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209-159
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q.0 - 1.51 Well History File Identifier Organizing(done) ❑ Two-sided II 1111111111111 ❑ Rescan Needed 111111111 IIIIIII RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: I Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: //7/11.f /s/ wiP Project Proofing 111111111011111 BY: Maria Date: 1/71#.1 /s/ rY1 P Scanning Preparation o2 x 30 = 610 + D. I = TOTAL PAGES 81 (Count does not include cover sheet) • BY: Date: ' j /s/ u Production Scanning 111111111111 11111 Stage 1 Page Count from Scanned File: 0 (Count does include cover sheet) 1 Page Count Matches Number in Scanning Preparation: kYES NO BY: 4112M Date: //7/1 it /s/ 4 I i.� Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1111E1111H I ReScanned 111111111110 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII I I IIII III 12/22/2011 Well History File Cover Paae.doc 0 Ci o f0 m o z 0 • N as U CO °' o c 4 I g ° `m E 'n A E — Z o S a fn I = o a > o o �( Z 0) N ' 0 U p- 4 E _ _ -.d w E 2 2 E �° y O U p O as r r 0 LN c . O N ;a 0. ►.O U w Z Z V CD U y A 0 } } w z y; U) Z L li 0 c t F2- u) V w > < > I U Z ° _ C> cc o 7O z F- Q iii 0 CC Z 43 7 N o o. Ira ea 2 tTi O 0,, c >. E i/i v ii V 0 o J )N p N a °f o w V ti o U J H o .o o R x >CV N N CO r� J M c p W t Cn `� ! U en Q • o ! ^) f • iii 1 Q Z a z°) o O E U 43 Z V J m it'. m E 3 R o re Z r cn ca Z co y, ` 0 •• O) 0 J L. 0 d �, N w H Z Z Z CO V E = Q r O W O Z d O >- >-p 0 To E E z ! re O O V �� V! Z V P• 0 o W LL m , O �' O O w ° = N '6 re Z W p a+ U >' a y J 0 N °' ° a 2 2 W a >. ° A T , O H J O I- a 0 <CL U 0 Marathon Alaska Production LLC Alaska Asset Team Alk Marathon P.O. Box 1949 MARATHON Alaska Production LLC Kenai,AK 99611 Telephone 907/283-1371 Fax 907/283-1350 q)21"4---r aC) 9 - I-5 RECEIVED March 12, 2010 MAR 16 2010 Mr. Winton Aubert AlseloWN&GesCon&Comnission Alaska Oil & Gas Conservation Commission knchotage 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-407 Well Completion Report and Log Field: Sunrise Lake Well: Sunrise Lake #2RD Dear Mr. Aubert: Submitted for your records is the Well Completion Report and Log for SL-2RD well. Marathon has decided not to drill SL-2RD. This sundry closes out Permit to Drill # 209-159 as a non-drilling activity. Please contact me at (907) 283-1371 if you have any questions or require additional information. Sincerely, -K.e.,(JIAA-'s (9 • Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-407 Well Completion Report & Log cc: Houston Well File Kenai Well File KJS .. « STATE OF ALASKA ALASkJ OIL AND GAS CONSERVATION COMMhoiON WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other • Abandoned ❑ Suspended lb.Well Class: Non-Work 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory El GINJ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: 0 Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill#: 209-159 Marathon Alaska Production LLC Aband.: NA Sundry#: 3.Address: PO Box 1949 6.Date Spudded: 13.API Number: Kenai Alaska, 99611-1949 Did not Drill 50-133-20587-01-00 4a.Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 1,375'FSL, 1,173'FEL, Sec.16, T8N, R8W, S.M. NA Sunrise Lake 2RD Top of Productive Horizon: 8. KB(ft above MSL): 15.Field/Pool(s): GL(ft above MSL): Total Depth: 9. Plug Back Depth(MD+TVD): Wildcat NA 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- y- Zone- 4 NA C-061579 TPI: x- y- Zone- 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- y- Zone- NA NA 18. Directional Survey: Yes ❑ No al 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) NA 21. Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD: 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 24.Open to production or injection? Yes❑ No 0 If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Sunrise Lake 2RD was not drilled. This sundry is closing DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED out Permit to Drill#209-159 as a non-work activity. 27. PRODUCTION TEST Date First Production: NA 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 po. 0 0 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate —•► 0 0 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑ Sidewall Cores Acquired? Yes ❑ No❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RBDMS MAR 16 2010 c h,, Form 10-407 Revised 7/2009 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and mark countered): 30. FORMA' ESTS NAME MD - TVD Well tested? Yes 111 No 111 If y: , ist intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top and submit detailed test information per 20 AAC 25.071. Permafrost-Base Formation at total depth: 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907)283-1371 Printed Name: Kevin J.Skiba Title: Regulatory Compliance Technician Signature: �,(jj(Jfn,`. Phone: (907)283-1371 Date: March 12,2010 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with prod Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional in Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 ''j1 Ii; i 1 \ I f ' r , 1. . sr ; / p € �� 1 ��C` I 1--' �; C SEAN PARNELL, GOVERNOR _ _ \ J F p f/ pf `.-.il/ . i, 0 '2 e:, ``./.) '� l ` L.. 1 r om. F 4% !i‘3 LP.Lt^ !' /ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION , ANCHORAGE,ALASKA 99501-3539 6 PHONE (907)279-1433 FAX (907)276-7542 Mr. Willard J. Tank Advanced Senior Drilling Engineer Marathon Oil Company 3201 C. Street, Suite 800 Anchorage, AK 99503 Re: Exploratory, Sunrise Lake 2RD Marathon Oil Company Permit No: 209-159 Surface Location: 1,375' FSL, 1,173' FEL, Sec. 16, T8N, R8W, S.M. Bottomhole Location: 3,795' FSL, 222' FWL, Sec. 15, T8N, R8W, S.M. Dear Mr. Tank: Enclosed is the approved application for permit to re-drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, / Daniel T. Seamount, Jr. Chair DATED this 3v day of December, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED DEC 092009 / "/44-41 STATE OF ALASKA y.1GA- ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil&Gas Cons.Comte 13°/z0O9 PERMIT TO DRILL Anchorage 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1G.Specify if well is proposed for: Drill ❑ Redrill 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory 0 Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 1111 Single Well ❑ 11.Well Name and Number: Marathon Oil Company Bond No. 5194234 Sunrise Lake 2RD 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3201 C.Street,Suite 800, Anchorage,AK 99503 MD: 13,533 TVD: 12,496 Wildcat 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1,375'FSL, 1,173'FEL,Sec.16,T8N,R8W,S.M. C-061579 Top of Productive Horizon: 8.Land Use Permit: 13.Approxi ate Spud Date: 3,795'FSL,222'FWL,Sec.15,T8N,R8W,S.M. Janu 310 / Total Depth: 9.Acres in Property: 14.Dista Ce-to Nearest Property: 3,795'FSL,222'FWL,Sec.15,T8N,R8W,S.M. 5,120 1,490 if to C-061578 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 207 feet 15.Distance to Nearest Well Open Surface:x-378,032.184 y- 2,478,022.235 Zone- 4 GL Elevation above MSL: 186 feet to Same Pool: 4,710 ft to Sunrise 1 16.Deviated wells: Kickoff depth: 3,400 feet 17.Maximum Anticipated Pressures in psig(see 20 2 .035) 1•044-Maximum Hole Angle: 47.659 degrees Downhole: 5,588 Surface: 4 5 S q 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 9 7/8" 7 5/8" 29.7 L-80 BTC 8,447' 0' 0' 8,468' 7,432' 323 sacks / 6 3/4" 4 1/2" 12.6 L-80 Hydril 563 5,263' 8,270' 7,236' 13,533' 12,496' 582 sacks / 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 9,734 9,607 9,734-7,334 3,500-3,400 3,400 3,400 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 78' 20" 99' 99' Surface 2,979' 10 3/4" 827 sacks 3,000' 3,000' Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 1511 BOP Sketch 0 Drilling Program El Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch IN Seabed Report ❑ Drilling Fluid Program EI 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Willard J.Tank Title Advanced Senior Drilling Engineer ill zoz F3°/P crtl Signature D,//Gc'/e.--y4A-,— 4. Gt rr Phone 713-296-3273 Date December 8,2009 Commission Use Only Permit to Drill p API Number: / v Permit A7,730/ See cover letter for other Number: o�Q9<$9 50Y3�ao6'�7of Date: e 9 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed mane/gas hydrates,or gas contained in shales: PP � Y P � P 9 Y 9 Q Other: Samples req'd: Yes❑ No[ Mud log req'd: Yes ❑ No R' H2S measures: Yes❑ No V Directional svy req'd: Yes ViNo ❑ Ietf .oPE iv 45oo loc- . !, ao P C fesf -t►tea t c.ekt_ei d s 7 d.etc( S . APPROVED BY THE COMMISSION If 1 3d ! DATE: . / COMMISSIONER ORIG1NA Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate Worldwide Drilling North America Ari)k Marath on P.O. Box 3128 THOOil Company Houston,TX 77253-3128 Telephone 713-629-6600 Fax 713-499-6737 December 8, 2009 RECE!`�'E Daniel T. Seamount, Jr. liLL =3 llli Commissioner State of Alaska Alaska Oil&Gas Cans.tacit:♦''"""" Alaska Oil & Gas Conservation Commission Anahoroga 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Drilling Permit Application Field: Wildcat Well: Sunrise Lake 2RD Dear Mr. Seamount Enclosed please find the PERMIT TO DRILL application, along with the associated attachments. The intent is to sidetrack out of the existing Sunrise Lake 2 well and drill an exploration well into the Tyonek in the Sunrise area. This would be done immediately after the evaluation and plug back of the Sunrise Lake 2 wellbore. For the directional data we utilize the National Geodetic Survey conversion in the program CORPSCON to calculate the State Plane Coordinates in NAD 27 for the planned and actual wellpaths from the NAD 83 data and present both in our directional survey attachment for the 10-401. We also provide the same data electronically, so that the AOGCC has this for data input into their database. It is Marathon's desire for this well to be classified as a TIGHT HOLE, especially due to the nature of this project. If there is anything additional we need to do to acquire or maintain this status, please let me know. If you require further information, I can be reached at 713-296- 3273 or by e-mail at wjtank @marathonoil.com. Sincerely, 474— Willard J. Tank Advanced Senior Drilling Engineer Enclosures Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC MARATHON MARATHON OIL COMPANY DRILLING PROGRAM Sunrise Lake 2RD Originator: Will Tank December 8, 2009 Date Reviewed by: Pete Berga /Z 'f.- 0 7 Date Brian Roy Date 12/8/2009 CONFIDENTIAL MATERIAL Page 1 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC TABLE OF CONTENTS 1. Emergency Response Information 4 1.1 Directions to Location 4 1.2 Rig Contact Numbers 4 1.3 Marathon Emergency Response Contacts 4 1.4 Outside Emergency Response 4 1.5 Marathon Contact List 5 2. Regulatory Agency Contacts 5 2.1.1. Internal Regulatory Contact 5 2.1.2. External Regulatory Contact 5 3. Regulatory Compliance 5 4. Drilling Program Summary 6 4.1 General Well Data 6 4.2 Working Interest Owners Information 6 4.3 Geologic Program Summary 6 4.4 Summary of Potential Drilling Hazards 7 4.5 Formation Evaluation Summary 7 4.6 Drilling Program Summary 8 4.7 Casing Program Summary 10 4.8 Casing Design 10 4.9 Calculation of Maximum Anticipated Pressures (MAWP and MASP) 10 4.10 Casing Test Pressure Calculations 12 4.11 Blowout Prevention Equipment, Testing and General Procedures 12 4.11.1. Function Testing 12 4.11.2. Pressure Testing 13 4.12 Wellhead Equipment Summary 13 4.13 Directional Program Summary 13 4.14 Directional Surveying Summary 14 4.15 Drilling Fluid Program Summary 15 4.16 Drilling Fluid Specifications 15 4.17 Solids Control Equipment 16 4.18 Cement Program Summary 17 4.19 Bit Summary 17 4.20 Hydraulics Summary 18 4.21 Formation Integrity Test Procedure 18 12/8/2009 CONFIDENTIAL MATERIAL Page 2 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC Attachments Group Attachment Attached Commercial Information AFE Days/Cost vs.Depth Curves X Project Objectives and Scorecard RSO Coding Information X Requisitions Vendor List Bonus Program Drilling Contract Regulatory/HES Information Emergency Evacuation Plan X H2S Contingency Plan n/a Regulatory Permits X Regulatory Rules and Regulations Risk Analysis Miscellaneous Programs(Vendors) Bit Proposal X Cement Proposal X Directional Plan X Fluids Program X Wellhead Equipment—Description/Drawings Drill String and BHA Summary Rig Mobilization/Mooring Procedure n/a Geological Information Location Map w/offsets X Offset Data Proposed Formation Pore Pressure,Mud Wt&Fracture Gradient X Temperature Curves Geologic Structure Maps Geologic Cross Section Bathymetry Map n/a Analysis Riser Analysis n/a Station Keeping Analysis—Mooring/DP n/a Stress Check Casing Design File X Maximum Allowable Overpull Miscellaneous Information Wellbore Diagram n/a Rig Elevations X Well Location Diagram X BOP Schematic X BOP Well Control Bridging Document Detailed Casing Specifications X Detailed Drill Pipe Specifications 12/8/2009 CONFIDENTIAL MATERIAL Page 3 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 1. Emergency Response Information 1.1 Directions to Location Method Directions Air Latitude-60°46'49.5224"N Longitude-150°41'04.7162"W (NAD 83) From the Kenai airport,go 0.5 mile South on Airport Way. Turn East on Kenai Spur Highway,go 10.2 miles. Continue East on Ground Sterling Highway 10.1 miles. Turn North on Swanson River Road,go 17.3 miles. Go Northwest on Swanson River Production Facility Road 4.9 miles. Continue East on new lease road,go 7 miles to the Sunrise pad. 1.2 Rig Contact Numbers Contact Office Cell Glacier Drilling Rig 1 7 Inlet Drilling Tool Pusher 907-283-1314 907-394-1321 Marathon Supervisor 907-283-1312 907-394-1317 1.3 Marathon Emergency Response Contacts Individual Postion Main Phone Alternative Kenai Gas Field Emergency Number 907-283-6465 CERT 24 hrs Notification 1-800-MOC-CERT CERT Crisis Center Houston 713-296-4230 713-296-4237 1.4 Outside Emergency Response Y onse p Location Contact Phone Fire Kenai/Soldotna,Alaska 907-262-4792 Ambulance Hospital Kenai/Soldotna,Alaska Central Peninsula Hospital 907-262-4404 Kenai Police 907-283-7879 Police Kenai/Soldotna,Alaska Soldotna Police 907-262-4455 State Police 907-262-4453 Coast Guard 800-478-5555 Spill and Contamination Alaska Alaska State Spill Reporting National Response Center Oil/Toxic Chemical Spills 800-424-8802 Best Practices: 1 Policy: Post emergency notification information on rig floor, company man's and tool pushers' office Comments: 12/8/2009 CONFIDENTIAL MATERIAL Page 4 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 1.5 Marathon Contact List Contact Title Office Mobile Facsimile Home Will Tank Drilling Engineer 713-296-3273 713-203-8398 _ 713-499-6737 832-934-2617 _ Pete Berga Drilling Superintendent 907-565-3032 907-529-0551 907-565-3076 907-346-3763 Bryan Roy Drilling Manager 713-296-3256 832-444-4772 713-499-6707 281-246-4686 Courtney McElmoyl Geologist _ 713-296-3597 713-208-0472 Clyde Scott Reservoir Engineer 713-296-2336 Craig Rang Completion Engineer 907-283-1372 _ 907-394-1824 _ Nick,Miller Completion Engineer 713-296-1920 713-294-1735 Rowland Lawson Drilling Supervisor 907-283-1312 907-394-0953 907-283-1313 John Nicholson Drilling Supervisor 907-283-1312 907-394-2641 907-283-1313 Mitch Burns Drilling Supervisor 907-283-1312 907-394-2641 907-283-1313 2. Regulatory Agency Contacts 2.1.1. Internal Regulatory Contact Contact Title Office Phone Cell Phone Home Phone Facsimile Tiffany Stebbins Regulatory Compliance 907-565-3043 979-529-0522 907-565-3076 2.1.2. External Regulatory Contact Contact Title Office Facsimile 24 hr Emergency Pager AOGCC 907-793-1236 AOGCC North Slope Pager-907-659-3607 3. Regulatory Compliance Regulation Requirement 20 AAC 25.035 e 10 A BOP testing interval requirement is now 1#lays. �� ----)t- 20 AAC 25.035 e 10 F Requirement for a 24 hour notice to AOGCC prior to BOP test. Comments 12/8/2009 CONFIDENTIAL MATERIAL Page 5 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 4. Drilling Program Summary 4.1 General Well Data Well Name Sunrise Lake 2 Lease/License Surface Location 1,375'FSL, 1,173'FEL,Sec. 16,T8N,R8W,S.M. WBS Code DX.09.20437.CAP.DRL Slot/Pad Sunrise Pad Field Wildcat Spud Date 01/31/10(est.) KB(above MSL) 207' County/Province Kenai Peninsula API No. GL(above MSL) 186' State/Country Alaska Permit No. Perm.Datum KB Total MD 13,533' Well Class Exploration Water Depth N/A Total TVD 12,496' Rig Contractor Glacier Drilling Water Protection Depth Rig Name Glacier Rig 1 Best Practices: 1 Comments: 4.2 Working Interest Owners Information Company Working Interest Address Phone Facsimile Marathon 100% P.O.Box 196168 907-561-5311 907-565-3076 Anchorage,AK 99519-6168 4.3 Geologic Program Summary Surface Location Coordinates—NAD 83 From Lease/Block Lines 1,375'FSL, 1,173'FEL,Sec. 16,T8N,R8W,S.M. Latitude 60°46'49.5224"N Longitude 150°41'04.7162"W UTM North(Y) 2,477,782.462' UTM East(x) 1,518,056.130' Tolerance Pore Pore / MD-RKB TVD—RKB Pressure Pressure Possible Formation (ft) (ft) (psi) (ppg) Lithology Fluid Content Beluga (Not a Target) 7,816 6,807 8.6 Sandstone Water Tyonek (Primary Target) 8,669 7,632 8.6 Sandstone Gas 12/8/2009 CONFIDENTIAL MATERIAL Page 6 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC Depth(KB) Horizontal Displacement(ft) MD TVD +N/-S +E/-W Tolerance Target (ft) (ft) Location (Y) (X) (ft) Tyonek 8,669 7,632 3,795'FSL,222'FWL,Sec.15,T8N, R8W,S.M. 2,420 1,395 Circle 150'radius TD 13,533 12,496 3,795'FSL,222'FWL,Sec.15,T8N,R8W,S.M. 2,420 1,395 Circle 150'radius 4.4 Summary of Potential Drilling Hazards Depth KB Hazard Event (TVD) Discussion Precautions Bit or BHA balling Surface Hole Maintain high pump rates to keep bit and BHA clean. Use extra circulation time if necessary. Intermediate Use good hole cleaning techniques with high pump Excessive pumping on bottom could Excessive Torque &Production rates. Add lubricant where necessary. result in hole washout. Hole Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +1- 8,669' MD (7,632' TVD) to total depth of the well. These sands are expected to be at normal pressure. The Flo-Pro mud system that will be properly weighted to hydraulically control all sands and lost circulation materials will be available on location, if required. Best Practices: 1 Comments: 4.5 Formation Evaluation Summary Interval LWD Electric Logs Mud Logs Intermediate Triple Combo Dipole Sonic Basic with GCA,shale density,temperature in and 3,400'—8,468'MD out,sample collection(10'samples). Production Triple Combo, Dipole Sonic. 8,468'—13,533'MD Density Imaging, Basic with GCA,shale density,temperature in and NMR out,sample collection(10'samples). Completion N/A GR,CCL,CBL N/A Comments: 12/8/2009 CONFIDENTIAL MATERIAL Page 7 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 4.6 Drilling Program Summary Drive Pipe: N/A Conductor: 20" previously set to approximately 99', prior to drilling rig move. Surface: 13-1/2" previously drilled to+/-3,000', 10-3/4"casing set. Intermediate: Kickoff cement plug at 3,400' MD and drill 9-7/8" hole to +/-8,468'set 7 5/8"casing. 1. PU 9 7/8"PDC bit and directional BHA. Tag cement plug at+/-3,300' MD. Dress off cement plug to KOP 3,400' MD. CBU. / 2. Drill 9 7/8"directional hole to 8,468' MD(7,432'TVD)as per directional program, short tripping as required. 3. At TD circulate hole clean. Make wiper trip. TOOH. 4. RU logging company. Run di e sonic open hole log as per plan. POOH and rig down logging company. 5. TIH with 9 7/8"bit to TD fo wiper tip. TOOH and lay down BHA and 5"drill pipe. Pull wear bushi ci.co 0 v„/Gk- 6. Change out pipe rams wi h 7 5/8"casing rams in single ram. Run test plug and test casing rams t. . ::. .si. 7. Run and cement 7 5/8"c ' . Land hanger in multibowl wellhead. ¢So 0 8. Back out landing joint. Change out 7 5/8"casing rams with pipe rams. Run test plug and test BOP's to 250/',e;i i. 9. Set wear bushing. Test intermediate casing to 2,500 psi. Best Practices: 1 Pre-heat mud mix water to help in early shaker screen blinding issues with the mud. 2 During cementing operations,take returns in the cellar, instead of into the pits. Eliminates the clean up of pits from cement that circulated to surface. Vac trucks will pull from cellar. Comments: The intermediate section should be drilled with 5"drill pipe to optimize hydraulics. It will already have been picked up from the surface drilling section on Sunrise Lake 2. Lay down 5"and pick ? up 4"for the production section. / - "�. �1 Y a t4A(- Production Liner: Drill 6 3/4" hole to +/- 13,533'set 4-1/2" liner. Tie back to surface with 4-1/2"tubing. 1. PU 6 3/4"bit and directional BHA on 4"drill pi. - d TIH. Drill float equipment and 20'of new formation.CBU. 2. Test shoe to LOT. Estimated Leak Off EMW .pg. i 3. Drill a 6 3/4"hole to an anticipated TD of 13, 33' MD(12,496'TVD)as per the directional program,short tripping as required. 4. At TD circulate hole clean. Make wiper trip. TOOH. 5. RU logging company. Run dipole sonic open hole log as per plan. POOH and rig down logging company. 6. TIH with 6 3/4"tri-cone bit to TD for wiper trip. TOOH and lay down BHA and drill pipe. Pull wear bushing. 7. RU and run 4 1/2" Hydril 563 casing liner with hanger on drill pipe. Run liner to TD with top of liner at approximately 8,270' MD. On bottom reciprocate and rotate liner while circulating the hole. 8. RU cementing company. Cement 4 1/2"while reciprocating and rotating pipe. Drop wiper plug and bump plug to pressure up and set the liner hanger. Release hanger running tool, pick up and clear seal area of any cement. Pick up out of liner. 9. Circulate hole clean. If cement circulates,TOOH. If cement doesn't circulate,WOC,then prepare and pump liner top job. 10. Once cement is either circulated or the liner top is squeezed, PU mill for 4 1/2"along with string mill for 7 5/8"casing. Make cleanout trip to top of 4 1/2"liner with mill combo on drill pipe. Polish 4 1/2"liner seal bore. 11. Run 4 1/2"liner hanger packer with hydraulic pusher tool. Stab into polish bore receptacle and set packer. TOOH laying down drill pipe. 12. Run 4 1/2"casing with seal unit. Displace hole with 3%KCL. Space out tubing and land hanger. ND BOP, NU tree and test to 5,000 psi. 13. Rig down and move out drilling rig. Best Practices: 1 Make up torque shown for the Hydril 563 is 80%of yield. The final make up torque for the liner should exceed any potential torque that would be used to release the running tool from the hanger. 12/8/2009 CONFIDENTIAL MATERIAL Page 8 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC Comments: Completion: Completion will be done without a rig. 1. The completion will encompass work to run a cement bond log,displace the KCL water in the wellbore with nitrogen, perforate several Tyonek intervals, and test the well for rate and pressure. No stimulation of the perforating intervals is anticipated. Best Practices: 1 Comments: 12/8/2009 CONFIDENTIAL MATERIAL Page 9 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LL C 4.7 Casing Program Summary MD(ft) Connection API Ratings Casing Makeup Hole a) - o. = o 07 Size Weight ID Drift O.D. Torque Size m �- 75 Y (in) Top Bottom (Ibs/ft) (in) (in) Grade Type (in) (ft-lbs) (in) 10 3/4 0 3,000 45.5 9.950 9.794 K-55 BTC 11.750 N/A* 13 1/2 3,580 2,090 715 7 5/8 0 8,468 29.7 6.875 6.750 L-80 BTC 8.500 N/A* 9 7/8 6,890 4,790 683 4 1/2 8,270 13,533 12.6 3.958 3.833 L-80 Hydril 563 5.200 10,080 6 3/4 8,430 7,500 288 Best Practices: 1 Have float equipment made up at Tubescope's yard prior to bringing casing to location. Buck on all equipment to the pin end and not make up to box below,due to rig height restrictions. 2 Make up torque shown for the Hydril 563 is 80%of yield. The final make up torque for the liner should exceed any potential torque that would be used to release the running tool from the hanger. *- Make up buttress connection to proper mark, not to a torque value. Comments: i. ALL CASING WILL BE NEW CASING. 4.8 Casing Design Casing Shoe Safety Factors Setting Maximum Casing Depth Mud Wt Frac. Form Surface n o Size Weight TVD When Set Grad Press Pressure o m (in) (Ib/ft) Grade (ft) (lb/gal) (Ib/gal) (Ib/gal) (psi) m U i- 10 3/4 45.5 K-55 3,000 9.2 13.0 8.6 966 1.38 1.46 3.30 7 5/8 29.7 L-80 7,432 9.6 14.6 8.6 1,809 1.41 1.29 2.37 41/2 12.6 L-80 12,496 9.7 15.0 8.6 1,809 1.12 1.19 1.68 4.9 Calculation of Maximum Anticipated Pressures (MAWP and MASP) Setting Casing Depth Size TVD MAWP* MASP** Mud/Gas (in) (ft) (psi) (psi) Percentage 10 3/4 3,000 2,444 1,703 30/70 7 5/8 7,432 4,784 2,822 30/70 4 1/2 12,496 4,784 2,822 30/70 * MAWP=Maximum allowable working pressure ** MASP= Maximum anticipated surface pressure The calculation method for MASPBHP has been modified from the standard AOGCC use of a Bottom Hole Pressure—0.1 psi/ft gas gradient to what Marathon considers a more accurate Bottom Hole Pressure—30% Mud Column—70%Gas Column. This method follows the MMS standard for any well with a TVD of 12,000'or less. Marathon believes that constant gas monitoring and proper rig supervisor well control training will prevent the possibility of a wellbore being completely evacuated with only a gas gradient remaining. 12/8/2009 CONFIDENTIAL MATERIAL Page 10 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC Surface casing: 10 3/4" (3,000' MD, 3,000'TVD) MASPfrac=((Fracture gradient at shoe)x .052 x TVDshoe)-Hydrostatic pressure of gas column at the shoe. MASPfrac=(13.0 ppg x.052 x 3,000')-(0.1 psi/ft x 3,000') MASPfrao=2,028 psi-300 psi MASPfrac= 1,728 psi. MASPnnP=BHPopen hole td—Hydrostatic pressure of mud portion-Hydrostatic pressure of gas portion MASPbhp= (8.6 ppg x.052 x 7,432'))-(0.3 x 9.5 ppg x.052 x 7,432')-(0.7 x 0.1 psi/ft x 7,432') MASPbhp=3,324 psi-1,101 psi-520 psi MASPbhp= 1,703 psi MASP=MASPbhp= 1,703 psi c.9 r ( ). 2 ) 2 ) - (o a)('7f13?) 7 S'O p CL. MAWP= (0.7 x Casing Burst)-(Mud Wt.-Backup Fluid Wt.)x.052 x TVD MAWP=(0.7 x 3,580)-(9.6-9.2)x.052 x 3,000' MAWP=2,506 psi-62 psi=2,444 psi Intermediate casing: 7 5/8" (8,468' MD, 7,432'TVD) MASPfrac=((Fractre gradient at shoe)x.052 x TVDshoe)-Hydrostatic pressure of gas column at the shoe. MASPfrac=(.14:6-ppg x.052 x 7,432')-(0.1 psi/ft x 7,432') MASPfrac=5,642 psi-743 psi MASPfrac=4,89J 15si. �Y ca j cI c-i MASPnnP= BHP open hole td-Hydrostatic pressure of a gas column MASPbhp=(8.6 ppg x.052 x 12,496')-(0.3 x 9.7 ppg x.052 x 12,496')-(0.7 x 0.1 psi/ft x 12,496') MASPbhp=5,588 psi-1,891 psi-875 psi MASPbhp=2,822 psi MASP=MASPbhp=2,822 psi O r 1 1,6,)( t c )(1 2 — (Ca,,)( _tl c/fr ) N? P MAWP=(0.7 x Casing Burst)-(Mud Wt.-Backup Fluid Wt.)x.052 x TVD MAWP=(0.7 x 6,890)-(9.7-9.6)x.052 x 7,432' MAWP=4,823 psi-39 psi=4,784 psi Production liner: 4 1/2" (Top-8,270' MD,7,236'TVD)(Bottom- 13,533' MD, 12,496'TVD) MASP=MASP 5/8"=2,822 P si MAWP=MAWP75/8"=4,784 psi Best Practices: 1 Comments: 12/8/2009 CONFIDENTIAL MATERIAL Page 11 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 4.10 Casing Test Pressure Calculations Casing test pressures calculations are based on the lesser of (1)MASP,or(2)70%of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 ppg back-up unless otherwise noted. Best Practices: 1 Comments: 4.11 Blowout Prevention Equipment, Testing and General Procedures BOP PROGRAM Casing Test Test Casing Test Fluid I Pressure Size MAWP MASP Press Density BOPS Low/High Casing (in) (psi) (psi) (psi) (lb/gal) Size&Rating (psi) (1)13-5/8"5M annular (1)13-5/8"5M pipe ram 4500 Surface 10 3/4 2,444 1,703 1,500 9.2 (1)13 5/8"5M blind ram 250/3,990' (1)13-5/8"5M drilling spool with 3-1/8"5M outlets (1)13-5/8"5M pipe ram (1)13-5/8"5M annular (1)13-5/8"5M pipe ram 45019 Intermediate 7 5/8 4,784 2,822 2,500 9.6 (1)13 5/8"5M blind ram 250/37@00 (1)13-5/8"5M drilling spool with 3-1/8"5M outlets (1)13-5/8"5M pipe ram (1)13-5/8"5M annular (1)13-5/8"5M pipe ram 450 0 Production 4 1/2 4,784 2,822 2,500 9.7 (1)13 5/8"5M blind ram 250/3990 `X (1)13-5/8"5M drilling spool with 3-1/8"5M outlets (1)13-5/8"5M pipe ram Blowout Preventers The blowout preventer stack will consist of a 13-5/8"x 5000 psi annular preventer, a 13-5/8"x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8"x 5000 psi drilling spool(mud cross)with 3-1/8"x 5000 psi outlets,and a 13-5/8"x 5000 psi single pipe ram. The choke manifold will be rated 3-1/8"x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. 4.11.1. Function Testing Function .Re ularl 9 Y 12/8/2009 CONFIDENTIAL MATERIAL Page 12 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 4.11.2. Pressure Testing The Marathon Drilling Supervisor will verify all pressure tests of BOP's, surface lines, seals, casings and FIT or LOT tests. All tests are to be recorded on the IADC and daily drilling reports. Best Practices: 1 Comments: 4.12 Wellhead Equipment Summary Component Description Casing Hanger Type 10 3/4"x 7 5/8"Fluted Casing Head 11"3M X 10-3/4"Slip Loc W/2,2"LPO,Landing Base for 20"Conductor,U,AA,PSL1,PR1 Mandrel Tubing Head 11"3M Studded Bottom X 11"5M Flg Top,W/2,2-1/16"5M Studded Outlets,U,AA,PSL1,PR1 10 3/4"x 4 1/2"Mandrel Adapter Flange 11"5M X 4-1/16"5M W/Seal Pocket and 3"H BPV Threads Best Practices: 1 Comments: 4.13 Directional Program Summary Build Turn Coordinates Sec. MD TVD Rate Rate Dogleg Inclination Azimuth +N/-S +E/-W VS No. Description (ft) (ft) (°/100') (°/100') (°/100') (deg) (deg) (ft) (ft) (ft) 1 Tie On/KOP 3,400.00 3,400.00 0 0 0 0 29.962 0 0 0 2 Build up Section 3.00 0 3.00 29.962 3 End of Build 4,988.64 4,811.67 3.00 0 3.00 47.659 29.962 540.17 311.39 623.49 4 Hold Section 0 0 0 47.659 29.962 5 End of Hold 7,080.06 6,220.33 0 0 0 47.659 29.962 1,879.44 1,083.45 2,169.37 6 Drop/Turn Section -3.00 0 3.00 29.962 7 End of Drop/Turn 8,668.69 7,632.00 -3.00 0 3.00 0 29.962 2,419.61 1,394.84 2,792.86 8 TD 13,532.69 12,496.00 0 0 0 0 29.962 2,419.61 1,394.84 2,792.86 12/8/2009 CONFIDENTIAL MATERIAL Page 13 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 1 --1 o--_ 3000— — — — — I - - t j 2000 2RD j 10 3/4" i Sunrise Lake _ -- — — - , c 4000 — c 2000— i — - w p Sunrise Lake 2RD TD o 6000— o L a I Q + 75/8"5 8000—_, Sunrise Lake 2RD Tyonek 1000— t 1 /, d Sunrise Lake 2RD TD- III o E2 10000— 12000— 4 1/2" 0 14000 -4000 -2000 0 2000 4000 6000 8000 0 1000 2000 Vertical Section at 29.962°(4000 ft/in) West(-)/East(+)(1000 ft/in) Comments: Vertical section calculated from a reference azimuth of 29.96°taken from surface location to bottom hole location. Potential Well Interference: None. No other wells present. Best Practices: 1 Comments: 4.14 Directional Surveying Summary Other Survey Interval MD(ft) MWD Survey Magnetic Multishot Gyro Multishot Remarks Tool Intermediate 3,400'—8,468' X Production 8,468'—13,533' X Best Practices: 1 Comments: 12/8/2009 CONFIDENTIAL MATERIAL Page 14 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 4.15 Drilling Fluid Program Summary Interval—TVD Minimum Inventory From To Density Gel (ft) (ft) (lb/gal) _ Fluid Description Additives Viscosifier Barite Flo-Vis,PolyPac UL,KCI,SafeCarb,Asphasol 3,400 7,432 9.2—9.6 3%KCL Flo-Pro w/Safecarb Supreme,Lo Torq,Caustic,Congor 404,Sodium Meta Bisulfite,KlaGard Flo-Vis,PolyPac UL,KCI,SafeCarb,Asphasol 7,432 12,496 9.2—9.7 3%KCL Flo-Pro w/Safecarb Supreme,Lo Torq,Caustic,Congor 404,Sodium Meta Bisulfite,KlaGard,SteelLube EP Best Practices: 1 Comments: 4.16 Drilling Fluid Specifications Interval—TVD LSRV Drill From To Density Vis 1 min PV YP Fluid Loss Solids (ft) (ft) (lb/gal) (sec/qt) (Ib./100ft2) (cP) (lb/100 ft2) (cc) pH (%) 3,400 7,432 9.2-9.6 30-40,000 10-16 12-18 5-7 +/-9.5 <6 7,432 12,496 9.2—9.7 30-40,000 10-16 12-18 5—7 +/-9.5 <6 Best Practices: 1 As a standard practice for tie-back string completions, displace the drilling mud above top of liner with brine treated with corrosion inhibitor(Congor 303A) at a concentration of 1 drum per 100 barrels of fluid. Comments: See mud prognosis for details. Sized CaCO3(SafeCarb)will be used to control leakoff. II II 12/8/2009 CONFIDENTIAL MATERIAL Page 15 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 4.17 Solids Control Equipment C o N U Co N co 6 N z N Co . m d U . 2 O 0 E (0 N tll C Interval 0 0 U 0 0 N Comments 0—13,533'MD X X X X Closed Loop System, Full Containment,Run shakers with finest screens possible Equipment Specifications Item (quantity,design type,brand,model,flow capacity,etc) Shaker 2—Swaco Mongoose PT Desander N/A Desilter 1—Derrick Model 0522 Mud Cleaner N/A Centrifuge 2—MI/Swaco units Cuttings Dryer N/A Cuttings Injection Marathon G&I Facility Zero Discharge N/A Best Practices: 1 Have vacuum trucks pull fluids from trough above slop pit to more efficiently pull fluids for disposal. This minimizes water added to the solids to suspend for pickup by the trucks,thus minimizing total volume to be disposed of. Comments: 12/8/2009 CONFIDENTIAL MATERIAL Page 16 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 4.18 Cement Program Summary Depth Gauge Top of Cement Gauge Ann Vol Slurry Casing Hole Ann Vol With OH Density Open Hole Thickening Size MD TVD Size MD TVD To TOC Excess Lead/Tail Excess Time (in) (ft) (ft) (in) (ft) (ft) (ft3) (ft3) (PPP) (%) (hrs) 20 99 99 Driven N/A 10 3/4 3,000 3,000 13 1/2 0 0 1,183 2,050 12.0 75 8 7 5/8 8,468 7,432 9 7/8 7,300 6,377 251 (372.) 15.8 40 8 V 4 1/2 13,533 12,496 6 3/4 8,270 7,236 729 1 .,21,1,7 13.5 40 N/A V Mix Water Compressive Casing Slurry TOC Strength Size Density Qty Yield Vol MD Qty WL FW (psi) (in) Slurry Cement Description (Ib/gal) (sx) (ft3/sx) (ft3) (ft) (gal/sx) Type (cc) (%) 8 hr 24 hr 10 3/4 Tail Type I Cement 12.0 827 2.48 2,050 0 10.33 Fresh 7 5/8 Tail Class"G" 15.8 323 1.15 372 7,300 4.96 Fresh I lGg 41/2 Tail Class"G" 13.5 582 1.74 1,012 8,270 7.14 Fresh SL63' Best Practices: 1 Pump several fluid calipers at TD to help with the hole volume determination from the open hole caliper log. Comments: See cement prognosis for details and spacer specifications. 1. Volume calculations assume 80'of internal cement for the shoe tracks. See cement prognosis for details and spacer specifications. 4.19 Bit Summary Interval—MD Type Recommended Estimated Expected From To Size WOB Rotating Minimum ROP (ft) (ft) (in) Manufacturer Model No. IADC (kips) RPM Hours (ft/hr) 3,400 8,468 9 7/8 Christensen HCM605Z M323 Up to 36 Motor 8,468 13,533 6 3/4 Christensen DP505X M323 Up to 36 Motor Best Practices: 1 Comments: See bit prognosis for additional information. Back up bits for the 9 7/8"hole section will consist of PDC and mill tooth bits. Back up bits for the 6 3/4"hole section will consist of 6 3/4"mill tooth and ICI tricone bits. 12/8/2009 CONFIDENTIAL MATERIAL Page 17 of 18 Sunrise Lake 2RD Marathon Oil Company Drilling Program Alaska Production LLC 4.20 Hydraulics Summary Max Press @ Displacement @ Max Rate @ Liner ID Stroke 90%WP 95%Vol.eff 95%Vol.eff Hole Sections Used Qty Make Model (in) (in) (psi) (gal/stroke) (spm/gpm) On 5 8 2,597 2.04 125/255 Surface 3 National Oil Well A600PT 5 8 2,597 2.04 125/255 Intermediate 5 8 2,597 2.04 125/255 Production Est. Hole Pump Standpipe Openhole Nozzle AP at Depth-MD Size Rate Pressure Min AV MW ECD Size bit (ft) (in) (gpm) (psi) (fpm) (ppg) (ppg) (32"s) (psi) Remarks(Drill string configuration) 3,400—8,468 9 7/8 550 1,743 186 9.2 9.7 MI Virtual Hydraulics @ 8,468'MD 8,468—13,533 6 3/4 350 2,059 290 9.6 10.5 MI Virtual Hydraulics @ 13,533'MD Best Practices: 1 The intermediate section should be drilled with 5" drill pipe for optimizing hydraulics. It will have been used on the surface hole section. 4" drill pipe will need to be utilized for the production hole. Comments: See mud program (Virtual Hydraulics)for additional information. 4.21 Formation Integrity Test Procedure Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests(LOT)are to be conducted as described below: 1. Drill 20'to 25'of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Best Practices: 1 Comments: 12/8/2009 CONFIDENTIAL MATERIAL Page 18 of 18 Marathon Oil Well Sunrise Lake 2 rol BOP Stack Flow Nipple --_____________* Flow LinE 13 5/8"5M Annular / Preventer 13 5/8"5M Double Ram Preventer III Pipe Ram . j v e R 2•V>3 " X c- it z 2 1/16"5M . Blind Ram . Check Valve 2 1/16"5M Manually 3 1/8"5M Manually Operated Valves Operated Valve 1� I I ` X X Kill Choke X Iz \ I 13 5/8"5M Cross �I, <1 1 3 1/8"5M Hydraulically Pipe Ram r Operated Valve 13 5/8"5M Single -, Ram Preventer > < Bottom of Single gate must be I 14 24-45"from ground level for J Glacier 1 rig placement. 135/8"5Mx135/8"5M r Drilling Spool (/\______ 11"5M x 13 5/8"5M DSA Marathon Oil Well Sunrise Lake 2 rd Choke Manifold To Gas Buster To Blooey Line Bleed off Line to Shakers MI VP la WV 1 1 Mr Nom mom aimmo II I (I 'I II /I .0• 8 0 8 0 8 000 000 0— II II i II II 1l It II I iI II 11 `I r 1 MUM I I /m\..... 1 II To CI =6 _ ....., ...., I�I I _ •_. IIi:•iiIIIt• 1' © -_IBC© Iil \ it I I 3" 5M Valves 0 1 2 9/16" 10M Swaco ` 3 1/8" 5M Manually Hydraulically Operated Adjustable Choke Choke Gauge Block e Fiji Choke Hose to HCR 1 (from BOP Stack) 0 - 6,000 psi Choke Control Pressure Gauge Pressure Sensor r=".'' ■ ■ 1`0 ENEOE/IMIIMMEt 7\---. -------i CO IC PAD LIMITS NO RTH - 6"WATER WELL C, \> 1173' FEL 0..- i ACCESS ROAD SUNRISE NO. 2 WELL W Z AS—BUILT • NAD27 ASP ZONE 4 U 1 GRID N: 2478022.235 GRID E: 378032.184 1r LATITUDE: 60°46'51.5464"N o LONGITUDE: 150°40'56.7519"W ELEVATION: 186.0 FT. NAVD88 KENAI NATIONAL WILDLIFE REFUGE 1375 FSL SEC. 16 T8N , R8W, S . M . , AK ,„.."1.11, 1)BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 2003)IS AN `� OPUS SOLUTION FROM NGS COORDINATES STATIONS'KEN5 CORS ARP", 0 F q �1 c1 l "TSEA ANCHORAGE CORS ARP',AND-ZAN1 ANCHORAGE WAAS 1 CORS ARP' w ` �!T.. /, SRS CP411 WAS DETERMINED TO AVE A LATITUDE OOF 60'47'18.08142"N AND A -*� 1±1 1\ *r*,' (ASP)ZONE OF 150°48'24.46462"W.THE 091E=1496261.210 STATE PLANE COORDINATES ELEV.361.74`(NAVD88) 2)BASIS OF VERTICAL DATUM IS NORTH AMERICAN VERTICAL DATUM OF 1988 (NAVD8B)COMPUTED USING GEOID06. ../# / 3)OFFSETS 0 SECTION LINES WERE DETERMINED FROM ELM PROTRACTED 'q� 47/71f SECTION CORNER VALUES FOR SECTION 16. /, STAN A. McLANE 4)NADCON DATUM CONVERSION UTILITY USED TO DERIVE NAD27 VALUES. /i 'Si's '. 46 7—S 9 i �fI r iEssIow- 0 t SCALE 0LE 400 X‘‘ I FEET I SEC. LINE T S16 S15 S21 S22 PROJECT REVISION: NIA O SUNRISE NO. 2 WELL AS-BUILT DATE, 12.02.38 OK, COMPANY SURFACE LOCATION DIAGRAM DRAVA/BY: BGB iIARAIMIN ��A 1 Bp NAD27 SCALE: 1,20u EAST SWANSON RIVER SATELLITES PAD'A' PROJECT NO 003077 4) ENGINEERING/MAPPING t SURVEYING I TESTING BOON NO. 3&2D Consulting ng Inc P.O-BOX 463 SOLDOTNA,AK 00630 LOCATION SHEET VOICE:L SAT 30-1213 FAX IECG263-32os S16 T8N R8W SEWARD MERIDIAN,ALASKA or 1 EMAIL SA7.ICLANE.E,LiCIANECG COI.I I� },,.. � it '„ g 1 ° frlJ 1 4'„,, CD E 11 i �ilT._dam!• t'I'R <---- rn I A '-'` -1 „' _ s t a_\ ...,„. NI lit 1% , .,,,__ ■ is ■- 1 v < _ U N ^,'O T y ` O c Y d -..”WI-) 7 ( / • / `� J t 0 E. J — (2 co J' - r —i-i--- . . Alr -- e„,„\,11...4.,____ _ / (-f-L...,_ / L.), 6 1 Q i- ti N N lir V4 ',C}'i a --- %' ■ o� '-� Tom. 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Ruin a n 0 t-..-Alf' a II r O x _ MOM YNM In —�f `- = Q O i R = --_=- _r O ._ LA O i' O 3 III O lib i 1 0 'p �'�� M MARATHON Oil Company BAKER Location: Cook Inlet,Alaska(Kenai Penninsula) Slot: Sunrise Lake#2 HUGHES MARATHON Field: Sunrise Lake Unit(NAD83) Well: Sunrise Lake#2 !!I[ (7V Facility: East Swanson River Satellites Pad'A' Wellbore: Sunrise Lake#2RD Plot reference wellpath is Sunrise Lake#2RD Version#2 True vertical depths are referenced to Glacier#1(RKB) Grid System:NAD83/TM Alaska State Plane,Zone 4(5004),US feet Measured depths are referenced to Glacier#1(RKB) North Reference:True north Glacier#1(RKB)to Mean Sea Level:207 feet Scale:True distance Mean Sea Level to Mud line(Facility:East Swanson River Satellites Pad'A'):0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by:jonethoh on 12/2/2009 Location Information Facility Name Grid East(USft) Grid North(USft) Latitude Longitude East Swanson River Satellites Pad'A' 1518056.130 2477782.460 60°46'49.522"N _ 150°4104.716"W Slot Local N(ft) Local E(ft) Grid East(USft) Grid North(USft) Latitude Longitude Sunrise Lake#2 0.00 0.00 1518056.130 2477782.460 60°46'49.522"N 150°41'04.716"W Comment As-Built Survey provided by W Tank 30-Nov-09&CORRECTED 2-Dec-09 Glacier#1 (RKB)to Mud line(Facility: East Swanson River Satellites Pad'A') _ 207ft Mean Sea Level to Mud line(Facility:East Swanson River Satellites Pad'A') Oft Glacier#1 (RKB)to Mean Sea Level 207ft Well Data Slot Well Wellbore Wellpath Sunrise Lake#2 Sunrise Lake#2 Sunrise Lake#2 Sunrise Lake#2 Version#4 Sunrise Lake#2 Sunrise Lake#2 Sunrise Lake#2RD Sunrise Lake#2RD Version#2 Tie-On Position MD(ft) Inc(°) _ Az(°) TVD(ft) Local N(ft) Local E(ft) Grid East(sry ft) Grid North(sry ft) Latitude Longitude 3400.00 0.000 29.962 3400.00 0.00 0.00 1518056.13 2477782.46 60°46'49.522"N 150°41'04.716"W Well Profile Data Design Comment MD(ft) Inc(°) Az(°) TVD(ft) Local N(ft) Local E(ft) DLS(°/100ft) VS(ft) RKB: 207' 0.00 0.000 29.962 0.00 0.00 0.00 0.00 0.00 Tie On/KOP 3400.00 0.000 29.962 3400.00 0.00 0.00 0.00 0.00 End of Build 4988.64 47.659 29.962 4811.67 540.17 311.39 3.00 623.49 Begin Angle Drop 7080.06 47.659 29.962 6220.33 1879.44 1083.45 0.00 2169.37 Tyonek Tgt/End of Drop 8668.69 0.000 29.962 7632.00 2419.61 1394.84 3.00 2792.86 TD 13532.69 0.000 209.962 12496.00 2419.61 1394.84 0.00 2792.86 Hole and Casing Sections Start End Start End Start Start End End Name MD(ft) MD(ft) Interval(ft) TVD(ft) TVD(ft) Local N(ft) Local E(ft) Local N(ft) Local E(ft) Wellbore 13 1/2"Open Hole 0.00 3000.00 3000.00 0.00 3000.00 0.00 0.00 0.00 0.00 Sunrise Lake#2 10 3/4"Casing Surface 0.00 3000.00 3000.00 0.00 3000.00 0.00 0.00 0.00 0.00 Sunrise Lake#2 9 7/8"Open Hole 3000.00 3400.00 400.00 3000.00 3400.00 0.00 , 0.00 0.00 0.00 Sunrise Lake#2 9 7/8"Open Hole 3400.00 8468.33 5068.33 3400.00 7432.00 0.00 0.00 , 2410.51 1389.60 Sunrise Lake#2RD 7 5/8"Casing Intermediate 0.00 8468.33 8468.33 0.00 7432.00 0.00 0.00 2410.51 1389.60 Sunrise Lake#2RD 6 3/4"Open Hole 8468.33 13532.69 5064.37 7432.00 12496.00 2410.51 , 1389.60 2419.61 1394.84 Sunrise Lake#2RD 4 1/2"Casing Production 0.00 13532.69 13532.69 0.00 12496.00 0.00 0.00 2419.61 1394.84 Sunrise Lake#2RD Targets Name MD(ft) TVD(ft) Local N(ft) Local E(ft) Grid East(USft) Grid North(USft) Latitude Longitude Sunrise#2RD Tyonek Tgt(NAD83)Revised 30-Nov-09 8668.69 7632.00 2419.61 1394.84 1519476.01 2480187.18 60°47'13.349"N 150°40'36.617"W Sunrise#2RD TD Tgt(NAD83)30-Nov-09 13532.69 12496.00 2419.61 1394.84 1519476.01 2480187.18 60°47'13.349"N 150°40'36.617'W Bottom Hole Location MD(ft) Inc(°) Az(°) ND(ft) Local N(ft) Local E(ft) Grid East(sry ft) Grid North(sry ft) Latitude Longitude 13532.69 0.000 209.962 12496.00 2419.61 1394.84 1519476.01 2480187.18 60°47'13.349"N 150°40'36.617"W MARATHON Oil Company VA Location: Cook Inlet,Alaska(Kenai Penninsula) Slot. Sunrise Lake 42 BAKER MARATHON Field: Sunrise Lake Unit(NAD83) Well Sunrise Lake#2 HUGHES N Facility: East Swanson River Satellites Pad'A' Wellbore: Sunrise Lake#2RD Plot reference wellpath is Sunrise Lake#2RD Version#2 True vertical depths are referenced to Glacier#1(RKB) Grid System:NAD83/TM Alaska State Plane,Zone 4(5004),US feet Measured depths are referenced to Glacier#1(RKB) North Reference:True north Glacier#1(RKB)to Mean Sea Level:207 feet Scale:True distance Mean Sea Level to Mud line(Facility:East Swanson River Satellites Pad'A'):0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by:jonethoh on 12/2/2009 $Cale 1 inch 400 N Easting(ft) -200 0 200 400 600 800 1000 1200 1400 1600 1 1 1 1 1 1 1 1 1 1 Sunrise#2R0 TD Tgt(NAD83)30-Nov-09 Sunrise Lake#2RD — 2600 Sunrise#2RD Tyonek Tgt(NAD83)Revised 30-Nov-09 4 1/2"Casing Production 7 5/8"Casing Intermediate Tyonek Tgt/End of Prop ➢P TD — 2400 Belgua ▪ 2200 — 2000 Begin Angle Drop — 1800 2 P,3000— . , 10.351h Casing'Swat= — 1600 0.60 Tie On/KOP 9.60° 4000— 18.60° 3.00°/100ft 27.60° — 1400 36.60° Z 45.64°End of Build a 5000— — 1200 uet 6000— 47.66° Begin Angle Drop — 1000 38.06° Beluga - 29.06°° Belgua a° 9 - 7000— 20.06°' eL 11.061,V. 7 5/8"Casing — 800 a> Intermediate �c O Sunri #2RD 2.06° Tyonek Tgt/End of Drop Co Tgt(NAD83)Revised 30-Nov-09 8000— Beluga N — 600 u) End of Build H 9000— - 400 cn 10000— 0.00°/100ft — 200 11000— Tie On/KOP — 0 Sunrise Lake#2 RKB: 207' 12000— —-200 Sunrise#2RD TD TD Tgt(NAD83)30-Nov-09 4 1/2"Casing Production 13000 Sunrise Lake#2RD 1 1 1 1 1 1 0 1000 2000 3000 4000 5000 Vertical Section(ft) Azimuth 29.96°with reference 0.00 N,0.00 E l - - 4 m I f � 1 1 .0 O C O > E E 'd0 O O O E E C O N,'-c? 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F W QFQ C+ CJ ° o C 3 Q x - 0 �n o o oa H Q A Co) °o °o o° M W; ° o ° ,. o x x o o A > O 0 000 U v)' Q °: x F 0 0 .0 x a N ° N aA c°, °o °vv o?S s U O O U W • r• °�W; . ., W 2 ° . i;-1 0 ° v c7 > a W; Q °� O C o 00 00 t� v� Q E cu a w ry 8'IAGtiR ;' a Y.r��tl ' -f 4 Tnk ' rd.� — 1 III I LING d C II III III - �� III I ��$-T—� .._ _ID S�� � III k g I IHIIIIiNli��r yr, ,(4\MARATHONJ t- a PP1111 M11 �/il• II III �IIIIII� 1iVii;l• Sunrise I ,ake #2 4,;:: 1 Prepared by: Jim Dwyer _,, ,,'-',- ,, Senior Project Engineer M-I SWACO Reviewed by: Dallas Rhodes/Hal Martens M-I SWACO Presented to: Will Tank Drilling Engineer Marathon 7 I `u SIN II IIII,I Marathon Oil Company PO Box 1 90168 Anchorage, Alaska 99519 ATTN: Will Tank Will: Enclosed is the drilling fluid program for the Sunrise Lake#2 Well. The following is a brief synopsis of the program. Overview: Sunrise Lake#2 is a well targeting the Beluga and Tyonek formations at the Swanson River field. A Gel/Gelex spud mud is recommended for the surface interval. Flo-Pro fluids will be used for both the vertical and directional intermediate and production intervals. After logging the production interval, the well will be completed with 4-1/2"liner cemented in place. Surface Interval: A standard fresh water Gel/Gelex spud mud will be used. Initial funnel viscosity should be in the 50 —75 sec/qt range. Lower funnel viscosity to 45 — 60 sec/qt after gravel has been drilled. Lower fluid loss to 10 - 12 cc's API prior to running surface casing. Intermediate and plug back kickoff Interval: This interval will be drilled with a Flo-Pro fluid. New fluid will be built for this hole after drilling out surface casing. Fluid loss should be maintained @ 5 - 7 cc's API for this interval. Lubricant should be added early as a preventative measure with a minimum of 2% LoTorq since the angle is minimal in the initial section. Fluid should be considered for reconditioning and reuse for the kick off plug at 3400'. Production Interval: After running 7 5/8" casing at approximately 8469', 6.75"hole will be drilled with new FloPro mud. z„ Fluid from previous section can be tested for possible reuse but if already reconditioned and reused ' t then new FloPro is recommended for this section. Completion: The completion will consist of a 4-1/2"liner cemented in place. Corrosion control (Conqor 303) will be added to the 6%KCl brine. Jim Dwyer Senior Project Engineer/M-I SWACO fi NOTE: This program is provided as a guide only. Well conditions will always dictate fluid properties required. Mi SWACC . EXECUTIVE SUMMARY A Our goal is zero spills and zero incidents and 100% compliance while providing fluids and solids control opy services to Marathon Oil Company. MI SWACC7 The Centrifuge unit will continue to assist in removal of LGS for minimizing mud weight and dumping and dilution of fluids. Disposal costs at G & I facility will be reduced with the use of the centrifuge unit. MI SWACO We expect to drill this well for a product cost of less than $22.68 per foot with no serious losses or unexpected pressures. �1k We estimate the use of less than 8400 barrels to drill "' °°-,:IFE this well, not withstanding any losses to the formation and reuse of fluid in directional 9 7/8" hole. a �h E I i i MI swac., Section 1 - Objectives I Benchmarks / Goals Goal / Objective Achieve Health, Safety and Environmental Goals Benchmark No Accidents, No harm to people, No damage to environment Performance Days away from work, medical treatments, fluids discharge, spills Measure Goal / Objective No NPT on well Benchmark No NPT due to mud properties out of specification. Performance Daily review of mud properties with mud engineer and project Measure engineer Goal / Objective Minimal losses to formation Benchmark Control and/or minimize seepage losses in under pressured sands. Performance Verify losses per hole section on well with OneTrax Measure Goal / Objective No NPT on well P Benchmark No hole cleaning issues upon following the program and/or rig site k, mud engineers recommendations. Performance Monitor NPT on daily Marathon reports Measure 1'1411444,1, '11fiiiirk.,1,11,1,,,tt'''''VA140,11!"ill: 11, 1)1''?I'AI4'101'04,04*.W41111'1111 r1,39',11 '41,44,04,4i„,,"14,001010 Lih,„ 11,10„1„11, 5:„.„ MHSWAC• Section 2 - Well Design Well Schematic Casing Hole Casing Depth TVD Mud Mud Weight Cost Sum Size Size Program (MD-SS) (TVD-SS) System (PPM ($) Days (in) (in) (ft) (ft) Conductor 100' 3000' 3000' GEL SPUD 8.7—9.2 5 10.75" 13.5" k '?° 9734' 9607' Plug 9.875" FLOPRO 8.9—9.5 8 xo; back 3400' w/3%KCL (PB) 7.625" 9.875" 8469' 7432' FLOPRO 9.2 9.6 7 ^' ' w/3%KCL 4 1/2" 6.75" L 13,533' 12,496 FLOPRO 9.2—9.7 7 w/3%KCL t 3%KCL 3 Comp Cost does include engineering charges FORMATION ESTIMATED PORE PRESSURES Est. Pore Pressure Formation MD (ft) TVD (ft) (ppg) Sunrise Lake 2 (vertical) Beluga 6906' _ 6782' 8.6 Tyonek 7834' 7707' 8.6 TD 9734' 9607' 8.6 Sunrise Lake 2 (directional) Beluga 7816' 6807' 8.6 Tyonek 8669' 7632 8.6 TD 13,533' 12,496' 8.6 "» i . NV 6Vg,%10.-- Section 2 — Well Design EMS Mud Cuttings and Mud Target Goals (bbls) Performance 13.5" OH 9.875" OH .875” 8.75" OH Benchmark Kickoff Section lc _ Section _ Section Section Length 3000 6734 5069 5064 Cuttings Discharges** 531 638 480 224 Mud*** Discharges 2125 1914 1441 448 Mud + Cuttings Discharges 2656 2552 1921 672 EMS Mud Cuttings and Mud Target Goals (bbls/ft.) Performance 13.5" OH 8,.875,, OH 9.875" 6.75" OH Section Benchmark Section Section \,‘ Kickoff \ s\ Section Length 3000 6734 5069 5064 Cuttings Discharges .177 .094 .094 .044 Mud Discharges .708 .284 .284 .088 Mud + Cuttings Discharges .885 .378 .378 117 *), Gauge hole cuttings ' Includes mud on cuttings rh1111111 11 11,11 I 111111111 11 Section 3 - Challenges Potential Problems Discussion / Recommendations COMMUNICATION — The Field Mud Engineer will communicate daily with the Project Engineer. The Project Engineer will then communicate daily with the rig Drilling Engineer. Communications should be about, but not limited to, fluid properties, hole difficulties, ossible changes to the mud p 9 program, and proposals to use products not included in the mud program. WHOLE MUD LOSSES TO THE FORMATION — Refer to LCM flowcharts in appendix for maintaining proper bridging material concentration in the mud system while drilling the intermediate and production intervals. FLUID LOSS CONTROL — In the production interval the API fluid will be maintained in the range of 4 — 6 cc's at all times. In addition to sufficient fluid loss agent additions, this may require adequate dilution of the mud system in order to keep reactive drill solids to a minimum. LSRV — When drilling with a FloPro fluid, the low shear rate rheology should be maintained around 30 — 40,000 cps. In addition to adequate additions of FloVis Plus, this will also require keeping reactive drill solids to a minimum in order to reduce or eliminate false and unwanted high LSRV. DRILL SOLIDS — MBT — The MBT should be kept at less than 5 ppb in the production interval , through aggressive use of solids equipment and dilution as needed. MIXING CONDITIONS — Whenever possible all treatments to the mud system should be made as pre-mix additions. Polymers and KCI should first be mixed in fresh water in that order and then blended into the active system over one or two circulations as needed. CORROSION — Conqor 404 additions should be made daily when drilling with FloPro fluid in order to maintain a Conqor 404 concentration of+/- 2000 PPM. CORROSION - Sodium Meta Bisulfate additions should be made daily as needed with any fluid in the hole. Maintain a DO reading of less than 3 ppm MYACIDE 25G ADDITIONS — Myacide 25G additions should be made daily when drilling in the production interval, in the range of 5 gallons per day. CENTRIFUGE UNIT — The centrifuge unit should be used whenever drill solids become un- acceptably high and reduction of drill solids in the mud can be more economically done with centrifuging and dilution then just with dumping and diluting. The weight of the drilling fluid alone should not be the determining condition for when to use the centrifuge. KCL CONCENTRATION— KCL will be maintained at 3% (11 ppb) as testing with K+ strips has shown this to be just as effective for inhibition as 6%. 3% KCL will also be used for the completion fluid. 4 MI SWACR :,-. Section 3 — Challenges/ Potential Problems Hole Cleaning Recommendations ❑ Low-shear rate viscosity"LSRV" values (6 and 3 rpm) has a greater impact on hole cleaning than yield point, in addition to providing barite suspension under dynamic as well as static conditions. Optimize rheology to increase hole cleaning efficiency of fluid (Adjustment of Yield Point and 6 rpm readings). ❑ Rheology and Hydraulics calculations will be run daily and the mud properties will be adjusted as needed to maximize hole cleaning. ❑ Use the highest possible annular velocity to maintain good hole cleaning. Annular velocity provides the upward impact force necessary for good cuttings transport. ❑ Control drill to manage difficult hole cleaning situations. Penetration rates determine the annular cuttings load. Use the PWD data (if available) to determine when it is necessary to stop drilling and circulate the hole. ❑ Keep cuttings concentration less than 5% (by volume) in order to minimize drilling problems. ❑ Sweep Recommendations: ❑ Don't recommend the use of sweeps unless hole conditions dictate the necessity. ❑ Hi- Vis sweeps are recommended to use if needed. The volume should be enough to cover at least 200-300 annular volume of the open hole. The recommended rheology of the sweep would have the Yield Point in the 35-40 range and the 6 RPM readings in the 15-20 range. ❑ Weighted sweeps are another option, but Hi-Vis sweeps are preferred. ❑ The need to pump LCM sweeps will be dictated by hole conditions. Bit/BHA Balling Recommendations ❑ The young clay formations can absorb high volumes of water and can be extremely sticky and problematic regardless of the degree of inhibition. ❑ The drilling rate should be controlled to keep the concentration of cuttings in the annulus below 5%. ❑ Short trips should be made as necessary to minimize buildup of cuttings in areas of hole washout. ❑ During trips, the BHA can accumulate cuttings that will potentially ball it. Recommend circulating for a short period to circulate up any formation that may have adhered to the BHA or bit during the trip. ) 3- I' �l 1 , 'hr�p� * m � s G� 0111 1 IpP1 1 101G1G1 I111G11 ...4*, Section 4— Lessons Learned & Offset Mud Data ; Offset well #1: Forest Oil Sunrise Lake 1 ;01#4.11i ,. . 1.r. Depth of Mud Wt. Hole Size Description of Information concerning the Event or Problem Event/ (ppg) Event Problem 2550 10.4 17.5" Casing parted Viscosity 67 sec. Lay down casing and condition hole before rerunning casing 9093' 9.6 9.875 Logging Viscosity 43. Continue drilling after logs 13,888 9.7 9.875 Logging Viscosity 66. Ran Sonic, Density, Dipmeter, SNP logs 14,500 9.7 9.875 TD/Logging Viscosity 87. Plug back well to 12,213 11,978 9.7 9.875 Run 5.5"casing Perforate and test xw, r,I. n11 1I �� f r I o gI l:0l u m n I „ I � 1 Al 504 � x F,y 0 W '4 y 4 P AR IN , J - tl I r 1 P ;l 1i 1 + I1 1 11ili i 1 1p1 l � V " { 1Po1G k 5 w fi X ir i> I' �w; Ri V 1 1+ G 01 0I P ry �f' -M.a V t + v 0 44'1 '1 Irk 10 4 l Iuu r,i ll I Bilker r f ' !: 1 a;0 4i���I411uI�G1�4� - sa"y3 a r� Mi SWAG,. Section 5 — Surface Interval (0' — 3000') Depth Interval 3000' MD (3000' TVD) (13.5" OH, 10.75" Casing) Drilling Fluid System Spud Mud Key Products MI GEL, Gelex, Caustic Solids Control Mongoose shakers, desilter, centrifuge Potential Problems Hole Cleaning, Hole Stability INTERVAL MUD PROPERTIES wirtel tit Vi k a dd - :I. t S °a (ft) (ppq) ( p) 1/3 ih'3in) (S rigt ) al 3000 8.7 -9.2 15-24 >30 <18 60 - 100 8.0 - 9.0 < 6 ➢ Treat drill water with Soda Ash to reduce hardness. ➢ Build spud mud with 20— 25 PPB M-I Gel to +/- 100 sec/qt funnel viscosity. ➢ Lower funnel viscosity to +/- 60 after gravel zone has been drilled. ➢ Add Gelex as needed to maintain sufficient viscosity for hole cleaning. ➢ Increase funnel viscosity if fill on connections begins to occur. ➢ Reduce fluid loss with additions of Polypac Supreme UL prior to running surface casing. ➢ Add 2 —5 PPB of MIX II to mud system if seepage losses become a problem. ➢ Condition mud prior to cementing casing to reduce yield point and gel strengths. 4i FI — e Mi SWAC Hydraulics / Hole Cleaning: Virtual Hydraulics Graphs The following graphs look at the ECD + cuttings at 3000' casing shoe and moving cuttings concentration (MCC) in the annulus while drilling the section. VH SNAPSHOT Mt SWAGO 9952008 M4LLC Surface 750 GPM MD.3000 Operator; M2 'MBA o,u i�I NO:3000 ft Well Marne:Suur ise Lake Bits ze:13.5 In laratlm Kenai Peninsula VIRTUALHVIRAUUCS' Sna Shot" Doe 11/76/2409__ � �. Alaska Degh Geometry Derv' Va Hde Clean Pre tre Distrlhtlan () NDlND CegOD11D (Iligl (Nmir� Iola (/e) 00 4n) 0 45 80 8.8 92 5fi 10.0 0 900 240 VG G F P Bit=14.3 Am=41 DS=81.6 q 100 0.000 G00 100 0.000 — .._. .— • _..1 m -'_400 600 • __.__._ eoo atoe.BgRuid .. = L— - WakrEased MuO 4 MumekJ4 9 93,0 1000 - 1 • TestTemP 90 'F FFF"' I. ... —r Syslem Dale tz00 , _+ Flay Rafe 750 galhn In ,co!i Penetration Rafe 150 Rh, ---__ —t Rotary Speed 100 rpm ol.. ,Onu weight.Bit 15 1000 IN a -- • - — - Sit 1.5 In noo ..— ■I - Promise Loom Mig Prover law 1 II 2000 I -- DrIIlStlry 1185 MwD xo r..1. 2200 ? Malor 250 Bit 29s F. 2400 £� Bit ONOO 100 iw .—_.. �.— Am4us 00 pe Surface Egip 49 ps j U-Tills Effect .4960100 8 p5 2800 EOM ��� Total Sysfam 2250 ps 2800 _ ESD ECD +Cut ae �II �■� ! CsgShce 9.06 9.19 9.50 3000 3000 13.500 TD 9.05 9.43 9.74 3000 LSD o HA I n JS • ETD :. 0,:u nlon y Ls� _ � _. lll l lM l �_ p ��l l�l tl i ' Ill - l l II 7,44-7-47.47t,--,,,Wh 117,ul ' N' !plx — ,,a 1, g Yom s J 1 r k 416 - 1 ,„ �- � f l0 :117,173401001',,; 1 4 0.O3'ti. £ Jl MI SWA4C I I II, „I III lal 0 'I gull I IIIII',IIhVI,r r• 1 II o I VH HOLE CLEANING ivia c�A=Af� f ©,"5-006Ma LAC. Suhce 7W GPM MD:3000 R Operator: Marathon -�� '^�•�`°n Ma�.i.c. 71/D:3000 R Well Name:Sur Ise Lake 2 VIR1DALHIDRAIJUOS VRDR' ats ize•13.5 In Laalon: Kenai PeNreWa j * _— Da�._71(2512109 _Counly_ Alaska — -_ Hole Cleaning I, Marathon Sunrise Lake 2 I 1.00 !” — ROP Su I0i -,. — ROP100Pohr ROP15011/hr Poor Hole Cleaning I 1. 0.75 x v c I a :- leaning .-._.. f. CI - ., C _._ -' '.___-_. 1 -_- -j_- .. m 0.50 o __._ GogoHok�lean g l- 0.25 --- 1 Very Good Hole Cleaning 0 400 500 600 700 800 Flow Rate(gal/min) P' I' I 'i Mi SWAC =t' Section 5 — Intermediate Interval (3000 - 9734') Depth Interval 9734' MD (9607' TVD) (9.875" OH, Plug back to 3400') Drilling Fluid System FLOPRO Flo-Vis / PolyPac UL/ KCI / SafeCarb F & M /Asphasol Supreme/ Key Products LoTorq / Caustic Soda /Conqor 404/Sodium Meta Bisulfate / Klagard fi Solids Control Mongoose shakers, desilter, centrifuge Potential Problems Hole Cleaning, Hole Stability, Seepage losses INTERVAL MUD PROPERTIES Depth Plastic Yield i TVD Mud Wt. Viscosity Point Fluid Loss LSRV = tB (ft) (ppg) (cp) (lb/100ft'') (rn113O titt) 1 min Cp ph 9734' 8.9 -9.5 10 - 16 12 - 18 5 - 7 30-40000 9- 9.5 < 6 Use one rig pit for drilling out surface casing. In other rig pits, build new Ho-Pro fluid. NOTE: LoTorq additions at 2% minimum will be made after mud is sheared down so no losses over shakers. LoTorq can be increased though hole section if necessary by torque readings. ➢ If running coals become a problem, treat with a 2-4 PPB addition of Asphasol Supreme. r Mi SWAC ,; `_ > - :40I I! 11v111111101l1 l wr re-Y' {p1$I'1 I Ipi �I llr I VI l r r- 1 1IIj111r1ili I111q iq�ll u 1111111' i1llll11111 I II III '� 1 11,1 h I itq!�^ - �.�`� � d t {y1� '9&1 Hydraulics / Hole Cleaning: " -fie i Virtual Hydraulics Graphs •The following graphs look at the ECD + cuttings at 9734' and moving cuttipcs concentration (MCC) in the annulus while drilling the section. {��Iw"lll�lll IV II II166"y.µit 1se� s, -'� 1, dy WliIIl11,III,1i I Ih44 r sf VH SNAPSHOT 7 Nei ©19952008MILLC. -- - 92 pp9�550 GPM --- MD:9736 R Operator: S.ese •N.h of ul 1 c. ND:9734 R Well Name:Surip lake 2 V IRNAL IIIDRAUUCSa Snapshot* Bit Size:9.875 in tncatlnn Karel Pa insua Dam'17Q!V2508 Couary Alaska Delft Geanetry Dersi Va Hde Clear PressIreDlsrIFell l (Iq NDJ1VD CsgOD110 P) Pd� (mm6 Ir1� (1 M pt) (in) 0 45 90 9.2 9.6 10.0 0 300 600 VS G F P sit_ Ann=18.9 DS=90.5 __ 000 2000 _ __ kr DrIR• Rdd -,,,,:x.,:',...'4:: 3000 3000 _ 10.750 8UT 'F� MudWel 9.2 RJ I 000 4000 Sysbn Data li - _. ._ Flaw Rafe 550 ge0m in Yr L. \\\ PereSe8un Rasa 80 ltltr l 5000 \ Rotary Speed 100 rpm n'. Weigh onset 20 1000 N11 741 Weigh zles 13-13-13-13-13 �I[ 1...6000 E __. 13.0.0-0-8 • Pdified eaasses - Modified Pover law - a 7000 • / ) Drill S erg 424 psi - ,.. MWD 350 psi Motes 250 psi . 8000 Bit 425 psi . I - -. !-- BitONOff 100 psi '� AmWas 198 psi 9000 Saface Egip 23 ial 0. - _ D Tube Effect 65 psi TTW Syakm 1834 psi s]34 9.875 ESD ECD +Cut 0. E. 10000 9607 Cog Shoe 914 8.66 9.78 m 9.21 0.64 9.77 - 1 11000 E^><O I.. �tlt 77 m e ®! o•.t• al af101z0031 . Hr. 11 1 lillll 1�1 IIIYII�I���r� y ,4 I 41 III NuII I001!14:111,t z's: — rk 1 e I '�, �^. I, a a''.�1 1 uIlk111i 1°YI 4: � - !f ,� ye r I C � � .sue :::;=lgkf7kY::LrZ7(,;Ttf:'';;?T5:2171-r-:2'F i u �>t r — it `aX h Il 11111 li�iyll Ih Y7 111 1 11111 p 1111 l 1 1 II 44" ", i 1 s . r'i"4t u . a_� I k 1d "R , ' a 9b 6 h .MA r✓'d �� 1St Mi SWAG. VH HOLE CLEANING Iv". ©1995-2008MJLLC. 9.2pta 0550 GPM MD:9734 R Operator Mar atlia1 •�1A/ps"_R9 "` ,�.rx ern. �x ND:9807 R Well N S i Lakn 2 VI RIVAL NVDRAOUCS* YNDN' Be Date:9.875 Locate K r P iireula Date 111252009 Hole Cleaning 1 00 Marathon Sunrise Lake 2 — ROP90tVhr - ROP120'— I Poor Hole Cleaning m o) .._.��___r____ Fair Hole Cleaning ,---_ j..—'--._—__`-- .. 0.50 ■ m U _. d o Good Hole Cleaning 0.25 . — Very Good Hole Cleaning 0 400 500 600 700 Flow Rate(gal/mini 6 iilli Ii i I E Mi SWACW Section 5 — Dir. Intermediate Interval (3400 - 8469') Depth Interval 8469' MD (7432' TVD) (9.875" OH, 7.625" Casing) Drilling Fluid System FLOPRO Flo-Vis/ PolyPac UL/ KCI / SafeCarb F & M /Asphasol Supreme/ Key Products LoTorq / Caustic Soda / Conqor 404 I Sodium Meta Bisulfate I ti Klagard Solids Control Mongoose shakers, desilter, centrifuge Potential Problems Hole Cleaning, Hole Stability, Seepage losses INTERVAL MUD PROPERTIES Depth , i,u�r '� f x, qh1 or VI II II pIIII IIIVIIIII uIp Nlllllp 11 II fIII 4IMrl j'""�,I�Pq IW lu m V4111 t epth P ' � I APl VIIIIIIIII ull rrl TVL1d 4tVt. Vt �II �l Fluid Loss tSR n I�lil� II �� LOS (ft) (p1 9) c ) (ibl1OOft } (m0--111 i r) 1 rein pH °lr 8469' 9.0-9.5 10 - 16 12 - 18 5 - 7 30 -40000 9- 9.5 < 6 D Pretreat Flo-Pro fluid for cement contamination for drilling kickoff plug. Check mud properties from previous section and discuss whether to recondition fluid or build new FloPro for next hole section. D If running coals become a problem, treat with a 2-4 PPB addition of Asphasol Supreme. D Periodic additions of LoTorq will be needed to maintain 3% minimal concentration. Y D Condition mud prior to running 7 5/8" casing. - fir 4;4 Syr Iv,uN rry I '� ` ��. �'�a9 r�9t aurh PplV�jIV 11INIYI I p' R'� hr g5r!u Mi SWAG Hydraulics / Hole Cleaning: Virtual Hydraulics Graphs The following graphs look at the ECD + cuttings at 8469' and moving cuttings concentration (MCC) in the annulus while drilling the section. VH SNAPSHOT 1 CHI VA0= \ ©l995-2009M4LLC. 9.2 ppg @550 GPM -- MD:8469 P Operator: Marathon �. luerx orra lLL ND:7432 8 Well Nam e:S unr ise take .. Y1R1IALII'mRAIJUCS' Snapshot* BXSIze:9.875 m Location Kona.Peiinstda Dept1 Ar�BD� Dab.11)25/2009 Canty. Alaska Ah MD/1VD Gec"'"Dsg OD1D t) ) lamed Hdi t+rtssre utso-tl11lia1 P1) 00 tin) 0 45 90 9.2 9.6 10.0 0 300 600 yG 0 F P Bit=43.7 Ann=1]2 DS=39.1 500 tl.p 1000 ■I•■r II__— 1600 II 2000. -.,__---- 4 Dri8kq Fhid FLOPRO NT 2500. _^.-__ Mod W eight 9.2 117/gal Test Temp 80 °F 3 3000 _ 10.750 ,,, � ,.,5, ----_— I Sy5lern Data 3500 Flow Rate 550 ga6m in — Penetration Rate 80 161. a1 — r Rotary Speed 100 rpm WeigMmBit 20 10001kt 04500 -__—_. �_ --._.— Bit Nozzles 13.13-13-13.13 5000 5500 Modified eL taw -- Drill Str ing 380 psi F i 6000 ■■■ MWD 350 psi ■I. Molar 250 psi 1 BR 4.25 psi k' 8500 BitOAGO 100 psi ]000 3III ilI■■■ U-Tome 167 psi t _._-- __ ___ r Svtace Equp 23 psi U-Tale Effect 48 psi III ■I■■■ Total System 1743 psi III 500 6000. // ESD ECD .Cut r 4' -L�' f CSg Shoe 9.24 9.67 9.79 ff(.8500 80469 --- 9.875 F. \ ■--- -- ( 1- TD 9.25 9.69 981 t 0452 Elm F'i •i q'.. - .n on . e Izoozl !!!! 9000. —d^`ty � 1�F F e Sonn..L.x.z.M Oeono - 1 k a i I S t 8 Mi SWAG• ,. VH HOLE CLEANING ,I --- ®19952008 MJ L LC.L c 9.3 ppg 0550 GPM NDD::8749 2- --_— t WO¢IpNm e: a*irt a ka2 ; VIRTUAL IIIIJRAUIICS8 VRDR" BITS :9.875 Locaton. Komi PaNroJa Dale:-11092009 - _ Ca.try Alaska ;t Hole Cleaning Marathon Sunrise Lake 2 ", 1.00 _ 3 t - ROPoO ft4u ---- - ROP901Ghr - R OO 12+',p** Poor Hole Cleaning — :OP150Rfir _ 8 ` 0.75 ----- d v e Fair Hole Cleaning "` __" _ � c• 0.50 _..____ U Good Hole Cleaning 0.251-- - ---_—__ 7 i Very Good Hole Cleaning 400 500 600 700 Flow Rate(qal/min) u 1 l E k s Section 5 — Production Interval (8469 - 13533') Depth Interval 13,533' MD (12,496' TVD) (6.75" OH, 4.5" Casing) Drilling Fluid System FLOPRO 1 Key Products LoTorq / Caustic Soda/ Conqor 404/Sodium Meta Bisulfate / Klagard/ SteelLube EP Solids Control Mongoose shakers, desilter, centrifuge Potential Problems Hole Cleaning, Hole Stability, Seepage losses INTERVAL MUD PROPERTIES TVD Mud Wt Viscosity Point Fluid Loss LSRV LGS , > If FloPro was reconditioned from initial vertical 9.875 interval for drilling previous hole oeoUon, build new Flo-Pro fluid for this hole section. > If running coals become a problem, treat with a 2-4 PPB addition of Asphasol Supreme. )=. Periodic additions of LoTorq will be needed to maintain 3% minimal concentration. • Have SteelLube EP available for metal to metal torque issues. 1% use if needed. > Condition mud prior to running 4-1/2" casing. II Mi SWAG_ . Hydraulics / Hole Cleaning: 3 af3 ki. Virtual Hydraulics Graphs The following graphs look at the ECD + cutting s at 13,533' and moving cuttings concentration (MCC) in the annulus while drilling the section. VH SNAPSHOT � � wr•sa t LIllit '' �V�R,Mi ©19952006 M1 LL.C. 9.8 ppp�350 GPM MD.13533 R Operator: MarvOtm n, p� �tr ND:12696 ft Welt Nam e•::01 se Lake2 YIIL �INV�Y�7* Sni°pSh�*� BOS9D:175 ,n LacaBm Periroda ■ n�YNN n�Y�INV YYP l Dah 11(252009 Gantry AWka Geanetry aa�a Va HdeCleal Prtast►e Distridtlm 1 uo7ND Cseoaro f) p (gmfr) Iryb Pr.) 0.1 (In) 0 /5 90 9.1 9.6 10.5 11.2 0 300 600 VG G F P Bit=11.3 Am=36 08=52.6 t 000 .'L.II,. ■„ ' I _ _ ■0oa E111111111111 IIIII 0000 .''..II,. ■„■® ' .. -.. ■■ — u ', a000 .'I..'i,. ■„■i ...--. ■■ MudWei¢i[ :PRO96 Idpl . NN 5000 .,'..I,. ■1111 ' TestTRIp 60 'F -_ - Sy51am Dffi .,'..I,. .,I■■ - RVS Rape 350 galhn m soon PerotraBOnRate 60 8Rr 7000 .II..I,. ■,I■ RaGry Speed 80 rpm 1-, e0o0'sazz ' ` 7,BZS / •IL.I,. ■,I� BtN @z Pressre Ltffies 0016f }- L` oao0 : ii:.I . ■I'iIU Maow :::M1 }... -.. Mato'I. I Bit 179 psi Bit 10D psi 12000 .'I. -. - ■.I -. __ Araaits 570 psi SLrkce EOP 17 psI • `_ •_-.-_- U Tea E18scl 42 psI .II. _. ■.I _ Tat13yabm 2058 pl 1300a esa3 8.750 ESD ECD aCft '. (/00s CagShas A& 10A8 10.55 ,aoo0 I TD 9.60 10.68 10.54 e`c 1 FIp9-v"ROLer Fee.Flet:eea 15000 .•. rle sunrise Lake z.m PaOao G1 141.u„'1,;33rg 1 v �f ' �I � lit-1$;!!.;#,":111111 s� 4 �'4'�11 Il ;y V 1 ; � u 'iI Mi SWAC VH HOLE CLEANING M�1SN 01sssZ00BkML.LC. 96 Py 500GPM MD:1 oPe,al6, 1eann nwxoiM i x.x ND:13533 Nes R Well Nam e'Sure ise Lake2 VIRTUAL HVDRAUUCS" YRDI SaSine 6.75 in Location: Alaska risua Date 1$1251009 Country- Alaska Ho Ca Marathon le Sunrise lenin Lake g 2 1 00 ROP50 Nhr - ROP75 Nhr Poor Hole Cleaning — ROP1001tfir 4" — ROP125Itfir 075 — •• bur _ 1 Fair Hole Cleaning m 0.50 U GoodHoleCleaning- 0.25 .-._. _. ....-----... Very Good Hole Cleaning -- 3340 360 380 400 420 440 460 480 500 520 540 560 Flow Rate(gal/min) I 1 MiSWAc" Section 6 - solids Control Equipment - ;41-,„,_,FEE:_„:_*----,4„,,t,__*----i-I:,,,,::,,---,:=7,7_,-7-1,1,1-'11_,7:„,_f__-_=:="i',___,-_=____„:1,7771_-__,„--7"--:_-_,==-"_E„,r_ Solids Removal Equipment Recommendations: The recommended SRE for this well are: Mongoose Shakers and Swaco Sohds Recommended shaker screens sizes are as follows: Interval Recommended Screen Sizes Recommend ,m y,',1 At S1Z(s (Shaker 1) (Shaker'I2) 0—3000' (Surface 165—200 mesh 165—204 mesh 3000—9734' (Intermediate) 200—230 mesh 200—230 mesh 3400—8469' (direetional 200—230 mesh 200—230 mesh 8469— 13,533' 230—275 mesh 230-275 mesh II Completion 230—275 mesh 230—275 mesh E. , Id, F, 1 ,'z .C. 3 ,li F z f E E % - - re aw F 4 } r ° 4 NNflk III K , V 4 k R� III I`+ Mi SWAL Section 7 — Summary of Cost and Product Usage 13.5 in Hole Sections (3000 ft.) Product Unit Size Units Required Total Cost M-1 Gel 50# Sx. 757 _ Caustic Soda 50 # Sx. 13 Gelex 2# Sx. 32 Polypac Supreme 50# Sx 13 CF Desco 25# Sx. 10 Soda Ash 50# Sx 13 Sodium Metabisulfite 50# Sx. 25 Total Estimated Product Cost $15,121 9.875 in Hole Section (3000 ft. -9734 ft.) Product Unit Size Units Required Total Cost M-1 WATE 50# Sx. 744 Asphasol / Resinex 50# Sx. 198 SafeCarb 50# Sx. 496 Soda Ash 50# Sx. 12 Caustic 50# Sx. 25 PolyPac UL 50# Sx. 99 FloVis 50# Sx. 149 Sodium Metabisulfite 50# Sx. 50 Ventrol 401 5 gal 124 Defoam X 5 gal 28 Conqor 404 55 gal 6 KlaGard 55 gal 22 LoTorq 55 gal 43 KCL 50# Sx. 545 Total Estimated Product Cost $183,822 k 1 u„ ul" , P 1 h i,i 1i ^i rya a li h i ! 5 �i it 1 nx 4 itl i lL o ,ii, Directional 9.875 in Hole Section (3400 ft. -8469 ft.) 'p `l +1li' "1ioll, l ';�i ' y" a <p„�I i ;, , i , �;e o Product I Unit Size Units Required j Total Cost M-I WATE 50# Sx. 580 Asphasol/ Resinex 50# Sx. 97 SafeCarb 50# Sx. 774 GSeal 50# Sx. _ 77 Caustic 50#Sx. _ 19 _ PolyPac UL 50#Sx. 39 .' FloVis 50# Sx. _ 77 Sodium Metabisulfite 50# Sx. 19 _ Ventrol 401 5 gal 97 Defoam X 5 gal 11 I Conqor 404 55 gal 5 KlaGard 55 gal 18 LoTorq 55 gal 53 KCL 50# Sx. 425 Total Estimated Product Cost $156,757 Directional 6.75 in Hole Section (8469 ft.-13,533 ft.) Product Unit Size Units Required Total Cost M-1 WATE 50#Sx. 573 Asphasol / Resinex 50# Sx. 98 SafeCarb 50# Sx. 115 Soda Ash 50# Sx. 11 Caustic 50# Sx. 23 PolyPac UL 50# Sx. 29 FloVis 50# Sx. 46 Sodium Metabisulfite 50# Sx. 11 SteelLube EP 55 gal 10 Defoam X 5 gal 6 Conqor 404 55 gal 5 KlaGard 55 gal 10 LoTorq 55 gal 26 KCL 50# Sx. 183 GSeal 50 # Sx. 46 Total Estimated Product Cost $86,906 ( , t 1 F Mi SWAC Section 8-- Summary of Product Cost and Engineering for P10, P50, P90 I Estimated Drilling Fluid Related Costs Engineering Depth Interval Costs Interval Cumulative (ft) Product Costs ($) Days Cost Cost (s) ($) ($) Surface $15,121 $5,400 5 $20,521 $20,521 Intermediate $183,822 $8,640 8 $192,462 $212,983 Dir. Intermediate $156,757 $7,560 7 $164,317 $377,300 Production $86,906 $7,560 7 $94,466 $471,766 Completion $8,604 $3,240 3 $11,844 $483,610 P10 P50 P90 Total Estimated Product and Engineering Cost $310,638 30 $483,610 $647,528 P10: Utilizing used fluids with no hole or other problems P50: Utilizing new fluids with no significant hole or mechanical problems P90: Utilizing new fluids with significant hole losses and /or mechanical problems. , t t t i k 1 i I h M � _ 111,11,1111,11o11111,111,111,1i4,11,1,1111111111'111'1111,11,1111 Appendix I — Lost Circulation Recommendations Lost Circulation / Seepage Action plan: ❑ Have sufficient sized LCM on rig to begin interval. ❑ Recommend hourly addition of LCM to keep a concentration in the system at all times. The addition of Calcium Carbonate (M, C), MIX II (cellulosic fiber), G-Seal (graphite)and Magma Fiber(spun calcium carbonate) can be adjusted as needed to combat losses. ❑ The particle size of the LCM is important. If the expected loss zone particulars are known, then plan to have LCM to offer a particle size distribution so the majority of the LCM has a D50 to cover 1/3 the expected pore throat size and a D90 of cover the pore throat size. The D90 material should make up 10% of the total LCM ppb pumped. L i Coordinate size and amount of LCM sweeps with company man and MWD personnel on rig. Li The majority of losses can happen when running casing, circulating to cement and while cementing. The use of Virtual Hydraulics surge calculations is recommended to establish safe casing running speeds. The use of open-float and bypass tools should be considered to help minimize surge pressures to formation. 1 pr' r `te aj ','� k rwr l 40 iiw i�'�I SCI h w kUm 4 r *: "4' «.may c '_� Appendix I —Lost Circulation Recommendations a :�„ ,, ,I` FP A The following proactive lost circulation decision tree can be modified to include any contingencies 4 that Marathon requires. The flowchart allows for planning of lost circulation material needs. l No LCM Restrictions IIrI�V „ti I $ VIIV V l�:::.,,, ml l7I II IrI ' - WIa - Losing fluid while drilling05 t I ij II .x � ,VI n* k Measure rate of loss gig% , �0:�� _ r- vi. ,--2%,?-,7044,L,',-,',:ltii5=.---2747- -3,16;li, , Seepage losses Partial losses Severe losses 5 -20 bbl/hr 20 -60 bbl/hr 60 200 bbl/hr or Total loss of returns — 4 Ate. If fault related drill across fault If fault related drill across fault If fault related drill across fault 1-1.5 times the length of the 1-1.5 times the length of the 1-1.5 times the length of the throw before treating losses throw before treating losses throw before treating losses I 1 1 Spot 45 ppb pill*: Spot 80 ppb pill: T Contact Drilling/ G-SEAL Plus 10 ppb _ No success G-SEAL 15 ppb _ No success —00. Asset Engineer M-I-X II M 15 ppb ♦ M-I-X II C 20 ppb for approval SAFE CARE 40 10 ppb M-I SEAL M 10 ppb NUTPLUG F 5 ppb 250 15 ppb / . pp NUTPLUG F 10 ppb Magma Fiber 5 ppb Magma Fiber 10 ppb Pump thru BHA Spot 80 ppb pill p Circ sub required Circ sub required G-SEAL 15 ppb M-I-X II C 20 ppb M-I SEAL M 10 ppb SAFECARB 250 15 ppb NUTPLUG F 10 ppb Magma Fiber Reg 10 ppb 1 Squeeze high-fluid-loss pill*: i FORM-A-SQUEEZE 80 ppb(2sx/bbl)in water ;' Weighted up to " desired density Pump thru BHA ( i cess i *The particle size of these products is smaller than Nut Plug M Spot plug: @, Gunk Squeeze or FORM-A-SET AK aim; t II Mi SWAC O LCM Restrictions Losing fluid while drilling I Measure rate of loss 7� / L--- Seepage losses Partial losses Severe losses 5 20 bbl/hr 20-60 bbl/hr 60—200 bbl/hr or Total loss it of returns / 1 • , If fault related drill across fault If fault related drill across fault If fault related drill across fault 1-1.5 times the length of the 1-1.5 times the length of the 1-1.5 times the length of the f throw before treating losses throw before treating losses throw before treating losses 1; 1 • F . Spot 50 ppb pill*: Spot 80 ppb pill No Contact Drilling/Asset success Circ sub required Engineer for approval SAFECARB 40 20 ppb No — SAFECARB 250 10 ppb ,uNo ► SAFECARB 40 10 ppb Il SAFECARB 500 15 ppb SAFECARB 250 15 ppb Magma Fiber Reg 5 ppb SAFECARB 500 30 ppb SAFECARB 1000 15 ppb Spot 80 ppb pill Pump thru BHA \ Magma Fiber Reg 10 ppb Circ sub required No succe„ I G-SEAL 15 ppb M-I-X H C 20 ppb No suCCess M-I SEAL M 10 ppb ,i SAFECARB 250 15 ppb NUTPLUG F 10 ppb Contact Drilling/Asset Magma Fiber Reg 10 ppb Engineer for approval • Spot 80 ppb pill y Circ sub required Squeeze high-fluid-loss pill: i G-SEAL 15 ppb M-I-X II C 20 ppb • FORM-A-SQUEEZE M-I SEAL M 10 ppb 80 ppb(2 sx/bbls)in water SAFECARB 250 15 ppb Weighted up to NUTPLUG F 10 ppb desired density Magma Fiber Reg 10 ppb Pump thru BHA 1 + sj *The particle size is smaller than Nut Plug Medium Spot plug: Gunk Squeeze or FORM-A-SET AK M SWAG e A ndix 2 — Minimum Time to Circulate u o C e Prior To POOH The BP model simply predicts the minimum flow rate required for adequate cuttings transport. No predictions are available for the rate at which cuttings are removed. Because the cuttings move more slowly than the circulating mud, it is essential that sufficient bottoms-up are circulated prior to tripping. A SINGLE BOTTOMS-UP IS NEVER ENOUGH! The minimum on bottom circulation time prior to tripping will be influenced by hole size, inclination and flow history (i.e. mud properties and flow rate). These factors will affect the height of any residual cuttings beds. Recent work by Exxon has indicated that the volume of cuttings left behind during normal drilling operations can be considerable. They recommend selection of bits/BHAs with large bypass areas to facilitate tripping out of the hole. Before tripping, monitor the shakers to ensure the cuttings return rate is reduced to an acceptable background level. The figures in the table below are guidelines based on simple slip velocity considerations and field experience: WELL INCLINATION SECTION LENGTH FACTOR RANGE 17-1/2 inch HOLE 12-1/4 inch HOLE 8-1/2 inch HOLE 0°- 10° 1.5 1.3 1.3 10°-30° 1.7 1.4 1.4 30°-60° 2.5 1.8 1.6 60°+ 3.0 2.0 1.7 Procedure 'llluiilulll p II _ 1. Effective length=Section length x section length factor. �Ih Illiulli Ilia 2. Circulation time= Effective Length x B/U Measured depth at Bit Example Since in practice not all of the section back to surface will be deviated at the same angle, the overall minimum circulation time prior to tripping should be apportioned in direct relation to the relative lengths of section at each angle. If Syr - `v1'•� JM`,_-_ zx" li Mi 13i/VAC ` Appendix 3 — HSE Issues t_ I���i��plllµ, �� Safety Recommendations for Mud System 1. The rig crew should be briefed on the makeup of the drilling fluid and its cost. Safety and care should be used when drilling with any drilling fluid. An M-I Engineer will brief rig crews about drilling fluid and basic safety procedures. 2. MINIMIZE contact with the drilling fluid; although it's non-toxic, it can irritate skin. 3. Wear personal protective equipment when you must work with the mud. Proper equipment includes: a. Safety glasses or goggles b. Hard hat c. Steel toed boots or shoes (recommend rubber for shaker and drill crew) d. Protective clothing (disposable suits or slicker suits) nPI,VMIq�'i,ll�l^ry e. Barrier cream f. Rubber gloves Note: As always, follow the rig and operators safety rules. 4. If you get mud on your skin, wash it off as soon as possible. Do not allow mud to stay in contact with your skin for longer than 30-40 minutes. Do not wash with rig soap! Use GOJO mechanics degreaser or other similar type product. 5. If clothing becomes saturated with drilling fluid, then change your clothes. Do not continue to work in clothes saturated with mud. 6. Designate one rig washing machine for muddy clothes. Do not wash other clothes in this ' machine. 7. Protective Equipment that has worked well on other jobs: a. Disposable suites: TYVEK BRAND b. Rubber boots: GOODALL BRAND POLY GRIP BOOTS MODEL#A1541 c. Coverall pants: GOODALL ARMOR LITE OVERALL, MODEL#C2522 D. Coverall Jacket: GOODALL ARMOR LITE JACKET, MODEL#C2520 8. Common sense when II working with drilling fluid will prevent any safety problems. If you get drilling fluid on you, wash it off. If you have to work with or around the mud, wear your protective equipment. Watch your step and clean up any spills. h'il Ma Appendix 4 — Recommended Drilling Practices ~ - A. Operational Procedures: 1. Stage into open hole several increments breaking circulation each time and circulating for a period of time to get the fluid moving 2. Idle pumps when beginning ci | i 3. Work pipe and rotate while circulating to hn|p break up gel strengths 4. Look for signs of barite sag when staging in the hole. Light mud near could be indicative of a sag problem. If sag is a prob|enn, the depth increment for staging might have to be shortened to prevent lost circulation problems. Deviated holes will have a tendency to aggravate barite sag problems. 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N N N N N N CO M CO M CO CO CC O Q IL LL () 6 O o (n LL W TRANSMITTAL LETTER CHECKLIST WELL NAME csG//V.e%S6" �,9,CE' o�•�p PTD# o?C .AS"'9 / War Development Service ✓ Exploratory Stratigraphic Test Non-Conventional Well FIELD: e`,l'/'LD/ ',474 '/ POOL: �y,C,i1/Oi✓A/ Circle Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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