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198-169
• STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION,MMISSION °'AY 6 I 4 WELL COMPLETION OR RECOMPLETION REPORT AND LO 8 la.Well Statu ❑ Gas❑ SPLUG ElOther ❑ Abandoned El . Suspended El 1 b.Well Class: t0 20AAC 25.105 20AAC 25.110 Development ❑✓ • Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 4/24/2018 ' 198-169/318-042 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive, Suite 1400,Anchorage AK, 99503 9/1/1998 50-029-22913-00-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3552'NSL, 5118'WEL, Sec.8,T13N, R10E, UM ' 9/10/1998 MILNE PT UNIT L-45 Top of Productive Interval: 9. Ref Elevations: KB: 50.6 17. Field/Pool(s): 1431'SNL,295'WEL, Sec. 18,T13N, R10E, UM GL: 16.7 BF: MILNE POINT/SCHRADER BLUFF OIL Total Depth: 3540 SNL, 541'WEL,Sec. 18,T13N, R10E, UM 10. Plug Back Depth MD/TVD: 18. Property Designation: 9,332'/4,054' ` ADL0025509/ADL0025515 ' 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 544759.5536 . y- 6031739.048 - Zone-ASP4 • 9,365'/4,054' ' N/A TPI: x- 544346.1942 y- 6026771.462 Zone-ASP4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 544104.5119 y- 6024731.939 Zone-ASP4 N/A 1,800'(Approx.)/1,727' 5. Directional or Inclination Survey: Yes U (attached) No 0 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD/LWD&GR/RES SCANNED MAY 1 12D 18 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 13-3/8" 68 L-80 35' 120' 35' 120' 16" 260 sx 5-1/2" 15.5 J-55 33' 7,345' 33' 4,035' 7-7/8" 1,365 sx 3-1/2" 9.3 J-55 7,213' 9,365' 4,004' 4,054' 4-3/4" 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(MD/TVD) Size and Number; Date Perfd): A'w ZA • DATE 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11 112.4116 Was hydraulic fracturing used during completion? Yes❑ No ❑ VEER. 'ED Per 20 AAC 25.283(i)(2)attach electronic and printed information Aka. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate — Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINIALi .: s-` '-! Y Altvr/kfc8 REDtLRS �& Q^ 6 2C18 5,V/ 28%CORE DATA Convent Core(s): Yes ❑ No Q SidewalSs: Yes ❑ No Q • If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q • Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1,800' 1,777' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval information,including reports,per 20 AAC 25.071. Schrader Bluff NA 6,810' 6,774' Schrader Bluff NF 7,325' 4,031' Schrader Bluff OA 7,808' 4,061' 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 StP Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Contact Phone: 777-8412 Signature: Date: 4/27/2018 INSTRUCTIONS General: This orm and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injectio , 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 measure ents 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 1235), 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 u ays 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 'he 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(explai ). 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,subm t 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 ORIGIN^L Only • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-45 Coil 50-029-22913-00-00 198-169 2/17/18 4/24/18 Daily Operations: - 2/14/2018-Wednesday No activity to report. 2/15/2018-Thursday No activity to report. 2/16/2018- Friday No activity to report. 2/17/2018'-Saturday MIRU SLB CTU #6 with 15110' of 2" CT. CV=41.8 bbls. Spot unit, raise mast. RU hardline.Spot heaters. R/U cementers. MU BHA#1: 2.0" CTC, 2 x 2.15" Stingers, 2" XO, 2.15" Nozzle. MU injector and BOP to tree. Pressure test lubricator and surface lines for coil 250psi/4,500 psi. PJSM with SLB coil and cementers. Open well but keep bottom 7" casing valve closed. RIH and tag 7" valve. Flag pipe. Open 7" casing valve. RIH 2'. Flag pipe. RIH with BHA#1 and dry tag CIBP at 198' (225' corrected). POH with BHA and obtain pick up weights and practice running speed of 42 fpm. RBIH to 198' (225' corrected). Pressure test cementers surface lines. Batch mix 8 Bbls of Arcticset 1 cement(15.7 ppg). Thickening time of 4 hours. Circulate 10 Bbls fresh water(76 degrees). Circulate 8 bbls of Arcticset 1 cement. Circulate 10 Bbls fresh water. Circulate 60 Bbls Nvis gel, 10 Bbls fresh water,42 Bbls McOH;Cement is at nozzle. Let 1 Bbl get behind coil and begin POH at 42 fpm. POH to flag 2' below lower 7" casing valve. See cement returns. See fresh water returns. POH to above lower 7" casing valve. Close 7" casing valve. Increase rate to 3 BPM and jet/clean tree/ BOP/surface lines with gel and fresh water. POH to above upper 7" casing valve. Close upper 7"valve. RDMO. Open lower 7" casing valve. 2/18/2018-Sunday No activity to report. 2/19/2018- Monday No activity to report. 2/20/2018-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-45 Coil 50-029-22913-00-00 198-169 2/17/18 4/24/18 Daily Operations: 4/11/2018-Wednesday No activity to report. 4/12/2018-Thursday No activity to report. 4/13/2018 - Friday No activity to report. 4/14/2018-Saturday No activity to report. 4/15/2018-Sunday MIRU Excavation crews. Start excavation around L-45 well. SDFN. 4/16/2018- Monday Continue excavation around L-45 well. Final depth 13' below top of pad level,4.5' below original tundra level. SDFN. • • H i lcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-45 Coil 50-029-22913-00-00 198-169 2/17/18 4/24/18 Daily Operations: 4/18/2018-Wednesday No activity to report. 4/19/2018-Thursday No activity to report. 4/20/2018- Friday No activity to report. 4/21/2018-Saturday No activity to report. 4/22/2018-Sunday No activity to report. 4/23/2018- Monday MIRU Casing Cutting Crews. Make cut on production casing and conductor at 3.5' below original tundra grade. Cement to surface on both strings. Notify AOGCC to witness marker plate install tomorrow. SDFN. 4/24/2018-Tuesday Set marker plate on well and weld. AOGCC Bob Noble onsite to witness. Collect GPS coordinates: 70° 29.840' N, 149° 38.233' W. Backfill location. Photos taken to document before and after marker plate setting. „,p'ns p '' H � �9� T: - • A Ps Y. x. xm 4 r - 3 ''''''- c r a r s ' RO. �t 'Al—:''.r•••',', a a 4-:” 3. - *Z..: it- ar t S • ,*'`,,y,"46- e - ..,:k a�' xs' :e,+. # X'.` ' J « Y & ,' �. 4 °-�"Kilt' A -.�a ".•, =, 1"F ,ro v- ,,�,-M. 6 tea $fig 'S't� e ° k 3 +-'+ m "L ,� 7 k --- •"* , . , -,%t° `moi, -t; A ° h i b t � 9 � �'` y -,:e" ,taq- „� t if ., tae ' i '� . cir off . Ct f �ksY °t�2'#-a A t,41.42' »' ".tet + .3. 'F# `' s { .,' 'a• �] `ods .'i +& :„ 3c" ) • ,, Lommir W N., i"� R " „, *a s ' c R '. 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'1; -.,". .,,... -, ,-;z411,,r ;"- ',..;4—.."i4„,..,. ..,..,-- , „: "i, - “-0, 4, ',4. .„,„.„7.,,--._ roti `'' ?: � a--:< . • .: .. , 3 a � 0 r* . t �:l i4.'a.y. .4$4, , ,,, , tL , d'Dvt. t at " l q.y ,y . ;7:::::;::::.:?-4„,,,...------:,..‘,,,,,it ;a S pb a n ss d {1 ,r` pM * a Y x. s„N Y,, s t y4. ' t . 4; :t;1 4M « 4 .2 Milne Point Unit •. Well: MPU L-45 .. H 0 SCHEMATIC Abandoned: 2/17/2018 Hilcorp Alaska,LLC PTD: 198-169 TREE&WELLHEAD Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) Tree 7-1/16"5M(Temporary Tree) p �� _ `rk Wellhead 7"5M Varco ADRS-7 Weld on style tti! I. 'r7 ar,�" Tubing Hanger NSCTT&B 2"CIW H BPV Profile OPEN HOLE/CEMENT DETAIL 1 111 37"x`tom^, s" 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole I 4'� 13-3/8"5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"in a 6-3/4""Hole " ,'4"1 4.75"OH Cemented openhole w/70 bbl 15.8 ppg Class G cement(3.5"Liner Removed) 1 ,R, Tx55"X p@ er 37 CASING DETAIL t-, Size Type Wt/Grade/Conn Drift ID Top Btm j 0t2 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' 7" Prod X-Over 26/L-80/BTC 6.276 Surface 37' 5.5" Production 15.5/J-55/BTC-MOD 4.950 37' 7,345' JEWELRY DETAIL z° No Depth Item 1, _1 225' CIBP z4 2 1,009' 5.5"Port Collar Cementer Port Collar. -- using139bblCemented to surface*, using WELL INCLINATION DETAIL using 139 bbl 12.0 ppg Coldset III KOP @ 550' Max Hole Angle=97 deg. @ 9,140' Hole Angle thru screen=+/-90 deg. GENERAL WELL INFO 9.0 ppg API:50-029-22913-00-00 o Drilled and Cased by Nabors 27E -9/17/1998 Initial Completion by Nabors 4ES—10/27/1998 .`r ,'C 9` ', TOC 606.. 3v , , } r.3�"yr° y 'm 1D=9,365'(MD)/TD=4,054'(TVD) PBTD=9,332'(MD)/PBTD=4,054'(IVD) Created By:STP 4/25/2018 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg p, Q/7'�o DATE: 4/24/2018 P. I. Supervisor `( ` FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector MPU L-45 Hilcorp Alaska - PTD 1981690; Sundry 318-042 4/24/2018: I traveled to MPU L-45 to do an inspection on the cut-off of the well. On arrival, I met with Hilcorp representative Billy Kruskie. We went over the details of the cut off. All strings of pipe were found to be full of good hard cement that was placed in February 2018. The well was cut off 3 feet 6 inches below tundra grade. The marker plate is 13 3/8" in diameter by '/4" thick. It was sized so there was no overhang of the casing. It had the proper markings welded onto it: - Well name MPU L-45 - - Oil company name Hilcorp AK - - API number 50-029-22913-00 PTD number 198-169 - Everything looked to be in compliance so I told Billy Kruskie that he could weld the marker plant on and back fill the hole. I also asked to him to make sure to mound over the well and send us a notification to inspect for location clearance. Attachments: Photos (2) y' SCANNED 2018-0424_Surface_Abandon_MPU_L-45_bn.docx Page 1 of 2 i • • • et 47;` ;.• • •••:,,,,, • :'•,„, ,•_,.,,,y, ,,:4 .,,, e, , ' ...4%.‘.. "f 4...' '''lit ' . ; .It.. •..• Yy. Off. -•- + .+ " . .v° 0, • .ot . ',... •:2•' 4 : ' ..:••••, ,... ':,,,$9 •• '.... --" --,,,, 44.0' „..,22, tn 4100 ''''' 'P" ''.41*: : ;11)tiotioix - . _,ice_ �:,. f . ... k ' A N ct O a I " N U i-• CA eq .,..4 .,. oc ,_. ........ 4,.... . . .._ . 4, cl CD co CO 0 15 ▪ p r ! 41 f LO rri I . ,. epN yxV a,' " , -y + y;i O , tit r " r�kO 0 . • , • a c 0 1 _, f fes,. �}.� U 0 0J O - .Q QIlk Y ' k 1�. { r >.W ♦. . + ' ID '— co O r offs,: ., .5 / ' • 0 0_ ,. of Tfi • //7,.; ywA�`\Is THE STAT! Alaska Oil and Gas ►-t om of/` T /` SKA Conservation Commission �..•: 333 West Seventh Avenue �ITh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 1*X---, Q, Main: 907.279.1433 AASL * Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCONE° F[:1-3 1 2 01 B Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU L-45 Permit to Drill Number: 198-169 Sundry Number: 318-042 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, Hollis S. French Chair DATED this day of February, 2018. RDDMS 1 -F - .' D18 • 4'-i'ti*N‘ RECEIVED STATE OF ALASKA JAN 3 1 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑� • Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC * Exploratory ❑ Development Q 198-169 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22913-00-00 • 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 ❑., / MILNE PT UNIT L-45 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0025509/ADL 0025515 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): 9,365 4,054 6,063 3,693 1,190 225 N/A Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' N/A N/A Surface 7,345' 5-1/2" 7,345' 3,984' 4,810 psi 4,040 psi Liner 2,152' 3-1/2" 9,365' 4,054' 6,890 psi 7,400 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary ❑� Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑, Exploratory ❑ Stratigraphic❑ Development❑, . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/14/2018 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. Authorized Name: Bo York Contact Name: Stan Porhola -91 Authorized Title: Operations Manager Contact Email: sporhola(u)hiIcorp.com Contact Phone: 777-8412 Authorized SignaturcA-73jiN P4is F Date: 1/31/2018 COMMISSION USE ONLY Conditions of approotify Commission so that a representative may witness Sundry Number: /8 00(-1 Plug Integrity / BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: REDMS LL F:3 - :' ?,18 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 4 Subsequent Form Required: /0 / 0 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:- 6 Al/ 4/5 /g , 1106/ ��z-S--/S4 ORIGINAL Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • 111 Well Prognosis Well: MPU L-45 Hilcorp Alaska,LL' Date:1/31/2018 Well Name: MPU L-45 API Number: 50-029-22913-00 Current Status: Suspended Pad: L-Pad Estimated Start Date: March 14th, 2018 Rig: Coil Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-169 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) art Number ]ob'Typ Current Bottom Hole Pressure: 1,590 psi @ 4,000' TVD (Last BHP measured 2/05/2007) Maximum Expected BHP: 1,590 psi @ 4,000' TVD (No new perfs being added) MPSP: 1,190 psi (0.10 psi/ft gas gradient) Brief Well Summary: MPU L-45 was drilled with Nabors 27E as a slim-hole horizontal Schrader Bluff oil producer.The original completion was ran in October 1998 using Nabors 4ES running an ESP.The well last produced in February 2001. The well's lateral completion was plugged ahead of drilling grassroots injectors and producers on L-pad using the Nordic #3 rig in 2015. Coiled tubing spotted a 9.0 ppg brine above the plugback depth of 6,063' and wireline set a CIBP at 225'. 2/,x//4 Notes Regarding Wellbore Condition Coy cut. • Well has not produced since 2001. • 52D2Lation interval plugged back.Top of cement at 6,063' MD. • Cast Iron Bridge Plug set at 225' MD. • Surface/Production casing cemented to surface using Port Collar at 1,009' MD w/ 139 bbl of cement with cement returns to surface. • CBL log ran above CIBP at 225' on 9/13/17 shows good bonded cement from 54'-74' RKB (btm of wellhead starts at 34' RKB).Annular space between the 5-1/2" surface/production casing and 13-3/8" conductor will be filled to surface after initial cutoff as required. Objective: The purpose of this work/sundry is to complete the final plug and abandonment of the well. Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/9.0 ppg NaCI. 2. Pressure test lubricator to 3,500 psi Hi 250 Low. a. No BOPE Test is being requested since this well has been plugged back and pressure tested. b. Utilize previous BOPE test within the last 7 days to confirm BOPE functionality. • • Well Prognosis Well: MPU 1-45 Iiilrora Alaska,Lb Date: 1/31/2018 3. RIH w/2.00" coil w/2.0" to 2.5" max OD wash nozzle BHA to CIBP at 225' and circulate 15.8 ppg permafrost cement to surface. POOH. 4. RD Coiled Tubing and ancillary equipment. 5. Turn well over to production. Surface Procedure: 6.. Notify AOGCC inspectors 24 hrs prior to cutoff of wellhead and welding marker plate. 7. Excavate cellar, cut off wellhead and casing 3' below natural GL. a. If cement fell back, bring cement top to level of cut utilizing permafrost cement. b. Confirm cement to surface in the 5-1/2" x 13-3/8". Bring to surface if needed. 8. Photograph casing stub before setting marker plate. `/ 9. Set marker plate, collect GPS coordinates. ps4-- a° 4'4 10. Photograph casing stub after setting marker plate. V' 11. Backfill cellar, close out location. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic H . • Milne Point Unit Well: MPU L-45 SCHEMATIC Last Completed: 4/7/17 fiilcorp Alaska,1 LC PTD: 198-169 Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) TREE&WELLHEAD Tree 7-1/16"5M(Temporary Tree) 1 6*� Wellhead 7"5M Varco ADRS-7 Weld on style }1, Tubing Hanger NSCTT&B 2"CIW H BPV Profile , t P kt OPEN HOLE/CEMENT DETAIL WON lig 13-3/8" 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole ',1 - 5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"in a 6-3/4""Hole '` 4.75"OH Cemented openhole w/70 bbl 15.8 ,;. p ppg Class G cement(3.5"Liner Removed) 1 E T'x5.5'X Over@3T CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm .0 2 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' / 7" Prod X-Over 26/L-80/BTC 6.276 Surface 37' 5.5" Production 15.5/J-55/BTC-MOD 4.950 37' 7,345' JEWELRY DETAIL No Depth Item 1 225' CIBP Port Collar. 2 1,009' 5.5"Port Collar Cementer Cemented tosurface WELL INCLINATION DETAIL using 139 bbl 12 0 ppg Coldset III KOP @ 550' Max Hole Angle=97 deg. @ 9,140' Hole Angle thru screen=+/-90 deg. x GENERAL WELL INFO 9.0 ppg NaG Brine a API:50-029-22913-00-00 ►'' Drilled and Cased by Nabors 27E -9/17/1998 9 Initial Completion by Nabors 4ES—10/27/1998 t, 1s r; 0 As TOC 6,063 P i. r d �yyR_ f.t 2 p'' ' ~0 TD=9,365'(MD)/TD=4,054'(TVD) PBTD=9,332'(MD)/PBTD=4,054'(TVD) Created By:STP 1/26/2018 . Milne Poi Well: MPU nt L-45Unit PROPOSED Last Completed: Proposed Mean)Alaska,LLC PTD: 198-169 TREE&WELLHEAD Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) Tree 7-1/16"5M(Temporary Tree) Wellhead 7"5M Varco ADRS-7 Weld on style Tubing Hanger NSCTT&B 2"CIW H BPV Profile • OPEN HOLE/CEMENT DETAIL • 13-3/8" 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole 5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"in a 6-3/4""Hole 4.75"OH Cemented openhole w/70 bbl 15.8 ppg Class G cement(3.5"Liner Removed) 1 ',AMP_ 7'x 5.5"X- Over@37 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Q 2 13-3/8" Conductor 68/1-80/BTC-MOD 12.191 Surface 150' 7" Prod X-Over 26/L-80/BTC 6.276 Surface 37' 5.5" Production 15.5/J-55/BTC-MOD 4.950 37' 7,345' JEWRY DETAIL No Depth Item 1 225' CIBP Port Collar: a 2 1,009' S.5"PortELCollar Cementer Cemented to surface WELL INCLINATION DETAIL using 139 bbl ' 12.0 ppg Coldset III KOP @ 550' Max Hole Angle=97 deg. @ 9,140' Hole Angle thru screen=+/-90 deg. GENERAL WELL INFO 9.0 ppg NaCI Brine API:50-029-22913-00-00 Drilled and Cased by Nabors 27E -9/17/1998 Initial Completion by Nabors 4E5—10/27/1998 TOC 6,063' 10.e I k^w TD=9,365'(MD)/TD=4,054'(TVD) PBTD=9,332'(MD)/PBTD=4,054'(TVD) Created By:STP 1/31/2018 II • • COIL BOPS MILNE POINT UNIT MPU L-45 I!Hemp Ala,ka,LLC 1/31/2018 MPU L-45 13% X 5/2 Coil Tubing BOP Lubricator to injection head 0 4 2.00"Single Stripper 11.1,1, Blind/Shea--' 1/16 10 11111 Blind/Shear •111.d Jillnil AIM 1.',', Blind/Shear —�Blind/Shearl,I�' il • Ella C_ —— 000 _ Slip 2= • 11Slip 1111 am 41 0111111 Pipe o-� ... Pipe I,IIII. 014 Crossover spool 4 1/16 10M X 4 1/16 5M 7:1r Pump-In Sub . / [= 4 1/16 5M N° [% : •,. 1502 Union iso um Manual Gate Manual Gate NM Crossover spool 2 1/8 5M 2 1/8 5M 4 1/16 5M X 7 1/16 5M Valve,Upper Master,WKM-M, PDo 7 1/16 5M FE IIIIIIIIIIIIIj Valve,Lower Master,WKM-M, t7 7 1/16 5M FE .`� Ilei' Tubing Adapter,7 1/16 5M ill STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS JAN 3 1 2018 1.Operations Abandon U Plug Perforations LI Fracture Stimulate U Pull Tubing Li of Gut�(w) U Performed: Suspend Q Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Chang/Approved Program ❑ k/ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: S.4.* C( 6 P 2.Operator Hilcorp Alaska LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development Q Exploratory ❑ 198-169 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-029-22913-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0015509/ADL0025515 MILNE PT UNIT L-45 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL POOL 11.Present Well Condition Summary: /,// ��S Total Depth measured 9365 feet Plugs measured 225 ��"—/meet true vertical 4054 feet Junk measured N/A feet Effective Depth measured 6063 feet Packer measured N/A feet true vertical 3693 feet true vertical N/A feet Z --1'f Y Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 13-3/8" 115' 115' N/A N/A Surface 7,345' 5-1/2" 7,345' 3,984' 4,810 psi 4,040 psi Intermediate Production Liner 2,152' 3-1/2" 9,365' 4,054' 6,980 psi 7,400 psi Perforation depth Measured depth N/A feet .°1.-p, )nlk True Vertical depth N/A feet SCONE Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A 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 El Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG 0 GINJ ❑ SUSP Q 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: ;3167� cSr Authorized Name: Bo York Contact Name: Stan Porhola_S Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Signature: L-,A-/ .�.-_-c aril Date: 3 I +� Zo( g Contact Phone: 907-777-8412 l Z -:S'-'-/S' Form 10-404 Revised 4/2017 11i RBDMS L`-EB - 1 2018 Sub Ori 4Only • • Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Thursday, February 01, 2018 2:58 PM To: Schwartz, Guy L(DOA) Subject: Re: L-45 P&A(Sundry 3.476) 3/6 Guy, 14- Based Based on a review of the well and the fact that the surface/production casing was cemented to surface, did not want to perf the casing and run the risk of not getting cement to surface.Would rather not compromise the integrity of the 5- 1/2"casing if we already have cement to surface.The cement bond log shows a component 20'segment of cement near the top of the 5-1/2". Therefore,the plan is to fill up the 5-1/2"to surface from the CIBP to surface and fill any gap on the backside of the 5- 1/2"after cutting off the wellhead. Stan Porhola Operations Engineer On Feb 1,2018,at 11:12 AM,Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov<mailto:guy.schwartz@alaska.gov» wrote: Stan, I am trying to recall why this well was not fully P&A'd last summer as proposed in sundry 317-476.We have received a 10-404 report that stops at step#8*(CIBP set). I see the CBL/USIT was run to evaluate cement. Can you clarify what reasoning was used and what further plans for abandoning are being proposed?Doesn't look like casing was ever perfed to circulate or attempt to circulate. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at(907-793- 1226)or(Guy.schwartz@alaska.gov<mailto:Guy.schwartz@alaska.gov>). 1 • Schwartz, Guy L (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Thursday, February 01, 2018 2:30 PM To: Schwartz,Guy L(DOA) Cc: Link, Liz M (DOA); Bo York; Stan Porhola Subject: RE: L-45 P&A(Sundry 316-476) Guy Hilcorp Alaska completed steps 1 through 8 on the approved sundry 316-476. After setting the CIBP in step 8,we elected to use coiled tubing to complete the plug and abandonment of this well. Due the availability of the coiled tubing unit,we did not complete the remainder of the abandonment work per the approved sundry 316-476 prior to the sundry expiring. Therefore, we submitted the 10-404 to close out Sundry 316-476 and submitted a new 10-403 sundry on 31 January (yesterday)to complete the abandonment of this well. We apologize for the confusion on this and should have been more proactive in our communications with you to let you know the plan and schedule. Sincerely Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907) 777—8333 (w) (907)444—2881 (c) From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, February 01, 2018 12:12 PM To:Stan Porhola<sporhola@hilcorp.com> Cc: Paul Chan<pchan@hilcorp.com>; Link, Liz M (DOA)<liz.link@alaska.gov> Subject: L-45 P&A(Sundry 317-476) Stan, I am trying to recall why this well was not fully P&A'd last summer as proposed in sundry 316-476 317 476.We have received a 10-404 report that stops at step#8*(CIBP set). I see the CBL/USIT was run to evaluate cement. Can you clarify what reasoning was used and what further plans for abandoning are being proposed?Doesn't look like casing was ever perfed to circulate or attempt to circulate. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged 1 410 Mn Well:ile MPUPoint L-45Unit 1 H e SCHEMATIC Last Completed: 4/7/17 Hilcorp Alaska.LLC PTD: 198-169 TREE&WELLHEAD Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) Tree 7-1/16"5M(Temporary Tree) l Wellhead 7"5M Varco ADRS-7 Weld on style " , Tubing Hanger NSCTT&B 2"CIW H BPV Profile rv>eoH OPEN HOLE/CEMENT DETAIL 13-3/8' 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole 5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"in a 6-3/4""Hole 4.75"OH Cemented openhole W/70 bbl 15.8 ppg Class G cement(3.5"Liner Removed) t T'x55"X over@3T CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm .0 Q 2 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' 7" Prod X-Over 26/L-80/BTC 6.276 Surface 37' / . 5.5" Production 15.5/J-55/BTC-MOD 4.950 37' 7,345' JEWELRY DETAIL No Depth Item 1 225' CIBP Port Collar. 'e 2 1,009' 5.5"Port Collar Cementer Cemented to surface Vit: using 139 bbl WELL INCLINATION DETAIL 12.0 ppg Coldset III KOP @ 550' Max Hole Angle=97 deg. @ 9,140' Hole Angle thru screen=+/-90 deg. 9.0 ppg GENERAL WELL INFO ' NaCl Brine API:50-029-22913-00-00 Drilled and Cased by Nabors 27E -9/17/1998 Initial Completion by Nabors 4ES—10/27/1998 L. It. it i y„ °4 i, A ta Too a ; 6063 , eiR 55 4m i4 r i, z TD=9,365'(MD)/TD=4,054'(TVD) PBTD=9,332'(MD)/PBTD=4,054'(TVD) Created By:STP 1/26/2018 i i Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-45 Coil/E-Line 50-029-22913-00-00 198-169 10/3/16 4/6/17 Daily Operations: . . I;1r11H,09' 10/3/2016- Monday MIRU Hal 1.75" CT mast unit.Test BOPE 250/3,500 psi. RIH and tag cement plug at 6,085'. Circ 9.0 ppg inhibited brine to surface. POOH to 2,175'. Continue to POOH. Freeze protect from 250' to surface w/60/40 McOH. OOH w/coil. Start rig down. Blow down coil reel w/ Nitrogen. ND BOPE. Rig down. Demobe off L-pad. 4/6/2017 -Thursday MIRU Pollard E-Line. Well Shut in.;MU E-Line tools, setting tool, and 5-1/2" CIBP. CIBP=4.24" OD. CCL to top of plug= 9'. CCL to COE = 9.6'. CCL to Bot of plug= 10'. PU and stab on well. KB to GL=40'/ Bot of plug is 6' off GL. Set starting depth of CCL to 24' MD. PT 250/3,000 psi/Open well to 0 psi/ RIH. RIH to 266'. Log up to set depth. Stop at 215.4' CCL depth. COE at 225' (middle of joint). Fire. See indication of shearing after 1 minute. (Slow burn). PU 30' and RBIH.Tag plug at 215' CCL depth. Good set. POOH. OOH. Shut in well. BD. Pop off and L/D tools. NO CIBP. RDMO E-Line. 56 ( vu G t l6P 02-1C1 .( I W n o❑ r Borough: North Slope CO T 0 mvo 00TWaW Wc O oc� oz Held: Milne Point O _ O m m N r- 0- O ,Q . .O 3 W a 2 • 2 2 < o Location: 3552'FSL&5118' FEL cQ c o p o Well: MPL-45 2 . -0 Company: Hilcorp Alaska LLC. CD Location: D o H N 2 O 0 Or D (n en r R Z i o ii 5- ° 3 rn N CD CD 0 N CO n) -1:' P ( r- O = c 0m ccNm PQo 3 n 10 73 co o DWoacp 0 -� 0.) -6.- o. ,0 dc 73 5 ocn n oo -t 111111 N) — tD C 1111111 rJr r r- (0 2 9i- 2: °JC) va W m cn D cD3w cn N° 0- 3 0, W 5' 5' r co (.0 CD m H D 71 cn cn o _ cn m m oT — A _ Z y = ii v _v 11111111111 .i62 Ci 3 -7 ❑6 O cT W o-D '� U1 Inno `°W b o CD ; 3 Disclaimer THE USE OF AND RELIANCE UPON THIS RECORDED-DATA BY THE HEREIN NAMED COMPANY(AND ANY OF ITS AFFILIATES, PARTNERS, REPRESENTATIVES, AGENTS, CONSULTANTS AND EMPLOYEES) IS SUBJECT TO THE TERMS AND CONDITIONS AGREED UPON BETWEEN SCHLUMBERGER AND THE COMPANY, INCLUDING: (a) RESTRICTIONS ON USE OF THE RECORDED- DATA; (b) DISCLAIMERS AND WAIVERS OF WARRANTIES AND REPRESENTATIONS REGARDING COMPANY'S USE AND RELIANCE UPON THE RECORDED-DATA; AND (c) CUSTOMER'S FULL AND SOLE RESPONSIBILITY FOR ANY INFERENCE DRAWN OR DECISION MADE IN CONNECTION WITH THE USE OF THIS RECORDED-DATA. Contents 1. Header 10. Cement Evaluation DSLT DSLT CBL VDL 2. Disclaimer 10.1 Integration Summary 3. Contents 10.2 Software Version 4. Remarks and Equipment Summary 10.3 Composite Summary 5. Depth Summary 10.4 Log (Sonic CBL with VDL) 6. External Image 10.5 Parameter Listing 7. Cement Evaluation IBC USI_CEMENT 11. Calibration Report 7.1 Integration Summary 12. Tail 7.2 Software Version 7.3 Composite Summary 7.4 Log ( USI Cement) 7.5 Parameter Listing 8. Cement Evaluation IBC USI COMPOSITE 8.1 Integration Summary 8.2 Software Version 8.3 Composite Summary 8.4 Log (USI Composite) 8.5 Parameter Listing 9. Cement Evaluation IBC IBC_S111) 9.1 Integration Summary 9.2 Software Version 9.3 Composite Summary 9.4 Log ( USI IBC SLG) 9.5 Parameter Listing Remarks and Equipment Summary Objective: Evalute cement at surface for P&A. Log correla -• . . • - e ing • . .. -. : --. . •aged CBL/VDL and IBC in seperate passes due to short logging interval. ogged from CIBP @ 225'to surface. ICE Processing used for mud impedance and fluid velocity calculations USI_FVEL_SEL=Automatic USI_ZMUD_SEL=Theortical IBC OFFSET SEL=UFAO UTAN: 33deg ZTCM: 1.9 Mrayl ZCMT: 5 Mrayl ZTGS: 0.01 Mrayl Tools ran as per toolsketch. Booster kit used on USIS. Well Pressured to"500psi for logging passes. CIBP Tagged at 224' Crew: Pate, Rodgers AFE: 1751293 SON: D69W-00136 Cement Evaluation DSLT: Remarks Cement Evaluation IBC: Remarks I. Cement Evaluation DSLT: Cement Evaluation IBC: Toolstring Toolstring Equip nameength MP nameOffset LEH-QT: 41.6 11 2665 LEH-QT: 2665 CAL-YA 38.68 /1:242 Equip namlength MP nameOffset CAL-YA: CCL 37.89 LEH-QT: 38.46 242 2665 LEH-QT: 2665 EDTC-B: 35.18 1 1 8273 CAL-YA 35.55 /1 EDTH-B: :242 8264 CAL-YA: CCL 34.75 EDTG-A: CTEM 31.68 242 8260 �ACCZ 0.00 EDTC-B: HV 0.00 8273 /Gamm 29.81 /a Ray EDTC-B: 32.05 TeJSta 28.68 8273 /tus EDTH-B: CME-AF 28.68 . 8264 [2]:69EDTG-A: CTEM 28.55 8260 ACCZ 0.00 '; * ) EDTC-B: HV 0.00 8273 Gamm 26.68 `I /aRay f #' TdSta 25.55 �tus DSLT-BB 24.89CME-AF 25.55 24.89 !F ti :8325 :69 ECH-KH: 8694 A , DSLC-B:8 N�f 325 II SLS-E:13 67 USIr-D:1534 21.75 ECH-MRA USIC-D:1 834 USIS-A:9 28 USSC-B: 930 IBCS-A:8 23 FAR-SEN SOR:3941 NEAR-SE NSOR:22 CBL 3f 12.42 58 t USI-SEN Upper- 12.42 SOR:814 Near EMITTER VDL 5 11.42 -SENSOR t-w ft :2241 Upper- 11.42 Far r Delta- 10.04 <.F T r4 -Lower 8.67 -Far Lower 7.67 -Near SLS-E 4.25 CME-AF 4.25 " •,; [1]:45 (f ,\ ) USI Se 0.84 /nsor BNS-STD 0.46 Head T Head T ension ension -TOOL_ZERO ',TOOL_ZERO Lengths are in ft Lengths are in ft Maximum Outer Diameter=3.800 in Maximum Outer Diameter=3.800 in Line:Sensor Location,Value:Gating Offset Line:Sensor Location,Value:Gating Offset All measurements are relative to TOOL_ZERO All measurements are relative to TOOL_ZERO Depth Summary Cement Evaluation DSLT Cement Evaluation IBC Depth Measuring Device Type IDW-B IDW-B Serial Number 2778-2 2778-2 Calibration Date 12-Sep-2017 12-Sep-2017 Calibrator Serial Number 18 18 Calibration Cable Type 7-39AI-XS 7-39AI-XS Wheel Correction 1 -1 -1 Wheel Correction 2 -4 -4 Tension Device Type CMTD-B/A CMTD-B/A Serial Number 9804 9804 Calibration Date 31-Aug-2017 31-Aug-2017 Calibrator Serial Number 265 265 Number of Calibration Points 10 10 Calibration Root Mean Square 16 16 Error Calibration Peak Error 23 23 Logging Cable VC I-7 4(1AI VC I'NC /-J JI"n-/\J /-JJ191-/\J Serial Number F71511 F715155 • Length 24000.00 ft 24000.00 ft Conveyance Type Wireline Wireline Rig Type Rigless Rigless Cement Evaluation DSLT:Depth Control Parameters Depth Control Remarks Log Sequence Subsequent Trip To the Well SLB Depth Measurement and Control Standard and Guideline Followed. Reference Log Name Pollard CIBP Setting Record Log correlated to Pollard CIBP Setting Record dated 07-Apr-2017 using CCL. Reference Log Run Number One Depth Accuracy:0.05% Reference Log Date 07-Apr-2017 Depth Repeatability:0.02% Subsequent Trip Down Log Z-Chart used as secondary depth control. Correction Cement Evaluation IBC:Depth Control Parameters Depth Control Remarks Log Sequence Subsequent Trip To the Well SLB Depth Measurement and Control Standard and Guideline Followed. Reference Log Name Pollard CIBP Setting Record Log correlated to Pollard CIBP Setting Record dated 07-Apr-2017 using CCL. Reference Log Run Number One Depth Accuracy: 0.05% Reference Log Date 07-Apr-2017 Depth Repeatability:0.02% Subsequent Trip Down Log Z-Chart used as secondary depth control. Correction Milne Point Unit Well: MPU L-45 SCHEMATIC Last Completed: 11/11/2015 Ilii/01Q alaaka. LLC PTD: 198-169 Orig.DFElev.:56.6GLElev.:1b3'(Nabors TREE&WELLHEAD '/ Tree 16"5M Wellhead 72-1/"SM Varco ADRS-7 Tubing Hanger NSCTT&8 2"CIW H BPVWeldon Profilestyle OPEN HOLE/CEMENT DETAIL 13-3/8' 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole 5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"in a 6-3/4""Hole 4.75"OH Cemented openhole w/70 bbl 15.8 ppg Class G cement(3.5"Liner Removed) CIBP 225 r:ssx- CASING DETAIL °"max,' Size Type Wt!Grade/Conn Drift ID Top Btm 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' 6040 • 1 7" Prod X-Over 26/L-80/8TC 6.276 Surface 37' ?MOH 5.5" Production 15.5/1-55/BTC-MOD 4.950 37' 7,345' WELL INCLINATION DETAIL KOP@550' Max Hole Angle=97 deg_ @ 9,140' Hole Angle thru screen=+/-90 deg. JEWELRY DETAIL No Depth Item 1 1,009' 5.5"Port Collar Cementer GENERAL WELL INFO API:50-029-22913-00-00 84Fpg Drilled and Cased by Nabors 27E -9/17/1998 Searater Initial Completion by Nabors 4ES—10/27/1998 Temaa.10 • T,�asosxcalr Wp g ethW 4°1, *40 4,1 71)=9365'(MD}/ID=4,054'(1 VD) PBTD=9,332'(MD)/PM 4,( 1ND) Created By:STP 9/07/2016 Cement Evaluation IBC USI_CEMENT Software Version Acquisition System Version Maxwell 2017 SP3 7.3.92069.3100 Pass Summary Run Name Pass Objective Direction Top Bottom Start Stop DSC Mode Depth Shift Include Parallel Data Cement Log[8]:Up Up 43.90 ft 216.50 ft 12-Sep-2017 12-Sep-2017 ON 1.00 ft Yes Evaluation 6:10:10 PM 6:27:47 PM IBC All depths are referenced to toolstring zero Log Company:Hilcorp Alaska LLC. Well:MPL-45 Cement Evaluation IBC: LOq[81:Up:S008 Description: USI Cement Format: Log(USI Cement) Index Scale: 5 in per 100 ft Index Unit:ft Index Type: Measured Depth Creation Date: 14-Sep-2017 05:10:33 TIME_1900-Time Marked every 60.00(s) :.ERAV_IRAV':. ERAV_RHF1 Casing Collar Locator IRAV_LHF1 .:IRAV_IRAV':. Ultrasonic (CCLU) USIT D LHF1_ERAV RHF1_IRAV -20 in 20 External Radii External Radii Gamma Ray Average(ERAV) Average(ERAV) USIT-D USIT-D (ECGR_EDTC)EDTC-B 3 in 1.9 1.9 in 3 Acoustic Impedance 0 gAPI 150 Internal Radius Internal Radius Minimum(AIMN) Averaged Value Averaged Value USIT-D Stuck Tool (IRAV)USIT-D (IRAV)USIT-D 0 Mrayl 10 Indicator, Total(STIT) 3 in 1.9 1.9 in 3 Acoustic I W,nnA',nno iiii 0 tt 50 Internal Radius Internal Radius "�„a I i Maximum Value Maximum Val Average(AIAV O SP, S (pc, i USIT-D Bonded N oo N v :CableDrag= (IRMX)USIT-D (IRMX)USIT- g g g g g a o "' �' `� N "' (0 �, 0 Mrayl 10 3 in 1.9 1.9 in 3 a o ,- N `� �' Gas Casing ICollar ( � I Acoustic Locator Custom Normalization Internal Radius Internal Radius Impedance ` Liquid Custom Normalization Amplitude Minimum Value Minimum Value k,, USIT-Acoustic Impedance With (CCL) Maximum CAL-YA (IRMN)USIT-D (IRMN)USIT-D USIT-Acoustic Impedance(AIBK) (AIMX)USIT Micro-debondin Micro-debonding Image USIT-D (AI_MDEBOND_IMG)USIT-D 19 13 in 1.9 1.9 in 3 (Mrayl) 0 Mrayl u 9 (Mrayl) 10 20 30 40 l Wellhead/Liner Hanger- L. -' — I. . . ,z — - 50� . — . . . . Last Reading ---- • • , 60 • • • • e ,..,.:7,0*-4,....-..:: ' " , . 1.:ks,;, ,,t:\s,"‘ ' ‘A:',:".',:::,,,,,:,-,,I744,v,„:._\ ._. k 70 . F � '.,,-- ter- , • . _�°s':^;.lh. ""`""" �. • • . . . 8 0 _. "1 • . • • , 90 • s 100i- . . .......__.... -......4, r, ▪ • • � • • 110 • . • • • . , mt 'C • • _ • • ,. m 120 ., 130 d • �� . 140 i ▪• • _ M. • • 15 • • . • • - �. • • , 160 � e . • • -: . . • I:.:•:.:.• „ 3 - - ;,� I � s per,, ��.,��: ,.".--•',,,- , s ;"el,'s' ' ' 4' ,,-1,4,,„al, :—:-.,-*'''''' .',,x. •▪••• h . . ,,,„ _, .1., ,4,q"...Aro, SlT • • • • • ^�: fix. x ¢fi ➢in `f ay., „ 210iff.... '''' , , .7'. 1: '';,:ii, _.*.irairsic t'''''' ';,-,"+,,°:' 4': ,. .•;II ---I– --I----:--}-4---- — o o 0 0 0 0 0 o Acoustic 0 COC0 CO N M a Casing Collar ••ERAV_IRAV••• ERAV_RHF1 o N Bonded .0 0 — M Locator a Impedance a Ultrasonic 1 :,rpt? Minimum(AIMN) En (CCLU) IRAV_LHF1 • IRAV_IRAV• •• USIT-D Ili M .. USIT-D Custom Normalization Custom Normalization -20 in 20 LHF1_ERAV RHF1_IRAV USIT-Acoustic Impedance(AIBK) 0 Mrayl 10 Liquid USIT-Acoustic Impedance With USIT-D Acoustic Micro-debonding Image Gamma Ray External Radii External Radii (Mrayl) Impedance Micro-debondin (AI_MDEBOND_IMG)USIT-D (ECGR_EDT Average(ERAV) Average(ERAV) Average(AIAV) g (Mrayl) C)EDTC-B USIT-D USIT-D USIT-D 0 gAPI 150 3 in 1.9 1.9 in 3 0 Mrayl 10 Stuck Tool Internal Radius Internal Radius Acoustic Indicator, Averaged Value Averaged Value Impedance Total (STIT) (IRAV)USIT-D (IRAV)USIT-D Maximum 0 ft 50 3 in 1.9 1.9 in 3 (AIMX)USIT-D 0 Mrayl 10 — Internal Radius Internal Radius -CableDrag— Maximum Value Maximum Value I (IRMX)USIT-D (IRMX)USIT-D Casing Collar Locator 3 in 1.9 1.9 in 3 Amplitude (CCL) Internal Radius Internal Radius CAL-YA Minimum Value Minimum Value 19 1 (IRMN)USIT-D (IRMN)USIT-D 3 in 1.91.9 in 3 TIME_1900-Time Marked every 60.00(s) Description: USI Cement Format: Log(USI Cement) Index Scale:5 in per 100 ft Index Unit:ft Index Type: Measured Depth Creation Date: 14-Sep-2017 05:10:33 Channel Processing Parameters Cement Evaluation IBC: Parameters Parameter Description Tool Value Unit ISSBAR Barite Mud Presence Flag Borehole No BHS Borehole Status(Open or Cased Hole) Borehole Cased BS Bit Size WLSESSION Depth Zoned in CBLO Casing Bottom(Logger) WLSESSION 7345 ft CCL MULTIPLIER Casing Collar Locator Multiplier CAL-YA 1 CDEN Cement Density USIT-D 0 g/cm3 CDEN Cement Density EDTC-B 2 g/cm3 CMTY(U-USIT_CEMT) Cement Type USIT-D Regular Cement DC MODE Depth Correction Mode DepthCorrection Real-time DFD Drilling Fluid Density Borehole 7.56 Ibm/gal DFT_CATEGORY Drilling Fluid Type Borehole Water DTMD Borehole Fluid Slowness Borehole 206 us/ft FD Fluid Density USIT-D 1.2 g/cm3 FDII FPM Data Interpolation Interval USIT-D 0 ft GCSE DOWN PASS Generalized Caliper Selection for WL Log Down Passes Borehole BS(RT) GCSE UP PASS Generalized Caliper Selection for WL Log Up Passes Borehole BS(RT) HEMA Hematite Presence Flag Borehole No FSOD USIT IBC Fluid Slowness Fits Casing Outer Diameter USIT-D 0 OFF IBC_FVEL_SEL BC Fluid Velocity ion USIT-D • Automatic IBC OFFSET SEL IBC Flexural Offset Srctor USIT-D UFAO IBC_ZMUD_SEL IBC Mud Impedance Selection USIT-D Theoretical ICE_PROCESS ICE Processing USIT-D Yes IMAR Image Rotation USIT-D Off MEAS_WLEN Tcube Processing Window Length in Measurement Mode USIT-D Depth Zoned us U-USIT_DFSZ Drilling Fluid Specific Acoustic Impedance USIT-D 0 Mrayl U-USIT_UFAO SIT Flexural Attenuation Offset USIT-D -12.19 dB/m UFGDE Fiberglass Density USIT-D 1.95 g/cm3 UFGPS Fiberglass Processing Selection USIT-D No UFGVL Fiberglass Velocity USIT-D 9678.48 ft/s U-USIT_UIAP IBC Answer Product Enabled USIT-D SolidLiquidGasMap ZMUD Acoustic Impedance of Mud Borehole 1.48 Mrayl ZTCM Acoustic Impedance Threshold for Cement USIT-D 1.9 Mrayl ZTGS Acoustic Impedance Threshold for Gas USIT-D 0.01 Mrayl Depth Zone Parameters Parameter Value Start(ft) Stop(ft) BS 16 9.17 150 BS 5.5 150 216.5 MEAS_WLEN 22.5 9.17 37 MEAS_WLEN 16.95 37 216.5 All depth are actual. Tool Control Parameters Cement Evaluation IBC: Parameters Parameter Description Tool Value Unit AGMN Minimum Gain of Cartridge USIT-D -4 dB AGMX Maximum Gain of Cartridge USIT-D 48 dB U-USIT_DDT5 USIC Downhole Decimation for T5 only USIT-D 0_NONE EMXV EMEX Voltage USIT-D Time Zoned V HRES Horizontal Resolution USIT-D 5 deg MAX_LOG_SPEED Toolstring Maximum Logging Speed WLSESSION 1125 ft/h TMUC Type of Mud USIT-D BRI U-USIT_UFWB Far Receiver Window Begin Time USIT-D 138 us U-USIT_UFWE Far Receiver Window End Time USIT-D 178 us ULOG Logging Objective USIT-D MEASUREMENT U-USIT_UNWB Near Receiver Window Begin Time USIT-D 107 us U-USIT UNWE Near Receiver Window End Time USIT-D 147 us UPAT USIT Emission Pattern USIT-D Pattern 600 KHz UWKM USIT Working Mode USIT-D 5 deg at 3.0 in HF USIT_DEPTHLOG Starting Depth Log for Ultrasonics USIT-D 1000 ft U-USIT_UTAN Transducer Angles USIT-D 33_DEG VRES Vertical Resolution USIT-D 3.0 in WINB Window Begin Time USIT-D 34.09 us WINE Window End Time USIT-D 74.09 us Time Zone Parameters Parameter Value Start Time Stop Time Start Depth(ft) Stop Depth(ft) EMXV 35 12-Sep-2017 18:10:10 12-Sep-2017 18:17:54 216.5 176.06 EMXV 38 12-Sep-2017 18:17:54 12-Sep-2017 18:23:58 176.06 95.05 EMXV 12-Sep-201718:23:58 12-Sep-2017 18:27:47 95.05 43.9 All depth are at tool zero. Cement Evaluation IBC USI_COMPOSITE Software Version Acquisition System Version Maxwell 2017 SP3 7.3.92069.3100 Pass Summary_ IIIMIMMIIIIIIIIIMMIMIIIII Run Name Pass Objective Direction Top Bottom Start Stop DSC Mode Depth Shift Include Parallel Data Cement Log[8]:Up Up 43.90 ft 216.50 ft 12-Sep-2017 12-Sep-2017 ON 1.00 ft Yes Evaluation 6:10:10 PM 6:27:47 PM IBC All depths are referenced to toolstring zero Log Company:Hilcorp Alaska LLC. Well:MPL-45 Cement Evaluation IBC: Loa 8 :U•:S008 Description: USI Composite Format: Log(USI Composite) Index Scale: 5 in per 100 ft Index Unit:ft Index Type: Measured Depth Creation Date: 14-Sep-2017 05:10:38 TIME_1900-Time Marked every 60.00(s) USIT Processing Flags(UFLG[0])USIT-D 1 -UFLG 1 Value within[0.0-1.5]- : • UTIM Error 2-UFLG 2 Value within[1.5-2.44]- : • Pulse Origin Not Detected 3-UFLG 2 Value within [2.44-2.5]- : 1 Spiky Waveform 4-UFLG 3 Value within [2.5-3.5]- : II WINLEN Error 5-UFLG 4 UFLG 5 UFLG 6 Value within [3.5-6.5]- : II Casing Thickness Error 6-UFLG 7 UFLG 8 UFLG 9 Value within [6.5-10]- : El Loop Processing Error --CableDrag= (Azimuth of Eccentering 000 0 N N o ERAV IRAV (AZEC) Q ' "'N ci USIT-D INE ••ERAV-IRA ERAV 0 deg 360 Explicit • V Normalizatio :IRAV-ERA': Casing Collar n IRAV V ' Locator Ultrasonic USIT Median of Median of Minimum of Amplitude of (CCLU) Unflagged Unflagged Unflagged Ratio of a- USIT D Unflagged Cement 2 N aCO Wave External External Casing a -20 in 20 (AWBKRF) Radii Radii Thickness Measuremen - USIT-D (ERAV_RF) (ERAV_RF) (THMN_RF) is to Total Amplitude of USIT-D USIT D USIT-D (CEMR) Custom Eccentering (dB) USIT-D Normalizatio for Unflagged Minimum of 3 in 1.9 1.9 in 3 0.1 in 0.6 n Waves Unflagged 1 0 USIT- (ECCE_RF) Wave Median Median Nominal Acoustic USIT-D Internal Internal Casing Micro-debond Amplitude Radius of Radius of Thickness ing Ratio Impedance 0 in 0.5 (AWMNRF) Casing Casing (THNO) (MDR) (AIBK) USIT-_D Corrected for Corrected for USIT-D E• 7, 0, Co USIT-D USIT-D Motor 0 dB 75 Eccentering Eccentering . o 0 0 0 1 0 (Mrayl) Revolution 0 0 0 0.1 in 0.6 C COCO 0 0 0 (IRAV RF) (IRAV_RF) N �, 0 M Speed a -' N "5 Average of USIT-D USIT-D °' 'r.:' :=',: 0 '';'• Median of Ratio of Gas Q RSAV � � � � � (RSAV) Unflagged a Unflagged Explicit Measuremen ' USIT-D Wave 3 in 1.9 1.9 in 3 IN .1111 Explicit Casing Normalizatio is to Total -8 cis -6 Nnrmali7atin Amplitude Maximum of Maximum of Explicit Thickness n E. o 0 0 0 (GASR) Custom n (AWAV_RF) Unf ged Unflagged Normalizatio (THAV_RF) AilLSIT- Q . M USIT-D Normalizatio Motor USIT-D Int adii Internal Radii n USIT-D n Revolution USIT-USIT lip(IR _RF) (IRMX_RF) agged 1 0 USIT CasingUSIT- Speed Processing 0 dB 75 0.1 in 0.6 (RSAV) Flags(UFLG) USIT-D USIT-D Unflagged Thickness Custom Bonded Acoustic Normalizatio USIT-D USIT-D Maximum of 3 in 1.9 1.9 in 3 Internal Radii Maximum of minus Impedance Unflagged minus Unflagged Median of n With 6 cls 8 USIT Minimum of Minimum of Wave Median Casing Unflagged USIT- Micro-debond Stuck Tool Processing Amplitude Unflagged Unflagged Internal Thickness Casing Acoustic � " ing Image Flags Internal Radii Internal Radii Liquid��� Indicator, (AWMX_RF) Radius (THMX_RF) Thickness Impedance �� (AI_MDEBO Total(STIT) (USIT D)) USIT-D (I US T DF) (I USIT DF) (IRBKM_RF) USIT-D (THBKM_RF) (AIBK) Micro debo ND_IMG) 0 ft 50 0 dB 75 USIT-D 0.1 in 0.6 USIT-D USIT-D USIT-D 1 6 3 in 1.9 1.9 in 3 (in) (in) (Mrayl) nding (Mrayl) . •` �Sl 14� _ .—...._ n +^4^ k} _ a J0 LVi r � 507, "..'i' ' Wellhead/Liner Hanger ? . ii. Last Reading ' ,� s 6:601 I 1 . �� , i •. w m• as rM ,1: : , likw . .; • • --f- •- - • • : - • • x . 0 fil .•.I' I{.•. i % t. I • •• . y. , 1Q . , i t. 1♦Q x' .ti 30 ' I, 0, t[([ t 4 , High Eccenteringl � 1 , k :� « 11 . �tiii.,. .„,t, itt 1 1, )' ;M ,.. { ,.. , t • .. t1 •.• ..•. ., . .• •. . ,,, ., ..., i, . r •1 « ry w.W . • • S 8T :: so h • 1 14 1•8d� , Y',', RSAV i, iii; oi . ., Hlgh Eccentering ▪i ' ' '� % « 210 J1),`t x' ;_ C O O O C 0 0 0 0 C - N (�O C N (00 C 0 0 0 0 C O -CableDra N `g ° N N OERAV IRAV _2 0 0 0 0 Minimum of .2 0 0 0 0 _ 40 M 40 Ratio of 12 N 40 4.6 g 2, CV cfl �f'i M N Cl-; -_--- – I i— Q a Q . . unnaggea a . . a uement a Azimuth of Casing 1, Measuremen rm. EccenteringExplicit ERA ERAV Thickness is to Total Explicit V • Explicit THMN_RF explicit Custom CEMR Custom AZEC Normalizatio ( ) ( ) ( ) Normalizatio ' Normalizatio Normalizatio Normalizatio Normalizatio USIT-D n .IRAV-ERA.'. USIT-D USIT-D 0 deg 360 USIT n -USIT USIT- IRAV V USIT- 0.1 in 0.6 USIT USIT 1 0 USIT Processing Amplitude of Median of Median of Unflagged Unflagged Acoustic Acoustic Casing Collar Flags(UFLG) Unflagged Unflagged Unflagged Intemal Radii Nominal Casing Impedance Micro-debond Impedance Locator USIT-Dg External External minus Casing Thickness (AIBK) ing Ratio (AIBK) Ultrasonic USIT (AWBK_RF) Radii Radii Median Thickness minus USIT-D (MDR) USIT-D (CCLU) Processing USIT-D (ERAV RF) (ERAVRF) Internal (THNO) Median of (Mrayl) USIT-D (Mrayl) USIT-D Flags (dB) USIT-D USIT-D Radius USIT-D Unflagged 1 0M -20 in 20 (UFLG[0]) (IRBKM_RF) 0.1 in 0.6 Casing Minimum of 3 in 1.9 1.9 in 3 Ratio of Gas USIT-D USIT-D — Thickness Amplitude of Unflagged Median of (THBKM_RF) Measuremen Eccentering 1 6 Wave Median Median (in) Unflagged s to Total for Unflagged Amplitude Internal Internal Casing USIT-D i(GA Tot) Custom Waves (AWMN_RF) Radius of Radius of Thickness (in) USIT-D Normalizatio (ECCE RF) USIT-D Casing Casing (THAV_RF) n USIT-D Corrected for Corrected for USIT-D 1 0 USIT- 0 dB 75 Eccentering Eccentering Acoustic 0 in 0.5 (IRAV ) (_RF IRAV ) _RF 0.1 in 0.6 Bonded Average of Impedance USIT-D USIT-D With Motor Unflagged Maximum ofEll Revolution Wave 3 in 1.9 1.9 in 3 Unflagged Micro-debond Speed Amplitude Maximum of Maximum of Casing ingg Image (RSAV) (AWAV_RF) Unflagged Unflagged Thickness Liquid (AI_MDEBO USIT-D USIT-D Intema9Radii Internal Radii (THMX_RF) ND IMG) -8 c/s -6 0 dB 75 (IRMX_RF) (IRMX_RF) USIT-D Micro-debo USIT-D USIT-D USIT-D0.1nding (Mrayl) Motor in 0.6 Revolution Maximum of 3 in 1.9 1.9 in 3 Speed Unflagged (RSAV) Wave Minimum of Minimum of USIT-D Amplitude Unflagged Unflagged (AWMX_RF) Internal Radii Internal Radii 6 c/s 8 USIT-D (IRMNRF) (IRMN_RF) Stuck Tool USIT-D USIT-D 0 dB 75 Indicator, 3 in 1.9 1.9 in 3 Total(STIT) 0 ft 50 USIT Processing Flags(UFLG[0])USIT-D 1 -UFLG 1 Value within[0.0-1.5]- : II UTIM Error 2-UFLG 2 Value within [1.5-2.44]- : • Pulse Origin Not Detected 3-UFLG 2 Value within[2.44-2.5]- : • Spiky Waveform 4-UFLG 3 Value within[2.5-3.5]- : • WINLEN Error 5-UFLG 4 UFLG 5 UFLG 6 Value within [3.5-6.5]- : II Casing Thickness Error 6-UFLG 7 UFLG 8 UFLG 9 Value within[6.5-10]- : 0 Loop Processing Error TIME_1900-Time Marked every 60.00(s) Description: USI Composite Format: Log (USI Composite) Index Scale:5 in per 100 ft Index Unit:ft Index Type: Measured Depth Creation Date: 14-Sep-2017 05:10:38 Channel Processing Parameters Cement Evaluation IBC: Parameters Parameter Description Tool Value Unit ISSBAR Barite Mud Presence Flag Borehole No BS Bit Size WLSESSION Depth Zoned in CDEN Cement Density USIT-D 0 g/cm3 CMTY(U-USIT_CEMT) Cement Type USIT-D Regular Cement THNO Nominal Casing Thickness-Zoned along logger depths WLSESSION 0.275 in (`VuTI nv (' �, vela c�.o,,,.�h_�.,.,a,a�I,..,..Innnor.ioNL.c \MI CFCCInA1 ccnnn rte; DC_MODE Depth Correction MO Depth Correction 0 Real-time DFD Drilling Fluid Density Borehole 7.56 Ibm/gal DFT_CATEGORY Drilling Fluid Type Borehole Water DTMD Borehole Fluid Slowness Borehole 206 us/ft FD Fluid Density USIT-D 1.2 g/cm3 FDII FPM Data Interpolation Interval USIT-D 0 ft HEMA Hematite Presence Flag Borehole No FSOD USIT IBC Fluid Slowness Fits Casing Outer Diameter USIT-D 0_OFF IBC_FVEL_SEL IBC Fluid Velocity Selection USIT-D Automatic IBC OFFSET SEL IBC Flexural Offset Selector USIT-D UFAO IBC_ZMUD_SEL IBC Mud Impedance Selection USIT-D Theoretical ICE_PROCESS ICE Processing USIT-D Yes IMAR Image Rotation USIT-D Off MEAS_WLEN Tcube Processing Window Length in Measurement Mode USIT-D 16.95 us U-USIT_DFSZ Drilling Fluid Specific Acoustic Impedance USIT-D 0 Mrayl U-USIT_UFAO SIT Flexural Attenuation Offset USIT-D -12.19 dB/m UFGDE Fiberglass Density USIT-D 1.95 g/cm3 UFGPS Fiberglass Processing Selection USIT-D No UFGVL Fiberglass Velocity USIT-D 9678.48 ft/s U-USIT_UIAP IBC Answer Product Enabled USIT-D SolidLiquidGasMap ZMUD Acoustic Impedance of Mud Borehole 1.48 Mrayl ZTCM Acoustic Impedance Threshold for Cement USIT-D 1.9 Mrayl ZTGS Acoustic Impedance Threshold for Gas USIT-D 0.01 Mrayl Depth Zone Parameters Parameter Value Start(ft) Stop(ft) BS 16 43.25 150 BS 5.5 150 216.5 All depth are actual. .. ..... .......... Tool Control Parameters Cement Evaluation IBC: Parameters Parameter Description Tool Value Unit AGMN Minimum Gain of Cartridge USIT-D -4 dB AGMX Maximum Gain of Cartridge USIT-D 48 dB U-USIT_DDT5 USIC Downhole Decimation for T5 only USIT-D 0_NONE EMXV EMEX Voltage USIT-D Time Zoned V HRES Horizontal Resolution USIT-D 5 deg MAX_LOG_SPEED Toolstring Maximum Logging Speed WLSESSION 1125 ft/h TMUC Type of Mud USIT-D BRI U-USIT_UFWB Far Receiver Window Begin Time USIT-D 138 us U-USIT_UFWE Far Receiver Window End Time USIT-D 178 us ULOG Logging Objective USIT-D MEASUREMENT U-USIT_UNWB Near Receiver Window Begin Time USIT-D 107 us U-USIT_UNWE Near Receiver Window End Time USIT-D 147 us UPAT USIT Emission Pattern USIT-D Pattern 600 KHz UWKM USIT Working Mode USIT-D 5 deg at 3.0 in HF USIT_DEPTHLOG Starting Depth Log for Ultrasonics USIT-D 1000 ft U-USIT_UTAN Transducer Angles USIT-D 33_DEG VRES Vertical Resolution USIT-D 3.0 in WINB Window Begin Time USIT-D 34.09 us WINE Window End Time• USIT-D • 74.09 us Time Zone Parameters Parameter Value Start Time Stop Time Start Depth(ft) Stop Depth(ft) EMXV 35 12-Sep-2017 18:10:10 12-Sep-2017 18:17:54 216.5 176.06 EMXV 38 12-Sep-2017 18:17:54 12-Sep-2017 18:23:58 176.06 95.05 EMXV 35 12-Sep-2017 18:23:58 12-Sep-2017 18:27:47 95.05 43.9 All depth are at tool zero. Cement Evaluation IBC IBC_SLG Software Version Acquisition System Version Maxwell 2017 SP3 7.3.92069.3100 Pass Summary Run Name Pass Objective Direction Top Bottom Start Stop DSC Mode Depth Shift Include Parallel Data Cement Log[8]:Up Up 43.90 ft 216.50 ft 12-Sep-2017 12-Sep-2017 ON 1.00 ft Yes Evaluation 6:10:10 PM 6:27:47 PM IBC All depths are referenced to toolstring zero Log Company:Hilcorp Alaska LLC. Well:MPL-45 Cement Evaluation IBC: Loa[81:Up:S008 Description: USI IBC SLG Format: Log(USI IBC SLG) Index Scale: 5 in per 100 ft Index Unit:ft Index Type: Measured Depth Creation Date: 14-Sep-2017 05:10:43 TIME_1900-Time Marked every 60.00(s) USIT Processing Flags(UFLG[0])USIT-D 1 -UFLG 1 Value within[0.0-1.5]- : • UTIM Error 2-UFLG 2 Value within[1.5-2.44]- : • Pulse Origin Not Detected 3-UFLG 2 Value within [2.44-2.5]- : • Spiky Waveform 4-UFLG 3 Value within [2.5-3.5]- : 1 WINLEN Error 5-UFLG 4 UFLG 5 UFLG 6 Value within[3.5-6.5]- : • Casing Thickness Error 6-UFLG 7 UFLG 8 UFLG 9 Value within [6.5-10]- : • Loop Processing Error ................. .................. ................. .................. Cable Drag ▪Tool_Tot./ ▪ Drag /////// Azimuth of Eccentering (AZEC) USIT-D 0 deg 360 Casing Collar Locator Ultrasonic (CCLU) USIT-D 0 0 0 0 -20 in 20 N N CO o � Q SLG White M N O Amplitude of 1 Points Ratio Eccentering (USLGWR) (ECCE) Explicit USIT-D Alnrm oli7ofinn IV USIT-D VIIIIaIILauu" 1 0 USIT Amplitu o 0 0 0 o amp 0 in 0.5 of Wave(AWB Q " Minimum SLG Liquid Ratio Flexural (USLGLR) USIT-D Acoustic Attenuation ( ) Revolution (dB) Impedance Custom USIT-D Speed Minimum(AIMN) (U-USIT_UFAN) p Amplitude of Normalization USIT-D 1 0 (RSAV) Wave Minimum USIT-D USIT Acoustic USIT-D : § (AWMN)USIT-D -1 Mrayl 9 Impedance 50 dB/m 200 SLG Cement 6 cls 7.5 < N 0 dB 75 (AIBK)USIT-D Average Flexural Ratio(USLGLR) Acoustic Attenuation USIT-D t.J tr .,ni.r. Explicit Impedance c (Mrayl) (U-USIT_UFAV) o 0 0 0 L gi : 1 0 Amplitude of M o o 0 Normalization Average(AIAV) N USIT-D E o o 0 0 o — N M Wave Average USIT-D a — "' `a `o a ' itv , - USIT-USIT (AWAV)USIT-D 50 dBlm 200 White points Processing Flags -1 Mrayl 9 n �' Explicit ' (UFLG)USIT-D 0 dB 75 Custom Maximum Custom Normalization CM Acoustic Normalization Flexural Normalization Stuck Tool USIT Processing Amplitude of Impedance USIT-Solid -= P Attenuation Indicator, Flags(UFLG[0]) Wave Maximum USIT-Acoustic USIT Flexural Liquid Gas 9 ( [ 1) Maximum (U-USIT_UFAX) q Liquid Total(STIT) USIT-D (AWMX)USIT-D (AIMX)USIT-D Impedance USIT-D Attenuation Sorted Color 0 ft 50 1 6 0 dB 75 (AIBK)USIT-D (UFAK)USIT-D Map(USLP) Cement -1 Mrayl 9 (Mrayl) 50 dB/m 200 (dB/m) USIT-D Wellhead/Liner Hanger .. -, 50 Ir. Last Reading g '„ = ' C il p � _ ' - . ■�' 11 asimmis a. I ' 'liElillE - ' "Ii-!..-41ralli4 . .... ��� fix +., .:_ /t`� Y.a' ...„. ....„.... .. . .,.. ,i . �. ...... - i_ 7, - -„,-,.. L __ _,Itir ,., ., . ��- - _ a.S� L„ ,. -t , , , . . .i., k, „rim i i it .- 1111111111r i'tt'i 111111r. 7- ::' ----- I'• -_-.P- ,, t ir_ r c _ AMR .. 1::-: -,... ti _ dillOgr HighEccenteringI '. %', ��'-- �.... Z — _ I 7 M (, . - -X/IL -. - H• - 4 :. ) ..iff' ••• ,,,. , ............... ........ •nri -. _ q. . • .• _ . — dna . ,i• S T ao 1 A • F It A. i „,. , -,..10 ..4 1111.1%"'01 :',,-- lt ., % , , ail, - -*: IiiV RSAV • , 4,,, 1, . High Eccentering I ! 1pit.- ` J' 23.0 m�c�m �r��mim ' J b 0 o O ... 8888 ......... Acoustic ....... 0 0 0 0 ..... 0 0 0 o O o 0 0 :•`:'” : N s s U N N 0 0 8 N F, F, § Minimum N 0 0 0 0 N § U) 0 SLG White Cable Drag :: N M N o N Sia o N a a Impedance ¢ Flexural a . Si a Points Ratio 2222/// „.< Minimum(AIMN) 1 gm Attenuation 1 , (USLGWR) • /Tool_Tot./ Explicit USIT-D U-USIT_UFAN Explicit USIT-D / Drag / p Explicit Custom ( ) Custom p /i/ rr/ Normalization Normalization -1 Mrayl 9 Normalization USIT-D Normalization Normalization 1 0 Azimuth of USIT-USIT USIT Amplitude USIT Acoustic 50 dB/m 200 USIT-Flexural USIT-Solid Eccentering Processing Flags Acoustic Attenuation Liquid Gas SLG Liquid Ratio AZEC (UFLG)USIT-D of Wave(AWBK) Impedance Impedance Average Flexural Sorted Color (USLGLR) (AZEC) USIT-D (AIBK)USIT-D Attenuation (UFAK)USIT-D USIT-D USIT-D USIT ProcessingAverage(AIAV) Map(USLP) (dB) USIT-D (Mrayl) (U-USIT_UFAV) (dBlm) USIT-D 0 deg 360 Flags(UFLG[0]) M o USIT-D 1 0 Amplitude of -1 9 " ., N USIT-D Mrayl � � M � � Casing Collar Wave Minimum a 50 dB/m 200 SLG Cement Locator 1 6 (AWMN)USIT-D Acoustic ii MEMORatio(USLGCR) UltrasonicImpedance Maximum USIT-D 0 dB 75 Maximum Custom Flexural (CCLU) Normalization Attenuation 1 0 USIT-D Amplitude of (AIMX)USIT-D Wave AverageUSIT-Acoustic (U-USITUFAX) 1 Mrayl 9 -20 in 20 (AWAY) Impedance USIT--D White points Amplitude of (AIBK)USIT-D 50 dB/m 200 Eccentering 0 dB 75 (Mrayl) El (ECCE) Amplitude of USIT-D Liquid Wave Maximum 0 in 0.5 (AWMX)USIT-D Motor 0 dB 75 Cement Revolution Speed (RSAV) USIT-D 6 cls 7.5 Ultrasonic Azimuth (U CAZ) USIT-D 0 deg 360 Stuck Tool Indicator, Total(STIT) 0 ft 50 USIT Processing Flags(UFLG[0])USIT-D 1 -UFLG 1 Value within[0.0-1.5]- : • UTIM Error 2-UFLG 2 Value within [1.5-2.44]- : • Pulse Origin Not Detected 3-UFLG 2 Value within[2.44-2.5]- : • Spiky Waveform 4-UFLG 3 Value within [2.5-3.5]- : • WINLEN Error 5-UFLG 4 UFLG 5 UFLG 6 Value within[3.5-6.5]- : • Casing Thickness Error 6-UFLG 7 UFLG 8 UFLG 9 Value within [6.5-10]- : • Loop Processing Error TIME_1900-Time Marked every 60.00(s) Description: USI IBC SLG Format: Log(USI IBC SLG) Index Scale:5 in per 100 ft Index Unit:ft Index Type: Measured Depth Creation Date: 14-Sep-2017 05:10:43 Channel Processing Parameters Cement Evaluation IBC: Parameters Parameter Description Tool Value Unit ISSBAR Barite Mud PresenSg Borehole • No BS Bit Size WLSESSION Depth Zoned in CDEN Cement Density USIT-D 0 g/cm3 CMTY(U-USIT_CEMT) Cement Type USIT-D Regular Cement DC MODE Depth Correction Mode DepthCorrection Real-time DFD Drilling Fluid Density Borehole 7.56 Ibm/gal DFT_CATEGORY Drilling Fluid Type Borehole Water DTMD Borehole Fluid Slowness Borehole 206 us/ft FD Fluid Density USIT-D 1.2 g/cm3 FDII FPM Data Interpolation Interval USIT-D 0 ft HEMA Hematite Presence Flag Borehole No FSOD USIT IBC Fluid Slowness Fits Casing Outer Diameter USIT-D 0_OFF IBC_FVEL_SEL IBC Fluid Velocity Selection USIT-D Automatic IBC OFFSET SEL IBC Flexural Offset Selector USIT-D UFAO IBC_ZMUD_SEL IBC Mud Impedance Selection USIT-D Theoretical ICE_PROCESS ICE Processing USIT-D Yes IMAR Image Rotation USIT-D Off MEAS_WLEN Tcube Processing Window Length in Measurement Mode USIT-D 16.95 us U-USIT_DFSZ Drilling Fluid Specific Acoustic Impedance USIT-D 0 Mrayl U-USIT_UFAO SIT Flexural Attenuation Offset USIT-D -12.19 dB/m UFGDE Fiberglass Density USIT-D 1.95 g/cm3 UFGPS Fiberglass Processing Selection USIT-D No UFGVL Fiberglass Velocity USIT-D 9678.48 ft/s U-USIT_UIAP IBC Answer Product Enabled USIT-D SolidLiquidGasMap ZMUD Acoustic Impedance of Mud Borehole 1.48 Mrayl ZTCM Acoustic Impedance Threshold for Cement USIT-D 1.9 Mrayl ZTGS Acoustic Impedance Threshold for Gas USIT-D 0.01 Mrayl Depth Zone Parameters Parameter Value Start(ft) Stop(ft) BS 16 43.25 150 BS 5.5 150 216.5 All depth are actual. Tool Control Parameters Cement Evaluation IBC: Parameters Parameter Description Tool Value Unit AGMN Minimum Gain of Cartridge USIT-D -4 dB AGMX Maximum Gain of Cartridge USIT-D 48 dB I U-USIT_DDT5 USIC Downhole Decimation for T5 only USIT-D 0_NONE EMXV EMEX Voltage USIT-D Time Zoned V HRES Horizontal Resolution USIT-D 5 deg MAX_LOG_SPEED Toolstring Maximum Logging Speed WLSESSION 1125 ft/h TMUC Type of Mud USIT-D BRI U-USIT_UFWB Far Receiver Window Begin Time USIT-D 138 us U-USIT_UFWE Far Receiver Window End Time USIT-D 178 us ULOG Logging Objective USIT-D MEASUREMENT U-USIT_UNWB Near Receiver Window Begin Time USIT-D 107 us U-USIT_UNWE Near Receiver Window End Time USIT-D 147 us UPAT USIT Emission Pattern USIT-D Pattern 600 KHz UWKM USIT Working Modal USIT-D . 5 deg at 3.0 in HF USIT_DEPTHLOG Starting Depth Log Itrasonics USIT-D 1000 ft U-USIT_UTAN Transducer Angles USIT-D 33_DEG VRES Vertical Resolution USIT-D 3.0 in WINB Window Begin Time USIT-D 34.09 us WINE Window End Time USIT-D 74.09 us Time Zone Parameters Parameter Value Start Time Stop Time Start Depth(ft) Stop Depth(ft) EMXV 35 12-Sep-2017 18:10:10 12-Sep-201718:17:54 216.5 176.06 EMXV 38 12-Sep-2017 18:17:54 12-Sep-2017 18:23:58 176.06 95.05 EMXV 35 12-Sep-2017 18:23:58 12-Sep-2017 18:27.47 95.05 43.9 All depth are at tool zero. Cement Evaluation DSLT DSLT_CBL_VDL Software Version Acquisition System Version Maxwell 2017 SP3 7.3.92069.3100 Pass Summary Run Name Pass Objective Direction Top Bottom Start Stop DSC Mode Depth Shift Include Parallel Data Cement Log[8]:Up Up 46.98 ft 224.76 ft 12-Sep-2017 12-Sep-2017 ON 0.00 ft Yes Evaluation 2:24:14 PM 2:32:23 PM DSLT All depths are referenced to toolstring zero Log Company:Hilcorp Alaska LLC. WeII:MPL-45 Cement Evaluation DSLT: Locif8l:UD:S008 Description: CBL_VDL Format: Log(Sonic CBL with VDL) Index Scale: 5 in per 100 ft Index Unit:ft Index Type: Measured Depth Creation Date: 14-Sep-2017 05:10:45 I—BIEP-Bond Index Event Pips DSLT-BB TIME_1900-Time Marked every 60.00(s) Stuck Tool Indicator, Total(STIT) 0 ft 50 Cable Tension Gamma Ray(ECGR_EDTC)EDTC-B (TENS) 0 gAPI 150 1000 lbf 0 Transit Time for CBL(TT)DSLT-BB CBL Amplitude(CBL)DSLT-BB Cable Drag Min Amplitude Max 400 us 200: ...•.•.•.•.•.•.•.•.•.•.•.•.•.•.;.; 0 mV 100 Casing Collar Locator Amplitude(CCL)CAL-YA/ToolTot. CBL Amplitude(CBL)DSLT-BB Variable Density Log(VDL)DSLT BB -19 1 ▪ Drag 0 mV 10 200 us 1200 _ ▪10 20 IF Ilhead/Liner Hanger IL III la "11111E 5'ILast Reading fir- : -I r__ :: .-- iiiiiiin ,,,„.., _ .....,, „ . ,,,,, .., .._ , ,..,,,,,,...3, ,,,. - 6 ii IVIL. NM ..l.,,,,::::,,',',‘,:',:s.,,,,,,,, .,,,, t i ' - , ,,,, . i - I8d ' ' . ,,,,,,„111111111111/ 90 I A' . WI - -align ,:' ' 11*- , , -. ,- 140 _ ., , 4 4, 110 - - - _ : 1 _ MI1;0 j ,,L A t 1 ` .... .: W �0 __ _ .„ , .. ..... : _ M10 ,, . i 1111 1,50 7 111, Mr 160 ` M. 170 i - 7M 180 o- SEM . 1s0 2n0 2iiENS - - la - . `First ReadingIF --.....--- ......_ _.__ .. ........... -.......-- --..... _ _..._.... zio Gamma Ray(ECGR_EDTC)EDTC-B Stuck Tool CBL Amplitude(CBL)DSLT-BB Min Amplitude Max Indicator, P 0 gAPI 150 0 mV 100 Total(STIT) Variable Density Log (VDL)DSLT-BB Transit Time for CBL(TT)DSLT-BB 0 ft 50 _ CBL Amplitude(CBL)DSLT-BB 200 us 1200 400 us 200 0 mV 10 Cable Casing Collar Locator Amplitude(CCL)CAL-YA Tension -19 1 (TENS) IUUU IDT U 110 able Drag:: .................. ............. . ..................... /Tool Tot.4 Drag TIME_190O-Time Marked every 60.00(s) I-BIEP-Bond Index Event Pips DSLT-BB Description: CBL_VDL Format: Log(Sonic CBL with VDL) Index Scale: 5 in per 100 ft Index Unit:ft Index Type: Measured Depth Creation Date: 14-Sep-2017 05:10:45 Channel Processing Parameters Cement Evaluation DSLT: Parameters Parameter Description Tool Value Unit ISSBAR Barite Mud Presence Flag Borehole No BHS Borehole Status(Open or Cased Hole) Borehole Cased BS Bit Size WLSESSION Depth Zoned in CBLG CBL Gate Width DSLT-BB 71 us CBLO Casing Bottom(Logger) WLSESSION 7345 ft CBRA CBL LQC Reference Amplitude in Free Pipe DSLT-BB Depth Zoned mV CCL_MULTIPLIER Casing Collar Locator Multiplier CAL-YA 1 CDEN Cement Density EDTC-B 2 g/cm3 CMCF CBL Cement Type Compensation Factor DSLT-BB Depth Zoned DC_MODE Depth Correction Mode DepthCorrection Real-time DETE Delta-T Detection DSLT-BB El DFD Drilling Fluid Density Borehole 7.56 Ibm/gal GCSE_DOWN_PASS Generalized Caliper Selection for WL Log Down Passes Borehole BS(RT) GCSE_UP_PASS Generalized Caliper Selection for WL Log Up Passes Borehole BS(RT) GOBO_CURR Good Bond in Arbitrary Cement DSLT-BB Depth Zoned mV MAHTR Manual High Threshold Reference for first arrival detection DSLT-BB 120 MATT_CURR Maximum Attenuation in Arbitrary Cement DSLT-BB Depth Zoned dB/ft MCI Minimum Cemented Interval for Isolation DSLT-BB Depth Zoned ft MNHTR Minimum High Threshold Reference for first arrival detection DSLT-BB 100 MSA Minimum Sonic Amplitude DSLT-BB Depth Zoned mV MSA_CURR Minimum Sonic Amplitude in Arbitrary Cement DSLT-BB Depth Zoned mV NMSG Near Minimum Sliding Gate DSLT-BB 240 us SGAD Sliding Gate Status DSLT-BB Off SGDT Sliding Gate Delta-T DSLT-BB 56 us/ft ZCMT Acoustic Impedance of Cement DSLT-BB 5 Mrayl Depth Zone Parameters Parameter Value Start(ft) Stop(ft) BS 16 9.17 150 BS 5.5 150 224.75 CBRA 62 9.17 37 CBRA 71 37 224.75 CMCF 0.45 9.17 37 CMCF 0.37 37 224.75 GOBO CURR 5.47 9.17 37 GOBO CURR 2.84 37 224.75 MATT_CURR 9.46 9.17 37 MATT_CURR 12.46 37 224.75 MCI 21.689.17 150 MCI 4.75 • 150 • 224.75 MSA 1.33 9.17 37 MSA 0.46 37 224.75 MSA_CURR 2.98 9.17 37 MSA_CURR 1.27 37 224.75 All depth are actual. Tool Control Parameters Cement Evaluation DSLT: Parameters Parameter Description Tool Value Unit MODE DSLT Acquisition Mode DSLT-BB CBL RATE DSLT Firing Rate DSLT-BB 15 Hz DTFS DSLT Telemetry Frame Size DSLT-BB 536 MAX_LOG_SPEED Toolstring Maximum Logging Speed WLSESSION 5000 ft/h Calibration Report DSLT-BB (Digitizing Sonic Logging Tool - BB) Calibration - Run Cement Evaluation DSLT Primary Equipment: Sonic Logging Sonde E supports 3'-5'BHC DT and CBLNDL SLS-E 1367 CBL Normalization - CBL Accumulations Master(Measured): 09:26:08 04-Jul-2017 Measurement Unit Phase Nominal Low Limit Actual High Limit 1 Upper Far Amplitude Master 4200.0 3200.0 3581.1 rill-1 Upper Near Raw Amplitude mV Master 33.000 27.000 29.617 43.000 1—TW1-7 Lower Far Amplitude Master 4200.0 3200.0 3488.5 Lower Near Raw Amplitude mV Master 46.000 27.000 33.559 68.000 CBL Normalization - CBLNDL Coefficients Master(Measured): 09:26:08 04-Jul-2017 Measurement Unit Phase Nominal Low Limit Actual High Limit I CBL Correction Factor for UT Master 3.500 2.700 3.917 4.300 CBL Correction Factor for LT Master 2.500 1.700 3.457 4.300 VDL Ratio between UT and LT for CBLB Mode Master 1.000 0.974 I--r--1 EDTC-B (Enhanced Digital Telemetry Cartridge - Version B) Calibration - Run Cement Evaluation IBC Primary Equipment: EDTC-B EDTC-B 8273 Calibration Parameter: Plus Reference EDTC-B Memory Data - EDTC-B Memory Data Master(EEPROM): 17:49:43 12-Sep-2017 Measurement Unit Phase Nominal Low Limit Actual High Limit 1 Initial PMT HV V Master 1511.000 Accelerometer Serial Number Master 541 Accelerometer Coefficients-0 Master — -- 3.009E+000 -- ( I Accelerometer Coefficients-1 Master -- --- 2.816E-004 --- ( I 1 Accelerometer Coefficients-2 Master -- --- 2.713E-007 -- Accelerometer Coefficients-3 Master -- -- -4.816E-008 -- Accelerometer Coefficients-4 Master -- -- 1.194E-009 — I I I Accelerometer Coefficients-5 Master — -- -9.051E-012 -- Accelerometer Coefficients-6 Master — -- 2.319E-014 -- Accelerometer Coefficients-7 Master — -- -2.530E-003 -- I I I Accelerometer Coefficients-8 Master — --- 5.936E-005 -- 1-1--1 Accelerometer Coefficients-9 Master -- -- -2.111E-008 — IM Accelerometer Coefficients-10 Master -- 6.616E-010 -- Accelerometer Coefficients-11 Master -- --- 3.292E-013 -- Gamma-Ray Detector Serial Number Master 7436MI Company: Hilcorp Alaska LLC. Schlumberger Well: MPL-45 Field: Milne Point Unit Borough: North Slope State: Alaska Cement Evaluation Log CAL-Y / EDTC / DSLT / IBC-A 13-September-2017 \.0,,i_ `c,01 • • Debra Oudean Hilcorp Alaska, LLC 8 6 GeoTech 3800 Centerpoint Drive, Suite 1400 Q Anchorage, AK 99503 Tele: 907 777-8337 Hilr+arp Alaska,TM: , ECEIVED Fax: 907 777-8510 DATA LOGGED E-mail: doudean@hilcorp.com koi3o/2o1Z OCT 2 4 2017 K.BENDER DATE 10/23/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPL-45 Cement Evaluation Log CAL-Y/ EDTC / DSLT/ IBC-A CD 1 : MPL-45 ►: Hilcorp_MPL-45 IBC CBL_13SEP17 FINAL 9/22/201712:33 PM File folder SCANWCU Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: • Or T�� • • 0.- //7,///,mss. THE STATE Alaska Oil and Gas tip►"s����, of T esKA Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g UT Main: 907.279.1433 SY' Fax: 907.276.7542 www.aogoc.alaska.gov Bo York ,. E H f._.'1 i Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB L-45 Permit to Drill Number: 198-169 Sundry Number: 316-476 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this 2a day of September, 2016. RBDMS LEEP 2 6 2016 ' • • . F E STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 'EF 1 5 20 lb il APPLICATION FOR SUNDRY APPROVALS GCC 't 20 AAC 25.280 1.Type of Request: Plug&Abandon O Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other. MBE Treatment❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. 198-169 ' c a=Z 4x Hilcorp Alaska,LLC Exploratory ❑ Development Q M. �E 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22913-00-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 i Will planned perforations require a spacing exception? Yes ❑ No ❑✓ f MILNE PT UNIT SB L-45 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0025509/ADL0025515 4 MILNE POINT/SCHRADER BLUFF OIL POOL. 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): 9,365' • 4,054' • 9,332' • - 4,054' 1,190 6,063' N/A Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' N/A N/A Surface 7,345' 5-1/2" 7,345' 3,984' 4,810psi 4,040psi Liner 2,152' 3-1/2" 9,365' 4,054' 6,980psi 7,400psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development❑., ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/26/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q , 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola STP Email sporhola( hilcorD.com Printed Name Bo York Title Operations Manager Signature ./ ,/,00, Phone 777-8345 Date 9/12/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `'C Plug Integrity Y / BOP Test El Mechanical Integrity Test ❑ Location Clearance [i]/ / Other: , - p/ / 6 ,---"-.4-4-1- Pf ec 4 S -c� I !' i9i.�"4,/ .e el ia[moi,„ Post Initial Injection MIT Req'd? Yes ❑ No ❑ C- 9. L 2-t IL, Spacing Exception Required? Yes ❑ No 07 Subsequent Form Required: !0 `{07 RBDMS -t-"SEP 2 6 2016 APPROVED BY Approved by:(11",47/9 -e4__ `F ,, COMMISSIONER THE COMMISSION Date:_ L aM 76(41//s- , 1-1/ 674. A24 1-z(--/‘ 4GIIIN (, Subs in Form ane Form 10-403 Revised 11/2015 A e ij'gl r 12 months from the date of approval. Attachments in Duplicate . 1 El 0 • • Well Prognosis Well: MPU L-45 Hilcorp Alaska,LL Date:9/12/2016 Well Name: MPU L-45 API Number: 50-029-22913-00 Current Status: Suspended Pad: L-Pad Estimated Start Date: September 26t", 2016 Rig: Coil/Wireline Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-169 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: a�'' w: Job Type: P&A �4) Current Bottom Hole Pressure: 1,590 psi @ 4,000' TVD (Last BHP measured 2/05/2007) (, era ' Maximum Expected BHP: 1,590 psi @ 4,000' TVD (No new perfs being added) MPSP: 1,190 psi (0.10 psi/ft gas gradient) i Brief Well Summary: MPU L-45 was drilled with Nabors 27E as a slim-hole horizontal Schrader Bluff oil producer.The original completion was ran in October 1998 using Nabors 4ES running an ESP. The well last produced in February 2001. The well's lateral completion was plugged ahead of drilling grassroots injectors and producers on L-pad using the Nordic#3 rig in 2015. Notes Regarding Wellbore Condition • Well has not produced since 2001. • Completion interval plugged back.Top of cement at 6,063' MD. Objective: The purpose of this work/sundry is to complete the final plug and abandonment of the well. Brief Procedure: Coiled Tubing Procedure: ( 'j'laei. 1<w F 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/9.0 ppg NaCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. � ' p b. • • A I _ --.. • . • es I : ;• - l'l'' t < i' - %.-. ,..' i''' ...i' 400�!C14.it, )r / -si- c. ••. t-i i •.ys. 3. RIH w/1.75" coil w/1.75" to 2.5" max OD wash nozzle BHA and circulate well over to 9.0 ppg NaCI brine w/corrosion inhibitor to PBTD at+/-6,063' MD. 4. PU to 250' and freeze protect well. POOH w/coil. 5. RD Coiled Tubing and ancillary equipment. 6. Turn well over to production. -reA,r '5i•-a- / b '1/1-4's-1,,,,_,)/ /... 7-?..i-it, 1 cif, (-tem' ' s**""t • • Well Prognosis Well: MPU L-45 IIilcorp Alaska,LI. Date:9/12/2016 Wireline Procedure: 7. MIRU Wireline. PT lubricator to 2,000 psi. 8. RIH and set 5.5" 15.5# Bridge Plug at±225' MD. POOH. 9. RIH and punch holes in 5.5" 15.5#casing at±220' MD. POOH. 10. RU Little Red Services. Pressure test lines to 2,000 psi. 11. Confirm circulation to surface thru punch holes w/pump truck w/freeze protect fluid. 12. Contingency: (If circulation holes do not circulate). a. RIH and punch holes in 5.5" 15.5#casing at 5' increments above previous holes. POOH. b. Confirm circulation to surface thru punch holes w/pump truck w/freeze protect fluid. 13. RD Little Red Services. 14. RD Wireline. 15. MIRU Cement Puming Unit. PT lines to 2,000 psi. 16. Mix and bullhead ±25 bbl of 15.6 ppg Permafrost cement to surface. 17. RDMO Cement Pumping Unit. Surface Procedure: 18. Notify AOGCC inspectors 24 hrs prior to cutoff of wellhead and welding marker plate. 19. Excavate cellar, cut off wellhead and casing 3' below natural GL. a. If cement fell back, bring cement top to level of cut. 20. Photograph casing stub before setting marker plate. 21. Set marker plate, collect GPS coordinates. p?,„. 7 J,.4A-c- 2S•I L‘) 22. Photograph casing stub after setting marker plate. 23. Backfill cellar, close out location. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic • Milne Well: MPUPoint L-45Unit SCHEMATIC Last Completed: 11/11/2015 Mem")Alaska,LLC PTD: 198-169 TREE&WELLHEAD Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) Tree 2-1/16"5M €k l F,4 Wellhead 7"5M Varco ADRS-7 Weld on style s V Tubing Hanger NSCTT&B 2"CIW H BPV Profile "r 4T IM OPEN HOLE/CEMENT DETAIL 13-3/8' 13-3/8" 260 sx Arcticsetl Approx)in a 16"Hole 5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"in a 6-3/4""Hole 4.75"OH Cemented openhole w/70 bbl 15.8 ppg Class G cement(3.5"Liner Removed) 7"x5.5'x- CASING DETAIL Over @37' Size Type Wt/Grade/Conn I Drift ID Top Btm 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' 60/40 0 1 7" Prod X-Over 26/L-80/BTC 6.276 Surface 37' McOH 5.5" Production 15.5/J-55/BTC-MOD 4.950 37' 7,345' WELL INCLINATION DETAIL KOP @ 550' Max Hole Angle=97 deg. @ 9,140' Hole Angle thru screen=+/-90 deg. JEWELRY DETAIL No Depth Item 1 1,009' 5.5"Port Collar Cementer GENERAL WELL INFO API:50-029-22913-00-00 84ppg Drilled and Cased by Nabors 27E -9/17/1998 Seawater Initial Completion by Nabors 4ES—10/27/1998 eil a ,k , s. Top of Cement "i, it Tagged 6,063 CTM ,° 1 `',-0 L 5 i k� It 55" A. fir$ , ptt :mss 9. � ; p ',.',10- w v' at fir` x 'r 't +, . $ TD=9,365'(MD)/TD=4,054'(TVD) PBTD=9,332'(MD)/PBTD=4,054'(TVD) Created By:STP 9/07/2016 • • Milne Point Unit 14Well: MPU L-45 PROPOSED Last Completed: Proposed Bacon)Alaska,LLC PTD: 198-169 TREE&WELLHEAD Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) Tree 2-1/16"5M ."*""tet A Wellhead 7"5M Varco ADRS-7 Weld on style 'a � `� a 'i t, Tubing Hanger NSCTT&B 2"CIW H BPV Profile >a r- ' OPEN HOLE/CEMENT DETAIL sr#-% Pay " t�' #v 't t 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole 13 3/8 . , ,�,y. V' , r 5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"in a 6-3/4""Hole s ;# +f - 4.75"OH Cemented openhole w/70 bbl 15.8 �`�, p ppg Class G cement(3.5"Liner Removed) Surface Cemented to surface w/+/-25 bbl 7"x5.5'X Over@37 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 0 2 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' 7" Prod X-Over 26/L-80/BTC 6.276 Surface 37' 5.5" Production 15.5/J-55/BTC-MOD 4.950 37' 7,345' JEWELRY DETAIL No Depth Item 1 225' CIBP(25 bbl cement circulated above) 2 1,009' 5.5"Port Collar Cementer WELL INCLINATION DETAIL KOP @ 550' Max Hole Angle=97 deg. @ 9,140' Hole Angle thru screen=+/-90 deg. soppg GENERAL WELL INFO NaO Bine API:50-029-22913-00-00 Drilled and Cased by Nabors 27E -9/17/1998 Initial Completion by Nabors 4ES—10/27/1998 lt, 177 ,a„ kh y V 9; it 6 y} !t e 5.5" gr a 'mss €-44:x -1. .-ti.;,.; TD=9,365'(MD)/TD=4,054'(TVD) PBTD=9,332'(MD)/PBTD=4,054'(TVD) Created By:STP 9/12/2016 •• • 0 Milne Point Unit 1 n COIL BOPE MPU L-45 9/12/2016 Nileorp%Isvika.tit MPU L-45 13% x534 Coil Tubin• BOP To injection head - 1.75"Double Stripper 1111 Lubricator 111 1 e� EII•',I, Blind 1/1615 Blind .�.'• ,,..1111111111111 mli IIIIIIIIIIIII- 1).01000Eill 1.010.1.1 0111111111011111 L•LI,I Slip PIE Mile SlipElk .I,'. J•I,I, Pipe = mumpa = Pipe 111114 _01 Crossover spool 4 1/16 15M X 41/16 10Mm>s' in; iiii Crossover spool zetimirl 41/16 10M X 4 1/16 5M 9/�a Pump-In Sub � � �Y� 9 `e `ii 41/165M •us k:'(°�• !iI!J ::(0-1 ,�IIili 1502 Union int iae Manual Gate Manual Gate Crossover spool 2 1/8 5M 2 1/8 5M 4 1/16 5M X 7 1/16 5M Valve,Upper Master,WKM-M, i 7 1/16 5M FE ».iia., Valve,Lower Master,WKM-M, °* 74 7 1/16 5M FE '4;;;1.9, Tubing Adapter,7 1/16 5M 111 1 i'n gni AOi STATE OF ALASKA KA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Plug&Abandon L lug Perforations Fracture Stimulate ❑ Pull Tubing U Operations shutdown ❑ Performed: V 'Suspend Perforate ❑ Other Stimulate [1 Alter Casing❑ Change Approved Program ❑ Plug for Redrill El arforate New Pool El Repair Well ❑ Re-enter Susp Well❑ �L Other: 7 0-5P Z 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development❑✓ Exploratory❑ 198-169 3.Address: Stratigraphic Service❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-50-029-22913-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0015509/ADL0025515 MILNE PT UNIT SB L-45 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL POOL 11.Present Well Condition Summary: CD Total Depth measured 9,365 feet Plugs measured 6,033 feet true vertical 4,054 feet Junk measured N/A feet:7)Cp 1 2016 5 Effective Depth measured 9,332 feet Packer measured N/A feet"r true vertical 4,054 feet true vertical N/A fee Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' N/A N/A Surface 7,345' 5-1/2" 7,345' 3,984' 4,810psi 4,040psi Liner 2,152' 3-1/2" 9,365' 4,054' 6,980psi 7,400psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED FED 2 3 2NU1 Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A .\ Intervals treated(measured): N/A 1/- t Treatment descriptions including volumes used and final pressure: N/A e t, .,4-1 i ‘6 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pre ure Prior to well operation: 0 0 0 900 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 ❑✓ Exploratory❑ DevelopmentLi Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: ( ei'":, r` Gas WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR El ❑ WAG EI GINJ ❑ /) ABDN 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: 315-541 Contact Stan Porhola Email sporholahilcorp.com S Printed Name Bo York Title Operations Engineer Signature Phone 777-8345 Date 9/12/2016 i /..,_ /D- S-i6 � ,/� RBDMS Uv SEP 1 6 2016 Form 10-404 Revised 5/2015 A/ / Submit Original Only II 0 Mime PointPU Unit We SCHEMATIC Last Completed: 11/11/2015 Hilcmrp Alaska,LLC PTD: 198-169 TREE&WELLHEAD Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) Tree 2-1/16"5M ;, l \i t Wellhead 7"5M Varco ADRS-7 Weld on style Tubing Hanger NSCTT&B 2"CIW H BPV Profile O / ke 13 3/8" 5.5" 818 sx Coldset III,191 sx FoamedPENHOLE Coldset CEMENT II&356 sx FoamedDETAIL 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole Class"G"in a 6-3/4""Hole 4.75"OH Cemented openhole w/70 bbl 15.8 ppg Class G cement(3.5"Liner Removed) 7'x65'X CASING DETAIL Over @37 Size Type Wt/Grade/Conn Drift ID Top Btm 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' 60/40 0 1 7" Prod X-Over 26/L-80/BTC 6.276 Surface 37' Medi 5.5" Production 15.5/J-55/BTC-MOD 4.950 37' 7,345' WELL INCLINATION DETAIL KOP@550' Max Hole Angle=97 deg. @ 9,140' Hole Angle thru screen=+/-90 deg. JEWELRY DETAIL No Depth Item 1 1,009' 5.5"Port Collar Cementer GENERAL WELL INFO API:50-029-22913-00-00 84 ppg Drilled and Cased by Nabors 27E -9/17/1998 Seanater Initial Completion by Nabors 4ES—10/27/1998 . / P 4 ,, ti Top of Cement i4 Tagged 6,063 CTM s;," L',J \\* F ._.y -.A.Rw 'yw"t "HTM#i l:4 5 5 A, " ,' , i , is= "= TD=9,365'(MD)/TD=4,054'(TVD) PBTD=9,332'(MD)/PBTD=4,054'(TVD) Created By:STP 9/07/2016 �� �� ~� Hilcorp Alaska, UU �- ^-^-~~ Weekly OperationsSummary .� Well Name Rig API Number Well Permit Number Start Date End Date MP L-45 Nordic#3 50'029'22913'80'00 198'169 9/17/15 11/12/15 9/16/2015-Wednesday No activity to report. 9/17/2015�Thursday Spot Rig over L-45. Spot rig support equipment. Berm up rig. Spot Flow back Tank, rig up hard line to same. PT hard line with air. Rig up squeeze manifold to Tree. Pull BPV with 950psi on tbg and 900psi on annulus. Begin loading pits with Sea Water. Load 2'3/8": handling equipment in Rig. PT lines to 2,000psi Bleed presure off and start pumping 8.5 sea water. Noticed pressure was increasing (fast) shut pumps down and checked the valve alignment and found out that the Hyd. safety valve on the Tree bled off to the closed position, contacted Pad Operator open. Continue pumping down the tubing taking returns up the IA pumping @ 2.5 bpm 190psi on the tubing 550 on the casing, after pumping calculated volume, pump was shut down to monitor pressure, while monitoring pressure would increase to 108psithis process was repeated 4 times with a total of 404bbl. pumped 338bbl. returned (84% returns) Decision was made to Bullhead 150bbl. down the IA (]0bbiover ca}c) 9/18/2015 - Friday Continue well kill operations, buUheadi 180bb| downU\ �D1'2bon� vv�hgS8toiShut down pump and noonhor well with pressure decline to 300psi in 1 hr. Bleed IA and Tbg down to zero. Shut in with stablized SICP and SITP @ 23Opsi Monitor shut in pressures while mixing 9.2 KWM. Shut in pressures decreased from 230pdto 170psi while mixing KWM. Line up to flow back tank. Pump 80 9.2 Brine down tubing through GLM @ 3,446' taking returns up the IA out to the flow back tank @ 3 bpm with 920psi, holding 150psi back pressure on the choke. Shut in Tbg and Bullhead down 90 bbls down the IA with FCP @ 1,030psi @ 2 bpm. Down on pump. Monitor well. Reverse circulate 1 hole volume from GLM @ 3,446' with 9.2 ppg in/out. Monitor well with 130pxi build after 10 minutes. Continue to monitor Shut in Pressures while W/O truck with Salt. Shut in pressures fell from 130psi to 80psi. SALT ON LOCATION @ 17:00 hrs Begin mixing and increase MW to 9.5 ppg. Circ. 9.5 the long way,taken retun the bleed off tank. pumping @ 3.4 bpm 826psi. Shut in and monitor well. Starting psi 63 end 103. Reverse circ. 63bbl @ 3bpm 450psi to clear tbg.Start bullheading 140bbls down IA @ 2bpm establishing an injection pressure of93Upoi Shut down pump and monitor well with pressure decline to 648psi in 10min. Bleed IA and Tbg down to zero. Shut in with stablized SICP and SITP @ 100psi. Blow down and monitor well. Pressure deceasing every blow down lOpsi. Back side dead.Tbg 3opsi. Reversed 15 of 9.Sppg and allowed IA and Tbg to U-tube. After 45min 0 pressure on both sides. Continue to monitor until Cannron arrived to set BPV. Nipple down Tree. Nipple up BOP's. 9/19/2015-SaturdaY Continued to N/D Tree, Inspect lift threads, threads good. N/U Bop,andassociated equipment. Pull BPV with IA and TBG on vac. Set TWC.TesBOP as Per Sundry with 0 failures.Test witness waived by Bob Noble of AOGCC. PJSM, Check for pressure on IA. IA on Slight Vac. Pull TWC, Fluid in tbg static. MU landing jt BOLDS. Unseat Tbg Hgr @ 75K. Pump down tbg with returns after 10 bbls. Close annular, Circulate btm up pumping down tbg taking returns to the flow back tank 2 3.3bpm vv/8S0psi FCP. Pump 8Ubb|sVVR'6soap pill @ 2bpm w/385psi taking returns to flow back tank. Let soak 30 min. Displace soap pill to flow back tank with 9.2 ppg. Pull hanger to floor and disconnect ESP penetrator and heat trace connect to reel-up spools, and L/D 7 X 2-3/8" hanger. POOH. Lay down Z-3/8" tubing and ESP, periodically monitoring well for flow. Stop @ S,637'circ.'B/U due to incorrect hole fill 3bpm 295psi Monitor well after B/U (no flow no gas). Continue POOH. Lay down 2'3/8" tubing and ESP, periodically monitoring well for flow. I Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-45 Nordic#3 50-029-22913-00-00 198-169 9/17/15 11/12/15 pally Operations 9/20/2015 -Sunday Continue POOH laying down 2-3/8" ESP completion f/4,000'. Lay down Btm GLM .Tbg below GLM is plugged off. Continue to Pull ESP completion pulling wet.The last 6 jts above the pump were sanded off. Lay down ESP Pump Assembly. Clean oil off floor,tools and walls. Rig down equipment, off load 2-3/8" tubing out of pipe shed &Tally 2-3/8" work string. Laydown 5" drillpipe out of derrick. 9/21/2015- Monday Continue to laydown 5" drillpipe out of derrick. Rig up crane and fly out ESP and Heat Trace Spoolers and associated equipment. Rig up 1-1/2" handling equipment. Run in hole picking up 1-1/2" CSH work string with 30' mule shoe to 2,200'. Change over handling equipment to 2-3/8".TIH picking up 2-3/8" PH-6 work string to 7,005'. Start watching for fill from 7,005'to TOL @ 7,213'. Wash in hole cleaning out 3-1/2" slotted liner from 7,213' to 8,288' @ lbpm 500psi. Rev circ @ 8,288' 2bpm 860psi to ensure that debris doesn't avalanche back in the hole around work string. Continue RIH F/8,288'to 9,332' (Did not encounter any fill in the 3-1/2" slotted liner). Rev circ @ 9,332' 3.5bpm 950psi. Opened up Annular and circ. long way to even out brine 8.7. 9/22/2015 -Tuesday Continue to circulate from 9,368' to balance well with 8.8ppg brine. Monitor well on trip tank.TOH from 9,368' laying down 2-3/8" PH-6 work string to 7,058'. CBU from 7,085' pumping 3.5 bpm, 2,500psi,flowcheck well, confirm wellbore breathing @ 3.5 bph. POH from 7,085' L/D 2-3/8" PH6 work string to 2,200', note: at 3,800'taking correct hole fill. 20 bbls under calculated hole fill due to wellbore breathing, flowcheck well, static. POH, L/D 1.5" CSH and mill shoe. Offload 1.5" CSH from pipeshed, monitor well using trip tank, well static. M/U fishing tools as follows, Itco releasing spear w/3.63" grapple, spear extension, spear stop, bumper sub, XO = 13.51', P/U and RIH with 2-3/8" PH6 work string to 7,160'. Correct fluid displacement on trip in the hole. M/U XO and top drive, P/U 67K, S/O 57K, ROT 64K. Circulate hole clean pumping 2.5 BPM, 1500 PSI. Note: 439u gas @ BU. Wash down pumping 1 bpm, 230psi 1/7,160'to 7,213'tag 3-1/2"TOL setting down 5k, p/u 20'with no overpull, set down 10k. Shut down pump. Pull 125k, 150k, 175k and then 185K max pull on 2-3/8" PH6 (including block wt of 35k) slacking off and setting down 10k each time. Continue to pull 185k and slack off setting down 10k several times attempting to free liner w/no movement.Turn pipe to the right 2 turns, release spear, flowcheck well, static. Blow down top drive. POH L/D 2-3/8" work string f/7,213' to 6,500'. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-45 Nordic#3 50-029-22913-00-00 198-169 9/17/15 11/12/15 Daily Operations: 9/23/2015 -Wednesday POH L/D 2-3/8" work string F/6,500'T/surface. L/D baker spear& Grapple assembly. Clean &Clear floor. Notified state of upcoming BOP test on L-20 for in the morning. P/U Weatherford 5.5 WRP with 4.5 OD. RIH while P/U 2-3/8" workstring T/2,007'. RBP set @ 2,007.7'. Pressure up down the tubing to 4,000psi. No shift. P/U pull 5k over on plug. Pressure up to 5,000psi &feel a shift in the tool along with 10K loss in wt. P/U 2' with no drag and 5K still lost.Attempt to circ down the 4`r›) tubing and pressure up. Bleed down. Line up for a casing test and pump down back side and tubing to 1,500ps._Chart for cif 30 min. Good test. Bleed down tubing and backside bled down. Good communication. R/U LRS to reverse circulate, close upper pipe ram, reverse circulate and displace the well with 50 bbls diesel pumping 1.7 bpm, 650 psi. R/D LRS, open upper pipe ram. Blow down topdrive and choke manifold. PJSM, POH from 2,000' L/D 2-3/8" PH6 work string and running tool. Clean rig floor. Install rig mats for rig footprint on MPU L-20. Pull 2-3/8" rams from top BOP and install in bottom BOP, install 2-7/8" ram in upper BOP. Finish off loading pits, N/D and P/U BOP stack and set on stump, continue to prep for rig move. Remove old tree from cellar. N/U dry hole tree per wellhead rep. R/U test pump fill well with diesel using test pump. Rig released from MPU L-45 @ 06:00 hrs. 9/24/2015 -Thursday No activity to report. rA 9/25/2015 - Friday No activity to report. 9/26/2015 -Saturday No activity to report. 9/27/2015-Sunday No activity to report. 9/28/2015 - Monday No activity to report. 9/29/2015-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-45 Coil 50-029-22913-00-00 198-169 9/17/15 11/12/15 Daily Operations: 11/4/2015-Wednesday No activity to report. 11/5/2015 -Thursday No activity to report. 11/6/2015- FridayC No activity to report. i, j''� 11/7/2015 -Saturday No activity to report. 11/8/2015-Sunday Pre spud meeting, and Milne point orientation for crews. Fire equipment. Back up to well. Start rigging up CTU 4. Upright tank loaded 300 bbls water. Rig up return iron. Whellhead bolts on 7" rusted.Attempt fluid pack CT string for BOP test. C- pump frozen.Thaw C pump. Fluid triplex frozen.Thaw Triplex pump. . Location secure. Cement crew will be on location in Morning. 11/9/2015- Monday Fire equipment. Make up tools. 2" CC, 2" nozzle ball drop cement nozzle. Start BOP test.Test all rams and valves to 250psi low/4,500psi high for 5 minutes. Pressure test good. Draw down test pass. Reel is fluid packed with 60/40 methanol. RIH with CT connector and 2"JS nozzle/ball drop cement nozzle. WHP 120psi. Master swab opened 24 turns. RIH. WHP increasing with pipe displacement choke closed. 2,000' WHP at 308psi still climbing.WT check 6,000' 15K. 350psi WHP.Tag PBTD @ 9,348'. Pick up 50' 24k weight. Close choke, ready to inject. Inject at.75..bbls/min.@ 250psi. Increase injection rate to 1 bbl/min 311psi. Down on pump. WHP level off at 150psi. 10 bbls of sea water injected into formation. Line up to cement truck and fresh water vac truck. Pump 5 bbls of fresh water ahead with cement pump. Pressure test cement iron to 250psi low/4,500psi high. Batch up cement. Online with class G cement at 1 bbl/min down CT,15.85 Ib/gal 81 degree. Increase rate to 1.5 bbl/min to fill CT with cement. 1,800psi CT pressure. Reel volume 44 bbls. Decrease pump rate to 1 ..-f'F''. bbl/min cement at nozzle. 44 bbls away. POOH laying in cement 1:1 at 45 ft/min. 30k weiht. 1,207psi circulating pressure. ,.r 92 degree fluid at 15.87 lb/gal. 60 bbls away density dropped to 15.64 lb/gal. Swapped to fresh water @ 71 bbls away, density dropped to 8.84 lb/gal. Continue laying in cement at 45 ft/min. 10 bbls of fresh water pumped on upright totalizer pumped 87 bbls. Dropping speed to 42 ft/min AT liner top 7,213'. Water at nozzle 114 bbls away. Depth 6,372'. Down on pump. PU to 5,500'. Online at 2 bbls/min at 5,800'. Cleaning CT string turbulent flow. Choke pinches back to 150-200psi. RIH to 6,000' pumping seawater at 2 bbls/min. 150psi on choke. Reel volume pumped POOH choke pinched in 150 psi. Parked at 5,240'. 120psi WHP. Cement van cleaning up. Isoloate fluids, pull CT out of hole to surface. Master swab closed. 50psi wellhead pressure. Continue to clean out cement pump. Fresh water vac truck (peak) off location 1630hrs. Cement van cleaned up. Freeze protecting CT. Freeze protect surface lines CT string with 60/40. 15 bbls of 60/40 pumped into well. Pop off well. Install night cap on BOPE. 320 bbls in return tank. Wellhead secure. Ground valves closed. Shut down equipment. • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-45 Coil 50-029-22913-00-00 198-169 9/17/15 11/12/15 Daily Operations: 11/10/2015-Tuesday Hold safety meeting. Discuss job procedure with crews. Review SLB JSA. Fire equipment. Pop night cap. Pick injector head. Stab on well. Fluid pack out to tank. Close choke pressure test stack to 250psi low/4,500psi high. High presssure test saw small drip on lubricator connection. Bleed down to OT. Blow down stack. Pop off well. Change out "O" ring.Stab lubricator. Pressure test 250psi low/4,500psi high. Good pressure test. Open master swab 23 turns. RIH. Wellbore fluid packed from previous cement job. Should see pressure increase as pipe displacement runs in. 250psi on wellhead. CT at 2,343'. Stop CT. Monitor pressure 250psi. Not bleeding down. Crack choke and continue to RIH.Tagged at 4,753. Possible :. cement stringer in casing dog leg. Pick up 50'. Come online with 80 degree seawater. Online 2 bbls min 3,200psi circulation 4 pressure. Made it past previous tag depth of 4,753'. RIH stack 10k @ 6,065'. Pick up 50' RIH stack 10k solid at 6,065'. Found TOC. Calculated TOC should be 6,079'.Tagged 14' high. Pick up 50' and prepare for pressure test of cement plug. Lined up down CT string. Pressure test to 1,500psi for 30 minutes. Bump pressure a few times due to 80 degree fluid cooling down. 1,649psi start pressure @ 11:04 end pressure 1,528psi @ 11:35 121psi drop over 30 minutes. Freeze protect CT 44bbls of 60/40 while waiting response from AOGCC.Wait for response from AOGCC. Called Jeff Jones. Was told he would respond to my notification when he was done with another inspection. Relayed message to town. Resubmitted for 24 hr notification at 14:30hrs, POOH from 6,000'to surface. 2,000' freeze protect wellbore. Tagged up at surface. Close master and swab. Blow down stack to OT. Pop off well stack injector on back deck. Install night cap. Pressure test night cap to 250psi low/4,500psi high. Pressure test good. Bleed down to OT. Open master and swab. Pressure test wellbore.Start 30 minute test at 15:53 1,650psi. 1,581psi at 16:24. Loss of 69psi. Wellsite secure crews off location. • ` Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-45 Coil 50-029-22913-00-00 198-169 9/17/15 11/11/15 Daily Operations: 11/11/2015 -Wednesday On location 0500 hrs. Hold safety meeting and discuss job procedure. Pop night cap. Pick injecotr head and lubricator. Stab on well. Pressure test stack to 250psi low/4,500 psi high. Good PT. Open well and RIH 0532 hrs. Stack 10 K at 6,063' found TOC. Pick up to 5,950'. Park at depth. Wait on state representative from AOGCC to arrive on location. State Offical on location. Tag TOC for state rep at 6,063'. Stack 10k. Pressure test to 1,500 psi 1,675 psi ending pressure 1584 psi. 30 Minute test good. 91 psi pressure loss after 30 minutes. State Rep Jeff Jones accepts test. POOH. Freeze protect from 2,000'to surface with 38 bbls 60/40.Tagged up. Master swab closed. Blow down stack. Pop off well. Stack down lubricator, break down tools tring. Set injector head on back deck. Start rigging down CTU 4. Move CTU to L-49.Ticket ended for L-45. 11/12/2015-Thursday No activity to report. 11/13/2015- Friday No activity to report. 11/14/2015 -Saturday No activity to report. 11/15/2015 -Sunday No activity to report. 11/16/2015- Monday No activity to report. 11/17/2015-Tuesday No activity to report. N4( 75LA, (' c_ ikArc S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 11/11/2015 P.I. Supervisor SUBJECT: Plug & Abandonement FROM: Jeff Jones MPU L-45 Petroleum Inspector Hilcorp Alaska LLC PTD: 1981690 - Section: 8 Township: 13N - Range: 10E - Meridian: Umiat Lease No.: ADL 0025515 Drilling Rig: SLB CTU#4 Rig Elevation: 18' Total Depth: 9365'MD " Operator Rep.: Cole Bartlewski Casing/Tubing Data: Casing Removal: Conductor: 13 3/8" O.D. Shoe@ 115' MD - Casing Cut@ Feet Surface: 5.5" O.D. Shoe@ 7345'MD Casing Cut@ Feet Intermediate: O.D. Shoe@ Casing Cut@ Feet Production: O.D. Shoe@ Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: O.D. Tail@ Casing Cut@ Feet Plugging Data: Type Plug Bottom of T.O.C. Mud Weight Pressure (bottom up) Founded on Cement(M.D.) T.O.C. Depth Verified? above plug Test Open Hole Bottom 9363'MD - 6063' MD - Drill pipe tag - 8.5 PPG 1584 psi Type Plug Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag SCANNED SEP 1 5 20'6 Casing Stub Retainer No Surface 11/11/2015: I traveled to Hilcorp's MPU well L-45 to witness a cement abandonment plug tag and presure test. A 70 BBL class "G"cement plug was placed from bottom to approximately 100'above the 5.5"casing shoe and allowed to harden for 36 hours. witnessed Schlumberger CTU#4 run in the hole and tag solid cement at 6063"MD with 10K lbs. downweight.The well bore was then pressured up to 1675 psi and monitored for 30 minutes.The test pressure stabilized at 1584 psi, passing the pressure test. Summary: I witnessed a successful CTU tag and pressure test of a permanent abandonment cement plug set in Hilcorp's MPU L-45. Attachments: Well bore schematics(2) Pressure test chart(1) Rev.:5/28/00 by L.R.G. 2015-1111_Plug_MPU_L-45jj.xlsx 12/30/2015 • • CV C II 8 L E \R__ 0 M2 7-- gZ 8 R - -70RI E Z 8 . 8 a.) .CD ec Z o�o O M L = .-- a p., ,:, i t 8 � a � • Milne Point Unit t Well: MPU L-45 SCHEMATIC Last Completed: 10/27/1998 nit or11 Alusk n,LLC PTD: 198-169 CASING DETAIL Org.OFElev.:56.6'/GLEbv.:'6.T(Nabors 27E) Size Type Wt/Grade/Conn Drift lD Top Btm 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' 4 j \ '11; 7" Prod X-Over 261L-80/BTC 6.276 Surrace 37' v` 5.5" Production 15.5/J-55/BTC-MOD 4.950 37' 7,345' 1 Tx5.5°X iiii3.5" Liner 9.3/J-SS[8RDSeC 2.992 7213' 9,365' 13-318' Over @37 TUBING DETAIL 2-3/8" Tubing 4.7/J-55/8RD ! 1.995 J Surface 1 7,144' .t 6 ,2 JEWELRY DETAIL ; 7' -) No Depth Item 1 'PO C ren2;3.8"x1' padetF 3MC-1.943' 2 -MO 55'RAE7 C -iEr 3 CrreEci238Scl'SotepcckEtF43\AIA:3dVJC3=1,915 4 1 23'8'I- JE: "t3r`.5'/No Go=1791" 5 3,500' Centrilift Heat Trace Bottom 6 7,115' KUDU PCP,100TP1800- htake N D @4,395' 7 7,151' Centrilirt Seal Section:FSTBDBILPFSAFLASHSN4 11i 8 7,163' Centrifft FMHI-54hp/p20V/35amp 9 7,174' Centrilift PHD-Bottom @ 7.176' OPEN HOLE/CEMENT DETAIL 13-3/8" 260sxArcticsetiApprox)ha 16"Hole 5.5" 818 sx Coldset llt'61 sx Foamed Coldset II&356 sx Foamed Class"G"in a 6-3/4""Hole 1,.::.: WELL INCLINATION DETAIL 6 KOP @ SSO' - I Max Hole Angle=97 deg. ©9,140' ti I t ! 7 Hole Angle thru screen= +/-90 deg. '}8 W TREE&WELLHEAD VIV Tree 2-1/16"SM ,, 9 Wellhead 7"SM Varco ADRS-7 Weld on style /i Tubing Hanger NSCTT&B 2"CIW H BPV Profile 10 1 GENERAL WELL INFO API: 50-029-22913-00-00 SSI' Driled and Cased by Nabors 27E-9/17/1998 hitial Completion by Nabors 4ES -10/27/1998 rrx f -,ii f� l= :T.' 3`3G.. 3-1/Z'a TD=9,365(MD)/TD=4,054'(ND) PBTD=9,332'(MD)/PBTD=4,054'(TVD) Created By:STP 8/05/2015 - • Milne Point Unit Well: MPU L-45 Jlilcorl I Alnsisn,LIC PR 0 POSED A BA NDO NE ME NT Last Completed: Proposed PTD: 198-169 CASING DETAIL ()rig.OF Ebv.:56.6/GL Ebv..:67'(Nabors 27E) 1 Size Type Wt/Grade/Conn Drift ID Top Btm ..;'.:7.--, ..1,,,,;:!:'' , .. . .-A'f.:A .i'"'v,;;; ':'; 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 _ Surfaog SO 7" Prod X-Over 26/L-80/BTC 6.276 Surface 37' ir); e 5.5" Production I SS/J-SS/BTC-MOD 4.9SO 37' 734S' ';,It TUBING DETAIL L...,..I10, 71- ,. , 4, ..i.„.,'#' 1,1:4; '-*" '-'7.„3: •,:v0,1 Tx55'X- Over©37 JEWELRY DETAIL No Depth Item 1 1 a:: , CIEP(3DIctcloarrErt cirtilAeold , 2 •COg 56'FtrtCtilherter OPEN HOLE/CEMENT DETAIL 13-3/8" 260 sx Arcticset I Approx) h a 16"Hole S.5" 818 sx Coldset III,191sx Foamed Coldset II&3S6 sx Foamed Class"G"In a 6-3/4"Ho 4.7S"OH Cemented openhole W'+1-SO bbl cement(35 Liner Removed) Surface Cemented to surface W/+/-30 bbl WELL INCLINATION DETAIL / t KOP@SSO ,1 Max Hole Angle r"'-'97 deg. ;-ii 940' .i. Hole Angle thru screen=+/-90 deg. TREE&WELLHEAD 0 ; 14 4 '4A FlTree 2-1,16"5M ol Wellhead 7"SM Varco ADRS-7 Weld on style Tubing Hanger NSCT T&B 2"CIW H BPV Profile It 11 '' 4 „ GENERAL WELL INFO API:SO-029-22913-00-00 5.5"r yr 'alisn Drilled and Cased by Nabors 27E -9/17/1998 At 1:Vi iv:, 0114 hitial Completion by Nabors 4ES- '0/27/1998 fk.t, fx ' Pg. I"' Created By:STP 8/31/2015 TO=9,365'(MO)/TO=4,054'(TVD) tiOF Ty. 4,4 \ 4. THE STATE Alaska Oil and Gas 4 ofALASKA Conservation Commission ' -�x_ _�^ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 (4,ALASI6' Fax 907.276.7542 CONED3 I www.aogcc.alaska.gov Stan Porhola CIS � /,y Operations Engineer j C( ^ W Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB L-45 Sundry Number: 315-541 Dear Mr. Porhola: 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, I #1 Cathy '. Foerster Chair DATED this D day of September, 2015 RBDMS SEP 0 9 2015 Encl. RECEIVED STATE OF ALASKA AUG 3 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION JAS 711)IS APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon 2 • Plug Perforations' 1 • Fracture Stimulate ❑ Pull Tubing E • Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Dell Number. Hilcorp Alaska,LLC • Exploratory ❑ Development Q , 198-169 - 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22913-00-00 • 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 O ✓ MILNE PT UNIT SB L-45 9.Property Designation(Lease Number): M1j 10.Field/Pool(s): ADL0025515 r a 55 i _ MILNE POINT/SCHRADER BLUFF OIL POOL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,365 ' 4,054 • 9,332. 4,054 - N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' Surface 7,345' 5-1/2" 7,345' 3,984' 4,810psi 4,040psi Liner 2,152' 3-1/2" 9,365' 4,054' 6,980psi 7,400psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 2-3/8" 4.71 /J-55/EUE 7,144' Packers and SSSV Type: No Packer Packers and SSSV MD(ft)and TVD(ft): No Packer No SSSV No SSSV 12.Attachments: Description Summary of Proposal ❑� '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic❑ Development❑✓ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/10/2015 ' Commencing Operations: OIL ❑ WI NJ ❑ WDSPL ❑ Suspended _1 16.Verbal Approval: Date: N/A 'GAS ❑ WAG ❑ GSTOR ❑ SPLUG Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned y 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email soorhola@hilcoro.com Printed Name tan Porhola Title Operations Engineer Signature `-- ,r-E---,_ Phone 777-8412 Date 8/31/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / 31 - `-lk Plug Integrity [? BOP Test [I Mechanical Integrity Test ❑ Location Clearance ❑ Other: Artr AAA -Sr�/ /V+C✓-' 14't..SrC'_del't G S P h l/4 �/ / - J A 1414.113 dotkn+i '-' 'ti c cy/1 LJcl�c 6 �� L 3o P�� 60 f r- Spacing //" Exception Required? Yes ❑ No d Subsequent Form Required: /0 1:10 APPROVED BY ..---- Approved by: dZe/47/3t ...e„,,,,-A14—._. COMMISSIONER THE COMMISSION Date: 9-U •—/5 vj ,mac 9%'ic RBDMS SEP �� CalQ i NrkWPSubmd Form and Fonn 10-403 Revised 5/2015 pi t for 12 months from the date of approv Attachments in Duplicate Well Prognosis Well: MPU 1-45 Hilcorp Alaska,LL) Date:8/31/2015 Well Name: MPU L-45 API Number: 50-029-22913-00 Current Status: SI Oil Well [ESP] Pad: Estimated Start Date: September 10th, 2015 Rig: C Nordic#3] iV Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-169 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: Current Bottom Hole Pressure: 1,590 psi @ 4,000' TVD (Last BHP measured 2/05/2007) Maximum Expected BHP: 1,590 psi @ 4,000' TVD (No new perfs being added) Max.Allowable Surf Pressure: 105 psi (Based on SBHP taken 2/05/2007 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: MPU L-45 was drilled with Nabors 27E as a slim-hole horizontal Schrader Bluff oil producer.The original completion was ran in October 1998 using Nabors 4ES running an ESP.The well last produced in February 2001. The well is being plugged and abandoned ahead of drilling grassroots injectors and producers on L-pad using the Nordic#3 rig. COACvr el/ 14,45 /lever q Notes Regarding Wellbore Condition 1 . / y� L.• SrroA /rdorl,ce rP& eiAc 'J cif /es, 7-14.ip • Well has not produced since 2001. (go 80PQ a �o� a/� ' ro .7l 'O /9 A/, �iolt.t.,: Objective: t rhe t.'�*• T� rnt If S � �' 2 ye-s (uta'- • hetrIO467, 14'i Gael, ." The purpose of this work/sundry is to plug and abandon the well. rept- t,"O,+ Of 4 ,eoff/Ov t1 Brief Procedure: dein/ h` �Icoyrarh f 40‘,/e/ a 11°' -for i fifr pve1 it"(Over/ WO Rig Procedure: fro 741.5 fern'0#‘ OC T4l po01, A qq,,- 1. MIRU Nordic#3 WO Rig. 2. Circulate well with 8.5 ppg sea water down tubing and fill casing. 3. Set BPV. ND Tree. 4. NU 11" BOPE. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-3/8"test joint. 5. Bleed any pressure off tubing and casing. Pull BPV. 6. MU landing joint and pull 10k tension over string weight on tubing hanger to confirm ESP free. a. ***Contingency*** If landing joint won't make up to tubing hanger(bad threads). b. MU spear and pull 10k tension over string weight on tubing hanger to confirm tubing cut. 7. POOH. Lay down 2-3/8"tubing and ESP. 8. MU 2.75" mill and RIH w/2-3/8"workstring to+/-9,332' (PBTD) cleaning out fill. 9. Circulate bottoms up x 2 with 8.5 ppg sea water. 10. POOH. Lay down mill. Rack back 2-3/8" workstring. . ii Well Prognosis Well: MPU L-45 Hilcorp Alaska,LL Date:8/31/2015 11. MU 3.5" spear and RIH w/2-3/8" workstring to+/-7,750' (above slotted liner). 12. Circulate well clean with 8.5 ppg sea water. 13. Spear into 3.5" liner C-2 setting sleeve. 14. POOH w/3.5" slotted liner. a. ***Contingency*** If slotted liner will not pull out of hole. b. Leave slotted liner on bottom (will cement inside w/coil if unable to recover). 15. Set retrievable bridge plug at+/-500'. 16. Test casing and plug to 1,500 psi for 30 min. 17. POOH. Lay down 2-3/8"tubing. 18. RD Nordic#3 WO Rig. 19. ND BOPE. NU dry hole tree. 20. Turn well over to production. Coiled Tubing Procedure: 21. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 22. RIH w/2.00" coil w/pulling tool to top of retrievable plug+/-500' MD. POOH. DZI' PIO- 23. RIH w/2.00" coil w/cement stinger and RIH to PBTD of+/-9,363' MD. 24. Mix and pump 70 bbl cement in the 4-3/4" openhole (4-3/4" capacity=44.3 bbl; 5-1/2" capacity= 2.4 bbl) laying cement from PBTD to 5.5"casing shoe. ori 25. Reverse circulate clean with 8.5 ppg sea water. POOH. a. Plan to leave cement top 100'above 5.5" casing shoe at+/-7,243' MD. _ - b. If 3.5" liner was unable to be removed, use same procedure for abandonment. N,,Wait on cement 12 hours. (7�)RIH w/2.00" coil w/2.5" mill to TOC(top of cement) at+/-7,243' MD an POOH to 2,000'. 28. Freeze protect top 2,000'of well. POOH to surface. } Poi-: f-7r..„,z_c 29. RD Coiled Tubing. "o +a- 30. Turn well over to production. �. p 7- P /S j',s.:- , Wireline Procedure: '3U � 31. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 32. MU 5.5" bridge plug and RIH to setting depth of+/- 150'. 33. Set bridge plug at+/- 150'. POOH. 34. RIH w/6'casing punch.Tag bridge plug. PU 5' above bridge plug. 35. Punch 5.5" casing from+/- 139'-145' MD. 36. POOH. RD E-line. 37. Install tubing hanger. 38. Establish circulation down casing and up annulus.(e. "--'k " r-• - 39. RU cementers Mix and pump 30 bbl of cement (permafrost cement). Circulate cement to surface. 40. Clean and clear rig floor. Flush all surface lines and clean pits. Surface Procedure: 41. Excavate cellar,cut off wellhead and casing 3' below natural GL. --_ /\)J-;Crj "s/�` irt- 42. Set marker plate,collect GPS coordinates. / -"�� z_ c_. A/4-c--2- /Z0 l , 43. Backfill cellar, close out location. 1-1/".-/- 14- 1P .�`©f - C r 4--f-- Attachments: Gam,a " Well Prognosis Well: MPU L-45 Hilcorp Alaska,LL) Date:8/31/2015 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Coil BOPE Schematic Milne Point Unit Well: MPU L-45 14 SCHEMATIC Last Completed: 10/27/1998 Mikan,Alaska,LLC PTD: 198-169 CASING DETAIL Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm N, li .4\ t 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' k' 7" Prod X-Over 26/L-80/BTC6.276 Surface 37' 4.950 37' 7,345' 4i Tx5.5'X 3.5" Liner 9.3/J-55/8RD SCC 2.992 7,213' 9,365' 13-3/8Over @3 P TUBING DETAIL 2-3/8" Tubing 4.7/1-55/8RD 1.995 Surface 7,144' rye f JEWELRY DETAIL 2Cr" No Depth Item 1 170' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" 2 1,009' 5.5"Port Collar Cementer 3 3,446' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" 4 3,461' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" 3 5 3,500' Centrilift Heat Trace Bottom 6 7,115' KUDU PCP,100TP1800—Intake TVD @ 4,395' 'Ig4 7 7,151' Centrilift Seal Section:FSTBDBILPFSAFLASHSN4 5 8 7,163' Centrilift FMH1—54hp/1,020V/35amp 9 7,174' Centrilift PHD—Bottom @ 7,176' OPEN HOLE/CEMENT DETAIL 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole 5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"i a 6-3/4""Hole/ 7rrr WELL INCLINATION DETAIL $1 i4: 6 KOP @ 550' Max Hole Angle=97 deg. @ 9,140' a I 117 Hole Angle thru screen=+/-90 deg. r. A.$ r 4 TREE&WELLHEAD li Tree 2-1/16"5M tiM 9 Wellhead 7"5M Varco ADRS-7 Weld on style l Tubing Hanger NSCTT&B 2"CIW H BPV Profile i4 I 10 4,(3°D GENERAL WELL INFO 7/‹ API:50-029-22913-00-00 5.5"1,014 Drilled and Cased by Nabors 27E -9/17/1998 2a°`" Initial Completion by Nabors 4ES—10/27/1998 3-1/2"A TD=9,365'(MD)/TD=4,054'(TVD) PBTD=9,332'(MD)/PBTD=4,054'(TVD) Created By:STP 8/05/2015 Milne Point Unit Well: MPU L-45 PROPOSED ABANDONEMENT Last Completed: Proposed Hilcorp Alaska,LLC c PTD: 198-169 CASING DETAIL Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm �,,.11.,: �s :,,t.., 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface _ 150' i ` 7" Prod X-Over 26/L-80/BTC 6.276 Surface 37' 5.5" Production 15.5/J-55/BTC-MOD 4.950 37' 7,345' - '` TUBING DETAIL 13-3/8 , - tip 1 7'x5.5 X- Over C 37 JEWELRY DETAIL 0 2 No Depth Item 1 150' CIBP(30 bbl cement circulated above) 2 1,009' 5.5"Port Collar Cementer /3T ,4 2" 5rkh - OPEN HOLE/CEMENT DETAIL I 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole 5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"in -3/4"" ) . 3-; ,, aft 4.75"OH Cemented openhole w/+/-50 bbl cement(3.5"Liner Removed) Surface Cemented to surface w/+/-30 bbl I 7—L—I5 ck rw, WELL INCLINATION DETAIL KOP @ 550' P A f„ Max Hole Angle=97 deg. @ 9,140' AHole Angle thru screen=+/-90 deg. TREE&WELLHEAD '' Tree 2-1/16"5M tri Wellhead 7"5M Varco ADRS-7 Weld on style Tubing Hanger NSCTT&B 2"CIW H BPV Profile "i A GENERAL WELL INFO API:50-029-22913-00-00 5.5"� - , Drilled and Cased by Nabors 27E -9/17/1998 .'4„ Initial Completion by Nabors 4ES—10/27/1998 V!'::4:1:;'1"t e#,'1* fr: 0 TD=9,365'(MD)/TD=4,054'(TVD) I PBTD=9,332'(MD)/PBTD=4,054'(TVD) Created By:STP 8/31/2015 11" BOP Stack r O v Aitaissais Hydril 11" 5M [111111L111111111 Shaffer * J _ 2 3/8" Rams _Oga) J _ oca.)Lii,, 11" 5 M 2 7/8-5.5 variables i — Hydril — 11" 5MBlinds o o� — ®3) Optional valve port 0iit,„____:_ -1.:,,j)e-Oilc 'GPJG► GI Milne Point Unit 11 COIL BODE MPU L-45 08/31/2015 Harrap ‘6.16a.LU. MPU L-45 13% X5% X2% Coil Tubing BOP 1 Lubricator to injection head O 1.75"Tandem Stripper f I 1 f •',I, Blind/Shears!' 1/1610 = Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, August 31, 2015 9:42 AM To: 'Stan Porhola' Cc: Bettis, Patricia K (DOA);Tom Fouts;samantha.carlisle@alaska.gov Subject: RE: L-45 P &A (PTD 198-169) (Sundry 315-475) Stan, AOGCC will withdraw sundry 315-475 for the suspend work on L-45 as per your request. Guy Schwartz Senior Petroleum Engineer SEP 1 6 2015 AOGCC SCANNE� 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Stan Porhola [nailto:sporhola(a>hilcorp.com] Sent: Friday, August 28, 2015 3:56 PM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K (DOA); Tom Fouts RBD 201 Subject: RE: L-45 P &A (PTD 198-169) ( Sundry 315-475) Guy, You can disapprove or cancel this sundry.A new sundry will be submitted utilizing the Nordic#3 rig for the plug and abandonment. Stan From: Schwartz, Guy L(DOA) [ nailto:guy.schwartz(aalaska.gov] Sent: Friday, August 28, 2015 3:25 PM To: Stan Porhola Cc: Bettis, Patricia K (DOA) Subject: RE: L-45 P &A (PTD 198-169) ( Sundry 315-475) Stan, Still have the sundry... Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains informau,n from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Schwartz, Guy L (DOA) Sent: Wednesday, August 12, 2015 3:40 PM To: Stan Porhola Cc: Bettis, Patricia K (DOA) Subject: L-45 P &A (PTD 198-169) ( Sundry 315-475) Stan, A couple of comments on the sundry to P&A L-45. 1) Will need 50 cement cap on the 314" retainer set at 7750' .... the slotted liner is regarded as OH so will need to comply with 20 AAC 25.112(b)(2). (1 would prefer a 5 1/2"retainer above the liner lap but either way is acceptable) 2) Our records indicate that the OH is 7 7/8" in the intermediate casing.( schematic indicates 6%"OH) 3) Also a 2nd stage cement job (139 bbl) was pumped from the port collar at 1009 ft. so there should be cement at surface in that annulus. Not sure you will need to(or should) perf the 5.5" casing and attempt to circulate to surface. Please change your procedure to reflect how you are going to get cement to surface in the 5.5" casing if you don't perf. 4) Well is not technically abandoned until wellhead is cut off and capped. So will be "suspended" status. Will require inspections per 20 AAC 25.110 Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.go ). 2 RECEIVED STATE OF ALASKA AUG 0 5 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A•op�'r 20 MC 25.280 1.Type of Request: Abandon ., Plug Perforations L Fracture Stimulate ❑ Pull Tubing Q- Operations shutdown❑ Suspend ` Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC , Exploratory ❑ Development ❑✓ • 198-169 - 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 56-029-22913-00-00 , 7. If perforating: 8.Well Name An'd Number: What Regulation or Conservation Ordergoverns well spacing in thispool? 9 p 9 C.O. 477.05 - G Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT SB L-45 • 9.Property Designation(Lease Number): 10 10. Field/Pool(s): ADL0025515I a ss-t4 MILNE POINT/ C -•DER BLUFF OIL POOL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,365 , 4,054 9,332 • 4,054 • N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' Surface 7,345' 5-1/2" 7,345' 3,984' 4,810psi 4,040psi Liner 2,152' 3-1/2" 9,365' ����llll 4,054' 6,980psi 7,400psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 2 4.7#/J-55/EUE 7,144' Packers and SSSV Type: No Packer )2- Packers and SSSV MD(ft)and TVD(ft): No Packer No SSSVNo SSSV 12.Attachments: Description Summary of Proposal A/ r13.Well Class after proposed work: Detailed Operations Program LI BOP -BOP Sketch Exploratory ❑ Stratigraphic ❑ Development❑✓ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/19/201`5 ,, Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG [l Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned L 17. I hereby certify that the foregoing is true and correct to tpe best of my knowledge. Contact Stan Porhola Email sporhola@hilcorp.com Printed Name /Stan Porhola Title Operations Engineer Signature y\._ / ' L Phone 777-8412 Date 8/5/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 5 y� 5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ?Aa 21053 84/45— ORIGINAL RBDMS Ep08 2015 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Well Prognosis Well: MPU L-45 Hilcorp Alaska,LL Date:8/05/2015 Well Name: MPU L-45 API Number: 50-029-22913-00 Current Status: SI Oil Well [ESP] Pad: L-Pad Estimated Start Date: August 19th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-169 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: Current Bottom Hole Pressure: 1,590 psi @ 4,000' TVD (Last BHP measured 2/05/2007) Maximum Expected BHP: 1,590 psi @ 4,000' TVD (No new perfs being added) Max. Allowable Surf Pressure: 105 psi (Based on SBHP taken 2/05/2007 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: MPU L-45 was drilled with Nabors 27E as a slim-hole horizontal Schrader Bluff oil producer.The original completion was ran in October 1998 using Nabors 4ES running an ESP.The well last produced in February 2001. The well is being plugged and abandoned ahead of drilling grassroots injectors and producers on L-pad using the Nordic#3 rig. / too ev� 57„04 COKE ��t �"`/ �e01 �fi 7Dfl0i 4 Notes Regarding Wellbore Condition //O Off d' U,� iv,' 0 e y�y,- of— Co�►�,�r `ten. • Well has notp roduced since 2001. lj j-o ec" —tel / '1 7 tii 70 �U /'v jvc t'�^ Objective: h0 f P rcioy -A' rite ' ",•' /e✓+l gr' ' ' Of i rS p(od KVe- /," e, 6-19 i in, tis (4C i 4 The purpose of this work/sundry is to plug and abandon the well. aal o-on ce 0-" ' 9r455- /0073 01 ,- tt`O4 '$ G Brief Procedure: 0 Ory denr of e c s' c" i WO Rig Procedure: 1. MIRU Hilcorp ASR#1 WO Rig. 2. Circulate well with 8.4 ppg lease water down tubing and fill casing. 3. Set BPV. ND Tree. 4. NU 7-1/16" BOPE. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-3/8"test joint. 5. Bleed any pressure off tubing and casing. Pull BPV. 6. MU landing joint and pull 10k tension over string weight on tubing hanger to confirm ESP free. a. ***Contingency*** If landing joint won't make up to tubing hanger(bad threads). b. MU spear and pull 10k tension over string weight on tubing hanger to confirm tubing cut. 7. POOH. Lay 2-3/8"tubing on the pipe rack(utilize as workstring). 8. MU 2.75" mill and RIH w/2-3/8"tubing to+/-9,332' (PBTD) cleaning out fill. 9. Circulate bottoms up x 2 with 8.4 ppg lease water. 10. POOH. Lay down mill. Lay down 2-3/8" tubing. Well Prognosis Well: MPU L-45 llilcorp Alaska.LL, Date:8/05/2015 11. MU 3.5" cement retainer and RIH w/2-3/8"tubing to+/-7,750' (above slotted liner). 12. Set cement retainer.Tag retainer w/10k down to confirm set. 13. Circulate well clean with 8.4 ppg lease water. 14. Test casing to 1,500 psi for 30 min. /C%L ' 15. Stab into retainer. Establish injectivity rate/pressure into formation. �) � '8" v•'0, 16. Mix and pump 40 bbl cement below retainer(liner capacity= 13.7 bbl). ' ( 3'5/ .. �,-? b� 17. Unsting out of retainer. Reverse circulate clean. sp' L 18. POOH. Lay down 2-3/8"tubing. 1,..,� cctro. 19. MU 5.5" bridge plug and RIH w/2-3/8"tubing to+/- 150'. 20. Set bridge plug at+/- 150'. POOH. Lay down 2-3/8"tubing. o< 21. RU E-line. ec 22. RIH w/6' casing punch.Tag bridge plug. PU 5' above bridge plug. 1,3Cn �4� 23. Punch 5.5" casing from+/- 139'445' MD. 24. POOH. RD E-line. 2 a� 25. Install tubing hanger. c " 26. Establish circulation down casing and up annulus. 27. RU cementers. Mix and pump 30 bbl of cement(permafrost cement). Circulate cement to surface. 28. Clean and clear rig floor. Flush all surface lines and clean pits. 29. RD Hilcorp ASR#1 WO Rig. 30. ND BOPE. NU dry hole tree. 31. Turn well over to production. WO Rig Procedure: 32. Excavate cellar, cut off wellhead and casing 3' below natural GL. 33. Set marker plate,collect GPS coordinates. 34. Backfill cellar, close out location. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Milne Point Unit 11 Well: MPU L-45 SCHEMATIC Last Completed: 10/27/1998 HiIc»rp Alaska,LLC PTD: 198-169 CASING DETAIL Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) ( Size Type Wt/Grade/Conn Drift ID Top Btm ` 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' 7" Prod X-Over 26/L-80/BTC 6.276 Surface 37' 5.5" Production 15.5/J-55/BTCMOD 4.950 37' 7,345' x5.5"X- 1 3.5" Liner 9.3/J-55/8RD SCC 2.992 7,213' 9,365' 13-3/8" 0137 TUBING DETAIL 2-3/8" Tubing 4.7/J-55/8RD 1.995 Surface i 7,144' y JEWELRY DETAIL i _,/ f°1:A No Depth Item c�^z 1 170' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" �bw 2 1,009' 5.5"Port Collar Cementer 3 3,446' Camco 2-3/8"x 1"Sidepocket KBMM GLM:ID=1.945" 4 3,461' 2-3/8"HES XN-Nipple:ID=1.875"/No Go=1.791" 3 5 3,500' _ Centrilift Heat Trace Bottom Al 6 7,115' KUDU PCP,100TP1800—Intake ND @ 4,395' Or ii. 4 7 7,151' Centrilift Seal Section:FSTBDBILPFSAFLASHSN4 5 8 7,163' Centrilift FMH1—54hp/1,020V/35amp 9 7,174' Centrilift PHD—Bottom @ 7,176' rt -1 D OPEN HOLE/CEMENT DETAIL ? 7 8 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole 5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"in 6-3/4""Hol !." WELL INCLINATION DETAIL s j :,K 774 d3�! I, 6 KOP @ 550' Max Hole Angle=97 deg. @ 9,140' /(#- 'i ii 1 7 Hole Angle thru screen=+/-90 deg. 4 v. c,µf 3 SZ 8a TREE&WELLHEAD ITree 2-1/16"SM i9a 9 �] Wellhead 7"5M Varco ADRS-7 Weld on style .7P LS Tubing Hanger NSCTT&B 2"CIW H BPV Profile o 10 r „, 5 -, GENERAL WELL INFO ,, 3 10` 4.3 c� c � n API:50-029-22913-00-00 5.5"$ g 1aj� ydY lik/ Drilled and Cased by Nabors 27E -9/17/1998 '5t" /f1 Initial Completion by Nabors 4ES—10/27/1998 3-1/7'1 0 TD=9,365'(MD)/TD=4,054'(TVD) `/ =9,332'(MD)/MD / HIM Created By:STP 8/05/2015 Milne Point Unit Well: MPU L-45 PROPOSED ABANDONEMENT Last Completed: Proposed Hilcorp Alaska,LL(: PTD: 198-169 CASING DETAIL Orig.DF Elev.:56.6'/GL Elev.:16.7'(Nabors 27E) Size Type Wt/Grade/Conn Drift ID Top Btm 13-3/8" Conductor 68/L-80/BTC-MOD 12.191 Surface 150' ' 7" Prod X-Over 26/L-80/BTC6.276 Surface 37' 5.5" Production 15.5/J-55/BTC-MOD 4.950 37' 7,345' 7"x 5.5"x- 3.5" Liner 9.3/1-55/8RD SCC 2.992 7,213' 9,365' 13 3/8 Over @37' TUBING DETAIL 2-3/8" Tubing 4.7/J-55/8RD 1.995 Surface 7,144' 1 JEWELRY DETAIL 2 No Depth Item 1 150' CIBP(30 bbl cement circulated above) 2 1,009' 5.5"Port Collar Cementer 3 7,750' Cement Retainer(40 bbl cement squeezed below) OPEN HOLE/CEMENT DETAIL 13-3/8" 260 sx Arcticset I Approx)in a 16"Hole 5.5" 818 sx Coldset III,191 sx Foamed Coldset II&356 sx Foamed Class"G"in a 6-3/4""Hole WELL INCLINATION DETAIL KOP @ 550' • Max Hole Angle=97 deg. @ 9,140' Hole Angle thru screen=+/-90 deg. TREE &WELLHEAD ".s Tree 2-1/16"5M • Wellhead 7"SM Varco ADRS-7 Weld on style Tubing Hanger NSCTT&B 2"CIW H BPV Profile 3 GENERAL WELL INFO API:50-029-22913-00-00 5.5"4 Drilled and Cased by Nabors 27E -9/17/1998 Initial Completion by Nabors 4ES—10/27/1998 3-1/Y'4:• TD=9,365'(MD)/TD=4,054'(TVD) PBTD=9,332'(MD)/PBTD=4,054'(TVD) Created By:STP 8/05/2015 Milne Point II 2015 ASR Rig 1 triro,rp:%a�.ka.1.1.1I. Knight Oil Tools BOP 7-1/16" BOPS Stripping Head • • lil Ill IiI Ill lit lii lil III 1 2.57' Shaffer 7 1/16 5000 nalirrtin i M III Ili 1!I 1 !1 Ill 2 3/8-3 1/2 variable _ CAMERON 3.68' - I 1I - awn * _ = Blind =�cowl - 7 1/16 5000• I! lig. EW Iii I11 111 III Iii 21 16 5M Kill Line Valvesden 21/16 5M Choke Line Valves i1, x< ; I!11111111'I11 IPI ' t. I ' Q �.. C t P1 ( 1.56' ':E; Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~/--/~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds Other COMMENTS: Scanned by: Beverly Mildred Daretha owell Date: ~"~/~- 0 Is/ [] TO RE-SCAN Notes' Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: ~si • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 '�� 7 December 30, 2011 16N- Mr. Tom Maunder Alaska Oil and Gas Conservation Commission INIPI......... 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPL -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPL -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, .,..„,..7) , a —,---- Mehreen Vazir BPXA, Well Integrity Coordinator . . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPL -Pad Date: 10/08/11 Corrosion Initial top of Vol. of cement Anal top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor , sealant date ft bbls ft gal MPL -01A 2030640 50029210680100 Sealed conductor N/A N/A N/A N/A NA MPL -02A 2091470 50029219980100 Sealed conductor N/A N/A N/A N/A NA MPL -03 1900070 50029219990000 Tanko conductor N/A N/A N/A N/A NA MPL -04 1900380 50029220290000 Sealed conductor N/A N/A N/A N/A NA MPL -05 1900390 50029220300000 Sealed conductor N/A N/A N/A N/A NA MPL -06 1900100 50029220030000 Sealed conductor N/A N/A N/A N/A NA MPL -07 1900370 50029220280000 Sealed conductor N/A N/A N/A N/A NA MPL -08 1901000 50029220740000 Sealed conductor N/A N/A N/A N/A NA MPL -09 1901010 50029220750000 Sealed conductor N/A N/A N/A N/A NA MPL -10 1901020 50029220760000 Sealed conductor N/A N/A N/A N/A NA MPL -11 1930130 50029223360000 Sealed conductor N/A N/A N/A N/A NA MPL -12 1930110 50029223340000 Sealed conductor N/A N/A N/A N/A NA MPL -13 1930120 50029223350000 Sealed conductor N/A N/A N/A N/A NA MPL -14 1940680 50029224790000 Sealed conductor N/A N/A N/A N/A NA MPL -15 1940620 50029224730000 3.3 N/A 3.3 N/A 15.3 8/9/2011 MPL -16A 1990900 50029225660100 23 Needs top job MPL -17 1941690 50029225390000 0.2 N/A 0.2 N/A 5.1 9/1/2011 MPL -20 1971360 50029227900000 0.4 N/A 0.4 N/A 3.4 8/10/2011 MPL -21 1951910 50029226290000 1.7 N/A 1.7 N/A 8.5 8/10/2011 MPL -24 1950700 50029225600000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -25 1951800 50029226210000 1.7 N/A 1.7 N/A 15.3 8/10/2011 MPL -28A 1982470 50029228590100 0.3 N/A 0.3 N/A 8.5 10/8/2011 MPL -29 1950090 50029225430000 0.5 N/A 0.5 N/A 3.4 8/7/2011 MPL -32 1970650 50029227580000 0.5 N/A 0.5 N/A 5.1 8/10/2011 MPL -33 1971050 50029227740000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -34 1970800 50029227660000 1.7 N/A 1.7 N/A 8.5 8/9/2011 MPL -35A 2011090 50029227680100 02 N/A 0.2 N/A 8.5 10/8/2011 MPL-36 1971480 50029227940000 0.1 N/A 0.1 N/A 7.6 9/1/2011 MPL -37A 1980560 50029228640100 6 N/A 6 N/A 47.6 8/13/2011 MPL-39 1971280 50029227860000 1.7 N/A 1.7 N/A 6.8 8/8/2011 MPL -40 1980100 50029228550000 1 N/A 1 N/A 6.8 8/8/2011 MPL -42 1980180 50029228620000 5.3 N/A 5.3 N/A 30.6 8/14/2011 MPL-43 2032240 50029231900000 17.5 Needs top job - ' - j MPL-45 1981690 50029229130000 10 N/A 10 N/A 8.5 8/10/2011 MEMORANDUM TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas ConServation Commission DATE: December 22, 2000 FROM: John Crisp, Petroleum Inspector SUBJECT: Safety Valve Tests Milne Point Field L Pad December 22, 2000: I traveled to BPX's Milne Point Field L pad to witness Safety Valve System tests. I conducted wellhouse inspections during SVS tests. Larry Niles was BP rep. in charge of SVS testing. As usual, Larry was ready to begin testing as soon as I arrived on location. Wellhouses on L Pad are heated & have lights, this makes for safe working conditions & minimal SVS failures. Wellhouses are clean & in good condition. The AOGCC test report is attached for SVS failure reference. SUMMARY: I traveled to BPX MPU L Pad for SVS tests. 20 wells, 40 components tested. I Failure witnessed. 2.5% failure rate. 20 wellhouses inspected. No failures to report, Attachments: SVS MPU L pad 12-22-00jc NON-CONFIDENTIAL SVS MPU L Pad 12-22,00jc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: .Larry Niles AOGCC Rep: John Crisp Submitted By: John Crisp Field/Unit/Pad: PBU MPU L Pad Separator Psi: LPS 140 Date: 12/22/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE L-01 1840050 L-02 1900060 140 100 90 P P OIL L-03 1900070 L-04 1900380 140 100 105' P P OIL L-05 1900390 140 100 100 P P OIL L-06 1900100 140 100 100 P P OIL L-07 1900370 140 100 100 P I P OIL L-08 1901000 4000 2000 1950 P P WAG! L-09 1901010 L-Il 1930130 140 100 115 P P OIL L-12 1930110 140 100 100 P P OIL . L-13 1930120 140 100 100 P P OIL L-14 1940680 140 100 95 P P 0IL L-15 1940620 L-16A 1990900: , L-17 1941690 L-20 1971360 140 100 100 P P OIL L-25 1951800' 140 100 105 P P' OIL I L-28A 1982470 140 100 110 P P OIL i,, L-29 1950090 140 100 95 P P OIL , L-32 1970650 140 100 100 P P OIL L-33 19710501 L-35 1970920 140 100 105 P P OIL L-36 1971480 140 100 105 P P ' OIL L-37A 19805601 , % L-40 1980100 140 100 100 P P' ~-c~\~ ~ -~:~.~ \'~ OIL L-45 1981690 140 100 105 P P tXX' OIL L-34 1970800 4000 2000 19~0 P 4 WAG Wells: 20 Components: 40 Failures: 1 Failure Rate: 2.5% Remarks: Page 1 of 2 SVS MPU L Pad 12-22'00jc.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE i Page 2 of 2 SVS MPU L Pad 12-22'00jc.xls °mpliance Report File on Left side of folder 198-169-0 MILNE POINT UNIT SB Roll #1: Start: Stop Roll #2: MD 09365 TVD 04054 Completion Date: L-45 50- 029-22913-00 Start Stop 10/27/98 Completed Status: 1-OIL BP EXPLORATION (ALASKA) INC Current: Name Interval D 8794 2,3 SPERRY GR/EWR4 Sent Received T/C/D OH 12/16/98 12/17/98 L DGR/EWR4-MD FINAL 4177-9365 OH 12/16/98 12/17/98 L DGR/NGP/EWR4-TVD FINAL 3193-4053 OH 12/16/98 12/17/98 R SRVY RPT Daily WelIOps _ _--_ __ Was the well cored? yes no SPERRY 0-9365. OH Are Dry Ditch Samples Required? yes Analysis Description Received? yes no 12/30/98 12/30/98 And Received? yes no Sample Set # Comments: Wednesday, November 08, 2000 Page 1 of 1 eare, d rvlce$ rilling BP Exploration / Arco Alaska Date: January 5, 1999 To: Attn: Alaska Oil & Gas Conservation Commission Steve McMains Reference: From: Steve' Completion Report - MPL-45 Carol Wit~y,, ~/ III Technict~'i~a'd~~ While reviewing the permit in preparation of the attached 10-407, I noticed the surface location had a typographical error. Please reference permit 98-169, APl number 50-029-22913. Incorrect 3552' NSL, 5118' EWL, SEC. 8, T13N, R10E Correct 3552' NSL, 5118' WEL, SEC. 8, T13N, R10E The attached 10-407 reflects the correct information. Thanks Steve. Cc: Well File RECE ¥ED JAN 06 1999 Al~ka Oil & Gas C0.~ Comrai~81ol~ ~chorage · ,, 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 [--I Gas E~ Suspended [~ Abandoned I--I Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-169 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22913 4. Location of well at surface I' -~~'~N~! 9. Unit or Lease Name 3552' NSL, 5118'WEL, SEC. 8, TlSN, R10E, UM ?~.ii:, :i.!-'-~ ' ' ~I;,~~ Milne Point Unit At top of productive interval 10. Well Number 1431' SNL, 295' WEL, SEC. 18, T13N, R10E, UM MPL-45 At tot,al depth , 11. Field and Pool 3540 SNL, 541 WEL, SEC. 18, T13N, R10E, UM · -- Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease DesignatiOn and Serial No. KBE = 50.55'I ADL025515 12. Date Spudded9/1/98 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre I 16' NO' Of C°mpleti°ns9/10/98 10/27/98 N/A MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 9365' 4054' FT 9332' 4054 FT ~]Yes [~]NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD/LWD, GR/RES 23. CASING, LINER AND CEMENTING RECORD CASING SE-FrING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68# L-80 35' 120' 16"' 260 sx Arctic Set (Approx.) 5-1/2" 15.5# J-55 33' 7345' 7-7/8" lB18 sx Coldset III, 191 sxColdset Ilfoamed, 356 isx Foamed 'G' 3-1/2" 9.3# J-55 7213' 9365' 4-3/4" ,Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" Slotted Liner 2-3/8", 4.7#, J-55 7144' None MD TVD MD TVD 7789' - 9365' 4010' - 4054' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect well with~2~bbls diesel 27. PRODUCT,ONTEST 0RIGINAL Date First Production I Method of Operation (Flowing, gas lift, etc.) November 3, 1998I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL P~'l~~f~ TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL iGAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 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 N-A Sands 6810' 6774' Schrader Bluff N-F Sands 7325' 4031' Schrader Bluff O-A Sands 7808' 4061' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certif/y.~ha~:Cn~.,regoi)~ true and correct to the best of my knowledge __/ Signed (,~/(..- ,' _~~ / Charles R. Mallary/,~("~_/-)_ ~ Title Drilling Superintendent Date ~¥h~k./' ""~ / 98-169 Prepared By Name/Number: Carol W/they, 564-4114 M PL-45 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21.' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility M Pt L Pad Progress Report Well MPL-45 Page Rig Nabors 4ES Date 1 22 December 98 Date/Time 25 Oct 98 26 Oct 98 27 Oct 98 03:30-05:00 05:00-06:00 06:00-11:30 11:30-13:00 13:00-14:30 14:30-15:00 15:00-15:30 15:30-16:00 16:00-17:00 17:00-18:00 18:00-18:15 18:15-19:30 19:30-20:30 20:30-23:00 23:00-00:00 00:00-00:30 00:30-02:00 02:00-03:00 03:00-03:15 03:15-05:15 05:15-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-09:00 09:00-10:30 10:30-18:00 18:00-18:15 18:15-02:00 02:00-02:30 02:30-04:30 04:30-06:00 06:00-09:00 09:00-09:15 09:15-09:30 09:30-10:30 10:30-12:00 12:00-12:30 12:30-12:45 12:45-13:00 13:00-13:30 13:30-14:00 Duration 1-1/2 hr 1 hr 5-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 1 hr 1/4 hr 1-1/4 hr 1 hr 2-1/2 hr 1 hr 1/2 hr 1-1/2 hr 1 hr 1/4 hr 2 hr 1/4 hr 1/2 hr 1/4 hr 1/4 hr 2-1/2 hr 1-1/2 hr 7-1/2 hr 1/4 hr 7-3/4 hr 1/2 hr 2hr 1-1/2 hr 3hr 1/4 hr 1/4 hr 1 hr 1-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr Activity Rigged down Drillfloor / Derrick Rigged down Fluid system Rig moved 100.00 % Rigged up Drillfloor / Derrick Installed High pressure lines Retrieved Hanger plug Tested High pressure lines Circulated closed in well at 3446.0 ft Circulated at 3446.0 ft Removed Xmas tree Held safety meeting Installed BOP stack Serviced Variable ram Tested All functions Rig waited: Equipment Retrieved Hanger plug Retrieved Tubing hanger Rigged up Completion string handling equipment Pulled Tubing in stands to 7049.0 ft Rig waited: Equipment Rigged up Completion string handling equipment Pulled Tubing in stands to 6930.0 ft Held safety meeting Serviced Drillfloor / Derrick Pulled Tubing in stands to 3652.0 ft Rigged up sub-surface equipment - Electric cable Ran Tubing in stands to 5241.0 ft Held safety meeting Ran Tubing in stands to 7120.0 ft Rigged up Tubing hanger Serviced Electric cable Serviced Electric cable Serviced Electric cable (cont...) Ran Tubing on landing string to 7144.0 ft Tested Tubing hanger Removed BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Installed Hanger plug Freeze protect well - 12.000 bbl of Diesel Removed High pressure lines Facility Date/Time 31 Aug 98 01 Sep 98 02 Sep 98 03 Sep 98 04 Sep 98 05 Sep 98 06 Sep 98 07 Sep 98 08 Sep 98 M Pt L Pad . , Progress Report Well MPL-45 Rig Nabors~ g~ Page Date Duration Activity 06:00-18:00 18:00-03:00 03:00-06:00 06:00-08:00 08:00-10:00 10:00-11:00 11:00-15:00 15:00-16:00 16:00-19:30 19:30-21:30 21:30-22:00 22:00-23:00 23:00-06:00 06:00-05:30 05:30-06:00 06:00-06:30 06:30-09:30 09:30-11:30 11:30-13:00 13:00-16:00 16:00-19:00 19:00-06:00 06:00-03:00 03:00-05:00 05:00-06:00 06:00-07:00 07:00-09:00 09:00-14:30 14:30-15:30 15:30-19:00 19:00-21:30 21:30-01:30 01:30-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-14:00 14:00-15:30 15:30-16:00 16:00-18:30 18:30-20:30 20:30-23:00 23:00-01:30 01:30-02:00 02:00-03:30 03:30-05:30 05:30-06:00 06:00-13:00 13:00-13:30 13:30-17:00 17:00-21:30 21:30-00:30 00:30-02:30 02:30-03:30 12hr 9 hr 3 hr 2 hr 2 hr lhr 4 hr 1 hr 3-1/2 hr 2 hr 1/2 hr 1 hr 7 hr 23-1/2 hr 1/2 hr 1/2 hr 3 hr 2 hr 1-1/2 hr 3 hr 3 hr llhr 21hr 2 hr 1 hr 1 hr 2 hr 5-1/2 hr 1 hr 3-1/2 hr 2-1/2 hr 4 hr 1-1/2 hr 1 hr 1/2 hr 1-1/2 hr 8 hr 1-1/2 hr 1/2 hr 2-1/2 hr 2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 2 hr 1/2 hr 7hr 1/2 hr 3-1/2 hr 4-1/2 hr 3 hr 2 hr 1 hr Rig moved 50.00 % Rig moved 100.00 % Rigged up Divertor Rigged up Divertor Ran Drillpipe to 0.0 ft (4in OD) Rig moved 100.00 % Racked back Drillpipe Held safety meeting Racked back Drillpipe Made up BHA no. 1 Held safety meeting Tested Divertor Drilled to 829.0 ft Drilled to 4177.0 ft Circulated at 4177.0 ft Circulated at 4177.0 ft Pulled out of hole to 830.0 ft Pulled BHA Serviced Top drive Made up BHA no. 2 R.I.H. to 4177.0 ft Drilled to 5716.0 ft Drilled to 7367.0 ft Circulated at 7367.0 ft Pumped out of hole to 6797.0 ft R.I.H. to 7367.0 ft Circulated at 7367.0 ft Backreamed to 2943.0 ft Pulled out of hole to 838.0 ft R.I.H. to 7367.0 ft Circulated at 7367.0 ft Pulled out of hole to 838.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 500.0 ft (5-1/2in OD) Ran Casing to 7344.0 ft (5-1/2in OD) Circulated at 7344.0 ft Held safety meeting Mixed and pumped slurry - 352.000 bbl Rigged down Cement head Ran Tubing in stands to 1008.0 ft Mixed and pumped slurry - 139.000 bbl Circulated at 0.0 ft Pulled Tubing in stands to 1008.0 ft Rigged down Divertor Rigged up Casing head Rigged up BOP stack Tested Casing Tested BOP stack Laid out 4in drill pipe from derrick Laid out Tubing from derrick Racked back drill pipe Serviced Block line 1 22 December 98 Facility Date/Time 09 Sep 98 10 Sep 98 11 Sep 98 12 Sep 98 13 Sep 98 14 Sep 98 M Pt L Pad Progress Report Well MPL-45 Rig Nabors;~S/~~ Page Date Duration Activity 03:30-04:30 04:30-06:00 06:00-13:30 13:30-15:30 15:30-01:00 01:00-01:30 01:30-06:00 06:00-08:30 08:30-09:00 09:00-18:30 18:30-19:00 19:00-02:00 02:00-03:00 03:00-06:00 06:00-07:00 07:00-07:30 07:30-10:30 10:30-11:30 11:30-13:30 13:30-14:30 14:30-01:00 01:00-02:00 02:00-03:30 03:30-05:30 05:30-06:00 06:00-08:00 08:00-11:00 11:00-13:30 13:30-15:00 15:00-15:30 15:30-18:30 18:30-23:30 23:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-09:30 09:30-13:00 13:00-23:00 23:00-02:00 02:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-10:30 10:30-12:30 12:30-14:00 14:00-16:00 16:00-16:30 16:30-23:30 23:30-03:00 03:00-05:30 05:30-06:00 1 hr 1-1/2 hr 7-1/2 hr 2 hr 9-1/2 hr 1/2 hr 4-1/2 hr 2-1/2 hr 1/2 hr 9-1/2 hr 1/2 hr 7 hr 1 hr 3 hr 1 hr 1/2 hr 3 hr 1 hr 2 hr 1 hr 10-1/2 hr 1 hr 1-1/2 hr 2 hr 1/2 hr 2hr 3 hr 2-1/2 hr 1-1/2 hr 1/2 hr 3 hr 5 hr 4-1/2 hr 1 hr 1 hr 1/2 hr 3 hr 3-1/2 hr 10hr 3 hr 2 hr 1 hr 1 hr 1/2 hr 2 hr 2 hr 2 hr 1-1/2 hr 2 hr 1/2 hr 7 hr 3-1/2 hr 2-1/2 hr 1/2 hr Serviced Drillstring handling equipment Made up BHA no. 3 R.I.H. to 7238.0 ft Drilled installed equipment - Float shoe Drilled to 7520.0 ft Serviced Top drive Drilled to 7644.0 ft Drilled to 7709.0 ft Serviced Top drive Drilled to 7993.0 ft Serviced Top drive Drilled to 8434.0 ft Took MWD survey at 8182.0 ft Drilled to 8561.0 ft Drilled to 8656.0 ft Serviced Top drive Drilled to 8750.0 ft Circulated at 8750.0 ft Pumped out of hole to 7332.0 ft R.I.H. to 8750.0 ft Drilled to 9365.0 ft Circulated at 9365.0 ft Pulled out of hole to 7332.0 ft R.I.H. to 9365.0 ft Circulated at 9365.0 ft Circulated at 9365.0 ft Pulled out of hole to 177.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Liner to 2140.0 ft (3-1/2in OD) Ran Tubing to 2112.0 ft (2.063 in OD) Ran Drillpipe in stands to 9365.0 ft Circulated at 9365.0 ft Cleared Mud pumps Cleared Mud pumps Circulated at 9365.0 ft Cleared Header box Filter Brine Circulated at 9365.0 ft Laid down 2155.0 ft of 2-7/8in OD drill pipe Circulated at 7212.0 ft Laid down 7212.0 ft of 2-7/8in OD drill pipe Serviced Top drive Laid down 7212.0 ft of 2-7/8in OD drill pipe Laid down 2112.0 ft of Tubing Laid down 1985.0 ft of 2-7/8in OD drill pipe Worked on BOP - BOP stack Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 2383.0 ft (2-3/8in OD) Pulled Tubing in stands to 2383.0 ft Repaired Completion equipment Ran Tubing to 500.0 ft (2-3/8in OD) 2 22 December 98 Facility Date/Time 15 Sep 98 16 Sep 98 17 Sep 98 M Pt L Pad Progress Report Well MPL-45 Rig Nabors 4F2S/~7~ Page Date Duration Activity 06:00-06:30 06:30-05:00 05:00-06:00 06:00-06:30 06:30-12:30 12:30-03:30 03:30-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-11:00 11:00-12:00 12:00-19:00 19:00-23:00 23:00-01:00 O1:00-03:00 03:00-06:00 1/2 hr 22-1/2 hr 1 hr 1/2 hr 6 hr 15hr 2-1/2 hr 1/2 hr 1-1/2 hr 1 hr 2 hr 1 hr 7 hr 4 hr 2 hr 2 hr 3 hr Held safety meeting Ran Tubing to 6100.0 ft (2-3/8in OD) Pulled Tubing in stands to 5000.0 ft Held safety meeting Pulled Tubing in stands to 3652.0 ft Ran Tubing in stands to 5920.0 ft Pulled Tubing in stands to 4300.0 ft Held safety meeting Pulled Tubing in stands to 3600.0 ft Rig waited: Assessed situation Ran Tubing to 4600.0 ft (2-3/8in OD) Held safety meeting Ran Tubing to 7175.0 ft (2-3/8in OD) Rigged down BOP stack Installed Xmas tree Freeze protect well - 50.000 bbl of Base oil Cleared Sand traps 3 22 December 98 Milne Point Unit Alaska State Plane Zone 4 Milne Point L Pad MPL-45 BPXA PDC O08951.7 SURVEY REPORT 17 September, 1998 ORIGINAL Your Ref: API-500292291300 Last Survey Date 02-September-98 Job# AKMWS0363 KBE- 50.55' DRILLING C;ERVlI~EC; Survey Reft svy2208 Milne Point Unit Sperry-Sun Drilling Services Survey Report for MPL-45 Your Ret: API-500292291300 Alaska State Plane Zone 4 Milne Point L Pad Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (fi) (fi) 0.00 0,000 0.000 -50.55 0.00 11.00 0.000 0.000 -39.55 11.00 211.60 0.920 349.670 161.04 211.59 304.59 1.100 349.930 254.02 304.57 396.59 0,560 313.700 346.01 396.56 488.98 0,790 202.900 438.39 488.94 578.86 1,490 186,420 528.26 578.81 673.26 2.780 185,450 622.59 673.14 764.59 4.150 195.340 713.75 764.30 864.15 5.610 196.160 812.95 863.50 955.09 6.050 193.970 903.42 953.97 1050.20 7.510 198.790 997.86 1048.41 1145.39 9.700 200.920 1091.97 1142.52 1241.97 11.200 191.870 1186.95 1237.50 1336.70 11.660 191.650 1279.80 1330.35 1433.41 13,230 186.450 1374.24 1424.79 1529.06 12.950 187.150 1467.41 1517.96 1626.25 15.610 190,720 1561.59 1612.14 1719.97 18.150 190.880 1651.26 1701.81 1817.03 20.260 191.010 1742.92 1793.47 1912.00 22.160 191.000 1831.45 1882.00 2008.04 24,650 188.070 1919.58 1970.13 2103.90 27.210 186.630 2005.79 2056.34 2197.54 30.110 186,810 2087.94 2138.49 2292.43 33.200 187.580 2168,71 2219.26 2387.81 36.080 188.630 2247.17 2297.72 2483.43 38.800 188.620 2323.09 2373.54 2580.62 41.590 188,190 2397.32 2447.87 2676.08 44.490 189.160 2467.08 2517.63 2771.67 47.310 189.520 2533.60 2564.15 Local Coordinates Northings (ft) 0.00 N 0.00 N 1.58 N 3.20 N 4.38 N 4.10N 2.37 N 1.13S 6.52 S 14.67 S 23.59 S 34.34 S 47.72 S 64.50 S 82.88 S 103.45 S 124.96 S 148.62 S 175.35 S 206.69 S 240.42 S 278.03 S 319.60 S 364.20 S 413.60 S 467.26 S 524.73 S 586.77 S 651.17 S 718.90 S Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (fi) (fi) (~) (°/100fi) 0.00 E 6031741.50 N 544760.28 E 0.00 0.00 E 6031741.50 N 544760.28 E 0,000 0.00 0.29W 6031743.08 N 544759.98 E 0,459 -1.55 0.58W 6031744.69 N 544759.68 E 0.194 -3.13 1.06W 6031745.87 N 544759.20 E 0.791 -4.26 1.63W 6031745.59 N 544758.62 E 1.211 -3.94 2.00W 6031743.86 N 544758.26 E 0.852 -2.18 2.36W 6031740.36 N 544757.93 E 1.367 1.34 3.44W 6031734.96 N 544756.88 E 1.631 6.81 5.75W 6031726.80 N 544754.62 E 1,468 15.13 8.15W 6031717.86 N 544752.28 E 0,542 24.23 11.36W 6031707.10 N 544749.13 E 1,646 35.23 16.23W 6031693.68 N 544744.34 E 2.325 48.99 21.06W 6031676.87 N 544739.61E 2,298 66.14 24.89W 6031658.47 N 544735.89 E 0.488 84.79 28.10W 6031637.88 N 544732.80 E 1.993 105.57 30.67W 6031616.36 N 544730.37 E 0,336 127.22 34.45W 6031592.68 N 544726.72 E 2,882 151.13 39.56W 6031565.92 N 544721.78 E 2,711 178.21 45,62W 6031534.54 N 544715.91 E 2,174 209.98 52.18W 6031500.77 N 544709.55 E 2,001 244.16 58.45W 6031463.12 N 544703.51E 2,861 282.19 63.78W 6031421.52 N 544698.42 E 2,750 324.07 69.04W 6031376.89 N 544693.43 E 3,098 368.96 75.29W 6031327.46 N 544687.48 E 3.284 418.72 82,95W 6031273.75 N 544680.14 E 3.084 472.86 91.67W 6031216.23 N 544671,77 E 2.645 530,88 100.83W 6031154.13 N 544662.98 E 2.885 593.50 110.67W 6031089.67 N 544653.53 E 3.116 658.52 121.82W 6031021.88 N 544642.79 E 2.962 726.98 Comment Continued.,. 17 September, 1998 - 10:26 - 2 - DrillQuest Milne Point Unit Sperry-Sun Drilling Services Survey Report for MPL-45 Your Ref: API-500292291300 Alaska State Plane Zone 4 Milne Point L Pad Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings (ft) (ft) (ft) (ft) 2866,94 49.760 188,670 2596.68 2647.23 789.39 S 2962.52 52.320 188.680 2656.77 2707.32 862,85 S 3057.97 54.380 186.480 2713.75 2764.30 938,75 S 3153.73 55.550 183.960 2768.73 2819.28 1016,83 S 3249.49 57.950 182.130 2821.23 2871.78 1096,79 S 3345.26 60.460 182.350 2870.26 2920.81 1178.98 S 3441.06 63,850 181.230 2915.00 2965.55 1263.64 S 3536.89 67.970 181.440 2954.11 3004.66 1351.08 S 3632.36 71,490 182.140 2987.18 3037.73 1440.58 S 3727.76 74.240 180.640 3015.28 3065.83 1531.70 S 3823.25 74.400 180.470 3041.09 3091.64 1623.63 S 3918.83 73.130 181.660 3067.81 3118.36 1715.38 S 4014.21 73.310 182.320 3095.35 3145.90 1806.65 S 4111.53 72.960 182.530 3123.58 3174.13 1899.70 S 4221.68 72.740 182.290 3156.06 3206.61 2004.86 S 4318.84 75.810 182.370 3182.39 3232.94 2098.29 S 4509.19 75,270 183,040 3229.92 3280.47 2282.40 S 4698.97 74.610 182.230 3279.23 3329.78 2465.47 S 4891.86 75.080 183.000 3329.66 3380.21 2651.46 S 5082.92 75,230 182.890 3378.61 3429,16 2835.89 S 5178.74 74.760 164,880 3403.42 3453,97 2928.23 S 5370.51 74.100 184.850 3454.90 3505,45 3112.30 S 5465.95 74.180 183,530 3480.98 3531,53 3203.85 S 5561.87 74,440 182.930 3506.92 3557.47 3296.05 S 5658.06 74.450 185.880 3532.72 3583.27 3388.43 S 5753.08 74.440 185.380 3558.20 3608.75 3479.53 S 5649.19 74.020 185.320 3564.32 3634.87 3571.62 S 5944.85 74.140 185.300 3610.56 3661.11 3663.22 S 6040.97 74.370 185.190 3636.64 3687.19 3755.34 S 6136.45 74.810 184.680 3662.02 3712,57 3847.05 S Eastings (ft) 133,09 W 144.30 W 154.38 w 161.50 W 165.74 W 168.95 W 171,59 W 173.63 W 176.43 W 178.63 W 179.52 w ' 181.23 w 184.40 W 188.34 W 192.76 W 196.57 W 205.26 W 213.69 W 222.19W 231.67 W 237.94 W 253.61 W 260.32 W 265.52 W 272.64 w 281.62 w 290,24 w 298.75 w 307.21 w 315.13 W Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) (°/100fi) 6030951.32 N 544631.95 E 2.657 798.20 6030877.79 N 544621.18 E 2.678 872.38 6030801.83 N 544611.56 E 2.842 948.89 6030723.72 N 544604.91E 2.477 1027.28 6030643.74 N 544601.15 E 2.972 1107,30 6030561.52 N 544598.43 E 2.628 1189.45 6030476.85 N 544596.31E 3.686 1273.99 6030389.40 N 544594.79 E 4.304 1361.25 6030299.89 N 544592.53 E 3.751 1450.64 6030208.75 N 544590,88 E 3.251 1541.59 6030116.81N 544590.54 E 0.240 1633.22 6030025.06 N 544589.39 E 1.787 1724,75 6029933.78 N 544586.77 E 0.689 1815,92 6029640.70 N 544583.39 E 0.415 1908,95 6029735.52 N 544579.59 E 0.289 2014,08 6029642.06 N 544576.35 E 3.161 2107.47 6029457.90 N 544568.77 E 0.443 2291.61 6029274.79 N 544561.44 E 0.539 2474.69 6029088.75 N 544554.07 E 0.456 2660.68 6028904.26 N 544545.69 E 0.096 2845.22 6028811.89 N 544539.98 E 2.065 2937.74 6028627.73 N 544525.42 E 0.344 3122.47 6028536.14 N 544519,26 E 1.333 3214.26 6028443.91 N 544514.61 E 0.660 3306.55 6028351.49 N 544508.05 E 2.955 3399.20 6028260.34N 544499.62 E 0.507 3490.73 6028168.20 N 544491.55 E 0.441 3583.23 6028076.55 N 544483,59 E 0.127 3675.22 6027984.37 N 544475,69 E 0.263 3767.73 6027892.62 N 544468,32 E 0.691 3859.78 Comment Continued,,. 17 September, 1998 - 10:26 - 3 - DrfllQuest Sperry-Sun Drilling Services Survey Report for MPL-45 Your Ref: API-500292291300 Milne Point Unit Alaska State Plane Zone 4 Milne Point L Pad Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) Comment 6231,97 74,020 186.000 3687.68 3738.23 6327.76 74.110 185.970 3713.98 3764.53 6423.53 73.810 188.390 3740.44 3790.99 6519.28 74.410 187,190 3766.66 3817.21 6615.69 75.140 188.730 3791.98 3842.53 6709.57 75.610 186.380 3815.69 3866.24 6806.24 75,420 186,000 3839.87 3890.42 6901.90 73.530 186,980 3865.47 3916.02 6996,86 73.510 188,880 3892.41 3942.96 7092.74 72.730 188.630 3920.25 3970,80 7188,43 74.140 186.940 3947.53 3998.08 7284,08 76.320 186.420 3971.92 4022.47 7309,85 76.540 186.720 3977.96 4028,51 7405.66 82.990 185.720 3994.98 4045,53 7467.28 85.900 185.210 4000.94 4051,49 7561.91 84.670 183.070 4008,72 4059,27 7656.69 92.000 182.670 4011.47 4062,02 7751.21 89.910 185,270 4009.90 4060.45 7783,52 88.890 185.880 4010.24 4060.79 7815.38 87.910 185.630 4011.13 4061.68 7844.50 89,600 185,690 4011.76 4062.31 7877.62 91.290 186.110 4011.50 4062.05 7908.21 90.180 187.760 4011.11 4061.66 7941.00 89.750 188.060 4011.13 4061.68 7973.67 86.390 186.980 4012.23 4062.78 8003.14 85.530 186.730 4014.31 4064.86 8035.07 84.510 186,200 4017.08 4067.63 8067.89 86,490 186.570 4019,65 4070.20 8098.85 87.750 186.220 4021.21 4071.76 8129.02 88.490 185.950 4022.20 4072.75 3938.66 S 323.69W 6027800.97 N 544460.32 E 1.567 3951.78 4030.26 S 333.29W 6027709.30 N 544451.26 E 0.099 4043.88 4121.57 S 344.79W 6027617.92 N 544440.31 E 2.449 4135.86 4212.81S 357.28W 6027526.61N 544428.38 E 1.359 4227.85 4304.94 S 370.16W 6027434.41 N 544416.05 E 1.717 4320.77 4394.98 S 382.10W 6027344.30 N 544404.65 E 2.473 4411.52 4488.03 S 392.19W 6027251.19 N 544395.12 E 0.428 4505.11 4579.61 S 402.61W 6027159.55 N 544385.26 E 2.209 4597.25 4669.79 S 415.17W 6027069.29 N 544373.24 E 1.919 4688.20 4760.47 S 429.13W 6026978.53 N 544359.82 E 0.851 4779.77 4851.34S 441.55W 6026887.59 N 544347.95 E 2.244 4871.39 4943.19 S 452.31W 6026795.67 N 544337.75 E 2.339 4963.84 4968.08 S 455.17W 6026770.77 N 544335.03 E 1.418 4988.89 5061.76 S 465.37W 6026677.03 N 544325.40 E 6.810 5083.11 5122.81S 471.21W 6026615.95 N 544319.92 E 4.794 5144.43 5216.86 S 478.02W 6026521.85 N 544313.68 E 2.602 5238.72 5311.42 S 482.76W 6026427.27 N 544309.51E 7.745 5333.31 5405.68 S 489.31W 6026332.97 N 544303.54E 3.529 5427.78 5437.84S 492.45W 6026300.79 N 544300.59 E 3.678 5460.09 5469.53 S 495.64W 6026269.09 N 544297.59 E 3.174 5491.94 5498.50 S 498.51W 6026240.10 N 544294.89 E 5,807 5521.05 5531.44S 501.91W 6026207.14 N 544291.68 E 5.258 5554.16 5561.80 S 505.61W 6026176.76 N 544288.17 E 6.500 5584.73 5594.28 S 510.12W 6026144.25 N 544283.86 E 1.599 5617.49 5626.64S 514.39W 6026111.86 N 544279.78 E 10.802 5650.11 5655.83 S 517.90W 6026082.65 N 544276.45 E 3.038 5679.49 5687.44S 521.48W 6026051.03 N 544273.06E 3.597 5711.29 5719.95 S 525.12W 6026018.49 N 544269.61 E 6.137 5744.00 5750,68 S 528.57W 6025987.74 N 544266.35 E 4.223 5774.92 5780,66 S 531.76W 6025957.74 N 544263.34E 2.611 5805.07 Continued.,. 17 September, 1998 - 10:26 - 4 - DrillQuest Milne Point Unit Sperry-Sun Drilling Services Survey Report for MPL-45 Your Ref: API-500292291300 Alaska State Plane Zone 4 Milne Point L Pad Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth Northings (fi) (ft) (ft) (ft) 8162.03 89.660 185.760 4022.73 4073.28 5813.50 S 8193.25 91.020 185.830 4022.55 4073.10 5844.55 S 8;224.03 91.320 186.340 4021.92 4072.47 5875.15 S 8255.20 92.100 186.580 4020.99 4071.54 5906.11 S 8286.37 90.000 186.610 4020.42 4070,97 5937.07 S 8319.60 89.050 187.160 4020.69 4071.24 5970.06 S 8384.44 94.190 190.500 4018.86 4069.41 6034.07 S 8414.25 90.220 191.220 4017.71 4068.26 6063.32 S 8447.28 88,890 191.260 4017.97 4068.52 6095.72 S 8476.44 86.670 190.090 4019.10 4069.65 6124.35 S 8508.23 85.350 186.730 4021.31 4071.86 6155.63 S 8541.64 85.290 188.850 4024.04 4074.59 6188.54 S 8572.70 85.720 188.040 4026.47 4077.02 6219.17 S 8603.79 88.770 187.800 4027.96 4078.51 6249.92 S 8635.69 91.540 192.560 4027.88 4078.43 6281.31 S 8667.32 91.630 192.480 4027.00 4077.55 6312.18 S 8698.03 88.770 190.630 4026.90 4077.45 6342.26 S 8728.84 88.740 188.830 4027.57 4078.12 6372.62 S 8761.83 88.890 189.410 4028.25 4078.80 6405.18 S 8791.99 88.650 189.470 4028.90 4079.45 6434.93 S 8823.62 89.420 188.480 4029.43 4079.98 6466.16 S 8886.17 93.140 189.970 4028,03 4078.58 6527.88 S 8918.38 93.020 188.880 4026,30 4076.85 6559.61 S 8950.79 91.450 187.700 4025,04 4075.59 6591.65 S 8982.33 90.280 187.850 4024,56 4075.11 6622.90 S 9014.80 92.340 187.370 4023.82 4074.37 6655.07 S 9046.95 92.680 186.510 4022.41 4072.96 6686.96 S 9076.81 94.220 186.590 4020.61 4071.16 6716.57 S 9108.83 96.540 187.150 4017.61 4068.16 6748.21 S 9140.21 97.660 186.820 4013.73 4064.28 6779.12 S Local Coordinates Global Coordinates Dogleg Vertical Eastings Northings Eastings Rate Section (ft) (fi) (ft) (°/100ft) (ft) 535.13 W 6025924.89 N 544260.17 E 3.591 5838.07 538.28 W 6025893.81 N 544257.20 E 4.362 5869.29 541.54 W 6025863.19 N 544254.13 E 1.922 5900.06 545.05 W 6025832.21 N 544250.81 E 2.618 5931.21 548.63 W 6025801.23 N 544247.42 E 6.738 5962.36 552.61 W 6025768.22 N 544243.63 E 3.303 5995.57 562.55 W 6025704.15 N 544234.07 E 9.452 6060.23 568.16 W 6025674.87 N 544228.64 E 13.535 6089.86 574.60 W 6025642.43 N 544222.40 E 4.028 6122.71 580.00 W 6025613,77 N 544217.17 E 8.604 6151.71 585.18 W 6025582,45 N 544212.18 E 5.954 6183.34 590.27 W 6025549,52 N 544207.29 E 0.400 6216.57 594.82 W 6025518,86 N 544202.92 E 2.945 6247.49 599.10 W 6025488.08 N 544198.83 E 9.840 6278.50 604.73 W 6025456.66 N 544193.38 E 17.263 6310.27 611.59 W 6025425.76 N 544186.71 E 0,381 6341.63 617.74 W 6025395.64 N 544180.75 E 11.091 6372.15 622.94 W 6025365.25 N 544175.72 E 5.842 6402.85 628.17 W 6025332.65 N 544170.69 E 1.816 6435.76 633.12 W 6025302.88 N 544165.92 E 0.820 6465.83 638.05 W 6025271.61 N 544161.18 E 3.965 6497.38 648.07 W 6025209.64 N 544151.53 E 6.406 6559.75 653.34 W 6025178.08 N 544146.45 E 3.400 6591.83 658.01 W 6025146.00 N 544141.98 E 6.058 6624.16 662.28 W 6025114.73 N 544137.90 E 3.740 6655.67 666.57 W 6025082.53 N 544133.79 E 6.514 6688.10 670.46 W 6025050.63 N 644130.11 E 2.874 6720.20 673.86 W 6025021.00 N 544126.88 E 5.164 6750.00 677.67 W 6024989.33 N 544123.26 E 7.452 6781.86 681.45 W 6024958.40 N 544119.66 E 3.719 6812.99 Comment Continued.,. 17 September, 1998 - 10:26 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for MPL-45 Your Ref: API-500292291300 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 9171.23 95.800 186.120 4010.10 4060.65 9233.65 91.350 185.430 4006.21 4056.76 9314.07 91.420 185.030 4004.26 4054.81 9365.00 91.420 185.030 4003.00 4053.55 6809.73 S 684.93W 6024927.77 N 544116.37 E 6.401 6843.78 6871.70 S 691.19W 6024865.77 N 544110.48 E 7.214 6906.06 6951.76 S 698.52W 6024785.66 N 544103.64 E 0.505 6986.46 7002.48 S 702.98W 6024734.92 N 544099.48 E 0.000 7037.37 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 185.203° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9365.00ft., The Bottom Hole Displacement is 7037.67ff., in the Direction of 185.733° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 0.00 0.00 0.00 N 0.00 E Tie-on Survey 9365.00 4053.55 7002.48 S 702.98 W Projected Survey Comment Projected Survey Alaska State Plane Zone 4 Milne Point L Pad 17 September, 1998 - 10:26 - 6 ~ DrillQuest I-I Ft I I__1__ I N I::S S I:::: FI ~J I r' I~ S To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPL-45, AK-MM-80363 December 16, 1998 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22913-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22913-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPIES OF THE TRANSMI'I~AL LETYER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Al~ _~q25~..~ .. DEC 17 199~ Date: /gas~ ....-~3a~ ~n~. Commi~ior~ 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 Company To: WELl, LOG TRANSMITr~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPL45, AK-MW-80363 December 16, 1998 1 LDWG formatted Disc with verification listing. API#: 50-029-22913-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPIES OF THE TRANSMITTAL LE'ITER TO THE AITENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. BP Exploration (Alaska) Inc. Petro-technical Data Cemer, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 DEC IT ".,..998 (;,ii .3,3::s c:ons. ' .... ~chor~..e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company MEMORANDUM TO: THRU' State of Alaska Alaska Oil and Gas Conservation Commission David John~,'~ Chairman Blair Wondzell, P. I. Supervisor ~(,~,/~6 FROM' Larry Wade,/~,~. SUBJECT: Petroleum Idspectdr DATE' 9/7/98 FILE NO' .DOC BOP Test Nabors 27E MPU L-45 PTD 98-169 September 7,1998: I traveled to Milne Pt to witness a BOP test on Nabors 27E. The last time I witnessed a BOP test on this rig it took 10 hours. This time the choke manifold was serviced and the right cross-overs were on the rig floor and the test time reflects it. Everything went well this time and the test time reflects it. SUMMARY: I witnessed a BOP test on Nabors 27E, 0 failures, 3.5 hours. Attachments: akqgigfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 5 1/2" Test: Initial Workover: Nabors BPX MPU L 45 Set @ Weekly Rig No. 27E PTD# Rep.: Rig Rep.: 7,343 Location: Sec. X Other 98-169 DATE: September ?, 1998 Rig Ph.# 6.59-4384 Paul Lockwood Leonard Schiller T. R. Meridian Test Pressures 3500 MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location X Standing Order Posted X BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign X Drl. Rig X Hazard Sec. X Quan. 1 Test Press. P/F P 3,500 P 3,500 P 3,500 P 3,500 P 3,5O0 P 3, 500 P 3,500 FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quart. Pressure P/F '1 3,500 P I 3,500 P 1 3, 500 P I 3,500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 3,500 P 38 3,500 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 2,900 I Pressure After Closure 2, 500 I MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 17 sec. Trip Tank X X' System Pressure Attained minutes 35 sec. Pit Level Indicators X' X' Blind Switch Covers: Master: x' I~emote: x Flow Indicator X' X' Nitgn. Btl's: 1900-2000-2000-2000 Meth Gas Detector X X , 2000-2000-2000-2000 Psig. H2S Gas Detector X' X' TEST'RESULTS~: Number of Failures: 0 ,Test Time: 3. D Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to tile AOCCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: Grig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade FI-021L (Rev.12/94) Akqgigfe.xls Maunde,r, Tho, ma,$ E Fro m: Sent: To: Sublect: Importance: Maunder, Thomas E (NTS) Friday, September 04, 1998 11:45 AM PBU, Dflg Rig 27E Pdnce, Paul K; Reeves, T Brent; Scott, George R (Codeco); Campoamor, Kathy L (NANA) Port Collar Depth-MP L-45 High This note documents the conversation of Mr. Dave Johnston, Chairman of AOGCC and Tom Maunder, ODE 27E regarding changing the planned depth of the port collar in MP L-45. As originally permitted, the port collar was planned to be set a minimum of 200' below the permafrost as a backup in case a 2nd cement stage was needed. It is proposed to raise the installed depth to about 1000' and increase the foamed cement volume to help reduce circulating densities. On well E-21 cement was neady circulated with a planned lead cement interval of surface to 2300'. With the port collar pJaced at 1000', the planned lead interval will be surface to 1500' and a new foamed interval will be placed from 1500' to 2300'. Foamed and neat cement volumes below 2300' will not change. ,,~~p~~s approved by Mr. Johnston. Tom Maunder (' ODE Nabors 27E cc: Mr. Dave Johnston, AOGCC Maunder, Thomas E (NTS) From: Sent: To: Cc: Subject: Importance: Maunder, Thomas E (NTS) Friday, September 04, 1998 11:45 AM PBU, Drlg Rig 27E Prince, Paul K; Reeves, T Brent; Scott, George R (Codeco); Campoamor, Kathy L (NANA) Port Collar Depth-MP L-45 High This note documents the conversation of Mr. Dave Johnston, Chairman of AOGCC and Tom Maunder, ODE 27E regarding changing the planned depth of the port collar in MP L-45. As originally permitted, the port collar was planned to be set a minimum of 200' below the permafrost as a backup in case a 2nd cement stage was needed. It is proposed to raise the installed depth to about 1000' and increase the foamed cement volume to help reduce circulating densities. On well E-21 cement was neady circulated with a planned lead cement interval of surface to 2300'. With the port collar placed at 1000', the planned lead interval will be surface to 1500' and a new foamed interval will be placed from 1500' to 2300'. Foamed and neat cement volumes below 2300' will not change. ~~~s approved by Mr. Johnston. Tom Maunder (" ODE Nabors 27E cc: Mr. Dave Johnston, AOGCC TONY KNOWLE$, GOVEF{NOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 26. 1998 T. Brent Reeves Drilling Engineering Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPL-45 BP Exploration (Alaska) Inc. Permit No. 98-169 Sur. Loc.: 3552~SL. 5118'EWL, Sec. 8, T13N, R10E. UM Btmhole Loc: 19752qSL, 487'WEL, Sec. 18, T13N. R10E. UM Dear Mr. Reeves: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given bx' contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman "' BY ORDER OF THE COMMISSION dlf/enclosures cc: Deparlment of Fish & Game. ttabitat Section w/o encl. Department of Environmental Conservation w/o encl. '- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work l~ Drill [-1Redrill Ilb. Typeofwell [-I Exploratory [] Stratigraphic Test I~DevelopmentOili [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 57' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025515 4. Location of well at surface tc_~--L 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3552' NSL, 5118'.E¥¢1~, SEC. 8, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3564' NSL, 303' WEL, SEC. 18, T13N, R10E, UM MP L-45 At total depth 9. Approximate spud date Amount $200,000.00 1975' NSL, 487' WEL, SEC, 18, T13N, R10E, UM 09/01/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025509, 3305.1.I No Close Approach 2544 9210' MD / 4086' TVD , 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' Maximum Hole An,qle 89.505° Maximum surface 1397 psig, At total depth (TVD) 4086' / 1827 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) 16" 13-3/8" 68# L-80 BTC-MOD 120' 31' 31' 151' 151' 260 sx Arctic Set (Approx.) 6-3/4" 5-1/2" 15.5# J-55 BTC-MOD 7420' 30' 30' 7450' 4053' 518 sx Coldset III "PF", 240 sx Foamed, 295 sx 'G' 4-3/4" 3-1/2" 9.3# J-55 8-RD. SCC 1760' 7350' 4043' 9210' 4086' ,. 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate . Production .. : Liner :~;.: : Perforation depth: measured: : r , 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: R. George Scott, 564-5862~ ..~,I\~ ~ ~ :~.. ,.,~) i. ~ ,,I of ,,~.. Prepared By NamelNumbe~'. Carol Withey, 564-4114 21. I hereby certify t o~ng ~s tr correct to)the best of my knowledge Signed ,--"~es~.Z~,//~ .-~ ' a. :~....¢J,/ ' / - T great Reeves_ ' -~/'~[ ~ 4 /'"1~.~//~/~.~ . :/./:/ ~ Title Drilling Engineering Supervisor Date // / ~---- '- Commission Use Only Permit Number I APl Number I Approval .Dat.e. ,.~ See cover letter ff~' - / (~ °t 5o- 0 2,.¢/- 2, 2. ¢/! 2, ~g _~:,~ ~ - 2'~ for other requirements Conditions of Approval' Samples Required [] Yes _[~rNo Mud Log Required [] Yes [~No Hydrogen Sulfide Measures []Yes'~No Directional Survey Required [~'~Yes [] No Required Working Pressure for BOPE F]2M; •3M; []5M; [-ll0M; []15M Other: ' ..,,g~u Johnston by order of Approved By uav, fl Commissioner the commission STATE OF ALASKA ALASKA ~. ~-AND GAS CONSERVATION COIV,~,~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work C~ Drill I--I Redrill lb. Type of well I'-'1 Exploratory I--1Stratigraphic Test [~ Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) i10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 57' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025515 '-~ 4. Location of well at surface ~..~¢.~.L.-- 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3552' NSL, 5118' EMCE, SEC. 8, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3564' NSL, 303' WEL, SEC. 18, T13N, R10E, UM MP L-45 Attotal depth 9. Approximate spud date Amount $200,000.00 1975' NSL, 487' WEL, SEC, 18, T13N, R10E, UM 09/01/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025509, 3305' I No Close Approach 2544 9210' MD / 4086' TVD 16. To be completed for deviated wells il 7. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' Maximum Hole Angle 89.505 ° Maximum surface 1397 psig, At total depth (-rVD) 4086' / 1827 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ,~,~ 16" 13-3/8" 68# L-80 BTC-MOD 120' 31' 31' 151' 151' 260 sx Arctic Set (Approx.) ,...6~4¢' 5-1/2" 15.5# J-55 BTC-MOD 7420' 30' 30' 7450' 4053' 518 sx Coldset II1 "PF", 240 sx Foamed, 295 sx 'G' 4-3/4" 3-1/2" 9.3# J-55 8-RD. aCC 1760' 7350' 4043' 9210' 4086' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition'sum.mary , . Total depth: measured · . · .'.. ~/ ~ :,i ':" Yeet Plugs(measured) ORIG!NAL true vertical "' '-" :'.~.feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production ~? ii.-;~ i/'" ~ ~ ~:,~i" !~ !%! Liner ~ ~'-::: '-"~. :: -~ ~- '~-' , Perforation depth: measured ~,'¢~,~'::'~.-~. :,i;; & {iir_~ C0:i~;. true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements i Contact Engineer Name/Number: R. George Scott, 564-5862 '.~-__¢.~¢~ ~. i ~. l ~ ~r. Prepared By Name/Number: Carol Withey, 564-4114 21. I hereby certify th~going is tr~ ¢ correct to)the best of my knowledge Signed ,---~"- ~ /< . -- .~' '/'-.-/../,?~.,,~ ~ T. Brent R?ves~,?~/~/j/ //~.~.~-~ Title Drilling Engineering Supervisor '" :.D, AtO~. ,~--///~'/Z-'~",~/ /' / /- / '-~" Commission Use Only Permit Number APl Number A~roval Date.,¢~ See cover letter ~" 1 6~ 50- O~Cl - Z~L q J.~ ~¢'-",~¢~;~ for other 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 Pressure for DOPE []2M; [--13M; []SM; []10M; [] 15M ~ Other: ~a[ .'419fl8Q 6y by order of ~,,~ ___ 0avid W. Johnston Approved By Commissioner the commission Date ~-~c~,~ Form 10-401 Rev. 12-01-85 Submit In Triplicate ' Shared Services Drilling Contact: R. George Scott I Well Name: IMP L-45 Well Plan Summary IType of Well (producer or injector): ISchrader Bluff Horizontal Producer 564-5862 Surface Location: 3,552' FSL, 5,118' FEL, S8 T13N R10E UM Target Location: 3564' FSL, 303' FEL, S18 T13N R10E UM Bottom Hole Location: 1975' FSL 487' FEL, S18 T13N R10E UM I AFE Number: 133143 I I Estimated Start Date: I 1 Sept. 98I IUD,' I 9210' I I TVD; Rig: I Nabors 27E Operating days to complete: 14o ' I 114.0 I KBE: ]57ft Well Design: [ Schrader Bluff Producer Formation Markers: Formation Tops MD TVDSS KOP 400 351' Base of Permafrost 1879 1800' :Fop of Ugnu 4667' 3276' Top M Sand 5633' 3531' Top NA 6925' 3873' Top of the N-A (EMW 8.6 ppg) 5-1/2" Casing Shoe 7450' 4004' (Picked by Geologist) Top "OA" 7609' 4017' Geo-steering will be required to keep in "OA" Base "OA" 9210 4037' TD 9210' 4037' TD Casing/Tubing Program: Hole ~ize - Csg~ Wt/Ft Grade Conn. Length Top Bottom Tb9 O.D. MDfrVD MD/TVD (bkb) 16" 13-3/8" 68# L-80 BTC-MOD 120' 31 '/31' 151' / 151' 7-7/8 .... 5-1/2"** 15.5# J-55 BTC-MOD 7420' 30'/30' 7450'/4053' 4-3/4" 3-1/2" 9.3# J-55 8-RD. SCC 1760' 7350'/4043' 9210'/4086' Internal yield pressure of the 5-1/2" 15.5# casing is 4,810 psi. With a full column of gas (0.10 psi/ft) to the reservoir at _+4027' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.6 ppg EMW), is 1397 psi, well below the internal yield pressure rating of the 5-1/2" casing (4810psi). ** ** Note: The top joint in the 5-1/2" surface casing consists of a X-over from 7" to the 5-1/2" 15.5# J-55 BTC-MOD Casing. The 3-1/2" 9.3# liner has an ID of 2.992", OD of 4.180", Drift-2.867", collapse- 7400psi, Internal Yield-6980psi, Yield-109.37M lbs. The 5-1/2" 15.5#/ft. BTC MOD Casing has an I.D of 4.95", Drift-4.825", Coupling OD-6.05" Collapse-4,040psi, Internal Yield-4,810, Yield-248M. MP L-45 Well Plan PAGE 3 1 Sept 98 Logging Program: Open Hole Logs: Surface: FINAL: Cased Hole Logs: MWD directional only from surface to +2500' MD. 4-Arm Caliper Log From 7450'MD to 151' M.D. (Base of 13-3/8" Conductor.* MWD directional and LWD (GR/Resistivity/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 fi/hr. MWD Directional and LWD GR/RES. 7450'MD-9210'MD. (TD) None Mud loggers are NOT required for this well. *A conditioning trip may be made if required to assure running of the caliper. Mud Program: Special design considerations An inhibitive polymer mud is planned from surface to 7450'MD. Solids control is critical to the success of the system. A drill in Mud with calcium carbonate to limit fluid invasion from 7450'-9,210'MD Surface Mud Properties: I Density Marsh Yield LSRV 10 min pH Fluid (PPG) Viscosity Point gel Loss 8.6 150 40 50,000 8.5 NC 9.2 to 9.0 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel '~ Loss 9.0 50 30 14 16 8.5 <6 to to to to 9.5 60 35 9.0 LSVR- 40,000+, Fann-600/50-55, 300/40-45, 200/33-37, 6/18-20, 3/14-17 The surface casing will be drilled out to +/- 20' of new hole then the mud changed out to drill in mud for horizontal section. Well Control: Well control equipment consists of: Rig (Nabors 27E) ,13-5/8" 5000 psi W.P.Annular and 3000 psi Diverter with 10" Diverter Line. This Rig is equipped with 5000 psi W.P. variable pipe rams, blind/shear rams, and annular preventer used for drilling the horizontal section and for the completion, capable of handling maximum potential surface pressures. Note it is planned to test the BOPE to 3500psi with a cup tester, and the 5-1/2" casing to 3500psi as the anticipated maximum BHP is 1930 psi. Directional: I KOP: 1400' MD : I Maximum Hole Angle: J 89.505° @ 8078'md ' Close Approach Well: ~ None Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A or Drill Site #4 facility. Fluids Handling: All drilling and completion fluids will be hauled to Drill Site #4 or CC-2A for injection. Annular Injection: Not planned. MP L-45 Well Plan PAGE 4 1 Sept 98 MP L-45 Proposed Summary of Operations 1. Drill and Set 13-3/8" Conductor. Weld landing ring assembly on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 27E rig. 4. NU and function test 13-3/8 .... diverter. Spud Mud Will Have been Built as per Mud Program. 4" D.P, 2-7/8" work string and 2-7/8" drill pipe will have been stood back prior to spud. 5. Drill a 7-7/8" surface hole as per directional plan. Run Directional MWD from surface to +/- 3000+'MD. 6. POOH. MU a PDC bit on a motor, with Directional MWD and LWD GR/RES/ROP. 7. Drill 7-7/8" hole to 7450' as per directional plan. Stand back drill string and run 4-Armed Caliper from the 7450' M.D. to the bottom of the 13-3/8" conductor. 8. Run and Cement 5-1/2", 15.5#, J-55, Buttress-Modified casing using the 3 plug system method. Refer to attached Detailed Cement Program and Back-up Port Collar Operating Procedure. 9. Following the cementing of the well and the landing of the 7"x5-1/2" landing joint, rig down cementers. N/D diverter, MU casing head to Landing Joint (9500 ft-lbs torque.) Install BOPE with 2-3/8" rams. Test BOPE and Casing individually to 3500 psi, 74% of burst of 5-1/2# J-55 Casing. 10. PU 4-3/4" directional BHA and drill out cement collar and shoe and 20' of new hole. A 4-3/4" S81PX steel bodied 3 blade PDC bit is recommended to drill out and to TD. Circ. & Cond. Mud, no LOT will be required. Pump a 20 bbl. High visc. pill (70 Y.P.) sweep ahead of drill in fluid. (See Mud Program). 11. Short trip as required before POOH for 3-1/2" liner. Circ and condition wellbore POOH for 3-1/2" liner. NOTES: Hold a "pre-reservoir" meeting as per page 20 of Drlg. Policy Manual. Record on Morning Report. Monitor torque and do not exceed 80% of DP torque. Pump Iow/Hi visc. sweeps every 500' of new hole. Maintain adequate flow rates to clean hole. 12. Run 3-1/2" pre-slotted liner as per attached liner procedure. 13. Hole will be left with Kill weight brine. POOH. It is planned to complete this well with Rig 27E. A separate Completion program will be issued. POST DRILL AND CASE: Nabors Rig 27E will run the completion on this well. DRILLING HAZARDS AND RISKS: See the latest Milne Point L-Pad Data Sheet for offset information on L pad. Specific potential hazards for this well are outlined below. The well will be completed with Rig 27E. 1. Hydrates: No hydrates have been encountered on L Pad. 2. Close Approach: There' are no close approaches. 3. Lost Circulation: Them have not been any significant lost circulation incidents reported on any of the L Pad wells. HOWEVER, STUCK PIPE INCIDENTS OCCURED WHILE Drilling. L-8 stuck pipe at key seat at 1316'. Some losses have also occurred while preparing to run and cement casing. 4. Stuck Pipe Potential: There has been STUCK PIPE incidents on Milne Point 'L' Pad. The L-8 well experienced a stuck pipe incident. Be especially aware of the need to maintain good hole cleaning properties and practices through the upper hole and the heavy clay sections at 3500'-4500' REFER TO THE PAD DATA SHEETS FOR MORE INFORMATION ON THE STUCK PIPE INCIDENT. The frequency of wiper trips should be a minimum of once every 1000' as determined by hole conditions. Viscous sweeps should also be made as determined by hole conditions using Hi/Low sweep combinations. If heavy gravel's are encountered while drilling the surface hole section, operations should be immediately stopped and the mud funnel viscosity is increased to help clean hole. Surface hole has only small gravel. Bit bailing and stickiness has been experienced in the clays. 5. Formation Pressure: The Schrader Bluff zone is anticipated to be normally pressured with a gradient of 0.4476 psi/ft (8.6 ppg EMW) and a pressure of 1930 psi in the middle of the Schrader Bluff at 4316' TVDSS. 6. Directional Drillinq Concerns MP L-45 will be an ultra slim 7-7/8" hole drilled to a depth of 7,450' md. Followed by 4-3/4" horizontal leg to TD. KOP is 400' md and a variable build rate from that point will yield a sail angle of 74.688 o at 3776' md. The maximum inclination of 89.505 deg. is reached at 8078' MD and held to TD. Departure is 6887'. 7. Cement The surface hole will be cemented to surface with Cold Set III Cement, a foamed 10# intermediate slurry followed by Class G. The excess will be run in the Cold Set III. The top of the Class G is planned for 500' above the top of the Schrader Bluff Sands. A back up port collar will be run approximately 200' below the permafrost the exact position determined from the caliper log. This is a full gauge tool and will be placed using the caliper in a slightly over gauge section. This program will be modified once the caliper log results are known. Surface casing cement jobs have generally went well some mud losses occurred on L-241 and L-161 but were healed with 9.1ppg mud with LCM. MP L-45 Well Plan PAGE 6 1 Sept 98 MP L-45 5-1/2 .... SURFACE CASING CEMENT PROGRAM - B.J. Alaska CASING SIZE: 5-1/2 .... CIRC. TEMP 80 deg F at 4695' TVDSS. Spacer 250bbls. Water 8.43 pp~l. STAGE1 LEAD: TYPE Cold Set III PERMAFROST, Foamed (10# Intermediate) WEIGHT: Cold Set III 12.2ppg YIELD: 1.92FT3/Sk. MIX WATER:10.53 GAL/sk. WEIGHT: Foamed 10.0ppg YIELD:2.02' ft3/sx MIX WATER: 6.06 gal/sk APPROX #SACKS: 518 Cold Set III THICKENING TIME: Greater than 6 hrs at 50° F 240 Foamed Greater than 4:30 hrs." ANNULAR VOLUME TOP OF TAIL CEMENT TO Port Collar +/- 2200' MD +50% EXCESS. (Confirm From Caliper) STAGE1 TAIL CEMENT TYPE: PREMIUM 'G' ADDITIVES: APPROX #SACKS: 295 FLUID LOSS: FI-33-.4%, CD-32- .3%, R-1-.1% FP-6L'lghs. WEIGHT: 15.8 ppg YIELD: 1.34 ft3/sx MIX WATER 6.06 gal/sk THICKENING TIME: Greater than 5 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 500 FEET TVD ABOVE SCHRADER BLUFF + NO EXCESS + 80'md 5-1/2 .... ,15.5# capacity for float joints. EST TOC 5000' m (Confirm from Caliper) STAGE2 Contingency: ADDITIVES: WEIGHT: APPROX #SACKS: 518 Cold Set III PERMAFROST (If Single Stage Unsuccessful) Retarder 12.0ppg YI ELD: 1.92 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM STAGE COLLAR AT 2200' MD TO SURFACE+ 50% Excess (Confirmed by Caliper) Note Excess is estimate only caliper will be used for final determination. DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT TOP JOB CEMENT TYPE: Permafrost Cold Set Set III NOTE: ADDITIVES: Retarder TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.2 ppg YIELD: 1.92 ft3/sx MIX WATER: 10.53 gal/sk APPROX NO SACKS: 100 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: MP L-45 Well Plan PAGE 7 1 Sept 98 i J4°ar~aUn : ....... D rillQ ues t' D R IL~L ;I~R~I~I~It Vl C 11'6 .. , .- FOR PE~I~ING ONLY Milne Point Unit Alaska S~te Plane Zone 4.., Milne Point L Pad YPL-45 , . 0- , . b ~ ~:. . : ............................. ~ 000 - ................ ~.. ~~ /~<~ __ ~.17 ~ I " I I J .... I I I I 0 t00 O 20~ 3000 ~ 600e ~000 7000 ~ie: liflcb s t00~ Venial S~tion ~ion ~m~ t85,2o3' (T~e ......... FOP, PEI~V~ITI'ING ONLY I DriHQuest' Milne Point Unit Alaska State Plane Zone 4 Milne Point L Pad MPL-45 Emstlngs .1~oo -gpo 5 1/2' Casing 7450.00 MO A~.17 ~D 31~" ~e I 0 0 -900 .goo 80O -1 BOO -2700 -2700 ~-$600 - -5400 - ~6300 -- -' 1800 ~00 0 90° -3600 'd ~SLS$gS-L06[ 'ON.'~' -. FOR PERAAI~NG ONLY Sperry-Sun Drilling Services Proposal Report for MPU45 IlifP2 o o MiMe point Unit Measured Depth Incl. Azim. 0.o0 0,000 0.000 I00.00 0.000 200,00 .0,000 300,00 0.000 0.050 400.O0 0.00~ 500,00 1'000 198500 600.eo 2,000 198.500 700.00 3.000 I98..500. 800,00 4,000 ' 198.500 900.03 5.000 198.aZ) 1000.00 6.4.95 197.318 1100,00 7,9~ 196,577 1200,00 9,491 196.(T~39 '1300,68 10,989 195.696 1367.44 12,000 195.500 1400.00 12.650 195.:309 1500.00 14.647 194.827 1600.00 16.644 194.458 1700.00 18.642 194.166 1767,9520.000 194.~00 1800,00 20.772 193.386 1678,90 22,681 192.047 1900,00 23,194 191.724 2000.00 25.630 190.361 2T00.00 26.076 189.220 2200.00 30.531 188.249 2300.00 32.991 187,410 2400.00 35.457 186,675 2500.00 37.927 186.023 2600.00 40.39~ 185.441 Sub. Sea Depth .49.40 50.60 150.60 260,60 350,60 ~o.59 550.56 ~0~. 75028 849.97 949.46 't048,68 li~?,49 1245,90 1311,99 1343.80 1440.97 153726 1696.67 1726,71 1800.00 1819.44 1910.4,9 1999.70 2086.90 2171.92 2254.59 2334.78 2412,30 Vedical Depth (fi) 0.00 100.00 2oo.oo 300.00 400.00 499,99 599.96 699.86 799,66 899.37 996.86 1098.06 1196.89 1295.30 1361.39 1393,20 1490,37 1586.66 1681.95 1746.07 1776.11 1849.40 1868.84 1959.89 2049.10 2136.30 2221;32 2303.99 2384,18 24.61.70 FOI~ PE~ITriNG ONLY Local Caordlnates Northlngs Eastings (~t) 0.OQN 0.~Q N aeON O.~N O. eo N 8.83,8 3.91 8 7.4~8 13,24 $ 20.~ S ~0.2t S 42.27 S 56.86 S 7396 S 86.90 S 93.69 S 116,39 S 142.48S 171.55S 193.65 S 2O450 S 232.,~ S 241.04. S 28!.60 S 326.11 S 374.49 S 426.63 S 482,4&S 541.82S 604',66 S 0.00 E O.00E O,O0 E 0.00 E 0,00 E 0.28W 1.11W 2.49W 4.43W 6.92W 9.98 W 13.65 W 17.92 W 22,78 W 26,~W 2824 W 34.,36W 4.1,18 W 48.66W 54.13 W 56.77 W 63.19 W 64,88 W 72.78 W 80.44 W 87.85W 95.01 W 101,89W 108,49W i 14.,79 W Global Coordinates Dogleg Vertical Northlngs Eastlngs Rate Section (it) (fi) (°lloofl) (fl) 6031741.50 N 644760,28 E 6031741.50 N 544760.28 E 6031741.50 N 544760.28 E 6031741.50 N ,544760,28 E 0031741,50 N 544760.28 E 6031740.67 N 544760.01 E 6031738.18 N 544759.19 E 6031734.04 N 544757,83 E 6031728,24 N' 544755.93 E 6031720,78 N 544753,49 E 6031711,23 N 544750,46 E 60316,99.15 N 544746.88 E 6031684.53 N 644742.70 E 6031667.41 N 544737.95 E 6031654.44 N 544734.41 E 6031647.73 N 544732.61 E 6031624.91 N 544726,62 E 6031598,77 N 544719.96 E 6031569.36 N 544712.65 E 603154.7.53 N 544707.31 E 6031536.66 N 544704,74 E 6031508.13 N 544698,49 E 6~1500,07 N 544696,85 E 6031459.47 N 54468920 E 6031414.91 N 544681.81 E 6031368A9 N 544674.68 E 6031314.31 N 544667.84 E 6031258,45 N 54466129 E 6031199.03 N 544655.06 E 6031136.16 N 544649.14 E 0.00 0.000 0.00 0.000 O.QO 0.000 0.00 0.000 0,00 1.ooo 0.85 1.000 3.40 1.000 7.64 1.000 13.56 1.000 2i.22 1.500 30.99 1:~00 43.34 1.500 68.25 1.500 7522 1.54i0 88.94 2,qXX) 9528 2.000 119.02 2.000 145.63 2.000 175.55 2.000 197.76 2'500 208.81 2.500 237,76 2.500 245.93 2.500 267,04 2.5O0 332,06 2.500 380,91 2.500 433,49 2.500 489.70 2.509 549.43 2.500 612,57 Comment BASE PERMAFROsT . Alaska State Plane Zone 4 MiMe Point L Pad Con~nue~,. 14 August, 1998. I3:51 . I- OrillOue;t Sperry-Sun Drilling Services Pr°Posal Report for MPL.45 WP2 Milne Point Unit, FOR PEI~ITrING ONLY Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogie9 Vertical Depth IncL Azfm. Depth Depth Northings Eastings Northirtgs Eastlngs Rate Section Comment (ft) (fi) 2700.00 42.875 184.914 2487.04 2536,44 670.82S 120,78 W 6031069.96 N 544643.55 E 2.500 679.01 2785.78 45.000 184.500 2548.81 2598,2i 730.14 S 12566 W 603101~].62 FI 544639,02 E 2.500 738.53 2800.00 45,426 184,41t2 2858.82 26(]8,22 74020 S 126,45 W 6031000.,55 N 544638,29 E 3000 748.62 2900.00 48.425 .[84,360 2627.11 2676.51 813.02 S 1'32.07 W 6030927,70 fi 544633.10 E 3.000 821,65 3000.00 51.424 184250 2691.48 2740,88 889.32S 137.82W 6030851.371~ 544627.82 E 3.000 896.15 3100,00 . 54.423 184.148 2751.76 2801.16 ' 968,87 S . 143-66 W 6030771,78 N 544622.46 E 3,000 977.91 3200.00 57,422 184.054 2807.79 2857.19 1051,48S 149.58W 6(]30689.14 N 544617,04 E 3.000 1060.71 3300.00 60,421 183.966 2859.40 2908.80 '[136.91 S 155,57 W 60~060~.68 N 544611,56 E 3-000 1146.33 3400.00. 63.420 183.8~3 2906.47 295~87 122492 S' 161.60 W 6030515,63 N 544606.06 E 3-000 '1234.53 3500-00 66.419 i8&.804 2948,85 2998.25 1315,28 $ I67.67 W ' 603042524 N 544600.53 E 3-000 1325.06 3600.00 69,418 183.729 2986.44 3035.84 1407,73 S 173.76 W 6030332.75 N 544595.00 E 3.000 1417,69 3700.00' 72.417 183.656 3019.13 3068,53 15~J~S 179.84W 60S0238.41 N 544589.49 E 3.{XIO 1512,15 . 3775,70 74.688 llt3.603 3040.56 3089,96 1574.49 S 184.44 W 6~016,5.93 Iq 544586,33 E 3.0~0 1584.72 38(]0.ffl 74.688 183,6(t3 3046.98 3096,~ 1597.87 S · 185.91 W 6030142.54 lq 544583.99 E 0.0~0 1608.15 3900.00 74.688' 183,603 3073,38 3122,78 1694.13 S 191.97 W 603004624 FI 544578.5! E 0.000 1704,56 40DO.O0 74.686 183,6~ 3099,79 3149,19 1790.39:S 198.03 W 8029949.95 N 544573.03 E 0.0~0 1800.97 4100.00 74.688 183.603 312620 3175.60 1886.65 S 204.09 W 6029853.65 N 544567,55 E 0.000 1897.39 4200.00 74.688 183.603 3152.61 3202.01. 1982.,91 S 210,16 W 6029757,36 N 544562.07 E 0.000 1993,80 4300.03 74.688 183,603 3179.02 3228.42 2079.17 S 216.22 W 60,?.9661.(~6 N 544556.59 E 0.000 209021 4400.00 74,688 183.603 3205.42 3254.82 2175.43 S 222.28 W 6029564.77 N 544551.11 E 0,000 2186.62 4500.00 74.688 183603 3231.83 3281.23 2271.69 S 228.34 W 602.9468,48 N 544545,62 E 0-000 2283.04 4600.00 74.688 183.603 3258,24 3307.64 2367,95 S 234.40 W 602,9372.18 N 544540.14 E 0.000 2379.45 4667.26 74.688 183,603 3276.00 3325.40 2432.69 S 238,48 W 6(Y29307.41 N 544,536.46 E 0.000 2444.30 UGNU 4700.00 74,688 I83.603 3284.65 3334,05 246421 S 24-0,46W 6029275.89 N 544,534,66 E 0.000 2475.86 4800.00 7¢.6~8 183.603 3311.(]5 3360.45 2560.47 S 246.52 W 60'29179,59 N ~44529,18 E 0.000 2572.27 4900.00 74.688 183-r~3 3337,46 3386.86 2656.73 S 252.58 W 6029063.30 N 544523.70 E 0.000 2668.69 5000-00 74.668 183.603 3363.87 341327 2752.99 S 25~.65 W 8026987,00 N 544518.22 E O.O00 2765,10 5100.03 74,688 183.603 3390,28 3439.68 284925 S 264.7'[ W 6028890.71 N ,544512.74 E O.O00 2861.51 5200.00 74.688 183.603 34.i6.68 3466.08 2945.51 S 270.77 W 6028794.42 N 544507.25 E 0.000 2957.92 5300.00 74.688 183.603 3443.09 3492,49 3041.77 S 276.83 W 6028698.12 N 544501.77 E 0.0O0 3054.;34 Alaska State Plane Zone 4 Milne Point L Pad FOR PEP~II?ING ONW Con,hued.., August, 1998,13:$t .2- Dflll~Juest Sperry-Sun Drilling Services Proposal Report for BPL-45 WP2 Milne Point Unit 'Measured Sub-Sea Vertical 'Depth Incl. Azln~ Depth (~) (n) '5400.00 74,668 183.603 3469.5{3 35t 8,,,ilo 5500.00 74,668 '[83.603 3495.91 3545,31 5600.00 74,688 183.603 3522.31 3,57131 5632.89 74`668 183.603 3531.00 3580.40 ,57G0.00 74.688 183.603 3548.72 3598.12 5800.00 7¢.668 183.603 3575.13 3624.53 5900,00 74.688. 183,603 3601.54 3650.94 6~00.00 74.668 183.603 3627.94 3677,34 6100,00 74.688 183.603 3654.35 370a.75 6200.00 74..68~ 183.603 3680.76 3730.16 6300,00 74.688 183.603 3707.17 3756~ 6~0.00 74.688 183.603 3733.68 3762.98 6600.00 74.688 183.603 37'59.98 380~38 6600.00 74,688 183.603 3786~89 3835.79 6700.00 74,688 183.603 3612.80 3862.20 6800.00 74.688 183.603 3839.21 3888.6t 683825 74,688 163.603 3849.31 3898.71 8900.00 73.837 185.312 3866.06 3915.46 8924.69 73.5~0 186.000 3873.00 3922.40 6930.83 73,287 186.030 3874.75 3924.15 70(30,00 73.287 186,030 3894.65 3~44.05 7100.00 73.287 185.030 3923.40 3972.80 ' 7188.47 73.287 186.030 3948.85 3996.25 7200.00 73.691 166.030 3952.12. 4001.52 7300,00 77,191 186,030 3977,26 4026.66 7400.00 80.691 188.030 3996.44 4045.84' 7450.00 82.441 186.030 4003.77 4053.17 7500.(30 84`19! 186,030 4009,59 4058,99 7600,00 87,691 . 186.030 4016.67 4066.07 7608.84. 88.0(]0 186.030 4817.00 4066.40 Local Coordinates Northlngs EaaUngs (lq 3138.03 S 3234.29 S 3330.54 S 3362.21 S 3426.80 S 3523.06 S 3619.32 S 3715.58 $ 3811,8¢ S 3908.10 $ 4004,36 S 4100.62 S 4196.88 S 4293,14. S 4389.4O S 4485,66 S 4522.48 S 4581.73 S 4605,3'1 4611,16 4677.04 4772.29 4856.56 4867,55 4963.78 5061,37 5110.55 5159.94 5259.12 5267.90 282.89W 288.95 W 295,01 W 297,01 W 301.07 W 307,14 W 313.20W 319,26 W 325,32 W 331.38 W 337.44 W 343,50 W 349.56 W 355,63W 361,68 W 367.75 W 370,07 W 374.68 W 377.02 W 377.64 W 384.60 W 394.66 W 403.56 W 404.72 W 414.89 W 425.19 W 430,39 W 435.61 W · 448.08 W 447.01 W FOR PERMi~ING ONLY Global Coordinates Dogie9 Vertical Northin§s Easlings Rate Section in) irt) (*/loon) 6028601,83 N 544496.29 E 0,000 6028505.53 N 544490.81 E 0,000 602840924 fl 544485.33 E 0,000 6028377,57 N 544483.53 E 0,000 6028312.84 N 544479.85 E 0,0~ 6028216.65 N ~74`37 E 0,000 6028f20.36 N 544468.88 E 0300 6028024,06 N 544463.40 E 0,000 6027927,77 Iq 544457.92 E 0,0~ 6027831.47 N 544452.44 E 0,004) 6027735.18 N 544446.96 E 0,0~0 6027638,88 N 544441.48 E 0,0~) 60Z75~.Z.59 N 544435.99 E 0,000 6027446,30 N 544430.51 E 6027350.00 N 544425.03 E 0,000 6027253,71 N 544419.55 E 6027216.87 N 544417.45 E 6027157.60 N 544413A9 E 6027134.00 N 544411.00 E 3,~0 6027128.15 N 544410.42 E 3,5~0 6027062.23 N 544403,86 E 0.(]00 6026966.92 N 544394.37 E 0.O00 6026882,60 N 544385.97 E O.000 602.687~.6! N 544384.88 E 3,5~ 6026775.31 N 544375.29 E 3.5~0 60266-r/.66 PI 54436537 E 3.500 60'26628.45 N 544360.67 E 3.500 6026579.03 N 544355.75 E 3.500 6026479.79 N 544.~5.88 E 3.500 6026471,0~ N 544345.00 E 3,500 Alaska, State Plane Zone 4 Uilne Point L Pad comment 315025 3247.16 3343,57 3375,29 TOP M SANO 3~9.99 3536.4o 3632.81 3729 23 3825.64 3922.05 4o~8.4~ J~O~ I~,RM~TTZNO ONLY 4114.88 4211.29 4307.70 4404J1 ~00.53 4537.41 4596.83 4620.53' .TOP SCHRADER BLUFF Targd: TITOP NA, Geological , 4626.41. 4692.65 4873.14 4884.19 5079.07 5128.52 5 1/2' Csslng 5178.f8 5277.9O 5286.73 TOPOA RESEVOIR Tar[~et: 'r2'TOP OA, Geological 14 AU§oe~, 19~8.13:5I -3- c:) Sperry-Sun Drilling Services PrOPosal Report for A/IPL.45 WP2 Mline Point Unit Measured Depth Incl. Azim. Sub-Sea Depth (It) Vertical Depth (fl) FOR PERMITTING ONLY Local Coordinates " Global Coordinates NorthTngs Eastrngs Northings Eastings ¢) (~) Ch) Dogleg VertiCal Rate Section (~oo~) (n) Comment Alaska State,Plane' ZOne 4 Miine Point L Pad 7647.25 89,30O 7700.00 89.300 7800.00 89,300 7900,00 89,300 8000,00 89.300 8100,00 8200.00 ~0o,00 8400.00 8S00.00 8600.00 8700,00 8800,00 8900,00 9000,00 9100,00 9200.~0 9209,81 89.300 88.300 89,800 89,300 89.300 89.300 69.800 89.800 89.300 89.300 8.9.3O0 · 89.3O0 89.300 186.373 I86.373 186.373 186,,373 186.373 186.373 186,373 i86,373 186,373 186.373 186,373 186,373 186.373 186.373 ' 186.373 186.373 186.373 166.373 4017.90 4067.30 4018.55 4067.95 4019.77 4069.17 4020.9~) 4070.39 402222 4071.62 4023,44 4072,84 4024.66 4074,06 4025.88 4075,28 4027.10 4076.50 4028.33 4077.73 4029.55 4078.95 4030.77 4080,17 4031.99 4081.39 4033.21 4082.61 4034.44 4O83.84 44335.66. 4085,06 4036.88 4086,28 '. 4037.00 4086.40 5306,08 S 5358,50 S 5457.87 S 5567.25 S 5656.62 S 5755.99 S 5855,37 S 5954.74 S 6054.12 $ 6153A95 6252.87 S 6352,24 'S 6451,62 S 6550,99 S 6650,37 S 6749.74 S 6849.11 'S 6858.86 S 451.16'W 6026432,80 N 544341.08 E ' 457.01 W , 6026380.35 N 544,335.54 E 468.11 W 6026280.91 N 544325,04 E 479.21 W 6025181.47 N 544314,54 E 490.3~ W 6026082.03 N 54,,4304.04 E 501A1 W 6025982.59 N 544293.54. E 512,51 W 6025883.15 N 544283.04 E 523,61 W 6025783.71 N 544272,54 E 5:)4.71 W 6025684,27 N 544262.04 E 54&81 W 6025584.83 N 544251,54 E 556,91 W 6025485,39 N 544241.04 E 568,0t W 6025385.95 Iq 544230,53 E 579.1 ! W 6025286.51 N 544220.03 E 590.21 W 6025187,07 N 544209,53 E 601,31 W 6025087.63 N 544199,03 E 612,41 W 6024988,19 N 544188.53 E 623.51 W 6024,888,75 N 544178.(~3 E 624.60 W 6024879.00 N 544177.00 E All data is in feet unless otherwise stated; Directions and coordinates are relative to True North. Vertical depths are relative toWelL Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100rt. Vedical Section is from Well and calculated along an Azimuth of 185.203° (True). 8.500 0,000 0,{300 0.000 0.000 0.000 0.000 ' 0.000 0.000 0.000 0,0% 0.0O0 0.0O0 0.030 O.OOO O.04X) O,OOO 0.000 5,325.13 5377.86 5477.83 5577.80 5677.78 57T/,75 5877,72 5977.69 6077.66 6177.63 6277.61 637'7.58 6887,24 FOR PEI~MI~iNG ONLY 31/2' Line[ BASE O Target.: T3 TD. Geo[ogicsl Based upon Minimum Curvature type calculations, at a Measured Depth of 9209.81ft., The Bottom Hole Displacement is 6887.24ft., in the D[rection of 185.203" (True). ~ 14 August, 1998 · 13:51 - 4. DrlgOuest Shared Services Drilling Contact: R. George Scott I Well Name: IMP L-45 IType of Well (producer or injector): Weft Plan Summary JSchrader Bluff Horizontal Producer 564-5862 Surface Location: 3,552' FSL, 5,118' FEL, S8 T13N R10E UM Target Location: 3564' FSL, 303' FEL, S18 T13N R10E UM Bottom Hole Location: 1975' FSL 487' FEL, S18 T13N R10E UM I AFE Number: 133143 Estimated Start Date: I 1 Sept. 98 ! I Rig: I Nabors 27E Operating days to complete: IuD: 19210' I ITvD: 14°86' I I 14.0 I KBE: 157 ft I Well Design: Schrader Bluff Producer Formation Markers: Formation Tops MD TVDSS KOP 400 351' Base of Permafrost 1879 1800' Top of Ugnu 4667' 3276' Top M Sand 5633' 3531' Top NA 6925' 3873' Top of the N-A (EMW 8.6 ppg) 5-1/2" Casing Shoe 7450' 4004' (Picked by Geologist) Top "OA" 7609' 4017' Geo-steering will be required to keep in "OA" Base "OA" 9210 4037' TD 9210' 4037' TD Casing/Tub ing Program: Hole ~ize ' Csg~ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 16" 13-3/8" 68# L-80 BTC-MOD 120' 31'/31' 151'/151' 7-7/8 .... 5-1/2"** 15.5# J-55 BTC-MOD 7420' 30'/30' 7450'/4053' 4-3/4" 3-1/2" 9.3# J-55 8-RD. SCC 1760' 7350'/4043' 9210'/4086' Internal yield pressure of the 5-1/2" 15.5# casing is 4,810 psi. With a full column of gas (0.10 psi/E) to the reservoir at _+4027' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.6 ppg EMW), is 1397 psi, well below the internal yield pressure rating of the 5-1/2" casing (4810psi). ** ** Note: The top joint in the 5-1/2" surface casing consists of a X-over from 7" to the 5-1/2" 15.5# J-55 BTC-MOD Casing. The 3-1/2" 9.3# liner has an ID of 2.992", OD of 4.180", Drift-2.867", collapse- 7400psi, Internal Yield-6980psi, Yield-109.37M lbs. The 5-1/2" 15.5#/ft. BTC MOD Casing has an I.D of 4.95", Drift-4.825", Coupling OD-6.05" Collapse-4,040psi, Internal Yield-4,810, Yield-248M. MP L-45 Well Plan PAGE 3 1 Sept 98 Logging Program: Open Hole Logs: Surface: FINAL: Cased Hole Logs: MWD directional only from surface to +2500' MD. 4-Arm Caliper Log From 7450'MD to 151' M.D. (Base of 13-3/8" Conductor.* MWD directional and LWD (GR/Resistivity/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr. MWD Directional and LWD GR/RES. 7450'MD-9210'MD. (-l-D) None Mud loggers are NOT required for this well. *A conditioning trip may be made if required to assure running of the caliper. Mud Program: Special design considerations An inhibitive polymer mud is planned from surface to 7450'MD. Solids control is critical to the success of the system. A drill in Mud with calcium carbonate to limit fluid invasion from 7450'-9,210'MD Surface Mud Properties: I Density Marsh Yield LSRV 10 min pH Fluid (PPG) Viscosity Point gel Loss 8.6 150 40 50,000 8.5 NC 9.2 to 9.0 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel ~ Loss 9.0 50 30 14 16 8.5 <6 to to to to 9.5 60 35 9.0 LSVR- 40,000+, Fann-600/50-55, 300/40-45, 200/33-37, 6/18-20, 3/14-17 The surface casing will be drilled out to +/- 20' of new hole then the mud changed out to drill in mud for horizontal section. Well Control' Well control equipment consists of: Rig (Nabors 27E) ,13-5/8" 5000 psi W.P.Annular and 3000 psi Diverter with 10" Diverter Line. This Rig is equipped with 5000 psi W.P. variable pipe rams, blind/shear rams, and annular preventer used for drilling the horizontal section and for the completion, capable of handling maximum potential surface pressures. Note it is planned to test the BOPE to 3500psi with a cup tester, and the 5-1/2" casing to 3500psi as the anticipated maximum BHP is 1930 psi. Directional' J KOP: J400' MD IMaximum Hole Angle: Close Approach Well: 89.505° @ 8078'md None Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A or Drill Site #4 facility. Fluids Handling: All drilling and completion fluids will be hauled to Drill Site #4 or CC-2A for injection. Annular Injection: Not planned. MP L-45 Well Plan PAGE 4 1 Sept 98 MP L-45 Proposed Summary of Operations 1. Drill and Set 13-3/8" Conductor. Weld landing ring assembly on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 27E rig. . NU and function test 13-3/8 .... diverter. Spud Mud Will Have been Built as per Mud Program. 4" D.P. 2-7~8" work string and 2-7/8" drill pipe will have been stood back prior to spud. . Drill a 7-7/8" surface hole as per directional plan. Run Directional MWD from surface to +/- 3000+'MD. 6. POOH. MU a PDC bit on a motor, with Directional MWD and LWD GR/RES/ROP. , Drill 7-7/8" hole to 7450' as per directional plan. Stand back drill string and run 4-Armed Caliper from the 7450' M.D. to the bottom of the 13-3/8" conductor. . Run and Cement 5-1/2", 15.5#, J-55, Buttress-Modified casing using the 3 plug system method. Refer to attached Detailed Cement Program and Back-up Port Collar Operating Procedure. . Following the cementing of the well and the landing of the 7"x5-1/2" landing joint, rig down cementers. N/D diverter, MU casing head to Landing Joint (9500 fi-lbs torque.) Install BOPE with 2-3/8" rams. Test BOPE and Casing individually to 3500 psi, 74% of burst of 5-1/2# J-55 Casing. 10. PU 4-3/4" directional BHA and drill out cement collar and shoe and 20' of new hole. A 4-3/4" S81PX steel bodied 3 blade PDC bit is recommended to drill out and to TD. Circ. & Cond. Mud, no LOT will be required. Pump a 20 bbl. High visc. pill (70 Y.P.) sweep ahead of drill in fluid. (See Mud Program). 11. Short trip as required before POOH for 3-1/2" liner. Circ and condition wellbore POOH for 3-1/2" liner. NOTES: Hold a "pre-reservoir" meeting as per page 20 of Drlg. Policy Manual. Record on Morning Report. Monitor torque and do not exceed 80% of DP torque. Pump Iow/Hi visc. sweeps every 500' of new hole. Maintain adequate flow rates to clean hole. 12. Run 3-1/2" pre-slotted liner as per attached liner procedure. 13. Hole will be left with Kill weight brine. POOH. It is planned to complete this well with Rig 27E. A separate Completion program will be issued. POST DRILL AND CASE: Nabors Rig 27E will run the completion on this well. DRILLING HAZARDS AND RISKS: See the latest Milne Point L-Pad Data Sheet for offset information on L pad. Specific potential hazards for this well are outlined below. The well will be completed with Rig 27E. 1. Hydrates: No hydrates have been encountered on L Pad. 2. Close Approach: There are no close approaches. 3. Lost Circulation: There have not been any significant lost circulation incidents reported on any of the L Pad wells. HOWEVER, STUCK PIPE INCIDENTS OCCURED WHILE Drilling. L-8 stuck pipe at key seat at 1316'. Some losses have also occurred while preparing to run and cement casing. 4. Stuck Pipe Potential: There has been STUCK PIPE incidents on Milne Point 'L' Pad. The L-8 well experienced a stuck pipe incident. Be especially aware of the need to maintain good hole cleaning properties and practices through the upper hole and the heavy clay sections at 3500'-4500' REFER TO THE PAD DATA SHEETS FOR MORE INFORMATION ON THE STUCK PIPE INCIDENT. The frequency of wiper trips should be a minimum of once every 1000' as determined by hole conditions. Viscous sweeps should also be made as determined by hole conditions using Hi/Low sweep combinations. If heavy gravel's are encountered while drilling the surface hole section, operations should be immediately stopped and the mud funnel viscosity is increased to help clean hole. Surface hole has only small gravel. Bit bailing and stickiness has been experienced in the clays. 5. Formation Pressure: The Schrader Bluff zone is anticipated to be normally pressured with a gradient of 0.4476 psi/ft (8.6 ppg EMW) and a pressure of 1930 psi in the middle of the Schrader Bluff at 4316' TVDSS. 6. Directional Drillinq Concerns MP L-45 will be an ultra slim 7-7/8" hole drilled to a depth of 7,450' md. Followed by 4-3/4" horizontal leg to TD. KOP is 400' md and a variable build rate from that point will yield a sail angle of 74.688 o at 3776' md. The maximum inclination of 89.505 deg. is reached at 8078' MD and held to TD. Departure is 6887'. 7. Cement The surface hole will be cemented to surface with Cold Set III Cement, a foamed 10# intermediate slurry followed by Class G. The excess will be run in the Cold Set III. The top of the Class G is planned for 500' above the top of the Schrader Bluff Sands. A back up port collar will be run approximately 200' below the permafrost the exact position determined from the caliper log. This is a full gauge tool and will be placed using the caliper in a slightly over gauge section. This program will be modified once the caliper log results are known. Surface casing cement jobs have generally went well some mud losses occurred on L-241 and L-161 but were healed with 9.1ppg mud with LCM. MP L-45 Well Plan PAGE 6 1 Sept 98 MP L-45 5-1/2 ....SURFACE CASING CEMENT PROGRAM - B.J. Alaska CASING SIZE: 5-1/2 .... CIRC. TEMP 80 deg F at 4695' TVDSS. Spacer 250bbls. Water 8.43 pp~. STAGE1 LEAD: TYPE Cold Set III PERMAFROST, Foamed (10# Intermediate) WEIGHT: Cold Set III 12.2ppg YIELD: 1.92FT3/Sk. MIX WATER:10.53 GAL/sk. WEIGHT: Foamed 10.0ppg YIELD:2.02' ft3/sx MIX WATER: 6.06 gal/sk APPROX #SACKS: 518 Cold Set III THICKENING TIME: Greater than 6 hrs at 50° F 240 Foamed Greater than 4:30 hrs." ANNULAR VOLUME TOP OF TAIL CEMENT TO Port Collar +/- 2200' MD +50% EXCESS. (Confirm From Caliper) STAGE1 TAIL CEMENT TYPE: PREMIUM 'G' ADDITIVES: APPROX #SACKS: 295 FLUID LOSS: FI-33-.4%, CD-32- .3%, R-1-.1% FP-6L lghs. WEIGHT: 15.8 ppg YIELD: 1.34 ft3/sx MIX WATER 6.06 gal/sk THICKENING TIME: Greater than 5 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 500 FEET TVD ABOVE SCHRADER BLUFF + NO EXCESS + 80'md 5-1/2 .... ,15.5# capacity for float joints. EST TOC 5000' m (Confirm from Caliper) STAG E2 Contingency: ADDITIVES: WEIGHT: APPROX #SACKS: 518 Cold Set III PERMAFROST (If Single Stage Unsuccessful) Retarder 12.0ppg YIELD:1.92 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM STAGE COLLAR AT 2200' MD TO SURFACE+ 50% Excess (Confirmed by Caliper) Note Excess is estimate only caliper will be used for final determination. DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT TOP JOB CEMENT TYPE: Permafrost Cold Set Set III NOTE: ADDITIVES: Retarder TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.2 ppg YIELD:1.92 ft3/sx MIX WATER: 10.53 gal/sk APPROX NO SACKS: 100 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: MP L-45 Well Plan PAGE 7 1 Sept 98 ~,~un ' -' DrillQuest' °"'L'h'"°-~"--.----~2=" FOil PE~IITING ONLY Milne Point Unlt Alaska State Plane Zone 4 ,. Milne Point L Pad MPL-45 o'5 I ~,oo- I~o FOR PEPSI'lNG ONI~¥ ~ ..................... 300 ~ - ..~-. ~~ ..... ~~ .............. ........ 0 t00 O 20~ 3000 ~ 500Q 6000 7000 ~le: 1inch ~ t00~ Venial ~tio~ S~ion ~m~ t85.203' (Tree Nodh) .................. /::OR PERMITTING ONL'Y I DrillQuest' Mllne Point Unit Alaska State Plane Zone 4TM ~Jr,¢h- 9oo~ Milne Point L Pad MPL-45 -O00 -2700 0-3600 -4500 -~400 u 1450,00 MD. 4086.40 0 .SaO0 -1800 -2700 -~600 0 *~tO0 7200 ~ -1800 ~00 0 900 .~.~alg*i 'Jlnc~h m 900'ft Eastings RErFOFonoe i,., Trade North FOR PERMITTING ONLY' 'ON X¥_4 ~]~S¥7~ NRS-. _::ids I70 Sperry-Sun Drilling Services Proposal Report for MPL-45 WP2 Milne Point Unit Measured Sub-Sea Vertical Depth incl. Azim, Depth Depth (it) (ti) (tt) 0.00 0.000 0.000 -49.~ 0.00 103.00 0.000 0,030 50.60 100.00 200.00 0.000 0,~;X~ 150,60 200.00 300,00 13.000 o.(x~o 250,60 300.00 400.60 o.ooo oJx)O 350,60 400.00 5~0.00 1,000 198.500 450.59 499.99 600.00 2,000 198.,,500 550,56 599.9'6 700.00 3,000 1985~ 650,48 699.86 800,00 4,000 198.500 750.28 799,68 900.00 5.000 198.500 849.97 899,37 1030.00 6.495 197.318 94.9.46 998.86 1100,00 7,993 196,577 1,04.8.66 1098.06 1200,00 9,491 196.069 114.7,49 1196.89 1300,00 10,989 195.696 1245,90 1295.30 1367.44 12,000 195.500 1311,99 1361.39 1400.00 12,650 1913~ 1343.80 1393,20 ~500.00 14.647 194.827 1440.97 1490,37 $600.00 16.644 194..45~ 1537.26 1586,66 1700,00 18.642 194.166 1632.55 1681,95 1767.95 20.000 1~4,~)00 1696.67 1746.07 1800,00 20,772 193,386 1728,71 1776,'[1 1878,90 22.6~1 192.047 1800,00 1849.40 1900,00 23,194 191.724 1819.44 18~.84 2000,00 25.630 190.361 1910.4~ 1959.89 2'[00.00 28.076 189.220 1999.70 2049,10 2200.00 30.531 188.249 208~.90 2136.:30 2300.00 32.991 187.410 2171.92 2221.32 2400.00 35.457 186,675 2254.59 2303,99 2500.00 37.927 185,~23 2334.78 2384,18 2600,00 40.3.99 185.441 2412,30 2461.70 FOR PERMITTING ONLY Local Caordinates NorthTru:js Eastings (ft) 0.0(I ti 0,00 E 0,.0O N O.00 E 0.00 N 0,00 E O,00 Fi 0.00 E 0,00 N 0.00 E 0.83S 026W 3.31S 1,11 W 7.45S 2.49W 13.24 $ 4.43 W 20.68 $ 6.92 W 30.21 S 9.98 W 42.27 S 13.65 W 56.86 $ 17.92 W 73.96 S 22,78 W 86.90 S 26.30 W 93.60 S 28,24 W 116.39 S 34-,36 W 142,46S 4-1,18W 171.85 S 48.68 W 193,65 S 54.13 W 20450 S 56.77 W 232.~ S 63.19 W 241.04, S 64,88 W 281.60 S 72.78 W 326.11 S 8O.4.4 W 37~49 S 87.85 W 426.63 S 95.01 W 482,44,8 101.89W 541.82 S 108.49 W 604,65 S i 1,t,79 W Global Coordinates Dogleg Vertical Northings Fastings Rate SectTon (It) (It) (oll0Oft) (fl) 6031741.50 N 544760,28 E 0.00 603174'I,50 N 544760.28 E 0,000 0.00 6031741.50 N 544760.28 E 0.000 0.00 6031741.50 N 544760.28 E 0.000 0.00 6031741.50 N 544760.28 E 0.000 0.~]0 6031740.67 N 544760.01 E 1,000 0.85 6031738.18 N 544759.19 E 1,000 3,40 6031734,04, N 544757.83 E 1.000 7.64 6031728,24 N' 544755.93 E 1.000 13,5~ 603 1720,78 N 544753,49 E 1.000 2i,22 6031711.23 N 544750,46 E 1.500 30.99 6031600.15 N 544746.88 E 1.500 43.34 6031684.53 N 544742.70 E 1,500 5825 6031667,41 N 544737.95 E 1.500 75.72 6031654.44 N 544734.4! E 1.5~ 88.94, 6031647.73 N 544732.61 E 2.000 95.78 6031624.91 N 544726.62 E Z000 119.02 6031598,77 N 544719.96 E 2.000 145.63 6031569,36 N 544712.65 E 2.000 175.55 603154-7.53 N 544707.31 E 2.000 197.76 60'31536,66 N 544704,74 E 2.500 208.81 6031608.13 N 544698,49 E 2.500 237,76 6031500,07 N 5446~6,85 E 2.500 245.93 6031459,47 N 54,46~9.20 E 2.500 287,04 6031414.91 N 544681,81 E 2.500 332,06 6031366,49 N 544674.68 E 2.500 380,91 6031314.31 N 54466'7.84 E 2.500 433,49 6031258,45 N 54466129 E 2.500 489.70 6031199.03 N 544 655.06 E 2.500 549.43 6031136.16 N 544649.14 E 2.50,0 612.57 Alaska State Plane Zone 4 Milne Point L Pad Comment BASE PERMAFROST ' Con,hued... <z: 14 AugUst, 1998.13:5I . I- OrUlOuest Sperry-Sun Drilling Services Proposal Report for MPL.45 WP2 Miine Point Unit FOR ~I~AI~[NG ONLY Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg 1/ertlcal Depth IncL Aztm. Depth Depth Northings Eastin§s Northings Eastlngs Rate Section Comment (~) (~) (~) (~) (~) (~) ¢) ('~lOOf~) (~) 2700.00 42875 184.914 2487.04 2536,44 67OJ12 S 120.78 W 6031069.96 N 544643,55 E 2.500 679,01 2785,78 45.0(30 184.500 2548.81 2598,21, 730.14 S 125,66 W 6031010,62 N 544639,02 E 2.500 738.53 28001~0 45.426 184,482 2558.82 2608,22 74020 S 126.45 W 6~1100055 N 544638,29 E 3.000 748.62 2900.00 48,425 '[84,360 2627.1 ] 2676,51 813.02 S 1'32.07 W 6030927,70 N 544633,10 E 3.000 821.65 3~ O0,00 51.424 184250 2691,48 2740.88 889.32 S 137.82 W 6030851,37 N 544627.82 E 3.000 898,15 3100.00 54.,423 184.148 2751.76 2801.16 968,8/S 143.66 W 6~30771,78 N 544622.46 E 3,000 971.91 3200.00 57,422 184,054 2807.79 2857.19 1051,48 S 149,58W 6030689.14 N 544617,04 E 3.000 1060.71 3300.00 60,421 183.966 2859,40 2908.80, '[136.$1 S 155,57 W 6030~03.68 N 544611.56 E 3.000 1146.33 3400.00 63,420 183.8;83 2906.47 2955;87 1224.92 $' 161,60 W 6030515.63 N 544606.06 E 3.00(] ' 1234..53 3500.00 66.416 i83.804 2948.85 29982.5 1315.28 .S 167,67 W 60.30425.24 N 544600.53 E 3.000 1325,06 3600,00 69.418 183.729 2986.44 303,5.84 1407,73S 173.76W '603033275 N 544595.00 E 3.003 1417.69 3700.00 72,417 183.656 . 3019.13 8068,53 15(2,038 179.84W 60,30288.41 N 544589.49E 3.~)03 1512,15 . 3775,70 74.688 183,603 3040.56 8089.96 1574.49 S 184.44 W 6030185.93 N 544585.33 E 3.000 1584.72 3800,00 74.688 183.603 3048.08 8006,38 15,.q7Jt7 8 185.91 W 6030t42.54, N 544583.99 E 0.O00 1608,15 3.~0,00 74.688 183,603 3073,38 3122,78 1694.13 S 191.97 W 6030046.24 N 544578.5! E O.0~ 1704,56 4000.00 74.6~ 18.t,603 3099,79 :3149.19 1790.39 8 198.03 W 0029949,95 N 544573.03 E 0.O00 1800.97 4100.00 74,68~ 183,603 3126,20 3175,60 1886.65 S 204.09 W 6029853.65 N 544567.85 IE O,000 1897.39 4200.00 74.688 183.603 3152,61 3202.01 1982.91 8 210.16 W 6029757.36 N 544562,07 E O.000 1993.80 4300,00 74.688 183.603 3179.02 3:228.42 207&I7 S 216.22 W 602~61.06 N 544556,59 E 0.000 20902.1 4400,00 74,688 183,603 3205.42 3254.82 2175,43 S 222.28 W 6029564.77 N 544551.11 E 0,000 2188.62 4500,03 74,688 183.603 3231.83 ,3281.23 2271,69 S 228,34 W 6029468,48 N 544545.62 E 0.000 2283.04 4600,00 74.688 183,603 3258,24 3307.64, 2367.95 S 234.40 W 6029372.18 N 544540.14 E 0,000 2379.45 466726 74.688 183,603 3276.00 3325.40 2432.69 S 238,48 W 6029307.41 N 544.536.46 E 0.000 2444.30 UGNU 4700,0(] 74,688 183.r~33 3284.65 3334,05 24642.1 S 24.0,46 W 6029275.89 N 544534.66 E 0.000 2475.86 4600,03 74..68& 183.603 3311.05 3360,4,5 2560.47 S 246,52 W 6029179.59 N 544529.18 E 0,000 2572.27 49'00.00 74.688 18:3.603 3337,46 3386.86 2656.73 S 252.58 W 6029.063,30 N 544523,70 E 0.000 2668.69 50C)0.00 74.6~ 183.603 3363.87 341327 2752.99 S 258.65 W 6028987,00 N 544518.22 E 0.000 2765,10 5100.00 74,688 183.603 3390,28 3439.65 284925 S 264,71 W 6028890.7'[ N 544512.74 E O.O00 2861.51 5200.00 74.688 183.603 34.16.68 3466.08 2945.51 8 270.77 W 6028794.42 N 544507.25 E 0.000 2957.92 5300.00 74,688 1B3,603 344~.09 3492,49 3041.7/S 276.83 W 6028698.12 N 544501.77 E O.O00 :3054,34 Alaska State Plane Zone 4 Milne Point L Pad FOR PERMITtiNG ONLY Continued... <3: 14 August, I~98.13:$I .2. Drttti~uest Sperry-Sun Drilling Services Proposal Report for MPL.45 WP2 I~ilne Point Unit Ue~sured Sub-Sea Vertical Depth l~cl. ,~ Depth Deptfl (~t} (~) (~) 5400.00 74.668 181603 3469.5(] 5500.00 74.668 181603 3495.g] 3545.3l ,5600.00 74.668 181603 3522.31 5632.89 74.668 181603 3531.00 358(L40 .5'700.00 74.688 183.603 3548.72 35~ ,,,qO0.O0 74.68~ 183.603 3575.13 3624.53 5~(30,00 74,68~ 183.603 360154 365~4 ~00.03 74.688 183.603 3~7.94 3b'77.34 6100.00 74.688 183.603 3654,35 3703.~ 6200.00 74.688 183.603 3680.76 3730.16 6,300.00 74.668 183.603 3707.17 6400.00 74.6 68 183.603 3733.58 37a2.~ 6500.00 74`688 183.603 3759.98 :38~38 6600.00 74..688 183.603 3786.39 3835.7~ 6700.00 74`68.~ 183.603 3612.80 6800.00 74,668 183.603 3~921 3888.6t 683825 74,688 183.603 3849.3! 38.98.71 6900.~ 73.837 185,312 3866.05 3915.48 6924,69 73,5~0 186.000 3873.00 :3922.40 6930,83 73.287 186.030 3874.75 3924.15 7000.0(] 73.267 186,030 3894.65 3544.05 710~.~ 73.287 186.030 3923.40 3872.80 7188.47 73287 186.030 3948.85 3S9&25 7200.~ 73.691 156.030 3052.12 4001 7300.00 77.191 166.030 3~17.26 7400.00 80.691 188.030 3996.44 4~84 7450.00 82.441 185.030 4003.77 4053.17 7500.00 84.191 185.030 4.009.59 7600.00 87.691 186.030 4016.67 4066.07 76Q8.84. 88.0Q0 186.030 4.(]17.00 4066.4Q Local Coordinates Northings Eaatings (ft) (~) 3138.03 S 282.80 W 3234.29 S 288.95 W 3330.54 S 295.01 W 3362.21 S 297.01 W 3426,8(] S 301.07 W 3523.06 S 307,14 W 3619,32 $ 313.20W 3715,58 S 319,28 W 3811.84. S 325,31! W 3908.10 S 331.38 W 4004,:36 S 337.44 W 4100.62 S 343.50 W 4196.88 S 349.56 W 4293,14. S 355,63 W 4389.40 S 361,69 W 4485.66 S 367.75 W 4522.48 S 370,07 W 4581.73 $ 374.68 W 4605,31 $ 377.02 W 4811,16 S 377.64 W 4577.04 $ 384.60 W 4772.29 S 304.66 W 4856.55 S 403.56 W 4867,55 $ 404.72 W 4963.78 $ 414.89 W 5061,37 S 425.19 W 5110.55 S 430.39 W 5159.94 S 435.61 W 5259.I2 S 448.08 W 5267.90 S 447.01 W FOR PEPJV[iTTING ONLY Global Coordinates Dogleg Vertical Northings Eastings Rate Section Comment (ltl (fi) ('/lOOft) ~oz~.~.s444~.2oE 0,000 31s0,7~ ~02~, ~.,~E 0,0~ ~4~,1~ 602"n~N ~83.53 E 0,0~ ~75,~ TOP M S~O 6027~7.nN ~57.02 E 0,0~ 3fi25.~ ~o27~.~7. ~52.~ o,~ ~.~ ~o~.~s. ~.~ o,~ ~.~ ~0~ PE~I~INO ONLy 60~ N ~5.99 E 0,~ ~11.29 ~o~,~. ~,~.~so.~~oo.~ 6~7134.~ N ~11.00 E 3,~ ~20.~ ~OP SCHRAD~ BLUFF 6~7128.15 N ~10.42 E 3.5~ 4626.41 6~706~ N ~03.86 E ~.~0 46~.65 60269~.92 N ~94.~ E 0.0~ 47~.41 6026~,~ N ~65.57 E 3.500 5079.07 6~662145 N 5~.~ E 3.5~ 5128.52 5 112' Ca~ng 602~9.~ N 5~.75 E 3.5~0 5178.18 6~929 N ~5.8~ E 3.500 6~H71.~ N ~5.~ E 3,5~0 528623 ~OP OA RES~OIR Ta~et: T2'TOP OA, Geologlc~ Alaska State Plane Zone 4 Uilne Point L Pad Continued_ 14 August, 1908.13:51 .3. Sperry-Sun Drilling Services prOPosal Report for MPI..-4$ ItFP2 Mllne Point Unit Measured Sub-Sea Vertical Depth Incl, Azim. Depth Depth Ct) (it) 7647.25 ,~9`300 I86.373 4017.90 4067.30 7700.00 Etg,300 186.373 4018.55 4067.95 7800.00 89,300 186.373 4019.77 4069.17 7900,00 89,300 188.373 4(]20.99 4070.39 8000.00 89,300 166.373 4022,22 4071.62 8100.00 89,300 186,373 4023,44 4072,84 8200.(X) 89.300 186.373 4024,65 4074,06 8300.00 89.300 186,373 4025.88 4075,28 ~00.00 89.300 186,373 4027.10 4076,50 6500.00 89,300 186,373 4028.33 4077.73 8600.00 89.300 186,373 40:)9.55 4078.95 870'0.00 69.800 186,373 4030.77 4080,17 8800.00 89.300 186.373 4031.99 4081.39 8900,00 89,,300 186.373 403321 4082.81 9000.00 69,300 '[86.373 4034.44 4083.84 8100,00 83.300 186.373 4~3.5.65 4085,05 9200.00 83.300 186.373 4036.88 4086,28 9209,81 89.30~ 186,373 4037.00 4086,40 FOR PE~ITTiNG ONLY Local Coordinates Global Coordinates Dogleg Vez'tical North[rigs East[rigs Northings Eastings Rate SeclJo~ Ct) (~t) (n) ¢) (S'lOOft) 5306,08 S 45`[.16 W. 60264.32.80 N 544341,08 E 8.500 5325.13 5358,50 S 457.0! W , 6026388.35 N 5-44335,54 E 0.000 53'n.86 5457.87 S 468.11 w 60262~0.91 N 544325,04 E 0.000 5477.83 5557.25 S 479.21 W 6026181.47 N 544314,54 E 0.0dO 5577.80 5656.62 S 490.31 W 6026082.03 N 544304.04 E 0.000 5677.78 5755.99 S 501,41 W 6025982.59 N 544293.54. E 0.000 5777.75 5855.37 S 512,5] W 6025883.'t5 N 544283.04 E 0.000 5877."/2 5954,74 S 523,61 W 6025783.7l N 544272.54 E 0.000 5977.69 6054.12 S 534.71 W 6025684,27 N 544262.04 E 0.000 6077.66 6153.49 $ 54.5.81 W 6025584.83 N 544251.54 E 0.000 6177.63 6252,87 S 556.91 W 6025485,39 N 544241,04 E 0.000 6277,61 6352,24 S 568.01 W 6025385,95 N 544230,53 E 0,000 6377..58 ro451,6Z S 579.11 W 6025286,51 N 544220.03 E 0.000 64.77.55 6550,99 S 590.21 W 6025187,07 N 544209,53 E 0.00~ 6577.52 6650.37 S 601,31 W 6025087,63 N 544199,03 E 0.00,0 6677.49 6749.74 S 612.41 W 6024,988.19 N 544188.53 E. 0.0(0 6777.46 6B49A! S 623,51 W 602488a.75 N 544178,03 E 0.000 6877.44 6858.86 $ 624,60 W 6024879.00 N 544177.(]0 E 0.000 6887.24 All data is [n feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths Are relative to Well, Northings and Eastings are relative [0 Well. The Dogleg Severity is in Degrees per 10011:, Vertical Section is from Well and calculated along an Azimuth of 185.203" (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9209,81[t., The Bottom Hole Displacement is 6887,24ft., in the Direction of 185.203° (True). Alaska State Plane Zone 4 I?iiine Point L Pad Comment FOR PER/~IT]'iNG ONLY 3 1/'2.' Liner BASEO Ta. rgel.: T3 TD, 14 August, 1998.13:51 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 070998 CKO70998J 100. O0 100. OO HANDLINO INST' s/h kathy campoamo~ x 5122 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~lrBlll~,,1~1 g · WELL PERMIT CHECKLIST COMPANY FIELD & POOL INIT CLASS WELL NAME/'~P f~ /~2 L - ¥~" PROGRAM: exp [] dev J~redrll [] serv [] wellbore seg El ann. disposal para req FI 0..~L..- GEOLAREA ~ c'(c) UNIT# ~ ~1,.~ ON/OFFSHORE ~/~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~~,~"~O psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY R DATE 30. Permit can be issued w/o hydrogen sulfide measures..._.;..~.,,,~ 31. Data presented on potential overpressu~ .... 32. Seismic analysis of shallow_C..sC~,e~- ............ 33. Seabed con~off-shore) ............ 34~rogress reports ....... exploratory oniyj ANNULAR DISPOSAL APPR DATE N N ~ N Y N Y N Y N Y N Y N 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; _. .... _.._. Y N (B) will not contaminate freshwate~r' ~~ril~ng waste., i Y U to surface; (C) will not imp~nical integrity of the well used for disposal; Y N (D) ~mage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLp~Y: ENGINEERING: UlC/Annular COMMISSION: RFC ~ BEW~__.~'~'f('~ WMI~'~ ~lZ./= DWJ .,-I,~- ~ JDH / coRNC £.z~ 8'/~"I Comments/Instructions: M:cheklist rev 05/29/98 dlf:C:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Dec 10 12:51:26 1998 Reel Header Service name ............. LISTPE Date ..................... 98/12/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Tape Header Service name ............. LISTPE Date ..................... 98/12/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Physical EOF Comment Record TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MW-80363 C. ASUCHAK P. LOCKWOOD MPL-45 500292291300 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 10-DEC-98 MWD RUN 3 AK-MW-80363 C. ASUCHA_K P. LOCKWOOD 13N 10E 3552 5118 50.60 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 16.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 5.500 7344.0 7.880 3.500 9365.0 4.750 9365.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA P_AY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 4. MWD RUN 3 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP). THE CHANGE FROM DGR TO NGP PROBES OCCURS AT 7326'MD, 4032'TV-D. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL MESSAGE FROM D. DOUGLAS FOR K. NITZBERG OF BP EXPLOP~ATION (ALASKA), INC. ON 10/29/98. 6. MWD RUNS 1 AND 2 REPRESENT MPL-45 WITH API~: 50-029-22913-00. THIS WELL REACHED A TOTAL DEPTH OF 9365' MD, 4053'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ , File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 4136 0 FET 4143 0 RPD 4143 0 RPM 4143 0 RPS 4143 0 RPX 4143 0 ROP 4179 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 9309.0 7332.5 7332.5 7332.5 7332.5 7332.5 9365.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 4177.0 7367.0 3 7367.0 9365.0 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 GR MWD API 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 4136 9365.5 6750.75 10460 4136 GR 15.1353 154.005 77.907 10322 4136 RPX 0.7597 17.3064 4.14519 6380 4143 Last Reading 9365.5 9309 7332.5 RPS 0.6378 23.5893 4.7343 6380 RPM 0.3478 33.6163 4.76364 6380 RPD 0.4184 2000 5.21237 6380 ROP 6.0724 475.363 166.583 10373 FET 0.0944 13.9759 0.492906 6380 4143 4143 4143 4179.5 4143 7332.5 7332.5 7332.5 9365.5 7332.5 First Reading For Entire File .......... 4136 Last Reading For Entire File ........... 9365.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/10 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 ....... 98/12/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NTO-MBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE ST/LRT DEPTH STOP DEPTH GR 4136 0 7325.5 FET 4143 0 7332.5 RPD 4143 0 7332.5 RPM 4143 0 7332.5 RPS 4143 0 7332.5 RPX 4143 0 7332.5 ROP 4179 5 7367.5 $ LOG HEADER DATA DATE LOGGED: 05-SEP-98 SOFTW/LRE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: DEPII(2.22A), SP4 (5.04) DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTP~ATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MEMORY 7367.0 4177.0 7367.0 72.7 76.5 TOOL NLTMBER P1043GR4 P1043GR4 7.880 7.9 POLYMER 9.40 58.0 9.0 10000 10.5 .480 .333 .380 .530 39.9 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 RPX MWD 2 RPS MWD 2 RPM MWD 2 RPD MWD 2 ROP MWD 2 FET MWD 2 API 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 FT/H 4 1 68 HOUR 4 1 68 4 8 12 16 20 24 28 Name DEPT GR RPX RPS RPM RPD ROP FET Min 4136 15 1353 0 7597 0 6378 0 3478 0 4184 13 2998 0 0944 Max Mean Nsam 7367.5 5751.75 6464 140.4 66.4289 6380 17.3064 4.14519 6380 23.5893 4.7343 6380 33.6163 4.76364 6380 2000 5.21237 6380 475.363 194.889 6377 13.9759 0.492906 6380 First Reading 4136 4136 4143 4143 4143 4143 4179.5 4143 Last Reading 7367.5 7325.5 7332.5 7332.5 7332.5 7332.5 7367.5 7332.5 First Reading For Entire File .......... 4136 Last Reading For Entire File ........... 7367.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R3tW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7326.0 ROP 7368.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9309.0 9365.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATUR3~L GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet ll-SEP-98 ISC 5.07 DEPII(2.22A), SP4 (5.04) MEMORY 9365.0 7367.0 9365.0 82.9 97.7 TOOL NUMBER PCG 42 4.750 4.8 FLOPRO 9.40 46.0 8.5 16000 7.0 .000 .000 .000 .000 32.9 .3 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 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 7326 9365.5 8345.75 4080 7326 GR 46.2351 154.005 96.4839 3942 7326 ROP 6.0724 364.031 121.41 3996 7368 Last Reading 9365.5 9309 9365.5 First Reading For Entire File .......... 7326 Last Reading For Entire File ........... 9365.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/12/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/12/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Ph).-sical EOF Physical EOF End Of LIS File
