Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
195-120
1 GENIE® • STATE OF ALASKA • %ry xtr ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ., li 'ilkql,if la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned Q . Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ❑ WINJ❑ WAGED WDSPL❑ No.of Completions: Service Q , Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC Aband.: 12/19/2017 195-120/316-474 • 3.Address: 7.Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 10/8/1995 50-029-22583-00-00 • 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2334'FSL,3785 FEL,SEC 33,T13N,R10E,UM 10/12/1995 MILNE PT UNIT 1-05 Top of Productive Interval: 9. Ref Elevations: KB: 64 17.Field/Pool(s): 2081'FSL, 1399'FEL,SEC.33,T13N, R10E, UM GL: 34.4 BF: N/A MILNE POINT/SCHRADER BLUFF OIL Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1939'FSL,755'FEL,SEC.33,T13N,R10E, UM Surface/Surface ADL0025906 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 551585 y- 6009449 Zone-ASP4 5,710'/4,403' N/A TPI: x- 553974 y- 6009213 Zone-ASP4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 554619 y- 6009075 Zone-ASP4 N/A 1,800'(Approx.)/1,774' 5. Directional or Inclination Survey: Yes u (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 sCANEFEB 1 5 2318 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 91.1 H-40 30' 112' 30' 112' 24" 250 sx 5-1/2" 17 L-80 29' 5,688' 29' 4,388' 8-1/2" 1,332 sx 24.Open to production or injection? Yes ❑ No Q 25.TUBING RECORD If Yes,list each interval open(MD/ND of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number;Date Perfd): 2-7/8" 4,743' 4,687'/3,745' pre -I GY3 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. _...--,--1--i--,----0— Was hydraulic fracturing used during completion? Yes❑ No Q Per 20 AAC 25.283(i)(2)attach electronic and printed information 0.11417- DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 3,497'-3,795' Tubing Punch Surface 100bbIs Cllass G Surface 28 Gallons Arctic Set Lite 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period —♦ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate — Form 10-407,' $4131 /2017 21 ,..2- V CONTINUED�ON�AGE 2 («D �� L� F`J _ L��iubmit ORIGINIAL o • • 28.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1,800' 1,774' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval information, including reports,per 20 AAC 25.071. NA Sands 4,848' 3,848' None NB Sands 4,889' 3,874' ND Sands 4,957' 3,917' NE Sands 4,974' 3,928' OA Sands 5,130' 4,026' Top West Sak'A' 5,238' 4,095' Formation at total depth: Scrader Bluff 31. List of Attachments: Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Contact Phone: 777-8412 Signature: Date:2/1/2018 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: 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 End Date MP 1-05 None 50-029-22583-00-00 195-120 12/12/17 12/20/17 Daily Operations: 12/12/2017 -Tuesday MIRU excavation equipment. Begin excavation. 12/13/2017 -Wednesday Remove cement from around outer annulus to new excavation point. 12/14/2017-Thursday No activity to report. 12/15/2017 - Friday Set trench box. Install wach saw. Cut casing at 4' below original tundra level. 12/16/2017-Saturday No activity to report. 12/17/2017 -Sunday No activity to report. 12/18/2017- Monday Inspector onsite.Take photos of casing stub. Weld marker plate on well.Take photos of marker plate. GPS location: 70° 26.177'N 149° 34.958'W 12/19/2017 -Tuesday Backfill location. Rig down. 12/20/2017-Wednesday Demobe equipment. • • s FP.� • a�,�yi s. 3 Y f.. �, ,44 44 k E 1,rp. t gra* ' 3+ ( "fit $;as �<'a zs es .� r tl?4. .,r 4 xr y, ', 44 4 S 8stk ,perk • s gat, . zip; i .,4° tes �: cad," 'p "�d'c,- � '"1"�,:q -a ` t m; k '''',::"Ii. to j��',' � a a�'"" s my t •Et Nz 6 a e c °I ' ''„ "€a , -p� ' a cv - t `' -._ �- c- �r L aK k•-1 r 'k 7,`i* § y' ° ' *4'""jii.'''4 .tt. ''- ' '4'44'441t,04"*4' ' -. *4, h � rt 11 e IP e, , § • • s� A f • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg M.112-(t1117 DATE: 12/18/2017 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector MPU 1-05 - Hilcorp Alaska LLC PTD 1951200 -' 1211812017: I traveled to Hilcorp's Milne Point Unit to inspect the final surface abandonment of MPU 1-05. Hilcorp reps Konrad Schruff and Micky Townsend met me on location with the information that I had requested. This well was previously abandoned (casing cut; marker plate installed) by BPXA on October 31, 2013 but the casing cutoff was not at the required depth below tundra. The October 31, 2013 effort was classified by AOGCC as a suspended well. I inspected the marker plate and it had the proper well name, oil company name, PTD, ' and API numbers. The plate diameter was 20 inches; thickness was 1/2-inch. I then inspected the cut off pipe and it was found full of good hard cement. The two inner casing string annuli had a darker colored cement but it was hard. The well was cut off a good 4+ feet below tundra level. The marker plate was placed on the well with no overhang. I witnessed them weld the plate to the casing stub. This represents the final surface abandonment for MPU I-05. ,- Attachments: Photos (2) SCANNED 4' g 2017-1218_Surface Abandon final MPU_I-05_bn.docx Page 1 of 2 r • • Surface Abandonment (Final) — MPU 1-05 PTD 1951200 Photos by AOGCC Inspector B. Noble 12/18/2017 . a `rRkx ^e* f uy ,h,„ , ' ,,., , . ., . . $....,.. , . . .0 1.t, ..„. .. ,,.. .. n *S t ' " �t 40#1if)*41 1'— ''' :1 /war R' s i $ S7i bm ti '. to ,fie, S r ' // 8 g 2017-1218 Surface Abandon final MPU I-05 bn.docx Page 2 of 2 OF Tit• • • � Iyyy. •6 THE STATE Alaska Oil and Gas ►'���� of LAsKA Conservation Commission €SrlE 2_= 333 West Seventh Avenue `� � , , t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *4 Main: 907.279.1433 O�ALAS. p. Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC SEAMED FEB 1 02017 3 800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-05 Permit to Drill Number: 195-120 Sundry Number: 316-474 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 by4:30 PM on the 23rd dayfollowingthe date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Okaf- /1°;-?-4/54---- Cathy . Foerster Chair 5- DATED this day of September, 2016. RBDMS SEP 2 6 2016 • • • RECEIVED STATE OF ALASKA SES, 1 5 201 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 11--,,,,,.....t. 20 AAC 25.280 1.Type of Request: Abandon ❑, Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ 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 ❑ 195-120 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service 0, 6.API Number: Anchorage Alaska 99503 50-029-22583-00-00 , 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 ❑ No ED ✓ MILNE PT UNIT SBI-05 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 ` 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): 570' 4,403' Surface Surface 0 Surface N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 4,388' 5-1/2" 5,688' 4,388' 7,740psi 6,390psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,743 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 5.5"Baker SAB 3&SLB Posi-Set Plug and N/A 4,687MD/3,745TVD&5,090MD/4,001 TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service Q 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 , 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 576) Email sporholaehilcorp.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. ^ 5 Plug Integrity Rr BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance El/ Other: Le ph 04-c eic c.�w�-,--r.- C 4-5 i r+-I cs.4. --c ti 4 u.st!r x„P r7¢. . (.2_1 I►b Post Initial Injection MIT Req'd? Yes ElNo ❑ Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: /O — /D-7 RBDMS LI, SEP 2 6 2016 APPROVED BY / Approved by: u COMMISSIONER THE COMMISSION Date: 4/�, O. Submit Form and Form 10-403 Revised 11/2015 ApproF�i pli�a 8alid for 1 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: MPU 1-05 Ililcoru Alaska,LL) Date:9/12/2016 Well Name: MPU 1-05 API Number: 50-029-22583-00 Current Status: Suspended Pad: I-Pad Estimated Start Date: September 30th, 2016 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-120 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) AAFEmaNithmber r fi Job Yp ' r Surface`P&A ,, � T e Current Bottom Hole Pressure: 0 psi (Plugged to Surface) Maximum Expected BHP: 0 psi (Plugged to Surface) MPSP: 0 psi (0.10 psi/ft gas gradient) Brief Well Summary: The Milne Point 1-05 was plugged back to surface in October 2013. However, the well abandonment marker was installed 4' below the surface of the gravel pad. Therefore, the well has remained in a suspended status since 2013. Notes Regarding Wellbore Condition • Plugged back to surface in 2013. • Well capped at 4' below gravel pad. Objective: Finalize the surface abandonment of the well. Surface Procedure: 1. Notify AOGCC inspectors 24 hrs prior to cutoff of wellhead and welding marker plate. 2. Excavate cellar, cut off wellhead and casing 3' below natural GL(9.3'below pad level). a. If cement fell back, bring cement top to level of cut. 3. Photograph casing stub before setting marker plate. 4. Set marker plate,collect GPS coordinates. —� nrf -�'�'4� Z5./ 5. Photograph casing stub after setting marker plate. 6. Backfill cellar, close out location. Attachments: 1. As-built Schematic • 0 Wellhead cut off 4'below pad grade.Will MPU I - 051 cut off 3'below original ground level Orig.DF elev.= 63.9'(N 22E) Orig.GL.elev.= 34.4' RT to 5.5"csg.hng.=29.5'(N22E) 20"91.1 ppf,H-40 113' KOP @ 750' WELLS TUBING AND IA WAS CEMENTED ' ON 8/26/13 Max.hole angle=49 to 51 deg.f/ 2500'to TD' 5.5", 17 ppf,L-80,Btrc.production csg. (drift ID=4.653",cap.=0.0232 bpf) OW EN 1"Split Shot @ 3793.5'-3795' 8/9/13 r 2 7/8"6.5 ppf,L-80,8 rd EUE tbg.. .1_ (drift ID=2.347".cap.=0.00592 bpf) 4/4/2013-Slickline tagged cement @ 3833' and state witnessed. 4/10/2013-MIT-IA passed to 2500 psi K Two 5.5"x 19.5'marker As_f/4469'to Minimum tubing restriction= 4508'wlm w/RA tag at the top. 2.205" 'XN'profile @ 4739' m.,. 5.S"Baker'SAB 3" 4687'and Packer Stimulation Summary , ( 2 7/8"HES'XN' 4739'and none npl.(w/2.313" performed packing bore& Perforation Summary 2 7/8" 4743'and Ref loq: 04/08/96 SBT/GR/CCL WL EG Size SPF Interval (TVD) 3 3/8" 6 4862'-4898' (3852'-3875') ' Dump Bail 10'of cement w/ E Line,Tagged at 5062'md w/ 5062'and 3 3/8" 6 4914'-4938' (3886'-3901') Slick Line 3 3/8" 6 4957'-4964' (3913'-3917') liiiiiiial 3 3/8" 6 4987'-5022' (3932'-3954') 4 Schlumberger Posi-Set Plug 5090' and 3 3/8" 6 5111'-5157' (4009'-4039') r Top at 5090'MD 3 3/8" 6 5208'-5249' (4072'-4098') 3 3/8"hollow carrier AlphaJet charges /� G @ 60 deg.phasing 5.5"float collar(PBTD) 5602'and 5.5"casing shoe 5688'rod DATE REV.BY COMMENTS MILNE POINT UNIT 10/15/95 JBF Drilled and Cased by Nabors 22E WELL I-051 04/11 /96 JBF Initial WIW Completion by Polar 1 API NO: 50-029-22583 1/16/03 MJA Plug set to isolate lower sands 04/25/2013 B.Bixby P/A Update HILCORP ALASKA LLC 08/26/2013 KRUSKIE P/A CEMENT Update XHVZF Pages NOT Scanned in this Well History File 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. / ¢~'~//2c'~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] 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 various kinds [] Other COMMENTS: Scanned by~Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • • GwP'\\I%%/s� THE STATE Alaska Oil Gas ", �' ®ALAS. KA Conservation Commission �h,, _ GOVERNOR SEAN PARNELL 333 West Seventh Avenue s..A., tow Anchorage, Alaska 99501-3572 ALAS 3- Main: 907.279.1433 Fax: 907.276.7542 Clint Spence S��NH� JUL 2 91p1. Interventions Team Leader �"' BP Exploration(Alaska), Inc. P.O. Box 196612 C V-- `aC--Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Pool, MPI-05 Sundry Number: 313-345 Dear Mr. Spence: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, (41")(4 Cathy P Foerster Chair DATED this�� day of July, 2013. Encl. • STATE OF ALASKA • 0 .. - ALASKA OIL AND GAS CONSERVATION COMMISSION 1/ktij • APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ,::�( '''ii y.;i :t 1. Type of Request: ❑Abandon ❑Plug for Redrill ❑Perforate New Pool ❑Repair Well ❑Change Approved Program IN Suspend ❑Plug Perforations ❑Perforate ❑Pull Tubing ❑Time Extension ❑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. ❑Exploratory ❑Stratigraphic 195-120- 3. Address: ❑Development ®Services 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-22583-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPI-05 • Will planned perforations require a Spacing Exception? ❑Yes ® No 9. Property Designatior 10.Field/Pool(s): ADL 025906 - Milne Point/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): • 5710' •4403' 3833' -3193' 3833'TOC, 5090' None Casing Length Size _ MD TVD Burst Collapse Structural Conductor 82' 20" 30'- 112' 30'- 112' Surface 5659' 5-1/2" 29'-5688' 29'-4388' 7740 6280 Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None 2-7/8",6.5# L-80 4743' Packers and SSSV Type: 5-1/2"Baker SAB-3 Packer Packers and SSSV •4687'/3745' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: -®Description Summary of Proposal ❑BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ❑Development ®Service-. 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: July 15,2013 ❑Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG ®Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Todd Sidoti;564-5113 Printed Name: , I; t v?nce Title: Interventions Team Leader Email: Todd.Sidoti @bp.com Signature: PI, Phone: 564-5709 Date: 71 11 3 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number i 3 tiJ ❑Plug Integrity ❑BOP Test ❑Mechanical Integrity Test ❑Location Clearance Other: Kph d fb d o c u " I 7/- /-y, a k-- fir✓ p1 a tG RBDMS JUL 1 s 2O Spacing Exception Required? ❑Yes No Subsequent Form Required: /a- 4_0 APPROVED BY r«' Approved By: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 1 /2012 Appr O11t °tlM r liAfo}12 months from the date of approval Submit In Duplicate VHF -/10/13 /"'� 1.-- N • • by 0 To: MPU Field Operations Team Leads Date: 6/11/2013 AFE: Z3-001 RM From: Todd Sidoti—Well Intervention Engineer IOR: N/A Subject: MPI-05 Fullbore P&A Est. Cost: 250M Please perform the following: 1. E Tubing punch 2. F Fullbore plug &abandon 3. 0 Cut off Wellhead, Top-off cement, Install Marker Plate-AOGCC witnessed Please contact Todd Sidoti at 564-5113(w) or 632-4113(c)with any questions or comments. Sundry approval required prior to performing this work. Well Information Current Status Suspended Injector Max Deviation 51° at 2500' MD Min ID Less than 1.4"" @ 226' ELMD (Restricted Tubing) Last Tag: SL tagged cement top at 3833' on 4-Apr-2013 Last Downhole Op: SL tagged cement top at 3833' on 4-Apr-2013 Latest H2S value: Not Recorded Ann Comm Status MIT-T& MIT-IA passed on 10-Apr-2013 SBHP/SBHT 2051 psi @ 4000'/89 DegF WELL HISTORY MPI-05 was drilled in October of 1995. • 20" 91.4#conductor to 112' • 8.5" hole drilled to 5688' o 5.5" 17#casing cemented with 768 sx of Permafrost `E'followed by 314 sx of Trinity Lite-Wate o Top job performed with 250 sx of Permafrost`E' • Perforated injection intervals: 4862'-4892', 4914'-4938', 4957'-4964', 4964'- 4974', 5111'-5157', 5208'-5249' (All perforations currently abandoned) JOB OBJECTIVE MPI-05 has been targeted for plug &abandonment due to collapsed tubing at 218' SLMD. As per AOGCC definitions, the proposed work will be for suspending the well. In March 2012, a program was submitted to run a caliper from 2000' MD to surface and the tools sat down at around 230' MD. A hot diesel treatment was pumped as an attempt to clear the blockage to no avail. A LIB was run to 219' SLM and returned with a scrape on one side. A bailer was also run and no sample was recovered. On April • • • 19, 2012, a video log was run and it was determined that the video log could not get past 226' because of partially buckled tubing. On March 16, 2013 the formation was abandoned through a fulibore cement job. The well passed an MIT-T and MIT-IA and slickline tagged the top of cement at 3833'. The next step is to fully P&A the well while we are still able to pass a small perforating charge through the obstructed tubing. For this job we will punch tubing at 3833' and circulate the tubing and IA full of cement from 3833'to surface.After waiting on cement we will cut off the wellhead, top off the cement and install a marker plate. The well will be cut off 4 feet below tundra level and the marker plate will be fully welded on at the time of pad remediation. VOLUMES Tubing OD ID bbl/ft 2-718", 6.5# 2-7/8" 2.441 0.0058 Casing OD ID bbl/ft 5-1/2", 17# 5-1/2" 4.892 0.0232 Annular Capacity 2-7/8" x 5-1/2" 0.0152 Minimum volume of cement to pump: 80.5 bbls MARKER PLATE BP Exploration Alaska, Inc MPI-05 API No. 50-029-22583-00 PTD No. 95-120 • Current Tree: 31/8"-5M MPU I - 05i Wellhead:11" 5M FMC Gen.6-2 .Hng., Orig.DF elev.= 63.9'(N 22E) Unibore WI 10"x 3.5"FMC Tb 9 9, 3.5" EUE 8 rd.lift threads 3.5"Btrc. Ong.GL.elev= 34.4' bottom to 5.5"csg.hog.=29-5'(N22E) ottom connection crossed back to 2 7/8"8 rd.,3" CIW "H"BPV profile 20"91-1 ppf,H40 113 KOP @ 750' Max-hole angle=49 to 51 deg.fl 2500'to TD' 5.5",17 ppf,L-80,Btrc.production Csg. (drift ID=4.653",cap.=0.0232 bpi) 2 718"6.5 ppf.L-80.8 rd EUE tbg.. (drift ID=2.347",cap.=0.00592 bpf k2 TOC Tagged @ 3833'SLM Ra i�i•�i� 1:414 A Two 5.5"x 19.5'marker Jts.V 4469'to Minimum tubing restriction= r;•;•A r••• 4508'wlmw/RA tag at the top. 2205" 'XN'profile @ 4739 i❖40 ="• 5-5"Baker'SAES 3" 4687'rnd amm Packet =•-ri-r ❖:44 Stimulation Summary 2 7/8'HES'XN' 4739'and none ;*�;:ti npl.(w/2.313" pertcrm2d MANOR i' packing bore 8 .❖: : �•'!WWN Perforation Summary i9;•:•∎•:14".•••••27!8" 4743'and Ref IOC]: 04/08196 SOT l GR;Cc,L :WpOMMAX. WLEG J •••••••••V Size SPF Interval (TVD) Oii•••i�ii;•i�ii 6 4862'-4898' (3852'-3875) r4•!•!44•!•!+S S!•. Dump Bail 10'of Cement wl E Line.Tagged at 5062'md w. 5062'and 3 3.6 6 4914'-4938' (3886'-3901') Slick Line 3 3/8". 6 4957-4964" (3917-3917) 3 318" 6 4987'-5022' (3937-3954') ' Scr lumberger Posi-Set Plug 5090'and 3 318® 6 5111'-5157' (4009'-4039') Top at 5090 MD 3 318° 6 5208'-5249' (4072'-4098') 3 3f8"hollow carrier AiphaJet charges @ 60 deg.phasing samogossz 5.5"float collar(Par()) { 5602'and 5.5'casing shoe 5688'and DATE REV.BY COMMENTS MILNE POINT UNIT 10/15/95 JBF Driller!and Cased by Naboc 22E WELL I-05i 04111 196 JBF ni2ial WIW Completion by Polar 1 API NO: 50-029-22583 1116103 MJA Plug set to isolate o,r'er sands BP EXPLORATION (AK) • • Proposed Tree: 31/8"-SM MPU I - 05i Wellhead:11" 5M FMC Gen,6-2 'v' J Unibore w? 10"x 3.5"FMC Tbg.Hng., i•••ii�ii'i'iiii �9 ©F elev.= 63.9'(N 22E) ••i•O,O•••i�.i4i Orig.GL.elev.= 34.4' 3.5" EUE 8 rd.lift threads 3.5"Btrc. �•�•�•�4•••••••�►•�.a ••.1. .:04 0. RT to 5.5'csg.h 29.5'(N22E) bottom connection crossed back to 2i ,•,•...•,.•., 7/8"$rd.,3" C I W "H"B PV profile • �•••••�.•••••�i a4444• 2J"31.1 opt.H40 11 .�•�.,Po •, .�l r••i•.�.••.,•..a p....•iiii�iiii P.❖•�Mo.0❖.•a KOP 750' i i%•i I%VA Voll Max.hole angle=49 to 51 deg.f/ MMIA,%•�O�•�.••i•a 2500'to TD' ���•���..•.S•.,',10:�•a ,•••...•,...a 1p....❖.•••/�.❖••t :fX44.0,144 p.M•❖.A.❖.••a :444 t444 •iii'.•ii•Oi 0i•••••••••i• 5.5",17 pP f,L-80,Btrc.production c3 g- + i 'i i i•0,' {drift ID=4.653`,cap.=0.0232 bpt) ii•. • ia a p••...••...•iii' ,••• •..,.•.a '�•i❖i ••Oi'.•iii Pi i•�.•••••,,.❖.•a p...'.••iii�iiii �i•••i i 4•••••...•eV Oi•Pi�.•iiii iii Oi 2718m 6.5 pof,L-80.8 rd EUE tbg.. pip••,4❖.4:;:;p•� ,�������y�•N 144:1 (drllt ID 2.347 cap.0 0-00592 bpi■ �i i i i O..••�.••••••a ,•v,•g!❖!•!•;0•j•�J, TOC Tagged @ 3833'SLM i.... ..•.. :4444 Two 5.5"x 19.5'marker Jts.f/4469'to Minimum tubing restriction= ..,p•• 4578"wlm w/IRA tag at the top. 2-205` 'XN'profite(g 4739 p'❖ •!••!� 5-5"Baker'SAB 3" 4687'and -. Packet Stimulation Summary ' 27/8°HES'XN' 4739'md .., npl.Cw/2.313" sr1 r =: `:* . packing bore& Perforation Summary •5.111J.• •�� 2 4743'and WIAfV AS ;, Ref loci: 04+081 96 SBT 1 GR 1 CCL •iiVAMCa WLEG y s•i•i•i•i•i•i•i•i•i /••••••••••■•••■•••■•••••••••••i a Size SPF Interval {TyD) I'O••••••••••❖•••'/ ••••+••••••• Dump Bail 10'of cement w,+ 33/8" 6 4862'-4$J8' (3852`-3875') �����.�+•i•.��.+a E Line-Tagged at 5062'md'w. 5062'and 3 3/8" 6 4914'-4938' (3886`-3901) Slick Line 3 3/8" 6 4951-4964' (3913'-3917') 3 3/8"' 6 4987'-5022' (3932'-3954°) Schlumberger Posi-Set Plug 5090'and 3 3/8" 6 5111'-5157' (4009'-4039°) i I Top at 5090'MD 0 3 3/8" 6 5208'-5249' {4072'-4098') 0: 3 3/8"hollow carrier AlphaJet charges @ 60 deg.phasing 5-5"float collar(PBTD) 5602'and 5.5"casing shoe 5688'and DA-E FE E; LOMMENTS MILNE POINT UNIT EEF Grilles and Cased by Nabors 22E WELL I -051 = nitial WIW Completion by Polar 1 API NO: 50-029-22583 F;l =lug set to isolate lower sands BP EXPLORATION (AK) RECEIVED • STATE OF ALASKA APR 2 6 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION pOCCC WELL COMPLETION OR RECOMPLETION REPORT AND LOO 1a. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned ®Suspended lb. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions Zero 0 Development IS Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 4/4/2013 195-120, 313-091 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 10/8/1995 50-029-22583-00-00 • 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 10/12/1995 MPI-05 • 2334'FSL,3785'FEL, Sec. 33.T13N, R10E, UM 8. KB(ft above MSL): 64 15.Field/Pool(s) Top of Productive Horizon: Milne Point/Schrader Bluff 2081'FSL, 1399'FEL,Sec.33,T13N, R10E, UM GL(ft above MSL): 34.4' Total Depth: 9.Plug Back Depth(MD+TVD) 1939'FSL, 755'FEL, Sec.33,T13N, R10E, UM 3833' 3193' 1 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 551585 y- 6009449 Zone- ASP4 5710' 4403'• ADL 025906 ' TPI: x- 553974 y- 6009213 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 554619 y- 6009075 Zone- ASP4 None 18.Directional Surve 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): y ❑Yes ®No N/A ft MSL 1800'(Approx.) (Submit electronic and printed information per 20 AAC 25.050) ( PP ) 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/NEU/DEN, RFT, CDN, FMT,GR/CCL/SBT N/A 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.1# H-40 30' _ 112' 30' 112' 24" 250 sx Arcticset I (Approx.) 5-1/2" 17# L-80 29' 5688' 29' 4388' 8-1/2" 768sx PF'E',314sx Trinity Lite-Wate,250sx PF'E' 24. Open to production or injection? 0 Yes ®No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) 2-7/8",6.5#, L-80 4743' 4687'/3745' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes 0 No SC OW) APR 2 9 2014 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 3833'-5062' 7 Bbls Class'G' 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 4 28. CORE DATA Conventional Core(s)Acquired? 0 Yes 0 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,photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS APR 2 6 201 Form 10-407 Revised 10/2012 CONTINUED ON gEVVRSE ?IAA L.1).12/i'( Submit Original Only 29. GEOLOGIC MARKERS(List all formations an ;ers encounter 30. FORMATION TESTS NAME MD ND Well Tested? 0 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. 'NA'Sands 4848' 3848' None 'NB'Sands 4889' 3874' 'ND'Sands 4957' 3917' 'NE'Sands 4974' 3928' 'OA'Sands 5130' 4026' Top West Sak'A' 5238' 4095' Formation at Total Depth: S 1 U; u3, WeSk Mu ‘4113.w 31.List of Attachment: Summary of Daily Reports,Well Schematic Diagram 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Email: Todd.Sidoti@bp.com Todd Sidoti,564- 113 Title: Drilling Technologist Printed Name: Jor_ stufka i ). `- - Phone 564-4091 Date: 4'/25/13 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 ND 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 10/2012 Submit Original Only MPI-05, Well History Date Summary 02/02/13 T/I/0=950/0 Inj Test/MIT IA PASS to 1000 psi (P&A) Pumped 40 bbls 60/40 down tubing. Injectivity rate of 2300 psi at 5 BPM. MIT-IA lost 0 psi in the first 15 minutes and gained 18 psi in the second 15 minutes. Final WHPs=840/0. 02/11/13 RAN 1.5" SAMPLE BAILER.S/D @ 231'SLM.BAILER EMPTY. RIH W/1.70" LIB.S/D @ 234'SLM. LIB INCONCLUSIVE. 02/12/13 RAN 1.74"GAUGE RING.S/D @ 233'SLM.UNABLE TO GET THRU. RAN 1.40"GAUGE RING.S/D @ 233' SLM.UNABLE TO GET THRU. 03/16/13 T/I/0=170/160.Temp=S/I.Assist on P&A(PLUG AND ABANDONMENT-RESERVOIR) Pressure up on IA to 650 psi. Pump 20 bbls diesel heated to 80*down tbg to push cement back into formation&for freeze protect. FWHP=550/1300. Swab,wing, &SSV closed. Master& IA open. 03/16/13 T/IA/OA=950/1350/0- Pump Injectivity test 5 bpm @ 2000 psi-Cement P&A with 7 bbls of cement drop foam balls, displace w/7 bbls FW 20 bbls 80 degF diesel, attemt to squeeze to 3500 psi.6 bbls CMT into perfs, 1 bbl left in TBG, 3500 psi squeeze pressure not reached. 03/17/13 Post P&A cementing T/I/O @ 14:30 on 3/17/13 was 300/650/NA. 04/04/13 RAN 1.42"GUAGE RING, S/D @ 218' SLM, UNABLE TO PASS THROUGH, FLAGGED WIRE RAN STINGER 10'x 1"WB& 1.25"S. BAILER BELOW SPANGS TO FLAG, NO ISSUES SWAPPED TO 1"TOOLSTRING AND RAN 1.25" KJ, 2'x 1.50"WB, & 1.25" S. BAILER BELOW SPANGS, S/D @ 3833' SLM, RECOVERED SAMPLE OF CEMENT IN BAILER,TURNED IN TO WSL MIT-T 2500psi, WITNESSED BY AOGCC REP JEFF JONES, DECLINED TO WITNESS TAG. 04/10/13 T/I= 160/580. MIT-IA PASSED to 2500 psi. Pumped 0.5 bbls diesel down Tbg to pressure to 1500 psi. RU to IA. Pumped 0.5 bbls diesel down IA.to reach test pressure Loss of 82 psi 1st 15 min. Loss of 15 psi 2nd 15 Min FWHP=150/350 SV,WV,SSV shut MV,IA Open. 04/10/13 T/I= 188/383. MIT-IA PASSED to 2500. Pressured Tbg.to 1500 PSI. Pumped 0.5 Bbls down IA to reach test pressure. Loss of 58 psi 1st 15 min. Loss of 17 psi 2nd 15 min. FWHP=150/350 SV,WV,SSV shut MV,IA Open. Page 1 of 1 Tree: 31/8"-5M • Wellhead:11" 5M FMC Gen.6-2 MPU I - 05i Unibore w/ 10"x 3.5" FMC Tbg.Hng., Orig. DF eleiv.= 63.9'(N 22E) • 3.5" EUE 8 rd.lift threads 3.5"Btrc. Orig.GL.elev.= 34.4' bottom connection crossed back to 2 RT to 5.5"csg.hng.=29.5'(N22E) 7/8"8 rd.,3" CIW "H"BPV profile 20"91.1 ppf, H-40 113' KOP @ 750' Max. hole angle=49 to 51 deg.f/ 2500'to TD' 5.5",17 ppf,L-80,Btrc.production csg. (drift ID=4.653",cap.=0.0232 bpf) 2 7/8"6.5 ppf,L-80,8 rd EUE tbg.. a; (drift ID=2.347",cap.=0.00592 bpf) 4/4/2013-Slickline tagged cement @ 3833' and state witnessed. 4/10/2013-MIT-IA passed to 2500 psi X Two 5.5"x 19.5'marker Jts.f/4469'to Minimum tubing restriction= 4508'wlm w/RA tag at the top. 2.205" 'XN'profile @ 4739' 4 - 5.5"Baker'SAB 3" 4687'and Packer Stimulation Summary ( 27/8"HES'XN' 4739'and none npl.(w/2.313" performed packing bore& Perforation Summary ";J 2 7/8" 4743' rnd Ref log: 04/08/96 SBT/GR/CCL WLEG Size SPF Interval (TVD) 3 3/8" 6 4862'-4898' (3852'-3875) - Dump Bail 10'of cement w/ 33886' 3901' E Line,Tagged at 5062'md w/ 5062' and 3/8" 6 4914'-4938' ( ) Slick Line 3 3/8" 6 4957'-4964' (3913'-3917') 3 3/8" 6 4987'-5022' (3932'-3954') Schlumberger Posi-Set Plug 5090' and Top at 5090'MD 3 3/8" 6 5111'-5157' (4009'-4039') 3 3/8" 6 5208'-5249' (4072'-4098') 3 3/8"hollow carrier AlphaJet charges @ 60 deg.phasing 5.5"float collar(PBTD) 5602'and ♦♦♦, 1111♦♦ " 5.5"casing shoe 5688'and DATE REV.BY COMMENTS MILNE POINT UNIT 10/15/95 JBF Drilled and Cased by Nabors 22E WELL I -05i 04/11 /96 JBF Initial WIW Completion by Polar 1 API NO: 50-029-22583 1/16/03 MJA Plug set to isolate lower sands 04/25/2013 B. Bixby P/A Update BP EXPLORATION (AK) Guhl, Meredith D (DOA) From: Sidoti, Todd [Todd.Sidoti@bp.com] Sent: Monday, April 28, 2014 10:02 AM To: Guhl, Meredith D (DOA) Subject: RE: MPI-05, PTD 195-120, Well recompletion report Hello Meredith, The formation at TD is the West Sak 'A'. Thanks, Todd Todd Sidoti I BPXA Well Intervention Engineer I Office 907-564-5113 I Cell 907-632-4113 I todd.sidotk bp.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhlOalaska.gov] Sent: Friday, April 25, 2014 9:56 AM To: Sidoti,Todd Subject: MPI-05, PTD 195-120, Well recompletion report Hello Todd, When reviewing the Well Recompletion Report for MPI-05, I noticed that the "Formation at Total Depth" in box 29 was not filled in.What is the formation at total depth for this well? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 • • 4,i, I / /7 6, THE STATE Alaska Oil and as °' 1L1 1S Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF ALAS P Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Clint Spence Interventions Team Lead SC�►NN LIAR 11 2013 BP Exploration (Alaska), Inc. P.O. Box 196612 — 1.9-0 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPI -05 Sundry Number: 313 -091 Dear Mr. Spence: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, fi_ Cathy P. Foerster Chair DATED this 4 day of March, 2013. Encl. II STATE OF ALASKA RECEIVED ALAI. OIL AND GAS CONSERVATION COM•ION FB 2 I. 201 • APPLICATION FOR SUNDRY APPROVAL 673 . 3 1 1' ! Z 20 AAC 25.280 AOG Rg 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ® Suspend • ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. - ❑ Exploratory ❑ Stratigraphic 195 -120 - 3. Add -g- Development Service l� � 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 11.51 9 50.029- 22583 -00 -00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPI-05' Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ADL 025906 • Milne Point / 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) 5710' 4403' - 5602' 4332' 5062' TOC, 5090' None Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 30' - 112' 30' - 112' Surface 5659' 5 -1/2" 29' - 5688' 29' - 4388' 7740 6280 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4862' - 5249' 3857' - 4103' 2 -7/8 ", 6.5# L -80 4743' Packers and SSSV Type: 5 -1/2" Baker SAB -3 Packer Packers and SSSV 4687' / 3745' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic -®- Development Service ��5 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation March 1, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Todd Sidoti; 564 -5113 Printed Name: r` 1 t i li - nce Title: Interventions Team Lead Email: Todd.Sidoti @bp.com Signature: OF �„ Phone: 564 - 5709 Date: Z II Z, fi5 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1 9. f all Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance VV'' �� Other: d 4 - h (ro r h v 7 e 1 406 CC fo tir 1 fvi rsS p) v c�5 / ` i-i 1 o p rra if � RBDMS MAR 0 5 201.3 Spacing Exception Required? ❑ Yes dNo Subsequent Fomi Required: / — 40 - APPROVED BY c: Approved By: L 14 / COMMISSIONER THE COMMISSION Date: 3 �C - /3 Form 10 403 Revi e 1 / 1 Approved application is valid for 12 months from the date of approval Submit In Duplicate 'b ORM� �L 2_/2./i3 v-L q . bp • • 0 To: MPU Field Operations Team Leads Date: 2/19/2013 From: Todd Sidoti - Well Intervention Engineer AFE: APBRISKM Subject: MPI -05 Fullbore Reservoir Abandonment IOR: N/A Est. Cost: 60,000 Please perform the following: 1. F Injectivity Test, Reservoir Abandon 2 S Drift & Tag TD & MIT -T to 2500 psi & chart. (AOGCC state witnessed per Sundry) Please contact Todd Sidoti at 564- 5113(w) or 632- 4113(c) with any questions or comments. Sundry approval required prior to performing this work. Well Information Current Status Suspended Injector 7 Max Deviation 51° at 2500' MD Min ID Less than 1.4" @ 226' ELMD (Restricted Tubing) Last Tag: CT tagged cement cap at 5057' on 2- Dec -2008 Last Downhole Op: SL ran 1.4" GR to 226' on 12- Feb -2013 Latest H2S value: Not Recorded Ann Comm Status 1000 psi MIT -IA passed on 2- Feb -2013 SBHP / SBHT 2051 psi @ 4000' / 89 DegF JOB OBJECTIVE MPI -05 has been targeted for reservoir abandonment due to collapsed tubing at 218' SLMD. As per .4' AOGCC definitions, the proposed work will be for suspending the well. This will isolate the reservoir but still allow access to the wellbore for re -entry or sidetrack in the future. In March 2012, a program was submitted to run a caliper from 2000' MD to surface and the tools sat down at around 230' MD. A hot diesel treatment was pumped as an attempt to clear the blockage to no avail. A LIB was fun to 219' SLM and returned with a scrape on one side. A bailer was also run and no sample was recovered. On April 19, 2012, a video log was run and it was determined that the video log could not get past 226' because of partially buckled tubing April 21, 2012, an MIT - IA passed to 3000 psi. On February 2, 2013 injectivity down the tubing was established pumping 5 BPM at 2300 psi. It has been decided to pump this abandonment stage while we still have (possibly diminishing) injectivity to the formation established. For this job we will bullhead and spot cement from the bottom perforations at 5022' to the packer at 4687'. The tubing will be left underbalanced to the formation using a column of diesel. After waiting on cement we will attempt to tag TOC with a 1.2" drift and perform a M IT -T. This will provide a -119' - cot, C u / Ai l e � C , S t el . , f e C o e for ,; ter/ /600 . fee rr 6 rd e 6 , ' / ��� 1 • • S column of cement above the Sag River in the 5.5" casing. Depending on the results of the drift we 9 9 P 9 will either punch tubing above the packer and bullhead a balanced plug or develop an alternative plan. VOLUMES Tubing OD ID bbl /ft 2 - 7/8 ", 6.5# 2 - 7/8" 2.441 0.0058 Casing OD ID bbl /ft 5-1/2", 17# 5-1/2" 4.892 0.0232 Annular Capacity 2 -7/8" x 5 -1/2" 0.0152 k ,... ;,. ��'.°. �/f ,, ,, , ., . iii ,i � r�i�� r � / //�,�/� / � /�f� 1 / r� sue/ �,�;'//f %// %/^ , f k[ [ l �'. - � , � r�1��.�$t1�y� "' � i ' � ; i%'�:��s %r/",.�` �,,r'�./!��/�,, �� ,,' iZ%';;;�! .. .':- /, L'7 e`,`fif.,�,1�'..f fir/ 1. Please review "Recommended Practice: Fullbore Cement Pumping" prior to conducting job. 2. Fullbore P &A Stage 1 per attached appendix. � %''�/ /ifs / /// 64//r1 Slickline — D &T TOC. CMIT -TxIA to 2500 PSI & Chart (AOGCC state iii s ' p i' 1. Drift tubing with a 1.2" s- bailer and tag TOC. Ensure a sample is obtained and note in AWGRS. 2. Using triplex perform a MIT -T to 2500 psi with any non- freezeable fluid, chart results for delivery to the state. If you can't get a charted test then move this step to fullbore. 3. Please send test chart to todd.sidoti(c�bp.com and retain hardcopy in wellfile. 4. The Sundry requires us to notify the state to witness pressure testing of cement and tag. 2 • • •�end 1 - Fu PBS r './ � :. 'r., '` ,,, // � „” ,.,: � ✓'/��j% %/f/jl� �% /� //� / Notes: • SLB to use their portable panel to take control of SSV • SLB to bring climbing harnesses for accessing top of well house • Diesel to be heated to 70 degrees to prevent thermal expansion while WOC • Track IAP and OAP during pumping, bleed off as necessary. • Do not exceed 2500 PSI differential ressure between tubing and IA while pumping. If it is P 9 necessary to go to the max squeeze pressure of 3500 psi then ensure the IA has at least 1000 psi applied. Cement Window Highest allowed TOC: 4052' MD Target TOC: 4687' MD Perf Info Top open perf: 4862' MD Bottom open perf: 5022' MD Total footage of open perfs: 102' Distance from top to bottom perf: 160' (3.7 bbl) Cement Design Unislurry BHST: 89 degF BHCT: 70 degF SBHP: 2050 psi Slurry density: 15.8 ppg Compressive strength: > 1000 psi Thickening time: 6 -7 hours Fluid loss: 80 -120 cc /30 min Pumpable volume required: 7 bbl Mix on the fly No gas block additives required Volumes Requested TOC (4687') to bottom perf (5022'): 6.8 bbl Shallowest TOC (4052') to top perf (4862'): 6.8 bbl Tubing volume from surface to desired TOC (4687'): 27.1 bbl Tubing volume from surface to top perf (4862'): 30.2 bbl 3 • Suggested Plan Forward Grease Crew Grease all tree valve cavities, including SSV Lock wing closed Rigup Crew Rig up iron for fullbore cement job with ball launcher loaded with 2 x 4" foam balls. Include horse trailer or 4 way manifold so that SLB only needs to rig up to the trailer. Schlumberger PT all iron per SOP: Well Entry Procedures Close lateral valve Ensure SLB has transducers to monitor IAP Pump Schedule • 5 bbl meth spear Divert flow through ball launcher and launch ball. Open workover valve and then low - torque, in that order. This step is to ensure that the ball will pass through the restriction with the well freeze protected. • 5 bbl meth spear • 45 bbls 1% KCL to establish injectivity at 5 bpm. ( -1.5 tubing vol) • 7 bbls 15.8 ppg class "G" cement • 2 bbls water to clear lines Divert flow through ball launcher and launch ball. Open workover valve and then low- torque, in that order. • 5 bbls water behind ball Open side of cement manifold so we are pumping into both inlets • 20 bbls diesel 20 bbls of diesel will put the cement at the requested top, 4687'. With 16 bbls of diesel away the leading edge of cement will be at the top perf. Slow rate to 1 bpm and begin pumping cement to the perfs. Do not exceed 20 bbls of diesel (27 bbls of TOTAL displacement.) If well squeezes off: (increase of 1000 psi or more starting when cement reached perfs) • Max squeeze pressure is 3500 psi • Hold pressure for 30 -60 minutes then bleed down to 1000 psi If no squeeze pressure is achieved: (less than 1000 psi increase with cement at perfs) • After designed displacement, shut -in well. Wash up cementers RD SLB cementers Call valve shop to service tree 4 • • Check WHP in 6 hours, if it is over 2000 psi bleed back down to 1000 psi. Current Schematic 5 • Tree: 3 1/8" - 5M MPU 1 - 05i Wellhead: 11" 5kil FMC Gen. 6-2 Orig. DF elev. = 6a9 (N • Unibore NW 10" x 3.5" FMC Tbg. . • 3.5" EVE 8 rd lift threads 3.5" arc. Orig. GL. a44' " bottom connection crossed back to 2 RT to 5.5 mg. hng. = 29.6' (N22E) TV' 8 rd., 3" CRY "H" BPV profile 20"911 ppf,1-1-40 61_ S frA- 113' 4 (44_4(4.• 11w KOP @ 750' Max. hole angle = 49 to 51 deg. 2500 to TD' 5 5 7 ppf, L-80. Biro production csg. dr ! ID =4.653", cap. = 0.0232 bp4 2718" 6.5 ppf, L-80, 6 rd ELE ( &id D = 2.347, cap. = 0.00592. Opt) Two 5.5" x 19..5' marker Jtz. 54469 to Minimum tutting restriction= 4506 winl v,o,' IRA tag at the top. 2.205" 'XN' profile 4739' — 5.5" Baker 'SAB 3" 1 4687' rnd Packer StiMulation Summary 2 716" HE 'XN' I 4739' mid none rt. (w2.313" performed packing bore & Perforation Sumrnary 2 7.8" I 4743' Ref loci: 04 08; 96 SBT GR CU WLEG Size SPF Intenfal (TVD) - 3 3,8' 6 4862' - 4898' (3852-3875') DUrnp Bail 10' eminent , tW E Line. Tagged at 5D62'md we' 5062' and 3 318' 6 4914' - 4938' (3886"-3901') 4 Li„ 3 318' 6 4957' - 4964' (3913-391 1 5090' md S um ofilberger Posi-Set Plug 3 368" 6 4987' - 5022' (3932 _ . at 5000 , MD 3318" 6 5111' - 5157' (4009'-40391 01 3 3/8" 6 5208' - 5240' (4072-4098' ) 0 0 3318" hollow car AlphaJet ch ; arges Id qi) 60 deg. phasing 5607 mot I 55" float C01131 (PBTD) • 5.5" casing shoe 5688' and DATE REV_ BY GOIMENTS MILNE POINT UNIT 10/15/95 DrP,4 and Cased try Ngisnrz 29F WELL I - 054 04/ 11 /96 „.115F Inftiat WIW Completion by Rolm 1 API NO: 50-029-22583 4. MJA Plug set to isolate tower sands BP EXPLORATION (AK) Proposed Schematic 6 • Tree: 3 1/8" - 5M MPU 1 - 05i Wellhead 11" 5811FMC Gen. 6-2 ele Unibore wr 10" x 3.5" FMC Tbg. Hng.„ Orig. DF v.= 63.9' (N 22E) 3.5" EUE 8 rd. lift threads 3.5" B1rc 1 Orig. GL elev.= 34.4' bottom connection crossed back to 2 FIT to 5.5 csg. hng. =29_5 (N22E) 7/8" 8 rd., 3" CPA! 1-1" BPV profile Id 20P 91.1 ppf, H-40 113' 'PI rD KOP @ 750' . Max. hole angle = 49 to 51 deg. V 2500' to TD 5.5" 7 opt, L-80. Btrc, production c..w drift ND = 4.653", cap. = 0.0232 ) 2 7$8" 6.5 or:if, L-80, rd ELIE tbg.. drift ID = 2.347% cap. = 0.00592 lot) X TOM 5.6" x 19.5' marker Jts. to 4469' tc Minimum tutting restriction = 4508' wim w1 PA tag at the too. 2.205" 'KN profile fg' 4739' 5.6" Baker 'S,AB I 4687' mid. Packer Stimulation Summary 2 7;3' HES ''XN' 4739' rod none np. (vto 2.313" perforrned packing bore & Perforation Summary 2 78" I 4743' rod ;0 :1■ Ref Ion: 04 08/ 96 SST g GRFOCt 4 , 4 * * * * * * * * ********* * * WLEG & TOC 0 S ISPF Intery - : i ize al trvp) •••••••••• 3 3/8" 6 4862' - 4895 (3852'-3875') 4:44 Dump Bali 19' of cement we E Line_ Tagged at 59112 w! I 51fra2 md I 33/8" 6 4914' - 4938' (3886-3901') a ' Slick Line 3 318" 6 4957 - 4964' (3913'-3917) IMMO I 509 and 3 318' 6 4987 - 5022' (3932-3954') Schlumberger Posi Plug Top at MOO' MD 3 318" 6 5111' - 5157' (4009'-4009') 3 318" 6 5208' - 5249' (4072'-4095) 3 318' hollow carrier Alphatet charges. )g 60 deg. phasing I 5602'r 5.5' float collar dPBTD) ; 6.5 casing shoe 5888' md DATE REV_ BY COMMENTS MILNE POINT UNIT 10/15)95 JRF Drill/ad and rAiitori hy Nabors P9F WELL 1 - 051 04/ 11196 JEF Initial WIW Completion by Polar 1 API NO: 50-029-22583 1/18483 MJA Plug set to isolate lower sands BP EXPLORATION (AK) 7 F • • Roby, David S (DOA) From: Sidoti, Todd <Todd.Sidoti @bp.com> Sent: Tuesday, February 26, 2013 3:56 PM To: Roby, David S (DOA) Subject: RE: MPI -05 Sundry Application Hi Dave, We expect that the current obstruction near surface is most probably buckled tubing (and possibly casing) due to subsidence. We are concerned that as subsidence continues, we will lose most or all injectivity into the formation. If that happens we would have to abandon the reservoir by drilling a relief well or mobilizing a snubbing unit. The restriction is less than 1.4" which is too small for the use of a coiled tubing, wireline or slickline intervention. At this point our only options are to pump from surface or bring a workover rig over the well. We believe that pumping a cement job from surface to safe out the well as quickly as possible (while we still have injectivity) is our best option for this well. Please let me know if you need any additional information or clarifications. Thanks, Todd Todd Sidoti I BPXA Well Intervention Engineer I Dir 907 -564 -5113 I Cell 907 - 632 -4113 I todd.sidoti @bp.com From: Roby, David S (DOA) [mailto:dave.roby Sent: Tuesday, February 26, 2013 3:23 PM To: Sidoti, Todd Subject: MPI -05 Sundry Application Todd; I am reviewing your sundry application to suspend the subject well and I was wondering why the decision was made to suspend this well as opposed to repairing it? Thanks, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793 -1232 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,April 17,2013 TO: Jim Regg �P, , 1 (Z6IG3 P.I.Supervisor ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC I-05 FROM: Jeff Jones MILNE PT UNIT SB 1-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB 1-05 API Well Number 50-029-22583-00-00 Inspector Name: Jeff Jones Permit Number: 195-120-0 Inspection Date: 4/4/2013 Insp Num: mitJJ130406065238 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ,Type J — - Well 19so2oo !Type Test SPT TVD 3745 IA 550 650 650 650 650 PTD 1500 OA 2360 Test psi - — g --t Interval�oTxER P/F I P • li Tubing 0 2550 - i 2310 } 2285 Notes: MIT-T of P&A plug isolating perfs;monobore. SCANNED MAR 1 3 2014 Wednesday,April 17,2013 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 StsiiiiiNEOFEB 17 2W12 195- /2_0 Mr. Tom Maunder /TO Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD it API # Initial top of cement pumped cement date inhibitor sealant date ft _ bbls It gal MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI-02 1900910 50029220660000 Sealed coductor , NA NA NA NA NA MPI -03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI-04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA ""3 MPI-05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 162 8/21/2011 MPI -08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 MEMORANDUM To: Jim Regg P.I. Supervisor ~ ~/~ 3~ ~I ~ i a FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, Mazch 02, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC I-OS MILNE PT iJNIT SB I-OS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .5~~ Comm Well Name: MILNE PT UNIT SB I-05 API Well Number: 50-029-22583-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ100227212456 permit Number: 195-120-0 Inspection Date: 2/8/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 1-os ~ Type Inj. ~'~' ~ TVD 3zas / IA o I - IZZO I6so ~ t6so P.T.D I9sizo° TypeTest ; SPT I Test psi Isoo OA i _ _ --~---~- --~- --- -- -~ -- -- ---- Interval aYRTST per, P ~ Tubing 900 ~ 900 _ 900 900 _ NOtes: monobore injector. 0.6 BBLS diesel pumped. 1 well inspected; no exceptions noted : ` ~:'~;`~~~ ~rP~ ~ ~~: 20tC~ Tuesday, March 02, 2010 Page 1 of 1 MEMORANDUM e TO: Jim Regg -;) :;)¡S/Dí,:, P.I. Supervisor Ai!11 :;¡ FROM: John Spaulding Petroleum Inspector Well Name: MILNE PT UNIT SB 1-05 Insp Num: mitJS060227121043 Rei Insp Num Packer Well iI-OS ¡Type Inj. :1 W TVD f------j I . P.T. i 195]200 !TypeTest I SPT Test psi Interval 4YRTST PiF P Notes Tuesday, February 28, 2006 State of Alaska e Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 28, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC ]-05 MILNE PT UNIT SB I-OS Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-22583-00-00 Permit Number: 195-120-0 Depth 3745 I i IA ¡ OA Tubing 936.25 Pretest Initial o ]980 i I ]100 I 1100 /1 0' \rvD \0\ Reviewed By: P.I. Suprv ::Jet:. Comm Inspector Name: John Spaulding Inspection Date: 2/15/2006 15 Min. 30 Min. 45 Min. 60 Min. ]920 i 1900 j ! I I I ¡ i I ]100 L ]100 i I Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operabon shutdown_ Stimulate _ Plugging _ Perforate _ SET POSI PLUG Pull tubing _ Alter casing _ Repair well_ Other_X SET PLUG 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 64 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 196612 Strabgraphic__ Anchorage, AK 99519-6612 Service__X Miline Point Unit 4. Location of well at surface 2946' FNL, 3784' FEL, Sec. 33, T13N, R10E, UM (asp's551586, 6009449) MPI-05 At top of productive interval. 9. Permit number / approval number 3198' FNL, 1399' FEL, Sec. 33, T13N, R10E, UM (asp's 553974, 6009214) x, '~ 195-120 At effective depth ~', 10. APl number 3231' FNL, 1237' FEL, Sec. 33, T13N, R10E, UM (asp's554136, 6009162) ~ 50-02922583-00 At total depth 11. Field / Pool 3340' FNL, 765' FEL, Sec. 33, T13N, R10E, UM (asp's 554619, 6009076) Miline Point Unit / Schrader Bluff Sands 12. Present well condition summary Total depth: measured 5710 feet Plugs (measured) Tagged TD @ 5062' (01/12/2003) true vertical 4402 feet Top of CMT @ 5080' (01/10/2003) Top of POSI Plug @ 5090' (01/10/2003) Effective depth: measured 5062 feet Junk (measured) true vertical 3983 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 112' 20" 250 sx Arcticset 1 (approx) 142' 142' 768 sx PF 'E', 314sx Production 5659' 5-1/2" Trinity Lite-Water, 250 sx 5688' PF 'E'. Perforation depth: measured Open Perfs 4862'-4898', 4914'-4938', 4957'-4964', 4987'-5022', 5111'-5157', Open Perfs under Plug 5208'-5249' true vertical Open Perfs 3852'-3875', 3886'-3901', 3913'-3917', 3932'-3954', 4009'-4039'L Open Perfs below Plug 4072'-4098' RECEIVED Tubing (s~ze, grade, and measured depth) 2-7/8", 6.5#, L-80 TBG to 4743' MD. Packers & SSSV (type & measured depth) 5-1/2" x 2-7/8" Baker 'SAB~3' Packer @ 4687'. J/~N ~ '~ 200~ 13. Stimulation or cement squeeze summary ~'"' .... Al'tcb0rage Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 01/05/2003 ? 1974 Subsequent to operation 01/25/2003 ,~l~,~i~i='l% E'[E'D /~ A ')nrt~ 1880 15. Attachments 16. Status of well classification'~: ........ ,-- ,-., u ~ ,.. ~, ~,~ Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ -(3as __ Suspended __ Service WATER Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .~~~ _~j~.~.~.~ T,tle: Technical Assistant Date January 30, 2003 DeWayne R Schnorr Prepared by DeWayne R Schnorr 564-5174 Form 10-404 Rev 06/15/88 · BDNiS BFL SUBMIT IN DUPLICATE ~--~ 01/09/2003 01/10/2003 01/12/2003 01/16/2003 01/29/2003 MPI-05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PACKERS/BRTDGE PLUGS/POGLMS: PLUG & ABANDON PERFS PACKERS/BRIDGE PLUGS/POGLMS: PLUG & ABANDON PERFS SLI'CKLI'NE --- TAG TOP OF CEMENT SL[CKL[NE --- RUN SBHP SURVEY TESTEVENT --- IN,JECTION PRESSURE, PSh 1787 TYPE: PW VOLUME: ? BPD 01/09/03 01/10/03 01/12/03 01/16/03 01/29/03 EVENT SUMMARY SET POSI PLUG AT 5090', CORRELATE TO ATLAS INJ PROFILE 7-JUN-98, TAG AND LOG OFF PLUG. MIX AND DUMP ONE LOAD OF CEMENT. SET POSI-PLUG, @ 5090', COMPLETED DUMPING 10' TOTAL CEMENT ON PLUG -TD=5080'. <<< LEFT WELL SHUT-IN >>> MIRU - CONDUCTED TGSM. RIH WITH 2" CENT, TEL, 2" BLIND BOX. LOCATED 'FT' @ 4716 FT WLM (4743 FT RKB) CORR = 27 FT. TAGGED BOTTOM @ 5035 FT WLM, 5062 FT CORRECTED MD. 40 FT BELOW PERFS. E-LINE SET POSI PULG @ 5090 FT ELM AND DUMP BAILED 10 FT OF CEMENT. THIS TAG MAY HAVE BEEN HIGH DUE TO A CEMENT STRINGER. MIRU - CONDUCTED TGSM. PT'd EQUIPMENT TO 3000# WITH TRIPLEX PUMP. RIH WITH SHOCK ABSORBER & DUAL SPARTEK GAUGES IN GAUGE CARRIER. USED 27 FT CORRECTION FROM TAG ON 01/12/2003. RECORDED ONE HOUR SBHP SURVEY @ 5056' ME (MID PERFS). SBHP @ 5056' MD, 3979' TVD WAS 2113 PSI @ 92 DEGREES. TESTEVENT --- INJECTION PRESSURE, PSI: 1787 TYPE: PW VOLUME: ? BPD FLUIDS PUMPED BBLS DISCRIPTION 1 DIESEL USED FOR PRESSURE TESTING SURFACE PRESSURE EQUIP 1 TOTAL SCANNED FEB 0 2003 Page I THE MATERIAL UNDER THIS COVER HAS BEEN MICROF'ILMED ON OR BEFORE JANUARY 03, 2001. M PL ATE IA L E U N D W E R T H IS M ARK E R C:LOR~4FILM.DOC PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS Page: 1 Date: 04/20/98 RUN RECVD 95-120 7217 ~SBT/GR 95-120 SR/CC/P~,RF '~SEPIA ~-~0 SBL/SR/CCL 95 - ~ 95-120 05/21/96 1 05/03/96 1 05/03/96 i .... FINAL 08/08/96 95-120 95-120 CDN ,~L 240-5620 CDR ~/300-5670 FINAL 08/08/96 FINAL 08/08/96 95-120 CDR - TVD ~/300-4370 FINAL 08/08/96 95-120 7366 ~I~CDR/CDN - MWD ,.. 10-407 ~'COMPLETION DATE ~aznY ~znn eps a / 6 / ?/~?~ TO 1,2 08/08/96 Are dry ditch samples required? yes ~o~~d received? yes-man--- Was Are well Well is the well cored? yes ;~h~') Analysis & description received? . tests required? yes h~ Received? in compliance Initial COMMENTS y e s._~: 'An~LL/ STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION CuMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-120 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22583 , 4. Location of well at surface ~' ............... '~ - 9. Unit or Lease Name 2334' NSL, 3785' WEL, SEC. 33, T13N, R10E ! ~:;'H":'~ ;-':'h'?i.~ i ~-'~ BRine Point Unit At top of productive interval i ~?~_i~i '~~ i[ 10. Well Number 2082' NSL, 1399' WEL, SEC. 33, T13N, R10E ~[ MPI-05i At total depth ~:: ~; 11. Field and Pool 1940' NSL, 754' WEL, SEC. 33, T13N, R10E ~ ......./u, -'-- ;.._~ .... Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 63.9'I ADL 025906 12. Date Spudded10/08/95 I13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re ' 16' N°' °f C°mpleti°nsl 0/12/95 04/10/96 N/A MSLI, One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrost 5710 4402 F~ 5602 4332 FT~ IXIVes []No I N/A MD/ 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR/RES/NEU/DEN, RFT, CDN, FMT, GR/CCL/SBT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 3o. 11 . 5-1/2" 17# L-80 29' 5688' 8-1/2" 768sxPF'E',314sxTrinityLite-Wate, 250sxPF~.~ V["~_)' ,,... ~ ] 24. Perforations open to Production (MD+TVD of Top and Bottom 25. ~-::~:~as Cons, 60rrirrlissJ0Q and interval, size and number) SIZE DEPTH SET (MD} ......... ~KER SET (MD} 3-3/8" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 4743' 4087' MD TVD MD 'I-VD 4862'-4892' 3857'-3876' 4914'-4938' 3890'-3905' 26. AO~D, FRACTURE, CEMENT SQUEEZE, ETC. 4957'-4964' 3917'-3921' 4974'-4964' 3928'-3958' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5111'-5157' 4014'-4043' Freeze protect w/48 bbls diesel 5208'-5249' 4076'-4102' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) June 2, 1996 I Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO iTEST PERIOD · I Flow Tubing Casing Pressure CALCULATED ° OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. ~_4-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. "--? i ;~ . ..¢ , Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Mark,.,~ 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) 'NA' Sands 4848' 3784' 'NB' Sands 4889' 3810' 'ND' Sands 4957' 3853' 'NE' Sands 4974' 3864' 'OA' Sands 5130' 3962' Top West Sak 'A' 5238' 4031' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is t~iue and,eerrect to the best of my knowledge s, ed -Rm Schofield ' Title Senior Drilling Engineer Date I ' · Prepared By Name/Number: Kathy Campo;~mo/', 564-5122 iNSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injectiOn, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP/ALI SHARED SERVICE DAILY OPERATION~ PAGE: 1 WELL: MPI-05I BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 22E WO/C RIG: NABORS 22E 10/08/95 (1) TD: 112'( 0) Alaska Oil & G~s Cons. Comm~ssiort Anchorage MI RIG MIRU. MOVE FROM MPI-07 TO MPI-05I. MW: 0.0 VIS: 0 10/09/95 (2) TD: 710' ( 598) 10/10/95 (3) TD: 3271' (2561) 10/11/95 (4) TD: 5040' (1769) 10/12/95 (5) TD: 5710'( 670) 10/13/95 ( 6) TD: 5710' ( 0) 10/14/95 ( 7) TD: 5710' ( 0) DRILLING MW: 0.0 VIS: 0 FINISH MIRU. MIX MUD, NU DIVERTER. PU BHA. FUNCTION TEST DIVERTER & ACCUMULATOR WAIVED BY JERRY HERRING W/AOGCC. PU BHA. DRILL F/l12' T/193'. PU CDN & LOAD SOURCE. DRILL F/193' T/710'. DRILLING MW: 0.0 VIS: 0 DRILL F/710' T/1551' CBU, MONITOR WELL, PUMP PILL SHORT TRIP. DRILL F/1551' ~/1868'. CIRC GAS CUT MUD. DRILL F/1868' T/1968'. DRILL F/1968' T/2506'. CBU, MONITOR WELL, PUMP PILL. SHORT TRIP. DRILL F/2506' T/3271' DRILLING MW: 0.0 VIS: 0 DRILL F/3271' T/3552'. CBU. MONITOR WELL, PUMP PILL. SHORT TRIP, HOLE TIGHT. WANTED TO SWAB. HIT FILL @ 3545'. WASH & REAM TO BOTTOM. DRILL F/3552' T/4409'__CBU MONITOR WELL, PUMP PILL. SHORT TRIP. DRILL F/4409' T/4504', TIME DRILL F/4580' T/5040'. PUMPING PILL MW: 0.0 VIS: 0 DRILL F/5040' T/5056'. CBU. MONITOR WELL & PUMP PILL. POOH TO CDN, WELL WANTED TO SWAB. DOWNLOAD CDN & CDR, POOH W/ REST OF BHA, CHANGE BITS. SERVICE CROWN & TOPDRIVE. RIH W/ BHA, TEST MWD. RIH. REAM F/4980' T/5056'. DRILL F/5056' T/5710'. TIME DRILL F/5056' T/5600'. CIRC HI/LO VIS SWEEP, MONITOR WELL, DROP EMS, PUMP PILL. POOH, L/D DP MW: 0.0 VIS: 0 POOH, L/D DP & BHA. R/U ATLAS, RIH W/FMT AND GR. CIRC AND COND MUD FOR CSG. PUMP HI/LO VIS SWEEP W/LIGHT GELATION TREATMENT. MONITOR WELL, PUMP PILL. POOH, L/D DP. NU ADAPTER FLANGE MW: 0.0 VIS: 0 POOH LD DP & BHA. RU TO RUN CASING. TAG BOTTOM, TRY TO WASH DOWN. LD LANDING JT. CIRC MUD. TEST CEMENT LINE, FLUSH RIG PUMPS. TEST HALLIBURTON LINES, UNTHAW WATER TANK VALVE, PUMP WATER & NSCI SPACER, PUMP PLUG. RD CEMENTING EQUIP. BACKOUT LANDING JT. DO TOP JOB. ND DIVERTER, NU WELLHEAD, INSTALL TUBING HANGER, NU ADAPTER. WELL : MPI-05I OPERATION: RIG : NABORS 22E PAGE: 2 10/15/95 (8) TD: 0 'PB: 0 RELEASED @ 1300 HRS,10/14 MW: 0.0 NU ADAPTER & TEST, INSTALL TREE, TEST METAL TO METAL SEAL. TEST ADAPTER. TEST TREE, PULL 2 WAY CHECK. TEST CASING, INSTALL BPV. PREP RIG MOVE. RIG RELEASED @ 1300 HRS., 10/14/95. SIGNATURE: (drilling superintendent) DATE: SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO WellName: MPI-05i RigName: Polar #1 AFE: 3301 83 Accept Date: 04/02/96 Spud Date: Release Date: 04/1 0/96 Apr 2 1996 MU BHA #1. Start PU 2-7/8" tubing. Tally & drift all tubing. Depth of BHA-3700'. Cont in hole. Apr 3 1996 Cont running tubing. Finish in hole with 177 jts tubing and BHA. Tag PBTD. RU temporary line to reverse fluids back to mud tank, RU HB&R & pressure test casing, Good test, Record test on chart. State elected not to witness, Reverse circ well clean with seawater, Lost pressure and hydraulic fluid in closing unit, Having gen set problems, Well is secure, Shut down to troubleshoot. Order out diesel to freeze protect well, Gen set wil not start. Back-up gen set will not handle extra demand. Only one heater remains in service. Freeze protect well down to 1000', Apr 4 1996 Mechanic troubleshoot gen set & repair, Load out Koomey unit & send to Camco shop to replace all seals, Generator now running, Now electrical problem. Find two extra small tioga heaters & tarp in BOP area. RU HB&R, Thaw & freeze protect surface lines with methanol, Well is frozen at the wellhead valve & in tubing, Cont to work on electrical problems, Found bad transformer on 4.2 Mil btu heater. Look for replacement transformer to try repair this one. Wellhead valves OK now. Tubing still remains plugged. Cont with repairs to Koomey, Electrical repairs now waiting on parts, Repairs continue, Apr 5 1996 Cont to repair Koomey unit & Tioga heater. Parts arrived for Koomey. Start to replace all bottle seals & o-rings. Also replace on bad bladder. Cannot repair Tioga until Monday. RU HB&R. Pressure test line. Pressure up on tubing. Check annulus. Bump pressure on both tubing/annulus. Well is in communitations. RD. Cont with repair. Page Apr 6 1996 Cont with repairs. Unload seawater. Fire up line heater & circulate pits. Got BTU heater working. Koomey unit arrives on location. Spot unit & RU hydraulic lines. Function test HCR valve, pipe rams & Hydril from the closing unit controls & the remote station. Repair one small leak. Good test. State elected not to witness test. RU to reverse circ well. Unable to break circ. Pressure up on casing several times. Try going down tubing also with same results. Call out HB&R pump truck. Move tubing-- normal string weight. HB&R arrive on location & RU. Pressure test line. Good test. Pump thru "slush plug" with methanol. Increase rate & clean up tubing with methanol. RD HB&R. Apr 7 1996 Start to reverse circ well to warm wellbore & to clean up. Pump problems--seal on pony rod leaking. Also discovered a wield on the mud pit that is seaping. Shut down for repairs to pump. Pump repairs complete. Test pump, OK. Order out brine. Start brine down backside & reverse out seawater. Circ brine. Recovered three chunks of rubber. RU to pull tubing & BHA. Start POOH, LD 28 jts. Stand remaining in derrick. Finish POOH, LD BHA--casing scraper & mule shoe. RU for e-line operations. Complete RU. Apr 8 1996 Complete RU for logging/perforation operations. Atlas WL on location. Start RU. PU lubricator--GR/CCL/SBT logging tools. Start in hole with SBT using marked line. Run logs. RU for perforating operations. Arm & PU gun #1. Attempt to pressure test lubricator--problems with tri-plex pump. Start in hole with gun #1. Log main tie-pass & flag line. Tie into Atlas SBL. Fire gun & POOH. Cont with perforating operations in the Schrader Bluff & shoot zones with 3-3/8" HSC guns loaded at 6 spf with 21 g Alpha Jet charges phasing 600. A total of 7 guns were used while making 5 runs. All shots fired in following zones: 5208'-5249',5111'-5157',4974'-5022',4957'-4964'. Well on slight vacuum. Cont with perf operations. Two runs remain to finish. Apr 9 1996 Cont perforating. Finish with perf operations. A total of 3 guns were used while making 2 runs. All shots fired in following zones: 4914'-4938',4862'-4892'. Start to RD e-line. Well dead. RU for running completion string. Start PU completion string. Baker packer @ 4687'top. Install 2-way check valve. Land hanger. RILDS. Start to ND BOPE. While using blocks to LD mud cross & spacer spool, the "dog knot" popped out of the flange on the drilling drum. The blocks slid into the cellar and the dog knot went to the crown. No one hurt & 1/2" needle valve damaged. Well remains secure with the 2-way check valve in hanger & the BOP's are still on the wellhead. Wellhead pressure is zero. Secure blocks with the sandline. Shut down to discuss method of repair. Slip drilling line--add more line to drum. Blocks back in service. Contwith ND BOPE. BOPE removed. Install tree. Page 2 Apr 10 1996 Cont NU tree. Finish NU tree. Pressure test tubing head adapter & tree. Good test. RU HB&R. Pressure test lines, OK. HU to annulus & pump brine. Swith to diesel & freeze protect annulus t/2200'. HU to tubing side pump diesel, drop 1" ball, pump diesel. WO ball. Bring pump on line-ball on seat. Walk pressure up and hold. Packer set. HU up to annulus & perform MIT on annulus. Record on chart. Good test. State waived attendance. Bleed pressures to zero. RD HB&R. Release rig from well. Start RD. Clean pits. Page 3 PAGE 1 ANADRILL SCHLUMBERGER SURVEY PROGRAM AFE # 33O183 APl # 50-029-95044-00 COMPANY BP WELL NAME MPI-0$ i LOCATION 1 MILNE POINT LOCATION 2 ALASKA MAGNETIC DECLINATION 28.76 GRID CONVERGENCE ANGLE 0.00 DATE 8.OCT-95 WELL NUMBER 05 i WEKK HEAD LOCATION LAT (N/-S) AZIMUTH FROM ROTARY TABLE TO TARGET IS TIE IN POINT (TIP): MEASURED DEPTH TRUE VERTICAL DEPTH INCLINATION AZIMUTH , LATITUDE (NI-S) DEPARTURE (E/-W) 1.12 1,12 0.00 0.00 0.00 0.00 0.00 DEP (E/-W) 96.36 PagE 2 ANADRILL SURVEY CALCULATIONS CIRCULAR ARC METHOD MEASURE INTERVAL VERTICAL TARGET STATION DEPTH DEPTH SECTION INCLN, ff ff ff ff deg · 112.00 0.00 112.00 0.00 0.00 204.70 92.70 204.70 -0.10 0.17 264.96 60.30 264.96 -0.17 0.09 353.72 88.80 353.72 -0.28 0.11 444.88 91.20 444.88 -0.41 0.33 AZIMUTH deg 0.00 234.12 198.72 262.68 355.93 537.93 93.10 537.93 -0.48 0.41 627.92 90.00 627.91 -0.54 0.61 718.00 90.10 717.99 -0.25 0.69 809.48 91.50 809.48 1.24 1.48 900.18 90.70 900.10 4.20 2.28 MPI-O5 989.86 89.70 989.66 8.80 3.61 1085.00 95.10 1084.49 16.40 5.60 1181.76 96.80 1180.38 29.16 9.60 1276.60 94.70 1273.10 48.49 13.98 1370.68 94.20 1364.47 71.34 14.11 LATITUDE DEPARTU displacem at AZIMUT DLS N/-S E/-W deg/ ft ff ff deg 100ff 0.00 0.00 0.00 -0.08 -0.11 0.13 -0.18 -0.20 0.26 -0.25 -0.31 0.40 -0.01 -0.41 0.41 3.04 0.59 -0.42 0.72 0.80 1.39 -0.39 1.45 44.89 2.26 0.00 2.26 85.02 2.75 1.56 3.16 97.14 2.62 4.51 5.22 0.00 234.12 228.10 230.40 269.16 324.95 344.32 359.90 29.56 59.84 0.00 0.18 0.17 0.12 0.38 0.10 0.22 0.54 1.15 0.99 101.78 1.82 9.05 9.24 78.60 1.51 101.55 0.28 16.54 16.54 89.02 2.09 100.23 -2.09 29.11 29.18 94.12 4.14 97.40 -4.97 48.24 48.49 95.89 4.66 97.71 -7.98 70.89 71.34 96.42 0.16 1465.95 95.30 1456.69 95.20 14.91 97.82 -11.20 94.54 95.21 1562.20 96.20 1549.31 121.37 16.66 98.85 -15.01 120.45 121.38 1657.19 95.00 1639.87 150.05 18.49 97.54 -19.09 1 48.85 150.07 1761.72 104.50 1738.32 185.12 20.73 98.28 -23.93 183.60 185.15 1856.61 94.90 1826.20 220.86 23.58 99.63 -29.52 218.94 220.92 96.76 97.10 97.31 97.43 97.68 1951.79 95.20 1911.65 262.68 28.61 96.35 -35.23 260.38 262.75 2048.28 96.50 1994.87 311.48 32.17 96.02 -40.48 308.90 311.54 2143.12 94.80 2073.70 364.19 35.37 95.68 -45.85 361.34 364.23 2238.74 95.60 2149.83 422.02 39.08 96.12 -51.80 418.86 422.05 2333.75 95.00 2221.82 483.99 42.37 94.98 -57.78 480.55 484.01 97.71 97.47 97.23 97.05 96.86 2428.70 94.90 2290.16 549.88 45.55 2524.82 96.10 2355.60 620.27 48.62 2620.14 95.30 2418.30 692.05 49.12 2715.57 95.40 2480.09 764.75 50.17 2811.16 95.60 2541.43 838.05 49.99 0.84 1.84 1.97 2.15 3.05 5.50 3.70 3.38 3.89 3.55 2906.78 95.60 2602.92 911.27 49.97 3002.39 95.60 2664.19 984.62 50.30 3097.62 95.20 2724.92 1057.95 50.47 3192.78 95.20 2785.37 1131.43 50.65 3286.42 93.60 2844.65 1203.89 50.80 96.63 -64.47 548.10 549.89 96.73 3.56 95.63 -71.97 616.09 620.28 96.66 3.28 94.60 -78.37 687.60 692.05 96.50 0.97 95.44 -84.73 760.04 764.75 96.36 1.29 95.26 -91.57 833.04 838.06 96.27 0.24 94.96 -98.09 905.98 911.27 96.18 94.47 -1 04.12 979.12 984.64 96.07 95.39 -110.43 1 052.21 1057.99 95.99 94.34 -116.67 1125.43 1131.46 95.92 94.90 -122.51 1197.69 1203.94 95.84 0.24 0.52 0.76 0.87 0.49 PAGE 3 MPI-05 ANADRILL SURVEY CALCULATIONS CIRCULAR ARC METHOD MEASURE INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTU displacem at AZIMUT DLS DEPTH DE~PTH SECTION INCLN. N/-S E/-W degl ff ff ft ff deg deg ff ff ft deg 100ff 3380.90 94.50 2904.29 1277.14 50.90 95.86 -129.38 1270.63 1277.20 95.81 0.79 3474.84 93.90 2963.21 1350.31 51.41 95.74 -136.78 1343.42 1350.37 95.81 0.55 3571.64 96,80 3024.09 1425.54 50.64 94.49 -143.50 1418.38 1425.62 95.78 1.28 3666.71 95.10 3084.68 1498.79 50.18 95.63 -149.96 1491.35 1498.87 95.74 1.04 3762.82 96.10 3146.99 1571.93 48.99 94.04 -156.14 1564.26 1572.04 95.70 1.77 3857.69 94.90 3209.27 1643.45 48.94 94.35 -161.38 1635.64 1643.58 95.63 0.25 3944.47 86.80 3266.17 1708.94 49.10 94.79 -166.60 1700.95 1709.09 95.59 0.43 4039.62 95.20 3328.07 1781.18 49.74 95.08 -172.81 1772.95 1781.35 95.57 0.71 4135.68 96.10 3390.15 1854.45 49.73 94.60 -178.99 1845.99 1854.64 95.54 0.38 4229.31 93.60 3450.97 1925.61 49.25 94.45 -184.61 1916.96 1925,83 95.50 0.52 4324.84 95.50 3513.61 1997.71 48.80 96.16 -191.28 1988.77 1997.94 95.49 1.44 4421.73 96.90 3576.33 2071.56 50.53 97.09 -199.81 2062.12 2071.78 95.53 1.93 4515.45 93.70 3635.58 2144.17 51.04 97.01 -208.72 2134.18 2144.36 95.59 0.55 4610.32 94.90 3695.65 2217.55 50.40 99.69 -219.37 2206.83 2217.70 95.68 2.29 4705.89 95.60 3756.78 2290.85 50.07 100.55 -232.27 2279.15 2290.95 95.82 0.78 4800.22 94.30 3817.22 2363.08 50.23 100.53 -245.52 2350.34 2363.13 95.96 0.17 4895.67 95.40 3878.14 2436.34 50.44 100.88 -259.17 2422.54 2436.37 96.11 0,36 4992.23 96.60 3939.29 2510.82 50.98 101.49 -273.68 2495.86 2510.82 96.26 0.74 5087,55 95.30 3999.25 2584.63 51.06 101.40 -288.38 2568.49 2584.63 96.41 0.10 5184.26 96.70 4060.75 2658.87 49.96 102.99 -304.13 2641.44 2658.89 96.57 1,71 5279.56 95.30 4122.13 2731.34 49.84 102.02 -319.92 2712.60 2731.40 95.73 0.79 5374.85 95.30 4183.79 2803.51 49.53 103.88 -336.20 2783.40 2803.63 96.89 1.53 5470.76 95.90 4246.18 2875.74 49.31 103.78 -353.61 2854.14 2875.96 97.06 0.25 5566.16 95.40 4308.43 2947.49 49.24 103.10 -370.41 2924.45 2947.82 97.22 0.55 5629.74 63.60 4349.97 2995.30 49.16 102.65 -381.13 2971.37 2995.71 97.31 0.55 THE LAST SURVEY IS PROJECTED 5710.00 80.30 4402.46 3055.66 49.16 102.65 -394.43 3030.62 3056.18 97,42 0.00 ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPI-05i 500299504400 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/17/95 DATE OF SURVEY: 101295 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50098 KELLY BUSHING ELEV. = 63.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -63.90 83 83.18 19.28 174 174.35 110.45 264 264.39 200.49 355 355.92 292.02 0 0 0 19 0 19 0 18 0 20 N .00 E .00 .00N .00E N 27.77 E .39 .21N .liE N 45.66 E .11 .62N .42E N 76.96 E .19 .86N .84E N 73.00 E .04 .99N 1.34E .00 .09 .35 .74 1.22 447 447.34 383.44 538 538.57 474.67 629 629.51 565.61 721 721.08 657.18 812 812.09 748.19 0 32 0 37 0 51 0 55 1 38 N 43.11 E .33 1.39N 1.89E N 37.11 E .11 2.10N 2.49E N 31.08 E .27 3.08N 3.14E N 58.39 E .46 4.06N 4.13E N 80.07 E .93 4.67N 6.03E 1.73 2.24 2.78 3.65 5.48 902 902.62 838.72 998 997.85 933.95 1093 1093.13 1029.23 1189 1187.85 1123.95 1283 1280.03 1216.13 2 29 3 47 5 53 9 53 14 13 S 85.83 E 1.09 4.75N 9.27E S 79.93 E 1.41 4.04N 14.45E S 78.51 E 2.19 2.51N 22.37E S 80.58 E 4.21 .19N 35.29E S 82.57 E 4.60 2.64S 54.78E 8.69 13.91 21.96 35.06 54.73 1379 1372.54 1308.64 1474 1464.92 1401.02 1570 1556.91 1493.01 1666 1648.01 1584.11 1761 1738.02 1674.12 14 18 14 57 16 58 18 51 20 59 S 82.46 E .11 5.70S 78.10E S 82.14 E .69 8.94S 102.02E S 81.87 E 2.10 12.60S 128.09E S 81.94 E 1.96 16.75S 157.25E S 81.03 E 2.25 21.59S 189.50E 78.25 102.38 128.70 158.13 190.73 1857 1826.56 1762.66 1952 1912.77 1848.87 2048 1994.99 1931.09 2143 2074.17 2010.27 2238 2149.92 2086.02 22 11 28 46 32 18 35 34 39 20 S 79.64 E 1.37 27.48S 224.03E S 82.42 E 7.01 33.77S 264.63E S 83.76 E 3.76 39.58S 312.80E S 84.13 E 3.43 45.19S 365.79E S 84.36 E 3.95 51.00S 423.53E 225.70 266.74 315.25 368.54 426.57 2334 2222.09 2158.19 2429 2289.85 2225.95 2524 2354.69 2290.79 2620 2417.21 2353.31 2715 2478.86 2414.96 42 37 45 50 48 47 49 16 50 19 S 84.48 E 3.43 57.10S 485.91E S 84.56 E 3.41 63.40S 551.58E S 84.44 E 3.09 70.14S 621.58E S 84.89 E .60 76.83S 693.27E S 84.57 E 1.14 83.53S 765.90E 489.25 555.20 625.52 697.52 770.44 2810 2539.85 2475.95 2842 2560.33 2496.43 2937 2621.40 2557.50 3033 2682.73 2618.83 3128 2743.20 2679.30 49 57 49 51 5O 4 50 13 50 31 S 84.42 E .41 90.55S 838.60E S 84.38 E .32 92.92S 862.81E S 84.44 E .24 100.00S 935.15E S 84.38 E .16 107.15S 1008.27E S 84.29 E .34 114.35S 1080.94E 843.47 867.79 940.47 1013.94 1086.96 SRRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPI-05i 500299504400 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/17/95 DATE OF SURVEY: 101295 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-50098 KELLY BUSHING ELEV. = 63.90 FT. OPERATOR: BP EXPLORATION 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. 3223 2803.81 2739.91 50 34 S 84.45 E .14 121.58S 1154.26E 1160.62 3411 2922.95 2859.05 50 59 S 83.40 E .49 137.02S 1299.44E 1306.62 3507 2982.52 2918.62 52 7 S 84.47 E 1.46 144.95S 1374.05E 1381.65 3603 3042.56 2978.66 50 11 S 83.80 E 2.09 152.56S 1448.22E 1456.20 3698 3103.35 3039.45 50 22 S 83.65 E .23 160.56S 1520.93E 1529.36 3793 3164.89 3100.99 48 59 S 84.60 E 1.64 167.98S 1593.06E 1601.87 3887 3226.77 3162.87 48 54 S 84.52 E .10 174.72S 1663.79E 1672.90 3983 3289.28 3225.38 49 27 S 84.59 E .58 181.58S 1735.84E 1745.27 4079 3351.22 3287.32 49 53 S 84.68 E .46 188.40S 1808.50E 1818.24 4173 3411.69 3347.79 49 45 S 84.39 E .28 195.23S 1879.80E 1889.86 4268 3473.77 3409.87 49 17 S 83.97 E .59 202.60S 1952.19E 1962.62 4364 3536.31 3472.41 48 46 S 83.64 E .61 210.38S 2023.81E 2034.66 4459 3597.85 3533.95 51 2 S 82.96 E 2.43 218.92S 2096.41E 2107.76 4555 3657.55 3593.65 51 37 S 81.72 E 1.18 228.86S 2170.34E 2182.33 4650 3717.80 3653.90 50 19 S 79.78 E 2.08 240.79S 2243.68E 2256.55 4744 3777.58 3713.68 50 36 S 79.36 E .46 253.91S 2314.92E 2328.80 4840 3838.32 3774.42 50 12 S 78.76 E .63 267.84S 2387.02E 2402.00 4935 3899.16 3835.26 50 48 S 79.00 E .65 282.07S 2459.45E 2475.56 5030 3959.19 3895.29 51 1 S 77.59 E 1.17 297.07S 2531.81E 2549.14 5126 4019.35 3955.45 50 46 S 77.85 E .34 312.81S 2604.15E 2622.78 5221 4080.28 4016.38 49 54 S 76.63 E 1.33 329.04S 2675.83E 2695.81 5317 4141.94 4078.04 49 41 S 76.46 E .27 346.02S 2746.79E 2768.21 5413 4204.06 4140.16 49 17 S 75.64 E .77 363.55S 2817.36E 2840.30 5508 4266.10 4202.20 49 15 S 76.10 E .36 381.14S 2887.26E 2911.71 5566 4304.01 4240.11 49 4 S 76.29 E .41 391.61S 2929.86E 2955.21 5706 4395.64 4331.74 49 4 S 76.29 E .00 416.66S 3032.57E 3060.06 THE C~LCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3061.06 FEET AT SOUTH 82 DEG. 10 MIN. EAST AT MD = 5706 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 96.36 DEG. EXTRAPOLATED DEPTH AT 5706' ~ ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPI-05i 500299504400 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/17/95 DATE OF SURVEY: 101295 JOB NUMBER: AK-EI-50098 KELLY BUSHING ELEV. = 63.90 FT. OPER3ITOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -63.90 .00 N .00 E 1000 999.73 935.83 4.02 N 14.57 E 2000 1953.96 1890.06 36.72 S 287.90 E 3000 2661.43 2597.53 104.65 S 982.81 E 4000 3299.95 3236.05 182.76 S 1748.26 E .00 .27 .27 46.04 45.77 338.57 292.53 700.05 361.48 5000 3939.70 3875.80 291.89 S 2508.29 E 5706 4395.64 4331.74 416.66 S 3032.57 E 1060.30 360.25 1310.36 250.06 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ,RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPI-05i 500299504400 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/17/95 DATE OF SURVEY: 101295 JOB NUMBER: AK-EI-50098 KELLY BUSHING ELEV. = 63.90 OPER3~TOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SI/B-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -63.90 63 63.90 .00 163 163.90 100.00 263 263.90 200.00 363 363.90 300.00 .00 N .00 E .11 N .06 E .58 N .37 E .86 N .84 E .00 N 1.38 E .00 .00 .00 .00 .00 .00 .00 .01 .00 463 463.90 400.00 563 563.90 500.00 663 663.90 600.00 763 763.90 700.00 863 863.90 800.00 1.50 N 2.00 E 2.33 N 2.66 E 3.52 N 3.41 E 4.41 N 4.75 E 4.87 N 7.59 E .01 .00 .01 .01 .02 .01 .04 .01 .08 .04 964 963.90 900.00 1064 1063.90 1000.00 1165 1163.90 1100.00 1267 1263.90 1200.00 1370 1363.90 1300.00 4.44 N 12.23 E 3.11 N 19.42 E .84 N 31.42 E 2.12 S 50.88 E 5.41 S 75.91 E .19 .11 .47 .28 1.23 .76 3.18 1.95 6.32 3.14 1473 1463.90 1400.00 1577 1563.90 1500.00 1682 1663.90 1600.00 1789 1763.90 1700.00 1897 1863.90 1800.00 8.90 S 101.75 E 12.90 S 130.20 E 17.51 S 162.62 E 23.14 S 199.31 E 30.22 S 240.14 E 9.66 3.34 13.72 4.06 18.96 5.24 25.64 6.68 33.91 8.27 2011 1963.90 1900.00 2130 2063.90 2000.00 2257 2163.90 2100.00 2392 2263.90 2200.00 2538 2363.90 2300.00 37.41 S 293.81 E 44.44 S 358.57 E 52.14 S 435.07 E 60.92 S 525.59 E 71.16 S 632.04 E 47.69 13.78 67.06 19.38 93.25 26.18 128.45 35.21 174.91 46.45 2692 2463.90 2400.00 2848 2563.90 2500.00 3003 2663.90 2600.00 3160 2763.90 2700.00 3318 2863.90 2800.00 81.83 S 747.95 E 93.33 S 867.02 E 104.94 S 985.77 E 116.85 S 1105.97 E 128.67 S 1227.04 E 228.36 53.46 284.28 55.92 339.96 55.68 396.77 56.81 454.25 57.48 3477 2963.90 2900.00 3636 3063.90 3000.00 3792 3163.90 3100.00 3944 3263.90 3200.00 4098 3363.90 3300.00 142.64 S 1350.23 E 155.32 S 1473.66 E 167.88 S 1591.93 E 178.79 S 1706.30 E 189.80 S 1823.49 E 513.54 59.29 572.92 59.38 628.32 55.40 680.63 52.31 735.08 54.45 RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE PT/MPI-05i 500299504400 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/17/95 DATE OF SURVEY: 101295 JOB NUMBER: AK-EI-50098 KELLY BUSHING ELEV. = 63.90 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 4253 3463.90 3400.00 201.40 S 1940.78 E 789.66 4406 3563.90 3500.00 213.91 S 2055.25 E 842.17 4565 3663.90 3600.00 230.02 S 2178.27 E 901.54 4723 3763.90 3700.00 250.83 S 2298.54 E 959.35 4880 3863.90 3800.00 273.83 S 2417.15 E 1016.19 54.57 52.51 59.37 57.8~ 56.83 5038 3963.90 3900.00 298.32 S 2537.51 E 1074.58 5196 4063.90 4000.00 324.54 S 2656.90 E 1132.51 5351 4163.90 4100.00 352.08 S 2771.96 E 1187.42 5504 4263.90 4200.00 380.53 S 2884.78 E 1240.84 5657 4363.90 4300.00 407.99 S 2996.99 E 1293.64 58.39 57.94 54.91 53.42 52.80 5680 4378.61 4314.71 412.01 S 3013.48 E 1301.39 7.75 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) August 5, 1996 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 R CE VE.D AUG 0 8 ~996 Alaska 0il & Gas Cons. commission Anchorage The following data of the Depth shifted CDR/CDN,CDR/CDN 'f'VD'.S forwell MPI-051 ~"- Job # 95349 was sent to' BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each 1 Depth shift display _ . . .---- State of Alaska /" Alaska Oil & Gas Conservation Comm. Attn: Larry Grant '------_30_.01 Porcupine Ddve " An c~-a~]-b-7, Al a ska - 9950 t 1 OH LIS Tape 1 Blueline each 1 RF Sepia each OXY USA, Inc Attn' Dadene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 429 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 15 May 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: MPZ-05 fff-/~O ~7217 1 LDWG TAPE+LIS ~T/G~ Run # 1 MPL-21 q]--Ill $72/~ i ~,DWC TAPE+~.IS X~r/~ Run ~ 1 ECC No. 6500.01 6661.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: ~aske 0~t & Gas Cons. Comm~ss~o~ Anr:hom.qe LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION ~ SBT FINAL BL+RF /1 PFC/PERF FINAL BL+RF '~ PLS FINAL BL+RF ~ PFC/PERF FINAL BL+RF /1 PLS FINAL BL+RF ~ GR/CCL FINAL BL+RF ~ PFC/PERF FINAL BL+RF ECC No. Run # 1 6500.01 Run # 1 Run # 1 6512.03 Run # 1 Run # 1 Run # 1 Run # 1 6644.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Received by: .... 90Anchorage, AK 99518 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: Date: RE: 24 October 1995 Transmittal of Data ECC #: 6500.00 Sent by: HAND CARRY D at a: FMT BP ~X~.NE ~OIN~ / S~P Enclosed, please find the data as described below: Prints/Films: 1 FMT/GR FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ , /~Or F~_~ (907)563-7803 . . an:horag~ commission. ~KA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 17, 1995 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPI-05 BP Exploration (Alaska), Inc. Permit No 95-120 Surf Loc 2338'NSL, 3906'WEL, Sec. 33, T13N, R10E, UM Btmhole Loc 2042'NSL, 1172'WEL, Sec. 33, T13N, R10E, UM Dear Mr. Schofield: 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 ddlling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be nspector 659-3607. _ ~. w~ ~ C. hair% ' ' ~ By ORDE~ MMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrilll-I lb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[] Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 110. Field and Pool BP Exploration (Alaska) Inc. KBE = 64 feet Milne Point / Schrader Bluff 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025906 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2338' NSL, 3906' WEL, SEC. 33, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2074' NSL, 1464' WEL, SEC. 33, T13N, RIOE MPI-05 2S100302630-277 At total depth 9. Approximate spud date Amount 2042'NSL, 1172' WEL, SEC. 33, T13N, RIO~ 08/18/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line 025627 2042 feet No Close Approach feet 2560 5385'MD/4115' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~ooo feet Maximum hole angle 6o.z o Maximum surface 1220 psig At total depth (TVD) 3849'/ 1593 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.4~ H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 8-1/2" 5-1/2" 17# L-80 Btm 5354' 31' 31' 5385' 4179' 719 sx PF 'E', 204 sx Trinity Lite-Ware, 250 sx PF 'E' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural SurfaceC°nduct°r. r' Intermediate Production AUG 0 8 1995 Liner Perforation depth: measured ,a~aska, IJll & Gas Cons, Commission true vertical '. 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] lDrilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirementsl-I 121. I hereby certify that the foregoing, i,sltrue and correct to the best of my knowledge Signed Z;;,~ ~ c:.fl~':-~,...~c~,~ Title Senior Drilling Engineer Date //7 Commission Use Only Permit Number IAPI number Approval date See cover letter ~',.~-//'_2_~:~ 150_c:~_,/~_ ~ ~ _~F'~'~,,~ ,~. / -~ . O,./,~'~ for other requirements Conditions of approval Samples required [] Yes ~E~No Mud Icg required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required J~ Yes [] No Required working pressure for DOPE [] 2M; [~3M; 1-15M; r-I10M; I-I15M; Other: Original Signea by order of Approved by David W. JohnstoR Commissioner [ne comm.ssion Date ~'t Form 10-401 Rev. 12-1-85 Submit in triplicate I Well Name: ] MPI-05i Well Plan Summary I Type of Well (producer or injector): I Schrader Bluff I I Injector Surface Location: 2338' FSL 3906' FEL Sec 33 T13N R10E UM., Ak. Target Location: 2074' FSL 1464' FEL Sec 33 T13N R10E UM., Ak. Bottom Hole Location: 2042' FSL 1172' FEL Sec 33 T13N R10E UM., Ak. ]AFENumber: ] 330183 Estimated Start Date: ] 8/18/95 I I Operating days to complete: 1 7 IUD: 15385' [ I TVD: 14115' bkb] [KBE: 164' Well Design (conventional, slimhole, etc.): ] 5.5" Uni-Casing Schrader Bluff Injector Formation Markers: Formation Tops MD TVD (BKB) Formation Pressure Data KOP 1000 1000 - Base Permafrost 1919 1884 - Top NA Sand 4928 3829 EMW 8.0 ppg Target 4928 3829 EMW 8.0 ppg Top NB Sand 4955 3849 EMW 8.0 ppg Top NC Sand 4987 3874 EMW 8.0 ppg Top ND Sand 5013 3894 EMW 8.0 ppg Top NE Sand 5046 3919 EMW 8.0 ppg Top OA Sand 5124 3979 EMW 8.0 ppg Top OB Sand 5203 4039 EMW 8.0 ppg AUG 0 B 1005 Base OB Sand 5235 4064 EMW 8.0 ppg TD 5385 4179 _ , ~A Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Corm Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.4# H-40 Weld 80' 32/32" 112'/112' 8.5 5.5" 17# L-80 btrc 5354' 31'/31' 5385'/4179' Internal yield pressure of the 5-1/2" 17# L-80 casing is 7740 psi. Worst case surface pressure would occur with a full column of gas on top of plugged perfs at the reservoir at 3849' tvd. Maximum anticipated surface casing pressure assuming virgin pressure of 1593 psi at 3849' tvd is 1220 psi, which is well below the burst pressure rating of the 5-1/2" casing. Logging Program: I Open Hole Logs: Production Cased Hole Logs: LWD CDR/CDN (GR/Res/Density/Neutron) RFT (Atlas) GR/CCL, SBT, and Wireline Perforate (w/out rig on well) Mud Program: [Special design considerations [None ABOVE PERMAFROST <2000' MD: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.0 90 35 15 30 10 15 PERMAFROST TO TD: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 9.2 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Lines. Completion Rig (Nabors 4ES) 5000 psi W.P. pipe ram, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: IKOP: I 1000', S-Shaped Maximum Hole Angle: I 60.67° Close Approach Well: I NONE Disposal: Cuttings Handling: CC2 Fluid Handling: All drilling and completion fluids will be hauled to CC2 for injection. Annular Injection: The MPI-05 well will not have an annulus available for annular pumping since it is being permitted as a single casing well (Same as the MPE-15 drilled in May 1995. Consequently, no drilling or completion fluid will be injected in this well.) / UG 0 8 1995 Gas Cons. Commission N~chorage o . o . . o . 10. 11. 12. 13. 14. MPI-05i Well Operations Summary Drill and set 20" conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. N/U and function test 20" Diverter system. Directionally drill 8.5" hole as per directional plan. Run Atlas (RFT) tool. Wiper Trip. Run and cement 5.5" 17# L80 Modified Buttress Tubing casing to surface (perform top job if req'd). N/D Diverter and N/U wellhead -- Test Tree. RDMO Nabors 22E. MIRU Nabors 4ES. N/U B OPE and test. Run SBT Cement Bond Log and Perforate the "N" and "O" sands without rig. Complete well with single permanent packer RIH on 2-7/8", 6.5#, L-80 EUE tbg. Set BPV. N/D BOP Stack and N/U x-mas tree. RDMO with Nabors 4ES Drilling Hazards and Risks: No drilling hazards or risks have been identified for this well. AUG 0 8 19 5 fJji .& Gas Cons. CommL~/o~ ,. ~omge MPI-05i 5-1/2" PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 5-1/2" CIRC. TEMP: 75° F at 4500' TVDss SPACER: 75 bbl fresh water. LEAD CEMENT TYPE: Temp E Permafrost ADDITIVES' Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX. # SACKS: 719 THICKENING TIME: Greater than 4 hrs at 50°F TAIL CEMENT TYPE: Trintiy Lite-Wate ADDITIVES: 2.0% CACL2, 0.2% CFR-3, 0.3% HALAD-344 WEIGHT: 12.8 PPG YIELD: 1.45 ft3/sx MIX WATER: 6.61 gal/sk APPROX. # SACKS: 204 THICKENING TIME: Greater than 3 hrs at 50°F FLUID LOSS: 50cc FREE WATER: 0 TOP JOB CEMENT TYPE: (If Needed) Permafrost E ADDITIVES: Retarder WEIGHT: 12.0 PPG YIELD: 2.17 ft3/sk ,, ED AUG 0 8 Gas Con~. Com~issiO. n mx APPROX. NO. SACKS: 250 CENTRALIZER PLACEMENT: 1.5-5/8" x 8-1/4" Straight Blade Turbulators -- two per joint on the bottom 19 its of 5-1/2" Casing (38 Total). This will cover 300' above the top of the "N" sands. 2. Run one 5-5/8" x 8-1/4" Straight Blade Turbulator inside of the 20" casing. OTHER CONSIDERATIONS: 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 requirements. Displace at 14 BPM Minimum. Batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry Volume is calculated to cover 500' md above the top of the upper "N" sands with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3.80' capacity for float joints. 4. Top Job Cement Volume will be 250 sx, if necessary. ~NCHOR~GEE TEL Ruq 02,95 15:5;1 No.004 P.O5 ..................~' ... w"-..~-x~..?~... ~'~?: ::.~ '" SHARED S' RVICES ORZLLI.N ....... I _ _, _ ,. · II ~ o o o o.oo,',-~ ~.~,.'~,... C) END 3/100 BUILD 302Z 2665 974 ~.67 .... , · O) DROP 2.5/~00 370~ ~998 1567 60.67 E) END 2.5/~00 DR~ 45~8 3523 e200 40.00 Section aL: 96.$6 F) TARG[T 4926 3829 2457 40.00 TVD Scale' I inch = 600 feet: 5385 4179 .a750 40.00 Oep Scale.' ~ inch = 600 feel TO ~ ~- Opawn ..... : 08/0Z/95 .... , ~0 ...................... ~nedr .. GOO - ' ' ' ' ~oo ~ .... A~G O ~ ~il A Gas Con~ C_o ~i~]~ B ~oo ............................ ~'~ ~[~ ~.: ................... K ...',. .' B t8oo ........ ~ ... .......... a~~ ~'!~ ': "" " ' ' ' -.~,~.~,, . ,~m.. ......... : ' NO~(~AP pRO ~[D FOR ,,oo ...... . 2700 .... ~ . .,- ....... · 'r ........ - - ~000 3~00 .................... ~ ........ X . ~00 ..... ~ .......... - .................. ~ - ~-~ .................. 3900 ......... ~.c ~ - - 4~00 .... '¢~E6 ~ ¢ -~ .............................. %', ... .,. · , , , .,'. .'. . '.. . · . .:., ; :. ~',: ;..: -.. ~fi00 ............................... ~g00 ....... 0 300 600 900 i~O0 t500 1800 2100 2400 2700 3000 3300 3600 3900 Section De ap[upe .......... DVICES DRI'ELI'NG" I ,4nadni]] £cl~lu. ber'ger' ! SHAREDSE ' i i i I i i ill I i~ i I ill i ii ii i ii ii I i I i i I MP 1-05 (P PLAN VIE~ i CLOSU~ - ~750 feet at Azimuth 96.16 ~. DECLI SCALE i- · ~AWN . · · El E~ 2 F) TAROT G) iD {J~l~lll' ~:)~Dm~IDOM I~l..~.:tI.t M 1) . ' . 200 0 " 2(]0 <- ~EST - E~.,c'I:' -) 1400 ltg~ ]BOD L~)O E~)O 2404} L~oO0 L:)BO0 ~00 ~)00 i IATION.: 28.79( E ' 1 inch = 400 feet · 08/0~/95 l~,nti f ication MO N/S E/M ~ .... i · 'BUILD 3/lOO lO00 0 0 . a/t~ BUILD 30~a ,04 9. I ANAl,: ~)LL AKA-DP(' ~ 2,5/100 370~ ~.5/tO0 ~P ~f 4~8 ~ ~442 ~ ~ ~. NO" APPRO'FED~FOR I bAbLU I I N . ~ ....,I .... ~ "' . . - . . · ~ U. 8 1: ~95 ~ : " F~. /'~ c.: . ' " . '... . " '" ~'¢ ':. . ' .....- ; - ::. . r. .~' . ' . . .... : ',~:' . .-.:. - ~...., .. , VVI=LL PERMIT CHECKLIST FIELD & POOL ~ ~--~,//~/ ~/ COMPANY INIT CLASS ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... ~ N 11. Permit can be issued without conservation order .... / N 12. Permit can be issued without administrative approval. ~ N 13. Can permit be approved before 15-day wait ....... \. N ENGINEERING UNIT# PROGRAM: exp [] dev [] redrll [] serv~ oN,oFF APPR DATE 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~OO psig. 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of ~2S gas probable ............. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ?'Y N 34. Contact name/phone for weekly progress reports . . . ?. Y N [exploratory only] ,' GEOLOGY: ENGINEERING: COMMISSION: JD~ / ~AD T~ \ ~'"X'------ Comments/Instructions: HOW/jo - A:~FORMS~cheklist rev 03/94 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. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : B.P. EXPLORATION WELL NAlVlE : MPI- 05 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22583-00 REFERENCE NO : 95349 Date~ LIS Tape Ver=£ication Listing Schlumberger Alaska Computing Center 1-AUG-1996 15:12 PAGE: **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 96/08/ 1 ORIGIN : FLIC REEL NA~E : 95349 CONTINUATION # : PREVIOUS REEL : COF~4~a%~f · BP EXPLORATION, MIL1VE POINT MPI-05, API# 50-029-22583-00 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE · 96/08/ 1 ORIGIN : FLIC TAPE NAME : 95349 CONTINUATION # : 1 PREVIOUS TAPE : COMPIEiVT : BP EXPLORATION, MILNE POINT MPI-05, API# 50~029-22583-00 TAPE HEADER MILNE POINT MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MPI- 05 500292258300 B. P. EXPLORATION SCHLUMBERGER WELL SERVICES 1 -AUG-96 BIT RUN 1 BIT RUN2 JOB NUMBER: 95349 95349 LOGGING ENGINEER: ST. AMOUR ST. AMOUR OPERATOR WITNESS: MOUNTJOY MOUNTJOY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING BIT RUN 3 33 13N IOE 2434 3785 63.90 63.90 34.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 20.000 112.0 LIS Tape Ver==ication Listing Schlumberger Alaska Computing Center 1-AUG-1996 15:~2 3RD STRING PRODUCTION STRING Well drilled 08~OCT through 12-0CT-95 with CDR/CDN. All data was collected in two bit runs. NOMAD data was collected. $ $ PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 96/08/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NI]M~ER: 1 EDITED MERGED~fWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SU~RY LDWG TOOL CODE .............. LWD $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (f4EASURED DEPTH) START DEPTH STOP DEPTH 239.0 5723.0 BASELINE DEPTH 88888.0 5490.5 5440.0 5397.5 5350.5 5320.0 5310.0 5280.5 5260.5 5235.0 5198.0 5167.5 5141.5 5102.0 5058.0 5014.0 4977.0 4961.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... LWD ....... 88901.5 5504 0 5453 0 5408 0 53 63 5 5334 5 5323 0 5293 0 5274.0 5248.0 5212.0 5180.5 5155.0 5115.5 5071.5 5028.0 4988.0 4975.0 LIS Tape Verx=ication Listing Schlumberger Alaska Computing Center 4947.0 4918.5 4898.5 4861.0 4832.0 4811.0 4801.5 4799.0 4784.5 4772.0 4749.5 4722.5 4696.0 4654.5 4629.0 4573.5 4565.0 4544.0 4540.0 4501.5 4453.0 4421.5 4416.0 4398.0 4391.5 4383.5 4370.0 4355.5 4330.0 4313.0 4260.5 4245.5 4203.0 4197.0 4184.5 4150.0 4115.0 4073.5 4O46.5 4035.5 4016.5 4004.0 3963.5 3936.5 3925.0 3920.0 3895.5 3813.0 3786.0 3784.0 3777.5 3772.5 3754.0 3743.0 3721.0 4961.5 4932 5 4912 5 4875 0 4844 0 4825 0 4815 5 4813 0 4796 0 4786 0 4763.0 4737.5 4710.0 4668.5 4643.0 4588.0 4578.5 4557.0 4550.5 4512.5 4464.5 4432.5 4426.5 4409.5 4400.0 4391.0 4381.5 4367.0 4342.0 4324.5 4272.5 4257.0 4214.5 4209.5 4196.5 4162.0 4127.5 4085.5 4058.5 4047.0 4028.5 4016.5 3974.5 3948.5 3937.0 3931.5 3907.5 3825.0 3798.0 3795.5 3789.0 3783.5 3765.0 3754.5 3732.5 1-AUG-1996 15:~2 PAGE: LIS Tape Verx~ication Listing Schlumberger Alaska Computing Center 1-AUG-1996 15:]~z PAGE: 3593.0 3587.5 3520.5 3514.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REM_ARKS: 3605.0 3599.0 3531.5 3525.5 100.0 BIT RUN NO. ~ERGE TOP MERGE BASE 1 239.0 5070.0 2 5070.0 5723.0 The depth adjustments shown above reflect the MWD GR to the GR logged by Atlas. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Ver~,~ication Listing Schlumberger Alaska Computing Center 1-AUG-1996 15:~tz PAGE: ** SET TYPE - CHAN ** NAbtE 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 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OI~ff4 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OHbfi~ O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OH2V~l O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~M O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OHbff4 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E O0 000 O0 0 1 1 1 4 68 0000000000 CALNt4WD IN O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GRCH GAPI O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 5723.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 151.260 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD -999.250 GRCH. GRCH -999.250 DEPT. 239.500 RA.t4WD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 FET.MWD GR.MWD -999.250 RHOB.I4WD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.14WD 40.900 GRCH. GRCH -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE - FLIC VERSION : O01CO1 DATE : 96/08/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Vez~=ication Listing Schlumberger Alaska Computing Center 1-AUG-1996 15:12 PAGE: **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iVL~4~ER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~W~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 239.0 5056.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (FIEMORY or REAL-TIM~) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMOl~ ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 12-0CT-95 FAST2.5 4.0C MEMORY 5710.0 239.0 5710.0 70 0.0 50.2 TOOL ~ER ........... RGS022 NDS022 8.500 112.0 LSND 10.50 50.0 LIS Tape Ve~xfication Listing Schlumberger Alaska Computing Center 1-AUG-1996 15 :~I2 PAGE: MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3): RESISTIVITY (Okff4M) AT TEMPERATURE (DEGF): MUD AT FiEAS~ TEMPERATURE (MT): 2.970 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 730 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN 1 ************* DRILLED INTERVAL 112 ' - 5056 ' RES TO BIT: 47.32'; GR TO BIT: 57.74 ' NEUT TO BIT: 109.28'; DENS TO BIT: 102.34' ************ RU/V 2 ************* DRILLED INTERVAL 5056' - 5710' DISTANCES TO BIT SAME AS RUN ONE DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA 73.0 73.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Ve~£ication Listing Schlumberger Alaska Computing Center 1-AUG-1996 15:12 PAGE: ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 RA LW1 OH~4~ O0 000 O0 0 2 1 1 4 68 0000000000 RP LW1 OH~4~ O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OP~4~ O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 FPHR O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LWl BN/E O0 000 O0 0 2 1 1 4 68 0000000000 CALN LW1 IN O0 000 O0 0 2 1 1 4 68 0000000000 NPHI LW1 PU-S O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 5055.500 RA.LW1 -999.250 RP.LW1 -999.250 DER.LW1 ROP.LW1 25. 034 FET. LW1 -999.250 GR.LW1 -999.250 RHOB.LW1 DRHO. LW1 -999. 250 PEF. LW1 -999. 250 CALN. LW1 -999. 250 NPHI. LW1 DEPT. 238. 500 RA. LW1 -999. 250 RP. LW1 -999. 250 DER. LW1 ROP.LWi -999.250 FET. LW1 -999.250 GR.LW1 -999.250 RHOB.LW1 DRHO.LW1 -999.250 PEF.LW1 -999.250 CALN. LW1 -999.250 NPHI.LW1 -999.250 -999.250 -999.250 -999.250 -999.250 43.800 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 96/08/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Ve~==ication Listing Schlumberger Alaska Computing Center 1-AUG-1996 15:12 PAGE: FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 4875.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIFiE) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) '. HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH .......... 5710.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (Otff4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 12-0CT-95 FAST2.5 4. OC MEMORY 571 O. 0 239.0 5710.0 80 49.2 51.1 TOOL NUMBER RGS022 NDS022 8.500 112.0 LSND 10.50 50.0 500 2. 970 73.0 2.730 73.0 SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-AUG-1996 15:12 PAGE: 10 TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 RE~AR~S: ************ RUN 1 ************* DRILLED INTERVAL 112' - 5056' RES TO BIT: 47.32'; GR TO BIT: 57.74' NEUT TO BIT: 109.28'; DENS TO BIT: 102.34' ************ RUN 2 ************* DRILLED INTERVAL 5056' - 5710' DISTANCES TO BIT SAME AS RUN ONE DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 36 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 O0 000 O0 0 3 1 1 4 68 0000000000 RA LW2 OH~ O0 000 O0 0 3 1 1 4 68 0000000000 RP LW2 OH~ O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 OH~ O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 FPHR O0 000 O0 0 3 1 1 4 68 0000000000 FET LW2 HR O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-AUG-1996 15:~2 PAGE: 11 * * DATA * * DEPT. 5709. 500 RA. LW2 -999. 250 RP. LW2 -999. 250 ROP. LW2 151.2 60 FET. LW2 -999. 250 GR. LW2 - 999. 250 DEPT. 4875. 000 RA. LW2 -999. 250 RP. LW2 -999. 250 ROP. LW2 - 999.250 FET. LW2 - 999.250 GR. LW2 - 999.250 DER. LW2 DER. LW2 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/08/ 1 ORIGIN : FLIC TAPE NAME : 95349 CONTINUATION # : 1 PREVIOUS TAPE : CO~ff~_2~T . BP EXPLORATION, MILNE POINT MPI-05, API # 50-029-22583-00 **** REEL TRAILER **** SERVICE NAFiE : EDIT DATE : 96/08/ 1 ORIGIN · FLIC REEL NA~E : 95349 CONTINUATION # : PREVIOUS REEL : CO~ENT · BP EXPLORATION, MILNE POINT MPI-05, API# 50-029-22583-00 MPI- 05 MILNE POINT i i _m _. _, I i:::~ WESTERN I _m' i'~~i:::1 V ATLAS I MAY 2 1 1996-.- · t, oggmg Services A!aska 0il & Ga~ Cons. COml~S~n Anchomfi~ ape Subfile 2 is type:' 'S TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: 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 MPI - 05 500292285300 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 03 -MAY- 96 6500.01 DAHL/BARKER L. HINKEL 33 13N 10E 2338 3906 63.90 34.40 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 20.000 115.0 PRODUCTION STRING 5.500 5688.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SBT GRCH 2 1 08-APR-96 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: SBT/GR/CCL. 91.10 17.00 LOG WAS RUN AS A MARKED LINE GAMMA RAY, ORIGINAL DEPTH REFERENCE. NOTE: REPEAT PASS IS 1' DEEP. SHIFT PROCEDURE AS FOLLOWS: 1) SECOND PASS GAMMA RAY DEPTH MATCHED TO FIRST PASS GAMMA RAY. $ , FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 3500.0 5550.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS) . NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPI - 05 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 2 TENS GR 68 1 LB 4 4 30 995 99 1 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 49 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 3500.000000 5550.000000 0.500000 Tape File Depth Un ~ = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12304 datums Tape Subfile: 2 140 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: ~iS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 5095.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 5108.5 5109 5 5211.5 5212.5 5212.0 5213.5 5239.0 5240.5 5240.0 5241.0 5274.5 5275.5 5324.0 5325.5 5327.0 5328.5 5335.5 5336.5 5343.0 5344.0 5361.0 5363.0 5365.5 5367.5 5366.5 5368.0 5367.5 5369.0 5368.0 5370.0 5439.0 5440.0 5444.5 5445.5 5445.5 5446.0 5446.0 5447.0 5457.5 5459.5 5459.0 5461.0 5545.0 5545.0 5545.5 5545.5 $ REMARKS: for each run in separate files. STOP DEPTH 5550.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH PASS 2 (REPEAT PASS) . TENS SHIFTED WITH GRCH CN WN FN COUN STAT /? ?MATCH2A. OUT $ : BP EXPLORATION : MPI - 05 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 04 ) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 995 99 1 4 30 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 11 1014 BYTES * Tape File Start Depth = 5090.000000 Tape File End Depth = 5550.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2764 datums Tape Subfile: 3 67 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: ~£S FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and lo9 header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3500.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR AC CENT SBT VDL CENT $ STOP DEPTH 5564.0 CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON CENTROLLER SEGMENTED BOND TOOL VDL SUB CENTROLLER 08-APR-96 FSYS REV. J001 VER. 1.1 1232 08-APR-96 5602.0 5596.0 3500.0 5588.0 1500.0 YES TOOL NUMBER 2330NA 1309XA 1633EA 1424MA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : LOGGER' S CASING DEPTH (FT) : 0.000 5688.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG): BRINE 8.70 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1 (MAIN PASS). $ CN : BP EXPLORATION WN : MPI - 05 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Cllrves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 4 30 635 99 1 20 * DATA RECORD (TYPE# 0 ) 1014 BYTES * Total Data Records: 197 Tape File Start Depth = 3500.000000 Tape File End Depth = 5565.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 61871 datums Tape Subfile: 4 274 records... ,~inimum record 'length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CIIRVES Curves and log header data for eaCh pass in separate files; raw'background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5090.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR AC CENT SBT VDL CENT $ STOP DEPTH 5564.5 CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON CENTROLLER SEGMENTED BOND TOOL VDL SUB CENTROLLER 08-APR-96 FSYS REV. J001 VER. 1.1 1042 08-APR-96 5602.0 5596.0 3500.0 5588.0 1500.0 YES TOOL NUMBER 2330NA 1309XA 1633EA 1424MA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT) : 0.000 5688.0 0.0 BOREHOLE COND I T IONS 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) : BRINE 8.70 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHER1KAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : 0.00 0.000 BLUELINE COUNT RATS NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN) : 0.0 REMARKS: PASS 2 (REPEAT PASS) . $ CN : BP EXPLORATION WN : MPI - 05 FN : MILNE POINT COLTN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 46 Tape File Start Depth = 5090.000000 Tape File End Depth = 5565.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 14171 datums Tape Subfile: 5 123 records... Minimum record 'length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS O1 **** REEL TRAILER **** 96/ 5/ 7 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 7 MAY 96 8:56a Elapsed execution time = 4.50 seconds. SYSTEM RETURN CODE = 0
