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Home My WebLink About197-165 RECEIVED • • STATE OF ALASKA FEB 0 ALASKA OIL AND GAS CONSERVATION COMMISSION z�18 WELL COMPLETION OR RECOMPLETION REPORT AlikOetc la.Well Status: Oil❑ Gas 1:1 SPLUG❑ Other ❑ Abandoned Q . Suspended 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ • Exploratory❑ GINJ ❑ WINJ❑ WAGE] WDSPL❑ No.of Completions: _0 Service ❑ Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC ' Aband.: 12/14/2017 197-165/316-472 ' 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 9/7/1997 50-029-22804-00-00• 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2805'FSL,4175'FEL,SEC 34,T13N, R10E, UM 9/11/1997 MILNE PT UNIT H-09 • Top of Productive Interval: 9. Ref Elevations: KB: 65.8 17. Field/Pool(s): 2544'FNL,4484'FEL,SECT 2,T12N, R10E,UM GL: 36.6 BF: N/A MILNE POINT/SCHRADER BLUFF OIL' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2903'FNL,4491'FEL,SEC 2,T12N, R10E, UM 7,806'/4,229' ' ADL0025906/ADL0380109 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 556470 y- 6009956 Zone-ASP4 7,915'/4,312' N/A TPI: x- 556206 y- 6004605 Zone- ASP4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 556202 y- 6004245 Zone- ASP4 N/A 1,800'(Approx.)/1,713' 5. Directional or Inclination Survey: Yes Li (attached) No Q 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (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 MWD, LWD,GR/RES,GR/CCL,&GR/JB scow1-TH 1 5 21 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" 91.1 H-40 32 112' 32 112 24" 250 sx 7" 26 L-80 31 7,890' 31 4,293' 8-1/2" 1,577 sx 24.Open to production or injection? Yes ❑ No Q 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MDrTVD) Size and Number; Date Perfd): �D�r� 2-7/8" 6,820' 7,022' 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. l2/%"+1 1} Was hydraulic fracturing used during completion? Yes❑✓ No ❑ Per 20 AAC 25.283(i)(2)attach electronic and printed information L.— DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Surface to 6,961' 385 bbls Class G 7602'-7632' 19,050Ibs 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 2/19/1998 N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .....11. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate —► Form 10-407 Revised 5/2017CONTINUED ON PAGE 2 Submit ORIGINIAL only I'M alllll� 2., C-1 q r/ RBDM S t" FEB - 2018 only/ • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 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 9 No ❑, Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1,800'(Approx.) 1,713' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 7,360' 3,888' information, including reports,per 20 AAC 25.071. Schrader Bluff 7,327' 3,863' Schrader Bluff 7,358' 3,887' Schrader Bluff 7,399' 3,918' Schrader Bluff 7,419' 3,933' Schrader Bluff 7,480' 3,980' Schrader Bluff 7,522' 4,012' Schrader Bluff 7,524' 4,013' Schrader Bluff 7,597' 4,069' Schrader Bluff 7,649' 4,109' Schrader Bluff 7,724' 4,166' Schrader Bluff 7,787' 4,214' 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 1 a: 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 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date I End Date MP H-09 None 50-029-22804-00-00 197465 11/28/17 JI 12/14/17 Daily Operations: 11/28/2017-Tuesday MIRU excavation equipment. 11/29/2017-Wednesday Begin excavation. 11/30/2017-Thursday Completed excavation. 12/01/2017- Friday No activity to report. 12/02/2017-Saturday Remove cement from around outer annulus to new excavation point. 12/03/2017-Sunday Continue removing cement. 12/04/2017-Monday Continue removing cement. 12/05/2017-Tuesday Set trench box. 12/06/2017-Wednesday Install wach saw.Cut casing at 4' below original tundra level. Mix 3 gal permafrost cement to bring cement inside casing to surface. 12/07/2017-Thursday No activity to report. 12/08/2017- Friday No activity to report. 12/09/2017-Saturday No activity to report. 12/10/2017-Sunday Notify AOGCC inspector for inspection of cut-off depth. 12/11/2017-Monday Inspector onsite.Take photos of casing stub. 12/12/2017-Tuesday Weld marker plate on well.Take photos of marker plate. GPS location:70°26.253'N 149°32.568'W 12/13/2017-Wednesday No activity to report. 12/14/2017-Thursday Backfill location. • • s I 4q4, _.. • • 4 • '0. . � , Y ce t. ♦ '..; A 4. . « 0 .`# 'ms t a„s • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg t2k DATE: 12/11/17 P. I. Supervisor 11 FROM: Lou Laubenstein SUBJECT: Surface P&A Petroleum Inspector MPU H-09 Hilcorp Alaska LLC PTD 1971650; Sundry 316-472 12/10/17: I traveled Milne Point to meet up with Jim Jackson and Billy Kruskie (Hilcorp) for a P&A cutoff and cover plate inspection of well H-09. The wellhead had been removed and all casings were cut 4 feet below tundra. There was solid cement to surface. The cover plate was on location and it had all the required information per regulation. Everything was in order and ready for the cover plate to be welded on and the hole backfilled. Attachments: Photos (2) 2017-1210_Surface Abandon MPU H-09_11.docx Page 1 of 2 r • • Fir §k� a# • 4:1101,,,,:' ':--''^ . r I 1 f t 1 - ...../ e' .. .N. >G U • /' 0 ..,/ p Y f` b o r +.v+ 1O ♦- Or . Gr IN w ;,. .,. ... 'd O O N O r N O') ma. r c O Q N I- 1 co d c ... ci, CD _CI CI- 0 = I J • U w+ * Q C c E s 4.17,,I. ' c U x:-": . O 0 ve C O .0 Q N. 4 Q >,r- rfi O• N OF TAr • • . 1%%y � THE STATE Alaska Oil and Gas ►.� iA� ofjL1s Conservation Commission x__ _ 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASFax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations ManagerNNED f b Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB H-09 Permit to Drill Number: 197-165 Sundry Number: 316-472 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, Cathy P. oerster Chair DATED this J day of September, 2016. RBDMS L/" SEP 2 6 2016 • •• STATE OF ALASKA cECESVED SEP 1 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION `1 APPLICATION FOR SUNDRY APPROVALS G F-;,n e-C 20 AAC 25.280 1.Type of Request: Abandon 0Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ AIDOperations 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 Q 4 197-165 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22804-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes LI No D 1 MILNE PT UNIT SB H-09 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906/ADL0380109 ' 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): 7,915' 4,312' Surface Surface 0 Surface N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 4,293' 7" 4,293' 2,743' 7,240psi 5,410psi 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 6820 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES Model 3L RBP,X HES Versatrieve,HES Isolation and HES BWD Sump 7,022MD/3,636TVD,7,203MD/3,770TVD,7,388MD I 3,910TVD and Packers and N/A 7,563MD/4,043TVD and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic El13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/30/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 4 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 STP Email sporhola@hilcorp.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. .... / 3\L L— 72 Plug Integrity el BOP Test ❑ Mechanical Integrity Test ❑ LocationtiioClearance % 0 Other: - Dila4a eic (-4-4- �-e w L 2`.�';hi c_01-60(j t' -1e ji...P / (4.. Post Initial Injection MIT Req'd? Yes ❑ No ❑ 1..kS - Q 1-2..t I k!O Spacing Exception Required? Yes ❑ No 2( Subsequent Form Required: /0"4107 RBDMS I,/ SEP 2 6 2016 / APPROVED BY Approved by. COMMISSIONER THE COMMISSION Date: 9.z//a 40,e ORIGINAL , .z0_i‘„,. Submit Form and Form 10-405sl eevjced J1/70/14 J`, Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 11 • • Well Prognosis Well: MPU H-09 Flilcuru Alaska,LL{ Date:9/08/2016 Well Name: MPU H-09 API Number: 50-029-22804-00 Current Status: Suspended Pad: H-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: 197-165 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: Job Type: StirfacQP8uk 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 H-09 was plugged back to surface in January 2014. However, the well abandonment marker was installed 2' below the surface of the gravel pad. Therefore, the well has remained in a suspended status since 2014. Notes Regarding Wellbore Condition • Plugged back to surface in 2014. • Well capped at 2' 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 wellhea an casing 3' below natural GL. 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. r, l 5. Photograph casing stub after setting marker plate. 6. Backfill cellar, close out location. Attachments: 1. As-built Schematic S Tree: FMC 2 Wellhe d: 11"x 6" 5M 2 9 16" 5M FMC •�'PU —0`' Orig.Orig. L (N 22E) GL Elev. = 36.6' Gen 6 2-7/8"eue 8 rd. btm. &top, RT To Tbg. Spool = 30.85 (N 22E) 2.5" CIW BPV profile. TBG &IA Cemented to 20" 91.1 ppf, H-40 112' Surface 1/29/2014 KOP @ 500'to 4500' Max. hole angle = 74 to 77 deg. Howco 7""ES"Cementer 2095 f/2900'to 6100' Hole angle thru'perfs= 40 deg. Casing integrity issue between 200-320'. USIT shows anomaly in casing @ 880'. 7"26 ppf, L-80, BTC mod production csg. (drift ID =6.276", cap. =0.0383 bpf) t 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID= 2.347", cap. =0.00592 bpf) o ' RBP Retrieving Head 6820' HES Model 3L RBP Packer 7022' w'200s 100 mesh sand on top Marker Joint ( 7,156'-7,197') Stimulation Summary OB'Sand-01/29/98- 19.1 M#of PropLok coated 16/20 Carbolite behind r: x" HES Versatrieve pkr. 7,203' pipe. ' 7 — Closing sleeve ass'bly 7,211' 'N'Sand -02/02/98-52.6 M#of 16/20 i — 127', 11 ppf, N-80, NU I — � Carbolite behind pipe. blank pipe (ID = 3.476") — 30, 0.012" Ga.pre-pack 7,358' 'OA'Sand -02/03/98 2nd stage tool had i screen (ID =3.476") to be fished. No Prop was pumped. the HES Iso. Pkr. assemble screen is pre-packed. (ID = 3.476") 7,388' _._. 109' , 11 ppf, N-80, NU Proposed — blank pipe (ID = 3.476") Perforation Summary — Ref Ioq: GR/CCL 01/28/98 7 304 SS ELPPP, 0.012" 7,523' Ga. screen (ID = 3.475") Size SPF Interval (TVD) �— t HES 'BW D' sump pkr. 7,563' "N"Sand 4.5" 4 7360'- 7380' (3888'-3906') "OA"Sand 4.5" 4 7524'-7554' (4013'-4036') p; "OB"Sand 4.5" 5 7602'-7632' (4073'-4096') 1 4.5" Big Hole charges @ 60 deg. phasing 7" landing collar(PBTD) 7,806' and 7"float collar(PBTD) 7,848'and 7"float shoe 7,890' and DATE REV.BY COMMENTS MILNE POINT UNIT 09-27-97 BDB 7" Cased Hole Completion 22E WELL No: H-09 API : 50-029-22804 02/10/98 MDO Gravel pack& completion 4 es 08/24/98 MDO ESP Completion 4 es 11/14/98 MDO Replace heat trace 4 es HILCORP ALASKA LLC Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. / ~/'/'--/~" File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items- Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [] Logs of vadous kinds [] Other COMMENTS: [3 Scanned by~ildred- Daretha TO RE-SCAN Notes: Nathan Lowell Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 December 30, 2011 SLANNED FEB r 7 201 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ` j 333 West 7 Avenue V I Anchorage, Alaska 99501 �n P H Subject: Corrosion Inhibitor Treatments of MPH -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -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 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPH -01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH -02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220830000 Sealed Conductor NA NA NA NA NA MPH-04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA MPH -05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH-06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH -08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 -'--->• MPH -09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 MPH-15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH -18 2041740 50029232240000 18.6 NA Need top job MPH -19 2071360 50029233710000 0.1 NA 0.1 NA 2.6 9/4/2011 ' STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION) REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other isi REPORT OF Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ INSPECTION 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 El Exploratory ❑ " 197 -1650 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22804 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 380109 . MPH -09 10. Field /Pool(s): MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 7915 feet Plugs (measured) 7022 feet true vertical 4312.35 feet Junk (measured) None feet Effective Depth measured 7806 feet Packer (measured) 7203 7388 7563 feet true vertical 4228.93 feet (true vertical) 3770 3910 4043 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.1# H -40 32 - 112 32 - 112 Production 7859' 7" 26# L -80 31 - 7890 31 - 4293 7240 5410 Intermediate Production Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ - _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 29 - 6820 29 - 3500 2 -7/8" 6.5# L -80 7203 - 7563 3770 - 4043 Packers and SSSV (type, measured and true vertical depth) HES Versatrieve Packer 7203 3770 HES Iso. Packer 7388 3910 HES BWD Sump Packer 7563 4043 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: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: s Copies of Logs and Surveys Run Exploratory Development II Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ `SUSP❑r SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam oe Last a I Title Petrotechnical Data Technologist \ Signatu k ` 0., ._,---) Phone 564-4091 Date 10/10/2011 Form 10 -404 Revised 10/201u Submit OCT 7 2011 fD • ie Submit Original Only MPH-09 197 -165 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPH -09 1/27/98 PER 7,602. 7,612. 4,072.65 4,080.28 MPH -09 1/27/98 PER 7,612. 7,632. 4,080.28 4,095.55 MPH -09 1/28/98 PER 7,360. 7,380. 3,888.38 3,903.55 MPH -09 1/28/98 PER 7,524. 7,554. 4,013.14 4,036.02 MPH -09 5/30/06 BPS 7,022. 7,360. 3,635.68 3,888.38 MPH -09 5/31/06 SPS 7,015. 7,022. 3,630.62 3,635.68 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 I • • • MPH -09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/17/2011 =T /I /O= 0 /0 /NA . Temp =SI RG -2401 (Surface casing corr. mitigation) PJSM. Strapped conductor @ 22 ". Install spill containment. Pumped 17 gal RG -2401 to fill conductor. t RDMO. MANDREL HANGER W /FLUTE. ... .. . . _ _... .. . . .. . ... 9/17/2011 Perform State witnessed AOGCC Suspended Well Inspection (John Crisp) I / / 1 � e FLUIDS PUMPED GALS 17 RG -2401 17 TOTAL • Milne Point Well H -09 PTD 1971650 Suspended Well Inspection Report BP Exploration Alaska (BPXA) completed a suspended well inspection of MPH -09 on 9/17/11. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC Inspector John Crisp witnessed the inspection. • Wellbore Diagram illustrating the current configuration of the well. • Pad map showing the well location and other wells within 'A mile radius of the surface location. • Photographs showing the condition of the wellhead and surrounding location. Supplemental Information: • MPH -09 was considered "Operations Shutdown" in 2006 after a rig workover attempt. A recent Application for Sundry Approvals to consider the well as ✓ 311 "Suspended" was submitted on 8/30/11 and approved on 9/08/11. A Well completion or Recompletion Report was submitted on 9/22/11. The date of suspension is considered to be 5/29/06. • MPH -09 is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The perforations are isolated with a bridge plug at 7022' MD, covered with100 mesh sand. • A leak in the production casing was confirmed at about 300'. The well is mechanically sound below 357' as proven by a pressure test of the casing and bridge plug to 1500 #. MLB 9/29/2011 • • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: MPH -09 Field /Pool: Prudhoe Bay /MPU Permit # (PTD): 1971650 API Number: 500292280400 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: Sept,8,2011 Surface Location: Section: 34 Twsp: 13N Range: 10E Nearest active pad or road: MPU H -Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good clean level gravel pad with no standing water Pad or location surface: Clean gravel Location cleanup needed: None Pits condition: No Pits/Water Surrounding area condition: Good Water /fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: No Access road condition: Good gravel road Photographs taken (# and description): 1 Front of well with well identification sign, 1 back of well Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: FMC wellhead and annular valves, Cameron tree and valves. All in good condition and funtion Cellar description, condition, fluids: 2' deep corrugated well cellar, clean gravel, no fluids Rat Hole: No Wellhouse or protective barriers: Yes Well identification sign: Yes Tubing Pressure (or casing if no tubing): 0 psi Annulus pressures: 0 psi Wellhead Photos taken (# and description): 1 close up of wellhead and cellar, 1 close up of tree Work Required: None n p Operator Rep (name and signature): Mehreen Vazir AOGCC Inspector: John Crisp • Other Observers: Jon Arend Inspection Date: 9/17/2011 AOGCC Notice Date: 9/13/2011 Time of arrival: 12:00 PM Time of Departure: 12:25 PM Site access method: Truck • • Tree: FMC 2 9/16" 5M M P U H-09 Orig. KB Elev. = 66.4' (N 22E) Wellhead: 11 "x 2 9/16" 5M FMC Orig. GL Elev. = 36.5 Gen 6 2 -7/8" eue 8 rd. btm. & top, RT To Tbg. Spool = 30.85 (N 22E) 2.5" CIW BPV profile. 20" 91.1 ppf, H-40 112' KOP @ 500' to 4500' 0 Homo 7" "ES" Cementer 2095 Max. hole angle = 74 to 77 deg. f/ 2900' to 6100' Hole angle thru' perfs = 40 deg. Casing integrity issue between 200 - 320'. USIT shows anomaly in casing @ 880'. 7' 26 ppf, L -80, BTC mod production csg. ( drift ID = 6.276 ", cap. = 0.0383 bpf ) 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) RBP Retrieving Head 1 6820' • HES Model 3L RBP Packer I 7022' w /2oo#100 mesh sand ontop ' / V Marker Joint ( 7,156' - 7,197' ) Stimulation Summary X 'OB' Sand - 01/29/98 - 19.1 M# of PropLok coated 16/20 Carbolite behind ► x" HES Versatrieve pkr. 7,203' pipe. PA Closing sleeve ass'bly 7,211' 'N' Sand - 02/02/98 - 52.6 M# of 16/20 — r, 127 , 11 ppf, N -80, NU F. Carbolite behind pipe. _ 1 blank pipe (ID = 3.476 ") 30', 0.012" Ga. pre - pack 7,358' 'OA' Sand - 02/03/98 2nd stage tool had / 0 screen (ID = 3.476 " ) to be fished. No Prop was pumped. the HES Iso. Pkr. assemble screen is pre - packed. (ID = 3.476 ") 7,388' — Proposed _ / 10 , , , NU p /, bl ank pipe 11 ppf (ID N - 80 3.476 ") Perforation Summary _ Ref log: GR/CCL 01/28/98 _ ', 304 SS ELPPP, 0.012" 7,523' Ga. screen (ID = 3.475 ") Size SPF Interval TVD) '� HES 'BWD' sump pkr. 7,563' "N" Sand 4.5" 4 7360' - 7380' (3888' - 3906') "OA" Sand 4.5" 4 7524' - 7554' (4013' - 4036') "OB" Sand 4.5" 5 7602' - 7632' (4073' - 4096') 4.5" Big Hole charges @ 60 deg. phasing 7" landing collar (PBTD) 7,806' and ' L 7" float collar (PBTD) 7,848' and 7" float shoe 7,890' and DATE REV. BY COMMENTS MILNE POINT UNIT 09 -27 -97 BDB 7" Cased Hole Completion 22E WELL No : H - API : 50 - 029 - 22804 02/10/98 MDO Gravel pack & completion 4 es 08/24/98 MDO ESP Completion 4 es 11/14/98 MDO Replace heat trace 4 es BP EXPLORATION (AK) • 0 V Enter /Exit \ \ e T.. ■ -, ‘,, , s ill 330' ► r c o N - 41 I 370' i .1 / 18 I I I 1---"F____. 1� O 1 6 -� 15 13 �III — � 5 b o r 12III I I3 I d' U 11 ' • 6 10 i._ 2 .III II iI► 9— I 1 E d ri 1 I , 1 i 0 ,__ / ___, a ._ / I /,-— // oao • • / O CEO, v%'1 P // E► — xit 4■17f 1 / . WELL PRODUCER • or 0 WELL INJECTOR A DATE : 12/2/2010 SCALE : 1" = 100' MAP DATE : 2010 MPU - H PAD WELL SLOT W /CONDUCTOR I bs14495.mxd .110 + mo: ,f� _ ; e t _ • �'' \ i 1 r ir , ' , X ' ** ,c c ' • • ,., 1 ', I - • fil ‘.. '' ttt t .11/36. — — J.. �a M ! r fc 3 " AS r t . • "" J •, t ' +S F • i 4 • J ` . • ' ..._ \ . _ ..... . 1. . \ilk . . : . , .., . , • ,... •, • ';' • ',... 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I"). ,, r m} __ _ .'aIt ..r IA r '. 1. *. ••1' ii. >�y i fr • t • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/17/11 Inspector: John Crisp Operator: BPX Well Name: MPU H -09 Oper. Rep: John Arend PTD No.: 1971650 • Oper. Phone: 659 -5766 Location Verified? Yes Oper. Email: areniCrD.bp.com If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 05/29/06 - Date AOGCC Notified: 09/14/11 Sundry No.: 10 -404; 6/7/06 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 0 Photos Taken? Yes IA 0 OA N/A Monobore Condition of Wellhead: Wellhead in good shape.SSV & hydraulic wing valve shut to tubing. Monobore with open ended kill string that has tubing & IA in - communication. 0 pressure on IA gauge. Condition of Surrounding Surface MPU H Pad. MPU Production Pad found as normal. Location: Follow Up Actions Needed: Attachments: 4 photos REVIEWED BY.... Insp. Supry . t 5k..— t0 I 7 ( 1 1 Comm PLB 08/2010 2011- 0917_Suspend_MPU_H- 09 jc.xls • • Suspended Well Inspection — MPU H -09 PTD 1971650 Photos by AOGCC Inspector J. Crisp 9/17/2011 4 _ ._... . P 744 T'. . . ; WELL NAME MPH•09 • I OWNER Mtn. Po t Ura! OFL ATC+R BP tLLPP,F , ... SUR LOCATION NW t d >.a 34 TUN P1« ' OBLONG PERMIT 87155 - -xi. ... . I lir ' - T 1 if , 4 . 4.0 .11101 n MPU H -09 Suspended Well Inspection 9 -17 -11 jc 1 N 1 � � x4 + r 4 # t iI ' '''''''''''''''''''V' „,'„*.-'''''''.'.'':' CDI CD ] '. i } ♦ 4 r� F t to .. F Y F : ' . 4 Ii ■ i„ %. y,l ,. " �, - . x .. t 4� . o : r: 3M' a *e U r F' 47` y ! s 1 . cu lit x ti y� QY ., Yh `.M �' 'rP '`.' ' d h - Y �# , 0. w t cu ,: IF, „iii0 0111\ •■ • yid ♦ X Kam♦ 4 k� ♦t Y • amp .�` * °�' .. °� V • k , . f r +, o.'tk' .. ' 0 , Y iY�Y � �r ,.i 1 w #: (x. .. o f ♦ f 9 , �:,y �7 # .� 4.� .ATM " �� « `, 0. P Y \ k. < *, f. • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISPN WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 5/29/2006 197 -165 311 -269 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 09/07/1997 50- 029 - 22804 -00 -00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 09/11/1997 MPH -09 2805' FSL, 4175' FEL, SEC. 34, T13N, R10E, UM 8. KB (ft above MSL): 65.8' 15. Field / Pool(s): Top of Productive Horizon: 2543' FNL, 4484' FEL, SEC. 02, T12N, R10E, UM GL (ft above MSL): 36.9' Milne Point Unit / Schrader Bluff Total Depth: 9. Plug Back Depth (MD +TVD): 2903' FNL, 4491' FEL, SEC. 02, T12N, R10E, UM 7806' 4229' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 556470 y - 6009956 Zone- ASP4 7915' 4312' ADL 025906 & 380109 TPI: x- 556206 y- 6004605 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 556202 y 6004245 Zone- ASP4 None 18. Directional Survey: ❑ Yes No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: MWD, LWD, GR / RES, GR / CCL, GR / JB N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE ToP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.1# H 32' . 112' 32' 112' 24" 250 sx Arcticset I (Approx.) 7" 26# L -80 31' 7890' 31' 4293' 8-1/2" 1357 sx PF 'E'. 120 sx 'G'. 100 sx PF 'C' 24. Open to production or injection? =i Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MO / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 - 1/2" Gun Diameter, 4 spf 2 -7/8 ", 6.5#, L -80 6820' None MD TVD MD TVD (Kill String) 7360' - 7380' 3888' - 3904' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7524' - 7554' 4013' - 4036' 7602' - 7632' 4073' - 4096' DEPTH INTERVAL (MD)J AMOUNT AND KIND OF MATERIAL USED 7022' Set Retrievable Bridge Plug w/ 200# 100 mesh 1 sand on top 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A 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 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes 0 No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, ph ographs and laboratory analytical results per 20 AAC 250.071. ECEIVED None SEP 2 2 2O1 RBrMS SEP 2 B 101 Alaska Oil Gas cone Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit Original Only 7.244 , e064, 29. GEOLOGIC MARKERS (List all formations and marks* countered): 30. 4110IATION TESTS NAME MD TVD Well Tested? ❑ Yes ■ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Schrader Bluff NA 7327' 3863' None Schrader Bluff NB 7358' 3887' Schrader Bluff NC 7399' 3918' Schrader Bluff NE 7419' 3933' Schrader Bluff NF 7480' 3980' Schrader Bluff D 7522' 4012' Schrader Bluff OA 7524' 4013' Schrader Bluff OBa 7597' 4069' Schrader Bluff OBb 7649' 4109' Schrader Bluff OBc 7724' 4166' Schrader Bluff OBd 7787' 4214' Formation at Total Depth (Name): Schrader Bluff OBd 7787' 4214' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. Si ned: Ran Daniel � vsnikAidrfee. Title: Engineering Team Leader Date t ) 9 Y I MPH-09 197 -165 311 -269 Prepared By Name/Number. Terre Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Mike Bill, 564 -4692 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50 -029- 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • . Milne Point Unit 11-09, PTD 1971650 Application for Suspend Well Status Technical Justification Well Status Milne Point Unit well 11-09 was completed in February 2008. The strata through which the well was drilled is neither abnormally geo- pressured or depleted. During a 2006 rig workover to change out the ESP, a leak in the 7" production casing was discovered at about 300 ft. A retrievable bridge plug was set at 7022' MD with 100 mesh sand on top to isolate the perforations. An open ended 2 -7/8" kill string was also run to 6820 ft MD. The well casing below 357' and RBP were pressure tested to 1500 psi before running the kill string. AOGCC was notified, the rig moved off and a Sundry Report was submitted on 06/07/06 for "Operations Shutdown ". Condition of the Wellhead and Surface Location MPH -09 is located on an active, well maintained gravel pad. Recent well pressure readings showed 0 on both the tubing d inntnnulus. Request We plan to plug and abandon well MPH -09 before 12/31/13. We request the well status be changed from to "Development, Oil Well, Single Completion" to "Suspended" status until the well is plugged and abandoned. A suspended well site inspection will be completed within 12 months of approval. A variance to the provisions of 20 AAC 25.110(c)(2) is also requested under 20 AAC 25.112(i) to allow the well to remain as suspended in its current condition. All hydrocarbon perforations are isolated below the RBP and there are no underground sources of fresh water in this area. 1)At ,51 ). 1 MLB 08/29/11 Tree: FMC 2 9/16" 5M M P U H-09 Orig. KB El. 66.4' (N 22E) Wellhead: 11 "x 2 9/16" 5M FM Orig. GL El 36.6 Gen 6 2 -7/8" eue 8 rd. btm. & top, RT To Tbg. Spool = 30.85 (N 22E) 2.5" CIW BPV profile. 20" 91.1 ppf, H-40 112' KOP @ 500' to 4500' Max. hole angle = 74 to 77 deg. 0 Howco 7" "ES" Cementer 2095 f/ 2900' to 6100' Hole angle thru' perfs = 40 deg. Casing integrity issue between 200 - 320'. USIT shows anomaly in casing @ 880'. 7" 26 ppf, L -80, BTC mod production csg. ( drift ID = 6.276 ", cap. = 0.0383 bpf ) 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg. ( drift ID = 2.347 ", cap. = 0.00592 bpf ) RBP Retrieving Head 1 6820' "trrsa HES Model 3L RBP Packer 7022' 200# 100 mesh sand on top Marker Joint ( 7,156' - 7,197' ) Stimulation Summary 'OB' Sand - 01/29/98 - 19.1 M# of PropLok coated 16/20 Carbolite behind ►— — x" HES Versatrieve pkr. 7,203' pipe. 7 7 Closing sleeve ass'bly 7 211' 'N' Sand - 02/02/98 - 52.6 M# of 16/20 127 , 11 ppf, N -80, NU Carbolite behind pipe. I pipe (ID = 3.476 ") 30', 0.012" Ga. pre - pack , • 'OA' Sand - 02/03/98 2nd stage tool had I screen (ID = 3.476 ") 7.358 to be fished. No Prop was pumped. the — HES Iso. Pkr. assemble screen is pre - packed. (ID = 3.476 ") 7,388' 109' , 11 ppf, N -80, NU Proposed 5 A blank pipe (ID = 3.476 ") Perforation Summary Ref log: GR/CCL 01/28/98 , 304 SS ELPPP, 0.012" 7,523' j # Ga. screen (ID = 3.475 ") Size SPF Interval TVD) ► • HES 'BWD' sump pkr. 7,563' "N" Sand 4.5" 4 7360' - 7380' (3888' - 3906') "OA" Sand 4.5" 4 7524' - 7554' (4013' - 4036') ;; "OB" Sand 4.5" 5 7602' - 7632' (4073' - 4096') 1 4.5" Big Hole charges @ 60 deg. phasing 7" landing collar (PBTD) 7,806' and k 7" float collar (PBTD) 7,848' and 7" float shoe 7,890' and DATE REV. BY COMMENTS MILNE POINT UNIT 09 -27 -97 BDB 7" Cased Hole Completion 22E WELL No : H - API : 50 - 029 - 22804 02/10/98 MDO Gravel pack & completion 4 es 08/24/98 MDO ESP Completion 4 es 11/14/98 MDO Replace heat trace 4 es BP EXPLORATION (AK) e • • S lurE [ ag\sEA 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 Ryan Daniel 1 (P 5' Engineering Team Leader I ` f t7 — BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPH -09 Sundry Number: 311 -269 Dear Mr. Daniel: `.? N E SEA'g u 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. Sinc - el i o ".# 1..1n om ' iss' . ner DATED this 'day of September, 2011. Encl. STATE OF ALASKA i1 ALASKA AND GAS CONSERVATION COMMISS -�CEIV APPLIC ION FOR SUNDRY APPRO L AUG 31 201 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change riiP COM. COMOSS on -■ Suspend - ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ; ncivIr g ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. _4 Development ❑ Exploratory 197 -165' 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50- 029 - 22804 -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: MPH -09 Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 380109 - Milne Point Unit / Schrader Bluff - 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): 7915' - 4312' - 7806' 4229' 7022' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface Intermediate Production 7859' 7" 7890' 4293' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7360' - 7632' 3888' - 4096' 2 - 7/8 ", 6.5# L - 80, Kill String 6820' Packers and SSSV Type: 7" Gravel Pack Screen Assembly with three packers Packers and SSSV 7203 / 3770' MD (ft) and TVD (ft): 7388' / 3910' . 7563' / 4043' 12. Attachments: 13. Well Class after proposed work: 0 Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory - 0 Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG - 0 Suspended 17. I hereby certify that the foregoing is tru nd • • rr- « o the best of my knowledge. Contact Mike Bill, 564 -4692 Printed Name Ryan Daniel Title Engineering Team Leader '��yy Prepared By Name/Number. Signature Phone 564 Date 9))) 9 4j 7, % � Terrie Hubble, 564 -4628 g Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I I _ C..�' I Sundry Number: -,3061 ❑ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance '— : r H S pc ,...4; a . cell .<.Lre..Q c.� C n c,«.. 3 r. o +1-4 S Other: 0 Subsequent Form Required: / D ` a / el APPROVED BY 9 $r�l Approved By: ( COMMISSIONER THE COMMISSION Date Form 10 -4�3•{;RY ys �. i rt9 0 8 20, ��, ` .Zvi 0 1 61 N A L / Submit In Duplicate 1t�11133(LJJ}�� • • Milne Point Unit H -09, PTD 1971650 Application for Suspend Well Status Technical Justification Well Status Milne Point Unit well H -09 was completed in February 2008. The strata through which the well was drilled is neither abnormally geo- pressured or depleted. During a 2006 rig workover to change out the ESP, a leak in the 7" p roduction c asing was discovered at about 300 ft. A retrievable bridge plug was set at 7022' MD with 100 mesh sand on top to isolate the perforations. An open ended 2 -7/8" kill string was also run to 6820 ft MD. The well casing below 357' and RBP were pressure tested to 1500 psi before running the kill string. AOGCC was notified, the rig moved off and a Sundry Report was submitted on 06/07/06 for "Operations Shutdown ". i Condition of the Wellhead and Surface Location MPH -09 is located on an active, well maintained gravel pad. Recent well pressure readings showed 0 psi on both the tubing and inner annulus. Request We plan to plug and abandon well MPH -09 before 12/31/13. We request the well status be changed from to "Development, Oil Well, Single Completion" to "Suspended" status uit-- until the well is plugged and abandoned. A suspended well site inspection will be completed within 12 months of approval. A variance to the provisions of 20 AAC 25.110(c)(2) is also requested under 20 AAC 25.112(i) to allow the well to remain as suspended in its current condition. All hydrocarbon perforations are isolated below the RBP and there are no underground sources of fresh water in this area. MLB 08/29/11 Tree: FMC 2 9/16" 5M M P U H 09 Ori KB = 66.4' (N 22E) Wellhead: 11"x 2 9/16" 5M FMC Orig. GL Elev. = 36.6 Gen 6 2 -7/8" eue 8 rd. btm. & top, RT To Tbg. Spool = 30.85 (N 22E) 2.5" CIW BPV profile. 20" 91.1 ppf, H -40 112' L`�` h "" -7 cso % 360 KOP @ 500' to 4500' p Howco 7" "ES" Cementer 2095 Max. hole angle = 74 to 77 deg. f/ 2900' to 6100' Hole angle thru' perfs = 40 deg. Casing integrity issue between 200 - 320'. USIT shows anomaly in casing @ 880'. 7" 26 ppf, L -80, BTC mod production csg. ( drift ID = 6.276 ", cap. = 0.0383 bpf ) 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg. ( drift ID = 2.347 ", cap. = 0.00592 bpf) 4,4 RBP Retrieving Head 6820' HES Model 3L RBP Packer 1 7022' w/ 200# 100 mesh sand on top Marker Joint ( 7,156' - 7,197' ) Stimulation Summary X 'OB' Sand - 01/29/98 - 19.1 M# of PropLok coated 16/20 Carbolite behind x" HES Versatrieve pkr. 7,203' pipe. 7 Closing sleeve ass'bly 7,211' 'N' Sand 02/02/98 52.6 M# of 16/20 — r. 127' , 11 ppf, N -80, NU Carbolite behind pipe. — I blank pipe (ID = 3.476 ") _ 30', 0.012" Ga. pre -pack , 'OA' Sand - 02/03/98 2nd stage tool had t screen (ID = 3.476 " ) 7,358 to be fished. No Prop was pumped. the HES Iso. Pkr. assemble screen is pre - packed. (ID = 3.476 ") 7,388' — 109' , 11 ppf, N -80, NU Proposed — c . blank pipe (ID = 3.476 ") Perforation Summary I Ref log: GR /CCL 01/28/98 _ 304 SS ELPPP, 0.03.475 12" 7,523' / Ga. screen (ID = ") Size SPF Interval TVD) � - HES 'BWD' sump pkr. 7,563' "N" Sand 4.5" 4 7360' - 7380' (3888' - 3906') "OA" Sand 4.5" 4 7524' - 7554' (4013' - 4036') "OB" Sand ` iy 4.5" 5 7602' - 7632' (4073' - 4096') 4.5" Big Hole charges @ 60 deg. phasing 7" landing collar (PBTD) 7,806' and • 7" float collar (PBTD) 7,848' and 7" float shoe 7,890' and DATE REV. BY COMMENTS MILNE POINT UNIT 09 -27 -97 BDB 7" Cased Hole Completion 22E WELL No : H - API : 50 029 - 22804 02/10/98 MDO Gravel pack & completion 4 es 08/24/98 MDO ESP Completion 4 es 11/14/98 MDO Replace heat trace 4 es BP EXPLORATION (AK) • • Note to File MPU H -09 (PTD 197 -165) t September 2, 2011 , V_ /6 S Discussion: Status of MPU H -09 to Suspended. H -09 was operationally shut down in 2006 due to a casing leak discovery at 300' md. during an RWO operation. The well was secured with an RBP above the gravel pack screens at a depth of 7022'md. A 200# sand plug was placed on top of the RBP for ease of retrieval. The operator BP requests that the well be considered "suspended" until a P & A can be performed in 2013. I recommend approval of the "suspend " status. Further P & A work should include the removal of the RBP and cementing the lower perforations properly followed by normal intermediate and surface plugs per regulations. Guy Schwartz Senior Petroleum Engineer AOGCC 907- 793 -1226 i:4) 'SEP RECEiVED 5 4/\(d ,Ci.. Schlumberger JUN 2 3 Z006 Alaska Data & Consulting Services . 2525 Gambell Street, Suite 400 .:...~ crt!: Gas Ccns. CcmmlSSiCn Anchorage, AK 99503-2838 .A,nchcrage ATTN: Beth _; rf\ .It tr~¿':3>IØ ·~·C· . bfJ4V' ~ ..- Well Job # Log Description Date 07-18 9153238 LDL 01/31/03 C-04A 10649975 SBHP SURVEY 06/26/03 N-11 C 10980595 PRODUCTION PROFILE 08/09/05 MPF-89 11084328 SCMT 11/24/05 D-10 10913021 MUL TI-FINGER CALIPER 06/02/05 NGI-09 11212860 US IT OS/23/06 MPH-09 11211412 US IT OS/28/06 MPH-15 11076486 CH EDIT PDC-GR OF USIT 12/15/05 MPS-90 11162721 CH EDIT PDC-GR OF USIT 11/27/05 AGI-07 A 11212865 CH EDIT PDC-GR OF USIT OS/28/06 15-20C 11075906 MCNL 08/12/05 18-30 11209593 MCNL 03/25/06 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 c~ \é}- 06/20/06 NO. 3854 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 CD Color 1 1 1 1 Prints sent earlier Prints sent earlier 1 ~ Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 A TIN: Beth .. STATE OF ALASKA _ RECEIVED ALASKA~L AND GAS CONSERVATION C~ISSION REPORT OF SUNDRY WELL OPERATIONS .JUN 082006 Alaska Oil & Gas Cons. Commission nc Drage 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Repair Well o Pull Tubing 18 Operation Shutdown o Other o Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 380109 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 7859' Perforation Depth MD (ft): Perforation Depth TVD (ft): 65.8' 7915 ' 4312 . 7806 4229 80' 7360' - 7632' 3888' - 4096' o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension 4. Well Class Before Work: ~ 18 Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 197-165 . 6. API Number: 50-029-22804-00-00 9. Well Name and Number: MPH-09 10. Field ¡Pool(s): Milne Point Unit ¡ Schrader Bluff feet feet Plugs (measured) -7020 feet Junk (measured) -300' feet Size MD TVD Burst Collapse 20" 112' 112' 1490 470 7" 7890' 4293' 7240 5410 2-7/8", 6.5# L-80, Kill String 6820' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" Gravel Pack Screen Assembly with three packers at 12. Stimulation or cement squeeze summary: Intervals treated (measured): 7203'; 7388'; 7563' Treatment description including volumes used and final pressure: RBDMS BFL JUN 15 2006 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Representative Dail Gas-Mcf Water-Bbl Tubin Pressure correct to the 15. Well Class after proposed work: o Exploratory 18 Development 0 Service 16. Well Status after proposed work: 18 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowle ge. Sundry Number or N/A if C.O. Exempt N/A o Copies of Logs and Surveys run 18 Daily Report of Well Operations 18 Well Schematic Diagram Title Technical Assistant Phone ex, 101"71 Prepared By Name/Number: Date II . // ð(pTerrie Hubble. 564-4628 c" Submit Original Only. þ-~\\,-\,O ~6;6;~ 564-4628 e e MPH-09, Rig Workover, Operations Shutdown Milne Point Unit 50-029-22804-00-00 197-165 Accept: Spud: Release: Ri; OS/22/06 N/A OS/29/06 Nabors 3S PRE-RIG WORK 04116/06 MIRU, MAKE UP BHA #1 - 1.75 DOWN JET NOZZLE. NO SOLID TAG APPARENT. WASH DOWN TO TOP OF PUMP AT 7088' CTM USING 1% XS KCL AND DIESEL SWEEPS. ESP APPEARED TO BE SPINNING BUT ". WAS NOT DRAWING AMPS. SPOTTED 5 BBLS OF 7.5% HCL ON TOP OF PUMP. ALLOW TO SOAK 30 MINUTES. UNABLE TO PUSH FLUID THROUGH THE PUMP. ATTEMPTED TO RUN PUMP AGAIN WITH THE SAME RESULTS. DISPLACE THE ACID USING 1 % KCL AND METHANOL FROM THE TOP OF THE PUMP. 04117/06 CIRCULATE BOTTOMS UP FROM TOP OF ESP AT 7084' CTM WITH METHANOL. TEMPORARILY SUSPEND OPERATIONS DUE TO FLOWLINE PROBLEM ON OFFSET WELL ON PAD. MU WFRD MHA WISLB 1.56" OD 2' X 4SPF TUBING PUNCH. RIH AND TAG TOP OF PUMP AT 7102' CTM, PULL UP TO 7101' AND PUMP 35.5 BBLS OF METHANOL TO FIRE GUNS. AFTER GUNS FIRED, POSITIVE INDICATION OF TUBING AND IA PRESSURES TRACKING TOGETHER. POOH PUMPING METHANOL TO KEEP HOLE LOADED. AT SURFACE, ALL SHOTS FIRED IN TUBING PUNCH. RDMO CTU. PAD OPERATOR NOTIFIED OF STATUS OF WELL. RD IN PROGRESS AT END OF WSR. JOB COMPLETE. e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-09 MPH-09 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/22/2006 Rig Release: 5/29/2006 Rig Number: N3S Spud Date: End: 5/29/2006 5/22/2006 00:00 - 06:00 6.00 RIGU P PRE MIRU Nabors 3S on MPH-09 06:00 - 08:00 2.00 RIGU PRE Accept rig. Rig up flowback tank, hardline, and choke and kill lines to Tree. 08:00 - 10:00 2.00 KILL DECOMP Pull BPV. WHP's TI IA I OA of 250 I 250 I 0 psi. Bleed annulus (gas) to Flowback tank. 10:00 - 13:00 3.00 KILL DECOMP Pump 8.6 #/gal Brine down tubing, with 50 Bbls returns from annulus to Flowback Tank. Close choke and bullhead 60 Bbls into formation. Open choke and circulate 250 Bbls to Tiger Tank, @ 4 BPM 800 psi Tbg, 350 psi IA. Shut down and monitor pressures. Tbg and IA @ 0 psi. Change out valve on Tiger Tank. 13:00 - 14:30 1.50 KILL DECOMP Circulate 100 Bbls Brine, clean fluid returns to tank. No flow test well for 20 minutes. Well on slight vacuum. Run TWC and test to 2500 psi from above. 460 Bbls pumped, 300 Bbls returns, 105 Bbls losses to formation. 14:30 - 00:00 9.50 BOPSU DECOMP N/D Tree. NU BOPE. Notified John Crisp wI AOGCC of impending BOPE test. 5/23/2006 00:00 - 06:00 6.00 BOPSU P DECOMP NU and test BOPE to 250 psi Low /3500 psi High. Witnessed by John Crisp wI AOGCC. 06:00 - 10:00 4.00 PULL P DECOMP Rig up Shieve wI shroud, drain hose, and Trunk for ESP and heat trace cable.. PU Lapso-Apso and torque up xo on bottom. Screw into hanger, MU Lubricator and Pull TWC. Check WHP's. Tbg and IA on vacuum. Laydown lubricator and Lapso-Apso. PUMU landing joint wI head pin and MU to hanger. BOLDS, unland hanger wI 32K #'s. Load hole wI 20 Bbls of 8.6 #/gal Brine. 10:00 - 13:00 3.00 PULL P DECOMP Break out and lay down Tbg Hanger. POH wI ESP completion including Raychem Heat Trace from 3500'. Losses of 6 Bbl I Hr. As pulling ESP cable over shieve with rope attached by "cable snake", ESP cable came loose and cable came to floor. Shut down operations, review procedures, re-rig cables and run over ESP Cable sheave wheel and to ESP Cable spooling unit as POH. 13:00 - 20:00 7.00 PULL P DECOMP POH wI ESP completion and 3500' of Heat Trace cable. Losses @ 6 Bbls/Hr. 20:00 - 00:00 4.00 PULL P DECOMP 70 bbls. brine in pits. Attempted to order 200 bbls. brine. No vac trucks available from VECO dispatch for undetermined amount of time. Stop continuous hole fill and commence filling hole every 10 jts. pulled. 58 jts. pulled @ 2130-hrs. 5/24/2006 00:00 - 06:00 6.00 PULL P DECOMP Continue POH w/ESP completion. OOH w/heat trace cable at 0130-hrs. 180 jts. POH @ 0500-hrs. Load of brine arrived at 0400-hrs. Filled pits and returned to continuous hole fill. Losses - 6 bbls./hr. 06:00 - 10:30 4.50 PULL P DECOMP Break out lay down perforated pup jt above ESP. Break out and lay down ESP. 10:30 - 15:00 4.50 RUNCMP PJSM discussing risks and hazards of PUMU new ESP and cable. Discussed proper procedures for handling of equipment. Rig down elephant trunk. PUMU new ESP. Perform Checks on Motor I Pump I Sensors I Cable. 15:00 - 17:30 RUNCMP RIH wI new ESP Completion. Hang up at 311' as RIH. Remove laSalle clamp and keep trying to work ESP in hole. failed to get ESP to go past obstruction. 17:30 - 19:00 1.50 PULL C DECOMP POH w/tubing and ESP BHA. Noted three vertical gouge Printed: 5/31/2006 1 :00:09 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-09 MPH-09 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/22/2006 Rig Release: 5/29/2006 Rig Number: N3S Spud Date: End: 5/29/2006 5/24/2006 17:30 - 19:00 1.50 PULL C DECOMP 19:00 - 22:00 3.00 CLEAN C DECOMP 22:00 - 00:00 2.00 CLEAN C DECOMP 5/25/2006 00:00 - 00:30 0.50 CLEAN C DECOMP 00:30 - 00:45 0.25 CLEAN C DECOMP 00:45 - 01 :30 0.75 CLEAN C DECOMP 01 :30 - 02:30 1.00 CLEAN C DECOMP 02:30 - 03:30 03:30 - 04:00 04:00 - 05:30 05:30 - 07:00 07:00 - 09:00 09:00 - 12:00 12:00 - 13:30 13:30 - 17:00 17:00 - 19:00 1.00 CLEAN C DECOMP 0.50 CLEAN C 1.50 CLEAN C DECOMP DECOMP 1.50 CLEAN C DECOMP 2.00 CLEAN C DECOMP ~~u Îå l \ 10\: 3.00 CLEAN C DECOMP 1.50 CLEAN C DECOMP 3.50 CLEAN C 2.00 CLEAN C DECOMP DECOMP marks in bottom -4' of ESP motor housing and one additional spiral gouge in the housing beginning at the bottom of the motor and continuing upwards for -1'. Attached PumpMate pickup clamp to bottom of ESP BHA and stood same back in derrick. Called out BFT and cleanout BHA w/fisherman. Wait on arrival of same. Crew staging drill collars and clear and clean rig floor and pipe shed. PUMU cleanout BHA #1. PUMU cleanout BHA #1. RIH w/BHA #1and 2-7/8" tubing. Herw.uag-et311'. Work and rotate pipe. Set down on obstruction with full weight of string - 5000#. Unable to work past obstruction. Rig up circulating equipment. Break circulation at 2.0 BPM at 70 psi. Increase rate to 5.0 BPM at 350 psi. Work pipe and rotate same with chain tongs with full string weight - 5000# - setting on obstruction. Unable to work past obstruction. Pulle¡j....2OOOI fMIW string weight to d~!iJ8 BHA from obstructed area. POH w/BHA #1. No visible mechanical damage or marks to mill shoe. UD reverse circulating junk baskets. No foreign material recovered in junk basket. Discuss plan forward. Decision to run 5.9375" swage on DC's. PUMU 3-1/2" 0.0. DP "johnny-whacker", 4 x 4-3/4" DC's, jars and bumper sub and RIH on 2-7/8" tubing to test passage through obstructed area while waiting on swage tools to arrive. max. O.D. on "ohnny-whacker" tool ft. - 5.0·. . Ran assembly through Obstruction Wlfhslfght sticking. - Aan as~ 40' past obstructed area. POH w/johnny-whacker assembly, DC's, jars and bumper sub and 2-7/8" tubing. Prepare to run 5.9375" swage. PUMU 5.9375" 00 tapered swage on DC's w/ jars and bumper sub. RIH to/311' wi swage. See slight bobble on Wèìght irIdicator¡båtnot hanging up. Work swage repeatedly, moving freely through tight spot with consistent bobble @ 311 '. RIH to 400'. POH and inspect swage. No marking on swage, only paint rubbed off. PUMU 5.9375" Guide shoe on 4 3/4" reverse circulating junk basket, bumper sub and jars, 43/4" DC's. RIH on 2 7/8" tubing and tag @ 311'. WorkHCJ8 wI Mill Shoe to 323'. Short tripping repeatedly, continuing to tag up @ 311', but able to work back down by utilizing power tongs and 1000 ft-Ib torque w/ 4000 #'s weight Mill Face.. POH Stand back Tbg and DC's, break out & lay down RCJB. Inspect BHA, gouge on side of Guide Shoe of RCJB similar to what was seen on ESP motor. Also rub-drag marks (no scoring) along bumper sub housing. PUMU Kelly. Torque all connections. PUMU Baker BHA with 5 3/4" Tapered Milil, 6.00" String Mill, 4 3/4" bumper sub and jars, 4 3/4" DC's, RIH on 3.5" DP. Tagged tigAt spot at 173' with string milt WórkM pipe through tight spot8times with no reduction in drag. Decision to pick up kelly and buff out tight spot. Printed: 5/31/2006 1 :00:09 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-09 MPH-09 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/22/2006 Rig Release: 5/29/2006 Rig Number: N3S Spud Date: End: 5/29/2006 DECOMP PU kelly and pressure test upper and lower kelly cock to 3500 PSI prior to breaking circulation and commencing milling operations. Upper kelly cock failed test. Replaced same and retested. DECOMP PU kelly and pressure test upper and lower kelly cock to 3500 PSI prior to breaking circulation and commencing milling operations. Upper kelly cock failed test. Replaced same and retested. DECOMP Break circulation at 4-5 BPM at 175 psi. Mill down through tight spot at 45-50 RPM. No noticeable torque increase in addition to free torque above tight spot. Dress tight spot with 4 passes of mill. Pass mill through tight spot not rotating. No noticeable drag. Tight spot gone. Set kelly back in rathole. RIH w/ 3-1/2" DP 1x1. Encountered tight spot at 243' Stacked string out. UD two jts. DP. PUMU 15' 3-1/2" DP pup jt. PU kelly. Break circulation at 4-5 BPM at 175 psi. Mill kelly down at 45-50 RPM. Losses = 5 BPH. Make connections and mill down through tight spots from 243'. RIH and tag @ 311' MD. Pump rate 4 BPM, 50 to 100 RPM, 4000 to 5000 # WOB, 0 Torque. Work String Mill throug/1 tight spot to clean lip. Metal shavings on ditch magnets. . Work mill @ varying SO speeds through tight spot until able to Drift through with Mill while not pumping. Drift w/ Mill from 311' to 347', PU and rotate BHA 1/4" turn and repeat Drift. Repeat 1/4 turn at a time until 360 deg, working BHA Mill through tight spot @ 311' down to 347'. Able to Drift w/out pumping, but still slight dragging as RIH. DECOMP Stand Back Kelly. PU 3 1/2" DP 1x1 and RIH to 778' with no sticking or drag. POH standing back DP and DC's. Break out and examine mill. No wear on 6.00" String Mill. Wear on Tapered Mill at 4.75" to 5.375" 00. DECOMP Break out Tapered Mill, MU 5.9375" Casing Swage below 6.00" String Mill. RIH and Tag @ 311'. Work Swage to 321'. No rotation of Swage. Unable to get deeper. POH and examine Swage. Ring on 00 of Swage +/- 3/4 of circumference @ 5.9375". DECOMP RBIH w/ 5.9375" Swage and 6.00" String Mill. Rotate mill and swage through obstruction from 300' to 347' several times. Drift w/mill and swage w/out pumping with no drag. DECOMP POH w/ mill and swage. No noticeable contact marks on string mill. Slight cut ring on bottom end of swage. Also noted circular cut marks on bottom end of bumper sub. UD bumper sub, jars, string mill and swage. DECOMP PUMU Hatco 7" RTTS packer and RIH wlDC's and 3-1/2" DP through obStructed area and set .at 759'. -MJ. to pressure test casing to 1500 psi and chart same. Bring up pump rate to 1 BPMand was unable to get pressure higher than 30 psi. Pumped 9 bbls. into indicating a breach in casing integrity. Release packer. POH w/packer and reset at 301 ft. and attempt to pressure test. Bring up pressure to 820 psi and was unable to get higher due to inadequate weight in string to keep packer elements energized. POH w/packer and DP. 5/25/2006 19:00 - 00:00 5.00 CLEAN C 5/26/2006 00:00 - 02:30 2.50 CLEAN C 02:30 - 03:30 1.00 CLEAN C 03:30 - 04:30 1.00 CLEAN C DECOMP 04:30 - 07:00 2.50 CLEAN C DECOMP 07:00 - 10:30 3.50 CLEAN C DECOMP 10:30 - 13:00 2.50 CLEAN C 13:00 - 16:00 3.00 CLEAN C 16:00 - 18:30 2.50 CLEAN C 18:30 - 20:30 2.00 CLEAN C 20:30 - 00:00 3.50 CLEAN C Printed: 5/31/2006 1 :00:09 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-09 MPH-09 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/22/2006 Rig Release: 5/29/2006 Rig Number: N3S Spud Date: End: 5/29/2006 5/27/2006 00:00 - 01 :00 1.00 CLEAN C DECOMP POH wlpacker to reorient DC's below packer to allow for adequate string weight to effectively energize packer sealing elements. 01 :00 - 02:30 1.50 CLEAN C DECOMP RIH w/6 x 4-3/4" DC's below packer and 3-1/2" DP above packer. 02:30 - 04:30 2.00 CLEAN C DECOMP S\tt packer at 285'. Pressure test casing to 1500 psi for 15 minutes. Good test. . Release packer. Reset ~er at aDO', Pressure up casing 10.1500 psi. p~ bled off to 0 psi in <5 minutes. Release packer and reset at 293'. Pressure up casinQto 1600 psUor aD minutes. ~ test. Release packer. Top of breach in casîng is b~tw~en 293' and 300'. 04:30 - 06:00 1.50 CLEAN C DECOMP POH LDDP, DC's and Halco 7" RTTS packer. Fluid losses = 5-6 BPH. Pit volume = 240 bbls. 06:00 - 09:30 3.50 CLEAN C DECOMP PU Kelly and mak~ service breaks. Break out and laydown 2 ea 4 3/4" DC's. Call Centrilift to come and break out and lay down ESP. Call HES for 7" 26# RBP and RTTS. Losses @ 6 Bbl I Hr. 09:30 - 13:00 3.50 CLEAN C DECOMP PU ESP, Break out and lay down. Rig down ESP cable, shieve, and move spooling unit. C & Crig floor 13:00 - 19:30 6.50 CLEAN C DECOMP PUMU Halco 7" :¿6# Model 3L RBP on 2 7/8" Tbg. RIH. Have to work through tight spot ·~··:J11·. Continue RIH to 7022' (222 jts.). 19:30 - 20:00 0.50 CLEAN C DECOMP Set Halco 7" 26# ModeI3L ASP @ 7022,'. POH .and stand back 1 stand tubing in derrick. 20:00 - 21 :00 1.00 CLEAN C DECOMP Dump 200# 20/40 mesh sand in tubing flushing with water. Displace sand out of tubing to top of RBP with 41 bbls. brine. 21:00 - 23:00 2.00 CLEAN C DECOMP POH and rack 10 stands tubing back in derrick. PUMU Halco 7" RTTS packer and RIH w/6 stands tubing. Set packer at 418'. 23:00 - 23:30 0.50 CLEAN C DECOMP Set packer at 418'. Pressure test casing to 1500 psi andctmrt same for 30 minutes. Good test. 23:30 - 00:00 0.50 CLEAN C DECOMP Release packer, lay down 2 jts. tubing. Set packer at 357' and pressure test casing to 1500 psi for 15 minutes. Good test. 5/28/2006 00:00 - 02:30 2.50 CLEAN C DECOMP Release packer, lay down 1 jt. tubing. Set packer at 326'. Pressure test casing to 1500 psi. No test. Pumped into leak at .5 BPM at 70 psi. Release packer. PU 1 jt. tubing. Set packer at 340'. Pressure test casing to 1500 psi. No test. Pumped into leak at .5 BPM at 50 psi. Release packer. Set packer at 347'. Pressure test casing to 1500 psi. No test. Pumped into leak at .5 BPM at 100 psi. As establised in earlier pressure testing, casing tested to 1500 psi for 30 minutes above 293'. Casing integrity is compromised between 293' and 357'. 02:30 - 03:00 0.50 CLEAN C DECOMP POH UD 2 jts. tubing. POH rack back 4 stands tubing in derrick. UD 7" Halco RTTS packer. 03:00 - 04:00 1.00 CLEAN C DECOMP RIH wI 9 stands of 2 7/8" tubing out of derrick. 04:00 - 06:30 2.50 CLEAN C DECOMP Break circulation. Establish circulation parameters at 3.0 BPM at 380 psi. Pump 20 bbl. Hi-Vis sweep. Circulate surface to surface volume = 275 bbls 8.6 ppg brine. Recovered and segregated hi-vis sweep to pill pit. 06:30 - 11 :00 4.50 CLEAN C DECOMP POH standing back 2 7/8" Tubing in Derrick. Notify Jeff Jones wI AOGCC of change of scope on RWO from ESP swap to suspension of well. Kuparuk River Bridge Road one out from breakup. Coordinate getting SLB tools across the river for Printed: 5/31/2006 1 :00:09 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-09 MPH-09 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/22/2006 Rig Release: 5/29/2006 Rig Number: N3S Spud Date: End: 5/29/2006 5/28/2006 06:30 - 11 :00 11 :00 - 12:30 12:30 - 14:30 14:30 - 19:00 19:00 - 00:00 5/29/2006 00:00 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 08:30 08:30 - 11 :30 11 :30 - 14:00 14:00 - 15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 00:00 4.50 CLEAN C 1.50 CLEAN C DECOMP US IT logging. DECOMP Short trip RBP retrieving head through tight spots 293' to 357', no sign of damage. Continue POH. Lay down 2 stands of 2 7/8" tubing and 2 stands of 4 3/4" DP. 108 stands 2 7/8" tubing in Derrick. PUMU 7" riser wI Otis quick connect tree cap. Losses @ +1- 2 Bbls I hour. Total losses since setting RBP - 10 Bbls. DECOMP SLB e-line unit and crew on location. MIRU DECOMP ~H WI SLB USf"fln Corrtìsive/Caffpermode andiogup from ~'. ~ anomaly @ 880' and ~ damage to Casing -300' for 30'. sectipn of Csg. Repeat ~ing pass. Send Data topr" ~t'lèftoragéca$ wen.~s on the Slope (ElmorelTempletòn},Aig dCMin St..B. RUNCMP RIH w/RBP retrieving head, 2-7/8" 8 rd. kill string and muleshoe WLEG. Land WLEG at 6820'. RUNCMP RIH w/RBP retrieving head, 2-7/8" 8 rd. kill string and muleshoe WLEG. Land WLEG at 6820'. RUNCMP PUMU FMC tubing hanger. Land hanger. Dry rod set TWC and PIT from above to 1000 psi. for 15 minutes. Good test. RUNCMP C&C rig floor and prep to NID BOPE. RUNCMP NID BOPE. RUNCMP NU 2 9/16" FMC Tree. Penetrator ports for ESP cable and Heat Trace cable are blanked. Test Tree to 5000 psi. RUNCMP MIRU LRS for Freeze protect of Tbg and Annulus. Pressure test lines to 1000 psi. Pump 100Bblsdieül down annulus taking returns from tubing to flowback tank. Get 15 Bbls returns. FP tubing with 15 Bbls diesel. Discuss wI MPU Operations and they wiill circ out the well with Dead Crude to FP after Rig moves. RUNCMP Blow down all lines, rig down same. Secure wellhead and cellar area. RUNCMP Rig up lubricator. Set BPV RUNCMP Clean mud pits of oil from RWO. Haul off returned fluids. RUNCMP Release rig. RDMO 2.00 CLEAN C 4.50 EV AL C 5.00 2.00 1.00 1.00 RUNCO 4.50 BOPSU 3.00 BOPSU 2.50 BOPSU 1.00 BOPSU 1.00 BOPSU 1.00 BOPSU 7.00 BOPSU Printed: 5/31/2006 1 :00:09 PM , .. Tree: FMC 2 9/16" 5M Wellhead: 11"x 2 9/16" 5M FMC Gen 6 2-7/8" eue 8 rd. btm. & top, 2.5" CIW BPV profile. 20" 91.1 ppf, H-40 I 112' KOP @ 500' to 4500' Max. hole angle = 74 to 77 deg. fl 2900' to 6100' Hole angle thru' perfs = 40 deg. 7" 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf) 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift 10 = 2.347", cap. = 0.00592 bpf ) Marker Joint (7,156' - 7,197' ) ~ Stimulation Summary 'OB' Sand - 01/29198 - 19.1 M# of PropLok coated 16/20 Carbolite behind pipe. 'N' Sand - 02/02/98 - 52.6 M# of 16/20 Carbolite behind pipe. 'OA' Sand - 02/03/98 2nd stage tool had to be fished. No Prop was pumped. the screen is pre-packed. Proposed Peñoration Summary Ref loa: GRlCCL 01/28/98 Size SPF Interval D) "N" Sand 4.5" 4 7360' - 7380' (3888' - 3906') "ON Sand 4.5" 4 7524' - 7554' (4013' - 4036') "OB" Sand 4.5" 5 7602' - 7632' (4073' - 4096') 4.5" Big Hole charges @ 60 deg. phasing MPU H-09 Orig. lev. = 66.4' (N 22E) Orig. G Elev. = 36.6 RT To Tbg. Spool = 30.85 (N 22E) ~ - - - - - - - - - - - - -- - - - -- 11_111""1"--",,, ~l~~~íïïI~ "",- ",_-. -- --, - ~ ~- DATE REV. BY COMMENTS 09-27-97 BDB 7" Cased Hole Completion 22E 02/10/98 MDO 4 es 08/24/98 MDO 11/14/98 MDO Howco 7" "ES" Cementer I 2095 RBP Retrieving Head I 6820' HES Model 3L RBP Packer I 7022' wi 200# 100 mesh sand on top x" HES Versatrieve pkr. Closing sleeve ass'bly 127' , 11 ppf, N-80, NU blank pipe (ID == 3.476") 30',0.012" Ga. pre-pack screen (ID =3.476") HES Iso. Pkr. assemble (ID == 3.476 ") 1 09' . 11 ppf, N-80, NU blank pipe (ID = 3.476") 304 SS ELPPP, 0.012" Ga. screen (ID == 3.475") HES 'BWD' sump pkr. 7" landing collar (PBTD) 7" float collar (PBTD) 7" float shoe 7,203' 7,211' 7,358' 7,388' 7,523' 7,563' 7,806' md 7,848' md 7,89a md MILNE POINT UNIT WELL No : H-09 API: 50-029-22804 BP EXPLORATION AK 197-165-0 MILNE POINT UNIT SB tt-09 50- 029-22804-00 BP EXPLORATION . MD 07915 TVD 04312 t~ompletion Date: J2/8/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 8417 ~ SPERRY MPT/GR/EWR4 OH 4/1/98 4/1/98 L CMTMAP tPII~L 204020"~1/"[['~°[~'~ CH 5 8/13/98 8/20/98 L DGR/EWR4-MD ,~L 4910-7915 OH 4/8/98 4/8/98 L DGR/EWR4-TVD 3-F~AL 2887-4312 OH 4/8/98 4/8/98 L GR/CCL ~ 6596-7770 1/29/98 CH 5 2/1/98 2/3/98 L GR/CCL-SET FINAL 753})-7563 1/30/98 ,,' CH 5 2/1/98 2/3/98 L GR/CCL/PERF ~ 7354-7718 1/27/98 CH 5 2/1/98 2/3/98 L GR/CCL/PERF zF-tN~L 73~46-7650 1/30/98'; CH 5 2/1/98 2/3/98 L STAT PRESfI'EMP ~L 7617-7617 1/28/98 CH 2/1/98 2/3/98 L STATPRES/TEMP ~FII~L 7639-76501/30/98 CH L STAT TEM SRVY ,-.-4''/' 204060 '7//c~/q ~ CH 5 L STATTEM SRVY '~'"'"" 204060 7/19/~'~ CH 5 L STATTEM SRVY ~ 204060 '7[ Iq/~'~ CH 5 R MWD SRVY ~Y 0-7915. OH T 8344 ~ SCHLUM GR CH Daily Well Ops ~//(~/c?) __ 2 Was the well cored? yes 2/1/98 2/3/98 8/13/98 8/20/98 8/13/98 8/20/98 8/13/98 8/20/98 4/2/98 4/3/98 3/26/98 3/25/98 Are Dry Ditch Samples Required? yes ~ And Re~-- Analysis Description R~ .... Sample-Set4g--------~- ©9© Comments: Thursday, February 03, 2000 Page 1 of 1 rn~ ~T}~Pa^L UNDER rn~s COVER ON OR BEFORE JANUARY 03 2001 BEEN . P L E TH IS.M ARK E R''' R C:LO~A~V~[LM. DOC GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11438 Company: Field: Alaska OII & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description. Date BL RF Sepia LIS Tape MPU F-62 Lx. ~ c_.. INJECTION PROFILE ' '9'80706 I 1 MPG-13 INJE6~ION PROFILE 980718 1 1 .... M PH-09 STATIC TEMPERATURE SURVEy/ 9 8 0 719 1 1 MPH-09 ....... STATIC TEMPERATURE ..SURVEY .... 980719 ! ! .... MPH-09 STATIC TEMPERATURE SURVEY 980 719 I 1 MpH-09 CEMENT MAP LOG .980.7.20 . 1 ....... I · MPJ-22 4 ARM CALIPER 980719 1 1 ..... .............. , 8/18/98 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED' AU6 2.0 1998' Alaska 0ii & Gas Cons. CommiSsion Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 WELL LOG TRANSMITTAL To: State of Alaska .alaska Oil and Gas Conservation Comm. .Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPH-09, AK-MM-70265 April 8. 1998 MPH-09: 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22804-00 '"3 I!II ,~ x 5 TVD Resistivity and Gamma Ray Logs: 50-029-22804-00 1 Bluelh~e 1 Folded Sepia 1 Bluelh~e t Folded Sepia PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO ~ ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, .alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. _Anchorage, Alaska 99519-6612 Date: ~/~/c~ ~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. STATE OF ALASKA LJ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [--] Gas [--1 Suspended [] Abandoned [~ Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-165 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22804 4. Location of well at surface~ '. ': i.'::!. ~'ti1~1~~ ......... 9. Unit or Lease Name 2805 NSL, 4175' WEL, SEC. 34, T13N, R10E, UM~ ' :;.'. ~-. Milne Point Unit At top of productive interval ;'~'- .-¢':,//'_.:~ ~ 10. Well Number 2543' SNL, 4480' WEL, SEC. 2, T12N, R10E, UM '~.'" :?_ '; MPH-09 At total depth ' '"(-- ~ 11. Field and Pool 2903' SNL, 4487' WEL, SEC. 2, T12N, R10E, UM , -'" Milne Point Unit / Schrader Bluff ,5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 65.8'I ADL 380109 12. Date Spudded I 13. Date I.D. Reached I 14. Date Comp., Susp., or Abari'dJl 5. Water depth, if offshore i 16. No. of Completions 9/7/97 9/11/97 2/8/98 N/A MSLI One 17. Total Depth (MD+-FVD)7915 4312 FT]I1 8' Plug Back Depth (MD+-I-VD)II 9' Directi°nal Survey 120' Depth where SSSV set 121' Thickness °f Permafr°st7806 4229 FTI [~Yes ~--]No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR/RES, GR/CCL, GR/JB 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 31' 7890' 8-1/2" 1357 sx PF 'E', 120 sx 'G', 100 sx PF 'C' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 7114' M D TVD M D TVD 7360'-7380' 3888'-3903' 7524'-7554' 4013'-4036' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 7602'-7632' 4073'-4095' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 85 bbls diesel Gravel pac, 7203'-7388' 52600# 16/20 Carbolite behind pipe Gravel pac, 7388'-7563' Pre-packed screen Proplok Frac, 7602'-7632' 19050# 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) February 19, 1998I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure OALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAWTY-API (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. /',PR 0,5 1998 Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluid~ Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. SBF1 7357' 3886' TSBD 7522' 4012' TSBB 7597' 4069' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby ce~th~'forego~ng.ls-tr-0~nd correct to the best of my knowledge Signed. ,._ -' ~-,"' _~' ,~,~/,~,~ .,'~.~ren~,~¢/~/~¢-//? A.~_-~¢--~ Title Drillin~tEngineerin~Supervisor Date MCH'-09 97-165 Prepared By Name/Number: Kathy Campoamor, 564-5122 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 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM28: If no cores taken, indicate'none'. -~"' "~'"~E" Form 10-407 Rev. 07-01-80 100.00 3 .~9.23 A i 903 ' -31- ~¢55023' 58.46" -,,, BB,~..&40.,64.38 I"~ OXY 8.81 ~ 58 46 41 ...,~4 2301 ARC""~ .46 BPX i41.,~,. ,' WF_Sq' IS, AK 1"/' AD BPE& ;OXY BPE, 52O ARCO BPX 12 25629 / ;.&':,l 8.81 5515 64.38 26.81 8.81' AD BP E OXY 1-29-01 01-29-01 ADL AE)L 5848 025516 E& MPU 9-0t~ 17 ARCO 58.46 BPX 4'1.54 03-2'; ADL02 MPU '-84 ~o 5627 O:X~U, OXY U MIl. NE POINT ~..,, ADL BPE& 8.81 A El BP E & 6,4 I~X 8, MP .. ~,.--.', ;A 8. ., ADL0, BP E I~PX 26. OXY USA 8.; .., ,. AD 3 82,!- !91.1~9 ;A ,8.81 OXY 11-03~ 0 A[ Facility Date/Time 06 Sep 97 07 Sep 97 08 Sep 97 09 Sep 97 10 Sep 97 11 Sep 97 M Pt H Pad Progress Report Well MPH-09 Rig Nabors~~ Page Date Duration Activity 13:00-14:00 14:00-18:00 18:00-21:00 21:00-01:00 01:00-03 :00 03:00-06:00 06:00-09:30 09:30-10:00 10:00-10:30 10:30-12:30 12:30-13:00 13:00-06:00 06:00-07:00 07:00-08:00 08:00-09:30 09:30-10:00 10:00-10:30 10:30-11:30 11:30-17:00 17:00-20:00 20:00-21:00 21:00-23:30 23:30-00:30 00:30-01:30 01:30-03:00 03:00-06:00 06:00-08:00 08:00-09:00 09:00-09:30 09:30-10:30 10:30-16:00 16:00-16:30 16:30-22:30 22:30-00:30 00:30-01:30 01:30-03:00 03:00-06:00 06:00-07:00 07:00-11:00 11:00-11:30 11:30-12:30 12:30-13:00 13:00-15:30 15:30-16:30 16:30-17:00 17:00-17:30 17:30-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-16:00 16:00-17:00 17:00-19:00 1 hr 4 hr 3hr 4hr 2hr 3hr 3-1/2 hr 1/2 hr 1/2 hr 2 hr 1/2 hr 17hr 1 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 5-1/2 hr 3 hr 1 hr 2-1/2 hr 1 hr 1 hr 1-1/2 hr 3 hr 2 hr 1 hr 1/2 hr 1 hr 5-1/2 hr 1/2 hr 6 hr 2 hr 1 hr 1-1/2 hr 3 hr 1 hr 4hr 1/2 hr 1 hr 1/2 hr 2-1/2 hr 1 hr 1/2 hr 1/2 hr 10-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 8-1/2 hr lhr 2 hr Rig moved 20.00 % Rig moved 40.00 % Rig moved 60.00 % Rig moved 80.00 % Rig moved 100.00 % Rigged up Divertor Rigged up Divertor Tested Divertor Held safety meeting Made up BHA no. 1 Tested Mud pumps Drilled to 2187.0 ft Drilled to 2462.0 ft Circulated at 2462.0 ft Pulled out of hole to 60.0 ft Serviced Additional services Serviced Top drive R.I.H. to 2462.0 ft Drilled to 3296.0 ft Pulled out of hole to 2000.0 ft Circulated at 2000.0 ft Pulled out of hole to 0.0 ft Serviced Top drive R.I.H. to 2100.0 ft Reamed to 3296.0 ft Drilled to 3676.0 ft Drilled to 4056.0 ft Circulated at 4056.0 ft Pulled out of hole to 3250.0 ft Reamed to 4056.0 ft Drilled to 4914.0 ft Circulated at 4914.0 ft Pulled out of hole to 4620.0 ft Pulled BHA Serviced Top drive R.I.H. to 2279.0 ft Reamed to 4914.0 ft Reamed to 4914.0 ft Drilled to 5504.0 ft Circulated at 5504.0 ft Backreamed to 4914.0 ft Reamed to 5504.0 ft Drilled to 5978.0 ft Circulated at 5978.0 ft Pulled out of hole to 5409.0 ft R.I.H. to 5978.0 ft Drilled to 7218.0 ft Circulated at 7218.0 ft Backreamed to 5978.0 ft Backreamed to 5691.0 ft R.I.H. to 7218.0 ft Drilled to 7915.0 ft Circulated at 7915.0 ft Pulled out of hole to 4931.0 ft 1 31 March 98 Facility Date/Time 12 Sep 97 13 Sep 97 M Pt H Pad Progress Report Well MPH-09 Rig Nabors ~fl~,,qP. A5 Page Date Duration Activity 19:00-19:30 19:30-22:30 22:30-00:30 00:30-01:00 01:00-01:30 01:30-02:30 02:30-05:00 05:00-06:00 06:00-10:30 10:30-13:00 13:00-18:00 18:00-19:00 19:00-20:30 20:30-06:00 06:00-06:30 06:30-07:00 07:00-09:30 09:30-11:00 11:00-14:00 14:00-15:30 15:30-19:00 19:00-20:00 20:00-21:00 21:00-23:30 23:30-06:00 1/2 hr 3 hr 2hr 1/2 hr 1/2 hr 1 hr 2-1/2 hr 1 hr 4-1/2 hr 2-1/2 hr 5 hr 1 hr 1-1/2 hr 9-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 3 hr 1-1/2 hr 3-1/2 hr 1 hr 1 hr 2-1/2 hr 6-1/2 hr Worked stuck pipe at 4931.0 ft Backreamed to 4549.0 ft Backreamed to 3530.0 ft Backreamed to 2204.0 ft Circulated at 2204.0 ft Pulled out of hole to 917.0 ft Pulled BHA Serviced Top drive R.I.H. to 7915.0 ft Circulated at 7915.0 ft Pumped out of hole to 901.0 ft Pulled BHA Rigged up Casing handling equipment Ran Casing to 7532.0 ft (7in OD) Ran Casing to 7890.5 ft (7in OD) Rigged up Cement head Circulated at 7890.0 ft Mixed and pumped slurry - 198.100 bbl Circulated at 7890.0 ft Mixed and pumped slurry - 370.900 bbl Rigged down Divertor Rigged down Casing handling equipment Rigged down Divertor Installed Casing on landing string Cleared Sand traps 2 31 March 98 Facility Date/Time 26 Jan 98 27 Jan 98 28 Jan 98 29 Jan 98 30 Jan 98 31 Jan 98 01 Feb 98 02 Feb 98 Progress Report M Pt H Pad Well MPH-09 Page 1 Rig Nabors 4ES Date 31 March 98 06:00-06:30 06:30-12:00 12:00-13:30 13:30-15:30 15:30-20:30 20:30-23:00 23:00-00:00 00:00-02:00 02:00-06:00 06:00-06:30 06:30-09:30 09:30-13:00 13:00-13:30 13:30-15:30 15:30-16:00 16:00-17:30 17:30-19:00 19:00-20:00 20:00-00:30 00:30-06:00 06:00-06:30 06:30-08:00 08:00-14:30 14:30-01:30 01:30-06:00 06:00-06:30 06:30-08:00 08:00-10:30 10:30-14:30 14:30-23:00 23:00-02:30 02:30-03:00 03:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-13:30 13:30-16:30 16:30-18:00 18:00-22:30 22:30-00:00 00:00-06:00 06:00-10:30 10:30-12:00 12:00-03:00 03:00-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-12:00 12:00-12:30 12:30-19:00 19:00-02:30 02:30-06:00 Duration 1/2 hr 5-1/2 hr 1-1/2 hr 2hr 5hr 2-1/2 hr 1 hr 2 hr 4 hr 1/2 hr 3hr 3-1/2 hr 1/2 hr 2hr 1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 4-1/2 hr 5-1/2 hr 1/2 hr 1-1/2 hr 6-1/2 hr llhr 4-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 4 hr 8-1/2 hr 3-1/2 hr 1/2 hr 3 hr 1/2 hr 2-1/2 hr 1/2 hr 4 hr 3 hr 1-1/2 hr 4-1/2 hr 1-1/2 hr 6 hr 4-1/2 hr 1-1/2 hr 15hr 3 hr 1/2 hr 1-1/2 hr lhr 3hr 1/2 hr 6-1/2 hr 7-1/2 hr 3-1/2 hr Activity Held safety meeting Rig moved 100.00 % Removed Xmas tree Rigged up BOP stack Tested BOP stack Made up BHA no. 1 Circulated at 2024.0 ft Drilled installed equipment - DV collar R.I.H. to 5701.0 ft Held safety meeting R.I.H. to 7736.0 ft Reverse circulated at 7736.0 ft Tested Other sub-surface equipment - Via annulus and string Pulled out of hole to 5000.0 ft Serviced Block line Pulled out of hole to 0.0 ft Worked on BOP - Lubricator Tested Lubricator Perforated from 7602.0 ft to 7632.0 ft Conducted electric cable operations Held safety meeting Conducted electric cable operations Ran Tubing to 7114.0 ft (3-1/2in OD) Displace treatment Monitor pressures Held safety meeting Monitor pressures Circulated at 7114.0 ft Pulled Tubing in stands to 0.0 ft R.I.H. to 7798.0 ft Circulated at 7798.0 ft Held safety meeting Laid down 4500.0 ft of 3-1/2in OD drill pipe Held safety meeting Laid down 3298.0 ft of 3-1/2in OD drill pipe Worked on BOP - Lubricator Conducted electric cable operations Perforated from 7534.0 ft to 7554.0 ft Perforated from 7524.0 ft to 7534.0 ft Conducted electric cable operations Perforated from 7360.0 ft to 7380.0 ft Conducted electric cable operations Conducted electric cable operations Worked on BOP - Lubricator Rigged up sub-surface equipment - Gravel pack tool Rigged down sub-surface equipment - Gravel pack tool Held safety meeting Rigged down sub-surface equipment - Gravel pack tool Ran Tubing in stands to 1608.0 ft Circulated at 1608.0 ft Pulled Tubing in stands to 0.0 ft Installed Sub sea tools Ran Tubing in stands to 7568.0 ft Functioned Gravel pack tool Facility Date/Time 03 Feb 98 04 Feb 98 05 Feb 98 06 Feb 98 07 Feb 98 M Pt H Pad Progress Report Well MPH-09 Page 2 Rig Nabors 4ES Date 31 March 98 06:00-06:30 06:30-08:00 08:00-10:30 10:30-13:00 13:00-13:30 13:30-19:30 19:30-22:30 22:30-01:30 01:30-06:00 06:00-07:30 07:30-12:00 12:00-15:00 15:00-19:30 19:30-00:00 00:00-04:00 04:00-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-10:30 10:30-10:45 10:45-13:30 13:30-16:30 16:30-17:00 17:00-17:30 17:30-20:30 20:30-21:00 21:00-21:30 21:30-22:30 22:30-02:00 02:00-03:00 03:00-04:30 04:30-06:00 06:00-14:30 14:30-15:30 15:30-15:45 15:45-20:00 20:00-21:00 21:00-01:00 01:00-03:30 03:30-04:30 04:30-06:00 06:00-06:15 06:15-06:30 06:30-08:30 08:30-11:00 11:00-11:15 11:15-13:30 13:30-14:00 14:00-18:00 18:00-19:30 19:30-01:00 06:00-06:15 06:15-06:30 Duration 1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 6 hr 3 hr 3hr 4-1/2 hr 1-1/2 hr 4-1/2 hr 3 hr 4-1/2 hr 4-1/2 hr 4 hr 2 hr 1/4 hr 1/4 hr lhr 3hr 1/4 hr 2-3/4 hr 3 hr 1/2 hr 1/2 hr 3 hr 1/2 hr 1/2 hr 1 hr 3-1/2 hr lhr 1-1/2 hr 1-1/2 hr 8-1/2 hr 1 hr 1/4 hr 4-1/4 hr 1 hr 4 hr 2-1/2 hr 1 hr 1-1/2 hr 1/4 hr 1/4 hr 2 hr 2-1/2 hr 1/4 hr 2-1/4 hr 1/2 hr 4 hr 1-1/2 hr 5-1/2 hr 1/4 hr 1/4 hr Activity Held safety meeting Reverse circulated at 7203.0 ft Laid down 167.0 ft of Tubing Circulated at 7203.0 ft Held safety meeting Mixed and pumped 550.000 bbl of treatment Reverse circulated at 7203.0 ft Circulated at 7203.0 ft Installed High pressure lines Injectivity test - 200.000 bbl injected at 5300.0 psi Functioned Sub sea tools Laid down 192.0 ft of Tubing Worked toolstring at 7203.0 ft Conducted electric cable operations Conducted electric cable operations Reverse circulated at 7203.0 ft Held safety meeting Serviced Drillfloor / Derrick Reverse circulated at 7203.0 ft Conducted electric cable operations Held safety meeting Conducted electric cable operations Pulled Tubing in stands to 0.0 ft Retrieved Wear bushing Installed BOP test plug assembly Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Made up BHA no. 1 R.I.H. to 5570.0 ft Serviced Block line R.I.H. to 6870.0 ft Fished at 6894.0 ft Fished at 6894.0 ft (cont...) Circulated at 7201.0 ft Flow check Pulled out of hole to 251.0 ft Pulled BHA Laid down fish Made up BHA no. 2 R.I.H. to 5000.0 ft Held safety meeting Held safety meeting (cont...) Serviced Draw works R.I.H. to 7190.0 ft Circulated at 7200.0 ft Flow check Circulated at 7200.0 ft Held safety meeting Laid down 6928.0 ft of 3-1/2in OD drill pipe Pulled BHA Ran Tubing in stands to 6935.0 ft Held safety meeting Laid down 125.0 ft of Tubing Facility Date/Time 08 Feb 98 Progress Report M Pt H Pad Well MPH-09 Page 3 Rig Nabors 4ES Date 31 March 98 06:30-09:30 09:30-10:30 10:30-11:30 11:30-13:00 13:00-20:30 20:30-21:45 21:45-22:00 22:00-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-10:45 10:45-11:00 11:00-13:00 13:00-14:30 14:30-15:15 15:15-15:45 15:45-16:00 16:00-18:00 Duration 3 hr lhr 1 hr 1-1/2 hr 7-1/2 hr 1-1/4 hr 1/4 hr 8hr 1/2 hr 1 hr 2-1/2 hr 3/4 hr 1/4 hr 2hr 1-1/2 hr 3/4 hr 1/2 hr 1/4 hr 2 hr Activity Ran Tubing to 2286.0 ft (2-7/8in OD) Pulled Tubing in stands to 0.0 ft Rigged up Completion string handling equipment Rigged up sub-surface equipment - Electrical submersible pumps Ran Tubing to 4814.0 ft (2-7/8in OD) Rigged up sub-surface equipment - Other sub-surface equipment Held safety meeting Ran Tubing in stands to 6245.0 ft Ran Tubing in stands to 6245.0 ft (cont...) Ran Tubing on landing string to 7114.0 ft Installed Electric cable Ran Tubing on landing string to 7114.0 ft Installed Hanger plug Removed BOP stack Installed Xmas tree Tested Xmas tree Removed Hanger plug Installed Hanger plug Freeze protect well - 85.000 bbl of Diesel ; 8-81-98 ; 17:58 ; BPX-MILNE POINT~ 907 564 519~;A 2/11 BP EXPLORATION (ALASKA) INC. Miine Point Unll; TO: S. Rossberg FROM: J. Fox DATE: 01 / 28 - 29 / 98 RE: MP H-09 'OB' DATA FRAC AND PROPLOK FRAC SERVICE CO'S.: Dowell, Halliburton, Nabors, and Peak Of the 67.6 M# of 16/20 PropLok coated proppant designed for this stimulation 19.1' Me was'placed behind pipe. A total of 21,300 lbs. Oarbo-Lite was pumped of which the balance, 2250# was left in the: casing as underdisplacement and drilled out by the rig. The wellbore was treating at a' constant.pressure ' (1100 psig) during the ramp up when the pressure started climbing unexpectedly in What appeared to be'a screen out. Flush was called and. about the time pmppant cleared the pumps the treating pressure broke' back from a maximum of approx. 2400 psig and stabilized. Displacement was pumped without any further pressure increase, During the last 20 bbls of displacement rates were gradually dropped in an unsuccessful attempt to induce a screenout, While the design was not reached, the objective of sand control (with resin coated proppant) was achieved and hopefully the 19 M# of pmppant placed will provide some benefit, A net pressure build of around 400 psig. was seen, Notes: · In an effort to minimize waste disposal costs and operational complications 9.8 ppg brine was used to prime pumps, warm / freeze protect / flush treating lines instead of diesel or glycol, Diesel had been used in the past but is considered hazardous unless exempted by recovering from downhole. Glycol has been tried on a few recent jobs but the cost is extremely high (>$24,800 for a typical job) and the supply in these volumes is yew limited, The pump trucks will still be freeze protected with glycol at the very end of the job. The 9.8 ppg brine offers the highest freeze protection for NaCt at -5 deg. which still isn't enough for the -24 deg, ambient temperatures. During the matrix per[Ion when only one pump was utilized there was not confidence that the other 3 pumps may not freeze up so it was opted to pump the matrix portion with the rig pump down the annulus. This also had the benefit of utilizing a smaller pump with a lower and more constant pump rate than the Kiddyfrac, · Rig up was somewhat delayed and complicated by the congestion on H-Pad with two rigs and one spotted where the frac fleet needed to spot their equipment. Fortunately the rig moved down the pad. tn the end the rig waited for a couple hours to complete rig up, · The 3,5" tubing tail was located at 7114', A Petredat gauge was installed in the GLM at a depth of 7061' (3664' tvd). It was recording data at 15 sec, intervals for a 60 hr, period starting at 0600 1/28/98, Following the perforatin,q a SBHP survey was performed at mid-perf, ,SBHP - 1843 psis (1856 psig) at 80 deg. F. · A 5000 psig pressure transducer was utilized on the annulus in order to get better resolution and accuracy. The first transducer did not operate properly and had to be replaced. A 15K gauge was used for the impulse test until the replacement gauge arrived, · A problem with a Pump #2 was experienced and had to be shut down and taken off line, 01/31/98 DATA FRAC & FRAC 9:49 PM SENT VIA MICROSOFT MAIL SENT BY:BPX-MPOC ; 3-31-98 ; 17:54 ; BPX-MILNE POINT~ 007 864 5193;~ 3/11 ,~ TIME RATE BPM II I1 I PUMPi,~G ~uMM'ARY .psIGI psIG. [ BBL , ~BL . . ..... . . , · A problem with the communication link prevented transmitting data to Anchorage real time. In addition, unable to download data file to a disk to transmit to Anchorage. · The 16/20 Carbolite proppant was coated with PropLok resin at e concentration of 3/8 gal. / 100#. · IMPULSE TEST Design 'Rate, Bb'ls Max' Rate, Fina'i STP, ISiP, NWB friction, Tre~t grad, BPM Pumped bpm .psi PSI psi psi/ft > 10 21.2 13.8 920 819 100 0.65 DATA FR.~C NO. 1 (WI GEL) Bbls Bbls 60# g~l' Time60# gel Final STP, ISIP, psi NWB Treat grail, Pumped to Perf,s on perfs psi,, friction, psi , psi/ff 101 100 5:00 1158 940 218 0,68 DATA.FRAC No. 2 (w/_KCJ water) Bbls "IBbls. KCI "-Time'gel on Final STP, ISIP,"psi NWB Treat grad, · Pumped ' tO Perfs p.erfs psi friction, psi psi/ff. · ' 49.§ ' '49.5 not appl. 1047 900 147 ' 0.67 , FRAC Sand Lead prop 'Tall prop De'sign total pumped, behind pipe, behind behind pipe, Liner Sand, ISIP Job wes M# M# 'pipe, M# M# M# /size /size flush b~Jt not 21,3-' 19.05 67.6 '2.25 920 to design 16/20 Carbo not appl. .... wi PropLok SENT BY:BPX-~POC ; 8-81-98 ; 17'55 ; BPX-MILNE POINT~ ~07 864 519fl;g 4/11 · ~ · · '"' ..... ' ........ OPERATIoI~S SUM'MAR';Y ....... - '" DATE/TIME [ [ 111 n,,, III II I I11[ 11 I I Ill' Il l[ II II 01128/§8 -16 deg., winds W @ 8 mph, -38 deg. WC 1030 Dowell on location ,, . 1330 Tubing on bottom. .., 11700 PJSM !..1. 835 o 1837 impulse test. .. 1948 Tubing on vacuum. ,S,,I annulus. Repl,ace 15 .K. transducer. W/5 K transducer. '2004. - 2134 Pump matrix test down annulus with rig pump. Start falloff, _ ,, 2157 - 2212., Pump and displace data frae#1 ( gel data frae). Start falloff, 2253 - 2257 ,,, Pump and ,,displace data frae#2 ( KCl only data frae). Start falloff. ,, ,, 01/29/98 =0102 - 0142 Pump_frae using original desig.n, ., :0142 Shut in wellbore. Monitor preasuro for a few minutes and start rig down. Allow time '[or _ pressure to bleed off and PropLok to set up. ., , T .'RATE ANNP WHP [STAGE CUM COMMENTS " B,.P.M IpslG. PS. IGI BBL BBL .............. · : ~,," 01/28/98 .. IMPULSE TEST DISPLACEMENT = 81.6 BBLS · 11834 . 0 46* 41' 0 0 prepare to start impulse test. * recorded press. .. ¢act.ual pressure is O. ,. ~1835 0 / 14' 993 2046 Start impulse test, bring rate up and hold at 1 bpm 1836 13.8 914 2290 1836+ 13.8 / 0 920 21.2 21.2 S/D pumps. Monitor pressure falloff. ISIP -- 819 ...... psig .. 1837 0 820 757 21.2 21,2 r , , 1840 0 782 720 SENT BY :BPX-~POC ' ' Page 4 ; 13-31-98 ; '.. · ! . 17'58 ; BPX-~ILNE POINT~ 907 664 5193;# 5/11 MATRIX INJECTION TEST 2004 0 / 0.5 o n/a Start pumping down annulus with rig pump at 8,5 ...... sp.m_ = 0.5 bp, m _, 2010 0.5 3 2020 0.5 8 ,,, 2030 0.5 13 2040 0.5 18 2050 O.5 23 21 O0 O.5 28 2110 0,5 33 2120 0.5 38 2134 0,5 . ., 45 ,S/D rig pump. Monit,.o.r falloff pressure. DATA FRAC #1 w/60 # HEC) '2154 0 476 412 0 21.2, Prepare to sta.rt data frac. ,.., !215_7 0 / !2 ,,~ , Siar[ data frac_ .. . . ,, 2158 1.2 1111 2018 2.7 ! 23.9 @ rate 2__201 12,1 1!.57 2311 , i 76 ., , '-. ~2204 11.9 1173 2417 [: ' 103, ~.Gel on perfs , · ' ,,, 2205 12.0 1227 2435 120.4 switch to KCI for flush , .. · 2208 .. 12.1 1180 2,362 1.~4.8 . · 2211 .. 12.1 1177 2366 178 ,: . - , 2212 12.1/0 1158 202.3 S/D pumps. Monitor pressure falloff. ISIP = 940 ...... psig .... ,, DATA FRAC #2 (w/KCI water only) ,. 12253 0 / 12 772 202 Start data frac 2255 12 1163 2618 206 At rate 2257 12.1/0 1047 2560 252 S/D pumps, monitor pressure falloff pressures. ISI P - 900 FRAC 10i 02 0 . 456 453 ,,. 0 0 .... Prep forfrac. . .... 0104 12 1045 2485 6.5 6.5 At rate 0106 12.0 1047 2440 35 35 0107 12.0 1051 2224 47 47 Sta~ sand 0110 12.0 1048 2197 82 Pad on peds .,. 0112 12.0 1114 2252 100 -. 0113 12.0 1109 2238 129 _.Prop. on peds. ._ 0116 12.0 1099 2215 158 SENT BY:BPX-MPOC ; 3-31-98 ; 17'56 ; BPX-MILNE POINT~ 907 564 5198;# 6/11 0120 12,0 .~1106 2183, 200 . 0i24 12,0 1560 3314 ;~33 Treating pressures increasing rapidly. Call for flush. O125 12.2 1705 3632 242 0126 12.0 1203 3034 260 Pressure breaking back. On flush 0127 12,0 1204 3034 266 0128 12.0 1214 2930 279 .0129 12,2 1218 2861, 291 Start reducing rate to induce screen out. 0130 6,6 1038 1812 302 0131 3,7 936 1464 308 Continue reducing rate. 0132 2,9 / 0 927 1369 309,7 S/D pumps w/10 bbl. underdisplacement, ISIP = ,, 920 p.sig. ,. FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 297 Bbls FRAC: 310 Bbls 607 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME ,. 5 sec. pres.s?e readings starting at 0600 on 01/28/98 far 60 hrs. ,, , i ~ u ..... u i ' t i , , ....... '.'. 60 ppt HEC gel w/2% KCI Page1 BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Bill Hill FROM: Kirby Walker DATE: February 2, 1998 RE: H-09 DATA FRAC AND FRAC SERVICE CO'S.: Dowell, Halliburton, Peak, Nabors II i JOB SUMMARY The fluid loss coefficient determined (0.018 ft/min2) from the initial HEC DataFRAC was slightly higher than the previously expected one used in the TSO spreadsheet. The redesigned job called for 28,591# of proppant to be pumped with 39% pad. As the job proceeded, the BHP remained quite steady and the decision was made to extend the 8 PPA stage until screenout occurred. Rate was reduced from 12 BPM to 8 with no immediate reaction. It was decided not to go over the mark of 60,000#. After 58,529# had been pumped, flush was called because of rising pressure. As planned the rate was dropped after 20 BBL of clean 60# HEC had been pumped. Screenout occurred immediately following. Reversing commenced to return the 24 BBL of 8 PPA slurry left in the tubing and to ready the well for the frac on the OA sand. NOTES: · Again, Anchorage had a problem linking up to the modem in the TCV. Another form of antenna is being looked into, updates to follow. · The 5,000 psi gauge seemed to smooth the pressure readings, very beneficial for falloff analysis. INJECTIVlTY TEST Design Rate, Bbls Max Rate, Final STP, ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psilft 20 63 20 3,367* 1,036 100 .702 · had to lower rate to 12 bp'n to stay under max pressure DATA FRAC Bbls Bbls XL gel Pump Rate, Final STP, ISIP, psi NWB Treat grad, Pumped to Perfs bpm psi friction, psi psilft 63 63 12 2,780 1,067 100 0.711 ---~RAC Sand Lead prop Design total Job was pumped, behind pipe, behind pipe, M# M# M# pumped to 58,529 52,612 28,591 completion Ft of Estimated sand in sand top Pipe Final ISIP, psi ISIP Incr STP, psi over datafrac I Actual % pad TSO, design, min TSO, Nolte Plot Page 2 12,7581 4,439 1" ,692 I 5,69= I 4,6=5 I 24. o I 9.5 I 41 DATE/TIME OPERATIONS SUMMARY 1300 Obtain Initial Circulating Pressure - 770 psi @ 2 bpm, 1,175 psi @ 3 bprn 1312 Obtain Initial Reverse Circulating Pressure - 1,935 psi @ 3.6 bpm 1321 Begin BREAKDOWN 1403 Begin MATRIX TEST 1554 Begin DataFRAC #1 with 60# HEC: ISIP - 1075 psi 1700 Begin DataFRAC #2 with KCI 1835 Begin Redesigned Fracture Treatment 1915 Complete Fracture treatment after pumping 430 BBLs fluid with 58,529# 16/20 CL 1950 Begin reversing out tubing 02/02/98 INJECTIVITY TEST/DATA FRAC TIME RATE TP AP STG DISPLACEMENT = 65.4 BBLS CUM 1300 2 770 5 6 - Obtain Initial Circulating Pressure 1305 3 1175 7 9 6 Increase rate 1307 - 15 Shutdown 1312 3.6 10 1935 15 - Initial Reverse Circulating Pressure 1319 - 15 Shutdown 1321 8 2580 16 50 - Circulate HEC to tubing tail for BREAKDOWN 1328 8 2652 21 12.5 50 Displace with KCI 1330 - 62.5 Shutdown - close choke 1332 20 5174 1400 91 62.5 Start BREAKDOWN 1335 17.5 4767 1280 143 Reduce rate - nearing max pressure 1337 12 3425 1125 12 154 Reduce Rate as per program 1338 - - - 166 shutdown - ISIP - 1060 psi 1403 0.5 793 752 45 - Start Matrix Test (rig pumps) 1530 - 1135 935 , - 58 Shutdown 1554 4 1100 181 i 62.5 - Start60# HEC DataFRAC 1609 - 1590 189 - 62.5 Shutdown - close choke 1611 12 3491 1200 ; 66 62.5 Start Displacement - KCI 1616 i ~ -- 'r 128.5 Shutdown - ISIP - 1220 psi Grad. - 0.71 Job redesigned around del:ermined leakoff o~0.018 ft/rr in^0.5. FRAC TIME RATE TP AP STG CUM 1835 12 3275 1150 96 - ; Start PAD 1842 12 2807 1199 48 96 i 1 PPA 1846 12 2642 1188 8 152 ; 2PPA 1847 12 2629 1185 8 160 3 PPA 1847 12 2633 1179 8 168 4 PPA 1848 12 2656 8 176 5 PPA 1849 12 2624 1173 8 184 6 PPA 1850 12 2638 1174 8 192 7 PPA 1851 12 2633 1170 72 264 8 PPA 1900 8 1890 1009 69 324 Reduce Rate 1910 8 2253 1061 17 393 Start Flush - 60# HEC 1915 8 4149 1266 20 410 Start KCI Flush 1918 2 5700 1315 - 430 Reduce Rate - Shut Down 179 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 383 Bbls FRAC: 430 Bbls IINONE PETREDAT WINDOW FLUID ADDITIVES 60# HEC gel (mixed at MI) · 2.5 #/1000 gal - J-134 (Breaker) · 2.0 gal/1000 gal- F-075N (Surfactant) Page1 BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: FROM: DATE: RE: SERVICE CO'S.: Dowell, Halliburton, Peak, Nabors Bill Hill Kirby Walker February 3, 1998 H-OS (OA) DATA FRAC JOB SUMMARY The job started with the determination of initial circulating pressure and reverse circulating pressure. During the Breakdown stage it was noticed that the annular pressure gauge, which was operating fine while taking circulating pressures, was reading uncharacteristically Iow. At the end of the stage Halliburton wanted to check their tool to see if it was in fact set correctly. It was finally decided to pull the entire workstring and physically check the tools. At the point when 186' of the 362' string was pulled from the screen assembly, it became stuck. Working the string made no improvements and it was planned to cut the tubing and attempt to fish the assembly. Atlas was expected to arrive on location around 7:00pm to do the cutting. The tubing will then be stood back and drillpipe will be picked up to do the fishing. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final STP, ISIP, NWB friction, Treat grad, BPM Injected bpm psi PSI psi psi/ft 20 105 22 5,333* 942 230 .691 · pressure wh~le at 20 BPM Drior to Iowerin(] rate to 12 BPV! DATE/TIME: OPERATIONS SUMMARY 05:50 Pressure Test treating lines to 7,000 psi 06:22 Obtain Initial Circulating Pressure - 870 psi @ 2 bpm, 1,010 psi @ 3 bpm 06:34 Obtain Initial Reverse Circulating Pressure - 1,933 psi @ 6 bpm 06:48 Begin BREAKDOWN - ISIP- 928 psi 02/02/98 Page 2 INJECTIVITY TEST/Dr~,TA FRAC TIME RATE TP AP STG DISPLACEMENT =0"65.4 BBLS CUM 06:22 2 870 10 6 - Obtain Initial Circulating Pressure KCI 06:25 3 1010 9 9 6 Increase rate KCl 06:28 - 15 Shutdown 06:34 6 6 1933 15 - Initial Reverse Circulating Pressure KCl 06:37 - 15 Shutdown 06:48 5 1290 9 65 - Circulate HEC to tubing tail for BREAKDOWN 06:56 5 1471 10 12 65 Displace with KCl 06:58 - 77.5 Shutdown - close choke 07:00 22 4320 53 93 77.5 Start BREAKDOWN 07:05 12 2685 102 12 170 Reduce rate - as per program 07:06 - 182 shut down - ISlP- 928 psi 07:15 - - - investigate Iow Annular pressure reading FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 212 Bbls FRAC: - Bbls I NONE PETREDAT WINDOW FLUID ADDITIVES 60# HEC gel (mixed at MI) · 2.5 #/1000 gal- J-134 (Breaker) · 2.0 gal/1000 gal- F-075N (Surfactant) SPE BP EXPLORATION, INC. MILNE POINT / MPH-09 500292280400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -65.80 112.00 112.00 46.20 201.90 201.90 136.10 297.14 297.14 231.34 385.23 385.22 319.42 475.42 475.36 409.56 565.65 565.42 499.62 653.83 653.22 587.42 747.56 746.28 680.48 835.32 833.07 767.27 931.85 927.98 862.18 1021.45 1015.29 949.49 1110.39 1100.90 1035.10 1202.78 1188.65 1122.85 1295.45 1274.84 1209.04 1386.29 1356.88 1291.08 1477.68 1437.84 1372.04 1568.57 1516.91 1451.11 1661.28 1596.27 1530.47 1752.62 1673.49 1607.69 1844.38 1750.08 1684.28 1936.55 1825.62 1759.82 2031.00 1900.82 1835.02 2121.57 1970.68 1904.88 2214.29 2038.75 1972.95 2304.08 2100.46 2034.66 2395.18 2158.91 2093.11 2490.68 2216.23 2150.43 2581.27 2266.07 2200.27 2675.02 2311.79 2245.99 2765.43 2349.74 2283.94 2858.35 2382.09 2316.29 2952.52 2409.31 2343.51 3044.97 2432.35 2366.55 3136.41 2453.61 2387.81 '-SUN DRILLING SERVICES . .~ PAGE ANCHORAGE ALASKA ~_ /~ ~-~ DATE OF SURVEY: 091197 MWD SURVEY JOB NUMBER: AK-MM-70265 KELLY BUSHING ELEV. = 65.80 FT. OPERATOR: BP EXPLORATION, INC. COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 0 0 N .00 E .00 .00N .00E .00 0 0 N .00 E .00 .00N .00E .00 0 12 S 70.21 W .22 .05S .15W .06 0 26 S 3.20 W .43 .47S .32W .49 1 18 S 6.66 E 1.00 1.81S .23W 1.82 2 20 S 8.29 E 1.15 4.67S .16E 4.65 4 20 S .27 E 2.27 9.92S .44E 9.87 6 7 S 4.07 W 2.06 17.95S .12E 17.91 7 31 S 5.84 W 1.51 29.04S .85W 29.04 9 25 S 5.92 W 2.17 41.89S 2.18W 41.95 11 30 S 4.75 W 2.18 59.35S 3.79W 59.47 14 25 S 3.42 W 3.26 79.40S 5.20W 79.57 16 55 S 2.38 W 2.83 103.38S 6.40W 103.58 19 27 S 2.30 W 2.75 132.19S 7.57W 132.41 23 36 S 1.73 W 4.47 166.17S 8.75W 166.40 27 12 S 2.52 W 3.98 205.10S 10.21W 205.35 28 4 S 3.25 W 1.02 247.44S 12.35W 247.73 31 0 S 3.39 W 3.24 292.17S 14.95W 292.54 31 15 S 3.00 W .34 340.02S 17.62W 340.47 33 17 S 3.51 W 2.25 388.70S 20.39W 389.23 33 32 S 3.94 W .38 439.13S 23.68W 439.76 36 21 S 5.18 W 3.16 491.75S 27.89W 492.54 38 5 S 5.08 W 1..83, 548.65S 33.00W 549.65 40 57 S 3.84 W 3.28 606.11S 37.46W 607.26 44 34 S 2.82 W 3.97 668.94S 41.10W 670.20 o 48 34 S 3.15 W 4.47 734.05S 44.50W 735.40 51 34 S 3.60 W 3.31 803.79S 48.62W 805.26 54 38 S 4.03 W 3.22 879.99S 53.71W 881.63 58 35 S 3.58 W 4.38 955.45S 58.72W 957.25 63 1 S 2.82 W 4.78 1037.14S 63.28W 1039.07 67 19 S 3.10 W 4.78 1119.07S 67.52W 1121.10 71 54 S 3.77 W 4.96 1205.99S 72.74W 1208.18 74 30 S 2.45 W 3.07 1296.00S 77.62W 1298.32 76 38 S .74 W 2.93 1385.49S 80.11W 1387.80 76 28 S .58 W .25 1474.42S 81.13W 1476.63 ORIGINAL Gas Cons. Commi~io~ ~chorage SPE1 BP EXPLORATION, INC. MILNE POINT / MPH-09 500292280400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN 3228.03 2475.27 2409.47 76 3323.75 2498.34 2432.54 75 3419.11 2521.98 2456.18 75 3514.73 2546.86 2481.06 74 3609.83 2571.52 2505.72 75 3703.75 2595.75 2529.95 74 3798.50 2619.89 2554.09 75 3893.83 2643.18 2577.38 75 3989.03 2667.03 2601.23 75 4084.27 2691.83 2626.03 74 -SUN DRILLING SERVICES ANCHORAGE ALASKA 10 55 21 28 27 37 50 52 6 41 4179.93 2715.80 2650.00 76 16 4274.21 2738.46 2672.66 75 54 4369.93 2762.23 2696.43 75 20 4464.81 2786.53 2720.73 74 58 4561.23 2809.51 2743.71 77 26 4656.74 2830.67 2764.87 76 56 4752.02 2852.23 2786.43 76 54 4846.93 2874.04 2808.24 76 31 4946.41 2897.03 2831.23 76 45 5041.95 2919.15 2853.35 76 27 PAGE 2 DATE OF SURVEY: 091197 MWD SURVEY JOB NUMBER: AK-MM-70265 KELLY BUSHING ELEV. = 65.80 FT. OPERATOR: BP EXPLORATION, INC. 5136.81 2941.69 2875.89 5232.47 2964.53 2898.73 5328.11 2986.91 2921.11 5423.01 3008.75 2942.95 5514.80 3029.75 2963.95 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 76 3 76 19 76 37 76 46 76 46 S 1.67 W 1.20 1563.42S 82.88W 1565.58 S .49 W 1.22 1656.29S 84.63W 1658.40 S 1.12 W .88 1748.66S 85.93W 1750.68 S 1.67 W 1.08 1840.96S 88.18W 1842.95 S 2.78 W 1.53 1932.73S 91.74W 1934.77 5609.10 3051.36 2985.56 76 44 5703.72 3073.13 3007.33 76 39 5800.64 3095.81 3030.01 76 16 5892.24 3117.47 3051.67 76 22 5990.85 3140.90 3075.10 76 8 S 3.12 W .95 2023.35S 96.41W 2025.50 S 3.09 W 1.29 2114.83S 101.38W 2117.12 S 3.73 W .65 2207.11S 106.87W 2209.56 S 3.73 W .80 2299.07S 112.87W 2301.72 S 4.03 W .53 2390.82S 119.09W 2393.67 S 3.38 W 1.78 2483.22S 125.07W 2486.26 S 3.87 W .65 2574.55S 130.86W 2577.78 S 3.63 W .62 2667.07S 136.92W 2670.50 S 3.40 W .46 2758.62S 142.55W 2762.21 S 3.78 W 2.60 2852.05S 148.41W 2855.83 S 3.50 W .61 2945.00S 154.32W 2948.96 S 3.56 W .07 3037.63S 160.04W 3041.77 S 3.61 W .41 3129.82S 165.81W 3134.14 S 3.16 W .50 3226.44S 171.53W 3230.93 S 2.85 W .45 3319.25S 176.40W 3323.87 6087.40 3165.02 3099.22 6183.10 3192.03 3126.23 6278.84 3224.17 3158.37 6374.38 3262.06 3196.26 6470.92 3306.34 3240.54 S 3.62 W .90 3411.25S 181.60W 3416.01 S 3.48 W .32 3503.96S 187.35W 3508.90 S 5.66 W 2.24, 3596.63S 194.76W 3601.85 S 5.29 W .41 3688.56S 203.57W 3694.14 S 5.10 W .20 3777.55S 211.66W 3783.45 S 4.80 W .31 3869.00S 219.58W 3875.21 S 5.47 W .69 3960.71S 227.82W 3967.25 S 6.10 W .75 4054.46S 237.32W 4061.39 S 6.47 W .41 4142.92S 247.06W 4150.28 S 5.98 W .54 4238.14S 257.45W 4245.95 74 56 72 15 68 30 64 45 60 38 S 3.21 W 3.04 4331.32S 264.94W 4339.41 S 2.06 W 3.03 4423.02S 269.17W 4431.20 S 1.92 W 3.92 4513.13S 272.30W 4521.34 S 1.57 W 3.95 4600.78S 274.98W 4608.99 S 2.16 W 4.29 4686.50S 277.76W 4694.72 SPEP~¥-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION, INC. MILNE POINT / MPH-09 500292280400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/97 DATE OF SURVEY: 091197 MWD SURVEY JOB NUMBER: AK-MM-70265 KELLY BUSHING ELEV. = 65.80 FT. OPERATOR: BP EXPLORATION, INC. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6565.91 3354.78 3288.98 58 1 S 3.51 W 3.01 4768.10S 281.79W 4776.42 6661.48 3406.53 3340.73 56 23 S 2.90 W 1.80 4848.30S 286.28W 4856.75 6756.73 3461.15 3395.35 53 37 S 3.12 W 2.91 4926.22S 290.38W 4934.77 6852.14 3519.95 3454.15 50 16 S 2.61 W 3.53 5001.25S 294.14W 5009.89 6947.49 3583.07 3517.27 46 48 S 4.03 W 3.81 5072.57S 298.25W 5081.33 7042.94 3650.85 3585.05 42 40 S 2.36 W 4.50 5139.64S 302.03W 5148.51 7139.00 3722.01 3656.21 41 42 S .81 W 1.48 5204.13S 303.83W 5212.98 7232.09 3791.72 3725.92 41 19 S .35 W .53 5265.82S 304.45W 5274.61 7327.22 3863.44 3797.64 40 48 S .82 W .63 5328.31S 305.09W 5337.03 7422.58 3935.78 3869.98 40 30 S .45 W .40 5390.44S 305.78W 5399.09 7517.24 4007.87 3942.07 40 17 S .87 W .37 5451.79S 306.48W 5460.37 7615.73 4083.01 4017.21 40 15 S .68 W .13 5515.45S 307.34W 5523.97 7710.98 4155.90 4090.10 39 52 S 1.43 W .65 5576.76S 308.47W 5585.23 7806.52 4229.21 4163.41 39 53 S 1.73 W .20 5638.00S 310.16W 5646.46 7838.53 4253.73 4187.94 40 5 S 1.51 W .77 5658.56S 310.74W 5667.02 7915.00 4312.24 4246.44 40 5 S 1.51 W .03 5707.79S 312.04W 5716.24 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5716.31 FEET AT SOUTH 3 DEG. 7 MIN. WEST AT MD = 7915 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG T8~.41 DEG. TIE IN SURVEY AT SURFACE 0.00'MD PROJECTED SURVEY STATION AT 7915.O0~MD S PE ~ PAGE 4 '-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION, INC. MILNE POINT / MPH-09 500292280400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/97 DATE OF SURVEY: 091197 JOB NUMBER: AK-MM-70265 KELLY BUSHING ELEV. = 65.80 FT. OPERATOR: BP EXPLORATION, INC. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATE S NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -65.80 .00 N .00 E 1000.00 994.48 928.68 74.19 S 4.87 W 2000.00 1876.42 1810.62 529.61 S 31.31 W 3000.00 2421.56 2355.76 1341.84 S 79.23 W 4000.00 2669.85 2604.05 2309.65 S 113.56 W .00 5.52 5.52 123.58 118.06 578.44 454.86 1330.15 751.71 5000.00 2909.33 2843.53 3278.52 S 174.37 W 6000.00 3143.10 3077.30 4246.98 S 258.35 W 7000.00 3619.76 3553.96 5110.06 S 300.61 W 7915.00 4312.24 4246.44 5707.79 S 312.04 W 2090.67 760.52 2856.90 766.23 3380.24 523.35 3602.76 222.52 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE~ -SUN DRILLING SERVICES "' ANCHORAGE ALASKA PAGE 5 BP EXPLORATION, INC. MILNE POINT / MPM-09 500292280400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/97 DATE OF SURVEY: 091197 JOB NUMBER: AK-MM-70265 KELLY BUSHING ELEV. = 65.80 FT. OPERATOR: BP EXPLORATION, INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -65 65.80 65.80 165.80 165.80 100 265.80 265.80 200 365.81 365.80 300 .80 .00 N .00 .00 .00 N .00 .00 .01 S .03 .00 .23 S .31 .00 1.37 S .28 E .00 E .00 .00 W .00 .00 W .00 .00 W .01 .01 465.86 465.80 400 566.03 565.80 500 666.48 665.80 600 767.25 765.80 700 868.50 865.80 800 · 00 4.28 S .10 .00 9.95 S .44 .00 19.30 S .03 .00 31.60 S 1.12 .00 47.29 S 2.74 E .06 .05 E .23 .18 E .68 .45 W 1.45 .77 W 2.70 1.25 970.54 965.80 1073.73 1065.80 1178.54 1165.80 1285.62 1265.80 1396.32 1365.80 900 1000 1100 1200 1300 .00 .00 .00 .00 .00 67.49 S 4.42 92.80 S 5.95 124.13 S 7.25 162.30 S 8.63 209.69 S 10.42 W 4.74 2.05 W 7.93 3.18 W 12.74 4.82 W 19.82 7.07 W 30.52 10.70 1509.53 1465.80 1625.64 1565.80 1743.42 1665.80 1863.31 1765.80 1986.56 1865.80 1400.00 1500.00 1600.00 1700.00 1800.00 262.68 S 13.22 321.56 S 16.65 383.66 S 20.08 449.65 S 24.43 521.41 S 30.58 W 43.73 13.21 W 59.84 16.11 W 77.62 17.78 W 97.51 19.89 W 120.76 23.25 2115.13 1965.80 2252.88 2065.80 2406.34 2165.80 2580.77 2265.80 2809.19 2365.80 1900 2000 2100 2200 2300 .00 601.92 S 37.t7 .00 696.42 S 42.49 .00 812.55 S 49.18 .00 955.02 S 58.69 .00 1159.70 S 69.84 ,W 149.33 28.57 W 187.08 37.75 W 240.54 53.46 W -314.97 74.42 W 443.39 128.42 3188.36 2465.80 3587.05 2565.80 3984.23 2665.80 4384.05 2765.80 4811.58 2865.80 2400.00 1524.90 S 81.78 2500.00 1910.71 S 90.67 2600.00 2294.45 S 112.57 2700.00 2680.71 S 137.79 2800.00 3095.51 S 163.65 W 722.56 279.17 W 1021.25 298.70 W 1318.43 297.18 W 1618.25 299.82 W 1945.78 327.53 5237.83 2965.80 5671.97 3065.80 6090.33 3165.80 6383.05 3265.80 6586.72 3365.80 2900.00 3000.00 3100.00 3200.00 3300.00 3509.16 S 187.67 3929.95 S 224.88 4334.14 S 265.09 4608.60 S 275.20 4785.72 S 282.87 W 2272.03 326.25 W 2606.17 334.13 W 2924.53 318.37 W 3117.25 192.72 W 3220.92 103.67 SPE. -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION, INC. MILNE POINT / MPH-09 500292280400 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/97 DATE OF SURVEY: 091197 JOB NUMBER: AK-MM-70265 KELLY BUSHING ELEV. = 65.80 FT. OPERATOR: BP EXPLORATION, INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 6764.51 3465.80 3400.00 4932.45 S 290.71 W 3298.71 6922.03 3565.80 3500.00 5053.91 S 297.01 W 3356.23 7063.28 3665.80 3600.00 5153.42 S 302.60 W 3397.48 7197.58 3765.80 3700.00 5243.04 S 304.31 W 3431.78 7330.34 3865.80 3800.00 5330.35 S 305.12 W 3464.54 77.79 57.52 41.25 34.30 32.76 7462.06 3965.80 3900.00 5416.09 S 305.98 W 3496.26 7593.18 4065.80 4000.00 5500.88 S 307.17 W 3527.38 7723.88 4165.80 4100.00 5585.03 S 308.68 W 3558.08 7854.30 4265.80 4200.00 5668.71 S 311.01 W 3588.50 7915.00 4312.24 4246.44 5707.79 S 312.04 W 3602.76 31.73 31.12 30.70 30.42 14.26 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS STATE OF ALASKA ALASKA O,-~.-~AND GAS CONSERVATION COM~'~,-~r~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown [~ Pull Tubing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2805' NSL, 4175' WEL, SEC. 34, T13N, R10E, UM At top of productive interval 2543' SNL, 4480' WEL, SEC. 02, T12N, R10E, UM At effective depth 2833' SNL, 4489' WEL, SEC. 02, T12N, R10E, UM At total depth 2903' SNL, 4487' WEL, SEC. 02, T12N, R10E, UM []Stimulate [] Plugging [] Perforate [--~Alter Casing [~ Repair Well [] Other Change Out ESP 5. Type of well: [] Development [-] Exploratory I--] Stratigraphic BI Service 6. Datum Elevation (DF or KB) KBE = 65.8' 7. Unit or Property Name Milne Point Unit 8. Well Number MPH-09 9. Permit Number / Approval No. 97-165 10. APl Number 50-029-22804 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 7915 feet true vertical 4312 feet Effective depth: measured 7806 feet true vertical 4229 feet Casing Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Length Size Cemented 80' 20" 250 sx Arcticset I (Approx.) 7859' 7" 1357 sx PF 'E', 120 sx 'G', 100 sx PF 'C' Perforation depth: measured 7360' - 7380', 7524' - 7554', 7602' - 7632' true vertical 3888' - 3903', 4013' - 4036', 4073' - 4095' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 7129' MD TVD 112' 112' 7890' 4293' Packers and SSSV (type and measured depth) Gravel Pack Screen Assembly with one 7" HES Versatrieve packer at 7203', 7" HES Iso packer assembly at 7388' and one 7" HES 'BWD' sump packer at 7563' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [] Oil ~ Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .¢('_ -- ~ TerrieHubble ~//1~./~..~_.. - Title TechnicalAssistantlll Prepared By Name/Number: Terrie Hubble, 564-4628 ~ Fn Form 10-404 Rev. 06/15/88 Progress Report Facility M Pt H Pad Well MPH-09 Page 1 Rig ~ ~:X~l'~ q~S Date 10 February 99 Date/Time 19 Aug 98 20 Aug 98 21 Aug 98 22 Aug 98 06:00-06:15 06:15-08:30 08:30-12:00 12:00-14:30 14:30-16:00 16:00-17:00 17:00-17:15 17:15-19:30 19:30-19:45 19:45-20:45 20:45-21:00 21:00-21:15 21:15-22:00 22:00-23:30 23:30-02:00 02:00-03:30 03:30-04:30 04:30-04:45 04:45-05:30 05:30-06:00 06:00-06:30 06:30-12:00 12:00-13:00 13:00-16:00 16:00-17:00 17:00-18:00 18:00-20:00 20:00-21:00 21:00-22:00 22:00-22:30 22:30-00:30 00:30-01:00 01:00-02:00 02:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-10:00 10:00-10:30 10:30-12:45 12:45-13:30 13:30-14:00 14:00-17:00 17:00-17:30 17:30-18:30 18:30-18:45 18:45-22:00 22:00-00:30 00:30-01:30 01:30-02:30 02:30-06:00 06:00-06:15 06:15-06:30 06:30-12:30 Duration 1/4 hr 2-1/4 hr 3-1/2 hr 2-1/2 hr 1-1/2 hr lhr 1/4 hr 2-1/4 hr 1/4 hr lhr 1/4 hr 1/4 hr 3/4 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1 hr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 5-1/2 hr lhr 3 hr 1 hr 1 hr 2 hr 1 hr lhr 1/2 hr 2 hr 1/2 hr 1 hr 4 hr 1/2 hr 1 hr 1/2 hr 2 hr 1/2 hr 2-1/4 hr 3/4 hr 1/2 hr 3 hr 1/2 hr 1 hr 1/4 hr 3-1/4 hr 2-1/2 hr 1 hr 1 hr 3-1/2 hr 1/4 hr 1/4 hr 6 hr Activity Held safety meeting Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Drillfloor / Derrick Rigged up High pressure lines Retrieved Hanger plug Bleed down well Circulated closed in well at 7077.0 ft Monitor wellbore pressures Circulated at 7077.0 ft Monitor wellbore pressures Installed Hanger plug Removed Xmas tree Installed BOP stack Tested All functions Retrieved Hanger plug Rigged up Tubing handling equipment Held safety meeting Retrieved Tubing hanger Circulated at 7057.0 ft Circulated at 7057.0 ft (cont...) Pulled Tubing in stands to 2265.0 ft Serviced Drillfloor / Derrick Pulled Tubing in stands to 41.0 ft Rigged down sub-surface equipment - Electrical submersible pumps Made up BHA no. 1 R.I.H. to 6975.0 ft Singled in drill pipe to 7202.0 ft Reverse circulated at 7190.0 ft Laid down 222.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 3.0 ft Pulled BHA Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment ~ Tool run (cont... Rigged down Slickline unit Made up BHA no. 2 R.I.H. to 7198.0 ft Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Laid down 222.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 3.0 ft Pulled BHA Rigged up Completion string handling equipment Held safety meeting Serviced Electrical submersible pumps Ran Tubing in stands to 4130.0 ft Serviced Block line Rigged up sub-surface equipment - Other sub-surface equipment Ran Tubing in stands to 5220.0 ft Held safety meeting Serviced Drillfloor / Derrick Ran Tubing in stands to 7095.0 ft Progress Report Facility M Pt H Pad Well MPH-09 Rig (null) Page 2 Date 10 February 99 Date/Time 12:30-13:00 13:00-14:00 14:00-16:00 16:00-16:45 16:45-17:00 17:00-18:00 18:00-18:15 18:15-19:00 19:00-19:30 19:30-20:30 20:30-20:45 20:45-21:00 21:00-22:30 22:30-23:00 Duration 1/2 hr 1 hr 2hr 3/4 hr 1/4 hr 1 hr 1/4 hr 3/4 hr 1/2 hr 1 hr I/4 hr 1/4 hr 1-1/2 hr 1/2 hr Activity Rigged up Tubing hanger Ran Tubing to 7117.0 fi (2-7/8in OD) Serviced Electric cable Ran Tubing on landing string to 7117.0 ft Installed Hanger plug Removed BOP stack Held safety meeting Removed BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Installed Hanger plug Freeze protect well - 20.000 bbl of Diesel Removed High pressure lines Progress Report Facility M Pt H Pad Well MPH-09 Page 1 Rig Nabors 4ES Date 10 February 99 Date/Time 12 Nov 98 13 Nov 98 14 Nov 98 15 Nov 98 09:30-11:30 11:30-18:00 18:00-19:30 19:30-22:00 22:00-22:30 22:30-00:30 00:30-01:00 01:00-01:30 01:30-02:30 02:30-03:00 03:00-05:00 05:00-06:00 06:00-12:30 12:30-14:00 14:00-14:30 14:30-15:00 15:00-17:00 17:00-19:30 19:30-20:00 20:00-20:30 20:30-21:00 21:00-22:30 22:30-03:30 03:30-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-18:00 18:00-18:15 18:15-19:30 19:30-21:30 21:30-01:30 01:30-02:00 02:00-03:00 03:00-03:30 03:30-04:30 04:30-04:45 04:45-05:00 05:00-05:45 05:45-06:00 06:00-06:15 06:15-06:30 06:30-07:00 Duration 2hr 6-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr 1 hr 1/2 hr 2hr 1 hr 6-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2hr 2-1/2 hr 1/2 hr 1/2hr 1/2 hr 1-1/2 hr 5hr 2-1/2 hr 1/4 hr 1/4 hr 1 hr 10-1/2 hr 1/4 hr 1-1/4 hr 2 hr 4 hr 1/2 hr 1 hr 1/2 hr 1 hr 1/4 hr 1/4 hr 3/4 hr 1/4 hr 1/4 hr 1/4 hr 1/2 hr Activity Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Drillfloor / Derrick Installed High pressure lines Retrieved Hanger plug Rigged up Lubricator Tested Lubricator Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Installed High pressure lines Reverse circulated at 7117.0 ft Circulated at 7117.0 fl Circulated at 7117.0 fl (cont...) Monitor wellbore pressures Installed Hanger plug Removed Xmas tree Installed BOP stack Tested All functions Retrieved Hanger plug Installed Tubing retrieval string Retrieved Tubing hanger Tested Hanger penetrator Pulled Tubing in stands to 4117.0 fl Rigged up sub-surface equipment - Electric cable Held safety meeting Serviced Drillfloor / Derrick Rigged up sub-surface equipment - Gas injection line Ran Tubing in stands to 6637.0 fl Held safety meeting Ran Tubing in stands to 7087.0 fl Ran Tubing to 7109.0 fl (2-7/8in OD) Serviced Electric cable Ran Tubing on landing string to 7129.0 ft Removed BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Installed Hanger plug Installed High pressure lines Freeze protect well - 14.000 bbl of Diesel Held safety meeting Freeze protect well - 14.000 bbl of Diesel Rigged down High pressure lines To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPH-09, A142-MM-70265 April 1, 1998 1 LDWG formatted Disc with verification listing. API#: 50-029-22804-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: ~/1/q _~tD_ Signed.~~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11961 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 3~26/98 Well Job # Log Description Date BL RF Sepia LIS Tape MPH-09 ~ '~'~ 98162 1GRPASS 980128 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 c ~ of Alaska AlaSka Oil & Gas Conservation Comm. Atten' Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to' Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 01-Feb-98 Well Name ',Services Bluelines i R/F Sepia Film MPF-34 ~SBT/GR 1 1; ' MPH-09 iSTATIC PRESSURE 1 1 1 MPH-09 i PFC/PERF 1 1; ;GR/CCL 1 1 MPH-09 MPH-12 PFC/PERF 1 MPH-12 STATIC PRESSURE 1 1 0' MPH-09 STATIC PRESSURE 1 1 0 MPH-09 ~GR/CCL PERF ~ 1 1 0 MPH-09 ;GR/CCL SETTING SRVS i 1 1 0 il Rece~ved~ Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 3, 1997 Chip Alvord Senior Drilling Engineer BPX Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPH-09 BPX Exploration (Alaska) Inc. Permit No. 97-165 .,. Sur. Loc 2805'NSL, 4175'WEL, Sec. 34, T13N, R10E, UM Btmhole Loc. 2576'NSL, 4508'WEL, Sec. 02, T12N, R10E, UM Dear Mr. Alvord: 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) 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 test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · ~hyai~7~~R OF~TH )SION dlffenclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. --- STATE OF ALASKA : ALASKA L -AND GAS CONSERVATION CON,. .:SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. 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 KBE = 41.5' Milne Point Unit / Schrader Bluff 3. Address i6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 ~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2805' NSL, 4175' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 2815' NSL, 4493' WEL, SEC. 02, T12N, R10E, UM MPH-09 At total depth 9. Approximate spud date Amount $200,000.00 2576' NSL, 4508' WEL, SEC. 02, T12N, R10E, UM 09/04/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025627, 772'I No Close Approach 2560 7812' MD /4202' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' Maximum Hole Angle 80-32° Maximum surface 1303 psig, At total depth (TVD) 3747' / 1680 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1 # H-40 Weld 80' 32' 32' 112' 112' 260 sx Arctic Set (Approx.) 8-1/2" 7" 26# L-80 BTC-Mod 6992' 31' 31' 7023' 4271' 798 sx PF 'E', 106 sx 'G', 100 sx PF 'C' 19. To be completed for Redrill, Re-entry, and Deepen Operations. AUG 2 c~ Present well condition summary Total depth: measured feet Plugs (measured) ~'~ 0il ,& Gas Cons, .6o. mmiss' true vertical feet ' ' ~nci?Qrage Effective depth: measured feet Junk (measured) ' true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface ~nrt°%u%etidSante 0 RIG INA L Liner Perforation depth: measured 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: James Robertson, 564-5159 or Chip Alvord, 564-4089 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 Chip Alvord ~.~~.~ 1~ ~~ Title Senior Drilling Engineer Date 2/(z,9 Commission Use Only Permit Number I APl Number Approval Date I See cover letter c~ '~ _ / ~-' 50- O~ q - ~ ~L ~ OW Y~'"-~7 for other requirements Conditions of Approval: Samples Required []Yes I'~No Mud Log Required []Yes Hydrogen Sulfide Measures []Yes [~No Directional Survey Required [~Yes [] No Required Working Pressure for DOPE ~2M; I'-I3M; 1--15M; [-I 10M; I--I 15M Other: Or,gmat 5igneo o~ J by order of Approved By David W. Johnston Commissioner the commission DateF-~'" Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): J. E. Robertson IMP H-09 Well Plan Summary ISCHRADER BLUFF PRODUCER 564-5159 Surface Location: 2805 FSL, 4175 FEL, S34 T13N R10E UM Target Location: 2815 FSL, 4493 FEL, S02 T12N R10E UM Bottom Hole Location: 2576 FSL, 4508 FEL, S02 T12N R10E UM I AFE Number: 1337096 Estimated Start Date: I 04SEP 97 I I Rig: I Nabors22E Operating days to complete: I MD.' I ITvD: I® I I Well Design: Formation Markers: 16.0 I KBE: 141.5 Schrader Bluff Producer Formation Tops MD TVDSS KOP 3OO 258 Base of Permafrost 1818 1725 Top of Ugnu Top M Sand 7253 3607 Top NA (Target) 7334 3747 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 7360 3770 NCND 7397 3802 NE 7416 3818 NF N/A N/A OA 7506 3896 OA4 N/A N/A OB 7576 3957 Top of Seabee 7612 3988 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 7812 4161 TD at 200' MD past base of Schrader Casin~l/Tub in~ Pro~ram: Hole ~ize Csg~ Wt/Ft Grade Conn. Length Top Bottom Tb~l O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112' / 112' 8-1/2" 7" 26# L80 BTC-Mod 6992' 31 '/31' 7023' / 4271' Pipe Specifications: O.'D. Wt/Ft Grade Conn. ID Area Tensile Max Pull Collapse Burst (bbl/ft) (kips) (80% TR) (psi) (psi) 20" 94# H-40 Weld 19.124" 0.3552 40.0 32.0 520 1530 7" 26# L-80 BTC-Mod 6.276" 0.0382 80.0 64.0 5410 7240 5" 19.5# G (Pr) 4-1/2" IF 4.276" 0.0178 436.1 348.9 8765 12163 5" 19.5# E (Pr) 4-1/2" IF 4.276" 0.0178 311.5 249.2 7041 8688 Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/ft) to the reservoir at +3747' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1680 psi (8.62 ppg EMW), is 1303 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: MWD from surface to TD LWD (GR/Resistivity) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals. Cased Hole Logs: GR/CCL with the completion rig.) Mudloggers are NOT re¢ uired for this well. Mud Program: Spud Mud I Special design considerations I See "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diver[er Line. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I 300', S-shaped profile IMaximum Hole Angle: Close Approach Well: 80.32 NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on H-Pad have been permitted for annular injection. AUG 29 MP H-09 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test diverter system. Build Spud Mud. 5. Drill 8-1/2" surface hole as per directional plan to 7,812' MD / 4,202' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity from the top of the Ugnu to TD. NOTE: Short trip no deeper than 300' MD past the base of permafrost. After the base of the permafrost, trips should be made every 1000'-1300' MD, or as hole conditions require. NOTE: Drill at a controlled rate of no more than 200 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing with centralizers appropriately placed as per program. 9. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost (2100' md). Displace STAGE1 cement with seawater at 8.0-10.0 bpm. NOTE: Reciprocate pipe while pumping cement if possible/practical. After opening the ES cementer, circulate seawater a minimum of 2 hours before pumping the STAGE2 cement slurry. Displace the second stage with diesel. 10. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: See the latest Milne Point H-Pad Data Sheet prepared by Pete Van Dusen for information on H pad. Particularly close attention should be paid to hydrate experiences on previous H-Pad wells. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: HYDRATES WERE ENCOUNTERED ON MP H-14 AND MP H-10. PLAN ON LECITHIN TREATMENT AS WELL AS WEIGHTING UP TO AN APPROPRIATE MUD WEIGHT TO MANAGE THE HYDRATES. 9.8 PPG WORKED ON MP H-14. Lecithin (DrillTreat) should be added to the mud system as a precaution before drilling through the base of the permafrost. If hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MP H-09. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. MPH-05 experienced lost returns at 3708' TVDSS while drilling with heavy 11.5 ppg mud that was used to deal with hydrates. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on H-Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 8. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7" annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. Plan on using a 'C' cement for the second stage tail cement due to probability of hydrates. MP H-09 7" SURFACE/PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ,,, 80°F SPACER: 50 BBL Weighted Spacer/Weighted to TD mudwei~ht). 'STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: FLOCELE (0.25 #/sk) WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sk APPROX #SACKS: MIX WATER: 11.63 gal/sk 408 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL AT 6753' MD TO THE ES CEMENTER STAGE TOOL (2100' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) WEIGHT: APPROX #SACKS: FLUID LOSS: 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 106 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (7812' MD) TO 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (7253' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. EST TOC 6753' MD STAGE2 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk 390 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM TOP OF STAGE2 TAIL AT 1670' MD TO SURFACE +300% EXCESS. STAGE2 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'C' PERMAFROST YIELD:0.95 ft3/sk MIX WATER: 3.60 gal/sk 100 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 430' OF ANNULAR VOLUME AT 30% EXCESS FROM ES CEMENTER AT 2100' MD. EST TOP 'C' 1670' MD Retarder 15.6 ppg WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - one (1) per joint on the bottom twenty-three (23) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (23+2 = 25 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 7.0-8.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. Ensure that the seawater has been treated with biocide and is relatively "bug-free." 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate seawater through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. Anadrill Schlumberger Alaska D£sCrict l£11 Bast 80th Avenue Allchorage, AK 99518 (907} 349-4511 Pax 344-2160 DIRHCTIONAL WELL PLoXN for SHARESJ S~RVICHS DRILGING Well ......... : MPR-09(P3) Field ........ : Milne Polar, H-?ad Co~putation..: MinimumCurvatuTe Units ........ : PEBT Surface l~at..: $0.43785030 N Surface Lo~g.: 149.53955~30 W Le~aL Description Suriace ...... : 2805 FSi 4L75 F~ S34 T13N R/0E UM Target ....... : 2835 ~SL 4493 F~h S02 T12N Rl0E tim BHL .......... : 2596 ~SL 4508 FRL S02 ?12N RI0E UM IDRNT£FICATXON DB?TH KB 0.00 0.00 KOP/Blll~.d) 1.5/[00 300.00 0.O0 400 .Oo ~ .50 BU~ 2/100 H00.O0 3.00 600.00 S.OO SUXh .~. 6/100 700.00 7.00 ~ 800.00 9.50 'o ~"'~ ~ oo. o o ~2. o o ~' c: ~ looo.oo ~ .5o ~ ~. ~,.~, ~ 1Loo. oo 17. O0 ~ O L200 O0 19.58 .~.~ ~ . CO ~'"~ 1300. O0 22.00 IdJCATION8 - AI~%SKA Zone: 4 X-Coord ¥-¢oord 556470.40 6009955-55 5~6196.00 6004684.00 ~6L83.57 6004445.21 DZRHCTION AZIMUTH 0.~0 0.00 ~e~.~l 383.41 183.4L 183.4! 183.43 183.41 L83.41 183.4L PROPOSHD WHLL PROP/LB ~HRTECAL - D~ PT'HS TVD SUB-SEA 0.00 -66.40 300.00 233.60 399-99 333.59 499.91 431.51 599.66 $33.~6 699.11 798.06 ~96.~o 993.63 L089.87 632.71 733.66 829,90 927.23 1023.47 Prepared ..... : 20 Aug 1997 vert sect az.: 183.41 KB elevation.: 66.40 ~agnetic Dcln: +2~.985 (R) 8caSe FacCor.: 0.99990362 Convergence..: +0.43386646 [ A:'--~--~,. F::R' [ k AKA-DPC FEASIBtL. 1TY PLAN i NOT APPROVED FOR EXECUTION ) PLAN $ :' SHCT IOl~ COORD£NATBS- FROM DH PART WELLHHAD 0.00 O.OO N 0.00 E -0.00 0.00 ~ O.00 E 1,3~ 1.3~ ~ 0.0~ ~.2~ ~ .23 ~ 0.33 ~ ~2.23 12.1~ 8 0.73 ALASKA Zone 4 TOOL Dh/ X Y FACE 100 556470.40 6009955.55 HS 0.00 556470.40 6009955.55 177~ 556470.33 6009954.24 177L 1.50 556470.~3 6009950.32 177L 1.50 556~69.77 6009943.36 l~TL 2.00 22.66 22.62 S 37.01 36.94 S. 55.66 55-56 S 78.58 78.44 S 105.72 105.53 S 1,35 W 556469.22 6009932.92 HS 2.00 2,20 W 556468.88 6009918.59 HS 2.50 3.3L W 556467.51 6009899.97 RS 2.fi0 4.68 W 556466.32 6009871.08 HS 2.50 6.29 W 556464.90 6009849.98 HS 2.60 ., 1184,83 1118.43 137.04 J36.$9 S 8.16 W 556463.28 6009828.~1 HS 2.50 1278.34 121L.94 i72.46 172.L6 S 20.27 W 556461.44 6009783.34 HS ~.50 (Anad~ll (c)97 MPH09P3 3.0C 9:56 .. Z ]> -0 NPH-09(eS] 20 Aug ~99T ~age 2 STATION IDHNTIFICATION Z · . END 3.5/L00 BUILD DROP 4/100 MEASURE0 1400.00 1500.00 1600.00 1700.00 1800.08 1860.42 1890.28 1920.42 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 PROPOSED ~ELL PROFILE INCL~I DIRECT[ON VHRTfCAL-DSPTH$ SECTION ANGLE AZIMUTh{ TVD SUB-SEA DHPART 24.50 183.41 1370,21 £303.81 211.93 27.00 183.4/ 3460,27 1393,89 255,37 29,50 183.41 1548.35 1481.95 ~02.70 32.00 183.43 1634.29 1567.89 353.83 ]4.50 183.41 1717.93 1651.53 408.65 COORDINATES-FROifl WELLHEAD 21~.56 S 1~,62 254.92 S 15-2l 302,17 $ 18.02 353,20 3 23.07 407.93 S 36.81 183.41 1367.25 1900.85 443.53 442.7~ 36.01 183.41 1991.40 L725.00 461,08 460.26 36.01 £83.41 181~,78 I349.38 478,80 477.95 ~8.80 L83,41 3878.99 1812.59 527,14 526,20 42.30 183.41 1954.97 1888.57 592.13 591.O8 45.80 183.41 2026.84 1960.44 661.64 660.47 49.30 183.41 2094.33 2027.93 735.42 734.11 52.80 183.41 2157.19 2090.79 813.17 81L.73 56.30 183,41 2215.18 2148.98 894.61 893.03 59.80 183,41 2268,10 2201,70 979.45 977.71 2700.00 63.30 183.41 2315.74 2249.34 3067.36 1065.46 2800.00 66,80 183.4t 2357.92 2291.52 1158.00 t155.95 2900.00 70.30 183.41 2394.49 2~28.09 125[.06 ~248.8~ 3000.00 73,80 183.41 2425.3/ 2358.91 1346.18 3343.79 3100.00 77,30 183.4] 2450,27 238~.87 1443.00 1440.4~ 317[.50 79.80 183.4~ 2464.46 2398.06 15/3.06 1510.38 5893.80 79.00 183.41 2946.64 2880.24 4/92.43 4£84,97 5900.00 79.55 183.41 2947.74 2881,34 4i98.43 4[90.98 6000.00 75.55 183.41 2969,29 2902,89 4296,86 4288,43 6100.O0 71-55 t83,4l 2997,60 2931.20 4391,94 4384.15 ALASKA Zone 4 Y 556459.38 6009743,92 556457.13 6009700.55 556454.69 6009653.29 556452.0l 6009602.~q 24.33 W 556449.16 6809547.49 'BDO[ DL/ FACE [00 HS 2.50 }IS 2,50 H$ 2.50 HS 2 .SO 85 2.50 26,4l W 556447.35 6009512.66 ils 2.50 27.45 W 556446.43 6009495.14 HS 0.00 28.53 W 556445.51 6009477.44 HS 0.O0 31.39 W ~6443.00 6009429.10 HS 3.50 35.26 ~ 5564~9,62 6009364.28 HS ].50 39.40 W 556436.01 6009294.86 lis 43.79 W 556432.18 6009221.20 HS 48.42 W 556428.~3 6009143.56 HS 53.27 W 656423.90 6009062.23 HS 58.32 W S56419.49 6008977.52 Ha 3.50 3.50 3.50 3.50 3~50 63.55 W 556434.92 6008889.94 ~S 3.50 68.95 W 556410.23 6008799.22 HS 3.50 74,49 W 556405.37 6008706.30 HS 3.50 80.16 W 556400.43 6008611.32 HS 3.50 85.92 N 556395.40 6008514.64 H$ 3.50 90.09 W 556391.76 6008444.68 HS 3.50 249.63 ~ 556252,49 6005969.21 LS 0.00 249.99 W 556252,~8 6005763.21 LS 4.00 255-80 263,S1 W 556242.~2 6005569.9q I.S 4.00 ]> Z 3> U i -U 6200.00 67.55 103.41 3032.52 2966.12 4485,63 4477.67 S 6300.00 63.55 183,41 3073,90 3007.50 4576.64 4568.52 S 6400,00 59,55 183.4L 3121.52 3055.12 4664.55 4656.27 S 267.09 W 55623'7.25 6005476.42 272.51 W 556232.52 600~385.54 277.74 W 556227.95 6005297.76 4.00 4.00 4.00 -U 3> ITl (Anadrll[ (c}97 ~PHogP3 3,0C 9:56 AM P) MPH-09 (]>3) STAT]20N £DENTI F£CATIO~ TOP UGNII END 4/100 DROP' TARGET MEASUREO DE?TH 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7092.44 7100.00 7138.84 7338.84 ANGLE 55.55 SI.SS 47.55 43.55 39.55 35 ,SS 31,86 31.55 30.00 30.00 PROPOSED ~ELb PROFILE DXRECT/ON AZIMUTH 183.42 [83.43 183-41 L83.4l 183.4£ 183.41 183.4L 183.41 183.43 183.41 20 Au9 199'; Pacje 3 ___ VERTICAL-DEPTHS SECTION C00RD/NATES-FRDM ALASKA Zone 4 TOOL DL/ TVD SUB-SEA DEPART ~ELL~8AD X Y PACE k00 3375.16 3L08,76 4748.92 4740,50 $ 282.76 ~ 556223,56 6005213.5L LS 4.00 3234.56 3168.16 4829.35 4820.?8 S 287.55 N 556239.]8 6005133,20 X,S 4.00 3299.42 3233.09 4905.43 4896.73 S 292.08 W 556215.43 6005057,22 LS 4.00 3369.43 3203.03 4956.81 4967.98 S 296.33 W 55621L.~2 600~985.95 LS 4.00 3444.25 3375.05 5043.23 5034.18 S 300.28 N 556208.27 6004919,73 LS 4,00 3523,51 3457.1L 5104.06 5095.0/ S 303.91 N 555205,10 6004858.88 I.S 4,00 3600.40 3534.00 5155.35 5146.~1 S 306.96 H 556202.44 6004807.66 LS 4-00 3606.83 3540.43 5159.32 5150.17 S 307.20 W 556202.23 6004803.70 LS 4.00 3640.~9 3573.79 5179.20 5170.01 S 308.3~ W 556201.20 6004783.86 ~S 4-00 3813.40 3747.00 5279.20 5269.83 S 314.34 W 556196.00 6004684.00 HS 0.00 TOP SCHRADER / NA TOP M SA~D NC/ND NF OA O44 OB BASH SCHRADER 7358.84 7353,85 7365.39 7402.34 742fl.82 7473.94 75£0.89 7545.53 7581.32 76£7.~2 30.00 30.00 30.00 30.00 30.00 30. O0 30.00 30.00 30.00 30.00 183.41 183.4i ]83.4L 183.4L 183.4L 183 .41 183.4:1 183.41 1~3.41 183.41 38~3.40 3747.00 5279.20 5269,82 S 3L4.34 W 556196.00 6004684.00 HS 0.00 3826.40 3$60.00 5286.70 5277,3~ S 3£4.79 W 556295.6£ 6004676.5:1 H$ O.00 3836.40 3770.00 5292,47 5283.08 S 315,13 ~ 556195.31 6004670,74 HS 0.00 3868.40 3802.00 5310,95 530L.53 S 316.23 N 556194.35 6004652.29 RS 0.00 3884.40 3818.00 5320.19 5310.75 S 316.78 W 556193.87 600~6{3.07 ~ 0.00 3930.40 3864.00 5346.75 5337.26 S 313.36 W 556192.49 60046L6.55 HS 0.00 396~.40 3896-00 5365.22 5355.70 S 3~9246 W 556L91,53 6004598.10 HS 0.00 3992.40 3926.00 5382.54 5372,99 S 320,49 ~ 556190.63 6004580.80 ~S 0,00 4023.40 3957.00 5400.44 5390.~6 $ 321,56 ~ 556189.70 6004562.93 RS 0.00 4054.40 3988.00 5418.34 5408.~2 S 322.62 N 556188.77 6004545.06 HS 0.00 Z C) 7" CAS]NG POINT TD 7817.12 7817.12 30,00 30,00 183.41 :183.4L 4227.61 4L61,2~ 5518.34 5508.55 S 318.58 N 556183.57 6004445.2£ 0.00 422~,61 4L61.2L ~SL8.34 ~0~.55 $ 32~.S~ W 576L83,57 6004445.2L 0.00 ANADR1LL AKA-DPC i FEASIBIL, ITY PLAN NOT APPROVED FOR. EXECUTION PLAN <_A~_adrill (c}97 MPH09P3 3.0C 9;56 AM P) Vi:~..~.~ ................................................................................... ~ ............. ~<,-,:,_-.~% ~ .... SHARED SERVIOES 'DRILLING', MPH-09 (P3) I *,,l_~n,~', ' VEHI IUAL UEUI 1UN V lb~ ,-,~ ~,- ,_..,,:,L L AKA-DPC · F.'~A~IRI! ITY_Pl AN Section at: AP! TVD Scale.' 1 inch = B00 feet ~ ~" Dep Sca~e.' ~ ~nch = 800 feet __ EXBZUT · '~" ., ~rker IdentSfication MD BKB SECTN INCL) A) KB 0 0 0 B) KDP/BU[LD 1.5/(DO 3QO 3DQ -0 C) BUILD 2/~00 ~0 500 5 3. ' D) BUILD 2.5/~00 700 699 23 E) END 2.5/)00 BUILD )960 ~767 444 36.~ F) ~ILD 3.5/~00 1920 ~B~6 479 ~.0 G) E~ 3.5/~00 BUILD 317~ 2464 1573 79.8( ~~ H) DRDP 4/~00 ~94 2947 4192 79.81 ..... J .... 6 ~'- ~-~-0~ I) END 4/100 BROP 7~39 3640 5179 J) TA~El 7339 38~3 5279 30.0 K) 7" CASING ~INT 7817 4229 55~B 30.0 L) rD 7817 4228 55~8 30.0 ' f~ U6N~ ~o ~ ........................ __ ~E -- :~~'~.~_ -- . ....... ~===ss- -=~-- :----- L~ l, K ~ ' ......... ~ .............. ~ .......... ~ ............... '.. ~ ................ ~ ............................................................. ~_~ ......................... I 0 400 IAnadri]L (£)97 NPflO~P3 3.0C 9:59 iH P) 800 1~00 S§O0 2000 24013 2800 32-00 3F:A)O 4UUIJ 44UU qUk)U ... Sect ion Depa. rture . z u "o 3> pi PAGE 10 SHARED SERV ICES DR ILL I NG VERTICAL SECTION VIEW '~ Section TVO Scale.' I inch = ~00 feet ~o-Oep S6818.'. 1 ~nch = ~100 feel Orawn ' 20 Aug 1997 '~nadriJ] Sch]um~rge( ~ N~rker Identification .N0 BK8 SEOTN INCLi lO -T~ g~ ~ -- -' _~ A) END 4/t00 OROP 7139 3640 5179 30.0' B) TARGET 7339 3813 5~79 30.0~ C) 7, CASING POINT 7817 42~8 5518 30.0~ ,0- , - D) TO 7817 4228 5518 30.0~. . ~ ¢;~T APP (OV,ED FOR .... 5000 5050 5100 5150 5800 5250 5300 5350 5400 5~50 5500 5550 5600 5650 Sect ion Departure 5700 i SHARED SERVICES DRILLiN8 Marker Identification MO N/S E/W A) KB 0 0 N B) KOP/BUILD ~.§/100 300 0 N C) BUILD 2/100 500 5 S D) BUILD 2.5/~00 700 23 S EJ ENO 2.5/~00 BUILD tB60 443 S F) BUILD 3.5/100 1920 478 S 6) ENO 3.5/t00 BUILD 3i71 i510 S HI OROP 4/100 5894 418§ S Ii ENO 4/i00 DROP 7t39 5t70 S J) TARGET 7339 5270 S K) 7' CASING POINT 7817 5509 S L) TD 7817 5509 S 26 w 29 w 9o w 250 W 30B W 3~4 w 329 w 329 w SCALE ....... : J inch = ~000 feet DRAWN. ' 20 Aug 1997 MPH-09 (P3) PLAN VlE[q i CLOSURE.: .... : 5518 feet et Azimuth 183.4 DECLINATION.' +27.985 (E) ' , AnadrJ ]] Schlumberger, ' 0 i ! k~y~ DRILL ....... . .......... AKA-J:'P,C t ' FEASIBILI fY i~LAh , N~DT )~PPROVE'D FCR~ ' - . .... J,.,.,.,m.,~' .~'--'--"--~ ~.~_ .~ ,a ...... _.et ( u LO0 feet . .... ~ m mmm . 3500 3000 2500 2000 i500 tO00 500 0 500 ~000 ~500 2000 2500 3000 ~3500 <- WEST' EAST -> , mil mi _ _ ~a~r~H [c197 WPHOg~ ~,~ ~ t6 ~ P) D{TE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET I ~_~;7'2997 CK07299/~ i00. O0 i00. O0 THE A~ACHED CHECK IS IN PAYME~ FOR ~MS DE~RIBED ABOVE. ~~!1~ ~ ~ =~ ~:~ ~ ~_~ ~. ~. · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~""'~ .~'"'/~ ~ INIT CLASS b ~X WELL NAME · /- ,/~/2~ _ 0 ~ PROGRAM: exp [] dev J~redrll [] serv [] wellbore seg LI ann. disposal para req 0 GEOL AREA d~ ~0 UNIT# / / _:~ ~ ? ON/OFF SHORE ~/,"'L ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. DAT, E 12. ,~'/,~ ~ 13. Permit fee attached ....................... (~ N Lease number appropriate ................... (~N Unique welt name and number .................. Well located in a defined pool .................. (~ N Well located proper distance from drilling unit boundary .... (~ N Well located proper distance from other wells .......... ~. N Sufficient acreage available in drilling unit ............ N If deviated, is wellbore plat included ............... q~ N Operator only affected party ................... ~~. N Operator has appropriate bond in force .............. N Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... (~ N ENGINEERING APPR 14. 15. 16. 17. 18. 19. 20. 21 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... (~N Surface casing protects all known USDWs ........... ~NNN N CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... ~,~N~ Adequate tankage or reserve pit ................. · If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. [ ) N If diverter required, does it meet regulations .......... "( ) N Drilling fluid program schematic & equip list adequate ..... N BOPEs, do they meet regulation /(, ) N BOPE press rating appropriate; te'st't~ ' ' "2~' ' ' I~sigC. ) N Choke manifold complies w/APl RP-53 (May 84) ........ ~ ) N Work will occur without operation shutdown ........... ~ ) N Is presence of H2S gas probable ................. )N GEOLOGY APPB 30. Permit carl be issued w/o hydrogen sulfide meas .~ee-'"~'~.... Y N 31. Data presented on potential overpressur~ ....... Y N 32. Seismic analysis of shallow~ ............. Y N 33. Seabed con--if off-shore) ............. Y N 34. Co e/phone for weeklypro.qress reports ....... Y N [exploratory only] REMARKS GEOLOGY: RPC~ ENGINEERING: COMMISSION' B EW~)z~.. ?/~:4¢~ ~' DWJ~ J D H__~ ~NC~_ Comments/Instructions: HOW/IjI - A:\FORMS\cheklist ~ev 07~97 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. Sperry-Sun Drilling Services LIS Scan Utility Mon Mar 30 15:18:46 1998 Reel Header Service name ............. LISTPE Date ..................... 98/03/30 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 ..................... 98/03/30 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 UNIT 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 MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-70265 TOBIAS LOCKWOOD 500292280400 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 30-MAR-98 34 13N 10E 2805 4175 .00 65.80 36.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 20.000 112.0 PRODUCTION STRING 8.500 7915.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBES, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 4. ALL MWD RUNS REPRESENT MPH-09 WITH API# 50-029-22804-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7915'MD, 4312'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PAHSE 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 FOR RESISTIVITY SENSOR. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE ROP FET RPD RPM RPS RPX GR $ Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 START DEPTH 4850 0 4851 5 4851 5 4851 5 4851 5 4851 5 4859 5 STOP DEPTH 7915 0 7855 5 7855 5 7855 5 7855 5 7855 5 7863 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 4910.0 7915.0 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMI~ 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 4850 16 7821 0 7007 0 6856 0 4769 0 4142 7 5345 0.16 Max Mean 7915 6382.5 116.366 60.8963 2000 11.7576 2000 10.7134 2000 9.016 2000 9.98386 2100.11 233.487 15.8356 0.933881 Nsam 6131 6008 6009 6009 6009 6009 6131 6009 First Reading 4850 4859.5 4851.5 4851.5 4851.5 4851.5 4850 4851.5 Last Reading 7915 7863 7855.5 7855.5 7855.5 7855.5 7915 7855.5 First Reading For Entire File .......... 4850 Last Reading For Entire File ........... 7915 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/30 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 ....... 98/03/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP FET RPD RPM RPS RPX GR $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4850.0 4851 5 4851 5 4851 5 4851 5 4851 5 4859 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 7855 7855 7863 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) : STOP DEPTH 7915 0 7855 5 7855 5 7855 5 5 5 0 ll-SEP-97 5.06 5.46 MEMORY 7915.0 4910.0 7915.0 39.9 76.8 TOOL NUMBER P0834CRG6 P0834CRG6 8.500 8.5 SPUD 9.30 60.0 9.0 8OO 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.4 3.300 2.790 3.000 3.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 AAPI 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHNiM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 28.9 Name DEPT ROP GR RPX RPS RPM RPD FET Min 4850 7 5345 16 7821 0 7007 0 6856 0 4769 0 4142 0.16 Max Mean Nsam 7915 6382.5 6131 2100.11 233.487 6131 116.366 60.8963 6008 2000 11.7576 6009 2000 10.7134 6009 2000 9.016 6009 2000 9.98386 6009 15.8356 0.933881 6009 First Reading 4850 4850 4859 5 4851 5 4851 5 4851 5 4851 5 4851 5 Last Reading 7915 7915 7863 7855.5 7855.5 7855.5 7855.5 7855.5 First Reading For Entire File .......... 4850 Last Reading For Entire File ........... 7915 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/03/30 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 ..................... 98/03/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * * . ****************************** * ............................ . ....... SCHLUMBERGER ....... * ............................ * ****************************** COMPANY NAME : BP EXPLORATION (ALASKA), INC. ~UELL NAME : MPH- 09 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292280400 REFERENCE NO '. 98162 Date~ ~ L'IS Tape Verification Listing Schlumberger Alaska Computing Center 25-MAR-1998 13:29 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/03/25 ORIGIN : FLIC REEL NA~E : 98162 CONTINUATION # : PREVIOUS REEL : CO~!ENT : BP EXPLORATION, MPH-09, MILNE POINT, API #50-029-22804-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/03/25 ORIGIN : FLIC TAPE NAME : 98162 CONTINUATION # : 1 PREVIOUS TAPE : COGENT · BP EXPLORATION, MPH-09, MILNE POINT, API #50-029-22804-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPH- 09 API NUMBER: 500292280400 OPERATOR: BP EXPLORATION (ALASKA) , INC. LOGGING COMPANY: WESTERN ATLAS TAPE CREATION DATE: 25-MAR-98 JOB NUMBER: 98162 LOGGING ENGINEER: E. MURPHY OPERATOR WITNESS: L. MEYER SURFACE LOCATION SECTION: 34 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 2805 FEL: 4175 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 65.80 DERRICK FLOOR: 64.80 GROUND LEVEL: 36.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 20. 000 112.0 26. O0 2ND STRING 7. 000 7890.0 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) ~ 25-MAR-1998 13:29 PAGE: 2 L'IS Tape Verification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMB~ : DATE LOGGED: LOGGING COMPANY: .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH $ REMARKS: THIS FILE CONTAINS THE LDWG FORMATTED CASED HOLE GR/CCL DATA AQUIRED BY WESTERN ATLAS ON BP EXPLORATION'S MPH-09 WELL. THE DATA HAS BEEN CLIPPED OF INVALID READINGS AT FIRST AND LAST READING. IT IS THE PRIMARY DEPTH CONTROL LOG FOR THIS WELL. $ $ **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE ' 98/03/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GR 7764.0 6596.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GR Li'S Tape Verification Listing Schlumberger Alaska Computing Center 25-MAR-1998 13:29 PAGE: RE~ARKS: THIS FILE CONTAINS THE CLIPPED DATA. THIS LOGH IS THE PRIMARY DEPTH CONTROL LOG FOR THIS WELL, SO IT HAS NOT BEEN SHIFTED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189704 O0 000 O0 0 1 1 1 4 68 0000000000 TENS GR LB 189704 O0 000 O0 0 1 1 1 4 68 0000000000 TEND GR LB 189704 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 189704 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 189704 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7764.000 CCL.GR 0.000 TENS.GR -40.592 TEND. GR 3139.511 GRCH.GR 55.152 ~ 25-MAR-1998 13:29 PAGE: 4 L~S Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 6596.000 CCL.GR 4.212 TENS. GR -999. 250 TEND. GR -999.250 GRCH. GR 31.334 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/03/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~J~RY VENDOR TOOL CODE START DEPTH STOP DEPTH 7778.0 6591.0 GR LOG HEADER DATA DATE LOGGED: 28 - JAN- 98 SOFTWARE VERSION: 3.1 TIME LOGGER ON BOTTOM: 300 28-JAN-98 TD DRILLER (FT): 7806.0 TD LOGGER (FT) : 7796.0 TOP LOG INTERVAL (FT) : 6596.0 BOTTOM LOG INTERVAL (FT) : 7764.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) L~IS Tape Verification Listing Schlumberger Alaska Computing Center 25-MAR-1998 13:29 PAGE VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : TOOL NUMBER ........... JCGR 7890.0 SEA WATER 8.40 80.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NOR2O. LIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. GA~IA RAY LOG RECORDED USING MARKED WIRELINE MEASUREMENTS. LOG WAS FOUND TO BE ON ON DEPTH WITH REFERENCE LOG, SPERRY SUN MWD DGR/EWR4 DATED 12-SEP-97. THIS FILE CONTAINS THE RAW DATA. $ LIS FORMAT DATA LiS Tape Verification Listing Schlumberger Alaska Computing Center 25-MAR-1998 13:29 PAGE: 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189704 O0 000 O0 0 2 1 i 4 68 0000000000 CCL GR V 189704 O0 000 O0 0 2 1 1 4 68 0000000000 GR GR GAPI 189704 O0 000 O0 0 2 1 1 4 68 0000000000 TEN GR LB 189704 O0 000 O0 0 2 1 1 4 68 0000000000 TTENGR LB 189704 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7764.000 CCL.GR TTEN. GR 3139.511 0.000 GR.GR 55.152 TEN. GR -40.592 ** END OF DATA ** LI~ Tape Verification Listing Schlumberger Alaska Computing Center 25-MAR-1998 13:29 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 98/03/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/03/25 ORIGIN : FLIC TAPE NAME : 98162 CONTINUATION # : 1 PREVIOUS TAPE : CO~ENT : BP EXPLORATION, MPH-09, MILNE POINT, API #50-029-22804-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/03/25 ORIGIN : FLIC REEL NAME : 98162 CONTINUATION # : PREVIOUS REEL : CO~!ENT : BP EXPLORATION, MPH-09, MILNE POINT, API #50-029-22804-00