MPI -10. RU. Test BOPE......Continued on WSR 03/08/2010 3/8/2010 CTU #9 w/1.5" OD CT. Job scope - Schmoo, log, set Baker IBP. «< Interact publishing »> Continued from WSR 03/07/2010. RIH w/2"od JSN, jetting w/SBG. Tagged up 8114'. Washed from 7800' - 8050' x 2. Painted flag at 8064'. POOH. MU PDS MEM logging tools and RIH. Tag TD @ 8114' ctmd, logged from 8110' to 7600' Flag at 8069' and POOH. Good data correct depth +8.5', MU 2.125" IBP. IBP snagged on stabbing deck and sheared the tool. LD IBP and WO another ;one to get here. MU IBP and RIH to flag and correct depth to mid element. PUH to 7987' (middle of joint) to set IBP Launch 1/2" steel ball. Set IBP. POOH. .....Continued on WSR 03/09/2010. 3/9/2 0 1 0 1 CTU #9 w/1.50" OD CT. Job scope - RDMO. Continued from WSR 03/08/2010. Finish POOH. Recovered ball. RDMO. (Top of IBP at 7,980'.) ****"Job complete. 4/22/2010'***WELL S/I ON ARRIVAL*"" (dump sluggits) RIG UP SWCP 5 - `***WSR CONT ON 4/23/10""" 4/22/2010 T/I/0=500/0 Freeze protect Tbg. Pump 2 bbls Neat meth and 13 bbls 60/40 meth down Tbg. Hang Tag. Swab, Wing, Ssv closed. Mst., IA open. Notify operator. FW HP=750/0. .___ _ _ _w._.__.._ ~_.._~ 4/23/2010 ***WSR CONT FROM 4/22/10"*" (dump sluggits) BRUSH & FLUSH TO OUT WLEG @ 7175' SLM W/ 2 7/8" BRUSH, 1.90" GAUGE RING. ;LRS PUMP 35 BBLS 90 DEGREE DIESEL. RAN KJ, 3'x 1 1/2" STEM, 2.15" CENT, TEL, S. BAILER. LOC TT @ 7,145' SLM :(7,179' MD) 34' CORRECTION. COULD NOT GET PAST 7,921' SLM (7,955' MD). REC 1 TBSP OF SANDY/SHMOO. RAN KJ, 10' x 2.0" DUMP BAILER (empty), 1-1/2" K-JAR, 2.05" cent, 2.14" cent. DRIFTED TO 7,934' SLM (7,968' MD). MADE SEVERAL RUNS W/ KJ, 10' x 2.0" DUMP BAILER (full of sluggits plus), 1- 1/2" K-JAR, 2.05" cent, 2.14" cent. DUMPED TOTAL OF 5-1/4 GALLONS @ 7,934' __ SLM (7,968' MDR 4/23/2010;T/I=650/0 Assist S-Line Brush & Flush Pumped 45 bbls 90* diesel down Tbg. DSO notified slb s-line on well upon LRS departure. FWHP's=650/0 • 4/24/2010 ~***CONT'D FROM 3-23-10***(dump bail) MADE 3 RUNS W/ KJ, 10' x 2.0" DUMP BAILER (full of sluggits plus), JAR, 2.05" cent, 2.14" cent. ;DUMPED ADDITIONAL 3.5 gal @ 7,934' SLM (7,968' MD). JOB POSTPONED, WILL RETURN. WELL LEFT S/I, TURN OVER TO DSO. """ JOB NOT COMPLETED"** 4/25/2010 ~ ***W ELL S/I ON ARRIVAL""'` RAN 2.13" CENT, T.E.L., 1.5" SAMPLE BAILER. WAS UNABLE TO LOCATE T.T. RECOVERED 1/4 CUP OF SLUGGITS AND WHAT LOOKS LIKE A FINGER FROM A CALIPER. ***CONT'D ON 4-26-10*** 4/26/2010 --- _.____~ ~_®e ...~....._ _ _..._. *'`*CONT'D FROM 4-25-10"**(dump sluggits) RAN 2.246" GAUGE RING. TAGGED XN NIPPLE @ 7133' SLM (7167' MD, -34' CORR.). MADE SEVERAL RUNS W/ KJ, 2.13" CENT, 10' x 2" DUMP BAILER(full of sluggits), 1-1/2" K-JAR, 2.06" CENT, 1.843" CENT. DUMPED TOTAL OF 7 GALLONS OF SLUGGITS ON IBP @ 7987' MD "**CONT'D ON 4-27-10**" 4/27/2010 *"*CONT'D FROM 4-26-10***(dump sluggits) MADE 2 RUNS W/ KJ, 10' x 2.0" DUMP BAILER (full of sluggits plus), JAR, 2.05" cent, 1.84" cent, 2.14" cent. DUMPED 2.5 GALLONS OF SLUGGITS. WELL S/I ON DEP, TURNED OVER TO DSO. ***JOB COMPLETE*** 1-1/2" K- 1-1/2" K- **"""""*"*''""**'*TOTAL OF 20 GALLONS OF SLUGGITS ON IBP @ 7,980' ********************* FLUIDS PUMPED BBLS 137 60/40 METH 60 1 % KCL XS 255 SCHMOO B GONE 2 NEAT MEOH 45 DIESEL 499 Total Y Tree: 2-9/16" - 5M Wellhead: 11" 5M FMC Gen. 6 w/6" x 2-7/8" FMC Tbg. Hng., 4.250 LH acme lift thds.. bottom 2 7/8" m api up tbg.,2.5" CIW "H" BPV profs 20" 91.1 ppf, H-40 107' KOP @ 400' Max. hole angle = 76 deg. 2500'- 4700' 70 deg. to 76 deg. Hole angle through perfs = 70 del 5.5", 17 ppf,L-80,Btrc-mod. (0 - 4,1 5.5", 17 ppf, L-80,IBT-mod.(4,164'- ( drift ID = 4.892", cap. = 0.0232 bl 2 7/8" 6.5 ppf, L-80, 8rd EUE-Mod ( drift ID = 2.347", cap. = 0.00592 Minimum tubing restriction = 2.205" 'XN' profile @ 7,167' Pertoration Summary Ref loa: SWS CBL 24 Aug, 2000 Size SPF Interval (1 OA sand 2" 4 7,912'-7,932' 3,865'- 2" 4 7,845'-7,865' 3,842'- OB sand ISOLAl 2" 4 8,042'-8,062' 3,910'-3 2" 4 8,087'-8,107' 3,926'- DATE REV. BY COMMENTS 8/28/00 MDO Drilled and Completed Doyon 141 9/10/00 M. Linder Initial OB perF. 11/15/00 MDO Initial OA Perforations 3/8/10 Hulme IBP set to isolate OB sands Orig. DF elev. = 62.30' (Doyon 141) Orig. GL. elev.= 34.6' RT to 5.5" csg. hng. = 26.7' I part collar 990' 'ES X-Nipple 2.313" id 2,591' i X-Nipple 2.313" id 7,127' :r KBH-22 Anchor seal assy. :r S-3 Permanent Packer 7,140' 3" HES 'XN' npl. !.313" packing bore & 7,167' 5" no-go) 8" WLEG 7,179' BOT IBP setto isolate the OB sands on 3/8/10. Top of IBP @ 7980`, Element @ 7987' ' float collar (PBTD) 8 208 .5' casing shoe 8,291' MILNE POINT UNIT WELL 1 -10i API NO: 50-029-22971-00 BP EXPLORATION MPU I -10i Maunder, Thomas E (DOA) From: Longden, Kaity [Kaity.Longden@BP.com] Sent: Friday, March 19, 2010 4:45 PM To: Maunder, Thomas E (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Tom- Page 1 of This well is comingled downhole so we have no true way of monitoring one or the other. We will be taking the samples at surface. Technically, we will be injecting the tracer into the LS of MPE-13B which is completed in the OA sand so we expect that the magnesium we see will be coming from the mother bore (MPE-20A) which is the lateral in the OA sand. Hope this helps. Kaity Longden Pad Engineer Milne Point Viscous Oil Team BP Alaska ACT From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 19, 2010 4:28 PM To: Longden, Kaity Cc: Roby, David S (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Thanks Kaity. One question ... will you be monitoring the mother bore (MPE-20A) as well as the lateral (MPE- 20AL1)for increased Mg++? Tom Maunder, PE ~@ ~-aCl Q~~ aOti-C~55 AOGCC From: Longden, Kaity [mailto:Kaity.Longden@BP.com] Sent: Friday, March 19, 2010 2:53 PM To: Maunder, Thomas E (DOA) Cc: Roby, David S (DOA) '~-O~ -O~'l~ Subject: RE: Question on Milne Point Schrader Bluff Injection Orders ~ ~ ~-D5y Thanks Tom for the response. We are planning to first try this tracer test on MPE-13BLS to MPE-20A late next week. We will then re-do the test on those wells following an MBE treatment in April. The next set of wells for the Epsom Salt tracer test will be MPI-10 to MPI-06 sometime early summer this year. I would be happy to send you updates on our findings as we ge the information ~~, -- - Kaity Longden ~ j..tpC~ `~•'~,-~~5 Pad Engineer Milne Point Viscous Oil Team BP Alaska ACT From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 19, 2010 9:00 AM To: Longden, Kaity Cc: Roby, David S (DOA) 3/22/2010 Page 2 of ~ ~ • • Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Kaity, Dave's interpretation is correct. By adding the Epson salt to the produced water you are creating the tracer fluid. Tracer fluids are clearly allowed by the injection order. Good luck with the trial. As the fluid movement information is quantified, we would appreciate a communication indicating the findings. Also, can you identify the possible candidate injection wells? Call or message with any questions. I will place a copy of this message in the Order file. Tom Maunder, PE AOGCC From: Longden, Kaity [mailto:Kaity.Longden@BP.com] Sent: Wednesday, March 17, 2010 4:31 PM To: Roby, David S (DOA) Cc: Maunder, Thomas E (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Sounds good Dave. Thanks for taking the time to make sure we have our bases covered. Kaity Longden Pad Engineer Milne Point Viscous Oil Teain BP Alaska ACT 564-5554 From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, March 17, 2010 4:22 PM To: Longden, Kaity Cc: Maunder, Thomas E (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders I would say your interpretation of the rule is correct but I would like for Tom Maunder, our UIC program manager, to weigh in on this to make sure I'm not missing something. Dave Roby (907)793-1232 From: Longden, Kaity [mailto:Kaity.Longden@BP.com] Sent: Wednesday, March 17, 2010 3:33 PM To: Roby, David S (DOA) Subject: Question on Milne Point Schrader Bluff Injection Orders Good Afternoon Dave, I was talking with Mike Bill here at BP yesterday about a tracer study we are looking to do here in the near future. We are looking to quantify the amount of injection water being cycled between injector and producer pre and post MBE treatment in order to judge success. In order to do this we will be increasing the Magnesium concentration in our normal produced water (by adding Epsom Salt) and injecting it in an injector while monitoring the concentration of Magnesium on the producer side. This will allow us to see what percentage of injected water is cycling directly through. We expect the tracer to come through in less than 6 hours. I believe this kind of study is authorized under the Area Injection Order No 10B, Part B: Schrader Bluff Oil Pool Authorized Fluids, section C) tracer survey fluid to monitor reservoir performance. Mike suggested that I confer with you prior to the job to make sure we do not need any additional notifications. Thank you in advance for your help on this. If you need addition information please write back or call my office 3/22/2010 L D'G SEAN PARNELL, GOVERNOR a J I j L AIASKA OIlL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ms. Kaity Longden Staff Geologist BP Exploration (Alaska), Inc. P.O. Box 196612 tacll Anchorage, AK 99519-6612 Re: Milne Point Unit Field, Schrader Bluff Pool, MPI-10 Sundry Number: 309-387 tW6'. Dear Ms. Longden: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, oh No an mis loner DATED this .% day of November, 2009 Encl. �,��, STATE OF ALASKA RECEIVED 3 ALAS�IL AND GAS CONSERVATION COMMIS y N � � ZOOS APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 41aska Oil & Gas Cons. Commission 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Re -enter SuspendIVOW81A Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Other E� Specify: MBE Repair Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 200 -1090 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑. 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22966 -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: Spacing Exception Required? Yes ❑ No ❑ MPI -10 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 025517 Milne Point Unit Field / Schrader Bluff Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8302 4000.17 8208 3697 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 107 20" 91.1#H-40 Surface 107 Surface 107 1490 470 Surface Intermediate Production Liner 8263 5 -1/2" 17# L -80 Surface 107 Surface 107 7740 6280 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached - - 2 -7/8" 6.5# L -80 Surface - 7180 Packers and SSSV Tvge: Baker S -3 Permanent PKR Packers and SSSV MD and ND fft): 7141' 3610' 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/30/2009 Oil ❑ Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kaity Longde Printed Name Kaity Longden Title Staff Geologist Signature Phone Date 564 -4531 11/16/2009 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:��7 Plug Integrity ❑ BOP Test [] Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: APPROVED BY Approved by: OMMISSIONER THE COMMISSION Date: (/ ��i�AL L s Form 1 Revised 07/2009 Submit in Duplicate I MPI -10 200 -109 I P RF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI -10 9/9/00 PER 8,086.4 8,106.4 3,925.49 3,932.36 MPI -10 11/13/00 PER 8,042. 8,062. 3,910.21 3,917.1 MPI -10 11/15/00 APF 7,845. 7,865. 3,842.92 3,849.74 MPI -10 11/15/00 PER 7,912. 7,932. 3,865.76 3,872.57 MPI -10 7/19/01 FIL 8,099. 8,106.4 3,929.82 3,932.36 MPI -10 9/12/01 FIL 8,097. 8,099. 3,929.13 3,929.82 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL T SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • r by 0 To: Mark O'Malley /Jerry Sharp Date: November 13, 2009 MPU Well Operations Supervisor From: Jack Lau, Wells Engineer 227 -2760 Kaity Longden, MPU Schrader -E Pad Engineer Subject: MPI -10 Gel Job Step Unit Operation 1 C Set plug to isolate zone for treatment 2 O Shut in all offset producers. Bullhead water into MPI -10. 3 O Bullhead gel treatment down MPI -10. Keep well and offset producers and injectors shut in for minimum of 2 days and flow producers to a tank before returning to production. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a rigid gel. Measure of success 1. Gel treatments are fully displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is seen. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. . • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant gel per guidance from the Environmental Team. PROCEDURE Stagel. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. High Volume Gel Treatment 5. Ensure offset producers are offline 6. Pump produced water preflush, followed by gel treatment and produced water over flush, then bbls freeze protect. 7. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 8. Rig down all equipment and hold post -job assessment meeting to capture learnings to be incorporated into future jobs. 9. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. a M P U I -101 OF elft. - 62.30' (Doyon 141) 11" 5M FUC Gen_ 5 w x 2 -7M' FMC Tdg. Hng., 4.250 Cr1g. GL_ elev.- 34.6' LH acrne IIR aids. . bottom 2 718' nXXl. RT to 5.5' csg. hng. - 26.7' apl up tbg.,2.5" CIW "H' BPV pnyfse 20' 91.1 ppf. H"40 - ioz - 1 Tam port cow 99T KOP Q 400' HES X- Nipple 2.313' Id t' Max. hole angle 76 deg - 25D0"- 4700' 70 deg. to 76 deg. Hole angle through perfs - 70 deg. 5.5', 17 pp1,L- 60,S1rc-mod. (0 - 4,1227) 5.5 - , 17 ppf.L- 80j5T- mod.(4,164'- shoe) ( drM ID - 4.892". Cap. - 0.0232 bpf ) 2 W8' 6.5 ppf, L -80, 8rd EUE -Mod tug-. OM D - 2 -34T°, Gap. - 0. bpf ) Minimum tubing restriction - 2 T1 ZT 2.205' WT prutlle Q 7.1b7' HES X- Nipple 3i3' Id Baker KBH-22 Anchors" assy. Baker S-3 Permanent Plackef 14C7r 2 7 +'& HES - XN' rte. (wJ 2.313" packing bore $ ' 2- no-go) 7,17�d' Perforation 7f8" WLEG ation Summary Ref kon SWS CBL 24 Aug. 2 DOD Size S;Ifl Interval (TVD) OA Sand 2' 4 7,917-7,932' 3,86F- 3,871• 2" 4 7.845' -7 MS 3.842'-3,849P OB sand 2" 4 6.047 - 8,062' 3.911r-3,917" 2 4 8,087' - 8,107 3,926- 3,932' 5.5 float collar (PBTD) g 5.3 casing Shoe DATE qrmv. By COMMEN MILNE POINT UNIT W2aW MOO orrled anrt CWWWW DDYW 141 WELL I -10i srtow M. Lleaer uANI as pert. API NO. 50-029 - 22971-00 t 1fism moo WW OA PVrfaraOMS BP EXPLORATION • S1- PeoAcrive DiAgNOSric SertvicES, INC. To: ADGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907j 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : - ~- - `~~~~ BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~~3 ~~~~~~.~ ~~ ~ ~: ~ 2ao ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907] 245-8952 1 j Injection Profile 16-Jun-09 MPU I-10 BL / ESE 50-029-22966-00 2j Signed Print Name: Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL: .~__ ----__---- WEBSITE C:~Dceumen6 and Settings\Diane Williams'~Desktop`Ttansmit_BP.duch 1VIE1l~®RA1~1I)L11!/I • To: Jim Regg ~~,,, ~'i ~ CJ P.I. Supervisor (`~ FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 23, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC I-10 MILNE PT UNIT SB [-] 0 Src: Inspector NON-CONFIDENTIAL Reviewed Br n P.I. Suprv J Ij~ Comm Well Name: MILNE PT UNIT SB I-10 Insp Num: mitCS0807210626i6 Rel Insp Num: API Well Number 50-029-22966-00-00 Permit Number: 200-109-0 Inspector Name: Chuck Scheve Inspection Date: 7/18/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ I-lo Type Inj. W TVD 3609 IA 360 2000 ~ 1930 1920 P T zoolo9o iTypeTest SPT ~ Test psi ~ ]soo pA ~ Interval 4YRTST p~F P ~ Tubing aso aso ~ aso aso Notes: ~~~~ Aug ~ 2o~s Wednesday, July 23, 2008 Page 1 of 1 F:\LaserFiche\CvrPgs _I nserts\M icrofi 1m _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ,i;~r 4'" ) ) Permit to Drill 2001090 MD 8302 TVD 4000 DATA SUBMITTAL COMPLIANCE REPORT 91912002 Well Name/No. MILNE PT UNIT SB 1-10 Operator BP EXPLORATION (ALASKA) INC Completion Dat 9/9/2000 ~ Completion Statu 1WINJ ~-- Current Status 1WINJ ., APl No. $0-029-22966-00-00 REQUIRED INFORMATION Mud Log N_go Sample N_.Qo Directional Survey ? y_ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Interval Log Log Run Name Scale Media No Start Stop 5100 8116 (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments Case 10/13/2000 09757-~5100-8116 T ED D ~n Profile R R 44 8254 final 7700 8080 CBL 5 FINAL 5100 8116 MD GP,/ROP/RES 2/5 FINAL 54 8302 TVD GPJ RES 2/5 FINAL 54 4000 10126 FINAL 44 8254 LIS Verification FINAL Open 5/1/2001 10126 44-8254 Case 12/1/2001 10493c--~ CH 9/15/2000 BL(C) 5100-8116 OH 5/1/2001 54-8302 BL, Sepia OH 5/1/2001 54-4000 BL, Sepia CH 5/1/2001 10126 44-8254 Digital Data CH 5/1/2001 LIS Verification. Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y / ~ Chips Received? ~ Analysis ~ R~.r.~.iv~.d? Daily History Received? Formation Tops ~N ~'/N Comments: Permit to Drill 2001090 MD 8302 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. MILNE PT UNIT SB 1-10 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22966-00-00 4OOO ~C~letion Dat 9/9/2000 Completion Statu 1WINJ Currant Status 1WINJ UIC Y Date: TRANSMITTAL ?roActive Diagnostic Services, Inc. To; State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 Lo(; DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S] OR CD-ROM FILM BLUELINE Open Hole I I 1 MPU 1-10i 11/9/01 Res. Eval. CH I I 1 Mech. CH I ........ Caliper Survey ;igned · :rint Name: RECEIVED .. Date' D~O i ~001 Alaska Oil & Gas ns. Commission Anct, orage ProAcTive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: www.memo lry_!gg.com STATE OF ALASKA ALASK~ L AND GAS CONSERVATION COM( R~PORT OF SUNDRY WELL OPERATIO"S SION 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 62.35' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2327' NSL, 3666' WEL, SEC. 33, T13N, R10E, UM MPI-10i At top of productive interval 9. Permit Number / ApproVal No. ' ....... 200-109 2043' NSL, 4241' WEL, SEC. 32, T13N, R10E, UM 10. APl Number At effective depth 50-029-22966-00 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 2027' NSL, 4671' WEL, SEC. 32, T13N, R10E, UM 12. Present well condition summary Total depth: measured 8302 feet Plugs (measured) true vertical 4000 feet Effective depth: measured 8208' feet Junk (measured) true vertical 3967 feet Casing Length Size Cemented MD TVD Structural Conductor 107 20" 260 sx Arctic Set (Approx.) 107 107 Surface Intermediate Production Liner 8263 5-1/2 650 sx AS III, 450 sx "G", 70 sx AS III 28-8291 24-3995 Perforation depth: measured 7845' - 7865', 7912' - 7932', 8042' - 8062', 8087' - 8107' true vertical 3843'-3850', 3866'-3873', 3910'-3917',3926'- 3933' RE[EIVED 2001 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 7180' ~"~ ~,laska 0it & G~s Cons. Commission Packers and SSSV (type and measured depth) Packer 7141' Anchorage 13. Stimulation or cement squeeze summary See Attachment. intervals treated (measured) Treatment description including volumes used and final pressure 14, Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service ~ 7. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed UichaelWilliams ~.~,~ ~~ Title Technical Assistant Date ~'/,.~"' 10-404 MPI-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/09/2000 PERF(REPERF) SUMMARY 1 GUN POWER JET , 4SPF,60 DEC PHASING GUN#1' 8086.4-8106.4 FT. TOOL STUCK AT 4010 FT.PUMP FLUID AT WORK IN CABLE INCREASING AND HOLDING TENSION BY STEP TO GET FREE. SECOND GUN PENDING, BUT NOT SHOT (INTERVAL 8042-8062) Fluids Pumped BBLS. I Description 30 METHANOL 30 Total REPERF O9/O9/2OOO SUMMARY The following interval was reperforated using one 20' gun Power Jet, 4 SPF, 60° phasing. 8086.4- 8106.4 MD WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPI-10, AK-MM-00147 April 26, 2001 MPI-10: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22966-00 Blueline Rolled Sepia "x 5" Density Logs: MD Neutron & i 50-029-22966-00 2"x 5" TVD Neutron & Density Logs: 50-029-22966-00 2" x 5" TVD Resistivity and Gamma Ray Logs: Blueline Rolled Sepia Blueline "~ Rolled Sepia Blueline ~ Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND' RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED MAY 0 200 Sig ' (~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs April 12, 2001 -Mtxt-E-~, AK-MM-00147 1 LDWG formatted Disc with verification listing. APl#: 50-029-22966-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED ~AY 0 ! 2001 'aJata Oit & ~as Co... Commi~m STATE OF ALASKA ALAS IL AND GAS CONSERVATION COM NSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned IR! Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-109 3. Address 18. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22966-00 ;:-~" ' ~ ' ~F 9. Unit or Lease Name 4. Location of well at surface '[-?~i'ii'~TM i?;/,?i ;LOC~~ i Milne Point Unit 2327' NSL, 3666' WEL, SEC. 33, T13N, R10E, UM ; ........... ~ . . At top of productive interval i,--~.~._ .~_" ..... ~ '~ ''~! ¥~ 2043' ,SL, 4241' WEL, SEC. 32, T13N, R10E, UMi t:Z.:..7~.~ ~ At total depth ~ .~ il~. ~ 10. Well Number q , ........ - .... --._...~ 11. Field and Pool " 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Milne Point Unit / Schrader Bluff KBE = 62.35' ADL 025517 12. Date Spudded8/15/2000 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'8/20/2000 0/0/2000 [ 15. Water depth, if offshoreN/A MSL [ 16. No. of CompletiOnSone 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set121. Thickness of Permafrost 8302 4000 FT[ 8208' 3967 FT[ [] Yes [] No[ N/A MD[ 1800' (Approx.) 22. Type Electric or Other Logs Run DIR, GR, PWD, RES, SCMT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE ' Top BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 27' 107' 30" 260 SX Arctic Set (Approx.) 5-1/2" 17# L-80 28' 8291' 7-7/8" 650 sx AS III, 450 sx 'G', 70 sx AS III , 24. Perforations .open to, P.roducti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and interval, size ancl numDerI SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 7180' 7141' MD TVD MD TVD CA Sands 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. , 7912' - 7932' 3866' - 3873' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7845' - 7865' 3843' - 3850' Freeze Protect with 80 BblsoLDiesel OB Sands EL, E I V r- 8042' 8062' 3910' - 3917' 8087' - 8107' 3926' - 3933' ,JAN O.,A ZOO1 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Alaska Oil & Gas Cons. Commission November 30, 2000 Water Injection Anchorage Date of Test iHours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER'BBL CHOKE SIZE ~ GAS'OIL RATIO TEST PERIOD I ,, Flow Tubing 3asing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. NA 7348' 3677' · NB 7433' 3706' NC 7530' 3738' NE 7579' 3754' NF 7731' 3804' OA 7843' 3842' OB 8042' 3910' RECEIVED JAN 04 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,~~..j~_ ~ , ,Title TechnicalAssistant' Date MP I-210i 200-109 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. , , INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24. show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no COreS taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL RECEIVED ., BP AMOCO JAN 0 izj: Z001 Page 1 of 3 Operations Summary Repo co.s. commi m ' Legal Well Name: MPI-2`10 Common Well Name: MPI-2`10 Spud Date: 8/`15/2000 Event Name: DRILL+COMPLETE Start: 8/'13/2000 End: 8/25/2000 Contractor Name: DOYON RiO Release: 8/25/2000 Group: RIG Rig Name: DOYEN 141 Rig Number: Date~: From ~ To ~ HOUrs actiVi~ COde phase DesCriPtion of OPerationS : 8/13/2000 21:00 o 00:00 3.00 MOVE PRE Move rig MPI-09 to MPI-210i 8/14/2000 00:00 - 02:00 2.00 MOVE PRE Finish moving rig MPI-09 to MPI-210i - 60' Accept rig at 0200 hfs 8/14/2000 02:00 - 06:00 4.00 DIVRTR INT1 Nipple up 20" Diverter system with single 16" diverter line 06:00 - 10:00 4.00 DRILL INT1 Load pipe shed with 4" 14.0 Ib/ft S-135 NC-40 drill pipe 10:00 - 16:30 6.50 DRILL INT1 Pick up and stand back in derrick 255 jts (85 stands) 4' drill pipe 16:30 - 19:30 3.00 DRILL INT1 Rig up handling equipment - Pick up and stand back in derrick 36 jts ( 12 stands) 3?" 9.3# Eue 8rd Tubing 19:30 - 20:00 0.50 DRILL INT1 Pre-Spud meeting on rig with drill crew and service personnel 20:00 - 23:00 3.00 DRILL INT1 Make up BHA: Pick up Sperry 6?" motor with 1.57 bent housing - Pick up Sperry MWD / PWD / GR tools - Orient MWD & UBHO sub - Make up Hughes 7 7/8" MXC-1 mill tooth bit Rig up Schlumberger wireline for running Gyro 23:00 - 23:30 0.50 DRILL INT1 Function test Diverter system Witness of Diverter test waived by Mr. John Spaulding of AOGCC Methane and Hydrogen Sulfide gas detector tested on 8/14/00 23:30 - 00:00 0.50 DRILL INT1 Fill hole with mud and Check for leaks - ok- no leaks 8/15/2000 00:00 - 00:00 24.00 DRILL INT1 Spud in & drill from 20" conductor at 107' to 1261' - Art 9.4 hrs Asr 5.6 hfs, Average Rep 77 ft/hr - Survey with Gyro every stand due to metal interference - Maintain mud wt. 9.2 ppg or less, Vis ? 150 sec / qt. - Flow rate 343 gpm 1700 psi - KOP at 300' - build angle at 1.57 / 100' increasing to 4? / 100' at 1000' 8/16/2000 00:00 - 10:00 10.00 DRILL INT1 Continue Directional drilling 1,261 to 2,096' - build angle 4? / 100 increasing to 6? / 100' build rate at 1600' - Survey at 2027' showed 11.77 dogleg 10:00 - 12:30 2.50 DRILL DIR INT1 Ream 1,930 to 2,080' - Attempt to lower serverity of dogleg - No Success 12:30 - 14:30 2.00 DRILL INT1 Continue Directional drill 2,096 to 2,364' - Building angle at 6? / 100' - Maintain mud wt. < 9.2 ppg - lower viscostiy to ? 100 sec / qt 14:30 - 15:00 0.50 DRILL INT1 Circulate around sweep 15:00 - 17:00 2.00 DRILL INT1 Short trip 8 stands to 1604' - No problelm Pooh or TIH - Precautionary wash 90' to bottom - no fill 17:00 - 00:00 7.00 DRILL INT1 Continue Directional drill 2,364 to 2,762 at 00:00 hrs - Build angle to 75? turn Azimuth to 267? - Pumping 360 gpm at 1950 psi - 60 rpm with 6,000 ft/# torque :8/17/2000 00:00 - 08:00 8.00 DRILL INT1 Directional drill 2,762 to 3,494' - small amount of Hydrate gas at ? 3250' md, 2390 'I'VD - mud cut to 7.7 ppg - Continue drilling with no problem - Maintain mud wt. < 9.2 ppg, Viscosity 60 to 70 sec/qt - 340 to 360 gpm 2000 psi 08:00 - 09:00 1.00 DRILL INT1 Circulate hole clean - two hole volume 09:00 - 11:30 2.50 DRILL INT1 Pooh 20 stand for wiper trip to 1600' - Back ream 2930 to 2371:)' due to swabing - max drag 20K - No problem TIH - Precautionary ream 90' to bottom - no fill 11:30 - 00:00 12.50 DRILL INT1 Directional drill 3,494 to 4,650' at 00:00 hrs - Maintain angle 72? - Maintain mud wt. < 9.2 ppg - Last 24 hrs Art 12.0 hrs, Ast 3.0 hrs, Average Rep 126 ft/hr 8/18/2000 00:00 - 04:30 4.50 DRILL INT1 Directional drill 4,650 to 5,062' - Art 3.0 hrs Ast .3 hrs, Average Rep 124 ft/hr - 360 gpm 2100 psi - Maintain mud wt. <9.2 ppg 04:30 - 06:00 1.50 DRILL INT1 Circulate hole clean - Two bottoms up - Monitor well - pump slug 06:00 - 12:00 6.00 DRILL INT1 Pooh for bit & Resistivity logging tools - Swabbing at 4600' - Backream 4620 - 4340' - max drag 25K - Down load LWD tools - Drain & lay down mud motor Printed: 8/30/2000 2:15:21 PM RECEIVED BP AMOCO JAN 0,,'J= Z001 page 2of 3 ! operations Summary Report & Legal Well Name: MPI-210 iCommon Well Name: MPI-210 Spud Date: 8/15/2000 Event Name: DRILL+COMPLETE Start: 8/13/2000 End: 8/25/2000 Contractor Name: DOYON Rig Release: 8/25/2000 Group: RIG Rig Name: DOYON 141 Rig Number: Date From- To HOurs Activi~ COde: Phase . ~: ~ DeSCriptiOn of Operations: 8/18/2000 12:00 - 13:00 1.00 DRILL INT1 Make up BHA #2: Pick up 6? Dyna drill w/1.157 BH - P/U Sperry GR / Res / PWD / MWD - Changed out MWD tools 13:00 - 15:00 2.00 DRILL INT1 Rig Repair: Repair Hydraulic leak on Top Drive 15:00 - 15:30 0.50 DRILL TDRV INT1 Finish Making up BHA - Program Logging tools - Orient MWD - Make up Hughes 7 7~8" MXC-1 mill tooth bit 15:30 - 19:30 4.00 DRILL INT1 TIH fill pipe every 25 stands - Wash through tight spot at 4030' & 4844' - Wash 200' to bottom - No fill 19:30 - 00:00 4.50 DRILL INT1 Directional drill 5,062 to 5,330 at 00:00 hfs - Art 2.8 hrs, Ast .5 hfs, Average Rop 81 fi/hr - 364 gpm 2450 psi - 80 rpm 6,000 fi/lb torque 8/19/2000 00:00 - 14:00 14.00 DRILL INT1 Directional drill 5,330 to 6,664' - 350 gpm 2500 psi - 10-15 wob - 80 rpm 9000 fi/# torque 14:00 - 15:00 1.00 DRILL INT1 Pump high vis sweep - circulate hole clean 15:00 - 20:00 5.00 DRILL INT1 Short trip 26 stands to 4000' - Pump out of hole 5,993 to 5,280 - due to swabbing - Max drag 25K - TIH wash through tight hole 5,130 to 5,450 and 6,000 to 6,300' - wash 70' to bottom at 6,664' 20:00 - 00:00 4.00 DRILL INT1 Directional drill 6,664 to 6900' at 00:00 hrs - 360 gpm 2650 psi- 80 rpm 9-10,000 fi/lb torque - Last 24 hrs Art 12.7, Ast .7 hrs, Average Rop 117 fi/hr - Maintain mud wt. < 9.2 ppg 8~20~2000 00:00 - 23:00 23.00 DRILL INT1 Directional drill 6,900 to TD at 8302' - Art 16.0 hrs, Ast 1.0 hfs Average Rop 82.4 fi/hr - Maintain mud wt. < 9.2 ppg with water, Lower APl fluid loss to < 4cc - 23:00 - 00:00 1.00 DRILL INT1 Pump Higher vis sweep - Circulate hole clean, two hole volume 8/21/2000 00:00 - 01:00 1.00 DRILL INT1 Continue Circulate hole clean - Two hole volume 01:00 - 05:00 4.00 DRILL INT1 Pooh 25 stands to 5,925' - Back ream 7,835 to 6,875 - Drag 30K & swabbing - no problem above 6,600' - TIH, wash through tight hole at 6,720 to 6,780 - Continue TIH no problem, Precautionary wash 70' to bottom 05:00 - 07:00 2.00 DRILL INT1 Circulate hole clean - two annular volume 07:00 - 12:00 5.00 DRILL INT1 Pooh with no problem - record p/u, sic & rotating wt. at 50 rpm every 5 stands without pumps 12:00 - 14:00 2.00 DRILL INT1 Lay down BHA#2 - Down Icad MWD data 14:00 - 16:30 2.50 DRILL INT1 Pick up 33jts ? 1045' 2 7~8' 6.5~ L-80 Eue tubing and stand back in derrick for Tam port collar cementing string 16:30 - 17:00 0.50 DRILL INT1 Make up BHA #3:7 7~8" Smith hole open with 7?" stablizer 42' back ~17:00 - 18:00 1.00 DRILL INT1 TIH to 1920' 18:00 - 00:00 6.00 DRILL lINT1 Ream with hole opener 1,920 to 4,175' at 00:00 hrs - Ream with 100 rpm, 423 gpm 1200 psi - 400 to 450 fi/hr - Maintain mud wt. < 9.2 ppg - Maintain fluid loss to < 4.0 cc 812212000 00:00 - 14:00 14.00 DRILL INT1 Continue washing and reaming from 4175'-8302'. Ream with 100 rpms and 425 gpm with 1700 psi. Torque increased from 6000 -9000 ft lbs at ~bottom. Ream 400 fi/hr and decreased to 200 fi/hr from 7000' to 8302'. 14:00 - 15:30 1.50 DRILL INT1 Pump hi-vis sweep. Increase pump rate to 510 gpm with 3100 psi and 120 rpms. Circulate hole clean and monitor well-static. 15:30 - 18:30 3.00 DRILL INT1 Pull 5 stands. Well taking fluid-no swabbing.. Pump dry job. Continue pooh recording up and down weights every 5 stands without pumps. 18:30 - 19:30 1.00 DRILL INT1 L/D bha and function test diverter. 19:30 - 21:00 1.50 CASE INT1 Rig up Frank's fill up tool and casing equipment. 21:00 - 00:00 3.00: CASE INT1 PJSM. Run 5-1/2" 17# BTC mod casing to 2400'. 00:00- 0.00 CASE INT1 ................... 0000-0600 Update ........................................... Hit tight spot at 2440. Break circulation with Frank's tool. Hole trying to pack off. Continue working pipe and circulating until pipe freed up. Circulate bottoms up and continue rih with casing. Printed: 8/30/2000 2:15:21 PM ,' (:' ( RECEIVED BP AMOCO JAN 0.~: Z001 page 3 of 3 Operations Summa Reportqa & cons. Legal Well Name: MPI-210 Common Well Name: MPI-210 Spud Date: 8/15/2000 ;Event Name: DRILL+COMPLETE Start: 8/13/2000 End: 8/25/2000 Contractor Name: DOYEN Rig Release: 8/25/2000 Group: RIG Rig Name: DOYEN 141 Rig Number: Act i Date From ~ T° ~ HoUrS: vi~ COde' Phase DescriPti°n of Operati°ns · , , 8~23~2000 00:00 - 07:00 7.00 CASE INT1 Continue running 5-1/2" 17# BTC M casing. M/u landing jt and land hanger. Shoe at 8291'. 07:00 - 10:00 3.00 CASE INT1 Make up cement head and break circulation slow. Final rate 6 bpm with 600 psi. Reciprocate casing while circulating with full returns. 10:00 - 13:30 3.50 CASE INT1 PJSM. Test lines 3500 psi. Pump 15 bbls water and 75 bbls spacer. Mix and pump 515 bbls ASIII @ 10.7 ppg. Tail with 93 bbls"G" @ 15.8 ppg. Reciprocate casing until 250 bbls of cement was on the annulus. Dropped top plug and displaced with seawater. Full returns entire job. Did not bump plug anddid not over displace. Final pressure was 2200 3si. Cement contaminated mud weighted 10.2 ppg. Bled off psi and floats held. ClP at 1330. 13:30 - 14:30 1.00 CASE INT1 Rig down cement head and lay down landing jr. Clear rig floor. 14:30 - 18:00 3.50 CASE INT1 Nipple down 20" diverter i 18:00 - 21:30 3.50 CASE INT1 Perform top job at 222'. Flush annulus with water. Mix and pump 54 bbls ASlII. Good cement returns to surface. R/d Dowell and lay down .1.25" top job string. 21:30 - 23:00 1.50 CASE INT1 NU 11" 5m Gen VI wellhead and test same. 23:00 - 00:00 1.00 CASE INT1 NU bope. 8~24~2000 00:00 - 01:00 1.00 CASE INT1 Finish nippling up bop's. 01:00 - 07:30 6.50 CASE INT1 Lay down 4" drill pipe from derrick. 07:30 - 08:30 1.00 CASE INT1 Install test plug, close annular. Test Iow-250/high 3500 psi. Install wear ring. 08:30 - 12:30 4.00 CASE INT1 Lay down 3-1/2" and 2-7~8" tubing from derrick. 12:30 - 15:30 3.00 CASE INT1 Rig up Schlumberger. Run 4.60" gauge ring and junk basket. Tagged bottom at 8095'. Pooh. 15:30 - 19:00 3.50 CASE INT1 Run in hole with SCMT bond log tools. Tagged bottom at 8116'(WLM). Log from 8116'-5100'. Good cement bond. 8' correction between LWD and SCMT. R/D Schlumberger 19:00 - 20:00 1.00 CASE INT1 Cut and slip drill line. Service top drive and adjust brakes. 20:00 - 20:30 0.50 CASE INT1 Pressure test casing 2500 psi for 30 minutes-good test. 20:30 - 21:00 0.50 CASE INT1 Pull wear ring. 21:00 - 22:00 1.00 RUNCO~fl COMP Rig up to run 2-7~8" tubing. 22:00 - 00:00 2.00 RUNCO~4 COMP PJSM. Running 2-7/8" packer assembly and tubing. 8~25~2000 00:00 - 10:30 10.50 RUNCOr COMP Finish running 2-7~8" 6.5~ L-80 EUE mod tubing. Tail pipe at 7180'. 10:30 - 11:00 0.50 RUNCO~ COMP M/u Tubing hanger. Land hanger and run in lock down screws. 11:00 - 12:00 1.00 RUNCOI~ COMP Set two way check and n/d bops. 12:00 - 14:30 2.50 WHSUR COMP N/U 2-9/16" and test 5000~ -15 minutes. Pull two way check. 14:30 - 16:00 1.50 CHEM COMP Circulate corrosion inhibitor into annulus -110 bbls. 16:00 - 16:30 0.50 CHEM COMP Circulate 80 bbls diesel down annulus for freeze protection 16:30 - 17:30 1.00 CHEM COMP Let well u-tube and equalize 17:30 - 18:30 1.00 EVAL COMP Drop 1" RHC metal ball and let land in XN nipple. 18:30 - 19:00 0.50 RUNCOr~ COMP Pressure up and set packer with 4500 psi. 19:00 - 20:00 1.00 RUNCOr~ !COMP Bleed psi to 3000 on tubing and held for 30 minutes-ok, 20:00 - 21:00 1.00 RUNCOI~I : COMP Bleed tubing psi to 0 and test annulus to 3500 psi for 30 minutes. All test witnessed by Jeff Jones with AOGCC. 21:00 - 22:00 1.00 WHSUR COMP ~PJd lines and set BPV in tree. 22:00 - 00:00 2.00 RIGD COMP Finish cleaning pits. Release rig at 0000 hrs. Printed: 8/30/2000 2:15:21 PM Well: M PI-210 Accept: 08/14/00 Field: Milne Point Unit Spud: 08/15/00 APl: 50-029-22966-00 Release: 08/25/00 Permit: 200-109 CTD Unit: Doyon 141 POST RIG WORK 09102/00 Attempted to perforate OB sand but left short bull nose in hole. Slickline will be needed to knock bull nose to bottom. 09/03/00 Tagged fish at 7096' sim, attempted to beat down hole. 09/04/00 Successfully knocked fish into rat hole. Tagged bottom at 8088' sim. 09/09/00 RIH to perforate lower OB sands using 2" guns. Could not make it to perf interval (3' short). Town gave okay to perf interval. (8087' - 8107') While pulling out of hole gun stuck at 4010' (perf debris?). Worked gun free by pumping and straight pulling. All tools recovered. Slickline will need to redrift before shooting remaining OB interval. 09/11/00 Drifted tubing to 'XN' nipple with 10' x 2.25" bailer. Had to beat it through several spots. 10" x 2.00" bailer went to bottom with no problems. 09/17/00 Drifted tubing w/brush. Tried to get a definite bottom hole fluid sample. Couldn't get bailer to fire. Soft bottom. Poor action. Fluid sample taken from trap both runs, bad sample. Will attempt another run with aluminum disc being made. 09/21/00 Obtained sbhp at 8090' sim. Top gauge 1467 psi at 79 deg. Bottom gauge read the same. Well stabilizsed for the static. Obtained bailer sample at 8096' sim, bailer sheared. Had the wrong botton on, but answered the question about being able to shear it. Drifted tubing to 2640' sim with 2.25". Still having trouble getting down with a 10' bailer. 10/06/00 Drifted with 10' x 2" spent dummy perf gun to TD. No problems going in or coming out. 11/13/00 Rigged up and pressure tested to 3000 psi. Run in hole with a 2" power jet, 4 spf at 60 deg phasing. Tied into SBL 08/22/00. Attempted to get into the perf interval, sat down several times at 8004' elmd. Unable to get past that area. Called out HB&R to assist tools through that area. HB&R rigged up and pressure tested. Worked tools down to 8037' elmd (OB sands). Fired guns, good indication on surface shot. Pull out of hole, all shots fired. Interval 8042' to 8062' shot. 11/15/00 Shot two intervals in the OA sands with 20' 2" power jet 4 spf, (7912' - 7932' and 7845' - 7865') RECEIVED JAN 04 001 Alaska 0it & Gas Cons. Commission Anchorage North Slope Alaska Alaska State Plane 4 Miine Point MPI MPI-210 Surveyed: 20 August, 2000 SURVEY REPORT 10/04/2000 13:07:28 PM Your Reft API-500292296600 Surface Coordinates: 6009443.52 N, 551704.74 E (70° 26' 11.5650" N, Kelly Bushing: 62.35ft above Mean Sea Level 149° 34' 42.3934" W) ~1~ l i~L. I'N t~tl i fill ImqVl C e;=' Survey Ref: svy9545 Sperry-Sun Drilling Services Survey Report for MPI-210 Your Ref: AP1-$00292296600 Surveyed: 20 August, 2000 North SloPe Alaska Measured Depth (tt) Incl. Azim. Sub-Sea Depth (st) Vertical Local Coordinates Global Coordinates Depth. Northings Eastings Northings Eastings (ft) (st) (ft) (tt) (St) Dogleg Rate (°/100ft) Alaska State Plane 4 Milne Point MPI Vertical Section (st) Comment MPI-210 Gyrodata 0.00 0.000 0.000 -62.35 0.00 203.00 0.700 86.400 140.64 202.99 293.00 1.100 63.900 230.63 292.98 386.00 2.500 36.600 323.59 385.94 480.00 2.900 30.200 417.48 479.83 575.00 2.300 294.600 512.42 574.77 668.00 2.500 270.100 605.34 667.69 768.80 2.100 267.200 706.06 768.41 856.00 3.300 252.200 793.16 855.51 951.00 6.700 228.000 887.80 950.15 1048.00 11.500 232.100 983.55 1045.90 MPI-210 1181.06 16.050 228.090 1112.75 1175.10 1273.47 18.940 235.670 1200.89 1263.24 1368.59 20.540 236.760 1290.42 1352.77 1461.24 23.910 234.340 1376.17 1438.52 1554.85 26.660 236.640 1460.81 1523.16 1647.30 26.670 247.680 1543.48 1605.83 1744.51 31.060 259.670 1628.66 1691.01 1838.99 32.650 272.180 1709.00 1771.35 1932.99 40.270 276.680 1784.56 1846.91 1965.97 44.290 279.590 1808.95 1871.30 0.00 N 0.00 E 0.08 N 1.24 E 0.49 N 2.56 E 2.51 N 4.57 E 6.21 N 6.99 E 9.09 N 6.47 E 9.87 N 2.74 E 9.78 N 1.30 W 8.93 N 5.29 W 4.39 N 12.01 W 5.34 S 23.85 W 25.79 S 48.02W 42.78 S 69.92W 60.64 S 96.63W 80.50 S 125.49W 103.11S 158.45W 122.41S 194.99W 135.21S 239.90W 138.61S 289.40W 134.11S 345.01W 130.95 S 366.96W 6009443.52 N 551704.74 E 6009443.61N 551705.98 E 6009444.03 N 551707.30 E 6009446.07 N 551709.30 E 6009449.78 N 551711.69 E 6009452.65 N 551711.14 E 6009453.41N 551707.41 E 6009453.29 N 551703.37 E 6009452.42 N 551699.39 E 6009447.83 N 551692.70 E 6009438.01N 551680.92E 6009417.40 N 551656.90 E 6009400.25 N 551635.12 E 6009382.21N 551608.54 E 6009362.15 N 551579.82 E 6009339.31 N 551547.01 E 6009319.76 N 551510.61 E 6009306.65 N 551465.78 E 6009302.90 N 551416.31 E 6009307.02 N 551360.67 E 6009310.03 N 551338.70 E 0.345 0.585 1.725 0.532 4.076 1.115 0.413 1.586 4.136 4.990 3.492 3.977 1.726 3.768 3.119 5.352 7.454 7,176 8.586 13.555 0.00 -1.24 -2.58 -4.69 -7.28 -6.89 -3.21 0.84 4.86 11.79 24.08 49.19 71.87 99.39 129.16 163.15 200.56 246.03 295.64 350.97 372.75 Tie-on survey to Gyrosteer MWD Magnetic 10/04/2000 13:07:29 PM - 2 - DrillQuest 1.05. 05 Sperry-Sun Drilling Services Survey Report for MPI-210 Your Ref: AP1-$00292296600 Surveyed: 20 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2000.48 47.350 280.510 1833.00 1895.35 2027.56 50.590 282.660 1850.78 1913.13 2124,53 49,510 283,050 1913.04 1975.39 2215.69 54,160 283,870 1969.36 2031.71 2310.43 57.930 282.560 2022.27 2084.62 2402.91 61.620 279.220 2068,82 2131.17 2499.17 64.100 272.720 2112.77 2175.12 2590,70 ~ 68.950 268.730 2149,23 2211,58 2681.41 75.140 267.850 2177.18 2239.53 2775.32 75.870 264.290 2200.69 2263.04 2871.18 75.470 265,630 ' 2224,42 2286.77 2968.21 74.280 265.190 2249.74 2312.09 3059.15 73.940 264.000 2274.63 2336.98 3343.60 73.180 268.740 2355.18 2417.53 3438.07 72.640 268,060 2382,94 2445.29 3532.61 71.390 267.550 2412.13 2474.48 3626.67 70.400 264.520 2442,92 2505.27 3721,13 68,850 269.160 2475.83 2538.18 3812.46 71.940 271.860 2506.47 2568,82 3906,24 75.090 270.790 2533.08 2595,43 3999.2'0 73.250 271.720 2558.44 2620,79 4091.02 72.300 272.240 2585,63 2647.98 4186.20 72.460 271.130 2614.44 2676.79 4280.00 75.680 266.580 2640,19 2702.54 4375.27 75.220 262.240 2664.14 2726.49 126.62S 391.32W 6009314.19 N 551314.30 E 122.51S 411.33W 6009318.16 N 551294.27 E 105.98S 483.80W 6009334.19 N 551221.68 E 89.28 S 553.48W 6009350.40 N 551151.89 E 71.34 S 629.97W 6009367.81N 551075.28 E 56.29 S 708.42W 6009382.32 N 550996.73 E 47.45 S 793.55W 6009390.57 N 550911.54 E 46.44 $ 877.45W 6009391.00 N 550827.63 E 49;02 S 963.66W 6009387.82 N 550741.44 E 55.26 $ 1054.35W 6009380.95 N 550650.80 E 63.42 $ 1146.87W 6009372.15 N 550558.34 E 70.91S 1240.23W 6009364.01N 550465.03 E 79.15 $ 1327.31W 6009355.17 N 550378.01 E 96.44 $ 1599.49W 6009335.99 N 550105.96 E 98.96 $ 1689.75W 6009332.85 N 550015.72 E 102.40 S 1779.60W 6009328.78 N 549925.89 E 108.54 S 1868.26W 6009322.03 N 549837.28 E 113.44 S 1956.64W 6009316.52 N 549748.93 E 112.65 S 2042.65W 6009316.71N 549662.92 E 110.58 S 2132.54W 6009318.16 N 549573.02 E 108.62 $ 2221.95W 6009319.49 N 549483.60 E 105.60 S 2309.60W 6009321.91 N 549395.93 E 102.93 S 2400.27W '6009323.95 N 549305.24 E 104.76 S 2490.41W 6009321.50 N 549215.12 E 113.74 $ 2582.16W 6009311.89 N 549123.43 E Dogleg Rate (°/100ft) 9.071 13.379 1.156 5.150 4.141 5.065 6.537 6.637 6.886 3.752 1.417 1.302 1.313 1.620 0.894 1,418 3.221 4.888 4.382 3.533 2.2Ol 1.168 1.124 5.791 4.436 Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment 396.88 416.67 488.28 557.o9 632.65 71o.29 794.91 878.67 964.90 lO55.79 1148.58 1242.2o 1329.57 1602.26 1692.54 1782.46 1871.3o 1959,82 2045.69 2135,38 2224.60 2312.00 2402.45 2492.58 2584.65 Continued... 10/04/2000 13:07:30 PM - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPI-210 Your Ref: API.500292296600 Surveyed: 20 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Fastings (ft) (ft) (ft) 4468.63 75.080 261,960 2688.07 2750.42 4561.45 75.510 263.170 2711.63 2773.98 4656.28 74.910 261.770 2735.84 2798.19 4752.19 76.030 262.640 2759.90 2822.25 4844.53 73.330 261.440 2784.30 2846.65 4939.65 73.150 261.370 2811.72 2874.07 5031.09 72.300 262.930 2838.88 2901.23 5126.38 71.750 263.300 2868.29 2930.64 5219.52 70.650 262.290 2898.30 2960.65 5311.74 69.230 264.390 2929.94 2992.29 5406.80 70.380 266.310 2962.75 3025.10 5500.22 71.270 268.530 2993.44 3055.79 5593.37 70.890 266.830 3023.65 3086.00 5781.08 70.170 270.410 3086.23 3148.58 5878.13 69.650 269.120 3119.57 3181.92 5972.19 69.610 269.350 3152.31 3214.66 6065.59 69.310 268.920 3185.08 3247.43 6158.38 69.820 269.730 3217.48 3279.83 6252.79 70.030 270.040 3249.88 3312.23 6346.62 70.320 269.720 3281.71 3344.06 6438.75 70.190 271.050 3312.83 3375.18 6533.62 70.010 270.490 3345.12 3407.47 6626.64 70.790 271.910 3376.33 3438.68 6719.15 71.190 271.870 3406.46 3468.81 6812.51 70.800 270.870 3436.87 3499.22 Global Coordinates Dogleg Northings Eastings Rate (fl) (ft) (°/lOOfl) 126.14 S 2671.55W 6009298.86 N 549034.13 E 137.76 S 2760.57W 6009286.63 N 548945.19 E 149.77 S 2851.46W 6009273.99 N 548854.38 E 162.36 S 2943.45W 6009260.76 N 548762.49E 174.68 S 3031.64W 6009247.82 N 548674.39 E 188.30 S 3121.69W 6009233.59 N 548584.43 E 200.22 $ 3208.19W 6009221.06 N 548498.02 E 211.09 S 3298.17W 6009209.57N 548408.11 E 222.15 S 3385.64W 6009197.91N 548320.72 E 232.20 S 3471.68W 6009187.26 N 548234.76 E 239.42 S 3560.59W 6009179.42 N 548145.89 E 243.39 S 3648.73W 6009174.84 N 548057.78 E 246.96 $ 3736.77W 6009170.66 N 547969.77 E 251.23 S 3913.66W 6009165.16 N 547792.91 E 251.60 S 4004.80W 6009164.16 N 547701.78 E 252.78 S 4092.97W 6009162.37 N 547613.62 E 254.10 S 4180.42W 6009160.44 N 547526.18 E 255.12 S 4267.37W 6009158.82 N 547439.24 E 255.30 S 4356.04W 6009158.03 N 547350.57 E 255.49 S 4444.31W 6009157.23 N 547262.31 E 254.90 S 4531.02W 6009157.21N 547175.60 E 253.70 S 4620.22W 6009157.79 N 547086.39 E 251.87 S 4707.82W 6009159.02 N 546998.78 E 248.98 S 4795.24W 6009161.30 N 546911.34 E 246.87 $ 4883.48W 6009162.80 N 546823.08 E 0.326 1.343 1.561 1,461 3.181 0.202 1.876 0.685 1.565 2.636 2.249 2.438 1.774 1.839 1.358 0.233 0.538 0.986 0.380 0.445 1.366 0.587 1.665 0.434 1.096 Alaska State Plane 4 Milne Point MPI Vertical Section (ft) Comment 2674.52 2764.oo 2855.36 2947.83 3036.51 3127.11 3214.07 3304.47 3392.37 3478.78 3567.94 3656.16 3744.28 3921.17 4012.22 4100.35 4187.77 4274.66 4363.24 4451.42 4538.01 4627.05 4714.47 48Ol.65 4889.70 Continued... DrillQuest 1.05.05 10/04/2000 13:07:30 PM - 4 - Drilling Services sperry-Sun, o for MPI'210 surveY_ ~ p , .500292296600 Your Her: APl surveyed: 20 AuguSt, 2000 North S%ope Alaska Measured Depth Incl. Azim. 6907,93 70.120 269.250 7000.80 70,330 269,760 7094.37 70,300 269.560 7187.98 70.950 267.320 7285.90 71.130 266.570 7375.18 69.950 267.230 70.670 267.130 7470.64 266.330 71.030 Sub-Sea Ve~icat Depth Depth Nothings (~) 24627S 3468.78 3531,13 247,51S 3562,55 248.02 S 3500~0 3594.07 250.43S 353122 3625.13 255.36S 356226 3656~5 3594.60 259.92S 3624.34 3686,69 264.34S 3718.65 269.47S 3656.50 3750.10 27326 S 368725 3780.72 278,04 S 3718.37 3812.34 Loca% Coordinates Northings Fastings (fi) Gtobat coordinates Eastings 6009162.27 N 4973.40 W 6009160.93 N 5060.79 W 6009159.81 N 5148.89 W 6009156.79 N 5237.16 W 6009151.21 N 5329.64 W 5413.69 W 6009146.08 N 5503.46 W 6009141.03 N 5593.30 W 6009135.28 N 6009130.38 N 5681.52 W 6009125.48 N 5771.12 W 5858.62 W 6009120,37 N 7565,90 268,110 6009116.43 N 5948.94 W 7659.38 70,730 3749,99 7754.50 70.450 266.420 282,54 S 3761.45 3643.80 285.85 S 6034.92 W 6009112.95 3876.56 288.74 S 6123.48 W 6009109.32 0 n40 267.690_ 3814 21 -- ~0 _ ~ ~nn~105.22 6129.U~ 69' 590 26/.~°~ 7 57 3979.9Z 298.02 ~ 8223.99 ' __ ,,n 391 · -~0~ 17 ' ~ ~9 69.570 ~;';~ 3937.82 4u ~. - - are retative to Tree NoAh. ~'~ 69.570 zo · - -"d coordinates - 6302.00 .... a nirections ~"~ .... ,~ relatNe to ~, · A~t dat~ ~,h~ are retat~ve ,u, .... Ve~iCa~ u~ .... 1° {30-Aug-00~ Magnetic Declination at Sudace is 26.57 . · · Degrees per 1.00ft. ot 267.2850 ~ e severity ts t~, ~n calculated atong an Azimuth Th~ Dog~ g .... ~ imm ~o .... d asure~ Depth ot 8302,00ff-, · ns ataMe 85o VeAiCal 5ect~o- ' ..... _ .... woe catcutat? ,~ n~rection ot 267.2 The Bottom Hole Disp~ace~"o'" ~ -s- Dogleg Rate Alaska State plane 4 Mitne point MPt Vertical comment section 546733.17 E 1.751 4979,51 546645,78 E 0.563 5066.84 546557,69 E 0.224 5154.86 546469.44 E 2.362 5243.15 546377.00 E 0.747 5335.75 546292.98 E 1.494 5419.93 546203.24 E 0.761 5509.80 546113,44 E 0.879 559929 1.827 5686.11 546025.26 E 5777.82 545935.68 E 1.701 5865.42 545846.22 E 1,357 545757.92 E 0,419 5955.81 545671.96 E 0.314 6041.83 545583.43 E 0,129 6130.43 545495.00 E 0239 6218.95 6237.69 545476.28 E 2,111 6292.05 545421.97~ 0.000 Last Survey proiected survey Z ;0 m rn Continued..' orillQUeSt 1.05,05 ~0~)4/2000 13:07:31 PM Drilling Services sperry-SUn o, for MPI-21_O survey_ surveyeu: '~ .... Alaska State plane 4 Milne point North Slope Alaska tea comments Easttngs Measured station coordtna Northtngs (,it) Depth TVD (it) 23.85 W (it) tit) 5.34 s 6230.67 w 1045.90 296.01 S 6284.99 W 1048.00 3979.92 298.02 S 8243.99 4000.17 8302.00 comment Tie-on su;ve¥ to Gyrosteer t.~st suwe¥ pm~ected suwe¥ surveY tool program T o F r o m Measured verttoat Measured vertical Depth Depth Depth Depth (It) ('It) o.oo .~.~s.~.o6 o.oo ~75.'~o 88o2.oo ,~ooo.'~7 1181.06 Survey Tool Oesoription k~WO Magnetic 10/04/2000 13:07:32 PM Z m bp November 7, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Davies: Subject: Well Re-Naming The operator request the following Milne Point Wells be re-named as follows: APl num Permit Number ..... Current Name New Name 500292296600 200-109 MPI-210 MPI-10 500292297000 200-120' M PJ-223 M PJ-23 5002§2297600 200-149 M PJ-224 M PJ-24 500292298000 200-166 M P E-225 M PE-25 500292298060 200-167 M P E-225L 1 M P E-25 L 1 Sincerely, Troy D. W~~eiss ' ACT, Production Optimization Team Leader TDW:mw CC: Well Files S. Copeland, MB LR-2 Gary Benson, MB 12-4 Larry Niles, MPU Chuck Mallary, MB 8-1 'Mike Bill, MB 7-5 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 611 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 1 O/12~00 Well Job # Log Description Date BL Sepia CD MPI-210 ~ ~ ~"~ 20410 SCMT (PDC) 000824 1 · · : · . ~ I · · . . . · PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED Date Delivered: oCT 13 2000 Alaska 0il. & Gas Cons. ~ommission Anr, hnr~l(1R Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A17N: Sherrie Received i~:~~~~ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 497 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 9/7/00 Well Job # Log Description Date BL Sepia Color MPI-210 20366 COLOR PRINTS SCMT 000824 1 , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED Date Delivered: v ~ - r-VMV, N.a~ja. Qit& Gas Cons. C, ommlssl~ Schlumberger GeoQuest 3940 Arctic Blvd Received ~y:~,'q_/\ ~""( ~ MEMORANDUM ,~ TO= Dan Seamount Chairman ~9.~'O THRU: Blair Wondzell (~~ P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: Aug. 25, 2000 SUBJECT: Mechanical Integrity Tests BPX I-Pad FROM: Jeff Jone MPU Petroleum ~a'Slile~t~N~ Milne Point Field ON CONFIDENTIAL ..... Packer Depth Pretest Initial 15 Min. 30 Min. W~i;~:~2J~,~;~Typelnj.I N I T.9. D.I 36'10 I Tubingl 0I 0 I 0 I 0 l lntervall ~ P.T.d.l,':,200:~!?]'Typetest] .P ,I-i-estpsil 3,500 Icasingl 0 I 35°° I :~4°° I 3380 ] P/F ]-P Notes: . WellI ' P.T.D.I Notes: weul P.T.D.I Notes: WellI '" p..T.D.i 'Notes: · Well[ · p.T.D.I Notes: I Typelnj. l' IT'v'o' I I"TubingI . I I ' I I IntervalJ Type testI I Test'psil , ' 0. I Casing I I . ] J I P/F I I Type Inj. I ] T.V.D. I ' I Tubing I I ] ] I~nter~a'l ITypetestl· ITestpsil',0' I caSingl' ' I I '1 IP/F I I'rype~"i.I ' ' ' I ~.v.~: I" ' I ~u~'~n~ I "I I I I~n~e~'"~l I Typetestl'' ' ITe. st p~il. 0 I,·Casing I ' I I I ' I P/F. ] ITypelnj'l I'T'V'D: ] ......'J Tubing,I : I I I ' Jlntervall I TYPetestl' ' ITest psiI · o ICasing,I I ' I. , ' I I P/F I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test· M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test ~ Four Year Cycle V= Required by Vadance W= Test during Workover O= Other (describe in notes) Test's Details Friday. August 25..,2000: I.traveled to BPX's MPU I-?ad to witness the initial MIT on well 1.210i. Rig personnel'were in the process of setting'the packer when I arrived. Subsequently, the tubing was successfully pressure tested with diesel to 3000 psi. The tubing pressure was then bled to zero. The annulus was pressured up to 3500 psi with diesel. I observed a 120 psi pressure drop in thirty minutes and the pressure stabilized at 3380 psi., indicating this well is suitable for injection. · The attachments listed below were faxed to the.AOGCC Anchorage office. Summary: I witnessed a successful MIT on BPX's MPU well 1-210i. .I.T.'s performed' ~_ Number of Failures: Attachments: Test Chart,'Tubin.q Summary Total Time during tests: 2 hrs. cc: NileslShiple¥ BPX-MPU MIT report form 5/12/00 L.G. MIT 1-210i MPU 8-25-00 JJ.xls 8/28/00 ( P. :. ,,," -~ ';- '~ ~'?~?~'~ ~'- ~:~,,~;.~t ,-'. :-.' '-' I -v~-~ ~v~v,~l~-: 'h,;' '-"- "~,' ,, .-~'' '', ' ''~ · · ". ' . ..~:~: ',:'~ ~- ..' _ -I.: , ...... .... """ "'' ''*" '~"~"%'~'~'~;': "'"*' '" " .... ' ""~ ' ~ ~'*'*~"' ~'~"J '" ~" *' %J~'2'~" ''~d't' ~: ~.". "., ;..; , ' ,. '.".' ...... ~.~'~'.';,.'~"%' ,,. ~;.; : ;;', , '" .... ~'~'..~ :,.:~;.-.,':~.",. , ' ' "2'- '":'. 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RE: MPI-10i..(PTD 200-109) cement operation Subject: RE: MPI-10i (PTD 200-109) cement operation Date: Thu, 24 Aug 2000 20:02:35 -0500 From: "PBU, Drlg Rig 141" <PBUDrlgRig141_@bp.oom> To: '"Tom Maunder'" <tom_maunder@admin.state.ak. us> Tom, We ran 1" pipe down to 222' where cement was tagged. Alter flushing the annulus with water, Dowell mixed and pumped 54 bbls AS III until good cement returns(10.7 ppg) were at surface. From: Tom Maunder[SMTP:torn_maunder@admin. state, ak. us] Sent: VVednesday, August 23, 2000 4:29 PM To: PBU, Drlg Rig 141 Cc: John Hartz; Blair Wondzell; AOGCC North Sope Office Subject: Re: IV~l-lOi (PTD 200-109) cement operation <<File: tom maunder, vcf>> Steve and Jimmy, Thanks for the calls and follow-up information. This situation is similar to one Paul Lockwood and I encountered on one of the early radicals. Based on what I saw; good returns, indicator color change and strong cement odor I proposed exactly what you have to Blair and received approval. During your initial call, Chuck Scheve and I concurred that based on your initial observations further work was not necessary unless something additional was observed as you proceeded. You provided further information via phone after ND the diverter and a summary via email. While waiting on your email, I have discussed the information with Jack Hartz. We concur that based on your reported observations of the job, that you are correct that cement is likely above the port collar and your chances of establishing circulation through it a few hours hence aren't good. We also concur that your proposal to run 1-1/4" pipe in the annulus to as deep as you can and perform a remedial cement job is the best choice. Good luck. Give a call if you need anything further. I am carrying the cell phone...244-1567. Othervcse I will be home... 345-0850. Best to you and Jimmy. Tom Maunder "PBU, Drlg Rig 141" wrote: > Tom, > Details for I-10i cement operation. > Depth:8303' ZOco- 09 1 of 2 8/25/00 7:32 AM RE:.MPI-10i...(PTD 200-109)cement operation(. 5 1/2" long string casing float ~llar @ 8209' float shoe @ 8291' theoretical displacement to shoe: 193 bbls actual displacement was 193 bbls did not bump plug full returns throughout operation redprocated pipe during job until pumping tail, landed csg in head cement volumes included 50% excess for below permafrost (2000') and 250% excess in the permafrost, 500 bbls lead and 97 bbls tail Once we saw the 10.0 ppg spacer with the red die vve had 75 bbls left of > > displacement, the volume of spacer was 60 bbls, with about 20 bbls left > of > > displacement we were seeing cement in the flow and weight at 10.2 ppg. > > Testing with phenopthalein we got a definite indication of the Caldum > ion > > (bright red). The quandrythat we are in is we are fairly sure that the > > good 10. 7 ppg lead slurry has to be right there at surface, if we opt to > go > > in and shift the DV tool (2-3 hours) the cement above the tool will have > set > > and we are very reticent to start trying to break circulation and start > > fracing out into the permafrost. Therefore, vve would like to opt for a > top > > job, take 1 1/4" tubing and work it down the annulus of the 5 1/2" > casing > > and open hole and perform a top job. > > Thanks > > Steve 2 of 2 8/25/00 7:32 AM re: MPI- 10i (PTD 200-109) cement operation Subject: Re: MPI-10i (PTD 200-109) cement operation Date: Wed, 23 Aug 2000 16:29:12 -0800 From: Tom Maunder <tom_maunder~admin. state.ak.us> Internal To: "PBU, Drlg Rig 141" <PBUDrlgRigl41_~bp.eom> CC: John Hartz <jack_hartz~admin.state.ak.us>, Blair Wondzell <blair__wondzell~admin. state.ak.us>, AOGCC North Sope Office <aogcc_prudhoe_bay~admin.state.ak.us> Steve and Jimmy, Thanks for the calls and follow-up information. This situation is similar to one Paul Lockwood and I encountered on one of the early radicals. Based on what I saw; good returns, indicator color change and strong cement odor I proposed exactly what you have to Blair and received approval. initial call, Chuck Scheve and I concurred that based on your During your initial observations further work was not necessary unless something additional was observed as you proceeded. You provided further information via phone after ND the diverter and a summary via email. W~ei~%n~tg~tO~a~ro%~g~ ~ehg~e~ig%~%g~t~%si~o~h%ti~ wg%~tJa~ ~;%tz. 'y p ' j, y correct that cement is likely above the port collar and your chances of establishing circulation through it a few hours hence aren't good. We also concur that your proposal to run 1-1/4" pipe in the annulus to as deep as you can and perform a remedial cement job is the best choice. Good luck. Give a call if you need anything further. I am carrying the cell phone...244-1567. ' Otherwise I will be home...345-0850. Best to you and Jimmy. Tom Maunder "PBU, Drlg Rig 141" wrote: > Tom, > Details for I-lOi cement operation. > Depth:8303' > 5 1/2" long string casing > float collar ~ 8209' > float shoe 8 8291' > theoretical displacement to shoe: 193 bbls , > actual displacement was 193 bbls > did not bump plug > full returns throughout operation > reciprocated pipe during job until pumping tail, landed csg in head > cement volumes included 50% excess for below permafrost (2000') > and 250% excess in the permafrost, 500 bbls lead and 97 bbls tail > Once we saw the 10.0 ppg spacer with the red die we had 75 bbls left of > displacement, the volume of spacer was 60 bbls, with about 20 bbls left of > displacement we were seeing cement in the flow and weight at 10.2 ppg. > Testing with phenopthalein we got a definite indication of the Calcium ion > (bright red). The quandry that we are in is we are fairly sure that the > good 10. 7 ppg lead slurry has to be right there at surface, if we opt to go > in and shift the DV tool (2-3 hours) the cement above the tool will have set > and we are very reticent to start trying to break circulation and start > fracing out into the permafrost. Therefore, we would like to opt 'fora top > job, take 1 1/4" tubing and work it down the annulus of the 5 1/2" casing > and open hole and perform a top job. > Thanks > Steve 1 of 2 8/28/00 8:45 AM ALASiIA OIL AND GAS CONSERVATION CO~IlSSION Chuck Mallary Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Milne Point Unit I-210 BP Exploration (Alaska) Inc. Permit No: 200-109 Sur. Loc. 2328'NSL, 3665'WEL, Sec. 33, T13N, R10E, UM Btmhole Loc. 2014'NSL, 4726'WEL, Sec. 32, T13N, R10E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other goVernmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the · BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may' be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~~Dllniel . .~ T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this / ~' day of August, 2000 dlf/Enclosures CC; Department of Fish & Gmne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA -' ALA~. OIL AND GAS CONSERVATION CO(" .IISSION I~-~ PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan 64.5' Milne Point Unit / Schrader '3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2328' NSL, 3665' WEL, SEC. 33, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number j _ ~_ I O 2033' NSL, 4308' WEL, SEC. 32, T13N, R10E, UM 4aPt='tOi- Number 2S100302630-277 At total depth 9. Approximate spud date 2014' NSL, 4726' WEL, SEC. 32, T13N, R10E, UM 08/15/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025627 & 025628, 2014' MDI 21' away from aPl-01 at 799' MD 2555 8310' MD / 3997' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 72 ° Maximum surface 781 psig, At total depth (TVD) 3933' / 1233 psig 18. Casing Program Specifications Setting Depth ?,ize Tr,o Be :~m Quantity of Cement Hole Casino Weiaht Grade Couplinq Lenqth MD TVD MD TVD (include staqe data) 30" 20" 94# H-40 PE 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.) 7-7/8" 5-1/2" 17# L-80 BTC-M 8310' 30' 30' 8310' 3997' 584 sx Arctic Set 3~ 453 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD 'I'VD Structural Conductor Surface Intermediate Production RECEIVED Liner 0 RI G INA L Ju, ooo Perforation depth: measured ~aska 0ii & Gas Cons. Commission A~ch0rage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Fred Johnson, 564-5427 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChuckMallary~ Z ~ ~ Title Senior Drilling Engineer Date 7~7(ee APl N~.b.~,::~ .~,~__.. ~ ...(..~ (~ ...., Approval D_ate I See cover letter PermitN.__.... _./(~_ 50- " ~'~---/--~') ("~) for other requirements Conditions of Approval: Samples Required r"l Yes .J~'No Mud Log Required [] Yes I~"No Hydrogen Sulfide Measures ~ Yes ]~No Directional Survey Required ~['Yes [] No Required Working Pressure for BOPE 1~2K; r"! 3K; r'l 4K; r"l 5K; [] 10K; I-I 15K Other: JRiGINAL SIGNED BY by order of ~ Approved By O Taylor Seamount Commissioner the commission Date~'-"'/ ~ ~)4~) Form 10-401 Rev. 12-01-85 Submit In Triplicate Schrader Bluff Tract 14 2000 Program MPI-10i Permit to Drill Support Document IWell Name: IMPI-10i Well Plan Summary Type of Well (producer or injector): I Water Injector Surface Location: 2328' FSL (2952' FNL), 3665' FEL (1615' FWL), Sec. 33, T13N, R10E X= 551705.13 Y= 6009443.88 Target Start: 2033' FSL (3245' FNL), 4308' FEL (971' FWL), Sec. 32, T13N, R10E Radius = 200' X = 545786.00 Y = 6009111.00 Z = 3792.00' TVDss Intermediate Bottom Hole Location: 2014' FSL (3264' FNL), 4726' FEL (553' FWL), Sec. 32, T13N, R10E X = 545368.00 Y = 6009089.00 Z = 3933.00' TVDss I AFE Number: Estimated Start Date: ~ Doyon 141 115 Aug 2000 I I Operating days to complete: I 13 IMD I 8310' I ITvDrkb: I3997' I IKBE: 164'5' I Well Desi~n (conventional, slim hole, etc.): I Conventional Injector (grass roots well) Objective: Drill a 7-7/8" hole out of 20" conductor to TD. Build angle from 1.5© - 6°/100' out of the conductor, reaching 72© tangent angle at 2496' MD. Hold tangent angle to target and to TD 8310' MD (3997' TVD). Run, cement and test 5 ~", 17#, L-80 BTCM long string. Run cement evaluation log. Complete the well with 2-7/8", 6.5#, L-80 tbg and packer. The well is designed for water injection initially into the Schrader Bluff 'OA' and 'OB' sands. Completion design will allow future recompletion in the Schrader "N" sands. Asset Production/Injection Forecast: Estimated Reserves: Injector to sweep 1100 MSTBO Expected Initial Rate: Injection rate: 2,000 b/d Expected 6 month avg: Injection rate: 1,500 b/d Current Well Information Well Name: APl Number: Well Type: BHP: BHT: MPI-10i Water Injector 1233 psi @ 3933' TVD (estimated from offset wells) ~ 6.03 ppg EMW 80°F @ 4,020' TVDss Mechanical Condition MPI-10i Cellar box: RKB to Cellar box: Doyon 141: Conductor: Elevation above MSL = 35.1' 29.5' RKB + MSL = 64.50' 80' of 20", 92#, frost grooved, H-40, PE RECEIVED JUL 1 8 2000 Alaske 0il & Gas C(~s. Commission ,. Schrader Bluff Tract 14 2000 Program MPI-10i Permit to Drill Support Document Drilling Program Overview Surface and Anti-Collision Issues Surface Shut-in Wells: None required for rig move by Milne Point policy. Well 1-01 spaced 30' West. Close Approach Wells: None, All wells pass BP close approach requirements I Well Name I Current Status I Production Priority I Precautions Well Control: Expected Formation Pressures & BOPE Test Pressures Expected BHP 1233 psi @ 3933' TVD (estimated) ~ 6.03 ppg EMW Max Exp Surface Pressure 781 psi (.115 psi/ft gas gradient) BOPE Rating 5,000 psi WP (Entire stack & valves) Planned BOPE Test Pres. 2000/250 psi Rams and Valves 2000/250 psi Annular Note: The wellbore will be drilled from surface to TD in the Schrader Bluff through a 20" surface diverter stack. The diverter will be removed and an 13-5/8", 5M BOP stack will be installed:and tested prior to running the 2- 7/8" completion. Mud Program A detailed Baroid mud program is included with the well plan. In summary, an LSND system with a 120 viscosity will be used initially to help lift the heavy gravels at the surface. The viscosity will then be relaxed to the 70 range for the remainder of the well. There are no LCM restrictions for this well. The ECD will be minimized by maintaining the tau0 in the 4 - 8 range with hydraulics monitoring and fluid testing. Density Funnel Yield pH APl Solids 10 Sec 10 Min (ppg) Viscosity Point Filtrate (% LGS) Gels Gels 8.6 120 50 8.5 12 < 6 20 30 to to to to to to to 9.2+ 70 23 9.5 < 6 < 6 8 10 Waste Disposal: No annular injection is planned at Milne point. All drilling waste will be hauled to KRU 'IR' pad or PBU Drillsite 4. Call the Pad 4 waste disposal site prior to truck leaving location so the site can be prepared. RECEIVED JUL 'i 8 ?_000 Alaska Oil & Gas Cons. C,~'~mission ~,r~nhnr.age Schrader Bluff Tract 14 2000 Program MPI-10i Permit to Drill Support Document Formation Markers Formation Tops MD TVDss Pore EMW Comments Pressure (ppg) (psi) Base Permafrost 1800 Top Ugnu - TUZC 3180 1440 Top Ugnu - TUZB 3390 1535 SBF2-NA 3629 1652 8.76 +/- 25 ft & hydrocarbon bearing SBF1-NB 3657 1663 8.75 Hydrocarbon bearing SBF4-NC 3688 1675 8.74 Hydrocarbon bearing SBF2-NE 3705 1682 8.73 Hydrocarbon bearing SBE1 -NF 3752 1701 8.72 Hydrocarbon bearing TSBD-OA 3792 1177 5.97 Hydrocarbon bearing TSBC 3828 1191 5.99 TSBB-OB 3862 1205 6.00 Hydrocarbon bearing SBA5 3885 1214 6.01 TD 3933 1233 6.03 Casing/Tubing Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 94 H-40 PE 80' 30' 110' 7-7/8" 5 Y2" 17# L-80 BTCM 8310' 30'/30' 8310'/3997' Tubing 2-7/8" 6.5# L-80 EUE-M 7250' 30'/30' 7220'/3660' Cement Calculations ICasing Size 15 YW' BTCM I Basis 1 80' shoe jts, 55% excess in open hole, 275% in permafrost (7-7/8" hole), cement to surface. lTD 8310' MD (3997' mVDrkb), Total Cement Volume: Pre-flush 10 bbls of water Spacer Lead Tail Temp 75 bbls of B45 Viscosified (1.5%) Spacer Weighted to 10 ppg. 584 sxs (432.7 bbls), ArcticSet 3 - Lite, Yield 4.44 f¢/sx, mix fluid 20.7 gps 453 sxs (92.6 bbls), Class 'G' + 0.35% D65 + 0.4% S001 + 0.45% D167 + 0.02 gal/sk D47 + 0.5% D20, Yield 1.17 ft3/sx, mix fluid 5.106 gps BHST 80° F from SOR, BHCT 65° F estimated by Dowell Centralizer Placement: 1. Run 2 rigid straight blade centralizers per joint on the first 22 joints. 2. Screw down each centralizer in the middle of each joint. 3. Run 1 Bow Spring centralizer on either side of the Port collar. Other Cement Considerations: 1. Batch mix this slurry (< 50 bbl) 2. Confirm blends and calculations at the rig site RECEIVED JUL i 8 2000 Alaska Oil & Gas Cons, Commission Schrader Bluff Tract 14 2000 Program MPI-IOi Permit to Drill Support Document Materials Needed: L-80 Long String: L-80 Completion: 8310' I x 5-1/2" I x 5-1/2" 22 - 5 ~" x 7 5/8" 2 - 5 ~" x 8-1/2" I x 5 Y2" 7250' 5 ½"x 2-7/8" I x 2-7/8" (2.205" no go) 2 x 2-7/8" 2.313" no go) I x 2-7/8" 2 Each x 2-7/8" 5.5", 17#, L-80, BTCM Casing Halliburton float collar Halliburton EDJ float shoe Rigid Straight Bladed Centralizers Bow Spring Centralizer on either side of port collar TAM Port Collar 2-7/8", 6.5#, L-80 EUE-M tubing Baker 44SAB32X25 Packer with Anchor 'XN' nipple 'X' Nipple (including upper 'X' nipple) WLEG 10', 8', 6', 4', 2' NSCT space out pups Survey and Logging Program 7-7/8" Section: Open Hole: DIR ! GR ! PWD above target, DIR / GR ! RES ! PWD through target zone Sample Catchers - None required Cased Hole: SCMT Perforating: Will be perforated Post-Rig via Wireline conveyed 2" guns Locations OA and OB sands Perf. Interval: 60'- 100' Gun Size/Type: 2" powerjet 60° phasing loaded @ 4 spf Delivery: E-line Under Balance: No, overbalance BHP: 1233 psi @ 3933' TVD BHT: 80OF Bit Recommendations Bit Type I Hole Size & Section Hughes MX-C1I 7-7/8" Surface - 8310' TD Mill tooth 15, 15, 15, 10 300 30 Insert Bits: If a 7-7!8" insert bit is run, notify the ODE before exceeding 450K rev's or 40 hours on the bit Motors and Required Doglegs BHA Motor Size and Motor Required Flow Rate RPM's Required Doglegs Number I 6 Y2" Sperrydrill 5/6, 3.5 stage F2000 250 - 450 53 - 124 motor Spud in and build to 72° (Mill tooth) Slow Speed, 1.5° adj bent hosuing with gpm 60 -100 rotate @ 3-6°/100' and hold Surface Hole optional 7.6" concentric stabiliser tangent to TD 2 6 Y2" Sperrydrill 5/6, 3.5 stage F2000 Same Same Hold 72° tangent angle (Mill tooth) Slow Speed, 1.5° or 1.15° adj bent to TD Tangent & hosuing with optional 7.6" concentric Drop stabiliser Note: 3.5 stage slow speed motor turns at 0.40 rprn/gal 5 Schrader Bluff Tract 14 2000 Program MPI-10i Permit to Drill Support Document MPI-10i Operations Summary Snapshot of Well Program 1. MIRU Doyon 141, NU diverter on 20" conductor, PU 4" rental drill pipe 2. MU BHA with 7-7/8" milltooth bit, 4-3/4" Sperry MWD/LWD(GR-Res)/PWD and 4" drill pipe Drill 7-7/8" hole to TD as per directional plan Slant well design with tangent angle of 72 degrees Surface hole drilled through OB with 150' rathole 3. Wiper trip as required, condition mud with lubes and spot casing running lube pill prior to running 5-1/2" casing 4. Run 5 Y2" casing to TD Cement casing to surface in one stage with TAM Port Collar contingency Be prepared to use top drive weight to assist running casing Displace cement with completion fluid 5. Install FMC 11" 5m Gen 6 wellhead NU and test 13-5/8" 5m BOP (or 11" 5m BOP) 6. Lay down 4" drill pipe 7. RU Schlumbergere-line Run cement bond log 8. Run 2-7/8" tubing and packer completion Space out packer with the tailpipe 100'md above OA interval Freeze protect tubing and annulus Drop ball and set packer 9. Set tubing plug and BPV ND BOP Install and test 2-9/16" tree 10. RDMO 11. Post Rig work: Well to be perforated through the 2-7/8" tubing after the rig has been moved off RECEIVED Schrader Bluff Tract 14 2000 Program MPI-IOi Permit to Drill Support Document Drillin Hazards and Contingencies 1) Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter Prior to spud, per crew Once per week per crew while drilling with diverter in place. D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. · IN ALL CASES, ENSURE THAT THE DRILLS ARE CAREFULLY CARRIED OUT AND DO NOT EXPOSE EQUIPMENT, CASING OR FORMATION TO EXCESSIVE PRESSURES AND LOADS. · See BP Well Control Manual for all details of these drills. 2) 3) 4) 6) 7) 8) Hydrogen Sulfide · MP I Pad is not designated as an H2S Pad. Hydrates and Shallow Gas Always be prepared for the unexpected possibility of hydrates, shallow gas and hydrocarbons. Gas hydrates were encountered at the base of the permafrost on the 1-05 which was drilled to the east. Gas hydrates are anticipated on this pad and contingencies will be in place if they are encountered. Lost Circulation There is no history of lost circulation problems drilling to the Schrader Bluff formation on I pad and none expected drilling this well. A Lost Circulation Decision Tree Matrix will be used if mud losses are encountered Faults · Fault: 50' down to North, 1500' North of target · Fault: 30' down to East, 1625' East of target · Fault: 150' down to East, 1000' West of target, 650' West of TD · Possible small faults in Ugnu and Schrader N-sand interval Unexpected Pressures · The "O" sands are expected to be underpressured (6 lb/gal equivalent) in this well and the "N" sands are expected to be at normal pressure (8.6 lb/gal equivalent. In this well, the Schrader Bluff formation will be drilled with 9.2 ppg mud to provide the required overbalance for the Ugnu and "N" sands. · Low "O" sand reservoir pressure could cause differential sticking both while drilling and running casing. A PWD sub will be run to monitor ECD and to provide indications of effective hole cleaning while drilling. Other Concerns · Will drop inclination if Schrader N-sands come in deep to prognosis · Tight hole conditions and swabbing should be expected in clay intervals · Low reservoir pressure could cause differential sticking RECEIVED JUL i 8 2000 Alaska Oil & Gas Coos, Commbsion Anchorage 9) Schrader Bluff Tract 14 2000 Program MPI-10i Permit to Drill Support Document Pad Data Sheet Please Read the I-Pad Data Sheet Thoroughly RECEIVED ?.u0u JUL i 8 "'"" Alaska Oil & Gas Cons. Commission Anch~age I 'D Quext North Slope Alaska Alaska State Plane 4 MILNEPT MPI-MP MPI-10 WPs 0 0 ~-o Scale: I inch = lO00ft Eastings -6000 -5000 -4000 -3000 -2000 - 1000 0 Begin Dir @ 6.000°/100ft: 2028.27ft MD, 1830.74ft I'VD x I 0 .?¢;v, ~ ~ End Dir' 2496.41ft MD 2088 75ft TVD x Total Depth: 8310.05ft MD 3932.57ft TVD -6000 -5000 -4000 -3000 -2000 -1000 0 Scale: linch = 1000ft Eastings Reference is True North ~ 1000 - 2000 - = 3000 - O II ~ 4000 - Scale: 1 inch = 1000ft I/Begin DIr @ 1.500°/100ft: 300.00ft MD, 235.50ft TVD ~ __ _ [//Incre.einDirRate@3.000o/100ft:806.67ftMD, 83,.93,t'rVD JUL i 8 D00 /Increase in Dir Rate @ 4.500°/100ft: 1096.67ft MD, 1030.75fl IVD · ,~o.~ ~ Alaska Oil &Anchora~Gas Cons. Commiss'mn ~. /End Dlr: 1918.33ft MD, 1760.00ft IVD . ~.?..~.. ~Begln Dlr @ 6.000°/100ff: 2028.27ft MD, 1839.74ft IVD ~,~.~,~ /End Dir: 2496.41 ft MD, 2088.75ff TVD ...................... ~( )"}';';~: ~?~,::/i'.~ },'¥b' 4200.00 4800.00 6O00.00 8600.00 ........................................................................................................................................................ -Teoo:oo- .................... 7bi* · 385?.00 ?'~v~ ;O$ \ Total Depth: 8310.95ft MD, 3932.57ft IVD I I I I I I I 0 1000 2000 3000 4000 5000 6000 Vertical Section Section Azimuth: 267.221° (True North) o o o 1-- '~Z Sperry-Sun Drilling ~ )rvices Proposal Data - MPI- 10 WPs - MPI- 10 Wp5 1 July, 2000 - 8:30 - 1 - DrillQuest RECL,vbD JUL i8 2900 Alaska 0il & Gas Cons. Cornish Anchorage Sperry-Sun Drilling Services Proposal Report for MPI- 10 WPs - MPI- 10 Wp5 Revised: 1 July, 2000 North Slope Alaska Measured Depth Incl. Azim. (ft) 0.00 0.000 0.000 100.00 0.000 0.000 200.00 0.000 0.000 300.00 0.000 0.000 400.00 1.500 0.000 483.33 2.750 0.000 500.00 2.500 0.000 600.00 1.000 0.000 666.67 0.000 0.000 696.67 0.000 0.000 700.00 0.050 230.000 800.00 1.550 230.000 896.67 3.000 230.000 900.00 3.100 230.000 1000.00 6.100 230.000 Sub-Sea Depth (ft) -64.50 35.50 135.50 235.50 335.49 418.76 435.41 535.36 602.03 632.03 635.36 735.35 831,93 835.26 934.93 1096.67 9.000 230.000 1030.75 1100.00 9.102 230.698 1034.04 1200.00 12.618 245.844 1132.25 1300.00 16.610 254.158 1229.01 1400.00 20.806 259.260 1323.71 1500.00 25.104 262.695 1415.77 1600.00 29.459 265.175 1504.63 1700.00 33.849 267.064 1589.74 1800.00 38.262 268.564 1670.56 1900.00 42.690 269.797 1746.61 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) fit) (ft) (ft) 0.00 0.00 N 0.00 E 6009441.04 N 551704.82 E 100.00 0.00 N 0.00 E 6009441.04 N 551704.82 E 200.00 0.00 N 0.00 E 6009441.04 N 551704.82 E 300.00 0.00 N 0.00 E 6009441.04 N 551704.82 E 399.99 1.31 N 0.00 E 6009442.35 N 551704.81 E 483.26 4.40 N 0.00 E 6009445.44 N 551704.79 E 499.91 5.16 N 0.00 E 6009446.21 N 551704.78 E 599.86 8.22 N 0.00 E 6009449.26 N 551704.76 E 666.53 8.80 N 0.00 E 6009449.84 N 551704.76 E 696.53 8.80 N 0.00 E 6009449.84 N 551704.76 E 699.86 8.80 N 0.00 E 6009449.84 N 551704.76 E 799.85 7.90 N 1.07W 6009448.94 N 551703.69 E 896.43 5.43 N 4.01W 6009446.45 N 551700.77 E 899.76 5.32 N 4.15W 6009446.33 N 551700.64 E 999.43 0.16 N 10.29W 6009441.14 N 551694.53 E 1095.25 8.00 S 20.02W 6009432.91N 551684.86 E 1098.54 8.33 S 20.42W 6009432.57 N 551684.46 E 1196.75 17.82 S 36.52W 6009422.97 N 551668.43 E 1293.51 26.19 S 60.24W 6009414.43 N 551644.76 E 1388.21 33.41 S 91.46W 6009407.00 N 551613.59 E 1480.27 39.42 S 129.97W 6009400.72 N 551575.13 E 1569.13 44.19 S 175.54W 6009395.64 N 551529.59 E 1654.24 47.68 S 227.88W 6009391.78 N 551477.27 E 1735.06 49.89 S 286.68W 6009389.17 N 551418.49 E 1811.11 50.78S 351.57W 6009387.82 N 551353.61E Alaska State. Plane 4 MILNEPT MPI-MP Dogleg Rate (°/100ft) 0.000 0.000 0.000 1.500 1.500 1.500 1 .,C~:)O 1.500 0.000 1.500 1.500 1.500 3.000 3.000 3.000 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 4.500 Vertical Section (ft) 0.00 0.00 0.00 0.00 -0.06 -0.21 -0.25 -0.40 -0.43 -0.43 -0.43 0.69 3.74 3.88 10.27 20.38 20.80 37.34 61.44 92.97 131.73 177.47 229.93 288.76 353.61 Comment Be~in Dir @ 1.500°/100ft: 300.00ft MD, 235.50ft TVD End Dir' 666.67ft MD, 602.03ft TVD Be¢l_ in Dir @ 1.500°/100ft: 696.67ft MD, 632.03ft TVD Increase in Dir Rate @ 3.000°/100ft· 896.67ft MD, 831.93ft TVD Increase in Dir Rate @ 4.500°/100ft' 1096.67ft MD, 1030.75ft TVD Continued... 1 July, 2000 - 8:30 - 1 - DrillQuest 1.05.05 RECEIVED "" i82000 Alaska 0il & Gas Coas, Commission Anchorage North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 1918.33 43.503 270.000 1760.00 1973.12 43.503 270.000 1799.74 1973.48 43.503 270.000 1800.00 2000.00 43.503 270.000 1819.24 2028.27 43.503 270.000 1839.74 2100.00 47.791 269.477 1889.87 2200.00 53.772 268.855 1953.07 2300,00 59.755 268.321 2007.86 2400.00 65.740 267.849 2053.63 2496.41 71.512 267.435 2088.75 2500.00 71.512 267.435 2089.89 2600.00 71.512 267.435 2121.60 2700.00 71.512 267.435 2153.31 2800.00 71.512 267.435 2185.02 2900.00 71.512 267.435 2216.73 3000.00 71.512 267.435 2248.44 3100.00 71.512 267.435 2280.15 3200.00 71.512 267.435 2311.86 3300.00 71.512 267.435 2343.57 3400.00 71.512 267.435 2375.28 3500.00 71.512 267.435 2406.99 3600.00 71.512 267.435 2438.70 3700.00 71.512 267.435 2470.42 3800.00 71.512 267.435 2502.13 3900.00 71.512 267.435 2533.84 Sperry-Sun Drillings.Services Proposal Report for MPI- 10 WPs - MPI- 10 Wp5 Revised: 1 July, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (~) (~) (~) (~) (~) 1824.50 50.81 S 364.09W 6009387.72 N 551341.09 E 1864.24 50.81 S 401.81W 6009387.45 N 551303.37 E 1864.50 50.81S 402.05W 6009387.45 N 551303.13 E 1883.74 50.81 S 420.31W 6009387.33 N 551284.87 E 1904.24 50.81S 439.77W 6009387.19 N 551265.41 E 1954.37 51.05 S 491.05W 6009386.59 N 551214.14 E 2017.57 52.19 S 568.48W 6009384.91N 551136.72 E 2072.36 54.27 S 652.06W 6009382.26 N 551053.16 E 2118.13 57.25 S 740.87W 6009378.66 N 550964.37 E 2153.25 60.95 S 830.53W 6009374.34 N 550874.73 E 2154.39 61.10 S 833.93W 6009374.17 N 550871.33 E 2186.10 65.34 S 928.68W 6009369.27 N 550776.62 E 2217.81 69.59 S 1023.42W 6009364.36 N 550681.91E 2249.52 73.83 S 1118.16W 6009359.46 N 550587.20 E 2281.23 78.08 S 1212.91W 6009354.56 N 550492.48 E 2312.94 82.32S 1307.65W 6009349.66 N 550397.77 E 2344.65 86.57 S 1402.40W 6009344.76 N 550303.06 E 2376.36 90.81 S 1497.14W 6009339.86 N 550208.35 E 2408.07 95.05 S 1591.88W 6009334.96 N 550113.63 E 2439.78 99.30 S 1686.63W 6009330.05 N 550018.92 E 2471.49 103.54 S 1781.37W 6009325.15 N 549924.21E 2503.20 107.79 S 1876.12W 6009320.25 N 549829.50 E 2534.92 112.03S 1970.86W 6009315.35 N 549734.78 E 2566.63 116.28 S 2065.60W 6009310.45 N 549640.07 E 2598.34 120.52 S 2160.35W 6009305.55 N 549545.36 E Dogleg Rate (°/100fi) 4.500 o.ooo o.ooo o.ooo o.ooo 6.000 6.000 6.000 6.000 6.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 MILNEPT MPI-MP Vertical Section (ft) 366.13 403.80 404.04 422.28 441.72 492.95 570.34 653.92 742.77 832.51 835.91 930.75 1025.59 1120.43 1215.27 1310.10 1404.94 1499.78 1594.62 1689.46 1784.30 1879.14 1973.97 2068.81 2163.65 Comment End Dir: 1918.33ft MD, 1760.00ft TVD B Perm Be~_ in Dir @ 6.000°/100ft: 2028.27ft MD, 1839.74ft TVD End Dir: 2496.41ft MD, 2088.75ft TVD Continued... 1 July, 2000 - 8:30 - 2 - DrillQuest 1.05.05 RECLIVED i82000 Alaska Oil & Gas Coos. Commi~i~ Anch0r~e North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (it) (it) 4000.00 71.512 267.435 2565.55 4100.00 71.512 267.435 2597.26 4200.00 71.512 267.435 2628.97 4300.00 71.512 267.435 2660.68 4400.00 71.512 267.435 2692.39 4500.00 71.512 267.435 2724.10 4600.00 71.512 267.435 2755.81 4700.00 71.512 267.435 2787.52 4800.00 71.512 267.435 2819.23 4900.00 71.512 267.435 2850.94 5000.00 71.512 267.435 2882.65 5100.00 71.512 267.435 2914.36 5200.00 71.512 267.435 2946.07 5300.00 71.512 267.435 2977.78 5400.00 71.512 267.435 3009.49 5500.00 71.512 267.435 3041.20 5600.00 71.512 267.435 3072.91 5700.00 71.512 267.435 3104.62 5800.00 71.512 267.435 3136.33 5900.00 71.512 267.435 3168.05 6000.00 71.512 267.435 3199.76 6100.00 71.512 267.435 3231.47 6200.00 71.512 267.435 3263.18 6300.00 71.512 267.435 3294.89 6400.00 71.512 267.435 3326.60 Sperry-Sun Drilling Services Proposal Report for MPI- 10 WPs - MPI- 10 Wp5 Revised: 1 July, 2000 Vertical Local Coordinates Depth Northings Eastings Northings (it) (ft) (it) (it) 2630.05 124.77 S 2255.09 W 6009300.65 N 2661.76 129.01 S 2349.84 W 6009295.74 N 2693.47 133.26 S 2444.58 W 6009290.84 N 2725.18 137.50 S 2539.32 W 6009285.94 N 2756.89 141.75 S 2634.07 W 6009281.04 N 2788.60 145.99 S 2728.81 W 6009276.14 N 2820.31 150.24 S 2823.56 W 6009271.24 N 2852.02 154.48 S 2918.30 W 6009266.34 N 2883.73 158.72 S 3013.04 W 6009261.44 N 2915.44 162.97 S 3107.79 W 6009256.53 N · 2947.15 167.21 S 3202.53 W 6009251.63 N 2978.86 171.46 S 3297.28 W 6009246.73 N 3010.57 175.70 S 3392.02 W 6009241.83 N 3042.28 179.95 S 3486.76 W 6009236.93 N 3073.99 184.19 S 3581.51 W 6009232.03 N 3105.70 188.44 S 3676.25 W 6009227.13 N 3137.41 192.68 S 3771.00 W 6009222.22 N 3169.12 196.93 S 3865.74 W 6009217.32 N 3200.83 201.17 S 3960.48 W 6009212.42 N 3232.55 205.42 S 4055.23 W 6009207.52 N 3264.26 209.66 S 4149.97 W 6009202.62 N 3295.97 213.90 S 4244.72 W 6009197.72 N 3327.68 218.15 S 4339.46 W 6009192.82 N 3359.39 222.39 S 4434.20 W 6009187.91 N 3391.10 226.64 S 4528.95 W 6009183.01 N Global Coordinates Eastings (it) 549450.65 E 549355.93 E 549261.22 E 549166.51E 549071.80 E 548977.09 E 548882.37 E 548787.66 E 548692.95 E 548598.24 E 548503.52 E 548408.81E 548314.10 E 548219.39 E 548124.67 E 548029.96 E 547935.25 E 547840.54 E 547745.83 E 547651.11E 547556.40 E 547461.69 E 547366.98 E 547272.26 E 547177.55 E Dogleg Rate (°/100~) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 MILNEPT MPI-MP Vertical Section (it) 2258.49 2353.33 2448.17 2543.00 2637.84 2732.68 2827.52 2922.36 3017.20 3112.03 3206.87 3301.71 3396.55 3491.39 3586.23 3681.06 3775.90 3870.74 3965.58 4060.42 4155.26 4250.10 4344.93 4439.77 4534.61 Comment Continued... 1 July, 2000 - 8:30 - 3 - DrillQuest 1.05.05 RECb!VED d:" i82000 Alaska 0il l Gas Cms. Commission Anchorage North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (~) (~) 6500,00 71,512 267.435 3358.31 3422.81 6600.00 71.512 267,435 3390.02 3454.52 6700,00 71.512 267.435 3421.73 3486.23 6800,00 71.512 267.435 3453.44 3517.94 6900.00 71.512 267.435 3485.15 3549.65 7000.00 71.512 267.435 3516.86 3581.36 7100.00 71,512 267.435 3548.57 3613.07 7200.00 71.512 267.435 3580.28 3644.78 7300.00 71.512 267.435 3611.99 3676.49 7400.00 71.512 267.435 3643.70 3708.20 7500.00 71.512 267.435 3675.41 3739.91 7600.00 71.512 267.435 3707.12 3771.62 7700.00 71,512 267.435 3738.83 3803.33 7800.00 71.512 267.435 3770.54 3835.04 7869.24 71.512 267.435 3792.50 3857.00 7900.00 71.512 267.435 3802.25 3866.75 8000.00 71.512 267.435 3833.96 3898.46 8100.00 71.512 267.435 3865.67 3930.17 8160.94 71.512 267.435 3885.00 3949.50 8164.10 71.512 267.435 3886.00 3950.50 8200,00 71,512 267,435 3897,39 3961.89 8300.00 71.512 267.435 3929.10 3993.60 8310.95 71.512 267.435 3932.57 3997.07 Proposal Report for MPI- 10 WPs - MPI- 10 Wp5 Revised: 1 July, 2000 Local Coordinates Nothings Eastings (~) (~) 230.88 S 4623.69W 235.13 S 4718.44W 239.37 S 4813,18W 243.62 S 4907.92W 247.86 S 5002.67W 252.11 S 5097.41TM 256.35 S 5192.16W 260.60 S 5286.90W 264.84 S 5381,64W 269.09 S 5476.39W Global Coordinates Northings Eastings (ft) (ft) 6009178.11 N 547082.84 E 6009173.21 N 546988.13 E 6009168.31 N 546893,41 E 6009163.41 N 546798.70 E 6009158.51 N 546703.99 E 6009153.60 N 546609.28 E 6009148.70 N 546514.57 E 6009143.80 N 546419.85 E 6009138.90 N 546325.14 E 6009134.00 N 546230.43 E 273.33 S 5571.13W 6009129.10 N 546135.72 E 277.57 S 5665.88W 6009124.20 N 546041.00 E 281.82 S 5760.62W 6009119.30 N 545946.29 E 286.06S 5855.36W 6009114.39 N 545851.58 E 289.00 S 5920.97W 6009111.00 N 545786.00E 290.31 S 5950.11W 6009109.49 N 545756.87 E 294.55 S 6044.85W 6009104.59 N 545662.15 E 298.80 S 6139.60W 6009099.69 N 545567.44 E 301.38 S 6197.34W 6009096.70 N 545509.72 E 301.52 S 6200.32W 6009096.55 N 545506.74 E 303.04 S 6234.34W 6009094.79 N 545472.73 E 307.29 S 6329.08W 6009089.89 N 545378.02 E 307.75 S 6339.45W 6009089.35 N 545367.65 E Dogleg Rate (°/100.) 0.000 o.ooo o.ooo o.ooo o.ooo o. ooo o.ooo o.ooo o.ooo o.ooo o.ooo o.ooo o.ooo o.ooo o.ooo 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 MILNEPT MPI-MP Ve~ical Section (fi) 4629.45 4724.29 4819.13 4913.96 5008,80 5103.64 5198.48 5293.32 5388.16 5482.99 5577.83 5672.67 5767.51 5862.35 5928.01 5957.19 6052.02 6146.86 6204.66 6207.65 6241.70 6336.54 6346.92 Comment T-oP . arge[ - MPI-IO T1 Option2 Base OA Total Depth: 8310.95ft MD, 3932.57ft TVD Continued... 1 July, 2000 - 8:30 - 4 - DrillQuest 1.05,05 ~ FMC Gan 6MP I10iCellar Box Elevation' 35.1' PROPOSED COMPLETION Rig RKB Elevation: 29.5' 11" 5m", 2-7/8" Tbg Hgr __=. with 2-1/2" ClW H BPV ' ''" "--- l '"'- I EUE threads pin x box 20", 91#, H-40, Welded ~ ........ ........ ~ 5112" TAM Port Collar r'"-- ~ 2-7/8" 'x' nipple, ID 2.313" Note: The completion tubing will ~~~~ be used for water injection 2-718", 6.5~, L-80, EUE- ~ ~ ~ ~ Packer & Tailpipe to be set DIRECTIONAL PLAN ~ 2-7/8" 'X' nipple, 2.313" ID ( o ~.~~ ~,'- ~ 51/2" x2-7/8" Baker SABL Pkr w K-Anchor ,PROPOSED PLAN W_ 5) . _ ......... , ...... . ........ Grass Roots Conventional Injector ~ z-fl~ ~,r~ topple, z.z=) lu Max. hole angle = 72° Tangent fro ~ Tubing Tail (VVLEG) Hole angle thru perf zone = 72° ...... ' ..... Schrader' OB; SANDS ~ ~ ',~': :~-!'.~'~i HOLE ANGLE at TD: 68° DATE REV. BY COMMENTS MILNE POINT UNIT 6/13/00 FJ Proposed Completion ~JJ_l~l.0J.' ' BP EXPLORATION (AK} · DATE · CHECK NO. porto,52 I.'1 170952 ( (. p6/2,/oo 1 I VENDOR ALASKASTI. 4 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET &2c)o0 CKO&2c/OOB 100. O0 100. O0 HANDLINO INST: PH TERRI HUBBLE X46;~8 A1TACHEO CHECK IS IN PAYMENT FOR ,lulls DE~RiaF. D ABOVE. ~lellf_,llE -,-- 1OO. OO 1OO. OO FIRST ~iATIO~.BANI('.' .OF AS~tI~AND 'ii : .:. :. :?' :ANii~,k"~.! BAT Ei.O~.: NA~N~'~I~,,BANK ': :.' .':.:~ ~":': :: ,.:.:'-. ~:... ':::::. ........ .:'.::::.:.: ~':.':::'::: ~'::..:~? .:'.::..~ :::::. :' ..:;¥%:389 :.~¥'.. ::~:::..~:.:::~.: :.' 412 :0017:0~52:?!':::i: ........ .: .~:i::..::' '-:':'!i'? DATE ::i?!!'?:: ";;!i :.:'::.:':"~:!: , ALASKA STATE !;DE~T...::.'O[:.. R'E~ENUE ~..:~:::: .::.i':;:;: :.:.:':..'::::;,. :!.:::.i:::[' Nm:i~/ALIO AFTER: AOO..C"'Ci?:;i:.;' :i!;'i.,~ i!?i::~: :;~):-." :?;:::.:~.' ..: : :'?.!.: .::?.;":: 13.OO:~::.::!::.~:ORcuP IN~::.i!!i~R::'::!i:~i:i: ..:::.::ii::::... :'::::'.:.i: :!i!!:i:!i,..>i:'i!:!:':~ :~"~~:' ANCHORAGE AK 99501-3120 WELL PERMIT CHECKLIST ~FIELD & POOL COMPANY ./~"~ ADMINISTRATION A~P/~ DATE . 7, INIT CLASS ENGINEERING DATE 1. Permit fee attached ........ - ............... 2. Lease number appropdate.;F~ 3. Unique well name and'number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... WELL NAME ~-~-~,'[:O PROGRAM: exp dev redrll serv v'" we,bore seg .. ann. disposal para req. GEOL AREA ~;;~c::~(~) UNIT# ~//~2.,<~/ ON/OFF SHORE ~ , 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, do~s it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to o~O(~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown...~ ........ N N N N Y N N Y N N N N IIGEOLOGY 29. Is preSence of H2S gas probable ................. DATE '7. 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ........... . ./t///'~ Y N 33. Seabed cOndition survey (if.off-shore) ....... . .~.,,~.. '. Y N 34. Contact name/phone for weekly progress reports [exploratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N. APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UlClAnnular COMMISSION: ~ -. Comments/Instructions: jcl O ITl Z .-I -r' c:~soffiCe\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the hiStory file. To improve the readability of the Well History file and to simplify'finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. zoo- o Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Apr 11 13:00:55 2001 Reel Header Service name ............. LISTPE Date ..................... 01/04/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/04/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM HSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 1 AK-MM-00147 STEPHANE HUI EDDIE VAUGHN MPI-210 500292296600 BP Exploration (Alaska), Inc. Sperry Sun ll-APR-0i MWD RUN 2 AK-MM-00147 STEPHANE HUI JIMMY PYRON 33 13N 10E 2328 3665 .00 62.35 34.60 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 110.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 3. DIGITAL DATA AND LOG DATA ARE DEPTH CORRECTED TO THE PDC GR LOG OF 8/24/00 WITH KBE = 62.35' A.M.S.L.. ALL MWD LOG AND HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 4. MWD RUNS 1 AND 2 REPRESENT WELL MPI-210 WITH API % 50-029-22966-00. THIS WELL REACHED A TOTAL DEPTH OF 8302' MD, 4000' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY SHALLOW SPACING ) · SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY DEEP SPACING SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH GR 44.0 ROP 105.0 RPD 5016.5 RPM 5016.5 RPS 5016.5 RPX 5016.5 FET 5016.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 4O 5091 0 5099 0 5102 0 5111 5 5119 0 5134 5 5136 5 5145 0 5148 0 5159 0 5161 5 5168 0 5174 0 5176 5 5181 0 5183 5 5217 5 5226 0 5228.5 5232.0 5237 0 5238 5 5241 5 5254 0 5267 5 5270 5 5292 0 5301 0 5303 5 5306 0 5332 5 5339 5 5356 5 5365 0 5382 0 5387 0 5394 5 5396 5 5405 5 5409 5 5419 5 5433 0 5440 0 GR 54 5101 5112 5115 5123 5129 5144 5146 5155 5157 5170 5174 5180 5185 5187 5191 5193 5225 5231 5233 5237 5241 5243 5248 5261 5274 5278 5300 5306 5309 5312 5336 5346 5362 5369 5385 5392 5398 5399 5409 5415 5425 5441 5450 STOP DEPTH 8254.5 8299.0 8261.5 8261.5 8261.5 8261.5 8261.5 EQUIVALENT UNSHIFTED DEPTH -- 5443 5455 5470 5474 5492 5508 5511 5518 5537. 5548. 5554. 5559. 5568. 5571 5574 5577 5580 5582 5590 5594 5595 5596 5603 5606 5634 5637 5644 56.46 5662 5675 5685 5688. 5691. 5695. 5700 5704 5715 5719 5725 5728 5732 5735 5741 5743 5753 5756 5772 5778 5788 5791 5804 5806 5809 5810 5812 5820 5822 5829 5830 5837 5840 5 5 5 0 0 0 5 5 0 5 0 0 0 5 0 0 5 0 5 0 5 0 5 0 5 0 0 5 0 5 0 0 5 5 5 5 5 0 5 0 5 0 0 5 5 0 5 0 5 5 0 5 0 5 5 0 0 0 5 5 5 5454.0 5464.0 5477.5 5482.0 5501.0 5516.0 5519.5 5527.5 5546.5 5557.0 5563.5 5569.0 5577.5 5579.5 5582.5 5584 0 5589 0 5591 0 5597 5 5602 0 5603 5 5605 0 5615 0 5618 0 5641 0 5644 0 5647 0 5649 5 5665 0 5680 0 5689 0 5694 5 5697 5 5702 5 5709 5 5713 5 5721 5 5727 5 5734 0 5736 5 5742 0 5745 5 5749 5 5751 0 5761 5 5763 0 5781 0 5787 0 5797 5 5801 0 5814 5 5816 5 5817 5 5819 0 5821 0 5826 5 5831 5 5837 0 5839 0 5847 5 5851 0 5845.5 5848.5 5856.5 5859.5 5864.0 5879.5 5882.5 5885 0 5888 0 5892 5 5898 5 5902 0 5904 5 5912.0 5921 0 5926 0 5939 0 5942 0 5946 5 5949 5 5950 5 5953 0 5958 5 5966.0 5969.0 5971.5 5976.0 5983.5 5986.0 5989 5 6000 0 6003 5 6005 0 6011 0 6014 5 6019 0 6023 0 6032 0 6035 5 6042 5 6048 0 6050 5 6056 0 6060 0 6062 5 6066 5 6069 0 6071 0 6073 0 6077 5 6083 0 6086 5 6090 0 6100 0 6114 0 6119 5 6127 0 6138 0 6142 0 6145 0 6149 5 5855. 5856. 5864. 5867 5872 5890 5893 5894 5897 5901 5909 5913 5917 5921 5930. 5933 5951 5955 5958 5960 5961 5964 5970 5979 5981 5983 5986 5994 5995 5997 6011 6015 6017 6021 6026 6030 6032 6040 6043 6052 6057 6059 6065 6069 6072 6075 6077 6078 6080 6083 6091 6096 6098 6109 6122 6128 6138 6149 6153 6156 6161 6153. 6157. 6171. 6175 6182 6186 6202 6210 6218 6226 6229 6232 6235 6241 6254 6262 6264 6272 6277 6279 6280 6281 6284 6287 6294 6299 6303 6307 6311 6315 6319 6330 6339 6347 6349 6352 6364 6366 6369 6374 6376 6379 6380 6383 6385 6392 6398 6401 6407 6412 6413 6415 6417 6424 6427 6434 6440 6445 6450 6461 6467 5 0 0 5 0 5 0 5 5 0 0 0 0 5 0 5 5 5 0 0 5 5 0 5 5 0 5 5 0 0 0 0 5 5 0 5 5 0 5 5 5 0 5 0 0 5 0 5 5 0 5 0 5 5 5 0 5 0 5 5 0 6164.0 6166.0 6178.5 6185.5 6192.5 6197.0 6210.5 6219.5 6230.0 6237.0 6239.0 6244.0 6247.0 6252.5 6264.5 6271.0 6274.5 6280.5 6286.0 6287.5 6289.5 6292.0 6295.5 6299.0 6306.0 6309.5 6314.0 6318.0 6320.0 6324.0 6328.5 6338.5 6348.0 6352 0 6353 5 6358 0 6374 0 6375 5 6377 5 6383 0 6386 0 6388 5 6391 5 6393 5 63945 6402 0 6407 5 6410 5 6420 5 6424 5 6425 5 6427 0 6428 5 6434 0 6437 0 6444 5 6450 0 6454 5 6460 0 6470 0 6476 0 6474. 6482. 6485. 6496. 6504. 6515. 6519. 6551. 6573 6575 6577 6580 6591 6593 6596 6599 6612 6615 6621 6624 6640 6644 6646 6652 6656 6658 6661 6663 6674 6676 6681 6686 6690 6692 6694 6698 6699 6702 6705 6709 6712 6722 6727 6738 6741 6746 6749 6752 6758 6764 6772 6781 6785 6789 6795 6803 6807 6808 6810 6813 6817 0 5 5 5 5 5 0 0 5 0 5 0 0 5 5 5 5 0 0 0 0 0 5 0 0 0 0 0 0 5 5 5 5 5 0 0 5 0 0 5 0 5 0 5 0 5 0 5 5 5 5 5 5 5 0 0 0 0 5 5 0 6485. 6493. 6495. 6507. 6514. 6526. 6530 6559 6580 6583 6585 6587 6603 6604 6607 6610 6618 6621 6627 6630 6648 6651 6654 6659 6664 6666 6671 6673 6683 6686 6690 6698 6700 6703 6705 6707 6710 6711 6714 6718 6722 6729 6735 6750 6753 6755 6759 6764 6769 6775 6782 6790 6795 6799 6802 6810 6815 6817 6819 6821 6823 0 5 5 0 0 0 5 5 5 0 5 0 0 5 5 5 5 0 0 5 5 5 5 0 5 5 5 0 5 0 5 5 5 5 0 5 0 5 0 0 0 5 5 5 5 5 5 0 5 5 5 5 5 0 5 5 5 5 0 5 0 6824. 6831. 6845. 6848. 6851. 6853. 6855 6864 6871 6884 6900 6905 6909 6912 6914 6924 6930 6933 6935 6940 6943 6945 6946 6950 6952 6954 6956 6959 6967 6970 6973 6979 6982 7003 7010 7017 7023 7029 7039 7046 7050 7052 7055 7058 7063 7066 7068 7076 7079 7081 7087 ',7092 7103 7107 7111 7113 7120 7123 7129 7132 7136 5 5 0 0 5 0 5 5 0 5 5 0 5 0 5 5 0 0 0 5 0 0 0 0 5 5 0 5 5 5 0 0 5 5 5 5 5 0 5 0 5 5 0 0 5 0 0 0 0 0 0 0 5 0 0 5 5 0 0 0 5 6830.0 6839.0 6851.5 6856.0 6859.0 6861.0 6863.5 6873.0 6881.5 6893.0 6907.5 6911.0 6916.0 6918.0 6921.0 6932 5 6939 5 6942 0 6943 5 6948 0 6950 0 6952 0 6954 0 6956 5 6960 5 6965 5 6969 0 6974 0 6979 0 6981 0 6982 0 6987 0 6992 0 7014 5 7020 5 7030 5 7035 5 7040 5 7051 0 7056 5 7061 0 7063 0 7066 5 7072 5 7075 5 7077 5 7080 0 7087 5 7090 5 7093 5 7097 5 7102 0 7111 0 7115 0 7118 0 7120 0 7127 0 7130 0 7135 5 7137 5 7142 0 7145 7178 7180 7201 7206 7218 7222 7224 7230 7232 7239 7247 7256 7275 7283 7291 7295 7297 7302 7329 7332 7335 7338 7341 7351 7358 7364 7380 7386 7390 7401 7405 7410 7416 7419 7422 7430 7432 7436 7445 7448 7452 7455 7463 7469 7472 7481 7483 7488 7493 7496 7521 7524 7527 7529 7536 7566 7569 7570 7582 7586 0 0 5 0 5 5 5 5 0 5 .5 0 0 0 5 5 5 5 5 5 0 5 0 5 5 5 5 5 0 0 0 0 5 0 0 0 0 5 0 5 5 5 0 0 5 5 0 5 5 0 0 5 0 0 0 5 0 0 5 0 0 7151 7186 7188 7213 7217 7225 7232 7234 7241 7243 7248 7258 7267 7288 7296 7304 7309 7310 7314 7340 7343 7346 7348 7350 7361 7367 7375 7391 7396 7402 7411 7417 7420 7424 7430 7432 7440 7444 7447 7456 7460 7462 7463 7474 7478 7483 7491 7493 7497 7501 7504 7532 7535 7537 7539 7547 7572 7575 7576 7590 7592 0 5 5 0 0 0 0 5 5 .5 .0 .0 .0 0 5 0 0 0 0 5 5 0 5 5 0 5 0 0 5 0 5 0 5 5 0 0 5 0 0 5 0 0 5 0 5 5 0 0 0 5 0 0 5 5 5 5 5 0 0 0 5 7589 0 7598 5 7603 0 7611 0 7619 0 7623 0 7642.5 7647.0 7654.0 7658.5 7661 5 7666 5 7668 5 7676 0 7678 0 7684 5 7691 5 7696 5 7699 0 7701 0 7703 0 7713 5 7723 0 7730 0 7736 5 7742 0 7745 5 7756 5 7780 5 7792 5 7799 0 7801 5 7813 5 7816 0 7820 5 7826 0 7835 5 7852 0 7859 5 7862 5 7870 0 7874 0 7883 0 7894 5 7903 0 7907 0 7908 5 7912 0 7915 5 7918 0 7920 0 7926 0 7929 5 7932 0 7935 5 7938.0 7941.5 7945.5 7967.5 7984.0 7993.0 7594 7605 7610 7618 7623 7626 7647 7651 7660 7666 7669 7672 7675 7681 7682 7688 7691 7698 7702 7705 7710 7722 7732 7738 7743 7750 7752 7761 7782 7797 7801 7803 7815 7818 7822 7831 7840 7859 7868 7870 7877 7880 7891 7902 7909 7913 7916 7918 7921 7924 7927 7935 7938 7941 7942 7945 7949 7956 7979 7997 8003 .5 .0 .5 .5 .5 .5 .5 .5 .5 0 5 5 0 0 5 0 5 0 5 0 0 0 5 0 0 0 5 5 5 5 0 0 5 0 0 0 5 5 5 0 0 0 0 0 5 5 0 0 5 5 0 5 5 5 5 5 5 0 5 0 5 7995. 8002. 8005. 8008. 8021. 8029. 8031. 8037. 8043 8049 8050 8052 8055 8065 8071 8074. 8081. 8089. 8299. $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: 8005.5 8011.0 8014.0 8015.5 8026.0 8036.0 8038 0 8044 0 8051 5 8056 5 8059 5 8061 5 8062 5 8069.0 8077.5 8080.0 8086.0 8092.5 8302.5 BIT RUN NO MERGE TOP MERGE BASE 1 54.5 5064.0 2 5064.5 8302.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HR 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Last Name Service Unit Min Max Reading DEPT FT 44 8299 8299 ROP MWD FT/H 0.35 4407.93 Mean Nsam 4171.5 16511 170.327 16389 First Reading 44 105 8299 GR MWD API 9.69 8254.5 RPX MWD OHMM 3.61 8261.5 RPS MWD OHMM 3.73 8261.5 RPM MWD OHMM 3 . 87 8261.5 RPD MWD OHMM 3.93 8261.5 FET MWD HR 0.09 8261.5 131 77 151 76 169 26 252 77 196 03 15 97 67.7675 16422 13.6528 6491 16.3348 6491 17.9821 6491 16.9568 6491 0.774241 6491 44 5016.5 5016.5 5016.5 5016.5 5016.5 First Reading For Entire File .......... 44 Last Reading For Entire File ........... 8299 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 54.5 5000.5 ROP 115.5 5064.0 $ # LOG HEADER DATA DATE LOGGED: 18-AUG-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 0.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): ' RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN : EWR FREQUENCY (HZ : REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 5064.0 .7 75.9 TOOL NUMBER 86562 7.875 Water Based 9.00 67.0 9.5 200 6.0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 74.4 .0 .0 First Last Name Service Unit Min Max Reading DEPT FT 54.5 5064 5064 ROP MWD010 FT/H 0.35 4407.93 5064 GR MWD010 API 9.69 121.3 5000.5 Mean Nsam 2559.25 10020 165.127 9898 63.6921 9893 Reading 54.5 115.5 54.5 First Reading For Entire File .......... 54.5 Last Reading For Entire File ........... 5064 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD RPM RPS RPX FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5001 0 5026 5 5026 5 5026 5 5026 5 5026 5 5064 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 8258 0 8265 0 8265 0 8265 0 8265 0 8265 0 8302 5 20-AUG-00 Insite 4.05.2 0.41 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Memory 8302.0 69.3 72.3 TOOL NUMBER PBO1585GR4 ?BO1585GR4 7.875 Water Based 9.00 84.0 9.4 3OO 4.2 2.850 2.156 3.500 1.200 65.0 88.1 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HR 68 68 68 20 24 28 Last Name Service Unit Min Reading DEPT FT 5001 8302.5 ROP MWD020 FT/H 3.52 8302.5 GR MWD020 API 17.29 8258 RPX MWD020 OHMM 3.61 8265 RPS MWD020 OHMM 3.73 8265 RPM MWD020 OHMM 3.87 8265 RPD MWD020 OHMM 3.93 8265 FET MWD020 HR 0.09 8265 Max 8302.5 896 21 131 77 151 76 169 26 252 77 196 03 15 97 Mean 6651.75 178.354 74.0683 13.5924 16.3023 18.0622 17.0481 0.775662 Nsam 6604 6477 6515 6478 6478 6478 6478 6478 First Reading 5001 5064.5 5001 5026.5 5026.5 5026.5 5026.5 5026.5 First Reading For Entire File .......... 5001 Last Reading For Entire File ........... 8302.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ...... · ..... STSLIB.004 Physical EOF Tape Trailer Service name ......... ~...LISTPE Date ..................... 01/04/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/04/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Scientific Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
