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197-149
1111 III F1ECEWED STATE OF ALASKA FEB 0 2 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANODOCC 1a.Well Status: Oil❑ Gas SPLUG ❑ Other ❑ Abandoned Q' Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q, Exploratory❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: _0 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC - Aband.: 12/14/2017 197-149/316-483 3.Address: 7.Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 8/23/1997 50-029-22795-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2834; FSL 4167'FEL,SEC.34,T13N, R10E, UM 8/27/1997 MILNE PT UNIT H-10 Top of Productive Interval: 9.Ref Elevations: KB: 66.0 17. Field/Pool(s): 441'FAL,4142'FEL,SEC.2,T12N, R10E,UMt,`• GL: 36.9 BF: MILNE POINT/SCHRADER BLUFF OIL' Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: ist 753'F1$L,4141'FEL,SEC.2,T12N, R10E,UM Surface ADL0380109/ADL0025906 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MDlTVD: 19. DNR Approval Number: Surface: x- 556479 y- 6009984 Zone-ASP4 6,080'/4,320' N/A TPI: x- 556529 y- 6006710 Zone-ASP4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 556532 y- 6046398 Zone-ASP4 N/A 1,800'(Approx.)/1,762' 5. Directional or Inclination Survey: Yes Lf (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 I EB 1 5 !.Q'IB 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 91.1 11-40 33 80 33 80 24" 250 sx 7" 26 L-80 31 6063 31 4307 8-1/2" 1,277 sx 24.Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MDlTVD) Size and Number;Date Perfd): N/A N/A 5,517'/3,875' 5,701'/4,021' 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes Q No ❑ 0o4-6- Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 12)1411/- 5.450' Set HES 7"EZSV CIBP 275' Set HES 7"EZSV CIBP LL- 5,810'-5,830' 123,200#Proplock 16/20 Carbolite 5,734'-5,754' 124,604#Proplock 16/20 Carbolite 5,580' 5,600' 80,478#Proplock 16/20 precoated Proppant w/ 15%Acid 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A 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. 4-Hour Rate .••► RD DiVIS 1, ' Form 10-407 Revised /2017 c ? CONTINUED ON PAGE 2 Submit ORIGINIAL onl • • 28.CORE DATA Conventional Core(s): Yes ❑ No ❑, Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top Surface Surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1,800' 1,762' Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval 5,580' 3,925' information, including reports, per 20 AAC 25.071. Schrader Bluff NA 5,571' 3,918' Schrader Bluff OA 5,731' 4,045' Schrader Bluff OB 5,806' 4,104' Formation at total depth: Schrader Bluff 31. List of Attachments: Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola©hilcorp.com Authorized Contact Phone: 777-8412 Signature: Date:2/1/2018 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: 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 H-10 None 50-029-22795-00-00 197-149 11/28/17 12/14/17 Dairy Operations: �,,�PW 11/28/2017-Tuesday MIRU excavation equipment. 11/29/2017-Wednesday Begin excavation. 11/30/2017-Thursday Completed excavation. 12/01/2017-Friday No activity to report. 12/02/2017-Saturday Remove cement from around outer annulus to new excavation point. 12/03/2017-Sunday Continue removing cement. 12/04/2017- Monday Continue removing cement. 12/05/2017-Tuesday No activity to report. 12/06/2017-Wednesday No activity to report. 12/07/2017-Thursday Set trench box. 12/08/2017-Friday No activity to report. 12/09/2017-Saturday Install wach saw. 12/10/2017-Sunday Cut casing at 4' below original tundra level. Notify AOGCC inspector for inspection of cut-off depth. 12/11/2017-Monday Inspector onsite.Take photos of casing stub. Weld marker plate on well.Take photos of marker plate. GPS location:70° 26.260'N 149°32.560'W 12/12/2017-Tuesday No activity to report. 12/13/2017-Wednesday No activity to report. 12/14/2017-Thursday Backfill location. • . .., , 0- . . ..6. .,.. .,..,. .., . -:,. . ._ • „. ...., . x .., ., , ..,„.. 0 , A -.'. ,,,.:;,1„iifi',,,f,!:,,,„.'` ' 1,.P4r.:',"-,,' ' : - ;, , , ; ,,, --•,,,,',, , --16:;,'-',.. , rfag' M `, ��° - '+ , �� Vi: • : r sttfk" r y$ �b T 1 C i LFa is �,,. bt`u ''j',:',';":",,;-',--',.".;''','-''''-'--:f . yx e Kar a'z is „= 'e°Ct f m4 a mp y E ,.n'j � � }p • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 7 TO: Jim Regg \ 9 (Z/1 �1� DATE: 12/11/17 P. I. Supervisor FROM: Lou Laubenstein SUBJECT: Surface Abandon Petroleum Inspector MPU H-10 Hilcorp Alaska LLC PTD 1971490; Sundry 316-483 12/10/17: I traveled Milne Point to meet up with Jim Jackson and Billy Kruskie (Hilcorp) for a P&A cutoff and cover plate inspection of well H-10. The wellhead had been removed and all casings were cut 4 feet below tundra. There was solid cement to surface. The cover plate was on location and had all the required information per regulation. Everything was in order and ready for the cover plate to be welded on and the hole backfilled. Attachments: Photos (2) SO- 2017-1210_SurfaceAbandon_MPU_H-10_11.docx Page 1 of 1 • • "" p •. 4 o as r ,I �' I t . t f a ` f ; o x 4. U ` d O 4 y Q+ fa' I s IN K, .° r ., , N Q bA ctCL) I a U t Ovi 0) '�� O cA ti i. o II j( , ..,ihik y,, r ECD � c U 73 c9 m .� o • 0 k = mac �. cna - SOF T4 • • �•e ���yj�s� THE STATE Alaska Oil and Gas ti '► i OfA LAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ain: 907.279.1433 ALAB�� MFax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCANNED 1:E ti 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB H-10 Permit to Drill Number: 197-149 Sundry Number: 316-483 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this '4-3 day of September, 2016. RBDMS '-"SEP 2 6 2016 • • • RECEIVED STATE OF ALASKA 5EP 2 0 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 4�L/OA fi"� APPLICATION FOR SUNDRY APPROVALS 47L/ icig 4 L 20 AAC 25.280 1.Type of Request: Abandon ❑J ., Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 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 0 Development '✓ 197-149 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22795-00-00 ' 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 Q / MILNE PT UNIT SB H-10 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109/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): 6,080' i • 4,320' , Surface %Surface 0 Surface N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Production 6,063' 7" 6,063' 4,307' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES 7"Perma Series/HES 7"Perma Series Sump and N/A 4 5,517MD/3,875TVD,5,701MD/4,021TVD and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 2. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/30/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned d, 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 �� Email sporhola@hilcorp.com Printed Name Bo York Title Operations Manager Signature • Phone 777-8345 Date 9/13/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity I BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 11" ph oi-c do c.t.t vr.0..sl' L:-Ls: C c� r_ . Post Initial Injection MIT Req'd? Yes ❑ No ❑ 1-1S P 11-1-I go Spacing Exception Required? Yes ED [2Subsequent Form Required: /0 q0 7. RBDMS 1, SEP 2 6 2016 APPROVED BY Approved by: di-64,1 `� y�.---- COMMISSIONER THE COMMISSION Date: 9�Z3// fie 1/2111(e .0,4, ^, Submit Form and Form 10-403 Revised 11/2015 IpGaliN AIL 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: MPU H-10 Iiilcoro Alaska,LL) Date:9/08/2016 Well Name: MPU H-10 API Number: 50-029-22795-00 Current Status: Suspended Pad: H-Pad Estimated Start Date: September 30th, 2016 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-149 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number, } 6 V Jr,+ o pew ur a 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 H-10 well was drilled as a Schrader Bluff development well that TD'd at 6,080' and ran and cemented 7" casing in August 1997. Cement of 7" production/surface casing was to surface during the second stage cement job from the cementer at 2,093'. The well was suspended during a RWO in September 2011 due to buckled casing discovered at 305' to 549'. During these operations an abandonment plug was set above reservoir at 5,450', with an additional bridge plug set at 275'. The most recent casing pressure test of casing above RTTS set at 290' &CIBP at 275'were performed to 1,000psi on 4/18/2011 and 4/21/2011 respectively. Subsidence issue identified from 305'to 549' in this well.The Nordic#3 rig plugged the well back to the surface in May 2015. Notes Regarding Wellbore Condition • Plugged back to surface in 2015. Objective: Finalize the surface abandonment of the well. Surface Procedure: 1. Notify AOGCC i_-nnpe_stors 24 hrs prior to cutoff of wellhead and welding marker plate. 2. Excavate cellar,cut off wellhead and casing 3' below natural GL. a. If cement fell back, bring cement top to level of cut. 3. Photograph casing stub before setting marker plate. 44. Set marker plate,collect GPS coordinates. ''�� 5. Photograph casing stub after setting marker plate. 6. Backfill cellar, close out location. Attachments: 1. As-built Schematic II . Milne 41 Well: MPUPoint H-10Unit SCHEMATIC Last Completed: 9/15/2006 Hileorp Alaska,LLC PTD: 197-119 CASING DETAIL Orig.KB AGL.:29.8'/GL Elev.:36.6' Size Type Wt/Grade/Conn ID Top Btm b �+ L 20" Conductor 91.1/H-40/N/A N/A Surface 80' M•P"''41j 'M' ' " 7" Production 26/L-80/Btc 6.276 Surface 6,063' 20' ,, 1i " tr JEWELRY DETAIL Cement Plug r , a i- Surfaceto275 q,, No Depth Item n .,....° 4. ��;I 1 275' HES 7"CIBP b y re 4t." 'i '4,,,t.'4` #!, 2 2,093' Leaking HOWCO 7"ES Cementer l" "�"� „ 1 3 5,450' HES 7"EZSV CIBP 4 5,517' HES 7"Perma-Series Packer Note:Casing has budded.Hole Milled 5 5,523' 3.5"250 Micron Screens and Blank Pipe-Bottom @ 5,701' M" in 7'Casing in area 6 5,701' Straight Slot Locator and Molded Seal Assembly 2,.,:„.::„:„'„,:,.":',',,,,:s4'::°., r from 305'to 549' 7 5,701' HES 7"Perma-Series Packer . ,°'.7'.°'.,':*''' 8 5,706' Collet Guide PERFORATION DETAIL Weatherford Casing Patch 2,082'to Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 2,102'(5.8"ID) 'NB'Sands 5,580' 5,600' 3,925' 3,941' 20 Open iF r� 'NC'Sands 5,617' 5,624' 3,954' 3,960' 7 Open °, 0'2 'NE'Sands 5,640' 5,660' 3,972' 3,988' 20 Open 'OA'Sands 5,734' 5,754' 4,047' 4,063' 20 Open 'OB'Sands 5,810' 5,830' 4,107' 4,123' 20 Open SLB Big Hole Charges @ 0°/180°phasing(EHD-0.7",TTP-7.9" 9.0 ppg Power Vis in OPEN HOLE/CEMENT DETAIL Wellbore 20" 250 sx of Arcticset I in 24"Hole 7" 1,097 sx PF'E',130sx Class`G'&50sx Class'C'in 8-1/2"Hole STIMULATION DETAIL 8/28/1998:'OB'Sand 120,5341bs of Prop-Lok coated 16-20 Carbolite behind pipe. 8/28/1998:'OA'Sand placed 119,4591bs.of Prop-Lok coated 16-20 Carbolite behind pipe. 8/31/1998:'N'Sand placed 76,8791bs.of ACFrac resin coated 16-20 Carbolite behind pipe. TREE&WELLHEAD M. " Tree Cameron 2-9/16"-5M Wellhead 11"x 2-7/8"ESP&HT 5M FMC Gen 6,2-7/8"8rd 1 bottom and top. 2.5"CIW BPV profile. 4 WELL INCLINATION DETAIL y (` KOP @ 500'to 4,600 Max Hole Angle=64 deg. Hole angle thru perfs=37 deg. A fi: 4+ GENERAL WELL INFO API:50-029-22795-00-00 Marker Joint ' *-4 5,407-5,44.' Drilled and Cased by Nabors 22E -8/31/1997 Perforated&Fracd-9/1/1998 ,. 5 Initial Completion-9/5/1998 `, ESP RWO w/4ES-2/24/2000 'i, If ESP RWO,Add Perfs&Screens w/4ES-8/14/2003 I.,: , 6 I.,,,',7 ESP RWO w/4ES-9/15/2006 :'' Pull ESP,Mill Out Casing&Set Kill String Doyon 16-4/22/2011 8 7" A . .4 ID=6,080'(MD)/TD=4,320'(TVD) PBTD=5,981'(MD)/PBTD=4,242'(TVD) Created By:TDF 9/5/2015 RECEVED STATE OF ALASKA • AgIOKA OIL AND GAS CONSERVATION COMMISSION SEP 1 7 2015 REPORT OF SUNDRY WELL OPERATIONS W „^q pa.g., 1.Operations Abandon ❑ Plug Perforations A Fracture Stimulate A Pull Tubing A Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Inspect Well ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska, LLC Development Li Exploratory ❑ 197-149 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22795-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380109IADL0025906 MILNE PT UNIT SB H-10 Ponv be t<-. -7" 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Surface,275'& Total Depth measured 6,080 feet Plugs measured 5,410' feet true vertical 4,320 feet Junk measured N/A feet Effective Depth measured 275 feet Packer measured 5,517&5,701 feet true vertical 275 feet true vertical 3,875&4,021 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' Surface Intermediate Production 6,063' 7" 6,063' 4,307' 7,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet SOWED NOV 1 62015 Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A 7"Perma-Series Packers and SSSV(type,measured and true vertical depth) 7"Perma-Series N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25 070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development ✓ Service ❑ Stratigraphic Li Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ Abandon❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP Li SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Stan Porhola Email sporhola(p7hiIcorp.com Printed Name / Stan Porhola Title Operations Engineer Signature `~i'k N /',=V`t_______.__ Phone 777-8412 Date 9/14/2015 Form 10-404 Revised 5/2015 T1, 2-.7'Y'r:f RBDM SP �� f Submit Original Only O4 f t( . • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/05/15 Inspector: Jeff Jones Operator: Hilcorp Well Name: MPH-10 Oper.Rep: Matthew Linder PTD No.: 197-149 Oper.Phone: 907-670-3387 Location Verified? Yes Oper.Email: mlinder@hilcorp.com If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 05/14/15 Date AOGCC Notified: 09/03/15 Sundry No.: 315-283 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA N/A Condition of Wellhead: Good condition,valves&guages operable,galvanized cellar box. No visible leaks.No flow line attached. Condition of Surrounding Surface Location: Gravel pad level and clean Follow Up Actions Needed: None(5 year inspection) Comments: None Attachments: Photos REVIEWED BY: WBS Insp.Supry Area Map Comm PLB 12/2014 MPH-10 Suspended Well Inspection . • Milne Well: MPointPU H-1Unit0 • SCHEMATIC Last Completed: 9/15/2006 ttileorp Alaska,LLC PTD: 197-119 CASING DETAIL Orig.KB AGL.:29.8'/GL Elev.:36.6' Size Type Wt/Grade/Conn ID Top Btm L 20" Conductor 91.1/H-40/N/A N/A Surface 80' 20 , , ti, 7" Production 26/L-80/Btc 6.276 Surface 6,063' JEWELRY DETAIL Cement Plug + . Surfaceto275 -"„ ,d g No Depth Item 1 275' HES 7"CIBP . 4* ' 2 2,093' Leaking HOWCO 7"ES Cementer r- _ n 1 3 5,450' HES 7"EZSV CIBP 4 5,517' HES 7"Perma-Series Packer Note:Casing has 5 5,523' 3.5"250 Micron Screens and Blank Pipe-Bottom @ 5,701' buckled.Hole Milled O• in 7"Casing in area 6 5,701' Straight Slot Locator and Molded Seal Assembly from 305'to 549' 7 5,701' HES 7"Perma-Series Packer 8 5,706' Collet Guide PERFORATION DETAIL Weatherford Casing, Patch 2,082'to Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 2,102'(5.8"ID) 'NB'Sands 5,580' 5,600' 3,925' 3,941' 20 Open ° 'NC'Sands 5,617' 5,624' 3,954' 3,960' 7 Open 0 10 2 'NE'Sands 5,640' 5,660' 3,972' 3,988' 20 Open 'OA'Sands 5,734' 5,754' 4,047' 4,063' 20 Open 'OB'Sands 5,810' 5,830' 4,107' 4,123' 20 Open SLB Big Hole Charges @ 0°/180°phasing(EHD-0.7",TTP-7.9" 9.0 ppg Power us in OPEN HOLE/CEMENT DETAIL Wellbore 20" 250 sx of Arcticset I in 24"Hole 7" 1,097 sx PF`E',130sx Class'G'&50sx Class'C'in 8-1/2"Hole STIMULATION DETAIL 8/28/1998:'OB'Sand 120,5341bs of Prop-Lok coated 16-20 Carbolite behind pipe. 8/28/1998:'OA'Sand placed 119,4591bs.of Prop-Lok coated 16-20 Carbolite behind pipe. 8/31/1998:'N'Sand placed 76,879lbs.of ACFrac resin coated 16-20 Carbolite behind pipe. TREE&WELLHEAD Tree Cameron 2-9/16"-5M Wellhead 11"x 2-7/8"ESP&HT 5M FMC Gen 6,2-7/8"8rd bottom and top. 2.5"CIW BPV profile. WELL INCLINATION DETAIL KOP @ 500'to 4,600 Max Hole Angle=64 deg. Hole angle thru perfs=37 deg. rsr..- -i . 3 GENERAL WELL INFO API:50-029-22795-00-00 MarkerJoint 4 Drilled and Cased by Nabors 22E -8/31/1997 5,407-5'44 Perforated&Fracd-9/1/1998 �,, 5= Initial Completion-9/5/1998 ESP RWO w/4ES-2/24/2000 ESP RWO,Add Perfs&Screens w/4ES-8/14/2003 6 ESP RWO w/4ES-9/15/2006 7 Pull ESP,Mill Out Casing&Set Kill String Doyon 16-4/22/2011 P 8 . 7"A'. ,x.11 TD=6,080'(MD)/TD=4,320'(1VD) PBTD=5,981'(MD)/PBTD=4,242'(TVD) Created By:TDF 9/5/2015 F s-n.. .� ,a < iq al NAME MPH .. 10 ER Milne Point Unit --R ATOR BP Exploration R. 'LOCATIONNW 1/4, Sec.34, T13N, R1OE k1LL1NG PERMIT 97-149 rt y • r # e x;y r p a.n • • > _.. ..vim .. ,. ..._.......-.�_ ' � � *.•, r • • • __am Rim...i of��...samiiim. � ���,a.- i iris. / . i 111111tt111t/r 14:11SIr1111111' Agmol 1 ' 1 all -. r N 14 1 *114111 ‘111111111111 . 11, ms,µ . 1 � \ -`.. i 7.141' , r 444 � ' ' � 1 � ELL NAME MPII1U r _ 4 . . ,..:„.„,......... ..„„:„‘r..... ._-,....,.... ... `,� .'i t :,:z.....0„„...: r- r Milne Point Unit _,3 k' '.,. ,ta,. OWNER ,� *�, ,......,.. o �. '� BP Expto►atioh y OPERATOR- �' „` TIONNW14. Sec.34. T13N,RtOE.,,....__ ,� SUR. LOCA� C�RILUNO PERMIT 9T11,,...;:::,.....7,,,,77:. -�. i , ,.,,,t" .- '• . aIR. — 4 '1... . fort .ii.v. , . 4110:, - . y.,;. . ` _ w • Fid ed" . * *wt n^ _ *, ,. ,r -♦. Ate'°M ++... ,�.� a r ,* .. r .., � �. moi. s 9 Mir ry t i 1 rwit c - mow a! d 111 l71 . -..,. , . Ty __ • -iv • :,--...!,r.", •+�,*y. �-rpt) 9 J''r""'lr 5.'+,.h S .+ t. ' . !kms al _. * ".y ., v�`�.T ..,;-*„.... ',...4...,4 +a'�'�.. ;ice . f'-?.?...-•,:4, -, x 'V .r is e► -' - R $� ' . 1 +h e� 4 •* - a• u 4...*.....--* g �, `.� #{ : . -� 11.f •t t4.• °�- . �� f , 5 !. '♦ . � or al'.SGS -: �y. s• y 1,1 +mss . �, a* .r F • a s. . s+ e s' t r s • 101 ,00. a .. �N� a"� . + 9• X173 • • . ., . iiiMilne Point Unit - F Pad AC Ilih•k,rp Alu,La,LH MPU F Pad July 25, 2006 Approximate Scale: 1"=200' 2006-19c-4-54 verified uPerl rli ,bits qt s } 4 'r - - N" r 4 5- C5'7i' a ,��t X af £. L yjO r 6, `�% Y ;f'."6.., 0'.fti � '''...1.,"''''' rjr y. Y fj -ii' f'<. r; ?'c4�J kf,i9Yy ; ‘,0,.., �J�. J_l x L ,,,::r."50-; 00-. "N4?, 4r-f'; 4 '., ' " MPU sA '.k,,,,,� F PAD '� < �.,r�-.a .+4, . ,.nn ... �. Feet x`,4x" DOU!Wilson-J Huai',,U7, STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing Li Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑r Exploratory ❑ 197-149 3.Address: Stratigraphic El Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22795-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL03801091ADL0025906 MILNE PT UNIT SB H-10 / SOT z 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): - N/A MILNE POINT/SCHRADER BLUFF OIL S EP 1 5 2016 11.Present Well Condition Summary: Surface,275'& Li Total Depth measured 6,080 feet Plugs measured 5,410' feet true vertical 4,320 feet Junk measured N/A feet Effective Depth measured Surface feet Packer measured 5,517&5,701 feet true vertical Surface feet true-vertical 3,875&4,021 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Production 6,063' 7" 6,063' 4,307' 7,240psi 5,410psi yy �p ;13 i' Perforation depth Measured depth See Attached Schematicscopoli-4: J 3 J 1 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A 7"Perma-Series Packers and SSSV(type,measured and true vertical depth) 7"Perma-Series N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A - Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP Q - Abandon El 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-283 Contact Stan Porhola Email sporholahilcorp.com Printed Name Bo York Title Title Operations Engineer Signature r" 2 e / Phone 777-8345 Date 9/13/2016 (0/1/74 RBDMS L,L FP 1 6 2016 Form 10-404 Revised 5/2015 Submit Original Only 14 • • Milne Point Unit Well: MPU H-10 ' SCHEMATIC Last Completed: 9/15/2006 Ililcorp Alaska,LLC PTD: 197 c �,2'Ti,t-1 CASING DETAIL Orig.KB AGL. 29.8'/GL Elev.:36.6' Size Type Wt/Grade/Conn ID Top Btm A "Ul .g17;.) L 20" Conductor 91.1/H-40/N/A N/A Surface 80' 20 ".� "f:, 7" Production 26/L-80/Btc 6.276 Surface 6,063' Cement Plug ' Z A," JEWELRY DETAIL Surface to 275' ;';:r,,-"-;04,4, *ti''' �'( No Depth Item 1" `ct ._ 1 6/ 1 275' HES 7"CIBP 4 2 2,093' Leaking HOWCO 7"ES Cementer fir'; 1 3 5,450' HES 7"EZSV CIBP -' Note:Casing has 4 5,517' HES 7"Perma-Series Packer il buckled.Hole Milled 5 5,523' 3.5"250 Micron Screens and Blank Pipe-Bottom @ 5,701' ? ' ..1 in 7'Casingin area 6 5,701' Straight Slot Locator and Molded Seal Assembly ,xt-r t� its- from 305'to 549' 7 5,701' HES 7"Perma-Series Packer ✓h ii ;' 8 5,706' Collet Guide r .5 PERFORATION DETAIL Weatherford Casing Patch 2,082'to t ` Y Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 2,102'(5.8"ID) 1 'NB'Sands 5,580' 5,600' 3,925' 3,941' 20 Open ' 'NC'Sands 5,617' 5,624' 3,954' 3,960' 7 Open '2 'NE'Sands 5,640' 5,660' 3,972' 3,988' 20 Open 'OA'Sands 5,734' 5,754' 4,047' 4,063' 20 Open 'OB'Sands 5,810' 5,830' 4,107' 4,123' 20 Open SLB Big Hole Charges @ 07 180°phasing(EHD-0.7",TTP-7.9" 9.0 ppg Power Vis in OPEN HOLE/CEMENT DETAIL Wellbore 20" 250 sx of Arcticset I in 24"Hole 7" 1,097 sx PF'E',130sx Class`G'&50sx Class'C'in 8-1/2"Hole STIMULATION DETAIL 8/28/1998:'OB'Sand 120,5341bs of Pro Lok F coated 16-20 Carbolite behind pipe. '"" 3, 8/28/1998:'OA'Sand placed 119,4591bs.of tr41. Prop-Lok coated 16-20 Carbolite behind pipe. 8/31/1998:'N'Sand placed 76,879Ibs.of ACFrac resin coated 16-20 Carbolite behind pipe. Illit-� 1 TREE&WELLHEAD Tree Cameron 2-9/16"-5M 9.4 Wellhead 11"x 2-7/8"ESP&HT 5M FMC Gen 6,2-7/8"8rd X.t bottom and top. 2.5"CIW BPV profile. * WELL INCLINATION DETAIL Fit KOP @ 500'to 4,600 r - Max Hole Angle=64 deg. .: Hole angle thru perfs=37 deg. ,_ "" _ 3 St t GENERAL WELL INFO Marker Joint ' ' ' 4 API:50-029-22795-00-00 5,407-5,44.' ": Drilled and Cased by Nabors 22E -8/31/1997 ,,:4 Perfa & r9/ InitialorCa -9/5/1998 g11.411 ESP RWO w/4ESF -acd 2/24/20001/1998 ,1' : ESP RWO,Add Perfs&1 Screens w/4ES-8/14/2003 ESP RWO w/4ES-9/15/2006 1; 7 Pull ESP,Mill Out Casing&Set Kill String Doyon 16-4/22/2011 tt °r TD=6,080'(MD)/TD=4,320'(TVD) PBTD=5,981'(MD)/PBTD=4,242'(TVD) Created By:TDF 9/5/2015 • Hilcorp Alaska, LLC itileorp Alaska,LLC Weekly Operations Summary Well Name API Number Well Permit-Number Start Date End Date MPH-10 - 50-029-22795-00-00 197;171—/54/ .z. '7 5/13/2015 5/14/2015 11--- id 1 5/13/15-Wednesday; ' MIRU. Berm cellar,spot and contain tanks,run hardline install BPV. ND tree,NU BOPE Pull BPV Install TWC.Shell test BOPE,good test continue with BOP test 250psi low/3,000psi high annular 250psi low/2,500psi,accumulator draw down test OK. Pull TWC,install landing joint, BOLD pull hanger and LD PU 2 singles and RIH tag as per tally. Pump fresh water and displace hole to clear diesel. Blow down TOOH rack pipe stands in derrick.There is a 4' MS on bottom.Close blinds/ and test casing to 1,500psi for 30 min.on,chart.Test actual pump roll to 1,700psi, maintain test at that pressue �✓ flatlined at 1,675 after 15 min. Hold for 45 minutes. RIH to 273' RU.Test all lines, pump 15 bbls 15.6 ppg cement Permafrost class C slurry,with 1 bbl H2O spacer tail,good returns throughout 5 bbls displaced to cuttings tank. Rig down cement head, POOH with pipe drift and rack back.Set hanger w 4'pup, RILD PU DP JT and wash nozzel clean out BOP.Open BOP doors and clean cavities. ND BOPE 5/14/15-Thursday ND BOPE NU tree RDMO. Release rig. 5/15/15-Friday �; ` L No operations to report. 5/16/15-Saturday �„ �.x . d'P' ” No operations to report. 5/17/15 Sunday Ni p,i, l� , q.„ No operations to report. 5/18/15-Monday w 143POrMr 1A No operations to report. 5/19/15-Tuesday F;Ukr No operations to report. ‹cA '2:N3 3119 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/05/15 Inspector: Jeff Jones Operator: Hilcorp Well Name: MPH-10 Oper. Rep: Matt Linder PTD No.: 1971490 Oper. Phone: 670-3387 Location Verified? yes Oper.Email: milne-wellsitesupervisorsI8 hilt If Verified,How? LAT/LONG Onshore I Offshore: Onshore Suspension Date: 04/21/11 Date AOGCC Notified: 09/03/15 Sundry No.: 311-135 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA N/A Condition of Wellhead: Well head appears to be in good condition,no visible leaks,no flow line attached.Operator indicates tubing and IA are plugged with cement and - BPV set in well head profile.Valves and guages are operable.Galvanized culvert cellar box. Condition of Surrounding Surface Location: good condition,level gravel pad Follow Up Actions Needed: None Comments: Operator rep.indicated they plan to excavate and permanently abandon this well this year. Attachments: Well head photo(1) - REVIEWED BY: Insp.Supry 6e— tZtZZ 11c Comm SCANNED AUG 2 2 2016 PLB 06/2014 2015-0905_Suspend_MPU_H-10,jj.xlsx • • Suspended Well Inspection—MPU H-10 - PTD 1971490 Photo by AOGCC Inspector J. Jones 1111\ i711111_U I_II ..t!!R■a„111 Ui"ar :T�tt I - 1. I �1� ye Y Ia --i.� .lel-.. 1 .max !T3A®1111 !— _,_-, - T WELL NAME MPN 10 3, i 9,v OWNEF Milne Point Uoit , xt S' '-'4111111i1711111 —WIN;, RP Exploration t ” :OPERATOR NW 1 4.SeI34.T13N.ROE '— , s: z -._• _ '-. s 6 'I STIR.LOC R N 14 pT10N Ah i ['KILLING PERM! B i .i.':- .- ..:- j IS:‘ y - ' ce " w 0 • is .4 a Y ¢- ^ ,. ,. ' r.- ' 2015-0905_Suspend_MPU_H-10photo,jj.docx 1 Page 1 of 1 V or Tb� I�j,'s� THE STATE Alaska Oil and Gas �'�� ALASKA Conservation Commission ham- � 2 _,_ __ 333 West Seventh Avenue 111,0-fGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279 1433 ALAS Fax 907 276 7542 ' AAS S� �i5U1 www.aogcc alaska.gov CANNED M 1r➢ Chris Kanyer Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB H-10 Sundry Number: 315-283 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair DATED this /2 day of May, 2015 Encl. RECEIVED STATE OF ALASKA MAY 0 8 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon(- Plug for Redrill ❑ P rforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend[ Plug Perforations ❑ Perforate❑ Pull Tubing Q - Time Extension ❑ Operations Shutdown L Re-enter Susp.Well [1� Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development a. 197-149 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22795-00-00• 7.If perforating: y77,.os-,yam.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.4Th Will planned perforations require a spacing exception? Yes ❑ No E MILNE PT UNIT SB H-10 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109IADL0025906 - MILNE POINT/SCHRADER BLUFF OIL• 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): 6,080 • 4,320 • 275 • 275 . 275',5,410'7 5,980' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' Surface Intermediate • Production 6,063' 7" 6,063' 4,307' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/8rd EUE 244' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): HES 7"Perma Series/HES 7"Perma Series Sump and N/A 5,517MD/3,875ND,5,701 MD/4,021TVD and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development E' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/14/2015 Oil ❑ Gas 0 WDSPL ❑ Suspended 16.Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned L. Commission Representative: N/A GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanverahilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature aPhone �� 777 8377Date 5/8/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ii BOP Test [Er Mechanical Integrity Test ❑ y�� �]Locatiioon Clearance 0 \ Other: �c 3GYX> pS L LXr P l�s F (/''LITS/ ` Z4 r$-) y- Alt- P , r ise.u.4.11,..i -;007/01,-4,4, � _ zo /11�A(- z--S-.11 2- (L) ,� I de c_t.t�.r....7� C4 S r ,-kA c 6A-t--a f!i( r. ;,{r, r.0 c-c P a/ Spacing Exception Required? Yes 0 No Subsequent Form Required: v�"/0 '-4/ 07- d / / ' P20,„4-___ APPROVED BY Approved by: COMMISSIONER APPROVED THE COMMISSION Date:s-/a kr- .0 � .0 ; .Si///5 r 146 S/its/{S Submit Form and Form 10-403(�/vised 10/2012) (3pRidGIN,Atipfor 12 months fromm th9 date of approval. Attachments in Duplicate O F/114,--- RBDMS MAY 1 2 2015 . El Well Prognosis ' Well: MPH-10 Hilcorp Alaska,LL, Date:5/08/2015 Well Name: MPH-10 API Number: 50-029-22795-00-00 Current Status: Suspended Pad: H Pad Estimated Start Date: May 14, 2015 Rig: Nordic 3 Reg.Approval Req'd? May 13, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-149 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) AFE Number: 1551189 Current Bottom Hole Pressure: N/A (N/A- No open Perfs) Maximum Expected BHP: N/A (N/A- No open Perfs) Max. Allowable Surface Pressure: 28 psi (Assume 0.1 psi/ft to plug at 275') Brief Well Summary: The Milne Point H-10 well was drilled as a Schrader Bluff development well that TD'd at 6,080' and ran and cemented 7" casing in August 1997. Cement of 7" production/surface casing was to surface during the second I- stage cement job from the cementer at 2,093'. The well was suspended during a RWO in September 2011 due to buckled casing discovered at 305' to 549'. During these operations an abandonment plug was set above reservoir at 5,450', with an additional bridge plug set at 275'. The most recent casing pressure test of casing above RTTS set at 290'&CIBP at 275'were performed to 1,000psi on 4/18/2011 and 4/21/2011 respectively. Subsidence issue identified from 305'to 549' in this well. Notes Regarding Wellbore Condition Current well status is suspended. RWO Objective: Complete install surface abandonment plug&abandon onshore well that has no future wellbore utility Brief Procedure: 1. MIRU Nordic#3 Rig. 2. ND tree, NU 11" BOPE and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 3. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is r___. eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email p explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an Kje5+- inspector to witness. 4-4- 10 ' b. With stack out of the test path,test choke manifold per standard procedure a 5 r 5 / c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the ��;,,. surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at 30 surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the yt S./EGr ' pumping rate and pressure. Well Prognosis • Well: MPH-10 Hilcorp Alaska,LL Date:5/08/2015 e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 4. Unseat hanger and LD same. 5. PU additional 2-7/8" tubing and RIH to top of surface plug at 275'. 6. Circulate out freeze protect from well with 8.5ppg seawater. Monitor well. 7. Spot cement plug from 275'to surface. 8. ND BOP, NU dry hole tree. 9. RDMO workover rig and equipment. Post Rig Activities: 10. Excavate well/remove cellar as necessary. Ocui 11. Cut off wellhead and casing at least 3' below original/natural ground level. 12. Install marker plate in accordance to 20AAC25.120 Attachments: �Z -J 5'/ c e lerl1 1. As-built Schematic - 0. 2. Proposed Schematic 3. BOP Schematic pi-LA- Milne Point Unit . ti Well: MPU H-10 SCHEMATIC Last Completed: 9/15/2006 Ililcorp Alaska,LLC PTD: 197-119 CASING DETAIL Orig.KB AGL:29.8'/GI Elev.:36.6' k Size Type Wt/Grade/Conn ID Top Btm }p D ,`. 20" Conductor 91.1/H-40/N/A N/A . Surface 80' 20:4 �; I bs 7" Production 26/L-80/Btc 6.276 Surface 6,063' E TUBING DETAIL '4 S t E ,,i''' 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 244' ',. L 4; A, JEWELRY DETAIL rr ' + No Depth Item ;7 1 1 275' HES 7"CIBP 4 Aphoi, Note:Casing has 2 2,093' Leaking HOWCO 7"ES Cementer A budded.Hole:Ailed 3 5,450' HES 7"EZSV CIBP 7'Casing inarea 4 5,517' HES 7"Perma-Series Packer .t0549' 5 5,523' 3.5"250 Micron Screens and Blank Pipe-Bottom @ 5,701' 11 6 5,701' Straight Slot Locator and Molded Seal Assembly y 7 5,701' HES 7"Perma-Series Packer Weatherfordering v8 5,706' Collet Guide r Patch 2,082'to ' i4 2,102(ss ID)` ,t PERFORATION DETAIL I Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 13 0 2 'NB'Sands 5,580' 5,600' 3,925' 3,941' 20 Open 'NC'Sands 5,617' 5,624' 3,954' 3,960' 7 Open 'NE'Sands 5,640' 5,660' 3,972' 3,988' 20 Open 9.Oppg 'OA'Sands 5,734' 5,754' 4,047' 4,063' 20 Open Power vis in 'OB'Sands 5,810' 5,830' 4,107' 4,123' 20 Open i Wellbore SLB Big Hole Charges @ 0°/180°phasing(EHD-0.7",TTP-7.9" OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 7" 1,097 sx PF'E',130sx Class'G'&50sx Class'C'in 8-1/2"Hole STIMULATION DETAIL 8/28/1998:'OB'Sand 120,534Ibs of Prop-Lok coated 16-20 Carbolite behind pipe. 8/28/1998:'OA'Sand placed 119,4591bs.of Prop-Lok coated 16-20 Carbolite behind pipe. 8/31/1998:'N'Sand placed 76,879Ibs.of ACFrac resin coated 16-20 Carbolite behind pipe. • TREE&WELLHEAD Tree Cameron 2-9/16"-5M Wellhead 11"x 2-7/8"ESP&HT 5M FMC Gen 6,2-7/8"8rd bottom and top. 2.5"CIW BPV profile. WELL INCLINATION DETAIL -moi• '3 KOP @ 500'to 4,600 4, Max Hole Angle=64 deg. F Hole angle thru perfs=37 deg. MarkerJdnt i ' ' :4 5,407-5,446. Sy ! GENERAL WELL INFO � _ API:50-029-22795-00-00 w 5 affDrilled and Cased by Nabors 22E -8/31/1997 fir Perforated&Fracd-9/1/1998 '1z 6 • Initial Completion-9/5/1998 i is 7 ESP RWO w/4ES-2/24/2000 71, r ESP RWO,Add Perfs&Screens w/4ES-8/14/2003 L� 8 ESP RWO w/4ES-9/15/2006 F. Pull ESP,Mill Out Casing&Set Kill String Doyon 16-4/22/2011 7'141112.4*` TD=6,080'(MD)/TD=4,320'(1VD) PBTD=5,981'(MD)/PBTD=4,242'(TVD) Created By:TDF 4/24/2015 n Well:Mile MPointPU HUnit-10 • 14 PROPOSED Last Completed: 9/15/2006 Mewl)Alaska,LLC PTD: 197-119 CASING DETAIL Orig.KB AGL:29.8'/GL Elev.:36.6' Size Type Wt/Grade/Conn ID Top Btm k 20" Conductor 91.1/H-40/N/A N/A Surface 80' 7" Production 26/L-80/Btc 6.276 Surface 6,063' Cement Plug JEWELRY DETAIL Surface to 275' -• No Depth Item 1 275' HES 7"CIBP • . 2 2,093' Leaking HOWCO 7"ES Cementer 1 3 5,450' HES 7"EZSV CIBP 4 5,517' HES 7"Perma-Series Packer Note:Casing has 5 5,523' 3.5"250 Micron Screens and Blank Pipe-Bottom @ 5,701' ' budded.Hole Killed +' in 7'Casing in area 6 5,701' Straight Slot Locator and Molded Seal Assembly from 305'to549' 7 5,701' HES 7"Perma-Series Packer 8 5,706' Collet Guide PERFORATION DETAIL VV atherfordCasing Patch 2,082'to Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 2,102'(5.8 ID) 'NB'Sands 5,580' 5,600' 3,925' 3,941' 20 Open N '<.j 'NC'Sands 5,617' 5,624' 3,954' 3,960' 7 Open 1 I� a 2 'NE'Sands 5,640' 5,660' 3,972' 3,988' 20 . Open 'OA'Sands 5,734' 5,754' 4,047' 4,063' 20 Open 'OB'Sands 5,810' 5,830' 4,107' 4,123' 20 Open SLB Big Hole Charges @ 0°/180°phasing(END-0.7",TTP-7.9" 9ppg e Power Vis i s in OPEN HOLE/CEMENT DETAIL Wellbore 20" 250 sx of Arcticset I in 24"Hole 7" 1,097 sx PF'E',130sx Class'G'&50sx Class'C'in 8-1/2"Hole STIMULATION DETAIL 8/28/1998:'OB'Sand 120,5341bs of Prop-Lok coated 16-20 Carbolite behind pipe. 8/28/1998:'OA'Sand placed 119,4591bs.of Prop-Lok coated 16-20 Carbolite behind pipe. 8/31/1998:'N'Sand placed 76,8791bs.of ACFrac resin coated 16-20 Carbolite behind pipe. TREE&WELLHEAD Tree Cameron 2-9/16"-5M Wellhead 11"x 2-7/8"ESP&HT SM FMC Gen 6,2-7/8"8rd bottom and top. 2.5"CIW BPV profile. WELL INCLINATION DETAIL KOP @ 500'to 4,600 Max Hole Angle=64 deg. • Hole angle thru perfs=37 deg. -Ji• 3 GENERAL WELL INFO API:50-029-22795-00-00 Marker Joint ° �-j°' ; 4 Drilled and Cased by Nabors 22E -8/31/1997 5,407'-5,446' •1♦ Perforated&Fracd-9/1/1998 5 Initial Completion-9/5/1998 ESP RWO w/4ES-2/24/2000 1 ESP RWO,Add Perfs&Screens w/4E5-8/14/2003 I` 67 ESP RWO w/4ES-9/15/2006 01711/4 Pull ESP,Mill Out Casing&Set Kill String Doyon 16-4/22/2011 8 4 ruca TD=6,0801MD)/TD=4,320'(TVD) PBTD=5,981'(IVO)/PBTD=4,242'(TVD) Created By:TDF 4/24/2015 11" BOP Stack , � O : lII . lIlIIlII1 Hydril 11" 5M 11"Lliala _A— L Shaffer 2 3/8" Rams _01:1D 11" 5M on 2 7/8-5.5 o variables - _ • 0 _ Hydril Mt ( 11" 5M ]_H_OinBlinds *9 , Optional valve port Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. //~7- /~/~ File Number of Well History File PAGES TO DELETE Complete RESCAN n Color items- Pages: GraYScale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type 'OVERSIZED n Logs of various kinds Other Sca n ned' by: Beverly Mildred, Oarelha ~)owell n TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ OF i.ke ��'�1//7 ,% T E STATE ' ,_ `:- c s 2 ,?_� 333 West Seventh Avenue "%'h e GC;\'I R OR SEA I�ARNEEI, Anchorage Alaska 99501-35/2 V o,n 907.279 /33 cicOVk Clint Spence S`034/4° Interventions Team Lead � �� r BP Exploration (Alaska), Inc. 117- 1'1" P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Schrader Bluff, MPH-10 Sundry Number: 314-081 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair DATED this 514day of March, 2014. Encl. • STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL FEB 1 I 2014 20 AAC 25.280 p TS 3/51/ 1--- 1. Type of Request: AOGCC ❑Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ®Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing ®Other Cement to Surface(Add'I suspend work) 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. 197-149 3. Address: ❑ Exploratory ❑Stratigraphic Alaska 99519-6612 ®Development 0 Service P.O. Box 196612,Anchorage, 6. API Number: 50.029-22795-00-00. 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPH-10 — Will planned perforations require a Spacing Exception? 0Yes ® No 9. Property Designatior 10.Field/Pool(s): ADL 025906&380109 • Milne Point Unit/Schrader Bluff . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6080' 4320' . 6021' - 4274' , 275',5450' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 32'- 112' 32'- 112' 1490 470 Surface Intermediate Production 6032' 7" 31'-6063' 31'-4307' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5580'-5830' , 3925'-4123' Kill String:2-7/8",6.5# L-80 244' Packers and SSSV Type: 7"HES Perma Series Packer Packers and SSSV 5517'/3875' 7"HES Perma Series Sump Packer MD(ft)and ND(ft): 5701'/4021' 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic �®Development. 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: April 15,2014 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG ®Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Abhijeet Tambe,564-4993 Printed Name: li t S nce Title: Interventions Team Lead Email: Abhijeet.Tambe@bp.com Signature: A----N. Phone: 564-5709 Date: ////,i./ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness \� �8 l 1 ° Sundry Number: 'Plug Integrity 0 BOP Test 0 Mechanical Integrity Test V Location Clearance Other: �/0 it Tt l 1 v)S1 C G 71-6r a I ✓> di'C 4L-C'C� Pb c10el,vY7 0'7-7L CU{off Cori' �inG/ vv�lclz c� ,47 la f� . Spacing Exception Required? 0 Yes RI/No Subsequent Form Required: /0 ... 4 t " BDMS' I'4Y 2014 APPROVED BY ' Approved By: aL �� COMMISSIONER THE COMMISSION Date: 3 -s-- L/ Form 10-403 Revised 102012 Apprdv�JlRacl�ll� i lil3o�12 months from the date of approval Submit In Duplicate/ V i-i 3/5-h+ ���////// '' `` VVVVVV 11 !!�-ll �� i�1�, d �ly ���/ ��':% • Procedure for additional suspension work of Milne Point Unit hail H-09: • Well History— MPH-10 was completed in 1998 as a production well. During the Rig Work-over conducted in 2011, Production Casing integrity was lost(in the vicinity of 305-349' MD). Cast Iron Bridge Plugs were set(by the Rig) at 5450' and 275' MD, with 9.0 ppg Gel left in the wellbore between the two. They were each tested to 1,000 psi (NOT to 1,500 psi) and Sundry application was approved for Suspended status from the AOGCC. The additional suspension work proposed here is intended to advance the wellbore to the P & A'd condition, with the exception that it will only be cut-off 1' below existing pad level. Deeper cut-off(to the regulatory 3' below original ground level)will occur at such time as all other wells on the pad are P&A'd. ✓ Wellwork Synopsis — • Service/Test Wellhead &Tree; Pull BPV • Fullbore pump 5 bbl diesel down 2-7/8" Tbg taking returns up 2-7/8" X 7" Annulus to surface • CT Tag & Mill-out center(2.0" pilot hole) of CIBP at 275' MD • CT jet-out (where frozen) / cleanout PowerVis to CIBP at 5450' MD. If shallow Csg leak loses fluid at > 0.5 bpm, POOH CT & bullhead 5 bbl POLYSWELL pill, complete FCO and tag lower CIBP • Perform negative pressure test(of lower CIBP)when wellbore cleanout complete • CT/Cementers lay-in 198 bbl Class G cement from top of CIBP at 5450'MD to CIBP junk at 275' MD. POOH CT. CT bullhead Class G cement down 2-7/8" Kill String taking returns up 2-7/8" X 7" Annulus until either at least 5 bbl cement returns to surface or 250 bbl total cement has been pumped. CT jet out tree & top 20' 2-7/8" Tbg. • Ensure no pressure on Tbg/Csg; Vac off any remaining fluid. Excavate around Wellhead in preparation to cutoff Wellhead &Tree. • Rig up Guillotine saw; cut both Casing and Tubing 1' below existing pad level. • Fill up any surface void space in either Casing or Tubing with cement to surface. • Notify AOGCC Inspector 24 hours in advance of opportunity to witness cut-off wellhead filled with cement to surface prior to welding Marker Plate. • Procedure for additional suspension work of Milne Point Unit H-09: • Tack Weld (not a full seal weld) Abandonment Marker Plate on top of 20" Casing (with the following information): BP Exploration Alaska, Inc. ✓ Milne Point Unit Well H-10 PTD# 197-149 API#50-029-22795 Current Tree: Cameron 2 9/16" 5M Orig. Elev. = 66.4' (N 22E) Wellhead: 11" x 2 7/8" ESP & HT 5M MPH-10 Orig. GL Elev. = 36.6' FMC Gen 6 2-7/8" 8rd bottom and RT To Tbg. Spool = 30.9' (N 22E) top, 2.5" CIW BPV profile. ID a> 2 7/8" Kill String 244' b 20" 91.1 ppf, H-40 =4i HES 7" EZSV CIBP 275' KOP @ 500' to 4,600' Max. hole angle = 64 deg. Hole angle thru' perfs = 37 deg. ' NOTE: The casing has buckled. Hole milled hole in 7" casing in area from 305' -549'. T 0 a/ 3 c N Leaking Howco 2093' 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg. 5 r 7" "ES" Cementer ( drift ID = 2.347", cap. = 0.00592 bpt iii 3 Weatherford casing patch 0 7" 26 ppf, L-80, BTC mod production O 2082'-2102' (5.8" ID) 0) casing a ( drift ID = 6.276", cap. = 0.0383 bpf ) o 0i Stimulation Summary 8-28-98-'OB Sand'placed 120,534#of PropLok coated 16/20 CarboLite behind pipe 8-29-98-'OA Sand' placed 119,459#of PropLok coated 16/20 CarboLite behind pipe Marker Joint ( 5,407 - 5,446 ) 8-31-98-'N Sand' placed 76,879# of HES 7" EZSV CIBP 5450' AcFrac resin coated 16/20 CarboLite behind pipe Perforation Summary Ref log: Sperry Sun GR 8/28/97 I HES 7" Perma-Series Pkr 5517' Size SPF Interval (TVD) 4.5 4 5580-5600 NB 3859-3875 ■•�'�■ rr Top DPZ (Schrader) 4.5 5 5617-5624 NC 3954-3960 •• 5545'MD (3831' TVD) 4.5 5 5640-5660 NE 3972-3988 C Ilu l• • I 4.5 4 5734-5754 OA 3981-3997 I I 4.5 4 5810-5830 OB 4041-4057 = II; 0 ,■ 3.5" 250 Micron Screens 5523-5701' I. and Blank Pipe SLB Big Hole charges @ 0°/180° deg. Straight Slot Locator and 5701' phasing (EHD - 0.7", TTP - 7.9") Molded Seal Assy HES 7" Perma-Series 5701' IIIA Sump Pkr 7" landing collar (PBTD) 5980' 5706' 8 7" float collar (PBTD) 5981' 8 Collet Guide == :. T. 7" float shoe 6063' DATE REV BY COMMENTS MILNE POINT UNIT 8-31-97 MDO 7" Cased Hole Completion 22E WELL No : H-10 9-01-98 KJW Perforated and Frac'ed API : 50-029-22795 9/5/98 M. Linder Inital Completion 02/24/00 M. Linder RWO Nabors 4-ES PTD 97-149 8/14/03 Lee Hulme 4E8 ESP do,Add Perfs,Add Screens 9/15/06 R.HANDY 4ES RWO ESP C/O 4/22/11 Lee Hulme Pulled ESP,Milled out Csg,Set Kill String Doyon 16 BP EXPLORATION (AK) . After P&A Tree:Cameron 2 9/16" 5fk. Orig. Elev. = 66.4' (N 22E) Wellhead: 11" x 2 7/8" ESP & HT 5M MPH-10 Orig. GL Elev. = 36.6' FMC Gen 6 2-7/8" 8rd bottom and RT To Tbg. Spool = 30.9' (N 22E) top, 2.5" CIW BPV profile. 2 7/8" Kill String 244' \\ 20" 91.1 ppf, H-40 112' \\*. Who* HES 7" EZSV CIBP 275' KOP @ 500' to 4,600' FrMax. hole angle = 64 deg. Hole angle thru' perfs = 37 deg. NOTE: The casing has buckled. Hole milled hole in 7" casing in area from 305' -549'. Leaking Howco 2093' 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg. 7" "ES" Cementer ( drift ID = 2.347", cap. = 0.00592 b)Df Weatherford casing patch 7" 26 ppf, L-80, BTC mod production 2082'-2102' (5.8" ID) casing ( drift ID = 6.276", cap. = 0.0383 bpf ) Stimulation Summary 8-28-98-'OB Sand'placed 120,534#of PropLok coated 16/20 CarboLite behind pipe 8-29-98-'OA Sana placed 119,459#of PropLok coated 16/20 CarboLite behind pipe Marker Joint ( 5,407 5,446 ) 8-31-98-'N Sand'placed 76,879#of Ansomoo. HES 7" EZSV CIBP 5450' AcFrac resin coated 16/20 CarboLite behind pipe Perforation Summary Ref log: Sperry Sun GR 8/28/97 I X HES 7" Perma-Series Pkr 5517' X Size SPF Interval (TVD) 4.5 4 5580-5600 NB 3859-3875 i 1 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 December 30, 2011 4-WED FEB 1 ? 2012 Mr. Tom Maunder 1019 _ 1 149 Alaska Oil and Gas Conservation Commission 9 0 333 West 7 Avenue Anchorage, Alaska 99501 \ Y `V' Subject: Corrosion Inhibitor Treatments of MPH -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 1 MPH -01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH -02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220630000 Sealed Conductor NA NA NA NA NA MPH-04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA MPH -05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH -06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH -08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 MPH -09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 --- -)10 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 MPH -15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH -18 2041740 50029232240000 18.6 NA Need top job MPH -19 2071360 50029233710000 0.1 NA 0.1 NA 2.6 9/4/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 07/07/11 Inspector: Bob Noble Operator: BP Well Name: MPU H -10 Oper. Rep: Jeff Rea PTD No.: 1971490 Oper. Phone: 670 -3387 Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 04/21/11 Date AOGCC Notified: 07/06/11 Sundry No.: 311 -135 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing N/A - Photos Taken? Yes IA 0 OA N/A Condition of Wellhead: Unable to get tubing pressure because of BPV in well. Mono bore well. Location verified with plot plan. All lines blinded. Guard rail around wellhead. - Condition of Surrounding Surface Good clan gravel, Dry cellar. Location: Follow Up Actions none Needed: Attachments: Photo (1) - REVIEWED BY: Insp.Supry )1 / 7 1J1/ Comm PLB 08/2010 2011- 0707_Suspend_MPU_H- 10_bn.xls • • Suspended Well Inspection — MPU H -10 PTD 1971490 Photo by AOGCC Inspector B. Noble te `pa , t ' t I f... - - 1. .; C, i :,.. .._.... 1 j It 1-10 / /, _ _ s,�.- t on .. • .... i ", t MPU H -10 Suspended Well Inspection 7 -7 -11 bn 1 STATE OF ALASKA . • ALASKA OAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other 0 REPORT OF Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ INSPECTION Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ , 197 -1490 3. Address: P.O. Box 196612 Stratigraphic El Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22795 -00 -00 8. Property Designation (Lease Number) : W ) q 9. Well Name and Number: ADLO- 025627 3'g® 1 14250 - MPH -10 10. Field /Pool(s): 1 1 MILNE POINT FIELD / SCHRADER BLFF OIL POOL 11. Present Well Condition Summary: Total Depth measured 6080 feet Plugs (measured) 275, 5450 feet true vertical 4320.31 feet Junk (measured) None feet Effective Depth measured 6021 feet Packer (measured) 5517 5701 feet true vertical 4273.7 feet (true vertical) 3875 4021 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 91.1# H-40 33 - 112 33 - 112 Surface Intermediate Production 6031' 7" 26# L -80 32 - 6063 32 - 4307 Liner Liner ���� � c� � `�� �� Perforation depth: Measured depth: SEE ATTACHED - a c - True Vertical depth: _ .L. _ Tubing: (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 31 - 244 31 - 244 Packers and SSSV (type, measured and true vertical depth) HES 7" Perma- Series Pkr 5517 3875 HES 7" Perma -Series Sumo Pkr 5701 4021 12. Stimulation or cement squeeze summary: Iii 'I `Oi Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Alq.;,:R Y4< (4,' " :; s . :1idrnission t :17 rhgs, 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development U Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGO GINJ ❑ SUSPo SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - , e Lastu °& 1 Title Petrotechnical Data Technologist Signatu MISIIIV 1 Phone 564 -4091 Date 7/25/2011 Form 10 -404 Revised 10/2010 MOMS JUL 25 gyp !` " " 4 ` 2 � MOMS bmit Original Only MPH -10 197 -149 • PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPH -10 9/1/98 PER 5,580. 5,600. 3,924.81 3,940.64 MPH -10 9/1/98 PER 5,734. 5,754. 4,046.89 4,062.76 MPH -10 9/1/98 PER 5,810. 5,830. 4,107.16 4,123. MPH -10 8/11/03 APF 5,640. 5,660. 3,972.32 3,988.18 MPH -10 8/12/03 APF 5,617. 5,624. 3,954.1 3,959.65 MPH -10 4/19/11 BPS 5,450. 5,830. 3,822.12 4,123. MPH -10 4/21/11 BPS 275. 5,450. 275. 3,822.12 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE III • • Milne Point Unit Well MPH -10, PTD 197 -1491 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of MPU MPH -10 on 07/07/2011. The following attachments document the inspection and the current condition of the well (reference 20 AAC 250.110 (e) and (f). • Suspended Well Site Inspection Form, documents the well pressures and site condition. AOGCC inspector Bob Noble witnessed the inspection. • Wellbore diagram illustrating the current configuration of the well • Pad map showing the well location and other wells within one - quarter mile radius of the surface location • Area photograph of pad and surrounding area • Photographs showing the condition of the wellhead, tree and the surrounding location Additional Pertinent Information: • MPH -10 was suspended 04/21/2011 because 7" casing failed pressure test • MPE -10 is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The wellhead and tree are secure and in good condition • The well is secure with cast iron bridge plugs set 275 and 5,450' • The well is mechanically sound and pressure tested MJL 18 Jul 2011 • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Milne Point Unit SB H -10 Field /Pool: Schrader Bluff Permit # (PTD): 197149 API Number: 5002922795 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 4/21/2011 Surface Location: Section: 34 Twsp: 13N Range: 10E Nearest active pad or road: G -Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: A little subsidence in the back of Well. The rest on the area Dry Pad or location surface: Dry Location cleanup needed: No Pits condition: None Surrounding area condition: Dry, Clean Water /fluids on pad: None Discoloration, Sheens on pad, pits or water: No Samples taken: None Access road condition: OK Photographs taken (# and description): 4; Wellhead Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: No S -Riser Cellar description, condition, fluids: Clean, Dry Rat Hole: N/A Wellhouse or protective barriers: Wellhead guard Well identification sign: Yes Tubing Pressure (or casing if no tubing): BPV Annulus pressures: IA: 0 psi OA: N/A (Monabore) Wellhead Photos taken (# and description): 4; Headhead Work Required: None Operator Rep (name and signature): Jeff Rea AOGCC Inspector: Bob Noble Other Observers: Bill Kruskie Inspection Date: 7/7/2011 AOGCC Notice Date: 7/6/2011 Time of arrival: 3:10 PM Time of Departure: 3:20 PM Site access method: Access Road • • Tree: Cameron 2 9/16" 5M Orig. KB Elev. = 66.4' (N 22E) Wellhead; 11" x 2 7/8" ESP & HT 5M M P U H-10 Orig. GL Elev. = 36.6' FMC Gen 6 2 -7/8" 8rd bottom and RT To Tbg. Spool = 30.9' (N 22E) top, 2.5" CIW BPV profile. To to f3 g 2 7/8" Kill String 1 244' 20" 91.1 ppf, H-40 112' HES 7 EZSV CIBP I 275' KOP @ 500' to 4,600' Max. hole angle = 64 deg. Hole angle thru' perfs = 37 deg. ' JJOTF: The casing has buckled. Hole milled hole in 7" casing in area from 305' - 549'. F2 o o 3 N Leaking Howco 2093' 2 7/8" 6.5 ppf, L -80, 8rd EUE tbg. c > ID 7" "ES" Cementer ( drift ID = 2.347 ", cap. = 0.00592 bpf) ro o Weatherford casing patch 7" 26 ppf, L-80, BTC mod production a 2082' -2102' (5.8" ID) r) casing a a ( drift ID = 6.276 ", cap. = 0.0383 bpf) o ai Stimulation Summary 8 -28 -98 -'OB Sand'placed 120,534# of PropLok coated 16/20 CarboLite behind pipe 8 -29 -98 - 'OA Sand'placed 119,459# of PropLok coated 16/20 CarboLite behind pipe 8 - 31 - 98 - 'N Sand'placed 76,879#of 0 HES 7" EZSV CIBP 5450' AcFrac resin coated 16/20 CarboLite behind PiPe Perforation Summary P Ref log: Sperry Sun GR 8/28/97 - - Ell HES 7" Perma- Series Pkr 5517' Size SPF Interval (TVD) :=z; 4.5 4 5580 -5600 NB 3859 -3875 is :..:emu LI Marker Joint ( 5,407 - 5,446 ) 4,5 5 5617 -5624 NC 3954 -3960 4.5 5 5640 -5660 NE 3972 -3988 : = :: 3.5" 250 Micron Screens 4.5 4 5734 -5754 OA 3981 -3997 '�: I5523 -5701' C and Blank Pipe 4.5 4 5810 -5830 OB 4041 -4057 :: . ii i. SLB Big Hole charges @ 0 "/180" deg. Straight Slot Locator and 5701' phasing (EHD - 0.7 ", TTP - 7.9 ") - ,, Molded Seal Assy III HES 7" Perma- Series 5701' tumuli Sump Pkr MII 7" landing collar (PBTD) 5980' 7" float collar (PBTD) 5981 • .0 • Collet Guide 5706' I 7" float shoe 6063' = =-= DATE REV. BY*NTS MILNE POINT UNIT 8 -31 -97 MDO 7' Cased Hole Completion 220 9 -01 -98 KJW Perforated and Fraced WELL No : H -10 9/5/98 M. Linder Inital Completion 02/24/00 M. Linder RWO Nabors 4 - API : 50 -029 -22795 8/14/03 Lee Hulrne 455 ESP do. Add Perfs. Add Screens 9/15/06 R HANDY 4FS RWO F.SP C/O 4/22/11 Lee Hulme Pulled ESP, Milled out Csg. Set Kill String Doyon 16 BP EXPLORATION (AK) . • • Enter /Exit / A 1 t p ‘, St 1 \ \ /3 0 r ‘i , Q • tl- 330' I j 'ez) I) V Izii N - 3 I 370' I P a ,7 Q T ail I 15 I ,4 J —� i t , ,.L_ ____MI EL - - - ---■ 5 CD CD � 12 I II 3 d" cr . 11 I — it 10 c 2 e E I j .. ,I0 Iii 1 ., J lia / ,— , V r pay ,iiA 4Plota \ei // / ' o E - xit / WELL PRODUCER • or WELL INJECTOR • DATE : 12/2/2010 SCALE : 1" = 100' MAP DATE : 2010 MPU - H PAD WELL SLOT W /CONDUCTOR Q bs +4495. rrxd O O N , _ - ,....''''. ''."".,"..:"-:' ',: ---41111614:-'/;' %.f.-. - .,.... (n a O'' t ! ! i i 5 -4 --ii. • • `k `Y — . w:.5n j j � j' • / ' r ' i I r` A ' a e ..._ 4,,,, ,. f .. .., . ...., ....• ...., ,A,, .. .. .. , 4,... , ,...„, , ).• ,.. ,„ . ,,.. . ... _ .„. ,. ..., .. ,...... •. .. .. ake , . „ ,... • t . ... ,., a 4 �r f ' ' , A r !r t p , - , 1 k. \ J w e . . 4 . \",,40.Sic::: . • • 1. _ . . • . - A - -.., .. S . ... . --- , . . 1. .1 . - - , . ,.... , . r - ... 1 Ir '........ . 44 ., . .. I, , . s 41. ?tirl . . , .... , • . ., . . .. . , , . . . .. A . ;... .... ....,..---„.,........„.......... , ._.--.,-,_ -,-..,,,,,....,..,...: .,.......„,... ...4. ,,, .......,,,,,...... _:. .,.,,...,,, ,... . , • -' ‘1,‘ ...e. . - - V S .,-....- ' .... '' .1, . ::: i/P . .-...NN. ',. ' : ;„ : - ,_ .--,,...' ' , --,_:.-,.. ,''''.. - , mo o . • ' _ A. 'A. -... : . _ - - ' ,, A; . ,,, .„ ,,,,,,' ' :„.-, . i .--4.... . „ : .:.• ..,.. - "k ,: -4 "*..-4 - 7 ' "'". '---',:- f* ..-. . .'. , „ - ,, *._ , -,-,,-,?` *.... , . . . - ' MPU I-1 - 10: Well Head (taken 07/07/2011) • I- . _..,.,. { . �:.� K ; :.'. ._ .. ..._ .. . , :....raw:.- .- +. ..... "- - .... , . . __ .... ........... ....„ .1 4..... . lea , ...„ „ '. x r ...,..,,_ f '`,,,+' _ ,...%' ',... .... ,k .,,,,,..:. r 10..' -'" " + - # c '" r „ ...... • .«. �. t 0 .;,,, ;0 e:'. :::: At' * _ 4 ,, t, t i , . ,,....- .,,,_,, sy „_......., � # y a a � �y�49�”' r �� s � + e Y d 7l { s a MPU H - 10: Well Head (taken 07/07/2011) • II • • �yuW ®.. ....-...0 ~ . 1 , : 4-3 " { *. f. , fi t _ _ ,,,_, tow . 4 4 . . .., - .,sii- , is i* . 1 A ,... * r i,t . _, .. , ,....„...„,,.........., _ _ _ iir • ... k . r g . a. c fi �. xY .. ' I. t . ...._ ,,..,,, s I or « s ,v s s k a gF. 4 MPU H - 10: Well Head (taken 07/07/2011) fi M ` I. i ` !M "rte p 'tom ,'# r � 1 r ,, . � Vv 1 4 -p 4 M xi'4 T � • ,.. ll 1 ..,. x` . . e rg* t . ;> 1 { --1 , i MI OW 1 4 . F . b . it 1r ..d 1 a p ' .� , i • i ! �" 1 9 "� Jd t� ^. a „ t °„ 4 t d " ! a i § 7I ' Y r 4 o , r,. 4 d 4 ., x ix 0 Schlumberger No. 5748 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 02 -12C BCRD -00105 SCMT 5/6/2015 1 1 C -22A BL65 -00022 MEMORY PPROF W/ GHOST 3/7/2015 1 1 MPE -28 BCRJ -00085 CEMENT BOND LOG 5114/2015 1 1 H -22A BL65.00028 MEMORY PPROF W/ DEFT 5/8/2015 1 1 C -02 AWJI- 00136 PPROF WI GHOST 3/28/2015 1 1 _ Z -112 BD88- 00093_ MEMORY PPROF W/ DEFT 312912015 _ 1 1 t co ,� 4 MPH-10 BCRD 0090 UST 4/21/2015 3/9/2015 1 1 1 - 1 JP S -128 BCZ2 -00035 CH EDIT (USIT) 1/312015 1 A -39A BL65 -00018 CH EDIT (PDC -GR) 2/4/2015 1 E -356 BHGR -00003 OH (FLEX EDIT 12/03/10 1 1 a PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E Benson Blvd Anchorage, AK 99503 -2838 - i v ' Aa SF,P 1 2 2Oi ) Y� A, 'j, M :4 7 111 { STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 04/21/2011 197 - 149 311 -135 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 08/23/1997 50 - 029 - 22795 - - 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 08/27/1997 MPH -10 2834' FSL, 4167' FEL, SEC. 34, T13N, R10E, UM 8. KB (ft above MSL): 66.00' 15. Field / Pool(s): Top of Productive Horizon: Milne Point Unit / Schrader Bluff 441' FNL, 4142' FEL, SEC. 02, T12N, R10E, UM GL (ft above MSL): . 36.9' Total Depth: 9. Plug Back Depth (MD +TVD): 753' FNL, 4141' FEL, SEC. 02, T12N, R10E, UM 6021 4274 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 556479 y - 6009984 Zone- ASP4 6080 4320 ADL 025627 TPI: x- 556529 y- 6006710 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 556532 Y 6006398 Zone- ASP4 None 18. Directional Survey: ❑Yes : No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) _ N/A ft MSL 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/ VD: `' MWD, GR / CCL N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP I BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.1# H-40 Surface 112' Surface 112' 24" 250 sx Arcticset I (Aoorox.) 7" 26# L -80 31' 6063' 31' 4307' 8 -1/2" 1097 sx Permafrost 'E', 50 sx PF 'C', 130 sx 'G' 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 - 1/2" Gun Diameter, 4 spf 4 -1/2" Gun Diameter, 5 spf Kill String: 2 -7/8" 244' MD TVD MD TVD 7" HES Perm Packers (2) 5517' / 3875' & 5701' / 4021' 5580' - 5600' 5617' - 5624' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5734' - 5754' 5640' - 5660' 5810' 5830' �, 4 ') 0'0 DEPTH INTERVAL (MD)1 AMOUNT AND KIND OF MATERIAL USED : 5450' Set HES 7" EZSV CIBP ''" 275' Set HES 7" EZSV CIBP V 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 4 I Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes No Sidewall Core(s) Acquired? ❑ Yes ® 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 Iaborato anal • I Insults per 20 AAC 250.071. I EC / None 'VMS MAY 1 § 2El1 kl q ail & GO irl l+saion Form 10-407 Revised 12/2009 ONTI ED ON REVERSE G /Ynerbge Sit riginal Only 29.' GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Schrader Bluff NA 5571' 3918' None Schrader Bluff OA 5731' 4045' Schrader Bluff OB 5806' 4104' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Wellbore Diagram 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. Signed: Terrie Hubble �1 / I / Title: Drilling Technologist Date: ��� 1 MPH - 197 - 149 311 - 135 Prepared By Name/Number Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Wilmer Hoffman, 564 -4592 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 la: Classification of Service Wells: Gas Injection, Water Injection, Water - Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only North America - ALASKA - BP Page 1 of 11 Operation Summary Report Common Well Name: MPH -10 AFE No Event Type: WORKOVER (WO) I Start Date: 4/10/2011 I End Date: 1X4- 00RN8 -E (500,000.00 ) Project: Milne Point Site: M Pt H Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/23/1997 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292279500 Active Datum: 25 : 10 2/19/2000 06:00 @55.90ft (above Mean Sea Level) Date From - To Hrs i Task Code ! NPT NPT Depth Phase Description of Operations (hr) (ft) 4/13/2011 18:00 - 00:00 6.00 MOB P PRE ( PREPARE TO UD DERRICK. ' -PJSM FOR UD DERRICK. -UD DERRICK. -MOB RIG OFF OF MPF -94. -SPOT ON MPF 4/14/2011 00:00 - 06:00 6.00 MOB P PRE SECURE BOPE STACK ON STORAGE RACK. -R/U BOOSTER WHEELS. - REMOVE RIG MATS FROM AROUND WELL. 1-0200 Hrs - MOB RIG FROM MPF PAD TO MPH PAD. _ 06:00 - 09:00 3.00 MOB P PRE I CONTINUE TO MOB RIG TO MPH PAD - TUBOSCOPE INSPECTED WELD ON FITTING FOR DOWNSTREAM CHOKE GUAGE ON RIG FLOOR. 09:00 - 12:30 1 3.50 MOB P PRE PJSM: SPOT RIG ON PAD - REMOVE REAR BOOSTERS I -RAISE DERRICK -RU FLOOR 12:30 - 14:30 2.00 MOB j P PRE PJSM: SPOT RIG OVER WELL -SPOT RIG OVER WELL AT 14:00 -SHIM UP RIG 14:30 - 15:00 0.50 MOB P PRE RIG EVAC DRILL -ALL SIGNED IN ACCOUNTED FOR IN MUSTER AREA, FORKLIFT DRIVER AT ENTRANCE TO PAD BLOCKING TRAFFIC 15:00 18:00 3.00 MOB P PRE SPOT FLOW BACK TANK -HARD LINE CREW MAKING UP HARD LINE TO TANK. � -R/U CELLAR. - - - -- I - ---- - - - - -- -- - - - - - -- - - -- -- 18:00 - 20:30 2.50 KILLW P DECOMP ?RIG ACCEPTED AT 18:00 HRS. -IA PRESSURE OF 1,350 PSI. -STEAM HARD LINE AND HEAT UP. -TAKE ON FLUIDS IN PITS. -HUNT DOWN ICE PLUG IN HARD LINE AND I FREE. -BLOW STEAM DOWN HARD LINE. 1- PRESSURE TEST HARD LINE PRE AND POST I CHOKE TO 250 PSI LOW AND 3500 PSI HIGH. 20:30 - 21:00 0.50 KILLW P DECOMP BLOW DOWN LINES TO FLOW BACK TANK. - 22:00 1.00 , KILLW i P - - -- '- - - - - -- - - -- - - -_ -- - 21:00 DECOMP I P/U AND R/U DSM LUBRICATOR. -MESSED UP THREADS ON RUNNING TOOL I ON LUBRICATOR AND HAD TO REPLACE. "DO I NOT HAVE RUNNING TOOL ON HYD. LUBRICATOR WHEN IT IS BROUGHT UP I SKATE„ -HOLD AAR WITH DSM ON P/U LUBRICATOR. 22:00 - 23:00 1.00 KILLW P DECOMP I PULL TWC WITH DSM LUBRICATOR. TUBING PRESSURE 1350 PSI. -I.A. PRESSURE 1350 PSI SET BACK LUBRICATOR. Printed 5/11/2011 10:22:33AM Northdtmerica - ALASKA - BP - Page 2 of 11 Operation Summary Report Common Well Name: MPH -10 AFE No Event Type: WORKOVER (WO) Start Date: 4/10/2011 End Date: X4- OORN8 -E (500,000.00 ) Project: Milne Point Site: M Pt H Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/23/1997 12:00:OOAM I Rig Release: Rig Contractor: DOYON DRILLING INC. j UWI: 500292279500 Active Datum: 25:10 2/19/2000 06:00 @55.90ft (above Mean Sea Level) Date From - To 1 Hrs Task 1 Code 1 NPT I NPT Depth Phase Description of Operations ( ) 1 (ft) 1 hr ft 23:00 - 00:00 1.00 KILLW P I DECOMP PJSM ON BLEEDING PRESSURE OFF OF ' 1 I WELL. - NOTIFIED DAY WSL AND RWO ENGINEER OF PRESSURES ONCE TWC WAS PULLED. BOTH AGREED THAT TO FOLLOW THE WELL PLAN AND BLEED OFF THE GAS CAP. - NOTIFY MPU AND PAD OP ON GAS VENTING I OPERATIONS. -OPEN MAN. CHOKE - 70 PSI ON DIVERTER ! , LINE. 4/15/2011 1 00:00 - 03:00 3.00 KILLW P 4 DECOMP 1 BLEED GAS CAP OFF WITH -75 PSI ON DIVERTER LINE. -BLEED PRESSURES DOWN TO 0 PSI ON IA AND TUBING. - VOLUME OF FLUID DURING BLEED OFF 1 RECOVERED IS 5 BBLS. 03:00 - 05:00 2.00 KILLW P DECOMP PJSM FOR WELL KILL. 1 -BRING TRUCKS UP AND RIG UP FOR WELL KILL. -LINE UP AND CIRCULATE 40 BBLS DOWN TUBING. -PUMP AT 5 BPM AND 790 PSI PUMP 40 BBLS WITH NO RETURNS. -BULL HEAD A TOTAL OF 355 BBLS OF 1 i 'SEAWATER DOWN TUBING AND ANN. ' -LINE UP TO PUMP DOWN TUBING AND IA 'WITH ICP AT 8.2 BPM AND 360 PSI, FCP AT ' 8.2 BPM AND 1000 PSI. 05:00 - 05:30 0.50 KILLW P ! DECOMP MONITOR WELL. ' -BOTH TBG AND IA ARE ON A VAC 1- ESTABLISH LOSS RATE @ - 18 BPH. 105:30 - 06:30 1.00 WHSUR P i DECOMP PU & MU HYD LUBRICATOR - TEST LUBRICATOR TO LOW 250 PSI AND HIGH 1500 PSI (1.5 X MASP) - MAINTAIN CONSTANT HOLE FILL AT A RATE _ , OF -20 BPH -r 06:30 - 08:00 1.50 WHSUR P 1 DECOMP PBU ASSISTING MPU WELLS GROUP TO SET ' TWC - TESTED TWC FROM ABOVE TO 250 PSI LOW I I AND 3500 PSI HIGH. - PERFORMED ROLLING TEST FROM BELOW FOR 10 MIN. - PUMPED 8 BPM AT 680 PSI. T - PUMPED TOTAL OF 50 BBLS. 08:00 - 10:00 2.00 WHSUR P DECOMP PJSM FOR ND OF TREE 1 1 1- ND 2 -9/16, 5K, CIW TREE AND ADAPTER. FMC REP ON LOCATION TO MAKE SURE TREE ALIGNMENT IS CAPTURED DURING ND. -CLEAN UP WELL HEAD AND PENETRATOR 10:00 - 13:00 3.00 WHSUR P DECOMP I NU 13 -3/8" BOPE I 1-MAINTAIN CONTINUOUS HOLE FILL AT 20 1 _ BPH LOSSES Printed 5/11/2011 10:22:33AM North America ALASKA - BP - Page 3 of 11 Operation Summary Report Common Well Name: MPH -10 1AFE No Event Type: WORKOVER (WO) Start Date: 4/10/2011 ; End Date: 1X4- 00RN8 -E (500,000.00 ) Project: Milne Point Site: M Pt H Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/23/1997 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292279500 Active Datum: 25 : 10 2/19/2000 06:00 @55.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (ft) 13:00 - 15:00 2.00 WHSUR 7 N SFAL DECOMP WSL AND TOOL PUSHER LOOKED AT THE FLANGE MAKE UP - A FEW BOLTS WERE NOT MADE UP TO SPEC. AND FEW WERE DAMAGED WITH THE LAST USE OF THE BOP - A DIFFERENT 13 -3/8" ADAPTER WAS USED FOR PROPER SPACING. THIS FLANGE WAS A LITTLE WIDER THUS CAUSING THE PAD STUDS TO BE SHORT & THE NUTS NOT TO MAKE UP ALL THE WAY. THE CREW HAD ATTEMPTED TO USE AN ALL THREAD STUD BOLT IN PLACE OF THE PAD STUD. - THE JOB WAS STOPPED UNTIL WE COULD GET SOME CLARIFICATION ON EITHER THE ALL THREAD BOLT COULD BE USED IN PLACE OF THE PAD STUD. THE TOOL PUSHER CONFIRMED WITH HYDRILL REP THAT THE PAD STUDS ARE PREFERRED. - THE CORRECT STUDS WERE FOUND AND USED TO REPLACE THE DAMAGED STUDS AND THE ONES THAT WERE TO SHORT. 15:00 - 19:00 1 4.00 WHSUR P DECOMP CONTINUE TO N/U BOPE. -BOPE WITH 4 RAM PREVENTER, ANNULAR, 2 -7/8" X 5" VBRS, BLIND SHEARS, 2 -7/8" SOLID BODY RAMS. 19:00 00:00 5.00 7 WHSUR P DECOMP TEST BOPE. 250 PSI LOW. 3500 PSI HIGH n PRESSURE. -ALL TESTS FOR 5 CHARTED MINUTES. -TEST W/ 2 -7/8" TEST JOINT. -TEST ANNULAR WITH 2 -7/8" TEST JOINT TO 250 PSI LOW AND 3500 PSI HIGH. -TEST WAIVED BY: BOB NOBLE- AOGCC. -TEST WITNESSED BY BP WSL, DDI TOOL PUSHER. - MAINTAIN CONTINUOUS HOLE FILL OF 20 PBH LOSS RATE. 4/16/2011 x00:00 - 02:30 2.50 BOPSUR P DECOMP I FINISH TESTING BOPE. - PERFORM ACCUMULATOR DRAW DOWN TEST: PRESSURE @ 2900 PSI DOWN TO 1725 PSI. 200 PSI INCREASE IN 15 SECONDS, FULL INCREASE IN 85 SECONDS. 5 BOTTLES AT 1 1800 PSI. -SUPER CHOKE FAILED DROP 100 PSI IN 2 I MIN. MECHANIC TO INSPECT AND RETEST. I -ALL OTHER TESTS PASS. -MAINTAIN CONTINUOUS HOLE FILL OF 20 BPH LOSS RATE. 02:30 - 03:00 0.50 BOPSUR P — — — DECOMP TEST FUNCTION INDIVIDUAL PREVENTER CLOSING TIMES. - ANNULAR - 51 SEC. -UPPER RAMS - 26 SEC. -BLIND SHEAR RAMS - 46 SEC. I -LOWER RAMS - 25 SEC. -CHOKE HCR - 1 SEC CLOSE PRESSURE DID NOT CHANGE. I -KILL HCR - 1 SEC CLOSE PRESSURE DID NOT CHANGE. - MAINTAIN CONTINUOUS HOLE FILL OF 20 BPH LOSS RATE. Printed 5/11/2011 10:22:33AM North America. ALASKA - BP Page 4 of 11 Operation Summary Report Common Well Name: MPH -10 AFE No Event Type: WORKOVER (WO) 1 Start Date: 4/10/2011 End Date: X4 -0ORN8 E (500,000.00 ) Project: Milne Point Site: M Pt H Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/23/1997 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292279500 Active Datum: 25 : 10 2/19/2000 06:00 @55.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase I Description of Operations 4 03 :00 - 04:00 1.00 BOPSUR P DECOMP RIG DOWN ALL TEST EQUIPMENT. -CLEAR RIG FLOOR OF 4" TOOLS. - MAINTAIN CONTINUOUS HOLE FILL OF 20 , BPH LOSS RATE. 04:00 - 06:00 . 200 PULL P ' I DECOMP ! P/U OPSO- LOPSO. -P /U LUBRICATOR AND INSTALL IN PIPE SHED. -PULL SUPER CHOKE. -HAVE MECHANIC INSPECT SUPER CHOKE. EVERYTHING LOOKS OK. - REINSTALL SUPER CHOKE. RE TEST. ROCK SOLID TEST. -MAINTAIN CONTINUOUS HOLE FILL OF 20 1 BPH LOSS RATE. 06:00 - 11:00 5.00 PULL P DECOMP VAC OUT STACK AND HANGER PROFILE TO PULL TWC. 1 -MAKE UP ADDITIONAL PUP ON OPSO LOPSO TO REACH TUBING HANGER (RKB IS HIGHER ON THIS WELL BECAUSE WELLHEAD IS BELOW GRADE) -MU OPSO -LOPSO AND PUMP -IN SUB -R/U DSM LUBRICATOR AND PRESSURE l i I TEST TO 250 PSI LOW AND 3500 PSI HIGH. - ATTEMPT TO PULL TWC 2 TIMES, CAN'T LATCH PLUG -PULL OPSO -LOPSO AND VAC OUT HANGER 'PROFILE - RETEST DSM LUBRICATOR, 250 PSI LOW, 3500 PSI HIGH -PULL TWC 1 -RIG DOWN DSM LUBRICATOR AND 13:00 2.00 PULL P DECOMP PR RIG 11:00 FLOOR . PREP RIG FLOOR TO PULL HANGER AND CUT ESP LINES (CABLE AND HEAT TRACE). -HANG ESP CABLE SHEAVE 1 13:00 - 13:30 0.50 PULL P DECOMP IrPJSM: PULL TUBING HANGER -FMC, CENTRALIFT AND RIG CREW PAR TICIPATION 13:30 - 15:30 2.00 - PULL P DECOMP I MU TIW VALVE TO LANDING JOINT - THREAD LANDING JOINT TO TUBING HANGER, 9 TURNS - VERIFIED WELL ON VAC -BOLDS PER FMC REP -PULL TUBING HANGER, CAME FREE AT 76K i I -BRING TO RIG FLOOR AND CLEAN - DISCONNECT ESP CABLE AND HEAT TRACE. -MAINTAIN 20 BPH HOLE FILL DOWN KILL LINE 15:30 16:00 0.50 PULL P DECOMP RIG UP TO CIRCULATE - CIRCULATE BOTTOMS UP. CIRCULATE AT 5 BPM WITH 1,110 PSI. 36 BBLS TO FILL. PUMP 180 BBLS TOTAL WITH 99 BBLS LOST. -120 BPH LOSS RATE AT 5 BPM. -SPR OF 30 SPM AND 300 PSI. -SPR OF 40 SPM AND 510 PSI. 16:00 16:30 0.50 PULL P I DECOMP MONITOR WELL FOR 30 MIN. 1 -WELL ON A VAC WITH A LOSS RATE —50 BPH STATIC. Printed 5/11/2011 10:22:33AM North America - ALASKA - BP Page 5 of 11 Operation Summary Report Common Well Name: MPH -10 AFE No Event Type: WORKOVER (WO) ' Start Date: 4/10/2011 End Date: X4- 00RN8 -E (500,000.00 ) Project: Milne Point Site: M Pt H Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/23/1997 12:00:OOAM I Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292279500 Active Datum: 25:10 2/19/2000 06:00 @55.90ft (above Mean Sea Level) Date 1 From - To Hrs Task Code I NPT I NPT Depth Phase Description of Operations ! (hr) i - (ft) 16:30 17:00 0.50 PULL P 1 DECOMP PULL ESP AND HEAT TRACE CABLE THROUGH SHEAVE. -RUN CABLES TO CENTRILIFT SPOOLING UNIT. 17:00 - 18:00 1 1.00 PULL P ' I DECOMP B/O CEMENT LINE AND BLOW DOWN. - STRETCH HERCULITE FROM RIG TO CENTRILIFT UNIT. 18:00 - 23:00 III 5.00 PULL P I DECOMP PJSM FOR POOH. -POOH WITH ESP COMPLETION FROM 5,485' ' ;TO 3,952 -RACK BACK THE FIRST 17 STAND OF 2 -7/8" ! 6.5# L -80 EUE 8 RD TUBING. - MAINTAIN CONTINUOUS HOLE FILL OF 40 BPI-I. ' I 1 - TUBING WAS VERY OILY. 1- INCREASE HOLE FILL TO 50 BPH AND T ACHIEVE RETURNS TO HELP CLEAN PIPE. -LOSS RATE SLOWED TO 27 BPH STATIC. 23:00 - 00:00 1.00 i PULL P DECOMP CLEAN FLAT GUARDS AND TIE AND BAG UP IN THREAD PROTECTOR BAG TO KEEP FROM DRIPPING ON PAD. i l -UD GUARDS. -MIXED DRUM OF SAFE -SURF 0 IN PILL PITS. I 4 � ;40 BBL PILL. -CLEAN RIG FLOOR OF CRUDE RESIDUE. 4/17/2011 00:00 01:30 1.50 I PULL P DECOMP PJSM FOR UD 2 -7/8" 6.5# L -80 EUE 8 RD (TUBING. -R/U CIRCULATION LINES. -PUMP 40 BBL SAFE -SURF 0 PILL SURFACE I TO SURFACE AT 5 BPM AND 1000 PSI. - DYNAMIC LOSS RATE OF 42 BPH. -SWEEP ON SURFACE SHOWED A 100% INCREASE IN BLACK SLUDGE AND CRUDE. 101:30 - 05:30 4.00 I PULL I P DECOMP, POOH UD 2 -7/8" 6 5# I -80 FIJE 8 Rn TI IRINC; . -POOH FROM 3952' -PIPE PULLING 75% CLEANER AFTER SAFE -SURF 0 SWEEP. -115 JOINTS OUT OF THE HOLE AT 0600 HRS. -MAINTAIN CONTINUOUS HOLE FILL AT 27 IBPH LOSS RATE. 05:30 - 06:00 0.50 PULL P T 7 I DECOMP I SPOOL UP HEAT TRACE TO SPOOLING UNIT ! -ALL FLAT GUARDS & CLAMPS RECOVERED 06:00 - 10:30 4.50 PULL P DECOMP I CmTwt TO I AY nnWN -7/8^ TI (RING 10:30 - 13:00 2.50 PULL P DECOMP FROM 2085' TO ESP ASSEMBLY CUT ESP CABLE AND LAD DOWN ESP I ASSEMBLY I - RECOVERED THE FOLLOWING: 37 LA SALLE CLAMPS 4 -3' FLAT GUARDS I 11 -4' FLAT GUARDS 565 -6' FLAT GUARDS 1727 FLATBANDS I I -PUMP PACKED WITH SAND - CENTRILIFT CONFIRMED TWISTED SHAFT AT LOWER END OF PUMP -2 EXTRA HOLES CUT IN PUMP IN- TAKE/GAS ISEPARATOR H LAY DOWN TANDEM SEALS & MOTOR Printed 5/11/2011 10:22:33AM North America - ALASKA - BP Page 6 of 11 Operation Summary Report Common Well Name: MPH -10 1 AFE No Event Type: WORKOVER (WO) Start Date: 4/10/2011 1 End Date: X4- 00RN8 -E (500,000.00 ) Project: Milne Point ' Site: M Pt H Pad -- - - - -- - - -- Rig Name /No.: DOYON 16 I Spud Date/Time: 8/23/1997 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292279500 Active Datum: 25 : 10 2/19/200006:00 ©55.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase ' Description of Operations (hr) i (ft) 1 113:00 - 15:00 2.00 DHB P DECOMP CLEAN AND CLEAR RIG FLOOR I - GATHER TOOLS AND CROSSOVER FOR RUNNING RTTS ON 2 -7/8" TUBING 15:00 - 15:30 1 0.50 DHB P 1 DECOMP I MAKE UP PUP JOINT TO WEAR RING RUNNING TOOL AND SET WEAR RING. 15:30 - 17:00 1.50 EVAL P DECOMP ; PJSM. RIH WITH 7" RTTS ON 2 -7/8" 6.5# , TUBING. j l ' - RIH ANr) TA(; 1IP AT' OR' fOWN 1 -APPLY ALL STRING WEIGHT OF 5K DOWN. ROTATE SEVERAL TIMES AND ATTEMPT TO WORK PAST TIGHT SPOT. NO GOOD. _ ; -NOTIFY ENGINEER IN TOWN. 17:00 - 18:30 1.50 I EVAL X WAIT ; DECOMP WAIT ON ORDERS. ! -CLEAN RIG.' - MAINTAIN CONTINUOUS HOLE FILL WITH 22 BPH LOSS RATE. 18:30 - 19:30 1.00 EVAL P DECOMP POOH WITH 7" RTTS. ; - INSPECT RTTS - NO INDICATIONS ON RTTS. -UD RTTS. - MAINTAIN CONTINUOUS HOLE FILL WITH 22 BPH LOSS RATE. 19:30 - 20:00. 0.50 EVAL P . ! D 1 P/U WEAR RING RUNNING TOOL. ; -PULL WEAR RING AND UD. 20:00 20:30 0 50 BOPSUR P DECOMP ' R/U TEST EQUIPMENT TO TEST BOPE. • -R/U TO TEST WITH 4" TEST JOINT. -MAINTAIN CONTINUOUS HOLE FILL WITH 22 BPH LOSS RATE. 20:30 - 21:00 I 0.50 PULL P DECOMP R/D TRUNK FROM RIG FLOOR TO _ i CENTRILIFT. L_ 21 :00 23:00 I 2.00 EVAL P DECOMP , WAIT ON TOOLS FROM DEADHORSE. ' -TEST PLUG FOR TESTING BOPE, 4-3/4" DRILL COLLARS, 4" DRILL PIPE AND ' EQUIPMENT. I -PULL 2 -7/8" OLD TUBING FROM PIPE SHED AND UD OUTSIDE TO MAKE ROOM FOR D /P. 1 -WORK ON WORK ORDERS. I- MAINTAIN CONTINUOUS HOLE FILL WITH 22 BPH LOSS RATE. I 23:00 - 00:00 1.00 BOPSUR P DECOMP SET TEST PLUG. -TEST BOPE 2 -7/8" VBR AND ANNULAR WITH j THE 4" TEST JOINT TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN. -TEST 4" TIW AND DART TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN. GOOD TESTS. 4/18/2011 �I 00:00 01:00 1.00 BOPSUR P DECOMP R/D TEST EQUIPMENT. I- INSTALL 9" WEAR RING. 01:00 02:00 1.00 1 FISH P DECOMP I LOAD AND TALLY 4" DRILL PIPE AND DRILL COLLARS. 02:00 - 02:30 !, 0.50 , FISH P DECOMP GATHER BHA TO RIG FLOOR. Printed 5/11/2011 10:22:33AM North America - ALASKA BP Page 7 of 11 Operation Summary Report __` �� Common Well Name: MPH -10 AFE No Event Type: WORKOVER (WO) Start Date: 4/10/2011 End Date: X4- 00RN8 -E (500,000.00 ) Project: Milne Point ! Site: M Pt H Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/23/1997 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292279500 Active Datum: 25 : 10 2/19/2000 06:00 @55.90ft (above Mean Sea Level) Date From - To Hrs I Task I Code NPT j NPT Depth Phase Description of Operations ft 02:30 04:00 1.50 FISH I P DECOMP PJSM FOR M/U BHA. -AFTER TALLY OF DC IT WAS DETERMINED THAT BY P/U 9 DC WITH BHA WE WOULD HAVE NON - SHEARABLE ACROSS THE BOPE, I WITH NO WAY FOR SURE WE WOULD BE ; ABLE TO RIH ON DP OR BE ABLE TO DROP DC AS WE WILL BE MILLING AT 306' WITH A ' 315 BHA. IT WAS DECIDED THAT WE WOULD ONLY RUN 6 DC AND THAT WOULD LEAVE US ;WITH SHEARABLES ACROSS THE BOPE AT 1 222' BHA. -BHA CONSIST• RI11 1 NOSE UPPER WHIPSTOCK MILL (6.059 "), XO,4 -3/4" BOOT BASKETS, BIT SUB, BUMPER SUB, OIL JARS, I - 6 EA. 4 -3/4" DC, XO TO DP. 04:00 - 06:00 2.00 i FISH P DECOMP I RIH AND TAG AT 305' MD. - OBTAIN PARAMETERS - UP 50K, DOWN 50K, ROT 50K AT 50 RPM AND 3K FREE TQ. -SLOW PUMP RATES OF 40 SPM AND 60 PSI, 50 SPM AND 80 PSI. -PUMP AT 3.5 BPM WITH 60 PSI LOSS RATE OF 36 BPH. - RFGIN MILLING OPS. MILL DOWN 11' (316') I AT 2 -5 K WOB WITH 7K TQ. I -WORK THROUGH TIGHT SPOT 4 TIMES. ' -P /U SHUT DOWN ROTATION AND TAG 4K AT 305' -P /U AND CONTINUE MILLING OPS WITH SAME PARAMETERS. -PUMP 20 BBL HI-VIS SWEEP SURFACE TO ' j I SURFACE SEEING AN INCREASE IN METAL 1 WITH LARGER METAL PIECES ON MAGNETS. 06:00 - 08:00 2.00 FISH P 1 DECOMP CONTINUE RUNNING IN HOLE WITH MILL - ROTATE FROM 318 -349' -PULL UP AND SLIDE THROUGH SAME INTERVAL WITH 5K WOB - CONTINUE IN HOLE SLIDING TO TIGHT SPOT T41 ' AT 3 51R' -BFI OW 51R O MORF WOR N 08:00 09:00 I 1.00 _ - — — — ' RIH T 75K, 6 72K FISH P DECOMP ,RIH TO 2006' - 30 BPH LOSSES - PUMP 20 BBL HI-VIS SWEEP AND CIRCULATE TO SURFACE, SMALL AMOUNT OF METAL IN RETURNS T 09:00 - 11:00 2.00 FISH P I DECOMP POOH FROM 2006' STANDING BACK 4" DP -STAND BACK DRILL COLLARS -LAY DOWN MILLING BHA -CLEAN OUT BOOT BASKETS, 1 GALLON METAL RECOVERED CLEAN/CLEAR RIG FLOOR 11:00 12:00 1.00 EVAL P DECOMP i PJSM: MU AND RIH RTTS -MU 1 (OD 5.75 ") -RIH WITH RTTS ON 4" DP I - TAGGED WITH 2K @ 305, PU AND CONTINUE RIH DRAGGING 5K TO 390' 12:00 - 13:30 1.50 EVAL , P ; DECOMP CONTINUE RIH WITH RTTS TO 2,006' -SET RTTS PACKER PER (HES) DIRECTION. Printed 5/11/2011 10:22:33AM North America ALASKA - BP Page 8 of 11 Operation Summary Report Common Well Name: MPH -10 — 1 AFE No Event Type: WORKOVER (WO) Start Date: 4/10/2011 End Date: 'X4- 00RN8 -E (500,000.00 ) Project: Milne Point � Site: M Pt H Pad 1 Rig Name /No.: DOYON 16 Spud Date/Time: 8/23/1997 12:00:OOAM I Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292279500 Active Datum: 25:10 2/19/2000 06:00 @55.90ft (above Mean Sea Level) Date From - To Hrs ! Task I Code NPT I NPT Depth Phase Description of Operations (hr) 1 i (ft) ,13:30 - 16:00 2.50 1 EVAL P DECOMP ! - ATTEMPT TO PRESSI JRF TFST CASING FROM 2006' TO SURFACE (2000 PSI DESIRED I ITEST PRESSURE) I - UNABLE TO BUILD SIGNIFICANT PRESSURE PUMPING 2 BPM @ 40 -60 PSI. -SHUT DOWN VERIFIED WITH (HES) PACKER REP THAT THE RTTS BYPASS WAS NOT OPEN. i I VERIFIED THAT OUR MUD PUMP POP OFF WAS CLOSED. - RELEASED THE PACKER AND PULLED UP HOLE AND RESET. ' ATTEMPTED ANOTHER PRESSURE TEST, PUMPED 12 BBLS AT 2 BPM WITH 60 -70 PSI. NOTIFIED RWO ENGINEER AND RWO SUPT ' OF THE SITUATION AND RECOMMENDED THAT WE PULL OUT OF THE HOLE AND 'CHECK THE PACKER FOR DAMAGE FROM RUNNING THROUGH THE DAMAGED _ I SECTION AT 306' 16:00 - 18:00 2.00 EVAL P DECOMP STARTED OUT OF THE HOLE WITH THE RTTS. - POOH F/ 2,010' - FLOW CHECK PRIOR TO BHA THRU THE STACK, - 15 BBLS TO FILL THE HOLE, MONITOR FOR ;10 MIN, FLUID FALLING. ' I OUT OF THE HOLE WITH RTTS. ', - PACKER HAND VERIFIED THE BY -PASS IS CLOSED, AND THE PKR ELEMENTS ARE GOOD. 18:00 - 20:30 '2.50 EVAL r P DECOMP P/U AND MIU RTTS. -RIH TO 290' CENTER OF ELEMENT. -TEST FROM SURFACE TO RTTS TO 250 PSI LOW AND 1000 PSI HIGH FOR 30 CHARTED MIN. GOOD TEST. - RELEASE RTTS. _ - MONITOR WELL, FLUID FALLING. 20:30 23:00 2.50 EVAL P 1 DECOMP I RIH TO 573'. ' - EXPERIENCED DRAG FROM 305' TO 517' I WORKING RTTS THROUGH TIGHT AREAS WITH 15K OVER. -SET RTTS. ATTEMPT TO PRESSURE TEST FROM SURFACE TO RTTS. PUMP AT 1 B PM ' WITH 60 PSI FOR 2 BBLS AND NO PRESSURE INCREASE. DOUBLE CHECK LINE UP AND INSPECT NEAR WELL HOUSES FOR SIGNS I OF FLUID TO SURFACE. START PUMPS AGAIN PUMPING AT 2 BPM WITH 70 PSI FOR 5 BBLS. NO PRESSURE BUILD UP. SHUT DOWN PUMPS AND OPEN BOP. -MONITOR HOLE WITH RTTS STILL SET. LOSING 7 BPH STATIC IN UPPER LEAK. 1 -DISCUSS OPTIONS WITH TOWN ENGINEER L AND RIG SUPT. Printed 5/11/2011 10:22:33AM . North America - ALASKA - BP Page 9 of 11 Operation Summary Report Common Well Name: MPH -10 AFE No Event Type: WORKOVER (WO) I Start Date: 4/10/2011 End Date: X4- 00RN8 -E (500,000.00 ) Project: Milne Point Site: M Pt H Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/23/1997 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292279500 Active Datum: 25 : 10 2/19/2000 06:00 @55.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) L (ft) 23:00 - 00:00 1.00 EVAL P DECOMP RELEASE RTTS. - MONITOR WELL, FLUID FALLING. -POOH WITH RTTS. -FLOW CHECK WELL PRIOR TO PULLING RTTS FLUID FALLING. 1 ! - INSPECT RTTS. LOOKED NEW. - MAINTAIN CONTINUOUS HOLE FILL AT 22 i BPH LOSS RATE. 4/19/2011 00:00 - 02:00 1 2.00 DHB P DECOMP j PJSM FOR SLIP AND CUT DRILLING LINE. I -SLIP AND CUT 54' OF 1 -1/4" DRILLING LINE. - SERVICE RIG. -CLEAN AND CLEAR RIG FLOOR. -WORK ON WORK ORDERS. I -WAIT ON DRILL PIPE. - MAINTAIN CONTINUOUS HOLE FILL AT 22 ,BPH LOSS RATE. _ 4 02:00 - 05:00 3.00 DHB P DECOMP I & MU HES 7" CIBP. I -LOAD AND STRAP DRILL PIPE. - MAINTAIN CONTINUOUS HOLE FILL AT 22 p 1, BPH LOSS RATE G � Pj` t 1 05:00 - 12:00 1 7.00 DHB P DECOMP RIH WITH 7" CIBP. -RIH, TIGHT SPOT FROM 305' TO 530' , 1 OK 14 DOWN TO GET THROUGH. -RIH TO 5,450' WITH CIBP SET PLUG PER HES (TOOL REP. 12:00 - 16:30 4.50 DHB P DECOMP POOH FROM 5,450' WITH 7" CIBP RUNNING TOOL. 1- PULL THROUGH TIGHT SPOT AT 545' PULLED 10K OVER TO SURFACE. 16:30 17:00 0.50 DHB P fi DECOMP BREAK OUT AND LAYDOWN RUNNING TOOL I- MAKE UP RTTS PER HES REP DIRECTION. 17:00 - 18:30 1.50 DHB P DECOMP RJH WITH RTTS TO 578' MD. ! - TOOK 1 OK DWN TO GET THROUGH TIGHT I SPOT AT —305' T _ 1 SET RTTS WITH 1 OK DOWN WT. 18:30 - 19:30 1.00 - DHB P DECOMP j RU TEST EQUIPMENT. ITEST DOWN THE DRILL PIPE AGAINST THE 7" BRIDGE PLUG TO PROVE THE BARRIER -TEST TO 1000 PSI FOR 10 MIN -OK. II - CHARTED SCANNED AND UPLOADED TO OPENWELLS AS ATTACHMENT. 19:30 - 20:30 1.00 DHB 1 P DECOMP ' RELEASE AND PULL RTTS. - 10 MIN FLOW CHECK - POOH F/ 578' TO SURFACE I- PULLED 10K OVER TO PULL THRU THE TIGHT SPOT F/ 550' TO 300' 1 120:30 - 00:00 3.50 DHB P DECOMP I RIH WITH 2 -7/8" TBG FROM DERRICK 1 - POH LAYING DOWN TBG. 1- CHANGE ELEVATORS TO 4" DP. -CLEAR & CLEAN RIG FLOOR. 4/20/2011 00:00 - 01:00 1.00 EVAL P DECOMP DU RISER THA. INSTALL DUTCH RISER SYSTEM. 01:00 - 02:00 1.00 EVAL I P DECOMP I PERFORM TABLE TOP STRIPPING DRILL. 02:00 - 08:30 6.50 EVAL N WAIT DECOMP 1 WAIT ON SLB E -LINE. CLEAR & CLEAN RIG. GENERAL HOUSEKEEPING. T ,- - PERFORM LIGHT MAINTENANCE. Printed 5/11/2011 10:22:33AM Page North America - ALASKA - BP 0 of 11 Operation Summary Report Common Well Name: MPH -10 ; AFE No Event Type: WORKOVER (WO) Start Date: 4/10/2011 End Date: f X4- OORN8 -E (500,000.00 ) Project: Milne Point Site: M Pt H Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/23/1997 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292279500 Active Datum: 25:10 2/19/2000 06:00 @55.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 16:30 8.00 EVAL P DECOMP RU SLB E -LINE FOR USIT LOGS AND CALIPER ' DATA. - RIH WITH USIT TOOL AND CALIPER TO 5,450' & LOG TO SURFACE. RUN USIT. 1- POOH WITH USIT TOOL ON E -LINE FROM 1 5,450' TO SURFACE. 16:30 - 18:00 1.50 EVAL P DECOMP RD SLB UNIT. - RD LINE WIPER AND BLOCKS. - B/O & UD DUTCH RISER. 18:00 - 22:00 4.00 EVAL P DECOMP CLEAN AND CLEAR RIG FLOOR. - PREP FOR RIH WITH 4" DRILL PIPE. -RIH TO 319' MD. WORK MULE SHOE PAST MILLED CSG POINT. -M /U TOP DRIVE AND ROTATE DOWN TO 574' MD. -10 RPM, 2K TQ, 5K WOB. - CONTINUE TO RIH ON ELEVATORS TO 5436' MD. -PUW= 117K, SOW= 90K. 22:00 - 23:00 1.00 EVAL P DECOMP CLEAN PITS 3 & 4 23:00 - 23:30 0.50 EVAL P DECOMP FILL PITS WITH 9.0 PPG GEO -VIS FLUID FROM M -I. 23:30 - 00:00 0.50 EVAL P DECOMP DISPLACE WELL TO GEO -VIS FLUID. -PUMP 7 BPM / 520 PSI. 1-ROTATE & RECIPROCATE PIPE. 30 RPM / 2 -3K TQ. -HOLE TAKING 3 BPH. 4/21/2011 00:00 - 01:00 1.00 TA P DECOMP CONTINUE TO DISPLACE WELL TO GEO -VIS FLUID. -PUMP 7 BPM / 520 PSI. 1 - ROTATE & RECIPROCATE PIPE. 30 RPM / 2 -3K TQ. - MONITOR WELL - OK. BLOW DOWN TOP DRIVE. 01:00 - 06:00 5.00 TA P DECOMP POH. UD DP TO 600'. STAND BACK 3 STDS. -FLOW CHECK PRIOR TO PULLING BHA n ( THROUGH STACK. �C -UD D.C'S. B/O & UD MULE SHOE. ('‘ - -- 06'00 08:30 2.50 -' - - - - - - -- --- - - - - -- - - -- TA P DECOMP PU & MU 7" EZ DRILL BRIDGE PLUG - RIM ON DP TO 275'. SET PLUG PER HES TOOL REP. - POH F/ 275' LD DRILL PIPE & RUNNING —I — —r TOOL. 08:30 09:30 1.00 TA P DECOMP j RU TEST LINES - BREAK CIRCULATION AND PRESSURE TEST THE PLUG SET AT 275' - PRESSURE TEST TO 1000 PSI FOR 10 CHARTF11 MIN TO TEST RARRI GOOD TEST 09 :30 10:00 0.50 TA P '. _ -- - I DECOMP 1 -- - . i RU TO PULL WEAR RING - PULL & LD WEAR RING. P DECOMP RIH WITH 2 -7/8" 6.5# EUE KILL STRING WITH 10:00 12:00 2.00 TA MULE SHOE ON BOTTOM PU & MU HANGER MADE UP WITH PENETRATOR PLUGS - LAND HANGER , FMC REP TO RILDS, - MULE SHOE SET AT 244' Printed 5/11/2011 10:22:33AM North America - ALASKA - BP Page 11 of 11 Operation Summary Report Common Well Name: MPH -10 ' AFE No Event Type: WORKOVER (WO) Start Date: 4/10/2011 End Date: X4- 00RN8 -E (500,000.00 ) Project: Milne Point Site: M Pt H Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 8/23/1997 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292279500 Active Datum: 25 : 10 2/19/2000 06:00 @55.90ft (above Mean Sea Level) Date From - To ' Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 13:00 1.00 TA P DECOMP RU LRS TO MUMP DIESEL FROM 244' TO SURFACE. - PUMPED 9 BBLS DOWN THE BACK SIDE AND 2 BBLS DOWN THE TBG ,13:00 - 16:00 3.00 TA P DECOMP SET AND TESTED 2 -1/2" "H" TWC - FMC REP DRY RODDED IN THE TWC - PRESSURE TESTED TWC FROM BELOW 250 'LOW AND 1000 HIGH FOR 10 CHARTED MIN. - PRESSURE TESTED FROM ABOVE 250 LOW AND 1000 HIGH FOR 10 CHARTED MIN. ' - ALL TESTS GOOD 16:00 - 17:30 1.50 BOPSUR P DECOMP ND 13 -5/8" HYDRILL BOP EQPT ND 13" X 11" SPOOL 17:30 - 19:00 1.50 WHSUR P DECOMP NU ADAPTOR FLANGE AND TREE 19:00 - 20:30 1.50 WHSUR P DECOMP 1 TEST ADAPTOR FLANGE TO 250 PIS - 5 MIN TEST ADAPTOR FLANGE TO 5000 PSI - 30 MIN 20:30 - 22:30 2.00 WHSUR P DECOMP TEST TREE TO 250 PSI LOW - 5MIN TEST TREE TO 5000 PSI HIGH - 30 MIN 22:30 - 23:00 0.50 WHSUR P DECOMP PU DSM LUBRICATOR AND TEST TO 250 LOW & 1500 HIGH 23:00 - 00:00 1.00 WHSUR P DECOMP PULL TWC MU BPV AND RETEST LUBRICATOR INSTALL BPV PT BPV FROM BELOW AT 1000 PSI - 10 MIN RD SECURE WELL AND RELEASE RIG AT 12400 FROM MPH-10 SEE MPJ-01 FOR FURTHER Printed 5/11/2011 10:22:32AM Tree: Cameron 2 9/16" 5M Orig. KB Elev. = 66.4' (N 22E) Wellhead: 11" x 2 7/8" ESP & HT 5M M P U H-10 Orig. GL Elev. = 36.6' FMC Gen 6 2 -7/8" 8rd bottom and RT To Tbg. Spool = 30.9' (N 22E) top, 2.5" CIW BPV profile. 2 7/8" Kill String 244' 20" 91.1 ppf, H -40 112' HES 7" EZSV CIBP 275' KOP @ 500' to 4,600' Max. hole angle = 64 deg. Hole angle thru' perfs = 37 deg. A NOTE: The casing has buckled. Hole milled hole in 7" casing in area from 305' - 549'. 0.) N Leaking Howco 2093' 2 7/8" 6.5 ppf, L -80, 8rd EUE tbg. > 7" "ES" Cementer ( drift ID = 2.347 ", cap. = 0.00592 bpf) iv o Weatherford casing patch 7" 26 ppf, L -80, BTC mod production o_ 2082' -2102' (5.8" ID) 0) casing a ( drift ID = 6.276 ", cap. = 0.0383 bpf) O rn Stimulation Summary 8 -28 -98 - 'OB Sand'placed 120,534# of PropLok coated 16/20 CarboLite behind pipe 8 -29 -98 - 'OA Sand'placed 119,459# of PropLok coated 16/20 CarboLite behind pipe 8 -31 -98 - 'N Sand' placed 76,879# of HES 7" EZSV CIBP 5450' AcFrac resin coated 16/20 CarboLite behind pipe Perforation Summary Ref log: Sperry Sun GR 8/28/97 HES 7" Perma- Series Pkr 5517' Size SPF Interval (TVD) C X ; 4.5 4 5580 -5600 NB 3859-3875 is Marker Joint (5,407 5,446 ) 4.5 5 5617 -5624 NC 3954 -3960 4.5 5 5640 -5660 NE 3972 -3988 1ii 3.5" 250 Micron Screens 4.5 4 5734 -5754 OA 3981 -3997 1�1 5523 -5701' 4.5 4 5810 -5830 OB 4041 -4057 '� and Blank Pipe SLB Big Hole charges @ 0 °/180° deg. Straight Slot Locator and 5701' phasing (EHD - 0.7 ", TTP - 7.9 ") I Molded Seal Assy HES 7" Perma- Series 5701' /111131111 Sump Pkr 7" landing collar (PBTD) 5980' 7" float collar (PBTD) 5981' 8 ® Collet Guide 5706' 7" float shoe 6063' DATE REV. BY COMMENTS MILNE POINT UNIT 8 -31 -97 MDO 7" Cased Hole Completion 22E 9 -01 -98 KJW Perforated and Frac'ed WELL No : H -10 9/5/98 M. Linder Inital Completion API 50 -029 -22795 02/24/00 M. Linder RWO Nabors 4 -ES 8/14/03 Lee Hulme 4ES ESP c /o, Add Perfs, Add Screens 9/15/06 R. HANDY 4ES RWO ESP C/0 4/22/11 Lee Hulme Pulled ESP, Milled out Csg, Set Kill String Doyon 16 BP EXPLORATION (AK) • • SSII BF ALARA SEAN PARNELL, GOVERNOR ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COAIIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem �,(•1 Engineering Team Leader ✓ " r--- \00 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPH -10 Sundry Number: 311 -135 Dear Mr. Reem: ,, APR 6 ZOli 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 a holid •r weekend. il • m issio er D this 5da of April, DATE t s �/ y p , 2011. Encl. STATE OF ALASKA , �yl , • ALASKA (AND GAS CONSERVATION COMMISSI ( � � � 1 - c i - � I RECEIVE `' t APPL FOR SUNDRY APPROVAL ti' ��, 2 ;101''' - 20 AAC 25.280 1. Type of Request: AI2Ska Uii &l f as Cans. Commis Lion ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Prograftyrt Rage ® 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. ® Development ❑ Exploratory 197 -149 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 22795 00 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPH -10 Spacing Exception Required? is No 9. Property Designation: 10. Field / Pool(s): AYC94 S9rG,A-E3t—e256.Hj 3ir0 Milne Point Unit / Schrader Bluff - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6080- 4320• 6021 4274 5450' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface Intermediate Production 6032' 7" 6063' 4307' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5580' - 5830' 3925' - 4123' Packers and SSSV Type: 7" HES Perma Series Packer Packers and SSSV 5517' / 3875' 7" HES Perma Series Sump Packer MD (ft) and TVD (ft): 5701' / 4021' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory - ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 19, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: 04/19/2011 ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: Guy Schwartz ❑WAG ❑ SPLUG ®Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Wilmer Hoffman, 564 -4592 Printed Name avid Reem Title Engineering Team Leader Prepared By Name /Number: Signature C-/ , yam- Phone 564 -5743 Date /i'/20 2b/i Terrie Hubble, 564 -4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 3t /1"— `� Sundry Number ❑ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Subsequent Form Required: (1 !MISSI0NER O THE COMMISSION Date Form 10-403 Revise j SLl�IdS APR 28 Submit In Duplicate ORIGINAL. ie yZz . •" Ay.�/ , • Suspend operations on well MPH -10 (PTD#1971490 and API #50- 029 - 22795) Page 1 of 1 • • Hubble, Terrie L From: Schwartz, Guy L (DOA) [guy.schwartz @alaska.gov] Sent: Tuesday, April 19, 2011 4:05 PM To: Hoffman, Wilmer Cc: Hubble, Terrie L; Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: Suspend operations on well MPH -10 (PTD #1971490 and API #50- 029 - 22795) Follow Up Flag: Follow up Flag Status: Red Wilmer, You have verbal approval to proceed with the plan below to secure the well and suspend operations. Please submit a 403 sundry requesting to suspend the well as soon as possible. (well status will be "suspended" once plugs have been set and tested ). Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Hoffman, Wilmer [mailto:hoffmawj @bp.com] Sent: Tuesday, April 19, 2011 3:41 PM To: Schwartz, Guy L (DOA) Cc: Hubble, Terrie L; Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: Suspend operations on well MPH -10 (PTD #1971490 and API #50- 029 - 22795) Guy, per our phone conversation we will be suspending workover operations on well MPH -10. This was a planned ESP swap. The well is a mono -bore casing well with 20" conductor set at 112' and a 7 ", 26# string of casing from surface to TD of 6,093'. There is no separate surface casing string. Throughout the workover operations, we planned on running a test packer (Halliburton RTTS) down to just above the perfs and test the 7" casing. However, we ran into a restriction in the casing at -300' with the test packer. We cleaned up the damaged casing with a 6- 1/16" string mill and then re -ran the test packer. The test failed due to the damaged casing. Because of the failing test and damage to the string of casing, we are electing to suspend workover operations on the well and come up with a plan of attack for a later date. Our plan to suspend will include the following steps: 1. Set 7" EZSV bridge plug at 5,450' MD just above the top of perfs to isolate formation. 2. Run 7" RTTS test packer and set below the damaged casing at -600'. Test the casing between the test packer and bridge plug to prove the bridge plug as a barrier. 3. Run USIT log on a -line for diagnostic work on the well for future plans. 4. Swap the well over from just above the bridge plug at 5,450' to a viscosfied 9.0 -ppg brine system. 5. Set 7" EZSV bridge plug above the damaged casing at -275'. 6. Test the plug at 275' back to surface to ensure the barrier. 7. Run 2 -7/8" kill string to just above the plug at 275 with a muleshoe on bottom. 8. Pump diesel to surface to fill the tubing and annulus with diesel freeze protect. As we discussed, please let us know of your approval to move forward as outlined above. We will submit a 403 request for suspended well status. Attached is a well schematic for your reference. Regards, Wa ne* G1 an. Operations Drilling Engineer Rig Workovers - BPXA Direct 907.564.4592 Cell 907.250.2601 4/20/2011 Tree: Cameron 2 9/16" 5M Orig. KB = 66.4' (N 22E) Wellhead: 11" x 2 7/8" ESP & M M P U H-10 0 Orig. GL . = 36.6' FMC Gen 6 2 -7/8" 8rd bottom and : 1 : RT To Tbg. Spool = 30.9' (N 22E) top, 2.5" CIW BPV profile. ; . 6s? ?,\\e(9 � p 20" 91.1 ppf, H-40 112' C = /J�jy, n�� ) . `/ ► V' Camco 2 7/8" x 1" KOP @ 500' to 4,600' ., sidepocket KBMM GLM 168' Max. hole angle = 64 deg. - Hole angle thru' perfs = 37 deg. C 1 42 1 r Leaking Howco 2093' - Oa � I I 7" "ES" Cementer Centrilift Heat trace 3450' Weatherford casing patch -- 2082'- 2102' (5.8" ID) 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. ( drift ID = 2.347 ", cap. = 0.00592 bpf) 7" 26 ppf, L -80, BTC mod production casing ( drift ID = 6.276 ", cap. = 0.0383 bpf ) I Camco 2 7/8" x 1" 5266' sidepocket KBMM GLM 2 -7/8" XN nipple 2.250" ID 5408' Stimulation Summary Centrilift 165P -12 PMSSD 5431' 8 -28 -98 - 'OB Sand' placed 120,534# of nt En PropLok coated 16/20 CarboLite behind pipe jM i -IC- S CO I 8 -29 -98 - 'OA Sand' placed 119,459# of Centrilift Tandem Seal Section J J 5453' PropLok coated 16/20 CarboLite behind pipe FSB3UTSSCVABPFSA/FSB3LTSBFSACL5 8 -31 -98 -'N Sand' placed 76,879# of Centrilift Series, FMH AcFrac resin coated 16/20 CarboLite behind 116 hp motor, 2210 volt, 35 Amp 5464' pipe 1 F > PumpMate w 6 Fin Cent. 5485' Perforation Summary KAM Ref Ioa: Sperry Sun GR 8/28/97 1M. - HES 7" Perma- Series Pkr 5517' Size SPF Interval (TVD) ; I • 111.1.111101 4.5 4 5580 -5600 NB 3859 -3875 ii : i ii 4.5 5 5617 -5624 NC 3954 -3960 p; II Marker Joint (5,407 5,446 ) 4.5 5 5640 -5660 NE 3972 -3988 1i 1 it 3.5" 250 Micron Screens 4.5 4 5734 -5754 OA 3981 -3997 IIIIMI 5523 -5701' 4.5 4 5810 -5830 OB 4041-4057 ii ' ∎' I: and Blank Pipe n n n i• n ,• SLB Big Hole charges @ 0 °/180° deg. Straight Slot Locator and 5701' phasing (EHD - 0.7 ", TTP - 7.9 ") 11/4111.M Molded Seal Assy HES 7" Perma- Series 5701' it' I, ; ,. Sump Pkr 7" landing collar (PBTD) 5980' .• . Collet Guide 5706' 7" float collar (PBTD) 5981' •• ■ii_ 7" float shoe 6063' DATE REV. BY COMMENTS 8 -31 -97 MDO 7" Cased Hole Completion 22E MILNE POINT UNIT 9 -01 -98 KJW Perforated and Frac'ed WELL No : H -10 9/5/98 M. Linder Inital Completion 02/24/00 M. Linder RWO Nabors 4 - API : 50 -029 -22795 8/14/03 Lee Hulme 4ES ESP c/o, Add Perfs, Add Screens 9/15/06 R.HANDY 4ES RWO ESP CIO BP EXPLORATION (AK) Suspend operations on well MPH -14TD# 1971490 and API #50- 029 - 22795: Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 19, 2011 4:05 PM To: 'Hoffman, Wilmer' Cc: Hubble, Terrie L; Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: Suspend operations on well MPH -10 (PTD #1971490 and API #50- 029 - 22795) Wilmer, You have verbal approval to proceed with the plan below to secure the well and suspend operations. Please submit a 403 sundry requesting to suspend the well as soon as possible. (well status will be "suspended" once plugs have been set and tested ). Regards, Guy Schwartz Senior Petroleum Engineers APP 2.U AOGCC 793 -1226 (office) 444 -3433 (cell) From: Hoffman, Wilmer [mailto:hoffmawj @bp.com] Sent: Tuesday, April 19, 2011 3:41 PM To: Schwartz, Guy L (DOA) Cc: Hubble, Terrie L; Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: Suspend operations on well MPH -10 (PTD #1971490 and API #50- 029 - 22795) Guy, per our phone conversation we will be suspending workover operations on well MPH -10. This was a planned ESP swap. The well is a mono -bore casing well with 20" conductor set at 112' and a 7 ", 26# string of casing from surface to TD of 6,093'. There is no separate surface casing string. Throughout the workover operations, we planned on running a test packer (Halliburton RTTS) down to just above the perfs and test the 7" casing. However, we ran into a restriction in the casing at -300' with the test packer. We cleaned up the damaged casing with a 6- 1/16" string mill and then re -ran the test packer. The test failed due to the damaged casing. Because of the failing test and damage to the string of casing, we are electing to suspend workover operations on the well and come up with a plan of attack for a later date. Our plan to suspend will include the following steps: 1. Set 7" EZSV bridge plug at 5,450' MD just above the top of perfs to isolate formation. 2. Run 7" RTTS test packer and set below the damaged casing at -600'. Test the casing between the test packer and bridge plug to prove the bridge plug as a barrier. 3. Run USIT log on a -line for diagnostic work on the well for future plans. 4. Swap the well over from just above the bridge plug at 5,450' to a viscosfied 9.0 -ppg brine system. 5. Set 7" EZSV bridge plug above the damaged casing at -275'. 6. Test the plug at 275' back to surface to ensure the barrier. 7. Run 2 -7/8" kill string to just above the plug at 275' with a muleshoe on bottom. 8. Pump diesel to surface to fill the tubing and annulus with diesel freeze protect. 4/19/2011 Suspend operations on well MPH -1iiPTD #1971490 and API #50- 029 - 22795) Page 2 of 2 As we discussed, please let us know of your approval to move forward as outlined above. We will submit a 403 request for suspended well status. Attached is a well schematic for your reference. «MPH- 10.pdf» Regards, Operations Drilling Engineer Rig Workovers - BPXA Direct 907.564.4592 Cell 907.250.2601 BOOMER SOONER,! 4/19/2011 Tree: Cameron 2 9/16" 5M Orig. KB Bo 66.4' (N 22E) Wellhead: 11" x 2 7/8" ESP & HT. M P U H-10 Orig. GL Elea!'= 36.6' FMC Gen 6 2 -7/8" 8rd bottom and RT To Tbg. Spool = 30.9' (N 22E) top, 2.5" CIW BPV profile. 20" 91.1 ppf, H -40 112' Camco 2 7/8" x 1" KOP @ 500' to 4,600' sidepocket KBMM GLM 168' Max. hole angle = 64 deg. Hole angle thru' perfs = 37 deg. - Leaking Howco 2093' 7" "ES" Cementer Centrilift Heat trace 3450' - Weatherford casing patch 2082' -2102' (5.8" ID) 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. ( drift ID = 2.347 ", cap. = 0.00592 bpf) 7" 26 ppf, L -80, BTC mod production casing ( drift ID = 6.276 ", cap. = 0.0383 bpf) Camco 2 7/8" x 1" 5266' sidepocket KBMM GLM 2 -7/8" XN nipple 2.250" ID 5408' Stimulation Summary Centrilift 165P -12 PMSSD 5431' 8 -28 -98 - `OB Sand' placed 120,534# of PropLok coated 16/20 CarboLite behind pipe - - 8 - - - `OA Sand' placed 119,459# of Centrilift Tandem Seal Section 5453' PropLok coated 16/20 CarboLite behind pipe FSB3UTSSCVABPFSA/FSB3LTSBFSACL5 8 - - - Sand= placed 76,879# of Centrilift Series, FMH AcFrac resin coated 16/20 CarboLite behind = 116 hp motor, 2210 volt, 35 Amp 5464' pipe 1.11 PumpMate w/ 6 Fin Cent. 5485' Perforation Summary Ref log: Sperry Sun GR 8/28/97 HES 7" Perma- Series Pkr 5517' Size SPF Interval (TVD) 4.5 4 5580 -5600 NB 3859 -3875 Marker Joint ( 5,407 - 5,446 ) 4.5 5 5617 -5624 NC 3954 -3960 4.5 5 5640 -5660 NE 3972 -3988 3.5" 250 Micron Screens 4.5 4 5734 -5754 OA 3981 -3997 5523 5701' and Blank Pipe 4.5 4 5810 -5830 OB 4041 -4057 SLB Big Hole charges @ 0 °/180° deg. 1 Straight Slot Locator and 5701' phasing (EHD - 0.7 ", TTP - 7.9 ") I , Molded Seal Assy HES 7" Perma- Series 5701' ® Sump Pkr 7" landing collar (PBTD) 5980' E Collet Guide 5706' == 7" float collar (PBTD) 5981' II • 7" float shoe 6063' DATE REV. BY COMMENTS 8 -31 -97 MDO 7" Cased Hole Completion 22E MILNE POINT UNIT 9 -01 -98 KJW Perforated and Frac'ed WELL No : H -10 9/5/98 M. Linder Inital Completion 02/24/00 M. Linder RWO Nabors 4 -ES API : 50- 029 -22795 8/14/03 Lee Hulme 4ES ESP c /o, Add Perfs, Add Screens 9/15/06 R.HANDY 4ES RWO ESP C/O BP EXPLORATION (AK) .. STATE OF ALASKA ALAšfI!'K Oil AND GAS CONSERVATION COM.ON REPORT OF SUNDRY WELL OPERATIONS RECEIVED OCT 0 4 2006 AI",,, ,,, na 0."" f". n 1. Operations Performed: _wu .......'"". [] ~ncho~ [] Abandon 181 Repair Well [] Plug Perforations [] Stimulate Re-Enter uspen Well [] Alter Casing 181 Pull Tubing [] Perforate New Pool [] Waiver 181 Other [] Change Approved Program [] Operation Shutdown [] Perforate [] Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development [] Exploratory 197-149 3. Address: [] Stratigraphic [] Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22795-00-00 7. KB Elevation (ft): 66.00' 9. Well Name and Number: MPH-10 8. Property Designation: 10. Field 1 Pool(s): ADL 025627 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 6080 feet true vertical 4320 feet Plugs (measured) N/A Effective depth: measured 6021 feet Junk (measured) N/A true vertical 4274 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface Intermediate Production 6032' 7" 6063' 4307' 7240 5410 Liner :' "'N" .t-r 'Ir':\f \ t"""; \:)CA, NC.J r~ 0" \) ¡(. Perforation Depth MD (ft): 5580' - 5830' Perforation Depth TVD (ft): 3925' - 4123' 2-7/8",6.5# L-80 5489' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" HES Perma Series Packer 5517' 7" HES Perma Series Sump Packer 5701' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: 0 0 0 300 276 Subsequent to operation: 13 1 1007 320 0 14. Attachments: [] Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations [] Exploratory 181 Development [] Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil [] Gas [] WAG [] GINJ [] WINJ [] WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Frank Roach, 564-4373 Printed Name Sondra Stewman Title Technical Assistant r--~~ Prepared By Name/Number: Sitmature (",.." Phone 564-4750 Date 10' U-l-Ol¡; Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 nR G\NAL RBDMS 8Ft 0 CT 0 [} 2006 Submit Original Only slon , ~ Tree: Cameron 2 9/16" 5 Wellhead: 11" x 2 7/8" ESP HT 5M FMC Gen 6 2-7/8" 8rd bottom and top, 2.5" CIW BPV profile. 20" 91.1 ppf, H-40 I 112' KOP @ 500' to 4,600' Max. hole angle = 64 deg. Hole angle thru' perfs = 37 deg. Centrilift Heat trace 3450' 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-80, BTC mod production casing ( drift ID = 6.276", cap. = 0.0383 bpf ) Stimulation Summary 8-28-98 - '08 Sand-'placed 120,534# of PropLok coated 16/20 CarboLite behind pipe 8-29-98 - 'OA Sand-' placed 119,459# of PropLok coated 16/20 CarboLite behind pipe 8-31-98 - 'N Sand! placed 76,879# of AcFrac resin coated 16/20 CarboLite behind pipe Peñoration Summary Ref loa: SDerrv Sun GR 8/28/97 Size SPF Interval 4.5 4 5580-5600 NB 4.5 5 5617-5624 NC 4.5 5 5640-5660 NE 4.5 4 5734-5754 OA 4.5 4 5810-5830 OB (TVO) 3859-3875 3954-3960 3972-3988 3981-3997 4041-4057 SLB Big Hole charges @ 0°/180° deg. phasing (EHD - 0.7", TIP - 7.9") 7" landing collar (PBTD) 7" float collar (PBTD) 7" float shoe 5980' 5981' 6063' MPU H-10 DATE 8-31-97 9-01-98 9/5/98 02124/00 8114103 9/15/06 REV. BY MD KJW M. Linder M. Linder Lee Hulm R.HANDY COMMENTS 7" Cased Hole ompletion 22E Perforated and Frac'ed Inital Completion RWO N bors 4-E 4ES ESP c/o, Add Perfs, Add Screens 4ES RWO ESP C/O ori. Elev. = 66.4' (N 22E) Ori Elev. = 36.6' RT To Tbg. Spool = 30.9' (N 22E) Camco 2 7/8" x 1" sidepocket KBMM GLM 168' Leaking Howco 7" "ES" Cementer 2093' Cameo 2 7/8" x 1" side pocket KBMM GLM 5266' 2-7/8" XN nipple 2.250" ID 5408' Centrilift 165P-12 PMSSD 5431' Centrilift Tandem Seal Section 1 5453' FSB3UTSSCVABPFSNFSB3L TSBFSACL5 Centrilift Series, FMH I 116 hp motor, 2210 volt, 35 Am~ 5464' PumpMate wI 6 Fin Cent. I 5485' HES 7" Perma-Series Pkr 1 5517' Marker Joint (5,407 - 5,446 ) 3.5" 250 Micron Screens 15523 -5701'1 and Blank Pipe Straight Slot Locator and Molded Seal ÄSsy HES 7" Perma-Series Sump Pkr 5701' 5701' Collet Guide 5706' MILNE POINT UNIT WELL No : H-10 API: 50-029-22795 BP EXPLORATION AK . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-10 MPH-10 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 9/6/2006 9/13/2006 Spud Date: 8/23/1997 End: 9/13/2006 9/912006 06:00 - 06:30 0.50 MOB P DECOMP Move off MPJ-24 06:30 - 08:00 1.50 MOB P DECOMP Scope in and lower Derrick 08:00 - 12:00 4.00 MOB P DECOMP Move Nabors 4ES to H Pad 12:00 - 16:00 4.00 MOB P DECOMP Spot Rig, Sub, Pipe Shed, Pits and Camp 16:00 - 18:00 2.00 MOB P DECOMP Raise Derrick 18:00 - 18:30 0.50 MOB P DECOMP Finish RU Nabors 4ES 18:30 - 19:00 0.50 KILL P DECOMP PU Lubricator and pull BPV. TBG Pressure= 140 psi, Annulus Pressure= 310 psi. 19:00 - 19:30 0.50 KILL P DECOMP Hook up circulating lines between Tree and Trip Tank for killing operation. Load 2% KCI Brine into Rig Pits 19:30 - 20:00 0.50 KILL P DECOMP Test Lines to 250 - 3500 psi 20:00 - 22:00 2.00 KILL P DECOMP Start kill operation by bleeding off Gas from TBG and Annulus to 20 psi. Pump TBG volume, 30 bbls, down TBG @ 5 BPMI 1700 psi. Bullhead 25 bbls to clear below circulating point of 5243' @ 3 BPMI 500 psi. Continue circulating taking returns through Choke and Tiger Tank at 4 BPMI 700 psi. 22:00 - 22:30 0.50 KILL P DECOMP Monitor well wI 70 psi on TBG and Annulus. Allow Crude to separate. 22:30 - 23:00 0.50 KILL P DECOMP Bleed off pressure and continue circulating taking returns back into Pits. Finish cleaning-up Wellbore. Monitor Well dead. 23:00 - 00:00 1.00 WHSUR P DECOMP Install and test TWC from bottom by bull heading into formation at 4 bpm/425 psi. Test TWC from top at 3500 psi x 10 minutes. 9/10/2006 00:00 - 01 :00 1.00 WHSUR P DECOMP Bleed off Hanger void. Nipple-down Production Tree. 01 :00 - 04:00 3.00 BOPSU P OECOMP Nipple-up Oouble Stud Adaptor and BOP Stack. 04:00 - 06:00 2.00 BOPSU P DECOMP Rig-up test equipment. Begin BOPE test. 06:00 - 08:00 2.00 BOPSU P DECOMP Complete BOPE test per BP/AOGCC requirements at 250/3500 psi. Good test. The State's right to witness the test was waived by J. Spaulding. Drain BOP Stack. Rig-down test equipment. 08:00 - 09:00 1.00 WHSUR P DECOMP Pick-up Lubricator. Pull TWC. Lay down same. Fill well bore (22 bbls). Static fluid level was -725'. Monitor Well. Fluid level slowely dropping. 09:00 - 10:30 1.50 WHSUR P DECOMP Pick-up Landing Joint. BOLOS. Pull Tubing Hanger to floor with no problems (50K). 10:30 - 11 :30 1.00 PULL P DECOMP Pull ESP and Heat Trace Cables over sheaves and attach to Spooling Unit. 11 :30 - 22:00 10.50 PULL P DECOMP Trip-out with 2 7/8" ESPIHT Completion with no problems. Break and lay down ESP Pump. 22:00 - 00:00 2.00 CLEAN P DECOMP MU BHA #1 with Mule Shoe on 2-1/16" CS HyDril Drill Pipe. 9/11/2006 00:00 - 02:00 2.00 CLEAN P OECOMP Continue RIH wI BHA #1 on 2-1/16" TBG Workstring. Tag Fill @ 5806' (-approx btm perfs). Find working parameters Up Wt= 30K, Down Wt= 25K. 02:00 - 06:00 4.00 CLEAN P DECOMP RU and to wash fill. Wash down from 5,806' to 5,922' at 4 BPMI 850 psi. Reverse Circulate after washing each single at 3 BPM/300 psi to 5,922'. Reverse a 25 bbls Hi-Vis Sweep while waiting on addintional fluids before continuing clean-out. 06:00 - 07:00 1.00 CLEAN N WAIT DECOMP Continue to wait on Vac Trucks. Continue circulating at 1 bpm and move Tubing. 07:00 - 09:00 2.00 CLEAN P DECOMP Off load additional 2% KCL Water. Continue to wash and reverse circulate from 5,921'-5,967' 4es md. (hard bottom...Landing Collar). 09:00 - 12:00 3.00 CLEAN P OECOMP Mix and reverse in with a 25 bbl Hi-Vis Sweep. Reverse Printed: 9/18/2006 11 :06:50 AM . . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-10 MPH-10 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 9/6/2006 9/13/2006 Spud Date: 8/23/1997 End: 9/13/2006 9/11/2006 09:00 - 12:00 3.00 CLEAN P DECOMP circulate sweep at 4.0 bpm/510 psi back to surface until returns were clean. Returns throughout the clean-out was SB silt and muck. Fluid loss at 4.0 bpm averaged 1.5 bpm. Monitor Well dead. 12:00 - 16:00 4.00 CLEAN P DECOMP Trip-out with 2 7/8" tubing and stand back in Derrick. Rig-up to handle 21/16" Hy-Drill. Finish tripping out and single down CS Hy-Orill in Pipe Shed. 16:00 - 18:00 2.00 CLEAN P DECOMP Clear and clean Rig Floor. Prep for running ESP Completion. 18:00 - 21 :30 3.50 RUNCO RUNCMP PUlMU and service ESP pump. 21 :30 - 00:00 2.50 RUNCO RUNCMP RIH wI 2-7/8" ESP Completion wI Heat Trace. 9/12/2006 00:00 - 06:00 6.00 RUNCO RUNCMP Continue RIH wI 2-718" ESP Completion wI Heat Trace. 06:00 - 06:30 0.50 RUNCO RUNCMP Pre-tour safety meeting and lubricate Rig. 06:30 - 11 :30 5.00 RUNCO RUNCMP RIH with 2 7/8" ESP Completion with Heat Trace. Stopping to test ESP and Heat Trace every 2,000 ft. Pump through at a rate of 1 bpm I 750 psi. 11 :30 - 15:30 RUNCMP Heat Trace failed at approximately 4,000' in the hole. Re-check with two different meters - no joy. Decision made to POH and replace Heat Trace cable. POH with ESP Completion and Heat Trace. 15:30 - 18:00 RUNCMP Change out Heat Trace cable in the Spooling Unit. Pull new Heat Trace cable over the Sheave and attach to the Tubing. Initial test - OK. Pre-tour safety meeting with night crew. 18:00 - 00:00 RUNCMP RIH with 2 7/8" ESP Completion with Heat Trace. Stop every 1,000 ft to check ESP and Heat Trace cables. 9/13/2006 00:00 - 06:00 6.00 RUNCMP Continue RIH wI 2-7/8" ESP Completion wI Heat Trace. Pump through at 1 bpm I 750 psi. 06:00 - 06:30 0.50 RUNCMP Lubricate & service rig. 06:30 - 08:00 1.50 RUNCMP Continue to RIH w/2 7/8" EUE ESP completion wI heat trace. 47K up wt, 37K down wt. 08:00 - 09:00 1.00 RUNCMP P/U landing joint. M/U tubing hanger & install penetrator. Ran a total of (565) 6' flat guards, (11) 4' flat guards, (4) 3' flat guards, (36) La Salle clamps, & (1727) flat bands. 09:00 - 14:00 5.00 RUNCMP PJSM. Attach field connection, splice heat trace, plug in & test heat trace & ESP connections, OK. 14:00 - 15:00 RUNCMP PJSM. Land hanger & RILDs. 15:00 - 15:30 RUNCMP PJSM. Set two way check, unable to test from the bottom due to open perfs & low BHP. Test from the top @ 1500 psi, 5 minutes, charted, OK. 15:30 - 17:30 2.00 BOPSU P RUNCMP PJSM. N/D BOPE. 17:30 - 19:00 1.50 WHSUR P RUNCMP NU Adapter and Production Tree. 19:00 - 20:00 1.00 WHSUR P RUNCMP Test Adapter and Hanger Void seal to 5,000 psi for 15 mins with FMC representative - good. Bleed pressure off. Perform final checks on ESP cable and Heat Trace cable. Final parameters as follows: Heat Trace: phase to phase = 3.9 ohms , phase to ground = 30 Giga ohms. ESP cable: phase to phase = 4.2 ohms, phase to ground = 2 Giga ohms. The pressure at intake = 1,592 psi. The temperature at the intake = 77 degrees. The temperature of the motor = 77 degrees. 20:00 - 21 :00 1.00 WHSUR P RUNCMP PU Lubricator and pull TWC with Well Site Maintenance Technician. Set BPV. Secure the Tree and Cellar. Rig released at 21 :00 hrs on 9/13/2006. Printed: 9/18/2006 11 :06:50 AM KA' STATE OF ALASKA C~'' ALAS ..,,L AND GAS CONSERVATION C ,~,,,vllSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: [] Abandon r"l Suspend [] Operation Shutdown [] Perforate [] Variance [] Othe~ [] Alter Casing [] Repair Well r"l Plug Perforations [] stimulate [] Time Extension Change Out ESP [] Change Approved Program [] Pull Tubing [] Perforate New Pool r-I Re-Enter Suspended Well [] Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) inc. [] Development [] Exploratory 197-149 3. Address: [] Stratigraphic [] Service ,6. APl Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22795-00-00 7. KB Elevation (ft): KBE = 66.00' 9. Well Name and Number: MPH-10 8. Property Designation: 10. Field / Pool(s): ADL 025627 Milne Point Unit / Schrader Bluff I11. Present well condition summary Total depth: measured 6080 feet true vertical 4320 feet Plugs (measured) N/A Effective depth: measured 6021 feet Junk (measured) N/A true vertical 4274 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' Surface Intermediate Production 6032' 7" 6063' 4307' 7240 5410 Liner , Perforation Depth MD (ft): 5580'- 5830' '"' ' Perforation Depth TVD (ft): 3925'- 4123' Tubing Size (size, grade, and measured depth): 2-7/8", 6.5# L-80 5473' Packers and SSSV (type and measured depth): 7" HES Perma Series Packer 5517' 7" HES Perma Series Sump Packer 5701' 12. Stimulation or cement'squeeze summary: N/A ' Intervals treated (measured): Treatment description including volumes used and final pressure: 13. ,,,, Representative Daily Avera~le Production or Injection Data ...... OiI-Bbl Gas-Mcf Water-Bbl Casin,q Pressure Tubing Pressure Prior to well operation: Subsequent to operation: , "~ 4. Attachments: 15. Well Class after proposed work: [] Copies of Logs and Surveys run [] Exploratory [] Development [] Service [] Daily Report of Well Operations 16. Well Status after proposed work: [] Oil [] Gas [] WAG [] GINJ [] WINJ [] WDSPL ~ 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Robert Odenthal, 564-4387 I Printed Name Sondra Stewman Title Technical Assistant ~~ .... Phone 564-4750,~,~ Date ~'~ - / ~'~_.~ So~;rP;rod BY Namo/NUCGb;~750Stewman, BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: MPH-10 'Common Well Name: MPH-10 Spud Date: 8/23/1997 Event Name: RECOMPLETION Start: 8/8/2003 End: 8/14/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/14/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations __ 8/8/2003 16:00 - 17:00 1.00 MOB ~ PRE Held PJSM. Rigged Down. Scoped Down and L / D Derrick. 17:00 - 18:00 1.00 MOB P PRE Broke Apart Rig Modules. Prepared to Move Rig. 18:00 - 20:30 2.50 MOB P PRE Held PJSM w/Truck Drivers and Drilling Crew. Moved Rig from MPJ-05 to MPH-10. Moved and Spotted Sub Over MPH-10. 20:30 - 23:00 2.50 MOB P PRE Spotted Pit Module, Pipe Shed and Camp. Bermed Rig. 23:00 - 00:00 1.00 MOB P PRE Held PJSM. Raised and Scoped Derrick. R / U Derrick and Rig Floor. 8/9/2003 00:00 - 01:00 1.00 KILL P DECOMP R / U Lines to Tree and Wellhead. R / U Tiger Tank and Hardlines. Took on Seawater. Accepted Rig at 0000 hrs 8 / 9 / 2003. 01:00 - 01:30 0.50 KILL P DECOMP Held PJSM. Pressure Tested Hardlines to 3,500 psi, OK. 01:30 - 02:00 0.50 KILL P DECOMP Held PJSM. R / U DSM Lubricator, Pulled BPV, R / D DSM. Tubing Pressure 520 psi, Annulus Pressure 500 psi. 02:00 - 04:30 2.50 KILL P DECOMP Held Pre Spud Meeting, Monitored Well, Tubing 500 psi, Annulus 500 psi. Pumped Down Tubing to Displace Well to 140 deg 8.4 ppg KCL Water. Pump Rate 3 bpm, 530 psi, w/ 200 psi on Annulus - Full Open Choke. Pump Rate Pmp Press Annulus Press Volume 3 bpm 530 psi 200 psi 40 bbls 4 bpm 850 psi 180 psi 70 bbls 4 bpm 930 psi 210 psi 130 bbls 4 bpm 990 psi 250 psi 160 bbls 4 bpm 900 psi 100 psi 192 bbls 4 bpm 840 psi 70 psi 250 bbls 4 bpm 800 psi 70 psi 288 bbls Shut Down Pump. Slight Leak on Choke Line to Gas Buster. Leaked Pint of KCL Water onto Pad. Shut Down Fixed Leak. 04:30 - 05:00 0.50 KILL ~ DECOMP Monitored Well, No Flow, Very Slight Blow on Annulus. 05:00 - 05:30 0.50 KILL ~ DECOMP Pumped Additional 58 bbls, Pump Rate 4 bpm, 700 psi. Full Open Choke, 0 psi on Annulus. Shut Down Pump and Monitored Well. Tubing on Slight Vacuum, Annulus Static. 05:30 - 06:00 0.50 KILL ~ DECOMP Shut In Well and Monitored for Pressure Build Up. 0 psi in 30 Minutes. 06:00 - 07:00 1.00 KILL ~ DECOMP Opened Well and Continued to Monitor. No Flow, Very Slight Blow of Gas from the Annulus. 07:00 - 07:30 0.50 WHSUR P DECOMP Set TWC and Tested to 1,000 psi, OK. 07:30 - 08:30 1.00 WHSUR P DF:COMP Held PJSM. N / D Tree. 08:30 - 10:30 2.00 BOPSUF.P DECOMP Held PJSM. N / U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Blind Rams, Mud Cross, Lower Pipe Rams w/2-7/8" x 5" Variable Rams. 10:30 - 13:30 3.00 BOPSUF:P DECOMP Held PJSM. R / U Test Equipment. Tested BOPE. Tested Lower Rams, Blind Rams, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 2,500 psi High / 250 psi Low. Tested Annular Preventer to 2,500 psi High / 250 psi Low. All Tests Held f/5 Min. All Pressure Tests Held w/No Leaks or Pressure Loss. Performed Accumulator Test. BOP Test Witnessed by AOGCC Rep Chuck Scheve. R / D Test Equipment. 13:30 - 14:00 0.50 BOPSUF P DECOMP Held PJSM. Drained BOP Stack and Blew Down and R / D Lines. 14:00 - 15:00 1.00 WHSUR P DECOMP Held PJSM. R / U DSM Lubricator, Pulled TWC, R / D DSM. . 15:00 - 15:30 0.50 PULL P DECOMP M / U 3-1/2" DP and XO. M / U to Tubing Hanger. M / U Printed: 8/18/2003 9:19:56AM BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: MPH-10 Common Well Name: MPH-10 Spud Date: 8/23/1997 Event Name: RECOMPLETION Start: 8/8/2003 End: 8/14/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/14/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From- To Hours Task Code NPT Phase Description of Operations __ 8/9/2003 15:00 - 15:30 0.50 PULL P DECOMP Circulating Head and Line. 15:30 - 17:00 1.50 PULL P DECOMP Displaced Well to 8.7 ppg Brine. Pump Rate 4 bpm, 850 psi. 17:00 - 17:30 0.50 PULL P DECOMP BOLDS. Pulled Tubing Hanger Offseat, P / U Weight 47,000#, Pulled Hanger to Rig Floor, String Weight Up 39,000#. 17:30 - 18:30 1.00 PULL P DECOMP Monitored Well, Tubing Static, Annulus had Slight Flow of Crude Oil Over Bell Nipple. 18:30 - 19:00 0.50 PULL P DECOMP Circulated Bottoms Up, Pump Rate 3 bpm, 400 psi. Rolling Gas to Surface at Bottoms Up, Circulated Out Gas. Weighted Up Brine to 9.0 ppg. 19:00 - 20:30 1.50 PULL P DECOMP Displaced Well to 9.0 ppg Brine, Pump Rate 3 bpm, 400 psi. 20:30 - 21:00 0.50 PULL P DECOMP Monitored Well, Slight Flow of Crude Oil and Brine Over Bell Nipple. 21:00 - 22:00 1.00 PULL P DECOMP Shut In Well and Monitored for Pressure Build Up. 0 psi in 1 hour. 22:00 - 22:30 0.50 PULL ~ DECOMP Bullheaded 15 bbls Downhole to Cover Wellbore from 5,430' to 5,800' w/9.0 ppg Brine. 2 bpm, 700 psi. Bled Down Pressure and Opened Well. Slight Flow from Annulus. 22:30 - 23:00 0.50 PULL = DECOMP Mixed Salt and Weighted Up 180 bbls of Brine to 9.5 ppg. Well Shut In, 0 psi. Waited on More Salt to Weight Up Entire System. 23:00 - 23:30 0.50 PULL = DECOMP Pumped 180 bbls of 9.5 ppg Brine, 5 bpm, 1,050 psi. Shut Down Pump and Monitored Well, Annulus Static. 23:30 - 00:00 0.50 PULL = 'DECOMP Monitored Well While Weighting Up Brine to 9.5 ppg. Annulus Static. 8/10/2003 00:00 - 00:30 0.50 PULL ~ DECOMP Monitored Well, Well Static. Weighted Up System to 9.5 ppg Brine. 00:30 - 01:30 1.00 PULL ~ DECOMP Circulated Around 9.5 ppg Brine, Pump Rate 5 bpm, 1,100 psi. Circulated Entire System Around. 01:30 - 02:30 1.00 PULL ~ DECOMP Shut Down Pump and Monitored Well. Annulus Static, Tubing : had Slight Flow. 02:30 - 03:30 1.00 PULL P DECOMP 'Shut In Well and Bullheaded 32 bbls of 9.5 ppg Brine Down Wellbore to Cover 5,430' to 5,800'. 2 bpm, 900 psi. 03:30 - 04:00 0.50 PULL P DECOMP Shut Down Pump and Bled Off Pressure. Well Flowed Back 11 bbls and Died. Annulus Static, Tubing Static. 04:00 - 04:30 0.50 PULL P DECOMP Broke Out and L / D Landing Joint, XO and Tubing Hanger. 04:30 - 10:00 5.50 PULL P DECOMP POOH w/2-7/8" Tubing to 2,890'. Spooled Up ESP and Heat Trace Cable. 10:00- 11:00 1.00 PULL P DECOMP Terminated Heat Trace Cable. Cleaned Up Rig Floor. 11:00 - 13:30 2.50 PULL P DECOMP POOH w/2 7/8" Tubing, Spooled Up ESP Cable. Racked Back 57 Stands in Derrick. L / D 6 Jts. POOH w/177 Joints 2-7/8" 6.5# 8rd EUE Tubing. Calculated Fill = 13.75 bbls, Actual Fill 20.0 bbls. 13:30 - 14:00 0.50 PULL . P DECOMP Cleared Protectors and Flat Guards From Rig Floor. Pulled ESP Cable Through Sheave. 14:00 - 15:30 1.50 PULL ~P DECOMP Inspected, Broke Out and L / D ESP Assembly. Top Pump Section Locked Up w/Broken Shaft. 15:30 - 16:00 0.50 PULL P DECOMP R / D Elephant Hose. R / D 2-7/8" Handling Equipment. 16:00 - 17:30 1.50 PULL P DECOMP Cleared and Cleaned Rig Floor. 17:30 - 18:30 1.00 CLEAN P DECOMP R/U 3-1/2" DP Handling Equipment. 18:30 - 19:00 0.50 CLEAN P DECOMP Held PJSM. M / U Clean Out BHA: 5.6" Flat Bottom Mill - Double Pin Sub - 2 x Boot Baskets - Double Box XO - 3 x 4-3/4" DC - Oil Jars. BHA Total Length: 116.41' 19:00 - 00:00 5.00 CLEAN P DECOMP RIH w/Clean Out BHA on 3-1/2" DP. P / U DP from Pipe Shed. Printed: 8/18/2003 9:19:56AM BP EXPLORATION Page 3 of 5 Operations Summa Report 'Legal Well Name: MPH-10 Common Well Name: MPH-10 Spud Date: 8/23/1997 Event Name: RECOMPLETION Start: 8/8/2003 End: 8/14/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/14/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations -- 8/11/2003 00:00 - 00:30 0.50 CLEAN P DECOMP RIH w/BHA on 3-1/2" DP to 5,500'. Drill String Took Weight at 5,500'. 00:30 - 01:30 1.00 CLEAN P DECOMP M / U Circulating Head and Line. Reverse Circulated Down from 5,500' to 5,550'. Pump Rate 5 bpm, 1,050 psi. Tagged Up on Hard Spot at 5,550'. 01:30 - 06:00 4.50 CLEAN P DECOMP Washed Down Full Joint Long Way, Closed Annular Then Reverse Circulated Volume Pumped Long Way Plus Drill Pipe Volume from 5,550' to 5,705'. Pump Rate Long Way 4 bpm, 700 psi, Pump Rate Reversing 5 bpm, 1,050 psi. 06:00 - 07:30 1.50 CLEAN ~ DECOMP Circulated Out Gas in Wellbore. Pump Rate 4 bpm, 600 psi. Circulated 2 x Hole Volume. 07:30 - 11:00 3.50 CLEAN ~ DECOMP Washed Down to Clean Formation Sand Out of Wellbore from 5,705' to 5,830'. Pump Rate 6 bpm, 1,400 psi. Circulated the Long Way to Avoid Charging Up the Formation. Shut Down Pump and Monitored Well. Tubing on Vacuum, Annulus Very Slight Flow. 11:00 - 12:30 1.50 CLEAN ~ DECOMP Washed Down Circulating the Long Way to Clean Formation Sand Out of Wellbore from 5,830' to 5,965'. Pump Rate 6 bpm, 1,400 psi. Tagged Up Hard at 5,965'. 12:30 - 14:00 1.50 CLEAN ~ DF:COMP Closed Annular and Lined Up to Reverse Circulate. Pumped and Reverse Circulated Around 30 bbls Hi-Vis Sweep. Pump Rate 4 bpm, 600 psi. ' 14:00 - 16:00 2.00 CLEAN ~ . DECOMP Pumped and Reverse Circulated Around 30 bbl Hi-Vis Sweep Followed by Clean 9.8 ppg Brine. Displaced Wellbore to 9.8 ppg Brine. 16:00 ~ 17:30 1.50 CLEAN P DECOMP Monitored Well, Well Static. Cleaned Pit #3, Offloaded 9.8 ppg into Pits. 17:30 - 19:00 1.50, CLEAN P DECOMP Held PJSM. POOH w/3-1/2" DP. Calculated Fill -- 34 bbls, Actual Fill = 37 bbls. 19:00 - 20:00 1.00 CLEAN ~P DECOMP Broke Out and L / D BHA. 20:00 - 20:30 0.50 CLEAN P DECOMP Cleared and Cleaned Rig Floor. 20:30 - 21:00 0.50 PERF P COMP Held PJSM w/Drilling Supervisor, Tour Pusher, Schlumberger Crew and Drilling Crew. 21:00 - 22:00 1.00 PERF P COMP R / U 7" Lubricator w/7" Otis Connection in Annular w/40' Schlumberger Lubricator w/Packoff. Tested Lubricator Against Top of Blind Rams to 500 psi f/10 Minutes, OK. 22:00 - 22:30 0.50 PERF P COMP Schlumberger M / U GR-CCL 20' - 4-1/2" HSD Perforating Gun w/4505 Power jet HMX 5 SPF 72 deg Phasing. 22:30 - 23:00 0.50 PERF P COMP RIH w/Perforating Assembly on E-Line to 5,947', E-Line TD. 23:00 - 23:30 0.50 PERF P COMP Logged Up from 5,947' to 5,350', Correlated and Tied into Sperry-Sun MWD Log, 28-August-1997. Relogged Interval to Confirm Correlation. Set On Depth, CCL at 5,633.8' / CCL to Top Shot Stand Off 6.2' - Top Shot at 5,640' Bottom Shot 5,660'. Fired Gun, Observed Good Surface Indication of Gun Firing. Monitored Well, Well on Vacuum. 23:30 - 00:00 0.50 PERF P COMP POOH w/Schlumberger, All Shots Fired. R / D 20' Gun. 8/12/2003 00:00 - 00:30 0.50 PERF P COMP Schlumberger M / U GR-CCL 7' - 4-1/2" HSD Perforating Gun w/4505 Power jet HMX 5 SPF 72 deg Phasing. 00:30 - 01:00 0.50 PERF P COMP RIH w/Perforating Assembly on E-Line to 5,800'. 01:00 - 01:30 0.50 PERF P COMP Logged Up from 5,800' to 5,400', Correlated and Tied into Previous Run. Relogged Interval to Confirm Correlation. Set On Printed: 8/18/2003 9:19:56 AM BP EXPLORATION Page 4 of 5 Operations Summar Report ,Legal Well Name: MPH-10 Common Well Name: MPH-10 Spud Date: 8/23/1997 Event Name: RECOMPLETION Start: 8/8/2003 End: 8/14/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/14/2003 Rig Name: NAB©RS 4ES Rig Number: 4ES Date From-To Hours Task Code NPT Phase Description of Operations -- 8/12/2003 01:00 - 01:30 0.50 PERF P COMP Depth, CCL at 5,608.1' / CCL to Top Shot Stand Off 8.9' - Top Shot at 5,617' Bottom Shot 5,624'. Fired Gun, Observed Good Surface Indication of Gun Firing. Monitored Well, Well on Vacuum. Filled Hole, Took 8 bbls to Fill. 01:30 - 02:00 0.50 PERF P COMP POOH w/Perforating Assembly. All Shots Fired. R / D GR-CCL 7' Perforating Gun. 02:00 - 03:00 1.00 EVAL ~ COMP M / U 5.75" Gauge Ring / Junk Basket to E-Line. 03:00 - 04:00 1.00 EVAL ~ COMP RIH w/GR / JB on E-Line to 5,950' E-Line Measurement. POOH w/No Problems. JB Empty. R / D GR / JB. 04:00 - 04:30 0.50 RUNCOr~ COMP Held PJSM. M / U Halliburton 7" Perma-Series Sump Packer to E-Line Setting Tool. 04:30 - 05:30 1.00 RUNCOI~ COMP RIH w/Sump Packer on E-Line. Unable to get through Tbg Patch at 2,082-ft. Made several attempts Tbg Patch ID -- 5.81". Pkr OD 5.750". 05:30 - 06:00 0.50 RUNCOI~ COMP POOH to inspect Pkr. 06:00 - 06:30 0.50 RUNCOr~ COMP Packer had a very slight mark on leading beavled edge, other wise OK. Remove Roller Stem from tool string to possibly change angle od packer entry into Patch. Hole angle at Patch is 33 degs. 06:30 - 07:30 1.00 RUNCOI~ COMP . Run Packer back in hole for second attempt. Tagged again at the same place. Unable to work thru. POOH. 07:30 - 08:00 0.50' RUNCO~' COMP Rig down Schlumberger. 08:00 - 08:30 0.50 RUNCO~P COMP Clear and clean Rig Floor. 08:30 - 09:00 0.50 RUNCO~P COMP Re-configure running tool to be run on Drill Pipe. 09:00 - 13:00 4.00 RUNCO~P COMP RIH with Halliburton Perma-series Sump Packer and 3 1/2" Drill Pipe. Saw a "bobble" when entering the top of the Casing Patch. Continue thru Patch with no problems. Continue RIH with Drill Pipe to 5,707-ft. Pull up hole and position Packer top at 5,701-ft. okb. Center of Packer Element at 5,703-ft okb. 13:00 - 14:00 1.00 RUNCOIt~ COMP Drop 3/4" Delrin Ball. Bring pump on line at 0.5 bpm to help ball get on seat. Ball on seat increase pressure to 500 psi. Hold for 5 min. Increase pressure to 2200 psi. Hold for 10 min. Pull string weight up to 105K and shear off of Packer. Packer set at 5,701-ft kb. Pressure up on Drill Pipe to 3300 psi and shear ball seat. 14:00 - 14:30 0.50 RUNCOI~F' COMP Circulate Drill Pipe volume to balance well. 14:30 - 17:00 2.50 RUNCOI~' COMP POOH. LD 8 Jts of Drill Pipe. Stand 57 stands in Derrick. 17:00 - 17:30 0.50 RUNCOr~I:) COMP Lay down running Tool. 17:30 - 19:30 2.00 RUNCOI~I~ COMP R/U screen running equipment. Monitor well. Hold PJSM. 19:30 - 20:30 1.00 RUNCOI~I~ COMP P/U screen & packer assy. RIH w/same. C/O handling equip for 3 1/2" DP. 20:30 - 21:00 0.50 RUNCOr~I:) COMP Adjust brakes on drawworks. 21:00 - 23:30 2.50 RUNCOr~I:) COMP RIH w/screen assy on 3 1/2" DP & space out. Record P/U 55K & S/O 70K.Sting into sump packer @ 5,701'. Slack off w/ 5K, then P/U to verify sting in. Note, did not have any problem going thru csg patch w/screen assy. 23:30 - 00:00 0.50 RUNCOi~!:) COMP Drop ball & allow to fall for setting packer. 8/13/2003 00:00 - 02:00 2.00 RUNCOI~!~ COMP Roll pump @ 1BPM until ball hit seat. Pressure up to 500 psi & check for leaks. Increase pressure to 2200 psi & set packer. Hold for 10 min. Bled off DP pressure to 0 psi. P/U w/25K over string weight & close pipe rams. Pressure up annulus to 2500 psi & hold for 30 min. Test, OK. Bled off annulus. Pressure up DP to 2500 psi & P/U to to 95K, Sheared free from packer. P/U Printed: 8/18/2003 9:19:56AM BP EXPLORATION Page 5 of 5 Operations Summa Report Legal Well Name: MPH-10 .Common Well Name: MPH-10 Spud Date: 8/23/1997 Event Name: RECOMPLETION Start: 8/8/2003 End: 8/14/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/14/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 8/13/2003 00:00 - 02:00 2.00 RUNCOI~F' COMP additional 10' & shear ball seat w/3800 psi. Charted entire set & testing procedure. 02:00 - 03:00 1.00 RUNCOI~ COMP Circulate & clean up well. 5 BPM @ 1100 psi. Had small amount of oil to surface w/gas bubbles. Monitor well, well dead. Lost 4 Bbls of 9.8 ppg fluid in 1 hr while circulating. 03:00 - 06:00 3.00 RUNCOI~ COMP Start POOH. Lay down 3 1/2" Drill Pipe in Pipe Shed. Crew change. 06:00 - 06:30 0.50 RUNCOr~ COMP PJSM. Lub Rig. 06:30 - 08:00 1.50 RUNCOI~ COMP Finish laying down Drill Pipe. 08:00 - 08:30 0.50 RUNCOI~ COMP Lay down Running Tools. Pull and lay down Wear Bushing. Rig down 3 1/2" handling equipment. 08:30 - 09:00 0.50 RUNCOI~ COMP Rig up 2 7/8" handling equipment. 09:00 - 12:00 3.00 RUNCOI~ COMP Load ESP Assembly in Pipe Shed. Hold PJSM with Centriiift 'Service Hand and Rig Crew. Pick-up and service ESP Assy. 12:00 - 13:00 1.00 RUNCO~ COMP Pull ESP and Heat Trace cables over sheave. Attach and secure ESP cable to Motor. Test. 13:00 - 00:00 11.00 RUNCO~/P COMP Start TIH with ESP Completion as follows: 5.50" Centrilizer, Pump Mate, Motor, Tandem Seal Section, Intake, Pump, 2 7/8" Pup Jt, 1 Jt 2 7/8" Tbg, XN-Nipple, 4 Jts 2 7/8" Tbg, 2 718" x 1" GLM Assembly, 168 Jts 2 7/8" Tbg, 2 7/8" x 1" GLM Assembly, 4 Jts 2 7/8" Tbg, 2 7/8" Pup Jt, 2 7/8" Pup Jt, and Tubing Hanger. Installed heat trace from 3450' to surface. Ran in hole w/50 of 59 stands @ midnight. 8/14/2003 00:00 - 03:00 3.00 RUNCOI~!= COMP Finish running in hole w/2 7/8" ESP Completion. M/U hanger & space out. 03:00 - 06:00 3.00 RUNCOI~F~ COMP Clear & clean floor. Splice ESP cable & heat trace connections. Crew change. 06:00 - 08:00 2.00 RUNCOI~ COMP PJSM. Completed Heat Trace cable splice. Test both the ESP and Heat Trace cable. Both good. Secure both cables. 08:00 - 08:30 0.50 RUNCOr~ COMP Land tubing Hanger. PUW = 50K. SOW -- 37K. RILDS. 08:30 - 09:00 0.50 RUNCOI~ COMP Set and test TWC. Drain BOP stack and blow down lines. 09:00 - 10:30 1.50 BOPSUI; ~ COMP Nipple down BOPE. 10:30 - 11:30 1.00 WHSUR ~ COMP Nipple up Production Tree with new Adaptor Flange. 11:30 - 12:00 0.50 WHSUR 3 COMP Test Adaptor Flange and Tree to 5,000 psi. Good test. Final ESP and Heat Trace Cable checked good. 12:00 - 13:00 1.00 WHSUR 3 COMP Pick-up lubricator. Pull TWC. Set BPV. Lay down lubricator. Secure Tree and cellar. Release Rig. Printed: 8/18/2003 9:19:56AM Well Compliance Report File on Left side of folder 197-149-0 MILNE POINT UNIT SB Roll #1: Start: Stop Roll #2: MD 06080 TVD 04320 Completion Date: H-10 50- 029-22795-00 Start Stop ~/5/98 Completed Status: 1-OIL BP EXPLORATION (A~ASKA) INC Current: Name Interval D 8734 ~ SPERRY MPT/GR/EWR4 OH L DGR/EWR4-MD b,,,,~AL 4634-6080 OH L DGR/EWR4-TVD ~,l~ 3306-4320 OH L GR/CCL -~AL 5300-5957 ~¢/~u.~k C[~ CH 5 L PERF ,.F4~AL 5900 g ~ I~'4'~ ~? ~ CH 5 L PEP~ .~ 5700-57400Zct ~.~ ?~' cH 5 L PEP. F ~ s378-~620 ~tgD~ c. 5 R M~ SRVY ~PE~Y 0-6080. OH Daily Well Ops ~1~'1~ ~, ~ " ~ ~[~/~. Was the well cored? yes ~ -- - Comments: Sent Received 11/18/98 11/18/98 12/2/98 12/2/98 12/2/98 12/2/98 10/22/98 10/22/98 9/25/98 10/22/98 9/25/98 10/22/98 9/25/98 10/22/98 12/29/98 12/30/98 T/C/D Are Dry Ditch Samples Required? yes (~____~And Receive~?'D,t~fl~-~. Analysis Description Receive,~~- Sample~%rt-g ' ' Wednesday, November 08, 2000 Page 1 of 1 ¢--" STATE OF ALASKA -~ ALASKa. _iL AND GAS CONSERVATION COMl. REPORT OF SUNDRY WELL OPERATIONS SION 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP ,,, 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 66.0' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit.) P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2834' NSL, 4167' WEL, SEC. 34, T13N, R10E, UM MPH-10 9. Permit Number/ Approval No. At top of productive interval '"'--, 197-149 441' SNL, 4142' WEL, SEC. 02, T12N, R10E, UM 10. APl Number At effective depth ~ 50-029-22795-00 716' SNL, 4140' WEL, SEC. 02, T12N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 752' SNL, 4141' WEL, SEC. 02, T12N, R10E, UM ..... 12. Present well condition summary Total depth: measured 6080 feet Plugs (measured) true vertical 4320 feet Effective depth: measured 6021 feet Junk (measured) true vertical 4274 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 80' 80' Surface 6032' 7" 1097 sx PF 'E', 50 sx PF 'C', 130 sx 'G' 6063' 4307' Intermediate Production Liner Perforation depth: measured 5580' - 5600', 5734' - 5754', 5810' - 5830' true vertical 3925' - 3941' 4047' - 4063', 4107' - 4123' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 5476' Anc,h0~'age Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) ~iI [~i: i (~'~ i [~I .~. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble Title TechnicalAssistantlll Date 02' · : : Prepared By Name/Number: Terrie Hubble, 564-4628 T Form 10-404 Rev. 06/15/88 Submit In Duplicate Progress Report Facility M Pt H Pad Well MPH-10 Page 1 Rig Nabors 4ES Date 28 February 00 Date/Time 19 Feb 00 06:00-12:00 06:00-12:00 12:00 12:00-20:00 12:00-20:00 20:00 20:00-21:00 20:00-21:00 21:00 21:00-22:00 21:00-22:00 22:00 22:00-06:00 22:00-01:00 20 Feb 00 01:00 01:00-05:00 05:00 05:00-06:00 06:00 06:00-13:30 06:00-13:30 13:30 13:30-15:00 13:30-15:00 15:00 15:00-17:00 15:00-17:00 17:00 17:00-19:30 17:00-19:30 19:30 19:30-21:00 19:30-20:00 20:00 20:00-21:00 21:00 21:00-06:00 21:00-06:00 Duration 6hr 6 hr 8hr 8hr 1 hr lhr lhr lhr 8hr 3 hr 4 hr lhr 7-1/2 hr 7-1/2 hr 1-1/2 hr 1-1/2 hr 2hr 2hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1 hr 9hr 9hr Activity Move rig Rig moved 100.00 % At well location - Slot Derrick management Rigged up Additional services rig lines to kill well & set tiger tank & take on sea h20 (WEATHER 38 MPH WIND & -78 DEG. WIND CHILL.) Equipment work completed Wellhead work Removed Hanger plug Equipment work completed Test well control equipment Tested High pressure lines TEST LINES TO 2500 PSI. Pressure test completed successfully - 2500.000 psi Well control Circulated closed in well at 5355.0 ft DISPLACE WELL BORE FLUIDS WITH SEA 820 & WELL FLOWED SHUT IN TBG=70-PSI. ANN= 100 PSI. Hole displaced with Seawater - 100.00 % displaced Circulated closed in well at 5355.0 ft RAISE WT TO 8.9 PPG. & MONITOR & TBG. STATIC ANNULUS FLOWING. Influx Out of hole Circulated closed in well at 5355.0 ft RAISE FLUID WT TO 9.0 PPG. Stopped · To hold safety meeting Well control (cont...) Circulated closed in well at 5533.0 ft CIRC WELL BORE 4-TIMES TO GET WT TO 9.6 TO GET Wt BORE TO BECOME STATIC. USED A RATE OF 4-BPM Influx Out of hole Wellhead work Removed Xmas tree INSTALL TWC & REMOVE TREE. Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Equipment work completed Removed Tubing hanger MAKE UP LANDING JT. & PULL HANGER TO FLOOR & CHECK ESP EQUIP & HEATER. Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 0.0 ft POOH & LAY DN ESP EQUIPMENT. (LOST 1-FLAT GUARE LL & AC Progress Report Facility M Pt H Pad Well MPH- 10 Page 2 Rig Nabors 4ES Date 28 February 00 Date/Time 21Feb 00 06:00 06:00-14:00 06:00-10:30 10:30 10:30-14:00 14:00 14:00-06:00 14:00-04:00 22Feb 00 04:00 04:00-05:00 05:00 05:00-06:00 06:00 06:00-12:30 06:00-09:00 09:00 09:00-12:30 12:30 12:30-06:00 12:30-14:30 14:30 14:30-17:00 17:00 17:00-06:00 23 Feb 00 06:00 06:00-13:00 06:00-07:00 07:00 07:00-12:00 12:00 12:00-13:00 Duration 8hr 4-1/2 hr 3-1/2 hr 16hr 14hr 1 hr lhr 6-1/2 hr 3 hr 3-1/2 hr 17-1/2 hr 2hr 2-1/2 hr 13hr 7hr lhr 5hr lhr Activity SAND.S Completed operations 2-7/8in. Drillpipe workstring run Ran Tubing in stands to 5717.0 ft rih with tbg. & 5-7/16" mill for clean out tag @ 5700' & push & wash to 5717' unable to make forward progress with out rotation @ 5717' Observed 15000.00 klb resistance Pulled Tubing in stands to 0.0 ft pooh & stand tbg. in derrick. Completed operations 3-1/2in. Drillpipe workstring run Singled in drill pipe to 5947.0 ft rih with 5-7/16" mill & two junk baskets & tag@ 5665' & push to 5699' & begin rotating & washing down & reversing clean after every kelly down until reach a clean out td of 5947' On bottom Reverse circulated at 5947.0 ft reverse circ well bore clean. Hole displaced with Brine - 125.00 % displaced Laid down 150.0 ft of 3-1/2in OD drill pipe Stopped: To hold safety meeting 3-1/2in. Drillpipe workstring run (cont...) Circulated at 4980.0 ft circ. & raise brine wt. to 9.9 Ppg. to balance well & monitor same. Obtained req. fluid properties - 105.00 %, hole vol. Laid down 4980.0 ft of 3-1/2in OD drill pipe recovered a few bands material in baskets. 177 joints laid out Run Single completion, 2-7/8in O.D. Functioned ESP mu esp and find that protectalizers are not correct~:~:'~~,i:~"..? and modify same. ESP failed - Change operation ' ~ ~''~ ~-, ~ ~ Functioned ESP modify protectalizers for esp assy. [~'i~'Ct ~ 7 ~70: Equipment work completed Ran Tubing in stands to 5457.0 ft ".~,~Sk:,"- Run in hole with esp assy. installing heat trace :,, .... o .-'~:,.. tape. (3000' tape) .... u~50 Completed run with ESP to 5457.0 ft Run Single completion, 2-7/8in O.D. (cont...) Installed Tubing hanger mu hanger & and space out for heat trace tape. Equipment work completed Installed Accessories hook heat trace to hanger & mu eft connector & mu to hanger. Equipment work completed Installed Tubing hanger install & set twc. & rilds. Facility M Pt H Pad Progress Report Well MPH- 10 Page Rig Nabors 4ES Date 3 28 February 00 Date/Time 13:00 13:00-15:00 13:00-15:00 15:00 15:00-16:30 15:00-16:30 16:30 16:30-17:30 16:30-17:30 17:30 17:30-06:00 17:30-18:00 18:00 Duration 2hr 2hr 1-1/2 hr 1-1/2 hr lhr lhr 12-1/2 hr 1/2hr Activity Tie-down bolts energised Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed Test well control equipment Tested Xmas tree Pressure test completed successfully - 5000.000 psi Wellhead work Installed Hanger plug pull twc & install bpv Equipment work completed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-149 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22795 4. Location of well at surface .~ '::~ :'~ ~'~'!'~!~'~ ~i,,, i~.'?i,"~.'_~i'.''' 9. Unit or Lease Name 2834' NSL' 4167' WEL' SEC' 34' T13N' R10E' UM' ~/~/'?~-'~ i-~::J~l' ~, -- ! ~'.,~~I1 Milne Point Unit At top of productive interval .- ~ , 10. Well Number ' ' "- .... ::- .' MPH-10 441 SNL, 4141 WEL, SEC. 3, T12N, R10E, UM .',.,,,. ~-. At total depth ~ ~ .... '::i:?~"'"'~'~ 11 Field and Pool . .. : . ~ ~-'....,~"'~-~ ~.~.~. ~ · 752' SNL, 4140' WEL, SEC. 3, T12N, R10E, UM Milne Point Unit/Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE: 66.0', ADL025627 12. Date Spudded8/23/97 I 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Abandl15' Water depth' if °ffsh°re 16' N°' °f C°mpleti°ns8/27/97 9/5/98 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVS)119. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 6080' 4320 FTI 6021' 4274 FTI []Yes [] NoI N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR/CCL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 33' 80' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 31' 6063' 8-1/2" 1097sxPF'E',50sxPF'C', 130sx'G' j~ ~'f",' ,', 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD ".i~!:;k,:~ Oil ,?., r~s ~.,,,,~, r Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SE~'~ 4-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 5473' None MD TVD MD TVD , 5810' - 5830' 4107' - 4123' 26. AO~D, FRACTURE, CEMENT SQUEEZE, ETC. 5734' - 5754' 4047' - 4063' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 70 bbls Diesel 5580' - 5600' 3925' - 3941' SEE ATTACHED FRAC SUMMARY 27. PRODUCTION TESTORiG, ,^, Date First Production I Method of Operation (Flowing, gas lift, etc.) I I ~l ~-~ L September 12, 1998 t Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCr WATER-DEL CHOKE SIZE I GAs-OIL RATIO iTEST PERIOD I Flow Tubing Casing Pressure :CALCULATED OIL-DEL GAS-MCr WATER-BEE OIL GRAVITY-APl (CORR) Press. i24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Schrader Bluff "F1" 5571' 3918' Schrader Bluff "D3" 5732' 4045' Schrader Bluff "B" 5806' 4104' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby cer~ff)y th~a'j~th~,,f~rego, i~g/~ true and correct~:o the best of my knowledge //_ Signed Charles R. Mallary .,~ Title Drillin9 Superintendent Date . .. MPH-10 ~ /97-149 Prepared By Name/Number: Carol Withey, 564-4114 Well Number V Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on thiS form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 WELL NAMIE: IVlPH-IO Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) 581 O' - 5830' 5734'-5754' 5580'-5600' Amount & Kind of Material Used 123200# Proplock 16/20 Carbolite, 120530# behind pipe, 2670# in casing 124604# Proplock 16/20 Carbolite, 119459# behind pipe, 5154# in casing 80478# Proplock 16/20 precoated proppant with 15% acid, 79567# behind pipe Facility Date/Time 23 Aug 97 24 Aug 97 25 Aug 97 26 Aug 97 27 Aug 97 28 Aug 97 M Pt H Pad Progress Report Well MPH- 10 _ abors Page Date O1:01-02:00 02:00-06:00 06:00-09:00 09:00-13:00 13:00-19:00 19:00-19:30 19:30-20:00 20:00-22:00 22:00-06:00 06:00-16:00 16:00-16:30 16:30-17:00 17:00-18:30 18:30-19:30 19:30-00:30 00:30-01:30 01:30-04:00 04:00-05:30 05:30-06:00 06:00-15:00 15:00-16:30 16:30-21:00 21:00-22:00 22:00-00:00 00:00-00:30 00:30-01:30 06:00-06:30 06:30-16:00 16:00-17:30 17:30-19:30 19:30-20:30 20:30-21:30 21:30-03:30 03:30-05:00 05:00-06:00 06:00-07:30 07:30-08:00 08:00-09:00 09:00-11:00 11:00-13:00 13:00-15:45 15:45-18:30 18:30-19:00 19:00-19:30 19:30-02:00 02:00-04:15 04:15-05:00 05:00-06:00 06:00-08:15 08:15-09:30 09:30-10:15 10:15-11:30 11:30-13:30 13:30-16:00 Duration 3/4 hr 4hr 3hr 4hr 6hr 1/2hr 1/2 hr 2hr 8hr 10hr 1/2 hr 1/2 hr 1-1/2 hr lhr 5hr lhr 2-1/2 hr 1-1/2 hr 1/2 hr 9hr 1-1/2 hr 4-1/2 hr lhr 2hr 1/2hr lhr 1/2hr 9-1/2 hr 1-1/2 hr 2hr lhr lhr 6hr 1-1/2 hr lhr 1-1/2 hr 1/2 hr lhr 2hr 2hr 2-3/4 hr 2-3/4 hr 1/2 hr 1/2 hr 6-1/2 hr 2-1/4 hr 3/4 hr lhr 2-1/4 hr 1-1/4 hr 3/4 hr 1-1/4 hr 2hr 2-1/2 hr Activity Rig moved 1.00 % Rig moved 30.00 % Rig moved 60.00 % Rig moved 100.00 % Rigged up Divertor Tested Divertor Held safety meeting Made up BHA no. 1 Drilled to 1185.0 ft Drilled to 2562.0 ft Circulated at 2562.0 ft Pulled out of hole to 908.0 ft Serviced Top drive R.I.H. to 2562.0 ft Drilled to 3491.0 ft Circulated at 3491.0 ft Pulled out of hole to 1730.0 ft R.I.H. to 3491.0 ft Drilled to 3587.0 ft Drilled to 4637.0 ft Circulated at 4637.0 ft Pulled out of hole to 908.0 ft Pulled BHA Made up BHA no. 2 Serviced Top drive Serviced Block line R.I.H. to 4637.0 ft Drilled to 5498.0 ft Circulated at 5498.0 ft Pulled out of hole to 2940.0 ft Serviced Top drive R.I.H. to 5498.0 ft Drilled to 6080.0 ft Circulated at 6080.0 ft Pulled out of hole to 4778.0 ft Pulled out of hole to 915.0 ft Pulled BHA Serviced Top drive R.I.H. to 6080.0 ft Circulated at 6080.0 ft Pulled out of hole to 915.0 ft Pulled BHA Installed Casing handling equipment Held safety meeting Ran Casing to 6063.0 ft (7in OD) Circulated at 6063.0 ft Mixed and pumped slurry - 143.000 bbl Displaced slurry - 229.000 bbl Circulated at 2093.0 ft Mixed and pumped slurry - 336.000 bbl Displaced slurry - 80.000 bbl Cleared Flowline Rigged down Casing handling equipment Rigged down Divertor 1 24 December 98 Facility M Pt H Pad Progress Report Well MPH- 10 Rig Nabors~*S Page Date 2 24 December 98 Date/Time 16:00-17:00 17:00-19:30 19:30-22:00 Duration lhr 2-1/2 hr 2-1/2 hr Activity Installed Casing head Installed Tubing hanger Installed Xmas tree Facility Date/Time 22 Aug 98 23 Aug 98 24 Aug 98 25 Aug 98 M Pt H Pad Progress Report Well MPH- 10 Rig Nabors 4ES Page Date 23:00-00:00 00:00-04:00 04:00-05:00 05:00-05:30 05:30-05:45 05:45-06:00 06:00-06:15 06:15-07:00 07:00-09:00 09:00-09:15 09:15-10:00 10:00-12:30 12:30-13:00 13:00-16:00 16:00-16:15 16:15-16:30 16:30-17:30 17:30-18:00 18:00-18:15 18:15-18:30 18:30-19:00 19:00-20:30 20:30-21:30 21:30-22:30 22:30-00:30 00:30-01:00 01:00-01:30 01:30-02:00 02:00-02:30 02:30-03:00 03:00-04:00 04:00-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-13:00 13:00-15:00 15:00-15:30 15:30-16:00 16:00-18:00 18:00-18:15 18:15-20:00 20:00-21:30 21:30-22:00 22:00-22:45 22:45-23:30 23:30-00:00 00:00-01:00 01:00-01:30 01:30-01:45 01:45-02:15 02:15-02:45 02:45-04:00 04:00-04:15 Duration lhr 4hr lhr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 3/4 hr 2hr 1/4 hr 3/4 hr 2-1/2 hr 1/2hr 3hr 1/4 hr 1/4 hr lhr 1/2hr 1/4 hr 1/4hr 1/2 hr 1-1/2 hr lhr lhr 2hr 1/2hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 2hr 1/4 hr 1/4 hr lhr 5-1/2 hr 2hr 1/2 hr 1/2hr 2hr 1/4 hr 1-3/4 hr 1-1/2 hr 1/2 hr 3/4 hr 3/4 hr 1/2hr lhr 1/2 hr 1/4 hr 1/2 hr 1/2hr 1-1/4 hr 1/4 hr Activity Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Drillfloor / Derrick Monitor wellbore pressures Removed Hanger plug Installed Hanger plug Held safety meeting Removed Xmas tree Installed BOP stack Retrieved Hanger plug Retrieved Tubing hanger Installed Kelly Installed BOP test plug assembly Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Made up BHA no. 1 Singled in drill pipe to 353.0 ft Held safety meeting Singled in drill pipe to 470.0 ft Circulated at 470.0 ft Singled in drill pipe to 2071.0 ft Circulated at 2058.0 ft Tested Kelly Drilled installed equipment - DV collar Circulated at 2150.0 ft Tested DV collar - Via annulus and string Pulled out of hole to 290.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 2150.0 ft Singled in drill pipe to 3307.0 ft Held safety meeting Serviced Drillfloor / Derrick Singled in drill pipe to 5971.0 ft Reverse circulated at 5971.0 ft Pulled out of hole to 290.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 5971.0 ft Held safety meeting Reverse circulated at 5960.0 ft Pulled out of hole to 293.0 ft Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Ran Drillpipe in stands to 2175.0 ft Circulated at 2175.0 ft Pulled Drillpipe in stands to 1987.0 ft Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations 1 24 December 98 Facility Date/Time 26 Aug 98 27 Aug 98 M Pt H Pad Progress Report Well MPH-10 Page 2 Rig Nabors 4ES Date 24 December 98 04:15-04:45 04:45-06:00 06:00-06:15 06:15-06:30 06:30-07:00 07:00-09:00 09:00-10:30 10:30-12:00 12:00-13:00 13:00-13:30 13:30-14:30 14:30-15:00 15:00-15:30 15:30-16:00 16:00-19:30 19:30-20:15 20:15-20:30 20:30-22:00 22:00-23:30 23:30-00:45 00:45-01:30 01:30-01:45 01:45-02:30 02:30-03:30 03:30-04:15 04:15-04:30 04:30-06:00 06:00-13:00 13:00-16:00 16:00-16:30 16:30-18:00 18:00-18:15 18:15-19:00 19:00-20:00 20:00-22:00 22:00-22:30 22:30-00:00 00:00-06:00 06:00-11:00 11:00-11:30 11:30-12:00 12:00-12:45 12:45-13:00 13:00-13:30 13:30-14:00 14:00-15:00 15:00-15:15 15:15-16:00 16:00-17:00 17:00-18:00 18:00-18:15 18:15-19:00 19:00-19:30 19:30-01:00 Duration 1/2 hr 1-1/4 hr 1/4 hr 1/4 hr 1/2hr 2hr 1-1/2 hr 1-1/2 hr lhr 1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 3/4 hr 1/4 hr 1-1/2 hr 1-1/2 hr 1-1/4 hr 3/4 hr 1/4 hr 3/4 hr lhr 3/4 hr 1/4 hr 1-1/2 hr 7hr 3hr 1/2 hr 1-1/2 hr 1/4 hr 3/4 hr lhr 2hr 1/2 hr 1-1/2 hr 6hr 5hr 1/2 hr 1/2 hr 3/4 hr 1/4 hr 1/2 hr 1/2 hr lhr 1/4 hr 3/4 hr lhr lhr 1/4 hr 3/4 hr 1/2 hr 5-1/2 hr Activity Rigged down Logging/braided cable equipment Pulled Drillpipe in stands to 0.0 ft Held safety meeting Serviced Drillfloor / Derrick Made up BHA no. 4 R.I.H. to 2056.0 ft Milled Other sub-surface equipment at 2090.0 ft Circulated at 2095.0 ft Pulled out of hole to 295.0 ft Pulled BHA Rig waited: Service personnel Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Rig waited: Service personnel Rigged up Logging/braided cable equipment Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Rigged down Logging/braided cable equipment Made up BHA no. 5 R.I.H. to 2099.0 ft Functioned Retrievable packer Pulled out of hole to 8.5 ft Pulled BHA Rig waited: Equipment Rig waited: Equipment (cont...) Rigged up sub-surface equipment - Other sub-surface equipment Held safety meeting Ran Drillpipe in stands to 1230.0 ft Held safety meeting Ran Drillpipe in stands to 2120.0 ft Set Internal casing patch at 2082.0 ft with 4000.0 psi Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 6 R.I.H. to 2145.0 ft Circulated at 2145.0 ft Circulated at 2145.0 ft (cont...) R.I.H. to 2200.0 ft Tested Internal casing patch - Via annulus and string Pulled out of hole to 96.0 ft Pulled BHA Installed Wear bushing Rigged down Bell nipple Installed Well control Held safety meeting Rigged up Logging/braided cable equipment Perforated from 5810.0 ft to 5830.0 ft Rigged down Logging/braided cable equipment Held safety meeting Rigged down Well control Installed Bell nipple Ran Tubing to 5309.0 ft (3-1/2in OD) Facility Date/Time 28 Aug 98 29 Aug 98 30 Aug 98 M Pt H Pad Progress Report Well MPH- 10 Page Rig Nabors 4ES Date Duration Activity 01:00-03:45 03:45-05:45 05:45-06:00 06:00-06:45 06:45-07:00 07:00-09:15 09:15-09:30 09:30-11:45 11:45-12:45 12:45-13:30 13:30-20:00 20:00-20:30 20:30-21:00 21:00-21:30 21:30-02:30 02:30-03:30 03:30-04:00 04:00-05:00 05:00-05:15 05:15-06:00 06:00-06:15 06:15-07:00 07:00-09:30 09:30-10:00 10:00-10:30 10:30-11:30 11:30-13:30 13:30-14:30 14:30-15:00 15:00-15:30 15:30-17:00 17:00-18:30 18:30-19:00 19:00-19:15 19:15-19:30 19:30-20:45 20:45-21:00 21:00-22:00 22:00-22:45 22:45-23:00 23:00-06:00 06:00-12:30 12:30-13:00 13:00-13:30 13:30-14:00 14:00-15:30 15:30-16:00 16:00-17:00 17:00-17:45 17:45-18:00 18:00-18:15 18:15-20:00 20:00-20:15 20:15-20:30 2-3/4 hr 2hr 1/4 hr 3/4 hr 1/4 hr 2-1/4 hr 1/4 hr 2-1/4 hr lhr 3/4 hr 6-1/2 hr 1/2 hr 1/2 hr 1/2 hr 5hr lhr 1/2 hr lhr 1/4 hr 3/4 hr 1/4 hr 3/4 hr 2-1/2 hr 1/2 hr 1/2 hr lhr 2hr lhr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1-1/4 hr 1/4 hr lhr 3/4 hr 1/4hr 7hr 6-1/2 hr 1/2hr 1/2hr 1/2hr 1-1/2 hr 1/2 hr lhr 3/4 hr 1/4 hr 1/4 hr 1-3/4 hr 1/4 hr 1/4 hr Rig waited: Service personnel Rigged up High pressure lines Held safety meeting Tested High pressure lines Injectivity test - 150.000 bbl injected at 4480.0 psi Monitor pressures FRAC job - 220.000 bbl injected at 3940.0 psi Monitor pressures FRAC job - 749.000 bbl injected at 3000.0 psi Rigged down High pressure lines Monitor pressures Reverse circulated at 5310.0 ft Flow check Singled in drill pipe to 5574.0 ft Washed to 5780.0 ft Injectivity test - 18.000 bbl injected at 1000.0 psi Injectivity test - 8.600 bbl injected at 2500.0 psi Reverse circulated at 5295.0 ft Flow check Laid down 570.0 ft of Tubing Held safety meeting Serviced Block line Pulled Tubing in stands to 0.0 ft Removed Bell nipple Installed Well control Rigged up Logging/braided cable equipment Perforated from 5734.0 ft to 5754.0 ft Rigged down Logging/braided cable equipment Removed Well control Installed Bell nipple Ran Tubing in stands to 5213.0 ft Rigged up High pressure lines Held safety meeting Tested High pressure lines Injectivity test - 150.000 bbl injected at 4125.0 psi Monitor pressures FRAC job - 170.000 bbl injected at 3930.0 psi Monitor pressures FRAC job - 760.000 bbl injected at 3010.0 psi Rigged down High pressure lines Monitor wellbore pressures Monitor wellbore pressures (cont...) Reverse circulated at 5213.0 ft Flow check Singled in drill pipe to 5535.0 ft Reverse circulated at 5650.0 ft Injectivity test - 2.500 bbl injected at 1150.0 psi Flow check Laid down 470.0 ft of Tubing Pulled Tubing in stands to 4830.0 ft Held safety meeting Pulled Tubing in stands to 0.0 ft Retrieved Wear bushing Installed BOP test plug assembly 3 24 December 98 Facility Date/Time 31 Aug 98 01 Sep 98 02 Sep 98 03 Sep 98 04 Sep 98 05 Sep 98 M Pt H Pad Progress Report Well MPH-10 Page 4 Rig Nabors 4ES Date 24 December 98 20:30-22:30 22:30-22:45 22:45-23:00 23:00-23:15 23:15-23:45 23:45-00:15 00:15-01:30 01:30-03:00 03:00-04:00 04:00-04:15 04:15-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-14:30 14:30-06:00 06:00-09:30 09:30-12:30 12:30-19:00 19:00-20:00 20:00-22:30 22:30-06:00 06:00-06:30 06:30-08:30 08:30-11:00 11:00-16:00 16:00-21:00 21:00-06:00 06:00-06:30 06:30-08:00 08:00-09:30 09:30-12:30 12:30-14:30 14:30-17:00 17:00-22:30 22:30-01:00 01:00-04:00 04:00-06:00 06:00-06:30 06:30-22:00 22:00-02:00 02:00-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-08:00 Duration 2hr 1/4 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1-1/4 hr 1-1/2 hr lhr 1/4 hr 1/4 hr 1-1/2 hr 1/2 hr lhr 7hr 15-1/2 hr 3-1/2 hr 3hr 6-1/2 hr lhr 2-1/2 hr 7-1/2 hr 1/2 hr 2hr 2-1/2 hr 5hr 5hr 9hr 1/2hr 1-1/2 hr 1-1/2 hr 3hr 2hr 2-1/2 hr 5-1/2 hr 2-1/2 hr 3hr 2hr 1/2 hr 15-1/2 hr 4hr lhr 1-1/2 hr lhr 1/2 hr 2hr Activity Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Held safety meeting Removed Bell nipple Installed Well control Rigged up Logging/braided cable equipment Perforated from 5580.0 ft to 5600.0 ft Rigged down Logging/braided cable equipment Removed Well control Installed Bell nipple Ran Tubing in stands to 3800.0 ft Held safety meeting Ran Tubing in stands to 5277.0 ft FRAC job - 655.000 bbl injected at 2500.0 psi Monitor wellbore pressures Monitor wellbore pressures Reverse circulated at 5277.0 ft Laid down 5527.0 ft of Tubing Made up BHA no. 10 R.I.H. to 5512.0 ft Reverse circulated at 5824.0 ft Held safety meeting Reverse circulated at 5971.0 ft Reverse circulated at 5971.0 ft Laid down 5971.0 ft of 3-1/2in OD drill pipe Ran Tubing to 2265.0 fl (2-7/8in OD) Rigged up sub-surface equipment - ESP Held safety meeting Ran Tubing to 3200.0 ft (2-7/8in OD) Rigged up sub-surface equipment - Other sub-surface equipment Pulled Tubing in stands to 0.0 ft Rigged down sub-surface equipment - ESP Rig waited: Equipment Ran Tubing in stands to 3200.0 ft Rig waited: Equipment Pulled out of hole to 0.0 fl Installed ESP Held safety meeting Ran Tubing in stands to 5473.0 ft Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 70.000 bbl of Diesel Freeze protect well - 70.000 bbl of Diesel SPt SHARED SERVICES DRILLING MILNE POINT / MPH-10 500292279500 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/97 f-SUN DRILLING SERVICES ANCHORAGE ALASKA DATE OF SURVEY: 082697 MWD SURVEY JOB NUMBER: AK-MM-70251 KELLY BUSHING ELEV. = 66.00 FT. OPERATOR: BP EXPLORATION PAGE 1 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. .00 .00 -66.00 112.00 112.00 46.00 199.83 199.83 133.83 291.77 291.76 225.76 384.56 384.55 318.55 0 0 0 0 0 27 0 34 0 59 N .00 E .00 .00N .00E N .00 E .00 .00N .00E N 86.28 E .51 .02N .34E S 65.03 E .31 .15S 1,13E S 54.27 E .47 .82S 2,20E .00 .00 -.02 .16 .84 476,86 476.83 410.83 567.43 567.37 501.37 658.77 658.59 592.59 753.50 753.09 687.09 838.00 837.23 771.23 0 58 1 59 3 33 4 25 6 3 S 50.99 E .06 1.78S 3.46E S 27.57 E 1.28 3.66S 4,79E S 15.70 E 1.82 7.80S 6,29E S 15.59 E .91 14.14S 8.07E S 8.91 E 2.06 21.68S 9,64E 1.81 3.71 7.86 14 . 22 21.77 930.00 928.59 862.59 1022,55 1020.15 954.15 1114.46 1110,73 1044.73 1206.32 1200.90 1134.90 1298.57 1290.62 1224.62 7 22 9 21 10 8 11 48 14 58 S 6.98 E 1.46 32.33S ll,10E S 5.86 E 2.15 45.70S 12,59E S 4.69 E .90 61.20S 14.02E S .17 E 2.03 78.66S 14,71E S 2.32 W 3.49 100.02S 14,25E 32.43 45.81 61.32 78.80 100.15 1390.34 1378.60 1312.60 18 1 1479.33 1463.25 1397.25 17 55 1570.73 1549.84 1483.84 19 22 1663.98 1637.26 1571.26 21 17 1756.55 1722.57 1656.57 24 23 S 1.13 W 3.34 126.08S 13,49E S 1.54 W .18 153.54S 12,85E S .05 W 1.67 182.77S 12,46E S .75 W 2.06 215.17S 12,23E S .47 E 3.39 251.09S 12,16E 126.20 153.65 182.88 215.27 251.20 1849.59 1806.18 1740.18 1940.43 1885.95 1819.95 2033.68 1966.19 1900.19 2129.83 2046.41 1980.41 2217.53 2115.95 2049.95 2309.07 2183.64 2117.64 2398.23 2244.51 2178.51 2492,60 2303.88 2237.88 2585.13 2358.11 2292.11 2679.02 2409.12 2343.12 27 36 29 30 31 43 35 10 39 52 44 43 49 9 52 51 55 22 58 48 S .05 E 3.47 291.87S 12,34E S .90 W 2.15 335.29S 12.01E S 1.38 W 2.38 382.76S ll.06E S .64 W 3.61 435.74S 10,14E S .28 W 5.36 489.13S 9.72E S .33 E 5.32 550.72S 9.76E S 2.17 E 5.19 615.82S 11.22E S 2.02 E 3.93 689.10S 13,90E S 2.68 E 2.77 764.00S 16.98E S 1.43 E 3.83 842.76S 19.79E 291.98 335.39 382.85 435.81 489.20 550.78 615.90 689.20 764.12 842.91 2769.82 2454.20 2388.20 2863.25 2497.28 2431.28 2956.47 2538.53 2472.53 3048.30 2578.25 2512.25 3140.31 2618.76 2552.76 61 39 63 25 64 2 64 41 63 2 S 1.44 E 3.13 921.54S 21,76E S .12 E 2.28 1004.42S 22.88E S .44 W .85 1088.01S 22.65E S .32 W .73 1170.81S 22.10E S 1.10 W 1.95 1253.40S 21.08E 921.70 1004.59 1088,18 1170.96 1253.54 ORIGINAL .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-10 500292279500 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/97 DATE OF SURVEY: 082697 MWD SURVEY JOB NUMBER: AK-MM-70251 KELLY BUSHING ELEV. = 66.00 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. 3233.35 2660.88 2594.88 63 7 S 1.21 W 3326.22 2702.48 2636.48 63 39 S 1.24 W 3422.22 2746.23 2680.23 62 7 S 1.69 W 3517.49 2790.89 2724.89 61 57 S 2.11 W 3614.62 2836.46 2770.46 62 4 S 2.51 W 13 .57 1 64 .43 38 1336.34S 19.40E 1336.47 1419.35S 17.63E 1419.46 1504.77S 15.45E 1504.85 1588.88S 12.66E 1588.92 1674.58S 9.20E 1674.59 3709.79 2881.75 2815.75 61 5 S .42 W 3805.47 2927.70 2861.70 61 30 S .20 E 3900.98 2973.31 2907.31 61 27 S .03 W 3995.58 3017.97 2951.97 62 12 S .41 E 4092.39 3062.61 2996.61 62 52 S .08 W 2 18 .71 22 .89 83 1758.24S 7.05E 1758.23 1842.16S 6.89E 1842.14 1926.08S 7.02E 1926.06 2009.47S 7.30E 2009.44 2095.36S 7.54E 2095.34 4187.75 3106.56 3040.56 62 13 S 1.90 E 4281.52 3149.66 3083.66 63 2 S 2.40 E 4375.86 3192.24 3126.24 63 17 S 2.52 E 4472.78 3235.50 31~69.50 63 40 S 1.90 E 4567.25 3277.04 3211.04 64 9 S 1.50 E 1 96 .99 .30 .69 .63 2179.97S 8.88E 2179.95 2263.18S 12.01E 2263.20 2347.29S 15.62E 2347.33 2433.95S 18.96E 2434.02 2518.76S 21.48E 2518.85 4664.34 3320.90 3254.90 62 7 S 1.95 E 4759.16 3367.01 3301.01 59 40 S 1.45 E 4853.40 3416.26 3350.26 57 17 S 1.33 E 4950.25 3470.52 3404.52 54 33 S .05 W 5043.04 3526.51 3460.51 51 12 S .63 W 2.12 2.63 2.53 3.06 3.66 2605.32S 24.08E 2605.43 2688.12S 26.55E 2688.25 2768.41S 28.50E 2768.56 2848.62S 29.41E 2848.77 2922.59S 28.98E 2922.74 5138.09 3588.59 3522.59 47 13 S 2.02 W 4 5230.80 3653.85 3587.85 43 16 S 1.86 W 4 5327.69 3726.49 3660.49 39 34 S .69 W 3 5421.64 3799.66 3733.66 38 5 S 1.20 E 2 5515.89 3873.99 3807.99 37 47 S 1.15 E 5611.96 3949.99 3883.99 37 37 S 1.07 E 5706.77 4025.16 3959.16 37 27 S .09 E 5800.82 4099.76 4033.76 37 33 S .50 E 5895.36 4174.49 4108.49 37 58 S .19 E 5991.26 4250.08 4184.08 37 58 S .04 E .32 .27 .89 .03 .31 .18 .65 .29 .49 .09 2994.53S 27.34E 2994.65 3060.32S 25.11E 3060.42 3124.39S 23.66E 3124.48 3183.29S 23.90E 3183.38 3241.24S 25.09E 3241.33 3299.99S 26.23E 3300.09 3357.76S 26.82E 3357.87 3415.03S 27.11E 3415.13 3472.93S 27.46E 3473.04 3531.95S 27.58E 3532.05 6006.24 4261.91 4195.91 37 47 S .55 W 2.70 3541.15S 6080.00 4320.19 4254.19 37 47 S .55 W .00 3586.36S 27.54E 3541.25 27.10E 3586.45 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3586.46 FEET AT SOUTH 0 DEG. 25 MIN. EAST AT MD = 6080 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 179.46 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 6,080.00' MD SP .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SH3kRED SERVICES DRILLING MILNE POINT / MPH-10 500292279500 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/97 DATE OF SURVEY: 082697 JOB NUMBER: AK-MM-70251 KELLY BUSHING ELEV. = 66.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -66.00 .00 N .00 E .0 1000.00 997.90 931.90 42.05 S 12.22 E 2.1 2000.00 1937.54 1871.54 365.06 S 11.48 E 62.4 3000.00 2557.58 2491.58 1127.15 S 22.34 E 442.4 4000.00 3020.03 2954.03 2013.37 S 7.32 E 979.9 2.10 60.35 379.96 537.55 5000.00 3500.00 3434.00 2888.69 S 29.27 E 1500.0 6000.00 4256.98 4190.98 3537.33 S 27.57 E 1743.0 6080.00 4320.19 4254.19 3586.36 S 27.10 E 1759.8 520.03 243.03 16.79 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP .Y-SUN DRILLING SERVICES ANCHORAGE A~LAS RA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-10 500292279500 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/97 DATE OF SURVEY: 082697 JOB NIIMBER: AK-MM-70251 KELLY BUSHING ELEV. = 66.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -66.00 66.00 66.00 .00 166.00 166.00 100.00 266.00 266.00 200.00 366.01 366.00 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .01 N .08 E .00 .00 .04 S .89 E .00 .00 .63 S 1.94 E .01 .01 466.03 466.00 400.00 566.06 566.00 500.00 666.19 666.00 600.00 766.45 766.00 700.00 866.93 866.00 800.00 1.66 S 3.32 3.62 S 4.77 8.24 S 6.42 15.11 S 8.34 24.69 S 10.11 E .03 .02 E .06 .03 E .19 .13 E .45 .26 E .93 .48 967.73 966.00 900.00 1069.03 1066.00 1000.00 1170.67 1166.00 1100.00 1273.14 1266.00 1200.00 1377.11 1366.00 1300.00 37.18 S 11.69 53.28 S 13.35 71.37 S 14.68 93.67 S 14.47 122.04 S 13.58 1.73 .79 3.03 1.31 4.67 1.64 7.14 2.47 11.11 3.97 1482.22 1466.00 1400.00 1587.86 1566.00 1500.00 1694.94 1666.00 1600.00 1804.57 1766.00 1700.00 1917.50 1866.00 1800.00 154.43 S 12.83 188.45 S 12.46 226.69 S 12.12 271.57 S 12.29 324.00 S 12.18 16.22 5.12 21.86 5.64 28.94 7.08 38.57 9.63 51.50 12.93 2033.46 1966.00 1900.00 2154.02 2066.00 2000.00 2284.55 2166.00 2100.00 2431.57 2266.00 2200.00 2599.11 2366.00 2300.00 382.65 S 11.06 449.92 S 9.99 533.69 S 9.69 641.29 S 12.17 775.52 S 17.49 67.46 15.96 88.02 20.56 118.55 30.53 ~-165.57 47.02 233.11 67.53 2794.67 2466.00 2400.00 3019.64 2566.00 2500.00 3244.68 2666.00 2600.00 3464.51 2766.00 2700.00 3677.19 2866.00 2800.00 943.40 S 22.31 1144.89 S 22.24 1346.45 S 19.19 1542.13 S 14.33 1729.70 S 7.27 328.67 95.57 453.64 124.96 578.68 125.04 698.51 119.83 811.19 112.69 3885.69 2966.00 2900.00 4099.82 3066.00 3000.00 4317.55 3166.00 3100.00 4541.92 3266.00 3200.00 4757.17 3366.00 3300.00 1912.65 S 7.03 2101.98 S 7.53 2295.27 S 13.35 2495.98 S 20.88 2686.40 S 26.50 919.69 108.50 1033.82 114.13 1151.55 117.73 1275.92 124.37 1391.17 115.25 S~ '.Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPH-10 500292279500 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/ 2/97 DATE OF SURVEY: 082697 JOB NUMBER: AK-MM-70251 KELLY BUSHING ELEV. = 66.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD- TVD DIFFERENCE VERTICAL CORRECTION 4942.41 3466.00 3400.00 2842.22 S 29.40 E 1476.41 5104.34 3566.00 3500.00 2969.47 S 28.10 E 1538.34 5247.38 3666.00 3600.00 3071.58 S 24.77 E 1581.38 5378.85 3766.00 3700.00 3156.89 S 23.37 E 1612.85 5505.78 3866.00 3800.00 3235.04 S 24.97 E 1639.78 85.24 61.93 43.03 31.48 26.93 5632.18 3966.00 3900.00 3312.34 S 26.46 E 1666.18 5758.23 4066.00 4000.00 3389.07 S 26.89 E 1692.23 5884.58 4166.00 4100.00 3466.30 S 27.44 E 1718.58 6011.42 4266.00 4200.00 3544.32 S 27.51 E 1745.42 6080.00 4320.19 4254.19 3586.35 S 27.10 E 1759.81 26.40 26.05 26.35 26.84 14.39 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST-20 FOOT MD (FROM MINIMUM CURVATURE) POINTS CI I=1 I I_1_ I ~ G SEFIL/I r'Ec: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPH- 10, AK-MM-70251 December 2, 1998 MPH-10: 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22795-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22795-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWl.EDGE RECE1PT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITFAL LETYER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. ~Anchorage, Alaska 99519-6612 Sign 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Com~anv C] I::i I I__1__ i ~ G SI~ FI~/I I-- E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPH- 10, November 18, 1998 AK-MM-70251 1 LDWG formatted Disc with verification listing. API#: 50-029-22795-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPIES OF THE TRANSMITYAL LETTER TO THIg ATI'ENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Cemer, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Signe(~ ~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al'tN: Sherrie NO. 11592 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 10/22/98 Well Job # Log Description Date BL Sepia LIS Tape MP8-03 PRODUCTION PROFILE 980823 1 i MPB-03 GAS LIFT SURVEY 980823 I 1 MPB-03 DIGITAL FLUID IMAGER 980823 1 1 MPB-04 PRODUCTION PROFILE 980823 1 1 MPB-04 GAS LIFT SURVEY 980823 1 1 MPB-04 DIGITAL FLUID IMAGER 980823 1 1 MPB- 10 PRODUCTION PROFILE 980823 1 1 MPB-10 GAS LIFT SURVEY 980823 1 1 MPB-10 DIGITAL FLUID IMAGER 980823 1 1 MPB- 15 PRODUCTION PROFILE 980825 1 1 MPB-15 GAS LIFT SURVEY 980825 1 1 MPB-15 DIGITAL FLUID IMAGER 980825 1 1 MPE-21 FOUR ARM CALIPER 980829 1 1 MPE-30 FOUR ARM CALIPER 980731 1 1 MPE-33 FOUR ARM CALIPER 980811 1 i MPG-01 WATER FLOW LOG 980717 1 1 MPH- 10 GAMMA RAY/COLLAR LOG 980825 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center M83-3 900 E. Benson BIvd. Anchorage, Alaska 99519-6612 Date Delivered: fl(,,-[ 2:2 1998 Oil & Gas/;.,:,,ns. (';o;'r~issio~ Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AT[N: Sherri~ t~" Received by: ..,,4 ~//L~ / 9/25/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 11515 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPB-03 JEWELRY LOG 9 8 0 8 2 3 I 1 MPB-04 JEWELRY LOG 9 8 0 8 2 3 I 1 MPB-10 JEWELRY LOG 9 8 0 8 2 3 I 1 MPB-15 JEWELRY LOG 9 8 0 8 2 5 I 1 MPB-20 JEWELRY LOG 9 8 0 91 1 I 1 MPC-22A TUBING PUNCHER RECORD 9 8 0 8 0 2 1 1 MPE-21 PERFORATING RECORD 9 8 0 9 0 3 I 1 M P E-30 PERFORATING RECORD 9 8 0 9 0 7 1 1 MPH-10 PERFORATING RECORD 9 8 0 8 2 7 I 1 MPH-10 PERFORATING RECORD 9 8 0 8 2 9 I 1 M P H- 10 PERFORATING RECORD 9 8 0 8 31 I 1 M P H- 11 PERFORATION RECORD 9 8 0 8 0 8 I 1 M P H- 14 PERFORATING RECORD 9 8 0 7 2 8 I 1 M PH-14 PERFORATING RECORD 9 8 0 7 3 0 I 1 MPH-14 PACKER SE'ri'lNG RECORD 9 8 0 8 01 I 1 MPJ-22 PERFORATION RECORD 9 8 0 7 3 0 I 1 MPJ-22 BRIDGE PLUG SET RECORD 9 8 0 813 1 1 MPJ-22 PERFORATION RECORD 9 8 0 817 1 1 MPK-21 ~ / ~ JEWELRY LOG 980913 I I !;21 c/g. / 2,--/ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-8612 Date Delivered: Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, AK 2'§5)03 A'I-I'N: S~ Receive~'/'' ~~ __ TONY KNOWLE$, GOVERNOR ALASKA OIL ~NIt GAS CONSI~RYA~ION CO~/ISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 7. 1997 Chip A!vord Senior Drilling Engineer BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Milne Point Unit MPH- 10 BP Exploration (Alaska) Inc. Permit No: 97-149 Sur. Loc.: 2834'NSL. 4!67'WEL, Sec. 34, T13N, RIOE. UM Btmhole Loc: 4537'NSL. 4134'WEL, Sec. '~ TI~N. R10E. UM Dear Mr. Alvord: Enclosed is tine approved application for permit to drill the above referenced well. Tine permit to drill does not exempt you from obtaining additional permits required bv la~v fi'om other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below tine surface casing shoe must be given so that a representative of tlne Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Clnairman BY ORDER OF THE COMMISSION dlt:'enciosures CC~ Department of Fish & Game. Habitat Section w/o encl. [Separtment of Envinomment ConserYation w/o encl. ¢ ~- STATE OF ALASKA ALASKA _.,L AND GAS CONSERVATION CON..,'IISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone D Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 66.4' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2834' NSL 4167' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 4870' NSL, 4137' WEL, SEC. 2, T12N, R10E, UM MPH-10 At total depth 9. Approximate spud date Amount $200,000.00 4537' NSL, 4134' WEL, SEC. 2, T12N, R10E, UM 08/22/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025906, 743'I No Close Approach 2560 6072' MD / 4278' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 600' Maximum Hole Angle 64.14° Maximum surface 1400 psig, At total depth (TVD) 4000' / 1800 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 BTC-Mod 6041' 31' 31' 6072' 4278' 889 sx PF 'E', 129 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~ '~''~ '~"' ! Present well condition summary Total depth: measured feet Plugs (measured) ~;~'~.. : ~"~"' true vertical feet Effective depth: measured feet Junk (measured):-..~. ,",-,~'~'.,:,.,,. 0r''''''~;¢\s ~ '~ff~;'- .... :,:~ true vertical feet t.~!~"¢;.;:~ D~t ~'~' ~'~j~,~0~.9" '~'' Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production Liner 'ORIGINAL Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Brofka, 564-4809 Prepared By Name/Number: Kathy Carnpoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAlvord ,~'~',-~- ~ ~/"~ Title Senior Drilling Engineer Date ? Commission Use Only Permit Number I APl Number I ApprovalDate I See cover letter / ? 5o- o ¢ - 2.. 7 %_<' - 7- 7 forother requirements Conditions of Approval: Samples Required []Yes ]~ No Mud Log Required []Yes ~]No Hydrogen Sulfide Measures []Yes~]No Directional Survey Required ~]Yes [.~No Required Working Pressur,~ for BOPE F"I2M; 1~3M; [-15M; I'-I10M; r-115M Other: 0t'10~[B?~/ SigjBed~'~ Approved By 9avid TM ,~0~flSt0f~ by order of · Commissioner the commission Date ~- Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): Mark J. Brofka I MPH-10 Well Plan Summary ISCHRADER BLUFF PRODUCER 564-48O9 Surface Location: 2834 FSL, 4167 FEL, S34 T13N R10E UM Tar~let Location: 4870 FSL, 4137 FEL, S02 T12N R10E UM Bottom Hole Location: 4537 FSL, 4134 FEL, S02 T12N R10E UM I AFE Number: I 337097 Rig: I Nabors 22E Estimated Start Date: I 22 AUG 97 I I Operating days to complete: 1 6.0 I D: 1 072' II TVD: 1427 ' I I KaE: Well Design: I Schrader Bluff Producer Formation Markers: Formation Tops MD TVDSS TVD (bkb) KOP 600 534 '600 Base of Permafrost 1830 1725 1791 Top of Ugnu 4934 3383 3449 Top M Sand 5275 3602 3668 Top NA(-I-arget) 5553 3814 3880 Top of Schrader Bluff Sands(EMW8.6 ppg) NB 5587 3840 3906 NCND 5628 3871 3937 NE 5650 3888 3954 NF 5711 3935 4001 OA 5754 3968 4034 OA4 5794 3996 4062 OB 5834 4029 4095 Top of Seabee 5872 4058 4124 Base of Schrader Bluff Sands(EMW8.3 ppg) TD 6072 4211 4278 TDat200' MD pastbase of Schrader Casin~l?i'ubing Program: Hole ,~ize - Csg~ Wt/Ft Grade Conn. Length Top Bottom Tbs O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112'/112' 8-1/2" 7" 26# L80 BTC-Mod 6041' 31'/31' 6072'/4278' Pipe Specifications: O:D. ' Wt/Ft Grade Conn. ID Area Tensile Max Pull Collapse Burst (bbl/ff) (kips) (80% TR) (psi) (psi) 20" 94# H-40 Weld 19.124" 0.3552 40.0 32.0 520 1530 7". 26# L-B0 BTC- Mod 6.276" 0.0382 80.0 64.0 5410 7240 5" 19.5# G (Pr) 4-1/2" IF 4.276" 0.0178 436.1 348.9 8765 12163 5" 19.5# E (Pr) 4-1/2" IF' 4.276" 0.0178 311.5 249.2 7041 8688 Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +4000' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.65 ppg EMW), is 1400 psi, well below the internal yield pressure rating of the 7" casing. Logging Program' Open Hole Logs: Cased Hole Logs: Mudloggers are NOT rec MWD from surface to TD LWD (GR/Resistivity) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals. NONE GR/CCL with the completion rig.) uired for this well. Mud Program: Spud Mud ISpecial design considerations I See "Drilling Hazards and Risks" section about dealing with the I possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid · (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I 600', S-shaped profile t Maximum Hole Angle: ~64.14© Close Approach Well: NONE Waste Management: Cuffings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on G-Pad have been permitted for annular injection. MP H-lO Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test 21-1/4" diverter line system. Build Spud Mud. 5. Drill 8-1/2" surface hole as per directional plan to 6,072' MD / 4,278' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity from the top of the Ugnu to TD. NOTE: Fill hole with mud and check riser for leaks before spudding in. NOTE: Short trip no deeper than 300' MD past the base of permafrost. After the base of the permafrost, trips should be made every 1000'-1300' MD, or as hole conditions require. NOTE: Utilize lubricants as necessary to enhance sliding performance and reduce drag when running casing to bottom. NOTE: The well will require two insert bits. Drill no deeper than the top of the Ugnu with the first bit, then POOH for a bit change, new MWD tool, and to pick up LWD tools. Current guidelines are to run the first bit at least 30 hours drilling. NOTE: Drill at a controlled rate of no more than 200 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing with centralizers appropriately placed as per program. 9. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. Displace STAGE1 cement with seawater at 7.0-8.0 bpm. NOTE: Reciprocate pipe while pumping cement if possible/practical. After opening the ES cementer, circulate seawater a minimum of 2 hours before pumping the STAGE2 cement slurry. Displace the second stage with diesel. 10. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS- The well is planned as a Schrader Bluff single casing string producer. The well will be drilled, cased, and cemented with Nabors 22E which will then suspend the well and move on. The well will be completed at a later date by a completion rig. See the latest Milne Point H-Pad Data Sheet prepared by Pete Van Dusen for information on H pad. Particularly close attention should be paid to hydrate experiences on previous H-Pad wells. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: Hydrates have occurred on H-Pad and there is a possibility that hydrates may be encountered in the drilling of MPH-10. Three wells drilled in 1995, MPH-05, MPH-06, and MPH-07 all encountered hydrates below the permafrost. On MPH-05 and MPH-06, mud weight was significantly cut as a result. Lecithin (DrillTreat) should be added to the mud system as a precaution before drilling through the base of the permafrost. If hydrates, are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrilITreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MPH-10. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. MPH-05 experienced lost returns at 3708' TVDSS while drilling with heavy 11.5 ppg mud that was used to deal with hydrates. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on H-Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concern-~ Also, due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 8. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7" annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. 7. Other There have been only a handful of wells drilled on the North Slope with an 8-1/2' surface hole and it is important that bit and directional performance is closely monitored and reported so that lessons learned can be included in the next well program. None of the drilling hazards and risks identified above are expected to be magnified by the change in hole size. '. MPH-10 7" SURFACE/PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 bbls fresh water spacer (1307' in 7" casing). STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 239 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (4775' MD) TO THE ES CEMENTER STAGE TOOL (2050' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) WEIGHT: APPROX #SACKS: FLUID LOSS: 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 129 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (6072' MD) TO THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (4775' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. STAGE2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg 650 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. PUMP UNTIL RETURNS ARE OBSERVED AT SURFACE BEFORE DROPPING CLOSING PLUG. +/- 350% EXCESS IS EXPECTED FROM THE ES CEMENTER (2050' MD) TO SURFACE. NOTE THAT 100 SACKS WiLL BE IN THE 20" x 7" ANNULAR SPACE. HAVE AT LEAST 1400 SACKS AVAILABLE. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - one (1) per joint on the bottom twenty-three (23)joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (23+2 = 25 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 7.0-8.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1st Stage: 1. The lead slurry volume is calculated to cover from the ES cementer tool (200' MD below base of permafrost) to the top of the tail slurry, at the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands, with 50% excess. 2. The tail slurry volume is calculated to cover the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands to TD with 50% excess. 3. 80' of 7", 26# capacity for the float joints (baffle collar, float collar, and float shoe). 2nd Stage: The slurry volume is calculated to cover from the ES cementer to surface with an excess of 350% expected to be required. Ensure that additional sacks of cement are onsite and available for use The slurry will be pumped until cement returns are seen at surface. Note that approximately 100 sacks will be required just to fill the 20" x 7" annular space. Note that in the event that hydrates are encountered, the Operations Drilling Engineer should be notified and a modified cement program will be submitted to ensure isolation of the hydrate zone. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. Ensure that the seawater has been treated with biocide and is relatively "bug-free." 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate seawater through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. AnadrilL SchLumbercjer Alaska District Llll Hast 80th Avenue F~%chorage, AK 99518 (907) 349-4511 Fax 344-2160 DIR~C~ZONAL WELL PLAN fOr SHARED SI~RVIC~S DRILLING Field ........ : M£fne Point, R-Pad Computation,.: MinimumCurvaCu~e Units ........ : FHHT Surface.Lat..: 70.437929~? N Surface Long.: £49,53948809 W Legal Description Surface ...... : 2834 PSL 4L67 FF, L S34 T13N R1OH bt4 TaTget ....... : 4870 FSL 413T F/gl S02 T12N RIOH UM B}[b .......... : 4537 PSh 4134 ~ S02 T12N RIOH UM LOCATIONS - /M~RSKA Zone: '4 X-Coord Y-Coord 556478.67 6009984.4B ~5~534.00'6006~42.00 $56539.69 6006408.WB PROPOSHD NHLb PROFILH STATION MHASUR~D :NCLN D[~J~CT[ON ~DHNTIPICATIO~ DEPTH ~GLH AZK~ 0.eO 0.O0 0.00 700.00 ~.25 900-00 4.2~ 179.46 ~: _- --_.=~:a mm m m mmmm Im mm mm :m I: VERT I C. AL- mmm~----~ m~mmmmmm 0.00 -66.40 600.00 $33.60 699,99 633.59 999.94 733 899 .'~6 833.36 DSPART 0.00 -0.00 ~.09 4 .~6 10.25 Prepared ..... ~ 28 Jul 199'7 Vert sect az.: L79,46 KB elevation.: 66,~0 ft Magnebic Ocli: +28.015 (H) Scale Pac~or.~ 0.99990362 ANADRILL PPROYED AKA-DPC FOR PERMITTING ONLY PLAN ~ --__ .... .= .... ,,,~ ,. ~ ....... , , ·, OOORDINATHS-FROW ALASKA ~one 4 TOOL Db/ ~LLHHAD X ¥ PAtH ~00 {mm ml::~::::mmm mmm ~mmmm mlmm ={am 0.gQ N 0.00 E SS6478.67 6009984.48 HS 0.00 0.00 ~ 0.00 E 556478.67 6009984.48 179R 0.00 ~.09 S 0.01 E $56~78.69 6009983.39 ~79A 1.25 4.~6 S 0.04 E 556478.74 6009980.12 17PR £.25 10.95 8 0.10 E ~56478.84 600997~.23 179~ L.75 BUZLD 2.S/LO0 1000.00 6.00 199.46 1100.00 &-S0 199.46 3200.00 '11.00 379.46 ~300.00 13.50 179-46 L400.00 16.00 L79.~6 999.36 932.96 1098,55 L032.15 1197.20 L130.70 ~294.8~ L220.41 1391.51 L325.11 19.18 31.80 48.93 69.95 95.41 19.L8 $ 0.18 H 5~6479.00 6009965.30 HS L-75 31.80 S 0.30 H 556479.21 6009952.69 F~S 2.~0 48.73 ~ 0.46 H ~56479.50 6009935.76 HS 2.50 69.95 S 0-66 H S56479.06 60099L4.55 ~,S 2.50 95.40 S 0,91 E 556(80.30 6009889.09 HS 2.50 LSO0.O0 18.S0 1600.00 21.00 179-46 L487.00 1420.60 125.06 179.46 L581.LL 15L4.73 1.58.85 L25.05 S L-~9 B 556{B0.80 6009859.45 HS 2.50 L58.B4 S L.51 B 556481.38 6009825.67 HS 2.50 Z (anadrtll (c) 9'; MPH1oP3 3.0C 9:36'AM P) P~OPOSKD ~[/~ PROF[L[~ mnnmmmmmmmmmmmmmmmmm mmmtm~uu ~ ~ ~ ~~m ~TAT£ON ~EASUR.SD INCLN DIRgCTION [D~NTIFICATEON DEPTH ANGL~ AZIMUTH 1~00,00 23.50 179.46 1800.00 26.00 ~79.46 ~ 2.S/~0 BUI~ 1800.06 ~6.0~ 179.46 BASE PS~FRO~ 1829.97 ~6.~ 179.4'6 BU~ 3.5/100 1860.06 26.00 %79.46 . 8ND 3.5/200 DROP 4/[00 1900.00 27.40 2000.00 30.90 2100.00 34.40 2200.00 37.90 2300.00 4L.40 2400.00 44.9G 2500,00 48.40 2600,00 SL.90 2700.00 65.40 2800.00 58.90 2900.00 62.40 2949.86 64.14 4749.83 64.14 4800.00 62.14 4900.00 58.[4 4933.65 56.80 5000.00 54.[4 5£00.00 50.L4 5200.00 46.L4 5274-84 43.L4 VHRTICAL-DHFFHS SHCTIO~ TVD SUB-S~ DHPART 1673.66 L607.26 L96.7~ 1764 147 L698.07 238.57 1764,5~ ~698.12 238.60 179~,40 L725.00 25~.71 L818,45 [752.O$ 264.91 28 Jul 1993 Page 2 OOOEDINAT~S-FROM AGASKA Zone 4 TOOL DL/ ~ELhHHAD X Y PACH 100 196.70 S 1.87 ~ 55648~.03 600978~.02 HS 2.50 238.56 S 2-26 E ~56482.74 6009745.96 KS 2.50 238.59 S 2.26 H 556482.74 6009745.94 ]{S 2.50 251.70 S 2-39 H 556482.96 6009552.83 264.89 S 2.51 H 556463.19 6009~9.64 L79.46 185~,13 [787.73 282.85 282.8~ 179.46 194~.45 [89~,05 331.55 331,54 179.46 2025,64 L959,24 385.49 385.47 [79-46 2106,3~ 2039.97 444.47 444,45 179.46 2L83,36 2~16,96 508.27 508,25 179.46 2256,30 2~89,90 5~6.65 576,62 179.46 2324,94 2258,54 649.36 649,33 179.46 2389,O1 2322,~[ ~26.~2 726.08 179.46 2~48.27 2381,87 806.64 806.6~ 179.46 2502.51 2436.11 890.64 990.60 179.46 255].S1 2485.11 977.79 97~.75 S 9.28 179.46 2573.~4 2507.54 [022.32 1022.27 S 9.70 179.46 3358.~1 3292.$1 2642.10 2641,98 S 25.07 ~79.46 3381,58 33~5.18 2686.86 2686,74 S 25.50 179.46 ~43~.36 3364.96 27~3.~7 2773,44 S 26,32 179.46 3449.40 ~363.00 280[.05 179.46 3487.07 ~420.67 2856.59 179.46 3~48.43 3482.03 2935.52 179.46 3615.]5 3546.75 3009.96 ~79.46 3668-40 3602-00 3062.56 2801.q2 2856.46 2935.39 3009.84 3062.42 $300.00 42 · L4 L79,46 3686.91 3620.5] 3079.60 3079.46 END 4/L00 DROP 5353.44 40.00 [79.46 3727-19 3660.79 3lL4.71 3LL4.57 TARCHT 5553.44 40.00 L79,46 3880.40 3814.00 3243.26 3245.~[2 0.00 · 2.68 R 556483_50 6009701.70 H$ 3.50 ~ '~-) 3.66 B 556485.25 6009599.08 I4R 3.50 4.22 H 556486.25 6009540.12 HS 3.50 6,89 ~ 55649~.06 6009258,54 RS 3.5~ 8,45 H 556493.86 6009094.06 ~S 556495.35 6009006.93 HS 3.50 ~ ~ ~.~ ~ 556523.74 6007343.02 hS 0.00 < 556525.99 6007211.58 LS 4.00 26.59 H 556526.47 6007~83.3L L9 4.00 27.11 H 556527.40 6003~28.58 LS 4.00 27.86 ~ 556526.~5 60070~9.67 LS 4.00 28.56 ~ 556530.02 6006975,23 [.tS 4-00 29.06 ~ 556530-92 6006922.66 [,~ 4.00 29.22 E 556531.2L 6006905.62 LS 4.00 29.56 g 556531.8[ 6006870.53 H.g 4.00 30.78 ~ 556534.00 6006742.00 HS 0.00 b-") P'I (AnadrLLL (c) 9'7 Mt~P.1OP3 3.0C 9:.16 AM P) MPH- 10 (PI) STATION ] DENT ! Ir[CAT ION Top SCHP, AD~,R / NA ~C/~D ~;~;a~m mmlmmm MRASURED INCLN DHETH ANGLH 5553.44 %0.00 5587.38 40.00 5627.84 40.00 5650.04 40.00 57~1.39 40.'00 mmmm~mmm= D~RRCT~OH V~RTICAh-DEPTHS AZ IMlrl~ TVD SUB - $~A mmmmmmmmm mmm:==:= =am~ma= L79.46 3880.40 3814 .00 179.46 3906.40 3~40.00 ~79-46 ~937.~0 ~871.00 lg9.46 3954.40 3888.00 179.46 4001.40 393~.00 S~CTION DEPART m~mm~== 3243.26 3265.08 ]291.09 3305.36 3344.80 CIA 5754.47 40.0° 179.46 i034.40 3968.00 3372,49 (1;%4 5791.02 40.00 179.46 4062.40 3956.00 3395.98 OB 5834.10 40.00 ~79.46 4095.40 4029.00 3423.67 BASE $CHRADER 5&gI.96 40.00 199.46 4~24.40 4058.00 3448.00 9' CASINO POINT '6071.96 40.00 1~9.46 4297.6~ 4211.2L 1576.~6 TO 6071.96 40.00 £~9.i6 4277.6~ 4211.2~ 3576.56 28 JuL 1999 Page 3 :.m{mmmmm~mmmmmmmmmm OOORDI NATHS - FROM #ELbI'mAD ~243.12 ,S 3290.95 S 3305.2L ~ 33~4.65 $ ALASKA Zone 4 .TOOL DL/ X Y FACH LO0 30,78 H, $56514.0~ 6006742.00 30.98 R ~56534.37 6006720.~9 RS 0,00 31.23 E 556534.82 6006694.~8 31.36 E 55653G.06 6006679,92 ~S 0.00 31.$4 E 556535.]3 6006640.49 ~S 0.00 3372.33 S 3395.83 S 3423.52 $ 3447.855 3576.40 S 3576~40 S · 32.00 E 32 .'72 ~.. 33'. 94 . 556536.20 6006612,82 HS 0.00 556536.6l 6006589.32 ~S 0.00 . 556539.08 600656L.64 HS 0.00 55653~,q9 6006537.31 HS 0.00 556539.69 6006408.78 0.00 556539.69 6006408.$8 0.00 : ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY , PLAN (Anadrill (c]97 MPK10P3 3.0C 9:36 AM P) (D ' SHAREB SERVZ'C'Es _ i i i · APPROVED ' DRILLING · m iiiiii i iii i i ! m mi MPH- ~ 0 (P3) VER_T I~A_L SECTION VIEW Sect. ion at.: ~79,46 FOR PERMITTING iTVD Scale ' :t inch = 600 feet Dep Scale - ~ inch = 600 feet ' ..... Anadr'.i ]] ,.,c£h]umber'ger Harker Identif 1cat&on t4D BKB SECTN INOLN :)- -- B AJ KB 0 0 0 O. O0 BI KOP/BUILD 1.25/t00 600 600 -0 O.OO C '- C) BUILD 1,75/J00 BO0 BOO 4 2.50 )-~ DJ BUILD ~.§/100 lO00 999 19 §.00 E) END 2.5/~00 BUILD 1800 t765 ~38 26.00 D ' F) BUILO 3.5/t00 t860 t818 265 26,00 ~__ G) END 3.5/100 BUZLB 2950 257~ 1022 64.14 H) DROP J/tO0 a750 3359 2642 64.~4 I) END a/lO0 DROP 5353 3727 3J15 40.00 ' J) TARGET 5553 3880 3243 aO,O0 ) I K) 7" CASING POINT 607~ 4278 3577 40.00 L) TD 6072 4278 3577 aO.O0 . F' . ,. . ~ ' , ~~ . . ,.: . . ,. .......... ~ ~" ............ . . · . ............ . ....... ...... . ..... I 0 300 600 900 J200 I500 JBO0 2100 2400 2700 3000 3300 3600 3900 Section De )attune (Anad~'~ll (c)g7 NPHIOP3 3.0C ~0: O~ M4 Pi "SHAREB sERVl-CES BRTLLZNG ~-- ,,' - --- --'~ MPH-1U J! ANADRILL AKA-D['C J : AI~PROVED I VERTICAL SECTION VIEW J f Sect ion at: 179.46 ~-- ~ FOg j'E~,M il'TiNG ' : TVD Sca]e.' 1 inch = 100 feet ! ONI.Y ] ....... .,,-]~,, ~ Oep Sca]e.' 1 inch = 100 feet )'~,.~ .- !'l-Ah ,,::~ .... ~' "" J. Drawn .ea dui J997 · . %. ............... :---~..~-~ AnadrJ]] Sch]uml~erger Marker Identification MD BKB SECTN ~NCLN ) A) ENO 4/100 OROP 5353 3727 3it5 40.00 %%% B) TARGET 5553 3860 3243 40,00 C) 7" CASING POINT 6072 4278 3577 40.00 )-. I D) TO 6072 4278 3577 40.00. · . . ~ ~, ~.! , .~ - ~.~ ..... . ...... . ........ .,~-.. ..... ~ ........... . '% ~/~- '¢~ r ........... ' '. ...',,, · j "- '~,g' - ~6-~ ..................... ~'-' ....... "- - - -' J ......... - . .a-~- .- . . -., ........ -~ ..... . '¢4' ',o~2' ............................. ~ ..................... I 3000 3050 3100 3150 3200 3250 3300 3350 3400 3450 3500 3550 3600 3650 3700 Section Departure I~ed¢~11 Icl 97 I~OP2 2.0C t0:05 ~ P! "SHARED' SERVICES" DRILLING "' · i i · Il · ~] 1(8 0 0 N 0 E ,(o,/,U~L., ~,~/~oo ~oo o, o ~ ~ PLAN VIEK ~UTLO ~.~/~oo ~oo ~ s o ~ i 6:ND 2...5/~00 BUTLD lBO0 ~3qS ;~ E CLOSURF ' 3§77 feel; 8t AzifilUth ~,,n ~.~/,oo ~ooo ~ s o ~ F) BUILD 3.~/~00 ~8§0 265 S 3 E 6) END-3.5/~O0 BUILD 2950 ~022 S ~0 E DECLINATION.' +2B.015 (E) H) D~DP 4/t00 4750 2642-S ~5 E SCALE, ' 1 inch = 600 feet Il ENO 4/~.00 DROP 5353 3~t5 s 30 E J) TARGET 5553 3243 S 3~ £ DRAWN ' 28 Jul 1997 K) 7" CASINB POINT §072 3576. $ 34 E L) TO 6072 3576 S 34 E , AnadrJ ]] $chJu~l)erger . 'A i~ 300. -. 2~ I ~-~---- ~'--- ~ AKA4 ~ ! ANI .DRILL "' ',l~ FOR ?ERJv~IT1.., _.~_. ~.,....--.___~_~.2 600 ':¢---~ ~.~.~ -.-. ~__.---.- 900 - '6 ~00 " -' · t§O0 .. . . J · ~800 ,- 2 :t.~0 ' ' . . . . 2400 ...... ; . · ' H _ 2.7ao , -, . 3000 . -; ..... " :: T8 ~lpt (RalIius ~00 feet ) - . 3300 ,.. ' . 3600 , I~[ . - - · 3900 , " ~]00 ]800 ~500 ~200 gO0 600 300 0 ]00 600 900 ~200 ~500 ~800 2100 <- NEST' EAST -> · lUl i i i , i Omaarll] ~)97 k~HiaP3 3.or i0:07 Al4 PI t ,/ / t / / / H-lO -~- H-g · I ~-~ I H-5 I H-3 I H-~ I-H-2 I H-8 I H-1 if ! H--7 -MPU H-PAD" / . / NO~S ? AS-BUILT WELL CONDUCTOR I EXISTING tAbU_ CONDUCTOR 1, DATE: OF' SURVEY: JULY ~, 1097. 2. REFERENCE FIELD BOOK: Mp97-06 (PGS. 26,30). 5. ALASKA' STATE pLAN[ COORDINATES ARE ZONE 4, NAD 27. '4. GEODEI~C 'COORDINATES ARE 'NAD 1927. 5. PAD SCALE FACTOR IS_ 0. g999 _035. 6. MomzONTAL/VER~cN. coNTRoL IS BASEO ON.MONUMENTS H--1 AND-H-2. 7. ELEVATIONS .. . L.OCA'TED ~ITHIN. PROTRACTED SECTION ~4, T; t3 N,, R.-lO E., UMiA'f U~RIDIAN ALASKA SURVI~yOR's CERTIFICATI~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND ECENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 8, 1997. WELL A.S;P~ PLANT " GEODETIC GEODETIC CIELLAR SECTION NO. COORDINATES'.: COORDINATES!pOSITIoN(DIMS;) POSlTION(O.DD;) SOX ELE,V. OFFSETS Y"6,009.g55.55 N= 1,235.-15 70'26'16.261, 70.4378503' " :2,8OS'-FSL H~9 X= :'556~470.40 E--' 760.00 -149'32'22-406" 149.'539557~': 36.9" 4,175' FEL H-lO Ym6;OOg.984.48 N-1,265.2~ 70'26'16.545"! '70;43792fi2'. - 2,83,/ FSL - X=. 556f478.67 .. E= 7&0.14 14g'.T,2'22.1.~7" 1.4g.53941~lo .. 36.9' 4T187' Frd. ~IBP EXPLORATION MILNE POINT UNIT H--PAD AS-BUILT CONDUCTORS WELLS H-g AND H-lO · WELL PERMIT CHECKLIST COMPANY ,/<~ WELL NAME /z~/~, .~-"z/~) FIELD & POOL ,~'-2_._,5~/.~'~:~ INIT CLASS ~,~.z..- -)-~)Y GEOL AREA PROGRAM: exp [] dev/~edrll [] serv [] wellbore seg r_;j ann. disposal para req UNIT# ,~,/,~.,~_.. ~ ON/OFF SHORE 43~ 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 drilling 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 APPR DATE 14. Conductor string provided ................... O N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... (~. N 17. CMT vol adequate to tie-in long string to surf csg ........ ..-,Y N 18. CMT will cover all known productive horizons .......... Cftc) N 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... d~) N 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ r_y.., N 26. BOPE press rating appropriate; test to .~Oo psig. ~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ (:~N 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N,,,,/~]/'"",~ 31. Data presented on potential overpressure zones ......... ~N ~ 32. Seismic analysis of shallow gas zones ............. N 33. Seabed condition survey (if off-shore) ............. ?/Y N 34. Contact name/phone for weeklyproclress reports ...... / Y N [explora~tory only] REMARKS GEOLOGY: ENGINEERII',J.G: COMMISSION: R P C~____, BEW ~ DWJ~~. ' JDH ,/' RNC ,~"~/,~--~ ~ Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 07/97 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of info'rmation. Sperry-Sun Drilling Services LIS Scan Utility Fri Nov 13 08:42:32 1998 Reel Header Service name ............. LISTPE Date ..................... 98/11/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/11/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPEP~ATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM-70251 HALL BURLEY MPH-10 500292279500 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 13-NOV-98 RECEIVED 13N lo~ NOV 18 1998 2834 416 7 AJa~i{8 u~ ~'. ~as (Jo.s, {50fil~i~Si0~ .00 DERRICK FLOOR: GROUArD LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 66.00 36.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 8.500 6080.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY P~LASE-4 (EWR4) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL MESSAGE FROM D. DOUGLAS FOR K. NITZBERG OF BP EXPLORATION (ALASK3~), INC ON 10/29/98 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6080'MD, 4320'TVD. SROP = SMOOTHED P~ATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA P~AY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMM~LRY PBU TOOL CODE START DEPTH STOP DEPTH RPD 4579.5 6024.5 RPM 4579.5 6024.5 RPS 4579.5 RPX 4579.5 GR 4587.0 FET 4634.0 ROP 4635.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 6024.5 6024.5 6032.0 6024.5 6080.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 4634.0 6080.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 RPX MWD OHM- 4 1 68 12 4 RPS MWD OHM- 4 1 68 16 5 RPM MWD OHM- 4 1 68 20 6 RPD MWD OHM- 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Min 4579.5 13.0466 18 5364 1 4476 1 5064 1 5295 1 7426 0 2015 First Max Mean Nsam Reading 6080 5329.75 3002 4579.5 468.377 159.203 2890 4635.5 114.797 61.4442 2891 4587 60.2347 7.38771 2891 4579.5 51.8316 7.5251 2891 4579.5 44.9845 7.32391 2891 4579.5 36.263 7.40817 2891 4579.5 6.642 0.807112 2782 4634 Last Reading 6080 6080 6032 6024.5 6024.5 6024.5 6024.5 6024.5 First Reading For Entire File .......... 4579.5 Last Reading For Entire File ........... 6080 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NLIMBER: 2 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NIIMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 4579.5 6024.5 RPM 4579.5 6024 5 RPS 4579.5 6024 5 RPX 4579.5 6024 5 GR 4587.0 6032 0 FET 4634.0 6024 5 ROP 4635.5 6080 0 $ LOG HEADER DATA DATE LOGGED: 27-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWN-HOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 6080.0 TOP LOG INTERVAL (FT) : 4634.0 BOTTOM LOG INTERVAL (FT) : 6080.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM Ai~GLE: 37.5 MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P_AY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MI/D DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MI/D CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/~DOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ................. ~...60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 62.1 TOOL NUMBER P0802CRG6 P0802CRG6 8.500 8.5 SPUD 9.80 79.0 9.0 8O0 .0 3.300 2.790 3.500 4.000 28.9 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 Name Min Max Mean Nsam DEPT 4579.5 6080 5329.75 3002 GR 18.5364 114.797 61.4442 2891 RPX 1.4476 60.2347 7.38771 2891 RPS 1.5064 51.8316 7.5251 2891 RPM 1.5295 44.9845 7.32391 2891 RPD 1.7426 36.263 7.40817 2891 ROP 13.0466 468.377 159.203 2890 FET 0.2015 6.642 0.807112 2782 First Reading 4579.5 4587 4579.5 4579.5 4579.5 4579.5 4635.5 4634 Last Reading 6080 6032 6024.5 6024.5 6024.5 6024.5 6080 6024.5 First Reading For Entire File .......... 4579.5 Last Reading For Entire File ........... 6080 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/11/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/11/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF ~IT~ $I~ ~0 pu~
