Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
209-156
RECEIVED JUN 262015 STATE OF ALASKA OGCC ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil L f Gas ❑ SPLUG ❑ Other 7 Abandoned ❑ Suspended❑ lb.Well Class: 20AAc 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ _J WINJ L WAG ❑ WDSPL ❑ No.of Completions: Service ❑✓ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: Caelus Natural Resources Alaska, LLC Aband.: I/3o11 5 3i ' eL'3s 209-156 • 3.Address: 7.Date Spudded: 15.API Number: 3700 Centerpoint Drive,Suite 500,Anchorage,AK 99503 12/10/2009 50-703-20605-01-00 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 2912' FSL, 1154' FEL, Sec. 11,T13N, R7E, UM 12/24/2009 ODSK-42Ai . Top of Productive Interval: 9.KB(ft above MSL): 56.2 17.Field/Pool(s): 3294' FSL, 4103' FEL, Sec. 13,T13N, R7E, UM GL(ft above MSL): 13.5 Oooguruk-Kuparuk Oil Pool ' Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation: 2519' FSL, 3785' FEL, Sec. 13 ,T13N, R7E, UM 3239'MD/2952'TVD ADL 355036 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 469,844.38 y- 6,031,028.13 Zone- ASP-4 9758'MD/6672'TVD 417497 TPI: x- 472,158.87 y- 6,026,121.75 Zone- ASP-4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 472,474.47 y- 6,025,345.33 Zone- ASP-4 745'MD/745'TVD 1,107'MD/815'TVD 5.Directional or Inclination Survey: Yes (❑✓ ched) No ❑ 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 3,179'MD/2918'TVD 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 No logs run in addition to those already submitted. 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 100.2# X-65 Surface 158' Surface 158' 24" Driven 10-3/4" 45.5# L-80 BTC Surface 3289' Surface 2980' 13-1/2" 458 sx PF'L';201 sx Class'G' 7-5/8" 29.7# L-80 BTC-M Surface 8654' Surface 5963' 9-7/8" 164 sx Class'G' 4-1/2" 12.6# L-80 Hyd 8521' 9753' 5884' 6668' 6-3/4" 259 sx Class'G' 521 24.Open to production or injection? Yes L No 7 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation Size SIZE DEPTH SET(MD) PACKER SET(MD/TVD) and Number): `��� 3-1/2",9.3#,L-80 TSHP 8538' UltraPak TH Pkr @ 8300'MD TA`�L"-'�^_c /5761'TVD;Liner Top Pkr @ ..f....- 8537'MD/5893'TVD t - 115 0 I-- 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes L J No L✓J ,' 'Ma?: Per 20 AAC 25.283(i)(2)attach electronic and printed information 1. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Ste© JUL 2 8 2015 2000' Freeze Protect w/80 bbls diesel 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate l-"/S.'-1S A2N ?I // RBDMS JUL - 1 2015 /�/ `" Form 10-407 Revised 5/2015 ILA '- CONTINUED ON PAGE 2 Submit ORIGINIAL ly 28.CORE DATA Conventional Core(s): Yes ❑ No ❑ Sidewall Cores: Yes ❑ No L If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No [E Permafrost-Top 838' 838' If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1677' 1668' Attach separate pages to this form, if needed,and submit detailed test information, including reports, per 20 AAC 25.071. Top West Sak 2376' 2320' Tuffaceous Shale 3194' 2927' Top Torok 7028' 5058' Top HRZ 8232' 5732' Base HRZ 8453' 5854' None Top Kuparuk 8740' 6009' LCU 8753' 6016' BCU 9092' 6214' Top Nuiqsut 9224' 6298' Base Nuiqsut 9301' 6349' Top Nechelik 9315' 6358' Base Nechelik . 9594' 6550' Formation at Total Depth 9758' 6672' 31. List of Attachments: Summary or daily operations,well schematic diagram, Definitive survey(s), casing cementing reports 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 .regoing is true and correct to the best of my knowledge. Contact: Kimberl -ape Email: kimberly.pape@caelusenergy.com Printed Name: Kim.-rI --.e Title: Engineering Analyst Signature. i Phone: 343-2130 Date: lQ/pyQ//s� INSTRUCTIONS General: This for - . the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram Item la: Multiple :• pletion is defined as a well producing from more than one pool with production from each pool completely segregated. Each Item 1b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Item 4b: TPI (Top of Producing Interval). Item 9: 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 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, 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 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 Fnrm 10-407 Revised S/2015 Submit ORIGINAL Only ...y AF rift Alaska Oil and Gas a`��11%%0 THE STATE o f A T As� Conservation Commission `y,.t xL 333 West Seventh Avenue ittit + � Anchorage,Alaska 99501-3572 � w` GOVERNOR BILL WALKER g Main:907.279.1433 °f r Fax:907.276.7542 www.aogcc.alaska.gov Alex Vaughan Sr. Drilling Engineer Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive, Suite 500 Anchorage,AK 99503 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK-42A Sundry Number: 314-635 Dear Mr. Vaughan: 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, PAg'1 /''2 --. David J.Mayberry Commissioner DATED this Int 'day of December, 2014. Encl. . RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ' ( 2 2014 APPLICATION FOR SUNDRY APPROVALS 4 20 AAC 25.280 / --ui'& 1— 1 JC, 1.Type of Request: Abandon L' Plug for Redrill DI Perforate New Pool 0 Repair Well❑ Chang Approved Program 0 Suspend 0 Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 Alter Casing 0 Other. ❑ 2.Operator Name- 4.Current Well Class: 5.Permit to Drill Number. Caelus Natural Resources Alaska,LLC Exploratory ❑ Development E 209-156 3.Address: Stratigraphic ❑ Service E=16.API Number. 3700 Centerpoint Drive,Anchorage,AK 99503 50-703-20605-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? tij Will planned perforations require a spacing exception? Yes ❑ No 0 ODSK-42Ai 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036 Oooguruk-Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9758' 6672' 9751' 6666' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3251' 10-3/4" 3289' 2980' 5210 2470 Intermediate 8616' 7-5/8" 8654' 5963' 6890 4790 Production Liner 1232' 4-1/2" 8521'-9753' 5884'-6668' 8430 7500 Perforation Depth MD(ft). Perforation Depth ND(ft)• Tubing Size: 'Tubing Grade: Tubing MD(ft): 8736'-8756' 6004'-6015' 3-1/2",9.3# L-80,TSHP 8538' Packers and SSSV Type: Wellstar TRSV;WFT UltraPak-TH Pkr, Packers and SSSV MD(ft)and ND(ft): 745'MD/745'TVD;8300'MD/ TSP Liner Top Pkr 5761'TVD;8357'MD/5899TVD 12.Attachments: Description Summary of Proposal ❑' 13.Well Class after proposed work: Detailed Operations Program D BOP Sketch ❑ -Exploratory ❑ Stratigraphic❑ Development U Service 0 14.Estimated Date for 15.Well Status after proposed work: jill Commencing Operations: 1/9/2015 Oil 0 Gas ❑ WDSPL ❑ Suspended 1_1_1 16.Verbal Approval: Date: !WINJ 0 GINJ 0 WAG 0 Abandoned L 1 Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact Kimberty Pape Email kimberly.Daaeta'�.caelusenergy.com Printed Name Alex Vaughan Title Snr Drilling Engineer Signature Phone 907-343-2188 Date 12/2/2014 -40'/ 41ti 4 ZZtilh v, /aX)/// COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3kK` -G2..b5 Plug Integrity 0 BOP Test V nMechanical Integrity Test 0 Location Clearance ❑ Other: 4( LI C0 p5.. /��f' /;-:f C /Yt,4S/9 = Z.S$, p.r Alfe..r"i2� pLa P i�c_�r..,_� cyr ro.,.S i.... 2� 4,46_ mss. ///b._� Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: 1 ©— 4/07 ( APPROVED BY Approved by:420----- COMMISSIONER THE COMMISSION Date:IM I //11 Submit Form and Form 10-403(Revised 10/2012) )rtjdfifu( 4ciTI Ellonths from the date of approval. Attachments in Duplicate ODSK-42Ai Final P&A Well Completion Schematic Final 6-25-2015 ...• .• ,,,„• 16"Conductor Whipstock Set t‘ Top @3,179'MD Bottom @ 3,199'MD — Surface Casing 1 '/4" EZ-Drill _ 10-3/4"45.5#L-80 BTC 0 °@ Cement Retainer top 3,289'MD/2,980'TVD set @ 3,239'MD 7-5/8"29.7#L-80 BTC-M V 27.23 bbls of Premium G Casing Stub Cut Cement pumped below @ 3,289'MD Cement Retainer Cement bottom•-3,525'MD 9-7/8" Open Hole in 9-7/8"Open Hole 11.07 bbls of Premium G Cement pumped on top of Y 7-5/8"EZ-Drill Bridge Plug Bridge plug top 1t Cement top-5,210'MD @ 5,534'MD 3-1/2"Tubing Stub @ 5,537'MD 3-1/2"x 7-5/8" Permanent is 25 bbls of Class G Production Packer Cement pumped in 1232' ✓ @ 8,300'MD of 4-'/z" 12.6#Lower Completion Section plus 721'of 3-% 9.2#Upper Completion Cut Section 7-5/8"29.7#L-80 BTC-M •••• • : @ 8,654'MD/5,964'TVD A Perforated Interval '-- _ --- 8,736'MD-8,756' MD -- _? eo, -7 Production 6-3/4" Hole TD at 9,758'MD/6,673'TVD Operations Summary Report - State Well Name: ODSN-42B CC- AEUJS Alaska Well Name: ODSN-42B Contractor: Expro Rig Number: 1 Job Category: MAINTENANCE Start Date: 1/7/2015 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 1/7/2015 1/8/2015 0.0 Pump cement abandonment of the 4-1/2"12.6#L-80 Hyd 521 lower wellbore *Pump 10 bbls of Tuned Spacer III at 10.59 ppg *Pump 25 bbls of Class G cement at 15.93 ppg *Pump 10 bbls spacer at 11 ppg *Pump 47.4 bbls of LVT displacement at 6.59 ppg *RDMO HES cement hardline and all associated equipment. *JOB COMPLETE. 1/17/2015 1/18/2015 0.0 0000 hrs 1/17/15-0000 hrs 1/18/15 *Pressure tested cement plug to 3500 DSL far 80 min-charted. 1/22/2015 1/23/2015 0 0 00:00 hrs 1/2215-00:00 hrs 1/23/15 MIRU HES Eline w/full PCE to jet cut 3.5 9.2#L-80 TC-Il tubing on Nabors 19 AC. 1/23/2015 1/24/2015 0.0 00:00 hrs 1/23/15-00:00 hrs 1/24/15 *HES Eline drifted w/2.74"gauge ring to 5657'ELM. *Correlate CCL to collar on tubing joint#93 @ 5541.8'elm. *Pressured tubing up to 400 psi. *Eline cut 3.5 9.2#L-80 TSHP tubing @ 5536.6'elm(5'above collar on tbg jt#93). *Good indication of cut,tubing pressure fell from 400 psi to 200 psi. *Circulate down tubing taking returns up IA to Operations flowback tanks. *RDMO HES Eline Report Printed: 6/26/2015 Operations Summary Report- State Well Name: ODSN-42B Ca CAUL S Ataska Well Name: ODSN-42B Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: ORIG DRILLING Start Date: 1/22/2015 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 1/22/2015 1/23/2015 0.0 8.40 Rig accepted on ODSN-42B at 00:01 on 22 January 2015. Install Back Pressure Valve in 3.5" tubing hanger. Nipple down production tree. Nipple up Vetco Gray riser&BOP stack. Install test joint and R/U test equipment. Test BOPE as per AOGCC&PTD: -Test upper and lower VBR w/3.5"test joint to 250 psi low/4500 psi high. c -Test upper and lower IBOP valves to 250 psi low/4500 psi high. AAo --Upper IBOP failed initial test,was changed out&re-tested good. D(� -Test annular w/3.5"test joint to 250 psi low/2500 psi high. -Test all floor valves to 250 psi low/4500 psi high. -Test 14 choke manifold valves to 250 psi low/4500 psi high. -All tests charted and all tests held for 5 min. -All tests performed with fresh water. -Initial system psi:3000, 1950 after closure;200 psi=38 sec,full pressure 1 min.57 sec. -AOGCC initially notified of test requirement @ 07:51 hrs on 21 January 2015. ***AOGCC Rep.Chuck Scheve witnessed BOP tests on 22 January 2015.*** R/D test equipment&L/D test joint. Install 3-1/2"landing joint. R/U Halliburton e-line w/ lubricator. 1/23/2015 1/24/2015 0.0 8.40 Attempt to pressure test lubricator. Water test fluid flash froze in head catcher. UD lubricator& thaw head catcher. R/U Little Red Services,M/U lubricator&pressure test E-line pressure control equipment to 1400 PSI w/diesel. RIH w/Halliburton E-line 2.74"gauge ring. Tag cement stringer @ 5635'then work down to 5641'. POOH,UD gauge ring&M/U Jet Cutter. RIH&cut 3.5"tubing @ 5536.5'. POOH&L/D E-line Jet Cutter assembly. Establish circulation through tubing cut w/125 GPM. R/D E-line equipment. Pump 62 bbl BaraScrub pill,then circulate surface to surface to displace IA freeze protect fluid w/8.4 ppg seawater. R/D landing joint,pump in sub&FOSV. Pressure test 3-1/2"x 7-5/8"casing to 3500 psi for 30 min.&chart same through kill line against blind rams. R/U casing equipment&control line de-spooler. Unseat 3-1/2"casing hanger&pull to the rig floor. Terminate control lines&L/D hanger. 1/24/2015 1/25/2015 3,199.0 0.00 8.40 M/U XO to safety valve&test to 250 psi low/4500 psi high. POOH w/3-1/2"9.3#TSHP L-80 tubing f/5493'U surface. Flush BOP stack&install 4"test joint. -Test upper&lower 2-7/8"x 5"VBR against 4"test joint. -Test TIW floor safety valve. /L -All tests performed to 250 psi low/4500 Dsi high. -Hold tests for 5 min.and chart same. -All tests performed w/8.4 ppg seawater. R/D test equipment&pull test plug. Slip&cut drilling line. M/U BHA#1,Baker cleanout BHA,f/ surface to 38'. TIH w/BHA#1 f/38'U 4179'. 1/25/2015 1/26/2015 3,199.0 0.00 8.40 RIH w/BHA#1 f/4179'U 5544'&tag 3-1/2"tubing stub w/15K down weight. Circulate 2x bottoms up. POOH f/5544'U surface&UD BHA#1. M/U BHA#2,Halliburton 7-5/8"EZ-Drill Bridge Plug. TIH w/BHA#2 f/surface U 5537'. Set the 7-5/8"EZ-Drill Bridge Plug w/top of plug @ 5534'. Shear free @ 167K PUW,47K overpull. Pressure test 7-5/8"casing against bridge plug&upper pipe rams to 3500 PSI,hold for 5 min.&chart same. Pump 11.07 bbls 15.8 ppg✓ ettvt. Premium G cement balanced plug(60 sks,1.17 ft^3/sk yield)@ 170 GPM,2 P Displace Q from cement unit w/8.4 ppg seawater @ 170 GPM,200 PSI. 53 bbls total displacement pumped w/cement in place @ 14:00. POOH cement f/5537'U 5210'. Pump 5"drill pipe wiper ball& circulate drill pipe clean. No cement observed at surface. POOH&UD Halliburton running tool. M/U BHA#3,Baker 7-5/8"Mechanical Cutter&TIH U 3289'. Cut 7-5/8"29.7#L-80 BTC casing irk 3289'. Circulate freeze protect out of OA wl 8.4 ppg seawater,165 bbls total seawater pumped. POOH w/BHA#3 f/3289'U surface&UD BHA. Begin to change upper rams to 7- 5/8". '8 .3L Page 1/7 Report Printed: 6/26/2015 • Operations Summary Report- State Well Name: ODSN-42B Cai CAEUJ S Frc,r.cy Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 1/26/2015 1/27/2015 3,199.0 8.40 Remove 2-7/8"V 3&instal.?5L6"gam in upper,ram pnsitinn Test 7-5/8"rams against 7-5/8" ~test joint to 250 PSI low/4500 PSI high. Each test held for 5 min.&charted. Test performed w/ seawater. M/U 7-5/8"spear&engage 7-5/8"casing below casing hanger. Pull hanger free, monitor well for 15 min.then pull hanger to the rig floor. Circulate 60 bbl BaraScrub pill surface to surface. R/U casing equipment. Release spear&L/D same. L/D 7-5/8"29.7#L-80 BTC casing f/3289'U surface. R/D casing equipment. Change upper rams to 2-7/8"x5"VBR. Change top drive IBOP f/4"XT39 U 4-1/2"IF. Install test plug&5"test joint. M/U 5"dart safety valve&floor safety valve. -Test upper&lower 2-7/8"x5"VBR against 5"test joint. -Test 5"dart safety valve&floor safety valve. -All tests performed to 250 PSI low/4500 PSI high. -All test performed w/8.4 ppg seawater. -All tests held for 5 min.&charted. M/U BHA#4,Baker 10-3/4"casing scraper assembly U 720'. TIH f/720'U 1670'w/5"drill pipe singles from the pipe shed. 1/27/2015 1/28/2015 3,199.0 8.40 Single in the hole w/BHA#5,10-3/4"casing scraper,f/1670'U 3289'&tag 7-5/8"cut casing stub @ 3289'. POOH f/3289'&UD BHA#5. M/U BHA#6,Halliburton 10-3/4"EZ-Drill Cement Retainer,&single in the hole w/5"drill pipe U 3241'. Circulate setting point clean&set 10-3/4" EZ-Drill Cement Retainer w/top of retainer @ 3239'. Shear free,rotate to extend stinger& circulate 2x bottoms up. Sting into cement retainer&perform injectivity test. Inject 12 bbls @ 3 BPM until pressure broke over @ 1040 PSI. Unsting from retainer&prepare for cement job. Pump 10 bbls 8.4 ppg seawater from cement unit,then pressure test lines to 3500 psi. Mix& pump 27,23_Ws 15.66 DM Premium G cement(144 sks,1.17 ft43_yield)at 2 BPM,915 PSI 4! initial&750 PSI final. Displace w/29 bbls 7.4 ppg seawater f/cement unit @ 2.75 BPM,515 PSI. Maintain 1000 PSI back pressure with manual choke valve. Sting into cement retainer& squeeze 30 bbls of 15.8 ppg cement below cement retainer @ 3 BPM,950 PSI initial,1225 PSI end. Slow to 1 BPM,1075 PSI for last 5 bbls. Cement in place @ 20:35. Unsting from retainer, monitor well static&R/D cement equipment. Circulate surface to surface to clear drill pipe. POOH&UD cement retainer. 1/28/2015 1/29/2015 3,179.0 48.00 9.85 RIH w/60 joints of drill pipe,pump to flush&POOH racking back in the derrick. M/U BHA#6, Baker 10-3/4"whipstock assembly&TIH U 3210'. Orient whipstock @ 30°right toolface. Set anchor,pull 10K to verify set,then set down 55K to shear free. Displace wellbore from 8.4 ppg seawater to 9.8 ppg LSND. Mill window in 10-3/4"45.5#L-80 BTC casing f/3179'U 3199'. Dril _ formation w/mills f/3199'U 3227'. Wdr�c`mT s roug wI .•'. • •• .. •.w. -ump sweep& circulate hole clean. Pull into casing&attempt to perform a FIT,but formation broke down. LOT @ 3179'MD/2918'TVD w/9.8 ppg LSND,665 psi=14.12 ppg EMW. ***28'of new formation was drilled,so will now revert to a 14 day drilling BOP test schedule.*** 1/29/2015 1/30/2015 3,227.0 93.00 9.80 POOH f/3150'U 363'&UD BHA#6 from 363'. Perform weekly function test of BOP equipment &flush stack of any residual metal cuttings from window milling. M/U BHA#7,Sperry motor kick -off assembly U 565'. TIH WI BHA#7 f/565'U 3129'. Orient motor across whipstock&through window. Wash under gauge hole U 3207'U 3227'. Drill 9-7/8"intermediate hole f/3227'U 3320'. 1/30/2015 1/31/2015 3,320.0 379.00 9.80 Drill 9-7/8"Intermediate#1 hole f/3320'U 3699'. Circulate hole clean w/4 bottoms up. Trip f/ 3699'U 3129'. Circulate 10-3/4"clean w/6.5x bottoms up. POOH w/BHA#7 f/3129'U 565'. Rack back&L/D BHA#7 f/565'U surface. Test BOPE as per AOGCC&PTD: -Test upper and lower VBR w/5"test joint to 250 psi low/4500 psi high. -Test upper and lower IBOP valves to 250 psi low/4500 psi high. -Test annular w/5"test joint to 250 psi low/2500 psi high. -Test all floor valves to 250 psi low/4500 psi high. -Test 15 choke manifold valves to 250 psi low/4500 psi high. -All tests charted and all tests held for 5 min. -All tests performed with 8.4ppg seawater. -Initial system psi:3000,2000 after closure;200 psi=30 sec,full pressure 1 min.59 sec. -AOGCC initially notified of test requirement @ 06:57 hrs on 28 January 2015. ***AOGCC Rep.Bob Noble waived witness of BOP tests©07:42 on 28 January 2015.*** Pull test plug&5"test joint. Clean clay from trip nipple in preparation for testing MPD equipment. Page 2/7 Report Printed: 6/26/2015 . . HALL 1 B U R TO 1•1 iCem' Service CAELUS ENERGY ALASKA LLC 16 Ca 3700 Centerpoint Dr. Anchorage, AK 99503 000gU ru k ODSN-42b Abandonment Squeeze/Plug Post Job Report For: Alex Vaughan Date: February 5, 2015 ODSN-42b Oooguruk Island Sales Order: 902073511 Sincerely, Jared Miller Legai Notice v�'.'•3'i"ilii D i �i rr. r Although the information contained in this report is based on sound engineering practices,the copyright owner(s)does(do)not accept any responsibility whatsoever,in negligence or otherwise,for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise.The application,therefore,by the user of this report or any part thereof,is solely at the user's own risk. Except as expressly set forth herein,there are no representations or warranties by Halliburton,express or implied,including implied warranties of merchantability and/or fitness for a particular purpose.In no event will Halliburton or its suppliers be liable for consequential,incidental,special,punitive or exemplary damages(including,without limitation,loss of data,profits,use of hardware, or software).Customer accepts full responsibility for any investment made based on results from the Software.Any interpretations, analyses or modeling of any data,including,but not limited to Customer data,and any recommendation or decisions based upon such interpretations,analyses or modeling are opinions based upon inferences from measurements and empirical relationships and assumptions,which inferences and assumptions are not infallible,and with respect to which professional may differ.Accordingly, Halliburton cannot and does not warrant the accuracy,correctness or completeness of any such interpretation,recommendation, modeling or other products of the Software Product.As such,any interpretation,recommendation or modeling resulting from the Software for the purpose of any drilling,well treatment,production or financial decision will be at the sole risk of Customer.Under no circumstances will Halliburton or its suppliers be liable for any damages. HALLIBURTON Table of Contents I 0 Ex='c}.Jnn,..e Sumniarj 4 De =gin 5 2.1 Customer Information 5 2.2 Well Conditions 5 IU.. . _."11i, 6 3.1 Job Event Log 6 3 2 Stage Summary—Cementing Unit 7 3.3 Stage Summary—Rig Floor 7 3.4 Volume Summary 7 . i0o17. S, 4.1 Volume Calculations 8 5.1 Cement Unit—Job Graph 9 52 CementUnit—WaterAhead 10 5.3 Cement Unit—Pressure Test 11 5.4 Cement Unit—Primary Cement 12 5.5 Cement Unit—Water Behind to Spot Cement 13 5.6 Cement Unit—Water Behind to Place Cement 14 5.7 Rig Floor—Job Graph 15 5.8 Rig Floor—Seawater Ahead 16 5.9 Rig Floor—Pressure Test 17 510 Rig Floor—Cement 18 5 11 Rig Floor—Water Behind to Spot Cement 19 5.12 Water Behind to Place Cement 20 6.1 Data Listing—Cement Unit 21 6.2 Data Listing—Rig Floor 24 7.1 Primary Cement 27 HALLIBURTON CAELUS ENERGY ALASKA LLC ODSN-42b Abandonment Squeeze/Plug 1 0 Executive Summary Alex Vaughan Caelus Energy Alaska LLC Anchorage,AK Mr.Vaughan, Halliburton appreciates the opportunity to perform the cementing services on the Oooguruk project.A pre-job safety meeting was held where details of the job were discussed,potential safety hazards were reviewed,and environmental compliance procedures were outlined. On January 26`h,2015 the existing 7.625"casing on ODSN-42b was cut and pulled in preparation for the abandonment squeeze/plug,the previous well name was ODSK-42i.A total of 78 full joints and a partial joint measuring 28.49'were pulled from the well.The cut according to the casing tally and cut joint length was at 3,285'. After cutting and pulling the casing, BHA#4 a Baker 10.75"casing scraper was installed and tripped in hole with 5" drill pipe to a depth of 3,289'.The BHA was pulled out of hole and BHA#5 a Halliburton EZ-Drill Cement Retainer was made up and tripped in hole. Once the cement retainer was at set depth 10 bbl @ 125 gpm seawater was circulated to clear the set point.The cement retainer was set at bottom depth of 3,242',with the top of the retainer at 3,239'. The retainer was set by rotating it 38 turns to the right,shearing from the retainer was accomplished by increasing the pull in 12K increments until it sheared at 167K,53K over pickup weight.The drill string was pulled up 15'and rotated 15 turns to the right to extend the stinger.Two bottoms were circulated at 525 gpm and then the stinger was stung into the cement retainer for an injectivity test.A total of 12 bbl seawater was injected at 3 bpm until pressure broke over at 1,040 psi.The cement retainer was then pressure tested to 3,500 psi for 15 minutes with seawater.After the pressure test the top drive and kill line were blown down,a side entry sub,TIW safety valve,lift sub and cement lines were rigged upon the rigfloor in preparation for the cement job. gg P P 1 On January 27`h, 2015 an abandonment squeeze/plug cement job was performed on ODSN-42b.The job began by pumping 10 bbl seawater ahead to fill lines prior to pressure testing.The pumps and lines were then pressure tested to 3,500 psi.After pressure testing 27.23 bbl of 15.66 ppg Primary Cement was pumped,30 bbl of 15.8 ppg Primary Cement was planned.The cement was spotted 2 bbl from the base of drill pipe by pumping 28.68 bbl seawater,27.5 bbl of seawater was planned. Pressure on the backside was maintained at 1,000 psi with the choke during all pumping.The drill string was then stung into the cement retainer with 20K down weight,the annulus pressure was bled off and the annular preventer was opened.The cement was placed by pumping 29.69 bbl seawater,32.0 bbl of seawater was planned.After placingcement the drill stringwas un-stungfrom the cement retainer,the well bore was observed to be static,the cement and side entry sub were rigged down and a 6"drill pipe wiper ball was inserted in the drill pipe.The wiper ball was circulated to surface to clear the drill pipe by pumping at 650 gpm. Cement was in place at 20:35:00. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well.We hope to be your solutions provider for future projects. Respectfully, Jared Miller iCem;Service Page 4 Created.Thursday,February 05,2015 HALLIBURTON CAELUS ENERGY ALASKA LLC ODSN-42b Abandonment Squeeze/Plug 2.1 Customer Information Customer: Caelus Energy Alaska LLC Sales Order: 902073511 Job Configuration: Conventional Cement Well Name: ODSK-42b Start Time: 19:00:00 State: Alaska UWI/API 703-20605-02-00 Country: USA H25 Present: Unknown CO2 Present: Unknown Customer Representative: C.A. Demoski Service Representative: Jeff Helms;Shayne Bitton 2.2 Well Conditions Casing Size and Weight: 7.625",29.7 lb/ft, L-80 BTC-M 10.75",45.5 lb/ft, L-80 BTC-M Casing Depth: 7.625"Casing Cut @ 3,289' (Cut at 3,285' according to casing tally&cut joint length. 10.75"Casing:0—3,289' Cement Retainer: 10.75" Halliburton EZ-Drill Cement Retainer Cement Retainer Depth: 3,339' Well Fluid: Seawater iCern Service Page 5 Created:Thursday,February 05,2015 to rnL o m _0 Oo V O LL ❑ N u a0 ,L OY OO M 2 in O- M C co 2 a) O l0 a) N Oo rn E I -o ul M (1) .4-,c_ .0 M i w M I U Ln oO N aJ Oi D 6O C j 4-, O CO +-' N CO EO- -o a� o E v I I E E 41 '� to .7,LL d - E ..)-,c_ ..,...c_ o t L °' U u ca -C c a a a) c u D D 0 N Oa CO N a — 41 E N c c CU OJ CO co 3 v rn ufi TS CU 0 o _ E E "0 co E a--1 C o0 O U U CU 7 N M a) C > c �' Q v Y O E a Y CO v a) Y 0.2 C _o w u E a, N E E E i< 7 7 O O a1 = Y O u a N O O o E v m E E o0 o n ° O m i l LID a) = LO o a) 0 0 0 1� o ai V) a o_ .e u i a c-I a OC I- IL I- N , . H N c- "4 u m o c J J d Y N fl O a , E Q▪ v' 3 E L Y OM O LL l7 > n N n w o v N M W N L D Q 0 J -0 N W r''' m N U N V O "C3 C C W W I Y C Y C 4-, C C a) a) a) a1 o E E a)vcu a U U U O a) a) 'v O O L ruo ruo QY la VI C a a W L 0 O'� O 0 I CO Y Y Y 4- Y Y 1:3 TS CD ID ra ca L C Q1 u C HI Ccu cu c L L W DI LI a)Q Q Y Y C C Y Y CO m E m m C L L , L L L a J L L cu a) a) a a1 a) a) cu aJ a) U N aJ o a E E C E E o O as a o � � �' v U oU U c a a N N a -o a s 0. a - a a tg E E v , E c E E E E c E E Y 7 7 L 7 . Y C 7 7 3 7 ' 7 3 v-) a a a c a s vl a s a a u) a a Z xt , N M V ul LO N OO Crl O a--1 N Cr) f`• 00 a-i r-1 L-1 e-1 a--I 4--I 0 I- re L_ 64 M �: J O N I. u, Ql 00 N Cf O t-0lfl O c-I M - W Q, c O M .--1 .5: N 7r. N M N M ul Lf) ul ul N 0 > E OR O M N Ol CO O M M ul N N Ol M J W O O r-1 i--1 a-l ci ul u-) O O i--1 a--1 a--1 M ' Ql Ql Ol Ol Cri 6 Ol Ol Cr) O O O O O O 4 -r''i �O c-1 a1 a1 a1 a1 a1 a-l 4-l i--1 N N N N N N 0 L.' I o M m a HALLIBURTON CAELUS ENERGY ALASKA LLC ODSN-42b Abandonment Squeeze/Plug 3.2 Stage Summary-Cementing Unit Actual Average Average Density Average Rate Volume Stage Summary # Pressure (PPO (bpm) (bbl) (psi) Start Job 1 19:00:00 - - - - Pump Water 2 19:07:32 393.59 8.23 3.77 10.42 Pressure Test 4 19:13:45 3597.71 8.73 0.00 0.00 Pump Cement- 7 19:48:22 1370.49 15.57 2.63 5.80 Before Shutdown Pump Cement- 9 19:53:20 1167.17 15.74 2.24 23.02 After Shutdown Pump Water 11 20:05:55 740.58 8.77 2.48 29.58 Behind to Spot Pump Water 17 20:19:53 1211.33 8.66 2.28 30.83 Behind to Place 3.3 Stage Summary-Rig Floor Stage Summary # Average Pressure Average Rate Volume Actual Time (psi) (bpm) (bbl) Start Job 1 19:00:00 - - - Pump Water Ahead 2 19:08:33 221.16 4.44 7.45 Pressure Test 4 19:13:45 3429.90 0.00 0.00 Pump Cement- 7 19:48:22 1025.03 2.45 5.32 Before Shutdown Pump Cement-After 9 19:53:17 868.82 2.13 21.91 Shutdown Pump Water Behind 11 20:05:45 544.53 2.39 28.68 to Spot Cement Pump Water Behind 17 20:19:52 1022.20 2.20 29.69 to Place Cement 3.4 Volume Summary Water Behind to Spot Water Behind to Place Description Water Ahead Primary Cement Cement Cement (bbl) (bbl) (bbl) (bbl) Cement Unit Volume 10.42 28.82 29.58 30.83 Rig Floor Volume 7.45 27.23 28.68 29.69 Actual Volume 10* 27.23 28.68 29.69 *Volume based on actual value pumped from cement unit displacement tank. iCern Service Page 7 Created:Thursday,February 05,2015 d 0. 'a C o _ _ E a -2 a Z LI, oDIo vi o v .21in m N t 0 0o Q .0 c fu E N u 0 0. In 0 C PIP E a `0 A 'a w aE n = E O oo u a E• L'°' � �bOQ W ^ O m ; > u » > E 01 0101 O E m ro M 0 CJ 00 0 —m fn m al m 0 <-1 J 0 m �V Q v .TI " o o Y fu a N N m ra ra - m a N -: U) Z 0 H O M co O M IV a' M O of N ^ as\ �-' Y � 7 Q N LI a u' m a u' N a .0 a 0 a a L 0 N 0 0 0 ID Ill N 10 0 N 0 0 N >- fU N t tll N O w N la N N co N CO O •O 0 (T �O 0 fn 0 r i LL -: I0 fT T N .+ vi m o0 co' Oi N O N lJ j, CC O d e N % .000000 N ti M M LIJc E LL a 0 0 0 0 0 Z % If) SJ fY vl b y �n Vt '� X b ~ • Q OC {:7 O C Lai N w C_ O1 O. 00 N fY -0 J _co ' b O in N •(T Q 'fp W v a o `o fr m Q +, a ix V/ w u Q a 30 --P. 101 to 0 e N v` O �.O r-: 6 = E w v I n a c n v 0 w w 0 n '0O u � ,� 3 v E fe0 Ic a, 0 3 °i = a - _a > o ._ c Q a a E u 3 E ¢ y c y d 0 � o > 0 w N 0 `a ai Ui v ° E E n a' ° ',D ¢ z O x E ° m g 8 Z m m= n c 3 c ` 0 c as w S S V1 - v o w N 0 0 0 .0 E 0 c E > in N a a 'C' w a m n m 0 a "' o a o a, u od _ moua > z > � Ou7an „ c Un 'n Un - a+ in in in in " a 7-- N .-- 0 E NNNN I8 v « m f'n. n m > > `w o n of in u o« o« of o« in o '> 3 1- 0 o. I- z° > o m• m fn nm N N M m m m 11 11 11 C6 u c mc y c y ¢ N O ▪ V of i� O E E u $ 0 m 2 0 .., FO II .,, n o W r N m Jro _ v fl 7.0 Lab Reports 7.1 Primary Cement HALLIBURTON Lab Results-Tail West Coast,Prudhoe Bay Job Information Request/Slurry 2211329/1 Rig Name NABORS#19AC Date 20/JAN/2015 Submitted By Jared Miller Job Type Plug to Abandon Bulk Plant Prudhoe Bay,AK USA Customer Caelus Energy Alaska,LLC Location Oooguruk Island Well ODSN-42B Well Information Casing/Liner Size 10.75 in/273.05 mm Depth MD 1002 m/3289 ft BHST 20°C/68°F Hole Size 9.875 in/250.825 mm Depth TVD 908 m/2980 ft BHCT 16°C/60°F Pressure 155 bar/2250 psi Drilling Fluid Information Mud Supplier Name Baroid Mud Trade Name Density Cement Information-Tail Design Qui UOM Cement/Additive Sample Type Sample Date Lot No. Cement Properties HalCem CPT 22.01.15 Slurry Density 15.798 Ibm/gal HALAD-413(PB) Bulk Blend 20.05.14 ZMIG0158A0 Slurry Yield 1.1721 ft3/sack Water Requirement 5.1039 gal/sack Total Mix Fluid 5.10 gal/sack Water Source Sea Water Water Chloride Pilot Test Results Request ID 2211329/1 Mixability(0-5)-0 is not mixable 22/JAN/2015 Mixability rating(0-5) Avg rpm mixing under load(-12,000) 5 12000 API Fluid Loss 22/JAN/2015 Test Temp("F) Test Pressure(psi) Test Time(min) API FL(cc/30 min) Meas.Vol. Conditioning time (min) 60 1000 30 16 8 30 This report is the property of Halliburton Energy Services and neither it nor any part thereof,nor a copy thereof,is to be published or disclosed without first securing the expressed written approval of Halliburton.It may however be used in the course of regular business operations by any person or concern receiving such report from Halliburton.This report is for information purposes only and the content is limited to the sample described.Halliburton makes no warranties,expressed or implied,as to the accuracy of the contents or results.Any user of this report agrees Halliburton shall not be liable for any loss or damage regardless of cause,including any act or omission of Halliburton,resulting from the use hereof. Page 27 of 30 Global Customer Report Free Fluid API 10B-2/ISO 10426-2 22/JAN/2015 Con.Temp(F) Heat Time(min) Cond.Time(min) Static time(min) Incl.(deg) %Fluid 60 10 30 120 90 0 Channeling,Settling & Foam on top API Rheology 22/JAN/2015 Temp("F) 600 300 200 100 60 30 6 3 Cond Time PV/VP (min) 60 262 151 109 63 42 24 13 3 30 145.33/9.64 This report is the property of Halliburton Energy Services and neither it nor any part thereof,nor a copy thereof,is to be published or disclosed without first securing the expressed written approval of Halliburton.It may however be used in the course of regular business operations by any person or concern receiving such report from Halliburton.This report is for information purposes only and the content is limited to the sample described.Halliburton makes no warranties,expressed or implied,as to the accuracy of the contents or results.Any user of this report agrees Halliburton shall not be liable for any loss or damage regardless of cause,including any act or omission of Halliburton,resulting from the use hereof. Page 28 of 30 Global Customer Report H L LI B U RTO N iCer6 Service CECAELUS ENERGY ALASKA LLC 3700 Centerpoint Dr. Anchorage, AK 99503 OCICgU rtk ODSN-42b Balanced Plug Post Job Report For: Alex Vaughan Date: February 5, 2015 ODSN-42b Oooguruk Island Sales Order: 901072815 Sincerely, Jared Miller Legal Notice Although the information contained in this report is based on sound engineering practices,the copyright owner(s)does(do)not accept any responsibility whatsoever,in negligence or otherwise,for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise.The application,therefore,by the user of this report or any part thereof,is solely at the user's own risk. Irl 'c:tl+.'•i' L- i: t, '"if. Except as expressly set forth herein,there are no representations or warranties by Halliburton,express or implied,including implied warranties of merchantability and/or fitness for a particular purpose.In no event will Halliburton or its suppliers be liable for consequential,incidental,special,punitive or exemplary damages(including,without limitation,loss of data,profits,use of hardware, or software).Customer accepts full responsibility for any investment made based on results from the Software.Any interpretations, analyses or modeling of any data,including,but not limited to Customer data,and any recommendation or decisions based upon such interpretations,analyses or modeling are opinions based upon inferences from measurements and empirical relationships and assumptions,which inferences and assumptions are not infallible,and with respect to which professional may differ.Accordingly, Halliburton cannot and does not warrant the accuracy,correctness or completeness of any such interpretation,recommendation, modeling or other products of the Software Product.As such,any interpretation,recommendation or modeling resulting from the Software for the purpose of any drilling,well treatment,production or financial decision will be at the sole risk of Customer.Under no circumstances will Halliburton or its suppliers be liable for any damages. HALLIBURTON Table of C onter t5 I Exec?itive 4 2U De ; l 5 2.1 Customer Information 5 2.2 Well Conditions 5 3.1 Job Event Log 6 3.2 Stage Summary—Cementing Unit 7 3.3 Volume Summary 7 4 1 Volume Calculations 8 5.1 Rig Floor—Job Graph 9 52 Rig Floor—Seawater Ahead 10 5.3 Rig Floor—Pressure Test 11 5.4 Rig Floor—Cement 12 5.5 Rig Floor-Displacement 13 61 Data Listing—Rig Floor 14 La.' r�UPUr,_ 1( .3 Lab Report—Primary Cement 16 HALLIBURTON CAELUS ENERGY ALASKA LLC ODSN-42b Balanced Plug 1.0 Executive Summary Alex Vaughan Caelus Energy Alaska LLC Anchorage,AK Mr.Vaughan, Halliburton appreciates the opportunity to perform the cementing services on the Oooguruk project.A pre-job safety meeting was held where details of the job were discussed,potential safety hazards were reviewed,and environmental compliance procedures were outlined. On January 22nd,2015 at 12:00 a.m. Nabors Drilling Rig 19AC moved on to ODSN-42b, previous well name ODSK-42i. The Vetco Gray riser and BOP stack were nippled up and pressure testing on the components was completed.At approximately 21:00, E-line was rigged up to perform a 2.74"gauge run to tag the top of cement from the cement squeeze job performed on January 7th,2015.Cement from the squeeze cementing operation was tagged at 5,641'. The gauge ring was rigged down and the Jet Cutter assembly was rigged up.The existing 3.5"tubing was cut at a depth of 5,536.5'.The tubing was pulled from the wellbore in preparation for the upcoming balanced plug job. On January 25th,2015 the rig tripped in hole with BHA#2,which included a Halliburton 7.625" EZ-Drill Bridge Plug. The BHA was tripped in hole to 5,537'where the bridge plug would be set.The EZ-Drill Bridge Plug was set by turning 38 turns to the right; it was then pulled in 12K increments until it sheared free at 167K hook load and 47K over pull. The top of the bridge plug was set at 5,534'.With the bridge plug installed the upper pipe rams were closed and a pressure test was completed by pumping seawater down the kill line and testing the 7.625"casing at 3,500 psi for 30 minutes.After completing the pressure test a pre-job safety meeting was held with all parties that would be involved in the balanced plug cement job. At 13:15:29 on January 25th, 2015 the balanced plug cement job began with Halliburton pumping 10 bbl of 8.5 ppg Seawater ahead to fill lines to the rig floor.After pumping water a five minute 3,500 psi pressure test was completed,the maximum pressure seen on the rig floor was 4,000.12 psi.Pressure on the lines was bled off and 11.07 bbl of 15.8 ppg Primary Cement was pumped, 10 bbl of cement was planned.After pumping the primary cement it was displaced with 53 bbl of Seawater.The rig floor flow meter recorded 45.98 bbl, however 53 bbl of displacement pumped from the displacement tanks on the cement unit was recorded by the Halliburton supervisor on location and witnessed by the Caleus representative on the cement unit.After pumping displacement the release line on the cement unit was opened to allow the cement plug to balance itself.Cement was in place at 13:54:27.The rig pulled out of the cement plug from 5,534 to 5,210'at approximately 5 minutes per stand.A 5"wiper ball was pumped down the drill pipe and circulated to surface to clean the drill pipe after the job. No cement was circulated to surface. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well.We hope to be your solutions provider for future projects. Respectfully, Jared Miller iCern'Service Page 4 Created:Thursday,February 05,2015 HALLIBURTON CAELUS ENERGY ALASKA LLC ODSN-42b Balanced Plug 2.1 Customer Information Customer: Caelus Energy Alaska LLC Sales Order: 902072815 Job Configuration: Conventional Cement Well Name: ODSN-42b Start Time: 12:14:07,January 25th, 2015 State: Alaska UWI/API 703-20605-02-00 Country: USA H2S Present: Unknown CO2 Present: Unknown Customer Representative: Rod Klepzig; Mike Thornton Service Representative: Jeff Helms;Shayne Bitton 2.2 Well Conditions Casing Size and Weight: 7.625", 29.7 lb/ft, L-80 BTC-M Bridge Plug: Halliburton EZ-Drill Bridge Plug Depth: 5,534' Well Fluid: Seawater iCerr' Service Page 5 Created:Thursday,February 05,2015 Y a) I W a E a) U ICL T CV Y v 00 E c O a) °' Q '- 0_ E Jam+ _ Q '6 �- a) _ Y U Q w ti r- as Q CL C E o' U v, GJ OU • of .-I INN O N • C Q Q _ a) O s O v ra U U.. - c v U on v fO orn 00)) Y 'n O_ a O to C 3 E 3 v 46- 0 ra O ul O — C N a) 'A JD 22 Y Lla �; E o Q m • u O E z 0 ,-I Lr1 y,, Q of .E 10 Q Q als- E aJ cra v1 a) O rv) 0_ , 0_ G 0 CO d . 0.. U b V n J J o- O_ p a V Yv or (J am E Q m 3 p L0 N LL � 7r > a , Q , , , O 00 , U ce C ' rri o W Q 000 Ln a W O V r J G1 W co Q `1 U U C 0 CL u 61a 0 G c c UJ w ' "O Y Y 10 10 c c c ra r1:2 'Y/I ,- C W a) a) -C -C I- gf,' "' I E E Q Q a) �, Y Y U c c N a) a) ro ro a) CI) 0 0_ Y Y VE 1- E E 0_ eL ro ro o �' v U U CI 0 E v,Q Q Q a. Q Q '- EE '- co Cl.) E E E E ro a = v. e 0 = = 0 = v ) Z *t ei N m Ul LO N 00 01 Q r-I 0 F ac W0.0ry M +.4J N 01 41 0 Lfl N -1 N W G../ ID O N N u'1 Lr1 e-I N G1 > E V Ln 1 in N 00 r-1 l0 0 e1 cr Jw e1 ,-I!,-I ,-I I-1N m v v in J 00 ~ N m I�,m m m m M m m m Q 0 _, e•-I e1 t--1 e-4 ,-I e-I e•I ,-I 1-1 ,-I t0 N to _ [} ro m rn a HALLIBURTON CAELUS ENERGY ALASKA LLC ODSN-42b Balanced Plug 3.2 Stage Summary—Cementing Unit Stage Summary # Average Pressure Average Rate Volume Actual Time (psi) (bpm) (bbl) Start Job 1 12:14:07 - - - Pump Water Ahead 2 13:12:11 29.30 2.85 9.39 Pressure Test 4 13:17:40 3944.58 0.00 0.001 Pump Cement 7 13:36:42 -24.58 2.66 11.07 Pump Displacement 9 13:41:15 96.08 3.48 45.98 End Job 10 13:54:27 - - - 3.3 Volume Summary Primary Cement Displacement Description Water Ahead(bbl) (bbl) (bbl) Rig Floor 9.39 11.07 45.98 Actual 10.00* 11.07 53.00* *Volumes based on fluids pumped from the displacement tanks.Actual displacement verified by Caelus company representative. NOTE:The Unipro data from the cementing unit was un-retrievable,and therefore is not show in this post job report. iCorn' Service Page 7 Created:Thursday,February 05,2015 u it • - x — W E• N ul ul O ul V OP 0 O. N u n M 00 o ,, o o ,L n a F N as uMi `S U N M - N IN L w N O w N o M 00 Y y No -2 N i� 0 0 o a u 00 Lp U Yn L• d w d w co V c0 mo 0 .-I 01 0 01 N CO (0 X ti M VI O ar•••: O T O Mn; 1.7 G c NOp m H C r` M = .'I V1 C O V1 O •O M N Vf M r O N N C a 0 - To co 2 C - `,-QLL u O < <O •o- j..' a. N N .00. a N a um 00 C O m a v E u U a - a c c a g ▪ c LE aar o a v u - d m5 o - v° LL o E 'a c m 3 0, c c ar .- u 0 01 U m _a E °' a, 3 n v U J a d 0, N N m E J a C — .> U U 0 0! 00 0 d U 0 N O Ol O O O 0 Q _ _ VY1 c no _a a u n x r cc j , a, 0 0, o (n t C pp Q 0 • — `°Ln E Zn — n1- `° c " C m •- v } d U 0 m N O N _O '> > H >° >° 2 >° 2 N l7 "I' U W vZ Z O L N 120 r J 3 h u LLI 0.Q -p ON enLe) v V u COo In In U C as II u n f0 U ; 04 c0 O a 21 a, a N S. Cr a m Z Ln 0 O )( ro o , N o m N. U, N N N ,n h V1 II II II U 01 [L I- 'a ° e co 2 Ln en 0 Ln o C co O u W U W n5 0.1 )1\J J ro 4 u > o I r. a a 7.0 Lab Reports 7.1 Lab Report—Primary Cement HALLIBURTON Lab Results-Tail West Coast, Prudhoe Bay Job Information Request/Slurry 2209687/2 Rig Name NABORS#19AC Date 14/JAN/2015 Submitted By Jared Miller Job Type Cased Hole Plug Bulk Plant Prudhoe Bay,AK USA Customer Caelus Energy Alaska,LLC Location Oooguruk Island Well ODSN-42B Well Information Casing/Liner Size 7.625 in/193.675 mm Depth MD 2225 m/7300 ft BHST 61°C/142°F Hole Size Depth TVD 1587 m/5207 ft BHCT 48°C/118°F Pressure 208 bar/3020 psi Drilling Fluid Information Mud Supplier Name Baroid Mud Trade Name Density 10.4 Ibm/gal Cement Information-Tail Design g Conc UOM Cement/Additive Sample Tyne Sample Date Lot No, Cement Properties HalCem IPT 22.01.15 Slurry Density 15.798 lbm/gal 0.15 %BWOC SCR-100(PB) Lab 20.05.14 14C002C Slurry Yield 1.1712 ft3/sack Water Requirement 5.1083 gal/sack Total Mix Fluid 5.11 gal/sack Water Source Sea Water Water Chloride Pilot Test Results Request ID 2209687/2 API Rheology 22/JAN/2015 Temp(°F) 600 300 200 100 60 30 6 3 Cond Time PV/YP (min) 70 180 86 60 36 25 17 8 7 0 78.7/8.18 This report is the property of Halliburton Energy Services and neither it nor any part thereof,nor a copy thereof,is to be published or disclosed without first securing the expressed written approval of Halliburton.It may however be used in the course of regular business operations by any person or concern receiving such report from Halliburton.This report is for information purposes only and the content is limited to the sample described.Halliburton makes no warranties,expressed or implied,as to the accuracy of the contents or results.Any user of this report agrees Halli burton shall not be liable for any loss or damage regardless of cause,including any act or omission of Halliburton,resulting from the use hereof. Page 16 of 18 Global Customer Report HALLI B U RTO N iCem`' Service CAELUS ENERGY ALASKA LLC s 3700 Centerpoint Dr. CE Anchorage, AK 99503 coogU ru k ODSK-42i Cement Squeeze Post Job 1 Report For: Alex Vaughan Date: February 5, 2015 ODSK-42i Oooguruk Island Sales Order: 902014167 Sincerely, Jared Miller Legal Notice Although the information contained in this report is based on sound engineering practices,the copyright owner(s)does(do)not accept any responsibility whatsoever,in negligence or otherwise,for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise.The application,therefore,by the user of this report or any part thereof,is solely at the user's own risk. Except as expressly set forth herein,there are no representations or warranties by Halliburton,express or implied,including implied warranties of merchantability and/or fitness for a particular purpose.In no event will Halliburton or its suppliers be liable for consequential,incidental,special,punitive or exemplary damages(including,without limitation,loss of data,profits,use of hardware, or software).Customer accepts full responsibility for any investment made based on results from the Software.Any interpretations, analyses or modeling of any data,including,but not limited to Customer data,and any recommendation or decisions based upon such interpretations,analyses or modeling are opinions based upon inferences from measurements and empirical relationships and assumptions,which inferences and assumptions are not infallible,and with respect to which professional may differ.Accordingly, Halliburton cannot and does not warrant the accuracy,correctness or completeness of any such interpretation,recommendation, modeling or other products of the Software Product.As such,any interpretation,recommendation or modeling resulting from the Software for the purpose of any drilling,well treatment,production or financial decision will be at the sole risk of Customer.Under no circumstances will Halliburton or its suppliers be liable for any damages. HALLIBURTON Table of Contents I 0 Exec ;t,Ve S,imrnary 4 De-,??n 5 2.1 Customer Information 5 2 2 Well Conditions 5 3 1 Job Event Log 6 3 2 Stage Summary—Cementing Unit 8 3.3 Volume Summary 8 4.1 Volume Calculations 9 51 Cement Unit—Job Graph 10 5 2 Cement Unit—Pressure Test and Injection Test 11 5.3 Cement Unit—LVT Average Density and Volume 12 5.4 Cement Unit—Tuned Spacer Ill Ahead Average Density and Volume 13 5 5 Cement Unit—Primary Cement Average Density and Volumes 14 5.6 Cement Unit—Spacer Behind Average Density and Volume 15 5 7 Cement Unit—LVT Displacement Average Density and Volume 16 6.1 Data Listing—Cement Unit 17 7.1 Lab Report—Tuned Spacer III 23 72 Lab Report—Primary Cement 25 HALLIBURTON CAELUS ENERGY ALASKA LLC ODSK-42i Cement Squeeze I.0 Executive Summary Alex Vaughan Caelus Energy Alaska LLC Anchorage,AK Mr.Vaughan, Halliburton appreciates the opportunity to perform the cementing services on the Oooguruk project.A pre-job safety meeting was held where details of the job were discussed,potential safety hazards were reviewed,and environmental compliance procedures were outlined. On December 15t, 2014 planning for a possible squeeze job on ODSK-42i was presented to Halliburton.The goal of the squeeze job would be to isolate the existing perforated zone without the presence of the rig.The cement job would take place through the existing 3.5"tubing, into the 4.5"liner and into the perforations in between 8,736'and 8,756'.The original plan was to leave the top of cement at a height of 7,800',then the rig would be moved in and the 3.5"tubing would be cut at 7,300'.The tubing would be pulled from the hole and a bridge plug would be placed in the existing 7.625"casing and 25'of cement would be pumped on top of the bridge plug.After discussing the original plan with both parties involved, Halliburton and Caelus, it was decided to pump 25 bbl of cement and to displace cement to a height of 6,800'. From this point the plan would proceed as originally designed,the 3.5" tubing will be cut and a bridge plug will be set—10'above the cut tubing with cement placed on top. On January 7th, 2015 at 12:52:36 the squeeze cementing job on ODSK-42i took place. Pumping began with 40.29 bbl of LVT to determine injection pressure and rate.While pumping LVT it was determined that the flow meter used for recording rate and total volume at the well head was not working correctly.Multiple steps were taken to determine why the flow meter was not working correctly, including switching the magnetic pick-up assembly,restarting the iCem program and tracing all connections and shielded cable for any discontinuities. When no solution on location could be determined the Wells Works Supervisors on location,with approval from Caelus in Anchorage,approved the job going forward without the ability to record the flowmeter data near the wellhead. Following pumping LVT, 20 bbl of Tuned Spacer Ill and 25 bbl of Primary cement were mixed in preparation for the job.When the fluids were mixed and densities had been verified pumping continued with 10 bbl of Tuned Spacer Ill at 10.59 ppg, 10 bbl mixed at 11.0 ppg was planned. Following spacer 25 bbl of Primary Cement mixed at 15.93 ppg was pumped, 25 bbl mixed at 15.8 ppg was planned. Next the line would be flushed with 2.5 bbl of Tuned Spacer Ill mixed at 11.11 ppg, pumping was shut down and a Pup joint was installed with a pre-installed wiper ball to be pumped behind the cement.With the new joint installed lines were pressure tested and then pumping continued.Another 7.5 bbl of spacer mixed at 11.11 ppg was pumped.After pumping spacer 50 bbl of LVT at an average density of 7.02 ppg was pumped for displacement.This would leave the top of cement at an estimated height of 6,896 ft. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well.We hope to be your solutions provider for future projects. Respectfully, Jared Miller iCem Service Page 4 Created:Thursday,February 05,2015 HALLIBURTON CAELUS ENERGY ALASKA LLC ODSK-42i Cement Squeeze 2.1 Customer Information Customer: Caelus Energy Alaska LLC Sales Order: 902014167 Job Configuration: Conventional Cement Well Name: ODSK-42i Start Time: 12:52:36, 1/7/2015 State: Alaska UWI/API 50-703-20692-00-00 Country: USA H2S Present: Unknown CO2 Present: Unknown Customer Representative: Chad Gueco; Jamey Bowman Service Representative: Jose Mota;Jared Miller 2.2 Well Conditions Casing Size and Weight: 3.5",9.5 lb/ft, L-80 TC-II Tubing 4.5", 12.6 lb/ft, L-80, Hydril 521 Casing Depth: 0'—8,538'(3.5",9.5 lb/ft) 8,538'—9,753' (4.5", 12.6 lb/ft) Perforated Interval: 8,736'—8,756' Previous Casing Size: 7.625",29.7 lb/ft, L-80 BTC-M Previous Casing Depth: 8,654' Hole Size: 6.75" Hole Depth: 8,654'—9,758' Well Fluid: Mixture of Diesel Freeze Protect, LVT,Seawater iCern' Service Page 5 Created:Thursday,February 05,2015 Y c C v a) 0 -O E E a ro t U 0 as C T C Y 0 C (0 3 Y _ 4- N- C 3 v c Y C .0E -p al 0 "O 3 N .0 C 3 Y d d .'-' 3 f0 rl ro n C a) - Y .- O C t Y D N n cu E 3 C 0 Y 3 V7 of d ro aJ 0) �, 'C C to c c 3 rri a E t -1) to co c ro rroo a) : 0 aa) ( c _ 00 0 72 c a o U 0 C E - • E c _o n °,�4 v w E o o n m m E u a Ton �+ n c O C N - t"I Y U .� C t) X U o of L U E a +-. N D Y C 3 Y I- uy" c-I 0 Y -C E Y U C +-' f0 '_ on •3 X ci,L Y fl ar0i ro v CO Co E v aci v aui •C ar E cB 3 = 0 3 a) oco o aEi .c c _ fp 0 oN E c 3 -+S a) .c- E Y u 3 a) -o_ E 0 v a' L o o • n Y 1.11 O N C 6 r, 3 a) U .X t t n Y +' L a1 o L Y 0 ON L_ � U u (o E _o _o Y U v) d 0 Y 4w aJ 1 L1 i1 i! n . O t VI '''C CESO� N O t .co C d v, CU ce a1 Y C - a1 .0 N N -' n a1 -0 a1 c n n n CU L = C ,� `o - v v v a) E E c E 'X E E E E f6 - v �+ • 3 0 3 a1 3 3 3 0 a1 of V) ii rz ri a D 3 rl U 1- U E a D_ rz 0 0 .E ii 0 U N U u J N •? O v • Y v2 C` O C Ln a . E > v p Cil a)lJ - > . � � � � O � O V1 O Lr( Vl l U �. ccLU ,1- c v ct N N N Ni N 19 Z CIO -0` NCS rA 2 N O H- -CJ J G W Q N V U 1v v co L a aJ 3 t v, a) a)v m a a`) t a) 9- UN Y CO OO -O c W 4ej as L ° °o a) v U m C E v c E a) a.) t o - L -0 a) a U +.. = Q v E C E - Y a, 'O 3 = u �►. =1 C = E vv, U L 0 a1 .0 T t C a1 n V 3 O1 l6 rn v, E v 2 F- S E t L a, O u Ln > a1 d COtm Q a1 01 -O C J r0 U Q Y Y E m rl n "6 0 C F- t v1 = c ^ .L = D v X c ° > U- O Y i L a) Q d L D_ Y} j 2 v Y n CU v 3 aEi n ocn F- To ro ro 00 J .3 = - C° 1- d n U 0. n v*'i C t v1 L vY' d t N 00 d4 N L 0- E C t N .0 Y 3 I H a v ♦� 3 H c c C to C p. c '= v roE X X C E C C c 3 F- E o v �' °.,' a) 0 3 o 1- 0-- 3 a) 1' 3 v a) CC _ 0 0 o v a1 ti C U TS Y u .0 C n n 'O y 0. 'O co J n co - v u ar a, a c v ao 'on E E 3 c E 3 Y _ v E .,J L C L °- '� t 0 ', aJ aJ 3 3 t 0 3 t - L 3 V Li: 0- - D_ U - rn U - m CO 0- 0- rn U 0- Ln - •U- rl D_ Z ik c I N M Cr Vl LO n 00 al O r 1 N CO Lr1 l0 r-) co Ql O c-1 e-i .--I .-1 .--I ei e-i r-) .--I ci N a I- ('6 JO YiD LD m Cr) r-I O V1 0o 01 O N 01 V1 C 1 Tr 00 00 00 D1 M WQ., C a) m Vl O m N O N N O ci O M In V N M O M E N 00 cr 01 O .-i .-i sr) N. N V1 C LD N N Ln n c-I'M V .0 w Vf m y cr V1 V1 N N N N M .-i .--I a--I .--I N N M i M [] �O ~ N M m M m m V Ln LO l0 l0 COLD l0 lD tD se. a .- I ri ri %i %i ti ,i �i � ,-I 11 %i 41 LO 0) M m a C co 4—,a)C OJ U (C Q T • E O H J O Ll) Q E CL 0 Lr. U v U JO J 41 '� Y• N )O Q C j ▪ N C Q N0 N O U z v L/ W z N O -o J W U V J C +J v CO r+ Y C C E E ~ U C N a_ E ^ as 0 U � f0 Q J Q O • E -O = C "J c1 N M (� N N N 0 a W V O L./1 COQl l0 M M Ln cc; 6 l0 4 •-1 e-i r-L n v m I HALLIBURTON CAELUS ENERGY ALASKA LLC ODSK-42i Cement Squeeze 3.2 Stage Summary-Cementing Unit Average Average Stage Summary # Actual Average Rate Volume Pressure Density Time (bpm) (bbl) (psi) (PPR) Start Job 1 12:52:36 - Injection Test with LVT 6 13:51:31 1360.39 7.01 1.25 40.29 Pump Tuned Spacer Ill Ahead 12 16:10:12 1094.00 10.59 1.93 10.91 Pump Primary Cement 13 16:16:09 883.25 15.93 2.83 24.94 Pump Tuned Spacer Ill Behind 16 16:25:44 374.50 11.11 1.43 2.49 Cement Pump Remaining Tuned Spacer 20 16:34:39 135.07 11.11 1.86 7.58 Ill Behind Pump LVT Displacement Begin 22 16:39:09 1559.25 7.02 2.94 52.42 End Job 23 16:56:57 - - - - 3.3 Volume Summary LVT- Primary Description Injection Test Spacer Ahead Cement Spacer Behind LVT Displacement (bbl) (bbl) (bbl) (bbl) (bbl) Design Volume 40.00 10.00 25.00 10.00 50.00 Cement Unit Volume 40.29 10.91 24.94 10.04 52.42 Actual Volume 40.29 10.00* 25.00* 10.00* 50.00* *Volumes based on tank capacities iCem' Service Page 8 Created:Thursday,February 05,2015 r. b N m on 00 n coQ7 00 00 oi00 00 00 co a 1a II II II II II II II n o. O a F2G IS! O O v cu 0• 01 = C 1 • E 0 ] 0 G 1 n O O E y1 y1 y n ..n• U M tt n 0 FO- 0] A Ui Ua, J J a, N Q J vii ' o Ln ._. a = la J m r Q E d } U cc• V W Y O zo J L.,.., O 0 L N 1- J Q) N Q Ni N N v U 0) = 3 3 a _ a ET Lw_o w n (n O N 00 N O Ui N ID O M M l0 O 01 l0 V1 (N EE N `� Om1 V 00 V 0011 V ¶ v -O .I CO 2 N up , v Y 0 N 0 c ao 01C 0o E 3 a, L x ° O U 12 m m 00 on N W E La 7 C C CN Y C O H I- L j 0 E m `- S m - ~ °- E o ` C O ^ m v0°i vt°i a o c c ar V n O ~O O `� 00 Ol CO E E E 0 V U L CO m E a .a O co U U to VI N m in r, > co O 7 2 a ^ 00 10 c E o 0 0l 0 0 O w 0 m 0 o m -, L LL CU E co 0o E . 0 U m S > 2 0 U r 00 N OJ L 0\ ^' z3 = d E 0O C 01 01 Ol O 3 , OO 0 N 00 M 0 i O O3 L L L 3 3 .0 _ yLn I-- N .-, on ta N N M ,-I.-, l Ln C In V1 to n0 M 0VNl O :.7... cri v v a+ 7 N u j2' > O to W 0 L C Ln C F G • C O O O E p N 0.1 2 c0 C cc u c.0 t0 O O) O 7 O U To U N O m a 00 U Ol ._ a M 4rc U O E al O no n ▪ O W N J _ o m v -J r6 o a v «• a v a• v a r o• 0 Q U > - c E E > > v m H O I- , i- . O 0 L v N (O u OD = G: •-, on v . in V1 in o o O o CO i Cl: m o a m e m v m m z a. HALLIBURTON CAELUS ENERGY ALASKA LLC ODSK-42i Cement Squeeze 7.0 Lab Reports 7.1 Lab Report—Tuned Spacer III HALLI B U RTON Lab Results- Spacer West Coast, Prudhoe Bay Job Information Request/Slurry 2207299/1 Rig Name NABORS#19AC Date 06/JAN/2015 Submitted By Jared Miller Job Type Intermediate Liner Bulk Plant Customer Caelus Energy Alaska,LLC Location Oooguruk Island Well ODSN-42B Well Information Casing/Liner Size 4.5 in/114.3 mm Depth MD 2669 m/8756 ft BHST 57°C/135°F Hole Size 6.75 in/171.45 mm Depth TVD 1834 m/6018 ft BHCT 49°C/120°F Pressure 246 bar/3570 psi Drilling Fluid Information Mud Supplier Name Mud Trade Name Density Spacer Information-Spacer Design Conc UOM Cement/Additive Sample Tyne Sample Date Lot No. Spacer Properties 40 lb/bbl Tuned Spacer III Lab 20.05.14 Slurry Density 11 Ibm/gal 36.32 gal/bbl Sea Water Lab 12.12.14 Slurry Yield 5.3561 ft3/sack 104.825 lb/bbl Barite Lab 20.05.14 Water Requirement 34.649 gal/sack 0.4 gal/bbl SEM-8 Lab 20.05.14 0.4 gal/bbl Dual Spacer Surfactant B Lab 20.05.14 Water Source Sea Water Water Chloride Pilot Test Results Request ID 2207299/1 Mixability(0-5)-0 is not mixable 06/JAN/2015 Mixability rating(0-5) Avg rpm mixing under load(-12,000) 5 4000 This report is the property of Halliburton Energy Services and neither it nor any part thereof,nor a copy thereof,is to be published or disclosed without first securing the expressed written approval of Halliburton.It may however be used in the course of regular business operations by any person or concern receiving such report from Halliburton.This report is for information purposes only and the content is limited to the sample described.Halliburton makes no warranties,expressed or implied,as to the accuracy of the contents or results.Any user of this report agrees Halliburton shall not be liable for any loss or damage regardless of cause,including any act or omission of Halliburton,resulting from the use hereof. Page 23 of 28 Global Customer Report HALLIBURTON CAELUS ENERGY ALASKA LLC ODSK-42i Cement Squeeze Rheology Compatibility—Spacer&LVT 06/JAN/2015 Test Temp Fluid Ratio 600 300 200 100 60 30 6 3 (°F) 120 100L 5 3 2 1 1 0 0.4 0.3 75L/25S 38 17 11 6 5 3 2 2 50/50 56 41 33 24 18 12 6 5 25L/75S 53 41 38 31 25 20 12 10 1005 54 41 36 29 26 22 14 11 Rheology Compatibility—Spacer and Cement(2204553/2) 06/JAN/2015 Test Temp Fluid Ratio 600 300 200 100 60 30 6 3 10 sec Gel 10 min Gel (°F) Strength Strength 120 100C 201 162 119 74 54 35 13 8 5.4 14.8 75C/25S 181 126 99 68 54 41 23 19 13 51 50/50 148 110 90 65 54 41 23 20 15 41 25C/75S 106 81 69 54 48 39 24 20 19 29 1005 61 42 36 29 26 21 14 11 12.7 19.8 This report is the property of Halliburton Energy Services and neither it nor any part thereof,nor a copy thereof,is to be published or disclosed without first securing the expressed written approval of Halliburton.It may however be used in the course of regular business operations by any person or concern receiving such report from Halliburton.This report is for information purposes only and the content is limited to the sample described.Halliburton makes no warranties,expressed or implied,as to the accuracy of the contents or results.Any user of this report agrees Halliburton shall not be liable for any loss or damage regardless of cause,including any act or omission of Halliburton,resulting from the use hereof. Page 24 of 28 Global Customer Report HALLIBURTON CAELUS ENERGY ALASKA LLC ODSK-42i Cement Squeeze 7.2 Lab Report—Primary Cement HALLIBURTON Lab Results- Tail West Coast, Prudhoe Bay Job Information Request/Slurry 2204553/2 Rig Name NABORS#I9AC Date 27/DEC/2014 Submitted By Jared Miller Job Type Shoe Squeeze Bulk Plant Prudhoe Bay,AK USA Customer Caelus Energy Alaska,LLC Location Oooguruk Island Well ODSN-42B Well Information Casing/Liner Size 4.5 in/114.3 mm Depth MD 2669 m/8756 ft BHST 57°C/135°F Hole Size 6.75 in/171.45 mm Depth TVD 1834 m/6018 ft BHCT 49°C/120°F Pressure 246 bar/3570 psi Drilling Fluid Information Mud Supplier Name Baroid Mud Trade Name Density Cement Information-Tail Design Conc UOM Cement/Additive Sample Type Sample Date Lot No. Cement Properties HalCem IPT Slurry Density 15.798 lbm/gal HALAD-413(PB) Slurry Yield 1.1743 ft3/sack 0.45 %BWOC SCR-100(PB) Water Requirement 5.0845 gal/sack Total Mix Fluid 5.08 gal/sack Water Source Sea Water Water Chloride Pilot Test Results Request ID 2204553/2 Mixability(0-5)-0 is not mixable 31/DEC/2014 1lixahility rating(0-5) Avg rpm mixing under load(--12,000) 5 12000 Thickening Time i.Hesitation 31/DEC/2014 Test Temp("F) Reached in Pressure(psi) Initial Stirring cycle Static cycle Start BC 30 BC(hh:min) 50 BC(hh:min) (min) shutdown time(min) time(min) (min) 135 33 3570 5 10 5 6.3 4:44 4:59 This report is the property of Halliburton Energy Services and neither it nor any part thereof,nor a copy thereof,is to be published or disclosed without first securing the expressed written approval of Halliburton.It may however be used in the course of regular business operations by any person or concern receiving such report from Halliburton.This report is for information purposes only and the content is limited to the sample described.Halliburton makes no warranties,expressed or implied,as to the accuracy of the contents or results.Any user of this report agrees Halliburton shall not be liable for any loss or damage regardless of cause,including any actor omission of Halliburton,resulting from the use hereof. Page 25 of 28 Global Customer Report HALLIBURTON CAELUS ENERGY ALASKA LLC ODSK-42i Cement Squeeze API Fluid Loss 30/DEC/2014 Test Temp("F) Test Pressure(psi) Test Time(min) API FL(cc/30 min) Meas.Vol. Conditioning time (min) 135 1000 30 72 36 30 Free Fluid API 10B-2/ISO 10426-2 01/JAN/2015 Con.Temp(F) Cond.Time(min) Static T.(F) Static time(min) Incl.(deg) %Fluid 135 40 135 120 45 0 UCA Comp.Strength 06/JAN/2015 End Temp Pressure 50 psi 500 psi 8 hr CS 12 hr CS 16 hr CS 24 hr CS 48 hr CS End CS End Time ("F) (psi) (hh:mm) (hh:mm) (psi) (psi) (psi) (psi) (psi) (psi) (hrs) 135 3000 7:02 8:16 466 1403 2026 2709 3324 3816 107 API Rheology 01/JAN/2015 Temp("F) 600 300 200 100 60 30 6 3 Cond Time PV/YP (min) 80 213 94 67 35 28 18 9 8 0 86.4/8.51 API Rheology 01/JAN/2015 Temp("F) 600 300 200 100 60 30 6 3 Cond Time PV/YP (min) 135 210 119 85 51 35 22 7 5 40 113.08/8.93 This report is the property of Halliburton Energy Services and neither it nor any part thereof,nor a copy thereof,is to be published or disclosed without first securing the expressed written approval of Halliburton.It may however be used in the course of regular business operations by any person or concern receiving such report from Halliburton.This report is for information purposes only and the content is limited to the sample described.Halliburton makes no warranties,expressed or implied,as to the accuracy of the contents or results.Any user of this report agrees Halliburton shall not be liable for any loss or damage regardless of cause,including any act or omission of Halliburton,resulting from the use hereof. Page 26 of 28 Global Customer Report • 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable b direct inspection of the file. ® - 5 Well History File Identifier Organizing (done) ❑ Two -sided 1 111 ❑ Rescan Needed II 111111 III 1 RE AN DIGITAL DATA OVERSIZED (Scannable) C Ior Items: ❑ Diskettes, No. ❑ Maps: C Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: 7/! 3 /s/ Project Proofing 1 1111111 I IIII BY: Maria Date: / /s/ fl Scanning Preparation x 30 = 1 a d + 1 U = TOTAL PAGES ' 3 (Count does not include cover sheet) r BY: Maria Date: �� (3 /s/ f Production Scannin g 13111 11111 Stage 1 Page Count from Scanned File: 13 7 (Count does include cove heet) Number in Scan in Preparation: t/ YES NO Page Count Matches u g p BY: (Mari Date: 7' 1 3 /s/ y l4 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 1 ReScanned III 11111111 IIII BY: Maria Date: /s/ Comments about this file: Quality Checked I 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 8/14/2012 Permit to Drill 2091560 Well Name /No. 000GURUK KUP ODSK -42A Operator PIONEER NATURAL RESOURCES AL API No. 50 -703 - 20605 -01 -00 ( 7 MD 9758 TVD 6672 Completion Date 12/30/2009 Completion Status 1WINJ Current Status 1WINJ `eft. REQUIRED INFORMATION Mud Log No Samples No Directional Su - DATA INFORMATION ■ Types Electric or Other Logs Run: LWD, MWD, GR, DIR, EWR, PWD, ALD, CTN, BAT / SONIC, GR, CC (data taken from Logs Portion of Master Well Data Maint Well Log Information: III Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED g-; C: Las 19376 Induction /Resistivity 150 9759 Open 2/24/2010 OH LAS, DLIS, LWD EWR Data Plus CGM, PDF, & Ci -, TIFF Graphics ED C Las 19377 Induction /Resistivity 150 9759 Open 2/24/2010 OH LAS, DLIS BAT Bi- I Modal Acoustic & EWR Data Plus CGM, PDF, & TIFF Graphics Log _,--" Induction /Resistivity 25 Col 153 9758 Open 2/24/2010 MD DGR, EWR, ALD, CTN, BAT Log - Induction /Resistivity 25 Col 153 9758 Open 2/24/2010 TVD DGR, EWR, ALD, CTN, BAT Log Induction /Resistivity 2 Col 153 9758 Open 2/24/2010 MD DGR, EWR, ALD, CTN Log Induction /Resistivity 2 Col 153 9758 Open 2/24/2010 TVD DGR, EWR, ALD, CTN Lo Induction /Resistivity 5 Col 153 9758 Open 2/24/2010 MD DGR, EWR, ALD, CTN III Loy Induction /Resistivity 5 Col 153 9758 Open 2/24/2010 TVD DGR, EWR, ALD, CTN Log/' Cement Evaluation 15 Col 153 9758 Case 2/24/2010 MD BAT Bi -Modal Acoutic, DGR Dual Gamma Ray Log / Cement Evaluation 5 Col 8510 9490 Case Advanced Cement L Evaluation Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 8/14/2012 Permit to Drill 2091560 Well Name /No. 000GURUK KUP ODSK -42A Operator PIONEER NATURAL RESOURCES AL API No. 50- 703 - 20605 -01 -00 MD 9758 TVD 6672 Completion Date 12/30/2009 Completion Status 1WINJ Current Status 1WINJ UIC Y ADDITIONAL INFORMATION Well Cored? Y % /t /NN Daily History Received? / � Chips Received? - -L-N -- Formation Tops �!/ N Analysis Received? Comments: • Compliance Reviewed By: __ Date: F • it c -.1. STATE OF ALASKA RECEIVEL EL . ALASIOIL AND GAS CONSERVATION COMMISIJ REPORT OF SUNDRY WELL OPERATIONS MAR 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate o Atekagl& Gds Cons. !Arminian Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Ancno=ne Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Pioneer Natural Resources Alaska Inc Development ❑ Exploratory ❑ ✓ 209 -156 3. Address: 700 G Street, Suite 600 Stratigraphic Service ell 6.ePl Number,:0 err) Anchorage, AK 99501 50- 703- 20605 7. Property Designation (Lease Number): . 8. Well Name and Number: ADL 355036 , ODSK -42Ai 9. Field /Pool(s): Oooguruk - Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 9758 feet Plugs measured N/A feet true vertical 6672 feet Junk measured N/A feet Effective Depth measured 9751 feet Packer measured See Below feet true vertical 6666 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3251' 10 -3/4" 3289' 2980' 5210 psi 2470 psi . Intermediate 8616' 7 -5/8" 8654' 5963' 6890 psi 4790 psi Production Liner 1232' 4 -1/2" 8521' - 9753' 5884' - 6666' 8430 psi 7500 psi Perforation depth Measured depth 8736' - 8756' feet True Vertical depth 6004' - 6015' feet Tubing (size, grade, measured and true vertical depth) 3 -1/2 ", 9.3# L -80, TSHP 8538' MD 5900' TVD TSP Liner Top Pkr Packers and SSSV (type, measured and true vertical depth) TRSSSV @ 745' Prod Pkr 0 8300' @ 8537' MD /5899' MD/745' TVD MD/5761' TVD TVD 11. Stimulation or cement squeeze summary: High Presssure Break Down Intervals treated (measured): 8736' - 8756' Treatment descriptions including volumes used and final pressure: 800 bbls slickwater; 27 bbls diesel; 4452 lbs 20/40 Carbolite proppant Average treating pressure = 4054 psi @ 16.6 bpm; Final Pressure = 2876 psi 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 500 N/A Subsequent to operation: 0 0 650 474 2736 13. Attachments: 14. Well Class after work: .. Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ICJ WAG ❑ GINJ p SUSP ❑ SPLUG ❑ 16. 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: 311 -012 Contact Tim Crumrine, 343 -2184 Prepared By: Kathy Campoamor, 343 -2183 Printed Name Tim Crumrine Title Completions Engineer Signature �— Phone 343 -2184 Date 3/9/2011 G. RBDMS MAR 1 UM d6r)--L .,i/`., 3. /0 •(/ Form 10 -404 Revised 10/2010 / /f/ t �/�� Submit Original Only PIONEER Operations Summary Report • NATURAL RESOl1ROES Well Name I Job Category ODSK -42Ai I WELL SERVICE Start Depth FootIM a ss Dens last Start Date End Date (RKE) (tU Mud (Iblpel) Summery 2/6/2011 2/7/2011 0.0 Ice Road closed due to water flooding near land ice transistion. Dry Watch SLB frac equipment. Load water in tanks until 0800 when biocide treatment begins at STP. Shoot FL in IA - at surface. Rig flange to allow holding pressure on IA. 2/7/2011 2/8/2011 0.0 Instal stinger tool. RU SOS lines and pressure test. Pressure up IA to 2500 psi using Pollard. Mix and . HPBD with Xsik C-H20 as per p ram. 800 bbis sl ; 27 bbls diesel freeze pro e.. ' urry cam" . o at ,,,:. st' l r .5 ppg 24 40 Ca .. ite proppant. Average treating pressure 4054 psi with an average pump rate of 16.6 bpm. Total proppant = 4452 lbs. 5D and monitor WHP. Monitor period was only 10 minutes due to seal tenure on pump while pumping job. RD stinger and SOS lines across island. Injec tivity test will be performed after getting N -18 lined out due to P-6 usage to dispose of produced flulds. 2/8/2011 2/9/2011 0.0 Perform injectivity test with CH2O at header pressure. Open 1" choke and increase flowrate from 750 bpd to 3000 bpd. Monitor WH pressure and flowrate with choke full open at 64 beans. WH pressure and rate cQ 64 beans = 2780 psi and 2900 bpd. Monitor WH pressure and flow rate until injection trend is stable. Adjust choke as needed. Page 112 Report Printed: 3/8/2011 • apro 2.69- 1567 JIECBANICAL INTEGRITY RE ?UD D =E : 1ZJ/o /61 OPER & FIELD / e x a t. - (�Do� r• RIG RELEASE: • IZ /•y /OS NUt•03ER D bSK- 1 12/1(4 ELL DATA TD : J 7 S a 2�... (072 'r'VD. ; = 3TD : TVD Casing Casing: 7 %g 4 Shoe: ` GSY JO 5q 63 TVD; DV: - SID . .T.VD , in „ Shoe dt7S .lam akci TVD • TOP MD TVD Tubing 3. leletioes r53� i r TVD; Set ,, 8306 „ /�7i ole Size Co 3 4 and ; Perfa 273 to SG ' :C ?J.NIC AL INTEGRITY - PART #1 • Annulus Press Test: IP j (nom r ak 15 min 3 min 4 4 6 ° • 2 /Z4 /0 S R Co eats : 30 �^ - s a'• ^`.? • MECHANICAL YNTEGRIT i - PART # 2 Cement Volumes: Amt. Liner Y S - . 6 ;14 - 4 441 DV Cant vol to cove= perfs ' .Z3 8BLS s & s 4 Theoretical TOO Tbp L-►. VS Cement Bond Log 11V or No) CSI-- ; In AOGCC File C$L Evaluation, one above perfs , P ,, 8 ?3G " c 1 .e4.eo,2 (1" Prod.utzion Log: Type A ; Evaluation CONCLUSIONS P srt #1 : I,c%'- -hess...Q M 1A ? j : "- 8 / pie' • L SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMNIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tim Crumrine Completions Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk River Oil Pool, ODSK -42Ai Sundry Number: 311 -012 Dear Mr. Crumrine: Enclosed is the approved Application for Sundry Approval relating to the above note the conditions of approval well. Please PP roval 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 holida or weekend. Sincerel, Jo .4 ► orm:n . m • sioner DATED this /9 day of January, 2011. Encl. 1 b 4 A STATE OF ALASKA 11 w • /, ALASKA OIL AND GAS CONSERVATION COMMISSION ' ` rk � APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate El Pull Tubing ❑ Time Extension El Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate El - Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development ❑ Exploratory ❑ 209 -156 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service 6. API Number: 0 1 / ;p ;, l4• / Anchorage, AK 99501 50- 703 -20605 7PJ-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: rr property line where ownership or landownership changes: Spacing Exception Required? Yes CI No El ODSK -42Ai 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 355036 ' Oooguruk - Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9758' - 6672' . 9751' 6666' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3251' 10 -3/4" 3289' 2980' 5210 psi 2470 psi Intermediate 8616' 7 -5/8" 8654' 5963' 6890 psi 4790 psi Production Liner 1232' 4 -1/2" 8521' - 9753' 5884' - 6668' 8430 psi 7500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8736' - 8756' 6004' - 6015' 3 -1/2 ", 9.3# L -80, TSHP 8538' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): Wellstar TRSV; Hyd Production Packer; TSP Liner Top Packer 745' MD/745' TVD; 8300' MD/5761' TVD; 8537' MD/5899' ND 12. Attachments: Description Summary of Proposal el 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El , 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/28/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 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 Tim Crumrine, 343 - 2184 Printed Name Tim Crumrine, 343 - 2184 Title Completions Engineer Signature - - ,11:). __ Phone Date Prepared By: Kathy Campoamor, 343 - 2183 1/13/2011 .4..,,, — ,-- _. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: j 1 I 019 Plug Integrity El BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance El Other: NEC E ti :r JAN 14 2011 Subsequent Form Required: /Q -- - Y 0 a ka G0 et C 7, , / APPROVED BY �p Approved by: COMMISSIONER THE COMMISSION ne 0!'i te: /.•! f -f( I " /•/1 ,•D /-/,1" Form 10 -403 • - JAN ; 1 G I N A L S ubmit' li �� , fi t it • PIONEER NATURAL RESOURCES ALASKA ODSK -42Ai High Pressure Breakdown /Step Rate Test Objectives: A. Well is under injecting, attempt HPBD to increase injectivity. B. Perform HPBD and then a step rate test to evaluate need for booster pump. Procedure: 1. MIRU Schlumberger tanks. Load tanks with seawater. 2. Heat fluids to 100 deg. Using hot oil truck. 3. MIRU Schlumberger frac pumps and associated equipment. 4. Line up P -6 and pressure up IA using diesel to 2500 psi. I/ 5. Rig up tree saver and associated lines to tree. Pressure test treating iron. 6. Pump the following at max rate allowable to maintain the WH treating pressure below 5000 psi. It is assumed that due to the 3.5" tubing a maximum of 20 -25 b/m will be the treating rate. a. 100 bbls slick water b. 200 bbls slick water with 0.5 ppa 16/30 carbolite c. 500 bbls slick water d. 20 bbls diesel for freeze protect and clear lines. 7. SD pumping and monitor WHP falloff for 1 hour. 8. Record WHP, BHP and BHT. 9. RD stinger and Schlumberger frac head and hard line. 10. Come on line with P -6 and seawater at 0.5 b /m. When WHP and BHP have stabilized maintain stable rate for 1 minute and move to the next step. The goal for this step rate test is to see if injection rate that can be accomplished using the available seawater with an injection pressure of 2800 psi. 11. Increase rate to 1 b/m , monitor for stabilized injection rate. Repeat for 1.5, 2 and 3 b /m. 12. Freeze protect well with 20 bbls diesel and SI. If injection is available return well to injection and do not freeze protect. 13. Bleed IA down to 200 psi. ODSK -42Ai HPBD $ • STATE OF ALASKA ALASKA* AND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well LJ Plug Perforations 11 Stimulate LJ Other U Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: '§i. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Development ❑ Exploratory ❑ 209 -156 3. Address: 700 G Street, Suite 600 Stratigraphic❑ Service El 6. API NuKnber: Anchorage, AK 99501 \ 50- 703 - 20605 -01 -00 7. Property Designation (Lease Number): N. 8. Well Name and Number: ADL 355036 , ODSK -42Ai 9. Field/Pool(s): Nt Oooguruk - Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 9758 feet Plugs (measured) N/A feet true vertical 6672 feet Junk (measured) N/A feet Effective Depth measured 9751 feet Packer (measured) See Below feet true vertical 6666 feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3251' 10 -3/4" 3289' 2980' 5210 2470 Intermediate 8616' 7 -5/8" 8654' 5963' 6890 4790 Production Liner 1232' 4 -1/2" 8521' - 9753' 5884' - 6668' 84'3►►0 7500 Perforation depth: Measured depth: 8736' - 8756' (rc ��� r ) E "' £ I AIiti 2 4 True Vertical depth: 6004' - 6015' Tubing (size, grade, measured and true vertical depth): 3 -1/2 ", 9.3# L -80, TSHP A �� 5900' TVD Wellstar TRSV, Hyd Production Pkr, TSP LineV�kr; Packers and SSSV (type, measured and true vertical depth): 745'MD/745TVD 8300'MD/5761TVD 8537'MD/5899TVD 11. Stimulation or cement squeeze summary: Re- perforate original interval depths, 20' gun, 6 spf @ 60° phasing - all shots fired Intervals treated (measured): 8736' - 8756' 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: 0 0 0 355 700 Subsequent to operation: 0 0 0 355 650 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service 0 Daily Report of Well Operations X 15. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ E ` SPLUG El 16. 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: 310 -218 Contact Tim Crumrine, 343 - 2184 Prepared By: Kathy Campoamor, 343 - 2183 Printed Name Tim Crumrine Title Staff Completions Engineer Signature --_ Phone 343 -2184 Date 8/24/2010 RBDMS AUG 2 5 2010 dl1 q • HO A " Form 10 -404 Revised 7/2009 Submit Original Only ` PIONEER "Operations Summary Report • NATURAL RESOURCES Well Name: ODSK -42Ai Contractor: NABORS DRILLING Rig Number: 19AC Job Category: WELL SERVICE Start Date: 7/22/2010 End Date: 7/24/2010 Depth Start Foot/Meters Last Mud Start Date End Date (ttKB) 0t) Dens fib/Sal) Summary 7/22/2010 7/23/2010 0.0 Move CTU 8 to ODS. perform of unit and BOP test. AFE- 018838 P 7/2312010 7/24/2010 0.0 MU CTC and pull test to 20k. Good MU remainder of tool string including MHA, 2 -318' motor, and underreamer. Load vac truck with C -H20 and add 10 gal J313. {friction reducer) Pressure test on backside to 2000 psi. RIH with underreamer assembly. Take returns to test header holding WHP at 1000 psi. At 8745' CTMD saw a slight weight bobble and passed through. Continue to RIH to 8820'. No problems seen. POOH to 8600'. On line with X -slk C -H20 at 0.5 b/m. WHP -1038 CTP -1161 up wt 14K. Pull up and and gently tag tailpipe. Pressure increase of 100 psi noted at 8519' CTMD no weight increase seen. SD pump and drop back down with coil . Repeat procedure 2x. Saw pressure increase again at 8519' CTMD. SD pump and flag pipe. POOH. Lay down lubricator and change pack -off. RD for night. AFE- 018838 7/24/2010 7/25/2010 0.0 MU gun #1, 20'. Pressure test surface equipment to 2000'. RIH to flag. Correct depth and continue RIH to 8760'. Pick up and put gun on depth with top shot at 8736'. Drop ball and displace with CH2O. Ball on seat with 38 bbls away. Pressure up to 3523 and fire nun to reperf interval 8736' - 8756' at 6 spg with random orientation and 60 degree phasing. POOH with gun #1. All shots fired. RDMO. Return well to injection. (Note:Total of 49 bbls CH2O pumped in well to reperf) AFE - 018838 Page 1/1 Report Printed: 8/19/2010 •Current Schematic - State Well Name: ODSK -42Ai PIONEER NATURAL RESOURCES Well Profile: HOBIZONTAL Sidetrack 1 8/23/2014 1'4 3 "We Attributes >, k,„;" .. '' r: , "`s°..t" DheMattG4 ✓, ; r APWWI Field Name Well Status Total Depth (ftKB) 50- 703 -20605 -0100 Oooguruk Unit DRILLED 9,758.0 Casin • Strin • s Conductors �, ` � , K1 r ; , , , C Casing Description String 0... Stnng ID ... Top (ftKB) Set Depth (ft... Set Dept... String Gr... String Top Thrd String Wt (I... Conductor 16 14.670 47.7 158.0 158.0 H40 Welded 109.00 Casin • Com • onents T..),,,,,. No Item i i : , , ,.: " (TVD) ( s : . , tom: 1 -1 Conductor Shoe 47.7 47.7 16 14.670 .: 4 Surface g°: 1' _ ' .'" , x Casing Description String 0... String ID ... Top (ftKB) Set Depth (ft... Set Dept... String Gr... String Top Thrd String Wt (I... 1 -1 Surface 10 3/4 9.794 38.2 3,289.2 2,980.0 L -80 BTC 45.50 Casin • Com • onents ;' 1-10 E �•tio. Item Description :11(Kt3 . }• ft 4 '!, t D to " - ,t ^, 6: Comment 2 -7 10 3/4" Surface Casing 3,287.4 2,979.0 10 3/4 9.794 HES Super Float II Shoe Shoe gitgrMiiiiii6 6544 OftKB : ::" r < » : Casing Description String 0... String ID... Top (ftKB) Set Depth (ft... Set Dept... String Gr... String Top Thrd String Wt (I... ® Intermediate 7 5/8 6.875 37.7 8,654.0 5,962.7 L -80 BTC -M 29.70 Casin • Com • onents ! TPp DeA 1 -16 1' item De$ot(ption r ",Top (ftKB)', (TW Xft OD.j #' ID( coronet*: ■ 3 -7 7 5/8" Intermediate Casing 8,652.3 5,961.9 7 5/8. Shoe I < •duction Liner 9,753AftK6 A .A- .A gv,i < Z F ® Casing Description String 0... String ID ... Top (ftKB) Set Depth (ft... Set Dept... String Gr... String Top Thrd String Wt (1... MI 1 Production 4 1/2 8,520.9 9,753.0 L -80 HYD 521 12.60 Liner Casin • Com • onents a D epth item... :. r . �. Di (. } : 1-28 4 -1 WFT PBR Tie -Back Sleeve 8,520.9 5,890.2 6 1/4 4 -2 TSP Liner Top Packer 8,537.3 5,899.4 6 1/4 4 -3 Hydraulic Liner Hanger 8,540.3 5,901.0 6 1/4 [ 4 -10 4 1/2" Production Liner 9,750.8 5 3/4 Reamer Shoe 1-34 Shoe 1 Tubin • Strin • s i Tubing Description String 0... String 1... Top (ftKB) Set Depth (... Set Dep... String Wt ... String G... String Top T... Completion 31/2 34.1 8,537.7 5,899.6 9.30 L -80 TSHP Tubin • Com • onents I tem '3 p e ®'.pth 1 -41 Na `4tem Desen' tort - W « fitKB) " : KB) a s 1 u P . € l! 1 - 10 HES Wellstar TRSV 2.813" 745.5 745.4 3 1/2 ® X profile 1 t 1 -16 Van Oil GLM 3.5 MMG x 3,455.3 3,076.3 3 1/2 t 1.5" 1 48 1 -22 Van Oil GLM 3.5 MMG x 8,055.4 5,634.3 3 1/2 ® 1.5" ti 1 -28 WFT Gauge Carrier 8,139.1 5,681.0 3 1/2 1. i 1 -34 HES 2.813" "X" nipple 8,217.3 5,724.1 3 1/2 1 -41 WFT UltraPak "TH" hyd 8,299.8 5,769.0 3 1/2 1 -54 i perm prod pkr ® 1 -48 HES 2.813" "X" nipple 8,388.9 5,818.1 3 1/2 1 -54 HES 2.813 "XN" nipple w/ 8,465.6 5,858.5 3 1/2 al ' re 2.75" No -Go igE 1-59 ii 1 -59 3.5" TC -II Tubing Tail 8,536.4 5,898.8 3 1/2 WLEG w/ 3.5" TCII box 41 t 4 -2 I I 4 -3 • a 4 -10 Page 1/1 Report Printed: 8/23/2010 • • SlinfE 1:11 ALASKA 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 Tim Crumrine Staff Completions Engineer Pioneer Natural Resources Alaska, Inc. 0 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK -42Ai Sundry Number: 310 -218 Dear Mr. Crumrine: 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. Sincerel ;` oh . Norman • • issioner DATED this 9 ( day of July, 2010. Encl. } ?IONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277 -2700 Fax: (907) 343 -2190 July 20, 2010 State of Alaska ECE %\ 0 Alaska Oil and Gas Conservation Commission 333 West 7 Ave, Suite #100 IlA 2 . ‘1 ZO Anchorage, AK 99501 Masks t & Gas rms. Commission RE: Application for Re- perforating ODSK -42Ai Ancfiarge Dear Mr. Schwartz: Please see the attached Application for Sundry Approval for Re- perforating an Existing Interval • in Pioneer's ODSK -42Ai injection well. Included with this request is a detailed operations summary for the proposed work. The first part of the procedure is for the fill clean out of the' well. This part includes how we propose to correlate the perforating guns on depth. In June 2010, Pioneer completed a drift and tag in which a tubing end locator was utilized to measure the distance between the end of the tubing and top of the fill. We then correlated the top the fill with the driller's tubing tally, gamma ray log, and cement bond log. When the top of the fill is tagged with the coiled tubing, we propose to flag the pipe for our coiled tubing conveyed perforating. The highlighted section of the procedure details the perforation plan and shows that we intend to perforate the exact same depth from 8736' MDrkb to 8756' MDrkb in the Kuparuk reservoir. Estimated commencement of the perforating is July 23, 2010. Since we do not have a coiled tubing unit staged on the island, this timing will allow for us to mobilize a unit during barge season, and since the Toad is considerable to also take advantage of favorable tides. Sincerely, Tim Crumrine, P.E. Staff Completions Engineer Attachments: Form 10 -403 Supporting Sundry information cc: ODSK -42Ai Well File • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate El • Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ I Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development ❑ Exploratory ❑ 209 -156 • 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service 0 , 6. API Number: Anchorage, AK 99501 50- 703 - 20605 -01 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No iv ODSK - 42Ai . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 355036 • Oooguruk - Kuparuk 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): 9758' , 6672' • 9751' • 6666' • N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3251' 10 -3/4" 3289' 2980' 5210 2470 Intermediate 1 8616' 7 -5/8" 8654' 5963' 6890 4790 Intermediate 2 Liner 1232' 4 -1/2" 8521' - 9753' 5884' - 6668' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8736' - 8756' 6004' - 6015' 3 -1/2 ", 9.3# L -80, TSHP 8538' Packers and SSSV Type: Wellstar TRSV; WFT UltraPak -TH Pkr; Packers and SSSV MD (ft) and TVD (ft): 745' MD/745' TVD; 8300' MD/ TSP Liner Top Pkr 5761' TVD; 8357' MD /5899'TVD 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/23/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 • 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 Tim Crumrine, 343 -2184 Printed Name Tim Crumrine, 343 -2184 Title Staff Completions Engineer Si nature Phone Date Prepared By: Kathy Campoamor, 343 -2183 7/20/2010 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / -318" Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RECEIVED � JUi_ 2 : 013. 2010 ::::::::::rm Required: / � `� ��� ;�� �# � �� AOcherao . Cl�,mi l °9 APPROVED BY TT • MIS THE COMMISSION Date: �?i/ .... RBDMS . 2 tiorli . 161 N A L * 70 submn5e 72 /D Fo rm 10 -403 Re1/20 • • Coiled Tubing Fill Clean Out and Reperforation Procedure 1. MIRU CTU #8. Flange up extra swab valve on tree below coil BOP's. Perform weekly BOP test using xslk water. 2. Load C -H2O at CPF -3. Mix J -313 friction reducer. Seawater temp is 60 deg from CPF -3. This temp has been cleared for mixing SLB friction reducer a. (10 gals. In a 300 bbl truck) 3. Pick up lubricator to cover UR BHA. (Lubricator needed is estimated at 30') 4. MU CTC and pull test to 15k. MU remainder of MHA. Min restriction is 2.75" at 8466' MD (XN nipple) Ensure the disconnect ball will pass through the MHA. 5. MU UR BHA. 6. Stab on well and pressure test lubricator to 4000 psi by pumping down coil at a low rate so as not to open UR arms in lubricator. • DO NOT TAG SWAB VALVE WITH THE UR ASSEMBLY. 7. Line up well to take returns to flowback tanks. 8. RIH with UR and tag bottom. Take returns as needed while RIH. Note coil tubing depth at this point. Correct back to the slickline tag of 8744' and adjust counters accordingly:: Pick up 20', come on line pumping and open UR arms. Gently ease back down and UR through existing perforation interval. (8736 -8756' MD). During June slickline drift and tag, a tubing end locator was run. Information was used to correlate top of fill with GR log 9. It is expected that we have a hard crust at the top of the obstruction and that there is Marcit gel below. 10. UR down to 8780' CTMD. Pick up to top of perfs and ensure clear and easy passage. 11. Drop back down to 8780 and pump a final slug of gel /xslk followed by 10 bbls xslk water. Drop circ sub ball and chase with xslk water. 12. Shear circ sub and chase slug out of the hole at 80% while POH. 13. Flag pipe at top of perfs as POH. 14. When final slug has cleared surface lines the pumping can be shut down as coil continues OOH. 15.At surface, lay down UR assembly and pick up 20' perf gun. (PowerJet 2506 Deep Penetrating 2.5" gun (2.66" swell in liquid) loaded at 6 spf with random orientation and 60 deg phasing). Ensure Dimpleon type connector is used. Remove circ sub from MHA assy. Do not perforate until copy of Sundry is approved by AOGCC 16. Pressure test lubricator on the backside. Do not pump down the coil with a live gun on the bottom. 17. RIH to flag painted in Step 12. Adjust counter. RIH to below perf interval. Pick back up to position gun in tension. Drop ball and circulate down using water. Fire gun with ball on seat. POH with gun #1. 18. POOH. Note any shots that did not fire. 19. RD down coil and return well to operations for injection. PIONEER Current Schematic - State Well Name: ODSK -42Ai NATURAL RESOURCES Well Profile: HORIZONTAL - Sidetrack 1, 6/10/2010 1:5... Well Attributes Schematic - Actual API /UWI Field Name Well Status Total Depth (ftKB) 1 . 50 -703- 20605 -0100 Oooguruk Unit DRILLED 9,758.0 Casing Strings Conductor, 158.0ftKB Casing Description String OD... 'String ID ... Top (ftKB) !Set Depth (ft... Set Dept... String Gr... I String Top Thrd String Wt (I... Conductor 16 14.670 47.7 158.0 , 158.0 H40 I Welded 109.00 Casin Com onents Item Top Depth No. Item Description Top (ftKB) (TVD) (ftKB) OD (in) ID (in) Comment 1 - Conductor Shoe 47.7 47.7 16 14.6701 • I - Surface, 3 289 2ftKB Casing Description String OD... String ID ... Top (ftKB) Set Depth (ft... !Set Dept... String Gr... String Top Thrd IString Wt (I... 1' Surface 103/4 9.794 38.2 3,289.2 12,980.0 L-80 BTC ' 45.50 Casin Components Item Top Depth 1 -10 1' No. Item Description Top (ftKB) (TVD) (ftKB) OD (in) ID (in) Comment 1 2 -7 '10 3/4" Surface Casing 3,287.4 2,979.0 10 3/4 9.794 HES Super Float II Shoe I Shoe Intermediate, 8,654.0ftKB Casing Description String OD... String ID ... Top (ftKB) Set Depth (ft... Set Dept.. String Gr... String Top Thrd '.String Wt (I... • ® Intermediate 7 5/8 6.875 37.7 8,654.0 5,962.7 L -80 BTC -M 29.70 Casin Components I Item Top Depth 1 -16 1 No. Item Description Top (ftKB) (TVD) (ftKB) OD (in) ID (in) Comment 3 -7 7 5/8" Intermediate Casing 8,652.3 5,961.9 7 5/8 Shoe 1 Production Liner, 9,753.0ftKB • , Casing Description String Set Dept... String Gr... String Top Thrd String Wt (I... ® f Production 4 ng 1 /2... lD... Top se 20.9 9,753 L -80 HYD 521 12.60 Liner i 1 Casing Components 1 Item ( Top Depth No. Item Description Top (ftKB) (TVD) (ftKB) OD (in) ID (in) Comment I 1 - 281 4 -1 WFT PBR Tie -Back Sleeve 8,520.9 5,890.2 6.38 5.750 1 4 -2 TSP Liner Top Packer 8,537.3 5,899.4 6.65 4.750 I 4 - Hydraulic Liner Hanger 8,540.3 5,901.0 6.7 4.750 4 - WTF Landing Collar 9,669.1 6,604.7 4 3/4 1.375 1 tl 4 - 4 1/2" Production Liner 9,750.8 5 3/4 Reamer Shoe I Shoe I , Tubing Strings a Tubing Description String 0... String I... Top (ftKB) Set Depth (... 'Set Dep... String Wt ...IString G... String Top T... - Completion , 31/2 34.1 8,537.7 5,899.6 9.30 I L -80 I TSHP I Tubing Components 1-41 1 Item - Top Depth No. Item Description Top (ftKB) (TVD) (ftKB) OD (in) ID (in) Comment I 1 -10 HES Wellstar TRSV 2.813" 745.5 745.4 5.2 2.813 I 1! X profile i 1 -16 Van Oil GLM 3.5 MMG x 3,455.3 3,076.3 5.43 2.992 1 1.5" 1-48 I i 1 -22 Van Oil GLM 3.5 MMG x 8,055.4 5,634.3 5.43 2.992 I 1.5" I ' 1 -28 WFT Gauge Carrier 8,139.1 5,681.0 5 3/16 2.992 1 1 -34 HES 2.813" "X" nipple 8,217.3 5,724.1 3.95 2.813 1 -54 I 1 -41 WFT UltraPak "TH" hyd 8,299.8 5,769.0 6 1/2 2.992 I perm prod pkr I 1 -48 HES 2.813" "X" nipple 8,388.9 5,818.1 3.95 2.813 • • 1 -54 HES 2.813 "XN" nipple w/ 8,465.6 5,858.5 3.98 2.813 h 2.75" No -Go 1 -59 , 14 -1I 1 -59 3.5" TC -II Tubing Tail 8,536.4 5,898.8 3.93 2.992 WLEG w/ 3.5" TCII box - 4 -2 l 4 -3 • ► -I3 -71 11-H 4 -61 NI -14 -101 Page 1/1 Report Printed: 6/11/2010 STATE OF ALASKA ALASPOIL AND GAS CONSERVATION COMMIS ON REPORT OF SUNDRY WELL OPERATIONS '' 1. Operations Abandon L Repair Well L Plug Perforations L Stimulate Neater Shut -Off Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Twsion ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended e t) ■ nn 2. Operator Name: 4. Well Class Before Work: 'b. i gtc ri tuber: Pioneer Natural Resources Alaska, Inc. Development ❑ Exploratory 3. Address: 700 G Street, Suite 600 Stratigraphic [ Anchorage, AK 99501 - 20605 -01 -00 7. Property Designation (Lease Number): \ 8. Well Name and Number: ADL 355036 ` ODSK -42Ai 9. Field /Pool(s): Oooguruk - Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 9758 feet Plugs (measured) N/A feet true vertical 6672 feet Junk (measured) N/A feet Effective Depth measured 9751 feet Packer (measured) See Below feet true vertical 6666 feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3251' 10 -3/4" 3289' 2980' 5210 2470 Intermediate 8616' 7 -5/8" 8654' 5963' 6890 4790 Production Liner 1232' 4 -1/2" 8521' - 9753' 5884' - 6668' 8430 7500 Perforation depth: Measured depth: 8736' - 8756' True Vertical depth: 6004' - 6015' Tubing (size, grade, measured and true vertical depth): 3 -1/2 ", 9.3# L -80, TSHP 8538' MD 5900' TVD Wellstar TRSV, WFT UltraPak -TH Pkr, TSP Liner Top Pkr, Packers and SSSV (type, measured and true vertical depth): 745'MD/745TVD 8300'MD/5761TVD 8357'MD/5899TVD 11. Stimulation or cement squeeze summary: see attached Operations Summary Report Intervals treated (measured): 8736' - 8756' Treatment descriptions including volumes used and final pressure: Tiorco Polymer Gel: 6911 bbls, 3010 psi final injection pressure Freeze Protect w/ 20 bbls diesel 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 2345 48 2581 Subsequent to operation: 0 0 891 361 2050 13. Attachments: \. Well Class after work: Copies of Logs and Surveys Run Exploratory Development Service IN Daily Report of Well Operations X Well Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ 'WAG ❑ GINJ ❑ WINJ El SPLUG ❑ 16. 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: 310 -104 Contact Tim Crumrine, 343 - 2184 Prepared By: Kathy Campoamor, 343 - 2183 Printed Name V Johns Title Drilling Superintendent Signature ��- Phone 343 -2111 Date 5/3/2010 RBDMS MAY 1 0 20'x' u 5 -/e) F rm 1 -404 Revised 7/2009 I ' / Submit Original Only 0 0 J%r A z ! /C F PIONEER Operations Summary Report • NATURAL RESOURCES Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Depth Start Fool/Meters ' Last Mud Stan Pate End Dale (fKB) (t) Dens (Ib/ga) Summary 4/13/2010 4/14/2010 0.0 Standby 4/14/2010 - 4/15/2010 0.0 Sport and rig up Schlumberger pump, TIORCO trailer and tank. Pumped 100 bbl for injectivity test and adjust overall injection rate with Operations injectivitity test OK begin stage one of the gel program 4/15/2010 4/16/2010 0.0 Complete stage one of gel treatment and begin stage 2 at 15:30. Increase of 75 psi seen due to friction in tubing with 35 bbls stage 2 gel away. Final stage one information: SOS inj P -1760 SOS inj rate -0.7 b /m; SOS density -8.7 ppg; TIORCO gel volume -766 bbls. 4/16/2010 4/17/2010 0.0 Complete stage two in squeeze at 0930. Begin stage 3 of squeeze. At 1300 injection rate declining. St 38 to maintain rate. Within 4 hours rate has dropped to 1000 b/d. After discussing with all involved decision made to isolate plant injection and continue with 2000 b/d rate using TIORCO and Schlumberger. 2030- SI plant injection on well. 2200 - On line. Troubleshoot problems with TIORCO unit. 4/17/2010 4/18/2010 0.0 Troubleshoot TIORCO unit. Thaw lines. 0230 - Back on line injecting at 1000 b/d with TIORCO unit stand alone. Increase rates incrementally to 1200 b /d. Hold this rate for approximately 2 hours and rate starts to decline. When injection rate hits 800 b/d displace tubing with 150 bbls C -H20. Rebuild centrifugal and proportioning valve. Both clean. Discuss options with town and TIORCO personnel. Redesign job. 4/18/2010 4/19/2010 0.0 Back on line after redesign. Step up to final CAPIT stage in 80 bbls slugs of varying concentration. Loose main pump and swap to backups with 50 bbls remaining In Capit stage. INJ pressure- 3010.Swap to overflush. 75 bbls 10000 ppm gel followed by 75 bbis c -H2O. 4/19/2010 4/20/2010 0.0 Complete Gel squeeze. Freeze protect well with 20 bbls diesel. Well remains SI for 7 days. RD equipment . Page 1/1 Report Printed: 5/3 /2010 The Science of Enhanced Oil Recovery Treatment Summary For Pioneer Natural Resources Company MARCIT Gel Conformance Oooguruk Field O D S K42Ai North Slope, Alaska April 20, 2010 TIO A NALCO & STEPAN COMPANY • TREATMENT SUMMARY PURPOSE Use MARCITSm polymer gel technology to improve injection conformance. Desired results are 1) improve injection profile, 2) higher injecting bottomhoie pressure, 3) diversion of subsequent injection water to improve sweep efficiency of oil- saturated rock, 4) improve oil recovery and economics. TREATMENT TIORCO equipment and personnel arrived on location on April 13, 2010. Safety meetings were held to discuss potential hazards specific to the job. TIORCO's Portable Unit 11 was connected to frac tanks for treatment supply water and to SLB pumping equipment for polymer solution injection. Additional water was supplied through the injection flow line by Pioneer injection plant. The treatment consisted of 6544 bbls of gel and 367 bbls of water. The treatment started on April 14, 2010 at 7:53 pm with a 100 bbl water preflush and ended April 19 at 12:17 am after pumping a 75 bbl of water for gel displacement. The gel was made -up of 11,110 Ibs of Water -Cut 204 (high molecular weight polymer), 3135 Ibs of Water -Cut 50 (low molecular weight polymer) and 3300 Ibs of Water -Cut 684 (crosslinker). Details for each stage of the treatment, job log, and injection charts are included. Due to issues with the TIORCO equipment the treatment was shortened from the original design. The issues were an inability to pump the desired 1000 BPD of polymer solution to the SLB pumping equipment. The reasons for this issue have not been determined, but will be investigated and reported. There were also issues requiring the polymer feeder to be operated in a manual mode rather than automatic, this will also be investigated and reported. MARCITSr GEL QA/QC Representative samples of cross - linked polymer solution were collected during all treatment stages to ensure that the intended gels would ultimately form. Pre -gel samples were stored at a temperature of 120 °F in an oven onboard the TIORCO portable polymer injection unit. All samples indicated that gels formed as intended. TIORCO is very interested in monitoring and evaluating the results of this treatment with time. If you should have questions or comments regarding the job, please do not hesitate to contact Dick Brown at 907.229.1233 or Dan Larsen at 303.923.6471. We greatly appreciate the opportunity to be of service to Pioneer and look forward to working with you again in the future. 2 • • TREATMENT LOG Date Time Date Time Polymer Gel WHP psi) Pump Rate (bpd) Comments Stage Begin Begin End I End I ppm bbls Begin 1 End Begin 1 End 1 4/14/10 7:53 PM 4/14/10 10:30 PM 0 100 2729 2769 0.993 921 Water PerFlush 2 4/14/10 10:30 PM 4/15/10 3:29 PM 3000 2049 2769 2750 921 2880 3000 PPM Polymer Gel 3 4/15/10 3:29 PM 4/16/10 9:12 AM 4500 2107 2750 2750 2880 3240 4500 PPM Polymer Gel 4 4/16/10 9:12 AM 4/18/10 4:59 AM 6000 1649 2750 2940 3240 993 6000 PPM Polymer Gel Inject water while resolving equipment 4 4/16/10 9:12 AM 4/18/10 4:59 AM 0 192 2990 2725 2040 880 issues 5 4/18/10 4:59 AM 4/18/10 6:55 AM 8000 80 2940 2950 993 979 8000 PPM Polymer Gel 6 4/18/10 6:55 AM 4/18/10 8:57 AM 10000 82 3100 3100 979 960 10000 PPM Polymer Gel 7 4/18/10 8:57 AM 4/18/10 8:45 PM 30000 502 3100 2950 960 1152 30000 PPM Cap -It Gel 8 4/18/10 8:45 PM 4/18/10 10:30 PM 10000 75 2950 2800 1152 1008 10000 PPM Polymer with no Crosslinker 9 4/18/10 10:30 PM 4/19/10 12:07 AM 0 75 2800 2880 1008 1271 Water Post Flush Totals 6911 MARCIT$M GEL QA/QC ..i \,, IY..itmcnt >! : ,.nnplc I).itr ',eii lc 1 !Inc ( tun Rbl. I'<J\Inc! ppm I'ol incr.A -I inl.ri R.un, (unnncnt' 1 2 4/15/2010 10:00 1502 3000 40:1 Gel Formed as intended 2 3 4/16/2010 07:00 3997 4500 40:1 Gel Formed as intended 3 4 4/16/2010 17:00 5042 6000 40:1 Gel Formed as intended 4 7 4/18/2010 15:00 6515 30,000 40:1 Gel Formed as intended 3 Nir 4 0 • RATE, PRESSURE, & CONCENTRATION 3,500 , : .. i i +_.. + -__ ,.... ,.... + _... h ___. { _._ _ _--4- _ a__-4-_. {.-{ L _- } _ - - - .1_,- ... { - ___ { __-- 1 - _G____4 -.; i___ - + -- _. + ___ 1 f---_ -f 1 --- i - _..__�..__ ..4____1 -1 ___ -_ _ - j.. .- -1 -- -- - ?___ i _ - 1 .__j_ . - .1- ._ ' ' .. t__ _ - -1 -- . ;. 0,000 � _-• 3 , -r - ' 1 --- -- - , ! 1 1 : : - 1 --- - ; - - ' 'E - -- ' • __' - �_." i'-- t - - - -i - 1..� -4-. ' ... -1 _ —f_ -1- 1111-! f— t-- 1---- --- t- --i• -- '_i-_-t 3,000 --•- ; -- --- --- t-----!- , -+ { --1- 4- -- -- y - ••'1_ - i-- — t--i--- - - - _ t - - — . {. - 1---- t- ---F--- ---- -- 1-- -}---" 27.500 ._ .. 1 .... r- - - -- 1 1111 1111 " - - ---- ' ---a '--- 1- 1- 111 - - --- -r ' - : t ' 1 ^1 « 1 - -- -- - T - 0 � ' ' I - 2500 - -- �-- - +- 4-- - ±----- i- ---+-- 111 -•f - - --- - --- --t- -4 t i- -4 i i- -t-- --1--- -t---- - ±-- t a-- ---t -- t -- i 4- 1 2,500 - i- i t -� j r - r 7• i .. F } ' -i _ - -; - r -1,- •i i•-- -- - j-- - 0 : : : : -- j ---- j -- 1-4 1- -i.. -- -f-� { -;---1 -i-- — - - - t —1-- i ; - h----+-- °�--- -- --i ---- -----L-j----- ;•-- - +-. .. �..- -a -1----1 1---1 } - ..�.-+---i• -- - � j'• -- —j --� — � --- - -t--- 1111. ..� e-. 1.111- }. . ..1 1111 - --- N : : ! ' - : 0 $ � -• ±-- • +• •- • 1 - -- + .. � .. y ..... i .. .--- +- - -• 1 i t --- F -- - - t -- 1 1. 11 -- j -- - -t-----h- - 11 1 111 - - --- - ' j --- 1 -- -- --;--- j -- �...F_ ..t- 1-- + � 2 •- • -• - , m ; -t- 1 ` -- - -- - 4 - ' = L y m 2 , 000 -.. 4- �____ _ -4 -+ - - : - __ .- - __..____ __ ._ -. _ _ -. .._. 1._ _ _... g W ' ! ! : _L ---i- -- 1 ! --•� -• -' — - - i - - 1 -- -- --- — - - - - - -- ! ---- `---� - -- 1 0 c d -- +"-- ' *--- 11. 11 - - } - -- - -- -� ---- -- - f- -- -t -- - - - --1- - - - -L -- -T•- -- ±- - +', -- 1.111- '- - - - -F -- ± -t' —f ---+ -- — --- F . 1.111 - + ; -- 111..1-- -1- --- , • °G - - +1111 + -- -i-- -- ---- t---+--- i--- i--• -t-•-4- - +-- i- --- 1--- i-- �---4- +- -- -f- -�•'-4— i-- i-- -11 --�--+ i -- 1 -- • -1-- 4-1-f-1111, i---- i : : -[ / t • - 15.000 -- 1 f f _ ? { f t __ t _- + ..�.. y _'i — - }•- i - - - 4-4—f---1--4-- 1 — — { - -- __1.- j a , : : : : m i ,500 __.. t .__ ._ __ _.- - ___ - _ . ____ +___. C 1-, i 7 T 1 -j -j - i i j -j -j - i 1 ? ' i . 4, . - - ? - -- 1-- -- t--- t--- t- -i- ---1 -- '-- -- ---4- -- --t- - - - -- : fi T i T T 1 1 ._- i --.___ 1 .___ y ..__ + .___ __ { ___ y __ i _.�__ y ._. y ... y .._j._- _- }_ -{__- + _�.__i.- _i_ -_�. _{___{_ ___+__. i- __i..._. p f i -. -4-4.-1-- 1---4 ..l__- .__. ___ -1.— _i_ _. -1____ .- 1.___«___.___..-- 1- __L___' -_ _ _ ___1--- - _-- 1____.� 0 00 0 0 _ 1 d 1 000 *-t---- ----f---1-----h-t----f--1 -1---- --- G-•-- +.._i...- - -{---- --1-- 1 -+ — {• 1111 t- --t —+ - - + ... 1 i -- -- \ , : : : : , t _ - -- + ---- i -- -i - -- 4111 11 i --- ! --- i - l .. _+ - -1---1- 11 •- -+- ---- -- --- -- - - - •- -• - --1 -- ----1 - --- --- 1 1-- - 4 -_ 0 • 500 - t --- t -- 1 ---- - --- ± ---- { ---- t ° t i i -F - t --1-- i ---- -- 1 -1---- - ---4 --- ; 1111` -•i -- -- - -- ' - - - - -[--1- --- - -` - - - i ' - , ; H-1-----t - - - -- --_ O . . + 1jt- t--- t--- i---- 1- -+ - -t- 1111 --- f--- F- i- t-- - {, - - 1 f t - i-- i- - - - - 1 - - -- - -i -- ♦ i - ---_- -- + ---- {--- - - - -�_. 0 -- 111 --- -- , . . -- 1- , , . i , , i 1 0 50 O s 1 9 a t • 0 1 to Cumulative BBLS. Injected -- - IN. Rate1BPDI - - -BHP Wye) WHP q,ei, - Poymin Caw. q>P11U • 4 h• Cum. Pressure (PSI Minutes) r 0 0 0 CO ° O o 0 0 0 °O O° c. o °O °O °o °o °o °o °o °o °o °o °o o° °o °o 0 0 0 0 0 o O O o O O ; ' ;`iii j II f i i i 3 111 i 111111111 --r '---F--+, --t--F• - r1- -- 1-- -r-r -t. f j - - t---t - -} - - ± -- - - --- 1--T-- f- -f-- - i � -- -- - t-l---1-1- r--j- --1- i j-- --- — ---F- -1--t-•F---- h-t-•1'-t- +,-•-!--t - - i ---4--1--- - +--t- -t- -I--- - --t -t- -t- - --t-•i--- - 1-±--f--1---h-1-4--t--1-- -- 1--i i i ' 1--1 L 1 I - a i - I 11 1 ` 1 ' i' `- ` j i I - 1 .L i m i_ i 1 s 1 - Li- t1 1-1 i _ - ' I I_ 4 I -! - i i ! i_ J a -' • • • i I I ' l i 1 i I i i 1- i -1 1 i i i i i y l _ 1 i 1 i i 1 i i i 1 ! I i % _ 1 111.i : 1 1 1 i i 1 1 1 t i I ii ii 11 1 1 11 I t t i i i i ' --1 °+ -- ' -- ' - - -' I --- 1-- I j 1 - 1 5--4 - -- -- --4-- -- T -- + - 1 --- 1-- i -- 4 • - {- - { - -- - I i i 1 T 1 1 1 i 1 1 1 1' .1 .1 1 t 1 1 t 1 t 1 I I I -tilt-. '-- --t- j- t- ti-- 1---F- -t--j-- 1 --t-- -. 1-i -r L --{- i -- --t- -- i-- j --j--t--{---j--j- -j- j--�- + j -- - - --1-i -t- t -•t - •t--l- t -f-i-- f --F- t { -F- f - •-t -4- t--F- -- - + - +-•a---F- ---j-- -t- i- 1- -t- - t + -- - • [1 , 1 1 1- • - -- - ---- - - - - -- - -- - --- - -- - - - - -- t4 1- 1 -- 1 I I- { r 1 - - _ - - --- 1 2 - 111i 1 1- { 1 - - 1 1" - - - 1 111 11 11 1 l 11 -e - 1 1 - 1 i i ■∎ i i i i 1 f I i 1 i i iii -- H 11 1-1 1 - 1 1- 1 - 1 i I I j 1 1 �-- L - L L - 1_ 1 _ -L -_ _i_._ 1 II i 1 1 1 1 1 1 1 1 1 {{ 1 __ ___ -- -_ __' _ 1_ 1 i t - _ __ i- f_i _ - i - i tt - i ITf tit T T r1i- { j--11 iri t i-1— r- t--: 1 r -r• i : 1 t - a-- F-- 1- i--i- t--r- + + -1-t- -- 1 -- *-- -•�-- -•{- - -'t-rj- i-4--?- - {----{- -{ I - l'1 I I I 1 1 1 I 11 1 --i I; J q , -- •F- ft-- t-•i•--F -� .-.i -- +.- j-- i-. L-. i-- i_+-- i- . i -- i-- t-•t--!-.F_!- - -, .- t- i- -F -i--F -1—i — -+-- - t , - 1 i IA I L F' 1 1 L- L 1 L 1 1- F ?- i- L-- i -1-1.1+.1 11_1 � . 1_1--1-1-1-1--1 i - j- 1 I c • - -L- 1 -_ 1 -- 1 - -! -- -1 ! -1-I -- 1-- 1--- 1-- , - -j--=- -' -! -l--T- ' -! I 1 ! -' ! - --! - 1- !- -1 --i- i 4__ i _ i_ i p t 11 I L 1 1 1 1 i i i i 1 1 1 1 1 1 - 1 i 1 - - j i i i 1 i 11 1 1 1 to i{ T j rltj }1i f 111 ij �r z i T 1i 1 co t , , � i I i ,,,, t1 r r1 T1 -- ++ i fij ±r1ri -fi i co - L i I : - - 1- -- I -- •' 1-- --k -1 ' t I 1 F l l- 1- 1-- + ' , -- -- i-- + i 4-- i - - - 4 --4-4 --- I ; I co ir. 1- t -1 1 -- 1--1 -1 i- --i- + 1- +'--i-- +- +-{- -+ 1-1-1- +--1- }- 1- -4- 1,- 1- -1- t - 1-- 1 --1 -a- - 1--1- --1- -- � — M I ; .11111111 :1111111111 11 it1l !:1111 ' - --, 1 - 1-- t te _ii - 1 1 1 I i -- iif 1 1 1 1 - r i1i1II1 iI !!1:11 rtr 1 t ; r -t -t- - -t - -r --t fit t � t - t 1 t .... ' • a 4'000 T fi i F ^i i , ' t j --IT j- t,' T --1 {- i - � 1 - s r t ° i T l 7 r f j - i t- t i - - , -- t- ;-- t-- 1-- + - -1 - -+ '-1--F4 -_ +__ ___ __1 1 ____ +__1__ _ __;. 1 __ + __ I __i_ 1 1_1 i + ____- ____ +_ 1 _ __ �_ ---F- ----t--r--F--r_i --�- -4--f--- -t--1- -1 -- , , . - -- - -i --' i. l t iii t I J i -• 1 f - -- -- -- -- - - -- - -- -- -- - -- -- •- -- •- • - 1 - -1--i- - - '' - - -4-- - -1 ' 1--1---1- 1-- -1 - -1- m -_ __ i l l i i 1 i i 1 1 1 1 i '1 , 1 1 1: 1 1 -- _ -1 -i - t - - 1 - • _ - 1 1 1 1- ttr- - iii 11 j 111rlt ,; �1 vo - II III;I ;; ^ - - 11:1: 1 1 ' -4-4-- F-t F t 1-1- t 4 t 1 ± -. +- _} -t -t 4-4-4-1-4-4-4--. - t--t-- +--1---I- t- -t-- +--1 --i-- L1�- 1.- 1- .LL_i_ {_a_ }_L- 1- -�_Lt_1 - -1i_� , ----,--,--,----.-4-4-4-4-4-4--.• 1-- 1 1 -L-1- j - -1—F— l li ' ' ' i i• iiii 111 1 t4.4.1__I___;___[__ _4_4444_4_1_ i -`--±--' i - - i--+--4 - - i - t--t i_ 1 --+-• i--+- i-- +•- +- -1- +--r- 4-- 1- - *--+--4-- +- - - Eiiii:HILIT -- + + -- t - + -- t - t-- t--t--t- j-- t- 1"--r--1-- -1 ---- -Y-j--+-- +- ---1 -- 11 1 -- i l i t I t t t-- j•••F• -r - -, f - - 1 - : 1; : t l I I f� t-- t-- j--- �-- 1- - -1 - -1 1, -- i- {t1 - -T - -t t-i-•t- •{- t -1' - - -1 - 1-- t- 1- -1 - -T_ - L -"i - -t I-'1--t-- 4-- T-- r --- -f -T-- -- -- T_1- -"i - -' -1_7-- t- T - -j_»- I --- P- t- 1 --t-- 1- 4- *- i-- }- -F- -1- {-- F--f-1 + -I- 4 -- -- t- 1 --t -• -- +- -+-- 4-- +4- +--1--i --t -- t -t i 1-- - *--1 I- 4-1 ---1- 1-- 1- 1 - •1•- -1- i • r _Ll_L- 1 _ 1 - -L '- 4 i- 1-- j-- L- ,I- 44- 1- 1- }- ;- ;--1 -- ---t--4--r--1--i---i--}--L1- 'i i_liil t 1: i1it1i B --- 1-- 1--- 1 - -+ -- -- t- +i_ + -_ -}-- t-- r-+- r-- +- -1'- f- }- I- - }-- I-- -I- } -4 -t -l- 4--- I-- t'- !- +-1--t--r---F- 1-- -1- -+--1�t- " " ., '' .,i i i i i i 1 i 1 1 I I, , i ,, 1 1: 1 1 , 1. 1 1 1 1 i, 1, I, O N C.) A CII Cn O G b b O C O O O O O O O O Hall Slope • DATA LOG TIME INJECT. RATE CUM. POLYMER DATE INJ. PS CONCENT COMMENTS Hr Min BPD BPM (BBLS) (PPM) Start Well Treatment at 100 Bbls of sea water (please note 14- Apr -10 19 53 1,000 0.69 0.0 2,729 0 TIORCO is pumping 1000 BPD and PNR is pumping 2000 BPD, combined rate 3000 BPD) 14- Apr -10 22 30 917 0.64 100.0 2,769 0 End water pre flush 14- Apr -10 22 30 917 0.64 100.0 2,769 3,000 Start Polymer Stage # 1 - 3000 ppm gel 14- Apr -10 23 00 3,072 2.13 164.0 2,762 3,000 15- Apr -10 0 00 2,976 2.07 288.0 2,848 3,000 15- Apr -10 1 00 2,952 2.05 411.0 2,797 3,000 15- Apr -10 2 00 2,952 2.05 534.0 2,728 3,000 15- Apr -10 3 00 2,952 2.05 657.0 2,733 3,000 15- Apr -10 4 00 2,928 2.03 779.0 2,733 3,000 15- Apr -10 5 00 2,808 1.95 896.0 2,692 3,000 15- Apr -10 6 00 2,832 1.97 1,014.0 2,678 3,000 15- Apr -10 7 00 3,096 2.15 1,143.0 2,687 3,000 15- Apr -10 8 00 3,096 2.15 1,272.0 2,715 3,000 15- Apr -10 9 00 2,616 1.82 1,381.0 2,719 3,000 Unit shut down (lost suction pressure) twice 15- Apr -10 10 00 2,904 2.02 1,502.0 2,728 3,000 Collected polymer sample for lab test 15- Apr -10 11 00 2,880 2.00 1,622.0 2,733 3,000 15- Apr -10 12 00 2,880 2.00 1,742.0 2,710 3,000 15- Apr -10 13 00 2,880 2.00 1,862.0 2,730 3,000 15- Apr -10 14 00 2,736 1.90 1,976.0 2,750 3,000 15- Apr -10 15 00 2,760 1.92 2,091.0 2,745 3,000 15- Apr -10 15 29 2,880 2.00 2,149.0 2,750 3,000 End stage # 2 - 3000 ppm gel 15- Apr -10 15 29 2,880 2.00 2,149.0 2,750 4,500 Start stage # 3 - 4500 ppm gel 15- Apr -10 16 00 2,648 1.84 2,206.0 2,750 4,500 15- Apr -10 17 00 2,760 1.92 2,321.0 2,750 4,500 15- Apr -10 18 00 2,712 1.88 2,434.0 2,750 4,500 15- Apr -10 19 00 2,808 1.95 2,551.0 2,750 4,500 15- Apr -10 20 00 2,832 1.97 2,669.0 2,750 4,500 15- Apr -10 21 00 2,712 1.88 2,782.0 2,750 4,500 15- Apr -10 22 00 2,880 2.00 2,902.0 2,780 4,500 15- Apr -10 23 00 3,048 2.12 3,029.0 2,790 4,500 16- Apr -10 0 00 3,096 2.15 3,158.0 2,820 4,500 16- Apr -10 1 00 2,976 2.07 3,282.0 2,800 4,500 16- Apr -10 2 00 2,976 2.07 3,406.0 2,800 4,500 16- Apr -10 3 00 2,856 1.98 3,525.0 2,840 4,500 16- Apr -10 4 00 2,784 1.93 3,641.0 2,850 4,500 16- Apr -10 5 00 2,808 1.95 3,758.0 2,840 4,500 16- Apr -10 6 00 2,904 2.02 3,879.0 2,850 4,500 16- Apr -10 7 00 2,832 1.97 3,997.0 2,850 4,500 Collected polymer sample for lab test 16- Apr -10 8 00 2,832 1.97 4,115.0 2,850 4,500 16- Apr -10 9 00 2,736 1.90 4,229.0 2,800 4,500 16- Apr -10 9 12 3,240 2.25 4,256.0 2,750 4,500 End stage # 3 - 4500 ppm gel 16- Apr -10 9 12 3,240 2.25 4,256.0 2,750 6,000 Start stage # 4 - 6000 ppm gel 16- Apr -10 10 00 3,180 2.21 4,362.0 2,840 6,000 16- Apr -10 11 00 2,664 1.85 4,473.0 2,860 6,000 16- Apr -10 12 00 2,592 1.80 4,581.0 2,890 6,000 16- Apr -10 13 00 2,544 1.77 4,687.0 2,860 6,000 1:55 pm - unit shutdown (low flow alarm) 16- Apr -10 14 00 2,400 1.67 4,787.0 2,880 6,000 16- Apr -10 15 00 2,088 1.45 4,874.0 2,880 6,000 16- Apr -10 16 00 2,112 1.47 4,962.0 2,890 6,000 16- Apr -10 17 00 1,920 1.33 5,042.0 2,880 6,000 Collected polymer sample for lab test 6 • TIME INJECT. RATE CUM. POLYMER DATE INJ. PSI) CONCENT COMMENTS Hr Min BPD BPM (BBLS) (PPM) 16- Apr -10 17 52 2,105 1.46 5,118.0 2,890 6,000 PNR water rate is on the decline 16- Apr -10 18 00 1,800 1.25 5,128.0 2,890 6,000 16- Apr -10 19 00 2,040 1.42 5,213.0 2,990 6,000 16- Apr -10 19 15 2,112 1.47 5,235.0 2,850 0 Shut off polymer / switch to water 16- Apr -10 19 43 3,086 2.14 5,295.0 2,830 0 Shut down - TIORCO Unit take over pumping polymer and water. 16- Apr -10 21 25 3,086 2.14 5,295.0 0 0 Restart unit to Pressure Test SLB hard line 16- Apr -10 21 30 1,440 1.00 5,300.0 0 0 End of Pressure Test 16- Apr -10 22 00 528 0.37 5,311.0 2,842 0 Eductor electrical valve problems 16- Apr -10 22 37 1,362 0.95 5,346.0 2,819 0 Shut down to make repairs 16- Apr -10 23 00 1,362 0.95 5,346.0 2,837 0 Restart unit 16- Apr -10 23 30 1,008 0.70 5,367.0 2,850 0 Shutdown to pull out low valves in triplex 17- Apr -10 1 08 1,008 0.70 5,367.0 2,297 0 Restart after ice in hard line. 17- Apr -10 2 15 129 0.09 5,373.0 2,531 0 Move water in line to make sure no more ice is in the hard line. 17- Apr -10 2 42 1,120 0.78 5,394.0 2,627 0 Shut down to reboot computer. Could not run in AUTO. Right after back up and running 17- Apr -10 3 00 880 0.61 5,405.0 2,725 6,000 17- Apr -10 4 00 1,032 0.72 5,448.0 2,780 6,000 17- Apr -10 5 00 912 0.63 5,486.0 2,800 6,000 17- Apr -10 6 00 888 0.62 5,523.0 2,799 6,000 17- Apr -10 7 00 912 0.63 5,561.0 2,833 6,000 17- Apr -10 7 30 1,152 0.80 5,585.0 2,837 6,000 SLB increased rate to 1000 BPD 17- Apr -10 7 58 926 0.64 5,603.0 2,883 6,000 SLB increased rate to 1155 BPD 17- Apr -10 8 00 720 0.50 5,604.0 2,880 6,000 17- Apr -10 9 00 1,152 0.80 5,652.0 2,900 6,000 SLB increased rate to 1255 BPD 17- Apr -10 10 00 1,488 1.03 5,714.0 2,890 6,000 17- Apr -10 11 00 1,272 0.88 5,767.0 2,900 6,000 Rate dropped to 1045 BPD 17- Apr -10 12 00 1,080 0.75 5,812.0 2,880 6,000 Rate dropped to 997 BPD 17- Apr -10 13 00 1,080 0.75 5,812.0 2,890 6,000 17- Apr -10 14 00 936 0.65 5,851.0 2,880 6,000 17- Apr -10 15 00 936 0.65 5,890.0 2,890 6,000 Rate dropped to 900 BPD 17- Apr -10 16 00 888 0.62 5,927.0 2,900 6,000 Rate dropped to 875 BPD 17- Apr -10 17 00 912 0.63 5,965.0 2,910 6,000 Rate dropped to 785 BPD 17- Apr -10 17 25 576 0.40 5,975.0 2,920 6,000 Switch to water 17- Apr -10 18 00 1,152 0.80 6,003.0 2,892 0 Shut down to inspect main charge pump and P- valve. 18- Apr -10 2 46 1,152 0.80 6,003.0 2,370 0 SLB pumped 122 more bbls for a total of 150 bbls @ 1440 BPD ending pressure 2940 psiq 18- Apr -10 2 57 1,440 1.00 6,014.0 2,620 6,000 18- Apr -10 3 00 1,440 1.00 6,017.0 2,620 6,000 18- Apr -10 3 30 912 0.63 6,036.0 2,800 6,000 18- Apr -10 4 00 1,008 0.70 6,057.0 2,800 6,000 18- Apr -10 4 30 960 0.67 6,077.0 2,860 6,000 18- Apr -10 4 59 993 0.69 6,097.0 2,940 6,000 End stage # 4 - 6000 ppm gel 18- Apr -10 4 59 993 0.69 6,097.0 2,940 8,000 Start stage # 5 - 8000 ppm gel 18- Apr -10 5 00 1,440 1.00 6,098.0 2,940 8,000 18- Apr -10 5 30 1,056 0.73 6,120.0 2,970 8,000 18- Apr -10 6 00 1,008 0.70 6,141.0 2,950 8,000 18- Apr -10 6 30 912 0.63 6,160.0 2,970 8,000 18- Apr -10 6 55 979 0.68 6,177.0 2,950 8,000 End stage # 5 - 8000 ppm gel 18- Apr -10 6 55 979 0.68 6,177.0 2,950 10,000 Start stage # 6 - 10000 ppm gel 18- Apr -10 7 00 864 0.60 6,180.0 2,950 10,000 18- Apr -10 7 30 912 0.63 6,199.0 2,980 10,000 18- Apr -10 8 00 1,008 0.70 6,220.0 3,020 10,000 18- Apr -10 8 30 1,008 0.70 6,241.0 3,070 10,000 18- Apr -10 8 57 960 0.67 6,259.0 3,100 10,000 End stage # 6 - 10000 ppm gel 18- Apr -10 8 57 960 0.67 6,259.0 3,100 _ 30,000 Start Stage # 7 - 10000 ppm of WC 204 gel and 20000 ppm of WC 7 i TIME INJECT. RATE CUM. POLYMER DATE INJ. PSI) CONCENT COMMENTS Hr Min BPD BPM (BBLS) (PPM) 50 gel. 18- Apr -10 9 00 960 0.67 6,261.0 3,100 30,000 18- Apr -10 9 30 1,008 0.70 6,282.0 3,070 30,000 18- Apr -10 10 00 1,152 0.80 6,306.0 3,100 30,000 18- Apr -10 10 30 816 0.57 6,323.0 3,080 30,000 18- Apr -10 11 00 1,104 0.77 6,346.0 3,060 30,000 18- Apr -10 11 30 1,008 0.70 6,367.0 2,980 30,000 18- Apr -10 12 00 1,056 0.73 6,389.0 3,010 30,000 18- Apr -10 12 30 1,008 0.70 6,410.0 2,988 30,000 18- Apr -10 13 00 1,008 0.70 6,431.0 2,984 30,000 18- Apr -10 13 30 1,008 0.70 6,452.0 2,990 30,000 18- Apr -10 14 00 960 0.67 6,472.0 2,980 30,000 18- Apr -10 14 30 1,104 0.77 6,495.0 2,980 30,000 18- Apr -10 15 00 960 0.67 6,515.0 2,975 30,000 Collected polymer sample for lab test 18- Apr -10 15 30 1,008 0.70 6,536.0 2,980 30,000 18- Apr -10 16 00 1,056 0.73 6,558.0 2,940 30,000 18- Apr -10 16 30 1,008 0.70 6,579.0 2,930 30,000 18- Apr -10 17 00 1,104 0.77 6,602.0 2,930 30,000 18- Apr -10 17 30 1,008 0.70 6,623.0 2,870 30,000 18- Apr -10 18 00 1,008 0.70 6,644.0 2,900 30,000 18- Apr -10 18 30 1,008 0.70 6,665.0 2,900 30,000 18- Apr -10 18 55 1,094 0.76 6,684.0 2,820 30,000 Eductor plug 18- Apr -10 19 00 576 0.40 6,686.0 2,840 30,000 18- Apr -10 19 10 1,008 0.70 6,693.0 2,860 30,000 Eductor plug 18- Apr -10 19 30 1,008 0.70 6,707.0 2,850 30,000 18- Apr -10 20 00 1,008 0.70 6,728.0 2,870 30,000 18- Apr -10 20 30 1,008 0.70 6,749.0 2,900 30,000 18- Apr -10 20 45 1,152 0.80 6,761.0 2,950 30,000 End stage # 7 - 30,000 ppm gel 18- Apr -10 20 45 1,152 0.80 6,761.0 2,950 10,000 Start Stage # 8 - 10,000 ppm with no crosslinker 18- Apr -10 21 00 1,248 0.87 6,774.0 2,970 10,000 18- Apr -10 21 30 1,008 0.70 6,795.0 2,950 10,000 18- Apr -10 22 00 960 0.67 6,815.0 2,930 10,000 18- Apr -10 22 30 1,008 0.70 6,836.0 2,800 10,000 End stage # 8 - 10,000 ppm with no crosslinker 18- Apr -10 22 30 1,008 0.70 6,836.0 2,800 0 Start stage # 9 - water over flush 18- Apr -10 23 00 576 0.40 6,848.0 2,800 0 18- Apr -10 23 30 960 0.67 6,868.0 2,870 0 19- Apr -10 0 00 1,104 0.77 6,891.0 2,910 0 19- Apr -10 0 17 1,694 1.18 6,911.0 2,880 0 Complete water flush • 8 • 1- SAH [IF ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMl►IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tim Crumrine Staff Completions Engineer Pioneer Natural Resources Alaska, Inc. 1 �p 700 G Street, Suite 600 �Q Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK -42Ai Sundry Number: 310 -104 Dear Mr. Crumrine: 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. Sea nount, Jr. Chair DATED this 0 day of April, 2010. Encl. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Water Shut -Off 0 • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development ❑ Exploratory ❑ 209 -156 • 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service 0 , 6. API Number: Anchorage, AK 99501 50- 703 - 20605 -01 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes III No 0 ODSK - 42Ai 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 355036 • Oooguruk - Kuparuk 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): 9758' ' 6672' . 9751' 6666' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3251' 10 -3/4" 3289' 2980' 5210 2470 Intermediate 8616' 7 -5/8" 8654' 5963' 6890 4790 Production Liner 1232' 4 -1/2" 8521' - 9753' 5884' - 6668' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8736' - 8756' 6004' - 6015' 3 -1/2 ", 9.3# L -80 TSHP 8538' Packers and SSSV Type: TSP Liner Top Pkr; WFT Ultrapak 'TH' Packers and SSSV MD (ft) and TVD (ft): 8357' MD / 5899' TVD; 8300' MD / Productin Pkr; Wellstar TRSSSV 5761' TVD; 745' MD / 745' TVD 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/12/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended p 16. Verbal Approval: Date: WINJ 0 • 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 Tim Crumrine, 343 -2184 Printed Name Tim_ Crumrine, 343 -2184 Title Staff Completions Engineer Signatur - " y Phone Date Prepared By: Kathy Campoamor, 343 4/7/2010 r ---s.. - 4 "9.17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:3 " — IV — I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: R ECEIVED Subsequent Form Required: JO ' / Q Y APR 0 7 2010 �118$fOR APPROVED BY r 4/ il i � Approved by: COMMISONER THE COMMISSION Date: RBp . APR 0 9 �•8.1a � �: 7 v Form 10 -403 Revised 1/2010 ORiGiNAL Submit in Duplicate , • • Pioneer Oooguruk ODSK -42Ai MARCIT Gel Treatment (MARathon Conformance Improvement Technology) OBJECTIVE • Shut off fracture channels in ODSK -42Ai TREATMENT PROCEDURE 1. Tie TIORCO equipment into water injection header at ODS with choke manifold in between TIORCO truck and header. Water source is Kuparuk SW from STP. 2. Once rigged up, pump 25 barrel water preflush to establish injectivity. 3. Treat the well with polymer gel with the recommended volume and concentrations per pump schedule below. Place thetreatment at a rate of 3000 BPD (2 BPM) and at a tubing pressure not to exceed fracture pressure. 4. Rig down TIORCO and keep well shut -in for a minimum of 7 days. , 5. Put well back on injection @ 3000 BWPD rate. 6. Monitor the offset producer ODSK -41 to measure treatment results. Medium Pdymer WATERCUT 204 - Bags 000 2,098 Low MW Polymer 2,000 1 067 Grssslnke WATERCUT 684 - Drum 40 42.22 456 Acce1erantiRewmlan� Flush Madiu-e VW Foh/mer WATERCUT 204 - Bags 4,500 3,147 Low VW Polymer 2 2 0.67 Crsxssl;nker WATERCUT 684 - Drum 40 63 -33 684 ■creleranL/Reardant Flush Madura MW Polymer WATERCUT 204 - Bags 6.000 16,783 Low MW Polymer 4 8 2 67 Cross! oke WATERCUT 684 - Drum 40 337.87 3,649 ?nrzkrent Reta: int, Flush Medan VW Polymer WATERCUT 204 - Bags 8000 13,986 5,000 Low MW Roomer 4 1.67 Crossl,ke WATERCUT 684 - Drum 40 281 -48 3,040 Ac! aniart Flush Medium k W Polyrwr WATERCUT 204 - Bags '10,000 8,741 2,500 Law MW Pot rrer 5 0 83 CsassInke WATERCUT 684 - Drum 40 175. 1,900 AocelerontrRetamtan ' Fluso Madre MW Pdyner WATERCUT 204 - Bags '10 1,748 Low MW Poly mer WATERCUT 50 20,000 3,497 6 500 0.17 Crossinker WATERCUT 684 - Drum 40 105.56 1,140 AcoetemotiRetardan ' F1u4, Medium M'APotyrner WATERCUT 204 - Bags 10,000 524 Low MW Polymer 7 150 0.0,m Crt.ssloker Acoelerant;Reardan`_ — Flush a • ODSK -42Ai Kuparuk Injection - As Built Completion Well Head: 9 5/8 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal Casing Item # Item MD (ft) TVD (ft) J 0 O A 16" Conductor A 153 153 B l0 %" 45.5# L-80 BTC, 8.835" ID 3,289 2,980 O C 7 29.7# L 80 BTC M, 6.875" ID 8,654 5,963 D 4 12.60# L -80 Hydril 521 9,753 6,668 E 3'/2" 9.3# L -80 TS HP 8,538 5,894 Upper Completion Item # Item MDrkb (ft) TVDrkb (ft) 1 VetcoGray Tubing Hanger 34 34 HES Wellstar TRSSSV w/ 3' /i' 9.2# TSHP Box x Pin 9 2 745 745 Chr w/ 2.813 "X' Profile w/ 1/4" x .049 SS CL to Surface O 3 GLM #1 HES Vanoil 3'h" x 11/4" Gas Lift Mandrel w/ 3 %" 3,455 3,068 9.2# TSHP Box x Pin w/ Shear Out Valve in place 4 GLM #2 HES Vanoil 3'/2' x 1'h" Gas Lift Mandrel w/ 3'h" 8,055 5,625 9.2# TSHP Box x Pin w/ Dummy in place 0 5 WFT Gauge & Carrier w/ 3'h" 9.2# 8rd EUE Pin x Pin 8,139 5,672 6 8,217 5,715 HES 2.813 "X' Nipple 9 Chr w/ 3' 9.2# TSHP Box x Pin '/z Weatherford 3 x 7 -5/8" Model "Ultra Pak -TH" Hydraulic 7 Set Permanent Production Packer w/ 3'% 9.3# TSHP Box 8,300 5,761 x Pin 8 8,389 5,811 HES 2.813 "X' Nipple 9 Chr w/ 3' /z" 9.2# TSHP Box x Pin HES 2.813 "XN" Nipple w/ 2.750" No -Go 9Chr w/ 3' /i' g 466 5,854 0 -1 9 TSHP Box x Pin w/ "RCH -M" Plug in Place 10 WLEG w/ 3'/2" TSHP Box 8,536 5,893 5 End of Assembly 8,538 5,894 O Q Item # Item Lower Completion MD (ft) TVD (ft) O 1 0 11 WFT PBR Tie Back Sleeve 15ft 5 -3/4" I.D. 8,521 5,884 WFT "NTH" Liner Top Pkr w/ Hold Down Slips 5 -1/2" x 7- © 8 537 5,893 J e 0 12 5/8" 0 13 WFT "PHR" Rotating Liner Hanger 5 -1/2" x 7 -5/8" 8,540 5,895 0 14 Reamer Shoe 9,751 6,666 ® __ End of Assembly 9,753 6,668 • x� O x _ P erforations fi Item # Item MD (ft) TVD (ft) 15 15 Perforations conducted via e line post rig 8,736 6,004 6 SPF 60 deg phasing 120 total shots 8,756 6,015 m O Date: Revision By: Comments 11/30/09 VTJ Proposed Completion PIONEER ODSK -42Ai Injector 12/2/2009 jdf Proposed completion - wp6 12/30/2009 TWC As Built NATURAL RESOURCES Well Schematic As Built I 1 Page 1 of 2 Maunder, Thomas E (DOA) From: Williams, Theresa [Theresa.Williams @pxd.com] Sent: Friday, March 26, 2010 9:36 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: MIT IA's I found the list and it has the current PTD #. Not sure where the operator got the one he used. Theresa Williams «= f - .9(( ` "C ( fI '7 O- IS L From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Friday, March 26, 2010 9:34 AM To: Williams, Theresa Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: MIT IA's Thanks Theresa. Kathy might have information that will assist you. Tom From: Williams, Theresa [ mailto :Theresa.Williams @pxd.com] Sent: Friday, March 26, 2010 9:30 AM To: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Cc: Regg, James B (DOA) Subject: RE: MIT IA's Thanks. I'll have to see what the current list says for this well. Sounds like it from the original. I'II update and pass onto the Slope. Theresa Williams CO Office %c:'] - 9 j'l3(1i f "34? ,f -. Office ' - (. ;_7i ,{ ,k(JL `'� ✓5 Cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, March 26, 2010 9:03 AM To: Brooks, Phoebe L (DOA); Williams, Theresa Cc: Regg, James B (DOA) Subject: RE: MIT IA's Phoebe is correct. Well identity is something that needs close attention. Tom From: Brooks, Phoebe L (DOA) 4/6/2010 • • Page 2 of 2 Sent: Friday, March 26, 2010 8:58 AM To: Williams, Theresa Cc: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: RE: MIT IA's Theresa, Well ODSK -42, PTD #2091200 has a P &A'd well status, I believe this report should reflect well ODSK -42A, PTD# 2091560. Attached is the revised report. If you disagree please let me know. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907 - 793 -1242 Fax: 907 - 276 -7542 From: Williams, Theresa [ mailto :Theresa.Williams @pxd.com] Sent: Friday, March 26, 2010 8:15 AM To: Brooks, Phoebe L (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: MIT IA's Attached are results for MIT IA after injection was started on ODSN -34 and ODSK -42. Regards, Theresa Williams tai 0,; rt t is n E ng nee C:neer N itJlcl Resol3EC Anchor(+ge, AK =u7 } ? 1 1:-; 230 (907) 382 _)9C> Cell Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 4/6/2010 • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; tom.maunder @alaska.gov; phoebe.brooks @alaska.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: Pioneer Natural Resources FIELD / UNIT / PAD: Oooguruk DATE: 03/06/10 � /1 OPERATOR REP: Tom Tredway ►v A p AOGCC REP: Chuck Sheavy `' � I(z) lL — t'((�}Qs Packer Depth Pretest Initial 15 Min. 30 Min. Well ODS Type Inj. W TVD 5,769' Tubing 2,490 2,490 2,490 2,490 Interval I P.T.D. ;L:1412TO Type test P Test psi 1,500' Casing 30 3,650 3,560 3,535 P/F P Notes: Post- Injection7y,, OA 325 450 430 425 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form PLB 10/26/09 MIT ODSK -42i 03- 06- 10.xls 41/ 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 10, 2010 TO: Jim Regg .I. ? (�.� Cho P Supervisor ^ SUBJECT: Mechanical Integrity Tests PIONEER NATURAL RESOURCES ALASK ODSK -42A FROM: Chuck Scheve OOOGURUK KUP ODSK -42A Petroleum Inspector Src: Inspector Reviewed By P.I. Supry . NON - CONFIDENTIAL Comm Well Name: • OGOGURUK KUP ODSK - 42A API Well Number: 50 703 - 20605 - 01 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS100307063833 Permit Number: 209 - 156 - Inspection Date: 3/6/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ODSK42A Type Inj. W f TVD 5761 / IA 30 3650 3560 3535 i P.T.D 2091560 TypeTest SPT Test psi Boo ' OA 325 450 ' 405 425 Interval INITAL p/F P -' Tubing 2490 2490 2490 2490 Notes: I Wednesday, March 10, 2010 Page 1 of 1 • PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: February 9, 2009 FROM TO Shannon Koh . AOGCC Pioneer Natural Resources Attn: Christine Mahnken 700 G Street, Suite 600 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report X Other — 2 CDs, 6 Well Logs ❑ Agreement DETAIL QTY DESCRIPTION ODSK -42A1 (API: 50- 703 - 20605 -0100) 2 CDs 2CDs LWD Final Processed Data & BAT Bi -Modal Acoustic Processed Data 6 Well Logs 6 Well logs DGR, EWR -Phase 4, ALD, CTN (1:600, 1:240) MD Iogs, TVD Iogs DGR, EWR -Phase 4, ALD, CTN, BAT Bi -Modal Acoustic (1:600/ 1:240) MD Iogs, TVD Iogs We request that all data be treated as confidential info f Y' i m ;�! .�. , ) c 1 70,1P Received by: i /� Date: Please sign and return one copy to Pioneer Natural Resou~rThc:, ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907 -343 -2190 fax 907- 343 -2128 phone RECEIVED ` • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION "Q� z�1� WELL COMPLETION OR RECOMPLETION REPORENtaigats.Commistion la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ '1b. Well Class: Angh.rsoo 20AAC 25 105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ EI ' WAG ❑ WDSPL ❑ No. of Completions: _ One Service El • Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.: 12/30/2009 209 -156 ° 3. Address: 700 G Street, Suite 600 6. Date Spudded: 13. API Number: Anchorage, AK 99501 12/10/2009 50- 703 - 20605 -01 -00 ° 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2912' FSL, 1154' FEL, Sec. 11, T13N, R7E, UM • 12/24/2009 ODSK -42Ai Top of Productive Horizon: .8. KB (ft above MSL): 56.2' 15. field /Pool(s): 3294' FSL, 4103' FEL, Sec. 13, T13N, R7E, UM GL (ft above MSL): 13.5' Total Depth: 9. Plug Back Depth(MD +TVD): Oooguruk - Kuparuk Oil Pool . 2519' FSL, 3785' FEL, Sec. 13 , T13N, R7E, UM N/A 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: • Surface: x- 469844.38 . y - 6031028.13 • Zone- ASP 4 ' 9758 MD / 6672' TVD • ADL 355036 . TPI: x- 472158.87 y - 6026121.75 Zone- ASP 411. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 472474.47 y - 6025345.33 Zone- ASP4 745' MD / 745' TVD 417497 18. Directional Survey: Yes i0 No U 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) 839' MD / 830' TVD • 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: LWD: MWD, GR, DIR, EWR, PWD, ALD, CTN, BAT /SONIC, GR /CCL/CBL 3287' MD / 2979' TVD 4 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# H -40 Surface 158' Surface 158' 24" Driven 10 -3/4" 45.5# Lao BTC Surface 3289' Surface 2980' 13 -1/2" 458 sx PF 'L; 201 sx Class 'G' 7-5/8" 29.7# L Surface 8654' Surface 5963' 9 -7/8" 164 sx Class 'G' - BTC - M 4 12.6# L - eo 8521' 9753' 5884' 6668' 6 - 3/4 " 259 sx Class 'G' HYD 521 _ 24. Open to production or injection? Yes p No El If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) -{be 3 9.3 #, UltraPak TH Pkr 8300 ' P,&:I L TSHP 8538 / 5761' TVD; Liner Top Pkr 8537' MD / 5893' TVD 2 -1/2" Gun Diameter @ 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. MD ✓ TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8736' - 8756' 6004' - 6015' 2000' Freeze Protect w/ 80 bbls diesel 27. PRODUCTION TEST . Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: 'Choke Size: Gas -Oil Ratio: Test Period .-■► Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: ' Oil Gravity - API (corr): Press. 24 -Hour Rate - 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 111 Sidewall Cores Acquired? Yes ❑ No 0 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, etas,,.„.„..., (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per AgaMikaIWN i � Y None Zia. III RBDMS FEB 01 20 0 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE 31 .2.,Z •/p Submit or Opal only • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes I -I I No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, ' Permafrost - Top 838' 838' and submit detailed test information per 20 AAC 25.071. Permafrost - Base 1677' 1668' Top West Sak 2376' 2320' Tuffaceous Shale 3194' 2927' None Top Torok 7028' 5058' Top HRZ 8232' 5732' Base HRZ 8453' 5854' Top Kuparuk 8740' 6009' LCU 8753' 6016' BCU 9092' 6214' Top Nuiqsut 9224' 6298' Base Nuiqsut 9301' 6349' Top Nechelik 9315' 6358' Base Nechelik 9594' 6550' Formation at total depth: 9758' 6672' 31. List of Attachments: Summary of Daily Drilling Operations, Well Schematic Diagram, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alex Vaughan, 343 - 2186 Printed Name: V Jo Title: Sr. Staff Drilling Engineer 1 28/2 °Y' Signature: , Phone: 343 -2111 Date: 1/29/2010 Well Name: ODSK -42Ai Permit No.: 209 -156 Prepared By: KathyCampoamor, 343 -2183 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 b: 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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other {explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 PIONEER "Operations Summary Report NATURAL RESOURCES 'Well Name: ODSK -42Ai Contractor: NABORS DRILLING Rig Number: 19 AC ,Job Category: DEVELOPMENT DRILL Start Date: 12/5/2009 End Date: � I Depth Start Foot/Meters Last Mud Stan Date End Date 4fK3) in) Dens l gal) Summary ,12/9/2009 12/10/2009 0.0 9.20;RIH w/ 549' of 2 -7/8" Tbg Cement Stinger on 4" DP t/3,540'. CBU. Set Balanced Cement Plug w/35 bbl (196 ix) 17.0 ppg Class "G" + 025% CaCl2 + 0.75% U-H -3 cement 1/3,54U' t/ 9,11)9'. !POOH 1/3,058'. CBU 2x. POOH and LD Cement Stinger. Change Lower Rams f/ 4" - V 5 ". C/O 14' Upper and Lower IBOP's, Gripper Dies and Stabbing Guide on Top Drive to 5 ". 'NOTE: At 05:00 hrs notified AOGCC and gave them 24 hr notice for BOPE test to be performed on 12/10/09. At 10:00 hrs on 12/09/09 AOGCC representative Jeff Jones waived witness of test. 1 i I j 12/10/2009 12/11/2009 3,289.0 10.00; 9.30 Wash down and Tap Cement at 3,179' w/ 10k. POOH stand back DP in derrick. Test Annular to 1250 psi low / 2500 psi high. Test Upper 2-7/$ x 5" VBR's, Lower 5" Single Bore Rams, Blind Rams. Choke and Kill Line HCR's, Choke and Kill Line Manual valves, Floor Safety valve, Dart valve, Upper and Lower IBOP, 14 Choke Manifold valves to 250 psi low / 4500 psi high. All low J and high tests held 5 min ea. All tests charted. Accumulator test, System Pressure 3050 psi, ;After Closer 2200 psi, Initial 200 psi recovery 23 sec's, Full recovery 1 min 34 sec's. RIH w/ 9 -7/8' BHA #6 1/3,179'. Clean out cement stringers V3,179 1/3,220', tagged hard cenTifiri f 25k bit wei.ht. Drill Cement f/3 220' 1/3 299'. NOTE: Witness of BOPE test waived by AOGCC representative Jeff Jones at 1000 hrs on 12/9/09. 3 ! 12/11/2009 12/12/2009 3,299.0 136.00 9.20,Dri11 9 -7/8" hole on Kick -Off Cement Plug 1/3.289' 1/3,435'. Unable to get desired hole inclination 'and azimuth to complete Kick -Off. POOH V3,303'. Attempting to Kick -Off utilizing troughing and ;time drilling 1/3,303' 1/3,337'. ! i 12/12/2009 12/13/2009 3,435.0 249.001 9.20 Time Drill Off Cement Plug 1/3,337' 113,344'. POOH w/ BHA 416. RIH w/ 9-7/8" BHA 47 1/3,344'. ; Perform Kick -Off with Motor 1/3,344' 1/3,435'. Directional Drill 9 -7/8' hole 1/3,435' 1/3,684'. CBU. 12/13/2009 112/14/2009 3,684.0, 0.00, 9.20 POOH w/ 9 -7/8" BHA #7 t/70'. RIH w/ RSS 9 -7/8" BHA #81/79'. Unable to resolve tool communications issues. Decision was made to LD RSS BHA. PU BHA #8, Drill Motor w/ PDC I Bit. RIH w/ BHA #81/3,289'. Remove Trip Nipple and install RCD element. Flow test MPD lines. 12/14/2009 12/15/2009. 3,684.0 1,446.00 9.20 RIH 1/3,396' 1/3,684'. Drill 9 -718' hole 1/3,684' 1/5,098'. Observed hole pack -off on connection, ' lost 88 bbls mud. Re- established circulation al 650 gpm. Drill 9 -718' hole 1/5,098' 115,130' maintaining 12.Oppg ECD w/ MPD. 12/15/2009 12/16/2009 5,130.0 1,680.00 9.20 Drill 9 -7/8' hole 1/5,130' 1/6,810' maintaining 12.5ppg ECD w/ MPD. 12/16/2009 12/17/2009 6,810.0 737.00 9.20 Drill 9 -7 /8' hole 1/6,810' t/7,314'. Lost Top Drive Blower Motor, trooleshoot and reset relay • breaker. Drill 9-7/8' hole 1(/7,314' 1/7,482'. Replace swab on 412 Rig Mud Pump. Drill 117,482' 1/7,547' maintaining 12.5ppg ECD w/ MPD. Circulate and condition mud tor wiper trip. POOH 1/7,547' 1/3,211'. 12/17/2009 12/18/2009 7,547.0 282.00 10.00 Function Test BOPE's. RIH 1/3,211' V7,358'. Circulate and perform Weight Up by displacing 9.2 ppg LSND with new 10.0 ppg LSND. Ream 1/7,358' 1/7,547'. Drill 9 -7/8' hole 1/7,547' 1/7,829' maintaining 12.5 ppg ECD w/ MPD. 12/18/2009 12/19/2009 7,829.0 796.00 10.00 Drill 9-7/8' hole 1/7,829' V8,625',maintaning 12.5ppg ECD w/ MPD. 12/19/2009 12/20/2009 8,625.0 40.00 12.50 Drill 9.7/8" hole 1/8,625' 1/8,665'. Pump 30 bbl hi -vis LCM sweep and circulate same out the hole. Back ream out the hole 1/8,665' V8,112'. POOH 1/8,112" 1/7,446'. TIH 1/7,446' V8,665'. CBU at 8,665'. POOH 1/8,665' 1/7,735'. TIH 1/7,735' 118,665'. CBU at 8,665'. Swap old 10.0 ppg mud w/ 800 bbls clean 10.0 ppg LSND mud to rig pits. Raise mud wt. from 10.0 ppg to 12.5 ppg using 400 bbls of 17.0 ppg spike fluid from the RSC and stepping down MPD pressures as mud wt increases to maintain ECD's at 13.0 ppg with no losses. Monitor well for 30 min - static. Pull RCD head and install trip nipple. Circulate and add 3% tubes to mud and spot same across open hole section. POOH 1/8,665' V6,604'. Page 1/3 Report Printed: 1/29/2010 PIONEER .Operations Summary Report • NATURAL RESOURCES Depth Stan FooUMeters i Last Mud Stan Date End Dale 4 Ma) t8) ; Dens MVO Summary 1 12/20/2009 12/21 /2009 8.665.0 0.00 12.50; POOH (/6,604' 1/644' (BHA). Install test plug and pull test joint. Change out upper Dim rams ;from 5" to 7 -5/8" casing rams. MU testing equipment. Test Annular to 250 psi low / 2500 psi 'high. Test Upper casing rams to 250 psi low / 4500 psi high. All low and high tests held 5 min lea. All tests charted. Pull test plug and RD testing equipment. RU 7 -5/8' casing equipment and hold pre job safety meeting with all involved personnel. PU and MU shoe track, thread lock all connections and establish circulation through same. RIH with 7 -5/8 ", L -80, 29.704, BTC -M casing f/115' V2,038'. � I • 12/21/2009 1 12/22/2009 8.665.0' 0.00 11.00' RIH with 7 -5/8" casing 1/2,038' 1/3,270'. Circulate 110 bbls of lubricated mud into 7-5/8' X 10 -3/4' annulus with full returns. RIH with 7 -5/8" casing 1/3,270'1/8,597'. PU casing hanger and landing joint at 8,597'; land casing at 8 654'. no returns while running casing from 6000' and to TD. RD fill up tool and RU cement head and lines. Pumped 1 casing capacity 400 bbls total of with no returns. Pump 10 bbls of seawater, test lines to 4500 psi - Good test, pump 55 bbls of spacer, pump 34.6 bbls (164 sx) Class G cement at 15.8 ppg. Clear cement lines with 20 bbls seawater. $_wap over to rig displace cement with 380 bbls 10.0 ppg mud with no returns, but saw lift pressure as cement exited casing, plug bumped and increased pressure to 4500 psi for casing test held 30 min on chart - Good test. CIP ® 19:45 hrs on 12/21/09. Run 7 -5/8" . casing hanger pack off. Test pack off to 5000 psi on chart for 15 min - Good test. I � 1 I 12/22/2009 12/23/2009 8.665.0 0.00' 10.00 Change out upper and lower pipe rams to 2 -7/8' X 5" VBR's in upper and 4" pipe rams in lower. 'Change out Upper IBOP from 4 -1/2 I.F. to 4" XT -39. Install test plug and test joint, RU testing equipment. Test Annular to 250 psi low / 2500 psi high with 4" and 4.5" test joints. Test Upper 2 -7/8" x 5' VBR's with 4' and 4.5" test joints. Lower 4" Single Bore Rams, Blind Rams, Choke and Kill Line HCR's. Choke and Kill Line Manual valves, Floor Safety valve, Dart valve, Upper :IBOP, 14 Choke Manifold valves to 250 psi low / 4500 psi high. Upper IBOP failed. All low and ' high tests held 5 min ea. All tests charted. Accumulator test, System Pressure 3100 psi, After Closure 2125 psi, Initial 200 psi recovery 20 sec's. Full recovery 1 min 22 sec's. Witness of .BOPE test waived by AOGCC representative Bob Noble at 11:00 hrs on 12/21/09. Pull Upper IBOP off of top drive and rebuild valve canister on same. Install upper and lower IBOP and !clamps. RU test equipment. Test upper IBOP valve to 250 psi low / 4500 psi high. f 12/23/2009 12/24/2009 8,665.0 0.001 9.95 Slip and cut drill line. MU Johnny Whacker and TIH picking up 4' singles from the pipe shed 114,731'. Circulate 1.5 times drill pipe capacity to ensure pipe was clear. POOH 1/4,731' V surface, and LD Johnny Whacker. PU and MU 6 -3/4' BHA and MWD toots 1/122. PU remainder of BHA 1/122' 1/402'. T11-11/402' (/7,829'. 12/24/2009 12/25/2009 8,665.0; 1,093.00 10.10 Perform BAT /SONIC cement quality log at 225 tph (/7,980' V8,568'MD. Drill cement and float iequipment 1/8,561' t/8,654'MD. CBU at 8,654', prior to picking up and install RCD head. Complete Drill out of Float shoe @ 8,656'MD, Wash and ream rat hole 1/8,656' V8,665'MD. Drill 10' of 6 -3/4' new hole (/8,665' V8,675'MD. Perform F.I.T. at 7 -5/8' casing shoe 8.6Se' MD / 5,962.4' TVD, w/ 775 psi , 10.0 ppg mud for EMW of 12.5 ppg - Good test. 1.1 bbls pumped and .7 bbls bled back 6 -3/4' hole 1/8,675' 119,758' maintaining 11.5ppg f=CD w/ MPD; (TD Called by Well Site Geologists). Take slow pump rates and survey on bottom at 9,758'. Pump 25 bbl hi- vis/LCM sweep and pump same out of the bit. Back ream out the hole 1/9,758' 1/9,179'MD. 12/25/2009 12/26/2009 9,758.0 0.00 11.95 Back ream out the hole 1/9179' 1/8 601'. CBU at 8,601'.11111/8,601' 1/9,758'. CBU at 9,758'. Circulate and raise mud wl from 10.0 to 12.0 ppg using 17.0 ppg spike 61dd. TIH (19,758' 1/8,600'. Pull RCD bearing and install trip nipple, pump dry job, and drop raid kt drill pipe. TIH 1/8,600' 11402' (BHA). Down load MWD and LD BHA. RU 4.5' ffnerloos, MU shoe track and circ thru same, RIH with 3Q joints total of 4.5', L-80, 12.6e, Hyd S21 tubing to 1,208% PU and MU WFT 'PHR' Hyd liner hanger. 'TSP' liner top packer, ''PBR" 16' Tile back sleeve, liner running tool, bumper jars and 1 stand of 4' HWDP. TIH with 4.5', L-80, 12.64, Hyd 521 tubing hung on 4' drill pipe 1/1,342' 113,270' (SLM). 1 , Page 213 Report Printed: 1/29/2010 PIONEER •perations Summary Report • NATURAL RESOURCES ii i Depth Stan Foot/ Meters Last Mud Stan Date End Date ttIKB) (ft) Dens ( gal) Summary 112/26/2009 12/27/2009 9.758.01 0.00 11.85;TIH with 4.5" liner 1/3,270' V8,576'. CBU at 8,576'. TIH with 4.5" liner (/8,576' V9.758'. Establish (circulation at 1/2 bpm and stage pumps up to 3 bpm. MU cement head and lines. Drop 1 -1/2" ,aluminum ball and pump down same at 1 bprn at 400 psi, seat ball with 2000 psi, set 50k down to set liner hanger, Pressure up and sheer ball seat with 3600 psi. Pump 10 bbls of seawater, test lines to 4500 psi - Good test. Pump 55 bbls spacer al 12.5 ppg, pump 54 bbls (259 sx) Class 'G' cement at 15.8 ppg, 5.12 gps mix water, 1.17 cu ft/sk yield. Drop plug, pump 30 bbls viscous 12.0 ppg brine. Swap over to rig pumps. displace cement at 5 bpm with 67.6 bbls 12.0 ,ppg mud at 1600 psi. Latched liner wiper plug at 48.9 bbls and sheer same with 3000 psi. Plug bumped and increased pressure to 2500 psi. Full returns throughout job. CIP at 12:45 hrs. PU 6' to expose packer setting dogs and slack of with 50k down to set liner top packer. PU 1/8,520' 1/8.470': CBU. shut down um s and line up to test IA. Attempt to test IA to 4500 psi - P P P P P unsuccessful: could not acheive over 4300 psi. POOH 1/8,470' V surface. PU bit and 7-5/8' Razor -back casing scraper and TIH 1/3,413'. I I I i 12/27/2009 12/28/2009 9,758.0 0.001 8.60 TIH with 7 -5/8" casing scraper 1/3,413' 1/8,520', tag liner top with 10k. Circulate hole clean with 2- 30 bbl hi -vis sweeps. TP t ca ing to 4 00 psi onchart held 30 min - Good test. Displace well from 12.0 ppg mud to seawater with 30 bbl hi -vis spacer. POOH 1/8,520' and LD scraper 'assembly. Pull wear bushing and install test plug in wellhead. Change out lower rams from 4" to 1 3.5 ". RU test equipment and attempt to lest lower rams - failed. Open ram doors and inspect rams, change out same. Test Annular to 250 psi low / 2500 psi high. Test lower pipe rams to 1 250 psi low / 4500 psi high. All low and high tests held 5 min ea. All tests charted - Good tests. 1 RD test equipment. RU 3.5" tubing tools. RIH with 3.5', L -80, 9.34, THSP tubing and jewelry 1/ I surface 1/405'. 1 1 I 12/28/2009 112/29/2009 9,758.0 0.00 8.60IPU WFT down hole pressure / temperature gauge carrier, install gauge, and test same - Good hest. RIH with 3.5 ". L -80, 9.311, THSP tubing and jewelry 1/405' 1/7,799'. PU HES TRSSSV - set 1@ 745.5'. MU control line on same, and test line to 5000 psi held 10 min - Good test. RIH with 13.5" tubing (/7,799' 1/8,494'. PU tubing hanger and landing joint, MU same. Make control line I penetrations through hanger. Land tubing hanger at 8,537.6', run in lock downs and test upper • and lower hanger seals to 5000 psi on chart held 10 min ea - Good tests. RD all 3.5" tubing 'equipment. Change out lower rams from 3.5" to 5 ". ND all MPD equipment. 12/29/2009 12/30/2009 j 9,758.0 0.00 8.601 ND BOPE. Make penetrations through well head with HES control line and WFT TEC wire. NU production tree and attempt to test void on same - no test. Remove production tree and change out gasket. Test void on tree to 5000 psi - Good test. Test tree to 250 psi low and 5000 si hi h - Good test. All tests charted and all tests held 5 min ea, Freeze protect well wt 107 bls diesel pumped down IA followed by 205 bbls corrosion inhibited seawater. RU rod lubricator and drop ball and rod. Pressure up to 4600 psi to set packer and told 4600 psi on chart for 30 min to test tubing. Test 3 1/2 X 7 5/8 annulus to 4600psi held 30 min on chart - Good teat. RU kill line • to OA, inject 170 bbls seawater, and freeze protect with 80 bbls diesel. RIH with overshot, latch on to ball and rod at 8,299' and POOH with same. RIH with plug catcher, latch on to RHC-M plug at 8,465' and POOH with same. RIM with radial CBL, CCL, and gamma -ray tool to 3,000' wlm. Jeff Jones waived witness of MIT o1 Tbg. packers for AOGCC. 12/30/2009 12/31/2009 9,758.0 0.00 Perform CBUCCUGR to 9,490' WLM. POOH( w/ same. RIH w/ CCUGR/2 -1/2" Peri Guns. Set Perf Guns 1/8,736' 1/8,756' WLM and Fire 2 -1/2' Guns. POOH and LD Guns and E -line. Prepare 6 j/ rig for move from ODSK -42Ai to ODSK -13i. Move rig to end of Wellbays. Blowdown rig water L ,/ system in pits, drain all pumps and transfer all excess water to RSC. Disconnect service lines in PUTZ and HUTZ. Disconnect all electrical lines between pits and substructure. Start pit complex moving generator. Laying rig mats around west end of Wellbay Modules while removing MPD Pump Module from under rig. AOGCC representative Mr. Jeff Jones waived witness of MIT of Tubing packers. Request charts to be sent in to the AOGCC Anchorage office. Witness of MIT once well has stabilized from initial injection. Release rig from ODSK -42Ai at2400hrs on 12/30/09. Accepted rig on ODSK -13i at 0001hrs on 12/31/09. Page 3/3 Report Printed: 1/29/2010 • • ODSK -42Ai Kuparuk Injection - As Built Completion Well Head: 9 5/8 ", 5K, VetcoGray Casing Tree: 3 - 1/2 ", 5K, Horizontal Item # Item MD (ft) TVD (ft) A 16" Conductor 153 153 I • O B 10 45.5# L -80 BTC, 8.835" ID 3,289 2,980 C 7%" 29.7# L-80 BTC M, 6.875" ID ' 5 ,963 © D 41/2# 12.60# L-80 Hydril 521 9,753 6,668 E 3'/2' 9.3# L -80 TSHP 8,538 5,894 i Upper Completion Item # Item MDrkb (ft) TVDrkb (ft) 1 VetcoGray Tuning Hanger 34 34 HES Wellstar TRSSSV w/ 3' /z" 9.2# TSHP Box x Pin 9 2 745 745 Chr w/ 2.813 "X' Profile w/ 1/4" x .049 SS CL to Surface 3 GLM #1 HES Vanoil 31/2" x 1'/2' Gas Lift Mandrel w/ 3'/2' 3,455 3,068 4 � 9.2# TSHP Box x Pin w/ Shear Out Valve in place 0_1 4 GLM #2 HES Vanoil 31/2" x 1' /z" Gas Lift Mandrel w/ 31/2" 8,055 5,625 9.2# TSHP Box x Pin w/ Dummy in place 5 WFT Gauge & Carrier w/ 31/2" 9.2# 8rd EUE Pin x Pin 8,139 5,672 O 6 HES 2.813 "X' Nipple 9 Chr w/ 31/2" 9.2# TSHP Box x Pin 8,217 5,715 Weatherford 3'/2 x 7 -5/8" Model "Ultra Pak -TH" Hydraulic 7 Set Permanent Production Packer w/ 3'/2 9.3# TSHP Box 8,300 5,761 x Pin 8 8,389 5,811 HES 2.813 "X' Nipple 9 Chr w/ 3'/z" 9.2# TSHP Box x Pin 9 HES 2.813 "XN" Nipple w/ 2.750" No -Go 9Chr w/ 3'/2" 8,466 5,854 TSHP Box x Pin w/ "RCH -M" Plug in Place 10 WLEG w/ 3'/2" TSHP Box 8,536 5,893 O J End of Assembly 8,538 5,894 Lower Completion © Item # Item __- MD (ft) TVD (ft) O ® 11 WFT PBR Tie Back Sleeve 15ft 5 -3/4" I.D. 8,521 5,884 12 WFT "NTH" Liner Top Pkr w/ Hold Down Slips 5 -1/2" x 7- 8,537 5,893 • o 13 WFT "PHR" Rotating Liner Hanger 5 -1/2" x 7 -5/8" 8,540 5,895 © • • 14 Reamer Shoe 9,751 6,666 End of Assembly 9,753 6,668 ® Perforations O _ Item # Item MD (ft) TVD (ft) 15 Perforations - conducted via e -line post rig 8,736 6,004 • - 6 SPF 60 deg phasing 120 total shots 8,756 6,015 15 0 0 Date: Revision By: Comments 11/30/09 VTJ Proposed Completion P 10 N E E R 12/2/2009 jdf Proposed completion - wp6 ODSK -42Ai Injector 12/30/2009 TWC As Built NATURAL RESOURCES Well Schematic As Built • Halliburton Company • Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -42i - Slot ODS -42 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -42i North Reference: True Wellbore: ODSK -42Ai Survey Calculation Method: Minimum Curvature Design: ODSK -42Ai Database: .Pioneer Alaska Project Oooguruk Development 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 ODSK -42i - Slot ODS -42 Well Position +N / -S 0.00 ft Northing: 6,031,028.13 ft • Latitude: 70° 29' 45.027 N +E / -W 0.00 ft Easting: 469,844.38 ft • Longitude: 150° 14' 47.689 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft 1 Wellbore ODSK -42Ai ! Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 12/6/2009 22.02 80.81 57,756 Design ODSK -42Ai Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,289.20 Vertical Section: Depth From (TVD) +N / -S +E/ -W Direction (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 155.17 'Survey Program Date 1/28/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 42.77 1,484.00 ODSK -42i Gyro (ODSK -42i KupG) SR- Gyro -SS Fixed:v2:surface readout gyro single shot 11/2/2009 1: 1,575.43 3,289.20 ODSK -42i MWD (ODSK -42i KupG) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 11/2/2009 1: 3,289.20 9,745.29 ODSK -42A MWD (ODSK -42Ai) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 11/30/2009 • Survey Map Map Vertical MD Inc Azi TVD TVDSS +N / -S +E / -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °i1o0') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,028.13 469,844.38 0.00 0.00 UNDEFINED 50.00 0.14 45.30 50.00 -6.20 0.01 0.01 6,031,028.14 469,844.39 1.92 0.00 SR- Gyro -SS (1) 100.00 0.18 167.40 100.00 43.80 -0.03 0.07 6,031,028.10 469,844.45 0.56 0.05 SR- Gyro -SS (1) 171.00 0.64 262.06 171.00 114.80 -0.19 -0.30 6,031,027.94 469,844.08 0.96 0.05 SR- Gyro -SS (1) 258.00 0.82 265.08 257.99 201.79 -0.31 -1.40 6,031,027.82 469,842.97 0.21 -0.31 SR- Gyro -SS (1) 348.00 0.89 241.49 347.98 291.78 -0.70 -2.66 6,031,027.44 469,841.72 0.40 -0.48 SR- Gyro -SS(1) 441.00 1.39 221.79 440.96 384.76 -1.89 -4.05 6,031,026.26 469,840.33 0.68 0.01 SR- Gyro -SS(1) 531.00 2.12 195.00 530.92 474.72 -4.31 -5.20 6,031,023.84 469,839.16 1.20 1.72 SR- Gyro -SS (1) 625.00 1.79 190.29 624.87 568.67 -7.43 -5.92 6,031,020.72 469,838.43 0.39 4.26 SR- Gyro -SS (1) 721.00 1.66 160.05 720.83 664.63 -10.21 -5.71 6,031,017.94 469,838.63 0.95 6.87 SR- Gyro -SS (1) 815.00 2.41 149.29 814.77 758.57 -13.19 -4.24 6,031,014.96 469,840.09 0.89 10.20 SR- Gyro -SS(1) 912.00 2.46 152.06 911.68 855.48 -16.79 -2.22 6,031,011.36 469,842.09 0.13 14.30 SR- Gyro -SS (1) 1/2812010 10:20:23AM Page 2 COMPASS 2003.16 Build 428 i Halliburton Company • Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -421 - Slot ODS -42 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Weil: ODSK -42i North Reference: True Wellbore: ODSK -42Ai Survey Calculation Method: Minimum Curvature Design: ODSK -42Ai Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N / -S +E / -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 1,007.00 3.23 165.85 1,006.56 950.36 -21.18 -0.61 6,031,006.95 469,843.68 1.08 18.97 SR- Gyro -SS (1) 1,101.00 4.99 179.14 1,100.32 1,044.12 -27.84 0.10 6,031,000.29 469,844.37 2.12 25.31 SR- Gyro -SS (1) 1,196.00 5.85 176.72 1,194.89 1,138.69 -36.80 0.44 6,030,991.33 469,844.67 0.94 33.59 SR- Gyro -SS (1) 1,292.00 7.26 175.88 1,290.26 1,234.06 -47.74 1.15 6,030,980.39 469,845.34 1.47 43.81 SR- Gyro -SS (1) 1,386.00 8.58 172.24 1,383.36 1,327.16 -60.61 2.53 6,030,967.52 469,846.66 1.50 56.07 SR- Gyro -SS (1) 1,484.00 10.82 170.95 1,479.96 1,423.76 -76.94 4.96 6,030,951.18 469,849.03 2.30 71.91 SR- Gyro -SS (1) 1,575.43 12.73 168.73 1,569.46 1,513.26 -95.30 8.28 6,030,932.81 469,852.27 2.15 89.96 MWD +IFR2 +MS +sag (2) 1,618.69 12.79 171.58 1,611.65 1,555.45 - 104.71 9.91 6,030,923.39 469,853.87 1.46 99.19 MWD +IFR2 +MS +sag (2) 1,712.47 15.65 162.09 1,702.56 1,646.36 - 127.02 15.32 6,030,901.06 469,859.19 3.92 121.71 MWD +IFR2 +MS +sag (2) 1,806.04 16.60 158.10 1,792.45 1,736.25 - 151.43 24.19 6,030,876.62 469,867.95 1.56 147.59 MWD +IFR2 +MS +sag (2) 1,906.59 18.70 155.57 1,888.26 1,832.06 - 179.44 36.22 6,030,848.57 469,879.87 2.22 178.06 MWD +IFR2 +MS +sag (2) 1,959.77 19.43 153.54 1,938.53 1,882.33 - 195.12 43.68 6,030,832.86 469,887.27 1.85 195.43 MWD +IFR2 +MS +sag (2) 1,999.47 20.97 152.67 1,975.79 1,919.59 - 207.34 49.89 6,030,820.61 469,893.42 3.95 209.12 MWD +IFR2 +MS +sag (2) 2,095.04 21.66 150.88 2,064.82 2,008.62 - 237.94 66.32 6,030,789.94 469,909.73 0.99 243.80 MWD +IFR2 +MS +sag (2) 2,191.30 23.69 151.46 2,153.63 2,097.43 - 270.45 84.21 6,030,757.36 469,927.48 2.12 280.81 MWD +IFR2 +MS +sag (2) 2,287.47 25.56 157.51 2,241.07 2,184.87 - 306.60 101.38 6,030,721.15 469,944.51 3.26 320.83 MWD +IFR2 +MS +sag (2) 2,347.37 26.64 158.20 2,294.86 2,238.66 - 331.01 111.31 6,030,696.70 469,954.34 1.87 347.16 MWD +IFR2 +MS +sag (2) 2,381.53 28.00 159.80 2,325.21 2,269.01 - 345.65 116.92 6,030,682.04 469,959.89 4.52 362.80 MWD +IFR2 +MS +sag (2) 2,474.31 30.49 162.69 2,406.16 2,349.96 - 388.57 131.45 6,030,639.07 469,974.24 3.08 407.85 MWD +IFR2 +MS +sag (2) 2,569.77 34.04 160.33 2,486.87 2,430.67 - 436.87 147.66 6,030,590.71 469,990.25 3.95 458.49 MWD +IFR2 +MS +sag (2) 2,667.55 38.31 161.04 2,565.78 2,509.58 - 491.32 166.72 6,030,536.18 470,009.09 4.39 515.92 MWD +IFR2 +MS +sag (2) 2,762.31 41.94 157.52 2,638.24 2,582.04 - 548.39 188.38 6,030,479.04 470,030.52 4.52 576.80 MWD +IFR2 +MS +sag (2) 2,857.29 44.80 155.75 2,707.28 2,651.08 - 608.24 214.27 6,030,419.08 470,056.16 3.27 641.99 MWD +IFR2 +MS +sag (2) 2,952.38 47.72 150.81 2,773.03 2,716.83 - 669.53 245.20 6,030,357.68 470,086.84 4.85 710.61 MWD +IFR2 +MS +sag (2) 3,047.36 49.19 148.11 2,836.03 2,779.83 - 730.73 281.33 6,030,296.33 470,122.72 2.63 781.32 MWD +IFR2 +MS +sag (2) 3,140.17 52.37 147.01 2,894.71 2,838.51 - 791.40 319.91 6,030,235.52 470,161.05 3.55 852.58 MWD +IFR2 +MS +sag (2) 3,237.43 56.17 144.26 2,951.50 2,895.30 - 856.52 364.50 6,030,170.22 470,205.37 4.53 930.41 MWD +IFR2 +MS +sag (2) 3,289.20 57.13 143.07 2,979.96 2,923.76 - 891.36 390.12 6,030,135.29 470,230.84 2.66 972.78 MWD +IFR2 +MS +sag (2) 3,321.67 56.52 144.26 2,997.73 2,941.53 - 913.25 406.22 6,030,113.33 470,246.86 3.59 999.41 MWD +IFR2 +MS +sag (3) 3,361.21 54.20 143.94 3,020.21 2,964.01 - 939.60 425.30 6,030,086.91 470,265.82 5.91 1,031.34 MWD +IFR2 +MS +sag (3) 3,393.94 53.53 143.20 3,039.51 2,983.31 - 960.87 440.99 6,030,065.58 470,281.43 2.74 1,057.23 MWD +IFR2 +MS +sag (3) 3,488.76 52.75 147.67 3,096.40 3,040.20 - 1,023.30 484.03 6,030,002.97 470,324.21 3.86 1,131.97 MWD +IFR2 +MS +sag (3) 3,552.93 53.58 150.60 3,134.88 3,078.68 - 1,067.39 510.37 6,029,958.79 470,350.36 3.88 1,183.03 MWD +IFR2 +MS +sag (3) 3,647.30 52.86 145.25 3,191.41 3,135.21 - 1,131.40 550.46 6,029,894.62 470,390.20 4.60 1,257.97 MWD +IFR2 +MS +sag (3) 3,740.95 53.69 147.58 3,247.41 3,191.21 - 1,193.93 591.97 6,029,831.93 470,431.45 2.18 1,332.15 MWD +IFR2 +MS +sag (3) 3,837.17 53.56 147.94 3,304.48 3,248.28 - 1,259.46 633.30 6,029,766.24 470,472.51 0.33 1,408.97 MWD +IFR2 +MS +sag (3) 3,932.52 54.07 148.33 3,360.77 3,304.57 - 1,324.82 673.93 6,029,700.72 470,512.86 0.63 1,485.35 MWD +IFR2 +MS +sag (3) 4,027.06 56.80 153.69 3,414.43 3,358.23 - 1,392.90 711.58 6,029,632.50 470,550.24 5.49 1,562.95 MWD +IFR2 +MS +sag (3) 4,080.23 56.99 154.64 3,443.47 3,387.27 - 1,432.98 730.99 6,029,592.34 470,569.48 1.54 1,607.48 MWD +IFR2 +MS +sag (3) 4,122.33 56.73 154.94 3,466.49 3,410.29 - 1,464.88 746.01 6,029,560.39 470,584.36 0.86 1,642.73 MWD +IFR2 +MS +sag (3) 1/28/2010 10:20:23AM Page 3 COMPASS 2003.16 Build 428 Halliburton Company Definitive Survey Report • Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -42i - Slot ODS -42 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -42i North Reference: True Welibore: ODSK -42Ai Survey Calculation Method: Minimum Curvature Design: ODSK -42Ai Database: .Pioneer Alaska 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 4,217.21 57.40 157.07 3,518.08 3.461.88 - 1.537.62 778.38 6,029,487.52 470,616.44 2.01 1,722.35 MWD +IFR2 +MS +sag (3) 4,314.21 56.87 156.47 3,570.71 3,514.51 - 1,612.49 810.52 6,029,412.53 470,648.27 0.75 1,803.79 MWD +IFR2 +MS +sag (3) 4,408.93 56.66 157.15 3,622.63 3,566.43 - 1,685.32 841.71 6,029,339.58 470,679.17 0.64 1,882.98 MWD +IFR2 +MS +sag (3) 4,503.39 56.97 156.33 3,674.33 3,618.13 - 1.757.94 872.93 6,029,266.84 470,710.09 0.80 1,962.00 MWD +IFR2 +MS +sag (3) 4,596.42 56.67 156.05 3,725.24 3,669.04 - 1,829.18 904.37 6,029,195.48 470,741.23 0.41 2,039.85 MWD +IFR2 +MS +sag (3) 4,694.24 57.48 156.66 3,778.41 3,722.21 - 1,904.39 937.29 6,029,120.14 470,773.85 0.98 2,121.94 MWD +IFR2 +MS +sag (3) 4,789.54 56.85 156.76 3,830.09 3,773.89 - 1.977.94 968.96 6,029,046.47 470,805.21 0.67 2,201.99 MWD +IFR2 +MS +sag (3) 4,882.83 58.46 157.02 3,880.00 3,823.80 - 2,050.43 999.89 6,028,973.87 470,835.84 1.74 2,280.77 MWD +IFR2 +MS +sag (3) 4,979.55 57.94 157.16 3,930.96 3,874.76 - 2,126.15 1,031.89 6,028,898.03 470,867.53 0.55 2,362.92 MWD +IFR2 +MS +sag (3) 5,072.50 57.86 157.13 3,980.36 3,924.16 - 2.198.71 1,062.47 6,028,825.35 470,897.82 0.09 2,441.61 MWD +IFR2 +MS +sag (3) 5,169.15 57.85 156.65 4,031.78 3,975.58 - 2,273.97 1,094.59 6,028,749.97 470,929.63 0.42 2,523.41 MWD +IFR2 +MS +sag (3) 5,264.91 57.27 155.15 4,083.15 4,026.95 - 2,347.74 1,127.58 6,028,676.07 470,962.32 1.45 2,604.22 MWD +IFR2 +MS +sag (3) 5,360.06 57.18 155.23 4,134.66 4,078.46 - 2,420.36 1,161.15 6,028,603.32 470,995.59 0.12 2,684.22 MWD +IFR2 +MS +sag (3) 5,454.47 57.03 155.26 4,185.93 4,129.73 - 2,492.35 1,194.35 6,028,531.21 471,028.49 0.16 2,763.49 MWD +IFR2 +MS +sag (3) 5,549.28 56.94 156.28 4,237.59 4,181.39 - 2,564.85 1,226.98 6,028,458.59 471,060.82 0.91 2,842.99 MWD +IFR2 +MS +sag (3) 5,645.41 57.56 154.80 4,289.60 4,233.40 - 2,638.43 1,260.45 6,028,384.87 471,093.99 1.45 2,923.83 MWD +IFR2 +MS +sag (3) 5,740.12 57.46 154.83 4,340.47 4,284.27 - 2,710.73 1,294.45 6,028,312.45 471,127.69 0.11 3,003.72 MWD +IFR2 +MS +sag (3) 5,835.49 57.23 154.76 4,391.93 4,335.73 - 2,783.38 1,328.64 6,028,239.67 471,161.59 0.25 3,084.01 MWD +IFR2 +MS +sag (3) 5,930.76 57.00 155.00 4,443.66 4,387.46 - 2,855.81 1,362.61 6,028,167.10 471,195.25 0.32 3,164.01 MWD +IFR2 +MS +sag (3) 6,026.13 57.48 153.35 4,495.27 4,439.07 - 2,928.00 1,397.54 6,028,094.78 471,229.90 1.54 3,244.20 MWD +IFR2 +MS +sag (3) 6,121.59 56.87 153.33 4,547.01 4,490.81 - 2,999.69 1,433.54 6,028,022.95 471,265.59 0.64 3,324.37 MWD +IFR2 +MS +sag (3) 6,217.39 56.18 152.98 4,599.85 4,543.65 - 3,070.99 1,469.62 6,027,951.52 471,301.38 0.78 3,404.23 MWD +IFR2 +MS +sag (3) 6,312.06 55.84 152.82 4,652.78 4,596.58 - 3,140.86 1,505.38 6,027,881.50 471,336.85 0.39 3,482.66 MWD +IFR2 +MS +sag (3) 6,407.91 56.24 155.15 4,706.33 4,650.13 - 3,212.30 1,540.24 6,027,809.93 471,371.42 2.06 3,562.14 MWD +IFR2 +MS +sag (3) 6,500.73 55.68 154.90 4,758.28 4,702.08 - 3,282.02 1,572.72 6,027,740.09 471,403.61 0.64 3,639.05 MWD +IFR2 +MS +sag (3) 6,597.47 54.22 155.02 4,813.84 4,757.64 - 3,353.77 1,606.24 6,027,668.21 471,436.84 1.51 3,718.25 MWD +IFR2 +MS +sag (3) 6,692.74 55.43 155.12 4,868.72 4,812.52 - 3,424.39 1,639.06 6,027,597.46 471,469.37 1.27 3,796.12 MWD +IFR2 +MS +sag (3) 6,787.22 55.57 155.71 4,922.24 4,866.04 - 3,495.20 1,671.45 6,027,526.54 471,501.47 0.54 3,873.98 MWD +IFR2 +MS +sag (3) 6,881.62 54.48 154.64 4,976.35 4,920.15 - 3,565.40 1,703.92 6,027,456.21 471,533.66 1.48 3,951.33 MWD +IFR2 +MS +sag (3) 6,977.53 57.12 154.17 5,030.25 4,974.05 - 3,636.93 1,738.19 6,027,384.55 471,567.63 2.78 4,030.64 MWD +IFR2 +MS +sag (3) 7,071.92 56.74 153.10 5,081.76 5,025.56 - 3,707.80 1,773.32 6,027,313.54 471,602.47 1.03 4,109.71 MWD+IFR2 +MS +sag (3) 7,167.92 56.32 154.76 5,134.71 5,078.51 - 3,779.73 1,808.51 6,027,241.48 471,637.36 1.51 4,189.77 MWD +IFR2 +MS +sag (3) 7,263.59 56.59 155.31 5,187.57 5,131.37 - 3,852.01 1,842.17 6,027,169.06 471,670.72 0.56 4,269.50 MWD +IFR2 +MS +sag (3) 7,358.24 55.49 155.44 5,240.44 5,184.24 - 3,923.38 1,874.88 6,027,097.57 471,703.14 1.17 4,348.01 MWD +IFR2 +MS +sag (3) 7,454.17 54.85 154.39 5,295.24 5,239.04 - 3,994.70 1,908.26 6,027,026.13 471,736.23 1.12 4,426.75 MWD +IFR2 +MS +sag (3) 7,548.56 54.53 156.50 5,349.80 5,293.60 - 4,064.75 1,940.27 6,026,955.96 471,767.95 1.86 4,503.76 MWD +IFR2 +MS +sag (3) 7,643.75 54.90 158.90 5,404.79 5,348.59 - 4,136.63 1,969.74 6,026,883.96 471,797.13 2.09 4,581.38 MWD +IFR2 +MS +sag (3) 7,739.65 56.49 154.88 5,458.85 5,402.65 - 4,209.45 2,000.85 6,026,811.02 471,827.94 3.84 4,660.54 MWD +IFR2 +MS +sag (3) I I 7,834.35 55.43 154.22 5,511.86 5,455.66 - 4,280.31 2,034.57 6,026,740.03 471,861.36 1.26 4,739.00 MWD +IFR2 +MS +sag (3) 7,929.27 56.18 155.11 5,565.21 5,509.01 - 4,351.27 2,068.16 6,026,668.94 471,894.66 1.11 4,817.51 MWD +IFR2 +MS +sag (3) 1/28/2010 10:20:23AM Page 4 COMPASS 2003.16 Build 428 Halliburton Company • Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -42i - Slot ODS -42 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Weil: ODSK -42i North Reference: True Welibore: ODSK -42Ai Survey Calculation Method: Minimum Curvature Design: ODSK -42Ai Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N / -S +E / -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 8,023.29 57.12 153.34 5,616.90 5,560.70 -4.421 99 2,102.32 6,026,598.10 471,928.53 1.86 4,896.03 MWD +IFR2 +MS +sag (3) 8,118.87 55.90 153.30 5,669.64 5,613.44 - 4.493.21 2,138.11 6,026,526.74 471,964.03 1.28 4,975.70 MWD +IFR2 +MS +sag (3) 8,215.75 56.49 153.22 5,723.54 5,667.34 - 4,565.10 2,174.33 6,026,454.71 471,999.95 0.61 5,056.15 MWD +IFR2 +MS +sag (3) 8,310.35 56.90 153.19 5,775.48 5,719.28 - 4,635.68 2,209.97 6,026,384.00 472,035.30 0.43 5,135.17 MWD +IFR2 +MS +sag (3) 8,405.51 56.61 153.76 5,827.65 5,771.45 - 4,706.88 2,245.51 6,026,312.65 472,070.55 0.59 5,214.72 MWD +IFR2 +MS +sag (3) 8,500.53 57.08 154.42 5,879.62 5,823.42 - 4,778.44 2,280.27 6,026,240.97 472,105.02 0.76 5,294.26 MWD +IFR2 +MS +sag (3) 8,596.00 56.49 156.00 5,931.92 5,875.72 - 4.850.94 2,313.76 6,026,168.33 472,138.21 1.52 5,374.12 MWD +IFR2 +MS +sag (3) 8,684.53 57.85 156.29 5,979.91 5,923.71 - 4,918.98 2,343.84 6,026,100.18 472,168.01 1.56 5,448.50 MWD +IFR2 +MS +sag (3) 8,780.71 55.96 155.60 6,032.43 5,976.23 - 4,992.55 2,376.68 6,026,026.48 472,200.55 2.05 5,529.07 MWD +IFR2 +MS +sag (3) 8,877.11 55.06 155.92 6,087.01 6,030.81 - 5,065.00 2,409.30 6,025,953.91 472.232.87 0.97 5,608.52 MWD +IFR2 +MS +sag (3) 8,973.79 53.57 156.50 6,143.41 6,087.21 - 5,136.85 2,440.98 6,025,881.94 472,264.26 1.62 5,687.03 MWD +IFR2 +MS +sag (3) 9,067.25 51.98 156.94 6,199.95 6,143.75 - 5,205.21 2,470.40 6,025,813.47 472,293.39 1.74 5,761.42 MWD +IFR2 +MS +sag (3) 9,165.99 50.16 156.96 6,261.99 6,205.79 - 5,275.89 2,500.47 6,025,742.68 472,323.17 1.84 5,838.19 MWD +IFR2 +MS +sag (3) 9,262.15 49.03 158.18 6,324.32 6,268.12 - 5,343.56 2,528.41 6,025,674.89 472,350.84 1.52 5,911.34 MWD +IFR2 +MS +sag (3) 9,359.17 47.58 158.48 6,388.85 6,332.65 - 5.410.89 2,555.16 6,025,607.47 472,377.32 1.51 5,983.68 MWD +IFR2 +MS +sag (3) 9,455.93 46.53 158.45 6,454.77 6,398.57 - 5,476.77 2,581.16 6,025,541.49 472,403.05 1.09 6,054.39 MWD +IFR2 +MS +sag (3) 9,552.27 45.51 159.66 6,521.67 6,465.47 - 5,541.51 2,605.95 6,025,476.66 472,427.57 1.39 6,123.55 MWD +IFR2 +MS +sag (3) 9,648.96 42.93 159.83 6,590.96 6,534.76 - 5,604.77 2,629.29 6,025,413.31 472,450.65 2.67 6,190.76 MWD +IFR2 +MS +sag (3) 9,745.29 40.12 160.98 6,663.07 6,606.87 - 5,664.91 2,650.73 6,025,353.08 472,471.84 3.02 6,254.35 MWD +IFR2 +MS +sag (3) 9,758.00 , 40.12 160.98 6,672.79 . 6,616.59 - 5,672.66 2,653.39 6,025,345.33 472,474.47 0.00 6,262.50 PROJECTED to TD 1/28/2010 10:20:23AM Page 5 COMPASS 2003.16 Build 42B ti • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U ' Other U Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -e er Suspended Well ❑ 2. Operator 4. Well Class Before Work: Permit to Drill Number: Name: Pioneer Natural Resources Alaska, Inc. Development ❑ Exploratory ❑ 209 -156 3. Address: 700 G Street, Suite 600 Stratigraphic❑ Service El \k. API Number: Anchorage, AK 99501 50- 703 - 20605 -01 7. Property Designation (Lease M fiber): 8. Well Name and Num er: ( , \ ADL 355036 ODSK -4 E AEI �! E 9. Field /Pool(s): Oooguruk - Kuparuk Oil Pool ' ti j (1 10. Present Well Condition Summary: Alaska (Jii ia,. Ct. Cammisstor Total Depth measured \ 9758 feet Plugs (measured) N/A fel{rx .p true vertical \ 6672 feet Junk (measured) N/A feet Effective Depth measured 9751 feet Packer (measured) see info below feet true vertical 6666 feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3251' 10 -3/4" 3289' 2980' 5210 2470 Intermediate 8616' 7 -5/8" 8654' 5962' 6890 4790 Production Liner 1232' 4 -1/2" 8521' - 9753' 5890' - 6668' 8430 7500 Perforation depth: Measured depth: 8736' - 8756' True Vertical depth: 6004' - 6015' Tubing (size, grade, measured and true vertical depth): 3 -1/2 ", 9.3# L -80, THSP 8538' MD 5900' TVD Wellstar SSSV P nduction Pkr Liner Top Pkr Packers and SSSV (type, measured and true vertical depth): 745'MD / 7451 t 00'MD / 5761'TVD 8537'MD / 5899' TVD to P eKle 11. Stimulation or cement squeeze summary: Intervals treated (measured): Kuparuk 8736' - 8756' MD Treatment descriptions including volumes used and final pressure: Initial injection 500 bbls Sea Water followed by 100 bbls Sea Water See attached chart for pressures 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: - - - 44 2 Subsequent to operation: - - 3100 400 2262 13. Attachments: ^fit. Well Class after work: Copies of Logs and Surveys Run X Exploratory Development Service IS , Daily Report of Well Operations X k. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ IS . SPLUG ❑ 16. 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: 309 -439 Contact Tim Crumrine, 343 - 2184 Prepared By: Kathy Campoamor, 343 - 2183 Printed Name Tim Crumrine Title Completions Engineer Signature ,..----- Phone 343 -2184 Date 1/11/2010 /_ /2 _QC) Form 10 -404 Revised 7/2009 Submit Original Only • Pioneer Natural Resources Alaska ODSK -42Ai High Pressure Break Down Operation Summary Jan. 1 2010 Max Pressure: 3625 psi Max Rate: 6.59 bpm 2:OOpm) PJSM/Hazzard Analysis w /Halliburton, ASRC, & Pioneer Personnel. All channel announcement made. All lines checked & safety whipped. 2:10pm) Pressure up IA on ODSK -42Ai w/Injection pump to 1,000psi & lock in same, (charted throughout the run & scanned same). 2:15pm) Line up on HT Unit through kill line manifold of drilling rig, (we were able to utilize rig equipment off critical path to provide safer operation). As unable to get ROC gauge to record to historian mode, have only requested recorded data. BHP= 3090psi / BHT= 142 F prior to start of procedure. 2:20pm) Est. circulation w /couple BBL's Seawater. Shut in line & pressure test to 4500psi. Held pressure w /drop off to 4460psi after 10min's (very cold outside, lines contracting — good test). 2:30pm) Bleed off pressure from HT unit to zero, & open Lo Torque valve to 3 -1/2" Tbg. 2:36pm) Begin pumping @ '/2 BPM & increase to approximately 2 BPM & hold until break over est. @ 1800- 1858psi, (ROC gauge had BHP= 415psi / BHT= 142 deg F at break over point). Continue to step up to 4500psi max. injection pressure, and able to achieve 6.6 BPM max. rate from the HT unit. Had a BHP= 4541psi / 142.3 F BHT @ 383 BBL's away of the 500 BBL's Sea Water total, @ 6.5 BPM rate, w /3500psi injection pressure. At the 500 BBL's total Sea Water pumped, had 5.9 BPM injection rate @ 3265psi. The BHP= 4843psi / 142.3 F BHT. The Sea Water has no additives added from Operation, (i.e. straight Sea Water, no surfactants or inhibitors of any kind). 4:10pm) ISIP= 1840psi 5min= 1615psi 10min= 1610psi 15min= 1603psi 20min= 1597psi 25min= 1591psi FSIP= 1586psi BHP= 3312.8psi / BHT= 142 F from ROC gauge at end of shut in. 4:45pm) Initialize pumping final 100 BBL's of Sea Water @ 2700psi rate Per Town Drilling Manager procedure. Average 5.1 -5.3 BPM rate @ the 2700psi max. injection pressure, w/a final 2470psi @ 3.8 BPM rate. • • Pioneer Natural Resources Alaska ODSK -42Ai High Pressure Break Down Operation Summary Jan. 1 2010 The final BHP= 4208.8psi / BHT= 142 F at the end of the 100 BBL's injection period. 5:10pm) ISIP= 2470psi 5min= 1716psi 10min= 1706psi 15min= 15min= 1697psi 20min= 1690psi 25min= 1681psi w/FSIP= 1675psi 5:40pm) Bleed off all pressures from IA, & TBG. Hoses & lines. Rig down all charts & recorders, & blow down same. Continue w /rig up operation. B Rate (bpm) B Density (lb gal) C Pressure (psi) F C F 26 —5000 14-13 4 I s 6 7 I - 24 12— — —4000 - ,,�� - 10— 18 -., —3000 Et ..,Q .. — 16 , - 6_ 1 -1-1 —2000 I%) — 12 Q , 10 —1000 2 8 —6 —0 4:10 14:15 14:20 14:25 14:30 14:35 14:40 1 1 2010 1 1;2010 Time Global Event Log Intersection P Intersection P I i I P6 - Applied 1000 psi on IA 14:10:12 2.888 4 Fill lines 14:14:55 6.738 15 I Test Lines 14:20:52 4564 16 Begin Pumping 14:30:10 23,52 I 7 Break over 1823 psi 14:34:54 1823 ustomer: Pioneer Natural Resources Alaska 1 Job Date: 01- Jan -2010 1 Sales Order #: B Rate (bp n) B Density (lb/gal) . C Pressure (ps) , F C F - —26 4000 14— 8 9 - .2 3500 _ �22 12— 3000 10— _ 14 � � _ � � ......... 2500 $ —16 2000 6— Trti —14 :kit 1500 —12 — J 1000 r -1a iii �__ —g 500 a � , 6 a 14:40 15:00 15:10 15:40 16:00 16:20 16:40 111:2010 11 2010 Time Global Event Loa Intersection P Intersection' 8 Begin 30 minute shut in 16:09:05 3287 9 Pump last 100 BBLs 16:42:00 ustomer: Pioneer Natural Resources Alaska I Job Date: 01- Jan -2010 Sales Order =: n,, ran, x-4 B Rate (bpm) B Density (lb /gal) C Pressure (psi) • F C F 26 -3000 14- 9 10 11 - - 12 -24 -1500 12- r---1 -22 _1a 10- -2000 . ,_.. _ :18 `,,,, . $~ -16 -1500 , - . 6- -14 tt - J ' Q -1000 _11 4 ) 6.1 J /11114111144411111114 y1 -10 y _ -500 0 T-i , I E 1 1 I I I I 1 . . . . 1 I . T 1 . I T I r h -0 16:40 16:50 17:00 17:10 17:20 17:30 17:40 1/1/2010 1 1 2010 Time Global Event Log Intersection P Intersection P 9 Pump last 100 BBLs 16:42:00 694.1 10 Beo_-in 30 minute shut in 17:07:21 2465 11 End Job 17:40:44 -58.72 12 Ending Job 17:42:12 -58,72 ustomer: Pioneer Natural Resources Alaska Job Date: 01- Jan -2010 1 Sales Order =: rltItir.arn VA ODSK -42Ai HPBD 5000 4500 4000 • 3500 W.,,,,,'."""....+". -.' ✓ .�- E a 3000 - -r--- m cz 3 ao 2500 I — i' cu V a - a a a 2000 —__ ___---- .__ -__- --- ..__._ -. a _ a o_ v 1500 / _ 1000 — 500 14:00:00 15:12:00 16:24:00 17:36:00 18:48:00 Time —I —Pump Pressure (psi) •Volume (bbl) —BH Pressure (psi) - Rate (bpm) BH Temp (degF) 1 , e • . - ODSK -42Ai Kuparuk Injection - As Built Completion Well Head: 9 5/8 ", 5K, VetcoGray Casing Tree: 3 -1/2 ", 5K, Horizontal Item # Item MD (ft) TVD (ft) A 16" Conductor 153 153 O" B go /" 45.5# L -80 BTC, 8.835" ID 3,289 2,980 1 C 7%" 29.7# L -80 BTC -M, 6.875" ID 8,794 6,036 O2 1.0 D 4'/2# 12.60# L -80 Hydril 521 9,753 6,668 E 3W 9.3# L-80 TSHP 8,538 5,894 ilin Upper Completion �-- ��-- MDrkb (ft) TVDrkb (ft) 1 VetcoGray Tubing Hanger 34 34 HES Wellstar TRSSSV w/ 3W 9.2# TSHP Box x Pin 9 2 745 745 Chr w/ 2.813 "X' Profile w/ 1/4" x .049 SS CL to Surface 3 GLM #1 HES Vanoil 31/2" x 1W Gas Lift Mandrel w/ 31/2' 3,455 3,068 OJ O B 9.2# TSHP Box x Pin w/ Shear Out Valve in place 4 GLM #2 HES Vanoil 31/2" x 11/2' Gas Lift Mandrel w/ 31/2' 8 055 5,625 9.2# TSHP Box x Pin w/ Dummy in place 5 WFT Gauge & Carrier w/ 3W 9.2# 8rd EUE Pin x Pin 8,139 5,672 O 6 HES 2.813 "X' Nipple 9 Chr w/ 31/2" 9.2# TSHP Box x Pin 8,217 5,715 Weatherford 31/2 x 7 -5/8" Model "Ultra Pak -TH" Hydraulic 7 Set Permanent Production Packer w/ 31/2 9.3# TSHP Box 8,300 5,761 4," x Pin 8 8,389 5,811 HES 2.813 "X' Nipple 9 Chr w/ 31/2" 9.2# TSHP Box x Pin 9 HES 2.813 "XN" Nipple w/ 2.750" No -Go 9Chr w/ 3' //' 8,466 5,854 TSHP Box x Pin w/ "RCH -M" Plug in Place 10 WLEG w/ 31/2" TSHP Box 8,536 5,893 O J End of Assembly 8,538 5,894 Lower Completion 0 ` ' Item # Item MD (ft) TVD (ft) 3 0 11 WFT PBR Te Back Sleeve 15ft 5 -3/4" I.D. 8,521 5,884 O - _ WFT "NTH" Liner Top Pkr w/ Hold Down Slips 5 -1/2" x 7- 0 r A ■ O 12 8,537 5,893 5/8" 13 WFT "PHR" Rotating Liner Hanger 5 -1/2" x 7 -5/8" 8,540 5,895 © J ■ i 0 14 Reamer Shoe 9,751 6,666 End of Assembly 9,753 6,668 Perforations ® ® _ Item # Item MD (ft) TVD (ft) 15 Perforations - conducted via e -line post rig 8,736 6,004 O ' - 6 SPF 60 deg phasing 120 total shots 8,756 6,015 0 0 0 Date: Revision By: Comments 11/30/09 VTJ Proposed Completion PIONEER ODSK -42Ai Injector 12/2/2009 jdf Proposed completion - wp6 NATURAL RESOURCES 12/30/2009 TWC As Built Well Schematic As Built • • Page 1 of 3 Regg, James B (DOA) Prl) 7 - 0 7 - 6(0 From: Regg, James B (DOA) Sent: Monday, January 04, 2010 12:22 PM �elq• 1 (4 (Zeta To: 'Williams, Theresa' Subject: RE: K-421 MIT Test report is not required to be submitted for the casing test unless specified as condition of permit. The casing test must be documented in daily drilling report (IADC Report) and Pioneer must maintain records that substantiate the test (e.g., chart) that are available to Commission inspection upon request. Jim Regg AOGCC 0451,(4' rrVr+ 333 W.7th Avenue, Suite 100 A 6 d Anchorage, AK 99501 907 - 793 -1236 From: Williams, Theresa [mailto:Theresa.Williams @pxd.com] Sent: Monday, January 04, 2010 12:04 PM To: Regg, James B (DOA) Subject: RE: K -42i MIT Jim, Is Drilling required to submit their test since the AOGCC does have the option of witnessing the test? Theresa Williams From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, January 04, 2010 12:01 PM To: Williams, Theresa Cc: Brooks, Phoebe L (DOA) Subject: RE: K -42i MIT Thank you; the test on 12/31 is the one we need. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Williams, Theresa [ mailto :Theresa.Williams @pxd.com] Sent: Monday, January 04, 2010 11:19 AM 1/4/2010 • • Page 2 of 3 To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA) Subject: RE: K -42i MIT The data I sent was from the casing test drilling did and I did not see the tubing pressure on the chart recorder plot. We did a MIT on the 31 and monitored all 3 pressures. I'll get that form into you later today. Theresa Williams From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, January 04, 2010 10:32 AM To: Williams, Theresa Cc: Brooks, Phoebe L (DOA) Subject: RE: K -42i MIT did you monitor pressure in the tubing during MIT, or was the tubing pressure in fact zero? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Williams, Theresa [mailto :Theresa.Williams @pxd.com] Sent: Thursday, December 31, 2009 10:35 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Crumrine, Tim; Campoamor, Kathy; Schwartz, Guy L (DOA) Subject: K -42i MIT Attached is the data for the tbg x casing MIT conducted Dec. 29 Theresa Theresa.Williams @pxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 1/4/2010 . • Page 3 of 3 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 1/4/2010 Page 1 of 1 Regg, James B (DOA) From: Williams, Theresa [Theresa.Williams @pxd.com] Sent: Monday, January 04, 2010 12:12 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: OoogurukProdSuper � 7 114* Subject: ODSK -42 MIT Attachments: MIT ODSK -42i 12- 31- 09.xls c K - 4 ZA Attached are results of 12 -31 -09 test. Theresa Williams Theresa.Williamspxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 1/4/2010 • i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; tom. maunder @alaska.gov; phoebe. brooks@ alaska. gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: Pioneer Natural Resources , \ eiy 1/4 (70,0 FIELD / UNIT / PAD: Oooguruk (( DATE: 12/31/09 OPERATOR REP: D Hulien AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well ODSK -42A Type Inj. W TVD °' 5,851' Tubing 465 676 650 630 Interval I P.T.D. 2091560 ' Type test P Test psi ' 2500 Casing 50 2,510 2,440 ''2,425 P/F P Notes: Pre - Injection MIT IA 3 bbls Diesel OA 645 710 690 685 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT ODSK -42i 12- 31- 09.xls 0 1 i h ` 'k C, 1, ' L p ' SEAN PARNELL, GOVERNOR ' 6 i , ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1'IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Mr. Tim Crumrine Completions Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Oooguruk - Kuparuk Oil Pool, ODSK -42Ai Sundry Number: 309 -439 Dear Mr. Crumrine: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). 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 Chair / DATED this 3 5 ` day of December, 2009 Encl. 4 • y RECEIVED December 30, 2009 DEC 3 A 2009 Alaska Oil & Ga3 Cons. Commission Anchorage State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: ODSN -42Ai Application for Sundry Approval for High Pressure Breakdown Permit to Drill #209 -156 Attachments: 10-403 Application for Sundry Approval ODSK -42Ai Wellbore Schematic Summary Operational Procedure Pioneer Natural Resources Alaska, Inc. (PNRA) is submitting a 10 -403 Application for Sundry Approval for a High Pressure Breakdown for the ODSK -42Ai for the purpose of breaking past . drilling skin damage and establishing formation breakdown pressure and rate with the seawater intended for service injection. As you will note requested commencement date for operations is December 30, 2009. Pioneer is requesting approval at your earliest possible convenience, so that the PNRA can analyze formation breakdown pressure and rate and ultimately determine a course of action to either sidetrack the well or possibly conduct a propped fracture stimulation. It is clearly understood that PNRA will not conduct any operations requiring AOGCC sundry without first obtaining written or verbal approval. Thank you for your assistance. Respectfully, • c _ Tim Crumrine, P.E. Staff Completions Engineer Pioneer Natural Resources Alaska, Inc. 907 - 343 -3184 907 - 240 -4295 41,.., �� 0 0 RECEIVED 4 STATE OF ALASKA e. / ALASKA OIL AND GAS CONSERVATION COMMISSION L1� i \V. APPLICATION FOR SUNDRY APPROVALS Alaska Oil Cons. Commission 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate❑ Re -enter SuspendeN e Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate 151 Other ❑ Specify: Change approved program❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Development ❑ Exploratory ❑ 209 - 156 • 3. Address: Stratigraphic ❑ Service Eg 6. API Number: 700 G Street, Suite 600, Anchorage, AK 99051 50 703 - 20605 - 01 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No IS ODSK - 42Ai 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 355036 . Oooguruk - Kuparuk 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): 9758' 6672' 9751' 6666' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3251' 10 - 3/4" 3289' 2980' 5210 2470 Intermediate 8616' 7 -5/8" 8654' 5962' 6890 4790 Production 1232' 4 - 1/2" 8521' - 9753' 5890' - 6668' 8430 7500 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8736 8756 3 -1/2 ", 9.3# L - 80, THSP 8538' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Wellstar SSSV; TSP Liner Top Packer 745' MD / 745' TVD; 8537' MD / 5899' TVD 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program IS BOP Sketch ❑ Exploratory ❑ Development ❑ Service IS 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/30/2009 Oil ❑ Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: 12 oat WINJ El , GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: q S ar( ' s. GSTOR ❑ SPLUG ❑ 17. I hereby certify that the forego;is true and correct to the best of my knowledge. Contact Tim Crumrine, 343 - 2184 Printed Name Tim Crumrine Title Completions Engineer Si n tur . } i(� /i Ph 343 -2184 Date 12/30/2009 �i 4.1 LLJ /i / ✓'� i L«�711 Prepared By: Kathy Campoamor, 343 -2183 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 G 9- / Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: F0 rWar.4 S I 1 A 41 COln /vt.: SSi HI, her /` e_ Le. 6 :Cy.J. Subsequent Form Required: iO ' 1 1 0 1 1 � APPROVED BY � Approved by: / COMMISSIONER THE COMMISSION Date: 1213// (7) • A , Z •3 /D`t DRIGINAL RBDMS JAN -2 1010 2 /i// Form 10 -403 Revised 7/2009 Submit in Duplicate , l 2. y of • • ODSK -42Ai Kuparuk Injection - Proposed Completion Well Head: 9 5/8 ", 5K, VetcoGray Casing Tree: 3 -1/2 ", 5K, Horizontal Item # Item MD (ft) TVD (ft) A 16" Conductor 153 153 O B 103/ 45.5# L -80 BTC, 8.835" ID 3,289 2,980 O C 7%" 29.7# L 80 BTC M, 6.875" ID 8,794 6,036 II O ■ D 4'/2# 12.60# L -80 Hydril 521 9,753 6,668 E 31/2" 9.3# L -80 TSHP 8,538 5,894 Upper Completion Item # Item IMDrkb (ft)ITVDrkb (ft) 1 VetcoGray Tubing Hanger 34 34 HES Wellstar TRSSSV w/ 3'h" 9.2# TSHP Box x Pin 9 2 745 745 Chr w/ 2.813 "X' Profile w/ 1/4" x .049 SS CL to Surface '` GLM #1 HES Vanoil 3'/2" x 1'/2" Gas Lift Mandrel w/ 3'/z' 3 3,455 3,068 N O 9.2# TSHP Box x Pin w/ Shear Out Valve in place O J 4 GLM #2 HES Vanoil 3 x 1'/z' Gas Lift Mandrel w/ 31/2 8,055 5,625 9.2# TSHP Box x Pin w/ Dummy in place 5 WFT Gauge & Carrier w/ 31/2" 9.2# 8rd EUE Pin x Pin 8,139 5,672 O 6 HES 2.813 "X' Nipple 9 Chr w/ 31/2' 9.2# TSHP Box x Pin 8,217 5,715 Weatherford 31/2 x 7 -5/8" Model "Ultra Pak -TH" Hydraulic 7 Set Permanent Production Packer w/ 31/2 9.3# TSHP Box 8,300 5,761 x Pin 8 8,389 5,811 HES 2.813 "X' Nipple 9 Chr w/ 3 9.2# TSHP Box x Pin 9 HES 2.813 "XN" Nipple w/ 2.750" No -Go 9Chr w/ 3'%" 8,466 5,854 TSHP Box x Pin w/ "RCH -M" Plug in Place 10 WLEG w/ 31/2' TSHP Box 8,536 5,893 O J End of Assembly 8,538 5,894 Lower Completion © Item # Item MD (ft) TVD (ft) 0 Q 11 WFT PBR Tie Back Sleeve 15ft 5 -3/4" I.D. 8,521 5,884 12 WFT "NTH" Liner Top Pkr w/ Hold Down Slips 5 -1/2" x 7- 8,537 5,893 • • ii 13 WFT "PHR" Rotating Liner Hanger 5 -1/2" x 7 -5/8" 8,540 5,895 © J • 0 14 Reamer Shoe 9,751 6,666 ® End of Assembly 9,753 6,668 Perforations 0 - Item # Item MD (ft) TVD (ft) - 15 Perforations - conducted via e -line post rig 8,736 6,004 • 6 SPF 60 deg phasing 120 total shots 8,756 6,015 15 0 O Date: Revision By: Comments 11/30/09 VTJ Proposed Completion P1 0 N E E R ODSK -42Ai Injector 12/2/2009 jdf Proposed completion - wp6 NATURAL RESOURCES 12/30/2009 TWC As Built Well Schematic As Built • 4110 G Pioneer Natural Resources Alaska ODSK -42Ai High Pressure Breakdown Operational Summary 1. Submit all necessary diagnostic tests to AOGCC to show that the injection interval is mechanically isolated including mechanical integrity tests conducted on the 7 -5/8" x 3 -1/2" annulus and 3 -1/2" tubing; and cement bond logs on the 7 -5/8" surface casing and 4 -1/2" liner completion. 2. Connect disposal pumps to inner annulus and connect cement pumps lines to wellhead. 3. Pressure test cement lines to 4500 psig. 4. Apply a minimum of 1000 psig pressure on the well's inner annulus. 5. Open wellhead to tubing and begin pumping a step rate test to determine breakdown pressure and rate using seawater. 6. Pump a maximum of 500 bbls during high pressure breakdown. 7. Shut down and record fall off pressures for minimum of 30 minutes. 8. Establish injection with a maximum injection pressure of 2700 psi for an additional 300 bbls fluid. 9. Shut down and record fall off pressures for minimum of 30 minutes. • Page 1 of 2 Regg, James B (DOA) 'Prb ZeN From: Regg, James B (DOA) O P Gf< 9-)-A Sent: Tuesday, December 29, 2009 1:53 PM To: 'Crumrine, Tim' Cc: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: RE: Pioneer Kuparuk K-42Ai Injection Notification Email is sufficient notice of intent to commence injection into ODSK -42 Before authorizing the commencement of injection, the Commission requires opportunity to review the results of the following documents once provided by Pioneer: 1) bond log (pdf or pds format); 2) MIT results; the Commission's North Slope Inspector should be contacted at least 24 hours in advance (659- 2714; preferably during working hours) of the planned MITs for opportunity to witness; MITs for tubing and IA should be conducted to a pressure at least equal to the high pressure breakdown pumping operation; the Commission will witness a post initial injection MIT once injection conditions in the well are stable (Pioneer to notify Commission); High pressure breakdown pumping operations require a 10 -403 unless already addreessed in a previously submitted and Commission approved request. Area Injection Order 33 includes some discussion about fracture modeling and indicates that pressures less than 2900 psi would not propogate fractures into the confining layers bounding the Kuparuk Oil Pool. Provide with the application the planned procedure, pressure, fluid and what impact this operation will have on the confining layers. Also address what monitoring will be in place to assure the confining layers are not penetrated. FYI - Tom Maunder has recently taken over duties for underground injection (he is out of the office until first week of January). Guy Schwartz is your contact for permitting issues at Oooguruk. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Crumrine, Tim [mailto:Tim.Crumrine @pxd.com] Sent: Tuesday, December 29, 2009 10:01 AM To: Regg, James B (DOA) Subject: Pioneer Kuparuk K -42Ai Injection Notification DearJim: In accordance to 20 AAC 25.420, I am notifying you and the commission that Pioneer intends to begin injection no more than 10 days from today's date into the Kuparuk reservoir via the ODSK -42Ai well. We are currently in the process of finalizing the completion, which will include conducting mechanical integrity tests on the 7 -5/8" x 3 -1/2" inner annulus, and 3 -1/2" injection tubing; a cement bond log on the 4 -1/2" liner completion; and perforating a 20' section of the Kuparuk reservoir. We have already conducted a cement bond log on the 7 -5/8" surface casing. These diagnostics are of course to provide evidence that we are injecting into and only into the Kuparuk reservoir. Formation evaluation logs indicate poor quality reservoir in this area of the Kuparuk reservoir. Pioneer is 12/29/2009 410 Page 2 of 2 requesting that we begin immediate injection upon successfully completing the mechanical integrity tests and cement bond logs by conducting a high pressure breakdown of reservoir. This should bypass any drilling related skin damage and provide us a baseline injectivity into the reservoir. If we are unable to inject at sufficient rate without exceeding safe injection pressure, Pioneer may decide to sidetrack the well, or possibly conduct a propped fracture stimulation. In summary, please let me know if a) this email is acceptable to serve as notification of our intent to begin injection, b) Pioneer is able to begin injection into the Kuparuk immediately after successful completion of diagnostics indicating that we are injecting 100% into the Kuparuk reservoir, or must we wait the 10 days. Respectfully, Tim Crumrine, P.E. Staff Completions Engineer Pioneer Natural Resources Alaska, Inc. tim.crumrine@pxd.com Office: 907 - 343 -2184 Cell: 907 - 240 -4295 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 12/29/2009 4 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg©alaska.gov; tom. maunder @alaska.gov; bob. fleckenstein@ alaska. gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: Pioneer Natural Resources �e% 114( Zi)1�:.3 FIELD / UNIT / PAD: Oooguruk 065 ‘C.- DATE: 12/29/09 OPERATOR REP: Joey Cortez CA _ P t S3 AOGCC REP: Waived i / Packer Depth Pretest Initial 15 Min. 30 Min. Well ODSK -42A Type Inj. W TVD " 5,851' Tubing Interval I P.T.D. 2091560 ° Type test P Test psi '4600 Casing 20 4,650 4,605 4,600 P/F P ' Notes: Drilling Tbg x Casing MIT OA_ Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT ODSK -42A 12- 29- 09.xis t • • Page 1 of 3 Schwartz, Guy L (DOA) From: Hazzard, Vance [Vance.Hazzard @pxd.com] p Z o q Sent: Wednesday, December 30, 2009 3:21 PM To: Schwartz, Guy L (DOA) Cc: Crumrine, Tim Subject: RE: Pioneer ODSK -42Ai CBL and MIT Submission We drilled to TD through the Nuiqsut interval in the 4 -1/2" liner. Here are some unofficial geologic tops from the well. The depths may vary a minor amount in the final 407. Torok Top 7,004 5,044' Torok Base 7,460' 5,300' Top HRZ 8,181' 5,704' Base HRZ 8,400' 5,824' Kalubik Marker 8,566' 5,915' ICP 8,656' 5,963' ICP Total Depth 8,665' 5,968' Top Ktm C - T'F 8,740 6,00 LCU 8,753' 6,016' BCU 9,092' 6,214' Top Nuigsut 9,224' 6,298' Base Nuiqsut 9,301' 6,349' Top Nechelik 9,315' 6,358' Base Nechelik 9,594' 6,550' TD 9,758' 6,672' Regards, Vance Vance Hazzard Drilling Manager Pioneer Natural Resources Alaska 907 - 343 -2116 (direct) From: Crumrine, Tim Sent: Wednesday, December 30, 2009 3:09 PM To: Hazzard, Vance Subject: Fw: Pioneer ODSK -42Ai CBL and MIT Submission Vance, I don't have this info with me. Could you answer Guy? From: Schwartz, Guy L (DOA) <guy.schwartz @alaska.gov> To: Crumrine, Tim 12/31/2009 • Page 2 of 3 Sent: Wed Dec 30 18:03:03 2009 Subject: RE: Pioneer ODSK -42Ai CBL and MIT Submission Tim, Now I remember , Kuparuk was just below the intermediate casing set depth. Do you have the interval for the exploration target (Toruk ?) in the 4.5" liner too? Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Crumrine, Tim [mailto:Tim.Crumrine @ pxd.com] Sent: Wednesday, December 30, 2009 2:57 PM To: Schwartz, Guy L (DOA) Subject: Re: Pioneer ODSK -42Ai CBL and MIT Submission 8740 -8753 MD, it's not very big at all From: Schwartz, Guy L (DOA) <guy.schwartz @alaska.gov> To: Crumrine, Tim Sent: Wed Dec 30 17:40:41 2009 Subject: RE: Pioneer ODSK -42Ai CBL and MIT Submission Tim, What is the Kuparuk zone... I know it is small but I don't see it on the GR log !! Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Crumrine, Tim [mailto:Tim.Crumrine @pxd.com] Sent: Wednesday, December 30, 2009 12:35 PM To: Schwartz, Guy L (DOA) Subject: Pioneer ODSK -42Ai CBL and MIT Submission Dear Guy: Please find attached the cement bond logs, MIT -IA and MIT -T pursuant to 20 AAC 25.402.c7 for your review. I will drop off two hard copies today to the AOGCC office. Sincerely, Tim Crumrine, P.E. Staff Completions Engineer Pioneer Natural Resources Alaska, Inc. tim.crumrine @pxd.com Office: 907 - 343 -2184 Cell: 907 - 240 -4295 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 12/31/2009 • 0 Page 3 of 3 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 12/31/2009 • December 30, 2009 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: ODSN -42Ai Cement Bond Log of Intermediate Casing and Liner, and Mechanical Integrity Tests for 7-5/8" x 3 -1/2" Inner Annulus and 3 -1/2" Tubing Permit to Drill #'2O3# Pioneer Natural Resources Alaska, Inc. (PNRA) is submitting the ODSK -42Ai 7 -5/8" Intermediate Casing Bi -Modal Acoustic Cement Log, 4 -1/2" Radial Cement Bond Log, MIT -IA pressure chart, and MIT -T pressure chart for the purpose of proving injection fluid isolation as per 20 AAC 25.402.c7. PNRA is proposing the following: 7-5/8" Intermediate Casing Apparent Top of Cement is located at 7,927' MD. Apparent Fair Bond 7,927' MD to 8,114' MD Apparent Good Bond from 8,114' MD to 8,479' MD. 7 -5/8" Casing set at 8,654' MD. 4 -1/2" Liner Apparent Good Bond 8550' to 9494' 7 -5/8" x 3 -1/2" IA 30 minute Mechanical Integrity Test 4650 psi starting pressure 4600 psi final pressure 3 -1/2" Tubing 30 minute Mechanical Integrity Test 4650 psi starting pressure 4600 psi final pressure Please find attached information as required by 20 AAC 25.402.c for your review. Pertinent information attached to this application includes the following: 1) Bi -Modal Acoustic Cement Log of the injection well. 2) Radial Cement Bond Log of the injection well. 3) Mechanical Integrity Test — Inner Annulus 4) Mechanical Integrity Test - Tubing Please note that no gas lift valves have been changed out since the completion was landed and MITs conducted as per usual practice. Currently, dummy gas lift valves are installed in the completion tubing and will remain in place for the foreseeable future. Sincerely, Tim Crumrine, P.E. Staff Completion Engineer • • 0051c- 4 1ZA PT1 Zo9 - / C-6 4 M( - -- - - -_ 15 __ 1,0* rs L` _ r-i` I 01, 0, - C Py y ____00 Z • —000b- //l ■ ► 000, / No- 7 , i T ''''' c ci)c .;? ..„. 7 .-r / ' ', -. :-...,, , i �� :0009; ,.► 1 , � J. mo o` —7 ��5 � �.c , - :6(5001% ' ► � , /' X500. 4 0,707 /* el • i . ; ' _. 30 00 — _ - - y ? 4r..----** ` 1' �/ 2000_ — ` _ — -- `1000 t ± T a'f • 0 i ooc - w st 0 Ark. _ ,{,1 A z 0 0 p-rp 7,4 M / 7 _ -- _ --- __ - _ . _ - - _- - _ A, ,---- i . i, „„ „ , 401 _ , , , ..... I I "{? < A 411 A , 0 - # r 4471 gi, 0, N . , / 8N, /It # Arlr A ^.- • N■ * v•ip IP 4 4", 4 / ‘ • • - * 4 - •.' 44 6 * "' .., -- — - -i- ___ , , 1 ,___ s - 110%,Z■ 8 .. 4 t, -.. ivi- 4 , 0 , h - - __ . . 0 -. 0 ___-- ., - , 5000 -_,. F,;" „, • . r1/ \ \ 4 00o. " ....,,, / 1, – ...-- - , .... ..._...--_-... -' / 1 --- /o --- - -- - ---- . oo -. : I- :-- - - r - • C ; 4.4 Si -- Vi OZ ----------- i ; RECEIVED December 30, 2009 DEC 3 0 "0119 State of Alaska iSka�� , �0�1. I,Q1EP�ii��3�es Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anz!:o„fvfx Anchorage, AK 99501 RE: ODSN -42Ai Cement Bond Log of Intermediate Casing and Liner, and Mechanical Integrity Tests for 7 -5/8" x 3 -1/2" Inner Annulus and 3 -1/2" Tubing Permit to Drill #209 -156 Pioneer Natural Resources Alaska, Inc. (PNRA) is submitting the ODSK -42Ai 7 -5/8" Intermediate Casing Bi -Modal Acoustic Cement Log, 4 -1/2" Radial Cement Bond Log, MIT -IA pressure chart, and MIT -T pressure chart for the purpose of proving injection fluid isolation as per 20 AAC 25.402.c7. PNRA is proposing the following: 7 -5/8" Intermediate Casing Apparent Top of Cement is located at 7,927' MD. Apparent Fair Bond 7,927' MD to 8,114' MD Apparent Good Bond from 8,114' MD to 8,479' MD. 7 -5/8" Casing set at 8,654' MD. 4 -1/2" Liner Apparent Good Bond 8550' to 9494' 7 -5/8" x 3 -1/2" IA 30 minute Mechanical Integrity Test 4650 psi starting pressure 4600 psi final pressure 3 -1/2" Tubing 30 minute Mechanical Integrity Test 4650 psi starting pressure 4600 psi final pressure Please find attached information as required by 20 AAC 25.402.c for your review. Pertinent information attached to this application includes the following: 1) Bi -Modal Acoustic Cement Log of the injection well. 2) Radial Cement Bond Log of the injection well. 3) Mechanical Integrity Test — Inner Annulus 4) Mechanical Integrity Test - Tubing Please note that no gas lift valves have been changed out since the completion was landed and MITs conducted as per usual practice. Currently, dummy gas lift valves are installed in the completion tubing and will remain in place for the foreseeable future. Sincerely, Tim Cr mrine, P.E. Staff Completion Engineer 73 77 H s 0 = Country : U.S.A. 40 -4(3) cn N 0 r 3 Cn K v Field : Oooguruk m 3 cn ti n Location : Lat: 70° 29' 45.03" North m E M n 0 a c a 0 Long: 150° 14' 47.69" West 0000 COs 0 0 .i 00 0o w w a T Well : ODSK-42Ai 1%) 0071(11(710 -n 0 .0 0 0 3O 3 0 n n n 5 G C Company : Pio Natural Resources AK r ' i o 0 0 0 0 3 Rig : Nabors 19AC COCOwCas o_ °O M `O = = o 0 i ' rn `° o o -n -n ° LOCATION N cncnu100 -. c 0 0 0 •• 0 0 0 0 0 0 0 00 3 a 0 o c 0 i 0 ., 0 ., r r D n 1 1 X 17 0 0 == STh ib CD i v i v = . ' c a m Co c n 9 9 „ a O < m m ` c Z CO 0o w w Ca — b O 2 -a -o m m C ,, cu A O N N c of cri71 C C 71 O --1 ,M .. .. a 00000 a" m -< X 0 1 o , 0000 •nOj G II II N `.`, C O 01 . a e0 .. .. .. O c 2. At, 0 in A A cn - 0- I Z > w <O v tn (Jf C 0 o Z Co � � -. m o o c A o ► ° C. 0 G O Cif o N .. .. .. m c m w O t Q ( gy p 3 m .. rn1 m o 01 e z o c Co) D • C? N 94 0 a <"' r v = �s a = N" Z NA 0 O D > . D o m cn co 0 v c cm C) e, D CO C7 N E 6 4 a 0 v W • 73 03 y W T' CC o I z 0 z r* — ID ,., T -- o 0 0 0 (D C) G) l O N n n • 3 = CD a mm o 3 0 r � °D te c n X n OD GJ c 0 j01 O A 0 rt 0) 0 w w C 0 (71 --1 e 0 01 A) 0 N r XI v) ' 0 m o o 0 0 Q1 '= 0 0 w .'x CQ 'G C) WELL INFORMATION MWD Run Number 700 Date run completec 25- Dec -09 Rig Bit Number 7 Bit Size (in) 6.750 Tool Nominal OD (in' 4.750 Log Start Depth (MD, ft 8,665.00 Log End Depth (MD, ft 9,758.00 Drill or Wipe Drill/Wipe Start Date and Tim( 23- Dec -09 13:32 Drill/Wipe End Date and Tim( 24- Dec -09 22:00 Min Inc (deg) @ Depth (MD, ft 40.12 @ 9,745.29 Max Inc (deg) @ Depth (MD, ft 57.85 @ 8,684.53 Bit TFA(in2) / Bit Type .39 / Flow Rate (gpm; 260.00 Max AV (fpm) / CV (fpm) @ MWI 217.0 / 217.0 1 Fluid Type Salt Water Gel Density (ppg) / Viscosity (spqt 10.00 / 42.00 Filtrate CL (ppm: 21,500.00 pH / Fluid Loss (mptm 9.00 / 0 PV (cP) / YP (Ihf2; 12 / 16.00 % Solids / % Sant 6.8 / 0.1 % Oil / Oil:Water Ratic 9.9 / 9.9:76. Rm @ Measured Temp (degF .20 @ 68.00 Rmf @ Measured Temp (degF .14 @ 68.00 Rmc @ Measured Temp (degF .03 @ 68.00 Max Tool Temp (degF) / Sourc( 148.47 / HCIM Rm @ Max Tool Temp (degF .11 @ 148.47 Lead MWD Engineei T. Ritc Customer Representative J. Brown SENSOR INFORMATION Downhole Processor Information Tool Type HCIM Software Version 88.20 Sub Serial Number 234005 Insert Serial Number 11391736 Date and Time Initialized 23- Dec -09 17:28 Date and Time Read 25- Dec -09 16:04 ECMB SW Version Directional Sensor Information Tool Type PCDC Distance From Bit (ft) 9.40 Software Version Sub Serial Number 163634 Sonde Serial Number 300499 Sensor ID Number Toolface Offset (deg) 0 Gamma Ray Sensor Information Tool Type DGR Distance From Bit (ft) 35.63 Recorded Sample Period (sec) 10 Software Version N/A Sub Serial Number 223559 Insert/Sonde Serial Number 241701 Resistivity Sensor Information Tool Type Slim P4 Distance From Bit (ft) 28.69 Recorded Sample Period (sec) 10 Software Version 5.55 Sub Serial Number 223559 Receiver Insert Serial Number 175828 Transmitter Insert Serial Number 166464 Receiver Orientation Up Sonic Sensor Information Tool Type BAT Distance From Bit (ft) 58.70 Recorded Sample Period (sec) 16 Sub Serial Number Receiver Insert Serial Number Transmitter Insert Serial Number 171937 MIT File R5Max_Run_f6.mi Config File Real -Time Window (uspf) 80 - 140 Battery Insert Serial Number MCM Software Version 5.07 DAQ1 /DAQ2 Software Version 2.54 / 2.54 DSM Software Version 36.17 4\ CEMENT EVALUATION STARTED AT 7,920' MD. APPARENT TOP OF CEMENT 7,927' MD, 5,564' TVD. APPARENT FAIR BOND 7,927' MD, 5,564' TVD TO 8,114' MD, 6,050' TVD. APPARENT GOOD BOND 8,114' MD, 6,050' TVD TO 8,479' MD, 5,867' TVD. 7" CASING SET AT 8,654' MD, 5,962' TVD. SGRC = SMOOTHED GAMMA RAY COMBINED. CASING = CASING COMPRESSIONAL WAVE SLOWNESS. DTC = FORMATION COMPRESSIONAL WAVE SLOWNESS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 1.1 FT. GAP FILL IS SET TO 5 FT FOR ALL CURVES. WARRANTY HALLIBURTON WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY OTHER THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION AND PRODUCTION OPERATION. HALLIBURTON MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDEDBYHALLIBURTON. CASING microsec per ft SGRC DTC DTC microsec per ft microsec per ft 240 40 240 40 a pi - - DTC CASING CASING microsec per ft microsec per ft microsec per ft 240 40 240 40 240 SGRC Casing Energy HF Waveform HB Waveform 0 100 MD BAT HF STC BAT HB STC 0 255 0 255 ft 240 40 240 40 u� 120 200 120 200 • 1200 api 1: microseconds 12u0 e_ 1 � CEMENT EVALUATION STARTED AT 7,920' MD I mlemmom L., APPARENT TOP OF CEMENT AT 7,927' MD, 5,564' TVD r r r APPARENT FAIR BOND 7,927' MD, 5,564' TVD TO 8,114' MD, 6,050' TVD. , L _ -- 8000 a? �— L i 1 - 1 ,— f 4111 ! f ` _ � :, fi o i f 8100 _ ''t �? I! ' c-- - APPARENT GOOD BOND 8,114' MD, 6,050' TVD TO 8,479' MD, 5,867' TVD .s „'r I r ,A I .1 # aa. a OLUU - _ - _ - - _— ___....,... tb,i �.*, S '� - =- ° ,,i-\- - '.. , ......, Z - - 3� - -i �;A � 11 yy Xj1i3 'I ___ _ _ ' � �' � I t i { { �L 55 s --MI - S t 8 300 — '= _ _ — :4 t 44 r � � 3. _ ffii r -'f' .f � 'a } .c S� i - �• _ - ) � 1 r - ;f ifI • '# if S a — 1 _ _ fa r !{f- r2" • a �� 8400 4i -� � 4� i�.i ;�y�3 jj J s 1 " ..°7 ' i' ',ii s" r ri i k-- .- - j 2f ` i 1-1'..iiiiiit "(' 8500 _ �= _ : t I I ? -y f • - — �' _ - - S 3 ==M. s .. fir... -' � }'. c 3 h „� `� L1 $. a± •' . _ - - t... 11011.1 '.- ''. 1:14,.._ =1 ' 1 - - - - - 8600 -- ;.,,, : _ t4 ; i : -, : 1 1 ,,,..:1 i :::.t — e : ::,-1 1 .1. - _ 2%,7 :: . _ . . ;:, : 1 ,i.zi _;.: : • �, _ - �� t g. .4_ 111117” CASING SET AT 8,654' MD, 5,962 ND. --q _ y- SGRC HF Waveform HB Waveform 0 100 MD BAT HF STC BAT HB STC Casing Energy 0 255 0 255 ft 240 40 240 40 200 1200 200 120 api 1 : 1200 microseconds microseconds DTC CASING CASING microsec per ft microsec per ft microsec per ft 240 40 L - SGRC DTC DTC 0 200 microsec per ft microsec per ft 240 40 240 40 ap i CASING microsec per ft CASING microsec per ft SGRC DTC DTC microsec per ft microsec per ft 240 40 240 40 ap i DTC CASING CASING microsec per ft microsec per ft microsec per ft 240 40 SGRC I HB Waveform n inn Casing Energy 0 255 0 2 MD BAT HF STC BAT HB STC T • 1 HALLIBURTDN RADIAL CEMENT BOND LOG i c Q Company Pioneer Natural Resources AK Well ODSK -42Ai o O Q Field 0ooguruk [ T2 4 9 2 County North Slope State Alaska z N Y o API No: 50- 703 - 20605 -01 Sery #: Other Services c v E ( 7 ) Location: Latitude : 70Deg 29' 45.03" North it Y o _c Lo : 150Deg 14' 47 West F o O o o c 5_ O O z i > PERFORATE F Q c i o ii > U [ Sec: Twp: Rge: L f tion Permanent Datum Mean Sea Level Elevation 0.00 Ft Elevation Log Measured From D. F. , 56.20FFitabove perm. datum K.B. 0.00 Ft D.F. 56.20 Ft Drilling Measured From G.L. 13.60 Ft L Date @ Time Logged Dec-29 -2009 Type Fluid in Hole COMPLETION Run No. One Density of Fluid i Depth - Driller 99750' Fluid Level Surface S Depth - Logger 9490' Cement Top Est. Logged 8720' i Bottom - Logged Interval 9486' Equipment / Location 10968215 / Dead Horse Top - Log Interval 6800' Recorded by O'Brien /MOSER 6 Max. Recorded Temp. N/A Witnessed by Jim Brown F CEMENTING DATA Surface Protection Production Liner [ String String String f Date / Time Cemented i Primary / Squeeze Expected c Compressive Strength psi@ hrs psi@ hrs psi@ hrs psi@ hrs F Cement Volume Cement Type /Weight / / / / c Formulation c Mud Type / Mud Wgt. / / / / n Borehole Record Casing & Tubing Record 92 f Run Number Bit From To Size Weight From To i [ 1 13.50" 153' 3,300' 7.625" 29.00Ibs Surface 9566' -0 i 2 9.875" 3,307' 9575' 10.750" 45Ibs Surface 3,289' ii 3 6.75" 9,575' 10,625' 3.5 SURFACE 8520 v _ 4.5 8520 9753 v HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OR WHCIH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS, OR RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF. Comments Log correlated to Halliburton, Sperry Drilling, ROP,DGR,CTN,ALD Log, Dated, 26- Dec -2009 Rig Nabors 19AC Thanks For Using Halliburton Energy Services, Dead Horse, Alaska (907- 659 -2805) Your crew today was: John O'Brien, Wes Moser,Terry Parker Sensor Report Database File: 42_ai_cbl.db Dataset Pathname: pass14 Dataset Creation: Wed Dec 30 01:19:24 2009 by Log Halliburton Casedho Sensor Name Offset (ft) CCL 21.34 WVFS6 14.07 WVFS5 14.07 WVFS4 14.07 WVFS3 14.07 a WVFS3 14.07 WVFS2 14.07 WVFS1 14.07 WVF3FT 13.41 WVF5FT 12.41 WVFTEMP 8.99 WVFCAL 8.99 GR 4.17 PMON 0 Sensor Offset (ft) Schematic Description Len (ft) OD (in) Wt (lb) CCL 21.34 �C 16 TE CCL Earth 1.67 1.69 10.00 h Mag) — \ _MOD_TOP 2.00 1.69 10.00 TOP MOD CENTRALIZER WVFS1 14.07 — \ _SCBLTEKSLIM -169 (168) 9.75 1.69 63.00 WVFS2 14.07 r J� I 11/16" RIB 400 Deg %A!\ /CC'2 r 1 A n7 Ji��i vvvro3 i4.u1 j WVFS4 14.07 WVFS5 14.07 WVFS6 14.07 WVF3FT 13.41 WVF5FT 12.41 WVFCAL 8.99 WVFTEMP 8.99 — MOD_CEN 2.00 1.69 10.00 CENTER MOD CENTRALIZER — GR- Tek -Co (168) 3.82 1.68 40.00 1 11/16 400 Deg. Logging Gamma Ray GR 4.17 (1110" � MOD _ BOT 3.17 1.69 10.00 BOTTOM MOD CENTRALIZER i • Dataset: 42_ai_cbl.db: field /well /run1 /passl5 Total Length: 22.41 ft Total Weight: 143.00 lb O.D. 1.69 in MAIN PASS 0 PSI HALLIBURTON III Database File: 42_ai_cbl.db Dataset Pathname: passl6.3 Presentation Format: scblco8 Dataset Creation: Wed Dec 30 05:18:00 2009 by Calc Halliburton Casedho Charted by: Depth in Feet scaled 1:240 CCL 0 GR 80 0 AMP (mV) 100 0 AMPAVG 100 200 MSG 1200 1 SECTORS 6 -2.5 2.5 0 AMPx5 (mV) 20 0 AMPMAX 100 10 90 140 TT (usec) 240 0 AMPMIN 100 I UJVV - ' •. r ,_ i 1 I : . • :. :. :. ' , ::� ' I . � 1 ..v 1 E 1 ` 1 4 � f 1 1 ■■...... it'll jig': r :: L- . . 1 i il ki 4 . • - •,1 l , 6 -- - li 0 • „ , V 7 f �w1.r �--�- ' A 4. NO . �;• _ - +7 _-- 1■ ��I ; : pi �/ , ,... _ ,i! - a_1 s M ♦ a .... . t C t t , G t 4 r CI- ,. ■ II ` < „ - Lo T , Q ti' ,1 lk ■ Nov a M a .► AL ANIIM. AL 1111111IL _„..... - -ter - - - it - 4•1. 1 U CD 0 } 0 T co il co 4 ■■■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■■■■■■ M■ ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■■■■■■E i■■ ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■■■■■ JRi■■ ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ 1111111111111111111111141111111111111111111111111111111111 ■■■■■■■■■■■■■■■■■MU■■ vru■■ ■■■■■■■■■■■■I■■■■■■■■■■■■■■■■■■ ■■■RROPR1/■■■■■■R�i■►■■■ Ili ■I1■■■■■4■■■�■5�■■■■5020011Wr: :2■■ %■■MINE M■■■■u ORS IEMI■E0011■■`:1■■■■■■■■i6i■■■■ ■■■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■ili■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■!■■■■■■■■■■■ ■■ ■■■■■■■■■■■■/w■iCii;M■■■PPOMI ■■■■■■■■■■■■■■■■■ui■■■■■ PSEE \■MOMP■ ■■N■MRNNIii i■11■11■■■■■■■■■■■■■■■■■/rt1== ■ ■ ■ ■ ■ ■i� ■ ■ ■ ■� ■!■■ ill■■ i■■■■■ ■ ■ ■ ■11 ■ ■ ■ii�� ■R��r \■R�i ■ ■ ■ ■ ■ ■ ■■ ■■■■■■■■■■■■■■ II■■■■■■■■■■■■■■■ ■■■Il /■/,!■■■R1■■■■\/■■■■■■■■■■ ■■■■■■■■■■■■■■ B■■■■■■■■■ 8■■■ p ■■Q■ii■i■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■ q■■■■■■■■■ Ma■■ I ■clll■■■■■■■■■■■■■■■■■■EIQ■■■■■ ■■!■■■ t1■■ A■■■■ N■■■■■■■■■■■ �■ i■■ ■q ■I�se� ■ ■e��els�e�Qe� ■■�e ■ ■ ■ - ■ Ilq■ R■ H■! iR■■■ f!■■■■■■■■■■■ id■ ■■■M■■■■■■■■■a■■■■■M■■■■■ONW ■ i■ i■■ N■ F■■ a■! i■■■■■■■■■■■■■■ ■■■aa■■■■■■■■■■■■■■■■N■■■■■Aiti . N■!■■ ■ ■■■■■■■E■■ / ■ ■.e■9 PROM � ■■E?l■■■■■■■■■■■■ ■■■■NNEM■ii�f_ I�lll �r iiir►,;:�ri rtl ti' ITAAMOVUic•VMJr :. ■ ■ ■ ■■ ■ ■ ■■ ■ ■ ■ ■■ ;R� ■■■■ ■■■■■■■■■■■■■■■■■■■■■■■i■■■■!�' .. "+, Ila�Y}:r•a ■■■■■■■■ ■■■■■■■■■■■■■■■ ■■ ■■ ■■■■■ ■■iAi► yiri -d ■■■■■■■i ■■■■■■■ ■■■■■■■■■■■ ■■■■■■ ■■ ■■■■ ■■■■■■■■I■■■■!■i■■■I■■■■■■■■■ 111111111110111111111111111.110111111111111111111M11011111 ■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■ 111111111111101111111101111111111111111111111111111111111111111 111111111111111111111111111111111111111111111111111111111111111 ■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■ r .« �J+rr•"�r,t �T. = yam ..�..�,., • , - • ~ r .I• �►� w M } 4 4-0 ,�� `1111, 4*** i • '.. 1 Arlia • • —o I o _ Noffigirmilawi r. .A__ ,.....,.. ____ ___ iill iiip - d - I ; I v" w I • • . { 0 1111111111111111111111111111 1111 I_I■■■■■ENEIVO �!:!�!�►■:1■■■■ I> m ilOP IIuIPOIOUIB■It�■\IH /! ■5i i ■■ / ■ / ■II ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■�/`� 11100■N■■:/■MM/■■ ■VIII■/■ 11111111111111111111111111111 `71 1111111111111111111111111111 ����\■■ �i��iiiR�ii�iiiii�iii�Rl ��Aii�l�7�� ■I,i \ ■ ■ ■�� ■ ■ ■ ■ ■ ■ ■ ■ ■is�� ■■ iiaNai■ s6ss■ iiIaMOsSH■■ ■■■si■■■aNsM■r■N.N■■■■M■■■ Q111111111■11111111111111111111 D D a ■ " ■ ■ ■ ■ ■ ■.. ■■ ■�.■a■a■■■■■■■■■■■■■■■.■■■■■■■■ 111111111111111111 ■ ■■■U■■■■■■■ ■■ ■■■■■■■■■■■■ ■■■■ -0 -0 ■ ■ ■Ht!■i■ ■E■i■■■■■ ■■■E ■■■■ ■■■■ ■B■■■■■■ ■■■■■ ■■■■■ ■■■■■ ■■■■ ■■ x ■■!■I�■■ai■■■■ ■ :p ;; 1111111111111111111111111111111 IIMuIIr1uIIuHhI sssessaeessaseeeos�sesesssseesse tmlu!m!ssessessemems!Ie AiMM•......... idik22146'�i ■i /■■■ii■■�i■i�:.: � :��::.:Y:.::::y+ ::.: Y: Emil■ ■■■■■/■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■i■■■i■■■■■i■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AIL/ •� • . . • • • w.wM• wM rMa wnAgtiNO MP. r"'• r II I _ i 0 _. o 0 I -. - - - Aallb- ' . _ ,.. A - ' ...- - --...- - yr - mir AlLak ill _ . —........--allINIEPUIL ■ Alb ■ wrap"... 11111111MIVIILL ....... . , - ...simmi.Ermilavanimi I ,. . , ,., .. , , ., , , . • ., , . . 4 i .. \ , , , • , . , I 1 A V 1 ' ' IL i 1 V 1 V ...■ ■ : ...... 1 ' . -..- .... ,... ._.. . -, ' ''r"--...- .. - • - -- .."' - - .. - Wadialliiiiiik:Aiiidirriiiir r illii . - - I II _ . _ • ' . , . ... _ , . - Aureemarm.rwidimboon' - . --........—........o.limprosommo e , i ftpc.:,4,14.0.004.440 • 0 1. . ..., . . ... . ... A ' . , ••• ' ,,.. .4••••• . . • • sr . 4 4.....,.., , s. .. ,. 444440te.44.44,6401iiimilloompoomebsiowymomm~6410641141•W441141•0■40/0.444111.P l'Netrar4/4110/1/0 ••••• 4. 4 4,10/00/0•0000.0"/011.4.1444/1~46/ . . . 4 _ I • • , I o 1 1 'V 'V "'AIIMIIIIIHIIII Tom; __ __- . s MM _ • -- / r •_ .• - -- ,ti • ... .r I 0 410 • ■■ ■■ 1111 1111 D ■■■■ b ■■■■ .� ■_ ���+�� ^ \I �� `fir _1�w�1�'1 1� �r ` I �� hill /1. r�■ l�r.// r�./■ r1 �1` I01 11.�...����2/r11�/ \�!�i/�./►!T 111■ 1111 1111 1111111111111111 IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII •■o\ A\■■■■■ ■■■=/m ■O■ ■■■ ■ ■ ■■■■ ■■ ■u■■ ■ ■■ ■ ■ ■■u■■■■■■■ ■■■■ ■ii ■111115 ■■911M101 S=■■ iii ■iMilliifiiiiiZli ■li/NNSiiiii 1111 i iii i iiuiuiuiimiiiiimiiim 'DD � Z r1n■ _1�11e1Ie 1111s I11 1I1!1 1Ie! 1UI11Ue1IIIe11!I._!1!UIe1!I1!1_ iii . 1i��ii ilig iimm�imitiitIONNOil�ill�i Riiillllil■i 111■ 1111 1111 1111 ■ Earn .eT =- ?' "vr4 w= .. ,:., -. •, 0 _ic $ o i o Arlarrabb- 0 111 > - a ■■■ 'rte c» mil D . fi Dom ' C D: 0 x iir1 r r • w ..,. • • 9500 __________ j ' CCL 0 GR 80 0 AMP (mV) 100 0 AMPAVG 100 200 MSG 1200 1 SECTORS 6 -2.5 2.5 0 AMPx5 (mV) 20 0 AMPMAX 100 - 10 90 140 TT (usec) 240 0 AMPMIN 100 REPEAT SECTION 0 PSI HALLIBURTON Database File: 42_ai_cbl.db Dataset Pathname: pass16.4 Presentation Format: scblco8 Dataset Creation: Wed Dec 30 05:30:32 2009 by Calc Halliburton Casedho Charted by: Depth in Feet scaled 1:240 CCL 0 GR 80 0 AMP (mV) 100 0 AMPAVG 100 200 MSG 1200 1 SECTORS 6 -2.5 2.5 0 AMPx5 (mV) 20 0 AMPMAX 100 INIMIN 10 90 140 TT (usec) 240 0 AMPMIN 100 1 C 1E / ' 1t l I 1 • 1 ______e___St : lb: . ' 1 1 1 l co i a WF irit�L�i�1. }y Ali ' ' •} • t rY 1::'' r: iifl�r :�11�►if/�i����t.t�� ■ t■ uiuu■ 1111uui• iu ■uuu111■■u•u■ui• ■t■■■■iI■■ ■ ■ ■m 1111 111 ■MI11■MI1111■1IIII■11•■ ■t■• ■t ■t■■I I■uI ■ ■• 111■ ■ ■■111111111111 ■ ■1111■ ■ ■■■11■■111111■■1■=■111111111111■■■ ■ ■M ■111111■=1111•I■■■■I•■■■•■■II IIIiiIIII■■ ■ IIII ■ u■■■■ u■ 1111uu■• uu ■ ■uu• ■■IMIIII• ■i ■ ■ ■ ■.0 ■ ■ ■ 1 IIM ■IIIIIII III•I IIIuI•uII• ■ ■t■• ■uIIIuI IIuI 1 N iiIu■■II =u■ ■•IuIIuiIIIII■■i• ■ ■II III■■■■IIII I � ■t mow.• M 1 pf •1ti .. f1 . ,V,^Y' I•Irr, w'.1 • ; , „ ,, , , . , .., , , , , , - - " '7 • i 411 . to co c..n i o 0 o o . _ . _ . -..""r"TraiMEEROVIMMEMMIMMIMEMNREMOOniMMIMPNOMIREM . olniimal _......................._„0.................. iiiiMENIUMBEICONIONNOMIMINIMMUMINOMEMOIRII I I' _ II --WMINIONVIPPLIMINMININI--- _ ---MMINMINNINFINIMMMINI ' ' . . • ...:**:... .... . . - - - . ' % - ,::::::-: ',,,:::,,,,:: ::::.......------,,,,,.....,:,,,::::.:::::,......:::: i .,:::: :::::::::::::::::::::::::::,.. lai iiiitit mrammilmhamilmmmmmiliii ,., III . . ._ , .. . ..,.... , A;m14.........N,.......... --......../- , -..4. , -......-... , ....... .................„,„,................, , , „................• .....,... ..• . . . ., .,, ,., .. ,. • .. , , . • . . - • . . . • ....0 - , •. ', wir ...,,,•., ..., , ,...., ' am .464% Aw, 11.. .. ' 'sm.. • -.4,......... A ,oIo k ...... O. ...4 - S 0 v vv ; 1 1 CCL 0 GR 80 0 AMP (mV) 100 0 AMPAVG 100 200 MSG 1200 1 SECTORS 6 -2.5 2.5 0 AMPx5 (mV) 20 0 AMPMAX 100` 10 90 140 TT (usec) 240 0 AMPMIN 100 Calibration Report Database File: 42_ai_cbl.db Dataset Pathname: pass15 Dataset Creation: Wed Dec 30 01:39:13 2009 by Log Halliburton Casedho Gamma Ray Calibration Report Serial Number: 168 Tool Model: Tek -Co Performed: Sun Jun 1311:33:21 1993 Calibrator Value: 1.0 Background Reading: 0.0 cps Calibrator Reading: 1.0 cps Sensitivity: 1.0000 /cps Segmented Cement Bond Log Calibration Report • Serial Number: 168 Tool Model: 169 Calibration Casing Diameter: 3.500 in Calibration Depth: 8477.055 ft I RA.-,n +,,. r`•.lih.•+i. -.r. ...,.f.,.vv,.,. -1 1Af. -..+ n.,,. 'WI 111 -nn. An 7nnn• Master Calibration, performed Wed Dec 30 01:09:49 2009: Raw (v) Calibrated (mv) Results Zero Cal Zero Cal Gain Offset 3' 0.010 0.892 0.500 94.517 106.567 -0.544 CAL -0.041 -0.042 5' 0.009 1.252 0.500 94.517 75.668 -0.188 SUM III Si 0.082 2.500 0.000 100.000 41.362 -3.405 S2 0.068 2.332 0.000 100.000 44.174 -3.014 S3 0.055 1.655 0.000 100.000 62.503 -3.460 S4 0.088 1.836 0.000 100.000 57.227 -5.064 S5 0.096 1.286 0.000 100.000 84.021 -8.027 S6 0.076 1.861 0.000 100.000 56.042 -4.285 S7 S8 Internal Reference Calibration, performed Wed Dec 31 15:00:00 1969: Raw (v) Calibrated (v) Results Zero Cal Zero Cal Gain Offset CAL 0.000 0.000 -0.041 -0.042 1.000 0.000 • 1 Air Zero Calibration, performed Wed Dec 31 15:00:00 1969: Raw (v) Calibrated (v) Results Zero Zero Offset 3' 0.000 0.000 0.000 r r\avv w) L,c111IJI aleU w) r∎CJULJ Zero Cal Zero Cal Gain Offset CAL 0.000 0.000 -0.041 -0.042 1.000 0.000 Air Zero Calibration, performed Wed Dec 31 15:00:00 1969: Raw (v) Calibrated (v) Results Zero Zero Offset • 3' 0.000 0.000 0.000 5' 0.000 0.000 0.000 SUM S1 0.000 0.000 0.000 S2 0.000 0.000 0.000 S3 0.000 0.000 0.000 S4 0.000 0.000 0.000 S5 0.000 0.000 0.000 S6 0.000 0.000 0.000 S7 S8 Company Pioneer Natural Resources AK Well ODSK -42A1 • Field 0ooguruk County North Slope State Alaska HALLIBURTON RADIAL CEMENT BOND LOG ., 1 ��. �"' ^ " ten > 47,0/4 i . . .__ ..., \ . l i or #7,fal/ ./ .0 0f 0 -.• 0 - 0 *04. itA it i ,,, / 40 .. , 0017 z 4,4 ,,,,, .... 1 le /fillf / 41114110wIllake,/ ' Wo ___, e \\ \ ua, .0-0.-_,:..4.... \ \ \ O h gektievw ts• 4:::: -a., *., S114% Olt q- k 1� d� .rha. 1111111 1 II IN/ m �� ��� �1Ajit i'r'�,,'.:•o'� P . - �. � ��;���t1l��11y1 �I����'�,t` �� N , � nrn � a � � � . 111�� NI �, + . a o rtii� u 1 '��� INIHP ■ a y , .� � ` �� u �11�111Y�►11t� rr ••'` o ,�� w ,� . ti� ,�'�j�M u� 1 �� N�H1,1�►�N��U� l� a. �3o Wi►e � , � I�t., �� 'N ''�1� \ 1111 ` .. . - ... � ♦� ►�a_r III 1 f � �I •I� , • I\ \ \\\ \ \ \ \��1�\ ♦ � . . / 1 ,#/ lh l// 14 1 /1 \ V AV: =70 's / • t ,e91 \ aft. is ........ wo o \ \ is A`-t. 411.==u1W, w # oi if 'I Si flara a 0° 0 f• " la, , � `` r��� I '( r . 4 N ■ik, 1144114444%. #04144 etem. iliwia0 _.....10 0 „ : , , ,, , , OW ..., ......„.. -......,... 1 .......,,EM 0-0r- '""...--W-M:Ms ' -------____ •w st _ _ 00 -.•••°1------01-1"13.Aimta --":—.."----------- / / , s o g r O w. • . ° aul.,=,,..1== 4 ".11-*" "at t • -4...` 41 "1°61411'4111'11k Z .. . i i , , 4 '` 44 4 1 ' 4 14''"i■,,,4, - '''.***- - .. % % s 4 4 i p •- ' .• ... _ .c=am . �,► ' �, ♦� i I/ 7 � ♦ 41-7-77 / t tt I .r � : �I'� . th f 1, ,�' • If�A o w ' � 1-4; i out �'t 1111b11111101141111404,0 r,. �� I f� w Agger"sul t' �.: >- Il�if '� ttt Ii,_ . 11h. � g' � r � rr 'mil II rr rrii� m !�� �4 au rrr ► +;�► may, x� � .,e.�►i t� 1�� f�� �� I ltttitt�tttt , ,:�•,.., 5 o o ., i ` , � ►,.�,. � ,, � , .,�� f1� lalal\ mum . , limix-- SOSO * \l,,,,,,\ .vizeAte ' 4‘ - ‘ 1:7A110.1% 40 Ad ::' - 7- feee //#4/ V 04 2?.......41..;..____„ds.,.. A ,/ 4 4p, ft.-ZI:15.w.,P-P #;,. /) 444„,.....ime 0 0., 7 , 00 , A • ,..........._____ ,,/ / it .■.4%,441441 ''.4-,...%.........WINr-""WAS 0 b"libik*04.4641117P '11 a 4.1" % i ".. wo, "1" : ".° 1, "..,:"*""M .0.0 w Wos • • • . �; a � : a ' G k , 9 c= o ` L .T SEAN PARNELL, GOVERNOR yy �a I p� ¢ . , ,, i t a Chi �. E k e J ALASKA I ALASKA OIL AND GAS r 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMl►IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 t FAX (907) 276-7542 Mr. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK -42Ai Pioneer Natural Resources Alaska, Inc. Permit No: 209 -156 Surface Location: 2912' FSL, 1154' FEL, Se. 11, T13N, R7E, UM Bottomhole Location: 2546' FSL, 3815' FEL, Sec. 13, T13N, R7E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, t -tom a y . Fo rster Com issioner DATED this day of December, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i STATE OF ALASKA + RECEIVED AL GA OIL AND GAS CONSERVATION COMIVI�SION L' 2009 PERMIT TO DRILL 20 AAC 25.005 ag Oi{ & I! CnnL. Commission 1 a. Type of Work: , 1b. Proposed Well Class: Development - Oil ❑ Service - Winj U • Single Zone , 1 c. Speci if f .r. ,'b �sed for: Drill ❑ Redrill Ei Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas NI GaeHydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Ei Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 ODSK -42Ai 3. Address: 700 G Street, Suite 600 6. Proposed Depth: 12. Field /Pool(s): Anchorage, AK 99501 MD: 9683' • TVD: 6600' , 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Oooguruk - Kuparuk Oil Pool • Surface: 2912' FSL, 1154' FEL, Sec. 11, T13N, R7E, UM . ADL 355036 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3173' FSL, 4062' FEL, Sec. 13, T13N, R7E, UM 417497 12/6/2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2546' FSL, 3815' FEL, Sec. 13, T13N, R7E, UM 5760 2546' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: . 56.2 feet 15. Distance to Nearest Well Open Surface: x- 469844.38 • y- 6031028.13 • Zone- ASP 4 GL Elevation above MSL: to Same Pool: ODSK -41 is . 13.5 feet 2497' away 16. Deviated wells: Kickoff depth: 3389' feet • 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 58.69 degrees Downhole: 3329 • Surface: 2603 • 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 9 -7/8" 7 -5/8" 29.7# L -80 BTC -M 8730' Surface Surface 8768' 6007' 161 sx Class 'G' - 6 -3/4" 4 -1/2" 12.6# L -80 HYD 521 1065' 8618' 5924' 9683' 6600' 198 sx Class 'G' , 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 10,625' 6705' N/A 10,618' 6699' N/A Casing Length Size Cement Volume MD TVD Conductor /Structural 110' 16" Driven 158' 158' Surface 3251' 10 -3/4" 458 sx PF 'L'; 202 sx Class 'G' 3289' 2980' Intermediate 9529' 7 -5/8" 163 sx Class 'G' 9567' 6014' Production 1223' 4 -1/2" 225 sx Class 'G' 9398' - 10,621' 5925' - 6702' Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A 20. Attachments: Property Plat 0 BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan, 343 -2186 Prepared By: Kathy Campoamor, 343 - 2183 Printed Name r Johnson Title Sr. Staff Drilling Engineer /L /i/ Signature / Phone 343 -2111 Date 12/1/2009 Commission Use Only Permit to Drill API Number: Permit Ap al See cover letter for other Number: `-�-- 1 60 50 7{-'S - 2.6 %_� -c) i r Date: 0 ? requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, as hydrates, or gas contained in shales: 27 Other: L` 500 's e f j e Samples req'd: Yes ❑ No[ Mud log req'd: Yes ❑ No d -$ 2 500 osi. Ah n • � ( f�w + CAM / , . ia .�M1 2 S measures: Yes ❑ No[ Directional svy req'd: Yes g No ❑ � F� l r G w / ��LM -aa.(� .,,oa� ,� -M /o P er /MC L S. 636(01) /►11T e a, ater roh tk etccoji 4o '1 Al 33 Q <.5 L '4-6-c, APPROVED BY THE COMMISSION DATE: IZ� - "L�1 i . , COMMISSIONER ORIGINAL /2. 3.08 ;z--='y.,/ Form 10 (Revised 7/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(8)) ubmit in Duplicate �� 1 • Oooguruk Well Plan Summary: Permit to Drill ODSK -42Ai — Kuparuk Injection Well Surface Location: 2912' FSL, 1154' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X = 469844.38 • Y = 6031028.13 Target: Oooguruk - Kuparuk 3173' FSL, 4062' FEL, Sec 13, T13N, R7E, Umiat X = 472200.00 Y = 6026000.0 1 6020' TVDrkb Bottom Hole Location: 2546' FSL, 3815' FEL, Sec 13, T13N, R7E, Umiat X = 472444.9 Y = 6025372.39 6600' TVDrkb AFE Number: TBA Est. Start Date: December 6, 2009 Rig: Nabors 19AC Operating days: 28 days to Drill and Complete TD: 9683' MD / 6600' TVDrkb Objective: Kuparuk 1 Well Type (exp, dev, etc): Development Well Design (conventional, slimhole, etc): Slim hole — Injector — wp5 Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' Conductor: 157.66' MDrkb Well Control: 9 -7/8" Intermediate Casing Hole Section: • Maximum anticipated BHP: 3029 psi @ 6007' TVDss (Based on 9.8 ppg Oooguruk- Kuparuk pore pressure) • Maximum surface pressure: 2369 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) 6 -3/4" Production Liner Hole Section: • Maximum anticipated BHP: 3329 psi @ 6600' TVDss (Based on 9.7 ppg Oooguruk - Nuiqsut pore pressure) • Maximum surface pressure: 2603 psi © surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Maximum casing pressure: 4500 psi @ surface Planned BOP test pressure: 4500 psi (annular to 2500 psi) Due to required 4500 psi casing pressure test. Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Pioneer Natural Resources Last Revised: November 30, 2009 ODSK -42Ai Permit To Drill Page 1 of 7 1 • 5000 psi BOP stack (see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/ studded connections Hydril 11" 5M single ram BOP w/ studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3 -1/8" 5M side outlets w /flanged connections 2 ea. 3 -1/8" 5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3 -1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/ studded connections Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 7 -5/8" Intermediate Shoe Rathole + 20' from shoe FIT 12.5 ppg Drilling Fluids Program: Intermediate Hole Mud Properties: 9 -7/8" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to Base 9.2 -9.8 (-10.5 40 - 60 15 -25 15-20 < 12 6 — 8 Torok ppg via MPD) From Base Torok 9.8 -11 ( -12.5 40 — 60 15 - 25 20 - 30 < 15 3 — 5 (8 -10 • to TD ppg via MPD) HTHP) Production Hole Mud Properties: 6 -3/4" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to TD 9.8 -11 ( -11.5- 40 — 60 15 - 25 20 - 30 < 15 3 — 5 (8 -10 • 12.5 ppg via HTHP) MPD) Pioneer Natural Resources Last Revised: November 30, 2009 ODSK -42Ai Permit To Drill Page 2 of 7 1 Formation Markers: Formation Tops MD (ft) TVDrkb Pore Press. EMW Comments (ft) (psi) (PK) Base of Permafrost 1677 1666 Top West Sak 2332 2281 1023 8.65 Base of fluvial sands Tuffaceous Shales 3193 2926 Surface Shoe 3289 2980 Brookian 2B 5642 4275 Top Torok Sand 7129 5099 2275 8.6 Base Torok Sand 7593 5356 Top HRZ 8280 5737 Base HRZ 8520 5870 Kalubik Marker 8652 5943 Intermediate Shoe 8767 6007 Top Kuparuk C 8777 6012 3090 9.8 Expected to be lower due to depletion — hydrocarbon Base Kuparuk (LCU) 8811 6031 BCU 9299 6330 Top Nuiqsut 9418 6411 3201 9.7 Hydrocarbon Base Nuiqsut 9587 6530 Nechelik 9601 6540 TD 9683 6600 Logging Program: 9 -7/8" Section: Drilling: Mud logging Dir / GR / Res / PWD Open Hole: N/A Cased Hole: BAT Sonic 6 -3/4" Section: Drilling: Mud logging • Dir / GR / Res / Dens / Neut / PWD Open Hole: N/A Cased Hole: Cement Bond Log Pioneer Natural Resources Last Revised: November 30, 2009 ODSK -42Ai Permit To Drill Page 3 of 7 • • Casing Program: Hole Casing / Weight Grade Conn. Casing CsgITbg Top Hole Btm Size Tubing Length MDrkb/TVDrkb MDrkb/TVDrkb 24" 16" 109# H -40 Welded 115' Surface 158' / 158' 13 -1/2" 10 -3/4" 45.5# L -80 BTC 3251' Surface 3289' / 2980' 9 -7/8" 7 -5/8" 29.7# L -80 BTC -M 8730' Surface 8768' / 6007' 6 -3/4" 4 -1/2" 12.6# L -80 Hydril 521 1065' 8618' / 6010' 9683' / 6600' Tubing 3 -1/2" 9.3# L -80 TSHP /TCII 8580' Surface 9847' / 6082' Casing Properties Size Weight Grade ID Drift ID Conn. Internal Collapse Tensile Strength Yield (psi) (psi) Joint Body 16" 109# H -40 14.67" 14.5" Welded Conductor casing 10 -3/4" 45.5# L -80 9.950" 9.794" BTC 5210 2470 1063M 1063M 7 -5/8" 29.7# L -80 6.875" 6.75 BTC -M 6890 4790 683 M 683 M 4 -1/2" 12.6# L -80 3.958" 3.833" TSHP /TCII 8430 7500 289 M 289 M l z.z•cq Cement Calculations: (Wu 7 Casing Size: 1 7 -5/8" Intermediate Casing - single stage Basis: TOC: -$76 -500' MD above the top of the Kuparuk 60% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 55 bbl 12.5 ppg Dual Spacer Primary 33.8 bbls / 161 sx Premium "G" + adds. 1.17 cf /sk Displ 448 bbls mud Temp BHST - 135° F at 6068' TVDrkb, -110° F BHCT Casing Size: 1 4 -1/2" Production Liner - single stage Basis: TOC: -8618' MD -150' MD above the top of intermediate casing shoe 60% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 55 bbl 12.5 ppg Dual Spacer Primary 41.2 bbls / 198 sx Premium "G" + adds. 1.17 cf /sk Displ 106 bbls mud Temp BHST - 165° F at 6100' TVDrkb, -135° F BHCT This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone. Disposal: Annular Infection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDWI -44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Pioneer Natural Resources Last Revised: November 30, 2009 ODSK -42Ai Permit To Drill Page 4 of 7 Pioneer Natural Resources Well Plan Summary Drilling Operations ODSK -42 Well condition 1. Surface casing, intermediate casing and liner have been run and cemented. The reservoir section has been abandoned and a bridge plug has been set in the 7 -5/8" casing -250' below the , surface casing depth (3539' MD). 2. 7 -5/8" casing has been cut -150' below the surface casing depth (3439' MD). 3. A cement plug has been placed over the casing stub, and up to 100' above the surface casing shoe (3189' MD). Ria Activity: Drill and Complete 1. Nabors 19AC should already be rigged up over the ODSK -42i wellhead finishing the abandonment phase of ODSK -42i. 2. NU BOPE and test as required. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 3. MU 9 -7/8" directional drilling, MWD /LWD. RIH and cleanout casing to kick off point at 3389' MD. • Displace well over to intermediate hole drilling fluid. 4. RD the MPD trip nipple and RU the MPD bearing assembly. 5. Drill 9 -7/8" intermediate hole to casing point at -8767' MD/ 6,007' TVDrkb. -5' TVD above the top of Kuparuk. 6. Displace to 12.5 ppg mud. 7. RD MPD bearing assembly and RU trip nipple. 8. Pull out of hole with drilling assembly. 9. Change one set of pipe rams to 7 -5/8" and test BOPE as required. 10. Run and cement the 7 -5/8 ", 29.7# intermediate casing. 11. Bump the plug, release pressure and ensure floats are holding. 12. Pressure test the 7 -5/8" casing to 4500 psi for 30 min. 13. Change pipe rams to 4 -1/2" and Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 14. MU 6 -3/4" MWD /LWD motor drilling assembly with BAT Sonic (for cement bond log). RIH and cleanout to landing collar. 15. RD the MPD trip nipple and RU the MPD bearing assembly. 16. Drill through intermediate shoe + 10' of new hole and perform FIT to 12.5 ppg. 17. Drill 6 -3/4" production liner to TD at -9683' MD/ 6600' TVDrkb. Note: Hole drilled below the Kuparuk base at - 8777 MDrkb / 6012' TVDrkb is for reservoir evaluation purposes only. There are currently no plans to produce the Nuiqsut formation from ODSK -42Ai. Note: Due to high potential of losses through the Kuparuk production hole drilling fluid is subject to change. AOGCC will be notified in this event. 18. RD MPD bearing assembly and RU trip nipple. 19. Pull out of hole with drilling assembly. 20. RIH and cement the 4 -1/2" production liner from TD to 150' inside the intermediate casing 21. Displace production drilling fluid with 11.5 ppg mud 22. Pump production liner cement job. Displace with 9.8+ ppg brine. 23. Set 4 -1/2" Liner hanger packer, unsting & circulate out excess cement. 24. Change pipe rams to 3 -1/2" and Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in Pioneer Natural Resources Last Revised: November 30, 2009 ODSK -42Ai Permit To Drill Page 5 of 7 1 advance of test. 25. Pull out of hole with liner running tool. 26. RIH with 3 %2" tubing. Locate liner top space out & land tubing hanger. 27. Test hanger seals to 5000 psi. 28. Install TWC. 29. ND BOPE, NU tree and test to 5,000 psi. 30. Pull TWC. 31. Circulate corrosion inhibited brine around the packer. 32. Drop ball and rod, set and test packer. 33. Pressure test 3 -1/2" tubing to 4,500 psi. Pressure test 3 -1/2" to 7 -5/8" annulus to 4,500 psi 34. Reverse circulate 2000' of freeze protection fluid down 3 -1/2" tubing annulus through gas lift mandrel shear out valve. 35. RDMO to perform remaining completion. Post -Rig Activity: Complete 1. RU Slickline/Wireline Unit 2. Pull the ball and rod. 3. Pull the shear out valve from the upper GLM. 4. RIH with Slickline and set gas lift valve in upper GLM 5. Pull the RHC -m plug with Slickline 6. Perform a wireline cement bond log across production liner i 7. RIH w/ wireline 6 spf, 60° phasing, perforation guns & fire across Kuparuk formation —34' MD. 8. RD Slickline/Wireline Unit. Pioneer Natural Resources Last Revised: November 30, 2009 ODSK -42Ai Permit To Drill Page 6 of 7 • • ODSK -42Ai Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre - reservoir meeting to outline heightened awareness for kick detection and lost circulation. o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. Lost Circulation /Breathing /Formation Stability /Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN -40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN -36 across this same interval. Review the DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK -33 well, an un- centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. In any event, keep the pipe moving and avoid allowing the pipe to remain stationary any longer than necessary to minimize the chances of differential sticking. • There is a small section of formation above the Top of the HRZ that is volcanic in nature (TUFFS) and can either have "glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK -33 and ODSN -45 - close attention while drilling this interval is advised. Kick Tolerance /Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Maximum Mud Weight Exp Pore Min LOT / FIT Interval Influx Volume Press 11 ppg Intermediate 79 (12.5 EMW w /MPD) 3070 12.5 ppg (LOT) 11 ppg Production Infinite (12.5 EMW w /MPD) 3246 12.5 ppg (FIT) NOTE: A LOT to 16.9 ppge was performed below the surface casing shoe, it is planned to perform an FIT 10' below the intermediate casing shoe to 12.5 ppg Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H site, however Standard Operating • Procedures for H precautions should be followed at all times. Faults • Sub seismic faults with throws <25' may be encountered. Losses may be associated with these faults. CONSULT THE ODS DATA SHEET FOR ADDITIONAL INFORMATION (still in development) Pioneer Natural Resources Last Revised: November 30, 2009 ODSK -42Ai Permit To Drill Page 7 of 7 0 • ODSK -42Ai Kuparuk Injection - Proposed Completion Well Head: 9 5/8 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal Casing Item # Item MD (ft) TVD (ft) - A 16" Conductor 153 153 ■ 1 A B 10 3/4" 45.5# L -80 BTC, 8.835" ID 3,289 2,980 O C 7%' 29.7# L -80 BTC M, 6.875" ID 8,798 6,007 D 4'h# 12.60# L -80 Hydril 521 9,683 6,600 E 3'/2' 9.3# L -80 TSHP 8,647 5,940 Upper Completion Item # Item MDrkb (ft) TVDrkb (ft) 1 VetcoGray Tubing Hanger 34 34 HES Wellstar TRSSSV w/ 3'/2" 9.2# TSHP Box x Pin 9 2 750 750 Chr w/ 2.813 "X' Profile w/ 1/4" x .049 SS CL to Surface 'r '/2 GLM #1 HES Vanoil 3' x 1'/2' Gas Lift Mandrel w/ 3 © O 3 3,327 3,000 9.2# TSHP Box x Pin w/ Shear Out Valve in place GLM #2 HES Vanoil 3W x 1'/2' Gas Lift Mandrel w/ 3'/2' 4 9.2# TSHP Box x Pin w/ Dummy in place (min 2 jts above 8,285 5,740 gauge) O 5 WFT Gauge & Carrier w/ 3'/2' 9.2# 8rd EUE Pin x Pin 8,345 5,773 2 joint above X nipple) 6 HES 2.813 "X' Nipple 9 Chr w/ 3'/2' 9.2# TSHP Box x Pin 8,405 5,806 (min 2 jts above packer) Weatherford 3'h x 7 -5/8" Model "Ultra Pak -TH" Hydraulic 7 Set Permanent Production Packer w/ 31/2 9.3# TSHP Box 8,465 5,839 x Pin (min 2 jts above X nipple) 8 HES 2.813 "X' Nipple 9 Chr w/ 3'/2' 9.2# TSHP Box x Pin 8,525 5,872 (min 2 jts above XN nipple) O '/2 HES 2.813 "XN" Nipple w/ 2.750" No -Go 9Chr w/ 3' 4 9 TSHP Box x Pin w/ "RCH -M" Plug in Place (min 2 jts 8,585 5,906 O above WLEG) 10 WLEG w/ 31/2' TSHP Box 8,645 5,939 O 101 End of Assembly 8,647 5,940 ower Completion .7. , O Item # Item MD (ft) TVD (ft) 11 WFT PBR Tie Back Sleeve 15ft 5 -3/4" I.D. 12 8,630 5,931 O �i WFT "NTH" Liner Top Pkr w/ Hold Down Slips 5-1/2" x 7 5/8 8,645 5,939 1 3 WFT "PHR" Rotating Liner Hanger 5 -1/2" x 7 -5/8" 8,648 5,941 I® 14 Liner Shoe (PLUGGED) 9,673 6,593 ® TD 9,683 6,600 O - Perforations 15 Item # Item MD (ft) TVD (ft) 15 Perforations conducted via e line post rig 8,777 6,012 6 SPF 60 deg phasing 204 total shots 8,817 6,033 O Date: Revision By: Comments 11/30/09 VTJ Proposed Completion PIONEER ODSK -42i Injector NATURAL RESOURCES Well Schematic Version 3.0 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -42i ODSK -42A ODSK -42A wp05 • Sperry Drilling Services Clearance Summary Anticollision Report 25 November, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -42i - ODSK -42A - ODSK -42A wp05 Well Coordinates: 6,031,028.13 N, 469,844.38 E (70° 29' 45.03" N, 150°14' 47.69" W) • Datum Height: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Scan Range: 3,390.0 to 9,682.7 ft. Measured Depth. Scan Radius is 1,164.0 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM ANTI- COLLISION SETTINGS Date: 2009- 11- 25T00:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 Depth Range From: 3390.0 To 9682.7 Depth From Depth To Survey /Plan Tool Results Limited By: Centre Distance: 1164.0 42.8 1484.0 ODSK -42i KupG Gyros (ODSK -421 KupG) SR- Gyro -SS 1575.4 3390.0 ODSK -42i KupG MD (ODSK -42i KupG) MWD +IFR2 -eMS+sag Reference: Plan: ODSK wp05 (ODSK 42i /ODSK 42A) W 3390.0 9682.7 ODSK - 42A wp05 (ODSK - 42A) MWD+IFR2 +MS+sag Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference o From Color To MD ODSK -41 PB7 Ku aF 330 0 3300 IV^ . ,,, 3300 -- 4000 0 30 30 330 ®:� �- `` : ` 4000 5000 �: _ _. � ` 5000 _. 5250 �� ��• �® W. 5250 5500 ��. ',, 60 5500 - 5750 4°,111W , 6 300 ,� ` 5 750 - - 6000 300 ,, ` 0 • �V ��r ``` 6000 -- 6250 ,,, ,, e` 6250 10000 t ♦ . oil IBM math, I .��..� . O _ � -_ � �� \�� 270 III" 90 Moog IW o � 270 ; -�!- ! _....! _..i._r ..... .............. ... .. 90 ,, ` �� ` kit," � s i ! s s= ttlii, 120 IL__ Alkiht. -... Ile �`:`�: 4' ". °i� '''Nam 240 `_'� d �,r .�1 a • . • r e � � s� O�� �' : ,` O 4 � +t� � �► � �r� ` i' � �� ��A t ��s� 210 � 150 %i �v 180 '44 - . 'I" , - ) I - 210 ' 150 III ODSN - PEI2 180 Travelling Cylinder Azimuth (TFO +AZI) I ?I vs Centre to Centre Separation 120 ft /in1 V '1 Travelling Cylinder Azimuth (TFO +AZI) ( ?J vs Centre to Centre Separation [100 ft /in) REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk Coordinate (N /E) Reference: Well ODSK -42i - Slot ODS-42, True North Calculation Method: Minimum Curvature Vertical (TVD) Reference: 42.7 + 13.5 @ 56.2ft (Nabors 19AC) Error System: ISCWSA Section (VS) Reference: Slot - ODS- 42(0.0N, 0.0E) Scan Method: Tray. Cylinder North Measured Depth Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Error Surface: Elliptical Conic Calculation Method: Minimum Curvature Warning Method: Rules Based NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -42i SECTION DETAILS Sec MD Inc AZ1 TVD +51-5 ■EI -W OLeg TFace VSec Target 1 3390 0 58 69 14139 30334 - 958.8 442 6 0.00 000 1056.0 Ground Level: 13.5 2 37813 5635 15504 3244.2 - 1238.1 6162 3.00 10511 1362.5 3 8791.1 5835 15504 60200 5019.0 2376.2 0.00 000 5553.0 ODSK -420 +N / -S +E /•W Northing 469844.38 Lat0 N Longitude Slot 4 96827 4233 16267 6600.0 -5605.1 2623.7 170 16000 6225.6 0.0 0.0 6031028.13 469844.38 70° 29' 45.027 N 150° 14' 47.689 W ODS -42 Well Planning - Pioneer - Oooguruk HALLI BURTON Oooguruk Development Anticollision Report for ODSK -42i - ODSK -42A wp05 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -42i - ODSK -42A - ODSK -42A wp05 Scan Range: 3,390.0 to 9,682.7 ft. Measured Depth. Scan Radius is 1,164.0 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site ODSK -41 - ODSK -41 KupF - ODSK -41 KupF Surveys 3,404.1 136.9 3,404.1 79.4 3,450.0 2.380 Clearance Factor Pass - Major Risk • ODSK -41 - ODSK -41 PB1 KupF - ODSK -41 PB1 KupF 3,404.1 136.9 3,404.1 78.8 3,450.0 2.357 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG ODSK -42i - ODSK -42i KupG - ODSK -42i KupG ODSK -42i - ODSK -42i KupG - ODSK -42i KupG wp10.b ODSN -11 i - ODSN -11 i IS11 - ODSN -11 i IS11 wp09 9,682.3 845.2 9,682.3 469.5 13,550.0 2.250 Clearance Factor Pass - Major Risk ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp13 - 8 9,178.6 709.4 9,178.6 361.4 12,750.0 2.039 Centre Distance Pass - Major Risk ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp13 - 8 9,233.4 711.7 9,233.4 358.5 12,825.0 2.015 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PB1 PN6 - ODSN-31PB1 PN6 S 3,397.4 1,049.2 3,397.4 982.3 3,750.0 15.670 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PN6 - ODSN -31 PN6 Surveys 3,397.4 1,049.2 3,397.4 982.9 3,750.0 15.813 Clearance Factor Pass - Major Risk ODSN -32i - ODSN -32i IN7 - ODSN -32i IN7 Surveys 3,397.9 952.0 3,397.9 893.9 3,800.0 16.370 Clearance Factor Pass - Major Risk ODSN -32i - ODSN- 32iPB1 IN7 - ODSN- 32iPB1 IN7 3,397.9 952.0 3,397.9 893.9 3,800.0 16.370 Clearance Factor Pass - Major Risk ODSN -34i - ODSN -34 IN9 - ODSN -34i IN9 Surveys 3,400.0 600.7 3,400.0 534.2 3,525.0 9.039 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB1 IN9 - ODSN- 34iPB1 IN9 3,400.0 600.7 3,400.0 534.2 3,525.0 9.037 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB2 IN9 - ODSN- 34iPB2 IN9 3,400.0 600.7 3,400.0 534.2 3,525.0 9.039 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB3 IN9 - ODSN- 34iPB3 IN9 3,400.0 600.7 3,400.0 534.2 3,525.0 9.039 Clearance Factor Pass - Major Risk • ODSN -36 - ODSN -36 - ODSN -36 PN10 Surveys 4,987.8 178.7 4,987.8 101.3 4,825.0 2.309 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 - ODSN -36 PN10 Surveys 5,225.5 195.6 5,225.5 85.4 5,075.0 1.775 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 4,987.8 178.7 4,987.8 101.3 4,825.0 2.309 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 5,225.5 195.6 5,225.5 85.4 5,075.0 1.775 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 4,987.8 178.7 4,987.8 101.3 4,825.0 2.309 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 5,225.5 195.6 5,225.5 85.4 5,075.0 1.775 Clearance Factor Pass - Major Risk ODSN -37 - ODSN -37 - ODSN -37 PN8 3,390.0 410.0 3,390.0 345.9 3,450.0 6.400 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40 PN12 - ODSN -40 PN12 Surveys 3,402.5 388.9 3,402.5 311.3 3,425.0 5.010 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB1 PN12 - ODSN -40PB1 PN12 3,402.5 388.9 3,402.5 310.8 3,425.0 4.980 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB2 PN12 - ODSN -40PB2 PN12 3,402.5 388.9 3,402.5 311.3 3,425.0 5.013 Clearance Factor Pass - Major Risk ODSN -46i - ODSN -46i IN14 - ODSN -46i IN14 wp13 3,396.7 870.1 3,396.7 791.4 3,575.0 11.067 Clearance Factor Pass - Major Risk 25 November, 2009 - 11:11 Page 2 of 5 COMPASS Well Planning - Pioneer - Oooguruk HALLI B U RTO N Oooguruk Development Anticollision Report for ODSK -42i - ODSK -42A wp05 Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 42.8 1,484.0 SR- Gyro -SS 1,575.4 3,390.0 MWD +IFR2 +MS +sag • 3,390.0 9,682.7 ODSK- 42Awp05 MWD +IFR2 +MS +sag Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • 25 November, 2009 - 11:11 Page 3 of 5 COMPASS l PION EE Project: Oooguruk Development 9000- OD'N -31 PN• 41/2' Site: Oooguruk Drill Site r 'rt 1111 11111 0111 ODSK -42i ODS -31PB1 'N• ODSK -42A ::::' oDS ..I 7 ! , r + • N 34IN9 1 ' 4 1/2' , _ 1 41/2" . '; 1 i :ir u 'B2IN9 , " ■ s 4 1/2 4500- • •••••••• MMI■M■►\ •11111•■■• ■ - • ••••••••••• N■■►\ \I fiffirk,IP . !NEE:111i e4i:n.r17•1• ■■ I • ■N ■••■ ■■ ■ ■ \ ■1 \\ ■■ •'�■■� ■■ • ■■■ ■_ ■■ Irk% , •110•11111••••••=1111• 3000 -- ■ .11.1111.111. ... ■' , ■_■■ �_ ■■ ■\�\ • r .34iPB3 I . �■M ■■ c 11•11A NIV/Arlir••11111•• _ • �•■•■iiiiii ' • 1° 11 \ ■ ■ ■ ■ ■\ MIME 11Ii• — ■■ _ �N ••� •••• ■••••���IN� • ■'1•NA 1500 ■ ■ ■ ■� ■ ■■ A ■••� \�\� •••h► a ■ o _ ••��••••� ••• ••• \� ■ ■ ■ ■ ∎\ ■I. I I o �■ ^'�.•.YLW�••• r _ _ _ .. __ ■ _ ■ — � ■��•■■ ■�1 ��� OD • v l r� • . 0581 0 - • •►■ •••••••►EW�•�� ••• y ■ ' L - • — ■ 11111■ 111111111111._ ■� �■ ■ ■ ■ ■■►_W —■■IZ� _ •••••• Z - Ill ' k7 . � �n� x . . 95/8" - - , ODSN ' ' PN7 IIIIIM o - I 4 NIIRIPAIN/1111 , C/) • D -33P:1 KupA �� ,k I,t, 3000- • : . _ �, ,► . �-�� — - o• IIVIII ® II:DS 7 36PB1 ' � ilo' I ilk ,' /�/ a •S ' -33 KupA ItEll • 11•113- I\�1►. • I ' 4'PB1 PN12 6000- . 5/8" • 11. 1.• • M ■ DS( wp05 M■ - 7500 - i ■� lit ®H1 + 11 I 111 1.1 ■ ■■ ■ ... ■ Mi■ ■I■ •••••■••• - ■ ■■��■■■ • :: _mpg Mink ■�� -9000 "' ®_ ®_"' II III .a 1. Sew s •■■■��■■■ •• ■ -10500 i i i i i I l i l t I I I I I l I l I If I i i I I I ti I r r i i If i i i i l i i i i i i ii 1 1 i I I I -16500 -15000 -13500 -12000 -10500 -9000 -7500 -6000 -4500 -3000 -1500 0 1500 3000 4500 6000 7500 9000 10500 West( -) /East( +) (3000 ft/in) Well Planning - Pioneer - Oooguruk HALLI B U RTO N Oooguruk Development Anticollision Report for ODSK -42i - ODSK -42A wp05 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to 42.7 + 13.5' @ 56.2ft (Nabors 19AC). Northing and Easting are relative to ODSK -42i - Slot ODS -42. Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04. Central Meridian is - 150,00 °, Grid Convergence at Surface is: -0.23 ?. Ladd Plot 1200 ' ' MP 900 i _I '''...' ' '''' .0,.. , 0 A ....Npr I �� C 600 `� y, a, PA 0 1 - I !s U J - - - - - -J -- • \ - -I ---- I - - / ••- O - a, Al I C U 300 fi ' ` v �., ' , � ' - -- J I i ' 0 � �n ?) ;L E G EE n nnn -44 'Disposal, OU CIW ID A9 S1 -44 ispe9E -A� OL) S N N-5 9 NJ - -37, OCIS�1'= C3r�7r���-,N8 VO 8000 � Cl � - g N -2, CD ID S NI3 PS9, c, ID S N ' - DA, (DID S K -33 KupG VO -- OIDS NJ -39i, (D L) �a4 t ,'cJrwia_ M 9 � -- OAS N -25, OIDS N -25, O� S N -2� 1 K11 rA, ( K_ 'A � PR1 IC.. . . ..rs y c \.cow (1r1 NI _4.ff)U) NI -an P NI '1 ? C r NI - .1 fl I NI 'I? C• Irvay "/0 (117 C NI - ?P. C111C N - ?R P NI 1, c 9 )e, 0IDS K -35 KupB Surveys VO $ OIDSN -40, OC)S N -4OPB1 F. NJ 12, OIDSN -4OPB1 PN 12 VO -new- O1DS N -271, (DID SN -27i I N 2, CD S Ip13, ODSK -38i Kup17 Surveys VO • 017S N -40, OIDSN -40P132 PN 12, OIDSN -40PB2 RN 12 VO - (DID SN -28, 017SN -28 PN3, CD S 3F, OC1SK -41 KupF Surveys VO $ OCISN -45, OIDSN -45^ Moraine, O -45A Surveys VO --- OIDS N -291, 0 -291 IN 4, CDC S 1 Ku pF, (DID S K -41 PB1 KupF VO - OIDSN -45, O ID S NJ -45i IN 13 PB1 , (DID S N -45i I Ni 13 PB1 Surveys V-841111-- OCtSN -30, OAS N -30 P NI 5, OCS Ip45, C:/IDS K-421 KupG VO -A- OIDSIDW2 -20, OIDSC1W2 -20 disposal, OIDSIDW2 -20 'Disposal wp9aeti.'O0ID8■ OCtSN -3i IS2. OEDSN -: 1 ?N6, OIDSN -31 P61 RN Surveys VO --Ea- OIDSK -131, OC1SK -13i KupB, OIDSK -131 KupB wpO5.a VO - 017SN -4, OCrSN -4 PS3, O IDS N -• 6, ODSN -31 PN6 Surveys VO '1- 0 IDS K -14, OIDS K -14 KupB, O [DSK -14 KupB wpO4.a VO $ OC1SN -43, O CS/ SN -43 PN14, 00: 7, 0IDSN -32i IN Surveys VO -40- OIDSK -421, OC1SK -421 KupG, OC1SK -42i KupG wp1O.b VO $ OC•SN -46i, 0IDSN -461 IN 14, 00: I1 IN7, OIDSN- 32iPB1 1N17 VO OIDSN -1, OCtSN -1, 017SN -1 NE3 wpO1 VO OIDSN -47, ODSN -47 SW11 wDO 9, OIDSN -341 IN9 Surveys VO --*F.3.- O1DSN -1O, CDC/ SN -10 PS12, 0IDSN -10 PS12 wp1 1 - 6K' Horiz VO$- O -48, OIDSn -48 SW9, CDC S t1 1N3, (DID N 3-4 :r D1 IN VO I - (DID 0 N 11:, (DID ON 11: 1011, •L)0 N 11: 1011 .... F .O3 VO OID 0 NJ 5:, CD ID 0 N 5: 104, (DID 0 N -! 25 November, 2009 - 11:11 Page 4 of 5 COMPASS Well Planning - Pioneer - Oooguruk HALL 1 BU RTON Oooguruk Development Anticollision Report for ODSK -42i - ODSK -42A wp05 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor T Magnetic Model : I GF2F20051 0 M Date: 25- Nov -09 Declination: 22.03? Inclination /Dip: 80.81 ? Field Strength: 57755 Gri rth is 0.23? West of T rue North (Grid Conve rgence) Magnetic North is 22.03? East of True North (Magnetic Declination) Magnetic North is 22.27? East of Grid North (Magnetic Convergence) To con a True Direction to a Grid Direction, Add 0.23? To convert a Magnetic Direction to a True Direction, Add 22.03? East To convert a Magnetic Direction to a Grid Direction, Add 22.27? 25 November, 2009 - 11:11 Page 5 of 5 COMPASS .,, Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK-42i - Slot ODS-42 ODSK-42A Plan: ODSK-42A wp05 r!- Standard Proposal Report 25 November, 2009 14: = tpy , , 2J ,t4 HALLIBURTOPJ Sperry Drilling Services J::? PIONE HALLIBURTON WELL DETAILS: ODSK -42i REFERENCE INFORMATION Coordinate (N/E) Reference: Well ODSK -42i - Slot ODS -42, True North Ground Level: 13.5 Vertical (TVD) Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) NATURAL RESOURCES "`s +N / -S +E/ -W Northing Easting Latittude Longitude Slot Measured Depth Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) 0.0 0.0 6031028.13 469844.38 70° 29' 45.027 N 150° 14' 47.689 W ODS -42 Calculation Method: Minimum Curvature Project: Oooguruk Development WELLBORE TARGET DETAILS (MAP CO- ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Site: Oooguruk Drill Site Name TVD +N / -S +E / -W Northing Easting Shape Calculation Method: Minimum Curvature Well: ODSK -42i ODSK -42A T1 6020.0 - 5019.0 2376.2 6026000.00 472200.00 Point Error System: ISCWSA Scan Method: Tray. Cylinder North Wellbore: ODSK -42A Error Surface: Elliptical Conic Plan: ODSK 42A WpO5 (ODSK - 421 /ODSK -42A) SURVEY PROGRAM Waming Method: Rules Based 1 - Date: 2009- 11- 25T00:00:00 Validated: Yes Version: SECTION DETAILS DDI = 5.96 C epth From Depth To Survey/Plan /Plan Tool P P Y Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 42.8 1484.0 ODSK -42i KupG Gyros (ODSK-42i Ku G SR -G ro -SS P Y ( P ) Y 1 3390.0 58.69 141.39 3033.4 -958.8 442.6100 0.00 1056.0 1575.4 3390.0 ODSK -42i KupG MWD (ODSK -42i KupG)MWD IFR2 MS sag 2 3781.3 56.35 155.04 3244.2 - 1238.1 616.2 3.00 105.11 1382.5 3390.0 96827 ODSK -42A wp0 5 (ODSK -42A) MWD +IFR2 +MS +sag 3 8791.1 56.35 155.04 6020.0 - 5019.0 2376.2 0.00 0.00 5553.0 ODSK -42A T1 4 9682.7 42.33 162.67 6600.0 - 5645.7 2623.7 1.70 160.00 6225.6 2400 5° _ p 0 tx FORMATION TOP DETAILS isi CASING DETAILS 2800 - ai' TVD MD Name Size TVDPath TVDss MDPath Formation - _ _ _ . Start DLS 3.00 TFO 105.11 2980.0 3289.2 10 3/4" 10.750 1666.2 1610.0 1674.8 Base of Permafrost - 6007.0 8767.7 7 -5 /8" 7.625 2281.2 2225.0 2332.1 Top West Sak / 6600.0 9682.7 4 -1/2" 4.500 2926.2 2870.0 3193.0 Tuffaceous Shales I 3200 / Start 5009.8 hold at 3781.3 MD 4275.2 4219.0 5642.0 Brook 2b 5099.2 5043.0 7129.2 Top Torok Ss - 10 3/4" 5356.2 5300.0 7593.1 Base Torok Ss 5737.2 5681.0 8280.7 Top Hrz 3600 5870.2 5814.0 8520.8 Base Ha 5943.2 5887.0 8652.5 Kalubik Mkr 6012.2 5956.0 8777.0 Kup C - _ 6031.2 5975.0 8811.2 Base Kup C (LCU) 4000 6330.2 6274.0 9299.0 BCU 6411.2 6355.0 9418.6 Nuiqsut - - 6530.2 6474.0 9587.2 Nuiq Base - 6540.2 6484.0 9601.0 Nechelik ° 0 4400 6600.0 6543.8 9682.7 TD o - co - Brook 2b s - a 4800 - m - ODSK -42A T1 0 - To 7 -5/8" o - 5200- / Start DLS 1.70 TFO 160.00 • (1) Top Torok Ss 5600- , Base Torok Ss - _ Top Hrz - , , G 6000- Q - Base Hrz h0 )0> � Kalubik Mkr ph \OOc�� 6400- Kup - p ry. _ 005 Base Kup C (LCU) , 1 /1 1 6800- „ - ' , ' „' / 1 ‘ BCU , � t t TD at 9682.7 - Nuiqsut ,' i 4 -1/2" 7200- Nuiq Base / / ODSK -42i /ODSK -42A wp05 Nechelik TD - - 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 F 1 1 1 1 1 1 1 1 1 1 1 1 1 1] 1 I 1 l I 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 l , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 l l I l I l I l I l l 1 1 1 1 1 : 1 1 1 1 1 1 1 1 1 1 1 1 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 10000 Vertical Section at 155.07? (1000 ft/in) 5 • 1 G, HALLIBURTON WELL DETAILS: ODSK -42i REFERENCE INFORMATION Ground Level: 13.5 Co-ordinate (N/E) Reference: Well ODSK -42i - Slot ODS-42, True North r� ' Sorry g Dr Ring Vertical (TVD) Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) NATURAL RESOURC ` p +N/-S +E/ -W Northing Easting Latittude Longitude Slot Measured Depth Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) - -- -- -- -- 0.0 0 0.0 6031028.13 3 469844.38 70° 29' 45.00227 N N 150° 14' 47..6689 9 W W ODS-42 Calculation Method: Minimum Curvature WELLBORE TARGET DETAILS (MAP CO- ORDINATES) Project: Oooguruk Development Name TVD +N / -S +E/ -W Northing Easting Shape COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Site: Oooguruk Drill Site ODSK -42A T16020.0 - 5019.0 2376.2 6026000.00 472200.00 Point Calculation Method: Minimum Curvature Well: ODSK -42i Error System: ISCWSA Wellbore: ODSK -42A Scan Method: Tray. Cylinder North Error Surface: Elliptical Conic Plan: ODSK -42A wp05 (ODSK - 42i /ODSK -42A) Waming Method: Rules Based SURVEY PROGRAM _ 25* Date: 2009- 11- 25T00:00:00 Validated: Yes Version: I -480- Depth FroiDepth To Survey /Plan Tool 10 3/4" 42.8 1484.0 ODSK -42i KupG Gyros (ODSK -42i KupG) SR- Gyro -SS �, _ � 1575.4 3390.0 ODSK -42i KupG MWD (ODSK -42i KupG) MWD +IFR2 +MS +sac -960- Star.. 3390.0 9682.7 ODSK -42A wp05 (ODSK -42A) MWD +IFR2 +MS +sac _ t DLS 300 TFO 10511 DDI = 5.97 -1440- Start 5009.8 hold at 3781.3 MD SECTION DETAILS - 0 - Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target _ 1 3390.0 58.69 141.39 3033.4 -958.8 442.6 0.00 0.00 1056.0 -1920- 2 3781.3 56.35 155.04 3244.2 - 1238.1 616.2 3.00 105.11 1382.5 - 3 8791.1 56.35 155.04 6020.0 - 5019.0 2376.2 0.00 0.00 5553.0 ODSK -42A T - 4 9682.7 42.33 162.67 6600.0 - 5645.7 2623.7 1.70 160.00 6225.6 _ AQ pO -2400- CASING DETAILS TVD MD Name Size q- 2880 - - -- q'e 1 10.750 6007.0 8767.7 7 -5/8" 7.625 ` - o - 6600.0 9682.7 4 -1/2" 4.500 0 ext -3360 - + _ g 0° o -3840- .i - o -4320- 50 - • - -4800 - _ 7 -5/8" , -(Lo _ 1 I ODSK -42A T1 -5280- Start DLS 1.70 TFO 160.00 _ .6600 -5760- _ - - - / ODSK -42i /ODSK -42i KupG - ODSK- 42i/ODSK -42A wp05 / 4 - 1/2" TD at 9682.7 -6240 - -6720 - II 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 i , 1 : , 1 1 1 l I 1 1 1 1 1 1 1 1 1 1 i 1 1 f 1 1 1 1 1 1 1 1 p 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1' 1 1 1 1 1 1 1 1 1 1 1 1 H 1 -480 0 480 960 1440 1920 2400 2880 3360 3840 4320 4800 5280 5760 6240 6720 7200 7680 8160 8640 9120 9600 10080 10560 11040 West( - )/East( +) (1200 ft/in) • Halliburton Company HALLIBURT0 Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -42i - Slot ODS -42 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) . Site: Oooguruk Drill Site North Reference: True Weil: ODSK =42i Survey Calculation Method: Minimum Curvature Wellbore: ODSK -42A Design: ODSK -42A wp05 Project Oooguruk Development 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 Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70° 29' 46.242 N From: Map Easting: 469,920.45ft • Longitude: 150° 14' 45.465 W Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: -0.23 ? Well ODSK -42i - Slot ODS -42 Well Position +N / -S 0.0 ft Northing: 6,031,028.13 ft • Latitude: 70° 29' 45.027 N +E / -W 0.0 ft Easting: 469,844.38 ft • Longitude: 150° 14' 47.689 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft • Wellbore ODSK -42A Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 11/25/2009 22.03 80.81 57,755 Design ODSK -42A wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 3,390.0 Vertical Section: Depth From (TVD) +N/.S +E/-W Direction (ft) (ft) (ft) ( ?) 42.7 0.0 0.0 155.07 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) ( ?) ( ?) (ft) ft (ft) (ft) ( ?1100ft) MOON) Nt) ( ? /100ft) ( ?) 3,390.0 58.69 141.39 3,033.4 2,977.2 -958.8 442.6 0.00 0.00 0.00 0.00 3,781.3 56.35 155.04 3,244.2 3,188.0 - 1,238.1 616.2 3.00 -0.60 3.49 105.11 8,791.1 56.35 155.04 6,020.0 5,963.8 - 5,019.0 2,376.2 0.00 0.00 0.00 0.00 9,682.7 42.33 162.67 6,600.0 6,543.8 - 5,645.7 2,623.7 1.70 -1.57 0.86 160.00 I 11/25/2009 4 :40 :38PM Page 2 COMPASS 2003.16 Build 42 • III Halliburton Company HALLI B U RTO N Standard Proposal Report Database: .Pioneer Alaska Local Coordinate Reference: Well ODSK -42i - Slot ODS-42 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -42i Survey Calculation Method: Minimum Curvature Wellbore: ODSK -42A Design: ODSK -42A wp05 Planned Survey Wasured Vertical Map Map Depth Inclination Azimuth Depth TVDss +MP-S +E/.W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 2,977.22 3,390.0 58.69 141.39 3,033.4 2,977.2 -958.8 442.6 6,030,067.64 470,283.04 0.00 1,056.02 Start DLS 3.00 TFO 105.11 3,400.0 58.62 141.73 3,038.6 2,982.4 -965.5 447.9 6,030,060.93 470,288.32 3.00 1,064.32 3,500.0 57.89 145.15 3,091.3 3,035.1 - 1,033.8 498.5 6,029,992.45 470,338.68 3.00 1,147.59 3,600.0 57.25 148.63 3,144.9 3,088.7 - 1,104.4 544.7 6,029,921.59 470,384.49 3.00 1,231.12 3,700.0 56.72 152.15 3,1 99.4 3,143.2 - 1,177.3 586.1 6,029,848.55 470,425.62 3.00 1,314.67 3,781.3 56.35 155.04 3,244.2 3,188.0 - 1,238.1 616.2 6,029,787.70 470,455.54 3.00 1,382.46 Start 5009.8 hold at 3781.3 MD 3,800.0 56.35 155.04 3,254.6 3,198.4 - 1,252.2 622.8 6,029,773.57 470,462.05 0.00 1,398.02 3,900.0 56.35 155.04 3,310.0 3,253.8 - 1,327.6 657.9 6,029,697.96 470,496.87 0.00 1,481.27 4,000.0 56.35 155.04 3,365.4 3,309.2 - 1,403.1 693.1 6,029,622.36 470,531.69 0.00 1,564.52 4,100.0 56.35 155.04 3,420.8 3,364.6 - 1,478.6 728.2 6,029,546.75 470,566.51 0.00 1,647.76 4,200.0 56.35 155.04 3,476.2 3,420.0 - 1,554.1 763.3 6,029,471.14 470,601.33 0.00 1,731.01 4,300.0 56.35 155.04 3,531.6 3,475.4 - 1,629.5 798.5 6,029,395.54 470,636.15 0.00 1,814.26 4,400.0 56.35 155.04 3,587.0 3,530.8 - 1,705.0 833.6 6,029,319.93 470,670.97 0.00 1,897.50 4,500.0 56.35 155.04 3,642.4 3,586.2 - 1,780.5 868.7 6,029,244.33 470,705.79 0.00 1,980.75 4,600.0 56.35 155.04 3,697.8 3,641.6 - 1,855.9 903.9 6,029,168.72 470,740.61 0.00 2,064.00 4,700.0 56.35 155.04 3,753.2 3,697.0 - 1,931.4 939.0 6,029,093.12 470,775.44 0.00 2,147.25 4,800.0 56.35 155.04 3,808.7 3,752.5 - 2,006.9 974.1 6,029,017.51 470,810.26 0.00 2,230.49 4,900.0 56.35 155.04 3,864.1 3,807.9 - 2,082.4 1,009.3 6,028,941.91 470,845.08 0.00 2,313.74 5,000.0 56.35 155.04 3,919.5 3,863.3 - 2,157.8 1,044.4 6,028,866.30 470,879.90 0.00 2,396.99 5,100.0 56.35 155.04 3,974.9 3,918.7 - 2,233.3 1,079.5 6,028,790.69 470,914.72 0.00 2,480.24 5,200.0 56.35 155.04 4,030.3 3,974.1 - 2,308.8 1,114.6 6,028,715.09 470,949.54 0.00 2,563.48 5,300.0 56.35 155.04 4,085.7 4,029.5 - 2,384.2 1,149.8 6,028,639.48 470,984.36 0.00 2,646.73 5,400.0 56.35 155.04 4,141.1 4,084.9 - 2,459.7 1,184.9 6,028,563.88 471,019.18 0.00 2,729.98 5,500.0 56.35 155.04 4,196.5 4,140.3 - 2,535.2 1,220.0 6,028,488.27 471,054.00 0.00 2,813.22 5,600.0 56.35 155.04 4,251.9 4,195.7 - 2,610.7 1,255.2 6,028,412.67 471,088.82 0.00 2,896.47 5,642.0 56.35 155.04 4,275.2 4,219.0 - 2,642.4 1,269.9 6,028,380.88 471,103.46 0.00 2,931.47 Brook 2b 5,700.0 56.35 155.04 4,307.3 4,251.1 - 2,686.1 1,290.3 6,028,337.06 471,123.64 0.00 2,979.72 5,800.0 56.35 155.04 4,362.7 4,306.5 - 2,761.6 1,325.4 6,028,261.45 471,158.47 0.00 3,062.97 5,900.0 56.35 155.04 4,418.1 4,361.9 - 2,837.1 1,360.6 6,028,185.85 471,193.29 0.00 3,146.21 6,000.0 56.35 155.04 4,473.5 4,417.3 - 2,912.5 1,395.7 6,028,110.24 471,228.11 0.00 3,229.46 6,100.0 56.35 155.04 4,528.9 4,472.7 - 2,988.0 1,430.8 6,028,034.64 471,262.93 0.00 3,312.71 6,200.0 56.35 155.04 4,584.3 4,528.1 - 3,063.5 1,466.0 6,027,959.03 471,297.75 0.00 3,395.96 6,300.0 56.35 155.04 4,639.8 4,583.6 - 3,139.0 1,501.1 6,027,883.43 471,332.57 0.00 3,479.20 6,400.0 56.35 155.04 4,695.2 4,639.0 - 3,214.4 1,536.2 6,027,807.82 471,367.39 0.00 3,562.45 6,500.0 56.35 155.04 4,750.6 4,694.4 - 3,289.9 1,571.3 6,027,732.22 471,402.21 0.00 3,645.70 6,600.0 56.35 155.04 4,806.0 4,749.8 - 3,365.4 1,606.5 6,027,656.61 471,437.03 0.00 3,728.94 6,700.0 56.35 155.04 4,861.4 4,805.2 - 3,440.8 1,641.6 6,027,581.00 471,471.85 0.00 3,812.19 6,800.0 56.35 155.04 4,916.8 4,860.6 - 3,516.3 1,676.7 6,027,505.40 471,506.67 0.00 3,895.44 6,900.0 56.35 155.04 4,972.2 4,916.0 - 3,591.8 1,711.9 6,027,429.79 471,541.50 0.00 3,978.69 7,000.0 56.35 155.04 5,027.6 4,971.4 - 3,667.3 1,747.0 6,027,354.19 471,576.32 0.00 4,061.93 7,100.0 56.35 155.04 5,083.0 5,026.8 - 3,742.7 1,782.1 6,027,278.58 471,611.14 0.00 4,145.18 11/25/2009 4 :40 :38PM Page 3 COMPASS 2003.16 Build 42 III Halliburton Company H HALLIBURTOIR Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -42i - Slot ODS -42 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True .Well: ODSK -42i Survey Calculation Method: Minimum Curvature Wel'bore: ODSK -42A Design: ODSK -42A wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +0-W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 5,043.00 7,129.2 56.35 155.04 5,099.2 5,043.0 - 3,764.8 1,792.4 6,027,256.49 471,621.31 0.00 4,169.51 Top Torok Ss 7,200.0 56.35 155.04 5,138.4 5,082.2 - 3,818.2 1,817.3 6,027,202.98 471,645.96 0.00 4,228.43 7,300.0 56.35 155.04 5,193.8 5,137.6 - 3,893.7 1,852.4 6,027,127.37 471,680.78 0.00 4,311.67 7,400.0 56.35 155.04 5,249.2 5,193.0 - 3,969.1 1,887.5 6,027,051.76 471,715.60 0.00 4,394.92 7,500.0 56.35 155.04 5,304.6 5,248.4 - 4,044.6 1,922.7 6,026,976.16 471,750.42 0.00 4,478.17 7,593.1 56.35 155.04 5,356.2 5,300.0 - 4,114.9 1,955.4 6,026,905.79 471,782.83 0.00 4,555.65 Base Torok Ss 7,600.0 56.35 155.04 5,360.0 5,303.8 - 4,120.1 1,957.8 6,026,900.55 471,785.24 0.00 4,561.42 7,700.0 56.35 155.04 5,415.4 5,359.2 - 4,195.6 1,992.9 6,026,824.95 471,820.06 0.00 4,644.66 7,800.0 56.35 155.04 5,470.9 5,414.7 - 4,271.0 2,028.0 6,026,749.34 471,854.88 0.00 4,727.91 7,900.0 56.35 155.04 5,526.3 5,470.1 - 4,346.5 2,063.2 6,026,673.74 471,889.70 0.00 4,811.16 8,000.0 56.35 155.04 5,581.7 5,525.5 - 4,422.0 2,098.3 6,026,598.13 471,924.53 0.00 4,894.41 1 8,100.0 56.35 155.04 5,637.1 5,580.9 - 4,497.4 2,133.4 6,026,522.53 471,959.35 0.00 4,977.65 8,200.0 56.35 155.04 5,692.5 5,636.3 - 4,572.9 2,168.6 6,026,446.92 471,994.17 0.00 5,060.90 8,280.7 56.35 155.04 5,737.2 5,681.0 - 4,633.8 2,196.9 6,026,385.90 472,022.27 0.00 5,128.09 Top Hrz 8,300.0 56.35 155.04 5,747.9 5,691.7 - 4,648.4 2,203.7 6,026,371.31 472,028.99 0.00 5,144.15 8,400.0 56.35 155.04 5,803.3 5,747.1 - 4,723.9 2,238.8 6,026,295.71 472,063.81 0.00 5,227.39 8,500.0 56.35 155.04 5,858.7 5,802.5 - 4,799.3 2,274.0 6,026,220.10 472,098.63 0.00 5,310.64 8,520.8 56.35 155.04 5,870.2 5,814.0 - 4,815.0 2,281.3 6,026,204.41 472,105.86 0.00 5,327.92 Base Hrz 8,600.0 56.35 155.04 5,914.1 5,857.9 - 4,874.8 2,309.1 6,026,144.50 472,133.45 0.00 5,393.89 8,652.5 56.35 155.04 5,943.2 5,887.0 - 4,914.4 2,327.5 6,026,104.80 472,151.73 0.00 5,437.60 Kalubik Mkr 8,700.0 56.35 155.04 5,969.5 5,913.3 - 4,950.3 2,344.2 6,026,068.89 472,168.27 0.00 5,477.14 8,767.7 56.35 155.04 6,007.0 5,950.8 - 5,001.3 2,368.0 6,026,017.74 472,191.83 0.00 5,533.46 7-5/8" 8,777.0 56.35 155.04 6,012.2 5,956.0 - 5,008.4 2,371.3 6,026,010.64 472,195.10 0.00 5,541.27 KupC 8,791.1 56.35 155.04 6,020.0 5,963.8 - 5,019.0 2,376.2 6,026,000.00 472,200.00 0.00 5,552.99 Start DLS 1.70 TFO 160.00 - ODSK -42A T1 8,800.0 56.21 155.10 6,024.9 5,968.7 - 5,025.7 2,379.4 6,025,993.29 472,203.09 1.70 5,560.38 8,811.2 56.03 155.18 6,031.2 5,975.0 - 5,034.2 2,383.3 6,025,984.80 472,206.98 1.70 5,569.72 Base Kup C (LCU) 8,900.0 54.62 155.82 6,081.7 6,025.5 - 5,100.6 2,413.6 6,025,918.27 472,236.98 1.70 5,642.70 9,000.0 53.03 156.56 6,140.7 6,084.5 - 5,174.5 2,446.1 6,025,844.31 472,269.27 1.70 5,723.40 9,100.0 51.44 157.33 6,202.0 6,145.8 - 5,247.2 2,477.1 6,025,771.46 472,299.93 1.70 5,802.40 9,200.0 49.86 158.14 6,265.4 6,209.2 - 5,318.8 2,506.4 6,025,699.79 472,328.94 1.70 5,879.65 9,299.0 48.30 158.98 6,330.2 6,274.0 - 5,388.4 2,533.7 6,025,630.08 472,355.99 1.70 5,954.30 BCU 9,30 , 0.0 48.28 158.99 6,330.9 6,274.7 - 5,389.1 2,534.0 6,025,629.36 472,356.26 1.70 5,955.06 9,400.0 46.72 159.88 6,398.4 6,342.2 - 5,458.1 2,559.9 6,025,560.24 472,381.88 1.70 6,028.57 9,418.6 46.43 160.05 6,411.2 6,355.0 - 5,470.8 2,564.5 6,025,547.56 472,386.45 1.70 6,042.00 Nuiqsut 11/25/2009 4:40 :38PM Page 4 COMPASS 2003.16 Build 42 Halliburton Company HALL Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK -42i - Slot ODS -42 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7 + 13.5 @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -42i Survey Calculation Method: Minimum Curvature Weiibore: ODSK -42A Design: ODSK -42A wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Fasting BLS Vert Section (ft) (7) (7) (ft) ft (ft) (ft) (ft) (ft) 6,411.78 9,500.0 45.16 160.82 6,468.0 6,411.8 - 5,525.8 2,584.1 6,025,492.48 472,405.78 1.70 6,100.12 9,587.2 43.80 161.68 6,530.2 6,474.0 - 5,583.6 2,603.7 6,025,434.56 472,425.18 1.70 6,160.86 Nuiq Base 9,600.0 43.60 161.81 6,539.5 6,483.3 - 5,592.0 2,606.5 6,025,426.15 472,427.92 1.70 6,169.64 9,601.0 43.59 161.82 6,540.2 6,484.0 - 5,592.7 2,606.7 6,025,425.47 472,428.14 1.70 6,170.35 Nechelik 9,682.7 . 42.33 162.67 6,600.0 . 6,543.8 - 5,645.7 2,623.7 6,025,372.39 472,444.91 1.70 6,225.59 TD at 9682.7 - TD - 4-1/2" 1 Targets Target Name - hitlmiss target Dip Angle Dip Dir. TVD +N/-S +E1-W Northing Easting - Shape ( ?) (7) (ft) (ft) (ft) (ft) (ft) ODSK -42A T1 0.00 0.00 6,020.0 - 5,019.0 2,376.2 6,026,000.00 472,200.00 - plan hits target - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter • (ft) (ft) Name (in) (in) 3,289.2 2,980.0 10 3/4" 10.750 13.500 8,767.7 6,007.0 7 -5/8" 7.625 9.875 9,682.7 6,600.0 4 -1/2" 4.500 6.750 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (7) (7) 2,332.1 2,281.2 Top West Sak 0.00 9,418.6 6,411.2 Nuiqsut 0.00 8,280.7 5,737.2 Top Hrz 0.00 9,299.0 6,330.2 BCU 0.00 3,193.0 2,926.2 Tuffaceous Shales 0.00 5,642.0 4,275.2 Brook 2b 0.00 8,811.2 6,031.2 Base Kup C (LCU) 0.00 9,682.7 6,600.0 TD 0.00 8,520.8 5,870.2 Base Hrz 0.00 7,593.1 5,356.2 Base Torok Ss 0.00 9,601.0 6,540.2 Nechelik 0.00 1 1,674.8 1,666.2 Base of Permafrost 0.00 9,587.2 6,530.2 Nuiq Base 0.00 7,129.2 5,099.2 Top Torok Ss 0.00 8,777.0 6,012.2 Kup C 0.00 8,652.5 5,943.2 Kalubik Mkr 0.00 11/25/2009 4:40 :38PM Page 5 COMPASS 2003.16 Build 42 I Halliburton Company HALLIBURTO Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -42i - Slot ODS -42 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -42i Survey Calculation Method: Minimum Curvature Weiibore: ODSK -42A Design: ODSK -42A wp05 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/ -W (ft) (ft) (ft) (ft) Comment 3,390.0 3,033.4 -958.8 442.6 Start DLS 3.00 TFO 105.11 3,781.3 3,244.2 - 1,238.1 616.2 Start 5009.8 hold at 3781.3 MD 8,791.1 6,020.0 - 5,019.0 2,376.2 Start DLS 1.70 TFO 160.00 9,682.7 6,600.0 - 5,645.7 2,623.7 TD at 9682.7 11/25/2009 4:40:38PM Page 6 COMPASS 2003.16 Build 42 • : Cr Legend - ti ° • 4 3 0 1 As —built Conductor k ° 1111 1 , o VC e. h e Project Loot ' aS vi I/ t i ;. u ry i :. � I , ,F r,Rt. W ''' ° ° . ry o' Location Map • GRAPHIC SCALE 410 ° • . is LJ I 0 ° 4%, � Alt � . 45 ° ry e 1 I, PUT i , ° • / • • .y� o+�P.• 4 i t rash • to e. ,,� ° /, � � ° ; • f � _ ! e A � 0. • ° " •• �I ip G. Dads : o 'gy • • • .i I S No. 4110.5 ,,.& 0 o % ° o k p , , RO F ESSIONA A. .�� ry 0 0 k� �w�l�e�er I, �y ° kry ° '..r,', ', , S ")' f t. P E III 0 ►A Pioneer Natural Resouoes JOB NAME: Oooguruk Drill Site DRAWN BY: BL !CHECKED BY: MA) . LOCATION: Protracted Section 11 SCALE: 1 " 30' Township 13 North Range 7 East DATE 7 -12 -07 Umiat Meridian Notes: NANUQ JOB NO. SHEET Coordinates are listed on sheets 3 and 4 DESCRIPTION: Alaska Nod 27. Zone 4 Conductor Ae —built Plan 05204 1 of 4 , „ill . 1 r-.1:0 . 3 is t • 1 • t i Vistrict Boundry t 8 _ , � OO SITE SE Corner of i V Protracted Section 11 . c +. l � u T s a ,.• � � Coordinates > > / k N 6028111.04 ! D 1 1 E 4 ••:•. :• i ‘ � • -1 o PI — R e#. AK BLM . u , it4 " 44 " 0 F Harrison; Bay Troctf "A" • -24 .. _ L..E?J rawin - --- 1 21 • 1 i ' *2 iii4"; at ‘ *i• c5 ' 6. 2-, 1 1 Z 1 P ° �� �0f� ore Iteroad =� 1�8es ♦' � • ear Shore lceroad =3.81Mlles I 13 m 1 20 to O 00 0vr uk Ske l � • • PI 7 to PI 20 - . \ !fir • . 1, .s f ~� - P&-14 Qy s Pi -23 1 � i / - i —PI- 13 1 * `� ^ J~ - 3,1-17 Tundra leerop DS 3N LOP. 2,. m g 1 " s I? Roods to Loki a ►w f { ci .. 1 PI - • , Q Pt-19 _ may • ",� T1 low ► t, • i Basis of Location U O • • • .,\ ,ZZA • n‘..."% . , B C. a j DS -3H West Monument ANA id MIL i iir y I I & Coordinates ,Pi ,,„ N 6001016.61 5 AXE Pt INFORMATION ONLY ' E 498081.23 41 15 • i % V i le ` , . „ ' Ref. Lownsbury & Assoc. ., D c i c Drawing No. cr , ` � -------- NSK 6.01 -d672 � y ••• rte. •'• v S - - _c', -----"z,,,,," .� , OF 1.^-,t'-1,51- � 1 •.•.•• ••• 4 ' e ••; 'C:'1. { t • flip G. Darin . .. o I - • S• • No. 4110-5 J j ' µ ; ' y ,' • J I 14144 - Pioneer Natural Resouces • JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 -12 -07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location 05204 2 of 4 • . - _ -- , • , Ala Wa Slate Pia , - Section Line Ofitib:t Well No, ------ ------ -------- X ---- . Latitu FS de (N) . Longitude !‘ • _--.-.:- L FE ------ Elev., • Y 1 6,031,151,32 469,920,45 70 29 46,24160 150 14 45,46468 3035 1077 --- 13,50 -- - 2 0,0.51,145,35 459,912 70 29 46,19252 150 14 4.5,50922 3030 1082 . 13,50. . • 3 • 6,031,141,39 469,910,59 70 29 46,14354 150 14 4_5,75575 5025 1087 13,50 • . 4 .. 5,031,136.46 469,905,67 . 70 29 46.09485 150 14 45,89799 3020 1092 13.50' 5 6,031,131,45 469,900,74 ' 70 29 46,0453U150 14 46,04252 3015 -- 1097 13,50 6 6,031,126,51 409,895,80 70 29 45,99660 150 14 46,18735 3010 1102 13.50 !. . 7 . 5,031,113,73 469,883713 70 29 45,87039 150 14 46,55579 2997 1115 . 13,50 8 6,031,108,73 469,878,21 "70 29 45,52102 150 14 46,70303 2992 1120 7 1 7 3,50 , . • 9 6,031,103.75 469,675,26 70 29 45.77184 150 14 46,54814 2957 1125 - 1 7-7 160 10 6,031,098,79 469,668,36 70 29 45,72206 150 14 40,99179. 2982 1130 t • 13,50 -77 11 6,031,093,84 469,865,39 70 29 45,67395 150 14 47,15750 2977 1135 ' 13,50 . .• 12 6,031,088,87 469,858,47 70 29 45,02490 150 14 47,25174 2972 1140 13.50 13 6,031,076,0 702945,49840 15014471,552887 296U 1152 13,50 14 6,031,071,09 469,840,87 70 29 45,44932 150 14 47,79770 2955 - 1157 - 13,50 - . • • - 15 6,031,060.15 469,835,96 70 29 45,40053 150 14 47,94165 2950 1162 13,50 16 6,031,061,18 - 469,531,04 70 29 45,35145 150 14 40,08588 2945 1167 . 13.50 ' 17 6,031,056,25 469,826,11 70 29 45,30277 150 14 48,23042 2940 1172 13,59. 7--- 18 6,031705117 459,621718102945,25359 150 14 48,37495 2935 1177 13.50 .'---7- 19 6,031,030,52 469,808,50 70 29 45,12768 150 14 48,74668 2922 1189 13,50 20 .. 6,031,033,50 409,003,59 70 29 45,07811 . 150 14 45,59061 2917 1194 13,50 • . . 21 0,031,028,53 469,798,62 70 29 45,02903 150 14 49,03032 • 2912 1199 13,50 ,--.- 22 6,031,023,58 469,793,67 70 29 44,96014 150 14 49,18144 2907 - 1204 • 13,50 . - . 23 v 70 3 44,93067 150 14 49,32537 2902 1209 7- 13,50 . . • 24 6,031,013,60 409,783,84 70 29 44,88159 ' 150 14 49,45960 2597 1214 - 13.50 . 4 - 4 0 ........ 4Ao. . ,r4;.0 .,.. %.: •C2• . ...v g ! 9T ,..,..::, .....: •• •... : . ............. • . • • ,,..1,--is• cs„ Philip G Davis : . e4 __,.....„ • • ......•.......„ e A No 4 1 1 0 - .S •.! " ..t• al F • .e...::iii •.. --'' .7-.t ,''' .'' ..-- • . g- 1 V se 4%r • :i --'• T ..-. .., - "CitA&•:,$ . :.: : ::..) . :V: A 0 iy •••••••• 0 411IP , , .:,-;','-:_4.'.',,,..::.'..*-7-',Z.P.;.' %1W WI • : ,,,,1 - , 32 .: , , ..Z:1' .. ,',iktr7; 4 a,%,„:.e7r . ' 116‘11":11001441P . ..,..,,... • ...., - . 74:ag .4vr:` . .'• 105s: .:.• & .: : *:.' . Notes: • - - . L-qzki• Tg::' - ---'f' 1, Elevations ore Posed on BP Mon So Level, 2, Coordinates are based on Alaska State Plane Nod 27, Zone 4, • 3, Alt conductors are within Protrocted Section 11. . Pioneer Natural Resouces ... JOB NAME: 00.2guruk Drill Site Conductors DRAWN BY: BL ' CHECKED BY: MJD LOCATION; ' Protracted Section 11 . SCALE: N/A Township 13 North . . - • Ronde 7 East DATE: 7-12-07 Urniat Meridian - NANIJO JOg NO. SHEET _ _ DESCRIPTION: . As-built Coordi ___ notes • . . 05204 3 of 4 Well No. Alaska. State PI Latitude (N) Longitude All Section Line Offset Pad Elev. X FSL FEL 25 6,031,128.32 469, 943.64 70 29 46.01630 150 14 44.77930 3013 1055 13.50 26 6,031,123.35 469, 938.69 70 29 45.96722 150 14 44.92442 3008 1060 13.50 27 6,031,118.33 469,933.76 70 29 45.91765 150 14 45.06895 300 1065 13.50 28 6,031,113.39 469,928.86 70 29 45.86887 150 14 45.21260 2997 1070 13.50 29 . " 6,031,108.44 469, 923.95 , 70 29 45.81999 150 14 45.35655 2992 1075 13.50 30 6,031,103.45 469,919.01 70 29 45.77071 150 14 45.50137 2988 1079 13.50 31 6,031,090.65 469,906.38 70 29 45.64431 150 14 45.87163 2975 1092 13.50 32 6, 031, 085.68 469, 901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 33 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128 2965 1102 13.50 34 6,031,075.73 469,891.57 70 29 45.49698 150 14 46.30581 2960 1106 13.50 35 6, 031, 070.76 469, 886.60 70 29 45.44789 150 14 46.45152 2955 1111 13.50 36 6,031,065.83 469,881.69 70 29 45.39921 150 14 46.59547 2950 1116 13.50 37 6, 031, 053.00 469, 869.00 70 29 45.27251 150 14 46.96749 2937 1129 13.50 38 6,031,047.99 469,864.14 70 29 45.22304 150 14 47.10995 2932 1134 13.50 39 6,031,043.03 469,859.20 70 29 45.17406 150 14 47.25478 2927 1139 13.50 40 6,031,038.10 469,854.21 70 29 45.12537 150 14 47.40108 2922 1144 . 13.50 41 6, 031, 033.05 469, 849.29 70 29 45.07551 150 14 47.54530 2917 1149 13.50 ? 42 6,031,028.13. 469,844.38 • 70 29 45.02692 150 14 47.68925 2912 • 1154 • 13.50 43 6,031,015.46 469,831.70 70 29 44.90180 150 14 48.06099 2899 1166 13.50 44 6, 031, 010.49 469, 826.79 70 29 44.85272 150 14 48.20493 2894 1171 13.50 45 6,031,005.53 469,821.86 70 29 44.80373 150 14 48.34946 2889 1176 13.50 46 6,031,000.54 469,816.94 70 29 44.75446 150 14 48.49369 2884 1181 13.50 47 6, 030, 995.50 469,811.98 70 29 44.7 150 14 48.63910 2879 1186 13.50 48 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.78304 2874 1191 13.50' OF A t, SURVEYOR'S CERTIFICATE 1 Oc' • ' • °r f• I HEREBY CERTIFY THAT I AM y • •• '' • •• 1P i PROPERLY REGISTERED AND S T , * a LICENSED TO PRACTICE LAND j•'• • :424 SURVEYING IN THE STATE OF < 1 • ° • ALASKA AND THAT THIS PLAT s I EY'S e � , . fi t ( • ilip G: Davis : o / REPRESENTS A SURVEY DONE BY s + ' '► No 41104 . ME OR UNDER MY SUPERVISION • e •• . I' - i •••.• 5 J � AND THAT I BEUEVE THAT ALL � � . .. •• a O .... �O p -p• i %0FESSIANAI. DIMENSIONS AND OTHER DETAILS �� Ro ��� r ye: ARE CORRECT AS SUBMITTED TO ME BY NANUQ, INC. AS OF JULY 12TH, 2007. Pioneer Natural Resouces • JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD, LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 -12 -07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: As -built Coordinates 05204 4 of 4 1 PIONEER 1.)k:, 0_t;tN NATURAL RESOURCES MOO ; ,1 a ties girt .. 6i)(t1ttliSStun � n Ha u sT Pioneer Natural Resourc s ask ,Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277 -2700 Fax: (907) 343 -2190 November 30, 2009 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSK -42Ai Surface Location: 2912' FSL, 1154' FEL, Sec. 11, T13N, R7E, UM X = 469844.38, Y = 6031028.13, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill an injection • well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be an injection well in the Oooguruk - Kuparuk formation. PNRA requests the permit to drill based on approved Pool Rules. ODSK -42i was originally drilled as a Kuparuk target in November, 2009. Due to limited thickness and poor reservoir quality, it was decided to sidetrack to another bottom hole location. The rig was moved to perform other work while plans were made to sidetrack the well. Application for a sundry permit for the abandonment of ODSK -42i will be made separately. Assuming there are no major problems during the abandonment of ODKS -42i, a sidetrack will be made from a kickoff /abandonment plug —100' below the surface casing shoe. A 9 -7/8" intermediate hole will be drilled to new targets and 7 -5/8" casing set and cemented above the Kuparuk sand. A 6 -3/4" production hole will be drilled below the intermediate casing shoe. If there are no major losses in the Kuparuk sands, drilling will continue to log and evaluate the Nuiqsut sand. After drilling and evaluating the interval, a 4 -1/2" liner will be ran and cemented to provide isolation between the Nuiqsut and Kuparuk. The upper completion will utilize 3 -1/2" tubing and the well will be perforated across the Oooguruk - Kuparuk for injection. PNRA plans to implement Managed Pressure Drilling technology (MPD) while drilling the intermediate and production hole of ODSN -42i. PNRA does not intend on drilling with a mud weight lower than the pore pressure of the exposed formations. PNRA plans to use this technique while drilling the production interval as outlined below. • From the Surface Shoe to below the Base of the Torok Sands Alaska Oil & Gas Consery Commission 1 November 30, 2009 Page 2of3 o Use -9.2 to 9.8 ppg fluid while using MPD to control pressure from the surface to -10.5 ppg EMW at the bottom of the hole. • Open formations: • Torok Sands, -8.7 ppg Pore Pressure • From the base of the Torok Sands to Production Hole TD o Use -9.8 to 11.0 ppg fluid while using MPD to control pressure from the surface to -12.5 ppg EMW at the bottom of the hole. • Open formations: • Torok Sands, -8.7 ppg Pore Pressure • Kuparuk Sands, -9.8 ppg Pore Pressure • • Nuiqsut Sands, -9.7 ppg Pore Pressure In the future, PNRA may provide information requesting the permitting for annular disposal of drilling wastes on this well. Please find attached information as required by 20 AAC 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 AAC 25.005 (a). 2) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A summary of the drilling operations. e. A summary of drilling hazards per 20 AAC 25.005 (c) (4). f. A wellbore schematic is also attached visually depicting the proposed well. 3) A copy of the Planned Directional Well Path - including traveling cylinder and development layout plots. The following items are on file with the AOGCC: 1) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 2) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19 -AC as required by 20 AAC 25.035 (b) and (c). Alaska Oil & Gas Conservai Commission • November 30, 2009 Page 3 of 3 3) A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). 4) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 AAC 25.065(1) will be functioning on the rig as standard operating procedure for all wells drilled by that rig. Products for treating H2S contamination in the drilling mud system will be maintained on the ODS. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vern Johnson, Senior Staff Drilling Engineer (20 AAC 25.070) 907.343.2111 vern.iohnsonapxd.com 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 AAC 25.071) 907.343.2134 paul.daggettapxd.com It is planned to set intermediate casing as close as possible to the Kuparuk sand without penetrating. To reduce the risk of penetrating the Kuparuk prior to performing the FIT, PNR requests dispensation from 20 AAC 25.030 (f), allowing the FIT to be performed after drilling 10' of new formation instead of 20 ft The anticipated spud date for this well is December 6, 2009. The short timeline between permit application and planned spud date is in reaction to the poor well results found when ODSN -42i was originally drilled. If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. Sincerely, Vern Johnson Senior Staff Drilling Engineer Attachments: Form 10 -401 Supporting permit information cc: ODSK -42Ai Well File Page 1 of 2 • Schwartz, Guy L (DOA) From: Johnson, Vern [Vern. Johnson @pxd.com] Sent: Thursday, December 03, 2009 8:31 AM To: Schwartz, Guy L (DOA) Cc: Franks, James Subject: FW: 1/4 mile radius plot Attachments: ODSK -42A Spider Plot .25 mile rad Letter Size.pdf Guy, As discussed yesterday, see the attached plot showing a 1/4 mile radius around the Kuparuk penetration on ODSK- 42Ai. As shown, there are no other Kuparuk wells within 1/4 mile. The closest Kuparuk penetration is ODSK -42i '1500', which will be abandoned. The two other wells on the plot which intersect the 1/4 mile radius are planned Nuiqsut laterals which are below the Kuparuk depth. Please call if you have any questions. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2111 office 907 - 575 -9430 cell From: Greg Griffin [mailto:Greg.Griffin @HALLIBURTON.com] Sent: Wednesday, December 02, 2009 5:40 PM To: Johnson, Vern Subject: 1/4 mile radius plot Vern, Does this work for you? All the laterals over there are plans only except KupG and KupF Grey Griffin Weil Design Sperry Drilling 700 G Street, Suit 600 Anchorage, AK 99501 (907) 343.21 19 Office (907) 441-1858 Mobile This e -mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Any review, use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient (or authorized to receive information for the intended recipient), please contact the sender by reply e -mail and delete all copies of this message. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission 12/3/2009 Page 2 of 2 in error, please notify the sender by reply e -mail and delete the message and any attachments. 12/3/2009 PIONEER Project: Oooguruk Development NA NATURAL RESOURCES AO PL. o1 Site: Oooguruk Drill Site TD .2 09- 6 -2250 all Ili a -3000 !ii!i j : / • ■ ■ ■ ■ ■... ■A ■■..1I■■ ■M ■.■■■■.■■■ V■ ■ ■.M■•. ■■ ■\ ■ ■ ■ ■ ■ ••■..■. ■ ■ ■■.IIMI■■■■■■ to \•1110■111.PW■11■. \1■ ■11 •0•.•. ••••• ■•••=••••••■••••IIIII••••• ■ \ \••IIIII■ ■ •••• = �i� - w °1 ii ■■ •1111■■\■ •01110•■ ••••• \■■■∎■. ■ ■ ■ ■.21.■ ■� ■ ■ ■ ■ ■ ■ ■1M1TrIe1'RlAll 1 1111■ ■■\11■ \i ■11!�••� \ ■ ■■ ■ ■ ■ ■ ■ ■ ■ ■1\ ■ ■ ■ ■ ■ ■ ■ ■ffibilliklibill iilr -3750 ......" ODSK- 42AT1A ► :a■.WE■ \iM. 1111111111011 •1111 ■■■ OS i■\�• ■ ■ \\. ■C\ ■■• ■. ■11 ■ \ ■ ■11■11d ■■.\■■■\ ■\ 4500 .■.■111111 ■1111.■11/I.. ■ ■1►I „!, . ■■■■ ■11■. \■■/1 ■•••� ►, ► . .1111 •■ •11■■■MA■ EW1111 \ ■ ■ ■ ■ ■ ■ = ■ ■ ■ ■ ■. ■ ■ ■ ■ ■•■ �. 4 1/2" 13 ■• " ui...n . 111111111111111111111111111111, 111!■!1 riiiiiMIME8M wk lk i � ■1II11111111 ■1111111111 ■111111 -5250 .■ ■ ■.. ■ ■1� ■ ■ ■ ■■ ' ..►.\...■ ■��� ■ ■ ■.••.����*!�!�. *. *�.• ■ ■•■ •U ■■.■.■l1 ■\ ■11■ ' 4 -1/2" 11■ I■\■■■■■ 11■■■•• ■=Irliiliil�lilWilrii■Wifi■■■■■ "1111 111V a' -immommiumENHE 1111 ■ U . ■ ■ ■ ■ ■ ■ ■ ■ ■. .r.�■■ . . .t O 1111 0DSK -42A 114 mile red K • aruk Top ■11.11 E l : I : : III! Z -6750 11■■■■ _ 7" r • ■r L ■ ■ ■ ■ ■ ■ ■ \ \ ■ ■ ■ ■ ■ ■■ ■..111 o cn -7500 11"11 • .1 MUM . DSK-4 PB � �� 1�111111111111 1•""" ::: 1111 1111111 11111i����Z:.:i1111 ■111111 1 ■.•.■•.... 111 625011111121••••••• ...... ■• IEEE L 41/2" ,1 • „ . • 9000 111111111111111111 41/2" I, 1 , r upF ■ •■\■•••■■• 11111111111111111111111 9750 ■ ■• ■•..11. 1 Hortz iiihk �DSiv -151 1514 11•,11"• _ ■• ■1 \ � 1111 1CC■■■■■■■■■• - 10500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 West( -) /East( +) (1500 Win) • Page 2 of 2 Vern From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Thursday, December 03, 2009 10:39 AM To: Johnson, Vern Subject: ODSK -42Ai ( PTD 209 -156) Vern, I was looking at the procedure and have a question regarding testing the 7 5/8" casing. In step 11 you state bumping the plug and in step 12 go to test the casing to 4500 psi. Is this after the stub is cut off and packoff installed ? ?? not clear in the procedure. Thanks, Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 12/3/2009 Page 1 of 2 • Schwartz, Guy L (DOA) From: Johnson, Vern [Vern.Johnson @pxd.com] Sent: Thursday, December 03, 2009 1:55 PM To: Schwartz, Guy L (DOA) Cc: Franks, James; Vaughan, Alex Subject RE: ODSK -42Ai ( PTD 209 -156) Guy, The packoff will be ran and tested separately, provided we are able to get to bottom and land the hanger. This was not explicit in the permit application, but we will add that as a step in the permit procedure. Of course if we are unable to land the hanger, or if the plugs do not hold, we would have to do the test later. Vern From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, December 03, 2009 1:13 PM To: Johnson, Vern Subject: RE: ODSK -42Ai ( PTD 209 -156) Vern, My concern is not with the cement, it is with the new connections that now become part of the permanent wellhead assembly. By not testing the casing immediately prior to drillout are all connections whether made up by the rig crew or factory made pressure tested after assembled by the rig? Our understanding in some cases is that there could be connections (field and factory) that may only be field pressure tested when the LOT /FIT is accomplished and then only to —1000 psi. Give me a call. I just want to make sure I understand this correctly. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson @pxd.com] Sent: Thursday, December 03, 2009 10:51 AM To: Schwartz, Guy L (DOA) Subject: RE: ODSK -42Ai ( PTD 209 -156) Guy- The casing will be run with a mandrel hanger to land in the Vetco wellhead, so no casing cut. We plan to test casing after the cement job is pumped, plugs bumped and the mandrel is landed. We will still have the landing joint in the rotary table, and it is prior to installing & testing the packoff. If there is anything suspicious when we start to pressure up (indicating that the plugs are not holding) we will postpone the test until just prior to drilling out the float equipment with our 6 -3/4" drilling BHA. This saves a small amount of rig time getting pressure and test equipment set up, and I don't think it has a negative impact on the cement job. 12/3/2009 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 AEO 2 6000000 ODSK -42Ai AEO 1 5950000 -� 5900000 40 CFR 147.102 (b)(3) • 5850000 400000 500000 600000 700000 800000 • TRANSMITTAL LETTER CHECKLIST WELL NAME ODSK -42 PTD# 2091560 Development X Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: Oooguruk POOL: Oooguruk, Oooguruk- Kuparuk Oil Pool 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 , Permit No. (If last two digits in API No. . Production should continue to be API number are reported as a function of the original API number stated above. between 60 -69) 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. Rev: 1/11/2008 ; .. . .. Field & Pool 000GURUK, KUPARUK OIL - 576100 Well Name: 000GURUK KUP ODSK -42A x Program SER Well bore seg PTD#: 2091560 Company PIONEER NATURAL RESOURCES ALASKA INC Initial Class/Type SER / PEND GeoArea 973 Unit 11550 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 12 Lease number appropriate Yes Entire well in ADL 355036. 3 Unique well name and number Yes Redrill 14 Well located ina defined pool Yes 000GURUK, KUPARUK OIL - 576100, governed by Conservation Order No. 596 and AIO No. 33 5 Well located proper distance from drilling unit boundary Yes CO 596 specifies no restrictions as to well spacing except no pay open within 500' 6 Well located proper distance from other wells Yes of external property line. of external property line. Well will be >2000' from exterior boundary of 7 Sufficient acreage available in drilling unit Yes Oooguruk Unit 1 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 12/2/2009 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 116 Pre - produced injector: duration of pre- production less than 3 months (For service well only) NA_ 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 18 Conductor string provided NA Conductor set in ODSK -42 Engineering 119 Surface casing protects all known USDWs NA Surface Casing set in ODSK -42 20 CMT vol adequate to circulate on conductor & surf csg NA Surface Casing cemented back to GL 21 CMT vol adequate to tie -in long string to surf csg No 7 5/8" intermediate to be cemented 500' above Kuparuk sands. 22 CMT will cover all known productive horizons Yes Cemented liner completion. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 309 -401 sundry 26 Adequate wellbore separation proposed Yes Proximity analysis performed ... no issues. Well path diverges from ODSK -42. 27 If diverter required, does it meet regulations NA Wellhead already in place. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure = 3329 psi ( 9.7 ppg) Will drill with 9.8- 11 ppg mud using MPD technique. GLS 12/3/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2603 psi Will test BOPs to 4500 psi III- 1 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No No H2S reported but rig has working alarms and sensors. 134 Mechanical condition of wells within AOR verified (For service well only) Yes AOR performed. ODSK -42 with 1/4 mile but is cemented and will be P &A'd. 35 Permit can be issued w/o hydrogen sulfide measures Yes None expected, but H2S monitors will be operational, and mud scavengers will be available. Geology 1 36 Data presented on potential overpressure zones Yes Expected max. pressure is 9.8 ppg EMW; will be drilled using 9.2-11.0 ppg mud and managed Appr Date 37 Seismic analysis of shallow gas zones NA pressure drilling to keep equivalent circulating density between 10.5 and 12.5 ppg as required. SFD 12/2/2009 38 Seabed condition survey (if off shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA 1 Geologic Engineering Public j\ Commissioner: Date: Woner. Date issioner � � ,/ C s/ ‘:\ Date %� V (\
