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210-047
• • Guhl, Meredith D (DOA) From: Lemke, Sandra D <Sandra.D.Lemke@conocophillips.com> Sent: Wednesday, February 08, 2017 3:51 PM To: Guhl, Meredith D (DOA) Cc: Elgarico, Richard E; Do, Anh Tram Subject: RE: CRU CD1-15, PTD 210-047, new TD box 4a and 4b values required The drilling of CD1-15PB2 was an unsuccessfully attempt and no hole was made. COPA drilling decided to rename CD1- 15PB2 to CD1-15 to close out the permit and no OH or MWD logging resulted in this attempt.The directional survey for CD1-15PB2 renamed CD1-15 shows the tie in and kick off point with no new survey points taken. Schlumberger CBL completion logs were acquired and delivered to AOGCC in 2016 at the time the well was complete as a WAG well. Completion logs are the only logs run in CD1-15 wellbore. Thank you for your patience as COPA verifies for you that no OH/MWD logs were run in CD1-15 in the drilling window timeframe. Sandra D. Lemke Alaska IT GGRE ConocoPhillips Alaska 700 G Street,ATO-07-704 Anchorage,AK 99501 SCAN N ° MAR 14 201?. (907)265-6947 phone, (907)440-4512(cell) Sandra.D.Lemke@conocophillips.corn RECEIVED initusie JUN OS bib Makana K Bender s � ITS•Mir CUM AOGCC '41. Natural 1R T in tl 6.411A * oil& C tion Commotion 141,( j Sodstarap,aNtallat • 331 11V 7 Ave &+we; .Ar►chlracre FS5r: u I( SEND has 4h; 4:01.11 340I"I.FM "Ii4M lt'411101111111:' /Mrory MLA= POOL .171" same XI-13 1.41101141111140 aaalaalin al wr.- vas. • flit. Iliese,111 1 1 Wellborn: CD1-15PB2 Survey Calculation Method: Minimum Curvet Design: CD1-15PB2 Database: CPAI EDM Prod Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Leve Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reit Map Zone: Alaska Zone 04 Using geodetic Well CD1-15 Well Position +N!-S 0.00 ft Northing: 5,975,805.80ft Latitude: +Ei-W 0.00 ft Easting: 385,901.08 ft Longitude: Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: Wellbore CD1-15PB2 Magnetics Model Name Sample Date Declination Dip Angle (5) (5) BGGM2009 511f2009 21.62 80.72 Design CD1-15PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: Vortical Section: Depth From(TVD) +W-S +E/-W Die (R) (ft) (n) 36.65 0.00 0.00 Survey Program Date From To (ft) (!t) Survey(Wellbore) Tool Name Description 81.00 1,006.00 CD1-15PB1 Gyro(CD1-15PB1) CB-GYRO-SS Camera based gyro single 1,106.18 3,063.;,, CD1-15P81 MWD(R200)(CD1-15PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,147.95 20,067.00 CD1-15PB1 MWD(R300)(CD1-15PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 20,114.00 20,114.00 CD1-15PB2(CD1-15PB2) BLIND Blind drilling From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent:Tuesday, February 07, 2017 1:12 PM To: Lemke, Sandra D<Sandra.D.Lemke@conocophillips.com> Subject: [EXTERNAL]RE: CRU CD1-15, PTD 210-047, new TD box 4a and 4b values required We didn't get any data for PB2 20114'TD, other than the survey, so if there were any logs run, both digital and paper need to be submitted. From: Lemke, Sandra D [mailto:Sandra.D.Lemke@conocophillips.com] Sent:Tuesday, February 07, 2017 1:08 PM To:Guhl, Meredith D (DOA)<meredith.guhl@alaska.gov> Subject: RE: CRU CD1-15, PTD 210-047, new TD box 4a and 4b values required 2 • • Any other action items on this one?? I am drinking out of a fire hose over here and can't even come up for air! From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent:Tuesday, February 07, 2017 1:04 PM To: Lemke, Sandra D<Sandra.D.Lemke@conocophillips.com>; Haggerty-Sherrod,Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: [EXTERNAL]RE: CRU CD1-15, PTD 210-047, new TD box 4a and 4b values required Sandra, Ann did get back to me on Jan 5 with updated values for the 10-407. Thanks, Meredith From: Lemke,Sandra D [mailto:Sandra.D.Lemke@conocophillips.com] Sent:Tuesday, February 07, 2017 1:01 PM To: Haggerty-Sherrod,Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Cc: Guhl, Meredith D (DOA)<meredith.guhl@alaska.gov> Subject: RE: CRU CD1-15, PTD 210-047, new TD box 4a and 4b values required Importance: High Ann, This well did have some challenges. Originally there were two wellbores; CD1-15PB1 drilled to 20700' and and CD1- 15PB2 which attempted to make it to CD1-15 target.They gave up on another attempt and renamed CD1-15PB2 to CD1- 15 with a TD of 20114'. Here is a screen shot of the headers in ATDB and I have attached the directional surveys. Sperry never made a correction to the well name and API on the final survey marked PB2 which should have been renamed CD1-15, 501032061900, but I made an edit in ADOBE to the header. Please have Wellview revised and if the Wellview folks have questions have them contact me. Meredith is correct. Revisions are due AOGCC for the 10-407 document related to TD (4b)and surface locations (4a). File Forms Options Tools Windows Help 74 to„ fA i LA Welmmore WELL_ID WELL_NAME API BUB_ID DATE_SPUD DATE_RIG_RLS KO_DPTH TD_ CD1-15 CD1-15 501032061900 WNS /2010 06/14/2010 20114.00 CD1-15 CD1-15PB1 501 1970 WNS 04/29/2010 06/14/2010 Please get the revised 10-407's to AOGCC at your earliest convenience. Sandra Lemke 3 110 From: Haggerty-Sherrod,Ann (Northland Staffing Services) Sent:Wednesday,January 04, 2017 11:33 AM To: Lemke,Sandra D<Sandra.D.Lemke@conocophillips.com> Subject: FW: CRU CD1-15, PTD 210-047, new TD box 4a and 4b values required Sandy, I need help from someone who has more knowledge than I have about these things. I received the message below from AOGCC regarding a discrepancy they have found. I cannot find an electronic copy of the definitive survey for CD1-15 (this was all done before I came on board) and when I look into Wellview the Act Btm (ftkb)for CD1-15 is 20,700,which is the depth on the 10-407. However,when I look at the Survey Data report in Wellview the bottom depth is 20,114. Can you shed any light on this issue? Do you get copies of the survey? I can go to central files this afternoon to see if there is a hard copy of the survey. I think that I can give her the information she is asking for but I am unsure that it will be correct. From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent:Tuesday,January 03, 2017 4:31 PM To: Haggerty-Sherrod,Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: [EXTERNAL]CRU CD1-15, PTD 210-047, new TD box 4a and 4b values required Hello Ann, According to ConocoPhillips digital survey archive,the TD for CD1-15, PTD 210-047, is actually 20,114'. Please provide new Box 4a and 4b Total Depth values for this new TD. I will update the 10-407 forms already submitted. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W.7th Ave,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 4 STATE OF ALASKA AL.OIL AND GAS CONSERVATION COASION GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1a.Test: U Initial H Annual LJ Special 1b.Type Test: LJ Stabilized Li Non Stabilized IA Multipoint ❑ Constant Time ❑ Isochronal ❑ Other: 2.Operator Name: RECEIVED 5. Date Completed: 11.Permit to Drill Number: ConocoPhillips Alaska, Inc. 6/24/2016 210-047 /316-083 3.Address: JUL 1 3 2016 6. Date TD Reached: 12.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 May 12,2010 50-103-20619-00,-70,-71 4a. Location of Well(Governmental Section): AOGCC 7. KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 322'FNL,2805'FEL,Sec.5,T11N, R5E, UM 56' CRU CD1-15 Top of Productive Horizon: 8. Plug Back Depth(MD+TVD): 14. Field/Pool(s): 630'FSL,974'FWL,Sec.33,T12N, R5E, UM +/-7,800'MD/3,486'ND Colevile River Unit Total Depth: 1847'FNL,528'FEL,Sec.35,T12N, R5E, UM 9.Total Depth(MD+ND): "Halo"Undefined Gas Pool 20,700'MD/6,515'ND 4b. Location of Well(State Base Plane Coordinates NAD 27): 10. Land Use Permit: 15. Property Designation: Surface: x- 385901' y- 5975806' Zone- 4 Tobin#932008,932082 ADL 25559,391580,25557,25558 TPI: x- 389690' y- 5976702' Zone- 4 16.Type of Completion(Describe): Total Depth: x- 404061' y- 5979305' Zone- 4 Cased and Perforated 17.Casing Size Weight per foot, lb. I.D. in inches Set at ft. 19. Perforations: From To 7-5/8" 29.7# 6.875 20225 5675' MD to 5788' MD 18.Tubing Size Weight per foot,lb. I.D. in inches Set at ft. 2992' TVD to 3019' TVD 4-1/2" 12.6 3.908 5673'MD 20. Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): 5551'MD Dry Gas Dry Gas 0.58 (Gas gravity) 24a. Producing through: 24b.Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure(Pa): 0 Tubing ❑ Casing 65 F° 1406 psia @ Datum 3000' TVDSS psia 25. Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H2S: Prover: Meter Run: Taps: 3000' 0.58 0.04 0.98 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice Size(in.) Size(in.) psig Hw F° psig F° psig F° Hr. 1. X 1228 43 7 2. X 1217 48 7 3. X 1174 47 3 4. X 1137 47 7 5. X Basic Coefficient Flow Temp. Super Comp. No. (24-Hour) hwPm Pressure Factor Gravity Factor Factor Rate of Flow Fb or Fp Pm Ft Fg Fpv Q1 Mcfd 1. 4877 2. 5652 3. 8081 4. 9776 5. No. Pr Temperature Tr z SCA4NS° t�F� EB` 0. ��u17I' for Separator for Flowing T Gas Fluid Gg G 1. 1.425 503 1.36 0.7842 2. 1.412 507 1.37 0.7939 3. 1.361 507 1.37 0.7975 Critical Pressure 862 862 4. 1.319 507 1.37 0.8023 Critical Temperature 369.67 369.67 5. Form 10-421 Rev. 7/2009 CONTINUED ON REVERSE SIDERBDMS I,L_JUL 1 3 2046mit in Duplicate Pc 1280 Pc2 1638. •Pf 1406 p{2 1976836 No. Pt Pt2 Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Ps2 Pf2-Ps2 1. 1228 1508680 129720 1347 1813213 163263 2. 1217 1481266 157134 1335 1782619 194217 3. 1174 1377719 260681 1301 1691546 285290 4. 1137 1292982 345418 1272 1618726 358110 5. 25. AOF (Mcfd) 29600 n 0.71 Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title �/iU�',�c �,�y Date4/2n DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ -I hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(TVD) L Length of flow channel, feet(MD) n Exponent(slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 7/2009 Side 2 • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAc 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: V2i/16 o '210-047 /316-083 3.Address: 7. Date Spudded: — 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 4/28/2010 50-103-20619-00,-70,-71 • 4a.Location of Well(Governmental Section): 1'101 8. Date TD Reached: 16.Well Name and Number: Surface: 322'FNL,2805'FEL,Sec.5,T11N, R5E, UM PJ, ,r,� 5/12/2010 CRU CD1-15 • Top of Productive Interval: N 9. Ref Elevations: KB: 56'MSL 17. Field/Pool(s): 630'FSL,974'FWL,Sec.33,T12N, R5E, UM GL: 19.5'MSL CRU/"Halo"Undefined Gas Pool ' Total Depth: k 10.Plug Back Depth MD/TVD: 18.Property Designation: 1952'FNL, 1089'FEL,Sec 35,T12N, R5E,UM +/-7,800'MD/3,486'ND ADL 25559,391580,25557,25558+ 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 1A(G 19. Land Use Permit: Surface: x- 385901' y- 5975806' Zone- 4 2U1f114MD/6311 ND "3' Tobin#932008,932082 TPI: x- 389690' y- 5976702' Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth' x- 403498 y- 5979209 Zone- 4 2,090'MD/1,939'ND 1601'MD/1556'ND 5. Directional or Inclination Survey: Yes ❑(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 (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 CASTM-Advanced Cement Evaluation Correlation Log SCANNED AN 2 $ 2.017 RECEIVED MJ U L 13 2016 23. CASING, LINER AND CEMENTING RECORD AOGCC WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT TOP BOTTOM TOP BOTTOM PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" Pre-installed 10.75" 45.5# L-80 36' 3112' 36' 2394' 13.5" 582 sx Arcticset Lite,297 sx G 7.625" 29.7# L-80 34' 20225' 34' 6405' 9.875" 305 sx G,200 sx G, 184 sx G 24.Open to production or injection? Yes Q No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number): 4.5" 5,673' 5,551'MD/2,964'ND 1 Top Halo Perforations:5,675'MD/2,992'ND Bottom Halo Perforations:5,788'MD/3,019'ND (r-COMPLETION 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. ,ATE Was hydraulic fracturing used during completion? Yes❑ No 0 –,- /z1/143 VERIFIED Per 20 AAC 25.283(i)(2)attach electronic and printed information [,L DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 4/17/2016 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 4/17/2016 123 Test Period —Diesel FP Only 37762 0 Variable Dry Gas Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 900-1150 410 24-Hour Rate .—► 0 7368 0 Dry Gas Form 10-407 Revised 11/2015 iiTt- kV&`I(. ��CONTINUED II �ON PAGE 2 RBDMS (,V ,JUL 1 4 2016Submit ORIGINIAL onl 2&.CORE DATA Conventional W(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes E No ❑ Permafrost-Top Ground Surface Ground Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1601' 1556' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. C-30 3209' 2417' C-20 4730' 2769' Well initially unloaded/tested 4/17/2016 for 123 hours,then shut-in for Top of PI(C-10) 5675' 2993' PBU. Interval perforated and tested is C-10,5675'-5788'. Multi-Point K-3 9011' 3774' test then run 6/20-6/24 for four different flow periods. Results of initial K-2 10005' 4007' test are on this completion report. Form 10-421 attached for Multi-point Albian 97 17977' 5874' test. Albian 96 18880' 6086' HRZ 19820' 6308' Kalubik 20382' 6441' Lower Kalubik 20608' 6493' Formation at total depth: 31. List of Attachments: Cover Letter,Summary of Daily Operations,Wellbore schematic, 10-421 well test results, Crt.. t &T (RiRb(2r. 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. Contact: Drew Huck @ 265-6828 Email: Andrew.Huck@cop.com /f/e Printed Name: G.L Alvord �/ Title: Alaska Drilling Manager Signature: • ,I 7/,;(0_ c5. L. RI-644one: 265-6120 Date: /I QI(eD INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • ConocoPh i l l i ps RECEIVED Alaska JUL 13 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 A July 12th,2016 AOGCC Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.has completed work under Sundry#316-083. The well was recompleted from March 13th to March 22nd. The well was perforated after the rig left and the initial flow test/unloading(Step#1 of the "Well Test"section for the approved procedure)occurred shortly after on April 17th. The well was then shut-in for a buildup test,during which time production piping was installed. Piping install was completed in the last few weeks, at which point the multipoint test was performed(Step#4 of"Well Test"procedure)starting on June 20th and completed on June 24th,which was the last step under the sundry. ConocoPhillips Alaska intends to use this well as a gas supply for the Alpine facility shutdown starting on July 22nd 2016. Please fmd enclosed forms 10-407 and 10-421 for completion of this work. Forms 10-422 will be submitted as normal for Alpine and include volumes from this test. If you have any questions or require any further information, please contact me at 265-6828,or Ilnur Mustafin at 263-4039. Sincerely, f•-&-;.-- ..,. /(.. 2 7/r 2_/I 6 Drew Huck Drilling Engineer CPAI Drilling and Wells a 4 Operations Summary (with Timelog Depths) ‘,10r:' CD1-15 C m co hiffips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKD)' 3/13/2016 3/13/2016 3.00 MIRU MOVE RURD P Continue prepare rig for module 09:00 12:00 separation.Complete blowing down lines. 3/13/2016 3/14/2016 12.00 MIRU MOVE MOB P Peak trucks arrived at noon.Separate 12:00 00:00 modules from sub base.Position pipe shed on pad.Cantilever the rig floor and derrick.Move modules and sub base to CD1 -15. 3/14/2016 3/14/2016 6.00 MIRU MOVE MOB P Continue move sub base and modules 00:00 06:00 from CD4-213B to CD1-15.Remove matting boards,load and truck same to new location. 3/14/2016 3/14/2016 12.00 MIRU MOVE MOB P Lay matting boards and herculite for 06:00 18:00 berming.Spot sub base over well. Remove tongue on sub base. Cantilever rig over center of well. Continue spot Pits,Pumps,and Motor modules,installing matting boards and herculite.Spot Rockwsher,and cuttings tank.Lay matting boards and herculite,and spot pipe shed module. 3/14/2016 3/15/2016 6.00 MIRU MOVE RURD P Continue install berming,and ensure 18:00 00:00 all steps are down,and rig up to accept rig as per rig acceptance checklist. 3/15/2016 3/15/2016 3.00 MIRU MOVE RURD P RU lines and other items for rig 00:00 03:00 acceptance,ASRC spotting and RU open top tank,choke skid,and hardline. Rig Accepted at 03:00. 3/15/2016 3/15/2016 2.00 MIRU WELCTL RURD P MU circulation lines to wellhead,take 03:00 05:00 on seawater to pits. Prepare for killing the well. 3/15/2016 3/15/2016 2.00 MIRU WELCTL RURD P Load 290 bbls 8.5ppg seawater to 05:00 07:00 pits. 3/15/2016 3/15/2016 1.00 MIRU WELCTL MPSP P RU and test FMC lubricator.Test to 07:00 08:00 1,500 psi and passed.Pull BPV and RD lubricator. 3/15/2016 3/15/2016 2.00 MIRU WELCTL SEQP P RU to reverse circ to the tiger tank. 08:00 10:00 Test lines with air and passed,test lines with seawater and passed to 1,500psi. 3/15/2016 3/15/2016 1.50 MIRU WELCTL KLWL P Reverse circulate 120bbls 8.5ppg • 10:00 11:30 seawater with deep clean at 5bpm, 175-320psi. 3/15/2016 3/15/2016 1.50 MIRU WELCTL OWFF P Observe well for flow for 30 minutes. 11:30 13:00 Fluid u-tubing out tubing to annulus. 3/15/2016 3/15/2016 1.00 MIRU WELCTL KLWL P RU and circulate.Pump 120bbls at 13:00 14:00 5bpm,330psi FCP down the tubing out the annulus. 3/15/2016 3/15/2016 0.50 MIRU WELCTL OWFF P Observe well,well out of ballance. 14:00 14:30 Continued to observe well and well was static. 3/15/2016 3/15/2016 2.00 MIRU WELCTL COND P Prep pits to circulate.Mix deep clean 14:30 16:30 pill.Offload used seatwater and bring on clean seawater and heat.R/D lines. Page 1/7 Report Printed: 7/11/2016 • Operations Summary (with Timelog Depths) `. `" CD1-15 • fi g ConocoPhriirps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS)- End Depth(ftkS) 3/15/2016 3/15/2016 1.00 MIRU WHDBOP MPSP P PU T-bar and set BPV.Test in the 16:30 17:30 direction of flow to 1,000psi for 10 min. Bleed down line and RD. 3/15/2016 3/15/2016 1.50 MIRU WHDBOP NUND P ND Tree. 17:30 19:00 3/15/2016 3/16/2016 5.00 MIRU WHDBOP NUND P PJSM.NU adapter flange/DSA and 19:00 00:00 BOP Stack. 3/16/2016 3/16/2016 2.00 MIRU WHDBOP RURD P Reposition Kill HCR 180 degrees to 00:00 02:00 allow for full movement of the BOP working platform. 3/16/2016 3/16/2016 2.00 MIRU WHDBOP RURD P Install flow riser,install kill line 02:00 04:00 manifold.MU choke and kill hoses. 3/16/2016 3/16/2016 1.00 MIRU WHDBOP RURD P PJSM and RU to test BOP. 04:00 05:00 3/16/2016 3/16/2016 3.50 MIRU WHDBOP PRTS P Test BOP.Test Choke manifold 05:00 08:30 valves 1-14,annular,top 3.5"x6"VBR, outter and inner stand pipe kill line valves, HCR and manual kill line valves with 3.5"test joint to 250 psi low/2,500 psi high for 5 min. 3/16/2016 3/16/2016 0.50 MIRU WHDBOP PRTS T Test lower 3.5"x6"VBR with 3.5"test 08:30 09:00 joint and test failed.Call out for a replacement. 3/16/2016 3/16/2016 2.50 MIRU WHDBOP PRTS P FOSV and dart valves with 3.5"test 09:00 11:30 joint to 250 psi low/2,500 psi high for 5 min. 3/16/2016 3/16/2016 1.50 MIRU WHDBOP PRTS P Test top 3.5"x6"VBR,annular,HCR 11:30 13:00 and manual choke line valves with 4.5"test joint to 250 psi low/2,500 psi high for 5 min. 3/16/2016 3/16/2016 1.50 MIRU WHDBOP PRTS T Change out test joints.Blanking plug 13:00 14:30 was leaking,pull blanking plug.Clean up and inspect grease and attempt to reinstall.Unable to screw into the hanger.Pump out stack and inspect blanking plug in stack. 3/16/2016 3/16/2016 2.00 MIRU WHDBOP NUND T PJSM. Lift stack to retrieve blanking 14:30 16:30 plug and nipple back up. 3/16/2016 3/16/2016 4.00 MIRU WHDBOP RURD T Remove choke hose,Change out 16:30 20:30 failed lower VBRs from 3.5"x6"to new 2.875"x5".Reinstall choke hose. 3/16/2016 3/16/2016 1.00 MIRU WHDBOP MPSP P MU test joint with blanking plug per 20:30 21:30 FMC rep.RU to test BOPs. 3/16/2016 3/17/2016 2.50 MIRU WHDBOP PRTS P PJSM.Test Lower VBR 2.875"x5"with 21:30 00:00 3.5"test joint,test blind rams,upper IBOP,lower IBOP and body test on choke line to 250 psi low/2,500 psi high for 5 min.Test annular preventor with 4"test joint. 3/17/2016 3/17/2016 2.00 MIRU WHDBOP BOPE P PJSM,Test with 4"and 4.5" test 00:00 02:00 joints on top VBRs 3.5"x6"and lower VBRs 2-7/8"x5"to 250 psi low/2,500 psi high for 5 minutes. Accumulator draw down test:Before Man-1500psi,Acc-2975psi,Ann- 775 psi.After Man-1400psi,Acc- 1900psi,Ann-680psi.200 psi-12 sec.Full psi-70 sec.N2-6 bottle average 2,525psi. Page 2/7 Report Printed: 7/11/2016 • 1111, s Operations Summary (with Timelog Depths) tt3, '. CD1-15 Conoccehillips sr =A'„:atks Rig: DOYON 142 Job: RECOMPLETION Time Lag Start Depth Start Time End Time Our(hr) Phase' Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKD) 3/17/2016 3/17/2016 0.50 MIRU WHDBOP RURD P PJSM.Pull blanking plug. RD BOP 02:00 02:30 testing equipment.break down choke and kill lines.Clean and clear rig floor. 3/17/2016 3/17/2016 0.50 MIRU WHDBOP MPSP P PJSM. Pull BPV as per FMC rep. 02:30 03:00 Monitor tbg and IA pressure to ensure well is static. 3/17/2016 3/17/2016 0.50 COMPZN RPCOMP RURD P RU GBR casing equipment. 03:00 03:30 3/17/2016 3/17/2016 1.50 COMPZN RPCOMP PULL P Install landing joint.MU to top drive. 03:30 05:00 BDcame freat 64K, hangingOLS.weightHanger withamblocks 62K. 3/17/2016 3/17/2016 0.50 COMPZN RPCOMP CIRC P Observed U-tubing.Circulate tubing 05:00 05:30 volume prior to laying down completion,22 bbls at 3bpm 70psi. 3/17/2016 3/17/2016 0.50 COMPZN RPCOMP PULL P PJSM. LD landing joint,hanger and 2,211.0 2,176.0 05:30 06:00 crossover. 3/17/2016 3/17/2016 3.00 COMPZN RPCOMP PULL P LD 69 joints of 3.5"kill sting. Hole fill 2,176.0 0.0 06:00 09:00 10.2 bbls while TOOH. 3/17/2016 3/17/2016 0.25 COMPZN RPCOMP OWFF P Observe well for 15 minutes,well was 0.0 09:00 09:15 static. 3/17/2016 3/17/2016 0.50 COMPZN RPCOMP RURD P LD tubing handling equipment and 09:15 09:45 clear floor. 3/17/2016 3/17/2016 0.75 COMPZN WELLPR BHAH P Pull tools to rig floor Baker scraper 0.0 0.0 09:45 10:30 BHA.Verify straps,and measurments. 3/17/2016 3/17/2016 2.50 COMPZN WELLPR SVRG P Change out saver sub on top drive 0.0 0.0 10:30 13:00 from 4.5"IF to 4"XT39 and die blocks. 3/17/2016 3/17/2016 1.50 COMPZN WELLPR RURD P Set 9"wear ring per FMC rep.RILDS 0.0 0.0 13:00 14:30 3/17/2016 3/17/2016 0.25 COMPZN WELLPR OWFF P Observe well for flow,well static. 0.0 0.0 14:30 14:45 3/17/2016 3/17/2016 1.50 COMPZN WELLPR BHAH P MU Baker 7 5/8"scraper assembly as 0.0 27.0 14:45 16:15 per baker rep.Total length of BHA= 27.15' 3/17/2016 3/18/2016 7.75 COMPZN WELLPR PULD P RIH with scraper assemnly on 4"XT39 27.0 3,951.0 16:15 00:00 DP 3, 1'. U 8 ,S88K. Observtoed 95calculatedP9KholOe fill. 3/18/2016 3/18/2016 5.50 COMPZN WELLPR PULD P Continue RIH with 4"DP from pipe 3,951.0 8,213.0 00:00 05:30 shed from 3951'-8213'.Did not observe any issue going by the Tam Port collar at 5679'.PU 117K,SO 91K. Rotating at 101K at 20 rpm with 5K torque.Observed proper hole fill. 3/18/2016 3/18/2016 0.50 COMPZN WELLPR SFTY P Held PJSM with crew,drivers and 8,213.0 8,213.0 05:30 06:00 mud engineers.Discuss circulation. Discuss safety and hazard recognition issues. 3/18/2016 3/18/2016 3.00 COMPZN WELLPR CIRC P Circulate 40 bbls 9.8ppg Hi-Visc 8,213.0 8,213.0 06:00 09:00 spacer, 40 bbls 8.55ppg Low-Visc heated Deep Clean chased with heated 8.5pp seawater at 5 BPM, 360psi while rotating at 55 rpms with 5K torque.Bleed down lines and transfer remainder of seawater to pits. 3/18/2016 3/18/2016 0.75 COMPZN WELLPR RURD P Bleed down top drive and mud line. 8,213.0 8,213.0 09:00 09:45 Observe well for flow,static. ' Page 3/7 Report Printed: 7/11/2016 • Operations Summary (with Timelog Depths) /4„:4)11',?'"it' i3 , y CD1-15 ConacoPtsiFitps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS)', End Depth MKS) 3/18/2016 3/18/2016 2.00 COMPZN WELLPR TRIP P POOH from 8,213'to 6,382'.PU 100K. 8,213.0 6,382.0 09:45 11:45 3/18/2016 3/18/2016 4.25 COMPZN WELLPR TRIP P Continue to POOH from 6,382'to 591'. 6,382.0 591.0 11:45 16:00 Observe well,static.Calc fill 43bbls, actual fill 52bbls. 3/18/2016 3/18/2016 1.00 COMPZN WELLPR BHAH P Lay down baker tools and clear rig 591.0 0.0 16:00 17:00 floor. 3/18/2016 3/18/2016 4.00 COMPZN WELLPR RURD P PU Dutch Riser assembly to rig floor. 0.0 0.0 17:00 21:00 SIMOPS:Test run PU control line spooler for completion,would not fit up beaver slide.RU Dutch Riser and PT to 1,000psi for 5 min,test passed. 3/18/2016 3/18/2016 2.50 COMPZN WELLPR ELOG P PJSM with E-line and Weltec.PU E- 0.0 0.0 21:00 23:30 line tools and RU for logging.Test tools at surface. 3/18/2016 3/19/2016 0.50 COMPZN WELLPR ELOG P RIH with bond log assembly.Log from 0.0 23:30 00:00 3,000'to 6,100'.Tool length 61.61', weight 499.6Ibs,max tool OD 4,38". 3/19/2016 3/19/2016 4.00 COMPZN WELLPR ELOG P PJSM.Log out of hole with bond log 00:00 04:00 assembly from 6,100'to 3,000'. SIMOPS:Drift 4-1/2"tubing to 3.833" and complete tally. 3/19/2016 3/19/2016 1.50 COMPZN WELLPR ELOG P PJSM with wireline crew.Pull tools out 04:00 05:30 of hole.Monitor well and confirm static.LD wireline tools and RD equipment. 3/19/2016 3/19/2016 0.50 COMPZN WELLPR RURD P RD dutch riser assembly and LD in the 05:30 06:00 pipe shed.RU flow riser. 3/19/2016 3/19/2016 6.00 COMPZN WELLPR TRIP P PJSM. MU Baker cement retainer and 0.0 5,690.0 06:00 12:00 TIH on DP.PU 95K,SO 85K. 3/19/2016 3/19/2016 1.75 COMPZN WELLPR TRIP P Continue to TIH from 5,690'to 8,006'. 5,690.0 8,006.0 12:00 13:45 PU 115K,SO 89K. 3/19/2016 3/19/2016 0.50 COMPZN WELLPR MPSP P Set Baker K-1 cement retainer as per 8,006.0 8,006.0 13:45 14:15 baker rep at 8,006'.Tag with 10K to ensure set. 3/19/2016 3/19/2016 1.00 COMPZN WELLPR CMNT P Lay down a single from 8,006'to 8,006.0 7,976.0 14:15 15:15 7,976'and RU for cement job. 3/19/2016 3/19/2016 0.50 COMPZN WELLPR CMNT P PJSM with Schlumberger for cement 7,976.0 7,976.0 15:15 15:45 job.Break circulation with 3 bpm at 148 psi. 3/19/2016 3/19/2016 1.00 COMPZN WELLPR CMNT P Pump 5 bbls fresh water,tested lines 7,976.0 7,976.0 15:45 16:45 to 4,000 psi,test good.Pumped 7.4 bbls 12.5ppg MPH,drop foam wiper ball.Pump 10 bbls 15.8ppg cement and drop 2nd foam wiper ball.Pump 2.6 bbls MPII and chase with seawater,73 BBLS 3/19/2016 3/19/2016 0.50 COMPZN WELLPR TRIP P POOH from 7,976'to 7,696'. 7,976.0 7,696.0 16:45 17:15 3/19/2016 3/19/2016 3.00 COMPZN WELLPR CIRC P Reverse circulate 2X bottoms up at 50 7,696.0 7,696.0 17:15 20:15 spm with 391 psi.Little or no cement returns observed at bottoms up.Shut down pumps and circ black water pill through pits to clean out any cement contamination.Reverse circ 140 bbls of KCL CI brine from vac trcuk at 50 spm with 398 psi.Chase with 127 bbls of seawater at 50 spm with 367 psi. Page 4/7 Report Printed: 7/11/2016 • . • a 'z,i� ,- Operations Summary (with Timelog Depths) elltzt,,%-;.,,,,-, :,,41 ',--'i- ifa '_ CD1-15 ConocoPhiilips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 3/19/2016 3/19/2016 0.75 COMPZN WELLPR RURD P RD equipment and BD lines.Monitor 7,696.0 7,696.0 20:15 21:00 well to confirm static.Line up BOPE for normal operations. 3/19/2016 3/19/2016 0.50 COMPZN WELLPR OTHR P Completion jewlery arrived arrived on 7,696.0 7,696.0 21:00 21:30 location. Load into short side of the pipe shed to warm up. 3/19/2016 3/20/2016 2.50 COMPZN WELLPR PULD P LD from 7,696'to 5,832'.PU 109K, 7,696.0 5,832.0 21:30 00:00 SO 94K.Monitor well on trip tank,calc hole fill 10.88 bbls,actual hole fill 11.1 bbls. 3/20/2016 3/20/2016 1.75 COMPZN WELLPR PULD P Continue to lay down DP from 5,832' 5,832.0 4,851.0 00:00 01:45 to 4,851'.PU 104K,SO 88K.monitor on trip tank,calc hole fill 5.6 bbls, actual hole fill 5.4 bbls. 3/20/2016 3/20/2016 0.25 COMPZN WELLPR PULD P RIH with remaining 5 stands in the 4,851.0 5,326.0 01:45 02:00 derrick from 4,851' to 5,326'. 3/20/2016 3/20/2016 4.00 COMPZN WELLPR PULD P LD DP from 5,326'to 1,566'.PU 68K, 5,326.0 1,566.0 02:00 06:00 SO 72K.Observed calculated hole fill. • 3/20/2016 3/20/2016 2.75 COMPZN WELLPR PULD P LD DP from 1,566'to surface.LD 1,566.0 0.0 06:00 08:45 Baker running tools.Observe well for flow,well static. 3/20/2016 3/20/2016 0.50 COMPZN WELLPR RURD P BOLDS,Pull wear ring. 08:45 09:15 3/20/2016 3/20/2016 1.50 COMPZN RPCOMP RURD P Strap completion equipment in the 09:15 10:45 shed.PU tubing handling equipment. 3/20/2016 3/20/2016 4.25 COMPZN RPCOMP SLPC P PJSM.Slip and cut drill line,cut off 10:45 15:00 87'. 3/20/2016 3/20/2016 1.75 COMPZN RPCOMP PUTB P RU and run TCP guns and completion 15:00 16:45 tubing.Pull control line spools and bail extensions to the rig floor. 3/20/2016 3/20/2016 0.25 COMPZN RPCOMP SFTY P PJSM to run tubing with Haliburton, 16:45 17:00 Schulmberger,Baker and GBR. 3/20/2016 3/20/2016 1.00 COMPZN RPCOMP PUTB P RIH with TCP guns on completion 0.0 115.0 17:00 18:00 tubing as per detail. 3/20/2016 3/20/2016 1.00 COMPZN RPCOMP RURD P Remove bail extensions,change out 0.0 115.0 18:00 19:00 elevators for 4-1/2"tubing.Verify tubing count in pipe shed.RU to fill tubing with a hose from the rig floor. 3/20/2016 3/20/2016 3.50 COMPZN RPCOMP PUTB P MU 4-1/2"completion as per running 115.0 2,579.0 19:00 22:30 order and baker rep to 2,579'. 3/20/2016 3/21/2016 1.50 COMPZN .RPCOMP RURD P PJSM with all involved to RU control 2,579.0 2,579.0 22:30 00:00 line and injection line.Secure both sheaves in derrick,inspect all overhead equipment and test lines Set 80 cannon clamps on the rig floor. 3/21/2016 3/21/2016 3.00 COMPZN RPCOMP PUTB P MU Chemical injection nipple. 2,579.0 3,682.0 00:00 03:00 Pressure test injection line connection to 7,600 psi and held. Keep 1,200 psi on control line while RIH.Trip in hole with completion and cannon clamps on every connection to 3,682'.PU 75K,SO 75K.Fill tubing with a hose and monitor displacement. Page 5/7 Report Printed: 7/11/2016 Operations Summary (with Timelog Depths) CD1-15 C onoa Blips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB),.. 3/21/2016 3/21/2016 4.50 COMPZN RPCOMP PUTB P MU BP-6i nipple and control line. 3,682.0 5,570.0 03:00 07:30 Pressure test control line to 5,000 psi and held.Continue TIH to 5,570'. Install cannon clamps every connection and steel bands every other connection,80 cannon clamps and 27 steel bands in the hole. 3/21/2016 3/21/2016 0.50 COMPZN RPCOMP HOSO P PU 2 space out pups and set on depth 5,570.0 5,790.0 07:30 08:00 from 5,770'to 5,790'. 3/21/2016 3/21/2016 4.00 COMPZN RPCOMP ELOG P RU to run E-line. 5,790.0 5,790.0 08:00 12:00 3/21/2016 3/21/2016 1.75 COMPZN RPCOMP ELOG P RIH with GR/CCL with weight bars(no 5,790.0 5,790.0 12:00 13:45 tractor)and did not pass though down hole jewelry.POOH. 3/21/2016 3/21/2016 1.50 COMPZN RPCOMP FLOG P RIH with under 2.5"OD tools,GR/CCL 5,790.0 5,790.0 13:45 15:15 and correlate gun depth.On depth with pipe tally.ROOH with wireline. 3/21/2016 3/21/2016 1.25 COMPZN RPCOMP FLOG P RD E-line. 5,790.0 5,790.0 15:15 16:30 3/21/2016 3/21/2016 1.00 COMPZN RPCOMP HOSO P LD 2 pup joints,2 full joints and space 5,790.0 5,788.0 16:30 17:30 out with pup joint and full joint as per tubing detail.MU crossover to hanger. 3/21/2016 3/21/2016 2.50 COMPZN RPCOMP THGR P Terminate control lines through 5,788.0 5,788.0 17:30 20:00 hanger.PT control line swedge lock to 5,000psi as per FMC.SIMOPs-drain stack,blow down kill line,choke line and hole fill. 3/21/2016 3/21/2016 1.50 COMPZN RPCOMP THGR P RU to set hanger.PU 90K SO 75K. 5,788.0 5,788.0 20:00 21:30 Land hanger and run LDS.Torque LDS to 450 ft/lbs.PT seals to 250 psi for 5 min,5,000psi for 5 min. 3/21/2016 3/22/2016 2.50 COMPZN RPCOMP PRTS P PJSM with crew on setting packer and 5,788.0 5,788.0 21:30 00:00 pressure testing.Pressure up tubing to 2,000 psi and hold for 5 minutes. Observed initial packer set at 960 psi, increase to 3,000 psi and hold for 5 minutes.Bleed off pressure.Pressure up on tubing to 3,000 psi and hold for 15 minutes,passed.Bleed down tubing to 2,000 psi and pressure test IA to 3,000 psi for 30 minutes and chart passing test. Bleed off IA then tubing. Pressure up IA to 2,500 psi and shear SOV.Varify circulation between tubing and IA. 3/22/2016 3/22/2016 1.00 COMPZN WHDBOP MPSP P Rig down circulating equipment.Lay 00:00 01:00 down landing joint A and set two way check per FMC.Pick up and make up landing joint B to test TWC.Test TWC in the direction of flow from the IA to 1,000 psi for 5 minutes.Lay down landing joint B. Blow down circulation lines. 3/22/2016 3/22/2016 1.50 COMPZN WHDBOP GLEN P Clean and clear floor.Lay down GBR 01:00 02:30 equipment.Rig down control line and injection line sheaves.Lay down Schlumberger equipment. Page 617 Report Printed: 7/11/2016 • • • r. x e,0%, Operations Summary (with Timelog Depths) r t..'A , ; P't siflips ~' Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/22/2016 3/22/2016 4.25 COMPZN WHDBOP NUND P PJSM. Rinse out drip pan,pull riser, 02:30 06:45 'remove bell nipple from annular.RD kill and choke lines.ND BOPE stack and rack back on BOPW deck and secure.Nipple down Alpine adapter and position on BOPE landing area. 3/22/2016 3/22/2016 4.50 COMPZN WHDBOP NUND P Install control line connection& 06:45 11:15 adapter flanges.Test both lines to 5,000 psi. 3/22/2016 3/22/2016 3.00 COMPZN WHDBOP NUND P PJSM-NU tree,test pack off 250/ 11:15 14:15 5,000 psi.Warm up tree valves with steam.Test tree 250/5,000 psi. 3/22/2016 3/22/2016 2.75 COMPZN WHDBOP FRZP P Pull TWC,PJSM with LRS-freeze 14:15 17:00 protect using 200 bbls of diesel.RU to freeze protect. 3/22/2016 3/22/2016 2.50 COMPZN WHDBOP FRZP P Freeze protect.test lines to tiger tank 17:00 19:30 to 1,000 psi.Little Red pumped 200 bbls at 2 bpm, 1,900 psi.FCP=1,600 psi,IA=200 psi.Allow well to U-tube and equilaize.Final pressures TBG= 0 psi, IA=50 psi,OA=25 psi. 3/22/2016 3/22/2016 1.00 COMPZN WHDBOP OTHR P Blow down and rig down circulation 19:30 20:30 lines. 3/22/2016 3/22/2016 0.50 COMPZN WHDBOP MPSP P Set H BPV per FMC. 20:30 21:00 3/22/2016 3/22/2016 0.50 COMPZN WHDBOP OTHR P Schlumberger pressure up and shear 21:00 21:30 DCIN @ 7,100 psi.Mark on tree- injection line and control line. 3/22/2016 3/23/2016 2.50 DEMOB MOVE MOB P Clean and clear cellar of all 21:30 00:00 I equipment.Secure tree with all gauges,valve handles and plugs. Page 7/7 Report Printed: 7/11/2016 • • Cement Detail Report ..� W ells CD1-15 ConocoPhilhps String: Cement Plug Job: RECOMPLETION, 3/13/2016 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug 3/19/2016 15:00 3/19/2016 16:45 CD1-15 Comment PJSM with Schlumberger for cement job. Break circulation with 3 bpm at 148 psi. Pump 5 bbls fresh water,tested lines to 4,000 psi,test good.Pumped 7.4 bbls 12.5ppg MPII,drop foam wiper ball. Pump 10 bbls 15.8ppg cement and drop 2nd foam wiper ball.Pump 2.6 bbls MPII and chase with seawater. POOH from 7,976'to 7,696'. Reverse circulate 2X bottoms up at 50 spm with 391 psi.Shut down pumps and circ black water pill through pits to clean out any cement contamination. Reverse circ 140 bbls of KCL CI brine from vac trcuk at 50 spm with 398 psi.Chase with 127 bbls of seawater at 50 spm with 367 psi. RD equipment and BD lines.Monitor well to confirm static.Line up BOPE for normal operations. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Cement Plug 7,731.0 7,976.0 Yes 0.0 No No Q Pump[nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 7,731.0 7,976.0 87 G 10.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pass) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 107.0 7.00 Additives Additive Type Concentration Conc Unit label D167 0.4 %BWOC Additive Type Concentration Conc Unit label D46 0.2 %BWOC Additive Type Concentration Conc Unit label D65 0.4 %BWOC Page 1/1 Report Printed: 4/18/2016 • eWNS PROD CD1-15 a ConoccPhd6ps a Well Attributes Max Angle&MD TD Alaska,Inc 1 Wellbore APIIUWI Field Name Weilbore Status nal(°) MD(ftKB) Act Dim/ftER) C„....PMolps + 501032061900 HALO PROD 78.02 7,616.40 20.700,0 N -•• Comment H25(ppm) Date Annotation End Date KB'Grd(it) Rig Release Date HORIZONTAL-C11-15,7/1220163.4148 PM SSSV:NIPPLE Last WO: 36.13 6/15/2010 - vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:CORRECTED SCHEMATIC. pproven 7/12/2016 H:ANGER.e.2- r ). WR DP&GUAGES C/O basing Strings Casing Description OD(In) ID(In) Top(ittKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Insulated 36" Casing Description OD(In) ID(in) Top(ftKB) Set Depth(RED) Set Depth(TVD)...Wt/Len g...Grade Top Thread SURFACE 103/4 9.950 35.8 3.112.2 2,393.5 45.50 L-80 BTC `' Casing Description OD(In) ID(In) Top(ftKB) Set Depth(PER) Set Depth(TVD)...WtfLen(1...Grade Top Thread WINDOW 8 7.000 20,067.0 20.081.0 6,369.3 Casing Description OD(In) ID(In) Top(9K13) Set Depth(ftKB) Set Depth(TVD)...Wt./Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 33.5 20,224.9 29.70 L-80 BTCM Tubing Strings CONDUCTOR Insulated 36`.1 1. Tubing Description String Ma...ID(in) Top(NKB) Set Depth(It...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 37.0-1144 TUBING 4 1/2 3.908 9.2 5.6500 2,986.7 12.60 4-80 Hyd 563 Completion Details Nominal ID NIPPLE.2,068.1 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des , Com (In) 9.2 9.2 0.00 HANGER FMC Tubing Hanger,Note:4 12"IBT threads on bottom. 3.908 2,068.7 1,923.7 45.56 NIPPLE Cameo 4 1/2"BP-61 Nipple 5.576"OD x 3.813"ID(DB) 3.813 WRDP.2,090.0 .' 3,171.2 2,407.8 76.12 NIPPLE Cameo DCIN-II Chemical Injection Nipple VAMTOP PIN 3.909 x PIN 5,529.9 2,958.9 78.34 PACKER Baker 4 1/T x 7 5/8"Premier Packer Assembly 3.908 5,598.3 2,974.8 76.66 NIPPLE HES"XN"Nipple 3.725"No Go.5"OD x 3.725"ID 3.725 3.813" SURFACE;35.e-3,,,z.z-4 '. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVG) Top Incl Top(1469) leeS) I") Des Com Run Date ID(In) NIPPLE;3.171.2 2,090.0 1.938.6 46.19 WRDP WROP(SN;HABS-0356)ON 3.81"DB LOCK 6/25/2016 5,620.0 2.979.8 76.76 GAUGES 3.81"XXN,XO,FLOW THRU SUB.SHOCK.DUAL 625/2016 1.250 SPARTEK GAUGES(OA1.=91")BATTS I CONNECTED(RE-PROGRAM GAUGES FOR 3 SECOND SAMPLE RATE FOR 60 DAYS) GAS LIFT:5,464.7 g- 5,650.0 2.986.7 76.64 TUBING CUT JET CUT TUBING-PUSHED TUBING TAIL& 4/6/2016 SPENT GUNS to 7560'-7713' 7,575.0 3.436.8 77.56 FISH 1/2 JOINT CUT,Crossover&Collar(OAL=22.5') 3/19/2016 0.000 7,601.6 3,442.4 77.85 PERF GUN HES TCP Gun System 4 5/8"guns.27/8"6.4"#EUE 3/19)2016 2.875 Box-Pushed Down`1,925' PACKER,5.529.9 _ 7.622.3 3.446.8 77.97 PERF GUN HES TCP Gun System 4 5/8"guns,2 7/8"6.4"#EUE 3/19/2016 2.875 Box-Pushed Down-1,925' lit 7,645.0 3,451.5 77.78 PERF GUN HES TCP Gun System 4 5/8"guns.2 7/8"6.4"#EUE 3/19/2016 2.875 Box-Pushed Down`1,925' 7;667.8 3,456.4 77.59 PERF GUN HES TCP Gun System 45/8-guns.2 7/8"6.4"#EUE 3/19/2016 2.875 NIPPLE;5,598.3 Box-Pushed Down-1,925' 7,690.3 3,461.3 77.40 PERF GUN HES TCP Gun System 45/8"guns.2 7/8"6.4"#EUE 3/19/2016 2.875 Box-Pushed Down-1,925' 8.006.0 3,533.2 75.97 Bridge Plug Cast Iron Bridge Plug run to Isolate lower portion of 3/19/2016 GAUGES:5,520.0 _ w/Cement wellbore Cap 19,705.0 6.281.1 76.58 RETAINER BAKER CMT RETAINER 6/12/2010 20,067.0 6,365.8 75.74 WHIPSTOCK WHIPSTOCK-ANCHOR BILLET-COULD NOT 6/7/2010 TUBING CUT;5,650.0 GET THRU CASING WINDOW 20 080.0 6.369.0 75.74 PACKER 6/7/2010 APERF.5.875.4-9786.0- 20,085.0 6.370.3 75.74 RETAINER BAKER CMT RETAINER 6/3/2010 Perforations&Slots I Shot Dena ,�gypp Top(TVD) Mrs(TVD) (shots!/ FISH,7,575.0 ie Top(MB) Btm(ftKB) (ftKB) (HKB) Zone Date I) Type Corn ®® 5.675.4 5,788.0 2,992.6 3,019.1 3/21/2016 5.0 APERF 4-5/8"Millennium II charges are 5 spf,72 PERF GUN:7.601 8 t Squeezesdegree phasing guns Cemen PERF GUN.7.6223 I•, Top(TVD) Bits(TVD) Top(ftKB) Btm(ftKB) (ftKB) 111119) I Des Start Date I Com PERF GUN:7.645.0 20.087.0 20,1(8.0 6,370.8 PLUG 5292010 PERF GUN,76678 - `: Mandrel Inserts PERF GUN.7.690.3 ,. St tn, atl on Top(TVD) Valve Latch Port Size TRO Run Bridge Plug vuCemml Cap; N Top(ftKB) MKS) Make Model OD(In) Sery Type Type (In) (pal) Run Date Com 8.008.0 1 5,464.7 2,943.3 Camco KBG-2 1 GAS LIFT OV BEK 0.250 0.0 3/31/2016 Notes:General&Safety q i End Date Annotation 4282010 NOTE:Cement plug set in open hole and back into conducter before drilling surface to avoid breach. RETAINER'19,705.0 - _ 6/18/2010 I NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 WHIPSTOCK,20,087.0 1:-W WINDOW,20,067.0-20,081.0 ° PACKER;20.080.0 - s_ar_ Al:. RETAINER;20,085.0 11-11 I14INTERMEDIATE,33.5-20.224.9 STATE OF ALASKA AL.OIL AND GAS CONSERVATION COM SSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1a.Test: L] Initial U Annual Lf Special 1b.Type Test: L Stabilized Lf Non Stabilized L] Multipoint ❑ Constant Time ❑ Isochronal ❑ Other: 2.Operator Name: RECEIVED 5. Date Completed: 11. Permit to Drill Number: ConocoPhillips Alaska, Inc. 6/24/2016 210-047 /316-083 3.Address: JUL 1 3 2016 6. Date TD Reached: 12.API Number: P.O. Box 100360 Anchorage,AK 99510-0360May 12,2010 50-103-20619-00,-70,-71 G4a. Location of Well(Governmental Section): < ti1 7. KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 322'FNL,2805'FEL,Sec.5,T11N, R5E, UM 56' CRU CD1-15 Top of Productive Horizon: 8. Plug Back Depth(MD+TVD): 14. Field/Pool(s): 630'FSL,974'FWL,Sec.33,T12N,R5E, UM +/-7,800'MD/3,486'TVD Colevile River Unit Total Depth: 1847'FNL,528'FEL,Sec.35,T12N, R5E, UM 9.Total Depth(MD+TVD): "Halo"Undefined Gas Pool 20,700'MD/6,515'TVD 4b. Location of Well(State Base Plane Coordinates NAD 27): 10. Land Use Permit: 15. Property Designation: Surface: x- 385901' y- 5975806' Zone- 4 Tobin#932008,932082 ADL 25559,391580,25557,25558 TPI: x- 389690' y- 5976702' Zone- 4 16.Type of Completion(Describe): Total Depth: x- 404061' y- 5979305' Zone- 4 Cased and Perforated 17.Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19. Perforations: From To 7-5/8" 29.7# 6.875 20225 5675' MD to 5788' MD 18.Tubing Size Weight per foot, lb. I.D. in inches Set at ft. 2992'TVD to 3019'TVD 4-1/2" 12.6 3.908 5673'MD 20. Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): 5551'MD Dry Gas Dry Gas 0.58 (Gas gravity) 24a. Producing through: 24b.Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure(Pa): E Tubing ❑ Casing 65 F° 1406 psia @ Datum 3000' TVDSS psia 25. Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H2S: Prover: Meter Run: Taps: 3000' 0.58 0.04 0.98 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice Size(in.) Size(in.) psig Hw F° psig F° psig F° Hr. 1• X 1228 43 7 2• X 1217 48 7 3• X 1174 47 3 4. X 1137 47 7 5. X Basic Coefficient Flow Temp. No. (24-Hour) Pressure Gravity Factor Super Comp. Rate of Flow 4 hwPm Factor Factor Fb or Fp Pm Ft Fg Fpv Q1 Mcfd 1. 4877 2. 5652 3. 8081 4. 9776 5. JAN Temperature Tr z NE® JAN 2 62017 for Separator for Flowing No. Pr T Gas Fluid Gg G _ 1. 1.425 503 1.36 0.7842 2. 1.412 507 1.37 0.7939 3. 1.361 507 1.37 0.7975 Critical Pressure 862 8.2 4. 1.319 507 1.37 0.8023 Critical Temperature 369.67 69, 7 5. Form 10-421 Rev. 7/2009 CONTINUED ON REVERSE SIDERBDMS I.-i--JUL 1 3 2046m v.0 ate Pc 1280 Pc2 163840 •f 1406 pf2 1976836 No. Pt Pte Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Ps2 Pf2-Ps2 1. 1228 1508680 129720 1347 1813213 163263 2. 1217 1481266 157134 1335 1782619 194217 3. 1174 1377719 260681 1301 1691546 285290 4. 1137 1292982 345418 1272 1618726 358110 5. 25. AOF (Mcfd) 29600 n 0.71 Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Signedf--- Title ii,-G>Gu c.,49--A FAq Date'Y-/-(Zn DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ -I hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(TVD) L Length of flow channel, feet(MD) n Exponent(slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 7/2009 Side 2 Calculated TOC 41) ' • 8,986'MD/3,768'TVD HES Stage Tool 4,022'TVD(10,070'MD) Cement Retainer#2 Depth 19,705'MDI 6,281'TVD Calculated TOC i 1 18,737'MD/6,052'TVD / l$ j 11( 3j ti Ilk 7-5/8"Cement Retainer#1 Vie, 20,085'MD/6,370'TVD r„'" "*—_=s 7-5/8"Casing Shoe CD1-15PB2 20,223'MD/6,404'TVD 6.75"Sidetrack CD1.15 F81 20,114'MD/6,377'TVD TD 9-7/8"Hole 20,700'MD/6,514'TVD • ! Guhl, Meredith D (DOA) From: Haggerty-Sherrod,Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod@contractor.conocophillips.com> Sent: Thursday, January 05, 2017 8:52 AM To: Guhl, Meredith D (DOA) Subject: RE: CRU CD1-15, PTD 210-047, new TD box 4a and 4b values required Meredith, This required a bit of research, as this was done quite a while ago. Here are those new values for this new TD Of 20,114. Thanks for your patience 4a. Location of Well(Governmental Section): Surface: Top of Productive Interval: Total Depth: 1952'FNL, 1089'FEL,Sec 35,T12N, R5E, UM 4b.Location of Well(State Base Plane Coordinates,NAD 27): Surface: TPI: Total x- 403498 y- 5979209 Zone- 4 Depth: From:Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent:Tuesday,January 03, 2017 4:31 PM To: Haggerty-Sherrod,Ann (Northland Staffing Services)<Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: [EXTERNAL]CRU CD1-15, PTD 210-047, new TD box 4a and 4b values required Hello Ann, According to ConocoPhillips digital survey archive,the TD for CD1-15, PTD 210-047, is actually 20,114'. Please provide new Box 4a and 4b Total Depth values for this new TD. I will update the 10-407 forms already submitted. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W.7th Ave,Anchorage,AK 99501 1 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl( alaska.gov. 2 • • r r � - ^ D N no l f- o�W o a , y � r h COC7 0 z v+ i - CO N W z r- >-C (r -�9m O _y o a-Y u a u v, > o w 0 0 v 0 C I- 0 O 9 >•-• Q 0 -1 w co in in o o ° E m HC7 < _ u - V( ,-' Li) F O y aa, aui Ln _C C C o C 2 1 0 0 E -' co - CV1 NJ O - -O - Q a, Z < N M M c rn a, Q C) Z a o E o >, d' V 0 F- - 7 a, 4'' CO O 4-+ u _C L Q O 0 cO a, u wa J J J o o `o } W w_ wDO c F- LL LL LL v, a, E -0 v' O Q J J J o. O▪ C a, U) F- Q Q Q G Z Cr) a Z Z Z v ria -0 `^ u LL LL LL a, s Q, 0 a, to Y E 0 C C E a; a o - 0 ,, Q v -o U ►R-. 0 0 _0 C a, CD 1� �, a a > G O 'C C co 0o a`i CI �" H s s Q a, t u > u U U fr M O ci y N • N = _ 0 co.1 0 d w U = w a� m � > l' 11.u, ►Mi > 0 0 Aq ®00 d «_ x Or. zI x ° d w 0 >. RS 0 d O J J FE E W ,„b- 8-gpr),....vilf 0 CU a > > > o s Y v u W LL > c. a `o Ci U Y Y c 00 T 0. cc X n O w M Tt in u O N t` N O 0 0 0 A 0 0 0 0 0 0 as Gs 0 Tr QQ E® 1 j,, "o c Z ,+ r0 Cr g C c0 p o 0 o u �D 0 0 0 v) CIC N. Vi u Q� • O O @P • 0 0 If) N in a+ O• c C d u E az W U1 f0 - 'a, (a a) C�.� rZ E a QWyJ Y W cc c .� Q• NcL = Q 1- 1.1 N aco a, a0+ N Z r Ocu H 2 a Q N . cam N1 F •- C,• rc ` 0 a Q 'LSI)—D RECEIVED MAY 06 201',.) 5 WELL LOG TRANSMITTAL 4,00CC To: Alaska Oil and Gas Conservation Comm. May 4, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 5/t t/2 1 ER SCANNED RE: CAST-M/CBL-M: CD1-15 Run Date: 19-21-APR-2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1-15 Digital Data in DLIS format, Digital Log Image file 1 CD Rom 50-103-20619-00 CASTM - Advanced Cement Evaluation 1 Color Log 50-103-20619-00 Correlation Log 1 Color Log 50-103-20619-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:/ / ....e :t'''"C • PTP 210 —© 4-5 Loepp, Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, March 31, 2016 12:00 PM To: Huck, Drew; Loepp,Victoria T (DOA) Cc: Bettis, Patricia K(DOA) Subject: RE: CD1-15 Perforation Interval Follow Up Flag: Follow up Flag Status: Flagged Drew, We have reviewed the OH logs and there is no issue with extending the Perf interval down 8ft. as proposed. New interval will be 5675'-5788' MD Regards, Guy Schwartz SCANNED APR 2 0 2096 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(Guv.schwartz@alaska.gov). From: Huck, Drew [mailto:Andrew.Huck@conocoghillips.coml Sent: Thursday, March 31, 2016 11:09 AM To: Loepp, Victoria T(DOA); Schwartz, Guy L(DOA) Cc: Bettis, Patricia K (DOA) Subject: CD1-15 Perforation Interval Guy/Victoria, I wanted to let you know that our TCP guns on the end of our completion ended up 8' longer than anticipated for a total of 113' (vendor confused net and gross footage and we ended up with 8'of connections basically). The proposed perforation interval was 5675'-5780' MD and we spaced out to 5675'-5788' MD with the extra length. The top of the sand looks like a flooding surface while the base is simply a coarsening upward sequence and we still have neutron density crossover in the entire interval,which is why we just moved the guns down. Please let me know if you have any questions or have any issue with this. We'll likely be firing the guns in the next week or two. Regards, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. 1 •PTj7 74 —01-7- Loepp, e+:-Loepp, Victoria T (DOA) From: Huck, Drew <Andrew.Huck@conocophillips.com> Sent: Monday, March 21, 2016 10:05 AM To: Schwartz, Guy L(DOA); Loepp,Victoria T (DOA) Cc: Quick, Michael J (DOA) Subject: RE:CD1-15 CAST-CBL processed result Attachments: CD1-15_CAST-CBL_19MAR16_ProcessedLog.pdf Follow Up Flag: Follow up Flag Status: Flagged Hopefully this works...here's the full version. I had to try to reduce the file size to send it,which is why I didn't just send the full log Saturday. Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 qC1 ' 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, March 21, 2016 9:27 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Huck, Drew<Andrew.Huck@conocophillips.com> Cc:Quick, Michael J (DOA)<miche el.quick@alaska.gov> Subject: [EXTERNAL]RE: CD1-15 CAST-CBL processed result I looked this morning too. Looks better than old CBL but using the depth scale they showed makes it hard to see detail. Need the real log with 5"/100ft scale . 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(Guv.schwartz@alaska.gov). From: Loepp, Victoria T(DOA) Sent: Saturday, March 19, 2016 2:20 PM To: Huck, Drew Cc: Schwartz, Guy L(DOA); Quick, Michael J (DOA) Subject: Re: CD1-15 CAST-CBL processed result 1 • • Drew, Approval is granted to move forward with the completion, perforation and flow test. Further review of the logs will be necessary before any consideration is given to gas injection. Thanx, Victoria Sent from my iPhone On Mar 19, 2016,at 11:10 AM, Huck, Drew<Andrew.Huck@conocophillips.com>wrote: Victoria/Mike/Guy, Pleas find results of our CAST-M/CBL-M run on rig last night/this morning below. The first picture is the whole logged section and then there are 2 specific sections of interest below. The first thing I will note is that the area from 3100' - 4800' MD,while it shows good bond, almost certainly is a result of solids from likely both a combination of settling from the 11 ppg MOBM and collapse of the hole in the primarily shaley section above the "Halo sand". I've ignored this area below, although it may present some barrier given the evidence of good bond in such a long interval. This is similar to the result we got from the SCMT we ran pre-rig. <image011.png> The area from the stage collar to—5475' is consistent with the original 1-11/16"VDL result, showing decent cement and no strong evidence of channeling,with bond index up to 80%. Our proposed perforations are 5,675'-5,780', so this would at least give us "200' of ok cement above the top perforation. This seems like it should be a decent barrier on top of our sand. <image013.jpg> The area between 5,450' and 4,800' looks like channeled cement/solids—From left to right in the cement track(track 7), is high side, low side, high side,. This supports channeling on the high side and potentially low side as well,with the best bond on the sides of the hole. <image015.jpg> Please let me know your thoughts for the current operation—we can discuss future injection in the coming week if that's ok. We are proceeding ahead with abandoning the lower wellbore with our bridge plug at 8,000' and may be ready to run our completion tomorrow. Thanks, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) 2 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ��'��� DATE: 3/17/16 P. I. Supervisor FROM: Guy Cook SUBJECT: Kill Line - Doyon 142 Petroleum Inspector CRU CD1-15 Conoco/Phillips Alaska PTD 2100470; Sundry 316-083 3/16/16: I traveled to Doyon Rig 142, which was located on Colville River Unit CD1 pad (Alpine), to check to see if deficiencies that were found on an earlier inspection had been addressed'. I needed to confirm if targeted 90's had been installed on the kill line and check the gas alarms to make sure they are functioning properly. I walked down the rig to the locations where the new targeted 90's had been installed. All four targeted 90's are welded into place and look good. Took photos of each. I also had the rig electrician function/test all the gas alarms. The alarms worked as required with the strobes and audible alarms alerting at the proper gas concentrations. Attachments: Photos (4) SCANNED SEP 2 12616 Refer to AOGCC Inspection#bopBDB 160310104650 and attachment; BOPE test dated 3/8-3/9/16 2016-0316_BOP_Doyon 142_kill-line_gc.docx Page 1 of 3 • • ., _ , , ,al ‘ i .,, , ... ii BM,,,, , J . �,:w s" ' .,1,,,,...,4.'**- .c., ( „....10 e. ,. as F� ' II ,/ 7r ci Iii C N Oj'` r ' r / E i r Sy �f a O .. 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'...,44-44.. . • //1 „ __ 11111111110 SOF T4. y/, s THE STATE Alaska Oil and Gas 4 ;._ �— of e T e c T Conservation Commission A. 333 West Seventh Avenue Oj irT,., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "A-S7 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Drew Huck Sr. Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, "Halo"Undefined Gas Pool, CRU CD1-15 Permit to Drill Number: 210-047 Sundry Number: 316-083 Dear Mr. Huck: 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, /°- 41X-14 Cathy . Foerster Chair DATED this lay of March, 2016. RBDMS LL MAR 1 4 2016 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 4 2016 APPLICATION FOR SUNDRY APPROVALS ^ 20 AAC 25.280 1\001 ❑ 1.Type of Request: Abandon L Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate Q ' Other Stimulate ❑ Pull Tubing Q , Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool Q . Re-enter Susp Well Q' Alter Casing ❑ Other: Well Test El,' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑ 210-047 - 3.Address: Stratigraphic ❑ Service ❑ ,6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20619-00,-70,-71 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 CRU CD1-15 ` Will planned perforations require a spacing exception? Yes , 1 No WI - i 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025559;ADL025557;ADL391580;ADL025558• Colville River Field I"Halo"Undefined Gas 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): 20700' - 6514' - 19705' ' 6281' . 1294 19705',20085' none Casing Length Size MD ND Burst Collapse Structural Conductor 77' 16 114' 114' Surface 3076' 10.75 3112' 2393' Intermediate 20191' 7.625 20225' 6405' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): -N/A-see schematic N/A 3.5" L-80 2212' for proposed Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Cement Retainer 19705'MD/6281'TVD Cement Retainer , 20085'MD/6370'ND 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q, Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/8/2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0, WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Drew Huck @ 265-6828 Email Andrew.Huck@conocophillips.com Printed Name Drew Huck 265-6828 Title Sr.Drilling Engineer Phone ` Signature �^� '- 2' ' Date " 3 /Q_o I b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3)co-on Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: f I40 ' Q irh pr,z ed req qt:LO'0a"G( ✓r r4 20 Ait 2.f: 23fcd)(6) TiierceVi oil IYrm i i' f ,(41A,i1 11 i4 PCedvre5. r/grI: y f- 6 r r prtcd i mor„7h/yOGS eii Pall'1-i.v, repo v-7 `v- qZz - it -ntf 'C va- by cr t 1 oz-` to.q :46 C r-C k!s r w l c1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ L�c tin /to(,Z.0 L W t yr a 11 t 1 Yr-ci Spacing Exception Required? Yes ❑ No w7 Subsequent Form Required: /e) _ 9 O'q APPROVED BY Approved by: Cie7 COMMISSIONER THE COMMISSIONF4 Date: 3 -It- / . cR 1 Submit and Form 10-403 Revised 11/2015 Approved application i v t f Gtisof approval. � Attachments in Duplicate RBDMS t,,,- MAR 1 4 2016 ✓ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 1st,2016 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to recomplete suspended well CD1-15 (PTD#210-047). CD1-15 was originally drilled in 2010 targeting the Alpine sands to the east of CD1. While running intermediate casing,hole conditions prevented the casing from reaching bottom and it was eventually set 477'MD high. An unsuccessful attempt was made to clean out the hole below the casing shoe,which was followed by a kickoff plug being pumped in the openhole and an unsuccessful sidetrack attempt. A retainer was then set at 20,085',above the casing shoe,and tested to 2,500 psi. Cement could not be pumped through the retainer at a pressure of 2,000 psi(17 ppg),so the retainer was left in that state. A fmal unsuccessful sidetrack attempt was made by placing a whipstock on top of the retainer and milling a window. After this fmal failure,a second retainer was placed just above the window and pressure tested to 2,500 psi. An attempt to pump cement through the retainer was unsuccessful to a pressure of 2,000 psi(17 ppg)and the retainer was left in that state. A kill string was run and an Operational Shutdown Sundry was submitted(#310-182). The well was eventually suspended. The goal of the proposed workover covered in this application is to recomplete CD1-15 in a shallow sand that is likely gas bearing encountered during drilling of the intermediate hole at 5,680' MD. This sand will henceforth be referred to as the"Halo"sand. A bridge plug with at least 75' of cement will be placed below the"Halo"sand,the sand will be perforated,and a 4-1/2"completion will be run. The bridge plug and cement are intended to complete abandonment of the entire lower wellbore.1After the rig moves off,a test will be conducted to determine the ...._. .._....... productivity of the sand. The long term goal will be to use this well for gas supply during planned and unplanned shutdowns of the Alpine Facility and to provide gas for facility start up. If you have any questions or require any further information,please contact me at 265-6828,or Brett Packer at 265- 6845. Sincerely, 2a Drew Huck Drilling Engineer CPAI Drilling and Wells • • CD1-15 Recomplete Abandon Lower Wellbore and Recomplete Shallow"Halo"Gas Sand (PTD#:210-047) Current Status: This well is suspended with a 4-1/2"kill string and had originally been intended as an Alpine sand producer. Scope of Work: Pull the existing 4-1/2"kill string,abandon lower wellbore,and run new 4-1/2"tubing with a packer and TCP gun tail. General Well info: Well Type: Gas Well to Test"Halo"Sand MPSP: 1,294 psi using 0.01 psi/ft gradient(500 psi average pressure,0.65 gas gravity) Reservoir Pressure/TVD: Estimated+/-1,324 psi @ 2,994'TVD(8.5 ppg) Wellhead type/pressure rating: FMC Gen V, 11"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT TXIA—03/03/2016 to 3,000 psi Earliest Estimated Start Date: March 12',2016 Production Engineer: Ilnur Mustafin Workover Engineer: Drew Huck(265-6828/Andrew.Huck@cop.com) Pre-Rig Work 1. RU Coil: Circulate out OBM to 6,100' MD. Run CBL over third stage cement job. (Complete) 2. PT tbg &csg packoffs, FT LDS's. (Complete) 3. Perform CMIT to 3000 psi on TxIA to check casing integrity and integrity of retainer. (Complete) 4. Set BPV w/i 24 hrs of rig arrival. Workover Procedure 1. MIRU. 2. Pull BPV. Reverse circulate KWF. Obtain SITP &SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set two-way check, PT to 1,000 psi from below, ND tree, NU BOPE &test to 2,500 psi high/250 psi low. 4. Pull two-way check. 5. RU to pull tubing, MU landing joint, BOLDS's, POOH laying down kill string. 6. Make cleanout run to 8,200'to circulate out old 11 ppg MOBM and scrape the casing. 7. RU E-line and run advanced cement evaluation log from 6,100' MD to above the surface casing shoe at 3,000' MD. R'C vIGr,11 I tti /fa CZC C wki 8. RIH with bridge plug, set at 8,000'. 9. Tag bridge plug, circulate in 75'cement on top. 10. Circulate in CI packer fluid and rathole fluid. 11. POOH, L/D setting tool. RIH w/new tubing and packer with TOP string tail 13. Locate TCP string on depth. 14. Install space out pups below the hanger, MU hanger, MU control lines to hanger. 15. Set the packer. PT the IA to confirm packer is set. 16. PT the tubing for 10 min. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 17. Pull the landing joint, install two-way check. PT two-way check to 1,000 psi from below. 18. ND BOPE. NU tree. If BPV is installed, pull BPV& install tree test plug. Test tree. Pull test plug/two-way check. 19. Load the well with corrosion inhibited diesel. 20. Install BPV. 21. RDMO. • • CD1-15 Recomplete Abandon Lower Wellbore and Recomplete Shallow"Halo"Gas Sand (PTD#:210-047) Post-Rig Work 22. Pull BPV. 23. RU Slickline: Change SOV for DV. 24. Pressure up tubing to activate firing head and fire TCP guns. 25. Turn well over to operations. Well Test *Gas production from CD1-15 will be taken into the Alpine Central Facility(ACF). There is some expected excess flaring due to CD1-15 gas production depending on ACF conditions. If we are unable to get sufficient drawdown and rates to the ACF,we may use a portable flare to accomplish this goal. Set BH gauge 1. Flow to create depletion (and drawdown test if possible) • Targeted BH DP between 50 psi—200 psi, the rate is adjusted accordingly. • Expected rate below 10MMscfd, expected WHP between 850 psi— 1000 psi • Up to 7days for drawdown test up to radial flow and first boundary • Important to have continuous, stable flow before a clean shutin 2. Shut-in for build up test • Objectives: transient data to derive reservoir pressure, k*h, min reservoir extent • 30 days to confirm minimal extent(edge of sand to the West) 3. lsochronal test for deliverability Requires a minimum 4 different rates. Recommended rates below • Sequence 1: 4MMscfd from 8pm-8am (night time); shutin 8am-8pm • Sequence 2: 6MMscfd from 8pm-8am (night time); shutin 8am-8pm • Sequence 3: 8MMscfd from 8pm-8am (night time); shutin 8am-8pm • Sequence 4: at minimum 10MMscfd for 4days, depends on ACF conditions; shutin Retrieve BH gauge. Expected extra flaring, but not exceeding the limits, during CD1-15 well test to stabilize Inlet Separator Pressure: Sequence 1 -flaring: upto 2.5 MMscf/d Sequence 2-flaring: upto 4 MMscf/d Sequence 3-flaring: upto 5 MMscf/d Sequence 4-flaring: upto 7.5MMscf/d 2 i • CD1-15 Huck 3-10-2016 Proposed Schematic = _ --_ Conductor(Driven): Set @ 5#'114'R B0 elded �/ _ :...,.-._= I BP-6i ported nipple with SS control line and WRDP profile @ 150-3/4'e 5.5#,urfacg-80,BTCM 4 i sssv I +/-2,300'MD/2,075'TVD Set @+/-3,112'MD 12,393'TVD 1 _I- Chemical Injection Mandrel with ciM side pocket Injection valve @+/-2,350'MD/2,104 TVD 3rd Stage Calculated TOC 4,908'MD/2,811'TVD GLM , KBG-2 with DCK-2 set to shear at 2,500 psi @ 5,550' Packer @+/-5,600' production Tubing: j XN Ni ple w/3.725"no-go(3.813"packing bore) 4 1/z", 12.6#L-80,Hydril 563 HES Chamfered TCP Tubing tail Top C10 "Halo"Sand Perforations +/-2,993'TVD{5,682'MD) 5,675'-5,780' IV I Ir ,4 3'd Stage TAM Port Collar 5,872'MD I 3,039'TVD Bridge Plug @+1-8,000'MD >=75'cement on top TCP gun system dropped in rathole after firing 2nd Stage Calculated TOC 8,986'MD/3,768'TVD C --__/, -- , 11 ppg Mineral oil based mud PI.To be considered i / abandoned below 0 U CD 2nd Stage Cement Collar bridge plug 10,070'TVD/4,022'MD / 1st Stage Calculated TOC 0/ 0/ Retainer @ 19,705', unable to 18,737'MD/6,052'TVD / pump in at 17.0 ppg 6/12/10 Production Casino: r i Sidetrack attempt with whipstock 7-5/8",29 7,L-80,BTC-Mod Window=20,067'MD,TD=20,114'MD Set @ +1-20,225'MD/6,405'ND Stuck off bottom Retainer @ 20,085', unable to Ooehole ommuir pump in at 17.0 ppg 6/5/10 9-7/8"hole,TD 20,700'MD/6,514'ND I TD below K-1 marker,but above top Kuparuk � - Openholec TOC @ 20,292',drilled 4` out cement to this depth .0---, ( WNS • CD1-15 Conocot`hiflips -' ,., Well Attributes Max Angle&MD TD Alaska.lid _ N Wellbore API/UMField Name Well Status Incl(") MD(ftKB) Act Btm(ftKB) c�om•nalips`tJ' 501032061900 ALPINE PROD 78.02 7,616.39 20,700.0 ... '" Comment HIS(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Web Canfia:HORIZONTAL-CDt-15.4/26/20136:18:47AM SSSV:NONE Last WO: 36.13 6/15/2010 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 1/29/2013 Casing Strings — —Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd HANGER,31 CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Insulated 36" CasingDescription String0... StringID...To ftKB Set Depth f...Set Depth ND StringWt...String P P(ftKB) Pt ( M (TVD) •••String Top Thrd SURFACE 103/4 9.950 35.8 3,112.2 2,393.4 45.50 L-80 ETC _ ___ _ Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd WINDOW 8 7.000 20,067.0 20,081.0 6,369.3 Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(WD)...String Wt..String...String Top Thrd INTERMEDIATE 7 5/8 6.875 33.5 20,224.9 6,404.7 29.70 L-80 BTCM Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING 31/2 2.992 30.6 2,212.0 2,017.9 9.30 L-80 EUE KILL STRING Completion Details 1 ~+ . Top Depth III (TVD) Top Mel Noml... Top(ftKB) MU) (") Item Description Comment ID(In) 1 ' 30.6 30.6 021 HANGER FMC TUBING HANGER 4.500 34.5 34.5 021 XO Reduang CROSSOVER 4.5"x 3.5" ' 3.958 2,211.5 2,017.5 49.47 WLEG WIRELINE ENTRY GUIDE 2.992CONDUCTOR ,,,, 1 Other In Hole reline retrievable plugs,valves,pumps,fish,etc.) Insulated 114 37-114 TopDepth (WD) Top Incl t---7 Top(ftKB) ( B) (") Description Comment Run Date ID(in) {`= 19,705.0 6,281.1 76.58 RETAINER BAKER CMT RETAINER 6/12/2010 WLEG,2,217---- . 20,067.0 6,365.8 75.68 WHIPSTOCK WHIPSTOCK-ANCHOR BILLET-COULD NOT GET 61//2010 THRU CASING WINDOW 20,080.0 6,369.1 75.69 PACKER '6/7/2010 I 20,085.0 6,370.3 75.70 RETAINER BAKER CMT RETAINER 6/3/2010 Notes:General&Safety End Date Annotation 4/28/2010 NOTE:Cement plug set in open hole and back into conducter before drilling surface to avoid breach. 6/15/2010 NOTE:WELL SUSPENDED,KILL STRING IN PLACE,PREPPED FOR SIDETRACK;PBTD 19705' 6/182010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE, 11242010 NOTE:SET BPV IN TREE 38.3,112 4/172012 NOTE:REQUEST TO AOGCC TO EXTEND SUSPENDED STATUS RETAI18,705NER, liii f WHIPSTOCK, _ 25067 1.11 WINDOW. MIN 20,067-20,081 PACKER. 20.080 'it RETAIN0R. 13 rftI 20,065 PLUG,20,087 >uV�\\\\\\� aks I NTERMEDIATE, 34-25225 TD(CD1-15), 20,700 • • ' Loepp, Victoria T (DOA) From: Huck, Drew <Andrew.Huck@conocophillips.com> Sent: Thursday, March 10, 2016 5:38 PM To: Loepp,Victoria T (DOA) Cc: Johnstone, Sam; Mustafin, Ilnur Subject: RE:CD-15 Cement Bond Log Attachments: CD1-15_SCMT-Observations.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, I've tried to stick to the facts here. Our interpretation is that there appears to be an area of better bond, although not a full bond signal with the top around 5,460',with the proposed perforations 5,675'-5,780' MD (Port collar is at 5,872' MD). Additionally,there is some bond, almost certainly in part due to some solids (not necessarily cement)from 5,460' all the way to the surface casing shoe. We pumped a total of 38 barrels of 15.8 ppg Class G cement,which should've had a height of just under 1,000' MD with gauge hole. See attached for a more complete explanation. Our FIT on the surface casing shoe was 16.6 ppg(2,065 psi) and the estimated reservoir pressure is+/-1,300 psi, so there should be no possibility of breaking the shoe with reservoir pressure. Our OA will be monitorable—currently we see no evidence of communication from the pressures over the last 5 years,which have been stable. Please let me know if you have any questions or need anything else. We are planning on adding the cased hole run of a larger cement evaluation tool on rig, as previously mentioned. Regards, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From: Loepp,Victoria T(DOA) [.nailto:victoria.loepp@alaska.gov] Sent:Thursday, March 10, 2016 10:28 AM To: Huck, Drew<Andrew.Huck@conocophillips.com> Subject: [EXTERNAL]RE: CD-15 Cement Bond Log Drew, Thanx for reviewing the CBL with us. Please add acquisition of another cement evaluation log to the sundry procedure and send the modified procedure as well as the cement interpretation we talked about and other changes. 1 • • • GR 0 qAPI 100 feren 450 us 250 Above Free Pipe -32767.u-711111. :1001' Incl • CCLD C5TT CBL VDL- 0. 0 Dec 90 -1 V 1 us 250 0 mV 100 200 1200 0!a5 1 Zone 1 : 5,460 '-5 820' _ _i. �, I - i I I 1 I r + ! ` -5400- I I r I I I: L _ i _-75.94 I �I I I i it i q f ' €11 _ The first 50ft above the TAM port do not show bond, , I I 1 I (' —\ with similar characteristic of Zone 2, possibly 3500- 1=t f I .1 1 indicating a slight overdisplacement of the third __76.37 I JIM�. � i I stage, which is possible with the TAM port collar. _ I I ilir_ ' t The interval 5,460'-5,820'exhibits a lower CBL value -5600- i iF ��!� }}{j'!i ,#' -76.77 • + -._ }." £ 4..' than the rest of the logged section, indicating a better I - C bond of the solids outside, although not a full bond _ _ i�er�limmismiLis.� . signal. It is likely given the location that some of this is • • i 1 —1MIL1 3700- I„ F I + " tf . a result of cement. 38 barrels of 15.8 ppg Class G - 7636 cement was pumped through the stage collar,which _ — ar M� f::; vt. NF1 would be nearly 1,000'with gauge hole. I mS—..11'' ). I 1 s1 � i#a4 3$00 I I" I v��t .1 , saw The zone of interest and proposed perforations are . T633 _ I � � ;� `'- kt` 5,675'-5,780'. TAM Port @5872Jt i_ i i 1. -5900--76.25- • ' -. 1 I ii=1.1 111117111111111Mor-liu t I F 1F t 'I lit 1 r. • 0 0 qAPI 100 fgrgn, TT .. Above Free Pipe V (ft) 450 us 25 -32767.00 1:500( ' Inc! • CCLD C5TT CBL VDL-R1 1399410ft e DEG 96 -1 V 1 150 us 25 0 mV 100 200 1200 a sn 1 Zone 2: 3, 085 '-5,460' ibaf3100) i i- I ' ,,-t ,..- i ` - 3200~76.4.9 1 -IT -aMft -330D_76.96 _ 1400 1111 '�� 76.7 _ _ I 1. The values of CBL amplitude varies between 10 and =3500;77.15 4Iit: I 20 mV, which is higher than Zone 1, indicating less =3600 7746 • e bond.This drop of amplitude could be solids and _37002.-76.26 / { .A t,4 3800 -76.64 • r. hole collapse or could possibly include some mixed — _ ' •_• 3900 76.71 — >a- i :, mud and cement, especially near the bottom of the -4000 -,6.39 • It_ �K ' ! ,� interval,where some cement might be expected. -4100 76.45 E11111111S` ' Z sTOC with gauge hole and no mixing or channeling -4200 76.64 • E - ); would have been around 4,900' MD. -4300 7677 • I A #l,€ -4400 -76.45 1 i F ; Y� _ II - - III tIf 7613 r A marked amplitude increase is seen around 3,100' -.moo 76 • i`ii. _ .;, MD, which would correspond to the surface casing -4700 -76.26 i I t ' ,, ' shoe. This indicated relatively free pipe compared -4800 76.71 • r' 4: to the rest of the interval. 00-76.59 • 5000 76.96 8 E _ I I y -76.71 • =5100 -75.82 1 5200 I " 76A8 • 76.66 1 I 5300 _ I Iilljt 5400_75.94 • I I I !'• I 1.k -Amon] I I I I I ? '_ - • CD1-15 Recomplete • Abandon Lower Wellbore and Recomplete Shallow"Halo"Gas Sand (PTD#:210-047) Current Status: This well is suspended with a 4-1/2"kill string and had originally been intended as an Alpine sand producer. Scope of Work: Pull the existing 4-1/2"kill string, abandon lower wellbore,perforate and run new 4-1/2"tubing with a packer. General Well info: Well Type: Gas Well to Test"Halo"Sand MPSP: 1,294 psi using 0.01 psi/ft gradient(500 psi average pressure,0.65 gas gravity) Reservoir Pressure/TVD: Estimated+/-1,324 psi @ 2,994' TVD(8.5 ppg) Wellhead type/pressure rating: FMC Gen V, 11" 5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: Casing test passed—06/15/2010 to 2,500 psi Earliest Estimated Start Date: March 8th,2016 Production Engineer: Ilnur Mustafm Workover Engineer: Drew Huck(265-6828/Andrew.Huck@cop.com) Pre-Rig Work 1. RU Slickline: Drift tubing to 7,000' MD, or as deep as practical. Perform CMIT to 2500 psi on TxIA to check casing integrity and integrity of retainer. 2. RU Coil, slickline or E-line: Attempt CBL over third stage cement job. 3. PT tbg &csg packoffs, FT LDS's. 4. Set BPV w/i 24 hrs of rig arrival. Workover Procedure 5. MIRU. 6. Pull BPV. Reverse circulate KWF. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 7. Set BPV& blanking plug or two-way check, PT to 1,000 psi from below if possible, ND tree, NU BOPE &test to 2,500 psi high /250 psi low. 8. Pull blanking plug & BPV or two-way check. 9. RU to pull tubing, MU landing joint, BOLDS's, POOH laying down kill string. 10. RIH with bridge plug, set at 8,000' 11. Tag bridge plug, circulate in 75' cement on top. 12. POOH, L/D setting tool. "13. R/U TCP, RIH and shoot perforations (see proposed schematic), POOH s 14. RIH w/new tubing and packer Jo 15. Spot a balanced pill of corrosion inhibited brine in the Tbg & IA. 16. Install space out pups below the hanger, MU hanger, MU control lines to hanger. 17. Set the packer. PT the IA to confirm packer is set. 18. PT the tubing for 10 min. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 19. Pull the landing joint, install BPV or two-way check. PT BPV or two-way check to 1,000 psi from below. 20. ND BOPE. NU tree. If BPV is installed, pull BPV& install tree test plug. Test tree. Pull test plug/two-way check. 21. Load the well with corrosion fluid. 22. Install BPV. 23. RDMO. 1 • CD1-15 Recomplete 1 Abandon Lower Wellbore and Recomplete Shallow"Halo"Gas Sand • (PTD#:210-047) Post-Rig Work 24. Pull BPV. 25. RU Slickline: Change SOV for DV, Pull RHC/plug 26. Turn well over to operations. Well Test *Gas production from CD1-15 will be taken into the Alpine Central Facility(ACF). There is some expected excess flaring due to CD1-15 gas production depending on ACF conditions. If we are unable to get sufficient drawdown and rates to the ACF,we may use a portable flare to accomplish this goal. Set BH gauge 1. Flow to create depletion (and drawdown test if possible) • Targeted BH DP between 50 psi—200 psi, the rate is adjusted accordingly. • Expected rate below 10MMscfd, expected WHP between 850 psi— 1000 psi • Up to 7days for drawdown test up to radial flow and first boundary • Important to have continuous, stable flow before a clean shutin 2. Shut-in for build up test • Objectives: transient data to derive reservoir pressure, k*h, min reservoir extent • 30 days to confirm minimal extent(edge of sand to the West) 3. Isochronal test for deliverability Requires a minimum 4 different rates. Recommended rates below • Sequence 1: 4MMscfd from 8pm-8am (night time); shutin 8am-8pm • Sequence 2: 6MMscfd from 8pm-8am (night time); shutin 8am-8pm • Sequence 3: 8MMscfd from 8pm-8am (night time); shutin 8am-8pm • Sequence 4: at minimum 10MMscfd for 4days, depends on ACF conditions; shutin Retrieve BH gauge. Expected extra flaring, but not exceeding the limits, during CD1-15 well test to stabilize Inlet Separator Pressure: Sequence 1 -flaring: upto 2.5 MMscf/d Sequence 2 -flaring: upto 4 MMscf/d Sequence 3 -flaring: upto 5 MMscf/d Sequence 4 -flaring: upto 7.5MMscf/d 2 • S Roby, David S (DOA) From: Huck, Drew <Andrew.Huck@conocophillips.com> Sent: Thursday, March 10, 2016 3:25 PM To: Roby, David S (DOA) Cc: Loepp,Victoria T (DOA); Bettis, Patricia K (DOA);Johnstone, Sam; Mustafin, Ilnur Subject: RE: Sundry application for CD1-15 (PTD 210-047) Dave, See answers below: 1. On quick question on this sundry application. During the flow back period will this well be continuously metered through the CD1 well test system,or is there some other means of metering? a. vac ie goii`ig to metei tiiiOugn the well test system anu ilidy use a pvi iaoie testing service in series. 2. I'm not sure what this statement means(are the rates listed the expected rates or the maximum rates?), could you please clarify it for me? a. Dave,this is the amount that would be flared if necessary during each well testing sequence. 3. Also,am I correct in assuming you're asking for authorization to flare gas in accordance with 20 AAC 25.235 (d)(6),which states"upon application,the commission will, in its discretion,authorize flaring or venting of as for purposes of testing a well before regular production."? a. Yes, pursuant to the answer to#2,we are asking for authorization to flare gas if necessary at the Alpine Central Facility flare. Ambient temperature dependent,we may be able to process the gas rather than flare it or at least process a portion of the gas to limit our flare volumes. The amounts covered under question 1 a meant to represent maximum flaring amounts for each corresponding well test rate. Does this cover all of your questions? Regards, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent:Thursday, March 10, 2016 3:02 PM To: Huck, Drew<Andrew.Huck@conocophillips.com> Cc: Loepp, Victoria T(DOA)<victoria.loepp@alaska.gov>; Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Subject: [EXTERNAL]RE: Sundry application for CD1-15 (PTD 210-047) Drew, 1 • • I lied; I have a couple more questions. In well testing procedure you state "Expected extra flaring, but not exceeding the • limits,during CD1-15 well test..." I'm not sure what this statement means(are the rates listed the expected rates or the maximum rates?),could you please clarify it for me? Also,am I correct in assuming you're asking for authorization to flare gas in accordance with 20 AAC 25.235(d)(6),which states"upon application,the commission will, in its discretion,authorize flaring or venting of as for purposes of testing a well before regular production."? Dave Roby (907) 793-1232 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 Dave Roby at(907)793-1232 or dave.robv@alaska.aov. From: Roby, David S (DOA) Sent: Thursday, March 10, 2016 2:53 PM To: andrew.huck@cop.com Cc: Loepp, Victoria T(DOA); Bettis, Patricia K(DOA) Subject: Sundry application for CD1-15 (PTD 210-047) Drew, On quick question on this sundry application. During the flow back period will this well be continuously metered through the CD1 well test system, or is there some other means of metering? Regards, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 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 Dave Roby at(907)793-1232 or dave.robv@alaska.aov. 2 i Loepp, Victoria T (DOA) From: Huck, Drew <Andrew.Huck@conocophillips.com> Sent: Thursday, March 10, 2016 1:33 PM To: Loepp, Victoria T (DOA) Subject: RE:CD-15 Cement Bond Log Attachments: CD1-15 Proposed 3-10-16.pdf; CD1-15 General Procedure_Revised.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please find attached a revised procedure including the full size cement evaluation log as well as an updated schematic. I've put the changes in green on the general procedure. The major schematic difference is just in perforating the whole interval instead of select spots within the sand. We're still looking at options for the exact log type, so I did not specify at this time. I will send along the cement interpretation shortly, but wanted to get these to you as soon as possible. Please let me know if you have any questions. Regards, Drew Huck Drilling Engineer ConocoPhiilips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, March 10, 2016 10:28 AM To: Huck, Drew< °drew.Huck@conocophillips.com> Subject: [EXTERNAL]RE: CD-15 Cement Bond Log Drew, Thanx for reviewing the CBL with us. Please add acquisition of another cement evaluation log to the sundry procedure and send the modified procedure as well as the cement interpretation we talked about and other changes. Victoria From: Huck, Drew [mailto:Andrew.Huck@conocophillips.com] Sent: Wednesday, March 09, 2016 4:59 PM To: Loepp, Victoria T(DOA) Subject: RE: CD-15 Cement Bond Log 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report - Date Inspected: 04/12/15 Inspector: John Crisp Operator: CPAI Well Name: CD1-15 Oper. Rep: Bruce Richwine PTD No.: 2100470 - Oper. Phone: 659-7022 Location Verified? Yes Oper. Email: N2238( COP.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 06/14/14 • Date AOGCC Notified: 04/04/15 Sundry No.: 313-193 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 150 Photos Taken? Yes IA 350 OA 350 SCANNED JUN 0 8 2015 Condition of Wellhead: Clean and dry.Normal Alpine horizontal tree with SSV.Blind flanges where required. Condition of Surrounding Surface Location: Alpine CD1 Pad.Wellhouse on the well. Follow Up Actions Needed: Missing well sign Comments: Attachments: Photo courtesy of CPAI ✓ REVIEWED BY: (......).Insp.SuprvV123'!S Comm PLB 12/2014 2015-0412_Suspend_CRU_CD1-15jc.xlsx J tCt v F''' -� SR-3 'G bJQFc__ - 651-4-;" -r- Regg, James B (DOA) Actr eco 4-r z- iS From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Monday, April 27, 2015 3:34 PM `f To: Regg, James B (DOA) Cc: NSK Well Integrity Proj Subject: Inspection Follow up CD1-15 PTD 210-047 Attachments: CD1-15 Supension Inspection 10-404 04-12-15.pdf Jim, This email is to follow up on the suspended well inspection on CD1-15 (PTD 210-047). At the time of the inspection the well identification sign was missing. It is now in place as shown in the attached photo. I also attached a copy of the Suspension inspection 10-404 that was submitted earlier this month. ConocoPhillips Alaska, Inc ! 1' LPI NE WELL NAME: CD1-15 API NUMBER: 50-103-20619-03-00, -70, -71 SURFACE LOCATION: 322' FNL, 2805' FEL, Sec. 5, T11N, R5E, UM PERMIT TO DRILL: 210-047 CD1 -15 PTD 20210-047 • ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips ;. Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska t Let me know if you have any questions. Regards MJ MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 2 • STATE OF ALASKA ` AL, ...,KA OIL AND GAS CONSERVATION COL.._..SSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon E Repair w ell r Rug Perforations r Perforate r Other F Suspended Well Alter Casing r Pull Tubing r Stimulate-Frac Waiver Inspection r r Time Extension r Change Approved Program rOperat Shutdow n r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name 4 Well Class Before Work. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210-047 3.Address. 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20619-00-00 7.Property Designation(Lease Number). 8.Well Name and Number: ADL 0025559,0391580, 0025557, 0025558 C9..0 CD1-15 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): COLVILLE RIVER FIELD/ALPINE OIL 11.Present Well Condition Summary: CMT RETAINER- 19705' Total Depth measured 20700 feet Plugs(measured) CMT RETAINER-20085' true vertical 6515 feet Junk(measured) WHIPSTOCK-20067' Effective Depth measured 19705 feet Packer(measured) 20080 true vertical 6281 feet (true vertical) 6369 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 1640 630 SURFACE 3076 10 3/4 3112 2393 5210 2470 INTERMEDIATE 20191 7 5/8 20225 6405 6890 4790 Perforation depth Measured depth: NONEbAt4t4��i t\I\ 1 DIC RECEIVED True Vertical Depth: NONE APR 2 1 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 2212 MD,2018 TVD-KILL STRING AOGCC Packers&SSSV(type,MD,and TVD) PACKER-PACKER @ 20080 MD and 6369 TVD SSSV-NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run _ Exploratory r Development r Service Stratigraphic r 16.Well Status after work• Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt NA Contact MJ Loveland/Martin Walters Email n1878@cop.com Printed Name Title Well Integrity Project Signature /744/414/(t— Phone 659-7043 Date: 04-12-15 //7/— 5/6�is RBDMS.\\A APR 21 2015 A y�jc Form 10-404 Revised 10/2012 Submit Original Only ~v • • ConocoPh•I I ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 12, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Colville River Unit CD1-15 (PTD 200-047) Dear Commissioner Foerster: Enclosed please find the suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Colville River Unit well CD1-15 (PTD 200- 047). This well was suspended July 17, 2014. The following documents are attached: - 10-404 Sundry - Suspended Well Site Inspection Form - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or me at 659-7043 if you have any questions. Sincerely, /970//4—/V Martin Walters ConocoPhillips Alaska Well Integrity Projects Supervisor Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: COLVILLE RIVER UNIT CD1-15 Field/Pool: COLVILLE RIVER/ALPINE Permit#(PTD): 210-047 Sundry 313-193 API Number: 50-103-20619-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 7/17/2014 Surface Location: 322' FNL, 2805' FEL Section: 5 Township: 11N Range: 5E Nearest active pad or road: CRU CD1 Meridian: UMIAT Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Alpine CD1 Pad. Normal conditions Pad or location surface: Snow covered Location cleanup needed: No Pits condition: N/A Surrounding area condition: Clean Water/fluids on pad: N/A Discoloration, Sheens on pad, pits or water: N/A Samples taken: N/A Access road condition: Normal Photographs taken (#and description): (1) of well and wellhouse Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Clean. Good condition Cellar description, condition, fluids: Shallow, clean Rat Hole: N/A Wellhouse or protective barriers: Wellhouse present Well identification sign: Not present. Requested to be installed on tree Tubing Pressure (or casing if no tubing): 150 psi Annulus pressures: IA= 350 psi, OA= 350 psi Wellhead Photos taken (#and description): (3) of wellhead, tree, and cellar Work Required: Install wellhead sign Operator Rep (name and signature): Bruce Richwine AOGCC Inspector: John Crisp Other Observers: N/A Inspection Date: 4/12/2015 AOGCC Notice Date: 4/4/2015 _ Time of arrival: 8:00 Time of Departure: 8:30 Site access method: Road vehicle agg Conor i'hiilips a la WNS CD1-15 .w.ih Well Attributes fSt MO .TO, Inc. Wellbore API/UWI Field Name Well Status Ind(*) MD(ftKB) Act Btm(ftKB) Alaska. «,"x,M1,,1l,l„ 501032061900 ALPINE PROD 78.02 7,616.39 20,700.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date •••Well Confyo:HORIZONTAL-CD1-15.4126/20136.1847AM SSSV:NONE Last WO: 36.13 6/15/2010 Schematic-Actual Annotation Depth(ftKB) End Date jAnnotation Last Mod...End Date Last Tag Rev Reason:WELL REVIEW osborl 1/29/2013 Casing Strings — — -- Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)..String Wt...String... String Top Thrd HANGER,31 t /11 r CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Insulated 36" Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 103/4 9.950 35.8 3,112.2 2,393.4 45.50 L-80 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd WINDOW 8 7.000 _ 20,067.0 _ 20,081.0 6,369.3 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd INTERMEDIATE 75/8 6.875 33.5 20,224.9 6,404.7 _ 29.70 L-80 BTCM Tubing Strings Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING 31/2 2.992 30.6 2,212.0 2,017.9 9.30 L-80 EUE I KILL STRING Top Depth (TVD) Top incl Nomi... Top(ftKB) MB/ ("1 Item Description Comment ID(In) 30.6 30.6 0.21 HANGER FMC TUBING HANGER 4.500 s' 34.5 34.5 0.21 XO Redudng CROSSOVER 4.5"x 3.5" 3.958 CONDUCTOR 2,211.5 2,017.5 49.47 WLEG WIRELINE ENTRY GUIDE 2.992 Insulated 36', d ,,„.«...... 37-114 Top Depth (TVD) Top Incl ai Top(RKB) (ftKB) C) Description Comment Run Date ID(In) WLEG,2,212-- 19,705.0 6,281.1 76.58 RETAINER BAKER CMT RETAINER 6/12/2010 - 20,067.0 6,365.8 75.68 WHIPSTOCK WHIPSTOCK-ANCHOR BILLET-COULD NOT GET 6/72010 THRU CASING WINDOW 20,080.0 6,369.1 75.69 PACKER 6/7/2010 20,085.0 6,370.3 75.70 RETAINER BAKER CMT RETAINER 6/3/2010 End Date Annotation 4/28/2010 NOTE:Cement plug set in open hole and back into conductor before drilling surface to avoid breach. 6/15/2010 NOTE:WELL SUSPENDED,KILL STRING IN PLACE,PREPPED FOR SIDETRACK;PBTD 19705' 6/182010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE. A , 11/24/2010 NOTE:SET BPV IN TREE 36 3117 4/17/2012 NOTE:REQUEST TO AOGCC TO EXTEND SUSPENDED STATUS - I RETAIN19,705ER, t WHIPSTOCK 20.067 WINDOW, 20,067-20,081— PACKER, 20,080 RETAINER, 1 1 20,085 PLUG.20.087 NT MEDIATE, , 34-26225 (C01-15), 20,700 =Q _ / S c-Al) d' OH G , w ni gr ,� �i UW• •, Qt.. - 8V30�E o i 7 it a-'O oNlailne J,,,,,_-0c�(l,La +4/ G> _ SdWnd d:1V3 H L.- J 831V3H >o°_. '7 N 32ln1 JI I U 110 lJ3 °oSdi'0,6 +/ 071-Jili � z3ja �b ■a Hi3a i!! 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P without express written 'i consent of ConocoPhillips Alaska . 1.-i::) r 1-0 210-047 ® onocn )hillios � d K , I f ll,. . Is photo is copyrighted Conocc�Phillips Alaska, . and cannot be -aced or published . it )ut express writtenI iii I r int o-r , .TcoPhillips Alaska C D 1 .. 1% . , .. , ..,,,. / -ari � - _ , A• 41 lit 2 V' sfs rF §fin s � � - Pia210-07 ConocoPhilfips phyto is copyrigh::t. 7-' c Conoco ' , ‘‘-, c. and ca ,:::-.;i.'' = ''e ., - leased or . .'� e ithout ex • nsent of =n . nocoPhilli 4 . - r i. or' \,,,, 4'' * ' .\ r J l 6 „t ,i-„ ,,,, -.....,-,- . ,. t:, — {• �F y rs • 1� ',z ''.r !! f' (i' 'l I CD1 ,_5 PTD 210-047 ©ConocoPhillips � ,r �� Alaska, Inc. This photo is copyright: by ConocoPhillips Alask Inc. and cannot be released or published without express written consent of • .$4',.'It‘,. 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V O 0 J %-. s } I1 a E 0a 0 a E E I— f' v _ e"n C z W o C c >v 2 0 a`�i E CO d' m o E J7 Cl) j p N c c D J _ c o a` o o i3 i ICC c a ° co 0 z Eo > DZu0 o 2 a co z m v o C ® N N CO •0 O 0 ' 0 C w ; 0 ›- li CO I- c co d' '0 o (0 0 6 co E o 0� 3 N G) W M Gs a y 4' o C ` = N > E E Z 0 N d w mre .` O N to O f F N 0 0 c i N N m Z a o o d o 0 Q iti as 0 �, _ a) . c E 0 0 a o n. a m a E c, v LL E o o E m E E a 0 3 Z 0 0_ 0 0 0 c ° 0 0 RECEIVED STATE OF ALASKA ,JUL 1 7 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND SCC la Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑✓ 1b Well Class' 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service 0 StratigraphicTest❑ 2 Operator Name5.Date Comp.,Susp, 12 Permit to Drill Number. ConocoPhillips Alaska, Inc. orAband June 14,2010 210-047/313-193 3 Address. 6.Date Spudded 13.API Number P.O.Box 100360,Anchorage,AK 99510-0360 April 28,2010 50-103-20619-00/-70/-71 4a Location of Well(Governmental Section): 7.Date TD Reached 14.Well Name and Number Surface: 322'FNL,2805'FEL,Sec.5,T11N, R5E, UM May 12,2010 CD1-15,CD1-15PB1,CD1-15PB2 Top of Productive Horizon: 8. KB(ft above MSL): 56'RKB 15.Field/Pool(s). not attained GL(ft above MSL): 19.5'AMSL Colville River Field Total Depth: 1847'FNL,528'FEL,Sec. 35,T12N, R5E, UM 9.Plug Back Depth(MD+ND) 19705'MD/6281'TVD Alpine Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27) 10.Total Depth(MD+ND) 16.Property Designation Surface: x-385901 y- 5975806 Zone-4 20700'MD/6515'ND ADL 25559,391580,25557,25558 TPI: x-not attained y- not attained Zone-4 11.SSSV Depth(MD+ND) 17.Land Use Permit Total Depth: x-404060 y- 5979307 Zone-4 none Tobin#932008,932082 18 Directional Survey Yes ❑✓ , No❑ 19.Water Depth,if Offshore 20.Thickness of Permafrost MD/TVD (Submit electronic and printed information per 20 AAC 25 050) N/A, (ft MSL) 1601'MD/1556'TVD 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 GR/Res not applicable 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" pre-installed 10.75" 45 5# L-80 36' 3112 36' 2394' 13 5" 582 sx Arcticset Lite,297 sx Class G 7.625" 29.7# L-80 34' 20225 34' 6405' 9.875" 305 sx Class G,200 sx Class G,184 sx CI G 24.Open to production or injection'? Yes ❑ No ❑ 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/ND) 3.5"kill string 2212' 20080'MD/6369'ND COMPLETION none /Z� G� I 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC Was hydraulic fracturing used during completion? Yes No Q DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cement retainer @ 19705'MD 36 bbls 17ppg cement 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) not applicable Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q . 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 NONE RBDMS JUL 17 2014 Form 10-407 Revised 10/2012 ��F ?j / /\' CONTINUED /VERSE ?K /411 (y Submit original only 29. GEOLOGIC MARKERS(List all formations and mais encountered). 30 FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1601' 1556' needed,and submit detailed test information per 20 AAC 25.071 C-30 3209' 2417' C-20 4730' 2769' C-10 5675' 2993' K-3 9011' 3774' K-2 10005' 4007' Albian 97 17977' 5874' Albian 96 18880' 6086' HRZ 19820' 6308' Kalubik 20382' 6441' Lower Kalubik / 20608' 6493' N/A CD1-15PB1 total depth 20700' 6515' CD1-15PB2 total depth 20014' 6377' Formation at total depth' not attained 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 1y� Contact. J G.Samuell @ 263-6309 Email: John.G.Samuell@conocophillips.com Printed Name G. L.Alvord Title: Alaska Drilling Manager Signature A- £ Phone 265-6120 Date 7(17(z61(4- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation. Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: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 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 i WNS CD1-15 ConocoPhillips ill Well Attributes Max Angle 8 MD TD Alaska Inc Wellbore APIIUWI Field Name Well Status Mel(°) MD(ftKB) Act Btm(ftKB) coriomiPtwepa 501032061900 ALPINE PROD 78.02 7,616.39 20,700.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(It) Rig Release Date ••-Well Contig:HORIZONTAL-CD1-15,42620136:18:47 AM SSSV:NONE Last WO: 36.13 6/15/2010 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 1/29/2013 Casing Strings _ CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 s-1-40ng stria g Top drd HMK3ER,37 t r 9 DescriptionStringString ( ) P ( P ( ) 9 H-00 Welded Casing 0... ...Top(ftKB) Set Depth ...Set a ... ria .1111- Insulated 36" —'° Casing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(ND)...String WE..String...String Top Thrd SURFACE 103/4 9.950 35.8 3,112.2 2,393.4 45.50 L-80 BTC Casing Description String 0... String ID...Top MKS) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd WINDOW 8 7.000 20,067.0 20,081.0 6,369.3 I Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WE..String...String Top Thrd INTERMEDIATE 75/8 6.875 33.5 20,224.9 6,404.7 29.70 L-80 BTCM Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt..String...String Top Thrd TUBING 31/2 2.992 30.6 2,212.0 2,017.9 9.30 L-80 EUE KILL STRING il :'1 / Completion Details Top Depth (ND) Top Incl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 30.6 30.6 021 HANGER FMC TUBING HANGER 4.500 1 34.5 34.5 021 XO Reducing CROSSOVER 4.5"x 3.5" 3.958 t 2,211.5 2,017.5 49.47 WLEG WIRELINE ENTRY GUIDE 2.992 CONDUCTOR Other In Hole(Wireline.retrievable plugs,valves,pumps,fish,etc.) Insulated Top Depth (ND) Top Incl Top(ftKB) (ftKB) (°) Description Comment Run Date ID(In) 19,705.0 6,281.1 76.58 RETAINER BAKER CMT RETAINER 6/12/2010 WLEG,2.212 - 20,067.0 6,365.8 75.68 WHIPSTOCK WHIPSTOCK-ANCHOR BILLET-COULD NOT GET 6/7/2010 THRU CASING WINDOW 20,080.0 6,369.1 75.69 PACKER 6/7/2010 20,085.0 6,370.3 75.70 RETAINER BAKER CMT RETAINER 6/3/2010 Notes:General&Safety End Date Annotation 4/28/2010 NOTE:Cement plug set in open Isle and back into conducter before drilling surface to avoid breach. 6/15/2010 NOTE:WELL SUSPENDED,KILL STRING IN PLACE,PREPPED FOR SIDETRACK;PBTD 19705' SURFAL 6/182010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 CE,__ /I 11242010 NOTE:SET BPV IN TREE 36-3112 4/17/2012 NOTE:REQUEST TO AOGCC TO EXTEND SUSPENDED STATUS RETAINER, 19.705R, )1 I pj WHIPSTOCK, 20,067 WINDOW, 20,067-20,081 PACK0R, 20.080 RETAINER, 29085 PLUG,20087 NTERMEDIATE, 34_20.2251 TD(C01-15), 20.700 ConocoPhiIIips Time Log & Summary We/Mew Web Reporting Report Well Name: CD1-15 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 4/27/2010 5:00:00 PM Rig Release: 6/15/2010 6:00:00 AM Time Logs - Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04/26/2010 24 hr Summary Began Moving Rig f/CD3 to CD1 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Separate Modules,Skid Floor-Tow Motors, Pits,&Pipe Shed w/Peak- Tow Ball Mill w/ASRC-Mobilize Sub Base Under Own Power-2 Miles f/CD3 @ Midnight 04/27/2010 Continue to Move Rig t/CD1 -Spot Sub Base-Spot&Connect Ball Mill,Motor and Pit Complexes-Take On Spud Mud-Connect High Line Power-N/U Riser 00:00 06:00 6.00 0 0 MIRU MOVE TRNS P Continue to Move Rig to CD1 -Ball Mill @ CD1 -Motors, Pits and Pipe Shed Being Towed by Peak to CD3/CD2 Interchange(9 Miles)-Sub Base Moving Under Own Power(6 Miles) 06:00 07:00 1.00 0 0 MIRU MOVE OTHR P Stop for Peak Crew Change and Refueling 07:00 12:00 5.00 0 0 MIRU MOVE TRNS P Continue to Move Rig t/CD1 12:00 22:00 10.00 0 0 MIRU MOVE RURD P Connect Motor and Pit Complexes- Remove Wind Walls-Spot Sub Base Over Well-Jack Floor Into Position-Spot Pits/Motors-Spot Pipe Shed-Hook Up Air/Steam and Water Lines-Hook up Service& Electrical Lines-Spot and Connect Ball Mill-Route and Connect High-Line Power Cable-Take On Spud Mud-Rig on High Line Power @ 2030-Rig Accept @ 1700 22:00 00:00 2.00 0 0 MIRU WHDBO NUND P N/U Riser and Load Pipe Shed w/5" HWDP&DP 04/28/2010 P/U 30 Stands of 5'DP,8 Stands of 5'HWDP,8"NMFDC's&Jars-M/U BHA#1 t/98'MD-PT Lines t/ 3500 Psi-Fill Riser and Check for Leaks(80 Bbl Loss)-Drill f/114'-140'MD-Stopped Drilling o Secure Conductor and Cure Lost Returns-L/D BHA#1 -Lay 20 Bbl, 15.8 PPG AS1 Cement Plug f/140'-46'MD- WOC While Welding Conductor Su•ports 00:00 07:30 7.50 0 0 SURFA( DRILL PULD P P/U 30 Stands of 5"DP,8 Stands of 5'HWDP,7 3/4"Jars and 8" NMFDC's 07:30 07:45 0.25 0 0 SURFA( DRILL RURD P R/U HES E-Line Unit 07:45 10:30 2.75 0 0 SURFA( DRILL PULD P M/U BHA#1 t/98'as Follows: Bit, Motor w/ABI, IBS, EM, Index Sub, Antenna Sub,DGR, EWR-4,HCIM, NMFS, UBHO 10:30 11:00 0.50 0 0 SURFA( DRILL SFTY P Hold-Pre-Spud Meeting w/Crew Page 1 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:00 13:30 2.50 0 0 SURFA( DRILL CIRC P Pt Surface Lines t/3500 Psi-Fill Riser and Check for Leaks-Pumped 70 Bbls 100 Vis,20 PPB Gel Mud, No Leaks, No Returns-Continue Filling Hole,No Returns-Pumped 32 Bbl 300 Vis Mud w/25 PPB Nut Plug,then 10 Bbls 300+Vis Mud- Regained Returns-Lost 80 Bbls to the Hole-Shut Down, Monitor Well (Slight Static Losses) 13:30 14:00 0.50 0 140 SURFA( DRILL DDRL P M/U NMFDC's and Drill f/114'-140' MD-Stop Drilling Due to Mud Ring Around Conductor-S/B NMFDC's 14:00 16:00 2.00 140 0 SURFA( DRILL PULD T LID BHA#1 to Work on Conductor 16:00 19:45 3.75 0 140 SURFA( DRILL RURD T P/U 4 Jts 3 1/2"Tubing-Excavate Cellar for Welding Conductor Supports-R/U to Cement Conductor Shoe 19:45 20:00 0.25 140 140 SURFA(CEMEN"SFTY T PJSM on Laying Cement Plug in Wellbore and Conductor 20:00 20:45 0.75 140 0 SURFA(CEMEN"CMNT T Lay Cement Plug as Follows: Pumped 25 Bbls SAPP/Water Pill- 55 Bbls Water-20 Bbls 15.8 PPG AS1 Cement-1.5 Bbls Wash Water -R/D Cement Hose-Pulled Tubing f/ Cement-Pumped 5 Bbls Wash Up to Clear Cement f/Lines-LAD Cement String-CIP 2045 20:45 00:00 3.25 0 0 SURFA(CEMEN"WOC T Wait on Cement-70 Bc Thickening Time 2:56-SIMOPS:Weld Conductor Support 04/29/2010 Continue to WOC and Weld Supports on Conductor-Clean Out Cement t/140'MD-Drill t/150'MD w/ Water-Monitor Well(9 BPH Static Losses)-M/U BHA#2-Displace to Spud Mud and Drill U 160'MD- Monitor Well(2 BPH Static Losses)-Continue to Drill Surface Hole U 1,402'MD 00:00 00:45 0.75 0 0 SURFA( DRILL WOC T Continue to WOC and Weld Conductor Supports 00:45 01:15 0.50 0 0 SURFA( DRILL PULD T M/U Bit,Motor,XO and HWDP 01:15 02:00 0.75 0 0 SURFA(CEMEN"DRLG T Clean out Cement f/50'to 140'MD- Drill 10'New Hole w/Water 02:00 02:30 0.50 0 0 SURFA( DRILL OWFF T Monitor Well on TT-Static Losses 9 BPH-POOH 02:30 04:30 2.00 0 0 SURFA( DRILL PULD T M/U BHA#2-Orient UBHO and Index Sub- 04:30 05:00 0.50 0 0 SURFA( DRILL CIRC T Dispalce U Spud Mud and Drill 10' New Hole-Monitor Hole for Static Losses(2 BPH) 05:00 05:30 0.50 0 0 SURFA( DRILL OTHR T Discusses Results w/Town Engineer -Wait on Orders 05:30 12:00 6.50 140 597 SURFA( DRILL DDRL P Drill 13 1/2"Hole w/Motor U 597'MD Taking E-Line Gyro's Every Stand ADT 2.4,AST 1.16,ART 1.24 P/U 110, Rot 110, S/O 110 Torque On/Off 4.5/4 WOB 2-20/RPM 40 450 GPM @ 730 Psi Page 2 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 597 1,402 SURFA( DRILL DDRL P Drill 13 1/2"Hole w/Motor t/1402' • MD-Took E-Line Gyro's t/1006'MD ADT 5.55,AST 3.2,ART 2.35 P/U 134, Rot 130,S/O 127 Torque On/Off 8/6.5 WOB 10-35/RPM 50 500 GPM @ 1160 Psi 04/30/2010 Drill f/1,402'-3,122'MD-CBU X2-Perform Wiper Trip to the Top of HWDP(932'MD)-RIH t/3,122'MD- Circ&Condition Mud for Trip 00:00 12:00 12.00 1,402 2,628 SURFA( DRILL DDRL P Drill 13 1/2"Hole w/Motor from 1402' MD to 2628'MD 2246'ND ADT 9.42 hrs.,AST 3.43 hrs.,ART 5.99 hrs. P/U 138, Rot 125, S/O 125 Torque On/Off 8.5/7.5 K ft/lbs WOB 25-35/RPM 55 700 GPM @ 2560 Psi No losses to well recognised 12:00 17:30 5.50 2,628 3,122 SURFA( DRILL DDRL P Drill 13 1/2"Hole w/Motor t/3,122' MD(2,396'ND)TD ADT 4.3,AST 1.6,ART 2.7 P/U 132,S/O 118, Rot 125 Torque On/Off 8/6.5-RPM 60 700 GPM @ 2650 Psi WOB 20-30 17:30 18:15 0.75 3,122 3,122 SURFA( DRILL CIRC P CBU X2 @ 700 GPM w/2250 Psi and 60 RPM 18:15 23:30 5.25 3,122 3,122 SURFA( DRILL WPRT P Perform Wiper Trip-BROOH @ 650-500 GPM w/2100-1100 Psi- OWFF(Static)-RIH t/3,122'on Elevators(No Tight Spots Encountered) 23:30 00:00 0.50 3,122 3,122 SURFA( DRILL CIRC P Circ&Cond Mud Pumping 700 GPM w/2400 Psi and 60 RPM 05/01/2010 C&C Mud f/3122'to 2827',POOH to 1022'(Tight @ 1067'&1056'),Circ @ 1022', POOH&L/D BHA,Rig& run 10-3/4"csg to 3112'(CBU @ 1206,2162'), Rig cmt head&C 7C Mud,Cement 10-3/4"csg w/468.0 bbls lead&61.4 bbls Tail displace cmt w/20 bbls fresh water&271.4 bbls mud, Bump plug w/1200 psi, Had full circ thru out job, Had 2229 bbls good cmt to surface,CIP @ 22:15 hrs 5/1/10, Rig Dn cmt heat, Flush riser, L/D landing jt.&csg equi•. 00:00 01:15 1.25 3,122 2,827 SURFA( DRILL CIRC P Circ&Cond.Mud f/Running 10-3/4" Casing at rate of 700 gpm @ 2430 psi,60 rpm,Stand back 1 stand every 30 min. 01:15 03:15 2.00 2,827 1,022 SURFA( DRILL TRIP P POOH f/2,827'to 1,022'(Tight @ 1,067'&1,056'),Monitor well- Static. 03:15 03:45 0.50 1,022 1,022 SURFA( DRILL CIRC P Circ Btm up at rate of 500 gpm @ 1140 psi. 03:45 04:45 1.00 1,022 75 SURFA( DRILL TRIP P Continue to POOH to HWDP, Monitor well-Static,Stand back HWDP&Flex Collars. Page 3 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:45 07:15 2.50 75 0 SURFA( DRILL PULD P PJSM, Lay down BHA-UBHO, HCIM,Antenna sub, Index sub, Break bit, Lay down Stab&Mud motor,Clean&Clear rig floor. 07:15 08:45 1.50 0 SURFA( CASING RURD P PJSM, Rig to run 10-3/4"csging, Static mud losses 2.5 BPH while rigging up. 08:45 13:00 4.25 0 1,206 SURFA( CASING RNCS P PJSM, Run 10-3/4"casing shoe track,Check same, RIH to 1206' (Work thru tight spots @ 284',450'). 13:00 13:30 0.50 1,206 1,206 SURFA(CASING CIRC P Circ btm's up(Had mild packing off- then freed up),Stage pumps up to 5 bpm @ 370 psi, Had full returns. 13:30 14:45 1.25 1,206 2,162 SURFA(CASING RNCS P Continue to run 10-3/4"casing to 2162'with no problems. 14:45 15:30 0.75 2,162 2,162 SURFA( CASING CIRC P Circ btm's up,Stage pumps up to 5 bpm @ 420 psi. 15:30 16:45 1.25 2,162 3,074 SURFA(CASING RNCS P Continue to run 10-3/4"casing to 3074'with no problems, Had good displacement while running casing. 16:45 17:30 0.75 3,074 3,112 SURFA( CASING RURD P Make up Hanger&Landing jt., Land casing @ 3112', Rig up Dowell Cmt head. 17:30 19:30 2.00 3,112 3,112 SURFA( CEMEN"CIRC P Circ&Cond.Mud for cement,Stage pumps up to 7 bpm @ 340 psi, Reciprocate casing 30'while circ Up 198K, Dn,150K.. 19:30 00:00 4.50 3,112 3,112 SURFA(CEMEN"CMNT P PJSM,Pump 75 bbls Nut plug maker mud followed by 35 bbls Biozan viscous spacer with rig,Turn over to Dowell&pump 5 bbls fresh water, Test lines to 3000 psi-OK, Drop Btm Plug, Mix&Pump 50 bbls 10.5 ppg MudPUSH II at rate of 6.0 bpm @ 175 psi, Followed by 468.0 bbls(582 sxs)10.7 ppg ARCTICSET Lite lead cement at rate of 6.4 bpm @ 160 psi, Followed by 61.4 bbls(297 sxs) 15.8 ppg Class"G"Tail cement at rate of 4.7 bpm @ 150 psi,Shut down, Drop Top Plug, Displace cement w/20 bbls fresh water& 271.4 bbls 9.9 ppg mud at rate of 7.0 bpm @ 350 to 840 psi,Slowed rate to 3 bpm @ 620 psi for last 10 bbls, Bump plug w/1200 psi, Had full circ thru out job, Had 229 bbls good cement to surface,C.I.P.@ 22:15 hrs 5/1/10. 05/02/2010 N/D Riser, N/U Wellhead&BOPE,Slip&Cut drlg line 250', P/U 5""S"&"G"pipe&stand back in drk. 00:00 01:30 1.50 SURFA(WHDBO NUND P PJSM,Nipple down riser. 01:30 02:45 1.25 SURFA(WHDBO NUND P Remove slip lock assembly, Insatll Wellhead&Test to 1000 psi-OK. 02:45 04:30 1.75 SURFA(WHDBO NUND P PJSM, Nipple up BOPE, Pick up Mouse hole. Page 4 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 07:00 2.50 SURFA( RIGMNT SLPC P PJSM,Slip&cut drilling line 250', Service top drive. 07:00 17:00 10.00 SURFA(WHDBO PULD P PJSM, Pick up 40 stands"S"Drill pipe from pipe shed&stand back in derrick. 17:00 17:45 0.75 SURFA(WHDBO SVRG P Service rig. 17:45 21:00 3.25 SURFA(WHDBO PULD P Continue to pick up 5"drill pipe via mouse hole&stand back in derrick. 21:00 22:00 1.00 SURFA( DRILL OTHR T Lost High line power,Wait on CD1 electricians to get rig back on high line power. 22:00 00:00 2.00 SURFA( DRILL PULD P Continue to pick up 5"Drill pipe (Total of 54 stands"S"pipe&109 stands"G"pipe),Total of 193 stands in drk(Will single in w/22 more stands"G"with BHA) 05/03/2010 Finish P/U 5"DP, Rig&test BOPE to 250/3500 psi Hydril to 250/2500 psi test waived by AOGCC Jeff Jones, Pull test plug,Thaw out Kelly hose, Retest Top drive IBOP to 250/3500 psi, P/U BHA&shallow test same,Single in to 1507',Circ&check pressure, Drop ball&open Well Commander sub,Close same, RIH to 2892', Rig to test 10-3/4"csg,Circ BTU. 00:00 00:30 0.50 0 0 SURFA( DRILL PULD P PU and stand back last 9 joints of 5" G drill pipe 00:30 06:00 5.50 0 0 SURFA(WHDBO BOPE P Set lower test plug and fill stack with water-RU and test BOPE-Tested choke,kill, manifol,top drive and floor safety valves to 250/3500 psi- Annular preventor to 250/2500 psi- Performed Accumulator test- AOGCC rep.Jeff Jones waived witnessing tests. 06:00 08:00 2.00 0 0 SURFA(WHDBO BOPE T Attempted to pull test plug from wellhead-tight.Tried with both tuggers-no good-Pulled 20K with top drive 4"movement-RU and displace stack to mud-wash top of test plug through drill pipe @ 8 bpm- pulled test plug with top drive-5-10K using bail kickers to rock test plug- inspected test plug-recovered a hand full of small mill cuttings off of plug body observed very minor scratching to test plug body 08:00 08:45 0.75 0 0 SURFA(WHDBO OTHR P MU stack washer sub-RIH carefully to 36'-wash up through stack- made several pases across ram cavities-LD wash sub 08:45 09:15 0.50 0 0 SURFA(WHDBO OTHR P Install long wear bushing into • wellhead-LD running tool 09:15 10:15 1.00 0 0 SURFA( RIGMNT RGRP P Thawed small ice plug from top drive circulating hose-MU hose to top drive 10:15 11:00 0.75 0 0 SURFA(WHDBO BOPE T Retest upper and lower top drive IBOP valves-250/3500 psi-good Page 5 of 39 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 11:00 12:00 1.00 0 0 SURFA( DRILL PRTS P Test mud lines from pumps to top drive IBOP valve-pop off sheared on first attempt @ 4200 psi-pinned pop offs up from 4600 psi to 5200 psi- obtained 4400 psi test of mud lines- repinned pop offs to 4600 psi for drilling mode. 12:00 16:00 4.00 0 101 SURFA( DRILL PULD P MU BHA#3-9 7/8"PDC bit, Geo-Pilot 7600,flex collar, DGR, EWR-P4, NM Stab, PWD, HCIM, SDL,CTN, POS Pulsur, -plug in and upload tools-ALD failed competency test 16:00 17:15 1.25 101 101 SURFA( DRILL PULD T Change out ALD&CTN collars. 17:15 18:15 1.00 101 124 SURFA( DRILL PULD P Up load MWd tools, Continue to pick BHA,Shallow test MWD tools. 18:15 20:15 2.00 124 214 SURFA( DRILL PULD P PJSM, Load RA Sources, Pick up Flex Collars 20:15 21:00 0.75 214 1,507 SURFA( DRILL PULD P Single in w/5""G"pipe from pipe shed to 1507'. 21:00 22:00 1.00 1,507 1,507 SURFA( DRILL DHEQ P Break circ&check pressures 167 spm/700 gpm @ 2240 psi,Drop ball&open Well Commander sub, Recheck pressures 167 spm/700 gpm @ 140 psi, Drop Closing ball& Close Well Commander sub, Recheck pressures 167 spm/700 gpm @ 2250 psi. 22:00 23:00 1.00 1,507 2,892 SURFA( DRILL PULD P Continue to Single in w/5""G"pipe from pipe shed to 2892'. 23:00 00:00 1.00 2,892 2,892 SURFA( DRILL CIRC P Rig to test 10-3/4"casing,Circ Btm's up. 05/04/2010 Tested 10 3/4"casing to 3500 psi-Washed down to top of cmt @ 3000'-Clean out shoe track,drilling FC @ 3025'&FS @ 3109'-Cleaned out rat hole to 3122'-Drilled 20'new hole to 3142'-Circ&performed LOT to 17.0 ppg EMW-Changed over f/spud mud to 9.6 ppg LSND-Drilled 9 7/8"hole w/Geopilot f/3142'to 5079' 00:00 01:00 1.00 2,892 2,892 SURFA( DRILL PRTS P RU and test 10 3/4"casing to 3500 psi for 30 minutes RD&blow down lines 01:00 01:45 0.75 2,892 3,025 SURFA(CEMEN-COCF P Wash and ream from 2,892'clean out cement from 3,000'to 3,025' (FC)-650 gpm/2230 psi/60 rpm @ 8500 ft/lbs. 01:45 05:45 4.00 3,025 3,122 SURFA(CEMEN"DRLG P Drill out FC,cement FS and clean out rathole to 3122'-650 gpm/2230 psi/60 rpm @ 8500 ft/lbs. 05:45 06:00 0.25 3,122 3,144 SURFA( DRILL DDRL P Drill 9 7/8"hole from 3,122'to 3,142' MD 2,401'ND 660 gpm/2170 psi/70 rpm @ 8500 ft/lbs. 10K WOB 06:00 06:30 0.50 3,144 3,144 SURFA( DRILL CIRC P Circulate and condition mud for FIT. 650 gpm/2150 psi/60 rpm @ 8000 ft/lbs MW in &out @ 9.6 ppg Page6of39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06:30 07:00 0.50 3,144 3,144 SURFA( DRILL LOT P RU and perform LOT-Determined leak off of 17.0 ppg EMW with 9.6 ppg mud and 920 psi applied surface pressure.-RD lines 07:00 12:00 5.00 3,144 3,558 INTRM1 DRILL DDRL P Drilled 9 7/8"hole with GeoPilot from 3,142"to 3,558'MD/2,497'TVD ADT 3.56 hrs,5-15K wob, 140 rpm's 750 gpm at 2240 psi. Torque on/off btm 10K/7Kft-lbs PUW 140K SOW 112K RotWT 125K 9.6 ppg MW, ECD 10.28 ppg. 12:00 00:00 12.00 3,558 5,079 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/3558'to 5079'MD 2849'TVD ADT-10.8 hrs. ECD-10.70 ppg Footage-1521' WOB 5-15 k RPM 140 GPM 775 @ 2850 psi String wt. PU 150 SO 115 ROT 130 Torque on/off btm.-10,000/8,000 ft/lbs 05/05/2010 Drilled 9 7/8"hole w/GP f/5079'to 7836' 00:00 12:00 12.00 5,079 6,412 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/GP f/5,079'to 6,412'MD 3,165'TVD ADT-6.95 hrs. ECD-10.75 ppg Footage-1333' WOB 5-13 k RPM 140 GPM 750 @ 3020 psi String wt. PU 160 SO 122 ROT 136 Torque on/off btm.-11,000/8,500 ft/lbs Added 275 bbls of 9.6 ppg whole mud dilution @ 5475'and 6015' 12:00 00:00 12.00 6,412 7,836 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/GP f/6412'to 7836'MD 3494'TVD ADT-7.47 hrs ECD-10.68 ppg Footage 1424' WOB 5/15 k RPM 150 GPM 750 @ 3200 psi String wt. PU 162 SO 127 ROT 142 Torque on/off btm.-11500/8500 ft/lbs 05/06/2010 Drilled 9 7/8"hole w/GP f/7836'to 10,309'-(string took wt.while reaming down on connection @ 9927'- reamed through spots @ 9841'-9855'-9877'-9903'&9908'-also reamed through spot @ 9978') Page 7 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 7,836 9,254 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/7,836'to 9,254'MD 3,829'ND ADT-7.3 hrs ECD-10.61 ppg Footage 1418' WOB 10/16 k RPM 150 GPM 775 @3510 psi String wt. PU 196 SO 129 ROT 150 Torque on/off btm.-14,000/11,500 ft/lbs Added 250 bbls whole mud dilutions @ 8150',8700',9050' 12:00 18:00 6.00 9,254 9,927 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/9254'to 9927'MD 3986'ND ADT-3.62 hrs ECD 10.69 ppg Footage-673' WOB 10/13 k RPM 150 GPM 775 @ 3350 psi String wt.PU 210 SO 126 ROT 154 Torque on/off btm.-14,500/12,500 ft/lbs 275 bbls whole mud dilution @ 9737' 18:00 19:00 1.00 9,927 9,927 INTRM1 DRILL REAM T String took wt while backreaming down @ 9841'-9855'-9877'-9903' &9908'-reamed through 2 X-f/ 9841'to 9908'-stopped rotary& slacked off w/pump f/9908'to 9911' -cont.reaming down f/9911'to 9927' -Hole wasn't packing off 19:00 00:00 5.00 9,927 10,309 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/9927'to 10,309'MD 4046'ND ADT 2.00 hrs ECD 10.50 ppg Footage-382' WOB 10/20 k RPM 140 GPM 775 @ 3350 psi String wt. PU 215 SO 130 ROT 155 Torque on/off btm.-15,500/13,500 ft/lbs 275 bbls whole mud dilution @ 10,200' 05/07/2010 Drilled 9 7/8"hole f/10,309'to 12,018'(Circ&cond.mud @ 11,875')-@ 12,018'-Pumped Hi-Vis sweep& circ 3 X btms up standing back 1 std DP every 30 mins.-Flow Ck(static)-BROOH f/11637'to 9072'@ 775 gpm @ 3000 psi w/140 rpm-torque 11.5 k-ECD 10.44 ppg Page 8 of 39 Time Logs Date - From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 12:00 12.00 10,309 11,637 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/GP f/10,309'to 11,637'MD 4,391'11/D ADT 2.00 hrs ECD 10.50 ppg Footage-1,328' WOB 10/15 k RPM 140 GPM 775 @ 3080 psi String wt. PU 225 SO 125 ROT 165 Torque on/off btm.-16,500/15,500 ft/lbs Tight spots while raming @ 11,432', 11,517', 11,527', 11,535'-no observed pump pressure increase while reaming 275 bbls 9.6 ppg whole mud dilution @ 10,974', 130 bbls @ 11,542' 12:00 13:30 1.50 11,637 11,875 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/GP f/11637'to 11,875'MD 4446'ND ADT-1.11 hrs, ECD 10.26 ppg Footage 238' WOB 10/15 k RPM 130 GPM 775 @ 3320 psi String wt. PU 205 SO 138 ROT 165 Torque on/off btm.-15,500/12,500 ft/lbs. Shaker screens greasing up' 13:30 14:30 1.00 11,875 11,875 INTRMI DRILL CIRC P Circ&condition mud @ 400 gpm @ 1100 psi w/130 rpm's-12 k torque- shakers screens greasing-screen down on#1 shaker 14:30 15:45 1.25 11,875 12,018 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/GP f/11,875'to 12,018'MD 4480'ND ADT-.69 hrs. ECD-10.26 ppg Footage-143' WOB 10/15 k RPM 130 GPM 775 @ 3320 psi String wt. PU 207 SO 135 ROT 163 Torque on/off btm.-16,000/12,000 ft/lbs 15:45 18:45 3.00 12,018 11,637 INTRM1 DRILL CIRC P Circ&condition mud for wiper trip- Pumped hi-vis sweep&Circ 3 X btms up-775 gpm @ 3130 psi w/ 140 rpm's-standing back 1 std DP every 30 mins-to 11,637' 18:45 00:00 5.25 11,637 9,072 INTRMI DRILL WPRT P Flow ck(well static)-BROOH f/ 11,637'to 9072'-775 gpm @ 3000 psi w/140 rpm-Torque 11,500 ft/lbs -ECD 10.44 ppg Page 9 of 39 Time Logs • • Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 05/08/2010 24 hr Summary Cont. BROOH f/9072'to 3124' w'775 gpm @ 2680 psi w/140 rpm -Torque 8 to 10 k-Worked thruogh various tight spots 7940'to 5229'&3414'to 3205'-Worked GP cutters&bit through casing shoe-Pumped hi-vis weighted sweep(40 bbls)&circ btms up-Monitor wel(Obseved slight ooze)Cut&slip drill line- Service TD(monitored well on TT w/no loss/no gain)-RIH to 3175'-Circ btms up-RIH to 4989'-Check GeoPilot OK-Cont.RIH f/4989'to 9547'-Hole in good condition-No problems 00:00 12:00 12.00 9,072 3,558 INTRMI DRILL TRIP P Continue with wiper trip-BROOH f/ 9,072'to 3,558'-775 gpm @ 2610 psi w/140 rpm-Torque 7,500 ft/lbs- ECD 10.42-10.9 ppg Worked through tight spots @ 7,950',7,625',7,131',6,397', 5,292'& 5,229'-Some pump pressure increase seen 100 to 150 psi,no packing off while while working through tight spots Began seeing increase in cutting volume at shakers from 4200' 12:00 14:45 2.75 3,558 3,083 INTRMI DRILL TRIP P Continue with wiper trip-BROOH f/ 3,558'to 3,083'-775 gpm @ 2680 psi w/80 rpm-Torque 8,000- 10,000 ft/lbs-ECD 10.9-10.1 ppg Had difficulty pulling non rotating stabalizer and bit into casing shoe- pulled 10k over to work each into shoe-Set deflection to 50%to assist pulling bit into shoe Observed increase in cuttings size and volume last 3 stands below shoe 14:45 15:30 0.75 3,083 3,083 INTRM1 DRILL CIRC P Pumped 35 bbls wt.'d sweep(11.8 ppg)and circulated hole clean-700 gpm until sweep out the bit(pulsor limit)775 gpm/2700 psi/60 rpm- monitor well-blow down top drive 15:30 15:45 0.25 3,083 3,083 INTRM1 DRILL OWFF P Monitor well,observed large bubbles breaking out 2-3 minutes apart- slight flow as bubbles rose to surface -fluid dropping below flowline after break out-Line up and monitor well on trip tank 15:45 16:00 0.25 3,083 3,083 INTRMI RIGMN1SFTY P PJSM-Discussed planned operations and hazards of job for long slip&cut of drill line 16:00 19:15 3.25 3,083 3,083 INTRM1 RIGMN7 SLPC P Cut&slip drill line-1800'-service top drive 19:15-19:45 0.50 3,083 3,175 INTRM1 DRILL TRIP P Flow ck(well static)RIH f/3083'to 3175 19:45 20:00 0.25 3,175 3,175 INTRM1 DRILL CIRC P MU TD-Circ btms up @ 3175'650 gpm @ 1730 psi w/60 rpm-torque 8 k-Flow ck.well static 20:00 21:15 1.25 3,175 4,989 INTRMI DRILL TRIP P Blow down TD-RIH f/3175'to 4989' Page 10 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 21:15 21:45 0.50 4,989 4,989 INTRMI DRILL CIRC P Fill pipe&test GeoPilot-775 gpm @ 2680 psi w/14o rpms-torque 8.5 k-Blow down TD 21:45 00:00 2.25 4,989 9,547 INTRM1 DRILL TRIP P RIH f/4989'to 9547'-PU wt. 167 SO wt. 122-Hole in good condition- no problems Fill pipe every 20 stds. 05/09/2010 Cont. RIH f/9547'to 11,732'-Hole in good condition-No problems-Break circ&wash down f/11,732'to 12,018'-775 gpm @ 2840 psi w/140 rpm's-Torque 14 k-dilute mud system w/1100 bbls 9,6 ppg new LSND mud-Drilled 9 7/8'hole w/GP f/12,018'to 14,299' 00:00 01:45 1.75 9,547 11,732 INTRM1 DRILL TRIP P Cont.to RIH from 9,547'to 11,732'- no problems-hole appears in good condition 01:45 03:15 1.50 11,732 12,018 INTRM1 DRILL CIRC P Precautionary wash and ream from 11,732'to 12,018'-circulate and condition mud-775 gpm/2840 psi/ 140 rpm @ 14,000 ft/lbs-diluted mud system with 825 bbls of new 9.6 ppg LSND mud 03:15 12:00 8.75 12,018 12,706 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/12,018"to 12,706'MD 4,639'TVD ADT-4.41 hrs, ECD 10.38 ppg Footage 688' WOB 10/16 k RPM 134/150 GPM 775@3140 psi String wt. PU 195 SO 143 ROT 165 Torque on/off btm.-14,500/11,500 ft/lbs. 12:00 00:00 12.00 12,706 14,299 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/GP f/12706'to 14,299'MD 5013'TVD ADT-6.96 hrs ECD-10.72 ppg Footage-1593' WOB 15/25 k RPM 150 GPM 775 @ 3040 psi String wt. PU 215 SO 140 ROT 170 Torque on/off btm.-16,000/12,500 ft/lbs 275 bbl whole mud dilution @ 12,885' 05/10/2010 Drilled 9 7/8"hole w/GP f/14,299'to 16,758' 00:001 12:00 12.00 14,299 15,820 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/GP f/14,299'to 15,820'MD 5,369'TVD ADT-6.32 hrs ECD-10.78ppg Footage-1,521' WOB 10/20 k RPM 150 GPM 775 @ 3450 psi String wt. PU 245 SO 143 ROT 175 Torque on/off btm.-18,500/15,500 ft/lbs 275 bbl whole mud dilution @ 15,500' Page 11 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 00:00 12.00 15,820 16,758 INTRM1 DRILL DDRL P Drilled 8 7/8"hole w/GP f/15,820'to 16,758'MD 5590'TVD ADT- 6.22 hrs ECD 10.44 ppg Footage-938' WOB 12/18 k RPM 140 GPM 775 @ 3350 psi String wt. PU 250 SO 145 ROT 180 Torque on/off btm.-19,000/16,000 ft/lbs. 275 bbls whole mud dilution @ 16,170'&16,605' 05/11/2010 Drilled 9 7/8"hole w/GP f/16,758'to 19,175' 00:00 12:00 12.00 16,758 18,064 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/16,758'to 18,064'MD 5895'TVD ADT-6.73 hrs. ECD 10.61 ppg Footage 1306' WOB 10/25 k RPM 150 GPM 775 @3410 psi String wt. PU 254 SO 148 ROT 188 Torque on/off btm.-20,500/17,000 ft/lbs 12:00 00:00 12.00 18,064 19,175 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/18,064'to 19,175'MD 6158'TVD ADT-6.45 hrs ECD 10.74 ppg Footage 1,111' WOB 10/16 k RPM 150 GPM 775 @ 3660 psi String wt. PU 270 SO 150 ROT 193 Torque on/off btm.-20,000/16,500 ft/lbs 05/12/2010 Drilled 9 781'hole w/GP f/19,175'to 20,700'TD of 9 7/8'hole section(worked on TD-Replaced dies in Grabbs&saveer sub)-Pumped Hi-Vis sweep&began circ 3 X btms up @ 700 gpm @ 3950 psi w/150 rpm's-torque 21 k-ECD 10.82 ppg Geo Picks-Top of HRZ 19,825'-Base of HRZ 20,395' K-1 20,610' 00:00 09:00 9.00 19,175 19,827 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/19,175'to 19,827'MD 6158'TVD ADT 5.59 hrs ECD 10.83 ppg Footage-652' WOB 10/20 k RPM 150 GPM 730 @ 3990 psi String wt. PU 275 SO 150 ROT 198 Torque on/off btm.-23,500/18,500 ft/lbs. 09:00 11:30 2.50 19,827 19,827 INTRM1 RIGMNT RGRP T Unable to break out pipe-Work on TD-Changed out dies&saver sub Page 12 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 19,827 19,875 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/19,827 to 19,875'MD 6320'TVD ADT.35 hrs ECD 10.83 ppg Footage-48' WOB 10/20 k RPM 150 GPM 730 @ 3990 psi String wt. PU 275 SO 150 ROT 198 Torque on/off btm.-23,500/18,500 ft/lbs 12:00 22:15 10.25 19,875 20,700 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/19,875'to 20,700'MD 6515'TVD ADT 6.32 hrs ECD 10.86 ppg Footage 825' WOB 12/15 k RPM 150 GPM 700 @ 3970 psi String wt. PU 290 SO 147 ROT 195 Torque on/off btm.-23,000/17,500 ft/lbs 22:15 00:00 1.75 20,700 20,700 INTRMI DRILL CIRC P Pumped Hi-vis sweep&begin circ 3 X btms up @ 700 gpm @ 3950 psi w/150 rpm-torque 21 k-ECD 10.82 ppg 05/13/2010 Circ 3 X btms up working pipe to 20,384'-BROOH f/20,384'to 19,454'-Circ 2 X btms up working pipe to 19,084'-Flow ck well static-RIH to 20,700'-Circ 3 X btms up while bumping mud wt.f/10.0 to 10.4 ppg working pipe to 20,477'-RIH to 20,700'-POOH w/pump spotting casing running pill f/20,700'to 19,455'- BROOH f/19,455'to 16,010' 00:00 03:00 3.00 20,700 20,384 INTRM1 DRILL CIRC P Circ hole for short trip 3 X btms up @ 700 gpm @ 3900 psi w/160 rpm- torque 20.5 k-working pipe f/ 20,700'to 20,384' 03:00 05:00 2.00 20,384 19,454 INTRM1 DRILL WPRT P BROOK f/20,384'to 19,454'-700 gpm @ 3810 psi w/150 rpm @21 k torque 05:00 08:30 3.50 19,454 19,084 INTRMI DRILL CIRC P Circ 2 X btms up @ 700 gpm @ 3810 psi w/150 rpm @ 21 k torque- working pipe f/19,454'to 19,084'- Blow down TD-Flow ck-well static 08:30 09:15 0.75 19,084 20,700 INTRM1 DRILL TRIP P RIH f/19,084'to 20,700'PU wt 278 SO wt. 144 09:15 15:15 6.00 20,700 20,700 INTRM1 DRILL CIRC P Circ 3 X btms up while bumping mud wt.f/10.0 ppg to 10.4 ppg @ 700 to 675 gpm @ 3950 to 3860 psi w/150 rpm's @ 22 to 20 k torque-wprking pipe f/20,700'to 20,477'-Flow ck- well ststic-RIH to 20,700' 15:15 17:00 1.75 20,700 19,454 INTRM1 DRILL TRIP P POOH w/pump spotting casing running pill f/20,700'to 19,454'@ 3 bbls/min @ 420 psi-PU wt.280 SO wt 143 17:00 00:00 7.00 19,454 16,010 INTRMI DRILL TRIP P BROOH f/19,454'to 16,010'@ 670 gpm @ 3770 psi w/150 rpm's @ 22 k torque-Rot wt. 190 05/14/2010 BROOH f/16,010'to 7362'-Worked through tight spots @ 14,570'-14,053'-12,829'-11,237'-9462' to 9453'-Added 275 bbls whole mud dilutions @ 15,629'&7362' Page 13 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 01:00 1.00 16,010 15,629 INTRM1 DRILL TRIP P Cont. BROOH f/16,010'to 15,629' - 670 gpm @ 3560 psi w/150 rpm's @ 18.5 k torque 01:00 03:00 2.00 15,629 15,535 INTRMI DRILL CIRC P Circ&add 275 bbl whole mud dilution-670 gpm @ 3470 psi w/150 rpm's @ 18 k torque-working pipe f/ 15,629'to 15,535' 03:00 12:00 9.00 15,535 12,018 INTRM1 DRILL TRIP P Cont. BROOH f/15,535'to 12,018'- 670 gpm @ 3190 psi w/150 rpm's @ 15 k torque-worked through tight spots @ 14,570'-14.035'&12,829' 12:00 17:30 5.50 12,018 9,462 INTRM1 DRILL TRIP P Cont. BROOH f/12,018'to 9462'- 715 gpm @ 3050 psi w/150 rpm's @ 12 k torque-Worked thruogh tight spot @ 11,237' 17:30 18:30 1.00 9,462 9,453 INTRMI DRILL TRIP T Worked through tight hole @ 9462 to 9453'-715 gpm @ 3050 psi w/150 rpm's @ 11.5 k toruqe 18:30 22:45 4.25 9,453 7,362 INTRM1 DRILL TRIP P Cont. BROOH f/9453'to 7362'-715 gpm @ 2900 psi w/150 rpm's @ 11 k torque 22:45 00:00 1.25 7,362 7,362 INTRM1 DRILL CIRC P Flow ck-well static-Circ&add 275 bbls mud dilution-715 gpm @ 2900 psi w/150 rpm @ 11,5 k torque 05/15/2010 BROOH f/7362'to 3082'-Pump hi-vis pill&circ btms up-Spot clay buster pill-C&S drill line-Pump bit balling pill&circ out clay buster pill.-Flow ck Static-POOH on TTto 2792'-Hole fill short-Flow ck Static- POOH w/pump to 2227'-POOH on TT to 1871'-LD 11 std DP f/derrick-POOH w/pump f/1871'to 625'& Std back in derrick-LD HWDP to 218' 00:00 12:00 12.00 7,362 3,082 INTRM1 DRILL TRIP P Cont. BROOH f/7362'to 3082'-700 gpm @ 2530 psi 150 rpm's-Worked through tight spots @ 7120',6130', & 5440' 12:00 13:15 1.25 3,082 3,082 INTRM1 DRILL CIRC P Circ&pump hi-vis sweep @ 3082'- 700 gpm @ 2450 psi w/60 rpm's @ 6.5 k torque 13:15 13:45 0.50 3,082 3,082 INTRM1 DRILL CIRC P Flow ck-well static-Observed well- Spot clay buster pill around BHA& let soak -Blow down TD 13:45 14:00 0.25 3,082 3,082 INTRM1 RIGMNT SFTY P PJSM on cut&slip drill line 14:00 15:15 1.25 3,082 3,082 INTRM1 RIGMNT SLPC P Cut&slip drill line 75'-Service top drive 15:15 15:45 0.50 3,082 3,082 INTRM1 DRILL CIRC P Pump bit balling pill w/12.5 ppb nut plug&circ out clay buster pill-700 gpm @ 2400 psi w/80 rpm's @ 6.5 k torque-Observed significant increase in cuttings&cuttings size 15:45 16:15 0.50 3,082 2,792 INTRM1 DRILL TRIP P Flow ck-well static-POOH on TT f/ 3082'to 2792'-Improper hole fill 16:15 17:00 0.75 2,792 2,227 INTRM1 DRILL TRIP P POOH w/pump f/2792'to 2227'- 700 gpm @ 2350 psi 17:00 19:00 2.00 2,227 1,817 INTRM1 DRILL TRIP P Flow ck-well static-Blow down TD - POOH on TT f/2227'to 1817'- having to pull slow to avoid swabbing -PU wt. 125-monitor well on TT 19:00 19:15 0.25 1,817 1,817 INTRM1 DRILL SFTY P Held PJSM on LD drill pipe Page 14 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 20:30 1.25 1,817 1,817 INTRM1 DRILL PULD P LD 11 stds DP f/derrick vai mouse hole 20:30 22:30 2.00 1,817 625 INTRMI DRILL TRIP P POOH w/pump f/1817'to 625'-Std back DP-LD Ghost reamer&Well Commander circ sub&ball catcher 22:30 00:00 1.50 625 218 INTRM1 DRILL PULD P LD HWPD&Jars 05/16/2010 POOH LD NM flex DC's-Down load MWD-LD BHA-Pull WB-RU&Test BOPE-Changed top pipe rams to 7 5/8'&Test-RU&Ran 7 5/8"casing to 1051'(25 jts total in hole) 00:00 04:00 4.00 218 0 INTRM1 DRILL PULD P LD MN flec DC's-Held PJSM on removing RA sources-Removed RA sources f/MWD tools-Plug in& down load MWD-Finish LD BHA MWD tools-GeoPilot&bit 04:00 06:30 2.50 0 0 INTRM1 WHDBO NUND P MU&RIH w/wear bushing pulling tool-Engage wear bushing-Back out lock downs-Attempt to pull WB w/tugger-Unable to pull-Latched& screwed in w/TD-work wear bushing loose-pulled 57 k-Pulled &LD WB-Observed gouged marks all around the top&a thin worn spot on the btm of the wear bushing 06:30 13:45 7.25 0 0 INTRM1 WHDBO BOPE P Set test plug&Ru to test BOPE- Tested BOPE-Annular(Hydril)to 250&2500 psi-tested pipe rams (VBR 3 1/2"x 6")-choke&kill line valves-Choke manifold valves- IBOP's-Floor safety&dart valves to 250&3500 psi w/5"test jt- performed Accumulator closure& recovery test-Tested blind rams to 250&3500 psi-PU 4"test jt.&test Annular(Hydril)to 250&2500 psi- Upper&lower pipe rams(VBR 3 1/2" x 6") to 250&3500 psi- Witnessing of test waived by Bob Noble AOGCC-Pulled test plug& blew down choke&kill lines 13:45 14:00 0.25 0 0 INTRMI WHDBO SFTY P Held PJSM on changing rams 14:00 14:30 0.50 0 0 INTRM1 WHDBO RURD P RU to change top pipe rams f/3 1/2" x 6"VBR to 7/58"solid body 14:30 15:45 1.25 0 0 INTRMI DRILL RURD P RU fill up tool&casing elevators while attempting to locate 7 5/8' rams 15:45 18:00 2.25 0 0 INTRM1 WHDBOOTHR T Service rig while waiting on 7 5/8" pipe rams f/Prudhoe Bay 18:00 20:00 2.00 0 0 INTRM1 WHDBO RURD P Install 7 5/8"rams-MU&set test plug-Test 7 5/8"pipe rams to 250& 3500 psi-Pull test plug-set thin wall wear bushing 20:00 20:45 0.75 0 0 INTRMI CASING RURD P Finish rigging up to run 7 5/8'casing -Held PJSM on running casing Page 15 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:45 00:00 3.25 0 1,051 INTRM1 CASING RNCS P Ran 7 5/8"29.7#L-80 BTCM casing as follows: Float shoe(Ray Oil Tools Silver bullet)2 jts casing- Float Collar( Halliburton super seal w/by-pass baffle installed in top of FC) 1 jt.casing-Halliburton Baffle landing collar-1 jt casing(4 jts total in hole)to 173'(first 4 connections made up w/BakerLoc-Filled pipe& checked floats-Cont. RIH w/casing f/173'to 1051'(25 jts total in hole)- PU wt. 100 So wt.95 Installed 1 straight blade centralizer on jt#1 &24 Tesco Hydro Form( 7.63"x 9.38")centralizers on jts.2 thru 25 05/17/2010 Cont. Running 7 5/8"casing f/1051'to 13559'(325 jts total in hole)-Circulated&conditioned mud @ 3137'- 5220'-7312'-9404'-11,488'-Installed Halliburton stage collar @ jt#243-Installed Hydro Form&EZee glider centralizers as per program 00:00 02:15 2.25 1,051 3,137 INTRMI CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTCM casing f/1051'to to 3137'(75 jts total in hole)Installed Tesco Hydro Form(7.63"x 9.38") centralizers on jts.26 thru 75 02:15 03:00 0.75 3,137 3,137 INTRMI CASING CIRC P Break circ&circ casing capacity& condition mud-Staged pump up to 6 bbls/min.-ICP 250 psi @ 3.5 bbls/min-FCP 450 psi @ 6 bbls/min 03:00 05:30 2.50 3,137 5,220 INTRMI CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTCM casing f/3137'to 5225'(125 jts total in hole)PU wt. 159 SO wt. 129- Installed EZEE glider centralizers on jts.76 thru 125 05:30 06:30 1.00 5,220 5,220 INTRM1 CASING CIRC P Break circ-Circ&condition mud- Stage pump up to 6 bbls/min-ICP 340 psi @ 3.5 bbls/min FCP 550 psi @ 6 bbls/min. 06:30 08:45 2.25 5,220 7,312 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTCM casing f/5220'to 7312'(175 jts total in hole)PU wt. 192 SO wt. 135-Installed EZee glider centralizers on jts 126 thru 175 08:45 09:45 1.00 7,312 7,312 INTRM1 CASING CIRC P Break circ-Circ&condition mud- Stage pump up to 6 bbls/min. ICP 320 psi @ 3.5 bbls/min FCP 560 psi @ 6 bbls/min 09:45 12:30 2.75 7,312 9,404 INTRMI CASING RNCS P Cont. RIH w/7 5/8'27.9#L-80 BTCM casing f/7312'to 9404'(225 jts total in hole) PU wt.215 SO wt. 140-Installed EZee glider centralizers on jts. 176 to 225 12:30 14:15 1.75 9,404 9,404 INTRM1 CASING CIRC P Break circ-circ&cond.mud- Stage pumps up to 6 bbls/min ICP 380 @ 3,5 bbls/min FCP 580 psi @ 6 bbls/min. Page 16 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:15 17:30 3.25 9,404 11,488 INTRM1 CASING RNCS P Cont.RIH w/7 5/8'29.7#L-80 BTCM casing f/9404'to 11,488'(275 jts total in hole) PU wt.245 SO wt 145 -Installed Halliburton HES stage collar @ jt#243(made up w/ BakerLoc)-Installed EZee glider centralizers on jts 226 to 230- Installed Tesco Hydro Form(9.83"x 7.63")on jts 243 to 268-Installed straight blade centralizers on jts 269 _ to 272 17:30 19:15 1.75 11,488 11,488 INTRM1 CASING CIRC P Break circ-Circ&cond.mud- Stage pump up to 5 bbls/min-ICP 380 psi @ 3.5 bbls/min FCP 600 psi @ 5 bbls/min 19:15 22:45 3.50 11,488 13,559 INTRM1 CASING RNCS P Cont.RIH w/7 5/8"29.7#L-80 BTMC casing f/11488'to 13559' 325 jts total in hole) PU wt.275 SO wt. 148 22:45 00:00 1.25 13,559 13,559 INTRM1 CASING CIRC P Break circ-Cric&cond. mud- stage pump up to 5 bbls/min-ICP 430 psi @ 3.5 bbls/min. 05/18/2010 Continue to Run Casing f/13,559'-20,223'MD(165 Joints),Stopped Every 50 joints to Condition the Mud- Appeared to Hit a Bridge at 20,223'MD-Franks Tool Seal Failed-UD Joint 485-Replaced Franks Tool- Attempted to Work Casing Through Bridge w/o Success 00:00 01:00 1.00 13,559 13,559 INTRM1 CASING CIRC P Continue to Condition Mud at Planned Circulation Point-5 BPM @ 550 Psi 01:00 05:00 4.00 13,559 15,648 INTRM1 CASING RNCS P Continue to RIH w/7 5/8"Casing U 15,648'MD(50 Joints)P/U 314,S/0 148 05:00 07:30 2.50 15,648 15,648 INTRM1 CASING CIRC P Circulate and Condition Mud While Staging Pumps Up f/2 BPM w/400 Psi to 5.5 BPM w/620 Psi 07:30 11:00 3.50 15,648 17,731 INTRM1 CASING RNCS P Continue to RIH w/7 5/8"Casing U 17,731'MD(50 Joints)P/U 350 S/O 148 11:00 14:30 3.50 17,731 17,731 INTRM1 CASING CIRC P Circulate and Condition Mud While Staging Pumps Up f/2 BPM w/500 Psi to 5.5 BPM w/670 Psi 14:30 17:30 3.00 17,331 19,610 INTRM1 CASING RNCS P Continue to RIH w/Casing t/19,610' MD(50 Joints)P/U 368,S/O 155 17:30 21:00 3.50 19,610 19,610 INTRM1 CASING CIRC P Circulate and Condition Mud While Stagin Pumps Up f/2 BPM wf 500 Psi to 6 BPM w/790 Psi 21:00 22:15 1.25 19,610 20,223 INTRM1 CASING RNCS P Continue to RIH w/Casing t/20,223' MD(15 Joints)-Hit Bridge @ 20,223' MD Page 17 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 00:00 1.75 20,223 20,223 INTRM1 CASING CIRC T Attempt to Work Casing Down While Pumping-Set Down to Block Weight w/o Success-Hole,Partially Packed Off Initially but Appeared to Clear-Seal Cup on Franks Tool Failed-UD Joint 485-Attempt to UD Joint 484 but Couldn't Due to Weight Restrictions, Picked Up to 430 Indicated-UD Franks Tool While Reciprocating Casing 05/19/2010 Continue Working Casing on Bridge @ 20,223'MD at Various Pump Rates w/Multiple Partial Pack Off Events-UD Franks Tool&Pull the Mouse Hole-R/U Scaffolding for Working Cement Ops 12'Above the Rig Floor-Establish Circulation Through the Cement Head&Record Base Line Pressures 00:00 12:00 12.00 20,223 20,223 INTRMI CASING RNCS T Attempt to Move Casing Past Bridge -Stage Pumps Up f/.5 to 5 BPM- Set Down to Block Wt.(75K indicated)and Pulled Up to 430K Indicated Numerous Times-Hole Partially Packed Off Several Times Above 3.5 BPM-Able to Reduce Pump Rate to 0-1/2 BPM and Slowly Return to Full Rate(5 BPM)- Pack Off Occurred Most Frequently While Pulling Up Near the Top of the Stoke-Maintained Full Circulation While Sitting on Bottom @ 20,223' MD 12:00 19:30 7.50 20,223 20,223 INTRM1 CASING RNCS T Continue to Attempt to Move Casing Past Bridge With and Without Pumps-Stage Pumps Up f/.5 to 5 BPM-Set Down to Block Wt. (75K indicated)and Pulled Up to 430K Indicated Numerous Times-Hole Partially Packed Off Several Times Above 3.5 BPM-Able to Reduce Pump Rate to 0-1/2 BPM and Slowly Return to Full Rate(5 BPM)- Average Pressure at Each Pack Off Event 1050 Psi @ 1 BPM-Pack Off Occurred Most Frequently While Pulling Up Near the Top of The Stoke -Maintained Full Circulation While Sitting on Bottom @ 20,223'MD Base Line Rates v. Pressures Through Franks Tool: 0.8 BPM 390 Psi 1.5 BPM 410 Psi 2.0 BPM 430 Psi 2.5 BPM 480 Psi 3.0 BPM 520 Psi 3.5 BPM 570 Psi 4.0 BPM 650 Psi 19:30 19:45 0.25 20,223 20,223 INTRM1 CASING SFTY T PJSM on UD the Mouse Hole and Franks Tool Page 18 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:45 20:15 0.50 20,223 20,223 INTRM1 CASING PULD T LID Franks Tool and Mouse Hole 20:15 21:30 1.25 20,223 20,223 INTRM1 CASING OTHR T PJSM-P/U and R/U Scaffolding for Installing Cement Head at Height 21:30 22:15 0.75 20,223 20,223 INTRM1 CEMEN-PULD P P/U Cross Over,Cement Head and Valves 22:15 00:00 1.75 20,223 20,223 INTRMI CEMEN-CIRC P Establish Circulation-Stage Pumps Upf/1.5BPM @280Psi U4BPM @ 530 Psi Base Line Rate v. Pressure Through Cement Head: 1.3 BPM 280 Psi 2.0 BPM 380 Psi 3.O BPM 450 Psi 3.5 BPM 500 Psi 4.0 BPM 530 Psi Wait for Crew Change Prior to Beginning Cement Job 05/20/2010 Cement 7 5/8"Casing Shoe w/63 Bbls of Class G Cement Displaced w/Rig Pumps-CIP @ 0510-Open HES Cementer-Cement Second Stage w/41.6 Bbls of 15.8 PPG Class G Cement Displaced w/Rig Pumps -CIP @ 0805-WOC-Cut Casing at the Bell Nipple-Change Saver Sub, Grabgbers,Bales&Elevators-Cut 7 5/8"Casing at Bell Nipple 00:00 00:15 0.25 20,225 20,225 INTRM1 CEMEN"SFTY P PJSM-Cementing 7 5/8"Shoe 00:15 01:45 1.50 20,225 20,225 INTRMI CEMEN"CMNT P Cement Casing Shoe as Follows: Pump 5 Bbls of CW100, Pressure Test Surface Lines t/3750 Psi, Pump 35 Bbls of CW100 @ 3.2 BPM w/500 Psi, Pump 43 Bbls of 11.5 PPG Mud Push @ 3.6 BPM w/510 Psi, Drop Bottom Plug, Pump Remaining 7 Bbls of Mud Push at Same Rate/Pressure, Load the Closing Plug, Pump 63 Bbls of 15.8 PPG Class G Cement w/Additives @ 3.8 BPM w/400 Psi, Drop Closing Plug, Pump 20 Bbls of Fresh Water @ 3.7 BPM w/170 Psi 01:45 05:30 3.75 20,225 20,225 INTRMI CEMEN-DISP P Displace Cement:Initial Rate/Pressure 4 BPM/200 Psi, Final Rate/Pressure 3 BPM/780 Psi- Pumped Plugs @ 9012 Strokes, Held 1280 Psi on Floats f/5 Minutes -Released Pressure and Checked Floats(Good)-CIP @ 0510 Hrs 05:30 06:00 0.50 20,225 20,225 INTRM1 CEMEN-CIRC P Shift Open HES Stage Collar @ 3250 Psi-Establish Circulation and Record Rates/Pressures Through Stage Collar as Follows: 4 BPM 270 Psi 5 BPM 320 Psi 6 BPM 370 Psi 7 BPM 440 Psi Page 19 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:15 0.25 20,225 20,225 INTRMI CEMEN"SFTY P PJSM on Second Stage Cement 06:15 07:15 1.00 20,225 20,225 INTRM1 CEMEN"CMNT P Cement K3 as Follows:Pumped 33 Bbls of 11.5 PPG Mud Push @ 4 BPM w/250 Psi, Pumped 41.6 Bbls of 15.8 PPG Class G Cement w/ Additives @ 5 BPM w/305 Psi, Dropped Stage Collar Closing Plug, Pumped 20 Bbls Fresh Water @ 5.1 BPM w/60 Psi 07:15 08:30 1.25 20,225 20,225 INTRM1 CEMEN"DISP P Displace Second Stage Cement w/ Rig Pumps at the Following Rates/Pressures: Initial 7 BPM/450 Psi,Slowed t/4.0 BPM/300 Psi @ 3500 Strokes, Bumped Plug @ 4429 Strokes, Held 1200 Psi f/5 Minutes 08:30 16:00 7.50 20,225 20,225 INTRM1 CEMEN"WOC P Wait on Cement 16:00 17:00 1.00 20,225 20,225 INTRMI CEMEN"RURD P R/D Cement Equipment and Scaffold 17:00 18:45 1.75 20,225 20,225 INTRM1 CASING RURD X Make Preparations to Cut Casing @ Bell Nipple 18:45 19:00 0.25 20,225 20,225 INTRM1 CASING SFTY T PJSM on Cutting Casing 19:00 20:30 1.50 20,225 20,225 INTRMI CASING CPBO X Cut 7 5/8"Casing at the Bell Nipple and N/U Flow Line 20:30 23:00 2.50 20,225 20,225 INTRMI CASING RURD X UD Casing Elevators and Long Bales -Change Saver Sub t/4"XT-39,Grab Heads, Bell Guide-Install Short Bales,4"Elevators-Service Rig 23:00 23:15 0.25 0 0 INTRMI CEMEMSFTY X PJSM on Running TAM Port Collar Tools and Packer 23:15 00:00 0.75 0 209 INTRMI CEMEN"PULD X P/U TAM Port Collar Shifting Tools,6 Jts 4"XT-39 DP and Baker 7 5/8" Retrievable Packer 65/21/2010 RIH w/TAM Setting Tools and Packer on 4"DP t/5,866'MD-M/U Pump In Sub Assembly-Circulate Through Stage Collar Staging Pumps Up f/1 to 4 BPM-Cement C10 Sand w/37 Bbls of 15.8 PPG Class G Tail Cement-Close and Release f/TAM Collar-Test U 1,000 Psi-CBU @ 3 BPM-POOH V 209'MD-UD Packer,6 Jts 4"DP and TAM Setting Tools-M/U Spear and N/D Well Head 00:00 02:00 2.00 209 209 INTRM1 CEMEN"PULD X P/U and M/U Pump in Sub,XO/s, TIW's,and Pup Joints-Set Aside for Later Use 02:00 08:30 6.50 209 5,866 INTRM1 CEMEN"TRIP X RIH w/4"XT-39 DP f/the Shed t/ 5,866'MD(178 Joints) 08:30 09:30 1.00 5,866 5,874 INTRMI CEMEN"PRTS X M/U Pump in Sub Assembly and Engage TAM Port Collar-Test Cups U 500 Psi and Cement Lines and Pump In Sub U 3500 Psi 09:30 12:30 3.00 5,872 5,874 INTRM1 CEMEN'CIRC X Condition Mud-Stage Pumps Up f/ 1 BPM@320 Psi t/4 BPM @ 410 Psi 12:30 12:45 0.25 5,874 5,874 INTRM1 CEMEN"SFTY X PJSM on 3rd Stage Cement 12:45 13:30 0.75 5,874 5,874 INTRM1 CEMEN"CMNT X Cement C10 Sand Through TAM Port Collar as Follows: Pump 10 Bbls CW100,21.3 Bbls of 11.5 PPG Mud Push, 37 Bbls of 15.8 PPG Class G Cement, and 20 Bbls of Water Page 20 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:00 0.50 5,874 5,874 INTRMI CEMEN"DISP X Displace Cement w/39.9 Bbls of 10.4 PPG LSND 14:00 14:30 0.50 5,874 5,700 INTRM1 CEMEN"PRTS X Close TAM Port Collar-Release and Test t/1000 Psi(Good) 14:30 16:00 1.50 5,700 5,700 INTRM1 DRILL CIRC X UD 6 Jts of 4"DP-Shear Ball Seat @ 2630 Psi and CBU @ 3 BPM w/ 440 Psi 16:00 21:00 5.00 5,700 209 INTRM1 DRILL TRIP X POOH on TT f/5,700'MD to 209'MD (172 Jts) 21:00 21:45 0.75 209 0 INTRMI DRILL PULD X OWFF(Static)-UD Packer,6 Stands of 4"DP and TAM Port Collar Setting Tool 21:45 22:15 0.50 0 0 INTRM1 DRILL PULD T M/U Casing Spear and Drain Stack and Casing-Stab Into Casing w/ Spear 22:15 22:45 0.50 0 0 INTRM1 DRILL PULD X Break Apart and UD Pump in Sub Assy: 10'Pup,TIW X2, Pump In Sub,4 1/2"IF to 4"XT39 Crossovers X2,and 15 Pup 22:45 00:00 1.25 0 0 INTRM1 WHDBO NUND T N/D Riser Surface Lines-Pull Mouse Hole-Break Wellhead Bolts 05/22/2010 Continue to N/D Well Head-Set 7 5/8"Emergency Slips w/150K-Cut&Remove Casing-Set 7 5/8"Pack Off-N/U Well Head-Test Pack Off t/3800 Psi f/10 Minutes-Change U.)per Rams-UD 5"DP f/the Derrick 00:00 01:30 1.50 0 0 INTRM1 WHDBO NUND T Continue to N/D well Head and raise BOPE 01:30 04:00 2.50 0 0 INTRM1 WHDBO NUND T P/U to 150K Over String Weight and Set Emergency Slips-Cut&Bevel 7 5/8'Casing w/WACHS Saw-UD Casing Spear and Cut Joint 04:00 05:30 1.50 0 0 INTRMI WHDBO NUND T Install Pack-Off and N/U Well Head (Torqued Bolts t/1900 ft/Ib) 05:30 06:00 0.50 0 0 INTRM1 WHDBO PRTS P Test Pack-Off t/3800 Psi f/10 Minutes(Good) 06:00 07:00 1.00 0 0 INTRM1 WHDBO OTHR P Pull Casing Wear Ring-Clean Cellar 07:00 09:00 2.00 0 0 INTRM1 WHDBO NUND P Change upper Rams t/3 1/2"by 6" Variables-N/U Hole Fill and Fill-Up Lines-Tighten and Secure Turn Buckles 09:00 09:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on Installing Mouse Hole and UD 5"DP 09:15 00:00 14.75 0 0 INTRM1 DRILL PULD P UD 5"DP Via Mouse Hole(160 Stands) 05/23/2010 Continue to UD 5"DP f/the Derrick(44 Stands+2 Stands HWDP)-R/U and Test Annular, Upper and Lower Rams w/4"and 3%"Test Joints-P/U BHA#4-Slip and Cut Drill Line-RIH t/5,450'MD-Test Casing Above TAM Collar t/1,000 Psi-RIH t/6,309'MD-Test Casing t/1,000 Psi Below TAM Collar-RIH t.6,595' MD(195 Jts Total) 00:00 05:00 5.00 0 0 INTRMI DRILL PULD P Continue to UD 5"DP f/the Derrick (44 Stands+2 Stands HWDP) 05:00 05:30 0.50 0 0 INTRM1 RIGMN7 SVRG P Service Rig 05:30 06:00 0.50 0 0 INTRM1 WHDBO RURD P R/U to Test BOPE Page 21 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:45 2.75 0 0 INTRMI WHDBO BOPE P Test Annular Preventer w/3%"and 4"Test Joints U 2500/250 Psi and Upper and Lower Variable Rams t/ 3500/250 Psi-Test Choke Line t/ 3500/250 Psi 08:45 09:15 0.50 0 0 INTRMI WHDBOOTHR P Install Bowl Protector 09:15 11:30 2.25 0 0 INTRMI DRILL PULD P P/U&Stand Back 18 Stands of 4" DP 11:30 14:30 3.00 0 400 INTRM1 DRILL PULD T P/U Clean Out BHA#4 as Follows: Bit, 1.2°Motor,2-NMFS, DM, Res, Pulser, BAT,3-NMFC,XO,Jars, 1 Jt HWDP, Bumper Sub,4 Jts HWDP 14:30 16:15 1.75 400 400 INTRM1 RIGMNT SLPC P Slip&Cut Drill Line-Service Top Drive 16:15 20:30 4.25 400 5,450 INTRM1 DRILL TRIP T RIH w/BHA#4 on 4'DP f/the Shed t/5,450'MD(159 Joints) 20:30 21:00 0.50 5,450 5,450 INTRM1 DRILL PRTS T Establish Circulation 5 BPM @ 1540 Psi-Test Casing Above TAM Port Collar to 1,000 Psi f/10 Minute s (Good) 21:00 22:15 1.25 5,450 6,309 INTRM1 DRILL TRIP T Continue to RIH w/BHA#4 f/the Pipe Shed t/5,831'MD(12 Joints)- Rotate 1 Stand f/the Derrick Through TAM Port Collar @ 30 RPM(5,831'- 5,926'MD)Pumping 3 BPM w/750 Psi-Continue to RIH on 4"DP f/the Shed t/6,309'MD(12 Joints) 22:15 22:45 0.50 6,309 6,309 INTRM1 DRILL PRTS T Establish Circulation 5 BPM @ 1570 Psi-Test Casing Below TAM Port Collar t/1,000 Psi f/10 Minutes (Good) 22:45 00:00 1.25 6,309 6,595 INTRM1 DRILL TRIP T Continue to RIH w/BHA#4 on 4"DP from the Pipe Shed t/6,595'MD(9 Joints) 05/24/2010 Continue to RIH w/BHA#4 on 4"DP f/the Shed t/9,838'MD-Wash Down&Drill HES Stage Collar U 10,219'MD-Circ&Cond Mud for Casing Test-R/U and Attempt to Test Casing t/3,500 Psi(Failed)- OWFF(Flowing)-CBU-OWFF(Flowing but Decreasing)-MADD Pass f/10,219 t/9,838'MD-OWFF (Static)-POOH on TT t/400'MD-UD BHA#4-P/U RTTS and RIH t/5,920'MD-Test Casing Above Packer t/Include TAM Port Collar(Failed)Leak Off Occurred @ 1,000 Psi-Test Casing&Components t/3,500 Psi f/10 Minutes(Good)-OWFF(Slight Flow)-CBU 00:00 02:30 2.50 6,595 9,838 INTRM1 DRILL TRIP T Continue to RIH w/4"DP from the Shed t/9,838'MD(102 Joints) 02:30 04:15 1.75 9,838 10,219 INTRM1 CEMEN"DRLG P Wash Down&Drill Out HES Stage Collar t/10,219'MD-230 GPM @ 2070 Psi&40 RPM(Tagged Stage Collar on Depth @ 10,070'MD 04:15 05:15 1.00 10,219 10,219 INTRM1 DRILL CIRC P CBU Prior to Testing Casing 230 GPM w/2020 Psi&40 RPM 05:15 06:15 1.00 10,219 10,219 INTRM1 DRILL PRTS P R/U and Test Casing(Failed)- Pressure Rose Steadily to 3050 Psi (9 Bbls Pumped)and Broke Over/Injected @ 3100 Psi w/9.5-10.0 Bbls Pumped 06:15 06:45 0.50 10,219 10,219 INTRMI DRILL OWFF X OWFF(Flowing) 06:45 08:00 1.25 10,219 10,219 INTRMI DRILL CIRC X CBU @ 230 GPM w/1990 Psi 7 40 RPM Page 22 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 09:00 1.00 10,219 10,219 INTRMI DRILL OWFF X OWFF(Flowing)-Flow Rate Reduced f/6 BPH to 1.5 BPH in 1 hour 09:00 10:15 1.25 10,219 9,838 INTRMI DRILL DLOG X MADD Pass f/10,219'-9,838'MD- OWFF(Static) 10:15 16:00 5.75 9,838 400 INTRM1 DRILL TRIP X Pump Dry Job&POOH on TT t/400' MD(99 Stands) 16:00 18:30 2.50 400 0 INTRM1 DRILL PULD X Download MWD Data and UD BHA #4 per DD and MWD Techs 18:30 21:45 3.25 0 5,920 INTRM1 CEMEN-TRIPX P/U Baker Retrievamatic and RIH t/ 5,920'MD(62 Stands)-Set Packer 21:45 23:15 1.50 5,920 5,920 INTRM1 DRILL PRTS X Pressure Test f/5,920'to Surface by Pumping Down Kill Line-Pressure Appeared to Inject w/1/2 Bbls Pumped @ 1,000 Psi, Pressure Bled U 350 Psi In 1 Minutes;Check Surface Equipment; Repeat Test w/ Injection @ 1,000 Psi and 2.1 Bbls Pumped, Pressure Bled U 650 Psi in 15 Seconds and 250 Psi in 2 Minutes-Pump Down Drill Pipe to Test Casing/Components f/5,920'to 20,093'MD-Pumped 9.5 Bbls w/ Pressure Rising Steadily to 3,500 Psi, Pressure Dropped f/3,400 Psi U 3,325 Psi in 10 Minutes-Suspect Problem w/TAM Port Collar 23:15 23:30 0.25 5,920 5,920 INTRM1 DRILL OWFF X OWFF(Flowing) 23:30 00:00 0.50 5,920 5,920 INTRM1 DRILL CIRC X CBU @ 5.5 BPM w/680 Psi 05/25/2010 OWFF(Flowing;Continuously Reducing f/1.6 BPH to 0 in 45 Minutes)-POOH while Pumping U 5,443'MD- OWFF(Static)-POOH&L/D Retrievamatic Packer-P/U PESI Tool and RIH U 5,872'MD-Close TAM Port Collar and Test 7 5/8"Casing U 3,500 Psi f/30 Minutes(Good)-Pull 45'Above TAM PC and Test U 3,500 f/ 10 Minutes(Good)-OWFF(Static)-POOH and L/D TAM Tool-Begin P/U BHA#5 00:00 00:45 0.75 5,920 5,920 INTRMI DRILL OWFF X OWFF(Flowing), Rate Continuously Reducing f/1.6 BPH to Static in 45 Minutes 00:45 01:30 0.75 5,920 5,443 INTRM1 DRILL TRIP X POOH w/Pumps U 5,443'MD- OWFF(Static) 01:30 07:30 6.00 5,443 0 INTRM1 DRILL TRIP X POOH on TT-L/D Retrievamatic Packer(62 Stands) 07:30 07:45 0.25 0 0 INTRM1 DRILL PULL X P/U PESI TAM Port Collar Closing Tools 07:45 16:30 8.75 0 5,872 INTRMI DRILL TRIP X RIH w/TAM Port Collar Closing Tools U 5,872'MD(62 Stands) P/U 130,S/O 102 Torque 7K @ 20 RPM 16:30 18:30 2.00 5,872 5,827 INTRMI DRILL PRTS X Engage/Close TAM Port Collar by Pulling 15k Over-Test 7 5/8"Casing U 3,500 Psi f/30 Minutes, Held 3,340 Psi-Disengage Tool and Pull 45'Above Collar-Retest Casing U 3,500 Psi f/10 Minutes 18:30 18:45 0.25 5,827 5,827 INTRMI DRILL OWFF X OWFF(Static) Page 23 of 39 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 18:45 22:15 3.50 5,827 0 INTRM1 DRILL TRIP X POOH w/TAM Collar Tools(62 Stands) 22:15 22:30 0.25 0 0 INTRM1 DRILL PULD X LID TAM Tool 22:30 23:00 -0.50 0 0 INTRM1 DRILL PULD X Clear Rig Floor 23:00 00:00 1.00 0 100 INTRMI DRILL PULD X P/U BHA#5 per DD and MWD Tech's to 100'MD 05/26/2010 P/U Remainder of BHA#5-RIH t/5,836'MD-Rotate Through Port Collar V 5,931'MD-RIH V 6,599'MD- Test Casing V 3500 Psi f/10 Minutes-RIH V 19,285'MD-Slip&Cut 60'Drill Line-RIh V 19,600'MD-Begin Logging Cement w/BAT Sonic and Drilling Float Equipment and Rat Hole V 20,239'MD 00:00 02:00 2.00 100 400 INTRM1 DRILL PULD X P/U Remainder of BHA#5 t/400'MD 02:00 06:45 4.75 400 5,836 INTRMI DRILL TRIP X RIH w/BHA#5 on 4"DP f/the Shed V 5,836'MD(57 Stands) 06:45 07:30 0.75 5,836 5,931 INTRM1 DRILL TRIP X Rotate Through Port Collar f/t/5,931' MD 07:30 08:00 0.50 5,931 6,599 INTRMI DRILL TRIP X Continue to RIH w/4"DP f/the Derrick V 6,599(7 Stands) 08:00 08:45 0.75 6,599 6,599 INTRM1 DRILL PRTS X R/U and Test Casing t/3500 Psi f/ 10 Minutes 08:45 17:45 9.00 6,599 19,285 INTRM1 DRILL TRIP T Continue to RIH t/19,285'MD(94 Stands f/the Derrick and 120 Joints f/the Pipe Shed) 17:45 19:15 1.50 19,285 19,285 INTRMI RIGMNT SLPC P Slip&Cut 60'Drilling Line 19:15 19:45 0.50 19,285 19,600 INTRM1 DRILL TRIP T Continue to RIH t/19,600'MD(4 Stands) 19:45 21:00 1.25 19,600 19,900 INTRM1 DRILL DLOG P Log Cement w/BAT Sonic Tool 21:00 00:00 3.00 19,900 20,239 INTRM1 CEMEN"DRLG T Washed Down w/20,092'MD- Drilled Cement,baffle Collar, Float Collar, Float Shoe and Rat Hole U 20,239'MD P/U 255,5/O 90, Rot 155 40 RPM-Motor RPM 177 230 GPM w/3060 Psi Torque 20 K • WOB 4-7K 05/27/2010 Continued to Attempt Hole Clean Out-Numerous Packoff Events @ 20,285',20,245',20,286'MD-Able to Reduce Pumps and Work Pipe Free To Regain Full Circulation After Returning to the Shoe Weight Up Mud System V 10.6 PPG-Conduct FIT V 15.0 PPG EMW-Continue to Wash/Ream t/20,303'MD-Weight Up Mud System V 10.8 PPG-Logged Cement w/BAT Sonic Tool f/Bit Depth 20,303'to 20,204'MD-Continued Cleaning Hole V 20,390'MD-Hole Packed Off-Reamed t/20,271 Before Full Circulation was Regained- Wash Down V 20,335'MD-Hole Packed Off-Worked Pipe Free and Reamed to Shoe Before Full Circulation Returned-POOH w/Pumps V 19,751'MD-OWFF(Static in 60 Minutes)-Continue to POOH w/Pumps V 19,189'MD Page 24 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 02:30 2.50 20,239 20,299 INTRMI DRILL FCO T Continue to Clean Out Hole t/20,285' MD-Attempt to Slide f/20,265'to 20,285'MD(Unable to Hole TF)- Hole Packed Off @ 20,285'MD- Worked Pipe Up&Down t/20,299' MD w/Pumps On/Off-POOH t/ Casing Shoe w/Rotation and Pulling 20K Over Rotating Weight P/U 260,S/0 95, Rot 155 Torque 20-23K @ 75 RPM 230 GPM @ 3100 Psi 02:30 04:45 2.25 20,220 20,220 INTRMI DRILL CIRC T CBU @ 20,220'MD 230 GPM @ 2950 Psi,75 RPM 04:45 06:15 1.50 20,220 20,220 INTRM1 DRILL FCO T Attempt to Clean Rat Hole t/20,245' • MD-Packed Off-Worked Pipe Back to Casing Shoe RPM 80-100,Torque 20-23K 230 GPM @ 2950 Psi 06:15 09:45 3.50 20,220 20,220 INTRM1 DRILL FCO T Establish Full Circulation and Attempt to Clean Hole-Washed U 20,303'MD-Hole Packed Off While Back Reaming @ 20,286'MD- Worked Pipe to Casing Shoe w/17 GPM-Establish Full Circ Rate Inside the Shoe-Begin Weighting up Mud System f/10.4 to 10.6 PPG 09:45 11:45 2.00 20,220 20,220 INTRMI DRILL WASH T Wash Down t/20,255'MD and Reamed Back to Shoe-Then Washed t/20,285'MD and Reamed Back to the Shoe-Hole Did Not Pack Off 11:45 13:00 1.25 20,220 20,220 INTRMI DRILL FIT T Perform FIT t/15.0 PPG EMW w/ 10.6 PPG MW In/Out-After Shut In Pressure Dropped t/1280 In 10 Minutes 13:00 14:15 1.25 20,220 22,303 PROD1 DRILL WASH T Clean/Wash Down t/20,303'MD- Back Ream w/No Problems-Make Second Pass w/Pumps Only, No Problems-Start Increasing MW to 10.8 PPG 245 GPM @ 3190 Psi 75 RPM w/21.5k Torque 14:15 14:45 0.50 22,303 20,204 PROD1 DRILL DLOG P Log Cement w/BAT Sonic Tool f/Bit Depth 20,303'-20,204'MD 14:45 16:45 2.00 20,204 20,271 PROD1 DRILL WASH T Clean Open Hole t/20,390'MD- Packed Off-Worked String Back U 20,271'MD @ BPM Before Regaining Full Circulation Rate 16:45 19:15 2.50 20,271 20,225 PROD1 DRILL WASH T Wash/Clean Open Hole t/20,335' MD-Packed Off-Worked Pipe U Casing Shoe @ 20,225'MD Before Regaining Full Circulation Rate 19:15 19:30 0.25 20,225 20,225 PROD1 DRILL OWFF T OWFF(Oozing-Rate Reducing) Page 25 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:15 1.75 20,225 19,571 PROD1 DRILL REAM T BROOH t/19,571'MD 21:15 22:15 1.00 19,571 19,571 PROD1 DRILL OWFF T OWFF-Rate Reduced f/2 BPH to Static in 60 Minutes 22:15 00:00 1.75 19,571 19,189 PROD1 DRILL TRIP T Attempt to POOH on TT(Swabbing)- POOH w/Pumps V 19,189'MD 5 BPM @ 2200 Psi 05/28/2010 Continue to POOH V 400'MD(197 Stands)-UD BHA#5-Rig Up and Test BOPE w/4"Test Joint V 250/5,000 Psi and Annular V 250,3500 Psi 00:00 01:00 1.00 19,189 18,140 PROD1 DRILL TRIP T Continue to Pump Out of Hole t/ 18,140'MD(11 Stands) 01:00 14:00 13.00 18,140 400 PROD1 DRILL TRIP T OWFF(Static-Not Swabbing)- Continue to POOH V 400'MD(186 Stands) 14:00 16:15 2.25 400 0 PROD1 DRILL PULD T UD BHA#5 per DD and MWD Technicians 16:15 17:30 1.25 0 0 PROD1 WHDBO NUND P Clean&Clear Rig Floor-Wash BOPE Stack-Drain BOPE Stack 17:30 18:00 0.50 0 0 PROD1 WHDBO NUND P Pull Wear Ring 18:00 19:00 1.00 0 0 PROD1 WHDBO BOPE P Set Test Plug-R/U To Test BOPE- Fill Stack and Choke w/Water- Grease Auto IBOP 19:00 00:00 5.00 0 0 PROD1 WHDBO BOPE P Test BOPE as Follows:Annular Preventer V 250/3500 Psi,Test Choke Manifold&Valves 1-16, Auto/Manual IBOP, HCR/Manual Choke&Kill, Floor Valve, Dart, Upper/Lower/Blind Rams V 250/5000 Psi w/4"Test Joint)-Performed Accumulator Test 05/29/2010 Continue to Test BOPE w/3'/z'Test Joint: Rams V 250/5000 Psi,Annular V 250/3500 Psi-Upper Rams Failed-Change Upper Rams Elements-Re-tested Upper Rams V 3 1/2 Test Joint(Good)-RIH w/30 Jts of 3'/"EUE Tubing and Drill Pipe V 20,209'MD(202 Stands)-Circ&Condition Mud Staging Pumps Up V 5 BPM-Wash In Hole t/20,368'MD-CBU-Spot Cement Plug f/20,368'-19,875'MD-Slowly POOH-Circ& Condition Mud to Clear Drill Pipe of Contaminants 00:00 01:30 1.50 0 0 PROD1 WHDBO BOPE P Continue BOPE Test w/3%:"test Joint; Upper/Lower Rams V 250/5000 Psi,Annular V 250/3500 Psi-Upper Rams Failed 01:30 05:00 3.50 0 0 PROD1 WHDBO NUND T Open Ram Doors, Inspect Ram Doors and Change Ram Elements 05:00 06:15 1.25 0 0 PROD1 WHDBO BOPE T R/U and Re-Test Upper Rams w/3 '%"Test Joint V 250/5000 Psi(Good) -AOGCC Inspector Chuck Scheve Waived Witnessing the Test 06:15 06:45 0.50 0 0 PROD1 WHDBO NUND P Pull Test Plug&Set Wear Ring 06:45 09:00 2.25 0 942 PROD1 DRILL TRIP T RIH w/30 Joints of 3%:"Tubing t/ 942'MD 09:00 10:15 1.25 942 2,177 PROD1 DRILL TRIP T RIH w/4"DP f/the Shed t/2,177' MD(39 Joints) 10:15 17:15 7.00 2,177 20,225 PROD1 DRILL TRIP T Continue to RIH w/4'DP f/the Derrick V 20,225'MD(190 Stands) P/U 282,S/O 88 Page 26 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:15 18:00 0.75 20,225 20,225 PROD1 DRILL CIRC T Establish Circulation and Stage Pumps Up f/1 to 5 BPM w/1780 Psi 18:00 19:45 1.75 20,225 20,368 PROD1 DRILL WASH T Wash Down t/20,368'MD @ 5 BPM w/1800 Psi-CBU 19:45 22:00 2.25 20,368 20,368 PROD1 CEMEN"PLUG T Set Cement Plug as Follows: Dowell Pumped 2 Bbl Water,Tested Surface Lines V 3,500 Psi, 15.5 Bbls 12 PPG Mud Push,36 Bbls 17 PPG Cement,4.5 Bbls 12 PPG Mud Push, 1 Bbl Water-Displaced Cement w/188 Bbls of 10.7 PPG Drilling Mud-CIP 2200 Hrs 22:00 23:15 1.25 20,368 19,636 PROD1 DRILL TRIP T POOH t/19,826'MD @ 10 FPM then V 19,636 @ 25 FPM-Est TOC After Tubing Removal 19,875'MD 23:15 00:00 0.75 19,636 19,636 PROD1 DRILL CIRC T Circulate and Condition Mud @ 5 BPM w/1950 Psi 05/30/2010 Continue to Circ and Condition Mud(Surface to Surface)-WOC;SIMOPS Change Top Drive Dollies for Preventive Maintenance-Wash Down and Tag Cement @ 20,116'MD-OWFF(Static)-POOH t/942'MD- L/D Cement Stinger(30 Joints of 31/:"Tubing)-R/U and Test Upper and Lower Pipe Rams w/5%"Test Joint t/250/5000 Psi and Annular V 250/3500 Psi 00:00 02:00 2.00 19,636 19,636 PROD1 DRILL CIRC T Continue to Circ&Condition Mud @ 5.5 BPM w/1820 Psi; P/U 260,SIO 90 02:00 06:00 4.00 19,636 19,636 PROD1 DRILL WOC T Monitor Hole on TT While WOC- SIMOPS:Change Two Top Drive Dollies(Preventive Maintenance) 06:00 08:15 2.25 19,636 20,116 PROD1 DRILL WASH T Wash Down f/19,636'-20,116'MD (Tagged Cement Plug @ 20,116'MD) -2 BPM @ 860 Psi; P/U 280, S/O 90 08:15 18:00 9.75 20,116 942 PROD1 DRILL TRIP T OWFF(Static)-POOH t/942'MD (212 Stands) 18:00 20:15 2.25 942 0 PROD1 DRILL PULD T R/U and LID Cement Stinger(30 Joints 31/2"EUE Tubing,Mule Shoe and XO's) 20:15 21:00 0.75 0 0 PROD1 DRILL RURD T R/D Tubing Handling Equipment 21:00 21:45 0.75 0 0 PROD1 WHDBO NUND P Set Test Plug, M/U 5 1/2"Test Joint -R/U Surface Lines 21:45 00:00 2.25 0 0 PROD1 WHDBO BOPE P Test Upper/Lower Rams t/250/5000 Psi and Annular to 250/3500 Psi w/5 1"Test Joint 05/31/2010 P/U BHA#6-P/T Lines,Shallow Test MWD and Load Nuclear Sources-P/U Remaining BHA Items and Test Circ Sub-RIH t/6,364'MD-Tested-Casing V 2,000 Psi f/10 Minutes-Continue to RIH t/19,280'MD- Wash Down V 20,120'MD-Begin Displacement V 11.2 MOBM 00:00 02:30 2.50 0 146 PROD1 DRILL PULD T PJSM-P/U BHA#6: Bit,Geo-Pilot, Geo-Flex,Smart Stab, Phase 4 Collar,Smart Stab, DM,ALD, CTN, PWD, Pulser, BAT, Float Sub t/146' MD 02:30 03:15 0.75 146 146 PROD1 DRILL PULD T Upload MWD Tools 03:15 04:15 1.00 146 146 PROD1 DRILL PRTS T Pressure Test Surface Lines, Pulse Test MWD-245 GPM @ 1080 Psi 04:15 04:30 0.25 146 146 PROD1 DRILL SFTY T PJSM on Loading Nuclear Sources Page 27 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:00 1.50 146 452 PROD1 DRILL PULD T Continue to M/U BHA#6:3 NMFDC's,XO,Jars, 1 jt HWDP, Bumper Sub,4 jts HWDP,XO,Well Commander Circ Sub and Catcher, XO t/452'MD 06:00 06:15 0.25 452 923 PROD1 DRILL TRIP T RIH w/5 Stands f/the Derrick U 923' MD 06:15 06:45 0.50 923 923 PROD1 DRILL DHEQ T Pulse Test MWD Tools-Function Commander Circ Sub 06:45 08:15 1.50 923 923 PROD1 RIGMN7 SLPC P Slip&Cut 83'of Drill Line 08:15 11:00 2.75 923 6,364 PROD1 DRILL TRIP T RIH w/BHA#6t/6,364'MD(Rotate Through TAM Collar @ 5,872'MD)- (57 Stands) P/U 140, S/O 89 Torque 8K @ 30 RPM 11:00 12:00 1.00 6,364 6,364 PROD1 DRILL PRTS T R/U and Pressure Test Casing t/ 2,000 Psi f/10 Minutes, Pressure Bled t/1870 Psi(Test Completed Twice w/Same Results)-Rig Down Testing Equipment 12:00 19:15 7.25 6,364 19,280 PROD1 DRILL TRIP T Continue to RIH t/19,280'MD(135 Stands) 19:15 23:30 4.25 19,280 20,120 PROD1 DRILL WASH T Wash Down&Tagged Cement @ 20,116'MD,Continue to Drill Cement V 20,120'MD-MWD/Geo-Pilot Detection Problems 23:30 00:00 0.50 20,120 20,120 PROD1 DRILL CIRC T Take SPR's at 1,2 and 3 BPM- Begin Displacement U 11.2 MOBM 06/01/2010 Changed well over f/10.8 ppg LSND to 11.2 ppg OBW-CO cmt to 20,204'-Problem w/MWD-Trouble shoot MWD-POOH for MWD-LD circ tool-Stood back HWDP-jars/bumper sbu&NM flex DC's-Down load MWD-LD MWD componets-Break bit&change jets f/5-11's to 5-12's 00:00 03:45 3.75 20,120 20,120 PROD1 DRILL CIRC T Pumped 80 bbls of water spacer with Safe-Surf-0 added-Changed well over to 11.2 ppg MOBM-from 20,120' -200 gpm/3150 psi/50 rpm @ 21K fUlbs tq.-flow check well,static 03:45 06:15 2.50 20,120 20,204 PROD1 CEMEN"DRLG T Drill out cement from 20,120'to 20,204'-220 gpm/3770 psi/60 rpm @ 14.5K ft/lbs tq. 06:15 08:30 2.25 20,204 20,204 PROD1 DRILL CIRC T Troubleshoot MWD tools-weak pulse-unable to decode-220 gpm/ /3770 psi/60 rpm @ 14.5K ft/lbs. tq.-flow check well,static 08:30 12:00 3.50 20,204 18,096 PROD1 DRILL TRIP T POOH on trip tank from 20,204'to 18,096'PUW 225K SOW 1320K- Hole taking proper fill-slugged drill pipe after first 10 stands 12:00 20:00 8.00 18,096 451 PROD1 DRILL TRIP T Cont. POOH on trip tank f/18,096'to 451'-Flow Ck-well static Page 28 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:00 00:00 4.00 451 0 PROD1 DRILL PULD T Handle BHA-LD Well Commander circulating tool-Stood back HWDP w/jars&bumper sub-stood back NM flex DC's-Removed RA sources f/MWD-Down load MWD-LD MWD-Pull up&break bit(change jets f/5 11's to 5 12's-MU bit 06/02/2010 MU BHA#7-RIH to 6364'(filling pipe every 20 stds&checking MWD pulse)-Tested casing to 1240 psi w/ BHA below TAM PC-Cont. RIH f/6463'to 20,099'-Cut&slip drill line&service rig-Wash down to top of cmt @ 20,204'-Clean out cement to 20,240'-Time drill off plu f/20,240'to 20,244' 00:00 02:45 2.75 0 146 PROD1 DRILL PULD T PJSM-P/U BHA#7:Bit,Geo-Pilot, Geo-Flex,Smart Stab, Phase 4 Collar,Smart Stab, DM,ALD, CTN, PWD, Pulser, BAT, Float Sub V 146' MD-upload tools-pulse test tools 02:45 03:00 0.25 146 146 PROD1 DRILL PULD T PJSM-Load source in tool 03:00 04:15 1.25 146 451 PROD1 DRILL PULD T Continue to M/U BHA#7:3 NMFDC's,XO,Jars, 1 jt HWDP, Bumper Sub,4 jts HWDP,XO,Well Commander Circ Sub and Catcher, XO U 451'MD 04:15 07:15 3.00 451 6,364 PROD1 DRILL TRIP T RIH w/BHA#7 t/6,364'MD(Rotate Through TAM Collar @ 5,872'MD)- (57 Stands) Fill pipe every 20 stands P/U 135,S/O 110 Torque 8K @ 30 RPM 07:15 08:15 1.00 6,364 6,364 PROD1 DRILL PRTS T R/U and Pressure Test Casing U 1240 Psi(w/11.2 ppg mw) Pressure Bled to 1130 Psi in 10 minutes-Rig Down Testing Equipment 08:15 12:00 3.75 6,364 13,805 PROD1 DRILL TRIP T Continue to RIH to 13,805"MD - PUW 177K SOW 110K Filled pipe every 20 stands- established circulate and checked MWD pulse at each fill up 12:00 16:15 4.25 13,805 20,099 PROD1 DRILL TRIP T Cont. RIH w/BHA#7 f/13,805'to 20,099'-Filling pipe every 20 stds& checking MWD pulse 16:15 17:45 1.50 20,099 20,099 PROD1 DRILL SLPC T PJSM-Cut&slip drill line-service rig 17:45 20:00 2.25 20,099 20,240 PROD1 DRILL WASH P Establish circ&wash down f/20099' to 20,204'(top of cmt.)Drill cmt f/ 20,204'to 20,240'@ 210 gpm 3603 psi w/50 rpm's-torque 15 k- Attempt to down link-command timed out-chnaged jet in Geo-Span *Good cement inside casing-ratty cement f/20,224'to 20,235'- polished off plug to 20,240' Page 29 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 20,240 20,244 PROD1 DRILL DDRL P Time drill off cmt plug f/20,240'to 20,244'MD 6409'TVD ADT 3.34 hrs ECD-12.66 ppg WOB 1/5 k RPM 110 GPM 210 @ 3630 psi String wt. PU 280 So 120 ROT 160 Torque on/off btm.-12,000/11,000 ft/lbs 06/03/2010 Time drilled f/20,244'to 20,280'- ABI @ 20,267'showed 74.63°indicating some drop&sample @ 20,252' was 90%shale-Circ btms up-Pull back to 7 5/8'shoe RU&perform FIT to 15.0 ppg EMW- Wash& Ream back to 20,280'hole packing off-work pipe back to 7 5/8"shoe-Wash&ream back to 20,280'(ABI @ 20,267'showing 77.71°after FIT-Conferred w/Sperry Sun RTO&the data indicated that the well has not been sidetracked off plug-Pulled back to 20,240'&began time drilling f/20,240'to 20,270' 00:00 08:15 8.25 20,244 20,280 PROD1 DRILL DDRL T Time drill off of cement plug from 20,244'to 20,280' 210 gpm/3230 psi-100 rpm @ 12.5 K ft/lbs tq. ADT-6.76 hrs. Had trouble with hole packing off @ 20,250,-20,254'-20,272' • Well appears to be sidetracked-RTI @ 20,267'74.63 degeres-ABI from 9 7/8"hole at 20,267'76.48 degrees 08:15 10:00 1.75 20,280 20,280 PROD1 DRILL CIRC T Circulate and condition mud for FIT- While working pipe back to shoe hole packed off with bit @ 20,228'- work to gain circulation and free pipe -worked pipe up into shoe-regained circulation-wiped hole down to 20,280'and back to shoe with out further problems. Rot PUW 175/180K ROT SOW 150K 10:00 11:00 1.00 20,280 20,280 PROD1 DRILL FIT T RU and perform FIT to 15 ppg EMW- 11.2 ppg MVO'with 1260 psi applied surface pressure -RD and blow down lines 11:00 14:30 3.50 20,280 20,280 PROD1 DRILL WASH T Wash and ream from 20,225'to 20,280'-210 gpm/3420 psi/100 rpm @ 12.5K ft/Ibs Hole packing off with bit @ 20,280'- work pipe free-regained full circulation-Pulled back to 20,240' Evaluate RTI data observed-20,268' now 77.71 degrees-Consult with Sperry RTO-concluded well had not been sidetracted 14:30 00:00 9.50 20,240 20,270 PROD1 DRILL DDRL T Time drilling f/20,240'to 20,270'MD 6418'TVD ADT 9.25 hrs. ECD 12,33 ppg WOB 2-3 k RPM 110 GPM 210 @ 3400 psi String wt. PU 280 SO 120 ROT 160 Torque on/off btm.-13,000/11,500 ft/lbs. Page 30 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06/04/2010 24 hr Summary Cont time drilling f/20,270'to 20,292'-hole packing off&torquing up-Back ream f/20,292'to 20,194'- POOH on TT f/20,194'to 451'(pumped dry;ob @ 19,144') Flow ck-well static-LD BHA 00:00 09:00 9.00 20,270 20,929 PROD1 DRILL DDRL T Cont.time drilling f/20,270'to 20,292'MD 6421'TVD ADT 9 hrs. ECD-12.33 ppg WOB O/5 k RPM 110 GPM 220 @ 3460 psi String wt. PU 238 SO 118 ROT 170 Torque on/off btm.-13.5/12.5 ft/lbs Observed packing&hi torque @ 20,292' 09:00 10:15 1.25 20,929 20,194 PROD1 DRILL REAM T BROOH f/20,292'to 20,194' @ 220 gpm @ 3460 psi w/110 rpm's Flow ck-well static 10:15 20:45 10.50 20,194 451 PROD1 DRILL TRIP T POOH on TT f/20,194'to 19,144'- PU wt.209 SO wt 118 -Pumped dry job-Cont.to POOH on TT f/ 19,144'to 451' 20:45 21:30 0.75 451 287 PROD1 DRILL TRIP T LD Well commander circ sub-Flow • ck-well static-Stand back 2 stds HWDP w/bumper sub 21:30 22:00 0.50 287 194 PROD1 DRILL TRIP T Change elevators to 3 1/2"-LD MN flex DC's 22:00 22:30 0.50 194 167 PROD1 DRILL PULD T PJSM on removing RA sources- Remove RA sources f/MWD-LD BAT sonic collar 22:30 00:00 1.50 167 125 PROD1 DRILL PULD T PLUG into MWD&Down load MWD -Pull pulser&LD TM collar 06/05/2010 Finish LD BHA-MU Baker cmt retainer-RIH&set @ 20.085'-RU&test casing to 2500 psi(Good Test)- String into retaine&attempt to perform full LOT-unable to break-down @ 2000 psi(17.0 ppg EMW)-Pump dry job&POOH w/DP&retainer running tool to 9542' 00:00 01:00 1.00 125 0 PROD1 DRILL PULD T Cont. LD BHA-LD pulser, PWD,RLL,DM,SP4-Geo-flex- Break bit&LD GeoPilot-Clear& clean-up rig floor 01:00 01:15 0.25 0 8 PROD1 DRILL PULD T PJSM-MU Baker K-1 cmt retainer& XO sub 01:15 12:30 11.25 8 20,085 PROD1 DRILL TRIP T RIH w/Baker cmt retainer on 4"DP f/8'to 19,940'(209 std DP)MU 4" DP pups&PU std#210-PU 1 single of DP to space out string for setting depth of retainer-PU wt.225 SO wt 125 12:30 13:15 0.75 20,085 20,085 PROD1 DRILL MPSP T MU TD-Break circ-Set Baker K-1 cmt retainer @ 20,085' 13:15 13:30 0.25 20,085 20,285 PROD1 DRILL CIRC T Circulate-staging pump f/3 to 5 bbls/min-ICP 800 psi-FCP-2160 psi-Blow down TD 13:30 14:15 0.75 20,285 20,285 PROD1 DRILL PRTS T RU&pressure test 7 5/8"casing and cement retainer to 2500 psi for 10 mins.Also confirmed TAM PC @ 5872'is closed-Good Test-Blow down lines&RD Page 31 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 17:15 3.00 20,285 20,085 PROD1 DRILL LOT T Pull up&stand back std.#210- Replace 5'pup jt w/10'pup jt-PU std#210-Remove bell guide f/btm of TD-MU 4"XT-39 head pin,valves &high pressure hose-Break circ- Sting into cmt retainer-Anchor tested retainer with 50K SOW- attempt to perform LOT-Pressure up to 2000 psi(17.0 ppg EMW) unable to go to full leak-off-Bleed off pressure to 500 psi&unsting f/ retainer-Flow ck well static-Blow down lines&RD-Replace bell guide. Conferred with Drilling Engineer in town-decision made not to attempt full leak off& Engineer conferred w/ AOGCC on decision. 17:15 17:45 0.50 20,085 20,085 PROD1 DRILL CIRC T MU top drive-pump dry job-Blow down TD 17:45 00:00 6.25 20,085 9,542 PROD1 DRILL TRIP T POOH on TT f/20085'to 9542'-PU wt. 150 SO wt. 110 06/06/2010 Finish POOH w/DP&cmt retainer setting tool-MU whipstock assembly-Cut&Slip drill line 75'&service rig-RIH w/whipstock assembly to 6491'-Test casing to 2000 psi to confirm TAM PC is closed-Cont. RIH w/WS assembly to 18,889' 00:00 03:15 3.25 9,542 0 PROD1 DRILL TRIP T POOH on TT from 9,542'-PJSM- Lay down retainer running tools- clear tools from rig floor Note Function tested pipe rams& hydril w/remote BOP station 03:15 03:30 0.25 0 0 PROD1 WHPST SFTY T PJSM on handling whipstock components 03:30 06:00 2.50 0 114 PROD1 WHPST PULD T MU Whipstock assembly-trip anchor,WS slide,starter mill,water mellon mill,flex jt., upper watermelon mill,xo, 1 jt. hwdp,xo, DM,SP4, TM,float sub-bolt mill to slide 06:00 06:45 0.75 114 114 PROD1 WHPST PULD T Initialize MWD tools 06:45 07:30 0.75 114 290 PROD1 WHPST PULD T MU remainder of BHA-Bumper sub, Commander circ sub,XO,5 jts of HWDP-shallow test MWD 07:30 09:00 1.50 290 290 PROD1 DRILL SVRG T PJSM-Cut and slip drilling line- Service top Drive and Drawworks 09:00 13:30 4.50 290 6,491 PROD1 WHPST TRIP T RIH from 290'to 6491"-PUW 110K SOW 105K-fill pipe every 20 stands 13:30 14:30 1.00 6,491 6,491 PROD1 WHPST PRTS T RU and test casing to 2000 psi for 5 minutes,good. RD and blow down lines 14:30 00:00 9.50 6,491 18,889 PROD1 WHPST TRIP T Continue RIH w/whipstock assembly on 4"DP f/6491'to 18,889'-filling pipe every 20 stds. PU wt.220 SO wt 130 Page 32 of 39 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 06/07/2010 24 hr Summary Cont. RIH w/Whipstock assembly f/18,889'to 20,035'-Orient whipstock to 64°right of high side-Wash down f/20035'to 20,085'-Tagged up on cmt retainer-set btm anchor @ 20,085'-Milled window f/20,067'to 20,080'-Drilled new hole f/20,080'to 20,112'to put top watermelon mill 20'outside window-Circ-Perform FIT to 15.2 ppg-POOH to 19,622'(improper hole fill-RIH to 20.034'-Drop ball&open well commander circ sub-Pump Super sweep&Circ btms up-Std back 1 std DP every 30 mins to 19,462'-POOH on TT to 18031'-Pumped dry job-POOH on TT to 17,651' 00:00 01:15 1.25 18,889 20,035 PROD1 WHPST TRIP T RIH w/7 5/8"Whipstock assembly from 18,889'to 20,035'-unwrap and inspect super sliders-PUW 225K SOW 123K 01:15 03:00 1.75 20,035 20,085 PROD1 WHPST CIRC T Circulate down from 20,035'to 20,085'210 gpm/2850 psi-orient whipstock slide to 64 degrees right of high side-slack off and set anchor- work assemble and sheer 35K carrier bolt 03:00 05:30 2.50 20,067 20,080 PROD1 WHPST WPST T Mill window in casing from 20,067'to 20,080'-210 gpm/2890 psi/80 rpm @ 13K ft/lbs-Pump 40 bbls mud w/.1 ppb Supper Sweep 05:30 09:15 3.75 20,080 20,112 PROD1 WHPST WPST T Drill formation from 20,080'to 20,112' MD 6376'TVD-enlarge window with watermelon mills to 6 3/4"-upper watermellon mill 20'out of window for planned GeoPilot run-pumped 40 bbls of mud with.1 ppb of Super Sweep added after top WMW in open hole 09:15 11:15 2.00 20,112 20,034 PROD1 WHPST CIRC T Circulate BU 210 gpm/2890 psi/80 rpm @ 13K ft/lbs made several passes rotating mills through window -shut down rotary and made two passes through window with mills- no problems flow chech well-static- set back 1 stand 11:15 12:00 0.75 20,034 20,034 PROD1 DRILL FIT T PJSM-RU and perform FIT to 15.2 ppg-11.0 ppg MOBM with 1380 psi applied surface pressure-RD&blow down lines 12:00 12:30 0.50 20,034 20,034 PROD1 DRILL OWFF T Flow check well,static-clean out solids built up in drip pan below rotary table 12:30 13:00 0.50 20,034 20,034 PROD1 DRILL CIRC T Pump dry job-blow down top drive 13:00 13:45 0.75 20,034 19,622 PROD1 DRILL TRIP T POOH on trip tank from 20,234'to 19,622'PUW 245K SOW 120- PUW increased 10K,well began swabbing 13:45 15:30 1.75 19,622 20,034 PROD1 DRILL REAM T Wash and ream from 19,610'to 20,034'-225 gpm/3130 psi/80 rpm @ 12K ft/lbs-155K Rot Wt. Page 33 of 39 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 15:30 17:00 1.50 20,034 20,034 PROD1 DRILL CIRC T Flow check well,static-drop operating ball for Commander sub- pump down at 2 bpm/600 psi-ball on seat after 1164 stks w/950 psi (calc 2000 stks)increase pressure 1500 psi and then 2000 psi-tool opened -circ @ 2 bpi/490 psi- increase rate to 7 bpm @ 3840 psi 17:00 20:45 3.75 20,034 19,462 PROD1 DRILL CIRC T Pump sweep 35 bbls OBM w/12 quarts of Super Sweep-300 gpm @ 3850 psi 100 rpm's-stood back 1 std DP wevery 30 mins.to 19,462' 20:45 23:00 2.25 19,462 18,031 PROD1 DRILL TRIP T Flow Ck well static-POOH on TT f/ 19,462'to 18,031' PU wt.215 SO wt 125(Hole taking proper fill) 23:00 23:15 0.25 18,031 18,031 PROD1 DRILL CIRC T Flow ck well static-Pumped dry job -Blow down TD 23:15 00:00 0.75 18,031 17,651 PROD1 DRILL TRIP T POOH on TT f/18,031'to 17,651' PU wt.215 SO wt 125 06/08/2010 Finish POOH&LD mill assembly-Flush stack-RU&test BOPE(Witnessed by AOGCC)-MU BHA#9 (GeoPilot)RIH to 921'Function Well commander circ sub 00:00 06:30 6.50 17,651 292 PROD1 DRILL TRIP T Cont. POOH w/mill assembly f/ 17,651'to 292'-Flow ck well static 06:30 08:45 2.25 292 0 PROD1 DRILL PULD T PJSM on LD BHA-Std back HWDP -LD Well Commander circ sub,XO, Bumper Sub,float sub, Download MWD-LD MWD tools(DM-SP4- TM)XO, 1 jt HWDP, upper&lower watermelon mills,starter mill-Clear rig floor of BHA tools-Clean-up rig floor of OBM 08:45 09:30 0.75 0 0 PROD1 WHDBO NUND T PJSM on flushing stack-MU stack washer&flush stacke-Function all rams&flush stack again-LD stacke washer&Blow down lines 09:30 11:00 1.50 0 0 PROD1 WHDBO BOPE T MU test jt.&pull wear bushing-Set test plug 11:00 17:00 6.00 0 0 PROD1 WHDBO BOPE T RU&Tested BOPE as follows; Hydril to 250&3500 psi-pipe rams, choke&kill line valves,choke manifold valves,floor safety&dart valves,upper&lower TD IBOP's, blind rams to 250&5000 psi (Used 4"test jt)-Performed accumulator recovery test-MU 5,1/2"test jt- Tested Hydril to 250&3500 psi- Tested upper pipe rams to 250& 5000 psi-Test witnessed& approved by Bob Noble AOGCC- Blow down kill&choke lines& choke manifold-Pull test plug 17:00 17:30 0.50 0 0 PROD1 WHDBO BOPE T Set wear bushing 17:30 18:00 0.50 0 0 PROD1 DRILL OTHR T Clean out drip pans under rig floor of MOBM Page 34 of 39 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:00 3.00 0 238 PROD1 DRILL PULD T PJSM on MU BHA- MU BHA#9- Bit(#4RR2)-GeoPilot 5200-Geo Flex-Smart Stab-MWD(Slim Phase 4-Smart stab-DM collar- ALD collar-CTN collar-PWD-TM w/pulser)-Plug in&up load MWD- MU BAT Sonic&NM flex DC's 21:00 21:45 0.75 238 238 PROD1 DRILL CIRC T MU TD-pulse test MWD @ 200 gpm @ 1050 psi-60 rpm's-4.5 k torque 21:45 22:15 0.50 238 238 PROD1 DRILL SFTY T PJSM on laoding RA sources-Load RA sources into MWD tool 22:15 23:00 0.75 238 449 PROD1 DRILL PULD T Finish MU BHA#9-XO,jars,l jt. HWDP, bumper sub,4 jts. HWDP, XO,well Commander circ sub,XO 23:00 23:15 0.25 449 921 PROD1 DRILL TRIP T RIH w/BHA#9 on 4"DP f/449'to 921' PU wt.90 SO wt.90 23:15 00:00 0.75 921 921 PROD1 DRILL CIRC T MU TD-Circ&establish rates- Function Well Commander circ sub- Opened&closed w/2300 psi- 06/09/2010 RIH to 6362'(rotated thru TAM PC)-RU&pressure test cag to 1000 psi Good Test-RIH to 16,182'-C&S drill line-Service TD-RIH to 20002-Obtain SPR-Wash down to 20122'-Drilled to 20,114'-string torqued up&hole packed off-stuck pipe-worked pipe free(5 hrs.)-pulled back to 20033'-Circ btms up-Attempt to wash back to TD-string taking wt.@ 20,064'(25 k)-worked pipe unable to wash&ream past 20,064' 00:00 02:45 2.75 921 6,362 PROD1 DRILL TRIP T RIH w/BHA#9(GP)f/921'to 6362' PU wt. 120 SO wt. 110-Filled pipe every 20 stds&checked MWD- Rotated through TAM PC @ 5857'20 rpm's @ 5 k torque 02:45 03:30 0.75 6,362 6,362 PROD1 DRILL PRTS T PJSM-RU&pressure test casing to 1000 psi for 10 mins.to confirm TAM PC is closed-Good Test RD&blow down lines 03:30 07:45 4.25 6,362 16,182 PROD1 DRILL TRIP T Cont. RIH f/6362'to 16,182'-PU wt. 198 SO wt. 120-filled pipe every 20 stds&checked MWD 07:45 10:00 2.25 16,182 16,182 PROD1 RIGMNTSLPC T PJSM-Cut&slip drill line 60'- Service TD-Changed swivel packing &tested to 4000 psi 10:00 12:00 2.00 16,182 20,002 PROD1 DRILL TRIP T Cont. RIH f/16,182'to 20,002' PU wt.215 SO wt. 120-filled pipe • every 20 stds&checked MWD 12:00 13:30 1.50 20,002 20,112 PROD1 DRILL WASH T Establish circ-Obtain SPR's-Wash down f/20,002'to 20,112'-225 gpm @ 3710 psi -PU wt.240 SO wt. 120 13:30 13:45 0.25 20,112 20,114 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/20,112'to 20,114'MD ADT-.07 hrs WOB 5 k RPM 35 GPM 225 @ 3800 psi String wt. PU 245 SO 120 ROT 170 Torque 12.5 k Page 35 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 18:30 4.75 20,114 20,033 PROD1 DRILL JAR T String torqued up&packed off& stuck pipe-Worked pipe-jarred up @ 325 k-slacking off to 100 k- applied 12 K torque&worked pipe- Cont.to work pipe-worked pipe free &pulled up to 20,033' 18:30 21:00 2.50 20,033 20,033 PROD1 DRILL CIRC T Established circ-staged pump up to drilling rate 225 gpm @ 3700 psi- Circ btms up @ 225 gpm @ 3700 psi -45 rpm's-torque 12.5 k-ROT wt. 170-Flow ck-well static Note-@ btms up didn't see any signs of shale-ditch magnets appeared to have increased in the amount of metal collected prior to beginning circulating btms up 21:00 00:00 3.00 20,033 20,064 PROD1 DRILL WASH T Begin washing down f/20,033'@225 gpm @ 3700 psi-String started taking weight @ 20,060'to 20,064'- 25 k-worked pipe several times f/ 20,033'to 20,064'w/pump-Wash& ream f/20,033'to 20,064'-string taking wt. @ 20,060'(20 k while rotating)worked pipe several w/ pump&rotary-Unable to pass below 20,064'(top of window 20,067')-Cont.working pipe- Conferred with drilling engineer and dicussed options. 06/10/2010 POOH w/GeoPilot assembly-LD BHA-Clean up rig floor-Work in pipe installing thread protectors on 5 1/2' liner&3 1/2"tbg-Remove 5 1/2" liner f/shed-LD Geo Span f/rig floor-MU milling assembly-RIH to 6157' -Test csg to 1000 psi for 10 mins.-Cont. RIH to 9780' 00:00 08:00 8.00 20,064 449 PROD1 DRILL TRIP T POOH on TT f/20,064'to 19,619'- Pumped dry job-Blown down TD- Cont. POOH on TT f/19,619'to 449' ' (top of BHA-Flow ck well static 08:00 09:15 1.25 449 145 PROD1 DRILL PULD T PJSM-LD BHA-LD XO,Well commander circ sub,XO-6 jts HWDP,jars&bumper sub, NM flex DC's 09:15 09:30 0.25 145 145 PROD1 DRILL PULD T PJSM-Remove RA sources f/MWD 09:30 12:00 2.50 145 0 PROD1 DRILL PULD T Cont. LD BHA-Down load MWD- LD MWD tools(BAT sonic,TM collar, PWD, CTN collar,ALD collar, DM collar)smart stab, Pull up&break bit-LD Slim phase 4,Smart stab, Geo flex,Geo Pilot-Clear rig floor of tools-Clean up rig floor 12:00 17:00 5.00 0 0 PROD1 DRILL OTHR T Cont.to clean up rig floor-LD Geo Span f/rig floor-Install thread protectors on 5 1/2"liner&remove f/ pipe shed-Install thread protects on 3 1/2"tbq Page 36 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:30 0.50 0 244 PROD1 DRILL PULD T MU milling BHA(starter mill, watermelon mill,flex jt.,watermelon mill,XO,2 boot bskts,bit sub,XO, Jars, 1 jt. HWDP,bumper sub,4 jts. HWDP,XO,Well Cmooander circ sub w/ball catcher,XO 17:30 21:00 3.50 244 6,157 PROD1 DRILL TRIP T RIH w/milling assembly on 4"DP to 6157'(ran slow thru TAM PC) 21:00 22:00 1.00 6,157 6,157 PROD1 DRILL PRTS T RU&pressure test casing to 1000 psi for 10 mins.(to check TAM PC) Good test-RD-Blow down lines 22:00 00:00 2.00 6,157 9,780 PROD1 DRILL TRIP T Cont. RIH w/milling assembly on 4" DP f/6157'to 9780' 06/11/2010 RIH w/mill assembly-Washed down f/19,987'to 20069'Tagged obstruction-PU to 19,987'Circ&cond. mud-POOH w/mill assembly-MU cmt retainer&RIH to 2863' 00:00 05:30 5.50 9,780 19 PROD1 DRILL TRIP T RIH f/9780'to 19,987'w/milling assembly-PU wt.220 SO wt. 125- Removed Super Sliders on trip in hole 05:30 06:00 0.50 19 20,069 PROD1 DRILL WASH T Wash down f/19,987'to 20,069'-3 bbls/min @ 1110 psi-tagged obstruction @ 20,069' 06:00 10:45 4.75 20,069 19,987 PROD1 DRILL CIRC T Circ&condition mud for trip-@ 19,987'-Dropped opening ball for Well Commander circ sub&pumped down-opened well commander- Pumped Super Sweep pill @ 7 bbls/min @ 3750 psi-Observed no metal cuttings w/sweep back to surface-Flow Ck.well static 10:45 12:00 1.25 19,987 19,510 PROD1 DRILL TRIP T POOH on TT f/19,987'to 19,510'- PU wt.215 SO wt. 125-Flow ck. well static-Pumped dry job 12:00 20:30 8.50 19,510 34 PROD1 DRILL TRIP T POOH on TT f/19,510'to 244'-Flow ck.well static-LD XO subs-Well commander-Stood back HWDP& jars-LD bumper sub 20:30 21:00 0.50 34 0 PROD1 DRILL PULD T LD-boot baskets&mills-no recovery in boot baskets 21:00 22:00 1.00 0 0 PROD1 DRILL PULD T Clean up rig floor-Send mills,circ sub down beaver slide-PU cmt. retainer 22:00 00:00 2.00 0 2,863 PROD1 DRILL TRIP T MU Baker K-1 cement retainer&RIH on 4"DP to 2863' 06/12/2010 RIH&Set cmt retainer @ 19,705'-Test casing&retainer to 2500 psi for 30 mins.-Attempt LOT-Pressure • to 2000 psi-No leak-off(FIT to 17.00 ppg-POOH w/DP&retainer running tool-RU&test top pipe ram to 250&3500"psi-RU&Ran 3 1/2"kill string to 2177'(69 jts)-Pull tbg running wear bushing 00:00 06:30 6.50 2,863 19,658 PROD1 DRILL TRIP T RIH w/Baker K-1 cement retainer f/ 2863'to 19658' 06:30 07:00 0.50 19,658 19,705 PROD1 DRILL MPSP T Space out&set retainer @ 19,705'- Release f/retainer 07:00 08:15 1.25 19,705 197,085 PROD1 DRILL PRTS T RU&test casing&retainer to 2500 psi for 30 mins. Page 37 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 09:45 1.50 197,085 19,626 PROD1 DRILL LOT T Sting into retainer-Attempt to perform LOT-Pressure up to 2000 psi w/no leak-off(17.0 ppg EMW) bled down to 1320 psi in 10 mins. RD test equipment-Pull up to 19,626'-Flow ck.well static 09:45 11:15 1.50 19,626 19,626 PROD1 RIGMN7 SLPC T PJSM-Cut&slip drill line 120'- Service TD 11:15 18:30 7.25 19,626 0 PROD1 DRILL TRIP T Pump dry job-POOH on TT f/ 19,626'w/cmt. retainer running tool- LD running tool 18:30 19:30 1.00 0 0 PROD1 WHDBO BOPE T Pull wear bushing-Set test plug& test upper pipe rams to 250&3500 psi-Pull test plug 19:30 20:30 1.00 0 0 PROD1 RPCOM RURD T Set tubing running wear bushing& RU to run 3 1/2"kill string 20:30 23:15 2.75 0 2,178 PROD1 RPCOM RCST T Ran kill string- 3 1/2"9.3#L-80 EUE 8rd tbg(69 jts.)w/WLEG to 2177.5' 23:15 00:00 0.75 2,178 2,178 PROD1 RPCOM RCST T MU pulling tool&Retrieve tbg running wear bushing 06/13/2010 Finish pulling tbg wear bushing-MU tbg hanger&land tbg w/tail @ 2211'-Test hanger seals to 5000 psi- Flush BOP stack-Break cap on Hydril-Remove rams f/stack(prep for rig maintenance)-ND BOP-NU& test tree-Freeze protect w/LVT to 100'-RU&LD 4"DP 00:00 00:30 0.50 2,178 2,178 PROD1 RPCOM RCST T Finish pulling tbg running wear bushing 00:30 01:00 0.50 2,178 2,211 PROD1 RPCOM RCST T MU tbg hanger-land 3 1/2"kill string @ 2211'-RILDS 01:00 01:30 0.50 2,211 2,211 PROD1 WHDBO PRTS T RU&test tbg hnager seals to 5,000 psi-RD-LD landing jt. 01:30 03:00 1.50 0 0 PROD1 WHDBO OTHR T RU&flush BOP stack w/Save Suf 0 to clean up OBM 03:00 09:45 6.75 0 0 PROD1 WHDBO NUND T ND bell nipple&flow line-RU spud masher&break cap on Hydril- Remove pipe rams&blind f/BOP stack-ND BOP stack 09:45 12:00 2.25 0 0 PROD1 WHDBO NUND T NU&test tree to 5000 psi-Pull TWC 12:00 12:45 0.75 0 0 PROD1 DRILL RURD T RU squeeze manifold&hard lines to tbg&annulus 12:45 13:00 0.25 0 0 PROD1 DRILL SFTY T PJSM on freeze protect well 13:00 15:30 2.50 0 0 PROD1 DRILL FRZP T Freeze protect well to 100'- Dowell pumped 10 bbls LVT down tbg.-shut in manifold&let well U-tube-Blow down&vac out lines-RU lines& manifold-Set BPV&Secure well 15:30 15:45 0.25 0 0 PROD1 DRILL SFTY T PJSM on LD DP 15:45 00:00 8.25 0 0 PROD1 DRILL PULD T LD 4"DP f/derrick via mouse hole for rig move 06/14/2010 Finish LD 4"DP via mouse hole&Remove remaining Super Sliders-Change TD dollies-Clean rig after OBM (blocks,TD, Iron roughneck-mud pits)Remove temporary hericulite wind walls in cellar-drained centrifugal pumps Page 38 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 14:00 14.00 0 0 PROD1 DRILL PULD T LD 4"DP f/derrick via mouse hole for rig move Removed remaining of Super Sliders on stds#206-#212 14:00 17:00 3.00 0 0 PROD1 RIGMNT RGRP T PJSM on changing TD dollies- Change out TD dollies 17:00 17:30 0.50 0 0 PROD1 RIGMNTSVRG T Service rig 17:30 00:00 6.50 0 0 PROD1 DRILL RURD T Clean up rig f/OBM-pressure wash blocks,TD,&iron roughneck.Clean mud pits-Remove hericulite wind walls in cellar area-Drained centrifugal pumps 06/15/2010 Continue to Clean Rig of OBM and Prep For Move-Rig Released on 15 Jun 2010 at 0600 L 00:00 06:00 6.00 0 0 PROD1 MOVE MOB P Continue to Clean Rig of OBM and Prep for Move to CD4-23 Page 39 of 39 CD1-15 WELL WORK SUMMARY DATE SUMMARY 10/6/2010 LOCATED WLEG @ 2184'SLM. LOGGED TEMP SURVEY PER PROCEDURE. 32.62 DEG @ 1462' RKB. FMC RE-INSTALLED BPV. COMPLETE. 11/21/2010 PULLED BACK PRESSURE VLV. IN PROGRESS. 11/23/2010 PERFORMED HIGH RESOLUTION TEMP SURVEY f/ 1004'TO 100' RKB. READY FOR BACK PRESSURE VLV. a El _3 ConocoPhillips(Alaska) Inc. 3 3 Western North Slope CD1 Alpine "ad _` 3 '3 CD1-15PB1 _3 501032061970 CP 10 - ? In - ervices Definitive Survey Report til 3 16 June, 2010 rg g tri • E• l kl 3 e _ HAL o 'idF "l `per ] T ;_ _; Sperry Drilling Services _3 v3 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: -Well CD1-15 Project Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference:" CD1-15 @ 56.15ft(D19(36.65+19.5)) Well - CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production .... ............._._. ...... .. .. .._. Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD1-15 Well Position +N/-S 0.00 ft Northing: 5,975,805.80ft Latitude: 70°20'33.932 N +E/-W 0.00 ft Easting: 385,901.08 ft Longitude: 150°55'33.713 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft Wellbore CD1-15PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 5/1/2010 21.17 80.73 57,625 Design CD1-15PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.65 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 36.65 0.00 0.00 79.00 Survey Program Date From To (ft) (ft) Survey(Wellbore)„ Tool.Name Description Survey Date 81.00 1,006.00 CD1-15PB1 Gyro(CD1-15PB1) CB-GYRO-SS Camera based gyro single shot 4/29/2010 1: 1,106.18 3,063.99 CD1-15PB1 MWD(R200)(CD1-15PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/30/2010 1: 3,147.95 20,666.44 CD1-15PB1 MWD(R300)(CD1-15PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/4/2010 12: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (') (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.65 0.00 0.00 36.65 -19.50 0.00 0.00 5,975,805.80 385,901.08 0.00 0.00 UNDEFINED 81.00 0.27 57.03 81.00 24.85 0.06 0.09 5,975,805.86 385,901.17 0.61 0.10 CB-GYRO-SS(1) 171.00 0.38 58.28 171.00 114.85 0.33 0.52 5,975,806.12 385,901.61 0.12 0.57 CB-GYRO-SS(1) 234.00 0.70 33.27 234.00 177.85 0.76 0.91 5,975,806.55 385,902.00 0.62 1.04 CB-GYRO-SS(1) 264.00 0.93 20.08 263.99 207.84 1.14 1.09 5,975,806.93 385,902.19 0.98 1.29 CB-GYRO-SS(1) 354.00 2.75 2.26 353.94 297.79 3.99 1.43 5,975,809.76 385,902.57 2.10 2.16 CB-GYRO-SS(1) 447.00 4.32 3.83 446.76 390.61 9.71 1.75 5,975,815.48 385,902.98 1.69 3.57 CB-GYRO-SS(1) 540.00 4.55 5.74 539.48 483.33 16.88 2.35 5,975,822.64 385,903.69 0.29 5.53 CB-GYRO-SS(1) 631.00 6.34 352.27 630.07 573,92 25.45 2.04 5,975,831.21 385,903.51 2.40 6.86 CB-GYRO-SS(1) 723.00 6.96 351.08 721.45 665.30 35.99 0.49 5,975,841.77 385,902.12 0.69 7.35 CB-GYRO-SS(1) 816.00 6.77 352.80 813.79 757.64 46.99 -1.07 5,975,852.80 385,900.73 0.30 7.92 CB-GYRO-SS(1) 911.00 7.80 2.76 908.02 851.87 58.99 -1.46 5,975,864.80 385,900.52 1.71 9.82 CB-GYRO-SS(1) 6/16/2010 10:12:24AM Page 2 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) -Site: CD1 Alpine Pad MD Reference:''. CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-WNorthing Easting DLS, Section (ft) (°) C) (ft) (ft) (ft) (ft) (ft) (ft) ("1100') (ft) Survey Tool Name 1,006.00 12.03 16.93 1,001.60 945.45 74.91 1.73 5,975,880.67 385,903.96 5.11 16.00 CB-GYRO-SS(1) 1,106.18 15.23 35.28 1,098.99 1,042.84 95.65 12.38 5,975,901.24 385,914.92 5.33 30.41 MWD+IFR-AK-CAZ-SC(2)' 1,163.05 16.07 45.33 1,153.76 1,097.61 107.29 22.30 5,975,912.72 385,925.01 4.98 42.36 MWD+1FR-AK-CAZ-SC(2) 1,257.40 19.11 52.64 1,243.70 1,187.55 125.84 43.87 5,975,930.95 385,946.86 3.98 67.07 MWD+IFR-AK-CAZ-SC(2) 1,353.84 22.01 57.15 1,333.99 1,277.84 145.23 71.60 5,975,949.91 385,974.88 3.42 98.00 MWD+IFR-AK-CAZ-SC(2) 1,449.22 25.81 61.60 1,421.18 1,365.03 164.81 104.90 5,975,968.98 386,008.47 4.41 134.42 MWD+IFR-AK-CAZ-SC(2) 1,544.31 28.82 64.36 1,505.66 1,449.51 184.58 143.78 5,975,988.15 386,047.64 3.43 176.36 MWD+IFR-AK-CAZ-SC(2) 1,639.08 30.49 66.69 1,588.02 1,531.87 203.98 186.46 5,976,006.90 386,090.61 2.14 221.95 MWD+IFR-AK-CAZ-SC(2) 1,734.54 34.30 67.36 1,668.61 1,612.46 223.92 233.54 5,976,026.13 386,137.98 4.01 271.98 MWD+IFR-AK-CAZ-SC(2) 1,829.12 38.29 67.37 1,744.82 1,688.67 245.47 285.20 5,976,046.88 386,189.97 4.22 326.80 MWD+IFR-AK-CAZ-SC(2) 1,923.99 40.41 70.58 1,818.18 1,762.03 267.00 341.35 5,976,067.56 386,246.42 3.10 386.02 MWD+IFR-AK-CAZ-SC(2) 2,018.71 44.09 72.14 1,888.29 1,832.14 287.33 401.69 5,976,086.96 386,307.06 4.04 449.13 MWD+IFR-AK-CAZ-SC(2) 2,114.41 46.91 70.87 1,955.36 1,899.21 308.99 466.41 5,976,107.63 386,372.10 3.09 516.79 MWD+IFR-AK-CAZ-SC(2) 2,209.25 49.52 73.06 2,018.55 1,962.40 330.86 533.64 5,976,128.47 386,439.65 3.25 586.97 MWD+IFR-AK-CAZ-SC(2) 2,304.06 53.34 72.61 2,077.65 2,021.50 352.74 604.45 5,976,149.27 386,510.78 4.05 660.65 MWD+IFR-AK-CAZ-SC(2) 2,398.99 57.31 74.21 2,131.65 2,075.50 375.00 679.26 5,976,170.38 386,585.92 4.41 738.33 MWD+IFR-AK-CAZ-SC(2) 2,494.57 59.53 75.52 2,181.71 2,125.56 396.24 757.86 5,976,190.43 386,664.82 2.60 819.54 MWD+IFR-AK-CAZ-SC(2) 2,589.21 63.01 75.36. 2,227.19 2,171.04 417.11 838.17 5,976,210.07 386,745.43 3.68 902.36 MWD+IFR-AK-CAZ-SC(2) 2,683.09 67.26 76.12 2,266.66 2,210.51 438.07 920.70 5,976,229.77 386,828.27 4.59 987.38 MWD+IFR-AK-CAZ-SC(2) 2,779.27 69.93 77.73 2,301.76 2,245.61 458.32 1,007.92 5,976,248.68 386,915.78 3.18 1,076.85 MWD+IFR-AK-CAZ-SC(2) 2,874.84 72.96 79.05 2,332.17 2,276.02 476.54 1,096.66 5,976,265.55 387,004.77 3.43 1,167.44 MWD+IFR-AK-CAZ-SC(2) 2,969.35 75.55 78.81 2,357.81 2,301.66 494.00 1,185.92 5,976,281.66 387,094.28 2.75 1,258.39 MWD+IFR-AK-CAZ-SC(2) 3,063.99 75.46 79.06 2,381.50 2,325.35 511.59 1,275.84 5,976,297.87 387,184.46 0.27 1,350.02 MWD+IFR-AK-CAZ-SC(2) 3,147.95 76.01 78.47 2,402.19 2,346.04 527.44 1,355.66 5,976,312.51 387,264.49 0.94 1,431.39 MWD+IFR-AK-CAZ-SC(3) 3,239.59 76.45 79.46 2,424.00 2,367.85 544.48 1,443.02 5,976,328.21 387,352.09 1.15 1,520.39 MWD+IFR-AK-CAZ-SC(3) 3,337.88 76.96 80.07 2,446.60 2,390.45 561.47 1,537.15 5,976,343.77 387,446.47 0.80 1,616.04 MWD+IFR-AK-CAZ-SC(3) 3,427.41 76.70 79.55 2,467.00 2,410.85 576.90 1,622.95 5,976,357.88 387,532.48 0.64 1,703.21 MWD+IFR-AK-CAZ-SC(3) 3,527.47 77.15 79.08 2,489.64 2,433.49 594.97 1,718.72 5,976,374.49 387,628.52 0.64 1,800.67 MWD+IFR-AK-CAZ-SC(3) 3,622.17 77.46 78.25 2,510.45 2,454.30 613.13 1,809.31 5,976,391.27 387,719.36 0.92 1,893.05 MWD+IFR-AK-CAZ-SC(3) 3,722.88 76.26 78.27 2,533.34 2,477.19 633.08 1,905.32 5,976,409.76 387,815.66 1.19 1,991.12 MWD+IFR-AK-CAZ-SC(3) 3,806.66 76.64 79.09 2,552.97 2,496.82 649.07 1,985.19 5,976,424.52 387,895.75 1.05 2,072.56 MWD+IFR-AK-CAZ-SC(3) 3,906.38 76.71 79.72 2,575.96 2,519.81 666.91 2,080.57 5,976,440.91 387,991.38 0.62 2,169.59 MWD+IFR-AK-CAZ-SC(3) 4,002.46 76.39 80.24 2,598.31 2,542.16 683.17 2,172.59 5,976,455.77 388,083.63 0.62 2,263.03 MWD+IFR-AK-CAZ-SC(3) 4,098.56 76.45 80.18 2,620.87 2,564.72 699.05 2,264.64 5,976,470.25 388,175.91 0.09 2,356.42 MWD+IFR-AK-CAZ-SC(3) 4,190.21 76.64 80.47 2,642.19 2,586.04 714.03 2,352.51 5,976,483.89 388,263.98 0.37 2,445.53 MWD+IFR-AK-CAZ-SC(3) 4,288.54 76.77 80.82 2,664.81 2,608.66 729.59 2,446.93 5,976,498.00 388,358.62 0.37 2,541.18 MWD+IFR-AK-CAZ-SC(3) 4,383.53 76.45 81.25 2,686.81 2,630.66 743.99 2,538.21 5,976,511.01 388,450.10 0.55 2,633.53 MWD+IFR-AK-CAZ-SC(3) 4,479.65 76.13 81.77 2,709.59 2,653.44 757.77 2,630.56 5,976,523.39 388,542.65 0.62 2,726.82 MWD+IFR-AK-CAZ-SC(3) 4,573.88 76.00 81.68 2,732.28 2,676.13 770.94 2,721.07 5,976,535.17 388,633.34 0.17 2,818.18 MWD+IFR-AK-CAZ-SC(3) 4,668.31 76.26 81.33 2,754.92 2,698.77 784.48 2,811.74 5,976,547.33 388,724.20 0.45 2,909.77 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:12:24AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference::' CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: ' CD1-15PB1 Database: CPAI EDM Production Survey - Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section (ft) (°) " (°) (ft) (ft) (ft) (ft) (ft) (ft) 01001 (ft) Survey Tool Name 4,762.92 76.71 80.90 2,777.03 2,720.88 798.69 2,902.63 5,976,560.15 388,815.28 0.65 3,001.69 MWD+IFR-AK-CAZ-SC(3) 4,859.62 76.58 80.76 2,799.36 2,743.21 813.68 2,995.51 5,976,573.73 388,908.37 0.19 3,095.73 MWD+IFR-AK-CAZ-SC(3) 4,954.00 76.96 79.85 2,820.96 2,764.81 829.15 3,086.07 5,976,587.82 388,999.15 1.02 3,187.58 MWD+IFR-AK-CAZ-SC(3) 5,049.78 76.71 79.91 2,842.78 2,786.63 845.54 3,177.88 5,976,602.81 389,091.19 0.27 3,280.83 MWD+IFR-AK-CAZ-SC(3) 5,144.79 75.82 78.67 2,865.34 2,809.19 862.69 3,268.56 5,976,618.57 389,182.12 1.58 3,373.12 MWD+IFR-AK-CAZ-SC(3) 5,240.27 76.08 78.62 2,888.52 2,832.37 880.93 3,359.37 5,976,635.42 389,273.19 0.28 3,465.74 MWD+IFR-AK-CAZ-SC(3) 5,334.97 75.68 79.46 2,911.62 2,855.47 898.39 3,449.54 5,976,651.51 389,363.60 0.96 3,557.58 MWD+IFR-AK-CAZ-SC(3) 5,430.78 75.94 79.66 2,935.10 2,878.95 915.22 3,540.89 5,976,666.95 389,455.19 0.34 3,650.46 MWD+IFR-AK-CAZ-SC(3) 5,528.32 76.33 80.66 2,958.48 2,902.33 931.40 3,634.19 5,976,681.71 389,548.72 1.07 3,745.14 MWD+IFR-AK-CAZ-SC(3) 5,621.09 76.77 81.15 2,980.06 2,923.91 945.66 3,723.28 5,976,694.61 389,638.01 0.70 3,835.31 MWD+IFR-AK-CAZ-SC(3) 5,711.12 76.38 80.51 3,000.96 2,944.81 959.62 3,809.73 5,976,707.25 389,724.65 0.82 3,922.84 MWD+IFR-AK-CAZ-SC(3) 5,811.41 76.33 80.49 3,024.62 2,968.47 975.70 3,905.85 5,976,721.86 389,821.00 0.05 4,020.26 MWD+IFR-AK-CAZ-SC(3) 5,902.97 76.25 80.46 3,046.32 2,990.17 990.42 3,993.58 5,976,735.25 389,908.93 0.09 4,109.19 MWD+IFR-AK-CAZ-SC(3) 6,001.81 76.63 80.25 3,069.49 3,013.34 1,006.52 4,088.30 5,976,749.90 390,003.88 0.44 4,205.24 MWD+IFR-AK-CAZ-SC(3) 6,094.77 76.51 79.76 3,091.08 3,034.93 1,022.21 4,177.35 5,976,764.23 390,093.15 0.53 4,295.65 MWD+IFR-AK-CAZ-SC(3) 6,191.66 76.33 79.07 3,113.83 3,057.68 1,039.51 4,269.93 5,976,780.12 390,185.97 0.72 4,389.83 MWD+IFR-AK-CAZ-SC(3) 6,282.72 76.45 78.67 3,135.26 3,079.11 1,056.60 4,356.77 5,976,795.88 390,273.05 0.45 4,478.33 MWD+IFR-AK-CAZ-SC(3) 6,380.98 76.89 78.46 3,157.92 3,101.77 1,075.55 4,450.48 5,976,813.41 390,367.04 0.49 4,573.94 MWD+IFR-AK-CAZ-SC(3) 6,477.93 76.65 78.48 3,180.11 3,123.96 1,094.42 4,542.95 5,976,830.86 390,459.78 0.25 4,668.31 MWD+IFR-AK-CAZ-SC(3) 6,571.23 77.02 78.14 3,201.35 3,145.20 1,112.83 4,631.92 5,976,847.91 390,549.00 0.53 4,759.15 MWD+IFR-AK-CAZ-SC(3) 6,667.35 76.70 78.28 3,223.21 3,167.06 1,131.95 4,723.54 5,976,865.64 390,640.91 0.36 4,852.75 MWD+IFR-AK-CAZ-SC(3) 6,761.79 75.82 78.39 3,245.64 3,189.49 1,150.50 4,813.39 5,976,882.81 390,731.01 0.94 4,944.48 MWD+IFR-AK-CAZ-SC(3) 6,854.81 76.63 77.92 3,267.79 3,211.64 1,169.05 4,901.81 5,976,900.01 390,819.70 1.00 5,034.81 MWD+IFR-AK-CAZ-SC(3) 6,952.15 76.20 77.69 3,290.65 3,234.50 1,189.03 4,994.29 5,976,918.59 390,912.46 0.50 5,129.41 MWD+IFR-AK-CAZ-SC(3) 7,044.81 76.32 79.19 3,312.66 3,256.51 1,207.07 5,082.47 5,976,935.28 391,000.90 1.58 5,219.41 MWD+IFR-AK-CAZ-SC(3) 7,141.39 76.77 79.03 3,335.13 3,278.98 1,224.81 5,174.70 5,976,951.61 391,093.39 0.49 5,313.34 MWD+IFR-AK-CAZ-SC(3) 7,235.54 76.13 78.53 3,357.19 3,301.04 1,242.62 5,264.48 5,976,968.05 391,183.42 0.85 5,404.86 MWD+IFR-AK-CAZ-SC(3) 7,332.00 75.74 79.35 3,380.63 3,324.48 1,260.57 5,356.31 5,976,984.60 391,275.50 0.92 5,498.43 MWD+IFR-AK-CAZ-SC(3) 7,426.53 76.58 78.93 3,403.25 3,347.10 1,277.87 5,446.45 5,977,000.52 391,365.89 0.99 5,590.22 MWD+IFR-AK-CAZ-SC(3) 7,521.98 76.96 77.82 3,425.09 3,368.94 1,296.59 5,537.46 5,977,017.86 391,457.17 1.20 5,683.12 MWD+IFR-AK-CAZ-SC(3) 7,616.39 78.02 77.52 3,445.54 3,389.39 1,316.27 5,627.50 5,977,036.16 391,547.49 1.16 5,775.27 MWD+IFR-AK-CAZ-SC(3) 7,711,63 77.22 77.74 3,465.96 3,409.81 1,336.20 5,718.37 5,977,054.70 391,638.64 0.87 5,868.27 MWD+IFR-AK-CAZ-SC(3) 7,804.85 77.01 77.29 3,486.75 3,430.60 1,355.85 5,807.09 5,977,073.00 391,727.64 0.52 5,959.11 MWD+IFR-AK-CAZ-SC(3) 7,900.20 76.83 76.47 3,508.33 3,452.18 1,376.93 5,897.54 5,977,092.70 391,818.40 0.86 6,051.92 MWD+IFR-AK-CAZ-SC(3) 7,996.22 76.01 75.62 3,530.87 3,474.72 1,399.43 5,988.12 5,977,113.82 391,909.30 1.21 6,145.13 MWD+IFR-AK-CAZ-SC(3) 8,091.41 75.63 75.41 3,554.19 3,498.04 1,422.52 6,077.48 5,977,135.54 391,998.99 0.45 6,237.25 MWD+IFR-AK-CAZ-SC(3) 8,186.75 75.88 75.07 3,577.65 3,521.50 1,446.06 6,166.84 5,977,157.72 392,088.69 0.43 6,329.46 MWD+IFR-AK-CAZ-SC(3) 8,277.58 75.75 75.21 3,599.91 3,543.76 1,468.64 6,251.95 5,977,179.00 392,174.13 0.21 6,417.32 MWD+IFR-AK-CAZ-SC(3) 8,375.41 75.81 77.24 3,623.94 3,567.79 1,491.22 6,344.05 5,977,200.17 392,266.56 2.01 6,512.03 MWD+IFR-AK-CAZ-SC(3) 8,471.95 76.01 78.70 3,647.45 3,591.30 1,510.74 6,435.63 5,977,218.29 392,358.41 1.48 6,605.65 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:12:24AM • Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report • Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND' TVDSS +N/-S +E/-W. Northing Easting DLS Section (ft) (°) (°) (ft) '' (ft) (ft) (ft) (ft) (ft) (°/100') (ft)` Survey Tool Name 8,559.89 76.32 78.55 3,668.47 3,612.32 1,527.58 6,519.34 5,977,233.86 392,442.36 0.39 6,691.04 MWD+IFR-AK-CAZ-SC(3) 8,661.35 76.19 78.51 3,692.58 3,636.43 1,547.18 6,615.93 5,977,251.98 392,539.23 0.13 6,789.59 MWD+IFR-AK-CAZ-SC(3) 8,756.03 76.13 78.81 3,715.23 3,659.08 1,565.25 6,706.06 5,977,268.68 392,629.62 0.31 6,881.52 MWD+IFR-AK-CAZ-SC(3) 8,852.33 77.23 79.06 3,737.42 3,681.27 1,583.24 6,798.03 5,977,285.26 392,721.84 1.17 6,975.23 MWD+IFR-AK-CAZ-SC(3) 8,943.79 76.45 79.70 3,758.24 3,702.09 1,599.65 6,885.56 5,977,300.34 392,809.60 1.09 7,064.28 MWD+IFR-AK-CAZ-SC(3) 9,041.44 76.64 78.71 3,780.96 3,724.81 1,617.44 6,978.85 5,977,316.70 392,903.14 1.01 7,159.25 MWD+IFR-AK-CAZ-SC(3) 9,133.06 76.57 78.48 3,802.19 3,746.04 1,635.06 7,066.22 5,977,333.00 392,990.76 0.26 7,248.37 MWD+IFR-AK-CAZ-SC(3) 9,231.80 76.63 78.59 3,825.07 3,768.92 1,654.16 7,160.35 5,977,350.65 393,085.17 0.12 7,344.42 MWD+IFR-AK-CAZ-SC(3) 9,323.73 76.39 78.14 3,846.51 3,790.36 1,672.18 7,247.91 5,977,367.34 393,172.98 0.54 7,433.81 MWD+IFR-AK-CAZ-SC(3) 9,420.41 76.89 79.02 3,868.85 3,812.70 1,690.81 7,340.11 5,977,384.56 393,265.45 1.03 7,527.87 MWD+IFR-AK-CAZ-SC(3) 9,513.25 76.89 79.58 3,889.91 3,833.76 1,707.60 7,428.95 5,977,399.99 393,354.53 0.59 7,618.29 MWD+IFR-AK-CAZ-SC(3) 9,612.05 76.44 79.25 3,912.70 3,856.55 1,725.26 7,523.45 5,977,416.21 393,449.28 0.56 7,714.42 MWD+IFR-AK-CAZ-SC(3) 9,702.93 75.44 78.46 3,934.78 3,878.63 1,742.29 7,609.95 5,977,431.93 393,536.02 1.39 7,802.58 MWD+1FR-AK-CAZ-SC(3) 9,802.78 76.59 78.41 3,958.91 3,902.76 1,761.72 7,704.87 5,977,449.90 393,631.22 1.15 7,899.46 MWD+IFR-AK-CAZ-SC(3) 9,896.37 76.33 77.76 3,980.82 3,924.67 1,780.50 7,793.90 5,977,467.33 393,720.51 0.73 7,990.44 MWD+IFR-AK-CAZ-SC(3) 9,991.27 76.13 78.14 4,003.41 3,947.26 1,799.75 7,884.04 5,977,485.20 393,810.93 0.44 8,082.59 MWD+IFR-AK-CAZ-SC(3) 10,087.34 76.14 78.88 4,026.43 3,970.28 1,818.32 7,975.44 5,977,502.38 393,902.59 0.75 8,175.86 MWD+IFR-AK-CAZ-SC(3) 10,178.49 76.77 79.23 4,047.78 3,991.63 1,835.15 8,062.44 5,977,517,88 393,989.83 0.79 8,264.48 MWD+IFR-AK-CAZ-SC(3) 10,277.05 76.77 79.08 4,070.34 4,014.19 1,853.20 8,156.67 5,977,534.49 394,084.32 0.15 8,360.42 MWD+IFR-AK-CAZ-SC(3) 10,373.74 76.53 80.52 4,092.66 4,036.51 1,869.86 8,249.26 5,977,549.74 394,177.14 1.47 8,454.48 MWD+IFR-AK-CAZ-SC(3) 10,468.40 76.51 80.41 4,114.73 4,058.58 1,885.11 8,340.04 5,977,563.60 394,268.14 0.11 8,546.51 MWD+IFR-AK-CAZ-SC(3) 10,563.75 76.58 80.80 4,136.91 4,080.76 1,900.25 8,431.53 5,977,577.35 394,359.84 0.40 8,639.20 MWD+IFR-AK-CAZ-SC(3) 10,658.73 76.20 80.71 4,159.26 4,103.11 1,915.08 8,522.64 5,977,590.79 394,451.16 0.41 8,731.47 MWD+IFR-AK-CAZ-SC(3) 10,749.57 76.13 80.31 4,180.99 4,124.84 1,929.62 8,609.64 5,977,604.00 394,538.36 0.43 8,819.65 MWD+IFR-AK-CAZ-SC(3) 10,848.65 76.46 80.04 4,204.46 4,148.31 1,946.05 8,704.49 5,977,618.98 394,633.44 0.43 8,915.88 MWD+IFR-AK-CAZ-SC(3) 10,943.84 76.78 79.01 4,226.49 4,170.34 1,962.88 8,795.55 5,977,634.43 394,724.74 1.11 9,008.49 MWD+IFR-AK-CAZ-SC(3) 11,038.57 76.76 78.75 4,248.17 4,192.02 1,980.67 8,886.03 5,977,650.83 394,815.47 0.27 9,100.70 MWD+IFR-AK-CAZ-SC(3) 11,133.10 76.20 78.29 4,270.27 4,214.12 1,998.96 8,976.10 5,977,667.75 394,905.81 0.76 9,192.61 MWD+IFR-AK-CAZ-SC(3) 11,227.58 76.58 78.17 4,292.50 4,236.35 2,017.69 9,066.00 5,977,685.11 394,995.97 0.42 9,284.43 MWD+IFR-AK-CAZ-SC(3) 11,323.51 76.08 78.26 4,315.17 4,259.02 2,036.73 9,157.25 5,977,702.76 395,087.49 0.53 9,377.63 MWD+IFR-AK-CAZ-SC(3) 11,415.81 76.02 78.04 4,337.42 4,281.27 2,055.12 9,244.92 5,977,719.81 395,175.42 0.24 9,467.20 MWD+IFR-AK-CAZ-SC(3) 11,512.50 75.88 78.40 4,360.90 4,304.75 2,074.27 9,336.74 5,977,737.56 395,267.51 0.39 9,560.99 MWD+IFR-AK-CAZ-SC(3) 11,601.81 76.32 78.42 4,382.35 4,326.20 2,091.69 9,421.67 5,977,753.68 395,352.69 0.49 9,647.68 MWD+IFR-AK-CAZ-SC(3) 11,701.69 76.26 78.16 4,406.02 4,349.87 2,111.38 9,516.68 5,977,771.93 395,447.98 0.26 9,744.70 MWD+IFR-AK-CAZ-SC(3) 11,797.82 76.50 78.46 4,428.66 4,372.51 2,130.31 9,608.17 5,977,789.46 395,539.74 0.39 9,838.12 MWD+IFR-AK-CAZ-SC(3) 11,888.40 76.26 78.81 4,449.99 4,393.84 2,147.66 9,694.47 5,977,805.49 395,626.29 0.46 9,926.15 MWD+IFR-AK-CAZ-SC(3) 11,987.84 76.44 78.95 4,473.46 4,417.31 2,166.30 9,789.29 5,977,822.68 395,721.38 0.23 10,022.78 MWD+IFR-AK-CAZ-SC(3) 12,080.37 76.71 78.85 4,494.94 4,438.79 2,183.63 9,877.61 5,977,838.66 395,809.94 0.31 10,112.79 MWD+IFR-AK-CAZ-SC(3) 12,177.23 76.45 78.85 4,517.42 4,461.27 2,201.84 9,970.05 5,977,855.47 395,902.64 0.27 10,207.00 MWD+IFR-AK-CAZ-SC(3) 12,270.65 76.32 78.78 4,539.41 4,483.26 2,219.46 10,059.12 5,977,871.72 395,991.96 0.16 10,297.79 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:12:24AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: '' Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) r) (°) (ft) - (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 12,366.43 76.07 78.85 4,562.27 4,506.12 2,237.50 10,150.36 5,977,888.37 396,083.46 0.27 10,390.81 MWD+IFR-AK-CAZ-SC(3) 12,463.16 76.26 79.03 4,585.40 4,529.25 2,255.52 10,242.54 5,977,904.98 396,175.89 0.27 10,484.73 MWD+IFR-AK-CAZ-SC(3) 12,557.47 77.26 78.59 4,607.00 4,550.85 2,273.33 10,332.60 5,977,921.43 396,266.20 1.15 10,576.53 MWD+IFR-AK-CAZ-SC(3) 12,653.78 77.03 78.86 4,628.42 4,572.27 2,291.69 10,424.68 5,977,938.38 396,358.55 0.36 10,670.43 MWD+IFR-AK-CAZ-SC(3) 12,748.02 76.96 78.81 4,649.63 4,593.48 2,309.47 10,514.77 5,977,954.78 396,448.88 0.09 10,762.25 MWD+IFR-AK-CAZ-SC(3) 12,837.57 76.97 78.95 4,669.83 4,613.68 2,326.30 10,600.37 5,977,970.30 396,534.73 0.15 10,849.49 MWD+IFR-AK-CAZ-SC(3) 12,939.33 76.06 78.80 4,693.56 4,637.41 2,345.39 10,697.47 5,977,987.92 396,632.09 0.91 10,948.45 MWD+IFR-AK-CAZ-SC(3) 13,032.96 76.13 78.65 4,716.06 4,659.91 2,363.16 10,786.60 5,978,004.33 396,721.48 0.17 11,039.33 MWD+IFR-AK-CAZ-SC(3) 13,128.62 76.32 79.16 4,738.84 4,682.69 2,381.04 10,877.77 5,978,020.81 396,812.90 0.55 11,132.24 MWD+IFR-AK-CAZ-SC(3) 13,220.47 75.82 79.35 4,760.95 4,704.80 2,397.66 10,965.36 5,978,036.10 396,900.72 0.58 11,221.39 MWD+IFR-AK-CAZ-SC(3) 13,318.64 76.19 78.92 4,784.69 4,728.54 2,415.62 11,058.90 5,978,052.63 396,994.53 0.57 11,316.64 MWD+IFR-AK-CAZ-SC(3) 13,414.08 76.83 78.80 4,806.95 4,750.80 2,433.55 11,149.96 5,978,069.17 397,085.84 0.68 11,409.45 MWD+IFR-AK-CAZ-SC(3) 13,505.48 76.26 78.56 4,828.22 4,772.07 2,450.99 11,237.12 5,978,085.29 397,173.25 0.67 11,498.34 MWD+IFR-AK-CAZ-SC(3) 13,603.49 76.08 78.93 4,851.65 4,795.50 2,469.57 11,330.46 5,978,102.44 397,266.85 0.41 11,593.50 MWD+IFR-AK-CAZ-SC(3) 13,698.53 76.76 79.01 4,873.96 4,817.81 2,487.24 11,421.14 5,978,118.73 397,357.78 0.72 11,685.89 MWD+IFR-AK-CAZ-SC(3) 13,790.88 77.15 79.31 4,894.81 4,838.66 2,504.16 11,509.50 5,978,134.30 397,446.38 0.53 11,775.85 MWD+IFR-AK-CAZ-SC(3) 13,889.41 76.58 79.74 4,917.20 4,861.05 2,521.61 11,603.85 5,978,150.30 397,540.98 0.72 11,871.80 MWD+IFR-AK-CAZ-SC(3) 13,984.43 76.76 79.58 4,939.11 4,882.96 2,538.20 11,694.81 5,978,165.51 397,632.17 0.25 11,964.25 MWD+IFR-AK-CAZ-SC(3) 14,079.69 76.56 79.59 4,961.09 4,904.94 2,554.96 11,785.97 5,978,180.88 397,723.57 0.21 12,056.94 MWD+IFR-AK-CAZ-SC(3) 14,174.09 76.44 79.25 4,983.12 4,926.97 2,571.81 11,876.20 5,978,196.35 397,814.04 0.37 12,148.73 MWD+IFR-AK-CAZ-SC(3) 14,270.30 76.26 79.20 5,005.83 4,949.68 2,589.29 11,968.05 5,978,212.43 397,906.13 0.19 12,242.22 MWD+IFR-AK-CAZ-SC(3) 14,359.35 76.08 79.48 5,027.12 4,970.97 2,605.29 12,053.02 5,978,227.13 397,991.33 0.37 12,328.69 MWD+IFR-AK-CAZ-SC(3) 14,460.21 76.25 79.23 5,051.23 4,995.08 2,623.38 12,149.27 5,978,243.75 398,087.84 0.29 12,426.62 MWD+IFR-AK-CAZ-SC(3) 14,554.94 76.51 78.52 5,073.54 5,017.39 2,641.14 12,239.61 5,978,260.14 398,178.42 0.78 12,518.68 MWD+IFR-AK-CAZ-SC(3) 14,650.26 76.59 78.60 5,095.71 5,039.56 2,659.53 12,330.47 5,978,277.14 398,269.55 0.12 12,611.39 MWD+IFR-AK-CAZ-SC(3) 14,743.97 76.58 78.69 5,117.45 5,061.30 2,677.48 12,419.84 5,978,293.72 398,359.17 0.09 12,702.54 MWD+IFR-AK-CAZ-SC(3) 14,842.49 76.84 78.92 5,140.10 5,083.95 2,696.09 12,513.90 5,978,310.90 398,453.49 0.35 12,798.42 MWD+IFR-AK-CAZ-SC(3) 14,935.66 76.64 78.55 5,161.47 5,105.32 2,713.81 12,602.83 5,978,327.26 398,542.69 0.44 12,889.10 MWD+IFR-AK-CAZ-SC(3) 15,030.95 76.32 78.79 5,183.75 5,127.60 2,732.01 12,693.68 5,978,344.08 398,633.79 0.42 12,981.75 MWD+IFR-AK-CAZ-SC(3) 15,125.35 76.39 79.07 5,206.02 5,149.87 2,749.62 12,783.71 5,978,360.32 398,724.07 0.30 13,073.49 MWD+IFR-AK-CAZ-SC(3) 15,220.77 76.46 78.63 5,228.42 5,172.27 2,767.56 12,874.71 5,978,376.86 398,815.32 0.45 13,166.24 MWD+IFR-AK-CAZ-SC(3) 15,315.25 76.13 78.27 5,250.80 5,194.65 2,785.94 12,964.64 5,978,393.87 398,905.52 0.51 13,258.03 MWD+IFR-AK-CAZ-SC(3) 15,410.39 76.06 78.44 5,273.66 5,217.51 2,804.58 13,055.09 5,978,411.13 398,996.23 0.19 13,350.37 MWD+IFR-AK-CAZ-SC(3) 15,505.28 76.20 78.26 5,296.41 5,240.26 2,823.18 13,145.32 5,978,428.36 399,086.72 0.24 13,442.49 MWD+IFR-AK-CAZ-SC(3) 15,599.83 76.51 77.99 5,318.72 5,262.57 2,842.09 13,235.23 5,978,445.89 399,176.91 0.43 13,534.36 MWD+IFR-AK-CAZ-SC(3) 15,695.28 76.63 78.84 5,340.88 5,284.73 2,860.73 13,326.18 5,978,463.15 399,268.12 0.88 13,627.19 MWD+IFR-AK-CAZ-SC(3) 15,790.36 76.64 79.14 5,362.86 5,306.71 2,878.40 13,416.98 5,978,479.43 399,359.17 0.31 13,719.70 MWD+IFR-AK-CAZ-SC(3) 15,884.80 76.56 78.70 5,384.75 5,328.60 2,896.05 13,507.14 5,978,495.71 399,449.58 0.46 13,811.57 MWD+IFR-AK-CAZ-SC(3) 15,978.51 76.50 78.61 5,406.58 5,350.43 2,913.98 13,596.49 5,978,512.27 399,539.19 0.11 13,902.70 MWD+IFR-AK-CAZ-SC(3) 16,075.53 76.25 79.34 5,429.43 5,373.28 2,932.01 13,689.04 5,978,528.89 399,631.99 0.78 13,996.99 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:12:24AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site. CD1 Alpine Pad MD Reference: =CD1-15 @ 56.155(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS;, Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0!100') (ft) Survey Tool Name 16,161.42 76.19 79.66 5,449.89 5,393.74 2,947.22 13,771.06 5,978,542.84 399,714.23 0.37 14,080.40 MWD+IFR-AK-CAZ-SC(3) 16,261.96 76.52 80.09 5,473.61 5,417.46 2,964.39 13,867.24 5,978,558.55 399,810.65 0.53 14,178.09 MWD+IFR-AK-CAZ-SC(3) 16,356.52 76.83 80.14 5,495.40 5,439.25 2,980.19 13,957.89 5,978,572.96 399,901.52 0.33 14,270.09 MWD+IFR-AK-CAZ-SC(3) 16,448.35 76.77 80.26 5,516.37 5,460.22 2,995.40 14,045.99 5,978,586.84 399,989.83 0.14 14,359.47 MWD+IFR-AK-CAZ-SC(3) 16,542.07 76.52 80.32 5,538.02 5,481.87 3,010.78 14,135.87 5,978,600.85 400,079.93 0.27 14,450.63 MWD+IFR-AK-CAZ-SC(3) 16,633.01 76.13 79.98 5,559.52 5,503.37 3,025.90 14,222.93 5,978,614.63 400,167.20 0.56 14,538.98 MWD+IFR-AK-CAZ-SC(3) 16,728.35 76.26 80.13 5,582.27 5,526.12 3,041.89 14,314.12 5,978,629.23 400,258.62 0.20 14,631.55 MWD+IFR-AK-CAZ-SC(3) 16,819.91 76.27 79.84 5,604.01 5,547.86 3,057.36 14,401.71 5,978,643.36 400,346.42 0.31 14,720.48 MWD+IFR-AK-CAZ-SC(3) 16,912.92 76.33 79.93 5,626.04 5,569.89 3,073.23 14,490.67 5,978,657.88 400,435.61 0.11 14,810.83 MWD+IFR-AK-CAZ-SC(3) 17,005.67 76.45 79.48 5,647.86 5,591.71 3,089.34 14,579.36 5,978,672.63 400,524.53 0.49 14,900.97 MWD+IFR-AK-CAZ-SC(3) 17,099.14 76.53 78.85 5,669.70 5,613.55 3,106.42 14,668.62 5,978,688.36 400,614.03 0.66 14,991.85 MWD+IFR-AK-CAZ-SC(3) 17,192.18 76.71 78.44 5,691.23 5,635.08 3,124.24 14,757.37 5,978,704.82 400,703.03 0.47 15,082.36 MWD+IFR-AK-CAZ-SC(3) 17,284.95 76.50 78.69 5,712.72 5,656.57 3,142.14 14,845.82 5,978,721.37 400,791.74 0.35 15,172.61 MWD+IFR-AK-CAZ-SC(3) 17,377.87 76.45 78.47 5,734.45 5,678.30 3,160.02 14,934.37 5,978,737.90 400,880.55 0.24 15,262.95 MWD+IFR-AK-CAZ-SC(3) 17,471.33 76.76 78.55 5,756.10 5,699.95 3,178.13 15,023.47 5,978,754.65 400,969.90 0.34 15,353.86 MWD+IFR-AK-CAZ-SC(3) 17,564.45 76.83 78.19 5,777.37 5,721.22 3,196.41 15,112.27 5,978,771.57 401,058.96 0.38 15,444.51 MWD+IFR-AK-CAZ-SC(3) 17,658.94 76.39 78.15 5,799.26 5,743.11 3,215.25 15,202.23 5,978,789.05 401,149.19 0.47 15,536.43 MWD+IFR-AK-CAZ-SC(3) 17,751.04 76.13 78.46 5,821.13 5,764.98 3,233.39 15,289.84 5,978,805.84 401,237.06 0.43 15,625.88 MWD+IFR-AK-CAZ-SC(3) 17,846.66 76.70 78.30 5,843.59 5,787.44 3,252.11 15,380.88 5,978,823.18 401,328.37 0.62 15,718.82 MWD+IFR-AK-CAZ-SC(3) 17,940.24 76.19 78.49 5,865.52 5,809.37 3,270.41 15,469.99 5,978,840.12 401,417.74 0.58 15,809.79 MWD+IFR-AK-CAZ-SC(3) 18,033.39 76.38 78.72 5,887.61 5,831.46 3,288.29 15,558.70 5,978,856.64 401,506.70 0.31 15,900.28 MWD+IFR-AK-CAZ-SC(3) 18,124.43 76.38 79.13 5,909.05 5,852.90 3,305.29 15,645.54 5,978,872.31 401,593.78 0.44 15,988.76 MWD+IFR-AK-CAZ-SC(3) 18,218.01 76.39 79.49 5,931.08 5,874.93 3,322.16 15,734.91 5,978,887,82 401,683.39 0.37 16,079.71 MWD+IFR-AK-CAZ-SC(3) 18,308.34 76.57 79.48 5,952.19 5,896.04 3,338.18 15,821.26 5,978,902.53 401,769.97 0.20 16,167.53 MWD+IFR-AK-CAZ-SC(3) 18,405.13 76.38 79.32 5,974.83 5,918.68 3,355.50 15,913.76 5,978,918.43 401,862.71 0.25 16,261.64 MWD+IFR-AK-CAZ-SC(3) 18,498.26 76.26 79.15 5,996.86 5,940.71 3,372.40 16,002.66 5,978,933.98 401,951.85 0.22 16,352.13 MWD+IFR-AK-CAZ-SC(3) 18,590.94 76.63 78.29 6,018.58 5,962.43 3,390.02 16,091.01 5,978,950.25 402,040.45 0.99 16,442.22 MWD+IFR-AK-CAZ-SC(3) 18,680.94 76.64 78.85 6,039.38 5,983.23 3,407.37 16,176.84 5,978,966.29 402,126.53 0.61 16,529.78 MWD+IFR-AK-CAZ-SC(3) 18,768.72 76.64 79.04 6,059.67 6,003.52 3,423.75 16,260.66 5,978,981.39 402,210.58 0.21 16,615.19 MWD+IFR-AK-CAZ-SC(3) 18,867.02 76.45 79.13 6,082.54 6,026.39 3,441.85 16,354.53 5,978,998.06 402,304.71 0.21 16,710.79 MWD+IFR-AK-CAZ-SC(3) 18,958.74 76.45 79.15 6,104.03 6,047.88 3,458.65 16,442.10 5,979,013.53 402,392.52 0.02 16,799.95 MWD+IFR-AK-CAZ-SC(3) 19,054.20 75.82 79.01 6,126.90 6,070.75 3,476.21 16,533.10 5,979,029.69 402,483.76 0.68 16,892.63 MWD+IFR-AK-CAZ-SC(3) 19,144.93 76.06 79.34 6,148.94 6,092.79 3,492.74 16,619.55 5,979,044.90 402,570.44 0.44 16,980.64 MWD+IFR-AK-CAZ-SC(3) 19,236.83 76.07 79.36 6,171.08 6,114.93 3,509.22 16,707.20 5,979,060.05 402,658.34 0.02 17,069.84 MWD+IFR-AK-CAZ-SC(3) 19,332.14 76.50 79.16 6,193.67 6,137.52 3,526.48 16,798.17 5,979,075.92 402,749.55 0.50 17,162.43 MWD+IFR-AK-CAZ-SC(3) 19,424.99 76.83 78.65 6,215.09 6,158.94 3,543.86 16,886.83 5,979,091.95 402,838.45 0.64 17,252.77 MWD+IFR-AK-CAZ-SC(3) 19,516.00 76.26 79.06 6,236.27 6,180.12 3,560.97 16,973.67 5,979,107.73 402,925.54 0.76 17,341.29 MWD+IFR-AK-CAZ-SC(3) 19,610.71 76.14 79.02 6,258.86 6,202.71 3,578.46 17,063.97 5,979,123.84 403,016.09 0.13 17,433.26 MWD+IFR-AK-CAZ-SC(3) 19,704.39 76.58 78.77 6,280.95 6,224.80 3,595.99 17,153.31 5,979,140.02 403,105.67 0.54 17,524.30 MWD+IFR-AK-CAZ-SC(3) 19,794.55 76.57 78.99 6,301.88 6,245.73 3,612.91 17,239.36 5,979,155.62 403,191.96 0.24 17,612.00 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:12:24AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore:) CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD ', TVDSS +N/-S +E/-W Northing Easting DLS I Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 19,889.66 76.76 79.31 6,323.82 6,267.67 3,630.33 17,330.25 5,979,171.65 403,283.10 0.38 17,704.54 MWD+IFR-AK-CAZ-SC(3) 19,980.31 76.32 79.34 6,344.92 6,288.77 3,646.66 17,416.88 5,979,186.66 403,369.96 0.49 17,792.70 MWD+IFR-AK-CAZ-SC(3) 20,074.90 75.69 79.11 6,367.79 6,311.64 3,663.82 17,507.04 5,979,202.44 403,460.37 0.71 17,884.48 MWD+IFR-AK-CAZ-SC(3) • 20,167.36 75.75 79.22 6,390.60 6,334.45 3,680.66 17,595.05 5,979,217.94 403,548.61 0.13 17,974.08 MWD+IFR-AK-CAZ-SC(3) 20,261.35 76.58 79.09 6,413.07 6,356.92 3,697.83 17,684.68 5,979,233.75 403,638.49 0.89 18,065.34 MWD+IFR-AK-CAZ-SC(3) 20,348.33 76.45 79.56 6,433.36 6,377.21 3,713.50 17,767.80 5,979,248.15 403,721.83 0.55 18,149.93 MWD+IFR-AK-CAZ-SC(3) 20,448.64 76.71 79.57 6,456.64 6,400.49 3,731.17 17,863.76 5,979,264.35 403,818.03 0.26 18,247.49 MWD+1FR-AK-CAZ-SC(3) 20,537.85 76.70 79.25 6,477.15 6,421.00 3,747.13 17,949.10 5,979,279.01 403,903.60 0.35 18,334.31 MWD+IFR-AK-CAZ-SC(3) 20,632.28 76.58 78.66 6,498.97 6,442.82 3,764.73 18,039.27 5,979,295.23 403,994.02 0.62 18,426.18 MWD+IFR-AK-CAZ-SC(3) 20,666.44 76.69 78.95 6,506.87 6,450.72 3,771.18 18,071.87 5,979,301.19 404,026.72 0.89 18,459.42 MWD+IFR-AK-CAZ-SC(3) 20,700.00 76.69 78.95 6,514.60 6,458.45 3,777.44 18,103.93 5,979,306.96 404,058.86 0.00 18,492.08 PROJECTED to TD 6/16/2010 10:12:24AM Page 8 COMPASS 2003.16 Build 69 __ P _ 3 1 .3 _41 5 3 -i p 3 ConocoPhillips(Alaska) Inc. Western North Slope CD1 Alpine Pad CD1-15PB2 Y 501032061971 4 _1 3 s a3 r N Sperry Drilling Seevices rt. Definitive Survey Report --L 3 = 16 June, 2010 Hi 5 TA KR PA 3 zi.3 gi 6 PI =- a VI 's .141 -3 4 i ifF 10 1111 ..... iii= Sperry Drilling Services 13 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project Western North Slope ND Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD1-15 _...._._.._._.....:_:._.:. Well Position +N/-S 0.00 ft Northing: 5,975,805.80 ft Latitude: 70°20'33.932 N +EI-W 0.00 ft Easting: 385,901.08 ft Longitude: 150°55'33.713 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft Wellbore CD1-15PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 5/1/2009 21.62 80.72 57,594 • Design CD1-15PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 20,067.00 Vertical Section: Depth From(ND) +N/-S +El-W Direction (ft) (ft) (ft) (°) 36.65 0.00 0.00 78.18 Survey Program Date From : To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 81.00 1,006.00 CD1-15PB1 Gyro(CD1-15PB1) CB-GYRO-SS Camera based gyro single shot 4/29/2010 1: 1,106.18 3,063.99 CD1-15PB1 MWD(R200)(CD1-15PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/30/2010 1: 3,147.95 20,067.00 CD1-15PB1 MWD(R300)(CD1-15PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/4/2010 12: 20,114.00 20,114.00 CD1-15PB2(CD1-15PB2) BLIND Blind drilling 6/16/2010 1: Survey ... - I Map ;Map Vertical MD Inc. Azi. ND. TVDSS +N/-S +E/-W Northing ;:Easting : DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/1001: (ft) Survey Tool Name 36.65 0.00 0.00 - 36.65 -19.50 0.00 0.00 5,975,805.80 385,901.08 0.00 0.00 UNDEFINED 81.00 0.27 57.03 81.00 24.85 0.06 0.09 5,975,805.86 385,901.17 0.61 0.10 CB-GYRO-SS(1) 171.00 0.38 58.28 171.00 114.85 0.33 0.52 5,975,806.12 385,901.61 0.12 0.58 CB-GYRO-SS(1) 234.00 0.70 33.27 234.00 177.85 0.76 0.91 5,975,806.55 385,902.00 0.62 1.04 CB-GYRO-SS(1) 264.00 0.93 20.08 263.99 207.84 1.14 1.09 5,975,806.93 385,902.19 0.98 1.30 CB-GYRO-SS(1) 354.00 2.75 2.26 353.94 297.79 3.99 1.43 5,975,809.76 385,902.57 2.10 2.21 CB-GYRO-SS(1) 447.00 4.32 3.83 446.76 390.61 9.71 1.75 5,975,815.48 385,902.98 1.69 3.70 CB-GYRO-SS(1) 540.00 4.55 5.74 539.48 483.33 16.88 2.35 5,975,822.64 385,903.69 0.29 5.76 CB-GYRO-SS(1) 631.00 6.34 352.27 630.07 573.92 25.45 2.04 5,975,831.21 385,903.51 2.40 7.21 CB-GYRO-SS(1) 723.00 6.96 351.08 721.45 665.30 35.99 0.49 5,975,841.77 385,902.12 0.69 7.85 CB-GYRO-SS(1) 816.00 6.77 352.80 813.79 757.64 46.99 -1.07 5,975,852.80 385,900.73 0.30 8.58 CB-GYRO-SS(1) 6/16/2010 10:15:46AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore:. CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc • Azi • ND TVDSS +N/-S +EI-dV' Northing Fasting DLS Section (ft) (°) (°) (ft) j (f4)! (f4) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 911.00 7.80 2.76 908.02 851.87 58.99 -1.46 5,975,864.80 385,900.52 1.71 10.65 C8-GYRO-SS(1) 1,006.00 12.03 16.93 1,001.60 945.45 74.91 1.73 5,975,880.67 385,903.96 5.11 17.04 CB-GYRO-SS(1) 1,106.18 15.23 35.28 1,098.99 1,042.84 95.65 12.38 5,975,901.24 385,914.92 5.33 31.71 MWD+IFR-AK-CAZ-SC(2) 1,163.05 16.07 45.33 1,153.76 1,097.61 107.29 22.30 5,975,912.72 385,925.01 4.98 43.80 MWD+IFR-AK-CAZ-SC(2) 1,257.40 19.11 52.64 1,243.70 1,187.55 125.84 43.87 5,975,930.95 385,946.86 3.98 68.71 MWD+IFR-AK-CAZ-SC(2) 1,353.84 22.01 57.15 1,333.99 1,277.84 145.23 71.60 5,975,949.91 385,974.88 3.42 99.83 MWD+IFR-AK-CAZ-SC(2) 1,449.22 25.81 61.60 1,421.18 1,365.03 164.81 104.90 5,975,968.98 386,008.47 4.41 136.43 MWD+IFR-AK-CAZ-SC(2) 1,544.31 28.82 64.36 1,505.66 1,449.51 184.58 143.78 5,975,988.15 386,047.64 3.43 178.53 MWD+IFR-AK-CAZ-SC(2) 1,639.08 30.49 66.69 1,588.02 1,531.87 203.98 186.46 5,976,006.90 386,090.61 2.14 224.28 MWD+IFR-AK-CAZ-SC(2) 1,734.54 34.30 67.36 1,668.61 1,612.46 223.92 233.54 5,976,026.13 386,137.98 4.01 274.45 MWD+IFR-AK-CAZ-SC(2) 1,829.12 38.29 67.37 1,744.82 1,688.67 245.47 285.20 5,976,046.88 386,189.97 4.22 329.43 MWD+IFR-AK-CAZ-SC(2) 1,923.99 40.41 70.58 1,818.18 1,762.03 267.00 341.35 5,976,067.56 386,246.42 3.10 388.79 MWD+IFR-AK-CAZ-SC(2) 2,018.71 44.09 72.14 1,888.29 1,832.14 287.33 401.69 5,976,086.96 386,307.06 4.04 452.02 MWD+IFR-AK-CAZ-SC(2) 2,114.41 46.91 70.87 1,955.36 1,899.21 308.99 466.41 5,976,107.63 386,372.10 3.09 519.80 MWD+IFR-AK-CAZ-SC(2) 2,209.25 49.52 73.06 2,018.55 1,962.40 330.86 533.64 5,976,128.47 386,439.65 3.25 590.09 MWD+IFR-AK-CAZ-SC(2) 2,304.06 53.34 72.61 2,077.65 2,021.50 352.74 604.45 5,976,149.27 386,510.78 4.05 663.88 MWD+IFR-AK-CAZ-SC(2) 2,398.99 57.31 74.21 2,131.65 2,075.50 375.00 679.26 5,976,170.38 386,585.92 4.41 741.66 MWD+IFR-AK-CAZ-SC(2) 2,494.57 59.53 75.52 2,181.71 2,125.56 396.24 757.86 5,976,190.43 386,664.82 2.60 822.95 MWD+IFR-AK-CAZ-SC(2) 2,589.21 63.01 75.36 2,227.19 2,171.04 417.11 838.17 5,976,210.07 386,745.43 3.68 905.83 MWD+IFR-AK-CAZ-SC(2) 2,683.09 67.26 76.12 2,266.66 2,210.51 438.07 920.70 5,976,229.77 386,828.27 4.59 990.91 MWD+IFR-AK-CAZ-SC(2) 2,779.27 69.93 77.73 2,301.76 2,245.61 458.32 1,007.92 5,976,248.68 386,915.78 3.18 1,080.42 MWD+IFR-AK-CAZ-SC(2) 2,874.84 72.96 79.05 2,332.17 2,276.02 476.54 1,096.66 5,976,265.55 387,004.77 3.43 1,171.01 MWD+IFR-AK-CAZ-SC(2) 2,969.35 75.55 78.81 2,357.81 2,301.66 494.00 1,185.92 5,976,281.66 387,094.28 2.75 1,261.96 MWD+IFR-AK-CAZ-SC(2) 3,063.99 75.46 79.06 2,381,50 2,325.35 511.59 1,275.84 5,976,297.87 387,184.46 0.27 1,353.58 MWD+IFR-AK-CAZ-SC(2) 3,147.95 76.01 78.47 2,402.19 2,346.04 527.44 . 1,355.66 5,976,312.51 387,264.49 0.94 1,434.94 MWD+IFR-AK-CAZ-SC(3) 3,239.59 76.45 79.46 2,424.00 2,367.85 544.48 1,443.02 5,976,328.21 387,352.09 1.15 1,523.94 MWD+IFR-AK-CAZ-SC(3) 3,337.88 76.96 80.07 2,446.60 2,390.45 561.47 1,537.15 5,976,343.77 387,446.47 0.80 1,619.56 MWD+IFR-AK-CAZ-SC(3) 3,427.41 76.70 79.55 2,467.00 2,410.85 576.90 1,622.95 5,976,357.88 387,532.48 0.64 1,706.70 MWD+IFR-AK-CAZ-SC(3) 3,527.47 77.15 79.08 2,489.64 2,433.49 594.97 1,718.72 5,976,374.49 387,628.52 0.64 1,804.14 MWD+IFR-AK-CAZ-SC(3) 3,622.17 77.46 78.25 2,510.45 2,454.30 613.13 1,809.31 5,976,391,27 387,719.36 0.92 1,896.52 MWD+IFR-AK-CAZ-SC(3) 3,722.88 76.26 78.27 2,533.34 2,477.19 633.08 1,905.32 5,976,409.76 387,815.66 1.19 1,994.60 MWD+IFR-AK-CAZ-SC(3) 3,806.66 76.64 79.09 2,552.97 2,496.82 649.07 1,985.19 5,976,424.52 387,895.75 1.05 2,076.04 MWD+IFR-AK-CAZ-SC(3) 3,906.38 76.71 79.72 2,575.96 2,519.81 666.91 2,080.57 5,976,440.91 387,991.38 0.62 2,173.05 MWD+IFR-AK-CAZ-SC(3) 4,002.46 76.39 80.24 2,598.31 2,542.16 683.17 2,172.59 5,976,455.77 388,083.63 0.62 2,266.45 MWD+IFR-AK-CAZ-SC(3) 4,098.56 76.45 80.18 2,620.87 2,564.72 699.05 2,264.64 5,976,470.25 388,175.91 0.09 2,359.81 MWD+IFR-AK-CAZ-SC(3) 4,190.21 76.64 80.47 2,642.19 2,586.04 714.03 2,352.51 5,976,483.89 388,263.98 0.37 2,448.88 MWD+IFR-AK-CAZ-SC(3) 4,288.54 76.77 80.82 2,664.81 2,608.66 729.59 2,446.93 5,976,498.00 388,358.62 0.37 2,544.48 MWD+IFR-AK-CAZ-SC(3) 4,383.53 76.45 81.25 2,686.81 2,630.66 743.99 2,538.21 5,976,511.01 388,450.10 0.55 2,636.78 MWD+IFR-AK-CAZ-SC(3) 4,479.65 76.13 81.77 2,709.59 2,653.44 757.77 2,630.56 5,976,523.39 388,542.65 0.62 2,730.00 MWD+IFR-AK-CAZ-SC(3) 4,573.88 76.00 81.68 2,732.28 2,676.13 770.94 2,721.07 5,976,535.17 388,633.34 0.17 2,821.28 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:15:46AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: = CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore; CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: ' CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS. Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,668.31 76.26 81.33 2754.92 2,698.77 784.48 2,811.74 5,976,547,33 388,724.20 0.45 2,912.80 MWD+IFR-AK-CAZ-SC(3) 4,762.92 76.71 80.90 2,777.03 2,720.88 798.69 2,902.63 5,976,560.15 388,815.28 0.65 3,004.67 MWD+IFR-AK-CAZ-SC(3) 4,859.62 76.58 80.76 2,799.36 2,743.21 813.68 2,995.51 5,976,573.73 388,908.37 0.19 3,098.66 MWD+IFR-AK-CAZ-SC(3) 4,954.00 76.96 79.85 2,820.96 2,764.81 829.15 3,086.07 5,976,587.82 388,999.15 1.02 3,190.47 MWD+IFR-AK-CAZ-SC(3) 5,049.78 76.71 79.91 2,842.78 2,786.63 845.54 3,177.88 5,976,602.81 389,091.19 0.27 3,283.69 MWD+IFR-AK-CAZ-SC(3) 5,144.79 75.82 78.67 2,865.34 2,809.19 862.69 3,268.56 5,976,618.57 389,182.12 1.58 3,375.96 MWD+IFR-AK-CAZ-SC(3) 5,240.27 76.08 78.62 2,888.52 2,832.37 880.93 3,359.37 5,976,635.42 389,273.19 0.28 3,468.58 MWD+IFR-AK-CAZ-SC(3) 5,334.97 75.68 79.46 2,911.62 2,855.47 898.39 3,449.54 5,976,651.51 389,363.60 0.96 3,560.41 MWD+IFR-AK-CAZ-SC(3) 5,430.78 75.94 79.66 2,935.10 2,878.95 915.22 3,540.89 5,976,666.95 389,455.19 0.34 3,653.27 MWD+IFR-AK-CAZ-SC(3) 5,528.32 76.33 80.66 2,958.48 2,902.33 931.40 3,634.19 5,976,681.71 389,548.72 1.07 3,747.91 MWD+IFR-AK-CAZ-SC(3) 5,621.09 76.77 81.15 2,980.06 2,923.91 945.66 3,723.28 5,976,694.61 389,638.01 0.70 3,838.03 MWD+IFR-AK-CAZ-SC(3) 5,711.12 76.38 80.51 3,000.96 2,944.81 959.62 3,809.73 5,976,707.25 389,724.65 0.82 3,925.51 MWD+IFR-AK-CAZ-SC(3) 5,811.41 76.33 80.49 3,024.62 2,968.47 975.70 3,905.85 5,976,721.86 389,821.00 0.05 4,022.89 MWD+IFR-AK-CAZ-SC(3) 5,902.97 76.25 80.46 3,046.32 2,990.17 990.42 3,993.58 5,976,735.25 389,908.93 0.09 4,111.77 MWD+IFR-AK-CAZ-SC(3) 6,001.81 76.63 80.25 3,069.49 3,013.34 1,006.52 4,088.30 5,976,749.90 390,003.88 0.44 4,207.78 MWD+IFR-AK-CAZ-SC(3) 6,094.77 76.51 79.76 3,091.08 3,034.93 1,022.21 4,177.35 5,976,764.23 390,093.15 0.53 4,298.16 MWD+IFR-AK-CAZ-SC(3) 6,191.66 76.33 79.07 3,113.83 3,057.68 1,039.51 4,269.93 5,976,780.12 390,185.97 0.72 4,392.32 MWD+IFR-AK-CAZ-SC(3) 6,282.72 76.45 78.67 3,135.26 3,079.11 1,056.60 4,356.77 5,976,795.88 390,273.05 0.45 4,480.81 MWD+IFR-AK-CAZ-SC(3) 6,380.98 76.89 78.46 3,157.92 3,101.77 1,075.55 4,450.48 5,976,813.41 390,367.04 0.49 4,576.42 MWD+IFR-AK-CAZ-SC(3) 6,477.93 76.65 78.48 3,180.11 3,123.96 1,094.42 4,542.95 5,976,830.86 390,459.78 0.25 4,670.80 MWD+IFR-AK-CAZ-SC(3) 6,571.23 77.02 78.14 3,201.35 3,145.20 1,112.83 4,631.92 5,976,847.91 390,549.00 0.53 4,761.64 MWD+IFR-AK-CAZ-SC(3) 6,667.35 76.70 78.28 3,223.21 3,167.06 1,131.95 4,723.54 5,976,865.64 390,640.91 0.36 4,855.25 MWD+IFR-AK-CAZ-SC(3) 6,761.79 75.82 78.39 3,245.64 3,189.49 1,150.50 4,813.39 5,976,882.81 390,731.01 0.94 4,946.98 MWD+IFR-AK-CAZ-SC(3) 6,854.81 76.63 77.92 3,267.79 3,211.64 1,169.05 4,901.81 5,976,900.01 390,819.70 1.00 5,037.33 MWD+IFR-AK-CAZ-SC(3) 6,952.15 76.20 77.69 3,290.65 3,234.50 1,189.03 4,994.29 5,976,918.59 390,912.46 0.50 5,131.94 MWD+IFR-AK-CAZ-SC(3) 7,044.81 76.32 79.19 3,312.66 3,256.51 1,207.07 5,082.47 5,976,935.28 391,000.90 1.58 5,221.95 MWD+IFR-AK-CAZ-SC(3) 7,141.39 76.77 79.03 3,335.13 3,278.98 1,224.81 5,174.70 5,976,951.61 391,093.39 0.49 5,315.86 MWD+IFR-AK-CAZ-SC(3) 7,235.54 76.13 78.53 3,357.19 3,301.04 1,242.62 5,264.48 5,976,968.05 391,183.42 0.85 5,407.39 MWD+IFR-AK-CAZ-SC(3) 7,332.00 75.74 79.35 3,380.63 3,324.48 1,260.57 5,356.31 5,976,984.60 391,275.50 0.92 5,500.95 MWD+IFR-AK-CAZ-SC(3) 7,426.53 76.58 78.93 3,403.25 3,347.10 1,277.87 5,446.45 5,977,000.52 391,365.89 0.99 5,592.72 MWD+IFR-AK-CAZ-SC(3) 7,521.98 76.96 77.82 3,425.09 3,368.94 1,296.59 5,537.46 5,977,017.86 391,457.17 1.20 5,685.63 MWD+IFR-AK-CAZ-SC(3) 7,616.39 78.02 77.52 3,445.54 3,389.39 1,316.27 5,627.50 5,977,036.16 391,547.49 1.16 5,777.80 MWD+IFR-AK-CAZ-SC(3) 7,711.63 77.22 77.74 3,465.96 3,409.81 1,336.20 5,718.37 5,977,054.70 391,638.64 0.87 5,870.82 MWD+IFR-AK-CAZ-SC(3) 7,804.85 77.01 77.29 3,486.75 3,430.60 1,355.85 5,807.09 5,977,073.00 391,727.64 0.52 5,961.68 MWD+IFR-AK-CAZ-SC(3) 7,900.20 76.83 76.47 3,508.33 3,452.18 1,376.93 5,897.54 5,977,092.70 391,818.40 0.86 6,054.53 MWD+IFR-AK-CAZ-SC(3) 7,996.22 76.01 75.62 3,530.87 3,474.72 1,399.43 5,988.12 5,977,113.82 391,909.30 1.21 6,147.80 MWD+IFR-AK-CAZ-SC(3) 8,091.41 75.63 75.41 3,554.19 3,498.04 1,422.52 6,077.48 5,977,135.54 391,998.99 0.45 6,239.99 MWD+IFR-AK-CAZ-SC(3) 8,186.75 75.88 75.07 3,577.65 3,521.50 1,446.06 6,166.84 5,977,157.72 392,088.69 0.43 6,332.28 MWD+IFR-AK-CAZ-SC(3) 8,277.58 75.75 75.21 3,599.91 3,543.76 1,468.64 6,251.95 5,977,179.00 392,174.13 0.21 6,420.21 MWD+IFR-AK-CAZ-SC(3) 8,375.41 75.81 77.24 3,623.94 3,567.79 1,491.22 6,344.05 5,977,200.17 392,266.56 2.01 6,514.99 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:15:46AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad • MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azr . TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100`) (ft) Survey Tool Name 8,471.95 76.01 78.70 3,647.45 3,591.30 1,510.74 6,435.63 5,977,218.29 392,358.41 1.48 6,608.62 MWD+IFR-AK-CAZ-SC(3) 8,559.89 76.32 78.55 3,668.47 3,612.32 1,527.58 6,519.34 5,977,233.86 392,442.36 0.39 6,694.00 MWD+IFR-AK-CAZ-SC(3) 8,661.35 76.19 78.51 3,692.58 3,636.43 1,547.18 6,615.93 5,977,251.98 392,539.23 0.13 6,792.56 MWD+IFR-AK-CAZ-SC(3) 8,756.03 76.13 78.81 3,715.23 3,659.08 1,565.25 6,706.06 5,977,268.68 392,629.62 0.31 6,884.48 MWD+IFR-AK-CAZ-SC(3) 8,852.33 77.23 79.06 3,737.42 3,681.27 1,583.24 6,798.03 5,977,285.26 392,721.84 1.17 6,978.18 MWD+IFR-AK-CAZ-SC(3) 8,943.79 76.45 79.70 3,758.24 3,702.09 1,599.65 6,885.56 5,977,300.34 392,809.60 1.09 7,067.22 MWD+IFR-AK-CAZ-SC(3) 9,041.44 76.64 78.71 3,780.96 3,724.81 1,617.44 6,978.85 5,977,316.70 392,903.14 1.01 7,162.18 MWD+IFR-AK-CAZ-SC(3) 9,133.06 76.57 78.48 3,802.19 3,746.04 1,635.06 7,066.22 5,977,333.00 392,990.76 0.26 7,251.30 MWD+IFR-AK-CAZ-SC(3) 9,231.80 76.63 78.59 3,825.07 3,768.92 1,654.16 7,160.35 5,977,350.65 393,085.17 0.12 7,347.35 MWD+IFR-AK-CAZ-SC(3) 9,323.73 76.39 78.14 3,846.51 3,790.36 1,672.18 7,247.91 5,977,367.34 393,172.98 0.54 7,436.74 MWD+IFR-AK-CAZ-SC(3) 9,420.41 76.89 79.02 3,868.85 3,812.70 1,690.81 7,340.11 5,977,384.56 393,265.45 1.03 7,530.80 MWD+IFR-AK-CAZ-SC(3) 9,513.25 76.89 79.58 3,889.91 3,833.76 1,707.60 7,428.95 5,977,399.99 393,354.53 0.59 7,621.21 MWD+IFR-AK-CAZ-SC(3) 9,612.05 76.44 79.25 3,912.70 3,856.55 1,725.26 7,523.45 5,977,416.21 393,449.28 0.56 7,717.32 MWD+IFR-AK-CAZ-SC(3) 9,702.93 75.44 78.46 3,934.78 3,878.63 1,742.29 7,609.95 5,977,431.93 393,536.02 1.39 7,805.47 MWD+IFR-AK-CAZ-SC(3) 9,802.78 76.59 78.41 3,958.91 3,902.76 1,761.72 7,704.87 5,977,449.90 393,631.22 1.15 7,902.36 MWD+IFR-AK-CAZ-SC(3) 9,896.37 76.33 77.76 3,980.82 3,924.67 1,780.50 7,793.90 5,977,467.33 393,720.51 0.73 7,993.34 MWD+IFR-AK-CAZ-SC(3) 9,991.27 76.13 78.14 4,003.41 3,947.26 1,799.75 7,884.04 5,977,485.20 393,810.93 0.44 8,085.52 MWD+IFR-AK-CAZ-SC(3) 10,087.34 76.14 78.88 4,026.43 3,970.28 1,818.32 7,975.44 5,977,502.38 393,902.59 0.75 8,178.78 MWD+IFR-AK-CAZ-SC(3) 10,178.49 76.77 79.23 4,047.78 3,991.63 1,835.15 8,062.44 5,977,517.88 393,989.83 0.79 8,267.39 MWD+IFR-AK-CAZ-SC(3) 10,277.05 76.77 79.08 4,070.34 4,014.19 1,853.20 8,156.67 5,977,534.49 394,084.32 0.15 8,363.32 MWD+IFR-AK-CAZ-SC(3) 10,373.74 76.53 80.52 4,092.66 4,036.51 1,869.86 8,249.26 5,977,549.74 394,177.14 1.47 8,457.36 MWD+IFR-AK-CAZ-SC(3) 10,468.40 76.51 80.41 4,114.73 4,058.58 1,885.11 8,340.04 5,977,563.60 394,268.14 0.11 8,549.33 MWD+IFR-AK-CAZ-SC(3) 10,563.75 76.58 80.80 4,136.91 4,080.76 1,900.25 8,431.53 5,977,577.35 394,359.84 0.40 8,641.98 MWD+1FR-AK-CAZ-SC(3) 10,658.73 76.20 80.71 4,159.26 4,103.11 1,915.08 8,522.64 5,977,590.79 394,451.16 0.41 8,734.20 MWD+IFR-AK-CAZ-SC(3) 10,749.57 76.13 80.31 4,180.99 4,124.84 1,929.62 8,609.64 5,977,604.00 394,538.36 0.43 8,822.34 MWD+IFR-AK-CAZ-SC(3) 10,848.65 76.46 80.04 4,204.46 4,148.31 1,946.05 8,704.49 5,977,618.98 394,633.44 0.43 8,918.54 MWD+IFR-AK-CAZ-SC(3) 10,943.84 76.78 79.01 4,226.49 4,170.34 1,962.88 8,795.55 5,977,634.43 394,724.74 1.11 9,011.12 MW0+IFR-AK-CAZ-SC(3) 11,038.57 76.76 78.75 4,248.17 4,192.02 1,980.67 8,886.03 5,977,650.83 394,815.47 0.27 9,103.32 MWD+IFR-AK-CAZ-SC(3) 11,133.10 76.20 78.29 4,270.27 4,214.12 1,998.96 8,976.10 5,977,667.75 394,905.81 0.76 9,195.23 MWD+IFR-AK-CAZ-SC(3) 11,227.58 76.58 78.17 4,292.50 4,236.35 2,017.69 9,066.00 5,977,685.11 394,995.97 0.42 9,287.06 MWD+IFR-AK-CAZ-SC(3) 11,323.51 76.08 78.26 4,315.17 4,259.02 2,036.73 9,157.25 5,977,702.76 395,087.49 0.53 9,380.27 MWD+IFR-AK-CAZ-SC(3) 11,415.81 76.02 78.04 4,337.42 4,281.27 2,055.12 9,244.92 5,977,719.81 395,175.42 0.24 9,469.85 MWD+IFR-AK-CAZ-SC(3) 11,512.50 75.88 78.40 4,360.90 4,304.75 2,074.27 9,336.74 5,977,737.56 395,267.51 0.39 9,563.65 MWD+IFR-AK-CAZ-SC(3) 11,601.81 76.32 78.42 4,382.35 4,326.20 2,091.69 9,421.67 5,977,753.68 395,352.69 0.49 9,650.34 MWD+IFR-AK-CAZ-SC(3) 11,701.69 76.26 78.16 4,406.02 4,349.87 2,111.38 9,516.68 5,977,771.93 395,447.98 0.26 9,747.37 MWD+IFR-AK-CAZ-SC(3) 11,797.82 76.50 78.46 4,428.66 4,372.51 2,130.31 9,608.17 5,977,789.46 395,539.74 0.39 9,840.80 MWD+IFR-AK-CAZ-SC(3) 11,888.40 76.26 78.81 4,449.99 4,393.84 2,147.66 9,694.47 5,977,805.49 395,626.29 0.46 9,928.83 MWD+IFR-AK-CAZ-SC(3) 11,987.84 76.44 78.95 4,473.46 4,417.31 2,166.30 9,789.29 5,977,822.68 395,721.38 0.23 10,025.45 MWD+IFR-AK-CAZ-SC(3) 12,080.37 76.71 78.85 4,494.94 4,438.79 2,183.63 9,877.61 5,977,838.66 395,809.94 0.31 10,115.45 MWD+IFR-AK-CAZ-SC(3) 12,177.23 76.45 78.85 4,517.42 4,461.27 2,201.84 9,970.05. 5,977,855.47 395,902.64 0.27 10,209.66 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:15:46AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore:.I CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production • Survey Map Map Vertical MD Inc Azi • TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) c (ft) (ft) (ft) (ft) (ft) (°/100`) (ft) Survey Tool Name 12,270.65 76.32 78.78 4,539.41 4,483.26 2,219.46 10,059.12 5,977,871.72 395,991.96 0.16 10,300.45 MWD+IFR-AK-CAZ-SC(3) 12,366.43 76.07 78.85 4,562.27 4,506.12 2,237.50 10,150.36 5,977,888.37 396,083.46 0.27 10,393.45 MWD+IFR-AK-CAZ-SC(3) 12,463.16 76.26 79.03 4,585.40 4,529.25 2,255.52 10,242.54 5,977,904.98 396,175.89 0.27 10,487.37 MWD+IFR-AK-CAZ-SC(3) 12,557.47 77.26 78.59 4,607.00 4,550.85 2,273.33 10,332.60 5,977,921.43 396,266.20 1.15 10,579.17 MWD+1FR-AK-CAZ-SC(3) 12,653.78 77.03 78.86 4,628.42 4,572.27 2,291.69 10,424.68 5,977,938.38 396,358.55 0.36 10,673.06 MWD+IFR-AK-CAZ-SC(3) 12,748.02 76.96 78.81 4,649.63 4,593.48 2,309.47 10,514.77 5,977,954.78 396,448.88 0.09 10,764.87 MWD+IFR-AK-CAZ-SC(3) 12,837.57 76.97 78.95 4,669.83 4,613.68 2,326.30 10,600.37 5,977,970.30 396,534.73 0.15 10,852.11 MWD+IFR-AK-CAZ-SC(3) 12,939.33 76.06 78.80 4,693.56 4,637.41 2,345.39 10,697.47 5,977,987.92 396,632.09 0.91 10,951.06 MWD+1FR-AK-CAZ-SC(3) 13,032.96 76.13 78.65 4,716.06 4,659.91 2,363.16 10,786.60 5,978,004.33 396,721.48 0.17 11,041.94 MWD+IFR-AK-CAZ-SC(3) 13,128.62 76.32 79.16 4,738.84 4,682.69 2,381.04 10,877.77 5,978,020.81 396,812.90 0.55 11,134.84 MWD+IFR-AK-CAZ-SC(3) 13,220.47 75.82 79.35 4,760.95 4,704.80 2,397.66 10,965.36 5,978,036.10 396,900.72 0.58 11,223.97 MWD+IFR-AK-CAZ-SC(3) 13,318.64 76.19 78.92 4,784.69 4,728.54 2,415.62 11,058.90 5,978,052.63 396,994.53 0.57 11,319.22 MWD+IFR-AK-CAZ-SC(3) 13,414.08 76.83 78.80 4,806.95 4,750.80 2,433.55 11,149.96 5,978,069.17 397,085.84 0.68 11,412.02 MWD+1FR-AK-CAZ-SC(3) 13,505.48 76.26 78.56 4,828.22 4,772.07 2,450.99 11,237.12 5,978,085.29 397,173.25 0.67 11,500.90 MWD+IFR-AK-CAZ-SC(3) 13,603.49 76.08 78.93 4,851.65 4,795.50 2,469.57 11,330.46 5,978,102.44 397,266.85 0.41 11,596.07 MWD+IFR-AK-CAZ-SC(3) 13,698.53 76.76 79.01 4,873.96 4,817.81 2,487.24 11,421.14 5,978,118.73 397,357.78 0.72 11,688.44 MWD+1FR-AK-CAZ-SC(3) 13,790.88 77.15 79.31 4,894.81 4,838.66 2,504.16 11,509.50 5,978,134.30 397,446.38 0.53 11,778.39 MWD+IFR-AK-CAZ-SC(3) 13,889.41 76.58 79.74 4,917.20 4,861.05 2,521.61 11,603.85 5,978,150.30 397,540.98 0.72 11,874.32 MWD+1FR-AK-CAZ-SC(3) 13,984.43 76.76 79.58 4,939.11 4,882.96 2,538.20 11,694.81 5,978,165.51 397,632.17 0.25 11,966.75 MWD+IFR-AK-CAZ-SC(3) 14,079.69 76.56 79.59 4,961.09 4,904.94 2,554.96 11,785.97 5,978,180.88 397,723.57 0.21 12,059.41 MWD+1FR-AK-CAZ-SC(3) 14,174.09 76.44 79.25 4,983.12 4,926.97 2,571.81 11,876.20 5,978,196.35 397,814.04 0.37 12,151.18 MWD+IFR-AK-CAZ-SC(3) 14,270.30 76.26 79.20 5,005.83 4,949.68 2,589.29 11,968.05 5,978,212.43 397,906.13 0.19 12,244.66 MWD+IFR-AK-CAZ-SC(3) 14,359.35 76.08 79.48 5,027.12 4,970.97 2,605.29 12,053.02 5,978,227.13 397,991.33 0.37 12,331.11 MWD+IFR-AK-CAZ-SC(3) 14,460.21 76.25 79.23 5,051.23 4,995.08 2,623.38 12,149.27 5,978,243.75 398,087.84 0.29 12,429.02 MWD+1FR-AK-CAZ-SC(3) 14,554.94 76.51 78.52 5,073.54 5,017.39 2,641.14 12,239.61 5,978,260.14 398,178.42 0.78 12,521.08 MWD+IFR-AK-CAZ-SC(3) 14,650.26 76.59 78.60 5,095.71 5,039.56 2,659.53 12,330.47 5,978,277.14 398,269.55 0.12 12,613.78 MWD+1FR-AK-CAZ-SC(3) 14,743.97 76.58 78.69 5,117.45 5,061.30 2,677.48 12,419.84 5,978,293.72 398,359.17 0.09 12,704.93 MWD+IFR-AK-CAZ-SC(3) 14,842.49 76.84 78.92 5,140.10 5,083.95 2,696.09 12,513.90 5,978,310.90 398,453.49 0.35 12,800.81 MWD+IFR-AK-CAZ-SC(3) 14,935.66 76.64 78.55 5,161.47 5,105.32 2,713.81 12,602.83 5,978,327.26 398,542.69 0.44 12,891.49 MWD+1FR-AK-CAZ-SC(3) 15,030.95 76.32 78.79 5,183.75 5,127.60 2,732.01 12,693.68 5,978,344.08 398,633.79 0.42 12,984.14 MWD+1FR-AK-CAZ-SC(3) 15,125.35 76.39 79.07 5,206.02 5,149.87 2,749.62 12,783.71 5,978,360.32 398,724.07 0.30 13,075.86 MWD+1FR-AK-CAZ-SC(3) 15,220.77 76.46 78.63 5,228.42 5,172.27 2,767.56 12,874.71 5,978,376.86 398,815.32 0.45 13,168.61 MWD+1FR-AK-CAZ-SC(3) 15,315.25 76.13 78.27 5,250.80 5,194.65 2,785.94 12,964.64 5,978,393.87 398,905.52 0.51 13,260.40 MWD+IFR-AK-CAZ-SC(3) 15,410.39 76.06 .78.44 . 5,273.66 5,217.51 2,804.58 13,055.09 5,978,411.13 398,996.23 0.19 13,352.75 MWD+IFR-AK-CAZ-SC(3) 15,505.28 76.20 78.26 5,296.41 5,240.26 2,823.18 13,145.32 5,978,428.36 399,086.72 0.24 13,444.87 MWD+IFR-AK-CAZ-SC(3) 15,599.83 76.51 77.99 5,318.72 5,262.57 2,842.09 13,235.23 5,978,445.89 399,176.91 0.43 13,536.76 MWD+IFR-AK-CAZ-SC(3) 15,695.28 76.63 78.84 5,340.88 5,284.73 2,860.73 13,326.18 5,978,463.15 399,268.12 0.88 13,629.59 MWD+IFR-AK-CAZ-SC(3) 15,790.36 76.64 79.14 5,362.86 5,306.71 2,878.40 13,416.98 5,978,479.43 399,359.17 0.31 13,722.09 MWD+1FR-AK-CAZ-SC(3) 15,884.80 76.56 78.70 5,384.75 5,328.60 2,896.05 13,507.14 5,978,495.71 399,449.58 0.46 13,813.95 MWD+IFR-AK-CAZ-SC(3) 15,978.51 76.50 78.61 5,406.58 5,350.43 2,913.98 13,596.49 5,978,512.27 399,539.19 0.11 13,905.08 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:15:46AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: !Well CD1-15 Project Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellborn: CD1-15P132 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +EI-W Northing Easting DLS Section (ft) (°) (") (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 16,075.53 76.25 79.34 5,429.43 5,373.28 2,932.01 13,689.04 5,978,528.89 399,631.99 0.78 13,999.36 MW0+IFR-AK-CAZ-SC(3) 16,161.42 76.19 79.66 5,449.89 5,393.74 2,947.22 13,771.06 5,978,542.84 399,714.23 0.37 14,082.76 MWD+IFR-AK-CAZ-SC(3) 16,261.96 76.52 80.09 5,473.61 5,417.46 2,964.39 13,867.24 5,978,558.55 399,810.65 0.53 14,180.41 MWD+IFR-AK-CAZ-SC(3) 16,356.52 76.83 80.14 5,495.40 5,439.25 2,980.19 13,957.89 5,978,572.96 399,901.52 0.33 14,272.38 MWD+IFR-AK-CAZ-SC(3) 16,448.35 76.77 80.26 5,516.37 5,460.22 2,995.40 14,045.99 5,978,586.84 .399,989.83 0.14 14,361.72 MWD+IFR-AK-CAZ-SC(3) 16,542.07 76.52 80.32 5,538.02 5,481.87 3,010.78 14,135.87 5,978,600.85 400,079.93 0.27 14,452.85 MWD+IFR-AK-CAZ-SC(3) 16,633.01 76.13 79.98 5,559.52 5,503.37 3,025.90 14,222.93 5,978,614.63 400,167.20 0.56 14,541.16 MWD+IFR-AK-CAZ-SC(3) 16,728.35 76.26 80.13 5,582.27 5,526.12 3,041.89 14,314.12 5,978,629.23 400,258.62 0.20 14,633.69 MWD+IFR-AK-CAZ-SC(3) 16,819.91 76.27 79.84 5,604,01 5,547.86 3,057.36 14,401.71 5,978,643.36 400,346.42 0.31 14,722.59 MWD+IFR-AK-CAZ-SC(3) 16,912.92 76.33 79.93 5,626.04 5,569.89 3,073.23 14,490.67 5,978,657.88 400,435.61 0.11 14,812.92 MWD+IFR-AK-CAZ-SC(3) 17,005.67 76.45 79.48 5,647.86 5,591.71 3,089.34 14,579.36 5,978,672.63 400,524.53 0.49 14,903.03 MWD+IFR-AK-CAZ-SC(3) 17,099.14 76.53 78.85 5,669.70 5,613.55 3,106.42 14,668.62 5,978,688.36 400,614.03 0.66 14,993.90 MWD+IFR-AK-CAZ-SC(3) 17,192.18 76.71 78.44 5,691.23 5,635.08 3,124.24 14,757.37 5,978,704.82 400,703.03 0.47 15,084.41 MWD+IFR-AK-CAZ-SC(3) 17,284.95 76.50 78.69 5,712.72 5,656.57 3,142.14 14,845.82 5,978,721.37 400,791.74 0.35 15,174.65 MWD+IFR-AK-CAZ-SC(3) 17,377.87 76.45 78.47 5,734.45 5,678.30 3,160.02 14,934.37 5,978,737.90 400,880.55 0.24 15,265.00 MWD+IFR-AK-CAZ-SC(3) 17,471.33 76.76 78.55 5,756.10 5,699.95 3,178.13 15,023.47 5,978,754.65 400,969.90 0.34 15,355.91 MWD+IFR-AK-CAZ-SC(3) 17,564.45 76.83 78.19 5,777.37 5,721.22 3,196.41 15,112.27 5,978,771.57 401,058.96 0.38 15,446.57 MWD+IFR-AK-CAZ-SC(3) 17,658.94 76.39 78.15 5,799.26 5,743.11 3,215.25 15,202.23 5,978,789.05 401,149.19 0.47 15,538.49 MWD+IFR-AK-CAZ-SC(3) 17,751.04 76.13 78.46 5,821.13 5,764.98 3,233.39 15,289.84 5,978,805.84 401,237.06 0.43 15,627.95 MWD+IFR-AK-CAZ-SC(3) 17,846.66 76.70 78.30 5,843.59 5,787.44 3,252.11 15,380.88 5,978,823.18 401,328.37 0.62 15,720.90 MWD+IFR-AK-CAZ-SC(3) 17,940.24 76.19 78.49 5,865.52 5,809.37 3,270.41 15,469.99 5,978,840.12 401,417.74 0.58 15,811.87 MWD+IFR-AK-CAZ-SC(3) 18,033.39 76.38 78.72 5,887.61 5,831.46 3,288.29 15,558.70 5,978,856.64 401,506.70 0.31 15,902.36 MWD+IFR-AK-CAZ-SC(3) 18,124.43 76.38 79.13 5,909.05 5,852.90 3,305.29 15,645.54 5,978,872.31 401,593.78 0.44 15,990.83 MWD+IFR-AK-CAZ-SC(3) 18,218.01 76.39 79.49 5,931.08 5,874.93 3,322.16 15,734.91 5,978,887.82 401,683.39 0.37 16,081.77 MWD+IFR-AK-CAZ-SC(3) 18,308.34 76.57 79.48 5,952.19 5,896.04 3,338.18 15,821.26 5,978,902.53 401,769.97 0.20 16,169.57 MWD+IFR-AK-CAZ-SC(3) 18,405.13 76.38 79.32 5,974.83 5,918.68 3,355.50 15,913.76 5,978,918.43 401,862.71 0.25 16,263.66 MWD+IFR-AK-CAZ-SC(3) 18,498.26 76.26 79.15 5,996.86 5,940.71 3,372.40 16,002.66 5,978,933.98 401,951.85 0.22 16,354.13 MWD+IFR-AK-CAZ-SC(3) 18,590.94 76.63 78.29 6,018.58 5,962.43 3,390.02 16,091.01 5,978,950.25 402,040.45 0.99 16,444.22 MWD+IFR-AK-CAZ-SC(3) 18,680.94 76.64 78.85 6,039.38 5,983.23 3,407.37 16,176.84 5,978,966.29 402,126.53 0.61 16,531.78 MWD+IFR-AK-CAZ-SC(3) 18,768.72 76.64 79.04 6,059.67 6,003.52 3,423.75 16,260.66 5,978,981.39 402,210.58 0.21 16,617.18 MWD+IFR-AK-CAZ-SC(3) 18,867.02 76.45 79.13 6,082.54 6,026.39 3,441.85 16,354.53 5,978,998.06 402,304.71 0.21 16,712.77 MWD+IFR-AK-CAZ-SC(3) 18,958.74 76.45 79.15 6,104.03 6,047.88 3,458.65 16,442.10 5,979,013.53 402,392.52 0.02 16,801.92 MWD+IFR-AK-CAZ-SC(3) 19,054.20 75.82 79.01 6,126.90 6,070.75 3,476.21 16,533.10 5,979,029.69 402,483.76 0.68 16,894.59 MWD+IFR-AK-CAZ-SC(3) 19,144.93 76.06 79.34 6,148.94 6,092.79 3,492.74 16,619.55 5,979,044.90 402,570.44 0.44 16,982.59 MWD+IFR-AK-CAZ-SC(3) 19,236.83 76.07 79.36 6,171.08 6,114.93 3,509.22 16,707.20 5,979,060.05 402,658.34 0.02 17,071.76 MWD+IFR-AK-CAZ-SC(3) 19,332.14 76.50 79.16 6,193.67 6,137.52 3,526.48 16,798.17 5,979,075.92 402,749.55 0.50 17,164.34 MWD+IFR-AK-CAZ-SC(3) 19,424.99 76.83 78.65 6,215.09 6,158.94 3,543.86 16,886.83 5,979,091.95 402,838.45 0.64 17,254.68 MWD+IFR-AK-CAZ-SC(3) 19,516.00 76.26 79.06 6,236.27 6,180.12 3,560.97 16,973.67 5,979,107.73 402,925.54 0.76 17,343.18 MWD+IFR-AK-CAZ-SC(3) 19,610.71 76.14 79.02 6,258.86 6,202.71 3,578.46 17,063.97 5,979,123.84 403,016.09 0.13 17,435.15 MWD+IFR-AK-CAZ-SC(3) 19,704.39 76.58 78.77 6,280.95 6,224.80 3,595.99 17,153.31 5,979,140.02 403,105.67 0.54 17,526.18 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:15:46AM Page 7 COMPASS 2003.16 Build 69 - ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (`) (') (ft) (ft) (ft) (ft) (ft) (ft) ('/100') (ft) Survey Tool Name 19,794.55 76.57 78.99 6,301.88 6,245.73 3,612.91 17,239.36 5,979,155.62 403,191.96 0.24 17,613.87 MWD+IFR-AK-CAZ-SC(3) 19,889.66 76.76 79.31 6,323.82 6,267.67 3,630.33 17,330.25 5,979,171.65 403,283.10 0.38 17,706.40 MWD+IFR-AK-CAZ-SC(3) 19,980.31 76.32 79.34 6,344.92 6,288.77 3,646.66 17,416.88 5,979,186.66 403,369.96 0.49 17,794.55 MWD+IFR-AK-CAZ-SC(3) 20,067.00 75.74 79.13 6,365.84 6,309.69 3,662.37 17,499.53 5,979,201.11 403,452.83 0.71 17,878.66 MWD+IFR-AK-CAZ-SC(3) 20,114.00 75.74 79.13 6,377.42 6,321.27 3,670.96 17,544.26 5,979,209.02 403,497.69 0.01 17,924.20 BLIND(4) 6/16/2010 10:15:46AM Page 8 COMPASS 2003.16 Build 69 Pro /0 - 04-7- Ferguson, 04- 7- Ferguson, Victoria L (DOA) From: Brunswick, Scott A<Scott.A.Brunswick@conocophillips.com> Sent: Thursday, April 25, 2013 4:35 PM To: Ferguson, Victoria L(DOA) Subject: RE: CD1-15 Conductor Question Attachments: CD1-15 Schematic Updated.pdf Victoria Would this work? From one of the engineers here in 2010. Began losing mud when started drilling surface hole,thawed permafrost and/or poor conductor cement job raised concern of broaching,so a cement plug was set in open hole and back into conductor. Then drilled surface hole and ran casing w/cement to surface. Thanks Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)-263-4249 Cell: (907)-227-8499 From: Brunswick, Scott A Sent:Thursday, April 25, 2013 3:33 PM To: Ferguson, Victoria L(DOA) [victoria.ferguson@alaska.gov] (victoria.ferguson@alaska.gov) Cc: Brunswick, Scott A Subject: CD1-15 Conductor Question Victoria It looks like they had remedial work performed on the conductor when they first began the CD1-15 well on 4-28-2010 and cemented the conductor. See attached Wellview reports. I believe this is why that grey area on the schematic shows up with the comment cement plug 46. I've asked that the schematic be updated and will send on a copy when that is completed. I don't see mention of cementing below the top retainer @ 19705 ft MD,also see attached Wellview reports. I know that we would like to keep all available candidates on all pads available for annular disposal as there are very few candidates left. Was there anything else I can answer? Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)-263-4249 Cell: (907)-227-8499 «File:CD1-15 WView Reports Conductor.pdf>> <<File:CD1-15 WView Reports Retainer at 19705.pdf>> 1 WNS CD1-15 ConocoPhillips g well Attributes Max Angle&MD TD Inc. Welborn APAWI Field Name ---Well Statue Niel("I MD(MB) Act Bin MKS) AlaskaCpnruPhNeDt 501032061900 ALPINE _ PROD 178.02 7,616.39 20,700.0 _____ Comment 112S(ppm) Date Annotation End Date KB43N(It) Rig Releaas Date AM •""NMI CoeSGHORI70 TAL-C01-15,4/16(2013¢:11:47 NN SSSV:NONE Last WO: 36.13 6/15/2010 $dneerec-15. Annotation Depth(BKS) End Date Annotation Last Mod...End Dab Last lag: Rev Reason:WELL REVIEW osborl 1/29/2013 ---- ___-________— ---- Casing Strings casing Description smog o... smog p...Top MKS) sat Depth(t..set Depth 4WD)...smog wt...String-.String Top Thrd HANGER,31 - CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 1.40 Welded Insulated 36" Casing Description String 0... String ID-.Top(SKS) Sat Depth(t..Sat Depth(ND)-.String Wt-.String_Stung Top Thrd SURFACE 103/4 9.950 35.8 3,112.2 2,393.4 45.50 L-80 BTC Casing Description Stung 0... String ID-.Tap(SKS) Sat Depth(t..SM Depth(ND)-.Stung WL.String...String Top TAN WINDOW 8 7.000 20,067.0 20,081.0 6,369.3 Casing Description String 0... String D_Top(SKS) Sat Depth(L.Set Depth(ND)-.String Wt...String_String Tap That INTERMEDIATE 75/8 6.875 33.5 20,224.9 6,404.7 29.70 L-80 BTCM Tubing Strings Tubing Description iString 0... Stung ID...Top(11KB) Sat Depth(t..Set Depth(ND)...Stung Wt..String... String Top Thrd TUBING 312 2.992 30.6 2,212.0 2,017.9 9.30 1-80 EUE KILL STRING , ;:—._..j .e COQ Details Top Depth (TVD) Top Inel Nomi... Top(KKS) VIM I') Item Description Comment ID(In) 30.6 30.6 0.21 HANGER FMC TUBING tiANGER 4.500 34.5 34.5 0.21 XO Reducing CROSSOVER 4.5'x 3.5" 2,211.5 2,017.5 49.47 WLEG WIRELINE ENTRY GUIDE 2.992 CONDUCTOR Other In Hole reline retrievableP lug s valves,pumps,fish,etc.}_ Insulated 381, - --- , pp f 37-114 Top Depth - - (TV) Top tool Top(1(8) ( (*) DascriptronComment _ Rem Dab ID(In) 19,705.0 6,281.1 76.58 RETAINER BAKER CMT RETAINER 6/122010 WLEG,2,212 20,067.0 6,365.8 75.68 WHIPSTOCK WHIPSTOCK-ANCHOR BILLET-COULD NOT GET 6/7/2010 THRU CASING WINDOW 20,080.0 6,369.1 75.69 PACKER 6//2010 20,085.0 6,370.3 75.70 RETAINER BAKER CMT RETAINER 6/3/2010 Notes:General&Safety --_ 2 E End Date Annotation I428/2010 NOTE:Cement plug set in open hole and back into conductor before drilling surface to avoid breach. 6/15/2010 NOTE:WELL SUSPENDED,KILL STRING IN PLACE.PREPPED FOR SIDETRACK;PBTD 19705' 6/182010 NOTE:VIEW SCHEMATIC W/Alaska Schematic-9.0 SURFACE. l 11242010 NOTE:SET BPV IN TREE 38-3.112 4/17/2012 NOTE:REQUEST TO AOGCC TO EXTEND SUSPENDED STATUS r 41 ,f tea✓ RETA1,,INER, 'v U L n WHIPSTOCK `/h 20.097 !::\ja41, WINDOW_ 20.1MND.091 PACKER, 111 20.093 RETAINER, PLUG,20017 T , NTERMEDIATE, 3430,225 TO(CDt-IS), 20.700 _IHR �.� 90M & A5I / 0000E,..... ..... ..4.21r.Wor ,, ,,... • e ...V:SIZIft..4"..•:,....._.'1..:4., , 111111)414/14 o .. ` �00����\\\\ �\\\\�������������\"\"",�1/ I/`�,i0 s 1• �o * `` `` 1,.00....4,4p..4%.-- \t‘ ��� �I I eii' r�Rra��p.�� �����������\`\��N`\"\\„�_ �' III! ��//ll '����I���i�!a eef .���C..:1� �' HH 'Ii- ,, llu„Hlry y1111,,,„ ,„„,;•,• ,..!„.,��,������i�u11���111111h� �����N , . ►, , ,.,,,..muu►�111 1,4„„lIIII(QIIIII(IIIiil((p��n� mini��e �IJm 1) )) I(IIIIIIN Nlllliiiiii►�": ; g Nimbi MR IR 1RIjj11II �N�Hnp Illuu �w••;,. r.. :,.,►►► i Nll �, )I. 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BeiI�IIi: ����� ��,)lit. � l� ill III mLIIIIIUhIIII1LIL((ftHin1ILILLa'caalit > > "Intl 11 u����n��a� Itflifitits � �� �� 11 ,I. � �`` �� �� // � �� �' ��\�\�\� \ , � �� �� 11�\��\\\\\\\\\\ o / �� 1\\\\\0�. • .c \ -..0 , 4,...,..,.......-,, . / / �/ dis 11 1 00, • ' ' \e �%oo ��..., ,....,..),......,,......_,;,.0 ......,,.,,.........„ / �,� 1 . .. . , x , • .................... --------'1-6---64.4‘7„ -A\ . .. 14'4 1-‘c VATief: uu. ..%%. \ . tiilititit4 ,• .`,•.� •�•� .�, \ \\\\\\ :\// , „ ., . �. f� ., ,�� � 111��/ 111 �i� ,, .. �; tx ..•�� •. �lar�:\�r!�t �'��� SIN ��o ��. o. '� � � • ,...•r. . � rr,111110 `''�IIII. �t�, ��,, .... . �. . s . . 11th1111I ���r'4” / :0:.:0..;.......7. 1.........„==......a..w."7":51 ,..,•••%.4w4"•%. . 4 01:1.--- .......-74..........1..... 0. I, � NI �rrr .un��1.114�1 ��� '11I .. ty�. 11II �► ��r ..rrr 1IIltiiii � � rz rr. 11 � � I IIII It �� �IIIA_ �n tll ��:I��rrn- r� I Il ( ��� ..�- , rrr 11� �� . III IM �`�� Ilhl uuntt r��i . �s, lm �N HJ . II� ���t o►� .• � •.��. ��� 111 ��� �. �) 1111 ���� . . . . � �� � I I t IIIIt111��rn� ,. r,. . i I � o\ , / �l I �� ��%%kr% .�..---- i ii. it- .fmoo. // \\%\ 44, �� =moi%% ww\�0����� 4, THE STATE Alaska Oil and Gas i M °ALASKA Conservation Commission ‘101,-MF GOVERNOR SEAN PARNELL 333 West Seventh Avenue (4'a Asap• Anchorage, Alaska 99501-3572 Main' 907.279.1433 Fax: 907.276.7542 Chip Alvord Alaska Drilling Manager Conoco Phillips Alaska, Inc. d)l d_ © (�' P.O. Box 100360 // Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD1-15, CD1-15PB1, CD1-15PB2 Sundry Number: 313-193 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this day of April, 2013. Encl. . t' RECEIVED STATE OF ALASKA APR 2 3 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend Q• Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other I ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Conocophillips Alaska,Inc. Exploratory ❑ Development ❑ 210-047 3.Address: Stratigraphic ❑ Service Q, 6.API Number: PO Box 100360,Anchorage,Alaska 99510 50-103-20619-00,-70,-71 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CD1-15, CD1-15PB1, CD1-15PB2 Will planned perforations require a spacing exception? ? t Yes Li No 09.Property Designation(Lease Number): -t 44( 10.Field/Pool(s): ADL 37-2408, 38421.4, 25559 33ISS'oI 256.67 2.55-5-8 S Colville River Field/Alpine 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): Q 20700 6514.6 19705 6281 Cmt Rtnr @ 19705'MD Casing Length Size MD TVD Burst Collapse Structural Conductor 78 16 114 114 Surface 3112 10.75 3112 2394 Intermediate 20225 7.625 20225 6405 Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None 3.5" L-80 2211 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Cmnt Retainer MD=19705 ND=6281 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑r . `t,� 14.Estimated Date for 15.Well Status after proposed work: '1'. Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended a 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Scott Brunswick 263-4249 Email scott.a.brunswick@conocophillips.com Printed Name Chip Alvord G�n�`�`C L. Title Alaska Drilling Manager Signature 7 Phone Date 4 to 44-;-(2.0r; COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Vt. " Spacing Exception Required? Yes ❑ No [� Subsequent Form Required: n /0 — 4-0 Approved by: COMMISSIONER APPROVED BY l'ir AO/ THE COMMISSION Date: 1-7Z...5/0 eR116011 Submit Forth and ,;�Form 10 403(Revised2�2) , Aplior months t �Zj/approval. Attacz�I� e Z\\\^'SC�dot \f� JH 3 0, t' RECEIVED STATE OF ALASKA APR 19 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A0000 20 AAC 25.280 1.Type of Request: Abandon 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well❑ Change Approved Program 0 Suspend Q Plug Perforations 0 Perforate ❑ Pull Tubing❑ Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate ❑ Alter Casing❑ Other I 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Conocophillips Alaska,Inc. Exploratory ❑ Development ❑ 210-047 ' 3.Address: Stratigraphic 0 Service Q 6.API Number: PO Box 100360,Anchorage,Alaska 99510 50-103-2061•-00,-70,-71 7.If perforating: 8.Well Name and Numb= . What Regulation or Conservation Order governs well spacing in this pool? CD1-15, CD1-15P=1, CD1-15PB2 Will planned perforations require a spacing exception? Yes 0 No Q 9.Property Designation(Lease Number): 91::21' 11915 10.Field/Pool(s): ADL 372108, 384214, 25559) .2SSSg Colville River Field/ -(pine Oil Pool• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs . easured): Junk(measured): 10074.9 6367.8 Cmt •tnr @ 19705'MD Casing Length Size MD TVD Burst Collapse Structural Conductor 78 16 114 114 Surface 3112 10.75 3112 2394 Intermediate 20225 7.625 20225 6405 Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size: Tubing Grade: Tubing MD(ft): None None 3.5" \ , L-80 2211 Packers and SSSV Type: . and SSSV MD(ft)and TVD(ft): I19705 TVD=6281 12.Attachments: Description Summary of Proposal Q V•.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ \, xploratory Li Stratigraphic❑ Development❑ Service ❑� 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: `� Oil 0 Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best• my knowledge. Contact Scott Brunswick 263-4249 Email scott.a.brunswick(a conocophillips.com Printed Name Chip Alvord Title Alaska Drilling Manager Signature Phone Date A-6.at„ 265--G lto 4(t5(L•t3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a r=.resentative may witness Sundry Number: ' I 1 q3 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 0 Ro Submit Fonn ane ( Lor Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 1 ConocoPhillips Anchorage,Alaskaa 995 99510-0360 Telephone 907-276-1215 April 18th, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 APR 19 2013 Re: Sundry Permit: Suspend CD1-15 AOGCC Dear Sir or Madam: ConocoPhillips Alaska, Inc. applied for a sundry permit for an operational shutdown extension on CD1-15 in April 2012 (Sundry 312-158). At the time that sundry was submitted the CD1-15 well was expected to be a candidate for resuming operations in 2013. The CD1-15 well was spud on April 28th, 2010. The 13-1/2" surface hole was drilled and cased as planned. The 9-7/8" intermediate hole was started on May 4th, 2010, and drilled to a depth of 20,700' MD. While running the 7-5/8" intermediate casing string, hole conditions prevented the shoe from getting to bottom, and it was eventually set and cemented 477' MD high at a depth of 20,223' MD. The inability to get the casing to bottom led to a series of events that resulted in the inability to drill the 6.75" production hole to its planned depth of 21,993' MD. A sundry application for the CD1-15 well was approved on June 16th, 2010 to put the well under Operational Shutdown after it was determined the well could not be drilled and completed in time to meet summer drilling requirements on CD4 pad. CPAI was unable to return to CD1-15 during the 12 month window of the original approved operational shut down due to casing running challenges on CD4 during May through July of 2011. The delays caused by casing running problems pushed the CD1-15 on the schedule out over 60 days. Therefore, that plan for CD1- 15 was to be re-entered in late 2011, this did not occur and an additional operational shutdown extension was to be filed on 8/3/2011. (Sundry 310-182) Due to competition with stronger well candidates with lower operational risks on the rig schedule and technical planning challenges that required further evaluation along with well cost incurred to complete the CD1-15 wellbore; an additional extension to the operational shutdown was submitted and approved (sundry 312-158). CD1-15 was to be re-scheduled for a future date in 2013 or later. For the same reasons stated above, CD1-15 has been pushed further back on the rig schedule. ConocoPhillips has decided the best option for the time being is to request the suspension of the well until such time that a proper drilling plan & risk evaluation may be performed. Prior to re-entering the CD1-15 a sundry for restarting operations will be submitted to the AOGCC with an accompanying new permit to drill. If you have any questions or require further information, please contact Nina Anderson at 265-6403 (Nina.Anderson d conocophillips.com) or Scott Brunswick at 263-4249 (Scott.A.Brunswick@conocophillips.com). Sincerely, Brunswick Drilling Engineer cc: CD1-15 Well File/Sharon Allsup Drake ATO 1530 WNS CD1-15 ConocoPhilips 01111 1 Attributes Angle&MD 1 TO ..n�ti., i!I-. WatW W lbore API Field Name Web Status Intl r) 10 MD 05) Act Btm OMB) lorawtw0lpz 501032061900 ALPINE PROD 78.02 j 7,616.39 20,700.0 Comment —CommentH2S(ppm) Date Annotation End Data 10B-0rd(tt) Rig Rebate DSM ••• SSSWIICanad:HORIZolITAL-CD1.15.4I28I20i3k1647AM -, V:NONE Lest WO: 36.13 6/15/2010 _ Sd,smetic-Acari Annotation Depth(SKS) End Dela Annotation - — —s-....- Last Mod.-End Date Last Tag: Rev Reason:WELL REVIEW osborl 1/29/2013 CasingStrings ' Casing Description String 0... String ID...Top(ORB) Set Depth p...Set Depth(TVD)...St rng Wt..String...String Top ThN__ HANGER 31 r CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Insulated 36' Casino Dwoilptlon String 0... String ID...Top(RCB) Set Depth(L.Set Depth(TVD)-.String WL.String-.String Top Thrd SURFACE 103/4 9.950 35.8 3,112.2 2,393.4 45.50 L-80 BTC Casing Description String 0... Biting ID...Top(SKB) Set Depth(f...Bet Depth(ND)...String WL.Stung..Siring Top TAN WINDOW 8 7.000 20,067.0 20,081.0 6,369.3 Casing Description String 0... Shing ID...Top(SKB) Set Depth(f...Set Depth(TVD)...Sting MA...Btrhq...String Top Tied INTERMEDIATE 75/8 6.875 33.5 20,224.9 6,404.7 29.70 L-80 BTCM II Tubing Strings Tubing Descriptor I Strop 0... String ID.../Top((Kat B) 'SDepth(1'...'Set Depth(TVD)...String Wt...String...String Top Tbrd TUBING 31/2 ' 2.992 1 30.6 2,212.0 2,017.9 9.30 L-80 EUE KILL STRING 1 s A.Com_pl_slion Details y` C OW) Top Ind a( Top pets) OMB) P) Rem Description Comment ID(M) 4.500• S K J 345 34.5 0.21 XO Reducing CCROSSOVERF4 4.5" 3.5' 3.958 2,211.5 2,017.5 49.47 WLEG __- WIRELINE ENTRY GUIDE 2.992 CONDUCTOR % R le.aerdOR 6Vttrer In Nolo Manillas retrievable Plugs,valves pumps,fish,etc.) 37-114 Top Depth (TVO) Tp and • Top MKS) (raB) C) Deeerlplbo Comment Run Dab ID On) WLEG,2,212 1:, 19,105.0 6,281.1 76.58 RETAINER BAKER CMT RETAINER 6/1212010 20,067.0 8,3858 75.68 WHIPSTOCK WHIPSTOCK-ANCHOR BILLET-COULD NOT GET 8/7/2010 THRU CASING WINDOW 20,080.0 6,369.1 75.69 PACKER 6/7/2010 20,085.0 6,370.3 75.70 RETAINER BAKER CMT RETAINER 6/3/2010 Notes:General&Safely End Dote Annotation 4/28/2010 --- NOTE Cement plug sat in open hole and batt into conduceer before drilling surface to avoid breath. 6/15/2010 _-NOTE WELL SUSPENDED,KILL STRING IN PLACE,•- •--r FOR SIDETRACK:PBTD 19705' 6/1812010 NOTE:VIEW SCHEMATIC W/Alael(a Schemedc9.0 SURFACE. I , 11/24/2010 NOTE:SET BPV IN TREE 't12 4/17/2012 NOTE:REQUEST TO AOGCC TO EXTEND SUSPENDED StATUS G' 511 DD �Q .k o v kr , ` 91 k 4-11v RETAINERIII W `-J 19.703 �.r ‘f\, WHIPSTOCK 1 20,087 .._. .,\ 03 WINDOW. 2007-20,081_ PACKER. 20,080 1.0 RETAINER, 20,085 _.. PLUG,20,087 9.')\ NTERMEDWTE, 31.20,775 TD(CD1-13), 10,700 • Bettis, Patricia K (DOA) From: Brunswick, Scott A[Scott.A.Brunswick@conocophillips.com] Sent: Monday, April 22, 2013 8:22 AM To: Bettis, Patricia K(DOA) Subject: RE: CD1-15: Application for Sundry Approval OK, apologies, I have no idea why I've entered 10074.9 ft MD &6367.8 ft TVD for the total depths. Total depth drilled on CD1-15PB1 to was 20,700 ft MD/6514.6 ft TVD. The 7-5/8" casing got stuck high and set off bottom @ 20225 ft MD/6404.7 ft TVD. If the effective depth would reflect the top mechanical retainer that would be the cement retainer set @ 19705 ft MD. Would you like me to provide an updated copy of the 10-403? Thanks Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907)-263-4249 Cell: (907)-227-8499 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, April 19, 2013 3:54 PM To: Brunswick, Scott A Subject: [EXTERNAL]CD1-15: Application for Sundry Approval Good afternoon Scott, I am reviewing the Sundry Application for CD1-15. For Box 11 (Present Well Condition Summary), it is stated that total depth is 10,074.9 feet MD. This does not match the wellbore schematic attached with the application. Total depth reached and effective or plugged back depth should be provided as well as depths for all packers and plugs. I would appreciate your help with providing this information. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 X N a) to W Www oo 0iri CUN la CO V m 00 0 N U N t 5 W 0 8 O0NL-' CO E V z � � CNI o c 0 oo co Q N- ix) Lo CO W o � o wow00 o_ p o) �- C c o N V 00 Cr) ° E N E N CD N co .... LIZ CO o > a .y � TT a y0 no U a0) o z0- _y C v. a) E LE) y 0Q) E = LU O N L. Z 0 w 75 w � "' a� C o f N pz o N 0 a CO Q o om Eo 0 a CO //� € Z v cu IT a) N c N N p 'z M G d Q ILL m •L V O co J O co ao of m O Q a O O y N C T A oo. ,- O O O O O C 0 ❑' v N Z co c ' W U ❑ ❑ O O U ;1 N u) g > N En CO+� Q io p y > a u.l r o a d E co r) U 0 > Lu oi Q W ❑ co M O . O Lo C Z 11- Z0 co co o a a� 0 Q > co Z � U Z :E ❑ a) El Cl) °- a Q Q o�❑ ❑ rn 0 (n W Z H y X w > u) E o t Z o o E C a * to c w Z . > m N U CO c 0) CI N o Oi Q I CD .p 0 O y OS J iii > > r o M r m m c co co le. tMn U) 1.... 3 00 V U ❑ � 0 U C o- z ❑ a co m E 0 a1-4 Q ❑ 0 rn m ~vi N E m 3 = m > 2 C 0,.O o d * O LL = C 3 O O O O O y C v J o Y p U d 17 > N O N N d C,1 Q GC -aON c P2 O CI C 0 co N 7 i o f0 c — C f0 C c ., o o C = o y ` C co N C Q •C •O .+ O N 7 0 f6 0) NI- o Y O U 7 d - E c 3 o ❑ co o) N CO CD co 0 m a) v m co N O O O O O . C a) oQOO O rn 'A -E' oco OOEy 0 IR, N P = x E 8 X a re _ o _ ❑ 0. L C'o�; C N W Qc. o O O N .7 y Ey - O C 'O U N c �. O UO L o .L.. O U •O = CO co L 0 ••• E s- C d C O. O co .! r l0 O U N O co H 0 'O t a C C .0 (0 O C O -a 0 N 'O N T • p a N M — \ N W 7 •• t0 E d N 4? LL o. -o V .0 ` m N N N M M p .0 Q C 0 N fn d 0 Q n-N M p N N N N 45 Nr 0> //SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION / ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Jolley Supervising Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 PVC) Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-15 Sundry Number: 312-309 Dear Mr. Jolley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. 7/<- Commissioner DATED this 2/ day of August, 2012. Encl. Davies, Stephen F (DOA) From: Jolley, Liz C [Liz.C.Jolley@conocophillips.com] Sent: Friday, August 10, 2012 4:14 PM To: Davies, Stephen F (DOA) Cc: Allsup-Drake, Sharon K Subject: CD1-15 Sundry to Extend Operations Hi, Steve, We are submitting the sundry to extend operations for another year. Due to wellbore stability issues on other drillsites, we have not been able to return to CD1-15 in the time proposed on the previous sundry. Let me know if you need any more information. Kind regards, Liz Liz Jolley (Galiunas) Supervising Drilling Engineer ConocoPhillips Alaska Office: 907.265.6247 Cell: 907.903.1200 1 STATE OF ALASKA U" /` - -0,13 EC E I V E D t x, AL A OIL AND GAS CONSERVATION COMA ION APPLICATION FOR SUNDRY APPROVALS AUG 0 y 2012 20 AAC 25.280 A1G(C 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved R'ogram r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension rr • Operational Shutdown r Re-enter Susp.Well r StimulateAlter casing 9 r Other:Extend Operational Shutdourj- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210-047 ' 3.Address: 6.API Number: Stratigraphic r Service F:7 P. O. Box 100360,Anchorage,Alaska 99510 50-103-20619-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No Po- CD1-15 . 9.Property Designation(Lease Number): 10.Field/Pool(s): Apt, 37//St F.-2•14311-2,42-1-4,25559 2-!5-5-57;24-5g Colville River Field/Alpine Oil Pool ' _ 11. sb P>i-(: PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): IJunk(measured): 10075 6368 140', 19705',20085',20368' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3076 10.75 3112' 2394' INTERMEDIATE 20191 7.625 20225' 6405' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 3.5 L-80 2212 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-Baker MD=20080 TVD=20080 no SSSV 12.Attachments: Description Summary of Proposal 1,7 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/1/2012 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r • Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Liz Jolley©265-6247 I Printed Name L. Jolley R:oR_ CH--t P fi-LJ.C'2,0 Title: Supervising Drilling Engineer Signature �,/ `00 �/ Phone:265-6247 Date g1g/i 2 Commission Use Only Sundry Number:312 30, Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other. y /ea '1-Z-67 -,967 ,I es, 1 3 Subsequent Form Required: , ,bl6+ y'Q5 I b aAtO'f f APPROVED BY ?,1/ ApprovedKOV/774" COMMISSIONER THE COMMISSION Date: ia Form 10-403 Revised 1/2010 yz y./ R1G1 0 arS AUG 3 0 20 ubin Du li ate j I'1 ' mi ( 04' : WNS CD1-15 • ConocoPhillips Well Attributes Max Angle&MD TD Inc, Wellbore APIIUWI Field Nana Well Status Incl r) MD(ftKB) Act Btm(ftKB) Alaska. .naRtagps 501032061900 ALPINE PROD 78.02 7,616.39 20,700.0 Comment H2S(ppm) Date Annotation End Date KBGrd(ft) Rig Release Date •••Well Conte:HORIZONTAL-C01-15.13/18/2010 7,46a4 AM - Last WO: 36.13 6/152010 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:NEW WELL,SUSPENDED Imosbor 6/18/2010 Casing Strings -..""Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER.31IIE ) CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(IVO)...String Wt...String...String Top Thrd SURFACE 103/4 9.950 35.8 3,112.2 2,393.4 45.50 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd WINDOW 8 7.000 20,067.0 20,081.0 6,369.3 Casing Description String 0... String ID...Top(ttt(B) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd INTERMEDIATE 75/8 6.875 33.5 20,224.9 6,404.7 29.70 L-80 BTCM Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 1;17.0.__! 1117 Tubing-Short String 31/2 2.992 30.6 2,212.0 2,017.9 9.30 L-80 EUE Completion Details Top Depth (ND) Top not Nomi... Top(ftKB) (ftKB) (•) Item Description Comment ID(In) 30.6 30.6 0.21 HANGER FMC tubing hanger 11"OD 4.500 34.5 34.5 0.21 XO Reducing XO-3 12"EUE 8rd(P)X 4 12"IBT 3.958 2,211.5 2,017.5 49.47'WLEG WLEG 2.99"ID-4.5"OD 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth CONDUCTOR, (ND) lop Incl 37-114 Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) Cement Plug, 48 19,705 6281.1 76.58 Cement BAKER CMT RETAINER 6/12/2010 1Retainer C 20,067 6,365.8 75.68 Whipstock WHIPSTOCK-ANCHOR BILLET 6/7/2010 WLEG.2.212 - 20,080 6,369.1 75.69 PACKER 6/7/2010 / 20,085 6,370.3 75.70 Cement BAKER CMT RETAINER 6/3/2010 Retainer Cement Squeezes Top Depth Btm Depth (TVD) (TVD) Top(ftKB) Btm(ftKB) (ftKB) MB) Description Start Date Comment 46.0 140.0 46.0 140.0 Cement Plug 4/28/2010 Layed 20 Bbl AS1 Cement Plug to Cure Lost Returns at Conductor Shoe 20,116.0 20,368.0 6,377.9 6,438.1 Cement Plug 5/29/2010 Spot Cement plug for Kick Off Notes:General&Safety SURFACE End Date I Annotation 56,112 6/15/2010 NOTE:WELL SUSPENDED,KILL STRING IN PLACE 6/18/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 II il Cement Retainer. 19.705 Whipstock. 20,087 I WINDOW. .lt 20.087-20,081 PACKER, 20,080 - Cement 1 Retainer, 2Q085 NTERMEDIATE, 34.20,225 Cement Plug, 20,118 TD(CDt-15), 20,700 STATE OF ALASKA AL A OIL AND GAS CONSERVATION COM. SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair well r Rug Perforations r Perforate r Other r Alter Casing r Rill Tubing r Stimulate-Frac r Waiver r Time Extension r 0 f)s� Change Approved Program r Operat.Shutdow n r Stimulate-Other E Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 210-047 3.Address: 6.API Number: ,�/, Stratigraphic r Service jai A��V1 P. O. Box 100360,Anchorage,Alaska 99510 ` 50-103-20619-00 7.Property Designation(Lease Number): 8.Well Name and Number: 372108,384214,25559 - CD1-15 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 10075 feet Plugs(measured) 140',19705',20085',20368' true vertical 6368 feet Junk(measured) None Effective Depth measured na feet Packer(measured) 20080 true vertical na feet (true vertucal) 6369 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3076 10.75 3112 2394 INTERMEDIATE 20191 7.625 20225 6405 RECEIVED Perforation depth: Measured depth: none AUG 0 9 2012 True Vertical Depth: none AOGCC Tubing(size,grade,MD,and ND) 3.5, L-80,2212 MD,2018 TVD Packers&SSSV(type,MD,and ND) PACKER @ 20080 MD and 6369 TVD no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service`r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG E 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: 31A -' 3°1 Contact Liz Jolley a 265-6247 Printed Name L. Jolley CAtiQ Title Supervising Drilling Engineer Signature ^ LA/ Phone:265-6247 Date /B IZ 7AUG 0 9 2012 c - 76 7-�-��. ,9/.9e— RBDMS Form 10-404 Revised 11/2011 Submit Original Only DATE SUMMARY OF OPERATIONS 110/6/1© LOCATED WLEG @ 2184 M. LOGGED TEMP SURVEY PER PRC 'JURE. 32.62 DEG @ 1462' RKB. FMC RE-INS). ._LED BPV. COMPLETE. 11/21/10 PULLED BACK PRESSURE VLV. IN PROGRESS. 11/23/10 PERFORMED HIGH RESOLUTION TEMP SURVEY f/ 1004'TO 100' RKB. READY FOR BACK PRESSURE VLV. a) ma) a) W 8 o- L o - isi Q) a0 N .? 8aas � N u o N w Q) 0 0U)) yew c o cn o 1 o ,C o L m C) o p cz. ii: Z o c 13 N V oo 46:13 CO 2 co L N 6 a) CO w 'C O = • � v= ` CO O• > 'y = a' "' v 8 t 0) 0a y D)0 Co .c Cr 43 n a) E w O o ;� w E Z' .. ▪ o m o z' Z = , a� D ai m 03 m z L O -t o ���//�� = E o co O "O (Ni a V♦ Z Z N C N Cr d Q ILL O C L U t a Q 4A (D— m oQoo • li _ v O O co � -0 Z °' E v en 0 0 0 0 `I O CO Nz -cso V W • ❑ ❑ r- c Q /��// o I.L aa) o Q ❑ o N - N CO Q m _i a a U) o a a in Laca J ❑ COos 0 CD Q will = W cn e E co Co M >+ CC Lu ❑ y co 747) O Z O p Z U al 0 > co U) wc� Z n 0 co o `n - N > (/) VLL fn O y H L = Z U to ~ oa 5 v E 83 a) w ? Zco N N o c to IC) L Q a) Co N U N y N 0 O) a) J Co 0 > > L 43 o CO co V) 3 aa) f- Q O `° N ❑ c MO � .a a 3 U 0 a �, - o 0 Y � ❑re () v vco uj 6 _a L. E o w Q ElL N N y O) a7 a) Ta 3 •m a) N w C O)-o "us. >> LL V N c 3 O 0m ` O ~ Y � J O y O _ co u cai 31 ` d ca d U Q Q ❑ � � o c CD a) V m m O) C as co O m y C o 7 a) U U C as C -0 .0 y as N �► C C 'p �, y .a w ca . CIfa Q o '0 d C a G= a1 E m O Y o U , o - E c 3 0co o 0 E a) E o- t N cv, 1 Q o o, y :° o m o 0 o a) c_ as o "' o `,J y o o E uyi m o o > ._ N a xo• c ._ N U E o 8 y a 0 .0 > ao R L m o ❑ ^ N C ul C N y_ w Q �a N V - O w co Pri —LU or o a d o .....2 oz vas' m m O t .. 2 o ILI __ o o u) .o O Co C a1 .. Z E ' <Cr O U y Y Q y N C L C C L fa o U U O N 0 .0 N M V \ N c N « E a2. C LL a) v La) m o a c E n a) O < U a�'� N N N in c+) W o a Q cc 0 d •rn •- _ m y Cl) d N c a 2 N N N N N • > V - 0 l , Lc � ,`. L i_ I' 0blAsEn illikSEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 D �f Anchorage, AK 99510 I 0 /� Re: Colville River Field, CD 1-15 Sundry Number: 312-204 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4,! /0401,1 I Cath P. Foerster Chair DATED this I4 day of June, 2012 Encl. RECEIVED STATE OF ALASKA JUN 0 '012 ALASKA OIL AND GAS CONSERVATION COMMISSION J %Gad( ( ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 1.Operator 3 Permit to Drill Name 2100470 • ConocoPhillips Alaska 4.API Number 50-103-20619-00-00 2.Address: 5.Well P.O Box 100360,Anchorage,Alaska CD1-15 ' 6. Field Colville River Field 7 Publicly recorded wells 8.Stratigraphic description a)All wells within one-quarter mile a)Interval exposed to open annulus. CD1-01, CD1-02, CD1-04, CD1-05, CD1-06, CD1-07, CD1-09, Torok and Seabee formation, shale,siltstone and sandstone CD1-10, CD1-13, CD1-14, CD1-16, CD1-17, CD1-19, CD1-23, CD1-24, CD1-25, WD-02 b)Waste receiving zone b)water wells within one mile Sand layers below the upper Cretaceous C30 marker None c)Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost 10. Hydrocarbon zones above waste receiving zone approximately 1663'MD/1600'TVD - None 11 Previous volume disposed in annulus and date: 12. Estimated slurry density. 13 Maximum anticipated pressure at shoe None Densities range from diesel to 12ppg 2067 14.Estimated volume to be disposed with this request. 15 Fluids to be disposed. 35,000 bbls. - Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel,formation fluids associated with the 16 Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 15-Jun-12 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 MC 25.005. 17.Attachments. Well Schematic(Include MD and TVD) ❑✓ Cement Bond Log(if required) ❑ FIT Records w/LOT Graph ❑✓ Surf Casing Cementing Data Other ❑✓ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. l ��, - Signature: �� l Title `�hU'6y Printed Phone 0 Name: Chip Alvord Number: 265-6120 Commission Use Only `, Conditions of approval: i`'�rv,�J/, Ce tv/f h ZD ,h►-C LOT review and approval: V A��/Ti 3 .�JfC� i��/ Subsequent form required. /1) �T/�2 Approval number 3i 2-- 4. / APPROVED BY THE COMMISSION Approved by' AIL 44i/ COMMISSIONER Date - f �; ir Form 10-403AD R: 6/2004 //�/ L INSTRUCTIONS ON REVERSE n D Su / ate It C(1 ConocoPhillips Alaska,Inc. IIPIr Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhi I I i ps Telephone 907-276-1215 June 1st , 2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD1-15 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD1-15 permitted for annular pumping of fluids occurring as a result of drilling operations,per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD1-15 approximately June 15th, 2012. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report&Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report(LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report&Daily Drilling Report during cement job 10. Formation LOT on 10-3/4" x 7-5/8" casing annulus 11. List of wells on CD1 pad and the lateral distance from the surface casing shoe. 12. Information regarding wells within '/ mile radius at AOGCC: CD1-01, CD1-05, CD1-07, CD1-09, CD1-10, CD1-13, CD1-16, CD1-19, CD1-23, CD1-25. 13. Information regarding remaining wells within '/ mile radius included in sundry package: CD1-02 , CD1-04, CD1-06, CD1-14, CD1-17,CD1-24, WD-02. 14. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The most recent annulus LOT performed on 5/30/2012 (14.6 ppg) occurred at a lower equivalent mud weight than the casing shoe test(16.6 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Weifeng Dai at 263-4324; Chip Alvord can also be reached by calling 265-6120. Sincerel , vatey Pel Weifen D ' CD1-15Well File Drilling Engineer Chip Alvord ATO-1577 Sharon Allsup-Drake ATO-1530 cc: Annulus Disposal Transmittal Form - Well CD1-15 AOGCC Regulations,20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD1-15 2 The depth to the base of freshwater aquifers and permafrost,if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost= 1600' TVD(RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref.AOGCC Conservation Order No.443, March 15. 1999) 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud,drilling cuttings,reserve disposed of and the estimated density of the waste slurry. pit fluids,cement-contaminated drilling mud,completion fluids,diesel,formation fluids associated with the act of drilling a well,drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings,and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. • 6 A description of any waste sought to be determined as drilling Cement rinsate,mud plant rinse fluid generated by rinsing waste under(h)(3)of this section. tanks and equipment after producing drilling/completion fluid (see included note from CD 1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2067 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports,LOT/FIT reports and base of any freshwater aquifer and permafrost,if present,and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones,if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation,not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and,if so,a summary of the dates of the disposal operations,the volumes of waste disposed of,and the wells where the drilling waste was generated. 14 The well(s)where the drilling waste to be disposed of was or CD1-22B,CD1-47,CD1-50,CD1-49 will be generated. 15 If the operator proposes not to comply with a limitation N/A established in(d)of this section,an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version 1.0-Jan'05 Well CD1-15 Assumptions Date 5/31/2012 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8"casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure(for wells on gas lift) 2,000 psi on Maximum Fluid Density to avoid Burst of Surface Casing Pburst85%=PHydrostatic+PApplied-PFormation 4,425 =( 2,394* 0.052 *MW )+ 1500 - ( 0.4337 * 2,394) krt0 MWmax = 31.8 ppg 2,394 TVD Surface Casing String Size 10.75 in v Weight 45.5 ppf iv Grade L 80 rburst100% 5,206 psi Pburst85% 4,425 psi Depth of Shoe 2,394 ft FIT/LOT @Shoe 16.6 ppg or 2,067 psi FIT/LOT for Annulus 14.6 ppg Max Surf.Pressure 1,500 psi TOC Est.@ 5,182' MD 2,875' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85%=PHydrostatic+PApplied-PGasGradient-PHeader 4,072 =( 2,875 * 0.052 *MWmax )+ 1,500 - ( 0.0700 * 2,875 ) - 2,000 X X MWmax = 31.9 ppg 3.5"Tubing 2nd Casing String • Size 7.625 in 6,369 TVD Weight 29.7 ppf Grade L 80 rcollapse100% 4,790 Psi Pcollapse85% 4,072 psi Top of Cement 2,875 ft Gas Gradient 0.07 psi/ft Max Surf.Pressure 1,500 psi Header Press 2,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable= Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable= ( 2,394 *.052* 16.6 ) Pmax allowable= 2,067 psi This is the value for the Injection Permit"Maximum Anticipated Pressure at Shoe". 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N) ) ) N)N N N N N N>.N N U CO U.,1 Q Q 2 N U 7,YE Q �_ LL y = N M V Cn CO N) (O m O .- N M V CO CO r N C) O (N N CM V CO CD r OO O O •- N M V Cn O I` COO O N M V lO CD W f6 N 0 0 0 0 0 0 0 0 0 (v (v N N N N N N N N M M M M M M M M , Ca Y LL D • 0 0 000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0000 (a :: U) 0 0 0 0 0 CD U CJ 0 C) 0 0 CD U CD 0 CJ 0 0 0 C) 0 0 0 0 0 CD U 0 CD 0 0 0 0 0 C) 0 0 0 0 0 0 0 0 0 0 0 -J Z 8S 88 �1 prj WOO O UU W €'8 8 I C'7 w<��1 F'88 O co E LIN a q Lo O \ \11N g , t Oi#001‘0 NN =t 4- O \41 1! O Lo IV1 11 t Lo Ls1.1 Q11(1 I E ` ,4 (s) y .03 �� X01 bk1L4 !. 1.-- � \:1„, C D Li) PhA Lt‘ .- N 111 1a il) IW ‘ r pOi r a> , QNNIE ►� i in Ti.C) 60 I e ►'I'l' 4k•I " _.„.„,,,- A,,,,„„4LI .Lo ,c'i Ag ., 'NJ 1 it\ Lo 1 o 0 0 0 0 0 o Ls) _o Lo N 1 (u!/}r055) (+)u1 oN/(-)u}noS CD1-15 Surface casing Well: CD1-15 10 3/4", 45.5#, L-80, BTC-M Casing Date: 5/1/2010 ConocoPhillips Rig: Doyon 19 Alaska.Inc. Depth Jt Number Joints Well Equipment and Comments Length Tops ............... ......... . ....................... .. ....... . ....................... . .......... .......... . ... Top of String or Top of Flange • RKB to Top of Landing Ring 35.80 FMC 10 3/4" Casing Hanger 2.12 35.80 Jts 3 to 74 72 Jts 10 3/4", 45.5#, L-80, Casing 2987.54 37.92 HES 10 3/4" Sure Seal II Float Collar 1.19 3025.46 Jts 1 to 2 2 Jts 10 3/4", 45.5#, L-80, Casing 83.31 3026.65 Ray Oil Tools 10 3/4" Silver Bullet Float Shoe 2.25 3109.96 3112.21 3112.21 3112.21 3112.21 3112.21 3112.21 13-1/2" TD @ 3,122' MD / 2,396' TVD (Inc 75.6°) 3112.21 10-3/4" Casing Shoe @ 3,112' MD / 2,394' TVD 3112.21 3112.21 3112.21 3112.21 3112.21 3112.21 3112.21 3112.21 3112.21 One bowspring on stop 10' above shoe and on collar of jt#1. 3112.21 One bowspring on stop 10' below collar of jt #2. 3112.21 One Bowspring Centralizer per Joint 3 -13, then Every Other Joint 15 - 71 3112.21 One positive stand off centralizer above stop ring 15' up on Jnt. #73 3112.21 Total 51 Bowsprings - Two Stop Collars 3112.21 3112.21 85 joints of casing in shed - Run 74 joints - last 11 joints stay out 3112.21 3112.21 3112.21 3112.21 3112.21 3112.21 3112.21 Remarks. Drifted to 9.88"w/ plastic rabbit Up Wt 190 K DnWt 150K Block Wt 75 K Supervisors:Burley/Thornton 000_ 0 00 000 0 000000000 N- N N N N _ _ C) C) C) C) CC a) 00 a) 00 a) Y 'c 0) C) 00I` N h- I-- N0- N- CO a000QDCO000000L„ N c Q N �- ai a, CO m iii c I- -C O LO LC) Ln N In M Lf) 7r LC) LO LC) O Lf) 1� Ln Cb Ln O «) O O Ce E w cn c (N! o c•i ri v Ili co r- cc ai = > a) Q o m. E in 0 _ CL c' 0 0 0 0 0 0 0 0 O O O O CONE` CO 0 co f` N- N CO 0 (/)00. y CA.Q N d' 0 Co N- 00 C) C) 0 CD 0) o Q i E Nd' Cc MONSa) a0 N 7t000OON7ra) 00ON7rC00CDN71• CO0.) 0 = CL _ ,_ = 1- N N N N N CO M MMM 7r d' LO LC) Lf) LO LO > a Y r U) O LY r. 0000 0000 000 0 00 ) N _ C) C) aD0o co 000000 MCor` CO Ln LO ` Y d in c c d' 7r d• 7r 7r - 7r 7t - a) C) E m - O co co CO CO CO CO CO CO CO CO CO CO CO CO ') E m 5 O 0 �. c O N CO Lf) CO 0- 00 0) 0 L- 0 N N 0 O 13 > 0 0)) > m H O ✓ - 0 0 0 0 0 0 0 0 C 0 0 0 0 0 0 0 0 0 0 0 0 N 0. 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CNI W o d l 01 2 N N iii2 � Y0 No \> w l 0 ,co Oo Yd O2 c 2 as 1- d = 0. fV Y N; J 0 0 0 0 0 0 0 0 0 >+ d m V 00 W r� o� ocN N o u' C c6 C) ~ m II i a) Z c 321f1SS32Id E 0 I I0 Security Level: AK Development' DrillingDaily Drilling Report &Wel CD1-15 convccsimiuips' Report Number: 6 Rig: DOYON 19 Report Date: 5/1/2010 AFE Type Network/ID# j Total AFE+Sup 10280349 13,599,998.001, Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-15 Development ALPINE 3.44 6.0 0.00 3,122.0 3,122.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 12,491.58 65,878.01 608,857.58 1,830,908.01 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/26/2010 4/29/2010 43.30 40.22 3.08 6/5/2010 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) SURFACE,3,112.2ftKB. Ops and Depth @ Morning Report 24hr Forecast Cut&Slip Drilling line N/D riser, N/U wellhead& BOPE, Cut&Slip di-1g line,P/U 5" "G"& "S"D.P.,Test BOPE. Last 24hr Summary C&C Mud f/3122'to 2827',POOH to 1022'(Tight @ 1067'&1056'),Circ @ 1022', POOH&LID BHA,Rig&run 10-3/4"csg to 3112'(CBU @ 1206',2162'), Rig cmt head&C 7C Mud,Cement 10-3/4"csg w/468.0 bbls lead&61.4 bbls Tail displace cmt w/20 bbls fresh water&271.4 bbls mud, Bump plug w/1200 psi,Had full circ thru out job, Had 2229 bbls good cmt to surface,CIP @ 22:15 hrs 5/1/10, Rig Dn cmt heat, Flush riser, L/D landing jt.&csg equip. General Remarks Weather Head Count No Accidents-No Spills 17°,WC-2, Overcast,Wind ENE @ 28 Mph 47.0 Supervisor Title Mike Thornton, Rig Supervisor Rig Supervisor Dave Burley, Rig Supervisor Rig Supervisor Time Log Start. End Dur Time Depth Start Depth End I Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (EKE) Operation ,00:00 01:15 1.25 SURFAC DRILL CIRC P 3,122.0 2,827.0 Circ&Cond. Mud f/Running 10-3/4" Casing at rate of 700 gpm @ 2430 psi, 60 rpm, Stand back 1 stand every 30 min. 01:15 03:15 2.00 SURFAC DRILL TRIP P 2,827.0 1,022.0 POOH f/2,827'to 1,022'(Tight @ 1,067' &1,056'),Monitor well-Static. 03:15 03:45 0.50 SURFAC DRILL CIRC P 1,022.0 1,022.0 Circ Btm up at rate of 500 gpm @ 1140 psi. 03:45 04:45 1.00 SURFAC DRILL TRIP P 1,022.0 75.0 Continue to POOH to HWDP,Monitor well-Static,Stand back HWDP&Flex Collars. 04:45 07:15 2.50 SURFAC DRILL PULD P 75.0 0.0 PJSM, Lay down BHA-UBHO, HCIM, Antenna sub, Index sub, Break bit, Lay down Stab&Mud motor,Clean&Clear rig floor. 07:15 08:45 1.50 SURFAC CASING RURD P 0.0 PJSM, Rig to run 10-3/4"csging,Static mud losses 2.5 BPH while rigging up. 08:45 13:00 4.25 SURFAC CASING RNCS P 0.0 1,206.0 PJSM, Run 10-3/4"casing shoe track, Check same,RIH to 1206'(Work thru tight spots @ 284',450'). 13:00 13:30 0.50 SURFAC CASING CIRC P 1,206.0 1,206.0 Circ btm's up(Had mild packing off- then freed up),Stage pumps up to 5 bpm ©370 psi,Had full returns. 13:30 14:45 1.25 SURFAC CASING RNCS P 1,206.0 2,162.0 Continue to run 10-3/4"casing to 2162' with no problems. 14:45 15:30 0.75 SURFAC CASING CIRC P 2,162.0 2,162.0 Circ btm's up,Stage pumps up to 5 bpm @ 420 psi. 15:30 16:45 1.25 SURFAC CASING RNCS P 2,162.0 3,074.0 Continue to run 10-3/4"casing to 3074' with no problems, Had good displacement while running casing. 16:45 17:30 0.75 SURFAC CASING RURD P 3,074.0 3,112.0 Make up Hanger&Landing jt., Land casing @ 3112', Rig up Dowell Cmt head. Latest BOP Test Data Date Comment Page 1/2 Report Printed: 6/1/2012: Security Level: AK Development Drilli_ Daily Drilling Report &Welts CD1-15 01 Report Number: 6 nt CoocoPhillpsa Rig: DOYON 19 Report Date: 5/1/2010 Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 17:30 19:30 2.00 SURFAC CEMENT CIRC P 3,112.0 3,112.0 Circ&Cond. Mud for cement, Stage pumps up to 7 bpm @ 340 psi, Reciprocate casing 30'while circ Up 198K, Dn 150K.. 19:30 00:00 4.50 SURFAC CEMENT CMNT P 3,112.0 3,112.0 PJSM, Pump 75 bbls Nut plug maker mud followed by 35 bbls Biozan viscous spacer with rig,Turn over to Dowell& pump 5 bbls fresh water,Test lines to 3000 psi-OK, Drop Btm Plug, Mix& Pump 50 bbls 10.5 ppg MudPUSH II at rate of 6.0 bpm @ 175 psi, Followed by 468.0 bbls(582 sxs) 10.7 ppg ARCTICSET Lite lead cement at rate of 6.4 bpm @ 160 psi, Followed by 61.4 bbls(297 sxs) 15.8 ppg Class"G"Tail cement at rate of 4.7 bpm @ 150 psi, Shut down, Drop Top Plug, Displace cement w/20 bbls fresh water&271.4 bbls 9.9 ppg mud at rate of 7.0 bpm @ 350 to 840 psi, Slowed rate to 3 bpm @ 620 psi for last 10 bbls, Bump plug w/ 1200 psi, Had full circ thru out job, Had 229 bbls good cement to surface,C.I.P. @ 22:15 hrs 5/1/10. Mud Check Data YP Calc Gel(10s) Gel(10m) Gel(30m) HTHP Filt Density Temp Solids,Corr. Type Depth(ftKB) Dens(Ib/gal) 'Vis(s/qt) PV Calc(cp) (Ibf/100ft2) (Ibf/100f0) (Ibf/100fr) (lbf/100ft2) MBT(lb/bbl) (mL/30min) pH {"F) (%) 3,122.0 10.00 300 44.0 124.0 86.0 98.0 109.000 32.5 9.0 63.0 Wellbores Wellbore Name Wellbore API/UWI CD1-15 501032061900 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date , CONDI 24 36.0 114.0 3/27/2004 3/27/2004 SURFAC 13 1/2 36.0 3,122.0 4/28/2010 4/30/2010 INTRM1 9 7/8 3,122.0 20,700.0 5/4/2010 5/12/2010 Casing Strings String OD String Wt Casing Description Run Date (in) Obs/ft) String Grade Set Depth(ftKB)- Comment SURFACE 5/1/2010 10 3/4 45.50 L-80 3,112.2 Rig&ran total of 74 jts, 10-3/4",45.5#, L-80, BTC casing, Configured of 10-3/4"Sliver Bullet Shoe, 2 jt, 10-3/4"Weatherford Float collar,follow by 72 jts 10-3/4"casing, Installed manule Hanger&Landed @ 3,112.21', Had tight spots @ 284'&450',Circ btm's up @ 1206'&2162', Had good displacement while RIH. Cement Surface Casing Cement-Started @ 5/1/2010 Type Wellbore Cemented String Cement Evaluation Results casing CD1-15 SURFACE,3,112.2ftKB Stg No. Description Top(ftKB) Bottom(ftKB) Q(end)(bb1/... P(final)(psi) Surface Casing Cement 35.8 3,112.2 5 840.0 I Fluid Class Amount(sacks) V(bbl) Density(Ib/gal),- Yield(ft'/sack) Est Top(ftKB) Est Btm(ftKB) Lead Cement G 582 10.70 4.51 35.8 2,622.0 Tail Cement G 297 15.80 1.16 2,622.0 3,112.0 Page 2/2 Report Printed: 6/1/2012 Casing OR Tubing OR Drilling Detail Well: CD1-15 7 5/8"29.7# L-80 BTCM Casing Date: 5/21/2010 ConocoPhillips Rig: Doyon 19 Alaska.Inc. Depth Jt Number Joints Well Equipment Description and Comments . Length Tops Pagel F 4+ F L Top of String or Top of Flange .. .............. Rig floor to lower lockdown screws 33.50 Jts 345 to 484 140 Jts 7 5/8" 29.7# L-80 BTCM Casing 5838.55 33.50 TAM Port Collar 2.08 5872.05 Jts 244 to 344 101 Jts 7 5/8" 29.7# L-80 BTCM Casing 4195.47 5874.13 Halliburton Stage Collar 2.38 10069.60 Jts 4 to 243 240 Jts 7 5/8" 29.7# L-80 BTCM Casing 10022.63 10071.98 Halliburton Baffle Collar 1.36 20094.61 Jts 3 to 3 1 Jts 7 5/8" 29.7# L-80 BTCM Casing 40.44 20095.97 Halliburton Float Collar w/ By-pass baffle on top 1.01 20136.41 Jts 1 to 2 2 Jts 7 5/8" 29.7# L-80 BTCM Casing 85.39 20137.42 Silver Bullet Float Shoe 2.10 20222.81 Bottom of Shoe @ 20224.91 20224.91 20224.91 500 jts in pipe shed - 485 to run - Last 10 jts stay out 20224.91 20224.91 10 3/4" Shoe 3,112' MD 20224.91 9 7/8" Hole TD @ 20,700' MD - 6515' TVD 20224.91 7 5/8" Shoe @ 20,224.91' MD - 6404' TVD 20224.91 20224.91 20224.91 1 Straight blade centralizer on jt. # 1 20224.91 1 Hydro Form centralizer on jts #2 thru # 75 20224.91 1 EZ Glider centralizer on jts # 76 thru # 230 20224.91 1 Hydro Form centralizer on jt # 243 - 10' below SC w/ stop ring 20224.91 1 Hydro Form centralizer on jts # 244 thru # 268 20224.91 1 Straight blade centralizer on jts # 268 thru # 272 20224.91 1 Straight blade centralizer on jts # 344 - 10 ' below TAM PC w/ SR 20224.91 Straight blade centralizers on jts # 345 thru # 372 20224.91 Straight blade centralizers on jts# 420, 421, 422,424,426,& 428 20224.91 1 LoTorque centralizer on Jts # 429 thru # 461 20224.91 Straight blade centralizers every other jt f/# 465 thru # 483 20224.91 20224.91 Hydro Form - 100 EZ Guilder - 155 LoTorq - 33 Straight blade - 50 20224.91 20224.91 Remarks: Casing Cut at Joint#484 Cemented all Three Stages- Installed Pack Off Up Wt 395 K Set on Emergency Slips- 150K Tension Dn Wt 140 K Block Wt 70 K Supervisors:Fred Herbert/Jeff Browning ' ! 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N i-• °i — in u) Q- _c -0 a) t o W . 0 » a) O 2 c N .N to •L - 1 c o I o E fn ' .. m 0 0 0 0) in U L j J E o o o C F N Y c a) Z �,05 cy, � wv = � 32if1SS3?!d E 6 I W U Security Level: AK Development Daily Drilling Report &Well $ CD1-15 CcxtocQPhil)ips Report Number: 24 Rig: DOYON 19 Report Date: 5/19/2010 AFE Type Network/ID# i Total AFE+Sup 10280349 13,599,998.00 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-15 Development ALPINE 21.44 24.0 0.00 20,700.0 20,700.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 5,017.26 1.462,589.97 164,415.26 6,938,547.97 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/26/2010 4/29/2010 43.30 38.49 4.81 6/3/2010 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) SURFACE, 3,112.2ftKB Ops and Depth @ Morning Report 24hr Forecast Hold PJSM for 2nd stage cement job Cement Casing-N/D BOPE-Cut casing-N/U BOPE-Cement Casing 3rd Stage Last 24hr Summary Continue Working Casing on Bridge @ 20,223'MD at Various Pump Rates w/Multiple Partial Pack Off Events-L/D Franks Tool&Pull the Mouse Hole-R/U Scaffolding for Working Cement Ops 12'Above the Rig Floor-Establish Circulation Through the Cement Head&Record Base Line Pressures General Remarks Weather Head Count No Accidents -No Splills 27°,WC 12°, Overcast,Wind ENE @ 23 Mph 51.0 Supervisor Title Fred Herbert, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer • ;Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P T X. Trip'Code Trbl Class. (ftKB) (ftKB) Operation 00:00 12:00 12.00 INTRM1 CASING RNCS T Hole Shale 20,223.0 20,223.0 Attempt to Move Casing Past Bridge- Conditions Stage Pumps Up f/.5 to 5 BPM-Set Down to Block Wt. (75K indicated)and Pulled Up to 430K Indicated Numerous Times-Hole Partially Packed Off Several Times Above 3.5 BPM-Able to Reduce Pump Rate to 0- 1/2 BPM and Slowly Return to Full Rate(5 BPM)- Pack Off Occurred Most Frequently While Pulling Up Near the Top of the Stoke-Maintained Full Circulation While Sitting on Bottom @ 20,223'MD Latest BOP Test Data Date': Comment 5/16/2010 Tested Annular to 250&2500 psi-All other components to 250&3500 psi-Witness of test waived by B. Noble AOGCC Page 1/3 Report Printed: 6/4/2012. Security Level: AK Development Q�riill� Daily Drilling Report &Welts ., CD1-15 cc�moeoe7►iuips Report Number: 24 Rig: DOYON 19 Report Date: 5/19/2010 fkTime Log --� Start End Dur Time Depth Start Depth End Time Time (hrs). Phase Op Code Activity Code PTX Trbl Code Trbl Class. (ftKB) (ftKB) Operation 12:00 19:30 7.50 INTRM1 CASING RNCS T Hole Shale 20,223.0 20,223.0 Continue to Attempt to Move Casing Conditions Past Bridge With and Without Pumps- Stage Pumps Up f/.5 to 5 BPM-Set Down to Block Wt.(75K indicated)and Pulled Up to 430K Indicated Numerous Times-Hole Partially Packed Off Several Times Above 3.5 BPM-Able to Reduce Pump Rate to 0-1/2 BPM and Slowly Return to Full Rate(5 BPM)- Average Pressure at Each Pack Off Event 1050 Psi @ 1 BPM-Pack Off Occurred Most Frequently While Pulling Up Near the Top of The Stoke- Maintained Full Circulation While Sitting on Bottom @ 20,223'MD Base Line Rates v. Pressures Through Franks Tool: 0.8 BPM 390 Psi 1.5 BPM 410 Psi 2.0 BPM 430 Psi 2.5 BPM 480 Psi 3.0 BPM 520 Psi 3.5 BPM 570 Psi 4.0 BPM 650 Psi 19:30 19:45 0.25 INTRM1 CASING SFTY T Hole Shale 20,223.0 20,223.0 PJSM on LID the Mouse Hole and Conditions Franks Tool 19:45 20:15 0.50 INTRM1 CASING PULD T Hole Shale 20,223.0 20,223.0 LID Franks Tool and Mouse Hole Conditions 20:15 21:30 1.25 INTRM1 CASING OTHR T Hole Shale 20,223.0 20,223.0 PJSM-P/U and R/U Scaffolding for Conditions Installing Cement Head at Height 21:30 22:15 0.75 INTRM1 CEMENT PULD P 20,223.0 20,223.0 P/U Cross Over,Cement Head and Valves 22:15 00:00 1.75 INTRM1 CEMENT CIRC P 20,223.0 20,223.0 Establish Circulation-Stage Pumps Up f/1.5 BPM @ 280 Psi t/4 BPM @ 530 Psi • Base Line Rate v. Pressure Through Cement Head: 1.3 BPM 280 Psi 2.0 BPM 380 Psi 3.0 BPM 450 Psi 3.5 BPM 500 Psi 4.0 BPM 530 Psi Wait for Crew Change Prior to Beginning Cement Job Mud Check Data YP Calc Gel(los) Gel(10m) Gel(30m) HTHP Filt Density Temp Solids,Corr. Type Depth(ftKB) Dens(lb/gal) Vis(sigh PV Calc(cp) (Ibf/100fi2) (Ibf1100ft) (Ibf/100fl2) (Ibf/100ft') MBT(Ib/bbl) (mU30min) pH (°F) (%) Glydril 20,700.0 10.35 42 11.0 17.0 7.0 8.0 9.000 175.3 9.3 11.0 Glydril 20,700.0 10.40 41 10.0 17.0 7.0 8.0 9.000 168.2 6.3 9.3 11.0 Page 2/3 Report Printed: 6/4/2012 Security Level: AK Development " ' ih, Daily Drilling Report a , s 4; CD1-15 CanceoPhiilips Report Number: 24 Rig: DOYON 19 Report Date: 5/19/2010 Injection Fluid :,i' I Fluid Source From Lease(bbl) Destination Vendor I Manifest Number Note Drilling Mud WBM CD1-15 350.0 CD1-19 339622 Hard Line f/Ball Mill 'Drilling Mud WBM CD1-15 310.0 CD1-19 339621 Hard Line f/Ball Mill Wellbores A1111,1 Wellbore Name Wellbore API/UWI CD1-15 501032061900 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 24 36.0 114.0 3/27/2004 3/27/2004 SURFAC 13 1/2 36.0 3,122.0 4/28/2010 4/30/2010 INTRM1 9 7/8 3,122.0 20,700.0 5/4/2010 5/12/2010 1Survey Data I MD(ftKB) Incl(°) Azm(") ND(ftKB) I VS(ft) NS(ft) EW(ft) DLS(°/100ft) 20,700.00 76.69 78.95 6,514.601 18,492.07 3,777.44 18,103.93 0.00 Page 3/3 Report Printed: 6/4/2012 Security Level: AK Development Daily Drilling Report &W I , ,k14:b,11 CD1-15 ConocoPhillips Report Number: 25 Rig: DOYON 19 Report Date: 5/20/2010 AFE Type Network/ID# Total AFE+Sup 10280349 13,599,998.00 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-15 Development ALPINE 22.44 25.0 0.00 20,700.0 20,700.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,989.92 1,466,579.89 1,480,969.12 8,419,517.09 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/26/2010 4/29/2010 43.30 39.49 3.81 6/4/2010 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) INTERMEDIATE,20,224.9ftKB Ops and Depth @ Morning Report 24hr Forecast RIH w/TAM Stage Tools @—2,700'MD Cement 3rd Stage Through TAM Collar-Cut Casing-L/D 5"DP Last 24hr Summary Cement 7 5/8"Casing Shoe w/63 Bbls of Class G Cement Displaced w/Rig Pumps-CIP @ 0510-Open HES Cementer-Cement Second Stage w/41.6 Bbls of 15.8 PPG Class G Cement Displaced w/Rig Pumps-CIP @ 0805-WOC-Cut Casing at the Bell Nipple-Change Saver Sub,Grabgbers, Bales& Elevators-Cut 7 5/8"Casing at Bell Nipple General Remarks Weather Head Count No Accidents -No Splills 26°,WC 17°, Overcast,Wind ENE @ 9 Mph 50.0 Supervisor Title Fred Herbert, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Log Start. End Dur Time Depth Start Depth End "µ!ii4'Vtlpup Time Time (firs) Phase Op Code= Activity Code P-T-X Trbl Code Trbl Class (ftKB) (ftKB) Operation 00:00 00:15 0.25 INTRM1 CEMENT SFTY P 20,225.0 20,225.0 PJSM-Cementing 7 5/8"Shoe 00:15 01:45 1.50 INTRM1 CEMENT CMNT P 20,225.0 20,225.0 Cement Casing Shoe as Follows: Pump 5 Bbls of CW100, Pressure Test Surface Lines t/3750 Psi, Pump 35 Bbls of CW100 @ 3.2 BPM w/500 Psi, Pump 43 Bbls of 11.5 PPG Mud Push @ 3.6 BPM w/510 Psi, Drop Bottom Plug, Pump Remaining 7 Bbls of Mud Push at Same Rate/Pressure, Load the Closing Plug, Pump 63 Bbls of 15.8 PPG Class G Cement w/Additives©3.8 BPM w/400 Psi, Drop Closing Plug, Pump 20 Bbls of Fresh Water @ 3.7 BPM w/170 Psi 01:45 05:30 3.75 INTRMI CEMENT DISP P 20,225.0 20,225.0 Displace Cement: Initial Rate/Pressure 4 BPM/200 Psi, Final Rate/Pressure 3 BPM/780 Psi-Pumped Plugs @ 9012 Strokes, Held 1280 Psi on Floats f/5 Minutes-Released Pressure and Checked Floats(Good)-CIP @ 0510 Hrs 05:30 06:00 0.50 INTRM1 CEMENT CIRC P 20,225.0 20,225.0 Shift Open HES Stage Collar @ 3250 Psi-Establish Circulation and Record Rates/Pressures Through Stage Collar as Follows: 4 BPM 270 Psi 5 BPM 320 Psi 6 BPM 370 Psi 7 BPM 440 Psi 06:00 06:15 0.25 INTRM1 CEMENT SFTY P 20,225.0 20,225.0 PJSM on Second Stage Cement Latest BOP Test Data Date Comment 5/16/2010 Tested Annular to 250&2500 psi-All other components to 250&3500 psi-Witness of test waived by B. Noble AOGCC Page 1/3 Report Printed: 6/1/2012 Security Level: AK Development ,-,, I1" Daily Drilling Report .d a 'A3,i. CD1-15 CorxKtcot'hillips z Report Number: 25 Rig: DOYON 19 Report Date: 5/20/2010 ;Time Log Start End Dur Time Depth Start r Depth End j Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 06:15 07:15 1.00 INTRM1 CEMENT CMNT P 20,225.0 20,225.0 Cement K3 as Follows: Pumped 33 Bbls of 11.5 PPG Mud Push @ 4 BPM w/250 Psi, Pumped 41.6 Bbls of 15.8 PPG Class G Cement w/Additives @ 5 BPM w/305 Psi,Dropped Stage Collar Closing Plug, Pumped 20 Bbls Fresh Water @ 5.1 BPM w/60 Psi 07:15 08:30 1.25 INTRM1 CEMENT DISP P 20,225.0 20,225.0 Displace Second Stage Cement w/Rig Pumps at the Following Rates/Pressures: Initial 7 BPM/450 Psi, Slowed t/4.0 BPM/300 Psi @ 3500 Strokes, Bumped Plug @ 4429 Strokes, Held 1200 Psi f/5 Minutes 08:30 16:00 7.50 INTRM1 'CEMENT WOC P 20,225.0 20,225.0 Wait on Cement 16:00 17:00 1.00 INTRM1 CEMENT RURD P 20,225.0 20,225.0 R/D Cement Equipment and Scaffold 17:00 18:45 1.75 INTRM1 CASING RURD X Hole Other 20,225.0 20,225.0 Make Preparations to Cut Casing @ Bell Conditions Nipple 18:45 19:00 0.25 INTRM1 CASING 'SFTY T Hole Shale 20,225.0 20,225.0 PJSM on Cutting Casing Conditions 19:00 20:30 1.50 INTRMI CASING CPBO X Hole Shale 20,225.0 20,225.0 Cut 7 5/8"Casing at the Bell Nipple and Conditions N/U Flow Line 20:30 23:00 2.50 INTRMI CASING RURD X 20,225.0 20,225.0 L/D Casing Elevators and Long Bales- Change Saver Sub t/4"XT-39,Grab Heads,Bell Guide-Install Short Bales, 4"Elevators-Service Rig 23:00 23:15 0.25 INTRMI CEMENT SFTY X 0.0 0.0 PJSM on Running TAM Port Collar Tools and Packer 23:15 00:00 0.75 INTRMI CEMENT PULD X 0.0 209.0 P/U TAM Port Collar Shifting Tools,6 Jts 4"XT-39 DP and Baker 7 5/8" Retrievable Packer Mud Check Data I t- _ YP Calc r Gel(10s) Gel(10m) Gel(30m) HTHP Filt Density Temp Solids,Corr. .r .,;r Ibf/100ft') (Ibf/100ft') (Ibf/100W) (IbfflOOft') MBT pH (°F) (%) Type Depth(t€t�H� Dens= (Ib/gal): Vis(s/qt) PV Calc(cps ( (Ib/bbl)> (mL/30min) Glydril 20,700.0 10.35 44 11.0 19.0 8.0 10.0 12.000 175.3 7.1 9.6 11.0 . I Injection Fluid I Fluid Source From Lease(bbl) Destination Vendor Manifest Number Note Drilling Mud WBM CD1-15 100.0 CD1-19 ASRC 339623 Wellbores Wellbore Name 'Wellbore API/UWI CD1-15 501032061900 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 24 36.0 114.0 3/27/2004 3/27/2004 SURFAC 13 1/2 36.0 3,122.0 4/28/2010 4/30/2010 INTRM1 9 7/8 3,122.0, 20,700.0 5/4/2010 5/12/2010 Survey Data MD(ftKB) Incl(°) Azm(°) ND(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/10Oft) 20,700.00 76.69 78.95 6,514.60 18,492.07 3,777.44 18,103.93 0.00 !Casing Strings String OD String Wt , Casing Description Run Date (in) (lbs/ft) String Grade Set Depth(ftKB) Comment INTERMEDIATE 5/20/2010 7 5/8 29.70 L-80 20,224.9 Centralizers; 100 hydroform, 155 EZ Gilder, 33 Lo-torq, and 50 Straight Blade !Cement Intermediate Casing Cement-Started @ 5/20/2010 Type Wellbore Cemented String Cement Evaluation Results casing CD1-15 i INTERMEDIATE, 20,224.9ftKB Page 2/3 Report Printed: 6/1/2012 Security Level: AK Development DrivingDaily Drilling Report BWel ' CD1-15 cc�n4coF'IrtiliipS Report Number: 25 Rig: DOYON 19 Report Date: 5/20/2010 Stg No. Description Top(ftKB) Bottom(ftKB) Q(end)(bbl/... P(final)(psi) 1 Intermediate Casing Cement 18,737.0 20,225.0 4 250.0 Fluid Class Amount(sacks) V(bbl) Density(Ib/gal) Yield(ft'/sack) Est Top(ftKB) Est Btm(EKE) '' Intermediate Cement G 305 63.0 15.80 1.16 18,737.0 20,225.0 Stg No. Description Top(ftKB) Bottom(ftKB) Q(end)(bbl/... P(final)(psi) 2 K3 Sand 8,986.0 10,072.0 5 161.0 I Fluid Class Amount(sacks) V(bbl) Density(lb/gal) Yield(ft'/sack) Est Top(ftKB) Est Btm(ftKB) 'Tail Cement G 200 41.6 15.80 1.16 8,986.0 10,072.0 Stg No. Description Top(ftKB) Bottom(ftKB) Q(end)(bbl/... P(final)(psi) 3 C10 Sand 4,908.0 5,874.1 4 312.0 Fluid Class Amount(sacks) V(bbl) Density(Ib/gal) Yield(ft'/sack) Est Top(ftKB) Est Btm(ftKB) Tail Cement G 184 37.0 15.80 1.16 4,908.0 5,874.0 • Page 3/3 Report Printed: 6/1/2012 Security Level: AK Development Daily Drilling Report ir tsdl w�iia4r 'mRA 1111 ' ,t III aMt{it i�,lwttmpi�rg�p�N{iln,, C� C D 1-15 tllReport Number: 26 CGcoPhillips Rig: DOYON 19 Report Date: 5/21/2010 fr 4.) x 1• AFE;Type Network/ID# Total AFE+Sup v, ;( 00 , 10280349 13,599,998.00 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-15 Development ALPINE 23.44 26.0 0.00 20,700.0 20,700.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,375.66 1,469,955.55 212,012.26 8,631,529.35 Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/26/2010 4/29/2010 43.30 40.49 2.81 6/5/2010 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) WINDOW,20,081.0ftKB Ops and Depth @ Morning Report 24hr Forecast Changing Rams t/3 1/2"X 6"Variables Cut Casing-Set Pack Off-N/U Weil Head-Test Pack Off-L/D 5" DP Last 24hr Summary RIH w/TAM Setting Tools and Packer on 4"DP t/5,866'MD-M/U Pump In Sub Assembly-Circulate Through Stage Collar Staging Pumps Up f/1 to 4 BPM- Cement C10 Sand w/37 Bbls of 15.8 PPG Class G Tail Cement-Close and Release f/TAM Collar-Test t/1,000 Psi-CBU @ 3 BPM-POOH t/209'MD- L/D Packer,6 Jts 4"DP and TAM Setting Tools-M/U Spear and N/D Well Head General Remarks Weather Head Count No Accidents -No Splills 28°,WC 19°, Overcast,Wind E @ 9 Mph 52.0 Supervisor Title Fred Herbert, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Log Start End Our '3. tmti Depth Start Depth End Time Time (firs) .:$1104o'k,.f Vte ;' _' �' TrbI Code Trbl Class (ftKB) (ftKB) Operation 00:00 02:00 2.00 INTRM1 CEMENT PULD X 209.0 209.0 P/U and M/U Pump in Sub,XO/s,TIW's, and Pup Joints-Set Aside for Later Use 02:00 08:30 6.50 INTRM1 CEMENT TRIP X 209.0 5,866.0 RIH w/4"XT-39 DP f/the Shed t/5,866' MD(178 Joints) 08:30 09:30 1.00 INTRM1 CEMENT PRTS X 5,866.0 5,874.0 M/U Pump in Sub Assembly and Engage TAM Port Collar-Test Cups t/500 Psi and Cement Lines and Pump In Sub t/ 3500 Psi 09:30 12:30 3.00 INTRM1 CEMENT CIRC X 5,872.0 5,874.0 Condition Mud-Stage Pumps Up f/1 BPM @ 320 Psi t/4 BPM @ 410 Psi 12:30 12:45 0.25 INTRM1 CEMENT SFTY X 5,874.0 5,874.0 PJSM on 3rd Stage Cement 12:45 13:30 0.75 INTRM1 CEMENT CMNT X 5,874.0 5,874.0 Cement C10 Sand Through TAM Port Collar as Follows: Pump 10 Bbls CW100,21.3 Bbls of 11.5 PPG Mud Push,37 Bbls of 15.8 PPG Class G Cement,and 20 Bbls of Water 13:30 14:00 0.50 INTRM1 CEMENT DISP X 5,874.0 5,874.0 Displace Cement w/39.9 Bbls of 10.4 PPG LSND 14:00 14:30 0.50 INTRM1 CEMENT PRTS X 5,874.0 5,700.0 Close TAM Port Collar-Release and Test t/1000 Psi(Good) 14:30 16:00 1.50 INTRM1 DRILL CIRC X 5,700.0 5,700.0 UD 6 Jts of 4"DP-Shear Ball Seat @ 2630 Psi and CBU @ 3 BPM w/440 Psi 16:00 21:00 5.00 INTRM1 DRILL TRIP X 5,700.0 209.0 POOH on TT f/5,700'MD to 209'MD (172 Jts) 21:00 21:45 0.75 INTRM1 DRILL PULD X 209.0 0.0 OWFF(Static)-UD Packer,6 Stands of 4"DP and TAM Port Collar Setting Tool 21:45 22:15 0.50 INTRM1 DRILL PULD T Hole Shale 0.0 0.0 M/U Casing Spear and Drain Stack and Conditions Casing-Stab Into Casing w/Spear 22:15 22:45 0.50 INTRM1 DRILL PULD X 0.0 0.0 Break Apart and UD Pump in Sub Assy: 10'Pup,TIW X2, Pump In Sub,4 1/2"IF to 4"XT39 Crossovers X2,and 15'Pup 22:45 00:00 1.25 INTRM1 WHDBOP NUND T Hole Shale 0.0 0.0 N/D Riser Surface Lines-Pull Mouse Conditions Hole-Break Wellhead Bolts Latest BOP Test Data Date Comment 5/16/2010 Tested Annular to 250&2500 psi-All other components to 250&3500 psi-Witness of test waived by B. Noble AOGCC Page 1/2 Report Printed: 6/1/20121 I. Security Level: AK Development Jli, Daily Drilling Report i 11 0 � ,:', ,.'-4,,,., 1 C D 1-15 { tips ,Il 4,,o. Report Number: 26 Rig: DOYON 19 Report Date: 5/21/2010 Mud Check Data YP Calc Get(10s), Gel(10m) Gel(30m); HTHP Filt Density Temp Solids,Corr. Type Depth)ftKB) Dens(Ib/gal) ,Vis(s/qt) PV Calc(cp) (Ibf/100ft') (Ib1/100fe) (Ibf/100fV), (IbfI100R2) MET(Ib/bbl) (mL/30min) pH (°F) (%) Giydril 20,700.0 10.35 44 11.0 19.0 8.0 10.0 12.000 175.3 7.1 9.6 11.0 Injection Fluid L._ Fluid Source From Lease(bbl) Destination Vendor Manifest Number Note Drilling Mud WBM CD1-15 450.0 CD1-19 ASRC 339624 Wellbores Wellbore Name Wellbore API/UWI CD1-15 501032061900 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start'.Date End Date CONDI 24 36.0 114.0 3/27/2004 3/27/2004 SURFAC 13 1/2 36.0 3,122.0 4/28/2010 4/30/2010 INTRM1 9 7/8 3,122.0 20,700.0 5/4/2010 5/12/2010 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) I VS(ft) NS(ft) : EW(ft) DLS(°1100ft) 20,700.00 76.69 78.95 6,514.601 18,492.07 3,777.44 18,103.93 0.00 Page 2/2 Report Printed: 6/1/2012 • To:t and Shannon, You have requested tp dispose of "new-product" clean up fluids from the routine mixing of mud and cement. at Alpine as well as the clean up fluids resulting from cleaning out the tanks at the mud plant in preparation for using oil base mud. • The Commission had previously approved disposing of the 'new product" clean up fluids via annular disposal at CD 1 pad. Due to the geological setting at Alpine, Class 1 and Class 2 disposal options are limited. Phillips' prededessor, ARCO, had established the limitation of disposal options to the Commission's saris;action. and .annular disposal was approved as Che practical and environmental alternative. In these requests the waste fluids are no different than previously approved and are the result of the ,ongoing development activities at Alpine. • The Commissioners have authoried me to send you this message.- By copy of this • email, Phillips is authorized to dispose of clan up fluids as described in your email. • Please call with any questions. Tom Maunder, PE Sr. Petroleum Engineer ACGCC ALP Env Coord +urate: > Dear ISL•. Maunder, > As noted in the attached email, Tom Manson previously requested > authorization to dispose of new-product clean un fluids such as cement > rinsate, and mud and brine pit rinses E:rrxif mixing operations via annular > injection in permittedwells at the Alpine CD2 Drill Site. As noted below, 1-OGCC approved such disposal at the CD1 Drill Site in 1999, based on the > integral relationship of the mud mixing facility and the on-site drilling > operation- > > Phillips would like to continuing pursuing this request. Significant clean • out of tanks at the •mud mixing facility. must Occur In preparation for the > temporary use of, oil based mud products at Alpine in the- coming months. s The availability of annular disposal as an option for tank rinse fluids and > similar wastes would greatly facilitate this. process. (Typically, routine > rinses are beneficially reused, however, there is a concern about the > potential quantity of fluid that 'could be generated during this large scale > clean up process. ) > Tanks a.-, the mud mixing facility xray contain either new and used mud > products. Though rinses in contact with used products may be injected in > the permitted class II disposal. well (CD19A) , rinses ..of new products would > potentially be routed to the class. I disposal well (Inn-02) , where there is > a difficulty managing solids content. The class I well is a critical > lifeline fat facility infrastructure, being the disposal location for all > domestic effluent, and it is a priority to prevent any compromise to this > disposal facility. Annular disposal presents a preferred waste management > alternative in this case. • ( > Thank you very much for your consideration of this request. Please do not > hesitate to contact Yee or My alternate via email or phone at (9071 6170-4200 > if you have questions or- need additional information. > Shannon Donnelly > spine Field Environmental Coordinator > (907) 670-4200 • --- Forwarded by ALP Env Coord/PPCO on 11/02/01 12:50 PM > ALP Env Coord > 08/31/01 12:45 PM > To: to;;, naunderBadmin.srate,alc.us cc: Subject: Reouest to Inject Cement Ri.nsate at CD2 > > Dear Mr. Maunder, > Injection of cement rinsate and clean-up fluids from mud and brine mixing > operations at: the Alpine mud plant facility into approved annular disposal > operations was granted by the Alaska Oil And Gas Conservation Commission > (AGGCC) in the March 17,• 1999 letter from AOGCC to Doug ;Chester. of ARCO > Alaska, Inc. , now Phillips Alaska, Inc. {PAI) . Ih approval was granted to > PAl specifically for Alpine Drill Site CDL and authorized volumes up. to > 35,000 barrels through the annular space. > > PAl request that this approval be extended to drilling operations at Alpine. > Drill Site CD2. Cement mixing operations for setting surface conductors > will he taking place at the Grind and Inject facility which is currently > attached to .the drilling rig at -CD2. Upon c_4rrplettnn of the cementing in > of the conductors, the lines and mixing tank will have to be rinsed and the • rinsate disposed of. PAI request approval to inject this rinsate, and > other clean-up fro_,, the mud and brine mixing operations, into the annual > space of approved wells located at Drill Site CD2. >. I1 you have any questions please contact me at 670-4200. > > Tom Manson > Aline Field Environmental Compliance tornjnaunder.vct . CD1-02 Attachment Casing Detail Well: CD1-02 9 5/8"Surface Casing Date: 11/9/2000 b" PHILLIPS PAlaskaS PETROLEUM, Inc. A Subsidiary of PHILLIMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.78 FMC Gen V Hanger 2.40 36.78 Jts 3 to 58 56 Jts 9-5/8" 36#J-55 BTC Csg 2361.84 39.18 Davis Lynch Float Collar 1.54 2401.02 Jts 1 to 2 2 Jts 9-5/8" 36#J-55 BTC Csg 76.36 2402.56 Davis Lynch Float Shoe 1.75 2478.92 2480.67 TD 12 1/4" Surface Hole 2491.00 RUN TOTAL 34 BOWSPRING CENTRALIZERS- 1 per jt on Jt#1 -#12 (On stop rings of Jt#1, #2) and over collars on jts.14,16,18,20,22,24,26,28,30 32,34,36,38,40,42,44,46,48,50,52,54,56 Use Best-o-Life 2000 pipe dope Remarks: Up Wt- 150k Dn Wt- 130k Block Wt-70k Supervisor. DON MICKEY Security Level: AK Development Daily Drilling Report „c.,. CD1-02 Cc�moc4Phillips Report Number: 2 RLmIcn Rig: DOYON 19 Report Date: 11/10/2000 AFE Type Network/ID# Total AFE+Sup 998C15 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-02 Development ALPINE 3.00 3.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 11/8/2000 11/8/2000 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) SURFACE,2,480.7ftKB Ops and Depth @ Morning Report 24hr Forecast PREP TO PERFORM LEAK OFF TEST DRILL 8 1/2"HOLE Last 24hr Summary General Remarks Weather Head Count Supervisor Title D.MICKEY, Supervisor Supervisor Time Log Start End Dur Time - Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 00:00 02:00 2.00 SURFAC PULD P 2,491.0 2,491.0 LID 12 1/4""BHA 02:00 03:30 1.50 SURFAC P 2,491.0 2,491.0 R/U to run 9 5/8""csg-Held PJSM 03:30 07:30 4.00 SURFAC CASE RUNC P 2,491.0 2,491.0 Ran 58 jts.9 5/8""36#J-55 BTC csg w/ shoe to 2480.67'FC @ 2401' 07:30 08:00 0.50 SURFAC P 2,491.0 2,491.0 L/D fill up tool-blow down TD-M/U cmt head 08:00 09:30 1.50 SURFAC CIRC P 2,491.0 2,491.0 Circ and condition mud for cmt job-Held PJSM 09:30 12:00 2.50 SURFAC CEMENT PUMP P 2,491.0 2,491.0 Cmt 9 5/8""csg-pumped 40 bbls vis water spacer w/nut plug-50 bbls Arco spacer @ 10.5 ppg-369 bbls lead slurrry @ 10.7 ppg-observed nut plug ©shakers-switch to tail slurry- pumped 48 bbls tail @ 15.8 ppg-drop top plug-displace w/20 bbls water& 167 bbls mud-bumped plug-floats held -CIP @ 11:30 hrs.-full returns-70 bbls cmt to surface 12:00 14:00 2.00 SURFAC P 2,491.0 2,491.0 Clear floor of csg equip-L/D cmt head& landing jt.-flush 20""hydril 14:00 15:30 1.50 SURFAC NUND P 2,491.0 2,491.0 N/D 20""Hydril-remove diverter&flow line 15:30 16:30 1.00 INTRM1 NUND P 2,491.0 2,491.0 N/U FMC 11""5K Unihead assembly- test seals to 1000 psi 16:30 19:00 2.50 INTRM1 NUND P 2,491.0 2,491.0 N/U BOPE 19:00 00:00 5.00 INTRM1 WELCTL BOPE P 2,491.0 2,491.0 Test BOPE-Hydril-250/2500 psi-rams and valves 250/3500 psi-witness of test waived by John Crisp AOGCC Wellbores Wellbore Name Wellbore API/UWI 001-02 501032035400 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date 18 0.0 114.0 11/8/2000 1/1/2000 11 5/8 114.0 2,491.0 11/8/2000 9 2,491.0 8,217.0 11/15/2000 8 1/8 8,217.0 12,773.0 11/26/2000 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) I DLS(°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.001 0.00 Latest BOP Test Data Date Comment Page 1/1 Report Printed: 6/4/2012 w^ --"- -' c:o y a,0.o. �g°i000000000 ge000 oo0000000000 W v Q y OOOOONOetOhhlDhN ° C -000OOOOOOCAO) 0200 Y ('(_ KO 100 . 001t) OMONMto1D000Nen 34700 en to to to inlptotoef et et et W < a r N Tr 0 0 r r r r r r N N N /- N N N N Na N N N N N N N N N H J = w ~ co (0 (0 (0 (0 (0 (0 (0 (0 (0 (0 (0 (0 W a Cl) w N u) N N yY �CYYY .YY _CY _C _NL _NL ❑ _C Y Y _C r r r r r .1 r r r r r r Qa Y .)C O +J r r r ren N N W 0 N N N N N M N h W I��= Uf' ONet10000NetOD00ONetOD00ON rn T- r r r N N N N N M M H CL a Z -J N ,n z c c c c c c c c c c .c c .c .c c CO J U o f z 'E E E E E 'E "E E 'E 'E E E E a 2N z w0 I- () 00000000000000 0 ouiolrio a.-` v iQ � N c7 etlnCOt� tO6r rNNc) Q 0) OD in _ m I- 0 w N in ._ ._ ._ ._ ._ - 0 �fa,es, 0 0 0 0 0 0 0 0 0 0 0 0 a o o o C O O O O o 0 0 0 Q K 0 0 0 c0 Co m' M N CO N N n Q) N It) as 2 O) 0 00 et N r O O 00 00 CO - 0. r N M CO IA O t0 OD CO h h j ti t. 10 10 O 10 to CO to O O Q ___1___L__1__J___1___L__ __ __J___1___L__ __ __J___1___L__1__1__J___L___L__1 y L_ __L__1__J___1___1__1__1__J___1___L__J Q U) 0 LL 0 L L 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O F r1• V 01 •et41COnCCltoOrlV Mato ee r r r r r r Q Y � Q W W rn 2 c c c c c c c c c c .- O Jw - '- '- '- '- I- cel- z E E E E E E E E E E E zz o o 1- 0 0 0 0 0 0 0 0 0 0 () W H 2 y o r N M4 1C) CD ti 00 d7 r0 O Z ❑ ❑ I 1 I I 2 > w T H H M 4) 01 V 'l. .�- Q w 67 Z co a 4 r .0 .0 N N C) so M W + r C y I- 2 - II II U H a)F � L.. 0 F W N Z SO o a) N • r) 0. m l I I-—U. 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N H 0 Z U L) 0 N N N N N r r r r r co 2 — y 321f1SS31d (Li Q H 0 z Casing Detail Well: CDI-02 ,W� PHILLIPS Alaska, Inc. 7"Intermediate Casinq Date: 11/14/2000 A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.42 FMC 11" X 7" Hanger 2.02 34.42 Jts 3 to 201 199 Jts 7" 26# L-80 BTCM Csg 8078.78 36.44 7" Davis Lynch Float Collar 1.41 8115.22 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 82.81 8116.63 7" Davis Lynch Float Shoe 1.70 8199.44 8201.14 TD 8 1/2" hole 8217.00 1 straight blade centralizer per jt #1 -#18 1 straight blade centralizer on every other jt. F/# 147 to# 197 Total -46 centralizers 209 jts. In pipe shed - 201 jts. To run Jts#34, 50,97,115,206,207,208,209 -STAY OUT Use Best-o-Life 2000 pipe dope Remarks: Up Wt-260 k Dn Wt-170 k Supervisor: Don Mickey Security Level: AK Development Daily Drilling Report CD1-02 CcmocQlPhitlps Report Number: 8 Rig: DOYON 19 Report Date: 11/16/2000 AFE Type Network/ID tt Total AFE+Sup 998C15 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-02 Development ALPINE 9.00 9.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 11/8/2000 11/8/2000 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) PRODUCTION,8,201.1ftKB Ops and Depth @ Morning Report 24hr Forecast RIH W/6 1/8""BHA-P/U 3 1/2""DP TEST CSG-DRILL 6 1/8"HOLE Last 24hr Summary General Remarks Weather Head Count Supervisor Title D.MICKEY/D.CUNNINGHAM, Supervisor Supervisor Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code `P-T-X Trbl Code TrblClass. (ftKB) (ftKB) Operation 00:00 03:00 3.00 INTRM1 CASE RUNG P 8,217.0 8,217.0 PJSM-Run 7""26#L-80 BTCM- Baker-Loc shoe track to 2480' 03:00 03:30 0.50 INTRM1 CIRC P 8,217.0 8,217.0 Circ casing volume @ 9 5/8"shoe 03:30 06:00 2.50 INTRM1 CASE RUNG P 8,217.0 8,217.0 Continue running 7"csg to 5149'(131 jts.) 06:00 06:30 0.50 INTRM1 CIRC P 8,217.0 8,217.0 Circ btms up 06:30 09:00 2.50 INTRM1 CASE RUNG P 8,217.0 8,217.0 Continue RIH w/7""csg to 8201'(201 jts.total)w/FC @ 8115' 09:00 10:00 1.00 INTRMI CIRC P 8,217.0 8,217.0 Circ&condition mud for cmt job 10:00 11:00 1.00 INTRM1 P 8,217.0 8,217.0 UD fill up tool-blow down TD-M/U crnt head-Circ.-PJSM 11:00 12:30 1.50 INTRM1 CEMENT PUMP P 8,217.0 8,217.0 Cement 7""csg-Pump 5 bbls Arco Wash-test lines to 3500 psi-pump 15 bbls Arco wash-50 bbls Arco spacer @ 12.5 ppg-drop btm plug-pumped 22 bbls.G w/addivites @ 15.8 ppg-drop top plug-displace w/9.9 ppg mud- bumped plug w/1060 psi-floats held Cip @ 12:30 hrs. 12:30 13:30 1.00 INTRMI P 8,217.0 8,217.0 UD cmt head landing jt.elevators and long bales 13:30 14:30 1.00 INTRM1 P 8,217.0 8,217.0 Pull thin wall WB-flash stack-set 7'X 9 5/8"packoff-test to 5000 psi 14:30 15:30 1.00 INTRM1 WELCTL BOPE P 8,217.0 8,217.0 Change top pipe rams to 3 1/2""X 6"" VBR 15:30 16:00 0.50 INTRM1 P 8,217.0 8,217.0 C/O top drive to 3 1/2"" 16:00 20:30 4.50 INTRM1 WELCTL BOPE P 8,217.0 8,217.0 Set test plug-test BOPE-Hydril- 250/2500-Rams&all valves 250/3500- Witnessing of test waived by Jeff Jones AOGCC-pull test plug-set WB 20:30 21:00 0.50 PROD P 8,217.0 8,217.0 Install bales elevators-prep to P/U 3 1/2""DP 21:00 22:00 1.00 PROD PULD P 8,217.0 8,217.0 P/U 750'31/2""DP f/shed-rack in derrick 22:00 00:00 2.00 PROD PULD P 8,217.0 8,217.0 M/U BHA#4-RIH picking up 3 1/2""DP ,f/shed Wellbores Wellbore Name Wellbore AP WWI CD1-02 501032035400 Latest BOP Test Data — — Date Comment Page 1/2 Report Printed: 6/4/2012 XVIII Security Level: AK Development 000 °: .. Daily Drilling Report C ith Report Number: 8 Rig: DOYON 19 Report Date: 11/16/2000 Section Size(in) Act Top(ftKB), Act.Btm(ftKB). Start Date End Date 18 0.0 114.0 11/8/2000 1/1/2000 11 5/8 114.0 2,491.0 11/8/2000 9 2,491.0 8,217.0 11/15/2000 8 1/8 8,217.0 12,773.0 11/26/2000 Survey Data MD(EKE) Incl(°) Azm(°) TVD(EKE) VS(ft) NS(ft) EW(ft) j' DLS(°/100ft) 0.00 0.00 0.00 0.00 0.001 0.00 0.001 0.00 Page 2/2 Report Printed: 6/4/2012 W 0 Z C 0 a w . y • rcn C re y W ..... o a y 0. O -Y CI I- wO z O w w a o . H J Np ______r__,r__y________rt__t__y_____-r-_Y.__y___y___�___r__�__y___y LU a I- ODw LU w N Q a w 4a lc K 4-' LU CO h0 F- CI a Z .....1" ,i 2 C C C C C C C C C C .0 C ,C .0 C W rii ya � zEEEEEEEEEEEEEEEa _ V � � z ° 01- 000 0000000000ao as N 0 = 0s-N M � InCOh00aiOLn882 0 h Q N N M -II) ) W � r---r---r---r---r---r--r---r--�---i---r---r---------r---r---r--------r--r---r-----�- �----r------r---r--r---r--T--i---r--r---r 0: . 0 to y y N N t/1 CO N N N In h to y In u) N y .N .c .N .co l a 7 .y N J Ls a.G.fl.n.a,O.G.O..a.>Z.o.n.0.0.o.0.. w C1,n.O.n.C.G.C.Cl.,0.0.n. I F, O A 00 of o O r- r.. 00 e- tD - t0 ID CO ID a LC) 0 0) 0) 0) 0) d' ma) .:t 0 a � 0If) NMNN00) N- Ne- 000N- D z (0 . I() MMNNN = . a- NC) ID DCD � OtDtDCDCDIDIAII) _ � et � etetd' etNt a ___L___L__1__J___J___L___L__1__J___1___L__1__1__J___L__L__1__l__J___L___L__1 yQ 0 Q II m 0 U. IDOICIOICCD14) OIDOOOMOOO OC mOO <- e. NNMMtterOlprDtDnr- 00 Q Oi W a W y C C C C C C C C C C .0 O k- C I-x 00Z E E E E E E E E E E Lii z u. -1 H 0 C. 0 0 0 0 0 0 0 0 O I- N N N 0 e- N M � Ln co(O ICO O c) Z 0 0 0 N 2 >. U 1- 1- m o C) — w Oi, � a 2 ..% H I) Q. d — I _ g C) CO CO n CD s z D + o o Di C — Y W D r c u n c) g_ > Zen V 0 I1 !:E — ILI Z ? W17) JZ LL ~ Z— 2 wz J -N • F OQ gU I- CD Lu 0 11 II — N O = CD L .0 • 1 y 1. 0 C ISN c Q LCV U e- 4) a) W F- X0 d 4 }O. I ,x rx z L9 iv 03 2 I- CD do O c c f>0 0 11 — m2 Z " 2< O - 2 > tT d 'O <-1/4 U'o_ mID; qt c ao O E mZ U � M � M O L 0_ QQ • o a) ONNcoLL 0 0) +2 ❑❑� ❑ a .' r N wDi- Q CO jZLL ,_ en uvi rn a x aa)) �1O -oC U0 N ' oZcccc t15 ° c T oINm CIF- a) • N O Nco 11 E ate) W .n W Cl) Cl) U 7 co 'y co U/ CO N .N •N N Cl) CI) Y 13 f0 O. o_ 0. a o. 0. 0. 0. 0. 0. a y CO Cl) a) n co O co O 0 co 0 O O 0 0 O w Z y LU EE 0 0 COOco COO I sf 0 0 H 0 Z U 0 c V) y 0 iX 321f1SS32ld w a D I- U z CD1 -04 Attachment Casing Detail Well: CD1.434 Date: 10I2=.2--_ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.30 FMC Gen V Hanger 2.34 36.30 Jts 3 to 64 62 Jts 9-5/8"36#J-55 BTC Csg 2607.10 38.64 Davis Lynch Float Collar 1.53 2645/4 Jts 1 to 2 2 Jts 9-5/8"36#J-55 BIC Csg 78.30 2647.27 Davis Lynch Float Shoe 1.75 2725.57 9 5/8" Shc 2727.32 TD 12 114"Surface Hole 2740.00 RUN TOTAL 35 BOWSPRING CENTRALIZERS- 1 per jt on Jt#1 -#12 (On stop rings of Jt#1, #2 ) and over collars on jts# 14,16,18,20,22,24,26,28 30,32,34,36,38,40,42,44,48,50,52,54,56,58,60. Use Best-o-Life 2000 pipe dope Remarks: Up Wt- 155k Dn Wt- 145K Block Wt-70k L— Supervisor. DON MICKEY Security Level: AK Development DIME Daily Drilling Report CD1-04 ConocoPhillips Report Number: 3 Rig: DOYON 19 Report Date: 10/25/2000 (,f. AFE Type Network/ID# Total AFE+Sup 998C11 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-04 Development ALPINE 4.00 4.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 10/22/2000 10/22/2000 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) SURFACE,2,727.3ftKB Ops and Depth @ Morning Report 24hr Forecast SLIP AND CUT DRILLING LINE. TEST CSG., CLEAN OUT CEMENT,LOT, DRILL 8-1/2"HOLE. Last 24hr Summary General Remarks Weather Head Count Supervisor Title D. BURLEY,Supervisor Supervisor Time Log .:.Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-7-xTrbl Code Trbl Class (ftKB) (EKE)` Operation 00:00 01:00 1.00 SURFAC LOG Np DH 2,740.0 2,740.0 POH, no problems. 01:00 02:30 1.50 SURFAC LOG Np DH 2,740.0 2,740.0 Stand back HWDP, laid down BHA,clear tools from floor. 02:30 06:00 3.50 SURFAC CASE RUNC P 2,740.0 2,740.0 Rig up to run casing, PJSM. Run 9-5/8"" casing to 1450'. 06:00 08:00 2.00 SURFAC Np DH 2,740.0 2,740.0 Wash and push casing from 1450'to 1510'. 08:00 09:30 1.50 SURFAC CASE RUNC P 2,740.0 2,740.0 Run casing to 2727'and establish circulation. 09:30 10:00 0.50 SURFAC CASE RUNC P 2,740.0 2,740.0 LD fill up tool and MU cement head. 10:00 11:00 1.00 SURFAC CIRC P 2,740.0 2,740.0 Circ and cond mud for cementing, PJSM. 11:00 13:00 2.00 SURFAC CEMENT PLUG P 2,740.0 2,740.0 Pumped 40 bbls of Biozan spacer with nut plug marker and 50 bbls of 10.5 ppg spacer.Cemented casing with 435 sxs of lead and 213 sxs of tail slurry.Displaced with 20 bbls of FW and 187.2 bbls of mud,bumped plugs,CIP @ 1300 hours. Full returns throughout,had 48 bbls of 10.7 ppg cement returns at surface. 13:00 15:30 2.50 SURFAC P 2,740.0 2,740.0 Ld cement head and landing jt.-flushed divertor and surface equipment. 15:30 19:00 3.50 SURFAC NUND P 2,740.0 2,740.0 ND Divertor system-install casing head and test M/M seal to 1000 psi. NU BOPE. 19:00 23:30 4.50 SURFAC WELCTL BOPE P 2,740.0 2,740.0 RU and test BOPE and Choke manifold valves to 250/3500 psi-Annular to 2500 psi. 23:30 00:00 0.50 SURFAC P 2,740.0 2,740.0 Pull test plug and install wear bushing. Welibores Wellbore Name ;Wellbore API/UWI CD1-04 501032034600 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date 18 0.0 114.0 10/22/2000 1/1/2000 11 5/8 114.0 2,740.0 10/23/2000 9 2,740.01 9,454.0 10/30/2000 81/8 9,454.0 13,977.0 11/8/2000 Latest BOP Test Data Date Comment Page 1/2 Report Printed: 6/4/2012 Security Level: AK Development Drilrind Daily Drilling Report :a &Wells CD1-04 ConoeegPhilii Report Number: 3 Rig: DOYON 19 Report Date: 10/25/2000 Survey Data I MD(ftKB) Ind(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Page 2/2 Report Printed: 6/4/2012 wd>i M C N N W N MA Mn Mn d1 co U) to U) c U) Ca w .- 'N .N W d) p,OJ.QQ1a..a.,GJC+ w �CJC O+Q,�Gaflr�OrGJQ.a.a.. J } —o 0 p•,a'Q'Q' 00000000 % 000 000000000000 W v Q w OOOOOnMDCpP0erop 07 Ne- « < OOOOOOMIO )� MD Y 03 g Q i 0 �' O N in O < M O r LI 3 t0 �A Mn Mp Mn 10 Mp Mp MA MC) Mn et �J < e- e- « N N N > N N CVN N N N N N N N N N N N 1- J I- LLI w U) 01 ""/"" -V YYYY .CYY 0 QY Y -L -G Y Y +.) 4., .. tJ +J .. .. a+ a W 04' 44' ..+ 4"' a'' N N N N co N M co W F F N N N N N Cr)=I_ y0Nd' MD0Oe- er- OD OD— NNN I- CL O a Z U) JNLH g y I 2 'C C C C C C C C C C C .E -, .5 •� U.! y Ua —N ? oF z = z LL u) 1- 000 ooC) 0000C) 0000 0 as • o = 0 <-N 014inOr- COCD ,_ � NN01 z w Q f- w = wrn _ J cc .- .- '- N N N CO N MQ CO N N V) MA v! v) N N W MA MQ MQ CO N W y m (I) re) u) C.C.O.O.O.O.O.C.O.C.C. z a O.C.O.O.O.O.O.04 O.O. 2 U °��Q"00000000000 a0000000000o C! W O OO O O inNt - in Mn < )- e4 up ? til OO up etM < OOOO y M < N N M �' M MO MD h = ti MD 1n 1n 0 Mn M() Mn et Tr 5E Q ___L___L__1__J___1___L___L__1__J___1___L___L__1__J___L___L_-1__1__J___L___L-_1 __-L--1-_J___1___L___L__1_-J___1__-L_-_ W CD 0 0 CD CD 0 0 0 0 O O O O O O O O N M CC Q O F < NMer •Mp <Of� COCD e < e Y V' J Q au Wy 2 C C C C C C C C C C S 0 Jw - - - - - - - - - - o o z E E E E E E E E E E z a � f. 00000000000 W E = O ,- N M 4 Ln co I.--: a) 6 c) Q v) Z 0 0 _ 11111111 2 > — _. W >. }- I- a) — M L e- M Cl N fA — ~ C. CO -01 03 'o N(Ni 0) M t < < _I H 2 N o 3 C E O —� W Z O C In N N •4 M E m —4 WI- LL i- I- 1- Z CO ID 'CB O cn C — Z_ _ d C L N a) 0 X a d d — -J O Z CO Z -i o C 7 O ZT p o (p N Q. ? 72 — ,w—Q cD 1- c sw y O L y •oo • LL 7 — F p W U _1 U F- E •E O a 1A LLL —4 w CO 0 f6 O II I) — 1 y O . 0 C 0 IS waQ p V CO o N CU H 7 U cD m MY Zo a • a) U CO _ < I- T o I- H cL p = C ,6 O II — N S W al (n d a • G p -5• - ~ 0 rn� 0 � 2 > • _ 5 T — C Q • H fa.cD n — o Z_ Z f6 •O a) M 0 E N _ ti s O U H n M OD -0 L d _ S <9 E o N 3 2 a N Mn N — u) ❑' ❑' ❑ O = t viCe L.1.111 Z Q LL• O .. •U IT d x O N O O -a Q .a) Na C O LN 2 ak H C T z a) CU o a a) • oCC D 75 I- v lA C) _1 O ~ fn N Cl) N ON N II -c ami W a I-Ili E CO 'CD U > > i_,_,_,_._. O 0 a Z a) c 2 I CL 'Gs a a a a a a a a a a a a a a a a a a a a a a.a a a a a O y'O- (' - y w E OJOO000000000000000O Q0000000o W' o COOopoo OOOO000000O 00000000 Z f0) a W ra) O V f0N1-00.CO N0 V N O a)�V<`7N,- I' N N N N N N N N N 1- .- .-.-r' CO 2 U 01 VJ H 321 1SS32ld W Q D p U z Casing Detail Well: CD_-04 --> _ PHILLIPS Alaska, Inc. - -= Date: A r.;,,`_ A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.42 FMC 11" X 7" Hanger 1.69 34.42 Jts 3 to 233 231 Jts 7" 26# L-80 BTCM Csg 9322.04 36.11 7" Davis Lynch Float Collar 1.50 9358.15 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 82.20 9359.65 7" Davis Lynch Float Shoe 1.70 9441.85 9443.55 1 straight blade centralizer per jt #1 -#18 1 straight blade centralizer on #'s 168 & 169 and every other jt #171 -#231. Total -51 centralizers Use Best-o-Life 2000 pipe dope Remarks: Up Wt- 325k Dn Wt- 170k Supervisor: David Burley ,:ilift Security Level: AK Development 40, Daily Drilling Report CD1-04 CgnotoPht7�ps Report Number: 8 Masks Rig: DOYON 19 Report Date: 10/30/2000 AFE Type Network/ID# Total AFE+Sup 998C11 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-04 Development ALPINE 9.00 9.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 10/22/2000 10/22/2000 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) SURFACE,2,727.3ftKB Ops and Depth @ Morning Report 24hr Forecast RUNNING 7""CASING FROM 6800'. RUN AND CEMENT CASING, INSTALL AND TEST PACKOFF, TEST BOPE. Last 24hr Summary General Remarks Weather Head Count Supervisor Title D. BURLEY, Supervisor Supervisor .Time Log j Start End Dur Time Depth Start. Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 00:00 09:00 9.00 INTRM1 DRILL DRLG P 9,093.0 9,454.0 Drill from 9093'to 9454'.ART=1.4 AST=4.1 09:00 10:00 1.00 INTRM1 CIRC P 9,454.0 9,454.0 Pump high/low/high vis sweeps and circ clean. 10:00 12:30 2.50 INTRM1 DRILL WIPR P 9,454.0 9,454.0 Monitor well, pump out first 4 stands and POH to 7800', no problems. RIH, precautionary wash last 90'. 12:30 14:00 1.50 INTRM1 CIRC P 9,454.0 9,454.0 Pump high/low/high vis sweeps and circ hole clean. 14:00 15:00 1.00 INTRM1 TRIP P 9,454.0 9,454.0 Pump out first 4 stands and POH to 8660',pump dry job. ' 15:00 19:00 4.00 INTRM1 TRIP P 9,454.0 9,454.0 POH to 3450', no problems. LD remainder of 5""drill pipe,flow check at shoe&hwdp. 19:00 20:30 1.50 INTRM1 PULD P 9,454.0 9,454.0 Standback hwdp, LD BHA. 20:30 21:30 1.00 INTRM1 P 9,454.0 9,454.0 Wash out stack and change out wear bushing for 7""casing. 21:30 00:00 2.50 INTRM1 CASE RUNC P 9,454.0 9,454.0 RU to run casing-PJSM-run 7""casing. Wellbores' Wellbore Name 1Wellbore API/UWI CD1-04 I 501032034600 [`:' - Section Size(in) .Act Top(ftKB) 1 Act Btm(ftKB). Start Date {.. End Date 18 0.0' 114.0 10/22/2000 1/1/2000 11 5/8 114.0 2,740.0 10/23/2000 9 2,740.0 9,454.0 10/30/2000 8 1/8 9,454.0 13,977.0 11/8/2000 Survey Data MD(ftKB) not(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) J DLS(°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.001 0.00 Latest BOP Test Data Date =Comment Page 1/1 Report Printed: 6/4/2012 Security Level: AK Development Daily Drilling Report �: &Welts CD1-04 ConocoPhillips Report Number: 9 Rig: DOYON 19 Report Date: 10/31/2000 AFE Type Network/ID# Total AFE+Sup 998C11 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-04 Development ALPINE 10.00 10.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 10/22/2000 10/22/2000 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) PRODUCTION,9,444.8ftKB Ops and Depth @ Morning Report 24hr Forecast MU BHA#6. RIH,CLEAN OUT CEMENT, LOT, CHANGE OVER, DRILL AHEAD. Last 24hr Summary General Remarks Weather Head Count Supervisor Title D. BURLEY, Supervisor Supervisor Time Log Start End Dur Time Depth Start Depth End (11111('0+ Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class, (ftKB) (ftKB) Operation 00:00 03:00 3.00 INTRM1 CASE RUNC P 9,454.0 9,454.0 Run 7""casing to 4428'. 03:00 04:00 1.00 INTRM1 CIRC P 9,454.0 9,454.0 CBU. 04:00 06:30 2.50 INTRM1 CASE RUNG P 9,454.0 9,454.0 Run casing to 7260'. 06:30 08:00 1.50 INTRM1 CIRC P 9,454.0 9,454.0 Circ and cond mud. 08:00 10:00 2.00 INTRM1 CASE RUNC P 9,454.0 9,454.0 Run casing to 9444'. 10:00 12:00 2.00 INTRM1 CIRC P 9,454.0 9,454.0 Est.circ,staged pumps up to 7.5 bpm and cond mud.PJSM. 12:00 13:30 1.50 INTRM1 CEMENT PUMP P 9,454.0 9,454.0 Test lines to 3500 psi,pumped 20 bbls of wash ,47 bbls of 12.5 ppg spacer, and 33 bbls of 15.8 ppg cement. Displaced with rig pumps @ 9.0 bpm, bumped plugs,floats held.CIP @ 13:30 hrs. 13:30 14:30 1.00 INTRM1 P 9,454.0 9,454.0 LD landing Jt.,RD running tools. 14:30 16:00 1.50 INTRM1 P 9,454.0 9,454.0 Pull wear bushing; install and test packoff to 5000 psi. 16:00 17:00 1.00 INTRM1 WELCTL BOPE P 9,454.0 9,454.0 Change top pipe rams and drive sub on TD. 17:00 22:30 5.50 INTRM1 WELCTL BOPE P 9,454.0 9,454.0 Test BOPE-manifold and surface safety valves 250/3500 psi.Annular 250/2500 psi-witnessed and approved by Jeff Jones(AOGCC). 22:30 23:00 0.50 INTRM1 P 9,454.0 9,454.0 Install wear bushing. 23:00 00:001 1.00 PROD PULD P 9,454.0 9,454.0 MU BHA#5. Well bores [Wellbore Name Wellbore API/UWI CD1-04 501032034600 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date 18 0.0 114.0110/22/2000 1/1/2000 11 5/8 114.0 2,740.0 10/23/2000 9 2,740.0 9,454.0 10/30/2000 81/8 9,454.0 13,977.0 11/8/2000 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) ` NS(ft) EW(ft) DLS(°/100ft) 0.00 0.00 0.00 0.00 0.00 0.001 0.00. 0.00 Casing Strings String OD String Wt Casing Description Run Date (in). ,.(lbs/ft). String Grade Set Depth(ftKB) Comment PRODUCTION 10/31/2000 7 26.00 L-80 9,444.8 Latest BOP Test Data Date Comment Page 1/1 Report Printed: 6/4/2012 Vi W FT Y al I— w 0 z O LU Q a c I- O 0 I LL cc 03 a1- Y W Y 0 <a Oa N LU NJ � � F- CL a Z co J C u) 1- 2 c c c c c c c c c c c .E. .E, .0 •E co J s Q L ( z 'E . .E 'ff 'E '-E ' •E 'E •E E E E E E a =- N ' z OLL o 1- o 0 o 0 0 0 0 0 0 0 00. 00. 0 0 Q.¢ E U = OrCV MTiLnCOI� cOOir4.3 RNc'M z u) 113in m I- C0 K . •N •N •V) •N •0 CO N V! .N •V) N N 0 N N •0 0 .N t/) V) •N N W u) •y •y N .y J „ a.0.0.0.0.0.a.a.a.0.a.a.a.a.a.0. z Q a.a.a.a,0.a.a.a.a.a. 2 ✓ 0.r 1s M0 C) e• 0 0 O C) 0 0 et 0 0 a O C) C) 1) co M M M co M co 0 Q K 0 0 1•••• tO It) CO (0 N r CO t0 I) ti n t0 h O ? CO t0 O to M M N N N = a r r N M M O 0 Cr er at = Tr M M M M M M co) MM M Q ___1___l__1__J___1___L__1__J___J___1___L__1__1__J___1___L__1__t__3___1___L__1 Q N C1 Q L 2 )n O to O to Otn O to 01n01n01n0 0 L 0 2 0 0 e= a= N N M M d' er CO U, CD CO P P O Q W Y -) Q W W u7 2 c c c c c c c c c c .0 J w 1 — — — — — — — — — - „ o o z E E E E E E E E E E E z U. -II- O O O O O O O O O O ~ o 1- E S O r N t�) e1' 1•n CO 1-- cd O r0 y z z O 0 p N >. UF- H Ian C) — N O 15 4, in co Q W m CD to C0 1s- a u) 00 0 co U Z 0 + a0 O — N -c C II II O 7 0 'c Je7/11 ,, hJkI In a) '� N M t m �U 0 cn •Q. c L N d x >.�. d N c O ZT H p O N N Q in ? N U SCI3 2o en N O O a o M Li Q U 1- <nIll E I ; (n O m U N o II 11 H I T T cn LLI o � � to w C '° T T - c cr lc a LL .77), F- 0 c y - l O }, N Q -p h a) +r E — co 2 J C L_ Q V a J I- r 0 0 X d , p Z Et r ° a Q I- O CD 2 I- O c c m CD u - m = WN 413n 0 0 = a co L Z U M M d Q O o N N N O Q ❑❑ ❑ o w 6 w Ce CI. o In 0 Z 1 .. U CD 'O X N C.4 O O E. in u) c = m U L 0 Y co Z 0 CC AI c ac°i o li H m c ID N N ON II c W W E co 'fp U _ ; o Y 0 H CO CO cp CD a Q Q Q a a Q a Q p F co W E� 0 0 0 Lo 0 0 el 0 CV 00 IX c U 0 u y Hix 321f1SS3?Jd di Q n I- U z CD1 -06 Attachment Casing Detail Well: CD1-06 LL5LirTaC Date: 612012000 trii PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.20 FMC Gen V Hanger 2.41 36.20 Jts 3 to 87 85 Jts 9-5/8" 36#J-55 BTC Csg 3455.30 38.61 Davis Lynch Float Collar 1.55 3493.91 Jts 1 to 2 2 Jts 9-5/8" 36#J-55 BTC Csg 80.10 3495.46 Davis Lynch Float Shoe 1.80 3575.56 3577.36 TD 12 1/4" Surface Hole 3587.36 RUN TOTAL 59 BOWSPRING CENTRALIZERS - 1 per jt on Jt#1 -#32 (On stop rings of Jt#1 & #2) #34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 84 86 Use Best-o-Life 2000 pipe dope Remarks: Up Wt- No Data On Wt- No Data Block Wt- 70k Supervisor: Scott D Reynolds Vz ._ ._ ._ ._ ._ ._ ._ ._ ._ ._ ._ ._ ._ ._ ._ a K • •. • •N •- ••• •- N N N N U) U) CO U) U) U) U) co fn U) U) U) C) U) U) U) N N N U) N U) co cu a,aJ QJ a,a a,a,a,aJ a1 aJ m a.aJ a aJ a,aJ aJ a.aJ aJ a,a,a,a.a. 0 1) a.,a"'a'gga'0a000000000 x000 00 in Lo u, U) OOininLoLa W ,o Q y 000OOLnNaa) inrCOrp. tor rinto Ln1ONNNNNNNNra- x. g Q wOerNOlO � OTMetcocoa) TNact 10 ZLC) erer ererd' er � ererverereter -V L° Q. T � fL ~ OTrrrrra-NNNN /- NNN NNN NN NNNNNNN 1- J 0 x Lu wI— rn U) N U) U) W U) U) fA W U) CA U) LU • a U) w U) U) U) U) � YYYYYYYYYYYY 0 Q a 0 a, r W W a U) U) N U) U) co U) N N LUca ta U) U) U) U) I COV!- ~ O es, er fD , O N at CD CO O N er CO CO O T = U1 W T T T T r N N N N N M M H CL z: Z. I/) _-i---4-- -- ---i---i--4-- _----,---i---4--•F_-�_-i---4---4--+•-_a___ __-4-- -----,---i---4-_•,•----_a---4---4-- --'�---i---4---1 w cn J ,� fn 0 2 c c C c C c c 0 0000000 c c S .c .c .S .c W J Q f 'E ' ' ' ' ' ' ' az E E E EEEEEEE NV' z ° F `= c� � oo0 000000000000 0 as E ow = O TN c6 .1Lt7Ccif- cOd) Q "4) NNM z rn EC! - 0 i K .- N U) CA U) CA Cl) to lA q) CA M N V) U) Q W SZ a.,U) N N N U) U) N N N c N a.a.a,a,a,a,a.a,a.a.a,a,a,a. to O a.a.a., a.a,a.a.a,0.. I h -.00000000000000v) '- c,) 0000000000 0 Q UIOrCO10cMa CO r-.. 0D art O) 100100) p - ? a0 C) - 00) CDN00 = a. rrNM � � OtD r` n0000) 0) r = �T 0) 0) O 0) 0000000 Qy L---L--1--J---1---L--J.__1__J_--1---L--J <- a Q c 0 w 0000000000. 0. Q. 555 O r0rCNMertt7CDtiCOCO ° erIo Q r r T T T T J Wy 2 c c c c c c c c •c C_ c J o o z E E E E E E E E E E E I- w z a -1 1- 0C:3000000 0 0 0 H 2 = OT NM Cr Ln CD CO .,_ o rn Z W LU 0 0 — 1111111 m H g > — w I H H O - 2 Q — f L 00 ( MCL N W Z W f7) CO r (9 a a - - D CT) L) M O In. N W L C II II — 0 Cl) I-- > O = 0 p ami 0 — w FW-• Cn Z Cn .00 .L !) (n .N O E Ix' — Z 1- U FW- I- ~ Z N 0 43 Ch co 0_ c _c a) U 0 X Q. a_ a) — _Ti � U Z Z J c O �- p o MO N Q :0 m _ I W w Y In I- C) W •, O a. o CO LI .�. I— r — a) (l) "co` ° o II II — �i I I vim) Lu p t0 _ O C a ) m � co — �, �' Qv _, ++ .0 = m T w. L. < V n Ili H . , N o Y Z c m H o U c m0� H oo _ 0 D W a) -c Q m u.) .0 co C 1=i — _ ,_. m � a 19 0 0 � Q. — y c w # 1-- I-- N a. n — Z cc o LD i. o 0 E — 4fX O E a In 0 0) > O a — 0 Q a) 1n M M 1r. -- co 5 L.L. 0 C) + w D❑ ❑ o r ui W zD cc a ow O •a a) ✓ oa) a V N x O N O o 0 cO N Z H d 0 • N Y p z cc CL RI c V) af0i o F- iii 0 � J H a� N O N @ H c 4.)-0 LU Y .o > 7 a) o 0 cn U > C ._._.y._._._._._._._._.- _._._._._._._._._._._.a._._._._._ a) ,n N41 a) E a a.a a a a a a a a a aa aa a a a a a a a a a n a a a a o O 13 O Z ct Cl) W E S 888888888888§888888888888888°N cor b o N o I- o CD 0. co.n t0 h e M N,-0 W 00 r- '^ C fJ Q N N N N N N N •- •- ,-,- U) G N N 32:1(1SSMId w d D 0 U z Casing Detail Well: CD1-06 7" Casing Date: 7/3/2000 etj PHILLIPS Alaska, Inc. A.Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.40 FMC Gen V Hanger 1.61 34.40 Jts 3 to 328 326 Jts 9-5/8" 36# J-55 BTC Csg 13378.84 36.01 Davis Lynch Float Collar 1.45 13414.85 Jts 1 to 2 2 Jts 9-5/8" 36#J-55 BTC Csg 82.06 13416.30 Davis Lynch Float Shoe 1.70 13498.36 13500.06 Run one straight blade cent./jt on jts# 1-#3 (total - 3). Run one turbulator per joint on joints#4-#32 (total - 29) Run one straight blade centrilizer/joint on joints on #244, #245,and #246. (total 3). Use Best-o-Life 2000 pipe dope Torque pipe to base of triangle -check every jt. Record displacement. CBU @ shoe. Circ and cond mud to 9.8 ppg at 6100', 8600', and11,500'. Brreak circ slow- circ @ 4.5 bpm. Remarks: Supervisor: MIKE WHITELEY tri PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD1-06 RIG: Doyon 19 TUBING DESCRIPTION: 7" 26#L-80 BTC DATE: 07/03/00 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 41.36 26 40.21 51 41.22 76 41.57 101 41.58 126 39.93 151 40.81 176 40.12 2 40.70 27 40.17 52 40.18 77 41.79 102 38.93 127 41.37 152 41.75 177 41.68 3 39.17 28 41.33 53 40.20 78 40.20 103 41.17 128 40.76 153 39.99 178 41.80 4 40.13 29 39.57 54 40.18 79 40.21 104 39.63 129 40.51 154 41.76 179 38.73 5 40.18 30 40.72 55 41.43 80 40.20 105 41.66 130 41.85 155 41.80 180 41.69 6 35.52 31 39.31 56 40.09 81 42.12 106 41.82 131 38.65 156 41.42 181 41.75 7 '' 36.15 32 41.23 57 40.49 82' 40.16 107 41.81 132 41.65 157 40.02 182 41.76 8 37.60 33 41.54 58 41.20 83 41.54 108 41.44 133 38.80 158 39.07 183 41.41 9 41.74 34 40.05 59 40.15 Q84,' 39.08 109 41.74 134 41.71 159 41.65 184 40.99 10 40.13 35 40.42 60 41.43 85 41.21 110 42.08 135 41.42 160 41.81 185 38.49 11 41.01 36 40.22 61 40.18 ' 86 41.81 111 41.27 136 41.70 161 41.42 186 41.18 12 40.17 37 40.21 62' 41.17 87 41.70 112 41.55 137 41.62 162 41.80 187 41.54 13 40.22 38 40.69 63 40.14 88 41.81 113 41.28 138 41.57 163 41.61 188 40.45 14 39.54 39 40.14 64 40.75 8-9 40.07 114 40.72 139 39.92 164 41.29 189 39.35 15 41.96 40 40.11 65 40.19 90 41.77 115 40.76 140 41.46 165 41.53 190 36.76 16 39.03 41 40.05 66 41.21 91 41.81 116 40.75 141 41.81 166 41.64 191 41.89 17 36.82 42` 41.66 67 40.72 92 41.61 117 41.80 142 41.58 167 41.78 192 41.69 18 41.78 43 40.72 68, 36.89 93 41.50 118 41.71 143 41.68 168 41.58 193 41.61 19 40.21 1, 44 39.08 69 40.23 94 41.64 119 40.98 144 41.06 169 40.03 194 40.95 20 39.59 45 41.13 r 41.30 95 41.52 120 41.49 145 41.76 170 41.20 195 41.79 21 41.59 '''04!.51 40.15 71 41.90 96 41.78 121 41.38 146 40.58 171 40.48 196 41.56 22 41.27 47 39.91 72 39.45 97 41.54 122 42.47 147 39.51 172 41.74 197 41.99 23 40.17 48 40.15 73 40.11 98 41.79 123 38.92 148 39.95 173 41.57 198 41.80 24 39.60 49 40.19 =74 41.77 99 42.07 124 40.73 149 41.22 174 41.71 199 41.81 25 40.48 50 40.16 75 40.92 100 41.59 125 41.62 150 41.35 175 40.82 200 41.76 Tot 996.12 Tot 1009.12 Tot 1013.50 Tot 1032.09 Tot 1029.29 Tot 1023.42 Tot 1030.28 Tot 1024.55 TOTAL LENGTH THIS PAGE= 8158.37 DIRECTIONS: TOTAL JOINTS THIS PAGE= 200 FLOAT SHOE 1.70 FLOAT COLLAR 1.45 HANGER 1.61 RKB 34.40 W ♦+Z = Va a! m ._ =g m Q r W ° Q maJ aQ. Y C�g 1- z O z0 W ui . ° m I- 0 in (C%- I— LU II Cl) w a a Y rcH LU JI- I-�a U) 0 QZ --•--• -'--'--� -_a- _` ' " ' " '- `---• �-a---'--'---'-� ' -'---'— V) (I) - � co m 2 c c c c c c c c c c s .S .S .E .E W J yQ cg w , 'E ' 'E '. 'I_ 'E 'E ';_ 'I_ ' E E E E E d Q. ', U I- _� z OLLt7 1- 000000000000000 Z as a u = 0r-N MTiLOCOf- cO6 $2 222c+7 z 9t---r---r--r--r--r--r---r-----�---r--r---r--i---r--r--r---r---r--�---r---r---r--+--- �r r r--r--r--r---r--�---�---r--r--� w F- _ ._ U' C: ._ co) M M U) CO N U) N U) N U) U) U) an p,Q,fl,Q, w C1 W U) U) U) fA N N U) U) U) = U) a a a a a.a 0.c.a.a a a a � � aaac.aac.aac. I m CO M M 00 CO W --rCOOO1Oe- a- NNOCO et ,I. cm MCOt. NON � t. fDe- fDCO 0 Q W 0NO011001CDOD - nNC0Tr000000 30tOMe•- 00 up w) CMN = IL e- MMet1A1nf01'- t` (0 (0CDC) 1- ,O1cnCD0002C000000C0 I- _ •: ". QLL1J11L1J1L11J1L11JJL1 _-L__1__J___1___L___L__1__J___1___L__J U.. m000000000 a ix LL m 0000000000Oe- NMsT 6 <5I CO m e- N M et 141 f0 P CO CD e- r e- e- e- e- e- e- e- Q Oi W -J Q W m m c c c c c c c c c c .c O 5 0 1- z E E E E E E E E E E E w Z a .J t- 0000000000 H m Z >- W . w c- I I eG m m — = - N CO W O U CO a s — Z Y 0 F- 6o c W D F. + QS c — (Sq----_ g 2 II II U cnn H O(7 w o a F W Z O U cp p (n 7) Em W � LL ~ � ~ z co a c -c 2 a) 0 o o O. a= al) — _ ZZ O Z � Z =� c = O U 0 o 10 (v) Q. a m W n W — C1 = = = o a)Ili • TLi F_ p _j U _j O H Ea) u) 1 o n 1 / if f a(n N c1 7.1 III — r wQN X WZN m� ✓ O O C m CD _ CO = O 1-Z cQ O CD z 4t CD N Q � — Z 0 o ° 0ai ro m — E O 76 mEy 1.11 Eo. M = ,� a � p 1n s Q 5U_ a m + a' — w 0 CI E :Ea . p W Z a a) a� LL• 9 ES N a) c = O N } f- ›, C U p N o Z cC CO c O D o cn 40 a� N O •N CU I I .0 ate) W a 0 �S9''�1 z c a) , a n a n n n a a n a a n a a CL 0 — CC m W a) = n N O 8 CO 8o 8 8 v M N o c I— O U 0 Q U) M CO y ix 321f1SS321d (U Q m O 0 Z CD1 -14 Attachment Casing Detail Well: C =--4 9 5/8" ''-_-- Casice_ Date: 2128/2001 tiPHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.80 FMC Gen V Hanger 2.21 36.80 Jts 3 to 86 84 Jts 9-5/8"40#L-80 MBTC Csg 3463.04 39.01 Davis Lynch Float Collar 1.60 3502.05 Jts 1 to 2 2 Jts 9-5/8"40#L-80 MBTC Csg 81.08 3503.65 Davis Lynch Float Shoe 1.77 3584.73 3586.50 TO 12 1/4" Surface Hole 3596.00 RUN TOTAL 48 BOWSPRING CENTRALIZERS - 1 per jt on Jt#1 -#12 (On stop rings of Jt#1 ) #14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44,46, 48, 50, 52, 54, 56, 58, 60, 62, 64, 66, 68, 70, 72, 74, 76, 78, 80, 82, 84. Last 4 joints stay out#87 thru#90. Use Best-O-Life 2000 pipe dope Remarks: Up Wt-175 k DnWt-135k Block Wt-70 Supervisor: Don Mickey Z C) N Cl) !T1 PRESSURE to a — +N N NNN N N N `I CD Z p 0 0 0 0 0 0 0 o s o 0 0 0 0 0 o-co ap�ppp S+o 0 0 0 0 0 o C cp y a O O O O O O O O O O O O O O O O O O O O O S 0000000 3 m T G) a a a a a a a a a a a a a a a a a a Si"Cl a a a a a a a a a cp El 3 CD Z ,< m a 7.., ° y - 0 CD c m O I C o m Cr) 0 Su U 0T aa) 0-, 0 X aO y cp < cD m 0 ml A O Z 0 m co m — * + m 0c ' D Cl) — cn m -i 0 — 0 c N w oo �. d co W N c o -0 G N O z 3 O < CA t07_) C CCD o Cv Z Z _0 — o .y. O - c - 0 0 O v CD (n 0 HI ? O tD .0 = co in 0 do ° C N—C O-1 — 7.1 0 mW `G m wZm C y — R.m - Cr O O = 3' 0c , m l — II n 2, < Cl)v T — ° o2 •F T O m o m o K D O D m �,� _ n c O cri V S 2 o. m cn -i cn > m m — CA a -a N CO o O CC o c m Z- 0 = 00 E Z — a c 0 N 0 FIT 0 o o 1T1 m 1 m T m m _ m 'O pa)j y n co c E D o cnzc/� m — xa �' o. c o m o! C/) 5 — n n R a 2 K H cfc s + * 0 cm inivm o — a lo- im w in aO er c -i - '" w rn 3 _ CO - -A - X' m — < CD 1111111 — 00 r--r--r---r----i---r--r---r--r------r-----r--r--i---r--r--------i---r--r---r------r--r---r-r--r--r--r---r--�-------r--c Z m O ocow "4 -0 .000 .060 -1 Cn403NsOc 3 • 0 0 0 0 0 0 0 0 0 0 -1 r m z Ti 33333333333. 2 ° A° m r O3 3 7 7 7 7 7 7 7 m N m D m 1 D � � � -4. .a DJ, CO V 0) coAC414 zPJ A W N O 0 0 0 •0 0 0 0 0 0 O 0 0 0 0 O m 1l O m a > == r__�___r �_ � r__+___r___�__�__r__+___,___�__r__+___�___r___,__r__+_ t___ D C - NNN W AC)) CDDOt07) t(0CVOz CO CDNODCCOONC)) V O - A0 � � 0m 33 D 5 0 0 0 0 0 0 0 0 0 0 0 m O O O O O O 0 0 O O O O L0 m I -13"0-0'C-0-0-a'•0-C-a-0 m b'13'C'O-a'8'C-0'O'C-0-13 1 H fA c 1- m• CA W. CO. tn. 0. CA. 01. CA. CA. m• c IA• CA. yy_ WN• yaA• yyyy _. - m G) --A (10 Z OCNTOChOOCb V CPC7tA W N-LO � y 3 n13 O 000000000000 000 -I c) - z =2 _3 3 3 3 3 B. 3 3 3 3 3 3 3 • 0 m p. to^ o m a m 5 5 5 5 5. 7 7 ° 7 ° 7 7 7 7 7 ; 1 mcn r -1 - 'C.) W W W W NNNNN -a -a -a . s m O _ i coCT) AN000 ) AN003CA ,A. N0CA 00A NO � _N m co co CA y CA y CO) CA y COCA CA y U) ,y.,. ,yy. ,CO y.' O v CA N N CA CA CA CA CA CA A CA CA y fA CA y CA co co y H -I -I A) m -�--• --�-J L--•---L--L-J 1 L - a= -L -- •--• -- --�--•------ - --•--- o to mNNNNNNNNNNNN NNN NNN --» " " ' C�DO) AN � .p 0 r71 Pr X CDCDV V V 00 COOCCOCOCOCAD CAO CAO -, Z -.a)) t7ICO -J COPOCAO0A000800000m -I �� � ,-013,13f-o13,-0,-0,-)313,-E1,13.-0 V'13 -o la V''a'8''a'•O,'C 13'0 nz ro N y N y a y. N. 0. !. y 5 D -= coCO). COCOCA0) U) CACA CACAy Ch. CA CA m y CO CA y CA CA y CA CA CA m z •m Casing Detail Well: CD1-14 eti PHILLIPS Alaska,IInc. 'rIntermediate Casing Date: 4/24/2001 PHILLIPSA Subsidiary of DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.33 FMC 11" X 7" Hanger 1.30 34.33 Jts 3 to 343 341 Jts 7" 26# L-80 BTCM Csg 13952.85 35.63 7" Davis Lynch Float Collar 1.53 13988.48 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 81.35 13990.01 7" Davis Lynch Float Shoe 1.70 14071.36 14073.06 TD 8 1/2" hole 14090' 1 SB centralizer per jt #1 -#20 1 SB centralizer every other jt #257-#341 Total -63 centralizers Use Best-o-Life 2000 pipe dope Remarks: Up Wt-425+k Dn Wt- 75k Supervisor: David P. Burley Z C) O c D m PRESSURE m N a 0 N A 0 H �, O S S S S a S O C CoCD Z a w a a a a a a - _7. m _ Z 0 - 7 7 g CO CD n II y N D ON CD - n H r- W = COC O0 a o M 7.1 z oPk- CD 0 n 0 o IVrn X c- CO �~ -n 1 y N m 0 -0' A z 1-11 co s co ca V C R ❑ O❑ E H E D 1 CD m * + CO 0 T Cr) K 01 CDo '" 1 N W —_ -' Q o w it �- v Z — -o -0 CD N fT 0 4* Cn 7 tn. — _ -1 Z c CD O 0 0 OD V O o ED -I CP -` ? 0 CD -0 S CD m C D -r II11 0 W O O C) _ 73o i 1 CD -I MPOD E O '< -I A 7 Z , w m n O O y N K C m o ...I- -- a - m l CD p al -n to• o m r O N m N O 3 fgf'I pap �- N o o 00 i c0' O' C N r G7 2 n O Z r _ 5o. c -0 x N ': : S 7 'a0K _orn C0coa.O w = F H v+ V OD 0 tD m CL] 0 --i* (S) C) K — I 0 1---7---T---i--Y-7---7---i---f--Y--T--7 z Co O QCoCo -.40Cr, A W N -- OE ; 0000070000001 r T z m 3 3 3 3 3 3 3 3 3 3 3 1 O xi y r 0 3 7 3 3 7 7 7 7 7 3 m m -- '---i---`--y--�---�---`---`--y--'---'-----y--y--'---a---`---`--y--'---a---`--y--i--'------`--y--'---'---`---`--y--'---'--- D r X m D -.. -1. -v .... ..,. ..1-2. -1-... ..... -. ... -1-1. COOD V mm .t. W N O tGW0DV VW0) CT0AtWN -n0 0m OUT001 00007) 000000000000000 y 7 C > o D ---___r-------r----------T------T--y--- = r-- 'r---r--r--y---r--r--T--r--y---*---__T__y'_-y---r---r--�'--y---T--- D r W= NWWWWAAtNWOi V Ca m DpOOOAW -LOO0WDMWOO ) WOW -4MNO 5 U O O O m O O U1 CAO _ v -.. - — 0 m 0 0 0 CT CO CO CD CO OD OD W 0D N V N V N - ra m I '13'13'CS'113'0'13'C"a"fl'C V m -O'C'V V V'C b T3 V V'C3 V'C't3 V'C V V V V'C3'C3'0 CO c r" WCO. CD. yyyyWCA. yCA, m W.N• CA. W. CO.CN. CO. W, WW. CA• W. CO. W CO. W. 0. 0, M 0• M• M. Co ' m 0 c 0 N N Z W CDChCa010 . b � tAU) A W N� Oc co; n� 0 000000000000 000 -I G) m z c= 3 3 3 3 3 • 3. 3. 3 3 3 3 3 3 3• ! m xi m D Qr' m 3 3 5' S' g' 5 5 3' 3' 3' 5'3' m -, Co to ,E.z7 o . r__y________. __y___r___r___r__.r__y___y___�___�__y___y______"__ __y___y________.t__y___y______r__.r__y___y___�___r__.y.__y___r___ ZT a V 0o 0 IN m C O m N 0 • W y a. m o CO 11111111111111 ZM OOm 312 COr0 -U r13 33 M MI y c > m = m 1- z 0 1111111111 c 1 1 1 1 1 1 1 1 1 1 1 1 1 � 1 -c. ... .'1'n CD1 -17 Attachment Casing Detail Well: 1- 7 9 5/8" surface -=__-__ Date: 1;:i1-2-/2;:= PHILLIPS Alaska, Inc. A Subsidiary or PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.75 FMC Gen V Hanger 3.21 36.75 Jts 3 to 64 62 Jts 9-5/8"36#J-55 BTC Csg 2382.68 39.96 Davis Lynch Float Collar 1.54 2422.64 Jts 1 to 2 2 Jts 9-5/8"36#J-55 BTC Csg 85.06 2424.18 Davis Lynch Float Shoe 1.77 2509.24 2511.01 TD 12 1/4"Surface Hole 2520.00 RUN TOTAL 38 BOWSPRING CENTRALIZERS- 1 per jt on Jt#1 -#13 (On stop rings of Jt#1,#2) and over collars on jts# 15,17,19,21,23,25,27,29,31 33,35,37,39,41,43,45,47,49,51,53,55,57,59,61,63. Use Best-o-Life 2000 pipe dope Remarks: Up Wt- 155k Dn Wt- 145k Block Wt- 70k Supervisor: DAVID BURLEY r--r--r--r---r--r-- --r--T--r--r--r--r--r--r---r--r--T---r---r--r--T---r--- -r--r---r--r-----r---r--r--T---r-- W 'N 'y 'y 'y 'y 'y 'y 'i 'y - •N •y•y •V5 •y •N •y N Q..Q.,c.,n.c.CI.°,°,°,°,°,gq°,°, aaa 0101cH04 y 0, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 P.1 00000000) Tr 01, w) it) o W N MIT N- N- I - II ›- 4X4X - - N01ts D000OON �tIts01 01141 hetet Tr-,Vret � W Q e- N M 141 N. 0) e- e-e- e- e- e- N-'N N N aa N N N N LY LU JLiJJLiJJLiJfLiJ_ J___L_i__J___J___ n O N l/) W CA tl) 00 0) 0) 0) N -I (/) w 0) 11"/"" -V -1C -V _Ne -v -Ne -Ne _v Je _v W Iliy _LYY _t -V r r r+ 4 ++ r+ 4+ r.J ...1 J✓ J+ O }' y y r N N H N N co N 0) N co N) 0 K CO CO N CO 07 F- ONetcDOpONe7CD000NCMNNN et 0, OD 01 W Ve w e- e- a- a- e- NNNNNN I Z NH C C .O C C ,C ((I) y Q 2 0 Z .E .E E E E E E W U z ° 0r000 0000 p- U = 01n,- rQNCO 0 w Z L--i--'---1---L--i--'---'---L---�--J---'---L---�--J---'---L--i--'---J-- --�'--'---J---L--A--J---J---L---L'--J---•---L--�---J---•--- Q T re _ ' , T ' V U) ��0000000 IL0lnoLC)0000000 Q C 0 0 CO 0) O e- N N 0 z 0 CO N C) OO OD OO CO I, f- t'- Wa. CD e- Net141CDh0O ? c000001f) tplC ) tf) l(') lt') tC) tn = Q = Q __ __________ __________ __________ __________ __________ ____ 0 LL L7 LL iLI y0 (0 u) 0 U.+ r r r ++ r r r a+ Q N N 07 W N N 0) 0 ( ) el) C) a- LLLLJ QF--+--i---+---F--+--+---+---F---I---i---+---E--+--i---+---F--+--i---+---F--+--i---+-----+--1---+---F--+---I---+---F--+--�---+--- V W 2 1/3 c c c c c c c c c c c 0 J 1- w1- ZEEEEEEEE .E .EE ~ Z OLL OJ I- 0 0 0 0 0 0 0 0 0 0 0 Ui 5 x0rNCO V' COCO1- 000) O 0 0 Z N 0 0 _ 11111111 '< c 2 > Y W t = I- F- ZA o- e m in a . - O N a W k- r / z 0 -c Ln V CO Z 7 - as N N O) J t W D C:3 + i w - F- to > Z `o a L in ro wc~i) zc~n 0° M ca 0 = CL a I.L. D ~ z X c 0 C 0) N 0) O x Q- 0 Z Z 11 1 = (I) O O 0.0 oI 8 Ti. - 1 Y CO I- Cn W �' E 2 o N _i Q p Q } t E p o tri J (-) -I0 F- = 1 (nL O L r y II II (� U A W 0 CC = _J 2 jp ,_ a W _ N w Z 0 y 4O Q (/) .0 .0 t Lt e- O T O) U sa O - giec 0 I— co ci H -c 0- m CO II - (I) Z m (n -8a a 0 0 t in o V CD p CQO a m > a� ft - 0:2• li op _ N W O � �❑ o a F. Z m p t 2 U. N- .Q p .� > 0 -tii- w F- _ x c p t a) c a a` 1Nn mIt COf ° • m 2 o D • U) o oI I- N LLI co c- to C o a� Y U 6 7, a a 6 6 3 0 0 a 6 6 7,7,' Oaa6666a0.aa667,7,.4- . a6aa 6 0Z C cn W a 288888888888888888§8 00 OIID h7NO Tl1COhlCO88888F-Z O 'V^ 3 U a 32i1SS21dQ E 0 I n z Security Level: AK Development Drii Daily Drilling Report _, &We1- CD1-17 Ccxwc4Phitlips4 Report Number: 2 Rig: DOYON 19 Report Date: 10/4/2000 AFE Type Network/ID# Total AFE+Sup 998C14 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-17 Development ALPINE 3.00 3.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) lJob Days Ahead(days) 'Projected Job End Date 10/2/2000 10/2/2000 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) SURFACE,2,511.0ftKB Ops and Depth @ Morning Report 24hr Forecast DRILLING 8-1/2""HOLE FROM 2550'. DRILL AHEAD. Last 24hr Summary I, General Remarks Weather Head Count Supervisor Title DAVID P. BURLEY, Supervisor Supervisor Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 00:00 01:45 1.75 SURFAC CIRC P 2,520.0 2,520.0 Circ and Gond mud, PJSM. 01:45 03:45 2.00 SURFAC CEMENT PLUG P 2,520.0 2,520.0 Test lines to 2500 psi,pumped 40 bbls of Biozan spacer with nutplug for marker and 50 bbls of 10.5 ppg spacer. Cemented casing with 309 bbls of lead and 48 bbls of tail slurry. Dispalced with 20 bbls of FW from cementers and 167.2 bbls of mud with rig pumps. Plugs bumped,floats held,CIP @ 0335 hrs. Monitor well,static. 03:45 06:00 2.25 SURFAC CEMENT PLUG P 2,520.0 2,520.0 RD cement head,LD LJ and flush Divertor and flowline.Clear running tools from floor. 06:00 09:00 3.00 INTRM1 NUND P 2,520.0 2,520.0 ND Divertor, NU wellhead body and test MMS to 1000 psi. NU BOPE. 09:00 10:30 1.50 INTRM1 RIGMNT RSRV P 2,520.0 2,520.0 Cut and slip drilling line,service blocks and T.D. 10:30 15:30 5.00 INTRM1 WELCTL BOPE P 2,520.0 2,520.0 RU and test all BOPE 250/3500 annular to 2500 psi. 15:30 16:30 1.00 INTRM1 P 2,520.0 2,520.0 Install wear bushing and change running tools to 5"". 16:30 22:30 6.00 INTRM1 P 2,520.0 2,520.0 PU and stand back 156 joints of 5""drill pipe. 22:30 00:00 1.50 INTRM1 PULD P 2,520.0 2,520.0 MU BHA#2. Well bores Wellbore Name Wellbore API/UWI CD1-17 501032035000 Section Size(in) Act Top(ftKB) Act Btm(ftKB). Start Date End Date 18 0.0 114.0 10/2/2000 1/1/2000 11 5/8 114.0 2,520.0 10/3/2000 9 2,520.0 13,193.0 10/11/2000 8 1/8 13,193.0 18,590 0 10/22/2000 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) I DLS(°I100ft) 0.00 0.00 0.00 0.00 0.001 0.00 0.001 0.00 Latest BOP Test Data Date Comment <. Page 111 Report Printed: 6/4/2012 Casing Detail Well: COI-17 41-14P't, PHILLIPS Alaska Inc.--7' intefrnediateCasin-----7-1 Date: 1011112.1 A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH rsit Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.33 FMC 11" X 7" Hanger 2.02 34.33 Jts 3 to 324 322 Jts 7" 26# L-80 BTCM Csg 13058.87 36.35 7" Davis Lynch Float Collar 1.40 13095.22 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 82.69 13096.62 7" Davis Lynch Float Shoe 1.70 13179.31 13181.01 1 SB centralizer per jt #1 -#16 1 SB centralizer every other jt #264-#322 Total -46 centralizers Use Best-a-Life 2000 pipe dope Remarks: Up Wt - k Dn VVt - k Supervisor: Mickey/Lutrick ---T--T--1---+-- -- Y--,---•---T---r.........T--,---•--- 1---•-- -,---T--T--1--- ---T--T-- --T-- -- t } w Y w . I-- 4 J IILU 111111 II II I1 , I 111111 p w 1 1 I I I . . 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(n o m c a w N N N ( II 11 E _ Y CD E a) _ _ _ _ _ UI N O o 2 Q o a a a a a . a a Z z '� w 8 8 S S S (~n 0 Z (j o_D 321flSS3Jd L � « O C1 a * — — Z Security Level: AK Development 0:44 " "efts t'I Daily Drilling Report CD1-17 ConocoPhillips Report Number: 11 Rig: DOYON 19 Report Date: 10/13/2000 AFE Type Network/ID# Total AFE+Sup 998C14 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-17 Development ALPINE 12.00 12.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date SAFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 10/2/2000 10/2/2000 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) PRODUCTION, 13,181.0ftKB Ops and Depth @ Morning Report 24hr Forecast SLIP AND CUT DRILLING LINE TEST CSG-0/0 CMT-PERFORM FIT-TRIP FOR DILLING ASSEMBLY Last 24hr Summary General Remarks Weather Head Count Supervisor Title MICKEY/LUTRICK, Supervisor Supervisor Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation. 00:00 01:00 1.00 INTRM1 CIRC P 13,193.0 13,193.0 Circ btms up F/7858' 01:00 06:00 5.00 INTRM1 CASE RUNG P 13,193.0 13,193.0 Continue running 7""26#L-80 MBTC csg-worked casing to btm f/12731'to 13181'-Landed on mandrel hanger in wellhead-Ran 324jts.total w/shoe @ 13181'&FC @ 13095' 06:00 06:30 0.50 INTRM1 P 13,193.0 13,193.0 R/D fill up tool-R/U cmt head&cmt lines 06:30 09:30 3.00 INTRM1 CIRC P 13,193.0 13,193.0 Pump sweep-Circulate and condition mud for cmt job-PJSM 09:30 11:30 2.00 INTRM1 CEMENT PUMP P 13,193.0 13,193.0 Cmt 7""csg.-pumped 5 bbls Arco wash -Test lines to 3500 psi-pumped 15 bbls Arco wash-50 bbls Arco spacer @ 12.5 ppg-drop btm plug-Mix&pump 27 bbls""G""@ 15.8 ppg-drop top plug w/ 20 bbls water f/Dowell-switch to rig pumps-displace cmt w/482.6 bbls mud (calc.481.5)Bumped plug w/1250 psi- floats held-CIP @ 11:30 hrs. Full returns 11:30 12:30 1.00 INTRM1 P 13,193.0 13,193.0 UD cmt head,landing jt.,casing equip. 12:30 13:30 1.00 INTRM1 P 13,193.0 13,193.0 Pull tbg spool bowl protector-flush stack -install 9 5/8""x 7""pack-off&test to 5000 psi 13:30 14:30 1.00 PROD WELCTL BOPE P 13,193.0 13,193.0 Change top pipe rams to 31/2""X 6"" variables 14:30 15:00 0.50 PROD RIGMNT RSRV P 13,193.0 13,193.0 Change saver sub in top drive to 3 1/2"" 15:00 20:30 5.50 PROD WELCTL BOPE P 13,193.0 13,193.0 Set test plug-test BOPE to 250-3500 psi w/annular to 2500 psi.Witness of test waived by AOGCC rep John Spalding.RD test equipment. Install wear bushing. 20:30 21:00 0.50 PROD P 13,193.0 13,193.0 Install bales and elevators. Prep to MU BHA. 21:00 21:30 0.50 PROD PULD P 13,193.0 13,193.0 MU BHA.Adjust motor. 21:30 00:00 2.50 PROD TRIP P 13,193.0 13,193.0 PU and RIH w/3 1/2""DP. Latest BOP Test Data Date Comment Page 1/2 Report Printed: 6/4/2012 flit/ Security Level: AK Development °t r �"` Daily Drilling Report sI II 61rI 11711"T" i77:,.:!... '7111141,41111.1011C 4 CD1-17 ���� ips _ Report Number: 11 'OoncscoPhIlp Rig: DOYON 19 Report Date: 10/13/2000 Wellbores Wellbore Name Wellbore API/UWI CD1-17 501032035000 Section Size(in) Act,Top(ftKB) Act Btm(ftKB) Start Date, End Date 18 0.0 114.0 10/2/2000 1/1/2000 11 5/8 114.0 2,520.0 10/3/2000 9 2,520.0 13,193.0 10/11/2000 8 1/8 13,193.0 18,590.0 10/22/2000 1Survey Data MD(ftKB) Inti(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS,(°1100ft) 0.00 0.00 0.00 0.001 0.00 0.00 0.00 0.00 Page 2/2 Report Printed: 6/4/2012 CD1 -24 Attachment Casing Detail 9.625" Surface Casing WELL: CD1-24 ARCO Alaska, Inc. DATE: 4/23/1999 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Landing jt. 46.50 TOPS Doyon 19 RKB to landing ring = 36.58' 36.58 FMC Gen V mandrel Hgr 2.43 36.58 27 Jts 9 5/8", 36#, J-55 BTC Jt#47 -Jt#73 1009.34 39.01 9 5/8" TAM port collar 2.93 1048.35 44 Jts 9 5/8" 36# J-55 BTC csg Jt#3 &Jt#46 1680.16 1051.28 9 5/8" Davis Lynch Float Collar 1.55 2731.44 2 Jts 9 5/8" 36# J-55 BTC csg Jt#1 &Jt#2 85.72 2732.99 9 5/8" Davis Lynch Float Shoe 1.76 2818.71 2820.47 TD>>> 2831.00 Rathole>>> 10.53 43 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, over stop collars and over casing collars on Jts. 3-12 and over collars of every 2nd jt to surface. 1 straight blade centralizer on Jt#46 and Jt#47 Remarks: MADE CSG UP WITH 9000 FT/LB TORQUE AND USE API MOD THREAD COMPOUND.. Doyon 19 Drilling Supervisor: Donald Lutrick Security Level: AK Development Drilling Daily Drilling Report &Wells CD1-24 Cc>noe+3Phillps Report Number: 3 Rig: DOYON 19 Report Date: 4/24/1999 AFE Type Network/ID# Total AFE'Sup 998605 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB)'Depth End(ftKB) CD1-24 Development ALPINE 3.00 3.0 0.0 0.0 Daily Mud Cost !Cumulative Mud Cost Daily Cost Total Cumulative Cost I Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/22/1999 4/22/1999 _ Last Casing String [ext Casing OD(In) Next Casing Set Depth(ftKB) SURFACE,2,820.5ftKB Ops and Depth @ Morning Report 24hr Forecast RIH W/PORT COLLAR TOOL. Last 24hr Summary General Remarks Weather Head Count - Supervisor Title DONALD LUTRICK, Supervisor Supervisor Time Log Start End Dur Time Depth Start Depth End Time Time (his) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class, (ftKB) (ftKB) Operation 00:00 01:00 1.00 SURFAC TRIP IP 2,831.0 2,831.0 POH. 01:00 02:30 1.50 SURFAC PULD P 2,831.0 2,831.0 LD BHA 02:30 03:00 0.50 SURFAC RIGMNT RSRV P 2,831.0 2,831.0 Service rig 03:00 03:30 0.50 SURFAC DRILL WIPR P 2,831.0 2,831.0 MU HO BHA. 03:30 06:00 2.50 SURFAC DRILL WIPR P 2,831.0 2,831.0 RIH to 2756'. Reamed f/1250'to 1474'. 06:00 06:30 0.50 SURFAC DRILL WIPR P 2,831.0 2,831.0 Wash and ream f/2756'to 2831'. 06:30 07:30 1.00 SURFAC DRILL WIPR P 2,831.0 2,831.0 Circ to/hi vis sweep 07:30 12:00 4.50 SURFAC DRILL DRLG Np DH 2,831.0 2,831.0 POH.Tight and packing off at 1865'. Back ream to 1104'. 12:00 13:00 1.00 SURFAC DRILL WIPR P 2,831.0 2,831.0 POH. 13:00 14:30 1.50 SURFAC DRILL WIPR P 2,831.0 2,831.0 LD BHA. 14:30 16:30 2.00 SURFAC P 2,831.0 2,831.0 Clear floor. RU to run csg. 16:30 17:00 0.50 SURFAC P 2,831.0 2,831.0 Held prejob safety meeting. 17:00 22:30 5.50 SURFAC P 2,831.0 2,831.0 RIH w/9 5/8""csg to 2821'.Push csg f/ 1600'to 2100'. No problems.LD fill up tool.MU hanger and land csg. 22:30 00:00 1.50 SURFAC P 2,831.0 2,831.0 Circ and condition mud. Wellbores Wellbore Name Wellbore API/UWI CD 1-24 501032029500 Section Size(in) Act Top(ftKB) Act Elm(ftKB) Start Date End Date 18 0.0 114.0 4/22/1999 11 5/8 114.0 2,820.0 9 2,820.0 10,771.0 8 1/8 10,771.0 13,706.0 8/5/2000 Survey Data MD(ftKB) not(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Latest BOP Test Data Date Comment Page 1/1 Report Printed: 6/4/2012 Security Level: AK Development Drilling Daily Drilling Report & cells CD1-24 Cr�ncac+ Phill)25 (` Report Number: 4 Rig: DOYON 19 Report Date: 4/25/1999 AFE Type I Network/ID# Total AFE+Sup 998B05 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-24 Development ALPINE 4.00 4.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/22/1999 4/22/1999 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) SURFACE,2,820.5ftKB Ops and Depth @ Morning Report 24hr Forecast MU BHA Last 24hr Summary General Remarks Weather Head Count Supervisor Title DONALD LUTRICK, Supervisor Supervisor Time Log Start End Dur Time Depth Start Depth End Time Time (hrs), Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 00:00 01:00 1.00 SURFAC CIRC P 2,831.0 2,831.0 Circ and condtion mud. 10 bpm at 1050 psi. Pumped celloflake as fluid cailper. Celloflake to surface at 50 bbls over guage hole. 01:00 04:00 3.00 SURFAC CEMENT PLUG P 2,831.0 2,831.0 Prejob safety meeting on cementing. Tested lines to 2500 psi.Pumped 100 bbls FW,50 bbls 10.5 spacer,395 bbls 10.5 lead(500 sx),49 bbls 15.8 tail(230 sx),20 bbls h20. Dispalce with mud with rig pumps. Bumped plug.Full returns throughout job. No cement to surface. 04:00 05:00 1.00 SURFAC P 2,831.0 2,831.0 RD csg equipment. RU to run DP. 05:00 06:00 1.00 SURFAC TRIP P 2,831.0 2,831.0 RIH w/port collar tool. Latch and open tool. 06:00 07:30 1.50 SURFAC P 2,831.0 2,831.0 Pump 5 bbls at 2 bpm at 500 psi. No I collar. and Close port co a Drop a d shear ball.RD. 07:30 08:30 1.00 SURFAC TRIP P 2,831.0 2,831.0 POH and LD tool. 08:30 12:00 3.50 SURFAC Np 2,831.0 2,831.0 Prep to run 1""CS Hydrill pipe. Unable to work mule into conductor pipe.Modify mule shoe.No success.Cut of 3""nipple on conductor. 12:00 14:30 2.50 SURFAC P 2,831.0 2,831.0 RIH w/1'"'pipe to TOC at 443'. 14:30 16:00 1.50 SURFAC CIRC P 2,831.0 2,831.0 Circ out 20 bbls cement.Pump 93 bbls FW. 16:00 19:00 3.00 SURFAC CEMENT PLUG P 2,831.0 2,831.0 Pumped 133 bbls 10.5 cement(168 sx) to fill annulus. 19:00 21:30 2.50 SURFAC NUND P 2,831.0 2,831.0 ND diverter.NU well head. 21:30 23:00 1.50 INTRM1 NUND P 2,831.0 2,831.0 NU BOPE. 23:00 00:00 1.00 INTRM1 WELCTL BOPE P 2,831.0 2,831.0 Install test plug.Test BOP to 300-4000 psi. Welibores Wellbore Name Wellbore API/UWI C D 1-24 501032029500 Section Size(in) Act Top(ftKB) Act Btm(EKE) Start Date End Date 18 0.0 114.0 4/22/1999 11 5/8 114.0 2,820.0 9 2,820.0 10,771.0 81/8 10,771.0 13,706.0 8/5/2000 Latest BOP Test Data Date Comment Page 1/2 Report Printed: 6/4/2012 iSecurity Level: AK Development, Driiliksw Daily Drilling Report &Wc CD1-24 ConocoPhillips laf ` Report Number: 4 04,44,1 Rig: DOYON 19 Report Date: 4/25/1999 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Page 212 Report Printed: 6/4/2012 Casing Detail 7"Intermediate Casing WELL: CD1-24 ARCO Alaska, Inc. DATE: 5/3/1999 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH 7" DAVIS LYNCH FLOAT SHOE 1.18 10771.00 2 jts 7"26# L80 BTM CSG 79.09 7" DAVIS LYNCH FLOAT COLLAR 1.40 10715.36 263JTS (JTS#3-#265) 7"26# L80 BTM CSG 10628.41 1 PIECE (JT#266) 7" 26# L80 BTM 25.92 (LANDED CSG WITH 140K ON SLIPS) RT TO CSG HEAD LDS 35.00 7" csg set AND CEMENTED @ 10771.00 RUN ONE STRAIGHT BLADE CENTRALIZER ON JTS#1 -#29, AND JTS# 31,33,35,37,39,41,43,45, AND#47. TOTAL 38 STRAIGHT BLADES. RUN ONE BOW SPRING CENTRALIZER ON JTS# 196,197,AND 198. TOTAL 3 BOWSPRINGS. DRIFTED TO 6.151" USED BEST-O-LIFE 2000 DOPE MAKE EVERY JT UP TO BASE OF TRIANGLE RUN PIPE SLOW- KEEP IT FULL - RECORD DISPLACEMENT WASH TO BTM WITH FILL UP TOOL AND CIRC BEFORE MU CMT HEAD WILL DISPLACE CMT WITH RIG PUMPS @ 8 BPM. Remarks: RAN CSG AND LANDED ON LANDING RING - LOST 20 BBLS MUD RUNNING CSG. UNABL TO CIRC - PACKED OFF AND PUMPING IN. CSG STUCK WITH SHOE AT 10771. 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CON• N, y y y y -- m m - - - - - - - - -- ••< m -( Security Level: AK Development Dri1I' Daily Drilling Report &Wei CD1-24 CcivcoE'hiuips Report Number: 13 Rig: DOYON 19 Report Date: 5/4/1999 AFE Type Network/ID# Total AFE+Sup -'- 998B05 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-24 Development ALPINE 13.00 13.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/22/1999 4/22/1999 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) PRODUCTION, 10,771.0ftKB Ops and Depth @ Morning Report 24hr Forecast FREEZE PROTECT 9 5/8""X 7""CSG/NU BOPS Last 24hr Summary General Remarks Weather Head Count Supervisor _ Title MIKE WHITELEY, Supervisor Supervisor Time Log Start End Dur Time - Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 00:00 10:00 10.00 INTRM1 P 10,796.0 10,796.0 RAN 7""26#L80 BTM CSG TO 10787'. HOLE TOOK 20 BBLS WHILE RUNNING PIPE. 10:00 16:00 6.00 INTRM1 Np DH 10,796.0 10,796.0 WORK PIPE AND ATTEMPT TO BREAK CIRC.HOLE PACKED OFF- PUMPING INTO FORMATION AT 1-2 BPM 650 PSI.SWABBING BACK SOME RETURNS WHEN MOVING PIPE UP. LOST+/-400 BBLS MUD.MUD WT OUT 10.3+.STUCK 7""CSG-SHOE AT 10,771'. 16:00 16:30 0.50 INTRM1 Np DH 10,796.0 10,796.0 WORKED STUCK CSG PULLING 125K OVER UP WT. NO MOVEMENT. 16:30 19:00 2.50 INTRM1 CEMENT PLUG P 10,796.0 10,796.0 PJSM. ESTABLISHED PUMP RATE WITH MUD-8 BBPM @ 1,140 PSI. PUMPED TOTAL 72 BBLS.DOWELL CEMENTED 7""WITH SHOE AT 10,771'.PUMPED 20 BBLS ARCO WASH,50 BBLS SPACER AT 12.5 PPG,AND 58 BBLS CEMENT AT 15.8 PPG.DISPLACED WITH 77 BBLS FW AND 333 BBLS 9.2 BRINE AT 7 BPM. HAD 30%-40%RETURNS WITH CEMENT OUT SHOE.CSG STUCK- DID NOT RECIPICATE. BUMPED PLUG AND PRESS UP TO 3,500 PSI.WELL FLOWING BACK-CLOSED HYDRIL ON 7""CSG.-150 PSI SICP.CIP 1900 HRS. 19:00 19:30 0.50 INTRM1 CEMENT PUMP P 10,796.0 10,796.0 HELD 3,500 PSI ON CSG FOR 5 MIN. HELD. FLOATS HELD. 19:30 00:00 4.50 INTRM1 CEMENT Np DH 10,796.0 10,796.0 WOC-CLEAN PITS,CHANGED SHAKER SCREENS, LOAD TBG IN PIPE SHED, PREPARE TO PU BOP'S. Well bores Wellbore Name Wellbore API/UWI CD1-24 501032029500 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date 18 0.0 114.0 4/22/1999 Latest BOP Test Data Date Comment Page 1/2 Report Printed: 6/4/2012 a !Phl Security Level: AK Development t , " '"' Daily Drilling Report ..&1102t We il 4'1401 4 --,-,a,4-- )iJeI CD1-24 Report Number: 13 ConocoPhillips if Rig: DOYON 19 Report Date: 5/4/1999 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date 11 5/8 114.0 2,820.0 9 2,820.0 10,771.0 8 1/8 10,771.0 13,706.0 8/5/2000 Survey Data MD(ftKB) Incl(°) Azm(°) I , TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 , Page 2/2 Report Printed: 6/4/2012 Security Level: AK Development !C� Daily Drilling Report a.WcIIs . i C D 1-24 ConocoPhillips Report Number: 14 Rig: DOYON 19 Report Date: 5/5/1999 r3l 7 AFE Type - Network/ID# - Total AFE«Sup 998605 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) CD1-24 Development ALPINE 13.67 14.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 4/22/1999 4/22/1999 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) OPEN HOLE, 13,706.0ftKB Ops and Depth @ Morning Report 24hr Forecast RIG RELEASED-BALL MILL RELEASED AT 14:45 HRS Last 24hr Summary General Remarks Weather Head Count Supervisor Title - r MIKE WHITELEY, Supervisor Supervisor Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 00:00 01:00 1.00 INTRM1 CEMENT Np DH 10,796.0 10,796.0 WOC. 01:00 01:30 0.50 INTRM1 CEMENT Np DH 10,796.0 10,796.0 NO PRESSURE ON ANNULUS.OPEN HYDRIL.OBSERVE WELL. PU STACK. 01:30 02:30 1.00 INTRM1 CEMENT Np DH 10,796.0 10,796.0 SET SLIPS ON 7""CSG.LANDED 7"" CSG WITH 140K ON SLIPS. CUT OFF 02:30 03:00 0.50 INTRMI CEMENT Np DH 10,796.0 10,796.0 LAY DOWN LANDING JT,HANGER, AND PIECE 7"". 03:00 03:30 0.50 INTRM1 CEMENT Np DH 10,796.0 10,796.0 SET BOP'S BACK. 03:30 05:30 2.00 INTRM1 CEMENT Np DH 10,796.0 10,796.0 MAKE FINAL CUT AND DRESS STUB. 05:30 06:00 0.50 INTRM1 P 10,796.0 10,796.0 INSTALL 7""PACK OFF AND TEST TO 3,500 PSI. 06:00 06:30 0.50 INTRM1 CEMENT 'Np DH 10,796.0 10,796.0 NU BOPS. 06:30 10:00 3.50 INTRM1 CEMENT Np DH 10,796.0 10,796.0 RIH PICKING UP 51 JTS 4.5""TUBING. M.U.HANGER AND INSTALL TWCV. MAKE UP LANDING JT.LAND TUBING AND RILDS.FREEZE PROTECTED 9 5/8""X 7""ANNULUS TO 1.600'. PUMPED 150 BBLS WATER/50 BBLS DIESEL. 10:00 10:30 0.50 INTRM1 P 10,796.0 10,796.0 CLEAR RIG FLOOR OF CSG/TUBING HANDLING TOOLS. 10:30 12:00 1.50 INTRM1 NUND P 10,796.0 10,796.0 ND BOP'S. 12:00 13:30 1.50 INTRM1 NUND P 10,796.0 10,796.0 NU ADAPTOR FLANGE AND 4 1/16"" 5M TREE.TEST TO 3500 psi. Held. Pulled TWCV. 13:30 15:00 1.50 INTRM1 CIRC P 10,796.0 10,796.0 RU TO CIRC. FREEZE PROTECT 4.5"" TUBING/ANNULUS TO 1625'. PUMPED 150 BBLS WATER AHEAD/ 48 BBLS DIESEL. 15:00 15:30 0.50 INTRM1 P 10,796.0 10,796.0 SET BPV. INSTALLED GAGES.RIG RELEASED @ 15:30 HRS 5-5-99. 15:30 16:00 0.50 INTRM1 P 10,796.0 10,796.0 CLEAN CELLAR Wellbores Wellbore Name Wellbore API/UWI CD 1-24 501032029500 _ Section Size(in) Act Top(ftKB) Act Etm(ftKB) T. Start Date End Date 18 0.0 114.0 4/22/1999 11 5/8 114.0, 2,820.0 Latest BOP Test Data Date Comment - Page 1/2 Report Printed: 6/4/2012 „k .. Security Level: AK Development �,.„,--.0,,, $-, - Daily Drilling Report ''''',1011110111701b6' ICD1-24 �dliX, Amp Report Number: 14 ConocoPhiillips Rig: DOYON 19 Report Date: 5/5/1999 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date 9 2,820.0 10,771.0 8 1/8 10,771.0 13,706.0 8/5/2000 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Casing Strings String OD String Wt Casing Description Run Date (in) (lbs/ft) String Grade Set Depth(ftKB) Comment _. OPEN HOLE 5/5/1999 6 1/8 13,706.0 Page 2/2 Report Printed: 6/4/2012 WD-02 Attachment Casing Detail 9.625" Surface Casing WELL: WD-2 ARCO Alaska, Inc. DATE: 3-12-99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Landing jt. TOPS Doyon 19 RKB to landing ring = 38.35', RKB to GL = 36.70' 38.35 FMC Gen V mandrel Hgr 1.95 38.35 jts#42-#65 9 5/8", 36#, J-55 BTC 1022.61 40.30 9 5/8" TAM port collar 3.00 1062.91 jts#3-#41 9 5/8" 36#J-55 BTC csg 1646.46 1065.91 9 5/8" Davis Lynch Float Collar 1.52 2712.37 jts#1-#2 9 5/8" 36# J-55 BTC csg 84.50 2713.89 9 5/8" Davis Lynch Float Shoe 1.73 2798.39 2800.12 2800.12 TD of 12 1/4" Hole 2810'. 37 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, over stop collars and over casing collars on Jts. 3-12 and over collars of every 2nd jt to surface. Run 2 Ridged centralizers on jt,#41 & 42. Remarks: MADE CSG UP WITH 9000 FT/LB TORQUE AND USE API MOD THREAD COMPOUND.. Doyon 19 Drilling Supervisor: M.C. HEIM Casing Detail 7" & & 7 5/8" Production Casing WELL : WD-2 ARCO Alaska, Inc. DATE : 3/31/1999 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 19 RKB TO BRADEN HEAD LDS 35.00 TOPS 39 Jts 7 5/8" 29.7# L-80 STL-FJ Csg Jt#226 - 264 1605.96 -22.12 XO - L-80 7 5/8" STL-FJ x 7" BTCM 1.32 1583.84 212 Jts 7" 26# L-80 BTC-M Csg Jt#2 -213 8574.27 1585.16 Davis Lynch Float Collar 1.43 10159.43 Jt"A" 7" 26# L-80 BTC-M Csg 40.07 10160.86 1 Jt 7" 26# L-80 BTC-M Csg Jt#1 41.37 10200.93 Davis Lynch Float Shoe 1.70 10242.30 10244.00 TD 10244.00 Leave out 11 jts 7 BTC - Jt#214 - 225 • Leave out 1 jt 7 5/8" STL - Jt#265 Run 67 straight blade centralizers on jt#1 -#67 Run 12 straight blade centralizers on jts #69, 71, 73, 75, 77, 79 81, 83, 85, 87, 89, 91 Torque STL to 5000 ft lbs. Need 600 bbls 80 deg water for cement Remarks: Doyon 19 Drilling Supervisor: Donald Lutrick Z - - C) O 3 M PRESSURE -0 C) m V) U) ((�� - - .-- + +N N - N.N(��N(N(,� NN NC m Cn — Z H O O O O O O O O O O O O O O O O O O O O O O O O O O O O46 K 5 Z ......................000.0.0 70 co N. a-N. a a a a a a N a a a a a FL, FL, 13. 12 N 13.13.13.13.13. N N a N 00 CD 0 - E-7,- _. ._. II II N N 3 m O O m 3. N cn F o o 0) y o F m (n a r C F. - W con c .. 0 E CU * 13 N V ao Z = cn a°< ` o. O _ - co + m 0m m - r? I K o ° D R1 c N O __5 cc, C) 3 co. .a c -. Z G7 j ► - p a Ul CD _0 0- .-- Z N - _ � w CO = co °m rn C _ Wa, O o 0 —I G) --I _ 1— or C) C`< W X m CP c:3- ao A -I CA : R1 D m r - * - r c ctOc —i _ CD CO c co vi 1 _ I I II cfl `� v U) I } _ o A o o = 3 -I D O D m A con -4 0 = CQ Cl) CD m - N.) V -0 O 0- O C m - _ci) x 1 ' - r a x 01 o m CD 7 a N Z C 0 _nO ` ! N p = N o, co. = o K ✓ m -1 _, -n _\ o v c Cr w2cnm - O � m o ° m cn - —mm + m 3 I m _ 2 - CO 03 cif). n Z g z _ mr" v 0 . - m Z - Cn o O CO CO V OCT A CO N --A O c 3 -I 60000000000 -. O O c !n 33333333333 ? -1z m r -1 5- 5zz = mmz = zmE cn m rco V C 4 cn A W N O CO COV 01 O A W N -� O M 0 .. .. .► .. .. .. .. .► .+ 7C 7C 7C 7C 7C 7C• 7C• 7C• 7C• 7r 7; UU, N M N Ute! N N N N y y N N U) Ul Ul U) U! N N y -•_ • -4ia 4 L � � 4i � is L � D -1 > CT cm CT cm cm N cn cn cm ()f _% CO CO CO V C3) CT A W N 1;1 -I N N N N N W W W A cn CD E O CA O W CAN A W -& ACO CAA W C.4 N CJ -1 O m D = 0 0 0 0 0 0 0 0 0 0 0 m O O O 0 O O O O O O O O 0 O O O O O Cn 10 13 13 13 'O 73 13 'a 'a V '8 CO m CO a 13 'O 'O -a a -a 'a '8 'a 'a 'a -a 13 -a v a c =• u) u) u) y u) y y y y N•N C,, N co u) u) u) u) y y y y y y y y y y y y • m r — — — — — — — — - c _, — — — — — — — — — A O m I -' _ CAOCTOcnc) . V OCJI ? CO N � Oc u) Z0 0 0 0 0 0 0 0 0 0 0 0 0 0 -. O 0 c 0 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 2 m A m D com Z m N N N i CO CO V CD cn A CO N j O - V CA O CA A W N -► O .. .. .. x .. .. .. .+ 51 7C 7C fT 7; 7i 7C 7C 7C 7C N x rn m = cn co N N CI) CA N U) N Vl N Ul Vl M N N N N NGO m N N N N N N N N N N N N NNN1 N N -k. — O A v D r NCrffJtCiCUftTCT VtcTtJttTcT cTC7Ccnz NN V W z m 000000000000 0 001 m cn V N C 0 Oy D -A O O O O O O O O O O O O O O O A 0 0 0 0 -C7 y m 1, 1313131373 .3 -3137373 -515 -3 -0 y 131573 .3 v a v, N . . U7 cn U! U! u) Ul cn cn. UJ. cn cn U!• CA. CA. CA• -. -. m . UC m U! N cn - - - - -< m Security Level: AK Development -!lin Daily Drilling Report WD-02 Ii11H;! Report Number: 5 QonocoPhillips Rig: DOYON 19 Report Date: 3/13/1999 AFE Type — Network/ID# Total AFE+Sup 998B01 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) WD-02 Development ALPINE 5.00 5.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 3/9/1999 3/9/1999 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) SURFACE,2,800.1ftKB Ops and Depth @ Morning Report 24hr Forecast PROGRAM&INSTALL SOURCE IN MWD. Last 24hr Summary General Remarks Weather Head Count Supervisor Title M.0 HEIM, Supervisor Supervisor Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) )ftKs) Operation 00:00 01:00 1.00 SURFAC P 2,810.0 2,810.0 Finish running 65 jts.9 5/8""36#J-55 csg. 01:00 02:00 1.00 SURFAC P 2,810.0 2,810.0 R/D csg.fill up tool=blow down top drive=m/u landing jt.=land csg.@ 2800'=install cementing head. 02:00 03:30 1.50 SURFAC CIRC P 2,810.0 2,810.0 Break circ.=stage circ. rate f/2 bpm to 10 bpm=circ.while preping dowels f/ cement job. 03:30 06:30 3.00 SURFAC CEMENT PLUG P 2,810.0 2,810.0 PJSM w/all hands on cementing procedures=Test lines to 2500#=Cement well as per program=full circ.thru out job=reciprocate pipe thru out job. Bumped plug on calculated strokes=recovered 69 bbl.cement returns @ 10.8#. 06:30 09:00 2.50 SURFAC CEMENT PLUG P 2,810.0 2,810.0 Wash out riser=work&wash out annular preventer=l/d cement head-landing jt.& csg.equipment. I 09:00 12:30 3.50 SURFAC NUND P 2,810.0 2,810.0 N/d flowline=riser=diverter line=annular preventer=etc. 12:30 18:00 5.50 SURFAC NUND P 2,810.0 2,810.0 N/u bop,s=riser=flowline&shorten riser. 18:00 00:00 6.00 SURFAC P 2,810.0 2,810.0 Pick up riser&test plug=test bope& choke manifold 250-4000#. Wellbores Wellbore Name Wellbore API/UWI WD-02 501032028500 Section-. Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date ' End Date 18 0.0 137.0 3/9/1999 1/1/1999 11 5/8 137.0 2,800.0 3/13/1999 9 2,800.0 10,255.0 4/4/1999 Survey Data 0.00 _ 0.00 0.00 0.00 0.00 0.00 0.00 . x )0.00 MD(ftKB) _ Incl(°) Azm(°) ND(ftKB) VS(ft) NS(ft) Eyy(fl) DhS moon Latest BOP Test Data Date Comment Page 1/1 Report Printed: 6/5/2012 Security Level: AK Development rilii Daily Drilling Report WD-02 +Connaal'hillipg Report Number: 23 fiusr, Rig: DOYON 19 Report Date: 3/31/1999 AFE Type NetworldID# Total AFE+Sup 998601 Wellbore Well Type Field Name DFS(days) DOL Depth Progress(ft) Depth Start(ftKB) Depth End(ftKB) WD-02 Development ALPINE 23.00 23.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost Actual Start Date Original Spud Date AFE Dur Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 3/9/1999 3/9/1999 Last Casing String Next Casing OD(in) Next Casing Set Depth(ftKB) PRODUCTION 7.625"x7"@ 1619', 10,279.0ftKB Ops and Depth i Morning Report 24hr Forecast TESTING BOP'S Last 24hr Summary General Remarks Weather Head Count Supervisor .. - Title - _... DONALD LUTRICK, Supervisor Supervisor Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 00:00 00:30 0.50 PROD P 10,255.0 10,255.0 CIRC WITH 7""CSG AT 8,800'. 00:30 01:30 1.00 PROD P 10,255.0 10,255.0 CHANGE HANDLING TOOLS FOR 7 5/8""CSG. 01:30 03:30 2.00 PROD P 10,255.0 10,255.0 RIH WITH 7 5/8""CSG.SHOE AT 10,230'. 03:30 05:30 2.00 PROD P 10,255.0 10,255.0 LAY DOWN FILL UP TOOL.MAKE UP LANDING JT AND CEMENTING HEAD. BREAK CIRC. 05:30 11:00 5.50 PROD P 10,255.0 10,255.0 CIRC AND COND MUD AND HOLE FOR CEMENT JOB.RECIPICATE PIPE. ESTABLISH CIRC RATE 8 BPM- 1,050 PSI. FULL RETURNS.NO MUD LOSS. 11:00 14.00 3.00 PROD CEMENT PUMP P 10,255.0 10,255.0 PJSM-CEMENTING.TEST LINES TO 3,500 PSI.DOWELL CEMENTED 7""X 7 5/8""CSG PUMPING 20 BBLS PREFLUSH,50 BBLS ARCO SPACER @ 12.5 PPG, 1800 SX CL""G""(367 BBLS) AT 14.6-15.8 PPG.DISPLACED WITH 9.0 PPG BRINE AT 6-8 BPM. PLUG BUMPED 37 BBLS EARLY.DID NOT HAVE FULL RETURNS PUMPING LAST 100 BBLS DISPLACEMENT. PLUG DOWN AND JOB COMPLETE @ 1400 HRS. FLOATS HELD.MUD FALLING IN 9 5/8""ANNULUS. 14:00 16:00 2.00 PROD P 10,255.0 10,255.0 MONITOR WELL ON TRIP TANK. START N.D.STACK.LOST TOTAL 15 BBLS IN 2 HRS.FINAL LOSS RATE 1.5 BPH. 16:00 18:00 2.00 PROD WELCTL BOPE P 10,255.0 10,255.0 P.U. BOP'S. LANDED 7""X 7 5/8""CSG WITH 120K ON SLIPS.CUTOFF CSG. 18:00 21:30 3.50 PROD P 10,255.0 10,255.0 L.D. LANDING JT.MOVE BOP'S.MAKE FINAL CUT AND BEVEL 7 5/8""CSG. 21:30 00:00 2.50 COMPZN WELCTL BOPE P 10,255.0 10,255.0 INSTALL 7 5/8""PACK-OFF.N.U. BOP'S.TEST PACK-OFF TO 3500 psi for 15 min. Latest BOP Test Data Date, I Comment Page 1/2 Report Printed: 6/5/2012 Security Level: AK Development Daily Drilling Report ►� � � of WD-02 �ililp5 Report Number: 23 All ka Rig: DOYON 19 Report Date: 3/31/1999 Welibores Wellbore Name Wellbore API/UWI WD-02 501032028500 Section Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date 18 0.0 137.0 3/9/1999 1/1/1999 11 5/8 137.0 2,800.0 3/13/1999 9 2,800.0 10,255.0 4/4/1999 Survey Data MD(ftKB) Incl(°) Jf I Azm(°) I fl TVD(1IKB) VS(ft) NS(ft)..... _ EW(ft) DLS(J100ft), -- 0 0 0 0 0.00 0.00 0.00 0 0 0.00 ao Page 2/2 Report Printed: 6/5/2012 Alpine CD1 -15 Operational Shut Down Status — 06.15. 0 J Existing wellbore depths based Lon actual rig surveys 16"Conductor to 114' 5/19/2010 i 10-3/4"45.5 ppf L-80 BTC-M1 Surface Casing Actual 3,112'MD 12393'TVD Cemented to surface 1. 11 Ilk, Calculate TOC f 4,908' MD/2,811'TVD i TAM Port Collar / 3,039'TVD(5,872'MD) �_",� Calculated TOC - 8,986'MD 13,768'TVD C HES Stage Tool 4,022'TVD(10,070'MD) S \_, Cement Retainer#2 Depth 19,705' MDI 6,281'TVD Calculated TOC 'i" 18,737'MDI 6,052'TVD am"` 10 i =i iri IIIP 7-5/8"Cement Retainer#1 '',_-_� 20,085'MD/6,370'TVD t_ Thik 7-5/8"Casing Shoe CD1-15PB2 20,223'MD/6,404'TVD 6.75"Sidetrack CD1-15 PBI 20,114'MD/6,377'TVD TD 9-7/8"Hole 20,700'MD/6,514'TVD Note to File CD1-15 (210-047 312-204) Colville River Unit (Alpine Oil Pool) ConocoPhillips Alaska, Inc ConocoPhillips has made application for annular disposal for the subject well for an estimated disposal of 35,000 barrels. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well (CD1-15). -- 10 3/4" Surface casing was cemented to surface successfully with good returns throughout. No problems were reported. Approximately 229 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 49% XS of the calculated hole volume. -- On the initial leak off test (LOT)for the surface casing shoe dated 5/4/10, the pressure slope rises smoothly to -16.6 EMW and continues at a slightly shallower slope to 17.6 EMW. Minimal fluid was pumped in. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7 5/8" casing was run and successfully cemented. Good returns were noted and the casing was reciprocated. The C10 sand unit was covered in the third stage (37 bbls) of the cement job. TOC for the third stage is estimated to be at 4770' md. --An initial injectivity test ( LOT #1) down 7 5/8" X 10 3/4" annulus was conducted on 5/30/2012. Pressure steadily increases until the break at 13.6 EMW. The pressure increased with additional pumping to 14.6 ppg EMW. During the observation period, the pressure stabilized at 15.0 ppg EMW. --Approximately 23 wells are within the 1/4 mile area of review. Three wells are within 200' of the most likely disposal interval in the CD1-15 annulus and include CD1-05, CD1-9 and CD1- 13. Examination of the cementing information did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, approval of ConocoPhillips' request for the subject well is recommended. 5 Jo Victoria Fergusoni,JJ ©r, , Sr. Petroleum Engineer - June 14, 2012 ✓ ig 11 f� Alpine CD1 -15 Operational Shut Down Status — 06.15.10 Existing wellbore depths based on actual rig surveys 16"Conductor to 114' 5/19/2010 10-3/4"45.5 ppf L-80 BTC-M Surface Casing Actual 3,112'MD/2393'TVD L Cemented to surface Calculate TOC I 4,908' MD/2,811'TVD ' TAM Port Collar i i� 3,039'TVD(5,872'MD) ���� Calculated TOC 8,986' MD/3,768'TVD '; HES Stage Tool \__ . O 4,022'TVD(10,070'MD) �0 Cement Retainer#2 Depth 19,705' MD/6,281'TVD . . ;":\ Calculated TOC 18,737'MD/6,052'TVD 'NN ,Iii!,. Qi! lii In lii 7-5/8"Cement Retainer#1 iJ'Gi7i gti-.....1. 20,085'MD/6,370'TVD i 7-5/8"Casing Shoe CD1-15PB2 20,223' MD/6,404'TVD 6.75"Sidetrack CD1-15 PBI 20,114'MD/6,377'TVD TD 9-7/8"Hole 20,700' MD/6,514'TVD Note to File CRU CD1-15 (PTD 2100470) June 8, 2012 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Additional Drilling Wastes within Well CD1-15 Request ConocoPhillips requests approval to dispose of 35,000 barrels of drilling waste in well CD1-15. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 7-5/8" surface casing shoe is set in this well at -2,338' true vertical depth subsea', near the base of a 450-foot thick shale and claystone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of silty sandstone and sandstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed additional annular injection activities will lie within a radius of about 115' from the wellbore. 8. If injected wastes reach nearby wells, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the approved disposal interval. Discussion ConocoPhillips' application was reviewed along with records from seven nearby wells.' The discussion that follows is based on well logs and mud logs from these wells. Index maps are provided in Figures 1 and 2,below. The proposed annular disposal injection interval in these wells lies in the Seabee formation within Sections 32 and 33, T12N, R5E, Umiat Meridian, which is about 3-1/2 miles from the current exterior boundary of the Colville River Unit. The surface casing shoes of these wells mainly lie between about -2,300' and to -2,350', near the base of a 450-foot thick interval that is dominated by claystone and shale and is continuous throughout the area. This claystone and shale interval will provide upper confinement for fluids disposed in the annulus of the well(see Figure 3,below). Unless otherwise noted,all depths presented herein are expressed as negative integers,which represent feet,true vertical depth below mean sea level(mean low,low water). All thicknesses are expressed as positive integers,which represent true vertical feet.All horizontal distances are expressed as positive integers,which represent feet. 2 Bergschrund I,Bergschrund 2,Bergschrund 2A,CRU CD1-02,CRU CD1-15,CRU CD1-22,and CRU WD-02 CD1-15 Annular Disposal June 8, 2012 Note to File Page 2 of 6 The annulus open to the disposal interval extends downward from the surface c,isia shoe at-2,340' to the top of cement for the 7-5/8" casing string, which is estimated to be -2,820'. The portion of the open annulus that will most likely accept the injected waste is a 100-foot thick interval containing several 1-to 3-foot thick beds of silty sandstone and sandstone that lies below the surface casing shoe between about -2,360' and -2,460'. The aggregate thickness of these thin,potential receptor beds is about 20'. The silty sandstone and sandstone beds are separated by thin shale and claystone intervals. Beneath the disposal interval is a 55-foot thick interval of shale, claystone and tuff that is continuous throughout the area. This interval, which lies between about -2,540' and -2,595', will provide lower confinement for any injected wastes. Four prominent, underlying, laterally continuous beds of claystone and shale that will provide additional lower confinement are also illustrated on Figure 3. CD1-01 CD1-19A I ' N - C RU D i" �.�'P >' �'- • h, \ CD1- 2\%.F, {., ;. r .� 11'I \ , r \\,43 I \ Review circ s CD1-15 mile radio,) Open / 1 t r.k \ Annulus Surface casing shoe marker 40,:-,.: i\ xz �`r cc lent m ffkeL-"— �� ; , / ,/4,:/ .• ..i .. A CD1-15 A la 11 vu-o2 CD1-0 AAAIA A A A A -4 CD1-04 A A A A A .\ Most ---t-,,,, , , : r ' `,a Likely ``-- . CD1-13 .,x CD! A Disposal [)1_1 Drill Site � � Interval " a.D1= A- 1, y. ,t �. , 0' 1000' Figure 1. CD1-15 Index Map (All depths shown are true vertical feet below sea level. The magenta-colored line depicts the path of the cross-section displayed in Figure 3.) The index map above displays trajectories for all wells drilled from and near the Colville River Unit CD1 Drill Site. Short tick-marks have been placed along each well trajectory at intervals of 500' true vertical depth below sea level, and they are labeled every 1,000'. The few bottom-hole locations visible on the map are represented by gray circles that measure 300' in diameter and well names are labeled using gray- colored text. The locations of the surface casing shoes for all well bores are illustrated using green- colored triangles, and the calculated locations of the tops of cement for production casing strings or liners for a few of these same wells are indicated by orange-colored semi-circles. The portions of each well CD1-15 Annular Disposal June 8, 2012 Note to File Page 3 of 6 bore that lie between the surface casing shoe and the top of production string cement are all assumed to be filled only with drilling mud, and are therefore possibly open to communication. The 'A-mile radius area of review (more correctly, a cylinder of review) surrounding the proposed disposal interval in CD1-15 is highlighted on Figure 1, above, by two blue circles; the left-most circle is centered at the location of the surface casing shoe, and the right-most circle is centered on the calculated top of cement for the production casing string. For a clearer view, Figure 2, below, displays an enlarged index map with a blue circle of 500-foot radius centered on the surface casing shoe of CD1-15. -5000 -3NB 1000 4500 f Most -4500 � Surface casing shoe marker' -SO° Likely -350 1 � , /\T ' 000 -6500 \ CD1-04 Disposal -5100 y � / f -4000 2.500 Interval 2500 ! -5500 F / WD-02 00 , -6000 5008 X7000 60{x'00 cel-15 ` i5Ra 55t: -2000 III 1-02 200 ; cas shoe •gi ;ani / -5500 2�'• at-2, I' 7110 j CDI-15 .. Ilik 0 - f ag500 CD - {500 -2,360' -80Q0 1 -15Q0 -4500 y R -BJU.; -2 _ 2500CD1-05 e0 -1500 0coA A -2000 CD1-15 �CD1-06 R•o 1-09 Open A 2500. 2500 2500 Annulus 20. ® 2000 RO - . -1500 500-foot radius circle 't15 2000 2000A =15R�1 2000 23002500 A2 0u -2 -21300 200, _15000 -2500 0' �..: 500' 50[) -1500 Figure 2. Enlarged CD1-15 Index Map (All depths shown are true vertical feet below sea level. The magenta-colored line depicts the path of the cross-section displayed in Figure 3.) In CD1-15, the open annulus lies between-2,340' to -2,820', with the most likely waste-disposal interval between -2,360' and -2,460' (see Figures 2 and 3, below). Approximately 23 wells are open to these same strata within the %-mile radius area of review.3 Portions of only seven of these wells lie within 500' of the surface casing shoe of CD 1-15; they are: CD 1-02, CD 1-04, CD 1-05, CD 1-06, CD 1-09, CD 1-13, and WD-02. Since WD-02 passes deeply beneath CD 1-15, only the CD 1-02, CD 1-04, CD 1-05, CD 1-06, CD1-09, and CD1-13 wellbores pass within 500' (horizontally or vertically) of the most likely disposal interval within the open annulus of CD1-15. 3 CD1-01,CD1-02, CD1-03,CD1-04,CD1-05,CD1-06,CD1-07,CD1-08,CD1-09,CD1-10,CD1-11,CD1-12,CDI-13,CDI- 14,CD1-15,CD1-16,CD1-17,CD1-19,CD1-22,CD1-23,CD1-24,CD1-25 and WD-02 CD1-15 Annular Disposal June 8, 2012 Note to File Page 4 of 6 NW 1982580 2001170 2100470 1952160 SE 501032028500 501032034600515' 501032061900 7048' 501032023200 4 332' * ► 4 ► CONOCOPHILLIPSALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK ARCO COLVILLE RIV UNIT WD-02 COLVILLE RIV UNIT CD1-04 COLVILLE RIV UNIT CD1-15 BERGSCHRUND 2 444 FSL 2052 FEL 243 FNL 2551 FWL 322 FNL 2805 FEL 964 FNL 1370 FWL TWP:12 N-Range:5 E-Sec.32 TWP:11 N-Range:5 E-Sec.5 TWP:11 N-Range.5 E-Sec.5 TWP.11 N-Range:5 E-Sec.9 ff.— off mE - :: Effeil iii ,000 ---.... „se — . - l _. .. -,000• ,.. ' ""` .1500 me wee „m Base of - •• Base of ,- Pe4 mafrost 1 Permafrost _ r HSurface _ -- Casing -A _ - Shoes Upper - Confining _ .' j , dost k __Interval _ 1, 1_ikeh Disposal2500 - - 1 N Interva5. Open _ - t - , ./...- �i nnulu Lower — -_F. - t - - Confinin- - b ; _ – Beds it wo € _ {, —.1.4-. � - i .3500 f — _ I i v 47. a# . TD=10255 TD=13977 TD=20700 TD=8600 Figure 3. CD1-15 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level;separation distance between wells is measured between the surface casing shoes) Figure 3, presents a structural cross-section view of CD1-15, nearby well CD1-04 and WD-02 and Bergschrund 2, which were both logged to surface using gamma-ray and resistivity tools. Resistivity measurements indicate that the base of permafrost occurs at about -1,450' in the CD1 Drill Site area, which is about 900' above the top of the proposed disposal interval. The shallow geologic section in the area surrounding the CD1 Drill Site contains methane gas. Mud logs were recorded in only four wells drilled in the vicinity of Drill Site CD1: Bergschrund 1, Bergschrund 2, Bergschrund 2A and CD1-22. Bergschrund 1 and CD1-22 are labeled near the top of the map presented in Figure 1. Bergschrund 2 and Bergschrund 2A are located immediately south of the index map of Figure 1, about 7,000' southeast of CD1-15. Bergschrund 2A is a redrill of Bergschrund 2, and the kick- off point of Bergschrund 2A in the Bergschrund 2 wellbore was -1905'. Bergschrund 1, CD1-22 and CD1-15 Annular Disposal June 8, 2012 Note to File Page 5 of 6 Bergschrund 2 encountered methane gas at-390',-120',and-510', respectively. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.3 to 10.0 pounds per gallon). The shallowest occurrences of more significant amounts of methane encountered in these wells(arbitrarily placed at 20 units of gas on the mud log)were-400', -680' and-690',respectively. So,the entire proposed disposal interval contains methane gas. The shallowest oil indicators recorded in nearby wells Bergschrund 1, CD1-22, Bergschrund 2 and Bergschrund 2A were encountered at -2,360', -2,390', -2,914', and -3,806' respectively. These oil indicators occur in or below the portion of the open annulus that will most likely accept the additional injected waste. The mud logging geologists rated these indicators as trace-to poor-quality oil shows. The shows are described as consisting of occasional, spotty black tarry oil stain, sample fluorescence ranging from none to medium yellow, solvent cut fluorescence from weak, milky yellow to dull yellow with a residual solvent-cut ring fluorescing from dull to moderate yellow. These characteristics suggest the presence of only trace quantities of immobile, residual oil in the geologic strata that will be affected by annular disposal in CD1-15. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Orders 27 and 28, which govern the Nanuq and Nanuq-Kuparuk Oil Pools, state that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. Injected Fluid vs Affected Radial Distance CD1-15 Wellbore (assumes 20'aggregate injection zone thickness and 24%porosity) 250 I 1 d � I; 200 0 E 0 150 d U C C6 Ul � 100 o U . 50 — — — 0 . 0 5,000 10.000 15.000 20.000 25,000 30,000 35,000 Amount of Injected Fluid(barrels) Figure 4. CD1-15 Area Likely Affected by Annular Injection CD1-15 Annular Disposal June 8, 2012 Note to File Page 6 of 6 The gamma ray curve recorded in CD1-15 indicates that about 20' of net sand are present in the most likely disposal interval. Inspection of the neutron and density porosity logs for correlative intervals in offset wells suggests an average sandstone and siltstone porosity of 24%at this depth. Based on these values, the area impacted disposal of 35,000 barrels of waste material lies within a radius of about 115' from the wellbore, assuming uniform, radial, piston-like displacement of the native formation fluid occurs (see Figure 4, above). The only three wells pass within 200' of the most likely disposal interval within the CD1-15 annulus. They are CD1-05, CD1-9, and CD1-13. If injected wastes reach these nearby wells, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the approved disposal interval. Summary The limited volume of rock that will be affected by this proposed annular disposal program contains methane gas, is situated beneath more than 1,450' of permafrost, and is bounded above and below by continuous layers of claystone and shale. This disposal interval lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. Injected wastes may reach nearby wells, but if they do, surface casing, cement, and confining claystone and shale layers will ensure injected materials remain within the disposal strata. I recommend approving this proposed annular disposal up to the limit of 35,000 barrels. . S (2- Steve ZSteve Davies Senior Petroleum Geologist fro.at. , "2—" -- rr. r- rf A n (T)Kff [ r i G L SEAN PARNELL,GOVERNOR f �+��tt ALASKA�tOIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 E. Galiunas Supervising Drilling Engineerqi p�,' ` !'J ConocoPhillips Alaska, Inc. o / P.O. Box 100360 Anchorage, AK 99510 :.....:. Re: Colville River Field, Alpine Oil Pool, CD 1-15 Sundry Number: 311-240 Dear Mr. Galiunas: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this/ & day of August, 2011. Encl. ConocoPhillips Alaska, Inc. tiV Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 August 3rd, 2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit: Request to Extend operational shutdown: 310-182 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for an extension of the operational shutdown for CD1-15 well (310-182). The CD1-15 well was spud on April 28th, 2010. The 13-1/2" surface hole was drilled and cased as planned. The 9-7/8" intermediate hole was started on May 4th, 2010, and drilled to a depth of 20,700' MD. While running the 7-5/8" intermediate casing string, hole conditions prevented the shoe from getting to bottom, and it was eventually set and cemented 477' MD high at a depth of 20,223' MD, The inability to get the casing to bottom led to a series of events that resulted in the inability to drill the 6.75" production hole to its planned depth of 21,993' MD. A sundry application for the CD1-15 well was approved on June 16th, 2010 to put the well under Operational Shutdown after it was determined the well could not be drilled an completed in time to meet summer drilling requirements on CD4 pad. CPAI was unable to return to CD1-15 during the 12 month window of the approved operational shut down due to casing running challenges on CD4 during May through July of 2011. The delays caused by casing running problems pushed the CD1-15 on the schedule out over 60 days. Therefore, CD1-15 will not be re- entered until late 2011 and is seeking an extension to the operational shutdown. Prior to re-entering the CD1-15 a sundry for restarting operations will be submitted to the AOGCC. Please reference the 10-403 submitted on 8-1-2011. If you have any questions or require further information, please contact Liz Galiunas at 265-6247. Sincerely, - -•. c"*(/--- ,...,,-;''„,-..=-.2,---___- Liz `` Drilling Engineering Supervisor Attachments: cc: CD1-15 Well File/Sharon Allsup Drake ATO 1530 Nina Anderson ATO 1706 Tim Schenider ATO 1768 Lanston Chin Kuukpik Corporation STATE OF ALASKA ALASK/ AND GAS CONSERVATION COMMISSIC.__ ,I0-II U A., APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r . Re-enter Susp.Well r Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development J ' Exploratory r 210-047 3.Address: Stratigraphic r Service F,—. 6.API Number. P. O. Box 100360,Anchorage,Alaska 99510 50-103-20619-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No rw CD1-15 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 372108,384214 . Colville River Field/Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(rt). Effective Depth TVD(ft): Plugs(measured): Junk(measured): 20700 ' 6514 19705' 6281' 19705', 20085' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3076 10.75 3112' 2397' INTERMEDIATE 20191 7.625 20225' 6404' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 3.5 L-80 2212 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER- MD=20080 TVD=6369 no SSSV 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Development r Service r • 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 8/15/2011 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r ' Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Liz Galiunas @ 265-6247 Printed Name E. Galiunas Title: Supervising Drilling Engineer Signature ��'�'..,- Phone.265-6247 Date 7/1//11 /11 Commission Use Only tt Sundry Number:31\ -a yo Conditions of approval: Notify Commission so that a representative may witness R,7. CFIvE-D Plug Integrity r BOP Test r Mechtg0 Integrity Test r Location Clearance r lu. ,2 j (c1,—,_...... Z t) !AO[ 0 I 101 Other: '� �� . S U 1`'� r' IV b-12.c� C o .�.;ss.£ - rse -s+-°.f f°` . Mai) Gil i r,A� Com. Commission ei�r /� �P�� �rl,.o„rdge Subsequent Form Required: J`(v,u --A '4-- -/c.....,-,...41-- APPROVED BY `�� r / Approved by: COMMISSIONER THE COMMISSION Date: V f l., 1 Form 10-403 Revised 1/2010 � f l_i' OR IR446 ���mit in Duplicate/�a I , AUG 112011 ' �� .� WNS CD115 Conoto�llip5 7 Well Attributes Max Angle&MD TD n -- --- AfES1ta Wellbore AMAMI F Id Name (Well Status 1 i(°) MD(ftK6) Act Bbn(EKE) t.r.� ,Inw. 501032061900 ALPINE PROD 78.021 7,61639 20,700.0 __ _____- Comment IH2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date WaiCont HQ-R, Q$Mema5c A4NT9�_CDt-1d,6i/1840107ABYual 44 AM - Last WO: 36.13 6/15/2010 — Annotation Depth(ftKB) End Date 'Annotation Last Mod. End Date Last Tag: I Rev Reason-NEW WELL,SUSPENDED Imosbor 6/18/2010 Casing Strings -- Casing Description String 0... String ID...Top(ftK8) Set Depth(f...Set Depth(TVD(...String Wt...String.. String Top Thal HANGER,31 . f CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded - Casing Deseription String 0... String ID...Top(NCB) Set Depth(f_.Set Depth(TVD)...String Wt...String._String Top Thrd SURFACE 103/4 9.950 35.8 3,112.2 2,393.4 45.50 L-80 BTC Casing Description String 0... String ID...Top(ftK6) Set Depth(f_.Sat Depth(TVD)...String WL..String...String Top Thn1 WINDOW 8 7.000 20,067.0 20,081.0 6,369.3 -------. n—--- --- ----- ; ; Casing Description String 0... String ID...Top(ftK6) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd INTERMEDIATE 7 5/8 6.875 33.5 20,224.9 6,404.7 29.70 L-80 BTCM Tubing Strings Tubing Description String 0... Stri g ID...Top(ftK6) Sot Depth(6...Set Depth(ND)...String Wt...String...String Top Thrd Tubing-Short String 31/2l 2.992 306 2,212.0 2,017.9 A 9.30 L-80 EUE Completion Details Top Depth I I (TVD) Top Incl Nomi... 1 _ I _. Top(NKB) (t(kB) el Nem Description Comment ID(in) 30.6 30.6 0.21 HANGER FMC tubing hanger 11"OD 4.500 34.5 34.5 0.21 XO Reducing XO 3 1/2'EUE 811:1(P)X 4 1/2"IBT 3.958 2,211.5 2,017.5 49.47 WLEG WLEG 2.99"ID-4.5"OD 2.992 Other In Hole(Wireline retrievableplugs,valves,pumps,fish,etc.) Top Depth CONDUCTOR. (TVD) Top Incl 37,14 Top(NCB) MKS) (C) Description Comment Ran Date ID(in) Cement Mug, \ 19,705 6,281.1 76.58 Cement BAKER CMT RETAINER 6/12/2010 Retainer 20,067 6,365.8 75.68 Whipstock WHIPSTOCK-ANCHOR BILLET 6/7/2010 _.. WLEG,2,212 20,080 6,369.1 75.69 PACKER 6/7/2010 20,085 6,370.3 75.70 Cement BAKER CMT RETAINER 6/3/2010 Retainer Cement Squeezes -10i:,- Top _cTop Depth Bhn Depth (TVD) (TVD) Top(NCB)Ste(NCB) (1KBN MKB) Description Start Dab Comment 46.0 140.0 46.0 140.0 Cement Plug 4/28/2010 Layed 20 Bbl AS1 Cement Plug to Cure Lost Returns at Conductor Shoe 20,116 0, 20,368 0 6,377.9 6,438.1 Cement Plug 5/29/2010 Spot Cement plug for Kick Off SURFACE,_, l Notes:General&Safety End Date Annotation 36.3,112 6/15/2010 NOTE:WELL SUSPENDED,KILL STRING IN PLACE 6/18/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 Cement Retainer. 111 19,705 Whipstock, 20,067 WINDOW, a 20,067-20,081 PACKER. - 20,080 / Cement Retainer, 20,0855 tl NTE RM EDlATE, 3e-20.225 Cement Plug, , 20,116 TO(CD1-15), 20,700 McMains, Stephen E (DOA) From: Allsup-Drake, Sharon K[Sharon.K.Allsup-Drake@conocophillips.com] Sent: Friday, July 29, 2011 11:11 AM To: McMains, Stephen E (DOA) Subject: cancel CD1-15 sundry#310-396 Steve McMains— PTD ,110 - 04i7 Pursuant to our telephone conversation of 7/28/2011, please cancel sundry#310-396 for well CD1-15. We will send another application for sundry (form 10-403) to extend the operations shutdown of this well. Thank you for all your help on this matter. Liz Galiunas Supervising Drilling Engineer ConocoPhillips Alaska 907-265-6247 ' 177 • • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 A P R 0 4 2011 ANCHORAGE,ALASKA 99510-0360 apliska ad&Sas Cons.Commission Anchorage April 01,2011 Commissioner Dan Seamount ,P1 047r Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 �� I Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 13-15 and March 27-28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Z,7/14J MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 4 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 04/01/2011 CD1 PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft _ bbls ft gal �CD1-15PB1 50103206190000 2100470 10" n/a 10" n/a 4.3 3/13/2011 CD1-20 50103205030000 2042400 6" n/a 24" n/a 5.4 3/13/2011 CD1-21 50103203620000 2010060 6" n/a 13" n/a 8 _ 3/13/2011 CD1-30 50103203480000 2001320 6" n/a 20" n/a 6.4 3/13/2011 CD1-31 50103203470000 2001180 6" n/a 14" n/a 6.4 3/13/2011 CD1-37 50103203020000 1990670 8" n/a 13" n/a 8.3 _ 3/13/2011 CD1-38 50103203230000 2000030 4" _ n/a 13" n/a 4.9 3/13/2011 CD1-39 50103203040000 1990800 4" n/a 15" n/a 4.4 _ 3/13/2011 CD1-40 50103202980000 1990440 4" I n/a 15" l n/a 5.2 3/13/2011 ijy- s / SEAN PARNELL,GOVERNOR ALASKA OIL ANI) GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 G. L. Alvord J 0 147 Alpine Drilling Manager a f ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-15 Sundry Number: 310-396 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this j day of December, 2010. Encl. • ConocoPhillips Alaska, Inc. Post Office Box 100360 ' Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 RECEIVED November 28th, 2010 DEC 0 1 2010 Alaska Oil andhAvenue, Suite 100 Gas Conservation Commission 333 West 7 Alaska Oil &Gas Cons.Commission Anchorage, Alaska 99501 Anciorage Re: Sundry Permit: Request to re-enter and drill CD1-15 well as originally permitted Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to re-enter the CD1-15 well and resume drilling ✓ operations. The CD1-15 well was spudded on April 28th, 2010. The 13-1/2" surface hole was drilled and cased as planned. The 9-7/8" intermediate hole was started on May 4th, 2010, and drilled to a depth of 20,700' MD. • While running the 7-5/8" intermediate casing string, hole conditions prevented the shoe from getting to bottom, and it was eventually set and cemented 477' MD high at a depth of 20,223' MD. The inability to get the casing to bottom led to a series of events that resulted in the inability to drill the 6.75" production hole to its planned depth of 21,993' MD. The well was left with 11.0 ppg MOBM in the hole, and a sundry application for the CD1-15 well was approved on June 16th, 2010 to put the well under Operational Shutdown after it was determined the well could not be drilled and completed in time to meet summer drilling requirements on CD4 pad. CPAI plans to move Doyon 19 to the CD1-15 well on December 8th, 2010 with the intention to resume drilling - operations and complete the production section of the wellbore. Once the rig is onsite and has pulled the 3.5" kill string from the well, a whipstock assembly will be used to mill a window in the existing 7-5/8" intermediate casing. A 6.75" drilling BHA will then be picked up and a formation integrity test will then be performed to 15.0 ppg EMW. This proposed shoe strength is required due to the pressure uncertainty in the Kuparuk and Alpine , formations. If a sufficient formation integrity test is achieved, the 6.75" hole will be drilled to TD and the well completed as • originally planned with a 5.5" liner and perforated using tubing conveyed guns. If the FIT fails to reach 15.0 ppg EMW, the 6.75" hole will be drilled to the K-1 marker above any potential reservoirs. The hole will then be under reamed to 7.50" before running and cementing a contingency expandable liner. A secondary FIT will then be executed below the expandable liner to prove the well has sufficient integrity to drill into a potentially over-pressured reservoir(s). The well with then be drilled to TD with a 6.00" bit and the well completed with a 4.5" liner and perforated post rig using e-line. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 2. CD1-15 Operational Shut Down Wellbore Schematic 3. CD1-15 Planned Re-Drill Schematic 4. CD1-15 Planned Completion Schematic 5. CD1-15 Contingency Drilling Schematic 6. CD1-15 Contingency Completion Schematic Information pertinent to the application that is presently on file at the AOGCC: 1 Diagrams of the BOP equtpmerri, divanef 'equipment and &Rake manifold lay Duas requtred oy 20 ACC 25.03.5 (a)and 0); 2. A cescroption of:rie dnifing fluids harqiing system 3. Dr:actrarn of riser set UO. If you have any questions or require tunnel.information, please contact Ryan Robertson at 265-6318 or Chip Alvord at 265-6120. Sincaraly, Ryan RoOertaon Drdiing Engineer Attachments: CD1-15 Weft SI-G(0n Ansup EkaKe ATO 1530 Liz Gauunai ATO 1500 Mark Cnarnbers ATC) 1566 Mike A Wirfree ATO 1706 Jack Walker ATO 1740 nstcn Chin Kookofk Corporation OX , ,7,/0 * .4 0 STATE OF ALASKA (Z 0%.;A' ALASKA OIL AND GAS CONSERVATION COMMISSION l Li APPLICATION FOR SUNDRY APPROVALSERfA,,.0.6a- .„j 1 20 AAC 25.280 1 Type of Request. AI radon r Rug for Redd! r Rat-borate fav Fbd r Rapair well r OggeApproved Rug.,1 i 1r !y'3'1a 9.spaid E Ru Rerfaabcrs r Ferfaate j— RJ TL6ing r Trre 6dersirn r Creraicnal 9-0.doavn r Fe-ester asp.Wall r Sine r Ater r.�sing j-” Other: Fre 5 - op. jr 2.Operator Name 4 Current Well Class 5 Permit to Drill Number ConocoPhillips Alaska, Inc. C>?✓dcp-ret r E<ploratory r 2100470 ' 3.Address: r. Ss vice F 6 API Number P.0.Box 100360,Anchorage,Alaska 99510 50-103-20619-00-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes. Spacing Exception Required? Yes f Fib I✓ CD1-15 9.Property Designation 10.Field/Pool(s) ADL 372108,384214 ' Colville River Field/Alpine Oil Pool 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) IITotal Depth TVD(ft) Effective Depth MD(ft) ,Effective Depth TVD(ft) Plugs(measured). Junk(measured) ' 20700 6514 19705' 6281' 19705',20085' Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" _ 114' 114' Surface 3075' 10 75 3112' 2397' 5750 3090 Intermediate 20186' 7.625 20223' 6404' 6,890 4790 Production Perforation Depth MD(ft): Perforation Depth TVD(ft) Tubing Size Tubing Grade' Tubing MD(ft) n/a n/a - - i - Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV 12 AttachrrE ts: CEscription Sunray d Rcpcsal f 13 Well Class after proposed work Detailed CperaicnsRuy.ell rt ( BCP sketch r EvIcratcxy r Development r Sereice Pi ' 14 Estimated Date for Commencing Operations 15. Well Status after proposed work 12/8/2010 01 r C-es r \AES t r Suspended r 16 Verbal Approval. Date VVNU r aw r vvsG R pion l 1 Commission Representative ( "TCR r SPL-UG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Ryan Robertson @ 265-6318 Printed Name G. L./�Alvord Title Alpine Drilling Manager AvSignature ( / �,( Phone 265-6120 Date /1/3 /2,D(,o //// Commission Use Only Sundry Number L,10. (/� Conditions of approval Notify Commissio o that a representative may witness ✓ X/ Fl gIntegrityr BCPTest ( MKnanic IntegrityTest r Location Clearance r Orr in e / D ca, i o+'ks 4 RECEIVED 0 1 N ED Other � Slip. �� // DEC 0 d 2010 Subsequent Form Required F;41 kid& /Q-4/6 7 Alaska Oil&Gas Cons. Comrossion /ic:/ Anc,orage Approved by: 4APPROVED BY )COMMISSIONER THE COMMISSION ate' ` /� Form 10-403 Revised 1/2010 LRBDMS DEC 07 tit in Duplicate Alpine CD1-15 Operational Shut Down Status — 06.15.10 Existing wellbore depths based on actual rig surveys 16"Conductor to 114' 5/19/2010 10-3/4"45.5 ppf L-80 BTC-M' Surface Casing Actual 3,112'MD/2393'TVD Cemented to surface Calculate TOC 4,908'MD/2,811'TVD TAM Port Collar 0 3,039'ND(5,872'MD) Calculated TOC 8,986'MD/3,768'ND HES Stage Tool 4,022'TVD(10,070'MD) A Calculated TOC 18,737'MD/6,052'TVD Cement Retainer#2 Depth r,l 19,705'MD/6,281'ND 111111011 7-5/8"Cement Retainer#1 - 20,085'MD/6,370'ND 7-5/8"Casing Shoe CD1-15PB2 20,223'MD/6,404'ND 6.75"Sidetrack p1.15 P61 20,114'MD/6,377'TVD TD 9-7/8"Hole 20,700'MD/6,514'TVD Riq Procedure-5.5" Liner 1. Move Doyon 19 onto CD1-15. 2. Pressure test intermediate casing through IA to 2,500 psi for 30 minutes-Confirms cement retainer " integrity(at 19,705' MD), 7-5/8"casing integrity, BPV in direction of flow and tubing hanger seals in direction of flow. 3. Nipple down Alpine Gen II tree. 4. Set blanking plug. / 35 "it." ✓aC.s • 5. Nipple up and test BOPE to 3,500 psi high/250 psi low. ✓ 6. Pull blanking plug. 7. Unseat 3.5"kill string and circulate bottoms up-Set at 2,211' MD. 8. Pull 3.5"kill string to surface. 9. Run in hole with whipstock assembly and set at 19,700' MD. / 10. Mill window through 7-5/8"casing and drill 20 ft of formation. 11. Perform FIT to 15.0 ppg EMW. / 12. Pull milling assembly from hole. 13. Perform clean out run with Baker VACS system to remove metal debris from window milling operations. 14. Make up 6.75"drilling assembly and drill to planned TD of 21,809' MD/6,816' MD 15. Run 5.5"liner and cement as per drilling program. 501° - s4-? f'(( 16. Set liner hanger with ZXP packer. 17. Pressure test casing and liner to 2,500 psi for 30 minutes. x jajo 4 18. Run in hole with memory CBL/GR on drillpipe to evaluate cement and Alpine C formation. ts-•"'"- 19. Displace MOBM to kill weight brine. 20. Run in hole with tubing conveyed guns and perforate Alpine C formation. 21. Run middle completion-3.5", 9.3 ppf, L-80 tubing with Baker Fl packer, Seal Bore Receptacle, HES XN and BOT Stinger with WLEG and solid shear out insert. 22. Run upper completion - 3.5", 9.3 ppf, L-80 tubing with SSSV, Camco GLM, and Baker GBH-22 Bonded Seal Assembly. 23. Pump corrosion inhibited kill weight brine with diesel cap for freeze protect. Monitor well for 30 minutes to ensure no flow. 24. Land tubing. 25. Pressure test tubing and annulus to 3,500 psi for 30 minutes., 26. Install TWC and nipple down BOP. ✓ 27. Install tubing head adapter assembly. Pressure test adapter assembly to 5,000 psi. 28. Remove two way check valve. 29. Install BPV and secure well. 30. Move rig off CD1-15. • 5-1/2" Production Liner run to 21,809 MD/6816'TVD: Cement from 21,809' MD to 19,530' MD with Class G +additives @ 15.8 PPG.Assume 20% excess annular volume. Liner Cap: (19,530'— 19,430')X 0.1705 ft3/ft X 1.0 (0%excess) = 17 ft3 Liner Lap: (19,700'—19,530')X 0.0928 ft3/ft X 1.2 (20%excess) = 19 ft3 Open Hole: (21,809'—19,700')X 0.0835 ft3/ft X 1.2 (20%excess)=211 ft3 Shoe Track: (21,809'—21,689')X 0.1337 ft3/ft X 1.0(0%excess) = 16 ft3 0 Total volume = 17+ 19+211 + 16=263 ft3=>227Sx @ 1.16 ft3/sk System: 227Sx Class G +0.2% D046 anti-foamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Alpine CD1-15 Planned Re-Drill — 11 .08.10 Existing wellbore depths based on actual rig surveys 16"Conductor to 114' Production Hole Depths based on CD1-15wp09 10-3/4"45.5 ppf L-80 BTC-M Surface Casing Actual Bottom Joint Centralizers Top Interval 3,112'MD/2393'TVD Type Joints Cemented to surface Depth Length Required Depth Length Hydro Form 21809 3 40 3 - 21689 120 Calculate TOC Bow Spring 21689 4 20 - 4 21609 80 4,908'MD/2,811'TVD ` Bow Spring 21609 3 40 - 3 21489 120 el • Bow Spring 21489 6 20 - 6 21369 120 TAM Port Collar Hydro Form 21369 4 40 4 - 21209 160 3,039'TVD(5,872'MD) Bow Spring 21209 8 40 - 8 20889 320 Hydro Form 20889 10 40 10 - 20489 400 Calculated TOC 8,986'MD/3,768'TVD HES Stage Tool 4,022'TVD(10,070'MD) / 0 7-5/8"Whipstock Window Start Depth 19,682'MDI 6,276'TVD 7-5/8"Whipstock Window Exit Depth 19,700'MD/6,280'TVD Cement Retainer#2 Depth 19,705'MD/6,281'TVD 20,989'MD/6,583'TVD Kuparuk C 111111111111101%1101,, 21,003'MD/6,586'TVD 21,454'MD/6,708'ND Alpine D ---- 21,509'MD/6,723'ND Alpine C 21,615'MD/6,753'ND 6.75"TD 21,809'MD/6,816'ND • CD1-15 Alpine "C" Pre-Producer / Injector Completion Sperry Sun L16"Insulated Conductor to Directional Plan WP10 '114' 11/11/2010 4-'/z'12.6 ppf L-80 IBT Mod Tubing ---, 3-1/2"SSSV with 2.813"X Landing Nipple 10-3/4"45.5 ppf L-80 BTCM Surface Casing J hi.. 3112'MD/2393'TVD Cemented to surface Ulmer Completion: TOD MD DIM TOC +/-4,908'MD 1) Tubing Hanger 32' 32' /2,811'TVD 2) 4-'14"12.6#/ft IBT-Mod Tubing(2 jts),XO Port 3) 3-'A"9.3#/ft EUE-Mod Tubing Cementing / 4) Camco TRMAXX-5E SSSV(2.812"ID) 2,200' 2013' Collar Q 0 01 C10 Bottom with control line to surface l +/-5760'MD 5) 3-'A 9.3#/ft EUE-Mod Tubing +1-5872'MD"' 6) 3-14"Camco MMG-HW GLM(ID=2.915") 15,000' 5,176' /3039'TVD /3015'TVD 7) 3-'A"9.3#/ft EUE-Mod Tubing 8) Baker GBH-22 80-40 Bonded Seal assembly 19,450' 6,222' /Middle Comoletion; Too MD IYQ Item 9) Baker 91-40 Model'F-1'Packer 19,420' 6,215' TOC 10) Baker 20 ft Seal Bore receptacle 19,450' 6,222' +/-8,986'MD 11) 3-14 9.3#/ft EUE-Mod Tubing /3,768'TVD 12) HES XN 2.813"(2.75"NoGo) 19,500 6,233' Stage 13) 3-/ 9.3#/ft EUE-Mod Tubing cementing ' 14) BOT Stinger w/WLEG and Solid Shear 19,560' 6,248' tool+/- ' O 0 out type insert 10070'MD ,c' K3 Basal Bottom Lower Comoletion• Too MD TVD /4022'TVD +/-10000'MD Item /4006'TVD 15) Baker 5-1/2"x 7-5/8"Flex-lock Liner Hanger 19,530' 6,240' with ZXP Liner Top Packer 16) 5-14", 15.5#/ft,L-80 BTC-Mod Liner with Qty 2 Aluminum Slide-On Centralizers (6.375"OD)per joint 17) 5-'A"Float Collar and Shoe BTC-Mod 21,809' 6,816' Connections 7-5/8"29.7 ppf L-80 0 BTC Mod Production Casing @ `� +1-76°19683'MD/ Top of cement �06276'TVD j 18,737'MD/6,052'TVD / `� `/. cr... ✓ /. %,'15.5 ppf L-80 BTC-Mod Liner Top HRZ Reservoir at+/- �' ® Abs....w , 14 (Cemented) 19908'MD/6327'TVD ey..- TD 6-3/4"hole 15 hli.-// 21809'MD/6816'TVD Base HRZ Reservoir at+/- _ 20419'MD/6442'TVD K1 Marker at+/- I 1 f/ 20641'MD/6494'TVD Rig Procedure-Expandable Liner Contingency(Continued from Step 13-Pane 5) 14. Make up 6.75"drilling assembly and drill to planned TD of 20,700' MD/6,508' MD. 15. Pull out of hole and make up 7.5" under reaming assembly. 16. Run in hole and under ream 6.75" hole to 7.5". ` � � 17. Pick up and run 6"OD expandable liner and cement per program. Vat_ ' o`�';� c5D cow" 18. Expand liner to 6.689"OD/6.001" ID. 19. Pressure test casing and expandable to 2,500 psi for 30 minutes. 20. Run in hole with 6" rotary steerable assembly and drill 20 ft of new formation. 21. Perform FIT to 15.0 ppg EMW. 22. Drill 6"hole to 21,809' MD/6,816'TVD. 23. Run 4.5"liner and cement per program.✓ 24. Set liner hanger with ZXP packer. 25. Pressure test casing and liner to 2,500 psi for 30 minutes. 26. Run upper completion - 3.5", 9.3 ppf, L-80 tubing with SSSV, Camco GLM, and Baker GBH-22 Bonded Seal Assembly. 27. Displace MOBM with corrosion inhibited brine and diesel cap for freeze protect. 31. Pump corrosion inhibited kill weight brine with diesel cap for freeze protect. Monitor well for 30 minutes to ensure no flow. 32. Land tubing. 33. Pressure test tubing and annulus to 3,500 psi for 30 minutes. 34. Install TWC and nipple down BOP. 35. Install tubing head adapter assembly. Pressure test adapter assembly to 5,000 psi. 36. Remove two way check valve. 37. Install BPV and secure well. 38. Move rig off CD1-15. Expandable Liner Specifications Pre-Expansion Specifications Post-Expansion Specifications Grade EX-80 Expansion Ratio 13.50% Nominal Yield 80,000 psi Collapse 3,390 psi Nominal Weight 20.1 lb/ft Nominal Weight 21.23 lb/ft Nominal OD 6.000 in Nominal OD 6.689 in Nominal ID 5.340 in Nominal ID 6.060 in Drift ID 5.215 in Drift ID 6.001 in Wall 0.330 in Wall 0.314 in Internal Yield 7,920 psi Internal Yield 6,769 psi Conn. Sleeves Conn. Sleeves (Overlap) 0.040 in (thick) (Overlap) 6.841 in OD Conn. Sleeves Conn. Sleeves (Open Hole) 0.080 (thick) (Open Hole) 6.841 in OD Expandable Liner Cement Program Cement from 20,700' MD to 19,900' MD with Class G+additives @ 15.8 PPG.Assume 20% excess annular volume. Calculations based on post expansion. Open Hole: (20,700'—19,900')X 0.0628 ft3/ft X 1.2 (20% excess) =61 ft3 Total volume = 61 ft3=> 53Sx @ 1.16 ft3/sk System: 53 Sx Class G +0.2% D046 anti-foamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk 4.5" Liner Cement Program Cement from 21,809' MD to 19,530' MD with Class G +additives @ 15.8 PPG.Assume 20% excess annular volume. Liner Cap: (19,530'— 19,430')X 0.1705 ft3/ft X 1.0 (0% excess) = 17 ft3 Liner Lap: (19,700'—19,530')X 0.0928 ft3/ft X 1.2 (20%excess) = 19 ft3 Open Hole: (21,809'—19,700')X 0.0835 ft3/ft X 1.2 (20% excess) =211 ft3 ✓✓✓ Shoe Track: (21,809'—21,689')X 0.1337 ft3/ft X 1.0 (0% excess) = 16 ft3 Total volume = 17+ 19+211 + 16= 263 ft3=>227Sx @ 1.16 ft3/sk System: 227Sx Class G +0.2% D046 anti-foamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Alpine CD1-15 Contingency Drilling Scenario — 11.08.10 Existing wellbore depths based L on actual rig surveys 16"Conductor to 114' Production Hole Depths based on CD1-15wp09 ) 10.3/4"45.5 ppf L-80 BTC-M Surface Casing Actual 3,112'MD/2393'ND -- -- L Bottom Joint Centralizers Top Interval Cemented to surface Type Depth Joints Length Required Depth Length Calculate TOC Hydro Form 21809 3 40 3 - 21689 120 4,908'MD/2,811 ND ------------'' ' Bow Spring 21689 4 20 - 4 21609 80 ,, i. • Bow Spring 21609' 3 40 - 3 21489 120 TAM Port Collar Bow Spring 21489 6 20 - 6 21369 120 3,039'ND(5,872'MD) Hydro Form 21369 4 40 4 - 21209 160 Bow Spring 21209 8 40 - 8 20889 320 Hydro Form 20889 4 40 4 - 20729 160 Calculated TOC -- 8,986'MD/3,768'ND HES Stage Tool 4,022'ND(10,070'MD) ems_ 7-5/8"Whipstock Window Start Depth -_--\ 19,682'MD/6,276'ND 7-5/8"Whipstock Window Exit Depth *�� 19,700'MD/6,280'ND / Cement Retainer#2 Depth 6.75 x 7.5"TD 19,705'MD/6,281'TVD 20,700'MD/6,508'ND lgj 20,989'MD/6,583'ND 6(� Kuparuk C ` --- 21,003'MD/6,586°ND Alpine D ' . , 21,454'MD 1 6,708'ND Alpine C - ,� 21,509'MD/6,723'ND ' ---- —\7 21,615'MD/6,753'ND 6.00"TD 21,809'MD/6,816'ND CD1-15 Alpine "C" Pre-Producer / Injector Contingency Completion Sperry Sun j... 16"Insulated Conductor to Directional Plan WP10 —114' ® 11/11/2010 .� 4-1/2"12.6 ppf L-80 IBT Mod Tubing • � 3-1/2"SSSV with 2.813"X Landing Nipple 10-3/4"45.5 ppf L-80 BTCM Surface Casing Iiiii 3112'MD/2393'TVD Cemented to surface Uooer Comotetion: Top MD IYQ TOC 1) Tubing Hanger 32' 32' +/-4,908'MD 2) 4-'/z"12.6#/ft IBT-Mod Tubing(2 jts),XO Port /2,811'TVD 3) 3-%'9.3#/ft EUE-Mod Tubing Cementing J 4) Camco TRMAXX-5E SSSV(2 812"ID) 2,200' 2,013' Collar 0 O 0 C10 Bottom with control line to surface +/-5872'MD _1 +/-5760'MD 5) 3-/= 9.3#/ft EUE-Mod Tubing /3039'TVD /3015'TVD 6) 3-W'Camco MMG-HW GLM(ID=2.915") 15,000' 5,176' 7) 3-W 9.3#/ft EUE-Mod Tubing 8) HES"XN"(2.75"min ID)@ 76 deg 19,500' 6,233' 9) 3-W 9.3#/ft EUE-Mod Tubing 10) Baker GBH-22 80-40 Bonded Seal assembly 19,560' 6,248' with 2 joints of 3-%"9.3#/ft EUE-Mod Tubing and a'A Mule Shoe -: TOC Lower Completion: 192 1112 I[Q +/-8,986'MD ttt<m Stage /3,768'TVD 11) Baker 5-1/2"x 7-5/8"Flex-lock Liner Hanger 19,530' 6,240' cementing j ZXP Liner Top Packer w/20 ft Seal Bore tool MD 0 Q Q!K3 Basal Bottom 12) Extension 11 10070' 12.6#/ft,L-80 BTC-Mod Blank Liner /4022'TVD +/-10000'MD with both Bow type and slide on centralizers /4006'TVD (Placement specified in the Completion Procedure). 13) 4-%"Float Collar and Shoe BTC-Mod 21,809' 6,816' Connections 7-5/8"29.7 ppf L-80 4BTC Mod Production Casing @ 0 +/-76°19683'MD/ Expandable 6276'TVD Casing TD @ +/-76° Top of cement 20700'MD/ 18,737'MD/6,052'TVD Q cit. 6508'TVD 4-%"12.6 ppf L-80 BTC-Mod Liner Post-Rig E-line TopHRZ Reservoir at+/ �j II (Cemented) Perforations 19908'MD/632T TVD 0._ Base HRZ Reservoir at+/- 20419'MD/6442'TVD TD 6"hole 21809'MD/ K1 Marker at+/- I I/ >� 6816'TVD 20641'MD/6494'TVD Page 1 of 2 Schwartz, Guy L (DOA) From: Robertson, Ryan G [Ryan.G.Robertson@conocophillips.com] Sent: Monday, December 06, 2010 1:06 PM To: Schwartz, Guy L(DOA) Subject: CD1-15 Expandable Liner .2 -oil 7 Guy, As discussed, below is an executive summary explaining expansion of the contingency expandable liner... The expandable liner for CD1-15 has been identified as a good contingency option as it will CPAI to perform a second FIT above the Kuparuk C and Alpine C reservoirs, while still enabling the ability to drill ahead with 4-3/4" tools, which are standard in Alpine production holes. The procedure of expanding tubulars takes the steel beyond its elastic limit, into the plastic region of the stress- strain curve, while still remaining safely below ultimate yield. To facilitate the expansion process, the wellbore section will be drilled with a 6.75" bit to the K1 marker. A dedicated under reaming run will then take place to open the hole to 7.5". At this point, the expandable liner will be run in the hole. ,I ----------------- --------- The housing at the bottom of the SET system, known as the launcher, contains an expansion assembly as well as a float assembly. The expansion assembly contains a solid cone that is driven through the expandable tubulars using hydraulic pressure or mechanical force, or a combination of both, which will enlarge the pipe radially to a 6.00"drift. If required, the expandable will be run in hole to a planned setting depth of 20,700' MD. This is facilitated by making up the launcher(pictured above)on surface. The liner is then run in the hole to the liner hanger. At this point, the 4" drillpipe inner string is run in the hole and made up to the Expansion Assembly (seen above). The liner is then run to bottom. 12/6/2010 Page 2 of 2 Once on bottom, the cement head is made up to the 4"drillpipe. The cement is pumped so that 80% of the open hole (post expansion) is filled with cement. The post expanded OD of the liner will be 6.689", requiring roughly 61 ft3 of 15.8 ppg, class G cement. Once the dart has landed and the cement is in place, the expansion process begins. The pressure below the expansion assembly will be brought up to 5,000 psi to initiate expansion. As the liner begins to expand, the expansion pressure will drop to 3,500 psi. During expansion, the driller will pick up on the drillstring to maintain a steady string weight. Expansion is expected to occur at a pump rate of 1 bpm and expansion rate 30 ft/min. The process will take place until the liner hanger joint begins to expand. After positive indication of expansion of the first two elastomer sections, the Expansion Assembly will be pulled through the remainder of the liner hanger joint. During the expansion process, the enlargement of the pipe diameter causes the overall pipe length to shorten from the top as a result of material balance. As the liner is expanded, its outer diameter(OD) increases significantly, while the wall thickness decreases only slightly. This preserves the greatest post-expansion burst and collapse values possible. Once the liner is full expanded, it will be pressure tested to 2,500 psi and the remainder of the Enventure BHA pulled from the hole. Ryan pilling Engineer ConocePh11hp,, Alaska Direct 1907)265-r,?18 1 Mobile (907)9P9-510- 12/6/2010 Expandable - .,i .a - 1 .,4 ;�� Openhole l� ` ! N SSystem . 1 [ 1 i M Y : r i - ' l r 1rj I — i I - i .. i � i_ ill '1 f I k I , Ro: . , ' 1K V ii` » _. - 7 - NA 7. i ,,,,,,i!LI.V.,,,, ' t ,,,:i Et*: -'-' li 44 . '?":-' '-x '',.. . '' . ell Ts,,,,.. .1 43 ),(.:, ;, ix.. It ., .. ir I t. rs ..,. 7; mii I _- I . _I . .4< t eau-- '. c r• _- Drill Hole Run Expandable Condition Mud, Pump Plug Latch Plug, Liner Cement Liner Start Expansion 10 Enventure Global Technology 4 Openhole Liner (OHL') System Installation Sequence RI _ Drill Hole Drill an oversized open- 1 hole interval. Run Expandable Lim Pick up the I i expandable liner, expansion assembly and launcher. 11- Condition Mud, Cement Liner. Run to a 4r the planned depth (or as deep as PI 3 x' hole conditions allow)and perform cementing operations. JR 1 Pump Plug. Displace cement with latch- r down plug. , + `.' j Latch Plug, Start Expansion Seat the ` latch-down plug and initiate expansion by expanding through the launcher. X y Expand Hanger Joint. Expand the liner ... including the anchor hanger joint in � t- t . ' i the overlap between the SET and the a 1 I base casing. Expand out of the top Expand Drill Out of the liner. Hanger Joint Shoe Drill out Shoe. Continue with next drilling operation. SET-Technology:The Facts 11 • Nose Assembly-left down hole Flapper Valve(composite) Drill Pipe Transition Nose(aluminum) '' Debris Catcher Guide Nose(composite) — '' 4 • — Expandable Casing ti°1..il 41411;? Expansion Assembly Stabilizer(steel) 1 ./ I Bypass Sleeve(steel) Rupture Disk(steel) :_- 11111° Launcher(steel) Cone(D2 steel) Cone Mandrel(steel) Page 1 of 2 s Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, November 19, 2010 1:11 PM To: 'Robertson, Ryan G' Subject: RE: CD1-15 Re-Entry (PTD 210-047) Ryan, Please call me to discuss. The commission will most likely require a 403 sundry application to officially approve the changes to the well plan.... especially the expandable liner contingency. Any major changes to the casing plan need to be approved with a sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Friday, November 19, 2010 8:37 AM To: Schwartz, Guy L(DOA) Subject: CD1-15 Re-Entry Guy, Outlined below is CPAI's operational strategy for re-entering the CD1-15 wellbore as discussed last week. A sundry application for the CD1-15 well was approved on June 16th, 2010 to put the well under Operational Shutdown after it was determined the well could not be drilled an completed in time to meet summer drilling requirements on CD4 pad. A schematic of the wellbore's current status can be seen below. Please note that the wellbore currently has 11.0 ppg MOBM from the cement retainer at 19,705' MD to roughly 100 ft from the wellhead. The top 100 ft has 6.8 ppg LVT(base oil)which was used as a spacer from the wellhead to the MOBM system. CPAI plans to move to CD1 pad in early December,with a planned re-entry date of 12.10.10. A generalized plan forward is outlined below: 1. Move on and rig up Doyon 19 on CD1-15 well 2. Test intermediate casing through IA to 2,500 psi for 30 minutes—Confirms cement retainer integrity (at 19,705' MD), 7-5/8"casing integrity, BPV in direction of flow and tubing hanger seals in direction of flow. 3. Nipple down Alpine Gen II tree 4. Set blanking plug 5. Nipple up and test BOPE 6. Pull blanking plug 7. Unseat tubing and circulate bottoms up 8. Pull tubing to surface 9. Run in hole with whipstock assembly and set at 19,700' MD 10. Mill window through 7-5/8" casing and drill 40 ft of formation 11. Perform FIT to 15.0 ppg EMW The drilling plan forward on this well depends on whether or not an FIT of 15.0 ppg EMW is acquired after the well is sidetracked out of the 7-5/8" casing. This formation strength is required due to the pressure uncertainty in the Kuparuk and Alpine formations. It is felt that the chances of acquiring the required FIT are high; however a 11/19/2010 Page 2 of 2 contingency scenario has been planned in the event the FIT does not reach 15.0 ppg EMW. The plan forward if a good FIT is achieved continues on from step 10 above: 12. Pull whipstock assembly from hole 13. Perform clean out run with Baker VACS system to remove metal debris from window milling operations 14. Make up 6.75"drilling assembly and drill to planned TD of 21,809' MD/6,816' MD 15. Run 5.5" liner and cement 16. Set liner hanger with ZXP packer 17. Run in hole with CBUGR to evaluate cement and Alpine C formation 18. Displace MOBM to kill weight brine 19. Run in hole with tubing conveyed guns and perforate Alpine C formation 20. Run 3.5" middle and upper completion strings 21. Freeze protect well 22. Nipple down BOPE/ Nipple up tree 23. Rig down and mobilize to CD2 pad The drilling and completion schematics for this scenario can be seen below: If an FIT of 15.0 ppg EMW is not achieved,the planned contingency option with expandable liner will be implemented, continuing from step 10 above: 1. Pull whipstock assembly from hole 2. Perform clean out run with Baker VACS system to remove metal debris from window milling operations 3. Make up 6.75"drilling assembly and drill to 20,700 MD/6,508' TVD 4. Pull out of hole and make up hole opening assembly 5. Run in hole and under ream 6.75" hole to 7.5" in order accommodate expandable liner 6. Pick up and run 6" OD expandable liner and pump cement 7. Expand liner to 6.689" OD/6.001" ID 8. Run in hole with 6" rotary steerable assembly and drill 20 ft of new formation 9. Perform FIT to 15.0 ppg EMW 10. Drill 6" hole to 21,809' MD/6,816' TVD 11. Run 4.5" liner and cement 12. Set liner hanger with ZXP packer 13. Run 3.5" upper completion 14. Freeze protect well 15. Nipple down BOPE/Nipple up tree 16. Rig down and mobilize to CD2 pad 17. Run CBL logs and perforate post rig .s,laM,o;!uoW The contingency drilling and completion schematics for this scenario can be seen below: The planned target and overall scope of this well has not changed from the originally permitted well besides the whipstock run and contingency scenario, both of which are a result of landing the 7-5/8" intermediate casing high in May 2010. Please advise if you have any questions or require additional information. Ryan a l r ri'i + Conu,u1'h 1h4;5,,1,14ri CjirF:ct 1,+07;26ti-6:.I;. Mobile (cJ7)98C-51iJ7 11/19/2010 Alpine CD1 -15 Contingency Drilling Scenario — 11 .08.10 .:.,_.LExisting wellbore depths based on actual rig surveys 16"Conductor to 114' Production Hole Depths based on CD1-15wp09 10-3/4"45.5 ppf L-80 BTC-M li!l'•' Surface Casing Actual ' 3,112'MD/2393'TVD j/ ► Bottom Joint Centralizers Top Interval Cemented to surface Type Depth Joints Length Required Depth Length Calculate TOC Hydro Form 21809 3 40 3 - 21689 120 4,908'MD/2,811'TVD Bow Spring 21689 4 20 - 4 21609 80 I L , . Bow Spring 21609 3 40 - 3 21489 120 TAM Port Collar l � Bow Spring 21489 6 20 - 6 21369 120 3,039'TVD(5,872'MD) Hydro Form 21369 4 40 4 - 21209 160 Bow Spring 21209 8 40 - 8 20889 320 Hydro Form 20889 4 40 4, - 20729 160 Calculated TOC 8,986' MD/3,768'TVD HES Stage Tool 4,022'TVD(10,070'MD) , 0 • . 7-5/8"Whipstock Window Start Depth 19,682'MD/6,276'TVD 7-5/8"Whipstock Window Exit Depth 19,700'MD/6,280'TVD Cement Retainer#2 Depth 6.75 x 7.5"TD 19,705' MD/6,281'TVD 20,700'MD/6,508'TVD ---- - 20,989' MD/6,583'TVD Kuparuk C 21,003' MD/6,586'TVD 21,454'MDI 6,708'TVD Alpine D 21,509' MD/6,723'TVD Alpine C 21,615' MD/6,753'TVD • 6.00"TD 21,809' MDI 6,816'TVD Alpine CD1 -15 Operational Shut Down Status — 06.15.10 • Existing wellbore depths based on actual rig surveys 16"Conductor to 114' 5/19/2010 10-3/4"45.5 ppf L-80 BTC-M Surface Casing Actual 3,112'MD/2393'TVD Cemented to surface Calculate TOC F_- 4,908'MD/2,811'TVD TAM Port Collar $ 401 3,039'TVD(5,872'MD) Calculated TOC 8,986'MD/3,768'TVD HES Stage Tool 4,022'TVD(10,070'MD) Cement Retainer#2 Depth 19,705' MD/6,281'TVD tT Calculated TOC 18,737'MD/6,052'TVD 7-5/8"Cement Retainer#1 • 20,085'MD/6,370'TVD7-5/8"Casing Shoe CD1-15PB2 20,223'MD/6,404'TVD 6.75"Sidetrack p1-15 PB 20,114'MD/6,377'TVD TD 9-7/8"Hole 20,700'MD/6,514'TVD Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, November 09, 2010 10:24 AM To: 'Robertson, Ryan G' �� Subject: RE: CD1-15 SUNDRY REPORT-07-6-10.xls �p 1 !� Z l o — dl • Ryan, A 403 sundry is not required to restart operations. Although all operations do revert back to the original PTD #210-047 stipulations including BOP testing requirements. An email notification including an outline of what you are planning is required a week or so before starting operations. As I recall there is a CIBP set above the WS with window cut and some OH drilled. What are the operational plans going forward?? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Monday, November 08, 2010 1:58 PM To: Schwartz, Guy L (DOA) Subject: CD1-15 SUNDRY REPORT- 07-6-10.xls Guy, CPAI is planning on re-entering the CD1-15 well in early December of this year using Doyon Rig 19. As you'll recall, this is the well that the intermediate casing was landed off bottom due to hole conditions. Two subsequent sidetrack attempts were made with the production drilling assembly once the string was cement in place, both ending in failure. As a result, the Alpine drilling team decided to temporarily suspending the well and moving to the CD4 pad before the roads thawed in mid June. A Sundry permit for an Operational Shutdown (see attached)was submitted in early July. Please correct me if I'm wrong, but to re-enter this well, we will need to submit a 10-403 Sundry to Re-Enter application? Thanks, Ryan 265.6318 11/9/2010 STATE OF ALASKA ALAL ,OIL AND GAS CONSERVATION COME. ,TION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other f Alter Casing rPerforate New Fool f Waiver r Time Extension r Change Approved Program Operat.Shutdown 17 1 Perforate r Re-enter Suspended Well r 2.Operator Name: ieCurrent Well Status: \6. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210-047 3.Address: \API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20619-00 7. PropertyResignatjon: $01 8.Well Name and Number: ADL 372108,384214,25559 .;153"5" 7 '1.7.16 CD1-15, CD1-15PB1, CD1-15PB2 9. Field/Pool(s): Colville River Field/Alpine Oil Pool 10.Present Well Condition Summary: Total Depth measured 20700 feet Plugs(measured) 19705', 20085' true vertical 6514 feet Junk(measured) None Effective Depth measured 19705' feet Packer(measured) 20080 true vertical 6281' feet (true vertucal) 6369 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 3112 10.75 3112 2394 INTERMEDIATE 20225 7.625 20225 ' 6405' RECEIVED Perforation depth: Measured depth: none True Vertical Depth: none Ail_ 0 7 2010 Alaska Oil&Cu Off.g.aimlmission Tubing(size,grade,MD,and ND) 3.5, L-80,2212 MD,2018 TVD AIti^iilt400 Packers&SSSV(type, MD,and ND) PACKER @ 20080 MD and 6369 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation not applicable Subsequent to operation 13.Attachments 14.Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service r 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WAG r GASINJ r WIND r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if CD Exempt: 310-182 Contact Ryan Robertson na 265-6318 Printed Name R a Robertson Title Alpine Drilling Engineer Signature Phone: 265-6318 Date /QG//O 17) o7zo� 7- 1—/°Submit Original Only Form 10-404 Revised 7/2009 RBDMS JUL ` WNS CD1-15 ConocoPhilli Well ributes Max Angie&MD_ TD PS Alaska.Inc r, Wellbore APWWI (FiLPINeld Name Well Status Incl r) IMO(RKB) Act Btm(RKB) rnrms>�1 I p,. € -501032061900 AE PROD 78.02 7,616 39 20,700.0 Comment H2S(ppn) Dab Annotation End Date - — KB-Grd(f0 Rig Release Date "' Last WO: 36.13 6/15/2010 •, ,HO I,,ONTfy__C01-1$,@/18,2010 746 44 AM _ -- — --._ _______866„,,A0141.1 tl�eroa66„,A al Annotation (Depth(RKS) End Date Annotation (Last Mod...End Dab Last Tag: Rev Reason:NEW WELL,SUSPENDED - Imosbor 6/18/2010 Casing Strings - -- --'-- - --'Cuing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WI..String...String Top That HANGER,31— --- - t CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 11-40 Welded Coring Description 'String 0... String ID...Top(R103) Sat Depth(0...SM Depth(ND)...String Wt...String...String Top Thrd SURFACE 103/4 9.950 35.8 3,112.2 2,393.4 45.50 L-80 ETC Casing Description String 0... String ID._Top(RKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd— WINDOW 8 7.000 20,067.0 20,081.0 6,369.3 Casing Description String 0... String ID...Top(fiKB) Set Depth(t...Set Depth(TVD)...String Wt...String...String Top Thrd INTERMEDIATE 7 5/8 6.875 _ 33.5 20,224.9 6,404.7 29.70 L-80 BTCM Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(L.Set Depth(TVD)...String Wt...i String...'String Top Thrd Tubing-Short String 3 1/2 2.992 30.6 2,212.0 2,017.9 9.30 j L-80 i EUE Completion Details . Top Depth (ND) Tp Incl Ir.."C _Top(RKB) ( B) (1 Hem Dasaipdon Comment ID(In) 30.6 30.6 0.21 HANGER FMC tubing hanger 11`OD 4.500 �1 34.5 34.5 0.21 XO Reducing XOL-3 112”EUE 8nd(P)X 4 7/2`IBT 3.958 1 2,211.5 2,017.5 49.47 WLEG WLEG 2.99"ID-4.5"OD 2.992 Other In Hole(Wirelineretrievable plugs,valves Wimps fish,etc.) Top Depth --- �•, CONDUCTOR, i (f VD) Top Incl c....37-114-\ ando u j Top(PIKE) MKB) C) Desenpdon Comment Run Date ID(b). 19,705 6,281.1 76.58 Cement BAKER CMT RETAINER 6/12/2010 Retainer 20,067 6,365.8 75.68 Whipstock WHIPSTOCK-ANCHOR BILLET 6/7/2010 WLEG,2,212 � _.-... _ 20,080 6,369.1 75.69 PACKER 617/2010—� 20,085 6,370.3 75.70 Cement BAKER CMT RETAINER 6/3/2010 li Retainer Cement Squeezes I I -- trop Depth Bim Depth -- -- - -- (TVD) (ND) T•. SKS)Bon(RKB) ( ) ( ) Description SW Dab Comment 46.0 140.0 46.0 140.0 Cement Plug 4/28/2010 Layed 20 Bbl ASt Cement Plug to Cure Lost Returns at Conductor Shce 20,116.0 20 360.0 6,377.9 6,438.1 Cement Plug 5/29/2010 Spot Cement plug for Klck OH Notes:General&Safety SURFACE, End Date Annotation 36-3,112 6/15/2010 NOTE:WELL SUSPENDED,KILL STRING IN PLACE 6/18/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1 __,..40 vit ° I 'Xi) )0 V Cement ! Retainer, 19,705 1 WH , 20,06 20,067 L.,„ WINDER. 1 )_j-2 t)14 fr.D 20067-20,061 PACKER, o\ / 20.080 Cement ReuYner, IN 20.065 NTERMEDIATE, 344%225N Cement PlugII 20,116 Id TO(CD1-16), 20,700 ConocoPhillips Time Log & Summary Wellvlew Web Reporting Report Well Name: CD1-15 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 4/27/2010 5:00:00 PM Rig Release: 6/15/2010 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/26/2010 24 hr Summary Began Moving Rig f/CD3 to CD1 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Separate Modules, Skid Floor-Tow Motors, Pits,&Pipe Shed w/Peak- Tow Ball Mill w/ASRC-Mobilize Sub Base Under Own Power-2 Miles f/CD3 @ Midnight 04/27/2010 Continue to Move Rig t/CD1 -Spot Sub Base-Spot&Connect Ball Mill,Motor and Pit Complexes-Take On Spud Mud-Connect High Line Power-N/U Riser 00:00 06:00 6.00 0 0 MIRU MOVE TRNS P Continue to Move Rig to CD1 -Ball Mill @ CD1 -Motors, Pits and Pipe Shed Being Towed by Peak to CD3/CD2 Interchange(9 Miles)-Sub Base Moving Under Own Power(6 Miles) 06:00 07:00 1.00 0 0 MIRU MOVE OTHR P Stop for Peak Crew Change and Refueling 07:00 12:00 5.00 0 0 MIRU MOVE TRNS P Continue to Move Rig U CD1 12:00 22:00 10.00 0 0 MIRU MOVE RURD P Connect Motor and Pit Complexes- Remove Wind Walls-Spot Sub Base Over Well-Jack Floor Into Position-Spot Pits/Motors-Spot Pipe Shed-Hook Up Air/Steam and Water Lines-Hook up Service& Electrical Lines-Spot and Connect Ball Mill-Route and Connect High-Line Power Cable-Take On Spud Mud-Rig on High Line Power @ 2030-Rig Accept @ 1700 22:00 00:00 2.00 0 0 MIRU WHDBO NUND P N/U Riser and Load Pipe Shed w/5" HWDP&DP 04/28/2010 P/U 30 Stands of 5'DP,8 Stands of 5'HWDP, 8"NMFDC's&Jars-M/U BHA#1 t/98'MD-PT Lines t/ 3500 Psi-Fill Riser and Check for Leaks(80 Bbl Loss)-Drill f/114'-140'MD-Stopped Drilling o Secure Conductor and Cure Lost Returns-L/D BHA#1 -Lay 20 Bbl, 15.8 PPG AS1 Cement Plug f/140'-46'MD- WOC While Welding Conductor Supports 00:00 07:30 7.50 0 0 SURFA( DRILL PULD P P/U 30 Stands of 5"DP,8 Stands of 5' HWDP, 7 3/4"Jars and 8" NMFDC's 07:30 07:45 0.25 0 0 SURFA( DRILL RURD P R/U HES E-Line Unit 07:45 10:30 2.75 0 0 SURFA( DRILL PULD P M/U BHA#1 t/98'as Follows: Bit, Motor w/ABI, IBS, EM, Index Sub, Antenna Sub, DGR, EWR-4, HCIM, NMFS, UBHO 10:30 11:00 0.50 0 0 SURFA( DRILL SFTY P Hold Pre-Spud Meeting w/Crew Page 1 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 13:30 2.50 0 0 SURFA( DRILL CIRC P Pt Surface Lines V 3500 Psi-Fill Riser and Check for Leaks-Pumped 70 Bbls 100 Vis,20 PPB Gel Mud, No Leaks, No Returns-Continue Filling Hole, No Returns-Pumped 32 Bbl 300 Vis Mud w/25 PPB Nut Plug,then 10 Bbls 300+Vis Mud- Regained Returns-Lost 80 Bbls to the Hole-Shut Down, Monitor Well (Slight Static Losses) 13:30 14:00 0.50 0 140 SURFA( DRILL DDRL P M/U NMFDC's and Drill f/114'-140' MD-Stop Drilling Due to Mud Ring Around Conductor-S/B NMFDC's 14:00 16:00 2.00 140 0 SURFA( DRILL PULD T L/D BHA#1 to Work on Conductor 16:00 19:45 3.75 0 140 SURFA( DRILL RURD T P/U 4 Jts 3 1/2"Tubing-Excavate Cellar for Welding Conductor Supports-R/U to Cement Conductor Shoe 19:45 20:00 0.25 140 140 SURFA( CEMEN"SFTY T PJSM on Laying Cement Plug in Wellbore and Conductor 20:00 20:45 0.75 140 0 SURFA( CEMEN"CMNT T Lay Cement Plug as Follows: Pumped 25 Bbls SAPP/Water Pill- 55 Bbls Water-20 Bbls 15.8 PPG AS1 Cement- 1.5 Bbls Wash Water -R/D Cement Hose-Pulled Tubing f/ Cement-Pumped 5 Bbls Wash Up to Clear Cement f/Lines-LID Cement String-CIP 2045 20:45 00:00 3.25 0 0 SURFA(CEMEN"WOC T Wait on Cement-70 Bc Thickening Time 2:56-SIMOPS:Weld Conductor Support 04/29/2010 Continue to WOC and Weld Supports on Conductor-Clean Out Cement t/140'MD-Drill V 150'MD w/ Water-Monitor Well(9 BPH Static Losses)-M/U BHA#2-Displace to Spud Mud and Drill V 160'M67 Monitor D- Monitor Well(2 BPH Static Losses)-Continue to Drill Surface Hole V 1,402'MD 00:00 00:45 0.75 0 0 SURFA( DRILL WOC T Continue to WOC and Weld Conductor Supports 00:45 01:15 0.50 0 0 SURFA( DRILL PULD T M/U Bit, Motor,XO and HWDP 01:15 02:00 0.75 0 0 SURFA(CEMEN-DRLG T Clean out Cement f/50'to 140'MD- Drill 10'New Hole w/Water 02:00 02:30 0.50 0 0 SURFA( DRILL OWFF T Monitor Well on TT-Static Losses 9 BPH-POOH 02:30 04:30 2.00 0 0 SURFA( DRILL PULD T M/U BHA#2-Orient UBHO and Index Sub- 04:30 05:00 0.50 0 0 SURFA( DRILL CIRC T Dispalce V Spud Mud and Drill 10' New Hole-Monitor Hole for Static Losses(2 BPH) 05:00 05:30 0.50 0 0 SURFA( DRILL OTHR T Discusses Results w/Town Engineer Wait on Orders 05:30 12:00 6.50 140 597 SURFA( DRILL DDRL P Drill 13 1/2"Hole w/Motor t/597'MD Taking E-Line Gyro's Every Stand ADT 2.4,AST 1.16,ART 1.24 P/U 110, Rot 110, S/O 110 Torque On/Off 4.5/4 WOB 2-20/RPM 40 450 GPM @ 730 Psi Page 2 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 597 1,402 SURFA( DRILL DDRL P Drill 13 1/2"Hole w/Motor U 1402' MD-Took E-Line Gyro's U 1006'MD ADT 5.55,AST 3.2,ART 2.35 P/U 134, Rot 130, 5/0 127 Torque On/Off 8/6.5 WOB 10-35/RPM 50 500 GPM @ 1160 Psi 04/30/2010 Drill f/1,402'-3,122'MD-CBU X2-Perform Wiper Trip to the Top of HWDP(932'MD)-RIH U 3,122'MD- Circ&Condition Mud for Trip 00:00 12:00 12.00 1,402 2,628 SURFA( DRILL DDRL P Drill 13 1/2"Hole w/Motor from 1402' I MD to 2628'MD 2246'TVD ADT 9.42 hrs.,AST 3.43 hrs.,ART 5.99 hrs. P/U 138, Rot 125, S/O 125 Torque On/Off 8.5/7.5 K ft/lbs WOB 25-35/RPM 55 700 GPM @ 2560 Psi No losses to well recognised 12:00 17:30 5.50 2,628 3,122 SURFA( DRILL DDRL P Drill 13 1/2"Hole_w/Motor t/3,122' MD(2,396'TVD)TD ADT 4.3,AST 1.6,ART 2.7 P/U 132,S/O 118, Rot 125 Torque On/Off 8/6.5-RPM 60 700 GPM @ 2650 Psi WOB 20-30 17:30 18:15 0.75 3,122 3,122 SURFA( DRILL CIRC P CBU X2 @ 700 GPM w/2250 Psi and 60 RPM 18:15 23:30 5.25 3,122 3,122 SURFA( DRILL WPRT P Perform Wiper Trip-BROOH @ 650-500 GPM w/2100-1100 Psi- OWFF(Static)-RIH U 3,122'on Elevators(No Tight Spots Encountered) 23:30 00:00 0.50 3,122 3,122 SURFA( DRILL CIRC P Circ&Cond Mud Pumping 700 GPM w/2400 Psi and 60 RPM 05/01/2010 C&C Mud f/3122'to 2827', POOH to 1022'(Tight @ 1067'&1056'),Circ @ 1022', POOH&L/D BHA, Rig& run 10-3/4"csg to 3112'(CBU @ 1206',2162'), Rig cmt head&C 7C Mud,Cement 10-3/4"csq w/468.0 bbls lead&61.4 bbls Tail displace cmt w/20 bbls fresh water&271.4 bbls mud Bum. .1u• w/1200 psi, Had full circ thru out job, Had 2229 bbls good cmt to surface, CIP @ 22:15 hrs 5/1/10, Rig Dn cmt heat, Flush riser, L/D landing jt.&csg equip. 00:00 01:15 1.25 3,122 2,827 SURFA( DRILL CIRC P Circ&Cond. Mud f/Running 10-3/4" Casing at rate of 700 gpm @ 2430 psi,60 rpm,Stand back 1 stand every 30 min. 01:15 03:15 2.00 2,827 1,022 SURFA( DRILL TRIP P POOH f/2,827'to 1,022'(Tight @ 1,067'&1,056'), Monitor well- Static. 03:15 03:45 0.50 1,022 1,022 SURFA( DRILL CIRC P Circ Btm up at rate of 500 gpm @ 1140 psi. 03:45 04:45 1.00 1,022 75 SURFA( DRILL TRIP P Continue to POOH to HWDP, Monitor well-Static,Stand back HWDP&Flex Collars. Page 3 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 07:15 2.50 75 0 SURFA( DRILL PULD P PJSM, Lay down BHA-UBHO, HCIM,Antenna sub, Index sub, Break bit, Lay down Stab&Mud motor,Clean&Clear rig floor. 07:15 08:45 1.50 0 SURFA( CASING RURD P PJSM, Rig to run 10-3/4"csging, Static mud losses 2.5 BPH while rigging up. 08:45 13:00 4.25 0 1,206 SURFA( CASING RNCS P PJSM, Run 10-3/4"casing shoe track,Check same, RIH to 1206' (Work thru tight spots @ 284',450'). 13:00 13:30 0.50 1,206 1,206 SURFA( CASING CIRC P Circ btm's up(Had mild packing off- then freed up), Stage pumps up to 5 bpm @ 370 psi, Had full returns. 13:30 14:45 1.25 1,206 2,162 SURFA( CASING RNCS P Continue to run 10-3/4"casing to 2162'with no problems. 14:45 15:30 0.75 2,162 2,162 SURFA( CASING CIRC P Circ btm's up, Stage pumps up to 5 bpm @ 420 psi. 15:30 16:45 1.25 2,162 3,074 SURFA( CASING RNCS P Continue to run 10-3/4"casing to 3074'with no problems, Had good displacement while running casing. 16:45 17:30 0.75 3,074 3,112 SURFA( CASING RURD P Make up Hanger&Landing jt., Land casing @ 3112', Rig up Dowell Cmt head. 17:30 19:30 2.00 3,112 3,112 SURFA( CEMEN-CIRCP Circ&Cond.Mud for cement, Stage pumps up to 7 bpm @ 340 psi, Reciprocate casing 30'while circ Up 198K, Dn 150K.. 19:30 00:00 4.50 3,112 3,112 SURFA(CEMEN-CMNT P PJSM, Pump 75 bbls Nut plug maker mud followed by 35 bbls Biozan viscous spacer with rig,Turn over to Dowell&pump 5 bbls fresh water, Test lines to 3000 psi-OK, Drop Btm Plug, Mix&Pump 50 bbls 10.5 ppg MudPUSH II at rate of 6.0 bpm @ 175 psi, Followed by 468.0 bbls(582 sxs)m10 7...ppg ARGTI�.aFT Lite dead cement at rate of 6.4 bpm @ 160 psi, Followed by_61.4.bbls(297 sxs) 15.8 ppg Class"G"Tail cement at rate of 4.7 bpm @ 150 psi,Shut down, Drop Top Plug, Displace cement w/20 bbls fresh water& 271.4 bbls 9.9 ppg mud at rate of 7.0 bpm©350 to 840 psi, Slowed rate to 3 bpm @ 620 psi for last 10 bbls, Bump plug w/1200 psi, Had full circ thru out job, Had 229 bbls good cement to surface, C.I.P. @ 22:15 hrs 5/1/10. 05/02/2010 N/D Riser, N/U Wellhead&BOPE, Slip&Cut drlg line 250', P/U 5""S"&"G"pipe&stand back in drk. 00:00 01:30 1.50 SURFA(WHDBO NUND P PJSM, Nipple down riser. 01:30 02:45 1.25 SURFA(WHDBO NUND P Remove slip lock assembly, Insatll Wellhead&Test to 1000 psi-OK. 02:45 04:30 1.75 SURFA(WHDBO NUND P PJSM, Nipple up BOPE, Pick up Mouse hole. Page 4 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04:30 07:00 2.50 SURFA( RIGMNT SLPC P PJSM, Slip&cut drilling line 250', Service top drive. 07:00 17:00 10.00 SURFA(WHDBO PULD P PJSM, Pick up 40 stands"S"Drill pipe from pipe shed&stand back in derrick. 17:00 17:45 0.75 SURFA(WHDBO SVRG P Service rig. 17:45 21:00 3.25 SURFA(WHDBO PULD P Continue to pick up 5"drill pipe via mouse hole&stand back in derrick. 21:00 22:00 1.00 SURFA( DRILL OTHR T Lost High line power,Wait on CD1 electricians to get rig back on high line power. 22:00 00:00 2.00 SURFA( DRILL PULD P Continue to pick up 5"Drill pipe (Total of 54 stands"S"pipe& 109 stands"G"pipe),Total of 193 stands in drk(Will single in w/22 more stands"G"with BHA) 05/03/2010 Finish P/U 5"DP, Rig&test BOPE to 250/3500 psi Hydril to 250/2500 psi test waived by AOGCC Jeff Jones, Pull test plug,Thaw out Kelly hose, Retest Top drive IBOP to 250/3500 psi, P/U BHA&shallow test same,Single in to 1507',Circ&check pressure, Drop ball&open Well Commander sub,Close same, RIH to 2892', Rig to test 10-3/4"csg,Circ BTU. 00:00 00:30 0.50 0 0 SURFA( DRILL PULD P PU and stand back last 9 joints of 5" G drill pipe 00:30 06:00 5.50 0 0 SURFA(WHDBO BOPE P Set lower test plug and fill stack with water-RU and test BOPE-Tested choke,kill, manifol,top drive and p floor safety valves to 250/3500 psi- 60 Annular preventor to 250/2500 psi- Performed Accumulator test- AOGCC rep.Jeff Jones waived witnessing tests. 06:00 08:00 2.00 0 0 SURFA(WHDBO BOPE T Attempted to pull test plug from wellhead-tight.Tried with both tuggers-no good-Pulled 20K with top drive 4"movement-RU and displace stack to mud-wash top of test plug through drill pipe @ 8 bpm- pulled test plug with top drive-5-10K using bail kickers to rock test plug- inspected test plug-recovered a hand full of small mill cuttings off of plug body observed very minor scratching to test plug body 08:00 08:45 0.75 0 0 SURFA(WHDBO OTHR P MU stack washer sub-RIH carefully to 36'-wash up through stack- made several pases across ram cavities-LD wash sub 08:45 09:15 0.50 0 0 SURFA(WHDBO OTHR P Install long wear bushing into wellhead-LD running tool 09:15 10:15 1.00 0 0 SURFA( RIGMNT RGRP P Thawed small ice plug from top drive circulating hose-MU hose to top drive 10:15 11:00 0.75 0 0 SURFA(WHDBO BOPE T Retest upper and lower top drive IBOP valves-250/3500 psi-good Page 5 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 0 0 SURFA( DRILL PRTS P Test mud lines from pumps to top drive IBOP valve-pop off sheared on first attempt @ 4200 psi-pinned pop offs up from 4600 psi to 5200 psi- obtained 4400 psi test of mud lines- repinned pop offs to 4600 psi for drilling mode. 12:00 16:00 4.00 0 101 SURFA( DRILL PULD P MU BHA#3-9 7/8"PDC bit, Geo-Pilot 7600,flex collar, DGR, EWR-P4, NM Stab, PWD, HCIM, SDL,CTN, POS Pulsur, -plug in and upload tools-ALD failed competency test 16:00 17:15 1.25 101 101 SURFA( DRILL PULD T Change out ALD&CTN collars. 17:15 18:15 1.00 101 124 SURFA( DRILL PULD P Up load MWd tools,Continue to pick BHA,Shallow test MWD tools. 18:15 20:15 2.00 124 214 SURFA( DRILL PULD P PJSM, Load RA Sources, Pick up Flex Collars 20:15 21:00 0.75 214 1,507 SURFA( DRILL PULD P Single in w/5""G"pipe from pipe shed to 1507'. 21:00 22:00 1.00 1,507 1,507 SURFA( DRILL DHEQ P Break circ&check pressures 167 spm/700 gpm @ 2240 psi, Drop ball&open Well Commander sub, Recheck pressures 167 spm/700 gpm @ 140 psi, Drop Closing ball& Close Well Commander sub, Recheck pressures 167 spm/700 gpm @ 2250 psi. 22:00 23:00 1.00 1,507 2,892 SURFA( DRILL PULD P Continue to Single in w/5""G"pipe from pipe shed to 2892'. 23:00 00:00 1.00 2,892 2,892 SURFA( DRILL CIRC P Rig to test 10-3/4"casing,Circ Btm's up. 05/04/2010 Tested 10 3/4"casing to 3500 psi-Washed down to top of cmt @ 3000'-Clean out shoe track,drilling FC @ 3025'&FS @ 3109'-Cleaned out rat hole to 3122'-Drilled 20'new hole to 3142'-Circ&performed LOT to 17.0 ppg EMW-Changed over f/spud mud to 9.6 ppg LSND-Drilled 9 7/8"hole w/Geopilot f/3142'to 5079' 00:00 01:00 1.00 2,892 2,892 SURFA( DRILL PRTS P RU and test 10 3/4"casing to 3500 psi for 30 minutes RD&blow down lines 01:00 01:45 0.75 2,892 3,025 SURFA( CEMEN-COCF P Wash and ream from 2,892'clean out cement from 3,000'to 3,025' (FC)-650 gpm/2230 psi/60 rpm @ 8500 ft/lbs. 01:45 05:45 4.00 3,025 3,122 SURFA( CEMEN-DRLG P Drill out FC, cement FS and clean out rathole to 3122'-650 gpm/2230 psi/60 rpm @ 8500 ft/lbs. 05:45 06:00 0.25 3,122 3,144 SURFA( DRILL DDRL P Drill 9 7/8"hole from 3,122'to 3,142' MD 2,401'TVD 660 gpm/2170 psi/70 rpm @ 8500 ft/lbs. 10K WOB 06:00 06:30 0.50 3,144 3,144 SURFA( DRILL CIRC P Circulate and condition mud for FIT. 1650 gpm/2150 psi/60 rpm @8000 ft/Ibs MW in &out @ 9.6 ppg Page 6 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:00 0.50 3,144 3,144 SURFA( DRILL LOT P RU and perform LOT-Determined leak off of 17.0 ppg EMW with 9.6 ppg mud and 920 psi applied surface pressure.-RD lines 07:00 12:00 5.00 3,144 3,558 INTRM1 DRILL DDRL P Drilled 9 7/8"hole with GeoPilot from 3,142"to 3,558'MD/2,497'TVD ADT 3.56 hrs,5-15K wob, 140 rpm's 750 gpm at 2240 psi. Torque on/off btm 10K/7Kft-lbs PUW 140K SOW 112K RotWT 125K 9.6 ppg MW, ECD 10.28 ppg. 12:00 00:00 12.00 3,558 5,079 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/3558'to 5079'MD 2849'TVD ADT-10.8 hrs. ECD-10.70 ppg Footage-1521' WOB 5-15 k RPM 140 GPM 775 @ 2850 psi String wt. PU 150 SO 115 ROT 130 Torque on/off btm.-10,000/8,000 ft/lbs 05/05/2010 Drilled 9 7/8"hole w/GP f/5079'to 7836' 00:00 12:00 12.00 5,079 6,412 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/5,079'to 6,412'MD 3,165'TVD ADT-6.95 hrs. ECD-10.75 ppg Footage-1333' WOB 5-13 k RPM 140 GPM 750 @ 3020 psi String wt. PU 160 SO 122 ROT 136 Torque on/off btm.-11,000/8,500 ft/lbs Added 275 bbls of 9.6 ppg whole _mud dilution @ 5475'and 6015' 12:00 00:00 12.00 6,412 7,836 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/6412'to 7836'MD 3494'TVD ADT-7.47 hrs ECD-10.68 ppg Footage 1424' WOB 5/15 k RPM 150 GPM 750 @ 3200 psi String wt. PU 162 SO 127 ROT 142 Torque on/off btm.-11500/8500 ft/lbs 05/06/2010 Drilled 9 7/8"hole w/GP f/7836'to 10,309'-(string took wt.while reaming down on connection @ 9927- reamed through spots @ 9841'-9855'-9877'-9903'&9908'-also reamed through spot @ 9978') Page 7 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 7,836 9,254 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/7,836'to 9,254'MD 3,829'TVD ADT-7.3 hrs ECD-10.61 ppg Footage 1418' WOB 10/16 k RPM 150 GPM 775 @3510 psi String wt. PU 196 SO 129 ROT 150 Torque on/off btm.-14,000/11,500 ft/lbs Added 250 bbls whole mud dilutions @ 8150', 8700',9050' 12:00 18:00 6.00 9,254 9,927 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/9254'to 9927'MD 3986'TVD ADT-3.62 hrs ECD 10.69 ppg Footage-673' WOB 10/13 k RPM 150 GPM 775 @ 3350 psi String wt. PU 210 SO 126 ROT 154 Torque on/off btm.-14,500/12,500 ft/lbs 275 bbls whole mud dilution @ 9737' 18:00 19:00 1.00 9,927 9,927 INTRM1 DRILL REAM T String took wt while backreaming down @ 9841'-9855'-9877'-9903' &9908'-reamed through 2 X-f/ 9841'to 9908'-stopped rotary& slacked off w/pump f/9908'to 9911' -cont. reaming down f/9911'to 9927' -Hole wasn't packing off 19:00 00:00 5.00 9,927 10,309 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/9927'to 10,309'MD 4046'TVD ADT 2.00 hrs ECD 10.50 ppg Footage-382' WOB 10/20 k RPM 140 GPM 775 @ 3350 psi String wt. PU 215 SO 130 ROT 155 Torque on/off btm.-15,500/13,500 ft/lbs 275 bbls whole mud dilution @ 10,200' 05/07/2010 Drilled 9 7/8"hole f/10,309'to 12,018'(Circ&cond. mud @ 11,875')-@ 12,018'-Pumped Hi-Vis sweep& circ 3 X btms up standing back 1 std DP every 30 mins.-Flow Ck(static)-BROOH f/11637'to 9072'@ 775 gpm @ 3000 psi w/140 rpm-torque 11.5 k-ECD 10.44 ppg Page 8 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 10,309 11,637 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/10,309'to 11,637'MD 4,391'TVD ADT 2.00 hrs ECD 10.50 ppg Footage-1,328' WOB 10/15 k RPM 140 GPM 775 @ 3080 psi String wt. PU 225 SO 125 ROT 165 Torque on/off btm.-16,500/15,500 ft/lbs Tight spots while raming @ 11,432', 11,517', 11,527', 11,535'-no observed pump pressure increase while reaming 275 bbls 9.6 ppg whole mud dilution @ 10,974', 130 bbls @ 11,542' 12:00 13:30 1.50 11,637 11,875 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/11637'to 11,875'MD 4446'TVD ADT-1.11 hrs, ECD 10.26 ppg Footage 238' WOB 10/15 k RPM 130 GPM 775 @ 3320 psi String wt. PU 205 SO 138 ROT 165 Torque on/off btm.-15,500/12,500 ft/lbs. Shaker screens greasing up 13:30 14:30 1.00 11,875 11,875 INTRM1 DRILL CIRC P Circ&condition mud @ 400 gpm @ 1100 psi w/130 rpm's-12 k torque- shakers screens greasing-screen down on#1 shaker 14:30 15:45 1.25 11,875 12,018 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/11,875'to 12,018'MD 4480'TVD ADT-.69 hrs. ECD-10.26 ppg Footage-143' WOB 10/15 k RPM 130 GPM 775 @ 3320 psi String wt. PU 207 SO 135 ROT 163 Torque on/off btm.-16,000/12,000 ft/lbs 15:45 18:45 3.00 12,018 11,637 INTRM1 DRILL CIRC P Circ&condition mud for wiper trip- Pumped hi-vis sweep&Circ 3 X btms up-775 gpm @ 3130 psi w/ 140 rpm's-standing back 1 std DP every 30 mins-to 11,637' 18:45 00:00 5.25 11,637 9,072 INTRM1 DRILL WPRT P Flow ck(well static)-BROOH f/ 11,637'to 9072'-775 gpm @ 3000 psi w/140 rpm-Torque 11,500 fUlbs -ECD 10.44 ppg Page 9 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/08/2010 24 hr Summary Cont. BROOH f/9072'to 3124' w'775 gpm @ 2680 psi w/140 rpm -Torque 8 to 10 k-Worked thruogh various tight spots 7940'to 5229'&3414'to 3205'-Worked GP cutters&bit through casing shoe-Pumped hi-vis weighted sweep(40 bbls)&circ btms up-Monitor wel(Obseved slight ooze)Cut&slip drill line- Service TD(monitored well on TT w/no loss/no gain)-RIH to 3175-Circ btms up-RIH to 4989'-Check GeoPilot OK-Cont. RIH f/4989'to 9547'-Hole in good condition-No problems 00:00 12:00 12.00 9,072 3,558 INTRM1 DRILL TRIP P Continue with wiper trip-BROOH f/ 9,072'to 3,558'-775 gpm @ 2610 psi w/140 rpm-Torque 7,500 ft/lbs- ECD 10.42-10.9 ppg Worked through tight spots @ 7,950',7,625',7,131',6,397',5,292'& 5,229'-Some pump pressure increase seen 100 to 150 psi, no packing off while while working through tight spots Began seeing increase in cutting volume at shakers from 4200' 12:00 14:45 2.75 3,558 3,083 INTRMI DRILL TRIP P Continue with wiper trip-BROOH f/ 3,558'to 3,083'-775 gpm @ 2680 psi w/80 rpm-Torque 8,000- 10,000 ft/lbs-ECD 10.9-10.1 ppg Had difficulty pulling non rotating stabalizer and bit into casing shoe- pulled 10k over to work each into shoe-Set deflection to 50%to assist pulling bit into shoe Observed increase in cuttings size and volume last 3 stands below shoe 14:45 15:30 0.75 3,083 3,083 INTRM1 DRILL CIRC P Pumped 35 bbls wt.'d sweep(11.8 ppg)and circulated hole clean-700 gpm until sweep out the bit(pulsor limit)775 gpm/2700 psi/60 rpm- monitor well-blow down top drive 15:30 15:45 0.25 3,083 3,083 INTRMI DRILL OWFF P Monitor well, observed large bubbles breaking out 2-3 minutes apart- slight flow as bubbles rose to surface -fluid dropping below flowline after break out-Line up and monitor well on trip tank 15:45 16:00 0.25 3,083 3,083 INTRM1 RIGMN1SFTY P PJSM-Discussed planned operations and hazards of job for long slip&cut of drill line 16:00 19:15 3.25 3,083 3,083 INTRM1 RIGMNT SLPC P Cut&slip drill line-1800'-service top drive 19:15 19:45 0.50 3,083 3,175 INTRM1 DRILL TRIP P Flow ck(well static)RIH f/3083'to 3175 19:45 20:00 0.25 3,175 3,175 INTRM1 DRILL CIRC P MU TD-Circ btms up @ 3175'650 gpm @ 1730 psi w/60 rpm-torque 8 k-Flow ck.well static 20:00 21:15 1.25 3,175 4,989 INTRM1 DRILL TRIP P Blow down TD-RIH f/3175'to 4989' Page 10 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 21:45 0.50 4,989 4,989 INTRM1 DRILL CIRC P Fill pipe&test GeoPilot-775 gpm @ 2680 psi w/14o rpms-torque 8.5 k-Blow down TD 21:45 00:00 2.25 4,989 9,547 INTRM1 DRILL TRIP P RIH f/4989'to 9547'-PU wt. 167 SO wt. 122-Hole in good condition- no problems Fill pipe every 20 stds. 05/09/2010 Cont. RIH f/9547'to 11,732'-Hole in good condition-No problems-Break circ&wash down f/11,732'to 12,018'-775 gpm @ 2840 psi w/140 rpm's-Torque 14 k-dilute mud system w/1100 bbls 9,6 ppg new LSND mud-,Qrilled97/8'hole w/GP f/12,018'to 14).299' 00:00 01:45 1.75 9,547 11,732 INTRM1 DRILL TRIP P Cont.to RIH from 9,547'to 11,732'- no problems-hole appears in good condition 01:45 03:15 1.50 11,732 12,018 INTRM1 DRILL CIRC P Precautionary wash and ream from 11,732'to 12,018'-circulate and condition mud-775 gpm/2840 psi/ 140 rpm @ 14,000 ft/lbs-diluted mud system with 825 bbls of new 9.6 ppg LSND mud 03:15 12:00 8.75 12,018 12,706 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/12,018"to 12,706'MD 4,639'TVD ADT-4.41 hrs, ECD 10.38 ppg Footage 688' WOB 10/16 k RPM 134/150 GPM 775 @ 3140 psi String wt. PU 195 SO 143 ROT 165 Torque on/off btm.-14,500/11,500 ft/lbs. 12:00 00:00 12.00 12,706 14,299 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/12706'to 14,299'MD 5013'TVD ADT-6.96 hrs ECD-10.72 ppg Footage-1593' WOB 15/25 k RPM 150 GPM 775 @ 3040 psi String wt. PU 215 SO 140 ROT 170 Torque on/off btm.-16,000/12,500 ft/lbs 275 bbl whole mud dilution @ 12,885' 05/10/2010 Drilled 9 7/8"hole w/GP f/14,299'to 16,758' 00:00 12:00 12.00 14,299 15,820 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/14,299'to 15,820'MD 5,369'TVD ADT-6.32 hrs ECD-10.78ppg Footage-1,521' WOB 10/20 k RPM 150 GPM 775 @ 3450 psi String wt. PU 245 SO 143 ROT 175 Torque on/off btm.-18,500/15,500 ft/lbs 275 bbl whole mud dilution @ 15,500' Page 11 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 15,820 16,758 INTRM1 DRILL DDRL P Drilled 8 7/8"hole w/GP f/15,820'to 16,758'MD 5590'TVD ADT- 6.22 hrs ECD 10.44 ppg Footage-938' WOB 12/18 k RPM 140 GPM 775 @ 3350 psi String wt. PU 250 SO 145 ROT 180 Torque on/off btm.-19,000/16,000 ft/lbs. 275 bbls whole mud dilution @ 16,170'&16,605' 05/11/2010 Drilled 9 7/8"hole w/GP f/16,758'to 19,175' 00:00 12:00 12.00 16,758 18,064 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/16,758'to 18,064'MD 5895'TVD ADT-6.73 hrs. ECD 10.61 ppg Footage 1306' WOB 10/25 k RPM 150 GPM 775 @3410 psi String wt. PU 254 SO 148 ROT 188 Torque on/off btm.-20,500/17,000 ft/lbs 12:00 00:00 12.00 18,064 19,175 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/18,064'to 19,175'MD 6158'TVD ADT-6.45 hrs ECD 10.74 ppg Footage 1,111' WOB 10/16 k RPM 150 GPM 775 @ 3660 psi String wt. PU 270 SO 150 ROT 193 Torque on/off btm.-20,000/16,500 ft/lbs 05/12/2010 Drilled 9 781'hole w/GP f/19,175'to 20,700'TD of 9 7/8'hole section(worked on TD-Replaced dies in Grabbs&saveer sub)-Pumped Hi-Vis sweep&began circ 3 X btms up @ 700 gpm @ 3950 psi w/150 rpm's-torque 21 k-ECD 10.82 ppg Geo Picks-Top of HRZ 19,825'-Base of HRZ 20,395' K-1 20,610' 00:00 09:00 9.00 19,175 19,827 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/19,175'to 19,827'MD 6158'TVD ADT 5.59 hrs ECD 10.83 ppg Footage-652' WOB 10/20 k RPM 150 GPM 730 @ 3990 psi String wt. PU 275 SO 150 ROT 198 Torque on/off btm.-23,500/18,500 ft/lbs. 09:00 11:30 2.50 19,827 19,827 INTRM1 RIGMNT RGRP T Unable to break out pipe-Work on TD-Changed out dies&saver sub Page 12 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 19,827 19,875 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/19,827'to 19,875'MD 6320'TVD ADT.35 hrs ECD 10.83 ppg Footage-48' WOB 10/20 k RPM 150 GPM 730 @ 3990 psi String wt. PU 275 SO 150 ROT 198 Torque on/off btm.-23,500/18,500 ft/lbs 12:00 22:15 10.25 19,875 20,700 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/GP f/19,875'to 20,700'MD 6515'TVD ADT 6.32 hrs ECD 10.86 ppg Footage 825' WOB 12/15 k RPM 150 GPM 700 @ 3970 psi String wt. PU 290 SO 147 ROT 195 Torque on/off btm.-23,000/17,500 ft/lbs 22:15 00:00 1.75 20,700 20,700 INTRM1 DRILL CIRC P Pumped Hi-vis sweep&begin circ 3 X btms up @ 700 gpm @ 3950 psi w/150 rpm-torque 21 k-ECD 10.82 ppg 05/13/2010 Circ 3 X btms up working pipe to 20,384'-BROOH f/20,384'to 19,454'-Circ 2 X btms up working pipe to 19,084'-Flow ck well static-RIH to 20,700'-Circ 3 X btms up while bumping mud wt.f/10.0 to 10.4 ppg working pipe to 20,477'-RIH to 20,700'-POOH w/pump spotting casing running pill f/20,700'to 19,455'- BROOH f/19,455'to 16,010' 00:00 03:00 3.00 20,700 20,384 INTRM1 DRILL CIRC P Circ hole for short trip 3 X btms up @ 700 gpm @ 3900 psi w/160 rpm- torque 20.5 k-working pipe f/ 20,700'to 20,384' 03:00 05:00 2.00 20,384 19,454 INTRM1 DRILL WPRT P BROOH f/20,384'to 19,454'-700 gpm @ 3810 psi w/150 rpm @21 k torque 05:00 08:30 3.50 19,454 19,084 INTRM1 DRILL CIRC P Circ 2 X btms up @ 700 gpm @ 3810 psi w/150 rpm @ 21 k torque- working pipe f/19,454'to 19,084'- Blow down TD-Flow ck-well static 08:30 09:15 0.75 19,084 20,700 INTRM1 DRILL TRIP P RIH f/19,084'to 20,700' PU wt 278 SO wt. 144 09:15 15:15 6.00 20,700 20,700 INTRM1 DRILL CIRC P Circ 3 X btms up while bumping mud wt.f/10.0 ppg to 10.4 ppg @ 700 to 675 gpm @ 3950 to 3860 psi w/150 rpm's @ 22 to 20 k torque-wprking pipe f/20,700'to 20,477'-Flow ck- well ststic-RIH to 20,700' 15:15 17:00 1.75 20,700 19,454 INTRM1 DRILL TRIP P POOH w/pump spotting casing running pill f/20,700'to 19,454'@ 3 bbls/min @ 420 psi-PU wt.280 SO wt 143 17:00 00:00 7.00 19,454 16,010 INTRM1 DRILL TRIP P BROOH f/19,454'to 16,010'@ 670 gpm @ 3770 psi w/150 rpm's @ 22 k torque-Rot wt. 190 05/14/2010 BROOH f/16,010'to 7362'-Worked through tight spots @ 14,570'-14,053'-12,829'-11,237'-9462' to 9453'-Added 275 bbls whole mud dilutions @ 15,629'&7362' Page 13 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 16,010 15,629 INTRM1 DRILL TRIP P Cont. BROOH f/16,010'to 15,629' - 670 gpm @ 3560 psi w/150 rpm's @ 18.5 k torque 01:00 03:00 2.00 15,629 15,535 INTRM1 DRILL CIRC P Circ&add 275 bbl whole mud dilution-670 gpm @ 3470 psi w/150 rpm's @ 18 k torque-working pipe f/ 15,629'to 15,535' 03:00 12:00 9.00 15,535 12,018 INTRMI DRILL TRIP P Cont. BROOH f/15,535'to 12,018'- 670 gpm @ 3190 psi w/150 rpm's @ 15 k torque-worked through tight spots @ 14,570'-14.035'&12,829' 12:00 17:30 5.50 12,018 9,462 INTRM1 DRILL TRIP P Cont. BROOH f/12,018'to 9462'- 715 gpm @ 3050 psi w/150 rpm's @ 12 k torque-Worked thruogh tight spot @ 11,237' 17:30 18:30 1.00 9,462 9,453 INTRM1 DRILL TRIP T Worked through tight hole @ 9462 to 9453'-715 gpm @ 3050 psi w/150 rpm's @ 11.5 k toruqe 18:30 22:45 4.25 9,453 7,362 INTRMI DRILL TRIP P Cont. BROOH f/9453'to 7362'-715 gpm @ 2900 psi w/150 rpm's @ 11 k torque 22:45 00:00 1.25 7,362 7,362 INTRMI DRILL CIRC P Flow ck-well static-Circ&add 275 bbls mud dilution-715 gpm @ 2900 psi w/150 rpm @ 11,5 k torque 05/15/2010 BROOH f/7362'to 3082'-Pump hi-vis pill&circ btms up-Spot clay buster pill-C&S drill line-Pump bit balling pill&circ out clay buster pill.-Flow ck Static-POOH on TTto 2792'-Hole fill short-Flow ck Static- POOH w/pump to 2227'-POOH on TT to 1871'-LD 11 std DP f/derrick-POOH w/pump f/1871'to 625'& Std back in derrick-LD HWDP to 218' 00:00 12:00 12.00 7,362 3,082 INTRM1 DRILL TRIP P Cont. BROOH f/7362'to 3082'-700 gpm @ 2530 psi 150 rpm's-Worked through tight spots @ 7120',6130',& 5440' 12:00 13:15 1.25 3,082 3,082 INTRM1 DRILL CIRC P Circ&pump hi-vis sweep @ 3082'- 700 gpm @ 2450 psi w/60 rpm's @ 6.5 k torque 13:15 13:45 0.50 3,082 3,082 INTRM1 DRILL CIRC P Flow ck-well static-Observed well- Spot clay buster pill around BHA& let soak -Blow down TD 13:45 14:00 0.25 3,082 3,082 INTRM1 RIGMN1SFTY P PJSM on cut&slip drill line 14:00 15:15 1.25 3,082 3,082 INTRM1 RIGMNISLPC P Cut&slip drill line 75'-Service top drive 15:15 15:45 0.50 3,082 3,082 INTRM1 DRILL CIRC P Pump bit balling pill w/12.5 ppb nut plug&circ out clay buster pill-700 gpm @ 2400 psi w/80 rpm's @ 6.5 k torque-Observed significant increase in cuttings&cuttings size 15:45 16:15 0.50 3,082 2,792 INTRM1 DRILL TRIP P Flow ck-well static-POOH on TT f/ 3082'to 2792'-Improper hole fill 16:15 17:00 0.75 2,792 2,227 INTRM1 DRILL TRIP P POOH w/pump f/2792'to 2227'- 700 gpm @ 2350 psi 17:00 19:00 2.00 2,227 1,817 INTRM1 DRILL TRIP P Flow ck-well static-Blow down TD - POOH on TT f/2227'to 1817'- having to pull slow to avoid swabbing -PU wt. 125-monitor well on TT 19:00 19:15 0.25 1,817 1,817 INTRM1 DRILL SFTY P Held PJSM on LD drill pipe Page 14 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 20:30 1.25 1,817 1,817 INTRM1 DRILL PULD P LD 11 stds DP f/derrick vai mouse hole 20:30 22:30 2.00 1,817 625 INTRM1 DRILL TRIP P POOH w/pump f/1817'to 625'-Std back DP-LD Ghost reamer&Well Commander circ sub&ball catcher 22:30 00:00 1.50 625 218 INTRM1 DRILL PULD P LD HWPD&Jars 05/16/2010 POOH LD NM flex DC's-Down load MWD-LD BHA-Pull WB-RU&Test BOPE-Changed top pipe rams to 7 5/$$Test-RU&Ran 7 5/8"casing to 1051'(25 jts total__in hole 00:00 04:00 4.00 218 0 INTRM1 DRILL PULD P LD MN flec DC's-Held PJSM on removing RA sources-Removed RA sources f/MWD tools-Plug in& down load MWD-Finish LD BHA MWD tools-GeoPilot&bit 04:00 06:30 2.50 0 0 INTRM1 WHDBO NUND P MU&RIH w/wear bushing pulling tool-Engage wear bushing-Back out lock downs-Attempt to pull WB w/tugger-Unable to pull-Latched& screwed in w/TD-work wear bushing loose-pulled 57 k-Pulled AsQ &LD WB-Observed gouged marks all around the top&a thin worn spot 01 on the btm of the wear bushing 06:30 13:45 7.25 0 0 INTRM1 WHDBO BOPE P Set test plug&Ru to test BOPE-, Tested BOPE-Annular(Hydril)to 250&2500 psi-tested pipe rams (VBR 3 1/2"x 6")-choke&kill line valves-Choke manifold valves- IBOP's-Floor safety&dart valves to 250&3500 psi w/5"test jt- performed Accumulator closure& recovery test-Tested blind rams to 250&3500 psi-PU 4"test jt.&test Annular(Hydril)to 250&2500 psi- Upper&lower pipe rams(VBR 3 1/2" x 6") to 250&3500 psi- Witnessing of test waived by Bob Noble AOGCC-Pulled test plug& blew down choke&kill lines 13:45 14:00 0.25 0 0 INTRM1 WHDBOSFTY P Held PJSM on changing rams 14:00 14:30 0.50 0 0 INTRM1 WHDBO RURD P RU to change top pipe rams f/3 1/2" x 6"VBR to 7/58"solid body 14:30 15:45 1.25 0 0 INTRM1 DRILL RURD P .RU fill up tool&casing elevators while attempting to locate 7 5/8' rams 15:45 18:00 2.25 0 0 INTRM1 WHDBO OTHR T Service rig while waiting on 7 5/8" pipe rams f/Prudhoe Bay 18:00 20:00 2.00 0 0 INTRM1 WHDBO RURD P Install 7 5/8"rams-MU&set test plug-Test 7 5/8"pipe rams to 250& 3500 psi-Pull test plug-set thin wall wear bushing 20:00 20:45 0.75 0 0 INTRM1 CASING RURD P Finish rigging up to run 7 5/8'casing ;-Held PJSM on running casing Page 15 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 00:00 3.25 0 1,051 INTRM1 CASING RNCS P Ran 7 5/8"29.7#L-80 BTCM casing as follows: Float shoe(Ray Oil Tools Silver bullet)2 jts casing- Float Collar( Halliburton super seal w/by-pass baffle installed in top of FC) 1 jt.casing-Halliburton Baffle landing collar-1 jt casing(4 jts total in hole)to 173'(first 4 connections made up w/BakerLoc-Filled pipe& checked floats-Cont. RIH w/casing f/173'to 1051'(25 jts total in hole)- PU wt. 100 So wt.95 Installed 1 straight blade centralizer on jt#1 &24 Tesco Hydro Form( 7.63"x 9.38")centralizers on jts.2 thru 25 05/17/2010 Cont. Running 7 5/8"casing f/1051'to 13559'(325 jts total in hole)-Circulated&conditioned mud @ 3137'- 5220'-7312'-9404'-11,488'-Installed Halliburton stage collar @ jt#243-Installed Hydro Form&EZee glider centralizers as per program 00:00 02:15 2.25 1,051 3,137 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTCM casing f/1051'to to 3137'(75 jts total in hole) Installed Tesco Hydro Form(7.63"x 9.38") centralizers on jts.26 thru 75 02:15 03:00 0.75 3,137 3,137 INTRM1 CASING CIRC P Break circ&circ casing capacity& condition mud-Staged pump up to 6 bbls/min.-ICP 250 psi @ 3.5 bbls/min-FCP 450 psi @ 6 bbls/min 03:00 05:30 2.50 3,137 5,220 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTCM casing f/3137'to 5225'(125 jts total in hole)PU wt. 159 SO wt. 129- Installed EZEE glider centralizers on jts.76 thru 125 05:30 06:30 1.00 5,220 5,220 INTRM1 CASING CIRC P Break circ-Circ&condition mud- Stage pump up to 6 bbls/min-ICP 340 psi @ 3.5 bbls/min FCP 550 psi @ 6 bbls/min. 06:30 08:45 2.25 5,220 7,312 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTCM casing f/5220'to 7312'(175 jts total in hole) PU wt. 192 SO wt. 135-Installed EZee glider centralizers on jts 126 thru 175 08:45 09:45 1.00 7,312 7,312 INTRM1 CASING CIRC P Break circ-Circ&condition mud- Stage pump up to 6 bbls/min. ICP 320 psi @ 3.5 bbls/min FCP 560 psi @ 6 bbls/min 09:45 12:30 2.75 7,312 9,404 INTRM1 CASING RNCS P Cont. RIH w/7 5/8'27.9#L-80 BTCM casing f/7312'to 9404'(225 jts total in hole)PU wt.215 SO wt. 140-Installed EZee glider centralizers on jts. 176 to 225 12:30 14:15 1.75 9,404 9,404 INTRM1 CASING CIRC P Break circ-circ&cond. mud- Stage pumps up to 6 bbls/min ICP 380 @ 3,5 bbls/min FCP 580 psi @ 6 bbls/min. Page 16 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 17:30 3.25 9,404 11,488 INTRM1 CASING RNCS P Cont. RIH w/7 5/8'29.7#L-80 BTCM casing f/9404'to 11,488'(275 jts total in hole) PU wt.245 SO wt 145 -Installed Halliburton HES stage collar @ jt#243(made up w/ BakerLoc)-Installed EZee glider centralizers on jts 226 to 230- Installed Tesco Hydro Form(9.83"x 7.63")on jts 243 to 268-Installed straight blade centralizers on jts 269 to 272 17:30 19:15 1.75 11,488 11,488 INTRM1 CASING CIRC P Break circ-Circ&cond. mud- Stage pump up to 5 bbls/min-ICP 380 psi @ 3.5 bbls/min FCP 600 psi @ 5 bbls/min 19:15 22:45 3.50 11,488 13,559 INTRM1 CASING RNCS P Cont. RIH w/7 5/8"29.7#L-80 BTMC casing f/11488'to 13559' 325 jts total in hole) PU wt.275 SO wt. 148 22:45 00:00 1.25 13,559 13,559 INTRM1 CASING CIRC P Break circ-Cric&cond. mud- stage pump up to 5 bbls/min-ICP 430 psi @ 3.5 bbls/min. 05/18/2010 Continue to Run Casing f/13,559'-20,223'MD(165 Joints),Stopped Every 50 joints to Condition the Mud- Appeared to Hit a Bridge at 20,_223'MD-Franks Tool Seal Failed-L/D Joint 485-Replaced Franks Tool- Attempted to Work Casing Through Bridge w/o Success 00:00 01:00 1.00 13,559 13,559 INTRM1 CASING CIRC P Continue to Condition Mud at Planned Circulation Point-5 BPM @ 550 Psi 01:00 05:00 4.00 13,559 15,648 INTRM1 CASING RNCS P Continue to RIH w/7 5/8"Casing t/ 15,648'MD(50 Joints)P/U 314,S/O 148 05:00 07:30 2.50 15,648 15,648 INTRM1 CASING CIRC P Circulate and Condition Mud While Staging Pumps Up f/2 BPM w/400 Psi to 5.5 BPM w/620 Psi 07:30 11:00 3.50 15,648 17,731 INTRM1 CASING RNCS P Continue to RIH w/7 5/8"Casing t/ 17,731'MD(50 Joints)P/U 350 S/O 148 11:00 14:30 3.50 17,731 17,731 INTRM1 CASING CIRC P Circulate and Condition Mud While Staging Pumps Up f/2 BPM w/500 Psi to 5.5 BPM w/670 Psi 14:30 17:30 3.00 17,331 19,610 INTRM1 CASING RNCS P Continue to RIH w/Casing t/19,610' MD(50 Joints) P/U 368, S/O 155 17:30 21:00 3.50 19,610 19,610 INTRM1 CASING CIRC P Circulate and Condition Mud While Stagin Pumps Up f/2 BPM w/500 Psi to 6 BPM w/790 Psi 21:00 22:15 1.25 19,610 20,223 INTRM1 CASING RNCS P Continue to RIH w/Casing t/20,223' MD(15 Joints)-Hit Bridge @ 20,223' MD Page 17 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 00:00 1.75 20,223 20,223 INTRM1 CASING CIRC T Attempt to Work Casing Down While Pumping-Set Down to Block Weight w/o Success-Hole Partially Packed Off Initially but Appeared to Clear-Seal Cup on Franks Tool Failed-LID Joint 485-Attempt to LID Joint 484 but Couldn't Due to Weight Restrictions, Picked Up to 430 Indicated-LID Franks Tool While Reciprocating Casing 05/19/2010 Continue Working.Casing an.. [idge..t 20,22T MD at Various Pump Rates w/Multiple Partial Pack Off Events-L/D Franks Tool&Pull the Mouse Hole-R/U Scaffolding for Working Cement Ops 12'Above the Rig Floor-Establish Circulation Through the Cement Head&Record Base Line Pressures 00:00 12:00 12.00 20,223 20,223 INTRM1 CASING RNCS T Attempt to Move Casing Past Bridge -Stage Pumps Up f/.5 to 5 BPM- Set Down to Block Wt. (75K indicated)and Pulled Up to 430K Indicated Numerous Times-Hole Partially Packed Off Several Times Above 3.5 BPM-Able to Reduce Pump Rate to 0-1/2 BPM and Slowly Return to Full Rate(5 BPM)- Pack Off Occurred Most Frequently While Pulling Up Near the Top of the Stoke-Maintained Full Circulation While Sitting on Bottom @ 20,223' MD 12:00 19:30 7.50 20,223 20,223 INTRM1 CASING RNCS T Continue to Attempt to Move Casing Past Bridge With and Without Pumps-Stage Pumps Up f/.5 to 5 BPM-Set Down to Block Wt. (75K indicated)and Pulled Up to 430K Indicated Numerous Times-Hole Partially Packed Off Several Times Above 3.5 BPM-Able to Reduce Pump Rate to 0-1/2 BPM and Slowly Return to Full Rate(5 BPM)- Average Pressure at Each Pack Off Event 1050 Psi @ 1 BPM-Pack Off Occurred Most Frequently While Pulling Up Near the Top of The Stoke -Maintained Full Circulation While Sitting on Bottom @ 20,223'MD Base Line Rates v. Pressures Through Franks Tool: 0.8 BPM 390 Psi 1.5BPM 410 Psi 2.0 BPM 430 Psi 2.5 BPM 480 Psi 3.0 BPM 520 Psi 3.5 BPM 570 Psi 4.0 BPM 650 Psi 19:30 19:45 0.25 20,223 20,223 INTRM1 CASING SFTY T PJSM on LID the Mouse Hole and Franks Tool Page 18 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:15 0.50 20,223 20,223 INTRM1 CASING PULD T L/D Franks Tool and Mouse Hole 20:15 21:30 1.25 20,223 20,223 INTRM1 CASING OTHR T PJSM-P/U and R/U Scaffolding for Installing Cement Head at Height 21:30 22:15 0.75 20,223 20,223 INTRM1 CEMEN-PULD P P/U Cross Over,Cement Head and Valves 22:15 00:00 1.75 20,223 20,223 INTRM1 CEMEN-CIRC P Establish Circulation-Stage Pumps Up f/1.5 BPM @ 280 Psi U 4 BPM @ 530 Psi Base Line Rate v. Pressure Through Cement Head: 1.3 BPM 280 Psi 2.0 BPM 380 Psi 3.0 BPM 450 Psi 3.5 BPM 500 Psi 4.0 BPM 530 Psi Wait for Crew Change Prior to Beginning Cement Job 05/20/2010 Cement 7 5/8"Casing Shoe w/63 Bbls of Class G Cement Displaced w/Rigyumps=CIP @ 0510-Open HES Cementer-Cement Second Stage w/41.6 Bbls of 15.8 PPG Class G Cement Displaced w/Rig Pumps -CIP @ 0805-WOC-Cut Casing at the Bell Nipple-Change Saver Sub, Grabgbers, Bales&Elevators-Cut 7 5/8"Casing at Bell Nipple 00:00 00:15 0.25 20,225 20,225 INTRM1 CEMEN'SFTY P PJSM-Cementing 7 5/8"Shoe 00:15 01:45 1.50 20,225 20,225 INTRM1 CEMEN-CMNT P Cement Casing Shoe as Follows: Pump 5 Bbls of CW100, Pressure Test Surface Lines t/3750 Psi, Pump 35 Bbls of CW100 @ 3.2 BPM w/500 Psi Pump 43 Bbls of 11.5 PPG Mud Push @ 3.6 BPM w/510 Psi, Drop Bottom Plug, Pump Remaining 7 Bbls of Mud Push at Same Rate/Pressure, Load the Closing Plug, Pump 63 Bbls of 15.8 PPG Class G Cement w/Additives @ 3.8 BPM w/400 Psi, Drop Closing Plug, Pump 20 Bbls of Fresh Water @ 3.7 BPM w/170 Psi 01:45 05:30 3.75 20,225 20,225 INTRM1 CEMEN-DISP P Displace Cement: Initial Rate/Pressure 4 BPM/200 Psi, Final Rate/Pressure 3 BPM/780 Psi- Pumped Plugs @ 9012 Strokes, Held 1280 Psi on Floats f/5 Minutes -Released Pressure and Checked Floats(Good)-CIP @ 0510 Hrs 05:30 06:00 0.50 20,225 20,225 INTRM1 CEMEN"CIRC P Shift Open HES Stage Collar @ 3250 Psi-Establish Circulation and Record Rates/Pressures Through Stage Collar as Follows: 4 BPM 270 Psi 5 BPM 320 Psi 6 BPM 370 Psi 7 BPM 440 Psi Page 19 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:15 0.25 20,225 20,225 INTRM1 CEMEN'SFTY P PJSM on Second Stage Cement 06:15 07:15 1.00 20,225 20,225 INTRM1 CEMEN'CMNT P Cement K3 as Follows: Pumped 33 Bbls of 11.5 PPG Mud Push @ 4 BPM w/250 Psi, Pumped 41.6 Bbl$ of 15.8 PPG Class G Cement w/ Additives @ 5 BPM w/305 Psi, Dropped Stage Collar Closing Plug, Pumped 20 Bbls Fresh Water @ 5.1 BPM w/60 Psi 07:15 08:30 1.25 20,225 20,225 INTRM1 CEMEN-DISP P Displace Second Stage Cement w/ Rig Pumps at the Following Rates/Pressures: Initial 7 BPM/450 Psi,Slowed t/4.0 BPM/300 Psi @ 3500 Strokes, Bumped Plug @ 4429 Strokes, Held 1200 Psi f/5 Minutes 08:30 16:00 7.50 20,225 20,225 INTRM1 CEMEN'WOC P Wait on Cement 16:00 17:00 1.00 20,225 20,225 INTRM1 CEMEN-RURD P R/D Cement Equipment and Scaffold 17:00 18:45 1.75 20,225 20,225 INTRM1 CASING RURD X Make Preparations to Cut Casing @ Bell Nipple 18:45 19:00 0.25 20,225 20,225 INTRM1 CASING SFTY T PJSM on Cutting Casing 19:00 20:30 1.50 20,225 20,225 INTRM1 CASING CPBO X Cut 7 5/8"Casio at the Bell Nipple and N/U Flow Line 20:30 23:00 2.50 20,225 20,225 INTRM1 CASING RURD X LID Casing Elevators and Long Bales -Change Saver Sub t/4"XT-39,Grab Heads, Bell Guide-Install Short Bales,4"Elevators-Service Rig 23:00 23:15 0.25 0 0 INTRM1 CEMEN-SFTY X PJSM on Running TAM Port Collar Tools and Packer 23:15 00:00 0.75 0 209 INTRM1 CEMEN'PULD X P/U TAM Port Collar Shifting Tools,6 Jts 4"XT-39 DP and Baker 7 5/8" Retrievable Packer 05/21/2010 RIH w/TAM Setting Tools and Packer on 4"DP t/5,866'MD-M/U Pump In Sub Assembly-Circulate C-k) Through Stage Collar Staging Pumps Up f/1 to 4 BPM-Cement C10 Sand w/37 Bbls of 15.8 PPG Class G 5:41Ia P Tail Cement-Close and Release f/TAM Collar-Test t/1,000 Psi-CBU @ 3 BPM-POOH t/209'MD-LID Packer,6 Jts 4"DP and TAM Setting Tools-M/U Spear and N/D Well Head 00:00 02:00 2.00 209 209 INTRM1 CEMEN'PULD X P/U and M/U Pump in Sub,XO/s, j TIW's, and Pup Joints-Set Aside for Later Use 02:00 08:30 6.50 209 5,866 INTRM1 CEMEN'TRIP X RIH w/4"XT-39 DP f/the Shed t/ 5,866'MD(178 Joints) 08:30 09:30 1.00 5,866 5,874 INTRMI CEMEN'PRTS X M/U Pump in Sub Assembly and Engage TAM Port Collar-Test Cups t/500 Psi and Cement Lines and Pump In Sub t/3500 Psi 09:30 12:30 3.00 5,872 5,874 INTRM1 CEMEN'CIRC X Condition Mud-Stage Pumps Up f/ 1 BPM @ 320 Psi t/4 BPM @ 410 Psi 12:30 12:45 0.25 5,874 5,874 INTRMI CEMEN'SFTY X PJSM on 3rd Stage Cement 12:45 13:30 0.75 5,874 5,874 INTRM1 CEMEN-CMNT X Cement C10 Sand Through TAM Port Collar as Follows: Pump 10 Bbls CW100,21.3 Bbls of 11.5 PPG Mud Push, 37 Bbls of 15.8 PPG Class G Cement, and 20 Bbls of Water Page 20 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:00 0.50 5,874 5,874 INTRM1 CEMEN-DISP X Displace Cement w/39.9 Bbls of 10.4 PPG LSND 14:00 14:30 0.50 5,874 5,700 INTRM1 CEMEN-PRTS X Close TAM Port Collar-Release and Test t/1000 Psi(Good) 14:30 16:00 1.50 5,700 5,700 INTRM1 DRILL CIRC X LID 6 Jts of 4"DP-Shear Ball Seat @ 2630 Psi and CBU @ 3 BPM w/ 440 Psi 16:00 21:00 5.00 5,700 209 INTRM1 DRILL TRIP X POOH on TT f/5,700'MD to 209'MD (172 Jts) 21:00 21:45 0.75 209 0 INTRM1 DRILL PULD X OWFF(Static)-LID Packer,6 Stands of 4"DP and TAM Port Collar Setting Tool 21:45 22:15 0.50 0 0 INTRM1 DRILL PULD T M/U Casing Spear and Drain Stack and Casing-Stab Into Casing w/ Spear 22:15 22:45 0.50 0 0 INTRM1 DRILL PULD X Break Apart and UD Pump in Sub Assy: 10'Pup,TIW X2, Pump In Sub,4 1/2"IF to 4"XT39 Crossovers X2, and 15'Pup 22:45 00:00 1.25 0 0 INTRM1 WHDBO NUND I T N/D Riser Surface Lines-Pull Mouse Hole-Break Wellhead Bolts 05/22/2010 Continue to N/D Well Head-Set 7 5/8"Emergency Slips w/150K-Cut&Remove Casing-Set 7 5/8"Pack Off-N/U Well Head-Test Pack Off t/3800 Psi f/10 Minutes-Change Upper.RarnS..-11D 5"DP Vibe—Derrick rrick 00:00 01:30 1.50 0 0 INTRM1 WHDBO NUND T Continue to N/D well Head and raise BOPE 01:30 04:00 2.50 0 0 INTRM1 WHDBO NUND T P/U to 150K Over String Weight and Set Emergency Slips-Cut&Bevel 7 5/8'Casing w/WACHS Saw-UD Casing Spear and Cut Joint 04:00 05:30 1.50 0 0 INTRM1 WHDBO NUND T Install Pack-Off and N/U Well Head (Torqued Bolts t/1900 ft/lb) 05:30 06:00 0.50 0 0 INTRM1 WHDBO PRTS P Test Pack-Off t/3800 Psi f/10 Minutes(Good) 06:00 07:00 1.00 0 0 INTRM1 WHDBO OTHR P Pull Casing Wear Ring-Clean Cellar 07:00 09:00 2.00 0 0 INTRM1 WHDBO NUND P Change upper Rams t/3 1/2"by 6" Variables-N/U Hole Fill and Fill-Up Lines-Tighten and Secure Turn Buckles 09:00 09:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on Installing Mouse Hole and UD 5"DP 09:15 00:00 14.75 0 0 INTRM1 DRILL PULD P UD 5"DP Via Mouse Hole(160 Stands) 05/23/2010 Continue to L/D 5"DP f/the Derrick(44 Stands+2 Stands HWDP)-R/U and Test Annular, Upper and Lower Rams w/4"and 3'Az"Test Joints-P/U BHA#4-Slip and Cut Drill Line-RIH U 5,450'MD-Test Casing Above TAM Collar t/1,000 Psi-RIH t/6,309'MD-Test Casing t/1,000 Psi Below TAM Collar-RIH t.6,595' MD(195 Jts Total) 00:00 05:00 5.00 0 0 INTRM1 DRILL PULD P Continue to L/D 5"DP f/the Derrick (44 Stands+2 Stands HWDP) 05:00 05:30 0.50 0 0 INTRM1 RIGMNTSVRG P Service Rig 05:30 06:00 0.50 0 0 INTRM1 WHDBO RURD P R/U to Test BOPE Page 21 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:45 2.75 0 0 INTRMI WHDBO BOPE P Test Annular Preventer w/3'/z'and 4"Test Joints t/2500/250 Psi and Upper and Lower Variable Rams t/ 3500/250 Psi-Test Choke Line t/ 3500/250 Psi 08:45 09:15 0.50 0 0 INTRM1 WHDBOOTHR P Install Bowl Protector 09:15 11:30 2.25 0 0 INTRM1 DRILL PULD P P/U&Stand Back 18 Stands of 4" DP 11:30 14:30 3.00 0 400 INTRM1 DRILL PULD T P/U Clean Out BHA#4 as Follows: Bit, 1.2'Motor,2-NMFS, DM, Res, Pulser, BAT, 3-NMFC,XO,Jars, 1 Jt HWDP, Bumper Sub,4 Jts HWDP 14:30 16:15 1.75 400 400 INTRM1 RIGMN1 SLPC P Slip&Cut Drill Line-Service Top Drive 16:15 20:30 4.25 400 5,450 INTRM1 DRILL TRIP T RIH w/BHA#4 on 4' DP f/the Shed t/5,450'MD(159 Joints) 20:30 21:00 0.50 5,450 5,450 INTRM1 DRILL PRTS T Establish Circulation 5 BPM @ 1540 Psi-Test Casing Above TAM Port Collar to 1,000 Psi f/10 Minutes (Good) 21:00 22:15 1.25 5,450 6,309 INTRM1 DRILL TRIP T Continue to RIH w/BHA#4 f/the Pipe Shed t/5,831'MD(12 Joints)- Rotate 1 Stand f/the Derrick Through TAM Port Collar @ 30 RPM(5,831'- 5,926'MD)Pumping 3 BPM w/750 Psi-Continue to RIH on 4"DP f/the Shed U 6,309'MD(12 Joints) 22:15 22:45 0.50 6,309 6,309 INTRM1 DRILL PRTS T Establish Circulation 5 BPM @ 1570 Psi-Test Casing Below TAM Port Collar t/1,000 Psi f/10 Minutes (Good) 22:45 00:00 1.25 6,309 6,595 INTRM1 DRILL TRIP T Continue to RIH w/BHA#4 on 4"DP from the Pipe Shed t/6,595'MD(9 Joints) 05/24/2010 Continue to RIH w/BHA#4 on 4"DP f/the Shed U 9,838'MD-Wash Down&Drill HES Stage Collar t/ 10,219'MD-Circ&Cond Mud for Casing Test-R/U and Attempt to Test Casing t/3,500 Psi(Failed)- OWFF(Flowing)-CBU-OWFF(Flowing but Decreasing)-MADD Pass f/10,219 t/9,838'MD-OWFF (Static)-POOH on TT t/400'MD-UD BHA#4-P/U RTTS and RIH t/5,920'MD-Test Casing Above Packer U Include TAM Port Collar(Failed) Leak Off Occurred @ 1,000 Psi-Test Casing&Components U 3,500 Psi f/10 Minutes(Good)-OWFF(Slight Flow)-CBU 00:00 02:30 2.50 6,595 9,838 INTRM1 DRILL TRIP T Continue to RIH w/4"DP from the Shed t/9,838'MD(102 Joints) 02:30 04:15 1.75 9,838 10,219 INTRM1 CEMEN-DRLG P Wash Down&Drill Out HES Stage Collar t/10,219'MD-230 GPM @ 2070 Psi&40 RPM(Tagged Stage Collar on Depth @ 10,070'MD 04:15 05:15 1.00 10,219 10,219 INTRMI DRILL CIRC P CBU Prior to Testing Casing 230 GPM w/2020 Psi&40 RPM 05:15 06:15 1.00 10,219 10,219 INTRMI DRILL PRTS P R/U and Test Casing(Failed)- Pressure Rose Steadily to 3050 Psi (9 Bbls Pumped)and Broke Over/Injected @ 3100 Psi w/9.5-10.0 Bbls Pumped 06:15 06:45 0.50 10,219 10,219 INTRM1 DRILL OWFF X OWFF(Flowing) 06:45 08:00 1.25 10,219 10,219 INTRM1 DRILL CIRC X CBU @ 230 GPM w/1990 Psi 7 40 RPM Page 22 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 09:00 1.00 10,219 10,219 INTRM1 DRILL OWFF X OWFF(Flowing)-Flow Rate Reduced f/6 BPH to 1.5 BPH in 1 _ hour 09:00 10:15 1.25 10,219 9,838 INTRM1 DRILL DLOG X MADD Pass f/10,219'-9,838'MD- OWFF(Static) 10:15 16:00 5.75 9,838 400 INTRM1 DRILL TRIP X Pump Dry Job&POOH on TT U 400' MD(99 Stands) 16:00 18:30 2.50 400 0 INTRM1 DRILL PULD X Download MWD Data and UD BHA #4 per DD and MWD Techs 18:30 21:45 3.25 0 5,920 INTRM1 CEMEN"TRIP X P/U Baker Retrievamatic and RIH t/ 5,920'MD(62 Stands)-Set Packer 21:45 23:15 1.50 5,920 5,920 INTRM1 DRILL PRTS X Pressure Test f/5,920'to Surface by Pumping Down Kill Line-Pressure Appeared to Inject w/1/2 Bbls Pumped @ 1,000 Psi, Pressure Bled V 350 Psi In 1 Minutes;Check Surface Equipment; Repeat Test w/ Injection @ 1,000 Psi and 2.1 Bbls Pumped, Pressure Bled V 650 Psi in 15 Seconds and 250 Psi in 2 Minutes-Pump Down Drill Pipe to Test Casing/Components f/5,920'to 20,093'MD-Pumped 9.5 Bbls w/ Pressure Rising Steadily to 3,500 Psi, Pressure Dropped f/3,400 Psi V 3,325 Psi in 10 Minutes-Suspect Problem w/TAM Port Collar 23:15 23:30 0.25 5,920 5,920 INTRM1 DRILL OWFF X OWFF(Flowing) 23:30 00:00 0.50 5,920 5,920 INTRM1 DRILL CIRC X CBU @ 5.5 BPM w/680 Psi 05/25/2010 OWFF(Flowing;Continuously Reducing f/1.6 BPH to 0 in 45 Minutes)-POOH while Pumping V 5,443'MD- OWFF(Static)-POOH&L/D Retrievamatic Packer-P/U PESI Tool and RIH V 5,872'MD-Close TAM Port Collar and Test 7 5/8"Casing V 3,500 Psi f/30 Minutes(Good)_Pull 45'Above TAM PC and Test t/3,500f/ 10 Minutes(Good)-OWFF(Static)-POOH and UD TAM Tool-Begin P/U BHA#5 00:00 00:45 0.75 5,920 5,920 INTRM1 DRILL OWFF X OWFF(Flowing), Rate Continuously Reducing f/1.6 BPH to Static in 45 _ Minutes 00:45 01:30 0.75 5,920 5,443 INTRM1 DRILL TRIP X POOH w/Pumps t/5,443'MD- OWFF(Static) 01:30 07:30 6.00 5,443 0 INTRM1 DRILL TRIP X POOH on TT-UD Retrievamatic Packer(62 Stands) 07:30 07:45 0.25 0 0 INTRM1 DRILL PULL X P/U PESI TAM Port Collar Closing _Tools 07:45 16:30 8.75 0 5,872 INTRM1 DRILL TRIP X RIH w/TAM Port Collar Closing Tools V 5,872'MD(62 Stands) P/U 130, SIO 102 Torque 7K @ 20 RPM 16:30 18:30 2.00 5,872 5,827 INTRM1 DRILL PRTS X Engage/Close TAM Port Collar by Pulling 15k Over-Test 7 5/8"Casing V 3,500 Psi f/30 Minutes, Held 3,340 Psi-Disengage Tool and Pull 45'Above Collar-Retest Casing t/ _ 3,500 Psi f/10 Minutes 18:30 18:45 0.25 5,827 5,827 INTRM1 DRILL OWFF X OWFF(Static) Page 23 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 22:15 3.50 5,827 0 INTRM1 DRILL TRIP X POOH w/TAM Collar Tools(62 Stands) 22:15 22:30 0.25 0 0 INTRM1 DRILL PULD X UD TAM Tool 22:30 23:00 0.50 0 0 INTRM1 DRILL PULD X Clear Rig Floor 23:00 00:00 1.00 0 100 INTRM1 DRILL PULD X P/U BHA#5 per DD and MWD Tech's to 100'MD 05/26/2010 P/U Remainder of BHA#5-RIH t/5,836'MD-Rotate Through Port Collar t/5,931'MD-RIH t/6,599'MD- Test Casing t/3500 Psi f/10 Minutes-RIH t/19,285'MD-Slip&Cut 60'Drill Line-Rlh t/19,600'MD-Begin logging Cement wL.BAT Sonic and Drilling_.F1oat.Equipmentand.Ratllo�e 00:00 02:00 2.00 100 400 INTRM1 DRILL PULD X P/U Remainder of BHA#5 t/400'MD 02:00 06:45 4.75 400 5,836 INTRM1 DRILL TRIP X RIH w/BHA#5 on 4"DP f/the Shed t/5,836'MD(57 Stands) 06:45 07:30 0.75 5,836 5,931 INTRM1 DRILL TRIP X Rotate Through Port Collar f/t/5,931' MD 07:30 08:00 0.50 5,931 6,599 INTRM1 DRILL TRIP X Continue to RIH w/4"DP f/the Derrick t/6,599(7 Stands) 08:00 08:45 0.75 6,599 6,599 INTRM1 DRILL PRTS X R/U and Test Casing t/3500 Psi f/ 10 Minutes 08:45 17:45 9.00 6,599 19,285 INTRM1 DRILL TRIP T Continue to RIH t/19,285'MD(94 Stands f/the Derrick and 120 Joints f/the Pipe Shed) 17:45 19:15 1.50 19,285 19,285 INTRM1 RIGMN1SLPC P Slip&Cut 60'Drilling Line 19:15 19:45 0.50 19,285 19,600 INTRM1 DRILL TRIP T Continue to RIH U 19,600'MD(4 Stands) 19:45 21:00 1.25 19,600 19,900 INTRM1 DRILL DLOG P Log Cement w/BAT Sonic Tool 21:00 00:00 3.00 19,900 20,239 INTRM1 CEMEN-DRLG T Washed Down w/20,092'MD- Drilled Cement, baffle Collar, Float Collar, Float Shoe and Rat Hole U 20,239'MD P/U 255, 5/0 90, Rot 155 40 RPM-Motor RPM 177 230 GPM w/3060 Psi Torque 20 K WOB 4-7K 05/27/2010 Continued to Attempt Hole Clean Out-Numerous Packoff Events @ 20,285',20,245', 20,286'MD-Able to Reduce Pumps and Work Pipe Free To Regain Full Circulation After Returning to the Shoe Weight Up Mud System U 10.6 PPG-Conduct FIT U 15.0 PPG EMW-Continue to Wash/Ream U 20,303'MD-Weight Up Mud System U 10.8 PPG-Logged Cement w/BAT Sonic Tool f/Bit Depth 20,303'to 20,204'MD-Continued Cleaning Hole U 20,390'MD-Hole Packed Off-Reamed U 20,271 Before Full Circulation was Regained- Wash Down U 20,335'MD-Hole Packed Off-Worked Pipe Free and Reamed to Shoe Before Full Circulation Returned-POOH w/Pumps U 19,751'MD-OWFF(Static in 60 Minutes)-Continue to POOH w/Pumps U 19,189'MD Page 24 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 20,239 20,299 INTRM1 DRILL FCO T Continue to Clean Out Hole t/20,285' MD-Attempt to Slide f/20,265'to 20,285'MD(Unable to Hole TF)- Hole Packed Off @ 20,285'MD- Worked Pipe Up&Down V 20,299' MD w/Pumps On/Off-POOH t/ Casing Shoe w/Rotation and Pulling 20K Over Rotating Weight P/U 260, S/O 95, Rot 155 Torque 20-23K @ 75 RPM 230 GPM @ 3100 Psi 02:30 04:45 2.25 20,220 20,220 INTRM1 DRILL CIRC T CBU @ 20,220'MD 230 GPM @ 2950 Psi, 75 RPM 04:45 06:15 1.50 20,220 20,220 INTRM1 DRILL FCO T Attempt to Clean Rat Hole t/20,245' MD-Packed Off-Worked Pipe Back to Casing Shoe RPM 80-100,Torque 20-23K 230 GPM @ 2950 Psi 06:15 09:45 3.50 20,220 20,220 INTRM1 DRILL FCO T Establish Full Circulation and Attempt to Clean Hole-Washed t/ 20,303'MD-Hole Packed Off While Back Reaming @ 20,286'MD- Shoe Pipe to Casing S oe w/17 GPM-Establish Full Circ Rate Inside the Shoe-Begin Weighting up Mud System f/10.4 to 10.6 PPG 09:45 11:45 2.00 20,220 20,220 INTRM1 DRILL WASH T Wash Down t/20,255'MD and Reamed Back to Shoe-Then Washed t/20,285'MD and Reamed Back to the Shoe-Hole Did Not Pack Off 11:45 13:00 1.25 20,220 20,220 INTRM1 DRILL FIT T Perform FIT t/15.0 PPG EMW w/ 10.6 PPG MW In/Out-After Shut In Pressure Dropped t/1280 In 10 Minutes 13:00 14:15 1.25 20,220 22,303 PROD1 DRILL WASH T Clean/Wash Down t/20,303'MD- Back Ream w/No Problems-Make Second Pass w/Pumps Only, No Problems-Start Increasing MW to 10.8 PPG 245 GPM @ 3190 Psi 75 RPM w/21.5k Torque 14:15 14:45 0.50 22,303 20,204 PROD1 DRILL DLOG P Log Cement w/BAT Sonic Tool f/Bit Depth 20,303'-20,204'MD 14:45 16:45 2.00 20,204 20,271 PROD1 DRILL WASH T Clean Open Hole V 20,390'MD- Packed Off-Worked String Back U 20,271'MD @'h BPM Before Regaining Full Circulation Rate 16:45 19:15 2.50 20,271 20,225 PROD1 DRILL WASH T Wash/Clean Open Hole U 20,335' MD-Packed Off-Worked Pipe U Casing Shoe @ 20,225'MD Before Regaining Full Circulation Rate 19:15 19:30 0.25 20,225 20,225 PROD1 DRILL OWFF T OWFF(Oozing-Rate Reducing) Page 25 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:15 1.75 20,225 19,571 PROD1 DRILL REAM T BROOH t/19,571'MD 21:15 22:15 1.00 19,571 19,571 PROD1 DRILL OWFF T OWFF-Rate Reduced f/2 BPH to Static in 60 Minutes 22:15 00:00 1.75 19,571 19,189 PROD1 DRILL TRIP T Attempt to POOH on TT(Swabbing)- POOH w/Pumps U 19,189'MD 5 BPM @ 2200 Psi 05/28/2010 Continue to POOH t/400'MD(197 Stands)-L/D BHA#5-Rig Up and Test BOPE w/4"Test Joint U 250/5,000 Psi and Annular U 250,3500 Psi 00:00 01:00 1.00 19,189 18,140 PROD1 DRILL TRIP T Continue to Pump Out of Hole t/ 18,140'MD(11 Stands) 01:00 14:00 13.00 18,140 400 PROD1 DRILL TRIP T OWFF(Static-Not Swabbing)- Continue to POOH U 400'MD(186 Stands) 14:00 16:15 2.25 400 0 PROD1 DRILL PULD T L/D BHA#5 per DD and MWD Technicians 16:15 17:30 1.25 0 0 PROD1 WHDBO NUND P Clean&Clear Rig Floor-Wash BOPE Stack-Drain BOPE Stack 17:30 18:00 0.50 0 0 PROD1 WHDBO NUND P Pull Wear Ring 18:00 19:00 1.00 0 0 PROD1 WHDBO BOPE P Set Test Plug-R/U To Test BOPE- Fill Stack and Choke w/Water- Grease Auto IBOP 19:00 00:00 5.00 0 0 PROD1 WHDBO BOPE P Test BOPE as Follows:Annular Preventer U 250/3500 Psi,Test Choke Manifold&Valves 1-16, Auto/Manual IBOP, HCR/Manual Choke&Kill, Floor Valve, Dart, Upper/Lower/Blind Rams U 250/5000 Psi w/4"Test Joint)-Performed Accumulator Test 05/29/2010 Continue to Test BOPE w/3'h"Test Joint: Rams U 250/5000 Psi,Annular U 250/3500 Psi-Upper Rams Failed-Change Upper Rams Elements-Re-tested Upper Rams U 3%Test Joint(Good)-RIH w/30 Jts of 3'/i'EUE Tubing and Drill Pipe U 20,209'MD(202 Stands)-Circ&Condition Mud Staging Pumps Up U 5 BPM-Wash In Hole U 20,368'MD-CBU-Spot Cement Plug f/20,368'-19,875'MD-Slowly POOH-Circ& Condition Mud to Clear Drill Pipe of Contaminants 00:00 01:30 1.50 0 0 PROD1 WHDBO BOPE P Continue BOPE Test w/3''A"test Joint; Upper/Lower Rams U 250/5000 Psi,Annular U 250/3500 Psi-Upper Rams Failed 01:30 05:00 3.50 0 0 PROD1 WHDBO NUND T Open Ram Doors, Inspect Ram Doors and Change Ram Elements 05:00 06:15 1.25 0 0 PROD1 WHDBO BOPE T R/U and Re-Test Upper Rams w/3 '/�'Test Joint U 250/5000 Psi(Good) -AOGCC Inspector Chuck Scheve _Waived Witnessing the Test 06:15 06:45 0.50 0 0 PROD1 WHDBO NUND P Pull Test Plug&Set Wear Ring 06:45 09:00 2.25 0 942 PROD1 DRILL TRIP T RIH w/30 Joints of 3'/z"Tubing t/ _942'MD 09:00 10:15 1.25 942 2,177 PROD1 DRILL TRIP T RIH w/4"DP f/the Shed t/2,177' MD(39 Joints) 10:15 17:15 7.00 2,177 20,225 PROD1 DRILL TRIP T Continue to RIH w/4'DP f/the Derrick U 20,225'MD(190 Stands) P/U 282, S/O 88 Page 26 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 18:00 0.75 20,225 20,225 PROD1 DRILL CIRC T Establish Circulation and Stage Pumps Up f/1 to 5 BPM w/1780 Psi 18:00 19:45 1.75 20,225 20,368 PROD1 DRILL WASH T Wash Down t/20,368'MD @ 5 BPM w/1800 Psi-CBU 19:45 22:00 2.25 20,368 20,368 PROD1 CEMEN-PLUG T Set Cement Plug as Follows: Dowell Pumped 2 Bbl Water,Tested Surface Lines V 3,500 Psi, 15.5 Bbls 12 PPG Mud Push,36 Bbls 17 PPG Cement,4.5 Bbls 12 PPG Mud Push, 1 Bbl Water-Displaced Cement w/188 Bbls of 10.7 PPG Drilling Mud-CIP 2200 Hrs 22:00 23:15 1.25 20,368 19,636 PROD1 DRILL TRIP T POOH V 19,826'MD @ 10 FPM then V 19,636 @ 25 FPM-Est TOC After Tubing Removal 19,875'MD 23:15 00:00 0.75 19,636 19,636 PROD1 DRILL CIRC T Circulate and Condition Mud @ 5 BPM w/1950 Psi 05/30/2010 Continue to Circ and Condition Mud(Surface to Surface)-WOC; SIMOPS Change Top Drive Dollies for Preventive Maintenance-Wash Down and Tag Cement @ 20,116'MD-OWFF(Static)-POOH U 942'MD- L/D Cement Stinger(30 Joints of 3'h"Tubing)-R/U and Test Upper and Lower Pipe Rams w/5''A"Test Joint V 250/5000 Psi and Annular V 250/3500 Psi 00:00 02:00 2.00 19,636 19,636 PROD1 DRILL CIRC T Continue to Circ&Condition Mud @ 5.5 BPM w/1820 Psi; P/U 260,S/O 90 02:00 06:00 4.00 19,636 19,636 PROD1 DRILL WOC T Monitor Hole on TT While WOC- SIMOPS:Change Two Top Drive _ Dollies(Preventive Maintenance) 06:00 08:15 2.25 19,636 20,116 PROD1 DRILL WASH T Wash Down f/19,636'-20,116'MD (Tagged Cement Plug @ 20,116'MD) 2 BPM @ 860 Psi; P/U 280, S/O 90 08:15 18:00 9.75 20,116 942 PROD1 DRILL TRIP T OWFF(Static)-POOH t/942'MD (212 Stands) 18:00 20:15 2.25 942 0 PROD1 DRILL PULD T R/U and LID Cement Stinger(30 Joints 3%:"EUE Tubing,Mule Shoe .and XO's) 20:15 21:00 0.75 0 0 PROD1 DRILL RURD T R/D Tubing Handling Equipment 21:00 21:45 0.75 0 0 PROD1 WHDBO NUND P Set Test Plug,M/U 5 1/2"Test Joint R/U Surface Lines 21:45 00:00 2.25 0 0 PROD1 WHDBO BOPE P Test Upper/Lower Rams V 250/5000 Psi and Annular to 250/3500 Psi w/5 ''/z'Test Joint 05/31/2010 P/U BHA#6-PR-Lines, Shallow Test MWD and Load Nuclear Sources-P/U Remaining BHA Items and Test Circ Sub-RIH V 6,364'MD-Tested Casing V 2,000 Psi f/10 Minutes-Continue to RIH V 19,280'MD- Wash Down V 20,120'MD-Begin Displacement V 11.2 MOBM 00:00 02:30 2.50 0 146 PROD1 DRILL PULD T PJSM-P/U BHA#6: Bit,Geo-Pilot, Geo-Flex, Smart Stab, Phase 4 Collar,Smart Stab, DM,ALD,CTN, PWD, Pulser, BAT, Float Sub V 146' MD 02:30 03:15 0.75 146 146 PROD1 DRILL PULD T Upload MWD Tools 03:15 04:15 1.00 146 146 PROD1 DRILL PRTS T Pressure Test Surface Lines, Pulse Test MWD-245 GPM @ 1080 Psi 04:15 04:30 0.25 146 146 PROD1 DRILL SFTY T PJSM on Loading Nuclear Sources Page 27 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:00 1.50 146 452 PROD1 DRILL PULD T Continue to M/U BHA#6: 3 NMFDC's,XO,Jars, 1 jt HWDP, Bumper Sub,4 jts HWDP,XO,Well Commander Circ Sub and Catcher, XO t/452'MD 06:00 06:15 0.25 452 923 PROD1 DRILL TRIP T RIH w/5 Stands f/the Derrick t/923' MD 06:15 06:45 0.50 923 923 PROD1 DRILL DHEQ T Pulse Test MWD Tools-Function Commander Circ Sub 06:45 08:15 1.50 923 923 PROD1 RIGMNT SLPC P Slip&Cut 83'of Drill Line 08:15 11:00 2.75 923 6,364 PROD1 DRILL TRIP T RIH w/BHA#6 t/6,364'MD(Rotate Through TAM Collar @ 5,872'MD)- (57 Stands) P/U 140, S/O 89 Torque 8K @ 30 RPM 11:00 12:00 1.00 6,364 6,364 PROD1 DRILL PRTS T R/U and Pressure Test Casing U 2,000 Psi f/10 Minutes, Pressure Bled t/1870 Psi(Test Completed Twice w/Same Results)-Rig Down Testing Equipment 12:00 19:15 7.25 6,364 19,280 PROD1 DRILL TRIP T Continue to RIH U 19,280'MD(135 Stands) 19:15 23:30 4.25 19,280 20,120 PROD1 DRILL WASH T Wash Down&Tagged Cement @ 20,116'MD, Continue to Drill Cement t/20,120'MD-MWD/Geo-Pilot Detection Problems 23:30 00:00 0.50 20,120 20,120 PROD1 DRILL CIRC T Take SPR's at 1,2 and 3 BPM- Begin Displacement t/11.2 MOBM 06/01/2010 Changed well over f/10.8 ppg LSND to 11.2 ppg OBW-CO cmt to 20,204'-Problem w/MWD-Trouble shoot MWD-POOH for MWD-LD circ tool-Stood back HWDP-jars/bumper sbu&NM flex DC's-Down load MWD-LD MWD componets-Break bit&change jets f/5-11's to 5-12's 00:00 03:45 3.75 20,120 20,120 PROD1 DRILL CIRC T Pumped 80 bbls of water spacer with Safe-Surf-O added-Changed well over to 11.2 ppg MOBM-from 20,120' -200 gpm/3150 psi/50 rpm @ 21K ft/lbs tq.-flow check well, static 03:45 06:15 2.50 20,120 20,204 PROD1 CEMEN-DRLG T Drill out cement from 20,120'to 20,204'-220 gpm/3770 psi/60 rpm @ 14.5K ft/lbs tq. 06:15 08:30 2.25 20,204 20,204 PROD1 DRILL CIRC T Troubleshoot MWD tools-weak pulse-unable to decode-220 gpm/ /3770 psi/60 rpm @ 14.5K ft/lbs. tq.-flow check well, static 08:30 12:00 3.50 20,204 18,096 PROD1 DRILL TRIP T POOH on trip tank from 20,204'to 18,096' PUW 225K SOW 1320K- Hole taking proper fill-slugged drill pipe after first 10 stands 12:00 20:00 8.00 18,096 451 PROD1 DRILL TRIP T Cont. POOH on trip tank f/18,096'to 451'-Flow Ck-well static Page 28 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 451 0 PROD1 DRILL PULD T Handle BHA-LD Well Commander circulating tool-Stood back HWDP w/jars&bumper sub-stood back NM flex DC's-Removed RA sources f/MWD-Down load MWD-LD MWD-Pull up&break bit(change jets f/5 11's to 5 12's-MU bit 06/02/2010 MU BHA#7-RIH to 6364'(filling pipe every 20 stds&checking MWD pulse)-Tested casing to 1240 psi w/ BHA below TAM PC-Cont. RIH f/6463'to 20,099'-Cut&slip drill line&service rig-Wash down to top of cmt @ 20,204'-Clean out cement to 20,240'-Time drill off plu f/20,240'to 20,244' 00:00 02:45 2.75 0 146 PROD1 DRILL PULD T PJSM-P/U BHA#7: Bit, Geo-Pilot, Geo-Flex, Smart Stab, Phase 4 Collar,Smart Stab, DM,ALD, CTN, PWD, Pulser, BAT, Float Sub U 146' MD-upload tools-pulse test tools 02:45 03:00 0.25 146 146 PROD1 DRILL PULD T PJSM-Load source in tool 03:00 04:15 1.25 146 451 PROD1 DRILL PULD T Continue to M/U BHA#7:3 NMFDC's,XO,Jars, 1 jt HWDP, Bumper Sub,4 jts HWDP,XO,Well Commander Circ Sub and Catcher, XO U 451'MD 04:15 07:15 3.00 451 6,364 PROD1 DRILL TRIP T RIH w/BHA#7 U 6,364'MD(Rotate Through TAM Collar @ 5,872'MD)- (57 Stands) Fill pipe every 20 stands P/U 135, S/O 110 Torque 8K @ 30 RPM 07:15 08:15 1.00 6,364 6,364 PROD1 DRILL PRTS T R/U and Pressure Test Casing U 1240 Psi(w/11.2 ppg mw) Pressure Bled to 1130 Psi in 10 minutes-Rig Down Testing Equipment 08:15 12:00 3.75 6,364 13,805 PROD1 DRILL TRIP T Continue to RIH to 13,805"MD - PUW 177K SOW 110K Filled pipe every 20 stands- established circulate and checked MWD pulse at each fill up 12:00 16:15 4.25 13,805 20,099 PROD1 DRILL TRIP T Cont. RIH w/BHA#7 f/13,805'to 20,099'-Filling pipe every 20 stds& checking MWD pulse 16:15 17:45 1.50 20,099 20,099 PROD1 DRILL SLPC T PJSM-Cut&slip drill line-service rig 17:45 20:00 2.25 20,099 20,240 PROD1 DRILL WASH P Establish circ&wash down f/20099' to 20,204'(top of cmt.)Drill cmt f/ 20,204'to 20,240'@ 210 gpm 3603 psi w/50 rpm's-torque 15 k- Attempt to down link-command timed out-chnaged jet in Geo-Span *Good cement inside casing-ratty cement f/20,224'to 20,235'- polished off plug to 20,240' Page 29 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 20,240 20,244 PROD1 DRILL DDRL P Time drill off cmt plug f/20,240'to 20,244'MD 6409'TVD ADT 3.34 hrs ECD-12.66 ppg WOB 1/5 k RPM 110 GPM 210 @ 3630 psi String wt. PU 280 So 120 ROT 160 Torque on/off btm.-12,000/11,000 ft/lbs 06/03/2010 Time drilled f/20,244'to 20,280'- ABI @ 20,267'showed 74.63°indicating some drop&sample @ 20,252' was 90%shale-Circ btms up-Pull back to 7 5/8'shoe RU&perform FIT to 15.0 ppg EMW- Wash& Ream back to 20,280'hole packing off-work pipe back to 7 5/8"shoe-Wash&ream back to 20,280'(ABI @ 20,267'showing 77.71°after FIT-,Conferred w/Sperry Sun RTO&the data indicated that the well has not been sidetracked off plus-Pulled back to 20,240'&began time drilling f/20240'to 2M70' 00:00 08:15 8.25 20,244 20,280 PROD1 DRILL DDRL T Time drill off of cement plug from 20,244'to 20,280' 210 gpm/3230 psi-100 rpm @ 12.5 K ft/lbs tq. ADT-6.76 hrs. Had trouble with hole packing off @ 20,250,-20,254'-20,272' Well appears to be sidetracked-RTI @ 20,267'74.63 degeres-ABI from 9 7/8"hole at 20,267'76.48 degrees 08:15 10:00 1.75 20,280 20,280 PROD1 DRILL CIRC T Circulate and condition mud for FIT- While working pipe back to shoe hole packed off with bit @ 20,228'- work to gain circulation and free pipe -worked pipe up into shoe-regained circulation-wiped hole down to 20,280'and back to shoe with out further problems. Rot PUW 175/180K ROT SOW 150K 10:00 11:00 1.00 20,280 20,280 PROD1 DRILL FIT T RU and perform FIT to 15 ppg EMW- 11.2 ppg MWT with 1260 psi applied surface pressure -RD and blow down lines 11:00 14:30 3.50 20,280 20,280 PROD1 DRILL WASH T Wash and ream from 20,225'to 20,280'-210 gpm/3420 psi/100 rpm @ 12.5K ft/lbs Hole packing off with bit @ 20,280'- work pipe free-regained full circulation-Pulled back to 20,240' Evaluate RTI data observed-20,268' now 77.71 degrees-Consult with Sperry RTO-concluded well had not been sidetracted 14:30 00:00 9.50 20,240 20,270 PROD1 DRILL DDRL T Time drilling f/20,240'to 20,270'MD 6418'TVD ADT 9.25 hrs. ECD 12,33 ppg WOB 2-3 k RPM 110 GPM 210 @ 3400 psi String wt. PU 280 SO 120 ROT 160 Torque on/off btm.-13,000/11,500 ft/lbs. Page 30 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/04/2010 24 hr summary Cont time drilling f/20,270'to 20,292'-hole packing off&torquing up-Back ream f/20,292'to 20,194'- POOH on TT f/20,194'to 451'(pumped dry'ob @ 19,144') Flow ck-well static-LD BHA 00:00 09:00 9.00 20,270 20,929 PROD1 DRILL DDRL T Cont.time drilling f/20,270'to 20,292'MD 6421'TVD ADT 9 hrs. ECD-12.33 ppg WOB O/5 k RPM 110 GPM 220 @ 3460 psi String wt. PU 238 SO 118 ROT 170 Torque on/off btm.-13.5/12.5 ft/lbs Observed packing&hi torque @ 20,292' 09:00 10:15 1.25 20,929 20,194 PROD1 DRILL REAM T BROOH f/20,292'to 20,194' @ 220 gpm @ 3460 psi w/110 rpm's Flow ck-well static 10:15 20:45 10.50 20,194 451 PROD1 DRILL TRIP T POOH on TT f/20,194'to 19,144'- PU wt. 209 SO wt 118 -Pumped dry job-Cont.to POOH on TT f/ 19,144'to 451' 20:45 21:30 0.75 451 287 PROD1 DRILL TRIP T LD Well commander circ sub-Flow ck-well static-Stand back 2 stds HWDP w/bumper sub 21:30 22:00 0.50 287 194 PROD1 DRILL TRIP T Change elevators to 3 1/2"-LD MN _flex DC's 22:00 22:30 0.50 194 167 PROD1 DRILL PULD T PJSM on removing RA sources- Remove RA sources f/MWD-LD BAT sonic collar 22:30 00:00 1.50 167 125 PROD1 DRILL PULD T PLUG into MWD&Down load MWD -Pull pulser&LD TM collar 06/05/2010 Finish LD BHA-MU Baker cmt retainer-RIH&set @ 20.085'-RU&test casing to 2500 psi(Good Test)- String into retaine&attempt to perform full LOT-unable to break-down @ 2000 psi(17.0 ppg EMW)-Pump dry job&POOH w/DP&retainer running tool to 9542' 00:00 01:00 1.00 125 0 PROD1 DRILL PULD T Cont. LD BHA-LD pulser, PWD,RLL,DM,SP4-Geo-flex- Break bit&LD GeoPilot-Clear& clean-up rig floor 01:00 01:15 0.25 0 8 PROD1 DRILL PULD T PJSM-MU Baker K-1 cmt retainer& XO sub 01:15 12:30 11.25 8 20,085 PROD1 DRILL TRIP T RIH w/Baker cmt retainer on 4"DP f/8'to 19,940'(209 std DP)MU 4" DP pups&PU std#210-PU 1 single of DP to space out string for setting depth of retainer-PU wt.225 SO wt 125 12:30 13:15 0.75 20,085 20,085 PROD1 DRILL MPSP T MU TD-Break circ-Set Baker K-1 cmt retainer @ 20,085' 13:15 13:30 0.25 20,085 20,285 PROD1 DRILL CIRC T Circulate-staging pump f/3 to 5 bbls/min-ICP 800 psi-FCP-2160 psi-Blow down TD 13:30 14:15 0.75 20,285 20,285 PROD1 DRILL PRTS T RU&pressure test 7 5/8"casing and cement retainer to 2500 psi for 10 mins.Also confirmed TAM PC @ 5872'is closed-Good Test-Blow down lines&RD Page 31 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 17:15 3.00 20,285 20,085 PROD1 DRILL LOT T Pull up&stand back std.#210- Replace 5'pup jt w/10'pup jt-PU std#210-Remove bell guide f/btm of TD-MU 4"XT-39 head pin,valves &high pressure hose-Break circ- Sting into cmt retainer-Anchor tested retainer with 50K SOW- attempt to perform LOT-Pressure up to 2000 psi( 17.0 ppg EMW) unable to go to full leak-off-Bleed off pressure to 500 psi&unsting f/ retainer-Flow ck well static-Blow down lines&RD-Replace bell guide. Conferred with Drilling Engineer in town-decision made not to attempt full leak off& Engineer conferred w/ AOGCC on decision. 17:15 17:45 0.50 20,085 20,085 PROD1 DRILL CIRC T MU top drive-pump dry job-Blow down TD 17:45 00:00 6.25 20,085 9,542 PROD1 DRILL TRIP T POOH on TT f/20085'to 9542'-PU wt. 150 SO wt. 110 06/06/2010 Finish POOH w/DP&cmt retainer setting tool-MU whipstock assembly-Cut&Slip drill line 75'&service rig-RIH w/whipstock assembly to 6491'-Test casing to 2000 psi to confirm TAM PC is closed-Cont. RIH w/WS assembly to 18,889' 00:00 03:15 3.25 9,542 0 PROD1 DRILL TRIP T POOH on TT from 9,542'-PJSM- Lay down retainer running tools- clear tools from rig floor Note Function tested pipe rams& hydril w/remote BOP station 03:15 03:30 0.25 0 0 PROD1 WHPST SFTY T PJSM on handling whipstock components 03:30 06:00 2.50 0 114 PROD1 WHPST PULD T MU Whipstock assembly-trip anchor,WS slide,starter mill,water mellon mill,flex jt., upper watermelon mill,xo, 1 jt. hwdp,xo, DM, SP4, TM,float sub-bolt mill to slide 06:00 06:45 0.75 114 114 PROD1 WHPST PULD T Initialize MWD tools 06:45 07:30 0.75 114 290 PROD1 WHPST PULD T MU remainder of BHA-Bumper sub, Commander circ sub,XO,5 jts of HWDP-shallow test MWD 07:30 09:00 1.50 290 290 PROD1 DRILL SVRG T PJSM-Cut and slip drilling line- Service top Drive and Drawworks 09:00 13:30 4.50 290 6,491 PROD1 WHPST TRIP T RIH from 290'to 6491"-PUW 110K SOW 105K-fill pipe every 20 stands 13:30 14:30 1.00 6,491 6,491 PROD1 WHPST PRTS T RU and test casing to 2000 psi for 5 minutes,good. RD and blow down lines 14:30 00:00 9.50 6,491 18,889 PROD1 WHPST TRIP T Continue RIH w/whipstock assembly on 4"DP f/6491'to 18,889'-filling pipe every 20 stds. PU wt.220 SO wt 130 Page 32 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/07/2010 24 hr Summary Cont. RIH w/Whipstock assembly f/18,889'to 20,035'-Orient whipstock to 64°right of high side-Wash down f/20035'to 20,085'-Tagged up on cmt retainer-set btm anchor @ 20,085'-Milled window f/20,067'to. 20,080'-Drilled new hole f/20,080'to 20,112'to put top watermelon mill 20'outside window-Circ-Perform FIT to 15.2 ppg-POOH to 19,622°(improper hole fill-RIH to 20.034'-Drop ball&open well commander circ sub-Pump Super sweep&Circ btms up-Std back 1 std DP every 30 mins to 19,462'-POOH on TT to 18031'-Pumped dry job-POOH on TT to 17,651' 00:00 01:15 1.25 18,889 20,035 PROD1 WHPST TRIP T RIH w/7 5/8"Whipstock assembly from 18,889'to 20,035'-unwrap and inspect super sliders-PUW 225K SOW 123K 01:15 03:00 1.75 20,035 20,085 PROD1 WHPST CIRC T Circulate down from 20,035'to 20,085'210 gpm/2850 psi-orient whipstock slide to 64 degrees right of high side-slack off and set anchor- work assemble and sheer 35K carrier bolt 03:00 05:30 2.50 20,067 20,080 PROD1 WHPST WPST T Mill window in casincg rom 20,067'to 20,080'-210 qpm/2890 psi/80 rpm @ 13K ft/lbs-Pump 40 bbls mud w/.1 ppb Supper Sweep et4 05:30 09:15 3.75 20,080 20,112 PROD1 WHPST WPST T Drill formation from 20,080'to 20,112' MD 6376'TVD-enlarge window with watermelon mills to 6 3/4"-upper watermellon mill 20'out of window for planned GeoPilot run-pumped 40 bbls of mud with.1 ppb of Super Sweep added after top WMW in open hole 09:15 11:15 2.00 20,112 20,034 PROD1 WHPST CIRC T Circulate BU 210 gpm/2890 psi/80 rpm @ 13K ft/lbs made several passes rotating mills through window -shut down rotary and made two passes through window with mills- no problems flow chech well-static- set back 1 stand 11:15 12:00 0.75 20,034 20,034 PROD1 DRILL FIT T PJSM-RU and perform FITJn 1c 9 ppg-11.0 ppg MOBM with 1380 psi applied surface pressure-RD&blow down lines 12:00 12:30 0.50 20,034 20,034 PROD1 DRILL OWFF T Flow check well,static-clean out solids built up in drip pan below rotary table 12:30 13:00 0.50 20,034 20,034 PROD1 DRILL CIRC T Pump dry job-blow down top drive 13:00 13:45 0.75 20,034 19,622 PROD1 DRILL TRIP T POOH on trip tank from 20,234'to 19,622'PUW 245K SOW 120- PUW increased 10K,well began swabbing 13:45 15:30 1.75 19,622 20,034 PROD1 DRILL REAM T Wash and ream from 19,610'to 20,034'-225 gpm/3130 psi/80 rpm @ 12K ft/lbs-155K Rot Wt. Page 33 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 17:00 1.50 20,034 20,034 PROD1 DRILL CIRC T Flow check well,static-drop operating ball for Commander sub- pump down at 2 bpm/600 psi-ball on seat after 1164 stks w/950 psi (calc 2000 stks)increase pressure 1500 psi and then 2000 psi-tool opened -circ @ 2 bpi/490 psi- increase rate to 7 bpm @ 3840 psi 17:00 20:45 3.75 20,034 19,462 PROD1 DRILL CIRC T Pump sweep 35 bbls OBM w/12 quarts of Super Sweep-300 gpm @ 3850 psi 100 rpm's-stood back 1 std DP wevery 30 mins.to 19,462' 20:45 23:00 2.25 19,462 18,031 PROD1 DRILL TRIP T Flow Ck well static-POOH on TT f/ 19,462'to 18,031' PU wt.215 SO wt 125(Hole taking proper fill) 23:00 23:15 0.25 18,031 18,031 PROD1 DRILL CIRC T Flow ck well static-Pumped dry job -Blow down TD 23:15 00:00 0.75 18,031 17,651 PROD1 DRILL TRIP T POOH on TT f/18,031'to 17,651' PU wt.215 SO wt 125 06/08/2010 Finish POOH&LD mill assembly-Flush stack-RU&test BOPE(Witnessed by AOGCC)-MU BHA#9 (GeoPilot)RIH to 921' Function Well commander circ sub 00:00 06:30 6.50 17,651 292 PROD1 DRILL TRIP T Cont. POOH w/mill assembly f/ 17,651'to 292'-Flow ck well static 06:30 08:45 2.25 292 0 PROD1 DRILL PULD T PJSM on LD BHA-Std back HWDP -LD Well Commander circ sub,XO, Bumper Sub,float sub, Download MWD-LD MWD tools(DM-SP4- TM)XO, 1 jt HWDP, upper&lower watermelon mills, starter mill-Clear rig floor of BHA tools-Clean-up rig floor of OBM 08:45 09:30 0.75 0 0 PROD1 WHDBO NUND T PJSM on flushing stack-MU stack washer&flush stacke-Function all rams&flush stack again-LD stacke _washer&Blow down lines 09:30 11:00 1.50 0 0 PROD1 WHDBO BOPE T MU test jt.&pull wear bushing-Set test plug 11:00 17:00 6.00 0 0 PROD1 WHDBO BOPE T RU&Teste BOP as follows; ydril to 250&3500 psi-pipe rams, choke&kill line valves, choke manifold valves,floor safety&dart valves, upper&lower TD IBOP's, D/� blind rams to 250&5000 psi(Used r� /" 4"test jt)-Performed accumulator recovery test-MU 5 1/2"test jt- Tested Hydril to 250&3500 psi- Tested upper pipe rams to 250& 5000 psi-Test witnessed& approved by Bob Noble AOGCC- Blow down kill&choke lines& choke manifold-Pull test plug 17:00 17:30 0.50 0 0 PROD1 WHDBO BOPE T Set wear bushing 17:30 18:00 0.50 0 0 PROD1 DRILL OTHR T Clean out drip pans under rig floor of MOBM Page 34 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:00 3.00 0 238 PROD1 DRILL PULD T PJSM on MU BHA- MU BHA#9- Bit(#4RR2)-GeoPilot 5200-Geo Flex-Smart Stab-MWD(Slim Phase 4-Smart stab-DM collar- ALD collar-CTN collar-PWD-TM w/pulser)-Plug in&up load MWD- MU BAT Sonic&NM flex DC's 21:00 21:45 0.75 238 238 PROD1 DRILL CIRC T MU TD-pulse test MWD @ 200 gpm @ 1050 psi-60 rpm's-4.5 k torque 21:45 22:15 0.50 238 238 PROD1 DRILL SFTY T PJSM on laoding RA sources-Load RA sources into MWD tool 22:15 23:00 0.75 238 449 PROD1 DRILL PULD T Finish MU BHA#9-XO,jars,1 jt. HWDP,bumper sub,4 jts. HWDP, XO,well Commander circ sub,XO 23:00 23:15 0.25 449 921 PROD1 DRILL TRIP T RIH w/BHA#9 on 4"DP f/449'to 921' PU wt. 90 SO wt. 90 23:15 00:00 0.75 921 921 PROD1 DRILL CIRC T MU TD-Circ&establish rates- Function Well Commander circ sub- Opened&closed w/2300 psi- 06/09/2010 RIH to 6362'(rotated thru TAM PC)-RU&pressure test cag to 1000 psi Good Test-RIH to 16,182'-C&S drill line-Service TD-RIH to 20002-Obtain SPR-Wash down to 20122'-Drilled to 20,114'-string torqued up&hole packed off-stuck pipe-worked pipe free(5 hrs.)-pulled back to 20033'-Circ btms up-Attempt to wash back to TD-string taking wt. @ 20,064'(25 k)-worked pipe unable to wash&ream past 20,064' 00:00 02:45 2.75 921 6,362 PROD1 DRILL TRIP T RIH w/BHA#9(GP)f/921'to 6362' PU wt. 120 SO wt. 110-Filled pipe every 20 stds&checked MWD- Rotated through TAM PC @ 5857'20 rpm's @ 5 k torque 02:45 03:30 0.75 6,362 6,362 PROD1 DRILL PRTS T PJSM-RU&pressure test casing to 1000 psi for 10 mins.to confirm TAM PC is closed-Good Test RD&blow down lines 03:30 07:45 4.25 6,362 16,182 PROD1 DRILL TRIP T Cont. RIH f/6362'to 16,182'-PU wt. 198 SO wt. 120-filled pipe every 20 stds&checked MWD 07:45 10:00 2.25 16,182 16,182 PROD1 RIGMNT SLPC T PJSM-Cut&slip drill line 60'- Service TD-Changed swivel packing &tested to 4000 psi 10:00 12:00 2.00 16,182 20,002 PROD1 DRILL TRIP T Cont. RIH f/16,182'to 20,002' PU wt.215 SO wt. 120-filled pipe every 20 stds&checked MWD 12:00 13:30 1.50 20,002 20,112 PROD1 DRILL WASH T Establish circ-Obtain SPR's-Wash down f/20,002'to 20,112'-225 gpm @ 3710 psi -PU wt.240 SO wt. 120 13:30 13:45 0.25 20,112 20,114 PROD1 DRILL DDRL P Drilled 6 3/4"hole f/20,112'to _ 20,114'MD ADT-.07 hrs WOB 5 k RPM 35 GPM 225 @ 3800 psi String wt. PU 245 SO 120 ROT 170 Torque 12.5 k Page 35 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 18:30 4.75 20,114 20,033 PROD1 DRILL JAR T String torqued up&packed off& stuck pipe-Worked pipe-jarred up @ 325 k-slacking off to 100 k- applied 12 K torque&worked pipe- Cont.to work pipe-worked pipe free &pulled up to 20,033' 18:30 21:00 2.50 20,033 20,033 PROD1 DRILL CIRC T Established circ-staged pump up to drilling rate 225 gpm @ 3700 psi- Circ btms up @ 225 gpm @ 3700 psi -45 rpm's-torque 12.5 k-ROT wt. 170-Flow ck-well static Note-@ btms up didn't see any signs of shale-ditch magnets appeared to have increased in the amount of metal collected prior to beginning circulating btms up 21:00 00:00 3.00 20,033 20,064 PROD1 DRILL WASH T Begin washing down f/20,033'@225 gpm @ 3700 psi-String started taking weight @ 20,060'to 20,064'- 25 k-worked pipe several times f/ 20,033'to 20,064'w/pump-Wash& ream f/20,033'to 20,064'-string taking wt. @ 20,060'(20 k while rotating)worked pipe several w/ pump&rotary-Unable to pass below 20,064'(top of window 20,067')-Cont.working pipe- Conferred with drilling engineer and dicussed options. 06/10/2010 POOH w/GeoPilot assembly-LD BHA-Clean up rig floor-Work in pipe installing thread protectors on 5 1/2' liner&3 1/2"tbg-Remove 5 1/2" liner f/shed-LD Geo Span f/rig floor-MU milling assembly-RIH to 6157' -Test csg to 1000 psi for 10 mins.-Cont. RIH to 9780' 00:00 08:00 8.00 20,064 449 PROD1 DRILL TRIP T POOH on TT f/20,064'to 19,619'- Pumped dry job-Blown down TD- Cont. POOH on TT f/19,619'to 449' (top of BHA-Flow ck well static 08:00 09:15 1.25 449 145 PROD1 DRILL PULD T PJSM-LD BHA-LD XO,Well commander circ sub,XO-6 jts HWDP,jars&bumper sub, NM flex DC's 09:15 09:30 0.25 145 145 PROD1 DRILL PULD T PJSM-Remove RA sources f/MWD 09:30 12:00 2.50 145 0 PROD1 DRILL PULD T Cont. LD BHA-Down load MWD- LD MWD tools(BAT sonic,TM collar, PWD,CTN collar,ALD collar, DM collar)smart stab, Pull up&break bit-LD Slim phase 4, Smart stab, Geo flex, Geo Pilot-Clear rig floor of tools-Clean up rig floor 12:00 17:00 5.00 0 0 PROD1 DRILL OTHR T Cont.to clean up rig floor-LD Geo Span f/rig floor-Install thread protectors on 5 1/2"liner&remove f/ pipe shed-Install thread protects on 3 1/2"tbg Page 36 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:30 0.50 0 244 PROD1 DRILL PULD T MU milling BHA(starter mill, watermelon mill,flex jt.,watermelon mill,XO,2 boot bskts, bit sub,XO, Jars, 1 jt. HWDP, bumper sub,4 jts. HWDP,XO,Well Cmooander circ sub w/ball catcher,XO 17:30 21:00 3.50 244 6,157 PROD1 DRILL TRIP T RIH w/milling assembly on 4"DP to 6157'(ran slow thru TAM PC) 21:00 22:00 1.00 6,157 6,157 PROD1 DRILL PRTS T RU&pressure test casing to 1000 psi for 10 mins.(to check TAM PC) Good test-RD-Blow down lines 22:00 00:00 2.00 6,157 9,780 PROD1 DRILL TRIP T Cont. RIH w/milling assembly on 4" DP f/6157'to 9780' 06/11/2010 RIH w/mill assembly Washed down f/19 987 to 20069'Tagged obstruction-,P 1.t9.,10,9$T Cimlasond mud-POOH w/mill assembly-MU cmt retainer&RIH to 2863' 00:00 05:30 5.50 9,780 19 PROD1 DRILL TRIP T RIH f/9780'to 19,987'w/milling assembly-PU wt.220 SO wt. 125- Removed Super Sliders on trip in hole 05:30 06:00 0.50 19 20,069 PROD1 DRILL WASH T Wash down f/19,987'to 20,069'-3 bbls/min @ 1110 psi-tagged obstruction @ 20,069' 06:00 10:45 4.75 20,069 19,987 PROD1 DRILL CIRC T Circ&condition mud for trip-@ 19,987'-Dropped opening ball for Well Commander circ sub&pumped down-opened well commander- Pumped Super Sweep pill @ 7 bbls/min @ 3750 psi-Observed no metal cuttings w/sweep back to surface-Flow Ck.well static 10:45 12:00 1.25 19,987 19,510 PROD1 DRILL TRIP T POOH on TT f/19,987'to 19,510'- PU wt.215 SO wt. 125-Flow ck. well static-Pumped dry job 12:00 20:30 8.50 19,510 34 PROD1 DRILL TRIP T POOH on TT f/19,510'to 244'-Flow ck.well static-LD XO subs-Well commander-Stood back HWDP& jars-LD bumper sub 20:30 21:00 0.50 34 0 PROD1 DRILL PULD T LD-boot baskets&mills-no recovery in boot baskets 21:00 22:00 1.00 0 0 PROD1 DRILL PULD T Clean up rig floor-Send mills,circ sub down beaver slide-PU cmt. retainer 22:00 00:00 2.00 0 2,863 PROD1 DRILL TRIP T MU Baker K-1 cement retainer&RIH on 4"DP to 2863' 06/12/2010 RIH&Set cmt retainer @ 19,7.05'-Test casing&retainer to 2500 psi for 30 mins.-Attempt LOT-Pressure to 2000 psi-No leak-off( FIT to 17.00 ppg-POOH w/DP&retainer running tool-RU&test top pipe ram to 250&3500'psi-RU&Ran 3 1/2"kill string to 2177'(69 jts)-Pull tbg running wear bushing 00:00 06:30 6.50 2,863 19,658 PROD1 DRILL TRIP T RIH w/Baker K-1 cement retainer f/ 2863'to 19658' 06:30 07:00 0.50 19,658 19,705 PROD1 DRILL MPSP T Space out&set retainer @ 19,705'- Release f/retainer 07:00 08:15 1.25 19,705 197,085 PROD1 DRILL PRTS T RU&test casing&retainer to 2500 psi for 30 mins. Page 37 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 09:45 1.50 197,085 19,626 PROD1 DRILL LOT T Sting into retainer-Attempt to perform LOT-Pressure up to 2000 psi w/no leak-off(17.0 ppg EMW) bled down to 1320 psi in 10 mins. RD test equipment-Pull up to 19,626'-Flow ck.well static 09:45 11:15 1.50 19,626 19,626 PROD1 RIGMN7 SLPC T PJSM-Cut&slip drill line 120'- Service TD 11:15 18:30 7.25 19,626 0 PROD1 DRILL TRIP T Pump dry job-POOH on TT f/ 19,626'w/cmt. retainer running tool- LD running tool 18:30 19:30 1.00 0 0 PROD1 WHDBO BOPE T Pull wear bushing-Set test plug& test upper pipe rams to 250&3500 psi-Pull test plug 19:30 20:30 1.00 0 0 PROD1 RPCOM RURD T Set tubing running wear bushing& RU to run 3 1/2"kill string 20:30 23:15 2.75 0 2,178 PROD1 RPCOM RCST T Ran kill string- 3 1/2"9.3#L-80 EUE 8rd tbg(69 jts.)w/WLEG to 2177.5' 23:15 00:00 0.75 2,178 2,178 PROD1 RPCOM RCST T MU pulling tool&Retrieve tbg running wear bushing 06/13/2010 Finish pulling tbg wear bushing-_MU tbg hanger&land tbg w/tail @ 2211'-Test hanger seals to 5000 psi- _ Flush BOP stack-Break cap on Hydril-Remove rams f/stack(prep for rig maintenance)-ND BOP-NU& test tree-Freeze protect w/LVT to 100'-RU&LD 4"DP 00:00 00:30 0.50 2,178 2,178 PROD1 RPCOM RCST T Finish pulling tbg running wear bushing 00:30 01:00 0.50 2,178 2,211 PROD1 RPCOM RCST T MU tbg hanger-land 3 1/2"kill string @ 2211'-RILDS 01:00 01:30 0.50 2,211 2,211 PROD1 WHDBO PRTS T RU&test tbg hnager seals to 5,000 psi-RD-LD landing jt. 01:30 03:00 1.50 0 0 PROD1 WHDBO OTHR T RU&flush BOP stack w/Save Suf 0 to clean up OBM 03:00 09:45 6.75 0 0 PROD1 WHDBO NUND T ND bell nipple&flow line-RU spud masher&break cap on Hydril- Remove pipe rams&blind f/BOP stack-ND BOP stack 09:45 12:00 2.25 0 0 PROD1 WHDBO NUND T NU&test tree to 5000 psi-Pull TWC 12:00 12:45 0.75 0 0 PROD1 DRILL RURD T RU squeeze manifold&hard lines to tbg&annulus 12:45 13:00 0.25 0 0 PROD1 DRILL SFTY T PJSM on freeze protect well 13:00 15:30 2.50 0 0 PROD1 DRILL FRZP T Freeze protect well to 100'- Dowell pumped 10 bbls LVT down tbg.-shut in manifold&let well U-tube-Blow down&vac out lines-RU lines& manifold-Set BPV&Secure well 15:30 15:45 0.25 0 0 PROD1 DRILL SFTY T PJSM on LD DP 15:45 00:00 8.25 0 0 PROD1 DRILL PULD T LD 4"DP f/derrick via mouse hole for rig move 06/14/2010 Finish LD 4"DP via mouse hole&Remove remaining Super Sliders-Change TD dollies-Clean rig after OBM (blocks,TD, Iron roughneck-mud pits)Remove temporary hericulite wind walls in cellar-drained centrifugal pumps Page 38 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 14:00 14.00 0 0 PROD1 DRILL PULD T LD 4"DP f/derrick via mouse hole for rig move Removed remaining of Super Sliders onstds#206-#212 14:00 17:00 3.00 0 0 PROD1 RIGMNT RGRP T PJSM on changing TD dollies- Change out TD dollies 17:00 17:30 0.50 0 0 PROD1 RIGMNT SVRG T Service rig 17:30 00:00 6.50 0 0 PROD1 DRILL RURD T Clean up rig f/OBM-pressure wash blocks,TD, &iron roughneck.Clean mud pits-Remove hericulite wind walls in cellar area-Drained centrifugal pumps 06/15/2010 Continue to Clean Rig of OBM and Prep For Move-Rig Released on 15 Jun 2010 at 0600 L 00:00 06:00 6.00 0 0 PROD1 MOVE MOB P Continue to Clean Rig of OBM and Prep for Move to CD4-23 Page 39 of 39 0 3 . 1 ,::: 'i: ConocoPhillips(Alaska) Inc. iCD1Western North Slope 4 CD1 Alpine Pad J -15PB1 501032061970 Sperry s � 4 � I 1 Definitive Survey Report i iii i,i1 16 June, 2010 i H'i; !i'l Ii 2 HALLIBURTON Sperry Drilling Services ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD1-15 Well Position +N/-S 0.00 ft Northing: 5,975,805.80ft Latitude: 70°20'33.932 N', +E/-W 0.00 ft Easting: 385,901.08 ft Longitude: 150°55'33.713 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft Wellbore CD1-15PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2009 5/1/2010 21.17 80.73 57,625 Design CD1-15PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.65 Vertical Section: Depth From(TVD) +W-S +E/-W Direction jl (ft) (ft) (ft) (0) 36.65 0.00 0.00 79.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 81.00 1,006.00 CD1-15PB1 Gyro(CD1-15PB1) CB-GYRO-SS Camera based gyro single shot 4/29/2010 1: 1,106.18 3,063.99 CD1-15PB1 MWD(R200)(CD1-15PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/30/2010 1: 3,147.95 20,666.44 CD1-15PB1 MWD(R300)(CD1-15PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/4/2010 12: Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.65 0.00 0.00 36.65 -19.50 0.00 0.00 5,975,805.80 385,901.08 0.00 0.00 UNDEFINED 81.00 0.27 57.03 81.00 24.85 0.06 0.09 5,975,805.86 385,901.17 0.61 0.10 CB-GYR0-SS(1) 171.00 0.38 58.28 171.00 114.85 0.33 0.52 5,975,806.12 385,901.61 0.12 0.57 CB-GYRO-SS(1) 234.00 0.70 33.27 234.00 177.85 0.76 0.91 5,975,806.55 385,902.00 0.62 1.04 CB-GYRO-SS(1) 264.00 0.93 20.08 263.99 207.84 1.14 1.09 5,975,806.93 385,902.19 0.98 1.29 CB-GYRO-SS(1) 354.00 2.75 2.26 353.94 297.79 3.99 1.43 5,975,809.76 385,902.57 2.10 2.16 CB-GYRO-SS(1) 447.00 4.32 3.83 446.76 390.61 9.71 1.75 5,975,815.48 385,902.98 1.69 3.57 CB-GYRO-SS(1) 540.00 4.55 5.74 539.48 483.33 16.88 2.35 5,975,822.64 385,903.69 0.29 5.53 CB-GYRO-SS(1) 631.00 6.34 352.27 630.07 573.92 25.45 2.04 5,975,831.21 385,903.51 2.40 6.86 CB-GYRO-SS(1) 723.00 6.96 351.08 721.45 665.30 35.99 0.49 5,975,841.77 385,902.12 0.69 7.35 CB-GYRO-SS(1) 816.00 6.77 352.80 813.79 757.64 46.99 -1.07 5,975,852.80 385,900.73 0.30 7.92 CB-GYRO-SS(1) 911.00 7.80 2.76 908.02 851.87 58.99 -1.46 5,975,864.80 385,900.52 1.71 9.82 CB-GYRO-SS(1) 6/16/2010 10:12:24AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/1001 (ft) Survey Tool Name 1,006.00 12.03 16.93 1,001.60 945.45 74.91 1.73 5,975,880.67 385,903.96 5.11 16.00 CB-GYRO-SS(1) 1,106.18 15.23 35.28 1,098.99 1,042.84 95.65 12.38 5,975,901.24 385,914.92 5.33 30.41 MWD+IFR-AK-CAZ-SC(2) 1,163.05 16.07 45.33 1,153.76 1,097.61 107.29 22.30 5,975,912.72 385,925.01 4.98 42.36 MWD+IFR-AK-CAZ-SC(2) ' 1,257.40 19.11 52.64 1,243.70 1,187.55 125.84 43.87 5,975,930.95 385,946.86 3.98 67.07 MWD+IFR-AK-CAZ-SC(2) 1,353.84 22.01 57.15 1,333.99 1,277.84 145.23 71.60 5,975,949.91 385,974.88 3.42 98.00 MWD+IFR-AK-CAZ-SC(2) 1,449.22 25.81 61.60 1,421.18 1,365.03 164.81 104.90 5,975,968.98 386,008.47 4.41 134.42 MWD+IFR-AK-CAZ-SC(2) 1,544.31 28.82 64.36 1,505.66 1,449.51 184.58 143.78 5,975,988.15 386,047.64 3.43 176.36 MWD+IFR-AK-CAZ-SC(2) 1,639.08 30.49 66.69 1,588.02 1,531.87 203.98 186.46 5,976,006.90 386,090.61 2.14 221.95 MWD+IFR-AK-CAZ-SC(2) 1,734.54 34.30 67.36 1,668.61 1,612.46 223.92 233.54 5,976,026.13 386,137.98 4.01 271.98 MWD+IFR-AK-CAZ-SC(2) 1,829.12 38.29 67.37 1,744.82 1,688.67 245.47 285.20 5,976,046.88 386,189.97 4.22 326.80 MWD+IFR-AK-CAZ-SC(2) 1,923.99 40.41 70.58 1,818.18 1,762.03 267.00 341.35 5,976,067.56 386,246.42 3.10 386.02 MWD+IFR-AK-CAZ-SC(2) 2,018.71 44.09 72.14 1,888.29 1,832.14 287.33 401.69 5,976,086.96 386,307.06 4.04 449.13 MWD+IFR-AK-CAZ-SC(2) 2,114.41 46.91 70.87 1,955.36 1,899.21 308.99 466.41 5,976,107.63 386,372.10 3.09 516.79 MWD+IFR-AK-CAZ-SC(2) 2,209.25 49.52 73.06 2,018.55 1,962.40 330.86 533.64 5,976,128.47 386,439.65 3.25 586.97 MWD+IFR-AK-CAZ-SC(2) 2,304.06 53.34 72.61 2,077.65 2,021.50 352.74 604.45 5,976,149.27 386,510.78 4.05 660.65 MWD+IFR-AK-CAZ-SC(2) 2,398.99 57.31 74.21 2,131.65 2,075.50 375.00 679.26 5,976,170.38 386,585.92 4.41 738.33 MWD+IFR-AK-CAZ-SC(2) 2,494.57 59.53 75.52 2,181.71 2,125.56 396.24 757.86 5,976,190.43 386,664.82 2.60 819.54 MWD+IFR-AK-CAZ-SC(2) 2,589.21 63.01 75.36 2,227.19 2,171.04 417.11 838.17 5,976,210.07 386,745.43 3.68 902.36 MWD+IFR-AK-CAZ-SC(2) 2,683.09 67.26 76.12 2,266.66 2,210.51 438.07 920.70 5,976,229.77 386,828.27 4.59 987.38 MWD+IFR-AK-CAZ-SC(2) 2,779.27 69.93 77.73 2,301.76 2,245.61 458.32 1,007.92 5,976,248.68 386,915.78 3.18 1,076.85 MWD+IFR-AK-CAZ-SC(2) 2,874.84 72.96 79.05 2,332.17 2,276.02 476.54 1,096.66 5,976,265.55 387,004.77 3.43 1,167.44 MWD+IFR-AK-CAZ-SC(2) 2,969.35 75.55 78.81 2,357.81 2,301.66 494.00 1,185.92 5,976,281.66 387,094.28 2.75 1,258.39 MWD+IFR-AK-CAZ-SC(2) 3,063.99 75.46 79.06 2,381.50 2,325.35 511.59 1,275.84 5,976,297.87 387,184.46 0.27 1,350.02 MWD+IFR-AK-CAZ-SC(2) 3,147.95 76.01 78.47 2,402.19 2,346.04 527.44 1,355.66 5,976,312.51 387,264.49 0.94 1,431.39 MWD+IFR-AK-CAZ-SC(3) 3,239.59 76.45 79.46 2,424.00 2,367.85 544.48 1,443.02 5,976,328.21 387,352.09 1.15 1,520.39 MWD+IFR-AK-CAZ-SC(3) 3,337.88 76.96 80.07 2,446.60 2,390.45 561.47 1,537.15 5,976,343.77 387,446.47 0.80 1,616.04 MWD+IFR-AK-CAZ-SC(3) 3,427.41 76.70 79.55 2,467.00 2,410.85 576.90 1,622.95 5,976,357.88 387,532.48 0.64 1,703.21 MWD+IFR-AK-CAZ-SC(3) 3,527.47 77.15 79.08 2,489.64 2,433.49 594.97 1,718.72 5,976,374.49 387,628.52 0.64 1,800.67 MWD+IFR-AK-CAZ-SC(3) 3,622.17 77.46 78.25 2,510.45 2,454.30 613.13 1,809.31 5,976,391.27 387,719.36 0.92 1,893.05 MWD+IFR-AK-CAZ-SC(3) 3,722.88 76.26 78.27 2,533.34 2,477.19 633.08 1,905.32 5,976,409.76 387,815.66 1.19 1,991.12 MWD+IFR-AK-CAZ-SC(3) 3,806.66 76.64 79.09 2,552.97 2,496.82 649.07 1,985.19 5,976,424.52 387,895.75 1.05 2,072.56 MWD+IFR-AK-CAZ-SC(3) 3,906.38 76.71 79.72 2,575.96 2,519.81 666.91 2,080.57 5,976,440.91 387,991.38 0.62 2,169.59 MWD+IFR-AK-CAZ-SC(3) 4,002.46 76.39 80.24 2,598.31 2,542.16 683.17 2,172.59 5,976,455.77 388,083.63 0.62 2,263.03 MWD+IFR-AK-CAZ-SC(3) 4,098.56 76.45 80.18 2,620.87 2,564.72 699.05 2,264.64 5,976,470.25 388,175.91 0.09 2,356.42 MWD+IFR-AK-CAZ-SC(3) 4,190.21 76.64 80.47 2,642.19 2,586.04 714.03 2,352.51 5,976,483.89 388,263.98 0.37 2,445.53 MWD+IFR-AK-CAZ-SC(3) 4,288.54 76.77 80.82 2,664.81 2,608.66 729.59 2,446.93 5,976,498.00 388,358.62 0.37 2,541.18 MWD+IFR-AK-CAZ-SC(3) 4,383.53 76.45 81.25 2,686.81 2,630.66 743.99 2,538.21 5,976,511.01 388,450.10 0.55 2,633.53 MWD+IFR-AK-CAZ-SC(3) 4,479.65 76.13 81.77 2,709.59 2,653.44 757.77 2,630.56 5,976,523.39 388,542.65 0.62 2,726.82 MWD+IFR-AK-CAZ-SC(3) 4,573.88 76.00 81.68 2,732.28 2,676.13 770.94 2,721.07 5,976,535.17 388,633.34 0.17 2,818.18 MWD+IFR-AK-CAZ-SC(3) 4,668.31 76.26 81.33 2,754.92 2,698.77 784.48 2,811.74 5,976,547.33 388,724.20 0.45 2,909.77 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:12:24AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (') (0) (ft) (ft) (ft) (n) (ft) (ft) MOO') (ft) Survey Tool Name 4,762.92 76.71 80.90 2,777.03 2,720.88 798.69 2,902.63 5,976,560.15 388,815.28 0.65 3,001.69 MWD+IFR-AK-CAZ-SC(3) 4,859.62 76.58 80.76 2,799.36 2,743.21 813.68 2,995.51 5,976,573.73 388,908.37 0.19 3,095.73 MWD+IFR-AK-CAZ-SC(3) 4,954.00 76.96 79.85 2,820.96 2,764.81 829.15 3,086.07 5,976,587.82 388,999.15 1.02 3,187.58 MWD+IFR-AK-CAZ-SC(3) 5,049.78 76.71 79.91 2,842.78 2,786.63 845.54 3,177.88 5,976,602.81 389,091.19 0.27 3,280.83 MWD+IFR-AK-CAZ-SC(3) 5,144.79 75.82 78.67 2,865.34 2,809.19 862.69 3,268.56 5,976,618.57 389,182.12 1.58 3,373.12 MWD+IFR-AK-CAZ-SC(3) 5,240.27 76.08 78.62 2,888.52 2,832.37 880.93 3,359.37 5,976,635.42 389,273.19 0.28 3,465.74 MWD+IFR-AK-CAZ-SC(3) 5,334.97 75.68 79.46 2,911.62 2,855.47 898.39 3,449.54 5,976,651.51 389,363.60 0.96 3,557.58 MWD+IFR-AK-CAZ-SC(3) 5,430.78 75.94 79.66 2,935.10 2,878.95 915.22 3,540.89 5,976,666.95 389,455.19 0.34 3,650.46 MWD+IFR-AK-CAZ-SC(3) 5,528.32 76.33 80.66 2,958.48 2,902.33 931.40 3,634.19 5,976,681.71 389,548.72 1.07 3,745.14 MWD+IFR-AK-CAZ-SC(3) 5,621.09 76.77 81.15 2,980.06 2,923.91 945.66 3,723.28 5,976,694.61 389,638.01 0.70 3,835.31 MWD+IFR-AK-CAZ-SC(3) 5,711.12 76.38 80.51 3,000.96 2,944.81 959.62 3,809.73 5,976,707.25 389,724.65 0.82 3,922.84 MWD+IFR-AK-CAZ-SC(3) 5,811.41 76.33 80.49 3,024.62 2,968.47 975.70 3,905.85 5,976,721.86 389,821.00 0.05 4,020.26 MWD+IFR-AK-CAZ-SC(3) 5,902.97 76.25 80.46 3,046.32 2,990.17 990.42 3,993.58 5,976,735.25 389,908.93 0.09 4,109.19 MWD+IFR-AK-CAZ-SC(3) 6,001.81 76.63 80.25 3,069.49 3,013.34 1,006.52 4,088.30 5,976,749.90 390,003.88 0.44 4,205.24 MWD+IFR-AK-CAZ-SC(3) 6,094.77 76.51 79.76 3,091.08 3,034.93 1,022.21 4,177.35 5,976,764.23 390,093.15 0.53 4,295.65 MWD+IFR-AK-CAZ-SC(3) 6,191.66 76.33 79.07 3,113.83 3,057.68 1,039.51 4,269.93 5,976,780.12 390,185.97 0.72 4,389.83 MWD+IFR-AK-CAZ-SC(3) 6,282.72 76.45 78.67 3,135.26 3,079.11 1,056.60 4,356.77 5,976,795.88 390,273.05 0.45 4,478.33 MWD+IFR-AK-CAZ-SC(3) 6,380.98 76.89 78.46 3,157.92 3,101.77 1,075.55 4,450.48 5,976,813.41 390,367.04 0.49 4,573.94 MWD+IFR-AK-CAZ-SC(3) 6,477.93 76.65 78.48 3,180.11 3,123.96 1,094.42 4,542.95 5,976,830.86 390,459.78 0.25 4,668.31 MWD+IFR-AK-CAZ-SC(3) 6,571.23 77.02 78.14 3,201.35 3,145.20 1,112.83 4,631.92 5,976,847.91 390,549.00 0.53 4,759.15 MWD+IFR-AK-CAZ-SC(3) 6,667.35 76.70 78.28 3,223.21 3,167.06 1,131.95 4,723.54 5,976,865.64 390,640.91 0.36 4,852.75 MWD+IFR-AK-CAZ-SC(3) 6,761.79 75.82 78.39 3,245.64 3,189.49 1,150.50 4,813.39 5,976,882.81 390,731.01 0.94 4,944.48 MWD+IFR-AK-CAZ-SC(3) 6,854.81 76.63 77.92 3,267.79 3,211.64 1,169.05 4,901.81 5,976,900.01 390,819.70 1.00 5,034.81 MWD+IFR-AK-CAZ-SC(3) 6,952.15 76.20 77.69 3,290.65 3,234.50 1,189.03 4,994.29 5,976,918.59 390,912.46 0.50 5,129.41 MWD+IFR-AK-CAZ-SC(3) 7,044.81 76.32 79.19 3,312.66 3,256.51 1,207.07 5,082.47 5,976,935.28 391,000.90 1.58 5,219.41 MWD+IFR-AK-CAZ-SC(3) 7,141.39 76.77 79.03 3,335.13 3,278.98 1,224.81 5,174.70 5,976,951.61 391,093.39 0.49 5,313.34 MWD+IFR-AK-CAZ-SC(3) 7,235.54 76.13 78.53 3,357.19 3,301.04 1,242.62 5,264.48 5,976,968.05 391,183.42 0.85 5,404.86 MWD+IFR-AK-CAZ-SC(3) 7,332.00 75.74 79.35 3,380.63 3,324.48 1,260.57 5,356.31 5,976,984.60 391,275.50 0.92 5,498.43 MWD+IFR-AK-CAZ-SC(3) 7,426.53 76.58 78.93 3,403.25 3,347.10 1,277.87 5,446.45 5,977,000.52 391,365.89 0.99 5,590.22 MWD+IFR-AK-CAZ-5C(3) 7,521.98 76.96 77.82 3,425.09 3,368.94 1,296.59 5,537.46 5,977,017.86 391,457.17 1.20 5,683.12 MWD+IFR-AK-CAZ-SC(3) 7,616.39 78.02 77.52 3,445.54 3,389.39 1,316.27 5,627.50 5,977,036.16 391,547.49 1.16 5,775.27 MWD+IFR-AK-CAZ-SC(3) 7,711.63 77.22 77.74 3,465.96 3,409.81 1,336.20 5,718.37 5,977,054.70 391,638.64 0.87 5,868.27 MWD+IFR-AK-CAZ-SC(3) 7,804.85 77.01 77.29 3,486.75 3,430.60 1,355.85 5,807.09 5,977,073.00 391,727.64 0.52 5,959.11 MWD+IFR-AK-CAZ-SC(3) 7,900.20 76.83 76.47 3,508.33 3,452.18 1,376.93 5,897.54 5,977,092.70 391,818.40 0.86 6,051.92 MWD+IFR-AK-CAZ-SC(3) 7,996.22 76.01 75.62 3,530.87 3,474.72 1,399.43 5,988.12 5,977,113.82 391,909.30 1.21 6,145.13 MWD+IFR-AK-CAZ-SC(3) 8,091.41 75.63 75.41 3,554.19 3,498.04 1,422.52 6,077.48 5,977,135.54 391,998.99 0.45 6,237.25 MWD+IFR-AK-CAZ-SC(3) 8,186.75 75.88 75.07 3,577.65 3,521.50 1,446.06 6,166.84 5,977,157.72 392,088.69 0.43 6,329.46 MWD+IFR-AK-CAZ-SC(3) 8,277.58 75.75 75.21 3,599.91 3,543.76 1,468.64 6,251.95 5,977,179.00 392,174.13 0.21 6,417.32 MWD+IFR-AK-CAZ-SC(3) 8,375.41 75.81 77.24 3,623.94 3,567.79 1,491.22 6,344.05 5,977,200.17 392,266.56 2.01 6,512.03 MWD+IFR-AK-CAZ-SC(3) 8,471.95 76.01 78.70 3,647.45 3,591.30 1,510.74 6,435.63 5,977,218.29 392,358.41 1.48 6,605.65 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:12:24AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI-W Northing Easting DLS Section (ft) (0) (`) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 8,559.89 76.32 78.55 3,668.47 3,612.32 1,527.58 6,519.34 5,977,233.86 392,442.36 0.39 6,691.04 MWD+IFR-AK-CAZ-SC(3) 8,661.35 76.19 78.51 3,692.58 3,636.43 1,547.18 6,615.93 5,977,251.98 392,539.23 0.13 6,789.59 MWD+IFR-AK-CAZ-SC(3) I 8,756.03 76.13 78.81 3,715.23 3,659.08 1,565.25 6,706.06 5,977,268.68 392,629.62 0.31 6,881.52 MWD+IFR-AK-CAZ-SC(3) 8,852.33 77.23 79.06 3,737.42 3,681.27 1,583.24 6,798.03 5,977,285.26 392,721.84 1.17 6,975.23 MWD+IFR-AK-CAZ-SC(3) 8,943.79 76.45 79.70 3,758.24 3,702.09 1,599.65 6,885.56 5,977,300.34 392,809.60 1.09 7,064.28 MWD+IFR-AK-CAZ-SC(3) 9,041.44 76.64 78.71 3,780.96 3,724.81 1,617.44 6,978.85 5,977,316.70 392,903.14 1.01 7,159.25 MWD+IFR-AK-CAZ-SC(3) 9,133.06 76.57 78.48 3,802.19 3,746.04 1,635.06 7,066.22 5,977,333.00 392,990.76 0.26 7,248.37 MWD+IFR-AK-CAZ-SC(3) 9,231.80 76.63 78.59 3,825.07 3,768.92 1,654.16 7,160.35 5,977,350.65 393,085.17 0.12 7,344.42 MWD+IFR-AK-CAZ-SC(3) 9,323.73 76.39 78.14 3,846.51 3,790.36 1,672.18 7,247.91 5,977,367.34 393,172.98 0.54 7,433.81 MWD+IFR-AK-CAZ-SC(3) 9,420.41 76.89 79.02 3,868.85 3,812.70 1,690.81 7,340.11 5,977,384.56 393,265.45 1.03 7,527.87 MWD+IFR-AK-CAZ-SC(3) 9,513.25 76.89 79.58 3,889.91 3,833.76 1,707.60 7,428.95 5,977,399.99 393,354.53 0.59 7,618.29 MWD+IFR-AK-CAZ-SC(3) 9,612.05 76.44 79.25 3,912.70 3,856.55 1,725.26 7,523.45 5,977,416.21 393,449.28 0.56 7,714.42 MWD+IFR-AK-CAZ-SC(3) 9,702.93 75.44 78.46 3,934.78 3,878.63 1,742.29 7,609.95 5,977,431.93 393,536.02 1.39 7,802.58 MWD+IFR-AK-CAZ-SC(3) 9,802.78 76.59 78.41 3,958.91 3,902.76 1,761.72 7,704.87 5,977,449.90 393,631.22 1.15 7,899.46 MWD+IFR-AK-CAZ-SC(3) 9,896.37 76.33 77.76 3,980.82 3,924.67 1,780.50 7,793.90 5,977,467.33 393,720.51 0.73 7,990.44 MWD+IFR-AK-CAZ-SC(3) 9,991.27 76.13 78.14 4,003.41 3,947.26 1,799.75 7,884.04 5,977,485.20 393,810.93 0.44 8,082.59 MWD+IFR-AK-CAZ-SC(3) 10,087.34 76.14 78.88 4,026.43 3,970.28 1,818.32 7,975.44 5,977,502.38 393,902.59 0.75 8,175.86 MWD+IFR-AK-CAZ-SC(3) 10,178.49 76.77 79.23 4,047.78 3,991.63 1,835.15 8,062.44 5,977,517.88 393,989.83 0.79 8,264.48 MWD+IFR-AK-CAZ-SC(3) 10,277.05 76.77 79.08 4,070.34 4,014.19 1,853.20 8,156.67 5,977,534.49 394,084.32 0.15 8,360.42 MWD+IFR-AK-CAZ-SC(3) 10,373.74 76.53 80.52 4,092.66 4,036.51 1,869.86 8,249.26 5,977,549.74 394,177.14 1.47 8,454.48 MWD+IFR-AK-CAZ-SC(3) 10,468.40 76.51 80.41 4,114.73 4,058.58 1,885.11 8,340.04 5,977,563.60 394,268.14 0.11 8,546.51 MWD+IFR-AK-CAZ-SC(3) 10,563.75 76.58 80.80 4,136.91 4,080.76 1,900.25 8,431.53 5,977,577.35 394,359.84 0.40 8,639.20 MWD+IFR-AK-CAZ-SC(3) 10,658.73 76.20 80.71 4,159.26 4,103.11 1,915.08 8,522.64 5,977,590.79 394,451.16 0.41 8,731.47 MWD+IFR-AK-CAZ-SC(3) 10,749.57 76.13 80.31 4,180.99 4,124.84 1,929.62 8,609.64 5,977,604.00 394,538.36 0.43 8,819.65 MWD+IFR-AK-CAZ-SC(3) 10,848.65 76.46 80.04 4,204.46 4,148.31 1,946.05 8,704.49 5,977,618.98 394,633.44 0.43 8,915.88 MWD+IFR-AK-CAZ-SC(3) 10,943.84 76.78 79.01 4,226.49 4,170.34 1,962.88 8,795.55 5,977,634.43 394,724.74 1.11 9,008.49 MWD+IFR-AK-CAZ-SC(3) 11,038.57 76.76 78.75 4,248.17 4,192.02 1,980.67 8,886.03 5,977,650.83 394,815.47 0.27 9,100.70 MWD+IFR-AK-CAZ-SC(3) 11,133.10 76.20 78.29 4,270.27 4,214.12 1,998.96 8,976.10 5,977,667.75 394,905.81 0.76 9,192.61 MWD+IFR-AK-CAZ-SC(3) 11,227.58 76.58 78.17 4,292.50 4,236.35 2,017.69 9,066.00 5,977,685.11 394,995.97 0.42 9,284.43 MWD+IFR-AK-CAZ-SC(3) 11,323.51 76.08 78.26 4,315.17 4,259.02 2,036.73 9,157.25 5,977,702.76 395,087.49 0.53 9,377.63 MWD+IFR-AK-CAZ-SC(3) 11,415.81 76.02 78.04 4,337.42 4,281.27 2,055.12 9,244.92 5,977,719.81 395,175.42 0.24 9,467.20 MWD+IFR-AK-CAZ-SC(3) 11,512.50 75.88 78.40 4,360.90 4,304.75 2,074.27 9,336.74 5,977,737.56 395,267.51 0.39 9,560.99 MWD+IFR-AK-CAZ-SC(3) 11,601.81 76.32 78.42 4,382.35 4,326.20 2,091.69 9,421.67 5,977,753.68 395,352.69 0.49 9,647.68 MWD+IFR-AK-CAZ-SC(3) 11,701.69 76.26 78.16 4,406.02 4,349.87 2,111.38 9,516.68 5,977,771.93 395,447.98 0.26 9,744.70 MWD+IFR-AK-CAZ-SC(3) 11,797.82 76.50 78.46 4,428.66 4,372.51 2,130.31 9,608.17 5,977,789.46 395,539.74 0.39 9,838.12 MWD+IFR-AK-CAZ-SC(3) 11,888.40 76.26 78.81 4,449.99 4,393.84 2,147.66 9,694.47 5,977,805.49 395,626.29 0.46 9,926.15 MWD+IFR-AK-CAZ-SC(3) 11,987.84 76.44 78.95 4,473.46 4,417.31 2,166.30 9,789.29 5,977,822.68 395,721.38 0.23 10,022.78 MWD+IFR-AK-CAZ-SC(3) 12,080.37 76.71 78.85 4,494.94 4,438.79 2,183.63 9,877.61 5,977,838.66 395,809.94 0.31 10,112.79 MWD+IFR-AK-CAZ-SC(3) 12,177.23 76.45 78.85 4,517.42 4,461.27 2,201.84 9,970.05 5,977,855.47 395,902.64 0.27 10,207.00 MWD+IFR-AK-CAZ-SC(3) 12,270.65 76.32 78.78 4,539.41 4,483.26 2,219.46 10,059.12 5,977,871.72 395,991.96 0.16 10,297.79 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10::12:24AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (') (ft) (ft) (ft) (ft) (ft) (ft) (11100') (ft) Survey Tool Name 12,366.43 76.07 78.85 4,562.27 4,506.12 2,237.50 10,150.36 5,977,888.37 396,083.46 0.27 10,390.81 MWD+IFR-AK-CAZ-SC(3) 12,463.16 76.26 79.03 4,585.40 4,529.25 2,255.52 10,242.54 5,977,904.98 396,175.89 0.27 10,484.73 MWD+IFR-AK-CAZ-SC(3) 12,557.47 77.26 78.59 4,607.00 4,550.85 2,273.33 10,332.60 5,977,921.43 396,266.20 1.15 10,576.53 MWD+IFR-AK-CAZ-SC(3) 12,653.78 77.03 78.86 4,628.42 4,572.27 2,291.69 10,424.68 5,977,938.38 396,358.55 0.36 10,670.43 MWD+IFR-AK-CAZ-SC(3) 12,748.02 76.96 78.81 4,649.63 4,593.48 2,309.47 10,514.77 5,977,954.78 396,448.88 0.09 10,762.25 MWD+IFR-AK-CAZ-SC(3) 12,837.57 76.97 78.95 4,669.83 4,613.68 2,326.30 10,600.37 5,977,970.30 396,534.73 0.15 10,849.49 MWD+IFR-AK-CAZ-SC(3) 12,939.33 76.06 78.80 4,693.56 4,637.41 2,345.39 10,697.47 5,977,987.92 396,632.09 0.91 10,948.45 MWD+IFR-AK-CAZ-SC(3) 13,032.96 76.13 78.65 4,716.06 4,659.91 2,363.16 10,786.60 5,978,004.33 396,721.48 0.17 11,039.33 MWD+IFR-AK-CAZ-SC(3) 13,128.62 76.32 79.16 4,738.84 4,682.69 2,381.04 10,877.77 5,978,020.81 396,812.90 0.55 11,132.24 MWD+IFR-AK-CAZ-SC(3) 13,220.47 75.82 79.35 4,760.95 4,704.80 2,397.66 10,965.36 5,978,036.10 396,900.72 0.58 11,221.39 MWD+IFR-AK-CAZ-SC(3) 13,318.64 76.19 78.92 4,784.69 4,728.54 2,415.62 11,058.90 5,978,052.63 396,994.53 0.57 11,316,64 MWD+IFR-AK-CAZ-SC(3) 13,414.08 76.83 78.80 4,806.95 4,750.80 2,433.55 11,149.96 5,978,069.17 397,085.84 0.68 11,409.45 MWD+IFR-AK-CAZ-SC(3) 13,505.48 76.26 78.56 4,828.22 4,772.07 2,450.99 11,237.12 5,978,085.29 397,173.25 0.67 11,498.34 MWD+IFR-AK-CAZ-SC(3) 13,603.49 76.08 78.93 4,851.65 4,795.50 2,469.57 11,330.46 5,978,102.44 397,266.85 0.41 11,593.50 MWD+IFR-AK-CAZ-SC(3) 13,698.53 76.76 79.01 4,873.96 4,817.81 2,487.24 11,421.14 5,978,118.73 397,357.78 0.72 11,685.89 MWD+IFR-AK-CAZ-SC(3) 13,790.88 77.15 79.31 4,894.81 4,838.66 2,504.16 11,509.50 5,978,134.30 397,446.38 0.53 11,775.85 MWD+IFR-AK-CAZ-SC(3) 13,889.41 76.58 79.74 4,917.20 4,861.05 2,521.61 11,603.85 5,978,150.30 397,540.98 0.72 11,871.80 MWD+IFR-AK-CAZ-SC(3) 13,984.43 76.76 79.58 4,939.11 4,882.96 2,538,20 11,694.81 5,978,165.51 397,632.17 0.25 11,964.25 MWD+IFR-AK-CAZ-SC(3) 14,079.69 76.56 79.59 4,961.09 4,904.94 2,554.96 11,785.97 5,978,180.88 397,723.57 0.21 12,056.94 MWD+IFR-AK-CAZ-SC(3) 14,174.09 76.44 79.25 4,983.12 4,926.97 2,571.81 11,876.20 5,978,196.35 397,814.04 0.37 12,148.73 MWD+IFR-AK-CAZ-SC(3) 14,270.30 76.26 79.20 5,005.83 4,949.68 2,589.29 11,968.05 5,978,212.43 397,906.13 0.19 12,242.22 MWD+IFR-AK-CAZ-SC(3) 14,359.35 76.08 79.48 5,027.12 4,970.97 2,605.29 12,053.02 5,978,227.13 397,991.33 0.37 12,328.69 MWD+IFR-AK-CAZ-SC(3) I 14,460.21 76.25 79.23 5,051.23 4,995.08 2,623.38 12,149.27 5,978,243.75 398,087.84 0.29 12,426.62 MWD+IFR-AK-CAZ-SC(3) 14,554.94 76.51 78.52 5,073.54 5,017.39 2,641.14 12,239.61 5,978,260.14 398,178.42 0.78 12,518.68 MWD+IFR-AK-CAZ-SC(3) 14,650.26 76.59 78.60 5,095.71 5,039.56 2,659.53 12,330.47 5,978,277.14 398,269.55 0.12 12,611.39 MWD+IFR-AK-CAZ-SC(3) 14,743.97 76.58 78.69 5,117.45 5,061.30 2,677.48 12,419.84 5,978,293.72 398,359.17 0.09 12,702.54 MWD+IFR-AK-CAZ-SC(3) 14,842.49 76.84 78.92 5,140.10 5,083.95 2,696.09 12,513.90 5,978,310.90 398,453.49 0.35 12,798.42 MWD+IFR-AK-CAZ-SC(3) 14,935.66 76.64 78.55 5,161.47 5,105.32 2,713.81 12,602.83 5,978,327.26 398,542.69 0.44 12,889.10 MWD+IFR-AK-CAZ-SC(3) 15,030.95 76.32 78.79 5,183.75 5,127.60 2,732.01 12,693.68 5,978,344.08 398,633.79 0.42 12,981.75 MWD+IFR-AK-CAZ-SC(3) 15,125.35 76.39 79.07 5,206.02 5,149.87 2,749.62 12,783.71 5,978,360.32 398,724.07 0.30 13,073.49 MWD+IFR-AK-CAZ-SC(3) 15,220.77 76.46 78.63 5,228.42 5,172.27 2,767.56 12,874.71 5,978,376.86 398,815.32 0.45 13,166.24 MWD+IFR-AK-CAZ-SC(3) 15,315.25 76.13 78.27 5,250.80 5,194.65 2,785.94 12,964.64 5,978,393.87 398,905.52 0.51 13,258.03 MWD+IFR-AK-CAZ-SC(3) 15,410.39 76.06 78.44 5,273.66 5,217.51 2,804.58 13,055.09 5,978,411.13 398,996.23 0.19 13,350.37 MWD+IFR-AK-CAZ-SC(3) 15,505.28 76.20 78.26 5,296,41 5,240.26 2,823.18 13,145.32 5,978,428.36 399,086.72 0.24 13,442.49 MWD+IFR-AK-CAZ-SC(3) 15,599.83 76.51 77.99 5,318.72 5,262.57 2,842.09 13,235.23 5,978,445.89 399,176.91 0.43 13,534.36 MWD+IFR-AK-CAZ-SC(3) 15,695.28 76.63 78.84 5,340.88 5,284.73 2,860.73 13,326.18 5,978,463.15 399,268.12 0.88 13,627.19 MWD+IFR-AK-CAZ-SC(3) 15,790.36 76.64 79.14 5,362.86 5,306.71 2,878.40 13,416.98 5,978,479.43 399,359.17 0.31 13,719.70 MWD+IFR-AK-CAZ-SC(3) 15,884.80 76.56 78.70 5,384.75 5,328.60 2,896.05 13,507.14 5,978,495.71 399,449.58 0.46 13,811.57 MWD+IFR-AK-CAZ-SC(3) 15,978.51 76.50 78.61 5,406.58 5,350.43 2,913.98 13,596.49 5,978,512.27 399,539.19 0.11 13,902.70 MWD+IFR-AK-CAZ-SC(3) 16,075.53 76.25 79.34 5,429.43 5,373.28 2,932.01 13,689.04 5,978,528.89 399,631.99 0.78 13,996.99 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:12:24AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (') (°) (ft) (ft) (ft) (ft) (ft) (ft) (e/100') (ft) Survey Tool Name 16,161.42 76.19 79.66 5,449.89 5,393.74 2,947.22 13,771.06 5,978,542.84 399,714.23 0.37 14,080.40 MWD+IFR-AK-CAZ-SC(3) 16,261.96 76.52 80.09 5,473.61 5,417.46 2,964.39 13,867.24 5,978,558.55 399,810.65 0.53 14,178.09 MWD+IFR-AK-CAZ-SC(3) 16,356.52 76.83 80.14 5,495.40 5,439.25 2,980.19 13,957.89 5,978,572.96 399,901.52 0.33 14,270.09 MWD+IFR-AK-CAZ-SC(3) 16,448.35 76.77 80.26 5,516.37 5,460.22 2,995.40 14,045.99 5,978,586.84 399,989.83 0.14 14,359.47 MWD+IFR-AK-CAZ-SC(3) 16,542.07 76.52 80.32 5,538.02 5,481.87 3,010.78 14,135.87 5,978,600.85 400,079.93 0.27 14,450.63 MWD+IFR-AK-CAZ-SC(3) 16,633.01 76.13 79.98 5,559.52 5,503.37 3,025.90 14,222.93 5,978,614.63 400,167.20 0.56 14,538.98 MWD+IFR-AK-CAZ-SC(3) 16,728.35 76.26 80.13 5,582,27 5,526.12 3,041.89 14,314.12 5,978,629.23 400,258.62 0.20 14,631.55 MWD+IFR-AK-CAZ-SC(3) 16,819.91 76.27 79.84 5,604.01 5,547.86 3,057.36 14,401.71 5,978,643.36 400,346.42 0.31 14,720.48 MWD+IFR-AK-CAZ-SC(3) 16,912.92 76.33 79.93 5,626.04 5,569.89 3,073.23 14,490.67 5,978,657.88 400,435.61 0.11 14,810.83 MWD+IFR-AK-CAZ-SC(3) 17,005.67 76.45 79.48 5,647.86 5,591.71 3,089.34 14,579.36 5,978,672.63 400,524.53 0.49 14,900.97 MWD+IFR-AK-CAZ-SC(3) 17,099.14 76.53 78.85 5,669.70 5,613.55 3,106.42 14,668.62 5,978,688.36 400,614.03 0.66 14,991.85 MWD+IFR-AK-CAZ-SC(3) 17,192.18 76.71 78.44 5,691.23 5,635.08 3,124.24 14,757.37 5,978,704.82 400,703.03 0.47 15,082.36 MWD+IFR-AK-CAZ-SC(3) 17,284.95 76.50 78.69 5,712.72 5,656.57 3,142.14 14,845.82 5,978,721.37 400,791.74 0.35 15,172.61 MWD+IFR-AK-CAZ-SC(3) 17,377.87 76.45 78.47 5,734.45 5,678.30 3,160.02 14,934.37 5,978,737.90 400,880.55 0.24 15,262.95 MWD+IFR-AK-CAZ-SC(3) 17,471.33 76.76 78.55 5,756.10 5,699.95 3,178.13 15,023.47 5,978,754.65 400,969.90 0.34 15,353.86 MWD+IFR-AK-CAZ-SC(3) 17,564.45 76.83 78.19 5,777.37 5,721.22 3,196.41 15,112.27 5,978,771.57 401,058.96 0.38 15,444.51 MWD+IFR-AK-CAZ-SC(3) 17,658.94 76.39 78.15 5,799.26 5,743.11 3,215.25 15,202.23 5,978,789.05 401,149.19 0.47 15,536.43 MWD+IFR-AK-CAZ-SC(3) 17,751.04 76.13 78.46 5,821.13 5,764.98 3,233.39 15,289.84 5,978,805.84 401,237.06 0.43 15,625.88 MWD+IFR-AK-CAZ-SC(3) 17,846.66 76.70 78.30 5,843.59 5,787.44 3,252.11 15,380.88 5,978,823.18 401,328.37 0.62 15,718.82 MWD+I FR-AK-CAZ-SC(3) 17,940.24 76.19 78.49 5,865.52 5,809.37 3,270.41 15,469.99 5,978,840.12 401,417.74 0.58 15,809.79 MWD+IFR-AK-CAZ-SC(3) 18,033.39 76.38 78.72 5,887.61 5,831.46 3,288.29 15,558.70 5,978,856.64 401,506.70 0.31 15,900.28 MWD+IFR-AK-CAZ-SC(3) 18,124.43 76.38 79.13 5,909.05 5,852.90 3,305.29 15,645.54 5,978,872.31 401,593.78 0.44 15,988.76 MWD+IFR-AK-CAZ-SC(3) 18,218.01 76.39 79.49 5,931.08 5,874.93 3,322.16 15,734.91 5,978,887.82 401,683.39 0.37 16,079.71 MWD+IFR-AK-CAZ-SC(3) 18,308.34 76.57 79.48 5,952.19 5,896.04 3,338.18 15,821.26 5,978,902.53 401,769.97 0.20 16,167.53 MWD+IFR-AK-CAZ-SC(3) 18,405.13 76.38 79.32 5,974.83 5,918.68 3,355.50 15,913.76 5,978,918.43 401,862.71 0.25 16,261.64 MWD+IFR-AK-CAZ-SC(3) 18,498.26 76.26 79.15 5,996.86 5,940.71 3,372.40 16,002.66 5,978,933.98 401,951.85 0.22 16,352.13 MWD+IFR-AK-CAZ-SC(3) 18,590.94 76.63 78.29 6,018.58 5,962.43 3,390.02 16,091.01 5,978,950.25 402,040.45 0.99 16,442.22 MWD+IFR-AK-CAZ-SC(3) 18,680.94 76.64 78.85 6,039.38 5,983.23 3,407.37 16,176.84 5,978,966.29 402,126.53 0.61 16,529.78 MWD+IFR-AK-CAZ-SC(3) ' 18,768.72 76.64 79.04 6,059.67 6,003.52 3,423.75 16,260.66 5,978,981.39 402,210.58 0.21 16,615.19 MWD+IFR-AK-CAZ-SC(3) 18,867.02 76.45 79.13 6,082.54 6,026.39 3,441.85 16,354.53 5,978,998.06 402,304.71 0.21 16,710.79 MWD+IFR-AK-CAZ-SC(3) 18,958.74 76.45 79.15 6,104.03 6,047.88 3,458.65 16,442.10 5,979,013.53 402,392.52 0.02 16,799.95 MWD+IFR-AK-CAZ-SC(3) 19,054.20 75.82 79.01 6,126.90 6,070.75 3,476.21 16,533.10 5,979,029.69 402,483.76 0.68 16,892.63 MWD+IFR-AK-CAZ-SC(3) 19,144.93 76.06 79.34 6,148.94 6,092.79 3,492.74 16,619.55 5,979,044.90 402,570.44 0.44 16,980.64 MWD+IFR-AK-CAZ-SC(3) 19,236.83 76.07 79.36 6,171.08 6,114.93 3,509.22 16,707.20 5,979,060.05 402,658.34 0.02 17,069.84 MWD+IFR-AK-CAZ-SC(3) 19,332.14 76.50 79.16 6,193.67 6,137.52 3,526.48 16,798.17 5,979,075.92 402,749.55 0.50 17,162.43 MWD+IFR-AK-CAZ-SC(3) 19,424.99 76.83 78.65 6,215.09 6,158.94 3,543.86 16,886.83 5,979,091.95 402,838.45 0.64 17,252.77 MWD+IFR-AK-CAZ-SC(3) 19,516.00 76.26 79.06 6,236.27 6,180.12 3,560.97 16,973.67 5,979,107.73 402,925.54 0.76 17,341.29 MWD+IFR-AK-CAZ-SC(3) 19,610.71 76.14 79.02 6,258.86 6,202.71 3,578.46 17,063.97 5,979,123.84 403,016.09 0.13 17,433.26 MWD+IFR-AK-CAZ-SC(3) 19,704.39 76.58 78.77 6,280.95 6,224.80 3,595.99 17,153.31 5,979,140.02 403,105.67 0.54 17,524.30 MWD+IFR-AK-CAZ-SC(3) 19,794.55 76.57 78.99 6,301.88 6,245.73 3,612.91 17,239.36 5,979,155.62 403,191.96 0.24 17,612.00 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:12:24AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB1 Survey Calculation Method: Minimum Curvature Design: CD1-15PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az! TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) ('/100') (ft) Survey Tool Name 19,889.66 76.76 79.31 6,323.82 6,267.67 3,630.33 17,330.25 5,979,171.65 403,283.10 0.38 17,704.54 MWD+IFR-AK-CAZ-SC(3) 19,980.31 76.32 79.34 6,344.92 6,288.77 3,646.66 17,416.88 5,979,186.66 403,369.96 0.49 17,792.70 MWD+IFR-AK-CAZ-SC(3) 20,074.90 75.69 79.11 6,367.79 6,311.64 3,663.82 17,507.04 5,979,202.44 403,460.37 0.71 17,884.48 MWD+IFR-AK-CAZ-SC(3) 20,167.36 75.75 79.22 6,390.60 6,334.45 3,680.66 17,595.05 5,979,217.94 403,548.61 0.13 17,974.08 MWD+IFR-AK-CAZ-SC(3) 20,261.35 76.58 79.09 6,413.07 6,356.92 3,697.83 17,684.68 5,979,233.75 403,638.49 0.89 18,065.34 MWD+IFR-AK-CAZ-SC(3) 20,348.33 76.45 79.56 6,433.36 6,377.21 3,713.50 17,767.80 5,979,248.15 403,721.83 0.55 18,149.93 MWD+IFR-AK-CAZ-SC(3) 20,448.64 76.71 79.57 6,456.64 6,400.49 3,731.17 17,863.76 5,979,264.35 403,818.03 0.26 18,247.49 MWD+IFR-AK-CAZ-SC(3) 20,537.85 76.70 79.25 6,477.15 6,421.00 3,747.13 17,949.10 5,979,279.01 403,903.60 0.35 18,334.31 MWD+IFR-AK-CAZ-SC(3) ' 20,632.28 76.58 78.66 6,498.97 6,442.82 3,764.73 18,039.27 5,979,295.23 403,994.02 0.62 18,426.18 MWD+IFR-AK-CAZ-SC(3) 20,666.44 76.69 78.95 6,506.87 6,450.72 3,771.18 18,071.87 5,979,301.19 404,026.72 0.89 18,459.42 MWD+IFR-AK-CAZ-SC(3) 20,700.00 76.69 78.95 6,514.60 6,458.45 3,777.44 18,103.93 5,979,306.96 404,058.86 0.00 18,492.08 PROJECTED to TD 6/16/2010 10:12:24AM Page 8 COMPASS 2003.16 Build 69 i i r' ConocoPhillips(Alaska) Inc. Western North Slope CD1 Alpine Pad CD1-15PB2 501032061971 sl 1 Sperry Drilling Services t Definitive Survey Report 16 June, 2010 Y , i 1 ' i '' 3 } I HALa CSR Sperry Drilling Services ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope ND Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD1-15 Well Position +N/-S 0.00 ft Northing: 5,975,805.80 ft Latitude: 70°20'33.932 N +E/-W 0.00 ft Easting: 385,901.08 ft Longitude: 150°55'33.713 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft Wellbore CD1-15PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) 11 1 BGGM2009 5/1/2009 21.62 80.72 57,594 Design CD1-15PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 20,067.00 Vertical Section: Depth From(ND) +NIS +E/-W Direction (ft) (ft) (ft) (0) 36.65 0.00 0.00 78.18 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 81.00 1,006.00 CD1-15PB1 Gyro(CD1-15PB1) CB-GYRO-SS Camera based gyro single shot 4/29/2010 1: 1,106.18 3,063.99 CD1-15PB1 MWD(R200)(CD1-15PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/30/2010 1: 3,147.95 20,067.00 CD1-15PB1 MWD(R300)(CD1-15PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/4/2010 12: 20,114.00 20,114.00 CD1-15PB2(CD1-15PB2) BLIND Blind drilling 6/16/2010 1: Survey Map Map Vertical MD Inc Azi ND TVDSS +N/S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 36.65 0.00 0.00 36.65 -19.50 0.00 0.00 5,975,805.80 385,901.08 0.00 0.00 UNDEFINED 81.00 0.27 57.03 81.00 24.85 0.06 0.09 5,975,805.86 385,901.17 0.61 0.10 CB-GYRO-SS(1) 171.00 0.38 58.28 171.00 114.85 0.33 0.52 5,975,806.12 385,901.61 0.12 0.58 CB-GYRO-SS(1) 234.00 0.70 33.27 234.00 177.85 0.76 0.91 5,975,806.55 385,902.00 0.62 1.04 CB-GYRO-SS(1) 264.00 0.93 20.08 263.99 207.84 1.14 1.09 5,975,806.93 385,902.19 0.98 1.30 CB-GYRO-SS(1) 354.00 2.75 2.26 353.94 297.79 3.99 1.43 5,975,809.76 385,902.57 2.10 2.21 CB-GYRO-SS(1) 447.00 4.32 3.83 446.76 390.61 9.71 1.75 5,975,815.48 385,902.98 1.69 3.70 CB-GYRO-SS(1) 540.00 4.55 5.74 539.48 483.33 16.88 2.35 5,975,822.64 385,903.69 0.29 5.76 CB-GYRO-SS(1) 631.00 6.34 352.27 630.07 573.92 25.45 2.04 5,975,831.21 385,903.51 2.40 7.21 CB-GYRO-SS(1) 723.00 6.96 351.08 721.45 665.30 35.99 0.49 5,975,841.77 385,902.12 0.69 7.85 CB-GYRO-SS(1) 816.00 6.77 352.80 813.79 757.64 46.99 -1.07 5,975,852.80 385,900.73 0.30 8.58 CB-GYRO-SS(1) 6/16/2010 10:15:46AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 r) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 911.00 7.80 2.76 908.02 851.87 58.99 -1.46 5,975,864.80 385,900.52 1.71 10.65 CB-GYRO-SS(1) I 1,006.00 12.03 16.93 1,001.60 945.45 74.91 1.73 5,975,880.67 385,903.96 5.11 17.04 CB-GYRO-SS(1) 1,106.18 15.23 35.28 1,098.99 1,042.84 95.65 12.38 5,975,901.24 385,914.92 5.33 31.71 MWD+IFR-AK-CAZ-SC(2) 1,163.05 16.07 45.33 1,153.76 1,097.61 107.29 22.30 5,975,912.72 385,925.01 4.98 43.80 MWD+IFR-AK-CAZ-SC(2) 1,257.40 19.11 52.64 1,243.70 1,187.55 125.84 43.87 5,975,930.95 385,946.86 3.98 68.71 MWD+IFR-AK-CAZ-SC(2) 1,353.84 22.01 57.15 1,333.99 1,277.84 145.23 71.60 5,975,949.91 385,974.88 3.42 99.83 MWD+IFR-AK-CAZ-SC(2) I 1,449.22 25.81 61.60 1,421.18 1,365.03 164.81 104.90 5,975,968.98 386,008.47 4.41 136.43 MWD+IFR-AK-CAZ-SC(2) 1,544.31 28.82 64.36 1,505.66 1,449.51 184.58 143.78 5,975,988.15 386,047.64 3.43 178.53 MWD+IFR-AK-CAZ-SC(2) ' 1,639.08 30.49 66.69 1,588.02 1,531.87 203.98 186.46 5,976,006.90 386,090.61 2.14 224.28 MWD+IFR-AK-CAZ-SC(2) 1,734.54 34.30 67.36 1,668.61 1,612.46 223.92 233.54 5,976,026.13 386,137.98 4.01 274.45 MWD+IFR-AK-CAZ-SC(2) 1,829.12 38.29 67.37 1,744.82 1,688.67 245.47 285.20 5,976,046.88 386,189.97 4.22 329.43 MWD+IFR-AK-CAZ-SC(2) 1,923.99 40.41 70.58 1,818.18 1,762.03 267.00 341.35 5,976,067.56 386,246.42 3.10 388.79 MWD+IFR-AK-CAZ-SC(2) 2,018.71 44.09 72.14 1,888.29 1,832.14 287.33 401.69 5,976,086.96 386,307.06 4.04 452.02 MWD+IFR-AK-CAZ-SC(2) 2,114.41 46.91 70.87 1,955.36 1,899.21 308.99 466.41 5,976,107.63 386,372.10 3.09 519.80 MWD+IFR-AK-CAZ-SC(2) 2,209.25 49.52 73.06 2,018.55 1,962.40 330.86 533.64 5,976,128.47 386,439.65 3.25 590.09 MWD+IFR-AK-CAZ-SC(2) 2,304.06 53.34 72.61 2,077.65 2,021.50 352.74 604.45 5,976,149.27 386,510.78 4.05 663.88 MWD+IFR-AK-CAZ-SC(2) 2,398.99 57.31 74.21 2,131.65 2,075.50 375.00 679.26 5,976,170.38 386,585.92 4.41 741.66 MWD+IFR-AK-CAZ-SC(2) 2,494.57 59.53 75.52 2,181.71 2,125.56 396.24 757.86 5,976,190.43 386,664.82 2.60 822.95 MWD+IFR-AK-CAZ-SC(2) 2,589.21 63.01 75.36 2,227.19 2,171.04 417.11 838.17 5,976,210.07 386,745.43 3.68 905.83 MWD+IFR-AK-CAZ-SC(2) 2,683.09 67.26 76.12 2,266.66 2,210.51 438.07 920.70 5,976,229.77 386,828.27 4.59 990.91 MWD+IFR-AK-CAZ-SC(2) 2,779.27 69.93 77.73 2,301.76 2,245.61 458.32 1,007.92 5,976,248.68 386,915.78 3.18 1,080.42 MWD+IFR-AK-CAZ-SC(2) 2,874.84 72.96 79.05 2,332.17 2,276.02 476.54 1,096.66 5,976,265.55 387,004.77 3.43 1,171.01 MWD+IFR-AK-CAZ-SC(2) 2,969.35 75,55 78.81 2,357.81 2,301.66 494.00 1,185.92 5,976,281.66 387,094.28 2.75 1,261.96 MWD+IFR-AK-CAZ-SC(2) , 3,063.99 75.46 79.06 2,381.50 2,325.35 511.59 1,275.84 5,976,297.87 387,184.46 0.27 1,353.58 MWD+IFR-AK-CAZ-SC(2) 3,147.95 76.01 78.47 2,402.19 2,346.04 527.44 1,355.66 5,976,312.51 387,264.49 0.94 1,434.94 MWD+IFR-AK-CAZ-SC(3) 3,239.59 76.45 79.46 2,424.00 2,367.85 544.48 1,443.02 5,976,328.21 387,352.09 1.15 1,523.94 MWD+IFR-AK-CAZ-SC(3) 3,337.88 76.96 80.07 2,446.60 2,390.45 561.47 1,537.15 5,976,343.77 387,446.47 0.80 1,619.56 MWD+IFR-AK-CAZ-SC(3) 3,427.41 76.70 79.55 2,467.00 2,410.85 576.90 1,622.95 5,976,357.88 387,532.48 0.64 1,706.70 MWD+IFR-AK-CAZ-SC(3) 3,527.47 77.15 79.08 2,489.64 2,433.49 594.97 1,718.72 5,976,374.49 387,628.52 0.64 1,804.14 MWD+IFR-AK-CAZ-SC(3) 3,622.17 77.46 78.25 2,510.45 2,454.30 613.13 1,809.31 5,976,391.27 387,719.36 0.92 1,896.52 MWD+IFR-AK-CAZ-SC(3) 3,722.88 76.26 78.27 2,533.34 2,477.19 633.08 1,905.32 5,976,409.76 387,815.66 1.19 1,994.60 MWD+IFR-AK-CAZ-SC(3) 3,806.66 76.64 79.09 2,552.97 2,496.82 649.07 1,985.19 5,976,424.52 387,895.75 1.05 2,076.04 MWD+IFR-AK-CAZ-SC(3) 3,906.38 76.71 79.72 2,575.96 2,519.81 666.91 2,080.57 5,976,440.91 387,991.38 0.62 2,173.05 MWD+IFR-AK-CAZ-SC(3) 4,002.46 76.39 80.24 2,598.31 2,542.16 683.17 2,172.59 5,976,455.77 388,083.63 0.62 2,266.45 MWD+IFR-AK-CAZ-SC(3) 4,098.56 76.45 80.18 2,620.87 2,564.72 699.05 2,264.64 5,976,470.25 388,175.91 0.09 2,359.81 MWD+IFR-AK-CAZ-SC(3) 4,190.21 76.64 80.47 2,642.19 2,586.04 714.03 2,352.51 5,976,483.89 388,263.98 0.37 2,448.88 MWD+IFR-AK-CAZ-SC(3) 4,288.54 76.77 80.82 2,664.81 2,608.66 729.59 2,446.93 5,976,498.00 388,358.62 0.37 2,544.48 MWD+IFR-AK-CAZ-SC(3) 4,383.53 76.45 81.25 2,686.81 2,630.66 743.99 2,538.21 5,976,511.01 388,450.10 0.55 2,636.78 MWD+IFR-AK-CAZ-SC(3) 4,479.65 76.13 81.77 2,709.59 2,653.44 757.77 2,630.56 5,976,523.39 388,542.65 0.62 2,730.00 MWD+IFR-AK-CAZ-SC(3) 4,573.88 76.00 81.68 2,732.28 2,676.13 770.94 2,721.07 5,976,535.17 388,633.34 0.17 2,821.28 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:15:46AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°) (') (ft) (ft) (ft) (ft) (ft) (ft) ('I100') (ft) Survey Tool Name 4,668.31 76.26 81.33 2,754.92 2,698.77 784.48 2,811.74 5,976,547.33 388,724.20 0.45 2,912.80 MWD+IFR-AK-CAZ-SC(3) 4,762.92 76.71 80.90 2,777.03 2,720.88 798.69 2,902.63 5,976,560.15 388,815.28 0.65 3,004.67 MWD+IFR-AK-CAZ-SC(3) 4,859.62 76.58 80.76 2,799.36 2,743.21 813.68 2,995.51 5,976,573.73 388,908.37 0.19 3,098.66 MWD+IFR-AK-CAZ-SC(3) 4,954.00 76.96 79.85 2,820.96 2,764.81 829.15 3,086.07 5,976,587.82 388,999.15 1.02 3,190.47 MWD+IFR-AK-CAZ-SC(3) 5,049.78 76.71 79.91 2,842.78 2,786.63 845.54 3,177.88 5,976,602.81 389,091.19 0.27 3,283.69 MWD+IFR-AK-CAZ-SC(3) 5,144.79 75.82 78.67 2,865.34 2,809.19 862.69 3,268.56 5,976,618.57 389,182.12 1.58 3,375.96 MWD+IFR-AK-CAZ-SC(3) 5,240.27 76.08 78.62 2,888.52 2,832.37 880.93 3,359.37 5,976,635.42 389,273.19 0.28 3,468.58 MWD+IFR-AK-CAZ-SC(3) 5,334.97 75.68 79.46 2,911.62 2,855.47 898.39 3,449.54 5,976,651.51 389,363.60 0.96 3,560.41 MWD+IFR-AK-CAZ-SC(3) 5,430.78 75.94 79.66 2,935.10 2,878.95 915.22 3,540.89 5,976,666.95 389,455.19 0.34 3,653.27 MWD+IFR-AK-CAZ-SC(3) 5,528.32 76.33 80.66 2,958.48 2,902.33 931.40 3,634.19 5,976,681.71 389,548.72 1.07 3,747.91 MWD+IFR-AK-CAZ-SC(3) 5,621.09 76.77 81.15 2,980.06 2,923.91 945.66 3,723.28 5,976,694.61 389,638.01 0.70 3,838.03 MWD+IFR-AK-CAZ-SC(3) 5,711.12 76.38 80.51 3,000.96 2,944.81 959.62 3,809.73 5,976,707.25 389,724.65 0.82 3,925.51 MWD+IFR-AK-CAZ-SC(3) 5,811.41 76.33 80.49 3,024.62 2,968.47 975.70 3,905.85 5,976,721.86 389,821.00 0.05 4,022.89 MWD+IFR-AK-CAZ-SC(3) 5,902.97 76.25 80.46 3,046.32 2,990.17 990.42 3,993.58 5,976,735.25 389,908.93 0.09 4,111.77 MWD+IFR-AK-CAZ-SC(3) 6,001.81 76.63 80.25 3,069.49 3,013.34 1,006.52 4,088.30 5,976,749.90 390,003.88 0.44 4,207.78 MWD+IFR-AK-CAZ-SC(3) 6,094.77 76.51 79.76 3,091.08 3,034.93 1,022.21 4,177.35 5,976,764.23 390,093.15 0.53 4,298.16 MWD+IFR-AK-CAZ-SC(3) 6,191.66 76.33 79.07 3,113.83 3,057.68 1,039.51 4,269.93 5,976,780.12 390,185.97 0.72 4,392.32 MWD+IFR-AK-CAZ-SC(3) 6,282.72 76.45 78.67 3,135.26 3,079.11 1,056.60 4,356.77 5,976,795.88 390,273.05 0.45 4,480.81 MWD+IFR-AK-CAZ-SC(3) 6,380.98 76.89 78.46 3,157.92 3,101.77 1,075.55 4,450.48 5,976,813.41 390,367.04 0.49 4,576.42 MWD+IFR-AK-CAZ-SC(3) 6,477.93 76.65 78.48 3,180.11 3,123.96 1,094.42 4,542.95 5,976,830.86 390,459.78 0.25 4,670.80 MWD+IFR-AK-CAZ-SC(3) 6,571.23 77.02 78.14 3,201.35 3,145.20 1,112.83 4,631.92 5,976,847.91 390,549.00 0.53 4,761.64 MWD+IFR-AK-CAZ-SC(3) 6,667.35 76.70 78.28 3,223.21 3,167.06 1,131.95 4,723.54 5,976,865.64 390,640.91 0.36 4,855.25 MWD+IFR-AK-CAZ-SC(3) 6,761.79 75.82 78.39 3,245.64 3,189.49 1,150.50 4,813.39 5,976,882.81 390,731.01 0.94 4,946.98 MWD+IFR-AK-CAZ-SC(3) 6,854.81 76.63 77.92 3,267.79 3,211.64 1,169.05 4,901.81 5,976,900.01 390,819.70 1.00 5,037.33 MWD+IFR-AK-CAZ-SC(3) 6,952.15 76.20 77.69 3,290.65 3,234.50 1,189.03 4,994.29 5,976,918.59 390,912.46 0.50 5,131.94 MWD+IFR-AK-CAZ-SC(3) 7,044.81 76.32 79.19 3,312.66 3,256.51 1,207.07 5,082.47 5,976,935.28 391,000.90 1.58 5,221.95 MWD+IFR-AK-CAZ-SC(3) 7,141.39 76.77 79.03 3,335.13 3,278.98 1,224.81 5,174.70 5,976,951.61 391,093.39 0.49 5,315.86 MWD+IFR-AK-CAZ-SC(3) 7,235.54 76.13 78.53 3,357.19 3,301.04 1,242.62 5,264.48 5,976,968.05 391,183.42 0.85 5,407.39 MWD+IFR-AK-CAZ-SC(3) 7,332.00 75.74 79.35 3,380.63 3,324.48 1,260.57 5,356.31 5,976,984.60 391,275.50 0.92 5,500.95 MWD+IFR-AK-CAZ-SC(3) 7,426.53 76.58 78.93 3,403.25 3,347.10 1,277.87 5,446.45 5,977,000.52 391,365.89 0.99 5,592.72 MWD+IFR-AK-CAZ-SC(3) 7,521.98 76.96 77.82 3,425.09 3,368.94 1,296.59 5,537.46 5,977,017.86 391,457.17 1.20 5,685.63 MWD+IFR-AK-CAZ-SC(3) 7,616.39 78.02 77.52 3,445.54 3,389.39 1,316.27 5,627.50 5,977,036.16 391,547.49 1.16 5,777.80 MWD+IFR-AK-CAZ-SC(3) 7,711.63 77.22 77.74 3,465.96 3,409.81 1,336.20 5,718.37 5,977,054.70 391,638.64 0.87 5,870.82 MWD+IFR-AK-CAZ-SC(3) 7,804.85 77.01 77.29 3,486.75 3,430.60 1,355.85 5,807.09 5,977,073.00 391,727.64 0.52 5,961.68 MWD+IFR-AK-CAZ-SC(3) 7,900.20 76.83 76.47 3,508.33 3,452.18 1,376.93 5,897.54 5,977,092.70 391,818.40 0.86 6,054.53 MWD+IFR-AK-CAZ-SC(3) 7,996.22 76.01 75.62 3,530.87 3,474.72 1,399.43 5,988.12 5,977,113.82 391,909.30 1.21 6,147.80 MWD+IFR-AK-CAZ-SC(3) 8,091.41 75.63 75.41 3,554.19 3,498.04 1,422.52 6,077.48 5,977,135.54 391,998.99 0.45 6,239.99 MWD+IFR-AK-CAZ-SC(3) 8,186.75 75.88 75.07 3,577.65 3,521.50 1,446.06 6,166.84 5,977,157.72 392,088.69 0.43 6,332.28 MWD+IFR-AK-CAZ-SC(3) 8,277.58 75.75 75.21 3,599.91 3,543.76 1,468.64 6,251.95 5,977,179.00 392,174.13 0.21 6,420.21 MWD+IFR-AK-CAZ-SC(3) 8,375.41 75.81 77.24 3,623.94 3,567.79 1,491.22 6,344.05 5,977,200.17 392,266.56 2.01 6,514.99 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10.'15:46AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical I MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (") (") (ft) (ft) (ft) (ft) (ft) (ft) ("/100') (ft) Survey Tool Name 8,471.95 76.01 78.70 3,647.45 3,591.30 1,510.74 6,435.63 5,977,218.29 392,358.41 1.48 6,608.62 MWD+IFR-AK-CAZ-SC(3) 8,559.89 76.32 78.55 3,668.47 3,612.32 1,527.58 6,519.34 5,977,233.86 392,442.36 0.39 6,694.00 MWD+IFR-AK-CAZ-SC(3) 8,661.35 76.19 78.51 3,692.58 3,636.43 1,547.18 6,615.93 5,977,251.98 392,539.23 0.13 6,792.56 MWD+IFR-AK-CAZ-SC(3) 8,756.03 76.13 78.81 3,715.23 3,659.08 1,565.25 6,706.06 5,977,268.68 392,629.62 0.31 6,884.48 MWD+IFR-AK-CAZ-SC(3) 8,852.33 77.23 79.06 3,737.42 3,681.27 1,583.24 6,798.03 5,977,285.26 392,721.84 1.17 6,978.18 MWD+IFR-AK-CAZ-SC(3) 8,943.79 76.45 79.70 3,758.24 3,702.09 1,599.65 6,885.56 5,977,300.34 392,809.60 1.09 7,067.22 MWD+IFR-AK-CAZ-SC(3) 9,041.44 76.64 78.71 3,780.96 3,724.81 1,617.44 6,978.85 5,977,316.70 392,903.14 1.01 7,162.18 MWD+IFR-AK-CAZ-SC(3) 9,133.06 76.57 78.48 3,802.19 3,746.04 1,635.06 7,066.22 5,977,333.00 392,990.76 0.26 7,251.30 MWD+IFR-AK-CAZ-SC(3) 9,231.80 76.63 78.59 3,825.07 3,768.92 1,654.16 7,160.35 5,977,350.65 393,085.17 0.12 7,347.35 MWD+IFR-AK-CAZ-SC(3) 9,323.73 76.39 78.14 3,846.51 3,790.36 1,672.18 7,247.91 5,977,367.34 393,172.98 0.54 7,436.74 MWD+IFR-AK-CAZ-SC(3) 9,420.41 76.89 79.02 3,868.85 3,812.70 1,690.81 7,340.11 5,977,384.56 393,265.45 1.03 7,530.80 MWD+IFR-AK-CAZ-SC(3) 9,513.25 76.89 79.58 3,889.91 3,833.76 1,707.60 7,428.95 5,977,399.99 393,354.53 0.59 7,621.21 MWD+IFR-AK-CAZ-SC(3) 9,612.05 76.44 79.25 3,912.70 3,856.55 1,725.26 7,523.45 5,977,416.21 393,449.28 0.56 7,717.32 MWD+IFR-AK-CAZ-SC(3) 9,702.93 75.44 78.46 3,934.78 3,878.63 1,742.29 7,609.95 5,977,431.93 393,536.02 1.39 7,805.47 MWD+IFR-AK-CAZ-SC(3) 9,802.78 76.59 78.41 3,958.91 3,902.76 1,761.72 7,704.87 5,977,449.90 393,631.22 1.15 7,902.36 MWD+IFR-AK-CAZ-SC(3) 9,896.37 76.33 77.76 3,980.82 3,924.67 1,780.50 7,793.90 5,977,467.33 393,720.51 0.73 7,993.34 MWD+IFR-AK-CAZ-SC(3) 9,991.27 76.13 78.14 4,003.41 3,947.26 1,799.75 7,884.04 5,977,485.20 393,810.93 0.44 8,085.52 MWD+IFR-AK-CAZ-SC(3) 10,087.34 76.14 78.88 4,026.43 3,970.28 1,818.32 7,975.44 5,977,502.38 393,902.59 0.75 8,178.78 MWD+IFR-AK-CAZ-SC(3) 10,178.49 76.77 79.23 4,047.78 3,991.63 1,835.15 8,062.44 5,977,517.88 393,989.83 0.79 8,267.39 MWD+IFR-AK-CAZ-SC(3) 10,277.05 76.77 79.08 4,070.34 4,014.19 1,853.20 8,156.67 5,977,534.49 394,084.32 0.15 8,363.32 MWD+IFR-AK-CAZ-SC(3) 10,373.74 76.53 80.52 4,092.66 4,036.51 1,869.86 8,249.26 5,977,549.74 394,177.14 1.47 8,457.36 MWD+IFR-AK-CAZ-SC(3) 10,468.40 76.51 80.41 4,114.73 4,058.58 1,885.11 8,340.04 5,977,563.60 394,268.14 0.11 8,549.33 MWD+IFR-AK-CAZ-SC(3) 10,563.75 76.58 80.80 4,136.91 4,080.76 1,900.25 8,431.53 5,977,577.35 394,359.84 0.40 8,641.98 MWD+IFR-AK-CAZ-SC(3) 10,658.73 76.20 80.71 4,159.26 4,103.11 1,915.08 8,522.64 5,977,590.79 394,451.16 0.41 8,734.20 MWD+IFR-AK-CAZ-SC(3) 10,749.57 76.13 80.31 4,180.99 4,124.84 1,929.62 8,609.64 5,977,604.00 394,538.36 0.43 8,822.34 MWD+IFR-AK-CAZ-SC(3) 10,848.65 76.46 80.04 4,204.46 4,148.31 1,946.05 8,704.49 5,977,618.98 394,633.44 0.43 8,918.54 MWD+IFR-AK-CAZ-SC(3) 10,943.84 76.78 79.01 4,226.49 4,170.34 1,962.88 8,795.55 5,977,634.43 394,724.74 1.11 9,011.12 MWD+IFR-AK-CAZ-SC(3) 11,038.57 76.76 78.75 4,248.17 4,192.02 1,980.67 8,886.03 5,977,650.83 394,815.47 0.27 9,103.32 MWD+IFR-AK-CAZ-SC(3) 11,133.10 76.20 78.29 4,270.27 4,214.12 1,998.96 8,976.10 5,977,667.75 394,905.81 0.76 9,195.23 MWD+IFR-AK-CAZ-SC(3) 11,227.58 76.58 78.17 4,292.50 4,236.35 2,017.69 9,066.00 5,977,685.11 394,995.97 0.42 9,287.06 MWD+IFR-AK-CAZ-SC(3) 11,323.51 76.08 78.26 4,315.17 4,259.02 2,036.73 9,157.25 5,977,702.76 395,087.49 0.53 9,380.27 MWD+IFR-AK-CAZ-SC(3) 11,415.81 76.02 78.04 4,337.42 4,281.27 2,055.12 9,244.92 5,977,719.81 395,175.42 0.24 9,469.85 MWD+IFR-AK-CAZ-SC(3) 11,512.50 75.88 78.40 4,360.90 4,304.75 2,074.27 9,336.74 5,977,737.56 395,267.51 0.39 9,563.65 MWD+IFR-AK-CAZ-SC(3) 11,601.81 76.32 78.42 4,382.35 4,326.20 2,091.69 9,421.67 5,977,753.68 395,352.69 0.49 9,650.34 MWD+IFR-AK-CAZ-SC(3) 11,701.69 76.26 78,16 4,406.02 4,349.87 2,111.38 9,516.68 5,977,771.93 395,447.98 0.26 9,747.37 MWD+IFR-AK-CAZ-SC(3) 11,797.82 76.50 78.46 4,428.66 4,372.51 2,130.31 9,608.17 5,977,789.46 395,539.74 0.39 9,840.80 MWD+IFR-AK-CAZ-SC(3) 11,888.40 76.26 78.81 4,449.99 4,393.84 2,147.66 9,694.47 5,977,805.49 395,626.29 0.46 9,928.83 MWD+IFR-AK-CAZ-SC(3) 11,987.84 76.44 78.95 4,473.46 4,417.31 2,166.30 9,789.29 5,977,822.68 395,721.38 0.23 10,025.45 MWD+IFR-AK-CAZ-SC(3) 12,080.37 76.71 78.85 4,494.94 4,438.79 2,183.63 9,877.61 5,977,838.66 395,809.94 0.31 10,115.45 MWD+IFR-AK-CAZ-SC(3) 12,177.23 76.45 78.85 4,517.42 4,461.27 2,201.84 9,970.05 5,977,855.47 395,902.64 0.27 10,209.66 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:1 5:46AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) Survey Tool Name 12,270.65 76.32 78.78 4,539.41 4,483.26 2,219.46 10,059.12 5,977,871.72 395,991.96 0.16 10,300.45 MWD+IFR-AK-CAZ-SC(3) 12,366.43 76.07 78.85 4,562.27 4,506.12 2,237.50 10,150.36 5,977,888.37 396,083.46 0.27 10,393.45 MWD+IFR-AK-CAZ-SC(3) 12,463.16 76.26 79.03 4,585.40 4,529.25 2,255.52 10,242.54 5,977,904.98 396,175.89 0.27 10,487.37 MWD+IFR-AK-CAZ-SC(3) I 12,557.47 77.26 78.59 4,607.00 4,550.85 2,273.33 10,332.60 5,977,921.43 396,266.20 1.15 10,579.17 MWD+IFR-AK-CAZ-SC(3) 12,653.78 77.03 78.86 4,628.42 4,572.27 2,291.69 10,424.68 5,977,938.38 396,358.55 0.36 10,673.06 MWD+IFR-AK-CAZ-SC(3) 12,748.02 76.96 78.81 4,649.63 4,593.48 2,309.47 10,514.77 5,977,954.78 396,448.88 0.09 10,764.87 MWD+IFR-AK-CAZ-SC(3) 12,837.57 76.97 78.95 4,669.83 4,613.68 2,326.30 10,600.37 5,977,970.30 396,534.73 0.15 10,852.11 MWD+IFR-AK-CAZ-SC(3) 12,939.33 76.06 78.80 4,693.56 4,637.41 2,345.39 10,697.47 5,977,987.92 396,632.09 0.91 10,951.06 MWD+IFR-AK-CAZ-SC(3) 13,032.96 76.13 78.65 4,716.06 4,659.91 2,363.16 10,786.60 5,978,004.33 396,721.48 0.17 11,041.94 MWD+IFR-AK-CAZ-SC(3) 13,128.62 76.32 79.16 4,738.84 4,682.69 2,381.04 10,877.77 5,978,020.81 396,812.90 0.55 11,134.84 MWD+IFR-AK-CAZ-SC(3) 13,220.47 75.82 79.35 4,760.95 4,704.80 2,397.66 10,965.36 5,978,036.10 396,900.72 0.58 11,223.97 MWD+IFR-AK-CAZ-SC(3) 13,318.64 76.19 78.92 4,784.69 4,728.54 2,415.62 11,058.90 5,978,052.63 396,994.53 0.57 11,319.22 MWD+IFR-AK-CAZ-SC(3) 13,414.08 76.83 78.80 4,806.95 4,750.80 2,433.55 11,149.96 5,978,069.17 397,085.84 0.68 11,412.02 MWD+IFR-AK-CAZ-SC(3) 13,505.48 76.26 78.56 4,828.22 4,772.07 2,450.99 11,237.12 5,978,085.29 397,173.25 0.67 11,500.90 MWD+IFR-AK-CAZ-SC(3) 13,603.49 76.08 78.93 4,851.65 4,795.50 2,469.57 11,330.46 5,978,102.44 397,266.85 0.41 11,596.07 MWD+IFR-AK-CAZ-SC(3) 13,698.53 76.76 79.01 4,873.96 4,817.81 2,487.24 11,421.14 5,978,118.73 397,357.78 0.72 11,688.44 MWD+IFR-AK-CAZ-SC(3) 13,790.88 77.15 79.31 4,894.81 4,838.66 2,504.16 11,509.50 5,978,134.30 397,446.38 0.53 11,778.39 MWD+IFR-AK-CAZ-SC(3) 13,889.41 76.58 79.74 4,917.20 4,861.05 2,521.61 11,603.85 5,978,150.30 397,540.98 0.72 11,874.32 MWD+IFR-AK-CAZ-SC(3) 13,984.43 76.76 79.58 4,939.11 4,882.96 2,538.20 11,694.81 5,978,165.51 397,632.17 0.25 11,966.75 MWD+IFR-AK-CAZ-SC(3) 14,079.69 76.56 79.59 4,961.09 4,904.94 2,554.96 11,785.97 5,978,180.88 397,723.57 0.21 12,059.41 MWD+IFR-AK-CAZ-SC(3) 14,174.09 76.44 79.25 4,983.12 4,926.97 2,571.81 11,876.20 5,978,196.35 397,814.04 0.37 12,151.18 MWD+IFR-AK-CAZ-SC(3) 14,270.30 76.26 79.20 5,005.83 4,949.68 2,589.29 11,968.05 5,978,212.43 397,906.13 0.19 12,244.66 MWD+IFR-AK-CAZ-SC(3) 14,359.35 76.08 79.48 5,027.12 4,970.97 2,605.29 12,053.02 5,978,227.13 397,991.33 0.37 12,331.11 MWD+IFR-AK-CAZ-SC(3) 14,460.21 76.25 79.23 5,051.23 4,995.08 2,623.38 12,149.27 5,978,243.75 398,087.84 0.29 12,429.02 MWD+IFR-AK-CAZ-SC(3) 14,554.94 76.51 78.52 5,073.54 5,017.39 2,641.14 12,239.61 5,978,260.14 398,178.42 0.78 12,521.08 MWD+IFR-AK-CAZ-SC(3) 14,650.26 76.59 78.60 5,095.71 5,039.56 2,659.53 12,330.47 5,978,277.14 398,269.55 0.12 12,613.78 MWD+IFR-AK-CAZ-SC(3) 14,743.97 76.58 78.69 5,117.45 5,061.30 2,677.48 12,419.84 5,978,293.72 398,359.17 0.09 12,704.93 MWD+IFR-AK-CAZ-SC(3) 14,842.49 76.84 78.92 5,140.10 5,083.95 2,696.09 12,513.90 5,978,310.90 398,453.49 0.35 12,800.81 MWD+IFR-AK-CAZ-SC(3) 14,935.66 76.64 78.55 5,161.47 5,105.32 2,713.81 12,602.83 5,978,327.26 398,542.69 0.44 12,891.49 MWD+IFR-AK-CAZ-SC(3) 15,030.95 76.32 78.79 5,183.75 5,127.60 2,732.01 12,693.68 5,978,344.08 398,633.79 0.42 12,984.14 MWD+IFR-AK-CAZ-SC(3) 15,125.35 76.39 79.07 5,206.02 5,149.87 2,749.62 12,783.71 5,978,360.32 398,724.07 0.30 13,075.86 MWD+IFR-AK-CAZ-SC(3) 15,220.77 76.46 78.63 5,228.42 5,172.27 2,767.56 12,874.71 5,978,376.86 398,815.32 0.45 13,168.61 MWD+IFR-AK-CAZ-SC(3) 15,315.25 76.13 78.27 5,250.80 5,194.65 2,785.94 12,964.64 5,978,393.87 398,905.52 0.51 13,260.40 MWD+IFR-AK-CAZ-SC(3) 15,410.39 76.06 78.44 5,273.66 5,217.51 2,804.58 13,055.09 5,978,411.13 398,996.23 0.19 13,352.75 MWD+IFR-AK-CAZ-SC(3) 15,505.28 76.20 78.26 5,296.41 5,240.26 2,823.18 13,145.32 5,978,428.36 399,086.72 0.24 13,444.87 MWD+IFR-AK-CAZ-SC(3) 15,599.83 76.51 77.99 5,318.72 5,262.57 2,842.09 13,235.23 5,978,445.89 399,176.91 0.43 13,536.76 MWD+IFR-AK-CAZ-SC(3) 15,695.28 76.63 78.84 5,340.88 5,284.73 2,860.73 13,326.18 5,978,463.15 399,268.12 0.88 13,629.59 MWD+IFR-AK-CAZ-SC(3) 15,790.36 76.64 79.14 5,362.86 5,306.71 2,878.40 13,416.98 5,978,479.43 399,359.17 0.31 13,722.09 MWD+IFR-AK-CAZ-SC(3) 15,884.80 76.56 78.70 5,384.75 5,328.60 2,896.05 13,507.14 5,978,495.71 399,449.58 0.46 13,813.95 MWD+IFR-AK-CAZ-SC(3) 15,978.51 76.50 78.61 5,406.58 5,350.43 2,913.98 13,596.49 5,978,512.27 399,539.19 0.11 13,905.08 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:15:46AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15©56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (') (') (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 16,075.53 76.25 79.34 5,429.43 5,373.28 2,932.01 13,689.04 5,978,528.89 399,631.99 0.78 13,999.36 MWD+IFR-AK-CAZ-SC(3) 16,161.42 76.19 79.66 5,449.89 5,393.74 2,947.22 13,771.06 5,978,542.84 399,714.23 0.37 14,082.76 MWD+IFR-AK-CAZ-SC(3) 16,261.96 76.52 80.09 5,473.61 5,417.46 2,964.39 13,867.24 5,978,558.55 399,810.65 0.53 14,180.41 MWD+IFR-AK-CAZ-SC(3) 16,356.52 76.83 80.14 5,495.40 5,439.25 2,980.19 13,957.89 5,978,572.96 399,901.52 0.33 14,272.38 MWD+IFR-AK-CAZ-SC(3) 16,448.35 76.77 80.26 5,516.37 5,460.22 2,995.40 14,045.99 5,978,586.84 399,989.83 0.14 14,361.72 MWD+IFR-AK-CAZ-SC(3) 16,542.07 76.52 80.32 5,538.02 5,481.87 3,010.78 14,135.87 5,978,600.85 400,079.93 0.27 14,452.85 MWD+IFR-AK-CAZ-SC(3) 16,633.01 76.13 79.98 5,559.52 5,503.37 3,025.90 14,222.93 5,978,614.63 400,167.20 0.56 14,541.16 MWD+IFR-AK-CAZ-SC(3) 16,728.35 76.26 80.13 5,582.27 5,526.12 3,041.89 14,314.12 5,978,629.23 400,258.62 0.20 14,633.69 MWD+IFR-AK-CAZ-SC(3) 16,819.91 76.27 79.84 5,604.01 5,547.86 3,057.36 14,401.71 5,978,643.36 400,346.42 0.31 14,722.59 MWD+IFR-AK-CAZ-SC(3) 16,912.92 76.33 79.93 5,626.04 5,569.89 3,073.23 14,490.67 5,978,657.88 400,435.61 0.11 14,812.92 MWD+IFR-AK-CAZ-SC(3) 17,005.67 76.45 79.48 5,647.86 5,591.71 3,089.34 14,579.36 5,978,672.63 400,524.53 0.49 14,903.03 MWD+IFR-AK-CAZ-SC(3) 17,099.14 76.53 78.85 5,669.70 5,613.55 3,106.42 14,668.62 5,978,688.36 400,614.03 0.66 14,993.90 MWD+IFR-AK-CAZ-SC(3) 17,192.18 76.71 78.44 5,691.23 5,635.08 3,124.24 14,757.37 5,978,704.82 400,703.03 0.47 15,084.41 MWD+IFR-AK-CAZ-SC(3) 17,284.95 76.50 78.69 5,712.72 5,656.57 3,142.14 14,845.82 5,978,721.37 400,791.74 0.35 15,174.65 MWD+IFR-AK-CAZ-SC(3) 17,377.87 76.45 78.47 5,734.45 5,678.30 3,160.02 14,934.37 5,978,737.90 400,880.55 0.24 15,265.00 MWD+IFR-AK-CAZ-SC(3) 17,471.33 76.76 78.55 5,756.10 5,699.95 3,178.13 15,023.47 5,978,754.65 400,969.90 0.34 15,355.91 MWD+IFR-AK-CAZ-SC(3) 17,564.45 76.83 78.19 5,777.37 5,721.22 3,196.41 15,112.27 5,978,771.57 401,058.96 0.38 15,446.57 MWD+IFR-AK-CAZ-SC(3) 17,658.94 76.39 78.15 5,799.26 5,743.11 3,215.25 15,202.23 5,978,789.05 401,149.19 0.47 15,538.49 MWD+IFR-AK-CAZ-SC(3) 17,751.04 76.13 78.46 5,821.13 5,764.98 3,233.39 15,289.84 5,978,805.84 401,237.06 0.43 15,627.95 MWD+IFR-AK-CAZ-SC(3) 17,846.66 76.70 78.30 5,843.59 5,787.44 3,252.11 15,380.88 5,978,823.18 401,328.37 0.62 15,720.90 MWD+IFR-AK-CAZ-SC(3) 17,940.24 76.19 78.49 5,865.52 5,809.37 3,270.41 15,469.99 5,978,840.12 401,417.74 0.58 15,811.87 MWD+IFR-AK-CAZ-SC(3) 18,033.39 76.38 78.72 5,887.61 5,831.46 3,288.29 15,558.70 5,978,856.64 401,506.70 0.31 15,902.36 MWD+IFR-AK-CAZ-SC(3) 18,124.43 76.38 79.13 5,909.05 5,852.90 3,305.29 15,645.54 5,978,872.31 401,593.78 0.44 15,990.83 MWD+IFR-AK-CAZ-SC(3) 18,218.01 76.39 79.49 5,931.08 5,874.93 3,322.16 15,734.91 5,978,887.82 401,683.39 0.37 16,081.77 MWD+IFR-AK-CAZ-SC(3) 18,308.34 76.57 79.48 5,952.19 5,896.04 3,338.18 15,821.26 5,978,902.53 401,769.97 0.20 16,169.57 MWD+IFR-AK-CAZ-SC(3) 18,405.13 76.38 79.32 5,974.83 5,918.68 3,355.50 15,913.76 5,978,918.43 401,862.71 0.25 16,263.66 MWD+IFR-AK-CAZ-SC(3) 18,498.26 76.26 79.15 5,996.86 5,940.71 3,372.40 16,002.66 5,978,933.98 401,951.85 0.22 16,354.13 MWD+IFR-AK-CAZ-SC(3) 18,590.94 76.63 78.29 6,018.58 5,962.43 3,390.02 16,091.01 5,978,950.25 402,040.45 0.99 16,444.22 MWD+IFR-AK-CAZ-SC(3) 18,680.94 76.64 78.85 6,039.38 5,983.23 3,407.37 16,176.84 5,978,966.29 402,126.53 0.61 16,531.78 MWD+IFR-AK-CAZ-SC(3) 18,768.72 76.64 79.04 6,059.67 6,003.52 3,423.75 16,260.66 5,978,981.39 402,210.58 0.21 16,617.18 MWD+IFR-AK-CAZ-SC(3) 18,867.02 76.45 79.13 6,082.54 6,026.39 3,441.85 16,354.53 5,978,998.06 402,304.71 0.21 16,712.77 MWD+IFR-AK-CAZ-SC(3) 18,958.74 76.45 79.15 6,104.03 6,047.88 3,458.65 16,442.10 5,979,013.53 402,392.52 0.02 16,801.92 MWD+IFR-AK-CAZ-SC(3) 19,054.20 75.82 79.01 6,126.90 6,070.75 3,476.21 16,533.10 5,979,029.69 402,483.76 0.68 16,894.59 MWD+IFR-AK-CAZ-SC(3) 19,144.93 76.06 79.34 6,148.94 6,092.79 3,492.74 16,619.55 5,979,044.90 402,570.44 0.44 16,982.59 MWD+IFR-AK-CAZ-SC(3) 19,236.83 76.07 79.36 6,171.08 6,114.93 3,509.22 16,707.20 5,979,060.05 402,658.34 0.02 17,071.76 MWD+IFR-AK-CAZ-SC(3) 19,332.14 76.50 79.16 6,193.67 6,137.52 3,526.48 16,798.17 5,979,075.92 402,749.55 0.50 17,164.34 MWD+IFR-AK-CAZ-SC(3) 19,424.99 76.83 78.65 6,215.09 6,158.94 3,543.86 16,886.83 5,979,091.95 402,838.45 0.64 17,254.68 MWD+IFR-AK-CAZ-SC(3) 19,516.00 76.26 79.06 6,236.27 6,180.12 3,560.97 16,973.67 5,979,107.73 402,925.54 0.76 17,343.18 MWD+IFR-AK-CAZ-SC(3) 19,610.71 76.14 79.02 6,258.86 6,202.71 3,578.46 17,063.97 5,979,123.84 403,016.09 0.13 17,435.15 MWD+IFR-AK-CAZ-SC(3) 19,704.39 76.58 78.77 6,280.95 6,224.80 3,595.99 17,153.31 5,979,140.02 403,105.67 0.54 17,526.18 MWD+IFR-AK-CAZ-SC(3) 6/16/2010 10:15:46AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-15 Project: Western North Slope TVD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Site: CD1 Alpine Pad MD Reference: CD1-15 @ 56.15ft(D19(36.65+19.5)) Well: CD1-15 North Reference: True Wellbore: CD1-15PB2 Survey Calculation Method: Minimum Curvature Design: CD1-15PB2 Database: CPAI EDM Production Survey Map Map Vertical j MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) ('11OO') (ft) Survey Tool Name 19,794.55 76.57 78.99 6,301.88 6,245.73 3,612.91 17,239.36 5,979,155.62 403,191.96 0.24 17,613.87 MWD+IFR-AK-CAZ-SC(3) 19,889.66 76.76 79.31 6,323.82 6,267.67 3,630.33 17,330.25 5,979,171.65 403,283.10 0.38 17,706.40 MWD+IFR-AK-CAZ-SC(3) 19,980.31 76.32 79.34 6,344.92 6,288.77 3,646.66 17,416.88 5,979,186.66 403,369.96 0.49 17,794.55 MWD+IFR-AK-CAZ-SC(3) 20,067.00 75.74 79.13 6,365.84 6,309.69 3,662.37 17,499.53 5,979,201.11 403,452.83 0.71 17,878.66 MWD+IFR-AK-CAZ-SC(3) 20,114.00 75.74 79.13 6,377.42 6,321.27 3,670.96 17,544.26 5,979,209.02 403,497.69 0.01 17,924.20 BLIND(4) 6/16/2010 10:15:46AM Page 8 COMPASS 2003.16 Build 69 WELL LOG TRANSMITTAL To: State of Alaska June 24, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 RE: MWD Formation Evaluation Data: CD1-15 PB1 AK-MW-0007264437 CD1-15 PB1 50-103-20619-70 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 2"x 5"MD BAT SONIC Logs: 1 Color Log 2"x 5" TVD BAT SONIC Logs: 1 Color Log Digital Log Images&LWDG-formatted LIS Data w/verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 . t-.. ielpn.com Date: Signed: / Atoka 3Gas Om.'Ci Anchave 0/0,°40 / 9/- Zsa Page 1 of 2 Schwartz, Guy L (DOA) From: Robertson, Ryan G [Ryan.G.Robertson@conocophillips.com] Sent: Thursday, June 10, 2010 2:00 PM To: Schwartz, Guy L(DOA) Subject: RE: CD1-15 Plan Forward (PTD 210-047) Guy, Thanks for the quick response. I will work on the 10-403 on Monday morning. Ryan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday,June 10, 2010 1:54 PM To: Robertson, Ryan G Subject: RE: CD1-15 Plan Forward (PTD 210-047) Ryan, You have verbal approval from the Commission to perform an Operational Shutdown of the well CD1-15 as outlined below. Please submit the 10-403 sundry requesting the shutdown as soon as possible. Additionally, a 10-404 will be required after the rig moves off detailing the well status, daily drilling reports and a well schematic showing the completion as left by the rig. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Thursday, June 10, 2010 12:01 PM To: Schwartz, Guy L(DOA) Subject: CD1-15 Plan Forward Guy, As per our discussion earlier... The Alpine Asset team had decided to temporarily suspend the CD1-15 wellbore due to continued difficulty sidetracking the 6.75" production hole. This inability to begin drilling has pushed the predicted completion date of this well into early July, making a rig move to the CD4 pad increasingly risky. The proposed plan forward for the CD1-15 well is as follows: • Run in the hole with a clean out assembly to ensure all debris from intermediate casing is removed • Pick up a 7-5/8" cement retainer and set at±19,700' MD/±6,280'TVD. This depth is just above the HRZ formation and will be used in the fall to set a new whipstock on the retainer and sidetrack the 6.75" production hole. • Pressure test casing above retainer to 2,500 psi for ten minutes • Sting into the cement retainer and attempt to break down open hole. If the open hole will not break down with 2,000 psi surface pressure, CPAI requests permission to waive placing cement above the retainer in order to leave the top of the retainer clean for setting a whipstock on top of it 7/9/2010 Page 2 of 2 in the fall. • Pull out of the hole • Run a kill string to 2,200' MD/2,000' TVD • Freeze protect • Secure the well • Move Doyon 19 to CD4 for the summer drilling program In the fall of this year, Doyon 19 will be move back to CD1-15 to make another attempt at drilling and completing the CD1-15 well as planned. This plan calls for a 5.5" liner to be run to TD and cemented in place. The liner will be set with a liner hanger and ZXP liner top packer. The cement job will be evaluated for integrity prior to perforating and running tubing. I have attached a schematic of the proposed plan prior to moving to CD4, along with the current completion schematic which will be implemented in the fall. A 10-403 operational shutdown permit will be submitted early next week. Please let me know if you require any additional information, Ryan Drilling Engineer 1 ConocoPhillips Alaska Direct (907)265 6318 1 Mobile (907)980-5107 7/9/2010 Page 1 of 2 4 Schwartz, Guy L (DOA) From: Robertson, Ryan G [Ryan.G.Robertson@conocophillips.com] Sent: Friday, June 04, 2010 3:31 PM To: Schwartz, Guy L(DOA) Subject: RE: CD1-15 Plan Forward (PTD 210-047) Thanks Guy. I will let you know how we are doing. Ryan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, June 04, 2010 3:23 PM To: Robertson, Ryan G Subject: RE: CD1-15 Plan Forward (PTD 210-047) Ryan, I discussed your plan with Commissioner Seamount and you have verbal approval to proceed as outlined below. In addition, if the circumstances call for an "Operational Shutdown" and moving the rig after abandoning the OH section below the casing point you have verbal approval for that scenario as well. Keep me posted over the weekend.... The abandoned portion of the well below the Whipstock will become CD1-15PB1 and need to be reported with the final 407 well report. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Friday, June 04, 2010 2:08 PM To: Schwartz, Guy L(DOA) Subject: CD1-15 Plan Forward Guy, As per our conversation, due to the fact that our directional drillers have been unable to sidetrack out of the existing 9-7/8" hole after a cement plug was set in it, the decision has been made to abandon the remaining 477' MD of 9-7/8" hole and set a whipstock in the casing to start a new sidetrack. Our plan forward will be to run the retainer to a depth of roughly 20,090' MD. This will put the retainer in the first joint of casing above the shoe track, which will allow it a better chance to set above any remaining cement. From that point we will squeeze cement into the remaining open hole to effectively isolate it. We believe there is roughly 70 ft of open hole below the casing shoe at which point we have solid cement. Our plan is to pump approximately 10 bbl of cement to isolate the open hole and shoe track below the retainer. We propose to establish an injection rate with mud below the retainer prior to cementing. If we cannot break down the rock, we would propose to spot 40 ft of cement above the retainer and pull out of the hole. 7/9/2010 Page 2 of 2 After the cement job, we will run back in the hole and set a whipstock to sidetrack a 6.75" assembly into the open hole. We will then drill the 6.75" production hole to the planned depth of 21,993' MD/6,828' TVD. The attached schematic shows the whipstock exiting the casing at 20,800' MD, however this depth could be as high as 19,700' MD to ensure that we put the exit point in the strongest rock possible to achieve our LOT. Once our final depth is chosen, I will pass along that information. Please let me know if you require any additional information. Ryan Dulling Engineer ConocoPhillips Alaska Direct (9071 265-6318 Mobile (907)980-5107 7/9/2010 Page 1 of 1 Schwartz, Guy L (DOA) From: Robertson, Ryan G [Ryan.G.Robertson@conocophillips.com] Sent: Thursday, May 27, 2010 2:15 PM To: Schwartz, Guy L(DOA) Subject: CD1-15 Update Guy, We have successfully pressure tested the 9-7/8" open hole to 15.0 ppg EMW at the intermediate shoe. Our plan forward is to clean out the remaining 9-7/8" hole as far as possible and then pull out to pick up a cementing assembly. We will cement back the open hole to roughly 200'within the 7-5/8" casing. Once cementing is completed, we will pull out and pick up our 6.75" GeoPilot assembly. The well will be sidetracked and we will expose a minimum of 20 ft of new rock prior to performing our LOT to 15.0 ppg EMW. If we achieve a successful test, we will proceed to drill ahead. This should take us into Monday. Thanks for your help today. Enjoy the weekend. Ryan Drilling L iigine e j Canr,cnpinliips Alaska: Direcl 1;10 i,215-,318 1 Mobile (9071980-5107 5/27/2010 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, May 27, 2010 9:47 AM To: 'Robertson, Ryan G' Subject: RE: Upcoming LOT on CD1-15 Ryan, Regulations actually state 20-50 ft of new formation ( drilling through cement below shoe doesn't count). We can discuss this later this morning when we have our meeting. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Wednesday, May 26, 2010 11:44 AM To: Schwartz, Guy L(DOA) Subject: Upcoming LOT on CD1-15 Guy, We are currently running in the hole with a 6.75"clean out assembly. Our plan forward is to drill out the intermediate shoe track and condition the remaining 477' MD of 9-7/8" hole below the 7-5/8" casing. We will then pull out of the hole and run in with a cement string to plug back the old hole along with roughly 200' of the 7-5/8" casing. We should be tripping in the hole with a GeoPilot assembly during the weekend to drill our production section. Our plan is to drill out the cement in the casing and then sidetrack low into new rock and perform a LOT. We generally drill our rat hole and 20 ft of new formation before we do a LOT. In this case we will likely need to drill further from the shoe to get into new rock prior to performing our LOT. I understand that we can drill 50 ft MD from the shoe before we are required to perform the LOT. If we drill 50' MD from the shoe to 20,273' MD prior to performing our LOT to ensure we are in new rock, are we still within guidelines? 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Pass LOT > 15.0 ppg • Plug back well o Old well is now CD1-15PB1?✓ • Sidetrack to same XY coordinates o How far can we sidetrack before we perform LOT • Submit Sundry for change in plans? o 10-403 o Schematic o Proposed plan ahead 1.2. Don't Pass LOT—Drill and run 5.5"liner to 20,700' MD • XY's are the same • One extra string of casing • Submit Sundry for change in plans? o 10-403 o Schematic o Proposed plan ahead 1.3. Don't Pass—Suspend and Abandon • Operational Shut down • Temporarily suspend well and move to D4 o Set plug in old hole �- o Pressure test casing o Run kill string • Submit Sundry for change in plans? o 10-403 o Schematic o Proposed plan ahead • Come back to the fall and redrill o Submit application to re-enter Page 1 of 1 Alpine CD1-15 7-5/8" Stage Tool Depths Depths based on actual rig surveys 5/19/2010 5/19/2010 16"Conductor to 114' 10-3/4"45.5 ppf L-80 BTC-mod Surface Casing Actual @ 3,112'MD/2393'TVD cemented to surface Top C10 2,993'TVD(5,682'MD) Trj, Planned TOC 5,182'MD Bottom C10 3,015'TVD(5,760'MD) TAM Port Collar I O 0 3,039'TVD(5,872'MD) I, K3 Basal Top / O+ 3,967'TVD(9,839'MD) Mill Planned TOC 761 9,339'MD K3 Basal Bottom 4,006'TVD(10,000'MD) • HES Stage Tool nil'. rAii 4,022'TVD(10,070'MD) Planned TOC 19,200'MD Top HRZ 6,307'TVD(19,819'MD) Base HRZ 7-5/8"Casing Shoe 6,404'TVD(20,223'MD) 6,443'TVD(20,390'MD) Planned Shoe Depth—Current Shoe Depth K1 Marker 108'TVD(467'MD) 6,492'TVD(20,604'MD) Planned 7-5/8"Shoe Depth 6,512'TVD(20,690'MD) TD 9-7/8"Hole 6,514'TVD(20,700'MD) ?/4tihel TI) 919 P3 ' - t CG BL F rvD) Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, May 19, 2010 4:47 PM To: 'Robertson, Ryan G' Subject: RE: CD1-15 Intermediate Casing Update(PTD 210-047) Ryan, Thanks for the update. Make sure you include the directional and logs for the old hole PB1 in the 407 report. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Wednesday, May 19, 2010 2:18 PM To: Schwartz, Guy L (DOA) Subject: RE: CD1-15 Intermediate Casing Update (PTD 210-047) Guy, Thanks for reviewing our plan forward. Once we get the three stage cement in place, we will run in the hole with a dumb iron assembly and drill out the 120 ft shoe track. From that point, we will likely work the assembly through the remaining ±480 ft to bottom and condition the hole before pulling back out to surface. The next procedure will involve running back to bottom with a cement stinger and spotting cement throughout the open hole and roughly 100 ft into the intermediate shoe. The strategy is to effectively eliminate the remaining open hole and start from scratch out of the intermediate casing shoe. Once the cement is in place in the open hole, and the cementing assembly is laid down, we will run in with a 6.75" Geo Pilot assembly. The plan will be to drill the shoe track and side track off the cement plug. We don't anticipate having to drill more than 100' MD before performing an FIT test. At that point, if the FIT looks good, we will drill the remaining ±1,800' MD of 6 75" production hole to the planned TD point and complete the well as planned. I will keep you updated on our plans and let you know if make any significant changes. Please let me know if you require any more information. Ryan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, May 19, 2010 1:22 PM To: Robertson, Ryan G Subject: RE: CD1-15 Intermediate Casing Update(PTD 210-047) Ryan, I have reviewed the cement calcs and your proposed TOC depths Everything seems to be in order to proceed to cement the intermediate liner in place where it is landed now. The upper C-10 and Qannik zone will be adequately isolated with cement with the current plan. Can you forward me your plan forward after drillout of the shoe track at your earliest convenience'? You mentioned laying in a cement plug and kicking off a sidetrack in our phone conversation earlier 5/19/2010 Page 2 of 2 A Thanks in advance, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Wednesday, May 19, 2010 11:35 AM To: Schwartz, Guy L(DOA) Subject: CD1-15 Intermediate Casing Update Guy, The 7-5/8" intermediate casing on the CD1-15 wellbore has unfortunately hit a bridge at approximately 20,223' MD/6,404' TVD which the shoe is unable to pass. This puts the intermediate shoe roughly 467' MD/ 108' TVD higher than the planned setting depth of 20,700' MD/6,512' TVD. Fortunately the HES collar that will be used to cement of the hydrocarbon bearing K3 Basal zone is currently situated roughly 70' MD below the bottom of that formation. At Alpine, we generally cement of the Qannik formation, however in the Alpine East development, the Qannik tends to shale out, and the K3 Basal trends into a hydrocarbon bearing sand at the same point. As a reminder, this well has a third stage cement job required to cement off the unexpected hydrocarbon bearing C-10 zone. The TAM port collar that will be used to cement of this formation is currently sitting roughly 112' MD below the bottom of the C10 zone. With the HES tool and TAM port collar located below the hydrocarbon bearing zones, isolating these zones with 500 ft of cement above their tops will be possible. I have attached a current schematic of the wellbore and intermediate casing string, as well as the planned cementing program. Please let me know if you require any more information, Ryan Linlhny Fuyuieer j ConocoPh!Ilips Alaska I Duecl (907)265-0318;Mobile (907)980-5107 5/19/2010 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, May 19, 2010 1:22 PM To: 'Robertson, Ryan G' Subject: RE: CD1-15 Intermediate Casing Update(PTD 210-047) Ryan, I have reviewed the cement caics and your proposed TOC depths. Everything seems to be in order to proceed to cement the intermediate liner in place where it is landed now. The upper C-10 and Qannik zone will be adequately isolated with cement with the current plan. Can you forward me your plan forward after drillout of the shoe track at your earliest convenience? You mentioned laying in a cement plug and kicking off a sidetrack in our phone conversation earlier. Thanks in advance, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Wednesday, May 19, 2010 11:35 AM To: Schwartz, Guy L (DOA) Subject: CD1-15 Intermediate Casing Update Guy, The 7-5/8" intermediate casing on the CD1-15 wellbore has unfortunately hit a bridge at approximately 20,223' MD/6,404'TVD which the shoe is unable to pass. This puts the intermediate shoe roughly 467' MD/ 108'ND higher than the planned setting depth of 20,700' MD/6,512' ND. Fortunately the HES collar that will be used to cement of the hydrocarbon bearing K3 Basal zone is currently situated roughly 70' MD below the bottom of that formation. At Alpine, we generally cement of the Qannik formation, however in the Alpine East development, the Qannik tends to shale out, and the K3 Basal trends into a hydrocarbon bearing sand at the same point. As a reminder, this well has a third stage cement job required to cement off the unexpected hydrocarbon bearing C-10 zone. The TAM port collar that will be used to cement of this formation is currently sitting roughly 112' MD below the bottom of the C10 zone. With the HES tool and TAM port collar located below the hydrocarbon bearing zones, isolating these zones with 500 ft of cement above their tops will be possible. I have attached a current schematic of the wellbore and intermediate casing string, as well as the planned cementing program. Please let me know if you require any more information, Ryan 5/19/2010 I NPV 4: •INE ConocoPhillips 7-5/8"Intermediate Casing—Three Stage Cement Proposal Primary Cement Job Cement from 20,223 MD to 19,200' MD with Class G+adds @ 15.8 PPG.Assume 40%excess annular volume. Lead: (20,223' — 19,200')X 0.2148 ft3/ft X 1.4 (40%excess)=308 ft3 annular vol. 120' X 0.2578 ft3/ft=31 ft3 shoe joint volume Total volume= 308 +31 =339 ft3=>292 Sx @ 1.16 ft3/sk System: 292 Sx Class G + 0.2%D046 antifoamer, 0.25%D065 dispersant, 0.25%D800 retarder and 0.18%D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Secondary Cement Job Cement from ports in a stage tool set at 10,070' MD to+/- 500' above the K2 interval with Class G+ additives @ 15.8 ppg. Assume 40% excess annular volume (10070' -9339')X 0.2148 ft3/ft X 1.4 (40%excess) =220 ft3 annular vol. Total Volume=220 ft3=> 188 Sk @ 1.17 ft3/sk 188 Sx Class G+0.2%D046 antifoamer, 0.3%D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.16 ft3/sk Third Stage Cement Job Cement from ports in a stage tool set at 5,872 MD to+/- 500' above the C10 interval with Class G+ additives @ 15.8 ppg. Assume 40% excess annular volume (5872' - 5182') X 0.2148 ft3/ft X 1.4(40%excess)=207 ft3 annular vol. Total Volume=207 ft3=> 179 Sk @ 1.17 ft3/sk 179 Sx Class G+0.2%D046 antifoamer, 0.3%D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.16 ft3/sk i I ZIO-- 0`17 Alpine CD1-15 7-5/8" Stage Tool Depths Depths based on actual rig surveys 5/19/2010) ,...., 5/19/2010 16"Conductor to 114' 10-3/4"45.5 ppf L-80 BTC-mod Surface Casing Actual @ 3,112'MD/2393'TVD cemented to surface Top C10 • 2,993'TVD(5,682'MD) Planned TOC Bottom C10 5,182'MD 3,015'TVD(5,760'MD) ' 0 0 TAM Port Collar 0 3,039'TVD(5,872'MD) K3 Basal Top Q, 3,967'TVD(9,839'MD) iiiiiiii iiiiiiiPlanned TOC 761 !iiiiii 9,339'MD K3 Basal Bottom 4,006'TVD(10,000'MD) IT(- HES Stage Tool f.: 4,022'TVD(10,070'MD) Planned TOC 1' `r. 19,200'MD If .r s. Top HRZ 6,307'TVD(19,819'MD) >.'; e:l(? \01 7-5/8"Casing Shoe Base HRZ ' ? 6,404'TVD(20,223'MD) 6,443'TVD(20,390'MD) ' Planned Shoe Depth—Current Shoe Depth K1 Marker 108'TVD(467'MD) 6,492'TVD(20,604'MD) Planned 7-5/8"Shoe Depth 6,512'TVD(20,690'MD) TD 9-7/8" Hole 6,514'TVD(20,700'MD) Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, May 12, 2010 4:20 PM To: 'Robertson, Ryan G' Subject: RE: CD1-15 -Third Stage Cement Job PTO Z►a—Oy7 Ryan, Your plan below is acceptable as we discussed. Good luck with the cement stages.... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Wednesday, May 12, 2010 3:54 PM To: Schwartz, Guy L(DOA) Subject: CD1-15 -Third Stage Cement Job Guy, As per our discussion earlier this afternoon, CPAI plans to implement a cement job across the unexpected sand zone that was encountered at a depth of 5,682' MD/2,994'TVD while drilling the CD1-15 intermediate hole. Isolating this unexpected zone will require a third stage cement job as a primary cement job will be pumped across the shoe, and a secondary job will be used to isolate the Qannik sand. The third stage cement job will be executed using a TAM port collar set at approximately 6,260' MD. This will allow for the planned 500 ft MD of cement to be set below the bottom of the zone, and an additional 500 ft MD of cement above the top. Prior to the cement job, the 7-5/8" pack off will be installed and pressure tested. A hard line from the outer annulus valve to the choke line will be hooked up using 1502 threaded connections. It is felt this is the best well control option as it will provide the ability to use the choke to control the annulus and the pipe rams and annular preventer to seal the casing. Please let me know if you have any additional questions. Ryan f„;,_ �ilrii + -G if; P1ril',ilP 1ri:r 5/12/2010 < < < < CDD — CD CD MD tD CD o Er '*' -t o �G o `C .. C CQ w 0 CD 0 37 o CD rn N W s W N W p C4C�OC71O �1 C oo ol o Cn -t O. 1 r' r ' ? V aO x 2 w i. Q sstvd 0 ! 7 1 q a o G ti N D 'SNI If la 9 `z T C� 1 1 n a — II o a,.. m sairE ., /iYLusEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMAIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Ryan Robertson Alpine Drilling Engineer ConocoPhillips Alaska, Inc. Glia — O 7 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-15, CD 1-15PB 1, CD1-15PB2 Sundry Number: 310-182 Dear Mr. Robertson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. / -r< Chair DATED this/b day of June, 2010. Encl. U',�Ip��� STATE OF ALASKA ALASK L AND GAS CONSERVATION COMMISS, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown I • Re-enter Susp.Well r Stimulate r Atter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210-047 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20619-00,-70, -71 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r CD1-15,CD1-15PB1,CD1-15PB2 9.Property Designation: yy,� `10.Field/Pool(s): ADL 372108,384214', 2.437 ,',yi7 l Colville River Field/Alpine 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): 20700' 6514' 19705' 6281' 19705',20085' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 3112 10.75 3112' 2394' INTERMEDIATE 20225 7.625 20225' 6405' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 3.5 L-80 2211 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) Baker cement retainer MD=19705 TVD=6281 no SSSV 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/15/2010 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: 6/10/2010 WINJ r- GINJ r WAG - Abandoned r Commission Representative: G.Schwartz GSTOR E SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Robertson @ 265-6318 Printed Name Ryan Robertson Title: Alpine Drilling Engineer Signature , Phone: 265-6318 Date 6‘./,s,lo Commission Use Only Sundry Number:3 ()1W Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RECEIVED No 11.5 Ce_..►+./J'.fio.� re_vi-.14.- /f o,tr .iak+'. v Other: A JUN 152010 Subsequent Form Required: /O , '011 20 44L ZS.- 4:17Z c b) Alaska Oil&Gas Ceram.Commission A�flohlQf►3q� APPROVED BY ‘//6-M'//� /fit Approved by: COMMISSIONER THE COMMISSION Date: 6 /` `� Form 10-403 Revise /2 171010 Submit in D licate o�� d�� � R I G I �� A L. `�'`�'° �� �il/� --=�s �u .1-15 Suspend Operations Procedure The Alpine Asset team had decided to temporarily suspend the CD1-15 wellbore due to continued difficulty sidetracking the 6.75" production hole. This inability to begin drilling has pushed the predicted completion date of this well into early July, making a rig move to the CD4 pad increasingly risky. The proposed plan forward for the CD1-15 well is as follows: • Run in the hole with a clean out assembly to ensure all debris from intermediate casing is removed • Pick up a 7-5/8"cement retainer and set at±19,700' MD/±6,280' TVD. This • depth is just above the HRZ formation and will be used in the fall to set a new whipstock on the retainer and sidetrack the 6.75" production hole. • Pressure test casing above retainer to 2,500 psi for ten minutes • Sting into the cement retainer and attempt to break down open hole. If the open hole will not break down with 2,000 psi surface pressure, CPAI requests permission to waive placing cement above the retainer in order to leave the top of the retainer clean for setting a whipstock on top of it in the fall. • Pull out of the hole • Run a kill string to 2,200' MD/2,000' TVD • Freeze protect • Secure the well • Move Doyon 19 to CD4 for the summer drilling program In the fall of this year, Doyon 19 will be move back to CD1-15 to make another attempt at drilling • and completing the CD1-15 well as planned. This plan calls for a 5.5" liner to be run to TD and cemented in place. The liner will be set with a liner hanger and ZXP liner top packer. The cement job will be evaluated for integrity prior to perforating and running tubing. I have attached a schematic of the proposed plan prior to moving to CD4, along with the current completion schematic which will be implemented in the fall. A 10-403 operational shutdown permit will be submitted early next week. Alpine CD1-1 5 Depths based on actual rig surveys 5/19/2010 Operational Shut Down Status 6/14/2010 AdJ ?'ii., 16"Conductor to 114' 10-3/4"45.5 ppf L-80 BTC-mod Surface Casing Actual @3,112'MD12393'TVD cemented to surface Calculate TOC 1- 4,908'MD/2,811'TVD ''' -;Y? ' 0 TAM Port Collar 0 0 3,039'TVD(5,872'MD) r' Calculated TOC 8,986'MD/3,768'TV[ h HES Stage Tool 4,022'TVD(10,070'MD) Calculated TOC 18,737'MD/6,052'TVD ,. 7-5/8"Whipstock Window Exit Depth Cement Retainer#2 Depth 20,080'MD/6,369'TVD 19,705'MD/6,281'TVD 7-5/8"Cement Retainer#1 CD1-15PB2 20,085'MD/6,370'TVD 6.75"Sidetrack 20,114'MD/6,377'TVD 7-5/8"Casing Shoe 6,404'TVD(20,223'MD) CD1-15PB1 9.875"Open Hole TD 9-7/8"Hole 6,514'TVD(20,700'MD) ' Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, June 10, 2010 1:54 PM To: 'Robertson, Ryan G' Subject: RE: CD1-15 Plan Forward (PTD 210-047) Ryan, You have verbal approval from the Commission to perform an Operational Shutdown of the well CD1-15 as outlined below. Please submit the 10-403 sundry requesting the shutdown as soon as possible. Additionally, a 10-404 will be required after the rig moves off detailing the well status, daily drilling reports and a well schematic showing the completion as left by the rig. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Thursday, June 10, 2010 12:01 PM To: Schwartz, Guy L (DOA) Subject: CD1-15 Plan Forward Guy, As per our discussion earlier... The Alpine Asset team had decided to temporarily suspend the CD1-15 wellbore due to continued difficulty sidetracking the 6.75" production hole. This inability to begin drilling has pushed the predicted completion date of this well into early July, making a rig move to the CD4 pad increasingly risky. The proposed plan forward for the CD1-15 well is as follows: • Run in the hole with a clean out assembly to ensure all debris from intermediate casing is removed • Pick up a 7-5/8"cement retainer and set at±19,700' MD/±6,280'TVD. This depth is just above the HRZ formation and will be used in the fall to set a new whipstock on the retainer and sidetrack the 6.75" production hole. • Pressure test casing above retainer to 2,500 psi for ten minutes • Sting into the cement retainer and attempt to break down open hole. If the open hole will not break down with 2,000 psi surface pressure, CPAI requests permission to waive placing cement above the retainer in order to leave the top of the retainer clean for setting a whipstock on top of it in the fall. • Pull out of the hole • Run a kill string to 2,200' MD/2,000' TVD • Freeze protect • Secure the well • Move Doyon 19 to CD4 for the summer drilling program In the fall of this year, Doyon 19 will be move back to CD1-15 to make another attempt at drilling and completing the CD1-15 well as planned. This plan calls for a 5.5" liner to be run to TD and cemented in place. The liner will be set with a liner hanger and ZXP liner top packer. The cement job will be evaluated for integrity prior to perforating and running tubing. 6/10/2010 Page 2 of 2 I have attached a schematic of the proposed plan prior to moving to CD4, along with the current completion schematic which will be implemented in the fall. A 10-403 operational shutdown permit will be submitted early next week. Please let me know if you require any additional information, Ryan frLU[rig E=ngineer ConocnPIi flips Alaska Direct 1907,2;35 63i8 l Mobile i9071980 5107 6/10/2010 CD1-15 Alpine "C" Pre-Producer / Injector Proposed Temporary Suspension Z'6 -by Sperry Sun 16" Insulated Conductor to Directional Plan WP04 -114' 6/10/2010 , \, 3-'/2'9.3 ppf L-80 IBT Mod Kill String 10-3/4"45.5 ppf L-80 BTCM Surface Casing J 3112' MD/2393'TVD Cemented to surface TOC Kill String: Too MD TVD €€ +1-5182' MD Port is /2874'TVD 1) Tubing Hanger 32' 32' Cementing 2) 4-%" 12.6#/ft IBT-Mod Tubing(2 jts),XO Collar 0 01 C10 Bottom 3) 3-'/z"9.3#/ft EUE-Mod Tubing 2,200 2,000 +/-5872' MD '''r '>"I +/-5760' MD /3039'TVD /3015'TVD 11111 TOC Fi +1-9339'MD Stage /3850'TVD cementing tool+/ 1 O 0 10070' MD EL. . K3 Basal Bottom /4022'TVD +/-10000' MD /4006'TVD CD1-PB2 20114' MD/6,377'TVD 001. Cement Retainer ±19700' MD/±6280'TVD 7-5/8"29.7 ppf L-80 BTC Mod Top of cement 76°20,225' MD/ 18,740' MD/6053'TVD , '' 6405'TVD Top HRZ Reservoir at+/- CD1-15PB1 19817' MD/6307'TVD !., 20700' MD/6,515'TVD Base HRZ at+/- 20364' MD/6437'TVD CD1-15AE Alpine "C" Pre-Producer / Injector Proposed Completion Sperry Sun 16" Insulated Conductor to Directional Plan WP04 —114' ® 6/10/2010 '"T, 4-W 12.6 ppf L-80 IBT Mod Tubing --------- „3-1/2"SSSV with 2.813"X Landing Nipple 10-3/4"45.5 ppf L-80 BTCM Surface Casing 3112' MD/2393'TVD Cemented to surface Upper Completion: Top MD TVD TOC 1) Tubing Hanger 32' 32' +1-5182'MD 2) 4-'/z" 12.6#/ft IBT-Mod Tubing(2 jts),XO Port !ilii U /2874'TVD 3) 3-'/2'9.3#/ft EUE-Mod Tubing Cementing : 4) Camco TRMAXX-5E SSSV(2.812"ID) 2,200' 2,013' (Th ii with control line to surface Collar C10 Bottom 5) 3-1/2'9.3#/ft EUE-Mod Tubing +/-5872' MD +/-5760' MD 6) 3-'/2"Camco MMG-HW GLM(ID=2.915") 15,000' 5,176' /3039'TVD /3015'TVD 7) 3-1/2"9.3#/ft EUE-Mod Tubing 8) HES"XN"(2.75"min ID)@ 76 deg 20,000' 6,350' 9) 3-1/2'9.3#/ft EUE-Mod Tubing 10) Baker GBH-22 80-40 Bonded Seal assembly 20,120' 6,379' with'/z Mule Shoe Lower Completion: Top MD TVD -=3 TOC Item +/-9339'MD 11) Baker 5-1/2"x 7-5/8"Flex-lock Liner Hanger 20,080' 6,369' Stage ,..-:E.• /3850'TVD ZXP Liner Top Packer w/20 ft Seal Bore cementing - Extension tool +/- ,, Q 12) 5-W, 15.5#/ft, L-80 BTC-Mod Blank Liner 10070' MD . 0 K3 Basal Bottom with both Bow type and slide on centralizers /4022'TVD +/-10000' MD (Placement specified in the Completion /4006'TVD Procedure). 13) 5-1A"Float Collar and Shoe BTC-Mod 21,985' 6,824' Connections ' 7-5/8"29.7 ppf L-80 BTC Mod Q Production Casing Whipstocked @ +/- 76° 19,700' MD/ Top of cement 6280'TVD 18,740' MD/6053'TVD 0 .0,_- 5-Y2" 15.5 ppf L-80 BTC-Mod Liner Top HRZ Reservoir at+/- (Cemented) 19817' MD/6307'TVD __ 0.7* 44 C) ® I // ..... Base HRZ at+1- _ TD 6-3/4" hole 20364' MD/6437'TVD �--___` : 21993' MD/ K1 Marker at+/- —/ I I / / 6827'TVD 20602' MD/6492'TVD Proposed Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, June 04, 2010 3:23 PM To: 'Robertson, Ryan G' Subject: RE: CD1-15 Plan Forward (PTD 210-047) Ryan, I discussed your plan with Commissioner Seamount and you have verbal approval to proceed as outlined below. In addition, if the circumstances call for an "Operational Shutdown" and moving the rig after abandoning the OH section below the casing point you have verbal approval for that scenario as well. Keep me posted over the weekend.... The abandoned portion of the well below the Whipstock will become CD1-15PB1 and need to be reported with the final 407 well report. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson@conocophillips.com] Sent: Friday, June 04, 2010 2:08 PM To: Schwartz, Guy L (DOA) Subject: CD1-15 Plan Forward Guy, As per our conversation, due to the fact that our directional drillers have been unable to sidetrack out of the existing 9-7/8" hole after a cement plug was set in it, the decision has been made to abandon the remaining 477' MD of 9-7/8" hole and set a whipstock in the casing to start a new sidetrack. Our plan forward will be to run the retainer to a depth of roughly 20,090' MD. This will put the retainer in the first joint of casing above the shoe track, which will allow it a better chance to set above any remaining cement. From that point we will squeeze cement into the remaining open hole to effectively isolate it. We believe there is roughly 70 ft of open hole below the casing shoe at which point we have solid cement. Our plan is to pump approximately 10 bbl of cement to isolate the open hole and shoe track below the retainer. We propose to establish an injection rate with mud below the retainer prior to cementing. If we cannot break down the rock, we would propose to spot 40 ft of cement above the retainer and pull out of the hole. After the cement job, we will run back in the hole and set a whipstock to sidetrack a 6.75"assembly into the open hole. We will then drill the 6.75" production hole to the planned depth of 21,993' MD/6,828' TVD. The attached schematic shows the whipstock exiting the casing at 20,800' MD, however this depth could be as high as 19,700' MD to ensure that we put the exit point in the strongest rock possible to achieve our LOT. Once our final depth is chosen, I will pass along that information. Please let me know if you require any additional information. Ryan UHI!mg Engineer j .onor,()Phillips Alaska Direct (907)265-6181 Mobile (807)980-5107 6/4/2010 Alpine CD1-15 7-5/8" Stage Tool Depths Depths based on actual rig surveys 5/19/2010 Al . 5/19/2010 16"Conductor to 114' EYrp Z(p — 0'41 10-3/4"45.5 ppf L-80 BTC-mod Surface Casing Actual @3,112'MD/2393'TVD • cemented to surface I41Top C10 . , Planned TOC 2,993'TVD(5,682'MD) 5,182'MD TAM Port Collar '1 O 0 3,039'TVD(5,872'MD) r K3 Top Q; e......3,967'TVD(9,839'MD) Planned TOC 761 9,339'MD K3 Basal 4,006'TVD(10,000'MD) :ili.ni:Nii:11:iiiiilliiii:il la `i'' HES Stage Tool 4,022'TVD(10,070'MD) \,TOC 18,723' MD '-5/8"Whipstock Window Exit Depth • 20,080' MD/6,369'TVD Top HRZ 6,307'TVD(19,819'MD) • 6.75"Sidetrack to Planned TD Base HRZ 21,993'MD/6,828'TVD 6,443'TVD(20,390'MD) Cement Ret ner Depth 7-5/8"Casing Shoe 20,090'MD/ ,372'TVD 6,404'TVD(20,223'MD) CD1-15PB1 TD 9-7/8" Hole 6,514'TVD(20,700'MD) sir[T1 i0, A _, Au SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Alaska Drilling Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD 1-15 ConocoPhillips Alaska, Inc. Permit No: 210-047 Surface Location: 1842' FNL, 523' FEL, Sec. 35, T12N, R5E, UM Bottomhole Location: 1606' FNL, 4571' FEL, Sec. 36, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. 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. Sincerely, .0 Daniel T. Seamount, Jr. Chair DATED this/ l day of April, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 13 2010 PERMIT TO DRILL 20 AAC 25.005 Alaska O1I&��( �.Commission 1 a Type of Work: 1 b Proposed Well Class: Development-Oil ❑ Service-Winj El Single Zone E _ 1c.Specify if wel pl is�roposed for Drill 0 . Re-drill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG • 0 Service-Disp ❑ Shale Gas ❑ 2 Operator Name: 5 Bond U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 . CD1-15 3 Address: 6 Proposed Depth 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:21993' TVD: 6828' Colville River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number) Surface:322'FNL,2805'FEL,Sec. 5,T11 N, R5E, UM • ADL 372108,384214- Alpine Oil Pool Top of Productive Honzon. 8 Land Use Permit. 13.Approximate Spud Date' 1842'FNL,523'FEL,Sec.35,T12N, R5E, UM Tobin Nos.932008 and 932082 4/28/2010 Total Depth 9 Acres in Property 14 Distance to Nearest Property 1606'FNL,4571'FEL,Sec.36,T12N, R5E, UM 3200 4,598'from ADL 399455 _ 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL' - 55 8 fee 15.Distance to Nearest Well Open Surface.x- 385901.08 • y- 5975805.8• Zone- 4 GL Elevation above MSL , 19 5 feet to Same Pool: Fiord 3A 3436' 16 Deviated wells: Kickoff depth: 300 • ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle: 79.01° ,deg Downhole:3089 psig • Surface:2406 psig • 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) 24" 16" 62.5# H-40 Welded 77 37 37 114 114 Pre-Installed 13.5" 10 75" 45.5# L-80 BTC-M 3105 37 37 3142 2400 630 sx ASL3,270 sx cl G 9.875" 7.625" 29.7# L-80 BTC-M 20663 37 37 20700 6515 298 sx cl G 6.75" 5.5" 15.5# L-80 BTC-M 1433 20550 6479 21983 6828 Liner /gOs4- d 6' , 3.5" 9.3# L-80 EUE 20528 32 32 . 20560 6479 Tubing Yid,'o i 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrdl and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20 Attachments: Property Plat❑ BOP Sketch ❑ Drilling Program 0 Time v Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 0 21.Verbal Approval Commission Representative. Date: Os22. I hereby certify that the foregoing is true and correct. Contact Nina Anderson @ 265-6403 Printed Name A.cot"._ Chip Alvord Title Alaska Drilling Supervisor Signature Phone Z(,S`_6/2a Date 4(t2(Zo io Commission Use Only Permit to Drill / API Number: /_ ] Permit A royal See cover letter Number: c' 7(.1 50- rtf'� Z� ''I G/�C Date: ��1 I,O for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m ane,gas hydrates,or gas contained in shales ❑/ 4'5. o psi /3Oe /G5 - _ Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No [r Other:125Q0 psi Aemi. ..t (eS/-6. ..)-I2S measures: Yes Q No ❑ Directional svy req'd: Yes u No ❑ u� 20 A.Qc Zs.o36-Ch XL) -/i,r i Ce u.A - - �i ver-fc.�- G/c.,F Gc I+;wi.a.... CD/0e- >Q.•c+K- Li. Acec. .Q ..,,fi4 ii to /2A Ls () RI •PPROVED BY THE COMMISSN l 7 ,Q DATE: 7Th1 U Nf-'1 COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval(20 • . 5.005(g)): ,-j/Submit in Duplicate O CD1-15 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13.5" Hole / 10.75" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots, traveling cylinder diagrams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries 9-7/8" Hole / 7-5/8" Casino" Interval Event Risk Level Mitigation Strategy Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' ND increase mud weight. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density(ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density(ECD) monitoring, weighted sweeps. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700'of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-3/4" Slant Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density(ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7-5/8" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density(ECD) monitoring, weighted sweeps. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 10.5 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers ORIGINAL Procedure 1. Move on Doyon 19. 2. Rig up riser, dewater cellar as needed. 3. Drill 13-1/2"hole to the surface casing point as per the directional plan. (Directional/MWD). 4. Run and cement 10-3/4"surface casing. 5. Install and test BOPE to 3500 psi high and 250 psi low. ' 6. Pick up and run in hole with 9-7/8"drilling BHA. 7. Pressure test casing to 3500 psi. 8. Drill out, shoe track and 20' of new hole. Perform leak off test. • 9. Drill 9-7/8" hole to intermediate casing point below the K1 marker. (LWD Program: GR/RES/PWD/Neut/Dens/Sonic) y 7%t Ra..I c/o f).77 60P 10. Run and cement 7-5/8" casing as per program. Carry out a leak off test down the 10-3/4" x 7-5/8" casing annulus to confirm the fracture pressure referenced to the casing shoe. 11. Freeze protect casing annulus and casing. 12. BOPE test to 3500 psi high and 250 psi low. 13. Pick up 6-3/4"drilling BHA. 14. Pressure test casing to 3,500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 15. Drill 6-3/4"slant production section to well TD (LWD Program: GR/RES/PWD/Neut/Dens/Sonic). 16. Circulate the hole clean and pull out of hole. s S.s'' /(,4M s - 1s#' 66e 17. Run lower completion with 5-1/2" liner, liner top packer, and liner hanger. Cement back to hanger. 18. RIH with slim hole cement mapping tool and evaluate cement. Displace to brine for perforating. em DILL et PE 19. RIH with TCP guns and perforate. 20. Run 3-'/2, 9.3#, L-80 tubing with SSSV, 1 gas lift mandrel, packer, CMU SL, XN nipple and stinger assembly. Sting in, space out and land hanger. 21. Install 2 way check and pressure test hanger seals to 5000 psi. 22. Nipple down BOP. 23. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. 24. Remove 2 way check valve. 25. Circulate tubing to diesel and install freeze protection in the annulus. 26. Drop ball and rod,set packer and test tubing and annulus to 3500 psi/30 mins. 27. Set BPV and secure well. Move rig off. ORIGINAL Well Proximity Risks_: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-14 is the nearest existing well to the CD1-15 plan. Ellipse to ellipse separation is 6.03' at 224' MD. AOR No other wells that exist within a %.mile radius of the planned injection zone on CD1-14wp04. Fiord 3A is the closest well within pool at a distance of 3436'. The Quarter Mile View plot illustrates this and can be found within the Sperry directional plan on pages 29—31. Drilling Area Risks: There are no high-risk events. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD1-15 will be injected into a permitted annulus on CD1 pad or the class I /class II disposal well on CD1 pad. The CD1-15 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000'TVD. The only significant hydrocarbon zone is the Qannik reservoir and there will be 500' of cement fill above the top of the Qannik as per regulations. Once CD1-15 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 would then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing Will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are • part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure= (12.0 ppg) *(0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) *(2400') + 1,500 psi =2997 psi Pore Pressure = 1,081 psi Therefore Differential = 2997— 1081 = 1916 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85%of 85%of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10-3/4" 45.5 L-80 3 BTC-M 2480 2108 psi 5210 psi 4428 psi 7-5/8" 29.7 L-80 3 BTC-M 4790 psi 4071 psi 6890 psi 5856 psi ORIGINAL DRILLING FLUID PROGRAM SPUD to Intermediate hole to Production Hole 10-3/4" surface 7-5/8" casing point— Section—6 3/4" casing point— 13-1/2" 9-7/8" Density 8.8—9.6 ppg 9.6— 10.5 ppg 10.5 ppg PV 10—25 10—15 YP 20—60 15—25 25—30 Funnel Viscosity 100—200 Initial Gels 4—8 10— 15 10 minute gels <18 12 -20 API Filtrate NC— 10 cc/30 min 4— 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5-9.0 9.0- 10.0 9.0-9.5 KCL 6 % Oil/Water Ratio Approx. 80/20 Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Flow line viscosity will be kept at ± 300 sec/qt while drilling gravels. Viscosity prior to cementing will be reduced to ± 80-100 sec/qt. Mud weight will be maintained at< 9.6 ppg by use of solids control system and dilution where necessary. Using cold make up water will help keep the flow line temperature as low as possible. Intermediate Hole Section: A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. Mud weight will be maintained at 9.6— 10 ppg while drilling. Good filter cake quality, hole cleaning, and maintenance of low drill solids (by diluting as required)will all be beneficial in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with an 80/20 oil/water ratio M-I Versa-Pro mineral oil based. drill-in fluid. The base fluid will consist of high flashpoint(>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. The potential for lost circulation exists, particularly after the Alpine reservoir is penetrated. Completion Schematic CD1-15 Alpine "C" Pre-Producer / Injector Completion Sperry Sun 16"Insulated Conductor to CD1-15wp04 v -'114' 4/9/2010 1YYY11 W1 4-'/z'12.6 ppf I--- 11' 80 IBT Mod Tubing �\ X3-1/2"SSSV with 2.813"X Landing Nipple 10 3/4"45.5 ppf L 80 BTCM Surface Casing 3142'MD/2400'TVD 4 Upper Completion: Too MD ND 1) Tubing Hanger 32' 32' 2) 4 /b"12.6#/ft IBT-Mod Tubing(2 jts),XO 3) 3-'/z'9.3#/ft EUE-Mod Tubing 4) Camco TRMAXX-5E SSSV(2.812"ID) 2200' 1915' with control line to surface TOC 3-'/�'9.3#/ft EUE-Mod Tubing +/-9536'MD/ 69751:0)))1 3-'/="Camco MMG-HW GLM(ID=2.915") 15,920' 5394' 3898'TVD 3-'/:"Tubing 9.3#/ft ft -Mod 2 joints Baker"DS"CMU Sliding Sleeve 2.813" 16,000' 5412' 3-'/z'9.3#/ft EUE-Mod Tubing ) HES XN 2.813"(2.75"NoGo) 20,520' 6472' H ES cill K2/Qannik sand ) 3 �'9.3#/ft EUE-Mod Tubing +/-10625' 12) BT Fluted locator,Stinger w/Fluted WLEG 20,560' 6481' +/-10036'MD/ vv-/:Baker GBH-22 Size 80 40 Bonded Seals MD/4153' 4016'TVD Lower ompletion: Too MD TVD TVD Item 13) Baker 5-1/2"x 7-5/8"Flex-lock Liner Hanger 20,550' 6479' with ZXP Liner Top Packer w/Sealbore Extension (Min ID=4.0") 14) 5'/]', 15.5#/ft,L-80 BTC-Mod Liner with Qty 2 Aluminum Slide-On Centralizers (6.375"OD)per joint 15) 5'/:"Float Collar and Shoe BTC-Mod 21983' 6828' Connections Top of cement NOTE:If Premier Packer is run 20180'MD/6392'ND inside tubing vs. liner top packer, 300'above Packer setting depth will be+/-20,480'MD. 0 TOC is planned for this contingency 0� OD • 5-1/ 15.5 ppf L-80 Hydril 511 `' Liner with 6-'/s"OD Centralizers at ��`. each joint connection(Cemented) ine C Sand+/- Al (174,14...._//ft 12 21642'MD/6736'ND �' TD 6 3/4"hole ® i/yiy�', 21993'MD/6828'ND 7 5/8"29.7 ppf L-80 BTC Mod Production Casing @ +/-76° , 20700'MD,6515'ND 4�/ // Perforation Interval TBD ORIGINAL PRESSURE INFORMATION (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (lbs. /gal) (psi) (psi) 16 114/ 114 10.9 52 53 10-3/4" 3142/2400 14.5 1086 1570 7-5/8" 20700/6515 16.0 2948 .2466'2Z 97 _WA 5.5 " 21993/6828 16.0 3089 N/A ..10-7 ;14- • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) -0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052)—0.1] D = [(10.9 x 0.052)—0.1] x 114 = 53 psi OR ASP = FPP—(0.1 x D) = 1086—(0.1 x 2400') = 846 psi 2. Drilling below surface casing (9-5/8") ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1] x 2400 = 1570 psi OR ASP = FPP—(0.1 x D) = 2948—(0.1 x 6515) = 2296 psi 3. Drilling below intermediate casing (7-5/8") ASP= FPP—(0.1 x D) = 3089—(0.1 x 6') = 2406 psi ORIGINAL Cementing Program: 10-3/4" Surface Casing run to 3142' MD /2400' TVD. Cement from 3142' MD to 2642' (500' of fill)with Class G + Adds @ 15.8 PPG, and from 2649'to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost(1743' MD). Lead slurry: (2642-1743') X 0.3637 ft3/ft X 1.5 (50% excess) = 490.5 ft3 below permafrost 1743' X 0.3637 ft3/ft X 3.5 (250% excess) = 2218 ft3 above permafrost Total volume = 490.5 + 2218 = 2709 ft3 => 608 Sx @ 4.45 ft3/sk System: 608 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk Tail slurry: 500' X 0.3637 ft3/ft X 1.5 (50% excess) = 272.8 ft3 annular volume 80' X 0.5397 ft3/ft = 43.2 ft3 shoe joint volume Total volume = 272.8 + 43.2 = 316 ft3 => 270 Sx @ 1.17 ft3/sk System: 270 Sx Class G + 0.2% D046 antifoamer+ 1%S2, 0.2%D46, 0.3%D65 accelerator @ 15.8 PPG yielding 1.16 ft3/sk 7-5/8" Intermediate Casing run to 20,700 MD/6515' TVD First Stage: Cement from 20700' MD to 20180' MD (500' of Class G + adds @ 15.8 PPG and minimum 300' MD above the packer). Assume 40% excess annular volume. Lead: (20700'-20180') X 0.2149 ft3/ft X 1.4 (40% excess) = 156.5 ft3 annular vol. 120' X 0.2577 ft3/ft= 30.9 ft3 shoe joint volume Total volume = 156.5 + 30.9 = 187.42 ft3 => 161 Sx @ 1.16 ft3/sk System: 161 Sx Class G + Class G + 1%S2, 0.2%D46, 0.3%D65 @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a Stage tool set 500' below the K2 interval to +/-500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (10625'-9536') X 0.2149 ft3/ft X 1.4 (40% excess) = 327 ft3 annular vol. Total Volume = 327 ft3=> 282 Sk @ 1.16 ft3/sk System: 282 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.16 ft3/sk 5-1/2" Production Liner run to 21,985 MD/6825' TVD: • Cement from 6-3/4" hole at 21,993' MD to Liner Hanger at 20,550' MD. Lead: (21993' -20400') X 0.0836 ft3/ft X 1.2 (20% excess) = 144.8 ft3 annular vol. Total Volume = 144.8 ft3=> 140 Sk @ 1.16 ft3/sk System: 140 Sx Class G + Class G + 1%S2, 0.2%D46, 0.3%D65 @ 15.8 PPG yielding 1.16 ft3/sk ORIGINAL ConocoPhillips(Alaska) Inc. Western North Slope CD1 Alpine Pad Plan: CD1-15 Plan: CD1-15 Plan: CD1-15wp04 Standard Proposal Report La rge File Do fN O T print 07 April, 2010 Permit Pa cK Added 200' MD of rathole. 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I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 1 1 1 1 1 l l l l l l I I I I l i l l i dUROSU17k L ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) • Project: Western North Slope MD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-15 Design: CD1-15wp04 Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site CD1 Alpine Pad Site Position: Northing: 5,975,904.92ft Latitude: 70°20'34.922 N From: Map Easting: 385,999.99ft Longitude: 150°55'30.868 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.87° Well Plan:CD1-15 Well Position +N/-S 0.00 ft Northing: 5,975,805.80 ft • Latitude: 70°20'33.932 N +EI-W 0.00 ft Easting: 385,901.08 ft . Longitude: 150°55'33.713 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft Wellbore Plan:CD1-15 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2009 4/7/2010 16.64 79.66 57,329 Design CD1-15wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (ft) (ft) (ft) (0) 36.30 0.00 0.00 79.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (0) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 36.30 0.00 0.00 36.30 -19.50 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 194.20 0.00 0.00 0.00 0.00 0.00 0.00 400.04 2.25 0.00 400.00 344.20 2.95 0.00 1.50 1.50 0.00 0.00 650.91 6.92 346.36 650.00 594.20 22.58 -3.57 1.90 1.86 -5.44 -20.00 852.58 8.22 19.13 850.00 794.20 48.02 -1.71 2.20 0.64 16.25 90.00 1,107.81 14.91 38.57 1,100.00 1,044.20 91.00 24.79 3.00 2.62 7.62 40.00 2,975.31 76.45 79.01 2,360.94 2,305.14 496.94 1,195.51 3.50 3.29 2.17 43.93 21,642.37 76.45 79.01 6,735.80 6,680.00 3,956.37 19,009.88 0.00 0.00 0.00 0.00 21,993.03 72.94 79.01 6,828.36 6,772.56 4,020.83 19,341.86 1.00 -1.00 0.00 180.00 4/7/2010 1:32:50PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) ' Project: Western North Slope MD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-15 Design: CD1-15wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) -19.50 36.30 0.00 0.00 36.30 -19.50 0.00 0.00 5,975,805.80 385,901.08 0.00 0.00 100.00 0.00 0.00 100.00 44.20 0.00 0.00 5,975,805.80 385,901.08 0.00 0.00 200.00 0.00 0.00 200.00 144.20 0.00 0.00 5,975,805.80 385,901.08 0.00 0.00 250.00 - 0.00 0.00 250.00 194.20 0.00 0.00 5,975,805.80 385,901.08 0.00 0.00 Start Build 1.50 300.00 0.75 0.00 300.00 244.20 0.33 0.00 5,975,806.13 385,901.09 1.50 0.06 400.00 2.25 0.00 399.96 344.16 2.94 0.00 5,975,808.74 385,901.13 1.50 0.56 400.04 2.25 0.00 400.00 344.20 2.95 0.00 5,975,808.75 385,901.13 1.50 0.56 Start DLS 1.90 TFO-20.00 500.00 4.09 350.85 499.80 444.00 8.43 -0.57 5,975,814.23 385,900.65 1.90 1.05 600.00 5.96 347.40 599.42 543.62 17.02 -2.27 5,975,822.85 385,899.08 1.90 1.02 650.91 6.92 346.36 650.00 594.20 22.58 -3.57 5,975,828.43 385,897.86 1.90 0.81 Start DLS 2.20 TFO 90.00 700.00 7.01 355.25 698.73 642.93 28.44 -4.51 5,975,834.30 385,897.00 2.20 1.00 800.00 7.66 11.79 797.93 742.13 41.04 -3.66 5,975,846.89 385,898.05 2.20 4.24 852.58 8.22 19.13 850.00 794.20 48.02 -1.71 5,975,853.84 385,900.11 2.20 7.49 Start DLS 3.00 TFO 40.00 900.00 9.35 24.77 896.87 841.07 54.72 1.02 5,975,860.50 385,902.93 3.00 11.44 1,000.00 11.95 32.99 995.14 939.34 70.79 10.06 5,975,876.42 385,912.22 3.00 23.38 1,100.00 14.69 38.24 1,092.45 1,036.65 89.43 23.55 5,975,894.86 385,925.99 3.00 40.18 1,107.81 14.91 38.57 1,100.00 1,044.20 91.00 24.79 5,975,896.40 385,927.25 3.00 41.69 Start DLS 3.50 TFO 43.92 1,200.00 17.38 46.08 1,188.55 1,132.75 109.83 42.10 5,975,914.97 385,944.85 3.50 62.29 1,300.00 20.29 52.12 1,283.20 1,227.40 130.84 66.55 5,975,935.60 385,969.61 3.50 90.30 1,400.00 23.36 56.67 1,376.03 1,320.23 152.38 96.81 5,975,956.68 386,000.19 3.50 124.11 1,500.00 26.53 60.20 1,466.70 1,410.90 174.38 132.76 5,975,978.12 386,036.47 3.50 163.59 1,600.00 29.76 63.02 1,554.86 1,499.06 196.74 174.27 5,975,999.85 386,078.31 3.50 208.61 1,601.08 29.80 63.04 1,555.80 1,500.00 196.99 174.75 5,976,000.09 386,078.79 3.50 209.12 Base Permafrost 1,700.00 33.05 65.32 1,640.20 1,584.40 219.40 221.18 5,976,021.79 386,125.56 3.50 258.98 1,800.00 36.37 67.26 1,722.40 1,666.60 242.25 273.33 5,976,043.85 386,178.04 3.50 314.53 1,900.00 39.72 68.90 1,801.13 1,745.33 265.23 330.50 5,976,065.94 386,235.56 3.50 375.04 2,000.00 43.09 70.33 1,876.13 1,820.33 288.23 392.50 5,976,088.00 386,297.89 3.50 440.29 2,100.00 46.48 71.59 1,947.09 1,891.29 311.18 459.09 5,976,109.93 386,364.82 3.50 510.03 2,200.00 49.88 72.72 2,013.76 1,957.96 333.99 530.03 5,976,131.66 386,436.09 3.50 584.02 2,300.00 53.29 73.74 2,075.89 2,020.09 356.58 605.03 5,976,153.10 386,511.42 3.50 661.96 2,400.00 56.70 74.67 2,133.25 2,077.45 378.85 683.84 5,976,174.17 386,590.55 3.50 743.57 2,500.00 60.12 75.53 2,185.63 2,129.83 400.74 766.15 5,976,194.80 386,673.18 3.50 828.54 2,600.00 63.55 76.34 2,232.82 2,177.02 422.15 851.66 5,976,214.90 386,759.00 3.50 916.56 2,700.00 66.98 77.10 2,274.65 2,218.85 443.01 940.04 5,976,234.41 386,847.68 3.50 1,007.30 2,800.00 70.42 77.82 2,310.97 2,255.17 463.23 1,030.98 5,976,253.25 386,938.90 3.50 1,100.42 2,900.00 73.86 78.51 2,341.64 2,285.84 482.75 1,124.12 5,976,271.34 387,032.32 3.50 1,195.58 2,975.28 76.45 79.01 2,360.93 2,305.13 496.93 1,195.48 5,976,284.44 387,103.89 3.50 1,268.33 Start 18667.05 hold at 2975.28 MD 1 2,975.31 76.45 79.01 2,360.94 2,305.14 496.94 1,195.51 5,976,284.44 387,103.91 3.50 1,268.36 4/7/2010 1:32.50PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-15 Design: CD1-15wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,310.93 3,000.00 76.45 79.01 2,366.73 2,310.93 501.51 1,219.07 5,976,288.66 387,127.54 0.00 1,292.37 3,060.05 76.45 79.01 2,380.80 2,325.00 512.64 1,276.38 5,976,298.91 387,185.01 0.00 1,350.74 C-30 3,100.00 76.45 79.01 2,390.16 2,334.36 520.04 1,314.50 5,976,305.73 387,223.24 0.00 1,389.58 3,141.97 76.45 79.01 2,400.00 2,344.20 527.82 1,354.56 5,976,312.90 387,263.41 0.00 1,430.39 10-3/4"x 13-1/2" 3,200.00 76.45 79.01 2,413.60 2,357.80 538.58 1,409.94 5,976,322.81 387,318.93 0.00 1,486.80 3,300.00 76.45 79.01 2,437.04 2,381.24 557.11 1,505.37 5,976,339.89 387,414.63 0.00 1,584.01 3,400.00 76.45 79.01 2,460.47 2,404.67 575.64 1,600.80 5,976,356.96 387,510.32 0.00 1,681.23 3,500.00 76.45 79.01 2,483.91 2,428.11 594.17 1,696.23 5,976,374.04 387,606.02 0.00 1,778.44 3,600.00 76.45 79.01 2,507.34 2,451.54 612.71 1,791.67 5,976,391.12 387,701.71 0.00 1,875.66 3,700.00 76.45 79.01 2,530.78 2,474.98 631.24 1,887.10 5,976,408.19 387,797.41 0.00 1,972.87 3,800.00 76.45 79.01 2,554.22 2,498.42 649.77 1,982.53 5,976,425.27 387,893.10 0.00 2,070.09 3,900.00 76.45 79.01 2,577.65 2,521.85 668.30 2,077.96 5,976,442.34 387,988.80 0.00 2,167.30 4,000.00 76.45 79.01 2,601.09 2,545.29 686.83 2,173.39 5,976,459.42 388,084.49 0.00 2,264.52 4,100.00 76.45 79.01 2,624.53 2,568.73 705.37 2,268.83 5,976,476.50 388,180.19 0.00 2,361.73 4,200.00 76.45 79.01 2,647.96 2,592.16 723.90 2,364.26 5,976,493.57 388,275.88 0.00 2,458.95 4,300.00 76.45 79.01 2,671.40 2,615.60 742.43 2,459.69 5,976,510.65 388,371.58 0.00 2,556.16 4,400.00 76.45 79.01 2,694.83 2,639.03 760.96 2,555.12 5,976,527.73 388,467.27 0.00 2,653.38 4,500.00 76.45 79.01 2,718.27 2,662.47 779.50 2,650.55 5,976,544.80 388,562.97 0.00 2,750.59 4,600.00 76.45 79.01 2,741.71 2,685.91 798.03 2,745.99 5,976,561.88 388,658.66 0.00 2,847.81 4,660.13 76.45 79.01 2,755.80 2,700.00 809.17 2,803.37 5,976,572.15 388,716.21 0.00 2,906.27 C-20 4,700.00 76.45 79.01 2,765.14 2,709.34 816.56 2,841.42 5,976,578.95 388,754.36 0.00 2,945.02 4,800.00 76.45 79.01 2,788.58 2,732.78 835.09 2,936.85 5,976,596.03 388,850.05 0.00 3,042.24 4,900.00 76.45 79.01 2,812.02 2,756.22 853.63 3,032.28 5,976,613.11 388,945.75 0.00 3,139.45 5,000.00 76.45 79.01 2,835.45 2,779.65 872.16 3,127.72 5,976,630.18 389,041.44 0.00 3,236.67 5,100.00 76.45 79.01 2,858.89 2,803.09 890.69 3,223.15 5,976,647.26 389,137.14 0.00 3,333.88 5,200.00 76.45 79.01 2,882.32 2,826.52 909.22 3,318.58 5,976,664.33 389,232.83 0.00 3,431.10 5,300.00 76.45 79.01 2,905.76 2,849.96 927.75 3,414.01 5,976,681.41 389,328.53 0.00 3,528.31 5,400.00 76.45 79.01 2,929.20 2,873.40 946.29 3,509.44 5,976,698.49 389,424.22 0.00 3,625.53 5,500.00 76.45 79.01 2,952.63 2,896.83 964.82 3,604.88 5,976,715.56 389,519.92 0.00 3,722.74 5,600.00 76.45 79.01 2,976.07 2,920.27 983.35 3,700.31 5,976,732.64 389,615.61 0.00 3,819.96 5,700.00 76.45 79.01 2,999.51 2,943.71 1,001.88 3,795.74 5,976,749.72 389,711.31 0.00 3,917.17 5,800.00 76.45 79.01 3,022.94 2,967.14 1,020.42 3,891.17 5,976,766.79 389,807.00 0.00 4,014.39 5,900.00 76.45 79.01 3,046.38 2,990.58 1,038.95 3,986.60 5,976,783.87 389,902.70 0.00 4,111.60 6,000.00 76.45 79.01 3,069.81 3,014.01 1,057.48 4,082.04 5,976,800.94 389,998.39 0.00 4,208.82 6,100.00 76.45 79.01 3,093.25 3,037.45 1,076.01 4,177.47 5,976,818.02 390,094.09 0.00 4,306.03 6,200.00 76.45 79.01 3,116.69 3,060.89 1,094.55 4,272.90 5,976,835.10 390,189.78 0.00 4,403.24 6,300.00 76.45 79.01 3,140.12 3,084.32 1,113.08 4,368.33 5,976,852.17 390,285.48 0.00 4,500.46 6,400.00 76.45 79.01 3,163.56 3,107.76 1,131.61 4,463.77 5,976,869.25 390,381.17 0.00 4,597.67 6,500.00 76.45 79.01 3,187.00 3,131.20 1,150.14 4,559.20 5,976,886.32 390,476.87 0.00 4,694.89 6,600.00 76.45 79.01 3,210.43 3,154.63 1,168.67 4,654.63 5,976,903.40 390,572.56 0.00 4,792.10 6,700.00 76.45 79.01 3,233.87 3,178.07 1,187.21 4,750.06 5,976,920.48 390,668.26 0.00 4,889.32 6,800.00 76.45 79.01 3,257.30 3,201.50 1,205.74 4,845.49 5,976,937.55 390,763.95 0.00 4,986.53 4/7/2010 1:32:50PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips '' i 4...,i Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-15 Design: CD1-15wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,224.94 6,900.00 76.45 79.01 3,280.74 3,224.94 1,224.27 4,940.93 5,976,954.63 390,859.65 0.00 5,083.75 II 7,000.00 76.45 79.01 3,304.18 3,248.38 1,242.80 5,036.36 5,976,971.71 390,955.34 0.00 5,180.96 7,100.00 76.45 79.01 3,327.61 3,271.81 1,261.34 5,131.79 5,976,988.78 391,051.04 0.00 5,278.18 7,200.00 76.45 79.01 3,351.05 3,295.25 1,279.87 5,227.22 5,977,005.86 391,146.73 0.00 5,375.39 7,300.00 76.45 79.01 3,374.49 3,318.69 1,298.40 5,322.65 5,977,022.93 391,242.43 0.00 5,472.61 7,400.00 76.45 79.01 3,397.92 3,342.12 1,316.93 5,418.09 5,977,040.01 391,338.12 0.00 5,569.82 7,500.00 76.45 79.01 3,421.36 3,365.56 1,335.46 5,513.52 5,977,057.09 391,433.82 0.00 5,667.04 7,600.00 76.45 79.01 3,444.79 3,388.99 1,354.00 5,608.95 5,977,074.16 391,529.51 0.00 5,764.25 7,700.00 76.45 79.01 3,468.23 3,412.43 1,372.53 5,704.38 5,977,091.24 391,625.21 0.00 5,861.47 7,800.00 76.45 79.01 3,491.67 3,435.87 1,391.06 5,799.82 5,977,108.32 391,720.90 0.00 5,958.68 7,900.00 76.45 79.01 3,515.10 3,459.30 1,409.59 5,895.25 5,977,125.39 391,816.60 0.00 6,055.90 8,000.00 76.45 79.01 3,538.54 3,482.74 1,428.13 5,990.68 5,977,142.47 391,912.29 0.00 6,153.11 8,100.00 76.45 79.01 3,561.98 3,506.18 1,446.66 6,086.11 5,977,159.54 392,007.99 0.00 6,250.33 8,200.00 76.45 79.01 3,585.41 3,529.61 1,465.19 6,181.54 5,977,176.62 392,103.68 0.00 6,347.54 8,300.00 76.45 79.01 3,608.85 3,553.05 1,483.72 6,276.98 5,977,193.70 392,199.38 0.00 6,444.76 8,400.00 76.45 79.01 3,632.28 3,576.48 1,502.26 6,372.41 5,977,210.77 392,295.07 0.00 6,541.97 8,500.00 76.45 79.01 3,655.72 3,599.92 1,520.79 6,467.84 5,977,227.85 392,390.77 0.00 6,639.19 8,600.00 76.45 79.01 3,679.16 3,623.36 1,539.32 6,563.27 5,977,244.92 392,486.46 0.00 6,736.40 8,700.00 76.45 79.01 3,702.59 3,646.79 1,557.85 6,658.71 5,977,262.00 392,582.16 0.00 6,833.62 8,800.00 76.45 79.01 3,726.03 3,670.23 1,576.38 6,754.14 5,977,279.08 392,677.85 0.00 6,930.83 8,900.00 76.45 79.01 3,749.47 3,693.67 1,594.92 6,849.57 5,977,296.15 392,773.55 0.00 7,028.05 9,000.00 76.45 79.01 3,772.90 3,717.10 1,613.45 6,945.00 5,977,313.23 392,869.24 0.00 7,125.26 9,055.03 76.45 79.01 3,785.80 3,730.00 1,623.65 6,997.52 5,977,322.63 392,921.91 0.00 7,178.76 K-3 Marker 1 9,100.00 76.45 79.01 3,796.34 3,740.54 1,631.98 7,040.43 5,977,330.31 392,964.94 0.00 7,222.48 9,200.00 76.45 79.01 3,819.77 3,763.97 1,650.51 7,135.87 5,977,347.38 393,060.63 0.00 7,319.69 9,300.00 76.45 79.01 3,843.21 3,787.41 1,669.05 7,231.30 5,977,364.46 393,156.33 0.00 7,416.91 9,400.00 76.45 79.01 3,866.65 3,810.85 1,687.58 7,326.73 5,977,381.53 393,252.02 0.00 7,514.12 9,500.00 76.45 79.01 3,890.08 3,834.28 1,706.11 7,422.16 5,977,398.61 393,347.72 0.00 7,611.34 9,600.00 76.45 79.01 3,913.52 3,857.72 1,724.64 7,517.59 5,977,415.69 393,443.41 0.00 7,708.55 9,700.00 76.45 79.01 3,936.96 3,881.16 1,743.17 7,613.03 5,977,432.76 393,539.11 0.00 7,805.77 9,800.00 76.45 79.01 3,960.39 3,904.59 1,761.71 7,708.46 5,977,449.84 393,634.80 0.00 7,902.98 9,852.94 76.45 79.01 3,972.80 3,917.00 1,771.52 7,758.98 5,977,458.88 393,685.47 0.00 7,954.45 Basal K-3 9,900.00 76.45 79.01 3,983.83 3,928.03 1,780.24 7,803.89 5,977,466.92 393,730.50 0.00 8,000.20 1 10,000.00 76.45 79.01 4,007.26 3,951.46 1,798.77 7,899.32 5,977,483.99 393,826.19 0.00 8,097.41 10,036.42 76.45 79.01 4,015.80 3,960.00 1,805.52 7,934.08 5,977,490.21 393,861.04 0.00 8,132.82 K-2 Marker 10,100.00 76.45 79.01 4,030.70 3,974.90 1,817.30 7,994.76 5,977,501.07 393,921.89 0.00 8,194.63 10,200.00 76.45 79.01 4,054.14 3,998.34 1,835.84 8,090.19 5,977,518.14 394,017.58 0.00 8,291.84 10,300.00 76.45 79.01 4,077.57 4,021.77 1,854.37 8,185.62 5,977,535.22 394,113.28 0.00 8,389.06 10,400.00 76.45 79.01 4,101.01 4,045.21 1,872.90 8,281.05 5,977,552.30 394,208.97 0.00 8,486.27 10,500.00 76.45 79.01 4,124.45 4,068.65 1,891.43 8,376.48 5,977,569.37 394,304.67 0.00 8,583.49 10,600.00 76.45 79.01 4,147.88 4,092.08 1,909.97 8,471.92 5,977,586.45 394,400.36 0.00 8,680.70 4!7/2010 1.32:50PM Page 5 COMPASS 2003.16 Build 69 ORGlN !+ ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-15 Design: CD1-15wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 4,100.00 10,633.78 76.45 79.01 4,155.80 4,100.00 1,916.23 8,504.16 5,977,592.22 394,432.69 0.00 8,713.54 Basal K-2 10,700.00 76.45 79.01 4,171.32 4,115.52 1,928.50 8,567.35 5,977,603.52 394,496.06 0.00 8,777.92 10,800.00 76.45 79.01 4,194.75 4,138.95 1,947.03 8,662.78 5,977,620.60 394,591.75 0.00 8,875.13 10,900.00 76.45 79.01 4,218.19 4,162.39 1,965.56 8,758.21 5,977,637.68 394,687.45 0.00 8,972.35 11,000.00 76.45 79.01 4,241.63 4,185.83 1,984.09 8,853.64 5,977,654.75 394,783.14 0.00 9,069.56 11,100.00 76.45 79.01 4,265.06 4,209.26 2,002.63 8,949.08 5,977,671.83 394,878.84 0.00 9,166.78 11,200.00 76.45 79.01 4,288.50 4,232.70 2,021.16 9,044.51 5,977,688.91 394,974.53 0.00 9,263.99 11,300.00 76.45 79.01 4,311.94 4,256.14 2,039.69 9,139.94 5,977,705.98 395,070.23 0.00 9,361.21 11,400.00 76.45 79.01 4,335.37 4,279.57 2,058.22 9,235.37 5,977,723.06 395,165.92 0.00 9,458.42 11,500.00 76.45 79.01 4,358.81 4,303.01 2,076.76 9,330.81 5,977,740.13 395,261.62 0.00 9,555.64 11,600.00 76.45 79.01 4,382.25 4,326.45 2,095.29 9,426.24 5,977,757.21 395,357.31 0.00 9,652.85 11,700.00 76.45 79.01 4,405.68 4,349.88 2,113.82 9,521.67 5,977,774.29 395,453.01 0.00 9,750.07 11,800.00 76.45 79.01 4,429.12 4,373.32 2,132.35 9,617.10 5,977,791.36 395,548.70 0.00 9,847.28 11,900.00 76.45 79.01 4,452.55 4,396.75 2,150.89 9,712.53 5,977,808.44 395,644.40 0.00 9,944.50 12,000.00 76.45 79.01 4,475.99 4,420.19 2,169.42 9,807.97 5,977,825.51 395,740.09 0.00 10,041.71 12,100.00 76.45 79.01 4,499.43 4,443.63 2,187.95 9,903.40 5,977,842.59 395,835.79 0.00 10,138.93 12,200.00 76.45 79.01 4,522.86 4,467.06 2,206.48 9,998.83 5,977,859.67 395,931.48 0.00 10,236.14 12,300.00 76.45 79.01 4,546.30 4,490.50 2,225.01 10,094.26 5,977,876.74 396,027.18 0.00 10,333.36 12,400.00 76.45 79.01 4,569.74 4,513.94 2,243.55 10,189.69 5,977,893.82 396,122.87 0.00 10,430.57 12,500.00 76.45 79.01 4,593.17 4,537.37 2,262.08 10,285.13 5,977,910.90 396,218.57 0.00 10,527.79 12,600.00 76.45 79.01 4,616.61 4,560.81 2,280.61 10,380.56 5,977,927.97 396,314.26 0.00 10,625.00 12,700.00 76.45 79.01 4,640.04 4,584.24 2,299.14 10,475.99 5,977,945.05 396,409.96 0.00 10,722.21 12,800.00 76.45 79.01 4,663.48 4,607.68 2,317.68 10,571.42 5,977,962.12 396,505.65 0.00 10,819.43 12,900.00 76.45 79.01 4,686.92 4,631.12 2,336.21 10,666.86 5,977,979.20 396,601.35 0.00 10,916.64 13,000.00 76.45 79.01 4,710.35 4,654.55 2,354.74 10,762.29 5,977,996.28 396,697.04 0.00 11,013.86 I 13,100.00 76.45 79.01 4,733.79 4,677.99 2,373.27 10,857.72 5,978,013.35 396,792.74 0.00 11,111.07 I 13,200.00 76.45 79.01 4,757.23 4,701.43 2,391.80 10,953.15 5,978,030.43 396,888.43 0.00 11,208.29 13,300.00 76.45 79.01 4,780.66 4,724.86 2,410.34 11,048.58 5,978,047.51 396,984.13 0.00 11,305.50 13,400.00 76.45 79.01 4,804.10 4,748.30 2,428.87 11,144.02 5,978,064.58 397,079.82 0.00 11,402.72 13,500.00 76.45 79.01 4,827.53 4,771.73 2,447.40 11,239.45 5,978,081.66 397,175.52 0.00 11,499.93 13,600.00 76.45 79.01 4,850.97 4,795.17 2,465.93 11,334.88 5,978,098.73 397,271.21 0.00 11,597.15 13,700.00 76.45 79.01 4,874.41 4,818.61 2,484.47 11,430.31 5,978,115.81 397,366.91 0.00 11,694.36 13,800.00 76.45 79.01 4,897.84 4,842.04 2,503.00 11,525.74 5,978,132.89 397,462.60 0.00 11,791.58 13,900.00 76.45 79.01 4,921.28 4,865.48 2,521.53 11,621.18 5,978,149.96 397,558.30 0.00 11,888.79 14,000.00 76.45 79.01 4,944.72 4,888.92 2,540.06 11,716.61 5,978,167.04 397,653.99 0.00 11,986.01 14,100.00 76.45 79.01 4,968.15 4,912.35 2,558.60 11,812.04 5,978,184.11 397,749.69 0.00 12,083.22 14,200.00 76.45 79.01 4,991.59 4,935.79 2,577.13 11,907.47 5,978,201.19 397,845.38 0.00 12,180.44 14,300.00 76.45 79.01 5,015.02 4,959.22 2,595.66 12,002.91 5,978,218.27 397,941.08 0.00 12,277.65 14,400.00 76.45 79.01 5,038.46 4,982.66 2,614.19 12,098.34 5,978,235.34 398,036.77 0.00 12,374.87 14,500.00 76.45 79.01 5,061.90 5,006.10 2,632.72 12,193.77 5,978,252.42 398,132.47 0.00 12,472.08 14,600.00 76.45 79.01 5,085.33 5,029.53 2,651.26 12,289.20 5,978,269.50 398,228.16 0.00 12,569.30 14,700.00 76.45 79.01 5,108.77 5,052.97 2,669.79 12,384.63 5,978,286.57 398,323.86 0.00 12,666.51 14,800.00 76.45 79.01 5,132.21 5,076.41 2,688.32 12,480.07 5,978,303.65 398,419.55 0.00 12,763.73 14,900.00 76.45 79.01 5,155.64 5,099.84 2,706.85 12,575.50 5,978,320.72 398,515.25 0.00 12,860.94 4/7/2010 1:32:50PM Page 6 COMPASS 2003.16 Build 69 ORIGIN!. L ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-15 Design: CD1-15wp04 1 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) C) (ft) ft (ft) (ft) (ft) (ft) 5,123.28 15,000.00 76.45 79.01 5,179.08 5,123.28 2,725.39 12,670.93 5,978,337.80 398,610.94 0.00 12,958.16 15,100.00 76.45 79.01 5,202.51 5,146.71 2,743.92 12,766.36 5,978,354.88 398,706.64 0.00 13,055.37 15,200.00 76.45 79.01 5,225.95 5,170.15 2,762.45 12,861.80 5,978,371.95 398,802.33 0.00 13,152.59 15,300.00 76.45 79.01 5,249.39 5,193.59 2,780.98 12,957.23 5,978,389.03 398,898.03 0.00 13,249.80 15,400.00 76.45 79.01 5,272.82 5,217.02 2,799.51 13,052.66 5,978,406.10 398,993.72 0.00 13,347.02 15,500.00 76.45 79.01 5,296.26 5,240.46 2,818.05 13,148.09 5,978,423.18 399,089.42 0.00 13,444.23 15,600.00 76.45 79.01 5,319.70 5,263.90 2,836.58 13,243.52 5,978,440.26 399,185.11 0.00 13,541.45 15,700.00 76.45 79.01 5,343.13 5,287.33 2,855.11 13,338.96 5,978,457.33 399,280.81 0.00 13,638.66 15,800.00 76.45 79.01 5,366.57 5,310.77 2,873.64 13,434.39 5,978,474.41 399,376.50 0.00 13,735.88 15,900.00 76.45 79.01 5,390.00 5,334.20 2,892.18 13,529.82 5,978,491.49 399,472.20 0.00 13,833.09 16,000.00 76.45 79.01 5,413.44 5,357.64 2,910.71 13,625.25 5,978,508.56 399,567.89 0.00 13,930.31 16,100.00 76.45 79.01 5,436.88 5,381.08 2,929.24 13,720.68 5,978,525.64 399,663.59 0.00 14,027.52 16,200.00 76.45 79.01 5,460.31 5,404.51 2,947.77 13,816.12 5,978,542.71 399,759.28 0.00 14,124.74 16,300.00 76.45 79.01 5,483.75 5,427.95 2,966.31 13,911.55 5,978,559.79 399,854.98 0.00 14,221.95 16,400.00 76.45 79.01 5,507.19 5,451.39 2,984.84 14,006.98 5,978,576.87 399,950.67 0.00 14,319.17 16,500.00 76.45 79.01 5,530.62 5,474.82 3,003.37 14,102.41 5,978,593.94 400,046.37 0.00 14,416.38 16,600.00 76.45 79.01 5,554.06 5,498.26 3,021.90 14,197.85 5,978,611.02 400,142.06 0.00 14,513.60 16,700.00 76.45 79.01 5,577.49 5,521.69 3,040.43 14,293.28 5,978,628.10 400,237.76 0.00 14,610.81 16,800.00 76.45 79.01 5,600.93 5,545.13 3,058.97 14,388.71 5,978,645.17 400,333.45 0.00 14,708.03 16,900.00 76.45 79.01 5,624.37 5,568.57 3,077.50 14,484.14 5,978,662.25 400,429.15 0.00 14,805.24 17,000.00 76.45 79.01 5,647.80 5,592.00 3,096.03 14,579.57 5,978,679.32 400,524.84 0.00 14,902.46 17,100.00 76.45 79.01 5,671.24 5,615.44 3,114.56 14,675.01 5,978,696.40 400,620.54 0.00 14,999.67 17,200.00 76.45 79.01 5,694.68 5,638.88 3,133.10 14,770.44 5,978,713.48 400,716.23 0.00 15,096.89 17,300.00 76.45 79.01 5,718.11 5,662.31 3,151.63 14,865.87 5,978,730.55 400,811.93 0.00 15,194.10 17,400.00 76.45 79.01 5,741.55 5,685.75 3,170.16 14,961.30 5,978,747.63 400,907.62 0.00 15,291.32 17,500.00 76.45 79.01 5,764.98 5,709.18 3,188.69 15,056.73 5,978,764.70 401,003.32 0.00 15,388.53 17,600.00 76.45 79.01 5,788.42 5,732.62 3,207.23 15,152.17 5,978,781.78 401,099.01 0.00 15,485.75 17,700.00 76.45 79.01 5,811.86 5,756.06 3,225.76 15,247.60 5,978,798.86 401,194.71 0.00 15,582.96 17,800.00 76.45 79.01 5,835.29 5,779.49 3,244.29 15,343.03 5,978,815.93 401,290.40 0.00 15,680.18 17,900.00 76.45 79.01 5,858.73 5,802.93 3,262.82 15,438.46 5,978,833.01 401,386.10 0.00 15,777.39 18,000.00 76.45 79.01 5,882.17 5,826.37 3,281.35 15,533.90 5,978,850.09 401,481.79 0.00 15,874.61 18,058.18 76.45 79.01 5,895.80 5,840.00 3,292.14 15,589.41 5,978,860.02 401,537.47 0.00 15,931.16 Albian 97 18,100.00 76.45 79.01 5,905.60 5,849.80 3,299.89 15,629.33 5,978,867.16 401,577.49 0.00 15,971.82 18,200.00 76.45 79.01 5,929.04 5,873.24 3,318.42 15,724.76 5,978,884.24 401,673.18 0.00 16,069.04 18,300.00 76.45 79.01 5,952.47 5,896.67 3,336.95 15,820.19 5,978,901.31 401,768.88 0.00 16,166.25 18,400.00 76.45 79.01 5,975.91 5,920.11 3,355.48 15,915.62 5,978,918.39 401,864.57 0.00 16,263.47 18,500.00 76.45 79.01 5,999.35 5,943.55 3,374.02 16,011.06 5,978,935.47 401,960.27 0.00 16,360.68 18,600.00 76.45 79.01 6,022.78 5,966.98 3,392.55 16,106.49 5,978,952.54 402,055.96 0.00 16,457.90 18,700.00 76.45 79.01 6,046.22 5,990.42 3,411.08 16,201.92 5,978,969.62 402,151.66 0.00 16,555.11 18,800.00 76.45 79.01 6,069.66 6,013.86 3,429.61 16,297.35 5,978,986.70 402,247.35 0.00 16,652.33 18,900.00 76.45 79.01 6,093.09 6,037.29 3,448.14 16,392.78 5,979,003.77 402,343.05 0.00 16,749.54 19,000.00 76.45 79.01 6,116.53 6,060.73 3,466.68 16,488.22 5,979,020.85 402,438.74 0.00 16,846.76 19,082.23 76.45 79.01 6,135.80 6,080.00 3,481.92 16,566.69 5,979,034.89 402,517.43 0.00 16,926.69 Albian 96 4/7/2010 1.32:50PM Page 7 COMPASS 2003.16 Build 69 I i ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-15 Design: CD1-15wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) 6,084.16 19,100.00 76.45 79.01 6,139.96 6,084.16 3,485.21 16,583.65 5,979,037.92 402,534.44 0.00 16,943.97 19,200.00 76.45 79.01 6,163.40 6,107.60 3,503.74 16,679.08 5,979,055.00 402,630.13 0.00 17,041.19 19,300.00 76.45 79.01 6,186.84 6,131.04 3,522.27 16,774.51 5,979,072.08 402,725.83 0.00 17,138.40 19,400.00 76.45 79.01 6,210.27 6,154.47 3,540.81 16,869.95 5,979,089.15 402,821.52 0.00 17,235.61 19,500.00 76.45 79.01 6,233.71 6,177.91 3,559.34 16,965.38 5,979,106.23 402,917.22 0.00 17,332.83 19,600.00 76.45 79.01 6,257.15 6,201.35 3,577.87 17,060.81 5,979,123.30 403,012.91 0.00 17,430.04 19,700.00 76.45 79.01 6,280.58 6,224.78 3,596.40 17,156.24 5,979,140.38 403,108.61 0.00 17,527.26 19,800.00 76.45 79.01 6,304.02 6,248.22 3,614.94 17,251.67 5,979,157.46 403,204.30 0.00 17,624.47 19,871.60 76.45 79.01 6,320.80 6,265.00 3,628.21 17,320.01 5,979,169.68 403,272.83 0.00 17,694.09 HRZ 19,900.00 76.45 79.01 6,327.45 6,271.65 3,633.47 17,347.11 5,979,174.53 403,300.00 0.00 17,721.69 20,000.00 76.45 79.01 6,350.89 6,295.09 3,652.00 17,442.54 5,979,191.61 403,395.69 0.00 17,818.90 20,100.00 76.45 79.01 6,374.33 6,318.53 3,670.53 17,537.97 5,979,208.69 403,491.39 0.00 17,916.12 20,200.00 76.45 79.01 6,397.76 6,341.96 3,689.06 17,633.40 5,979,225.76 403,587.08 0.00 18,013.33 20,300.00 76.45 79.01 6,421.20 6,365.40 3,707.60 17,728.84 5,979,242.84 403,682.78 0.00 18,110.55 20,400.00 76.45 79.01 6,444.64 6,388.84 3,726.13 17,824.27 5,979,259.91 403,778.48 0.00 18,207.76 20,426.30 76.45 79.01 6,450.80 6,395.00 3,731.00 17,849.37 5,979,264.41 403,803.64 0.00 18,233.33 Base HRZ 20,500.00 76.45 79.01 6,468.07 6,412.27 3,744.66 17,919.70 5,979,276.99 403,874.17 0.00 18,304.98 20,600.00 76.45 79.01 6,491.51 6,435.71 3,763.19 18,015.13 5,979,294.07 403,969.87 0.00 18,402.19 20,660.98 76.45 79.01 6,505.80 6,450.00 3,774.49 18,073.33 5,979,304.48 404,028.22 0.00 18,461.48 K-1 Marker 20,700.00 76.45 79.01 6,514.94 6,459.14 3,781.73 18,110.56 5,979,311.14 404,065.56 0.00 18,499.41 7-5/8"X 9-7/8" 20,800.00 76.45 79.01 6,538.38 6,482.58 3,800.26 18,206.00 5,979,328.22 404,161.26 0.00 18,596.62 20,900.00 76.45 79.01 6,561.82 6,506.02 3,818.79 18,301.43 5,979,345.29 404,256.95 0.00 18,693.84 21,000.00 76.45 79.01 6,585.25 6,529.45 3,837.32 18,396.86 5,979,362.37 404,352.65 0.00 18,791.05 21,053.53 76.45 79.01 6,597.80 6,542.00 3,847.24 18,447.95 5,979,371.51 404,403.87 0.00 18,843.10 Kuparuk C 21,066.33 76.45 79.01 6,600.80 6,545.00 3,849.62 18,460.16 5,979,373.70 404,416.12 0.00 18,855.54 LCU-Miluveach 21,100.00 76.45 79.01 6,608.69 6,552.89 3,855.85 18,492.29 5,979,379.45 404,448.34 0.00 18,888.27 21,200.00 76.45 79.01 6,632.13 6,576.33 3,874.39 18,587.72 5,979,396.52 404,544.04 0.00 18,985.48 21,300.00 76.45 79.01 6,655.56 6,599.76 3,892.92 18,683.16 5,979,413.60 404,639.73 0.00 19,082.70 21,400.00 76.45 79.01 6,679.00 6,623.20 3,911.45 18,778.59 5,979,430.68 404,735.43 0.00 19,179.91 21,500.00 76.45 79.01 6,702.43 6,646.63 3,929.98 18,874.02 5,979,447.75 404,831.12 0.00 19,277.13 21,578.36 76.45 79.01 6,720.80 6,665.00 3,944.51 18,948.80 5,979,461.13 404,906.11 0.00 19,353.31 Alpine D 21,600.00 76.45 79.01 6,725.87 6,670.07 3,948.52 18,969.45 5,979,464.83 404,926.82 0.00 19,374.34 21,642.33 76.45 79.01 6,735.79 6,679.99 3,956.36 19,009.85 5,979,472.06 404,967.32 0.00 19,415.50 Start DLS 1.00 TFO 180.00 21,642.37 76.45 79.01 6,735.80 6,680.00 3,956.37 19,009.88 5,979,472.06 404,967.36 0.00 19,415.53 Alpine C-CD1-15wp03 T1 21,700.00 75.87 79.01 6,749.59 6,693.79 3,967.04 19,064.82 5,979 481.89 405,022.44 1.00 19,471.49 4/7/2010 1:32:50PM Page 8 COMPASS 2003.16 Build 69 1 G 1 NA L , ii ConocoPhillips LI B V RTO Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-15 Design: CD1-15wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,710.00 21,764.94 75.22 79.01 6,765.80 6,710.00 3,979.02 19,126.55 5,979,492.94 405,084.35 1.00 19,534.38 UJU 21,800.00 74.87 79.01 6,774.85 6,719.05 3,985.48 19,159.80 5,979,498.89 405,117.69 1.00 19,568.25 21,900.00 73.87 79.01 6,801.79 6,745.99 4,003.84 19,254.33 5,979,515.80 405,212.48 1.00 19,664.55 21,993.00 72.94 79.01 6,828.35 6,772.55 4,020.83 19,341.82 5,979,531.46 405,300.21 1.00 19,753.67 TD at 21993.00-4-1/2"x 6-3/4" 21,993.03 72.94 79.01 6,828.36 6,772.56 4,020.83 19,341.86 5,979,531.46 405,300.24 1.00 19,753.70 riargets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting ' -Shape (°) (0) (ft) (ft) (ft) (ft) (ft) CD1-15wp03 T1 Circle 0.00 0.00 6,735.80 3,956.37 19,009.88 5,979,472.06 404,967.36 -plan hits target center -Circle(radius 1,320.00) CD1-15wp03 Ti 0.00 0.00 6,735.80 3,956.37 19,009.88 5,979,472.06 404,967.36 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,141.97 2,400.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 I 20,700.00 6,514.94 7-5/8"X 9-7/8" 7-5/8 9-7/8 21,993.00 6,828.35 4-1/2"x 6-3/4" 4-1/2 6-3/4 4/7/2010 1:32:50PM Page 9 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan:CD1-15(36.3+19.5)@ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-15 Design: CD1-15wp04 Formations I Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 9,852.94 3,972.80 Basal K-3 4,660.13 2,755.80 C-20 21,642.37 6,735.80 Alpine C 21,578.36 6,720.80 Alpine D 19,082.23 6,135.80 Albian 96 21,764.94 6,765.80 UJU 18,058.18 5,895.80 Albian 97 10,036.42 4,015.80 K-2 Marker 21,066.33 6,600.80 LCU-Miluveach 1,601.08 1,555.80 Base Permafrost 21,053.53 6,597.80 Kuparuk C 3,060.05 2,380.80 C-30 20,660.98 6,505.80 K-1 Marker 10,633.78 4,155.80 Basal K-2 19,871.60 6,320.80 HRZ 20,426.30 6,450.80 Base HRZ 9,055.03 3,785.80 K-3 Marker Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 250.00 250.00 0.00 0.00 Start Build 1.50 400.04 400.00 2.95 0.00 Start DLS 1.90 TFO-20.00 650.91 650.00 22.58 -3.57 Start DLS 2.20 TFO 90.00 852.58 850.00 48.02 -1.71 Start DLS 3.00 TFO 40.00 1,107.81 1,100.00 91.00 24.79 Start DLS 3.50 TFO 43.92 2,975.28 2,360.93 496.93 1,195.48 Start 18667.05 hold at 2975.28 MD 21,642.33 6,735.79 3,956.36 19,009.85 Start DLS 1.00 TFO 180.00 21,993.00 6,828.35 4,020.83 19,341.82 TD at 21993.00 417/2010 1:32:50PM Page 10 COMPASS 2003.16 Build 69 ORIGINAL N m Q U L I"' m I N a� c J M FL _! 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N . r - N U �� 41..m.., o M (.0 - 0a V M Awa — — c.",CA 'C — a� '° aZ-. 3� o O.�a — 0 =+d+0 - V? .:E y v - — v o — c _ o - I I I , I I I I , I I I A , I , 1 I I I I 1 I I I I 1 I I I I I I I I I I I I , , I , , , , I I I I I I I I I I I I I I I I I I I I I I I I I 1 (um;00S£) 6ui4poN ORIGINAL HALLIBURTON ConocoPhilllips CD1 Sperry Drilling ANTI-COLLISION SETTINGS 15:07,April 062010 Interpolation Method: MD, interval:25.00 Major Risk Depth Range From: 36.30 To 21993.00 Results Limited By: Centre Distance:2395.67 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1000.00 CD1-15wp04(Plan: CD1-15) CB-GYRO-SS 1000.00 21993.00 CD1-15wp04(Plan: CD1-15) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2400.00 3142.04 10-3/4"x 13-1/2" 10-3/4 6514.95 20700.00 7-5/8"X 9-7/8" 7-5/8 6828.36 21993.00 4-1/2"x 6-3/4" 4-1/2 Im •,,-._. m Ft `0. :i a o.< 0® ®o (o)) o 'o S a ® fNU UVU COU V V V - -....■.y/.>!I1��,I��i ' ,p V 110 /t1 �� 1 / / o 110 ;100 lir \ I IF / T i 1 1 a GI/ 53 :::::::: lliI4 , 2IlII1 Ir I'' Z - -"MIMI "0'14 ' il 2 .4, limilildillh Apr. ,,, - :dil Aro 0 I 1 I 1 1 I 1 I I I I I 1 1 I i 1 I I I I I I I I I I I 1 I I 1 I I I , , I I i 0 450 900 1350 1800 2250 2700 3150 Measured Depth LEGEND - CD1-01,CD1-01,CD1-01 V1 -0- CD1-11,CD1-11,CD1-11 V3 -,- CD1-22,CD1-22,CD1-22 V6 -B- CD131,CD131,CD1-31 V6 -X- CD1-01,CD1-01PB1,CD1-01PB1 V1 CD1-12,CD1-12,CD1-12 V5 -X- CD1-22,CD1-22A,CD1-22A V6 -e- CD131,CD131 CAZ,CD1-31 CAZ V1 CD1-02,CD1-02,CD1-02 V2 -i-- CD1-12,CD1-12L1,CD1-12L1 V2 -e- CD1-22,Ran:CD1-22B,CD1-22Bwp02 VO -I- CD1-31,C0131 IIFR,CD1-31 IIFR V1 CD1-03.C01-03,CD1-03 V1 -e- 0)1-13,CD1-13,CD1-13 V1 -9- CD1-229(aka NO1),CD1-229,CD1-229 V1 CD132,CD1-32,CD1-32 V1 ▪ CD1-04,CD1-04,CD1-04 V1 -A- CD1-14,CD1-14,CD1-14 V1 --e- CD1-229(aka NC11),CD1-229PB1,CD1-229P8. 4- CD1-32,CD1-32PB1,CD1-32PB1 V3 -B- CD1-05,CD1-05,C01-05 V1 --1- CO1-14,CD1-14PB1,CD1-14PB1 V5 -e- CD1-229(aka NO1),Plan:CD1-29,CD1-29wp01E0- CD1-33,CD1-33,CD1-33 V1 - CD1-05,CD1-05PB1,CD1-05PB1 V1 -X- CD1-16,CD1-16,CD1-16 V1 --8- CD1-23,CD1-23,CD1-23 V3 $- CD1-34,CD1-34,CD1-34 V1 -e- CD1-06,CD1-06,CD1-06 V1 -0- CD1-16,CD1-16PB1,CD1-16PB1 V1 -9- CD1-24,CD1-24,CD1-24 V4 -9- CD1-35,CD1-35,CD1-35 V1 -8- CD1-06,CD1-06PB1,CD1-06PB1 V1 -9- CD1-17,CD1-17,CD1-17 V2 -e- CD1-25,CD1-25,CD1-25 V1 CD1-36,001-36,CD1-36 V1 - CD1-07,CD1-07,CD1-07 V26 $- CD1-18,CD1-18,CD1-18 V2 -X- CD1-26,CD1-26,CD1-26 V1 -A- CD1-36,CD1-36PB1,CD1-36PB1 V1 --X- CD1-07,CD1-07PB1,CD1-07PB1 V26 - CD1.19,CD1-19,CD1-19 V2 $- CD1-26,CD1-26PB1,CD1-26PB1 V1 -jam CD1-37,CD1-37,CD1-37 V5 - CD1-07,CD1-07PB2,CD1-07PB2 V25 -A- CO1-19,C01-19A,CD1-19A V4 -X- CD1-27,CD1-27.CD1-27 V1 -X- C01-39,CD1-39,CD1-39 V1 ▪ CD1-08,CD1-08,CD1-08 V4 -0.- C01-20,CD1-20,CD1-20 V2 CD1-28,CD1-28,C01-28 V1 -0- CD1-39,CD1-39PB1,CD1-39PB1 V1 -A- CD1-09,CD1-09,CD1-09 V2 -0- CD1-21,CD1-21,CD1-21 V1 -0- C01-28,CD1-28PB1,CD1-28PB1 V1 $ Plan:CD1-50,Ran:C01-50,CD1-50wp01 VO - CD1-09,CD1-09PB1,CD1-09PB1 V1 -X- CD1-21,CD1-21L1,CD1-21L1 V1 -e- CD1-30,CD1-30,CD1-30 V1 -9- CD1-15wp04 -A- CD1-10,CD1-10,CD1-10 V1 -6- CD1-21,CD1-21PB1,CD1-21PB1 V1 --8_ CD1-30,CD1-30PB1,CD1-30PB1 V1 GINAL O N i- M p SL m C a. ~ 0 f00 � -.,�,�14-, N s1.. 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NN WN § N n J 2 0 2 ,E m f Q orr iO Jo§ 7''' a IT ^ l a aS O O0 5o o 6 Eo O tt -. o t2 m U a E j o o E n N 1-0, , o E 0 ���gfQ •c I-. 1 O •=c, LL g 1 0 m 4 m g 1 O C ',U > jN. r6� 3 0O)O rj '+ 0 co ▪ R FL n aa ✓ , A v , A v , a $ 6. 3 p Q in 3 p_ O 3 .{{ N + + mS N -7- + rn G c.(-) +' + m A 6 a z w 6 ¢ Z w in ") cS ¢ z w "' r Er § 7 N V m r- `° V w ) `° V m I- O 0 0 0 w z 1- a 3 i :2 d• .E Q 0- Q d - Q Lo tz- (0 L g o L N r N r A ✓ t s u u u co As co O 0 0 L L L a a O. IA W N g co 51 ' g O y g c_ O T) m M O Ti ` O O Ti c n v A A in V A c M U Ao 3 lD U A o E E E U) a ORIGINAL.... ConocoPhillips Alaska, Inc. NOV' Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 April 12, 2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-15 APR 2010 -Alaska oil Dear Sir or Madam: Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the CD1 drilling pad. The intended spud date for this well is 04/28/2010. It is intended that Doyon Rig 19 be used to drill the well. The intermediate section of CD1-15 will be drilled and landed below the K-1 marker which is above the Alpine C sand. 7-5/8" casing will be run and cemented in place. The production section will be drilled to penetrate the reservoir as a slant well and completed with a cemented liner. At the end of the rig program, the well will be flowed back for 2-3 days to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities connection that will allow the well to begin injection. Once drilled, the K2 (Qannik) sand will be reviewed to determine if it's a significant hydrocarbon bearing zone. After running 7-5/8" casing, the plan forward would be to pump lead cement, open the stage tool, and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. ' At CD1, there has not been a significant show of shallow gas or gas hydrates through the - surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program. 3. A proposed completion diagram. 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Riser setup If you have any questions or require further information, please contact Nina Anderson, 265-6403, or Chip Alvord at 265-6120. Sincerely, Svc Nina Anders n Drilling Engineer Attachments cc: CD1-15 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1570 Ryan Robertson ATO 1702 Tim Schnieder ATO 1768 Lanston Chin Kuukpik Corporation ___„..... _ ,.7., io,..._----"eHi.ti. .• —5-e--/ .... _ _ ------ -- F" CJI CA I ;.. CFI I ...•.- cr ,- .11,1 1Lf o I 47" . 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TRANSMITTAL LETTER TCHECKLIST WELL NAME PTD# C� Development `' Service Exploratory Stratigraphic Test Non-Conventional/ Well / FIELD: ( G) ( (, /-e ,�/G �� POOL: �7 [(/�fti�_ 0T( ��J I 1/ 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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