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Home My WebLink About212-103Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2025 InspectNo:susKPS250517193719 Well Pressures (psi): Date Inspected:5/17/2025 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:4/8/2019 #318-572 Tubing:0 IA:0 OA:600 Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:5/9/2025 Type of Inspection:Subsequent Well Name:OOOGURUK TOR ODST-47 Permit Number:2121030 Wellhead Condition Well head was in good shape, Well is located in well bay so no cellar Surrounding Surface Condition Everything was clean in well area Condition of Cellar N/A Comments Supervisor Comments Photos (3) Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, July 21, 2025 9 9 9 9 9 9 9 9 MEU 2025-0517_Suspend_Ooogurtuk_ODST-47_photos_ksj Page 1 of 2 Suspended Well Inspection – Oooguruk ODST-47 PTD 2121030 AOGCC Inspection Rpt # susKPS250517193719 Photos by AOGCC Inspector K. StJohn 5/17/2025 2025-0517_Suspend_Ooogurtuk_ODST-47_photos_ksj Page 2 of 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION "Mut1vtU Ann nn wtLL GUMPLETION OR RECOMPLETION REP RT ANETrWO "'I 7a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Suspended 1b. Well Class: C % 20AAt 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: It 2. Operator Name: 6. Date Comp., Susp or Caelus Energy Alaska Abend.: 4/8/2019 \t"%I Development �O �(plbrIK ❑ Service ❑ Stratigraphic Test ❑ 14. Permit to Drill Number / Sundry: ' 212-103 / 318-572 3. Address: 7. Date Spudded: 15. API Number: 3700 Centerpoint Dr. Suite 500 Anchorage Alaska 99503 8/15/2012 50-703-20660-00-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: Surface: 2879' FSL, 11 86'FEL, Sec. 11, T13N, R7E, UM Top of Productive Interval: 9/26/2012 ODST-47 9. Ref Elevations: KB: 56.2' 17. Field / Pool(s): 4824' FSL, 1259' FEL, Sec. 22, T13N, R7E, UM Total Depth: 838' FSL, 3468' FEL, Sec. 23, T13N, WE, UM Oooguruk -Torok Oil Pool " 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: , ADL 355036 / ADL 355038 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: r Surface: x- 469811.98 Y- 6030995.50 Zone- asp4 17,245' MD / 5288' TVD TPI: x- 464432.41 y- 6022404.67 Zone- asp 12. SSSV Depth MD/TVD: 19. DNR Approval Number: 417497 20. Thickness of Permafrost MD/TVD: Total Depth: x- 467490.14 y- 6018405.22 Zone- asp4 2410' MD / 2028' TVD 943' MD / 933' TVD 5. Directional or Inclination Survey: Yes (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (tt MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16" 109# H-40 Surface 158' Surface 158' 24" Driven 10-3/4" 45.5# BTS M Surface 5380' Surface 2998' 13-1/2" 657 sx PF'L'; 250 sx Class 'G' 7-5/8" 29.7# L-80 HYD 511/BTG M Surface 12,138' Surface 5004' 9-7/8" 264 sx Class'G' 4-1/2" 13.5# P-110 HYD 521 11,938' 17,191' 4989' 5281' 6-3/4" emen e Cement top @ 12223' and 24. Open to production or injection? Yes ❑ No Q 25. TUBING RECORD If Yes, list each interval open (MD1TVD of Top and Bottom; Perforation Size and Number; Date Perfd): S; -OL 5 Yeie SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4 1/2 11,986' 11,938 DAT 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. $ 0 (f Was hydraulic fracturing used during completion? Yes No Q V RIFIED ._ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 12,223-17,245 MD 1200 bbls Class GCement - 73.3# Torok Lateral Plugged 27. PRODUCTION Cement PIT pass 3000 psi Combo MIT passed 3500 psi TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing ®r19s$4-407 Revis Casing Press: 5/2017 Calculated 24 -Hour Rate Oil -Bbl: CONT UED Gas -MCF: Water -Bbl: N PAGE 2 Oil Gravity - API (torr): Submit ORIGINIAL only 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top 860' 854' Permafrost - Base 1803' 1668' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. West Sak 2990' 2278' Top Cretaceous Tuffs 4906' 2853' Hue 2 6002' 3196' Brookian 213 9231' 4221' Top Torok 12,053' 4998' Base Nuna (Torok) 17,192' 5281 Formation at total depth: 17,245' 5288' 31. List of Attachments: Form 407 - Well Schematic post abandonment- Well Service Report, Abandoned Completion packer placement- Directional Survey- Combo MIT Pressure test, Cement Job Pressure test 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. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Jack Kralick Contact Name: Jack Kralick Authorized Title: Wells Superintendent Contact Email: 'ack.kralick caelusener .cora AuthorizedContact Phone: 345-2185 Signature: Date: 4/9/2019 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 5/2017 Submit ORIGINAL Only CE CAELU S Alaska April 9, 2019 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Ave, Suite#100 Anchorage, Alaska 99501 RE: ODST-47 10-407 Sundry to plug the Torok lateral REF: Approved Permit to Drill# 212-103 — 10-403 Sundry# 318-572 Caelus Natural Resources Alaska, LLC (CNRA) submits a 10-407 to complete the abandonment work on the Torok lateral in ODST-47. Future plans include possible sidetrack out of the 10 %" casing to a Nuiqsut location. The Oooguruk Island has limited slots available and reclamation of the ODST-47 wellbore sidetracked to a new location is quite valuable. The Torok lateral was successfully abandoned with 200 bbls Class G 13.3# Cement. The cement top was tagged at 12,223' and the cement job pressure test to 3000 psi was good. The combo MIT was also successful holding 3500 psi for 30 min. Included in the package is the completed form 10-407, updated well schematic, Well Service reports, Combo MIT pressure test, Cement job pressure test, list of lateral jewelry that is now cemented in and a directional survey. Sincerely, Jack Krali k Wells_S perintendent Attachments: Form 10-407 Supporting documentation cc: ODST-47 wellfile ODST-47 Torok Production Well Completion Final 4/8/2019 Abandoned Torok Lateral — Retained Wellbore Torok Lateral Abandoned vuc Top of Cement 7-5/8" 29.7 ppf L-80 BTC -Mod Casing @ 12,138' MD / 5004' TVD -� Loper Com leo tion MD TVD 1) Tubing Hanger 34' 34' 16" Conductor 2) 4 -Yd' 13.5#/ft Hydril 521 Tubing (2 its) - 9 bbls of cement laid in lateral from 12,800' 4-1l2" 13.5 f 3) 4-Y2" 13.5#/ft Hydril 521 Tubing to 12,223'. (top of cement) Packer Fluid mix: 4) 4-Y2" Halliburton'XXO' SVLN w/ 3.813" "X" profile RTS -8 2410' 2028' Inhibited Kill weight with singlet/4" x .049" s/s control line. No SSSV installed. 10,9151. Brine Cannon Cross -coupling clamps on every joint - 106 bbls of Seawater from top of Barazan D with 2000' TVD 5) 4-Y2" 13.5#/ft Hydril 521 Tubing pill to diesel freeze protect. Tubing 6) 4-Y2" x 1" GLM, KBMG Hydril 521 w/ 1/4" GLV Set at max 68 deg 2674' 2157' diesel cap 7) q -Y2" 13.5#/ft Hydril 521 Tubing surface. / 8) HES X 3.813" Set at max 68 deg 2776' 220 9) 4-12" 13.5#/ft Hydril 521 Tubing on the first attempt. 10) 4-Y2" x 1" GLM, KBMG Hydril 521 w/ 1/4" GLV 5580' 3062' 11) 4-Yi' 13.5#/ft Hydril 521 Tubing -BPV installed in tubing hanger 12) 4-Y2" x 1" GLM, KBMG Hydril 521 w/ 1/4" GLV 8595' 4020' 10-3/4" 45.5 ppf L-80 BTC 13) 4-%" 13.5#/ft Hydril 521 Tubing Surface Casing 14) 4-Y2" x 1" GLM, KBMG Hydril 521 w/ 5/16" OV 10944' 4766' @ 5380' MD / 2998' TVD 15) 4-%" 13.5#/ft Hydril 521 Tubing 16 HES XN 3.813" 3.725" NoGo) - with RHC 11045' 4797' cemented to surface 17) 4-Y2" 13.5#/ft Hydril 521 Tubing 18) 4-1/2" Halliburton'ROC' Gauge Carrier w/ 1/4" x 0.049" s/s control line 11849' 4978" 19) 4-Y2" 13.5#/ft Hydril 521 Tubing RETAINED 20) GBH -22 Locator Tubing Seal Assembly with Auto Entry Mule Shoe 11983' 4993' Bottom of Shoe 11986' 4994' WELLBORE X= 464511.93, Y= 6022052.32 4471.8' FSL, 1178.2' FEL, TOC Estimated Sec.22, T13N, R7E, 500' above top ofin ADI,355038 Torok FAILED ECP Fish Left in hole Coil — 13.021' MD: •Tempress Screen Sub — 1.95 ft long •Tempress Hydro Pull —1.68 ft long •Xtreme Motor -8.16 ft long •Mill (2.700" OD) -0.09 ft long Total fish length: 11.91 ft long Pert E Pert Perforations: 12,815' — 12,830' 13,810' — 13,814' 14,510'— 14,520' 14,525'— 14.535' 4-Y2" Hydril 521 Liner with Baker Hughes Multi -Point Frac Sleeves (3 per stagel) isolated with ECP's + Resman Carriers (2 per stage)_ Cemented RESIDUAL i Section WELLBORE 6-3/4" Hole TD at at 17,245' MD / 5288' TVD Com leo ted. - 191 bbls of cement squeezed in lateral - 9 bbls of cement laid in lateral from 12,800' 4-1l2" 13.5 f to 12,223'. (top of cement) PP - 20 bbls of Barazan D laid in from 12,223' to P-110 Hydril 10,9151. 521 - 106 bbls of Seawater from top of Barazan D pill to diesel freeze protect. Tubing - 61 bbls of diesel laid into TBG from 4000' to surface. / - Cement was tested to 3000 psi and passed v on the first attempt. - MIT combo passed to 3500 psi. -BPV installed in tubing hanger X= 464511.93, Y= 6022052.32 4471.8' FSL, 1178.2' FEL, TOC Estimated Sec.22, T13N, R7E, 500' above top ofin ADI,355038 Torok FAILED ECP Fish Left in hole Coil — 13.021' MD: •Tempress Screen Sub — 1.95 ft long •Tempress Hydro Pull —1.68 ft long •Xtreme Motor -8.16 ft long •Mill (2.700" OD) -0.09 ft long Total fish length: 11.91 ft long Pert E Pert Perforations: 12,815' — 12,830' 13,810' — 13,814' 14,510'— 14,520' 14,525'— 14.535' 4-Y2" Hydril 521 Liner with Baker Hughes Multi -Point Frac Sleeves (3 per stagel) isolated with ECP's + Resman Carriers (2 per stage)_ Cemented RESIDUAL i Section WELLBORE 6-3/4" Hole TD at at 17,245' MD / 5288' TVD CCAELUS CAELUS NATURAL RESOURCES ALASKA LLC. REPORT DATE: 4172019 Alar. REPORT NUMBER: 132 Well Name: ODST-47 Alaska Wells Report Field Name R%4fJJI'M OOOGURUK 50403-20660-00-00 8/15/2012 17,191.0 real AFE I Sup(Co) Safety Summary Field Estimate Job Cost Summary HSE l-eem Yes rii IncWenl Rama. Spill 1- SLB Coiled Tubing pack off was not cleaning the pipe efficiently while pulling out of hole and drips began falling off of the coil and onto the pad. ACS quantified the fluid at 1 quart. The pack off was pressured up form 1200 to 1500 psi antl the pipe was then being cleaned and dry while POOH. Coe Ty p Reld Bl(Caetl CWC 1,214,639.18 um Daily Summary Day Told cpm ro Dale Ico¢p 10,326.00 1 421,159.18 Spill 2- Upon the RDMO of SLB Cement the pump unit was down on Meice pad. A diesel fuel line burst on the power pack of the unit and filled me sump inside of the engine room. Upon the sump being filled up there was a bolt hole that had been drilled to mount the stairs to enter the unit. Diesel was dripping from the bolt hole. A duck pond was immediately plait under the leak. ACS quantified the spill at 1 cop of diesel out of containment. RoltRB1ememlaoto¢avonl 220 Daily Contacts . era¢mm rna Chad Gueco Wells Supv Dally Oparallons opeme¢n¢.wepvnrme Ek Wilson Wegs supe, HES Slickline to pull OV & set eY FXE SSSV. Personnel Log opention¢summa, 00:00 416119-00,00 417/19 ICT Torok P&A) • Squeeze 200 bola of cement into the formation and lay in 9 bible in the lateral tubulars. Contaminate the cement with 20 Dols of Barazan 0 on top of cement. • Top of cement at 12,223' am. Cement in place at 0&10 am. conpaq Colin Well Solutions In 2 Halliburton Energy Services 5 Little Red Services Inc 3 SCHWNTERSER MCHNMmY colla 8 • Freeze protect the TBG from 4000' chin to surface with 60 able of diesel. • Pump 1.13" ball all the way through the wiled tubing on surface to flush any trace of cement in coil. • Discuss plan f0i w/Anchorage team. Decision to RDMO SLB CT and MIT -Tubing to 3000 psi @ 1100 pm ager cement has set. Alaska Crane 2 W EATHERFORD US LP 1 ' RDMO SLB Coiled tubing. Baker Hughes, Inc. 1 • 23:05 pm: LRS performed MIT -Tubing to 3000 psi for 30 minutes. MIT -Too lost 78 os' the first 15 minn, lost 26 Dv the quld Summary 2ntl 15 min. Total P. so.TToss iS4 pal � 10 %of test pressure. • MIT passed on first attempt. Cement Plug is Abandon of Torok is successful. RDd cu. weal (W len m mw.ar (cut ' Begin moving SLB Coiled Tubing & support equipment over to ODSN-03i. R.mmb 00.00-06 00 4/7119 • Standby for HES Slickline to pull OV & set 4.5" FXE SSSV I fga Riu Tye 01alet n¢Nm Repoli'mad HES Sideline to pull OV & set 4.5" FXE SSSV. Complete well handover from Wells to Ops. Rq alert Dee Rig ftNene Dare Time Log start rime End nme I D. mr) I ngmtipn Crim Do 00 06:00 6 Continue Torok PBA. • 00:30 Re -rig micro motion in hardline to read down and up coil and back to return lank. - 00:59 Install choke in return line so we can maintain bad pressure 1:1 returns if we reverse out cement from and. • 01.08 SLB re -pressure tested hardline to 4000 psi. ` 01:23 Pump 4 bible of warm diesel down coil for warm interface. Coil volume = 43 bola • 01:30 SLB cement online down it w/10 bible fresh water until MM reads 60 degrees. sit & PT lines to 4500 psi. Begin hatching 13.3 Me G cement. ••'Thickening time 10:12 am, Tag time 14 hrs 46 min after cement is in place ••• • 01:47 Starting treating pressures - WHP: 695 psi, Circ: 703 psi, IA: 22 psi, OA. 491 psi. • 01 53 SLB online down mil w/13.3 to G cement @.5 bpm. Density MM 13.54. • 02:30 Depth'. 12,800'0m, 24 bible of 13.3 Ib G cement down coil @.7 bpm. WHP: 1830 psi, Circ: 4030 psi, 11 22 psi, OA: 494 psi. • 02:55 Depth: 12,800' dm. 43 bola away, Cement I@ nozzle. WHP1917 psi, Ciro: 4179 psi, IA' 22 psi, 01 501 psi, Rate .7 bpm. • 03:38 Depth: 12,800' dm. 73 bible cement away, 30 bola out the nozzle. WHP: 2195 psi, Circ: 4120 psi, IA: 23 psi, OA: 525 psi, Rate .7 bpm. • 03:55 Weight check 25k ® 12,795'0m. • 04.15 Depth: 12,800 dm. 100 bible mment away, 57 bible out the nozzle. WHP: 1996 psi, Circ: 4004 psi, IA: 23 psi, OA: 539 psi, Rate: .8 bpm. • 05:05 Depth: 12,797' dm. 135 bible of cement away, 92 ails out the nozzle. WHP. 2007 psi, Circ'. 4277 psi, IA. 23 psi, 01 556 psi, Rate. .7 bpm. ` 05:15 Move pipe to verify cement Is dear, pu weight 25k. • 05:30 Depth: 12,792' can. 153 bola of cement away. 110 mils cement out the nozzle. WHP: 1956 psi, Cim: 4140 psi, IA. 23 psi, OA. 631 psi, Rate .7 bpm. Page 113 CC- CALLUS CAELUS NATURAL RESOURCES ALASKA LLC. G1.15:: Well Name: ODST-47 Alaska Wells Report Time Log Ste Tim I tMe Mr IMI Comizon Cam 06:00 woo 3 Coil Continue Torok PBA. • 06:30 Depth. 12,788cm. 200 bble of cement away, 157 tints cement out the nozzle. WHP: 1959 psi, Cim: 4145 psi, IA. 23 psi, OA: 631 pa, Rate .7 bpm. 06:31 Swap to freshwater from the Cementing unit pumping down the well. • 06:45 Swap over to Barazan D pill. Pump a total of 20 bole into the wit to contaminate the cement. • 07:22 Shut down on pump. Swap micro motion to returns on backside of coil to begin laying in all cement in lateral at 1 for 1. 9 plods of cement left in wiled tubing, 20 bola of bbls of barazin d in wil. ` 07:33 Prep to begin laying in cement to 12,200' while taking returns. 1 for 1. ` 07.36 Return line form WHIP is frozen, reconfigure to enable returns. • 07:54 Back online. Pushing returns to the 212 at 1 for 1. Lay in cement from 12,800 to 12,200. 9 bbls. Ensure the micro motion is in line to monitor the return rate. WHIP: 2058 psi, Circ 4220 psi, W: -10 psi, 01 648 psi, Rate: .7 bpm. taking returns at .7 bpm. PUW - 25.3K. • 07:59 Lay in cement at 1 for 1 returns plus displacement. WHIP -2009 psi, dirt - 2167 psi. POOH at 46 fpm. Pumping at 82 taking returns at 7 bpm. Cement in place at 08:10. All cement in place, top of moment 12,223' Gm. PUW falls off from 25.3K to 21.9K once out of top of cement and all cement is out of nozzle. Good verification of top of cement. ` 08'.19 RIH to top of cement to begin laying in 20 bible of Barazan D to contaminate. Begin laying in cement at 12,223'dm. Take 1 for 1 returns plug displacement of pipe. POOH at 35 torn while laying In Barazan D at .7 bpm. • 09:07 All 20 bbls of Barazan D out of coil at 10,915 ctm. POOH at 50 fpm while trickling in diesel down the coil to fulfill pipe displacement. Total pipe displacement is 18 bola to surface. WHP'. 1261 psi. Cim: 1350 psi. IA: -11 psi, OA: 647, PUW -21 6K MOO 18:00 9 Coil Continue Torok PBA. ` 09:56 LRS rigged up to pump down the wiled tubing. Pumping at .1 bpm to ensure displacement of coiled tubing is pumped while POOH at 50 fpm. WHP: 618 psi, Circ: 755 psi, IA: -12 psi, OA: 638 psi, Rate: 0.1 bpm. taking no returns, well shut in. PUW-16,3K. • 12:04 LRS begin pumping at .65 bpm while taking .6 bpm in returns from wellhead to freeze protect the TBG. Depth -4000' Gm, WHP: 1262 psi, Circ 1350 psi, IA: -11 psi, OA: 621 psi, Rate .7 bpm. laking returns at.7 bpm. PUW - 3.3K POOH laying in a 60 bbl freeze protect. ` 14:36 Well freeze protected to 4000' MD (2600' TVD). On surface with wiled tubing. Close swab valve. Holding 1800 psi on well. • 14:55 Pop off of the well head and break do" the BHA, Dnll a hole in the wiled tubing just above the connector and install a nozzle. Stab back onto the well. • 15:24 Load a 1.13" ball to drift the wit to ensure all cement is cleared from the will. Pump 45 bible of diesel, 16:28 Pop off of the well and confirm that the ball Is retrieved. Coil drilled, • 16:45 Begin RDMO of coiled tubing as per ANC team. • 14hr 46min wait time to P/T cement. P 8 A cement will be able to test at 22'.45 on 4.6-19. 17:30 1.75" Coiled tubing un stabbed form the injector head, Continue to RDMO Coiled Tubing. 1800 0000 6 Coil RDMO SLB CT. MIT -Tubing to test cement. -1 BAS Discuss plan forward wlAnchorage team. Decision to ROMO SLB CT and MIT -Tubing to 3000 psi @ 1100 pm after cement has set. • 18:30 SLB continue ng down activities. Unstab BOP stack a flow cross from well and marsh tree cop flange. `20:00 Break down at 2" 1502 hardline an ground 8 prep equipment to move over to ODSN-03i. 20'.30 Standby to MIT -Tubing to 3000 psi as per anchorage team. • 23:05 LRS performed MIT -Tubing to 3000 psi for 30 minutes. Starting pressures: T-3013 psi, W-0 psi, CA .585 psi, 15 min pressures: T -2935 psi, IA -0 psi, OA - 585 psi. Tog lost 78 psi. • 30 min pressures: T-2909 psi, IA- 0 psi, OA- 585 psi. Tbg bet 26 psi. •ressu MIT-Tbg4 78 psi the first 15 min, lost 26 psi 91e 2nd 15 min. Total Pressure loss psi o 10% of test pressure. MIT passed on first attempt. p g SI Begin moving SLB Coiled Tubing 8 support equipment over OOSN43i. Mandrel Inserts en I v Type Ren Dib do (o) PwtSheenl Lakh Tyq tom 4 Dome 4/18/2013 1 1I4 BK -2 3 Dame 4/18/2013 1 1/4 BK -2 2 Dome 4/18/2013 1 1/4 BK -2 1 ORIFICE 4/18/2013 11 5/18 BK -2 Upper Completion sib page(.. n IT Run Dare SLina My ... Ip Onl smneareae Aper Coral ..92. Upper Completion 11,986.4 4,992.9 10/4!2012 412 3.920 P-110 Upper Canpbnion Tubing Tally nem nmpon OD Nommel lint ID(m Top eon Vn r VG Frac Hanger 41121 3.920 37.2 Ibm ommon OD Nomlmlenl IDlln) Top peplM1l 1 HES X%OSVLN w/3.813" 41/2 3613 2.409.6 ryem peunPS Op NcmlW lel ID (nl op Deplalal(61 4.5 X 1" Vanoii GLM 4 4 w/ Dome 4 12 3.920 2,674.3 Item Deeonyan ODNamin Iln) IDlip TaP0aga1nia HES 3.813" "X" Nipple 4 12 3.813 2.775.8 Page 2/3 REPORT DATE: 417/2019 REPORT NUMBER: 132 CCAELUS CAELUS NATURAL RESOURCES ALASKA LLC. REPORT DATE: 4/8/2019 4ie.nd Alaska Wells Report REPORT NUMBER: 1333 Well Name: ODST47 FieldName ppLWtll Spud Ord Toad Dean coup) Total AFE I sup l Coat) 00 GURUK 50-703-20660-00-00 Bit 52012 1],191.0 Safety bummary Fleur Estimate Job Cost Summary RSE inaeem NSElwdam RameM cow 1 paid E&(coup CWC 1,214,639.18 Dairy ons maa)Rep operaoon rme .p., Dally Summary ryround rycoat) Cun aDaro (curry 1.348 877.18 Operadara s....r, 00:00 4 - 00:00 4/8/19 (CT Torok P&A7 Polop .000eloo Lwan.o) HES ' MIRU HES SIL to secure the after the P8 Awas 4 0 Dally Contacts • Attempt drift and nip the XN nipple ring, Tag 3.80" gauge ring. Tag at 2703'slm. POOH antl inspect tools. with C forwent. • Consult with the ANC team on a plan3.50"cdod rme ' Brush the nipple at MD w/ 3.50" cent and brush. us. Chad Guem Wells Supv comes ' es back t0 surface with small face me amount of cement in brush. Decision Is made not to put a SSSV in the well. Personnel Log DDD Contact to GES set a BPV in the wellhead. co cpgm M ' RDMO HES SIL offthe well, Inc. Well Solutions Inc. 1 • Bleed the TBG. IA and OA to 0 psi. an Remarks HaUlDmOn Energy Services 3 00'.00 - 06:00 418/19 Fluid Summary Operations NeatRepon PeriM Com ro was puna 1 oan Lowncau.nAl Time Log Rigs said ams ad Ines I our mr) I Opemgad Cam 00:00 06.00 6 WT No Wellwork ASSuity. Rig rvce I • Daylight SIL crew only. 06'.00 12:00 6 WT Na rk Activity. Bladen Dare Ig RNeefe Dale ' Daylight BIL crew only. 1200 0000 12 Slickline Post Torok P&ASIL program ' 06:00 MIRU HES SIL to secure Ne well after the P&A was completed. • 07:30 Attempt to drift and to the XN nipple w/ a 3.80" gauge Mg. Tag at 2703'sim. POOH and inspect tools. ' 08:00 Consult with the ANC team on a plan forward. ' 09:00 Brush the XXO nipple at 2410' MD w/ 3.50" cent and 4.5" brush. • 10:00 Brush comes back to surface with small amount of cement in brush. Decision is made not to put a SSSV in the well. Contact GE to set a BPV in the wellhead. ' 1100 RDMO HES SIL o8 of the well. ' 18:00 Bleed the TBG, IA and OA to 0 psi. Mandrel Inserts SM ws"'T"" Run"S' CD Im) PM B¢e lin) Lartli Type C. 4 Dome 4/182013 1 1/4 BK -2 3 Dome 14118MO13 11 1/d BK -2 2 Dome 141181203 11 1/4 BK -2 11 ORIFICE 14MIN2013 1 5118 BK -2 U rcom Mon Tudne Deacnpnon att DepM er Depth (.. Run Dab Slnng My N.. IOlin) SYnrg Grede Upper Completion 11.986.4 4,992.9 10/42012 47/2 3.920P-110 U rCompieflon Tubing Tally nem oD Nominel Gm ID (an) rop Degn (IY Free a VG Frac Hanger 37 412 3.920 3].2 Item peaxnPoan OD Nmmin rD(i.) a (nl p MInKBI HES XXOSVLN w/3.813" 412 3.813 2,409.6 lo—Deeangan 7o No.ewon) IDI..1 Tapoam va.) 4.5 X 1" Vanoil GLM Al 4 w/ Dame 4 112 3.920 2,674.3 in. Deun(mon pO Namiiul(in) IDe) Tap DepM (IIKB) HES 3.813" "X" Nipple 41/2 3.813 2,775.8 kem xnpdon ODNemina!(in) ID(p Top DegnnlK ) 4.5X1"Vanoil GLM #3 wl Dome 412 3.865 5.579.9 Iran Daeplon U.N—nm on To (in) T., Oagn lN<Bn 4.5X1"Vanoil GLM#2w/Dome 412 3.920 8,595.3 Ilam Onnomoan ODNominY(n) To Top OepM lnKB) 4.5 X 1" Vano)I GLM # 1 w/ Onfice 4112, 3.920 10,944.3 Ile. D—apron co Nominal (in' ID lin) Top lo."plKB) HES 3.813" "XN" Nipple .13.725 No -Go 4 12 3.920 11,044.9 nem Dp11- DD NamM.l(in' ID nn) op Degn HES ROC Gauge 412 3.920 11 848.7 nem Oeeapdon OD Nomnal(nl mlinl Tap Dean nlKal 81-1119247 Locator Sub 512 3.870 17,947.0 11. D.eanpoon ODNamiw(nn midi rapoegnllIXBl BHI G1311416 Seal Assembly 4.74 3.860 11,948.] nem Dee own oD Noinnel lint ID 1M1 rop DegnlnK ) BHI Self Aligning Mule Shoe 4 114 3.820 11.983.1 Page 1/1 CCAELUS CAELUS NATURAL RESOURCES ALASKA LLC. REPORT DATE: 417/201 1 A(asn.. REPORT NUMBER: 132 Well Name: ODST-47 Alaska Wells Report Upper Completion Tubing Tally em--on01lon ODNamina (n) ID(ip Top Degn(va) 4.5X1"VanoiI GLM#3w/Dome 41/2 3.865 5,579.9 nem—no"n OD NommN(inl Io tm1 TappaplM1 (In(BI 4.5X1"VanoiI GLM w/Dome 8112 3920 8,595.3 nem oaecnppm pO NwMM (ip ID(p rop Degn(ne6) 4.5X1"VanoiI GLM#1 w/Onece 41/2 3.920 10,944.3 Ium Dexnrtian pDNamini(Inl To (in)- Til Oegn(KK ) HEB 3.813" "XN" Nipple w/ 3.725 No{io q 12 3.920 11,044.9 nem D..ail#en oD Nomma(m) m(m) op p.pn0o) HES ROC Gauge 412 3.920 11,848.7 Ikm ¢amyl on o NnmirT U7 rop Degn mna) BHI 19247 Locator Sub 51/2 3.870 11,947.0 rom Deeenpeon oD Nomma(m1 ID h1 Toppepm (Nral BHI GBHJ6 Seal Assembly 4.74 3.860 11,948.] Item Oaunµon ODNmtirul(in Ip(in) Topp>y1i (ryKB) BHI Self Aligning Mule Shoe 4 1/4 3.820 71.983.1 Page 313 ODST-47 Cement Job Pressure Test 4/9/2019 7:07:09 AM /s/17 gga a t. wsa.ea.. 1 o fm see.xcs� tmmox .&.+X X50.0 .n L'.5 LR ODST-47 Combo MIT-T---MIT-IA 4/9/2019 7:18:00 AM Pioneer Natural Resources Alaska Inc. ODST-47 Page 3 AOGCC Form 10-407 Well Completion or Recompletion Report and Log Packer Set (MD/TVD), Box #25 - Attachment ZXP Liner Top Packer MD TVD 11,938' 4989' ECP Packers MD TVD 12,543'- 12,567' 5027'-5028' 12,586' - 12,609' 5029'- 5030' 13,083'- 13,106' 5059'-5061' 13,544'- 13,567' 5092'-5094' 14,088' - 14,111' 5131' - 5133' 14,876'- 14,899' 5157' - 5157' 15,150' - 15,174' 5161'- 5161' 15,778'— 15,801' 5174'— 5175' 16,302'— 16,325' 5199'— 5201' 16,951'— 16,974' 5255'— 5257' HALLIBURTON DIRECTIONAL SURVEY REPORT Pioneer Natural Resources Inc. ODST-47 Oooguruk North Slope Borough Alaska U.S.A. AK -XX -0009646431 Measured Depth (feet) Inclination (degrees) Direction (degrees) Vertical Depth (feet) Latitude (feet) Departure (feet) Vertical Section (feet) Doglel (deg1106 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 42.70 0.00 0.00 42.70 0.00 N 0.00 E 0.00 0.00 100.00 0.11 64.97 100.00 0.02 N 0.05 E -0.03 0.19 171.00 0.40 315.08 171.00 0.23 N 0.06W -0.22 0.63 264.00 0.44 255.05 264.00 0.37 N 0.64 W -0.28 0.45 358.00 1.89 210.71 357.98 1.06S 1.78 W 1.28 1.71 451.00 3.51 211.62 450.87 4.80S 4.05 W 5.27 1.74 544.00 5.46 208.60 643.58 11.11 S 7.66 W 11.99 2.11 639.00 7.91 210.76 637.93 20.70S 13.17 W 22.19 2.59 734.00 12.26 215.94 731.44 34.49S 22.44 W 37.03 4.67 782.28 13.76 214.78 778.48 43.36S 28.72 W 46.62 3.15 875.78 16.04 216.00 868.83 62,94S 42.66 W 67.80 2.46 969.78 16.82 215.04 958.99 84.69S 58.10 W 91.21 0.88 1067.02 20.21 214.09 1051.18 110.02S 75.60 W 118.64 3.50 1161.88 22.52 214.98 1139.52 138.48S 95.20 W 149.33 2.46 1254.24 24.14 215.06 1224.33 168.438 116.19 W 181.68 1.75 1350.56 30.42 214.70 1309.89 204.648 141.41 W 220.77 6.52 1444.77 32.61 215.53 1390.20 244.91S 169.75 W 264.28 2.37 1541.16 34.97 215.58 1470.30 288.62S 200.92 W 311.46 2.45 1636.79 40.08 214.12 1647.71 337.33S 234.85 W 364.14 5.31 1733.51 42.50 214.36 1618.87 388.99S 270.02 W 419.81 2.56 1825.98 48.08 215.94 1683.90 442.68S 307.87 W 477.82 6.15 1919.22 49.35 218.14 1745.43 498.59S 350.08 W 538.58 2.24 2015.43 49.63 216.13 1807.93 556.908 394.23 W 601.97 1.61 2110.98 52.96 216.29 1867.67 617.058 438.28 W 667.18 3.49 2206.27 58.17 215.29 1921.53 680.79S 484.20 W 736.18 5.54 2301.76 57.21 216.94 1972.57 745.99S 531.76 W 806.83 1.77 2395.81 60.42 216.14 2021.27 810.63S 579.65 W 876.97 3.49 2491.80 60.39 214.38 2068.68 878.78S 627.84 W 950.63 1.59 2587.25 61.51 213.68 2115.02 947.93S 674.53 W 1025.09 1.34 2681.99 60.95 214.67 2160.62 1016.64S 721.17 W 1099.11 1.09 2778.62 66.38 214.91 2203.47 1087.73S 770.57 W 1175.84 5.62 2871.73 70.07 213.98 2238.01 1159.03S 819.46 W 1252.71 4.07 2968.21 70.18 216.42 2270.81 1233.16S 871.76 W 1332.82 2.38 3059.04 72.38 215.92 2299.96 1302.60S 922.52 W 1408.09 2.48 3154.76 70.65 215.97 2330.31 11376.10S 976.81 W 1487.69 1.81 3249.09 72.83 215.06 2359.87 1449.01 S 1027.84 W 1566.55 2.49 3341.91 71.59 213.67 2388.23 1521.96S 1077.73 W 1645.19 1.95 3438.78 70.91 212.79 2419.36 1596.69S 1128.00 W 1727.61 1.11 3533.72 73.64 212.34 2448.27 1674.89S 1176.67 W 1809.33 2.91 3629.82 75.15 212.19 2474.12 1753.16S 1226.08 W 1893.18 1.58 3723.24 72.10 213.49 2500.45 1828.46S 1274.67 W 1973.98 3.53 3817.07 72.14 213.29 2529.26 1903.02S 1323.81 W 2054.12 0.21 3913.27 73.20 213.63 2557.91 1979.63S 1374.45 W 2136.48 1.15 4007.24 73.43 213.77 2584.89 2054.52S 1424.39 W 2217.04 0.28 4100.35 73.00 213.34 2611.78 2128.808 1473.66 W 2296.92 0.64 4198.36 73.18 212.94 2640.29 2207.32S 1524.93 W 2381.26 0.43 4292.16 73.52 212.40 2667.17 2282.97S 1573.43 W 2462.40 0.66 4388.61 72.14 212.87 2695.64 2380.57S 1623.13 W 2545.62 1.50 4480.68 72.25 213.30 2723.79 2434.02S 1670.98 W 2624.49 0.46 4576.31 72.46 213.45 2753.39 2511.71S 1722.16 W 2708.00 0.26 4673.80 72.34 213.21 2782.26 2587.76S 1772.17 W 2789.72 0.27 4766.95 72.27 213.34 2810.57 2661.96S 1820.86 W 2869.44 0.15 4862.14 72.10 213.16 2839.70 2737.75S 1870.55 W 2950.86 0.25 4959.42 72.15 213.53 2869.55 2815.09S 1921.44 W 3033.98 0.37 5054.11 72.86 213.69 2898.02 2890,30S 1971.43 W 3114.87 0.77 5149.99 71.87 214.84 2927.07 2965.818 2022.88 W 3196.25 1.54 5244.13 72.04 214.87 2956.23 3039.27S 2074.03 W 3275.54 0.18 5339.52 72.47 214.91 2985.30 3113.79S 2126.00 W 3355.99 0.45 5428.02 71.65 215.66 3012.56 3182.52S 2174.63 W 3430.28 1.23 .AGo 71 71 7C 71, 1nll CC "no .R 0 7107 471./ 1 .. 94 4 7A 5554.17 71.13 215.67 3053.09 3279.54S 2244.33 W 3535.28 0.15 5646.73 70.81 215.64 3083.92 3362.17S 2296.44 W 3613.88 0.34 5744.43 71.47 215.94 3114.86 3425.63S 2349.40 W 3693.41 0.75 5839.23 71.85 216.00 3144.69 3498.46S 2402.25 W 3772.29 0.41 5934.42 71.45 215.72 3174.66 3571.68 S 2455.18 W 3851.58 0.50 6029.29 71.97 213.69 3204.43 3645.73S 2506.46 W 3931.48 2.10 6124.45 71.01 213.48 3234.64 3720.90S 2556.38 W 4012.32 1.03 6218.22 71.65 213.98 3264.66 3794.78S 2605.71 W 4091.81 0.85 6314.56 71.86 213.96 3294.82 3870.66S 2656.83 W 4173.51 0.22 6408.08 71.45 213.65 3324.25 3944.42S 2706.22 W 4252.88 0.54 6504.75 71.08 214.26 3355.30 4020.36S 2757.35 W 4334.63 0.71 6599.67 71.45 215.30 3385.79 4094.19S 2808.63 W 4414.32 1.11 6694.15 71.80 213.81 3415.58 4168.03S 2859.48 W 4493.96 1.54 6788.99 71.65 214.25 3445.32 4242.67S 2909.88 W 4574.33 0.47 6883.97 71.45 215.07 3475.38 4316.77S 2961.12 W 4654.28 0.85 6978.59 71.51 215.40 3505.43 4390.06S 3012.88 W 4733.48 0.34 7073.30 71.78 214.62 3535.26 4463.68S 3064.45 W 4812.99 0.83 7169.00 71.66 214.69 3565.27 4538.43S 3116.12 W 4893.64 0.14 7264.23 71.53 213.69 3595.34 4613.178 3166.90 W 4974.16 1.01 7359.68 71.46 212.62 3625.64 4688.95S 3216.40 W 5055.55 1.07 7454.65 71.14 212.44 3656.09 4764.79S 3264.77 W 5136.87 0.38 7549.81 71.25 211.76 3686.76 4841.10S 3312.64 W 5218.58 0.69 7644.91 71.52 211.85 3717.12 4917.69S 3360.14 W 5300.53 0.30 7740.12 71.58 211.42 3747.25 4994.59S 3407.51 W 5382.76 0.43 7834.54 71.26 213.03 3777.34 5070.30S 3455.23 W 5463.86 1.65 7929.83 71.46 214.00 3807.79 5145.68S 3505.09 W 5544.80 0.99 8023.48 70.99 214.29 3837.93 5218.96S 3554.85 W 5623.85 0.58 8118.06 71.80 214.39 3868.11 6292.978 3605.42 W 5703.62 0.86 8211.76 70.93 215.95 3898.05 5365.55S 3656.56 W 5782.05 1.83 8308.73 71.34 216.73 3929.41 5439.47 S 3710.93 W 5862.20 0.87 8403.17 71.79 216.15 3959.27 5511.54S 3764.15 W 5940.38 0.75 8499.15 71.46 216.49 3989.53 5584.93S 3818.10 W 6019.96 0.48 8594.07 71.52 215.26 4019.66 5657.86S 3870.84 W 6098.94 1.23 8688.91 71.27 214.10 4049.92 5731.78S 3921.99 W 6178.69 1.19 8783.13 72.05 214.44 4079.57 5805.68S 3972.35 W 6256.33 0.90 8879.15 71.40 214.90 4109.68 5880.67S 4024.21 W 6339.24 0.82 8975.74 71.66 214.51 4140.28 5955.99s 4076.37 W 6420.50 0.47 9070.93 71.21 214.23 4170.59 6030.47S 4127.31 W 6500.79 0.55 9165.49 72.12 213.17 4200.33 6105.14S 4177.11 W 6581.12 1.43 9260.65 70.80 213.53 4230.59 6180.51 S 4226.71 W 6662.12 1.43 9352.42 71.72 214.06 4260.07 6252.73S 4275.05 W 6739.83 1.14 9448.84 71.33 214.01 4290.63 6328.51S 4326.23 W 6821.44 0.41 9545.11 70.61 214.23 4321.86 6403.90S 4377.31 W 6902.64 0.58 9640.59 71.20 214.32 4352.94 6478.50S 4428.15 W 6983.04 0.42 9735.28 72.11 214.97 4382.74 6552.44S 4479.25 W 7062.80 1.16 9830.61 72.17 213.63 4411.98 6627.40S 4530.38 W 7143.58 1.34 9925.56 72.49 212.70 4440.80 6703.13S 4579.87 W 7224.93 0.99 10020.33 71.39 213.37 4470.18 6778.66S 4628.99 W 7306.03 1.34 10115.67 71.27 213.76 4500.70 6853.93S 4678.92 W 7386.96 0.41 10210.87 71.47 213.74 4531.11 6928.938 4729.04 W 7467.67 0.21 10305.60 71.47 214.36 4561.21 7003.35S 4779.33 W 7547.81 0.62 10400.87 70.82 214.31 4592.00 7077.80S 4830.19 W 7628.05 0.68 10495.17 71.39 214.33 4622.54 7151.49 S 4880.49 W 7707.47 0.60 10591.16 70.87 215.29 4653.59 7226.06S 4932.34 W 7787.96 1.09 10684.50 71.66 216.50 4683.57 7297.678 4984.16 W 7865.50 1.49 10780.24 71.70 215.51 4713.66 7371.19S 5037.59 W 7945.15 0.98 10874.41 71.34 214.22 4743.51 7444.47S 5088.65 W 8024.26 1.35 10965.44 71.71 213.78 4772.36 7516.05S 5136.93 W 8101.33 0.61 11066.02 72.81 211.97 4803.01 7596.50 S 5188.92 W 8187.67 2.03 11161.06 75.91 207.52 4828.64 7675.948 5234.28 W 8272.18 5.56 11255.85 75.96 202.30 4851.69 7759.31 S 5273.00 W 8359.75 5.34 11350.84 76.09 196.42 4874.65 7846.23S 5303.54 W 8449.81 6.01 11446.01 76.41 192.97 4897.27 7935.638 5326.98 W 8541.45 3.54 11541.30 76.92 190.18 4919.26 8026.46S 5345.58 W 8633.90 2.90 11636.48 77.86 188.26 4940.04 8118.14S 5360.46 W 8726.72 2.20 11731.24 79.26 183.76 4958.84 8210.48S 5370.17 W 8819.55 4.88 11826.64 81.38 180.84 4974.89 8304.43S 5373.94 W 8913.23 3.75 11921.58 83.69 177.24 4987.22 8398.53S 5372.35 W 9006.38 4.48 12015.78 85.92 173.21 4995.76 8491.99S 5364.64 W 9098.13 4.87 12111.51 66.60 169.45 5002.00 8586.41S 5350.14 W 9189.99 3.98 12205.25 87.41 168.31 5006.90 8678.268 5332.09 W 9278.85 1.49 12283.73 87.90 169.04 5010.11 8755.15S 5316.69 W 9353.19 1.12 12379.24 86.30 165.83 5014.94 8848.23S 5295.94 W 9442.94 3.75 12478.18 85.30 164.11 5022.19 8943.53S 5270.36 W 9534.27 2.01 12569.25 87.53 162.62 5027.89 9030.588 6244.26 W 9617.36 3.01 12671.20 86.60 159.31 5033.11 9126.79S 5210.98 W 9708.63 3.27 12768.08 87.29 156.88 5038.27 9216.54S 5174.89 W 9793.14 2.60 12862.83 85.68 151.97 5044.08 9301.82S 5134.08 W 9872.63 5.44 12959.88 86.67 148.38 5050.56 9385.81 S 5065.93 W 9949.91 3.83 13055.06 85.43 144.84 5057.12 9465.08S 5033.68 W 10022.00 3.93 13151.94 87.22 143.35 5063.33 9543.38S 4976.99 W 10092.56 2.40 13247.90 86.67 140.45 5068.44 9618.78S 4917.87 W 10159.95 3.07 13343.76 84.81 139.07 5075.56 9691.75S 4856.12 W 10224.59 2.41 13441.38 85.86 139.01 5083.50 9765.22S 4792.34 W 10289.48 1.08 13534.61 85.06 138.32 5090.88 9835.01S 4730.96 W 10351.00 1.13 13634.00 85.92 137.27 5098.70 9908.40S 4664.40 W 10415.46 1.36 13730.33 86.91 137.05 5104.72 9978.89S 4599.03 W 10477.20 1.05 13826.75 85.80 135.82 5110.85 10048.62S 4532.71 W 10536.04 1.72 13921.15 85.43 137.26 5118.07 10116.93S 4467.97 W 10597.70 1.57 14020.24 85.30 137.91 5126.08 10189.85S 4401.35 W 10661.67 0.67 14115.86 85.67 138.32 5133.60 10260.826 4337.71 W 10724.09 0.58 14212.66 88.27 138.28 5138.72 10332.98S 4273.41 W 10787.62 2.69 14304.32 88.46 139.75 5141.34 10402.15 S 4213.32 W 10848.69 1.62 14403.11 87.66 139.94 5144.68 10477.618 4149.66 W 10915.57 0.83 14497.59 88.71 140.60 5147.67 10550.23S 4089.30 W 10980.04 1.31 14595.80 88.77 140.54 5149.83 10626.07S 4026.94 W 11047.45 0.09 14689.83 88.58 139.78 5152.01 10698.25S 3966.71 W 11111.50 0.83 14788.65 88.40 141.33 5154.61 10774.53S 3903.95 W 11179.31 1.58 14885.21 89.08 142.08 5156.73 10850.30 S 3844.13 W 11246.96 1.05 14979.04 89.33 140.80 5158.04 10923.66S 3785.65 W 11312.41 1.39 15077.72 88.89 140.10 5159.57 10999.74S 3722.82 W 11380.00 0.86 15173.22 89.51 138.61 5160.90 11072.19 S 3660.62 W 11444.07 1.69 15269.55 88.58 138.25 5162.51 11144.25S 3596.72 W 11507.54 1.04 15365.29 89.33 137.88 5164.25 11215.46S 3532.74 W 11570.16 0.87 15458.93 89.02 136.87 5165.60 11284.35S 3469.34 W 11630.55 1.13 15557.53 69.94 136.76 5166.50 11356.24S 3401.87 W 11693.40 0.94 15656.20 87.47 134.65 5168.73 11426.848 3332.99 W 11754.79 3.29 15750.16 87.29 134.72 5173.02 11492,84S 3266.25 W 11811.90 0.21 15841.68 87.97 135.69 5176.81 11557.73S 3201.83 W 11868.19 1.29 15938.50 87.66 137.43 5180.50 11627.98S 3135.30 W 11929.53 1.82 16039.08 86.29 139.32 5185.81 11703.05S 3068.59 W 11995.64 2.32 16136.81 87.22 140.03 5191.34 11777.44S 3005.45 W 12061.51 1.20 16233.43 87.72 139.63 5195.60 11851.20S 2943.19 W 12126.88 0.66 16327.51 85.74 138.56 5200.97 11922.18S 2881.69 W 12189.58 2.39 16424.86 85.74 138.96 5208.20 11995.18S 2817.69 W 12253.97 0.41 16520.36 87.10 138.93 5214.17 12067.06 S 2755.09 W 12317.42 1.42 16615.84 84.93 136.36 5220.80 12138.55S 2692.16 W 12380.45 2.35 16713.42 83.26 137.98 5230.84 12210.87S 2627.43 W 12444.07 1.75 16809.44 83.69 138.54 5241.75 12282.05S 2563.92 W 12506.72 0.73 16906.15 84.93 138.10 5251.34 12353.92S 2499.93 W 12570.00 1.36 17002.19 84.93 137.82 5259.83 12424.97S 2435.87 W 12632.44 0.29 17098.86 83.44 137.00 5269.62 12495.77S 2370.79 W 12694.52 1.76 17181.44 82.57 136.26 5279.68 12555.35S 2314.50 W 12746.56 1.39 17245.00 82.57 136.25 5287.90 12600,88S 2270.91 W 12786.26 0.00 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 187.21 DEGREES (TRUE) A TOTAL CORRECTION OF 20.19 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 17245.00 FEET IS 12803.87 FEET ALONG 190.22 DEGREES (TRUE) Date Printed:27 September 2012 DATA SUBMITTAL COMPLIANCE REPORT 3/6/2017 Permit to Drill 2121030 Well Name/No. OOOGURUK TOR ODST-47 MD 17245 TVD 5288 REQUIRED INFORMATION Operator CAELUS NATURAL RESOURCES ALA API No. 50-703-20660-00-00 Completion Date 10/5/2012 Completion Status 1-0I1- Current Status 1-0I1- UIC No Mud Log I b` Samples fs�� \ �1� Directional Survey Yes V DATA INFORMATION J Types Electric or Other Logs Run: GYRO, MWD/LWD, PCDC, DGR, DDSR, DIR, ABG, EWR, PWD, BA (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 22053 Digital Data ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C 22053 Digital Data 22053 Digital Data 22053 Digital Data 22053 Digital Data 22053 Digital Data 22053 Digital Data 22053 Digital Data 22053 Digital Data 22053 Digital Data 22053 Digital Data 22053 Digital Data 22053 Digital Data Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 147 17245 12/14/2012 Electronic Data Set, Filename: T22053 Composite.las 1 1 12/14/2012 Electronic Data Set, Filename: T22053 , Geotap_Test-01.las 2 2 12/14/2012 Electronic Data Set, Filename: T22053 ' Geotap_Test-02.las 8 8 12/14/2012 Electronic Data Set, Filename: T22053' Geotap_Test-03.las 11 11 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-04.las 11 11 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-05.las 20 20 12/14/2012 Electronic Data Set, Filename: T22053 ' Geotap_Test-06.las 20 20 12/14/2012 Electronic Data Set, Filename: T22053* Geotap_Test-07.las 2 2 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-08.1as , 3 3 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-09.las 7 7 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-10.las 7 8 12/14/2012 Electronic Data Set, Filename: T22053' Geotap_Test-11.1as 8 8 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-12.las AOGCC Page I of 5 Monday, March 06, 2017 DATA SUBMITTAL COMPLIANCE REPORT 3/6/2017 Permit to Drill 2121030 Well Name/No. OOOGURUK TOR ODST-47 Operator CAELUS NATURAL RESOURCES ALA API No. 50-703-20660-00-00 MD 17245 TVD 5288 Completion Date 10/5/2012 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 22053 Digital Data 6 6 12/14/2012 Electronic Data Set, Filename: T22053 • Geotap_Test-13.las ED C 22053 Digital Data 6 7 12/14/2012 Electronic Data Set, Filename: T22053 , Geotap_Test-14.las ED C 22053 Digital Data 7 7 12/14/2012 Electronic Data Set, Filename: T22053 . Geotap_Test-15.1as ED C 22053 Digital Data 7 7 12/14/2012 Electronic Data Set, Filename: T22053 , Geotap_Test-16.las ED C 22053 Digital Data 7 7 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-17.1as ED C 22053 Digital Data 11 11 12/14/2012 Electronic Data Set, Filename: T22053 , Geotap_Test-18.las ED C 22053 Digital Data 17 17 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-19.1as ED C 22053 Digital Data 18 18 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-20.las ED C 22053 Digital Data 21 22 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-21.las ED C 22053 Digital Data 22 22 12/14/2012 Electronic Data Set, Filename: T22053 - Geotap_Test-22.las ED C 22053 Digital Data 6 6 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-23.las ED C 22053 Digital Data 6 6 12/14/2012 Electronic Data Set, Filename: T22053• Geotap_Test-24.las ED C 22053 Digital Data 15 15 12/14/2012 Electronic Data Set, Filename: T22053 . Geotap_Test-25.las ED C 22053 Digital Data 19 19 12/14/2012 Electronic Data Set, Filename: T22053 Geotap_Test-26.las ED C 22053 Digital Data 1 19 12/14/2012 Electronic Data Set, Filename: T22053 G eotap_Tests_Merg ed.las ED C 22053 Digital Data 146 17245 12/14/2012 Electronic Data Set, Filename: T22053 TC_Log_Data.las ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 2in_TC_MD.cgm ' ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 2in TC_MD.emf ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 2in_TC_MD.pdf , AOGCC ['age 2 of 5 Monday, March 06, 2017 DATA SUBMITTAL COMPLIANCE REPORT 3/6/2017 Permit to Drill 2121030 Well Name/No. OOOGURUK TOR ODST-47 Operator CAELUS NATURAL RESOURCES ALA API No. 50-703-20660-00-00 MD 17245 TVD 5288 Completion Date 10/5/2012 Completion Status 1-0I1- Current Status 1-0IL UIC No ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 2in TC MD.tiff ' ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 2in_TC_TVD.cgm ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 2in TC TVD.emf , ED C 22053 Digital Data P12/14/2012 Electronic File: T22053 2in_TC_TVD.pdf ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 2in TC TVD.tiff , ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 5in _TC_MD.cgm ' ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 5in TC MD.emf ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 5in_TC_MD.pdf ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 5in TC MD.tiff , ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 5in_TC_TVD.cgm ' ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 5in_TC_TVD.emf, ED C 22053 Digital Data R 12/14/2012 Electronic File: T22053 5in_TC_TVD.pdf, ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 5in TC TVD.tiff . ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 GeoTap_Report.pdf ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 presentation_mobility_calculation_for_4.75inch_ . GT.xls ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 Processed_Geotap.cgm ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 Processed_Geotap.emf . ED C 22053 Digital Data b 12/14/2012 Electronic File: T22053 Processed_Geotap.pdf ' ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 Processed_Geotap.tiff - ED C 22053 Digital Data 12/14/2012 Electronic File: T22053 Tests.ppt • ED C 22069 Digital Data 11/29/2012 Electronic File: T22069 2MD DEL CVE.pdf ED C 22069 Digital Data 11/29/2012 Electronic File: T22069 2MD DEL.emf ED C 22069 Digital Data D 11/29/2012 f Electronic File: T22069 2MD DEL.pdf ' ED C 22069 Digital Data 11/29/2012 Electronic File: T22069 21VID DEL.tiff - ED C 22069 Digital Data 11/29/2012 Electronic File: T22069 21VID FEL CVE.pdf ' ED C 22069 Digital Data 11/29/2012 Electronic File: T22069 21VID FEL.emf ED C 22069 Digital Data 11/29/2012 Electronic File: T22069 21VID FEL.pdf AOGCC' Page 3 of 5 Monday, March 06, 2017 DATA SUBMITTAL COMPLIANCE REPORT 3/6/2017 Permit to Drill 2121030 Well Name/No. OOOGURUK TOR ODST-47 MD 17245 TVD 5288 ED C 22069 Digital Data ED C 22069 Digital Data ED C 22069 Digital Data ED C 22069 Digital Data ED C 22069 Digital Data ED C 22069 Digital Data ED C 22069 Digital Data ED C 22069 Digital Data ED C 22069 Digital Data ED C 22069 Digital Data ED C 22069 Digital Data ED C 22069 Digital Data Well Cores/Samples Information: Name Cuttings Completion Date 10/5/2012 Interval Start Stop 5409 17245 Operator CAELUS NATURAL RESOURCES ALA API No. 50-703-20660-00-00 Completion Status 1 -OIL Current Status 1-0I1- UIC No 11/29/2012 Electronic File: T22069 2MD FEL.tiff 4011/29/2012 Electronic File: T22069 2MD GIRL CVE.pdf 11/29/2012 Electronic File: T22069 2MD GRL.emf ' 11/29/2012 Electronic File: T22069 2MD GRL.pdf . 11/29/2012 Electronic File: T22069 2MD GRL.tiff' P 11/29/2012 Electronic File: T22069 5MD FEL CVE.pdf ` 11/29/2012 Electronic File: T22069 5MD FEL.emf 11/29/2012 Electronic File: T22069 5MD FEL.pdf 11/29/2012 Electronic File: T22069 5MD FEL.tiff ` 11/29/2012 Electronic File: T22069 SDL EOW Rpt.pdf " 11/29/2012 Electronic File: T22069 SDL Final.adi - 158 17246 3/6/2017 Electronic Data Set, Filename: ODST-47 Mudlog.las Sample Set Sent Received Number Comments 10/14/2012 1360 INFORMATION RECEIVED Completion Report Directional / Inclination Data/ Y) Mud Logs, Image Files, Digital Dat NA Core Chips Y/ A Production Test Information Y NA Mechanical Integrity Test Information Y") Composite Logs, Image, Data File Y Core Photographs Y / Geologic Markers/Tops 0 Daily Operations Summary 0 Cuttings Samples Y NA Laboratory Analyses Y/ A COMPLIANCE HISTORY Completion Date: 10/5/2012 Release Date: 8/1/2012 Description Date Comments AOGCC Page 4 of 5 Monday, March 06, 2017 DATA SUBMITTAL COMPLIANCE REPORT 3/6/2017 Permit to Drill 2121030 Well Name/No. OOOGURUK TOR ODST-47 Operator CAELUS NATURAL RESOURCES ALA API No. 50-703-20660-00-00 MD 17245 TVD 5288 Completion Date 10/5/2012 Completion Status 1-0I1- Current Status 1-0I1- UIC No Comments: Compliance Reviewe Date: J AOGCC Page 5 of 5 Monday, March 06, 2017 STATE OF ALASKA ;KA OIL AND GAS CONSERVATION COMN, ION REPORT OF SUNDRY WELL OPERATIONS REL,cI ED DEC 17 2013 1. Operations Abandon Li Repair W Plug Perforations Li PerforU Other Li - Performed: Alter Casing ❑ Pull Tubic Stimulate - Frac Q Wad(] Time Extension ❑ Change Approved Program ❑ Operat. Shutdov❑ Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Pioneer Natural Resources Alaska, Inc Development ❑ Stratigraphic ❑ Explorati❑ Servo 212-103- 3. Address: 700 G Street, Suite 600 6. API Number: Anchorage, AK 99501 50-703-20660-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 355036 / ADL 355038 ODST-47 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Oooguruk - Torok Oil Pool - 11. Present Well Condition Summary: Total Depth measured 17,245 feet Plugs measured N/A feet true vertical 5,288 feet Junk measured N/A feet Effective Depth measured 17,191 feet Packer measured See Attach., pg 3 feet true vertical 5,281 feet true vertical See Attach., pg 3 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5337' 10-3/4" 5380' 2998' 5210 psi 2470 psi Intermediate1 3314' 7-5/8" 12138' 5004' 6890 psi 4790 psi Intermediate2 Liner 6182' 4-1/2" 11938' - 17191' 4989'- 5281' 11590 psi 9210 psi Perforation depth Measured depth See Attach., pg 2 feet True Vertical depth See Attach., pg 2 feet Tubing (size, grade, measured and true vertical depth) 4-1/2", 13.5# P-110, Hyd 521 11986MD 4994' TVD Packers and SSSV (type, measured and true vertical depth) 11,938' MD / 4,989" 5-1/2"x7" Lnr Tp Pkr TVD SVLN 2,410' MD / 2,028' TVD 12. Stimulation or cement squeeze summary: See attached vendor documentation Intervals treated (measured): Into Perforation Depths (see Attachment, pg. 3) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Developno • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ GSTOR ❑ WIN.❑ WAGE] GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313-052 Contact Jack Kralick Email Jack. KralickCc�gxd.com Printed Name Jack Kralick Title Well Work Supervisor Signature — Phone 343-2185 Date 1Z 13 115 Form 10-404 Revised 10/2012 !H1+ADEC 2 0 2 Submit Original Only Pioneer ._.ural Resources Alaska Inc. ODST-47 Page 2 AOGCC Form 10-404 Report of Sundry Operations Open to Production or Injection Attachment Open to production or injection 4-'/", 12.6#, P-110 Hydril 521 Uncemented Liner Frac Sleeves: MD TVD 12,699'- 12,702' 5035'- 5035' 12,857'- 12,860' 5044'- 5044' 12,973'- 12,976' 5051'- 5052' 13,201'- 13,205' 5066'- 5066' 13,317'- 13,321' 5073'- 5074' 13,433'- 13,436' 5083'- 5083' 13,662'- 13,665' 5101'- 5101' 13,778'- 13,781' 5108'- 5108' 13,935'- 13,938' 5119'- 5119' 14,284'- 14,287' 5141'- 5141' 14,483'- 14,487' 5147'- 5147' 14,682'- 14,685' 5152'- 5152' 14,975'- 14,978' 5158'- 5158' 15,049'- 15,053' 5159'- 5159' 15,123'- 15,126' 5160'- 5160' 15,310' - 15,314' 5163'- 5163' 15,467'- 15,471' 5166'- 5166' 15,625'- 15,628' 5168'- 5168' 15,876'- 15,880' 5178'- 5178' 16,034'- 16,038' 5186'- 5186' 16,191'- 16,194' 5194'- 5194' 16,483'- 16,487' 5212'- 5212' 16,599'- 16,603' 5219'- 5220' 16,757'- 16,760' 5236'- 5236' Pressure Activated Sleeves: MD TVD 17,076'- 17,079' 5267'- 5267' 17,089'- 17,091' 5269'- 5269' Pioneer Natural Resources Alaska Inc. ODST-47 Page 3 AOGCC Form 10-404 Report of Sundry Operations Packer Set (MD/TVD), Box #25 - Attachment ZXP Liner Top Packer MD TVD 11,938' 4989' ECP Packers MD TVD 12,543'- 12,567' 5027'-5028' 12,586'- 12,609' 5029'- 5030' 13,083'- 13,106' 5059'-5061' 13,544'- 13,567' 5092'-5094' 14,088' - 14,111' 5131'- 5133' 14,876'- 14,899' 5157'- 5157' 15,150'- 15,174' 5161'- 5161' 15,778'— 15,801' 5174'— 5175' 16,302'— 16,325' 5199'— 5201' 16,951'— 16,974' 5255'— 5257' Pioneer Natural Resources Treatment Summary ODST-47 - Part 1 Zones 1-4 Alaska Section 11 Township 13N Range 7E API #: 50-703-20660 Torok 25# Hybor-G March 29 2013 SO# 900262042 HALLIBURTON HALLIBURTON I Enhdncti.,, t Table of Contents Section Page(s) Cover Sheet 1 TOC 2 Wellbore Information 3 Executive Summary 4-9 Stage Summary 10 Design Worksheet 11 Fann 35 0,C 12 Lab C 13 Sand_OC 14 Treatment Plots 15-18 Chemical Plots 19-20 Net Pressure Plots 21-22 TOC Page 2 TOO Customer Pioneer Natural Resources Formation Torok Lease ODST-47 - Part 1 Zones 1-4 API 50-703-20660 Date 3/2/2013 MALLIBURTON ( Treatment Flowpat h Tubular Information Description Sleeve/Pert Depth (ft) Top Sleeve Volume Frac String 4.5" 12.6# P-110 0.6392 0 11938 ft 7,631 gal Ball Drop Time Ball Hit Time JSV Drop JSV Hit Early Seat Differential ft Displacement to ft 0 gal ft 0 gal Zone # Sleeve/Pert (gal) (BBLS) Top Btm Zone # HH:MM:SS HH:MM:SS bbl bbl bbl(psi) Peak (psi) si 5 9,572 227.9 14,975 15,124 5 4:15:42 0.6392 4 9,786 233.0 15,310 15,626 4 3:08:24 3:15:54 4697 4897 33.0 1714 4390 2676 3 10,148 241.6 15,876 16,192 3 2:14:02 2:22:35 2795 3010 26.6 2 10,536 250.9 16,483 16,758 2 2:14:02 2:22:35 16.2 324 -56.9 1809 2018 209 11 10,915 259.9 17,076 17,090 11 11:41 1 1 123 65131 6390 ( Treatment Flowpat h Tubular Information Description Tubular Size FUF (gal/ft) Top Btm Volume Frac String 4.5" 12.6# P-110 0.6392 0 11938 ft 7,631 gal Production Liner 4.5" 12.6# P-110 0.6392 11938 17191 ft 3,358 gal ft 0 gal ft 0 gal ft 0 gal ft 0 gal ft 0 gal Total 10,988 gal Completion Tubular FUF (gal/ft) 4.5" 11.6# 0.6392 Total MD 17191 ft Wellbore Information Page 3 HALLIBURTON Engineering Executive Summary On 03/02/13 a stimulation treatment was performed in the Torok formation on the ODST-47 - Part 1 Zones 1-4 well. The following information was gathered during the treatment. Sales Order #: 900262042 API#: 50-703-20660 25# Hybor G Volume: 254,646 gal 6063 bbls 25# Water Frac G Volume: 0 gal 0 bbls Freeze Protect Volume: 7,350 gal 175 bbls Total Fluid (Used): 261,996 gal 6238 bbls Clean Fluid Downhole (No Hydro or LVT): 254,646 gal 6063 bbls Carbolite 16/20 Pumped: 703,500 lbs Carbolite 20/40 Pumped: 30,000 lbs Formation: Torok Total Stim-Sleeve Zones: 9 Total Zones: 9 Net Pay Interval: 4391 ft Average Rate: 29.0 bpm Average Pressure: 4447 psi Maximum Rate: 53.4 bpm Maximum Pressure: 7607 psi Maximum Horsepower: 7579 HHP Average Visc: 19 cp Average pH: 9.3 Average Temp: 60 deg F BE -6 Pre-treated in tanks: 22 lbs (0.15 ppt) LO -65 Pre-treated in tanks: 293 gal (2 gpt) Prior to pumping the job, Quality Control tests were conducted on location to determine hydration time, crosslink time, and gel viscosity. Chemical concentrations were adjusted, as needed, according to test results, pump times, and onsite water. We appreciate the opportunity to service your well. If you have any questions about the job, or anything else, please call me at (435)-621-2192. Thank you, Johann Baltrusch Technical Professional Halliburton Energy Services Caitlin McCarthy Technical Professional Halliburton Energy Services Executive Summary Page 4 Treatment Information Executive Summary Page 5 Zone 1 Zone Summary Initial Rate (Breakdown): 1.4 bpm Initial Pressure (Breakdown): 6513 psi Max Rate: 3.7 bpm Max Pressure: 6,995 psi Average Rate: 0.4 bpm Average Pressure: 2,748 psi Max Horsepower: 463 hhp Average Visc: 19 cp Average pH: - Average Temp: 55 F Carbolite 16/20: 0 lbs Carbolite 20/40: 0 lbs Total Proppant Pumped: 0 lbs Proppant in Formation: 0 lbs 25# Hybor G Volume: 997 gal 24 bbls 25# Water Frac G Volume: 0 gal 0 bbls Freeze Protect Volume: 690 gal 16 bbls Comments: Got initial break, but could not establish injection rate. Decision was made to drop zone 2 ball; just after it past the wellhead and was marked, it looked like the sleeve opened. Brought rate up to 12 bpm to shift zone 2 sleeve. Will use 311 sacks of sand in each of the next treatments. At the end of each sand ramp, there will be a hold stage of the 311 sacks Executive Summary Page 5 Executive Summary Page 6 Zone 2 Zone Summary Initial Rate (Breakdown): 19.9 bpm Initial Pressure (Breakdown): 2652 psi Max Rate: 53 bpm Max Pressure: 6,336 psi Average Rate: 40 bpm Average Pressure: 5,456 psi Max Horsepower: 7579 hhp Average Visc: 17 cp Average pH: 9.5 Average Temp: 53 F Carbolite 16/20: 299,700 lbs Carbolite 20/40: 0 lbs Total Proppant Pumped: 299,700 lbs Proppant in Formation: 299,700 lbs 25# Hybor G Volume: 100,113 gal 2384 bbls 25# Water Frac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Comments: Executive Summary Page 6 Executive Summary Page 7 Zone 3 Zone Summary Initial Rate (Breakdown): 16 bpm Initial Pressure (Breakdown): 1994 psi Max Rate: 41 bpm Max Pressure: 6,016 psi Average Rate: 39 bpm Average Pressure: 4,989 psi Max Horsepower: 5493 hhp Average Visc: 20 cp Average pH: 9.3 Average Temp: 65 F Carbolite 16/20: 193,300 lbs Carbolite 20/40: 30,000 lbs Total Proppant Pumped: 223,300 lbs Proppant in Formation: 223,300 lbs 25# Hybor G Volume: 68,718 gal 1636 bbls 25# Water Frac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Comments: Sand bins ran out on schedule. Ran remaining 30,000 lbs of 20/40 CarboLite on the zone. Executive Summary Page 7 Executive Summary Page 8 Zone 4 Zone Summary Initial Rate (Breakdown): 14.6 bpm Initial Pressure (Breakdown): 2227 psi Max Rate: 43 bpm Max Pressure: 6,390 psi Average Rate: 37 bpm Average Pressure: 4,651 psi Max Horsepower: 5963 hhp Average Visc: 20 cp Average pH: 9.3 Average Temp: 66 F Carbolite 16/20: 210,500 lbs Carbolite 20/40: 0 lbs Total Proppant Pumped: 210,500 lbs Proppant in Formation: 210,500 lbs 25# Hybor G Volume: 80,547 gal 1918 bbls 25# Water Frac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Comments: Swapped to the ARC Mover; Bins 345 would not open. Slowed down to 10 bpm to help and shut down. Got it fixed and pumped another 1300 sacks before losing sand concentration again. Customer was fine with the amount of sand pumped. Also had to swap Downhole crosslinker around. Could not keep it running properly. Executive Summary Page 8 Executive Summary Page 9 Zone 5 Zone Summary Max Rate: 31 bpm Max Pressure: 7,607 psi Average Rate: 28 bpm Average Pressure: 4,391 psi Max Horsepower: 5124 hhp Carbolite 16/20: 0 lbs Carbolite 20/40: 0 lbs Total Proppant Pumped: 0 lbs Proppant in Formation: 0 lbs 25# Hybor G Volume: 4,271 gal 102 bbls 25# Water Frac G Volume: 0 gal 0 bbls Freeze Protect Volume: 6,660 gal 159 bbls Comments: Dropped ball for zone 5. approximately 60 bbls later, max pressure was reached and the trucks kicked out. Crew is done with this well until it is figured out what happened. Executive Summary Page 9 Customer Pioneer Natural Resources Well ODSTTorok- Paclzonesla HALLIMUPYUN P'oduction Formation Torok Enhnncamnnt Stage Summaries Interval Pressure Rate Average I Visc I Temp I pH Max Pressure Rate 25# Hybor G gal bbl 2S# Water Frac gal GFreeze bbl gal Protect bbl Total Fluid gal bbl Carbolke 16/20 lbs cruvvaa s Carbolate 20/40 lbs Total Proppant lbs 1 2748 0.4 19 55 - 6995 3.7 997 24 0 0 690 16 1,687 40 0 0 0 2 5456 40 17 53 9.5 6336 53.4 100,113 2,384 0 0 0 0 100,113 2,384 299,700 0 299,700 3 4989 39.2 20 65 9.1 6016 41.1 68,718 1,636 0 0 0 0 68,718 1,636 193,300 30,000 223,300 4 4651 37 20 66 9.3 6390 43 80,547 1,918 0 0 0 0 80,547 1,918 210,500 0 210,500 S 4391 28.38 - - - 7607 30.51 4,271 102 0 0 6,660 159 10,931 260 0 0 0 Planned Actuals Stage Summary Page 10 Customer Pioneer Natural Resources 3/2/- API 50.70-20660 Lea. ODST-47-Part l Z... 14 HALLIBURTON m"e F,.. Treatmem Imensal Stage Number Auld Deal Ion Stage Decriptlon Proppam Descrlptlan Drop cone (ppg/ Slurry Rete (bpm Design Clean Volume (god) Design Clean Volume (bbl) Stage Time kh:mmsec Pump Time kkmm- -..I Clean Volume 901 A .l Clean Volume Deign Pmp Total Na Actual Pmp CL -31 Total 16a/ pt) M667 CL -22 OC (9pt (9pr Cl wow, (91") 8L-7 (9pt) Lo5urf 3000 (9P0 LVF -20D (,) 0101.11 SP WG36 t 1 Freeze Prot- ShiNPresure Sleeve 15 500 11.9 O. :U 2A3A7 6% 16.4 1000 2 25p H bor G Pad 0 12,000 285.] 0. 4:46 2A2S9 997 23.7 0.30 0.30 0.90 0.50 0.25 1.00 4.00 3.00 25.00 3 25p H bor G 1.0- 23S 2/ I RAMP Ce,bolae 16/20 I.as GO 6,9090:02:425.00164.5 0:02:45 2:38:13 12,954 0.30 0.30 0.90 0.50 0.25 1.00 4.00 3.00 25.00 1 4 2S2H bore 2.75-4.5#/ptRAMP Grl,ollte 16/20 3.63 0 6,909 3645 092.5 235:29 25,045 0.30 0.30 0.90 0.50 0.25 1.00 4.00 3.00 25.00 5 2S2 HyborG 4.S-6.252/ IRAMP Carboltte 16/20 5.38 0 6,909 MAS MAS 232M 37,136 0.30 0.30 0.90 0.50 0.25 1.00 4.00 3.00 25.00 6 7 252H bare 25H HyborG 6.25-8.0 tt/gal RAMP Spacer Carbolke 16/20 7.13 60 SS 6,909 420 164.5 IOA 092-05 O90A0 2309p 2:27:15 49,22] 0.30 0.30 0.30 0.30 0.90 0.90 0.50 0.50 0.25 0.25 1.00 LAD 4.00 4100 6.00 6.0 25.1D 25AD 8 252H G 2.563"gall Out 15 d2 1.0 090.0 2:2635 0.50 0.40 0.90 0.50 0.25 1.0 4.00 3.00 25.00 9 252H G Pad 30 2 000 619.0 0:20.38 226:31 291S6 04.2 0.50 OAO 0.90 0.50 0.25 1.00 4.00 3.00 25.00 10 252 b9rG 1.0.2.]58/gal MMP Carboltte 16/20 IAB 0 15,20 30.2 OM03 29553 15,275 30.7 28,599 31,750 0.50 OAO 0.90 0.50 0.25 2.00 4.00 3.0 25.00 2 11 252 l rG 2.75-4.5#/plRAMP Cerbo1ke 1620 3.0 0 15,253 30.2 09693 35950 15,296 364.2 55292 55,10 0.50 OAO 0.90 0.50 0.25 1.00 4.00 3.00 25.00 12 252 bor G 4.5 - 6.25 p gal RAMP Carboltte 16/20 5.38 0 35,253 30.2 09693 153:07 15,254 30.2 81,985 81,80 0.50 OAO 0.90 0.50 0.25 1.00 4.00 3.00 25.00 13 14 258 bmG 252 HyborG 6.25-8.02/ (RAMP Spacer Cer olke 16/20 7.13 0 60 15,253 420 30.2 10.0 010693 090:10 1A7A4 1:41M 23,957 1,175 570.4 2810 108,678 13LM 0.50 0.90 0.40 OAO 0.90 0.90 0.50 0.50 0.25 0.25 1.00 1.00 4.00 4100 6.00 6.0 25.00 25-00 IS 252H borG -s" Bell 0. 15 42 IA 09094 1:41:30 1,226 29.2 0.50 0.40 0.90 0.50 0.25 1.00 4.00 3.0 25.00 16 252 N bor G Pad 30 19,00 452.4 0:1595 1:41:26 20,011 476.5 0.50 0.40 0.90 0.50 0.25 1.00 4.00 3.00 25.00 3 17 25pH bore 1.0-3.0 p/ IRAMP Carbolae lb/20 2.00 0 11,088 264.0 094:24 1:26:22 11,085 20.9 22,176 24,300 0.50 0.40 0.90 0.50 0.25 1.00 4.00 3.00 25.00 18 252H borG 3.0-5.02/ (RAMP Carbo1ke 1620 4.00 0 11098 264.0 0:04:24 121:58 11,05 264.2 44,352 44,100 0.50 0.40 0.90 0.50 0.25 1.00 4.00 3.00 25.00 19 2S2HborG 5.0-).0#/,1 RJUMP Carbolke 1620&20 6.00 0 11088 2154.0 09424 1:17:34 10914 259.9 66528 65000 0.30 0.40 0.90 0.50 0.25 1.00 4.00 3.00 25.00 20 21 252Hb4rG 252 Hyb,,G TO -9.0 1RAMP Spacer [arbolke 1620 8.00 0 0 11088 420 264.0 1010 0:0424 090:10 1:13:10 198106 13,356 1,031 318.0 20.5 88,704 89,900 0.30 0.311 0.40 0.40 0.90 0.90 0.50 0.50 0.25 0.25 1.00 1.00 11 .00 4.00 6.00 6.00 25.00 25.00 22 2S2N bmG 2.688'Bell Out IS 42 1.0 090.04 196:36 L087 25.9 0.30 0.30 0.90 0.50 0.25 1.00 4.00 3.00 25.00 23 Hybo, G Pad 30 24,000 571.4 0:1993 198:32 24465 582.50.30 0.30 0.90 0.50 0.25 1.00 4.00 3.00 25.00 4 24 2WHybrG IM -3.02 (RAMP Corbolke 16 2.0 0 13,170 313.6 0.05:14 0.49:29 13,164 313.4 26,340 27300 0.30 0.30 0.90 0.50 0.25 1.00 4.03.00 25.0 25 252 b9rG 310-5102 IRAMp Urbolke 1620 4.0 0 13170 313.6 0105:14 044:15 13688 325.9 52680 51600 0.30 17.30 0.90 0.50 0.25 1.00 4.00 3.00 25.00 26 254141b.16 5.0-7.02 IggMP Cadplke 3620 6.0 0 13170 313.6 095:14 0:3992 13,018 310.0 79020 3500 0.30 0.30 0.90 0.50 0.25 1.00 4.00 3.00 25.00 27 28 252 !,orG 252 Hyb9rG 7.0-9.02 IRAMP Spacer Carbolke 16no 8.0 0 0 13.170 420 313.6 10.0 095:14 090:10 0:33-08 0:2835 14122 11003 336.2 23.9 10530 96.600 0.30 0.30 ----42 0.30 0.30 0.90 0.90 0.50 0.50 0.25 0.25 1.00 1.00 4.00 4.0 6.00 6.00 25.00 25.00 29 252H bore 2.70"ea110m is 1.0 090:01 0:2825 1039 24.7 0.30 0.30 0.90 0.50 0.25 1.0 4.00 3.0 25.00 30 25pH bore Pad 30 900 2143 09):09 028:21 3232 7711 0.30 0.30 0.90 0.50 0.25 1.04.0 3.0 25.0 31 32 252H borG 25p H bor G 1.0-3.252 IRAMP 3.25- 5.5 N/pi RAMP Carbolke 16/20 Carb912e 16/20 2.13 4.38 0 0 5,272 5,272 125S 125.5 092-06 092.'06 .21:12 01996 11203 23,05 0.30 0.30 0.30 0.30 0.90 0.90 0.50 0.50 0.25 0.25 1.0 1.0 4.0 4.0 3.0 3.0 25.0 25.0 5 33 34 2528 borG 2. H bor G 5.5-7.75 e/ (RAMP 7)5-10.0 g/ ai RAMP Urbolkel . Qul olke 16/20 6.63 8.88 0 0 5,272 5 2]2 125.5 125.5 0M:06 092960.14:55 0.1791 34927 46,7891 0.30 1 0.30 0.30 0.30 0.90 0.90 0.50 0.50 0.25 0.25 1.0 1.0 4.0 4.0 3.0 6.0 25.0 25.0 35 2528 bore 1 5 ace, 15 420 SOA 09040 012:50 0.30 0.30 0.90 0.50 0.25 LOO 4.0 6.0 25.0 36 2528 bore 2.813"gall Out 42 IA 09094 0:12:m 0.30 0.30 0.90 0.50 0.25 1.0 4.0 6.0 25.0 37 38 252 Water Frac G Freeze Protect Flush Cleanup EELEE15 30 20 9 573 3,)80 227.9 90.0 09736 09430 0:12-06 094:30 6,60 158.6 0.50 0.25 1.0 10000 4.0 6.0 25.0 Fann 35 Break Chart 3750 3500 HALLIBURTON I ......=mA 3000 300 2750 2500 t 80 2250 2000 60 x 1750 E � 1500 Fluid System: 25# Hybor-G 1250 INFORMATION Testing done by:, Caplin McCarthy 40 750 Customer: Pioneer Natural Resources Dater 2/28/2013 20 250 Well Name: _ 230 Break Test 0 15 30 45 60 75 90 105 120 135 150 165 Data Calculated viscosity Time (min) Well Number:- ODST-47 _ Well Location: Torok TVD (ft).. .... BHST (F) Water Used Test# 1 2 sr 3 4 5 Water Analysis: Chemical units Chemical Concentrations Temp(F). 78 'BE -7 gpt 0.25 0.25 0.25 0.25 0.25 pH. 7.67 L065 2 2 2 2 Chlorides (mg/L)' 22730 Losurf _ gpt ` _ 1.00 1 1 1 1 Carbonates (mg/L). 0 Claweb gpt ,050 0.5 0.5 0.5 0.5 Bicarbonates (mg/L)'. 142 MO 67 gpt 0.90 0.9 0.9 0.25 0.25 j --S Iron (mg/L): 0. CL -22 gpt 0.90 _ 0.9 0.9 0.9 0.9 Sulfates(mg/L) 800 SP GO 3.00 _ 3 6 3 6 Hardness 10000 OII pti gpt 4.00 4 4 _ 4 _ 4 Potassiu m (mg/L)-- 8000 CL -31 _ 'Pt 0_50 0.5 0.5 0.5 0.5 TDS(mg/L) 45000 Specific Gravity: 1.021 ., TDS(mg/L) 45000 .._...___ ...,...... ,..__.... Specific Gravity: 1.021 Test# 1 2 FLUID PROPERTIES 3 4 5 Gel Hydration Water pH 7.68. 7.68 7.68 7.78 7.78 Min Visc (CP) Temp (F) Base Gel (#) 25 25 25 25 25 1 9 78 Base Gel Visc (cP).. 21 22 21 24 24 3 Base Gel pH 7.84 8.02 7.84 7.86 7.86 6 20 78 Base Gel Temp (F) 78 - 81 72 72 9 10.39 10.35 9.43 9.34 12 - 22 78 Crosslink pH 10.33 .. ... 10.24 8.69 8.63 Final pH',. 8.91 Test Temp (F): 100 100 100 100 Break Time(hr:min) Fann 35 Break Chart 3750 3500 120 3250 3000 300 2750 2500 80 2250 2000 60 x 1750 E � 1500 F --- 1250 --- 100 - - - 1000 40 750 500 20 250 230 Break Test 0 15 30 45 60 75 90 105 120 135 150 165 Data Calculated viscosity Time (min) 1 1 1 1 1 _ 1 1 I 1 �\ 1 V 1 1 1 1 - _ 1 1 1 1 1 1 1 Earn 35 OC Page 12 Lab QC Page 13 JOB INFORNIATIONAND TESTING CONDITIONS tstomer: Pioneer Fluid System: Hybor G Bob Type: B5X ell Name: F ODS Main line Water Source: Source Nater Shear Rate (1/sec): 40 te: 10'19/12 Temp. (°F): 122 Lab Project ID: RS2012-50196 FLITID DESIGN Test No: 3 2 3 1 17-5 & 9 {Vater 's18 Lot # Chemical Units Chemical Concentrations Sample ID:W0136 WG -35 ppt 25.00 25.00 Specific Gratz 1.021 LoSwf300D Spt 1.00 1.00 T erature ° 71.00 Cls -Web Att 0.50 0.50 H 7.27 MCS -2510T at 0.50 0.50 Conduch94ti S/cm) 35000.00 MC 58630 Er 025 0.25 Resistivity 12-m 0.00 Iron msdL.) 0.70 CL-22UC ppt 0.90 0.90 Potassitun ( 370.00 CL -31 gpt 0.30 1 0.30 1 1 1 1 Sodittm (ss1g/L)i 7097.00 MO -67 ppt 1.00 1.00 Calciuuu 308.80 Opti -II ppt 4.00 4.00 NU sium (nI 933.10 SP Breaker ppt 6-00 3.00 Chloride (mgt) 13054.00 Sulfate 1900.00 Carbonate mm2 0.00 Bicarbonate mm2 152.50 TDS (mI 23100 'calculated ♦slues Test No: 1 2 3 5 e .c� Gel Hydntim (770 Water pH 727 7.27 Mia Viscosity (cP) Base Gel (#) 25 25 1 9.0 Base Gel Visc (cP) 19.0 19.0 3 16.0 Base Gel pH 736 7.36 6 18-0 Base Gel Temp. (°F) 70 70 9 18.0 12 19.0 1 70 Crosslink pH 10.25 10.11 Final pH 9.90 9.24 Test Temp. (°F) 108 122 Break Time (hr rain) 1:39 0:56 --Notes: -Y 1 -Vac2 ----Tempt -_--T-p2 1800 f 1600 - - - 200 1400 b � 173 1200 - rz y, 1000 150 S 600 123 -__•== 600 -• -------------------------------------------------- • • ________________100 --------- �. • 400 ' 75 200 I 0:00 0:15 0:30 0:45 1:00 1:15 1:30 1:45 2:00 Elapsed thee. hr:mhn Lab QC Page 13 Customer: Pioneer Natural Resources Well: ODST-47 Date: 2/28/2013 Formation: Torok Ticket #: Comp 5 Wt. Sand Type Carbolite 16/20 HALLIBURTON Pan Size Comp 1 Wt. % Comp 2 Wt. % Comp 3 Wt. % Comp 4 Wt. % Comp 5 Wt. Pan #12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% #DIV/0! Pan #16 5.5 5.5% 4.9 4.9% 3.9 3.9% 3.1 3.1% #DIV/0! Pan #18 59.7 60.1% 61.8 62.1% 48.5 48.5% 46.9 46.8% #DIV/0! Pan #20 33.8 34.0% 32.8 33.0% 44.9 44.9% 47.2 47.1% #DIV/0! Pan #25 0.4 0.4% 0.01 0.0% 2.1 2.1% 2.2 2.2% #DIV/0! Pan #30 0.0% 0.0 0.0% 0.5 0.5% 0.7 0.7% #DIV/0! Pan 0.0% 0.0 0.0% 0.1 0.1% 0.2 0.2% #DIV/0! Total 99.4 100.0% 99.5 100.0% 100.0 100.0% 100.3 100.0% 1 0.0 #DIV/0! Retained 94.1% 95.1% 1 93.4% 93.8% #DIV/01 Sand Type Carbolite 16/20 Pan Size Comp 1 Wt. % Comp 2 Wt. % Comp 3 Wt. % Comp 4 Wt. % Comp 5 Wt. Pan #12 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! Pan #16 #DIV/0! #DIV/01 #DIV/01 #DIV/0! #DIV/0! Pan #18 #DIV/0! #DIV/01 #DIV/0! #DIV/0! #DIV/01 Pan #20 #DIV/0! #DIV/01 #DIV/0! #DIV/0! #DIV/01 Pan #25 #DIV/0! #DIV/0! #DIV/0! #DIV/01 #DIV/0! Pan #30 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/01 Pan #DIV/01 #DIV/0! #DIV/0! #DIV/0! #DIV/0! Total 0.0 #DIV/01 0.0 #DIV/0! 0.0 #DIV/01 0.01 #DIV/0! 0.0 #DIV/0! Retained #DIV/01 #DIV/0! #DIV/0! #DIV/0! #DIV/0! Sand Type Carbolite 16/20 Pan Size Comp 1 Wt. % Comp 2 Wt. % Comp 3 Wt. % Comp 4 Wt. % Comp 5 Wt. Pan #12 #DIV/0! #DIV/0! #DIV/0! #DIV/01 #DIV/0! Pan #16 #DIV/0! #DIV/01 #DIV/01 #DIV/0! #DIV/0! Pan #18 #DIV/01 #DIV/0! #DIV/0! #DIV/01 #DIV/0! Pan #20 #DfV/0! #DIV/01 #DIV/0! #DIV/0! #DIV/01 Pan #25 #DIV/0! #DIV/01 #DIV/01 #DIV/01 #DIV/01 Pan #30 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/01 Pan #DIV/0! #DIV/0! #DIV/0! #DIV/01 #DIV/0! Total 0.0 #DIV/0! 0.0 #DIV/0! 0.0 #DIV/0! 0.0 #DIV/0! 0.0 #DIV/01 Retained #DIV/0! #DIV/01 #DIV/0! #DIV/0! #DIV/0! Sand Type Carbolite 16/20 Pan Size Comp 1 Wt. % Comp 2 Wt. % Comp 3 Wt. % Comp 4 Wt. % Comp 5 Wt. Pan #12 #DIV/0! #DIV/0! #DIV/01 #DIV/01 #DIV/0! Pan #16 #DIV/01 #DIV/01 #DIV/0! #DIV/0! #DIV/0! Pan #18 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/01 Pan #20 #DIV/01 #DIV/01 #DIV/0! #DIV/0! #DIV/0! Pan #25 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/01 Pan #30 #DIV/0! #DIV/0! #DIV/01 #DIV/01 #DIV/0! Pan #DIV/0! #DIV/0! #DIV/01 #DIV/0! #DIV/01 Total 0.0 #DIV/0! 0.0 #DIV/0! 0.0 #DIV/0! 0.01 #DIV/0! 0.01 #DIV/01 Retained #DIV/0! #DIV/01 #DIV/0! #DIV/0! #DIV/0! Sand QC Page 14 fl A Treating Chart - Zone 1 Attempt Treating Pressure (psi) A Slurry Rate (bpm) BH Proppant Cone (]b/gap C Slurry Proppant Cone (lb/gal) B Cmuge BH Pres (psi) A Actual BH Temp ff) B C D C D 6 [160 4 140 2 [120 0 100 23:40 23:50 00:00 00:10 0020 00:30 00:40 3/2/2013 3/3/2013 Time 3/3/2013 Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSITE far SimiAian v4.4.0 Well Description: ODST 47 UWI: 50-703-20642 1W-130 .21 A 1201 0 U Treating Chart - Zone 2 Ball Drop Treating Pressure (psi) A Slurry Rate (bpm) BH Proppant Cone (Ib/gal) C Slurry Proppant Cone (Ib/gal) B Gauge BH Pres (psi) A Actual BH Temp (aF) C D C D 6 160 4 140 2 120 0 100 00:30 00:40 00:50 01:00 01:10 3/3/2013 Time 3/3/2013 Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSfTE far StimlMan v6.4.0 Well Description: ODST 47 UWI: 50-703-20642 14J-1315:00 Treatment Plots Page 15 A 1000 Treating Chart - Zone 2 Treating Pressure (psi) A Slurry Rate (bpm) BH Proppant Cone (lb/gal) C Slurry Proppant Cone (Ib/gal) B Gauge BH Pres (psi) A Actual BH Temp (°F) B C D C D 6 160 140 2 120 100 00:40 01:00 0120 01:40 02:00 02:20 3/3/2013 Time 3/3/2013 Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSITE far1315:03ddim X4.3.1 Well Description: ODST 47 UWI: 50-703-20642 07-J-1375:03 Treating Chart - Zone 3 Ball Drop Treating Pressure (psi) A Slurry Rate (bpm) B BH Proppant Conc (Ib/gal) C Slurry Proppant Cone (lb/gal) C A B Gauge BH Pres (psi) A Actual BH Temp (°F) D C D 8000 80 1 16 7160 1 4 X140 2 X120 0 X100 02:14 02:16 02:18 02:20 0222 0224 3/3/2013 Time3/3/2013 Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSITE for 3li 1315:01 v4.4.0 Well Description: ODST 47 UWI: 50-703-20642 14Jv�1315:01 Treatment Plots Page 16 A 1000 Treating Chart - Zone 3 Treating Pressure (psi) I A Slurry Rate (bpm) BH Proppant Conc (lb/gal) C Slurry Proppant Conc (lb/gal) B Gauge BH Pres (psi) A Actual BH Temp (°F) r B C D C D 6 160 4 140 2 120 0 100 02.20 0230 02:40 02:50 0300 03:10 03:20 3/3/2013 Time3/3/2013 Customer: PIONEER NATURAL RESOURCES -EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSfrEfar 1314.,42X4.3.1 Well Description: ODST 47 UWI: 50-703-20642 07-Ju41314:42 Treating Chart - Zone 4 Ball Drop Treating Pressure (psi) A Slurry Rate (bpm) B BH Proppant Conc (]b/gal) C Slurry Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Actual BH Temp (°F) D C D 8000-1 80 16 x160 6000 1 4 X140 2 '120 0 X100 0308 03:10 03:12 03:14 03:16 03:18 3/3/2013 Time 3/3/2013 Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSfrE for Stimlgim W.4.0 Well Description: ODST 47 UWI: 50-703-20642 1 14J-1315:03 Treatment Plots Page 17 rreatmg-ressure(ps BH Proppant Cone (I A B Gauge BH Pres (psi) 12000 10500 6000 4500 Treating Chart - Zone 4 0 A Slurry Rate (bpm) (lb C Slurry Proppant Cone (lb/gal) A Actual BH Temp ff) C D C D 6 160 4 140 2 120 0 100 03:10 03:20 03:30 03:40 03:50 04:00 04:10 0420 04:30 3/3/2013 3/3/2013 Time Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mat -2013 Sales Order #: 900262042 INSRE for SIIrrWafion v6.4.0 Well Description: ODST 47 UWI: 50-703-20642 11-J-1309.22 Treating Chart - Zone 5 Ball A B 12000 eating Pressure (psi) A Slurry Rate (bpm) i Proppant Cone (lb/gal) C Slurry Proppant Cone (lb/gal) C D 6 x160 4 140 2 120 0 100 04:10 04:15 04:20 0425 04:30 0435 04:40 3/3/2013 3/3/2013 Time Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSITE for Stlmlation X4.4.0 Well Description: ODST 47 UWL 50-703-20642 11-J-130924 Treatment Plots Page 18 Chemical Chart - Zones 1-4 CLA-Web Cone (gaUMgal) A BE -7 Cone (gaUMgal) A SP Breaker Cone pb/Mgal) — 4 3 2- 1 A CLr31 Cone (gaVMgal) B A W Cr36 Cone (]b/Mean B B 50 WIT -40 -30 -20 10 0 0 00:00 01:00 02.00 03.00 04:00 3/3/2013 3/3/2013 Time Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSITE far SlimlAian v4.4.0 Well Description: ODST 47 UWL 50-703-20642 11-Ju}1309,25 Chemical Chart - Zones 1 & 2 MO -67 Cone (gaUMgal) A Losurf-300D Conc (gaUMgal) A CLr3l Conc (gaUMgal) A CLA-Web Conc (gaUMgal) A BE -7 Conc (gaUMgal) B SP Breaker CI (lb/Mgal) A WG -36 Cone (Ib/Mgal) B 10.0.1 Flo I 1 4 Vwwi -40 -30 -20 10 0 0 00:00 01:00 02.00 03.00 04:00 3/3/2013 3/3/2013 Time Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSITE far SlimlAian v4.4.0 Well Description: ODST 47 UWL 50-703-20642 11-Ju}1309,25 Chemical Chart - Zones 1 & 2 MO -67 Cone (gaUMgal) A Losurf-300D Conc (gaUMgal) A CLr3l Conc (gaUMgal) A CLA-Web Conc (gaUMgal) A BE -7 Conc (gaUMgal) B SP Breaker CI (lb/Mgal) A WG -36 Cone (Ib/Mgal) B 10.0.1 Flo I 1 4 Vwwi B 50 30 30 ?0 E 00 23:40 00:00 0020 00:40 01:00 0120 01:40 02:00 02:20 02.40 3/2/2013 3/3/2013 3/3/2013 Time Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INS1rE far Stimlgion v4.4.0 Well Description: ODST 47 UWI: 50-703-20642 11-Jur130 .Z7 Chemical Plots Page 19 Chemical Chart - Zone 3 M0-67 Conc (gaVMgal) A Losurf-300D Conc (gaVMgal) A CLr31 Conc (gaVMgal) A CLA-Web Conc (gaVMgal) A BE -7 Cone (gal/Mgal) B A SP Breaker Conc( lb/Mgal) A W&36Conc(lb/Mgal) B B 0220 0230 02:40 02:50 03.00 03:10 0320 3/3/2013 3/3/2013 Time Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSITE fa S0mlAian v1.4.0 Well Description: ODST 47 UWI: 50-703-20642 11-J-130929 Chemical Chart - Zone 4 A 4 3 2 H M0-67 Conc (gaVMgal) A Losurf-300D Conc (gaVMgal) A CLr31 Conc (gaVMgal) A CLA-Web Conc (gaVMgal) A B>s7 Conc (gaVMgal) B L1 o J1 Con c Ob,'Mg-,d) i SP Breaker Conc (]b/Mgal) A W&36 Cone (Ib/Mgal) B I -11 =N11 I � ,Y'p porm I M �NrrlIfrUl.rw VIL B 50 W 30 ?0 E 00 03:10 0320 03:30 03:40 03:50 04.00 04:10 0420 3/3/2013 Time 3/3/2013 Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 900262042 INSrrE for Stimiation v1.4.0 Well Description: ODST 47 UWI: 50-703-20642 11-,1 x130930 Chemical Plots Page 20 Net Pressure Plot Zones 1 & 2 Net Calc'd BH Pres (psi) A Time NetPr BPC Slope BH Proppant Cone (Ib/gal) B 01 -1389.05 0.000 0.000 0.000 A Slope of Net Pressure (psi min) C B 100000 20 10 Time (min) (0 = 38.666667) Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 90024 Well Description: ODST 47 UWI: 50 703 20642 A 10 1 100 Net Pressure Plot - Zone 2 Net Calc'd BH Pres (psi) A Time NetPr BPC Slope — BH Proppant Cone (Ib/gal) B Slope of Net Pressure (psi/min) C 1� -1389.05 0.000 0.000 0.000B 8 6 4 2 0 Me] Time (min) (0 = 7.266667) Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 90024 Well Description: ODST 47 UWI: 50-70320642 Net Pressure Plots Page 21 A 100 10 Net Pressure Plot Zone 3 Net Calc'd BH Pres (psi)A Time NetPr BPC Slope BH Proppant Conc (Ib/gal) B -1389.05 0.000 0.000 0.000 Slope of Net Pressure (psi/min) C 3 Time (min) (0 = 38.666667) Customer: PIONEER NATURAL RESOURCES- EBUS Job Date: 02 -Mar -2013 I Sales Order #: 90024 Well Description: ODST47 UWI: 50-703-20642 10 Net Pressure Plot Zone 4 - Net Calc'd BH Pres (psi) A Time NetPr BPC Slope - BH Proppant Conc (Ib/gal) B -1389.05 0.000 0.000 0.000 Slope of Net Pressure (psi/min) C B Time (min) (0 = 38.666667) Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 02 -Mar -2013 Sales Order #: 90024 Well Description: ODST 47 I UWI: 50-703-20642 Net Pressure Plots Page 22 10:00 PM 12:00 AM Waiting for vac truck to get to location to suck out the hydro; broke down on the way 12:00 AM 4:00 AM Clean up trucks and lines as much as possible February 28, 2013 4:00 AM 10:00 AM Crew off for rest 11:00 AM 11:30 AM Conf. Call with Lead Engineer; PE service Manager; Acct Rep; and Pioneer to discuss Scale pumping Break off all the trucks from the missile to do housekeeping; All had to be towed out and many had 10:00 AM 6:30 PM snow up past the fenders. 10:00 AM 6:00 PM Pull out the 1138 and 5094 and replace valves. Remove fluid from the hydro; some was thick and had to be rolled. Added 50# GBW-30 to help break 12:00 PM 7:00 PM it up. 12:00 PM 8:00 PM Break down 4" iron; 2" iron; the wellhead is off; and they will swing the 40 footers out of the way 6:00 PM 7:00 PM Break for dinner 8:00 AM finish working for the evening; crew got iron that had ice in it and rigged it out of the iron. They also 7:00 PM 10:00 PM folded tarps and cleaned up location. March 1, 2013 10:00 PM 8:00 AM Crew off for sleep 7:00 AM 7:30 AM Morning Conference Call with MBU, Engineer, Mechanics, and Etech with GJ 8:00 AM 8:30 AM Pre -work safety meeting 8:30 AM 11:00 AM Crew split up between the frac pad and the wellhead 7:00 AM 3:30 PM Remove snow from frac pad by non -HES employees and equipment 12:00 PM 3:00 PM Mover side snow removal completed; begin rigup of HHP. 3:30 PM TCC side snow removal complete; start rigging up 7:00 AM 6:00 PM Wellhead rigup complete; had to wait for a wellhead ring from town. 4:00 PM 9:00 PM SLB brought out some scale inhibitor; tests looked good March 2, 2013 9:00 PM 6:00 AM Crew off for Rest 6:30 AM 7:00 AM Morning Safety meeting with crew 7:00 AM 10:00 AM Crew had to add SLB scale to tanks. Acct rep will look into different methods of loading it 10:55 PM Brought up to 8959 psi; frac iron looked good; brought up ball dropper pressure and had a leak to fix After getting proposal late last night, found out that not enough SP was on location. Got more Start Job 8:00 AM 11:15 AM hotshotted out 11:42 PM 12:00 PM 12:30 PM Ready to go; eat lunch 12:04 AM Chemicals ready to go; 6641 Besser quit running; mechanics were working on it 12:30 PM 1:00 PM Pre -job Frac Meeting 12:15 AM Made decision to drop the ball and skip the stage Kusco truck broke down; found out about it at 13:00; said it would be 14:00 before it would be on shut down and bled pressure down to 430 psi to open cement and drop ball. 1:00 PM location. It was the truck used to evacuate the lines. 3843 is not running properly; will not use it for the job. Mechanics got it running but it still wasn't able 1:00 PM to use it for the job 1:15 PM 1:45 PM 8177 Panther has can problems; etech fixed the problem 1:30 PM 2:00 PM Customer used CH2MHILL instead for vac truck and got it spotted 2:00 PM 2:35 PM LRS Hot oiler monitoring the IA needed fittings to rig up to the IA 2:00 PM 2:10 PM Primeup on LVT ODSN-47 2:10 PM 2:17 PM had to swap a discharge hose on 5094 SO# 2:30 PM 3:15 PM Crew believes there is ice in the iron somewhere 900262042 3:30 PM 7:00 PM Take apart iron; found the blockage in and around one of the CBS's and a 40 footer Zones 1-4 3:35 PM 4:30 PM Remove LVT from lines Primeup on LVT; still had some ice; crew thought it was between the CBS and the ball dropper tee. 7:25 PM 8:40 PM Also, one of the bleed off lines was still frozen; but the other was free. Found a broken butterfly valve on one of the pumps; went through the rest to make sure they were all 8:40 PM 10:00 PM ready to go (0986: no rate, 7534: hose) 10:00 PM 10:15 PM Pressure test; had to fix a leak on a chicksan by the ball dropper. 10:15 PM 10:24 PM Repressure test; had to retighten the wing 10:44 PM 10:55 PM Tried to test again; got to 8000 psi; shut down to fix a different leak. 10:55 PM Brought up to 8959 psi; frac iron looked good; brought up ball dropper pressure and had a leak to fix 11:37 PM Start Job 11:41 PM Shift sleeve; max pressure at shift 6513 psi 11:42 PM 12:01 AM shut down to mix hydro and flood chemical lines March 3, 2013 12:01 AM 12:04 AM Chemicals ready to go; 6641 Besser quit running; mechanics were working on it 12:04 AM Resumed pumping; pressure would not roll over; kicked out a couple times 12:15 AM Made decision to drop the ball and skip the stage 12:30 AM shut down and bled pressure down to 430 psi to open cement and drop ball. 12:30 AM Lower LVT driver on had 15 bbls left with a full tub on the ADP and upper driver had 70-80 bbls 12:36 AM Dropped ball; shortly after pressure dropped significantly brought rate up 12:37 AM Pressure sleeve shifted 1:26 AM had to shut down the 7534 pumptruck due to pumptruck leaking around the pod 1:28 AM had to shut down the 1358 pumptruck due to topcaps 1:40 AM Sand was not matching setpoint, increased concentration 2:14 AM Drop Zone 3 Ball 2:22 AM Zone 3 Ball on seat 3:08 AM Drop Zone 4 Ball 3:15 AM Zone 4 Ball on Seat 3:45 AM lost sand concentration due to not getting ARC to move sand 3:49 AM Shut down to fix sand issue 3:50 AM Resumed pumping 4:07 AM Pumped approximately 1300 sacks; could not get sand running, cut the zone and dropped the next ball 4:10 AM Came offline due to cement not responding to calls 4:14 AM Resumed pumping 4:15 AM Dropped Ball Trucks kicked out due to max pressure being reached. Tried to repump and pressured out. Customer is unsure of what is downhole. This happened approximately 60 bbls after the ball was heard passing 4:18 AM through the wellhead 4:25 AM Job complete. Customer may run a gauge ring to see where the ball is. 4:25 AM 6:00 AM Post iob cleanup Pioneer Natural Resources Treatment Summary ODST-47 - Part 2 Zones 5-7 Alaska Section 11 Township 13N Range 7E API #: 50-703-20660 Torok 30# Hybor-G March 20, 2013 SO# 900295335 HALLIBURTON Table of Contents Section HALLIBURTON ' Enhancement Page(s) Cover Sheet 1 TOC 2 Wellbore Information 3 Executive Summary 4-7 Stage Summary 8 Design Worksheet 9 Fann 3S QC 10 Lab C 11 Sand C 12 Treatment Plots 13-14 Chemical Plots 15-16 Net Pressure Plots 17 TOC Page 2 Customer Pioneer Natural Resources HALLIBURTON Formation Torok Lease ODST-47 - Part 2 Zones 5-7 API 50-703-20660 Date 3/20/2013 sleeven-eff ueptn(tt) I I Sleeve BalID rop Time Ball Hit Time JSV Drop JSV Hit Earty Seat Differential Sleeve/Pert (gal) (BBLS) Top Btm Zone # .uu...■..cc. iuu......cc, ��„ Peak (psi) 51 9,572 I 227.91 14,9 9 130 217.4 284 15,6831 SIN/A 22:53:59 N/A 23:07:01 N/A 8417 N/A1033.81 25.3 1 5861 76291 1768 1 15.6 12699 17,090 Wellbore Information Page 3 Treatment Flowpath Tubular Information Description Tubular Size FUF (gal/ft) Top Btm Volume Frac String 4.5" 12.6# P-110 0.6392 0 11938 ft 7,631 gal Production Liner 4.5" 12.6# P-110 0.6392 11938 17191 ft 3,358 gal ft 0 gal ft 0 gal ft 0 gal ft 0 gal ft 0 al Total 10,988 gal Completion Tubular FUF (gal/ft) 4.5" 11.6# 0.6392 Total MD 17191 ft Wellbore Information Page 3 HALLIBURTOI Engineering Executive Summary On 03/20/13 a stimulation treatment was performed in the Torok formation on the ODST-47 - Part 2 Zones 5-7 well. The following information was gathered during the treatment. Sales Order #: 900295335 API#: 50-703-20660 10# Water Frac G Volume: 26,282 gal 626 bbls 30# Hybor G Volume: 161,171 gal 3837 bbls 30# Water Frac G Volume: 63,408 gal 1510 bbls Freeze Protect Volume: 7,350 gal 175 bbls End Hydro Strap Volume: 22,500 gal 536 bbls Total Fluid (Used): 280,711 gal 6684 bbls Clean Fluid Downhole (No Hydro or LVT): 250,861 gal 5973 bbls Carbolite 16/20 Pumped: 358,800 lbs Formation: Torok Total Stim-Sleeve Zones: 9 Total Zones: 9 Net Pay Interval: 4391 ft Average Rate: 31.5 bpm Average Pressure: 6593 psi Maximum Rate: 60.1 bpm Maximum Pressure: 8908 psi Maximum Horsepower: 8858 HHP Average Visc: 28.5 CP Average pH: 9.9 Average Temp: 89 deg F BE -6 Pre-treated in tanks: 57 lbs (0.15 ppt) MC S-2263 Pre-treated in tanks: 26 gal (0.25 gpt) Prior to pumping the job, Quality Control tests were conducted on location to determine hydration time, crosslink time, and gel viscosity. Chemical concentrations were adjusted, as needed, according to test results, pump times, and onsite water. We appreciate the opportunity to service your well. If you have any questions about the job, or anything else, please call me at (435)-621-2192. Thank you, Johann Baltrusch Technical Professional Halliburton Energy Services Andrew West Technical Professional Halliburton Energy Services Executive Summary Page 4 Treatment Information Executive Summary Page 5 Zone 5 Zone Summary Max Rate: 6 bpm Max Pressure: 8,908 psi Average Rate: 2 bpm Average Pressure: 7,489 psi Max Horsepower: 500 hhp Average Temp: 6 F Carbolite 16/20: 0 lbs Total Proppant Pumped: 0 lbs Proppant in Formation: 0 lbs 30# Hybor G Volume: 0 gal 0 bbls 30# Water Frac G Volume: 46,325 gal 1103 bbls Freeze Protect Volume: 0 gal 0 bbls Comments: After several attempts to shift the sleeve, zone 5 was skipped. Executive Summary Page 5 Executive Summary Page 6 Zone 6 Zone Summary Initial Rate (Breakdown): 40.4 bpm Initial Pressure (Breakdown): 6551 psi Max Rate: 60 bpm Max Pressure: 7,697 psi Average Rate: 49 bpm Average Pressure: 5,429 psi Max Horsepower: 8594 hhp Average Visc: 27 cp Average pH: 10 Average Temp: 86 F 3/18/13 ISIP: 1528 psi Initial Fracture Gradient: 0.74 psi/ft 3/18/13 ISIP: 1578 psi Final Fracture Gradient: 0.75 psi/ft 3/20/13 ISDP: 950 psi Final Fracture Gradient: 0.63 psi/ft Carbolite 16/20: 305,000 lbs Total Proppant Pumped: 305,000 lbs Proppant in Formation: 275,000 lbs 30# Hybor G Volume: 105,487 gal 2512 bbls 30# Water Frac G Volume: 13,899 gal 331 bbls Freeze Protect Volume: 0 gal 0 bbls Comments: Could not get breakdown on zone 6 on 3/18/2013, so crew shut down so Coil Tubing could perforate. On 3/20/2013, the crew pumped a wellbore volume and shut down for an ISIP. Once pumping was resumed, rate was established at 60 bpm before dropping back to 45 bpm. As 7.5 ppg sand hit formation; pressure began to rise. The pressure rose suddenly and kicked the pumps out. The crew then went bypass and tried to flush at 15 bpm. At 14:14 pm, a valve on the blender failed, which caused a spike on the slurry rate. Downhole rate was still at 15 bpm though. At 14:15, pressure jumped up to max pressure, at which all the pumps came offline. Pumped 90 bbls of flush, which left 30,000 lbs in the wellbore. Placed 275,000 in formation for the zone. Executive Summary Page 6 Zone 7 Zone Summary Initial Rate (Breakdown): 5.5 bpm Initial Pressure (Breakdown): 2008 psi Max Rate: 50 bpm Max Pressure: 8,706 psi Average Rate: 44 bpm Average Pressure: 6,860 psi Max Horsepower: 8858 hhp Average Visc: 30 cp Average pH: 10 Average Temp: 92 F ISIP: 2012 psi Initial Fracture Gradient: 0.83 psifft Carbolite 16/20: 53,800 lbs Total Proppant Pumped: 53,800 lbs Proppant in Formation: 39,600 lbs 10# Water Frac G Volume: 26,282 gal 626 bbls 30# Water Frac G Volume: 3,184 gal 76 bbls 30# Hybor G Volume: 55,684 gal 1326 bbls 30# Water Frac G Volume: 7,350 gal 175 bb/s Freeze Protect Volume: 7,350 gal 175 bbls End Hydro Strap Volume: 22,500 gal 536 bbls Comments: After perforating from 13810-13814, a step-down test was performed. Pad volume was extended from 730 bbls to 900 bbis and 5500 lbs of 16/20 was pumped at the start of pad. Dropped rate after proppant hit from 50 bpm to 40 bpm and continued designed pad, 1.5, and 3 ppg clean volumes. As 3 ppg stage was on formation, job screened out. Crew attempted to pump more fluid but could not. Left 14,200 lbs in the wellbore, placing 39,600 lbs in formation. The crew rigged off the well and turned it over to coil tubing. Executive Summary Page 7 Customer Pioneer Natural Resources Well 17057-47- Part 2Zones S-7 NALLIBURTON j Formation Torok r h Stage Summaries Planned Actuals Pressure e I 444e I 30c I Tern, 92 I 10 I Pressure 76 7 87068 I 6501 I 26 282 I 626 55 6484 13216 13, 84 1 31 7, 0 175 220500nbb6f 1530386 00 2:13 _- 05800 , -_ 55000 .• Stage Summary Page 8 I Customer Pioneer Nature 1 Resources 3/20/2013 API 50-703-20660 Lease ODST-47 - Part 2 Zones 5-7 MALLIBURTON Formation TOrnk Treatment Interval Stage Number Fluid Description Stage Description Prpppant Description Prop Conc (ppg) Slurry Rate (bpm) Design Clean Volume (gol) Design Clean Volume (bbl) Stage Time hh:mm:sec Pump Time hh:mm:sec Dual Clea Actual Clear Volume Volume (gol) (bbl) Design Prop Actual Prop CL -31 MO -67 CL -22 UC CLA-Web Total Total rosslin Buffer CL_" lay Con (lbs) (lbs) (gpt) (gpt) (gpt) (gptf BE -7 8iocid (gp[l LoSurf300D LVT-200 MC 5-2263 Optiflo-ll SP Surfactant hird Pa cele lnhlbi Breaker Breaker lgptJ lgpt) (gptJ 1pptl 1pptl I, , 1 30# Water Frac G Pre Pad 60 9,660 230.0 0:03:50 2:02:43 7,073 168.4 0.50 0.25 1.00 0.25 30.00 2 30# Water Frac G Pre Pad 60 91660 230.0 0:03:50 1:58:53 9,840 234.3 0.50 0.25 1.00 0.25 30.00 5 3 30# Water Frac G Spacer 60 2,100 50.0 0:00:50 1:55:03 0.50 0.25 1.00 0.25 4.00 1.0030.00 4 30# Water Frac G 2.813" Ball Out 60 42 1.0 0:00:01 1:54:04 116 2.8 0.50 0.25 1.00 0.25 4.00 1.00 30.00 5 30# Water Frac G Pad 60 31,000 738.1 0:12:18 1:54:03 29,296 524.8 0.50 0.25 1.00 1 0.25 1 4.00 1.00 30.00 6 30# Water Frac G Load Well 60 10,000 10,119 240.9 0.50 0.25 1.00 0.25 4.00 1.00 30.00 7 30#Hybor G Pad 60 31,000 738.1 0:12:18 1:41:53 31,069 739.7 0.30 0.60 0.90 0.50 0.25 1.00 0.25 4.00 1.00 30.00 8 3D# Hybpr G PLF Carbolite 16/2 1.50 60 21,059 501.4 0:08:21 1:29:35 20,825 495.8 31,589 33,800 0.30 0.75 0.90 0.50 0.25 1.00 0.25 4.00 1.00 30.00 6 9 30# Hybor G PLF Carbolite 16/2 3.00 60 9,915 236.1 0:03:56 1:21:14 9,894 235.6 29,745 30,600 0.30 0.90 0.90 0.50 0.25 1.00 0.25 4.00 1.00 30.00 10 30# Hybor G PLF Carbolite 16/20 4.50 60 12,490 297.4 0:04:57 1:17:18 12,472 297.0 56,205 57,600 0.30 0.90 0.90 0.50 0.25 1.00 0.25 4.00 1.00 30.00 31 30#Hybor G PLF Carbolite 16/2 6.00 60 17,755 422.7 0:07:03 1:12:21 17,746 422.5 106,530 107,200 0.30 0.90 0.90 0.50 0.25 1.00 0.25 4.00 1.00 30.00 12 30# Hybor G PLF Carbolite 16/2 7.50 60 11,249 267.8 0:04:28 1:05:18 13,481 321.0 84,368 75,800 0.30 0.90 0.90 0.50 0.25 1.00 0.25 4.00 1.00 30.00 13 30# Water FracG Flush 60 2,100 50.0 0:00:50 1:00:50 3,780 90.0 OSO 0.25 1.00 0.25 1.00 30.00 14 10# Water Frac G Step-down Test 45 10,000 238.1 0:05:17 1:00:00 26,282 625.8 0.50 0.25 1.00 0.25 4.00 1.00 10.00 15 30# HyborG Pad Carbolite 16/20 0.50 40 32,250 767.9 0:19:12 0:54:43 1 37,822 900.5 5,400 5,400 0.30 1.13 0.90 0.50 0.25 1.00 0.25 30.00 16 30#HyborG PLF Carbolite 16/20 1.50 40 5,000 119.0 0:02:59 0:35:31 5,040 120.0 7,500 9,200 0.30 1.25 0.90 0.50 0.25 1.00 0.25 30.00 7 17 30# Hybor G PLF Carbolite 16/20 3.00 40 10,000 238.1 0:05:57 0:32:32 9,996 238.0 30,000 30,700 0.30 1.25 0.90 0.50 0.25 1.00 0.25 30.00 18 30# Hybor G PLF Carbolite 16/20 4.50 40 15,000 357.1 0:08:56 0:26:35 2,826 67.3 67,500 8,500 0.30 1.25 0.90 0.50 0.25 1.00 0.25 30.00 19 30# HyborG PLF Carbolite 16/20 6.00 40 20,000 476.2 0:11:54 0:17:39 120,000 0.30 1.25 0.90 0.50 0.25 1.00 0.25 1$4.001.00 30.00 20 30# Water Frac G Flush40 2,100 50.0 0:01:15 0:05.45 3,184 75.8 0.50 0.25 1.00 0.25 30.00 21 22 End Hydro Strap Freeze Protect Hydration Tank Volume Flush 20 25,000 3,780 595.2 90.0 0:04:30 0:04:30 0:04:30 22,500 7,350 535.7 175.0 0.50 0.25 1000 30.00 Total Proa CL -31 I MO -67 CL -22 UCI CLA-Web I BE -7 I LOSurf 3000 LVT-200 MCS -2263 OptiOo-II SP I WG -36 9=1 I Design Worksheet Vage9 Fann 35 Break Chart 3500 140 3250 3000 120 2750 2500 100 2250 2000 80 „ 1750 0 4rvemo in 1500 60 4� nnci 1250 1000 40 750 SW 20 250 0p 0 20 40 60 80 100 120 140 160 Time (min) Farm 35 QC Page 10 HALLIBLJRTON 0 �ntid��m�nt Fluid System: 30#HyborG _ WEIEL/JOB INFORMATION Testing done by::, Andrew West Customer: Pioneer Dater 3/18/2013 Well Name ODST Well Number:. 47 Well Location:; Torok TVD (ft) 5200 BHST(F) 135 _ Water Used! Frac Tanks 6-15 w/ BE -6 & S-2263 Test# 13 14 FLUID DESIGN Water Analysis: Chemical q units _ Chemical Concentrations Temp (F) 50 WG -36 ppt 30 30 pH 6.84 Specific Gravity 1.0281 BE -7 gpt 0.25 ..0.25 Bicarbonates (mg/L) 1881 Cla-WEB _ gpt 0v50. 0.50 Carbonates (mg/L)0 Lo5uf30 --r0D t gp.. 100 100 _ Conductivity YIPS/cm)* _ 6_8.939 -- — .._ Hardness (mg/L) 4,000 MO -67 gpt 0.60 0.60 .,_ ___.._.. _.__. Iron (mg/L) 0'i CL -22 UC gPt.,_ _,_ .. .. 0.90 0.90 Potassium (mg/L)' 4,800: CL -31 gpt 0.30 0.30 Resitivity (0m)* 0 Sulfates (mg/L) 1,800 OptiFlo-ll ppt 4.00 4.00 w TDS (mg/L) 45,500; SP Breaker ppt T 3.00 _ *calculated values Test# 13 14 FLUID PROPERTIES _ _ Gel Hydration Water pH 6.90 6.90 Min Visc(cp) Temp (F) Base Gel (#) 30 30 1 9 _ 60 Base Gel Visc (0) 26 26 3 18 60 Base Gel pH 7.03 to 10.10 7.03 to 10.10 _ 5 j. 26 60 Base Gel Temp (F) 55 55__ _ 9 (_ 27 60 12 Crosslink pH 10.02 10.08 j Final pH 9.00 9.07 Test Temp (F) 135 135 Break Time(hr:min). 2:30 0:45 Fann 35 Break Chart 3500 140 3250 3000 120 2750 2500 100 2250 2000 80 „ 1750 0 4rvemo in 1500 60 4� nnci 1250 1000 40 750 SW 20 250 0p 0 20 40 60 80 100 120 140 160 Time (min) Farm 35 QC Page 10 Lab QC Page 11 • i INFORMATION AND TESTING CONDITIONS Cttstonler: Pioneer Fluid System: Hybor G Bob Type: B5X ell Name: ODS Main Line Water Source: Source Nater Shear Rate (1/sec): 40 Date: 10/19/12 Temp. (�F): 122 Lab Project ID: RS2012-S0196 FLITID DESIGN Test No: 1 I z 1 3 s Io Nater Analysis Lot i# Chemical Units Chemical Concentrations Sample M:W0136 WG -35 ppt 25.00 25.00 Specific (3Tavity 1.021 LoS=0001) pert 1.00 1.00 Temperature ° 71.00 Cla-Web ppt 0.50 0.50 pH T27 MCS -2510T pin 0.50 0.50 Conductivity tS/cm) 35000M MC B-8630 19 025 0.25 Resistivity n -m) 0.00 111011 11tY/L 0.70 CL-22UC ppt 0.90 0.90 Potassium ( 370.00 CL -31 ppt 0.30 0.30 Sodium (mg/L)s 7097.00 MO -67 1-00 1 1.00 Calcium 308.80 Opti -11 ppt 4.00 4.00 I.Magnesium ( 933.10 SP Breaker ppt 6.00 3.00 Chloride (mg/L) 13054.00 Sulfate {mg/L) 1900.00 Carbonate ( 0.00 Bicarbonate 152.50 TDS ( e' 23100 •talc« lamd snlmas Test No: i 2 FLUID PROPERTIES 3 S _ a 10 Gel tion (S1La) Water pH 7.27 7.27 Mia Viscosity (M Temp. (oF): Base Ciel (#) 25 25 1 9.0 70 Base Gel Vise (cP) 19.0 19.0 3 16.0 70 Base Ciel pH 736 7.36 6 18.0 70 Base Gel Temp. (°F) 70 70 9 18.0 70 12 Mo 70 Crosslink pH 10.25 1011 FinalpH 9.90 9.24 Test Temp. ('P) 108 122 Break Time (br:111i11) 1:39 0:56 eat Noeea: -Ypt 1 -Yuc 2 ----Temp t ----Temp 2 1800 F- - -- - - 225 1600 200 1400 b I 175 1200 f I! $ Z• 1000 I 150 f 2 600125 600 --- -- ---------------------------------------------- ---- s - ------ -_____-- - ------ --------- - ------ -------------------------------- 100 400 400 _ - 75 200 I, 0 -___--------- _-------- _--- _----------------- _---------------- ----- _S0 0:00 0:15 0:30 0:45 1:00 1:15 1:30 1:45 2:00 Elapsed Tfine. Immie Lab QC Page 11 Customer: Pioneer Natural Resources Well: ODST-47 - Part 2 Zones 5-7 Date: 3/20/2013 Formation: Torok Ticket #: 900295335 Sand Type Carbolite 16/20 ACE Mover -10961036 MALLINURTON I Pan Size Comp 1 Wt. % Comp 2 Wt. % . Comp 3 Wt. % Comp 4 Wt. % Comp 5 Wt. 0.0 Pan #12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan #16 4.0 4.5% 4.9 5.5% 5.6 5.7% 5.5 5.5% 3.9 4.3% Pan #18 63.3 70.9% 65.7 73.6% 66.1 67.8% 69.2 69.7% 60.9 67.1% Pan #20 21.5 24.1% 20.3 22.7% 25.2 25.8% 24.4 24.6% 25.2 27.8% Pan #25 0.5 0.6% 0.9 1.0% 0.6 0.6% 0.2 0.2% 0.8 0.9% Pan #30 0.0 0.0%1 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan 1 0.0 0.0% 0.01 0.0% 0.0 0.0%1 0.01 0.0%1---0.01 91.1% 0.0% Total 1 89.31 100.0%1 91.81 102.8% 97.5 100.0%1 99.31 100.0%1 90.81 100.0% Retained 1 95.0% 1 96.3% 93.6% 1 94.3% 1 94.8% Sand Type Carbolite 16/20 Besser 2 - 10193838 Pan Size Comp 1 Wt. % Comp 2 Wt. % Comp 3 Wt. % Comp 4 Wt. % Pan #12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan #16 5.1 5.6% 6.1 6.1% 8.3 8.3% 5.3 5.3% Pan #18 65.1 71.3% 65.3 65.2% 65.2 64.9% 70.2 70.2% Pan #20 20.6 22.6% 28.3 28.3% 26.3 26.2% 24.3 24.3% Pan #25 0.5 0.5% 0.4 0.4% 0.6 0.6% 0.2 0.2% Pan #30 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.01 0.0% Total 91.31 100.0%1 100.11 100.0% 100.41 100.0%1 100.01 100.0% Retained 93.9% 1 93.5% 91.1% 1 94.5% Sand Type Carbolite 16/20 Besser 1- 11566641 Pan SizeComp 1 Wt. % Comp 2 Wt. % Comp 3 Wt. % Comp 4 Wt. % Pan #12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan #16 5.8 6.2% 6.0 6.4% 8.0 8.4% 5.1 5.2% Pan #18 70.2 74.8% 66.4 70.3% 60.3 63.1% 63.2 64.8% Pan #20 17.3 18.4% 21.2 22.5% 27.0 28.2% 28.3 29.0% Pan #25 0.6 0.6% 0.8 0.8% 0.3 0.3% 0.9 0.9% Pan #30 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Total 93.9 100.0% 94.4 100.0% 95.6 100.0% 97.5 100.0% Retained 93.2% 92.8% 91.3% 93.8% Sand QC Page 12 A 1201 6000 Treating Chart - Zone 5 Attempt Treating Pressure (psi) A Slurry Rate (bpm) BH Proppant Conc (]b/gal) C Slurry Proppant Conc (Ib/gal) B Actual BH Temp ff) D Gauge BH Pres (psi) B C A C D 6 160 4 140 2 120 0 X100 11:00 12:00 13:00 14:00 15:00 3/17/2013 3/17/2013 Time Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 17 -Mar -2013 Sales Order #: 900295335 INSI7ErvS 1309.42 v4.4.0 Well Description: ODST 47 UWI: 50-703-20642 11-J-1309.42 Treating Chart - Zone 6 Attempt 1 Treating Pressure (psi) A Slurry Rate (bpm) B BH Proppant Conc (Ib/gal) C Slurry Proppant Conc (Ib/gal) C A B Actual BH Temp (°P) D Gauge BH Pres (psi) A C D 12000, 80 16 x160 1 4 [-140 2 X120 0 k-100 22:40 23:00 2320 23:40 00:00 00:20 3/18/2013 Time 3/19/2013 3/19/2013 Customer: PIONEER NATURAL RESOURCES - EBUS I Job Date: 17 -Mar -2013 Sales Order #: 900295335 INSITE -J S 13 0MCI v1.4.0 Well Description: ODST 47 UWI: 50-703-20642 1i-,hn.�3op;43 Treatment Plots Page 13 r reatmg rressure (psi) — BH Proppant Cone (lb/gal) A B Actual BH Temp (°F) — 120007 10500 P 1 Chart - Zone 6 Attempt 2 A Slurry Rate (bpm) C Slurry Proppant Cone (lb/gal) D Gauge BH Pres (psi) C A C D 6 160 4 140 2 120 0 100 13:00 13:20 13:40 14:00 14:20 14:40 15:00 3/20/2013 Time 3/20/2013 Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 17 -Mar -2013 Sales Order k 900295335 INSITEfa Stirnlatim vi.4.0 Well Description: ODST47 1 UWI: 50-703-20642 11-J-13 09 44 Treating Chart - Zone 7 A B Treating Pressure (psi) A Slurry Rate (bpm) B BH Proppant Cone (lb/gal) C Slurry Proppant Conc (Ib/gal) C A —.-I nv — I.— n -- ncr .-- 1-..:1 A C D 6 160 4 140 2 120 0 100 12:30 12:40 12:50 13:00 13:10 13:20 13:30 13:40 13:50 3/23/2013 3/23/2013 Time Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 17 -Mar -2013 I Sales Order 9: 900295335 INSfrEtar 1309:46 Well Description: ODST 47 UWI: 50-703-20642 11-J-1309:46 Treatment Plots Page 14 r Chemical Chart - Zone 6 Attempt 1 MO -67 Conc (gal/Mgal) A Losurf-300D Conc (gaVMgal) A CLr31 Conc (gaVMgal) A CLA-Web Conc (gaVMgal) A BE -7 Conc (gaVMgal) B A SP Breaker Conc (lb/Mgal) A W G36 Conc (lb/Mgal) B B 3 2 I1 0 22.40 23.00 23:20 23:40 00:00 3/18/2013 Time3/19/2013 Customer: PIONEER NATURAL RESOURCES - EBUS Jab Date: 17 -Mar -2013 Sales Order #: 900295335 INSRE far13 M.an v6.4.0 Well Description: ODST 47 UWI: 50-703-20642 11-Jun130947 Chemical Chart - Zone 6 Attempt 2 M0-67 Conc (gaVMgal) A Losurf-300D Conc (gaVMgal) A CL.31 Conc (gaVMgal) A CLA-Web Conc (gaVMgal) A BE -7 Conc (gaVMgal) B 111if10-11 Coea ;@b/l ,fgai} .��-. SP Breaker Conc (16/Mgal) A W&36 Conc (lb/Mgal) B I B 50 t0 E L 0 12:20 12:40 13:00 13:20 13:40 14:00 1420 3/20/2013 Time 3/20/2013 Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 17 -Mar -2013 Sales Order #: 900295335 INSRE for StirtaAation v1.4.0 Well Description: ODST 47 UWI: 50-703-20642 11 -Jin 130948 Chemical Plots Page 15 F 4 3 2 it 0 Chemical Chart - Zone 7 M0-67 Conc (gal/Mgal) A Losurf-300D Conc (gaVMgal) A CL31 Conc (gaI/Mgal) A CIA -Web Conc (gal/Mgal) A BE -7 Conc (gaUMgal) B SP Breaker Cone (lb/Mgal) A WG -36 Conc (lb/Mgal) B JILL -------- L-1 . . . . . . B 50 N E E R 1220 12:30 12.40 12:50 13:00 13:10 13:20 1330 13:40 3/23/2013 Time 3/23/2013 Customer: PIONEER NATURAL RESOURCES :IMUS Job Date: 17 -Mar -2013 Sales Order #: 900295335 INSITE faS 1309,.an v4.4.0 Well Description: ODST 47 11-J-1309,.49UWI: 50-703-20642 ff-�faosas Chemical Plots Page 16 1 1 Net Pressure Plot Zone 6 Attempt 2 — Net Gauge BH Pres (psi) A Time NetPr BPC Slope BH Proppant Conc (Ib/gal) B F(:j) 439.72 199.7 0.000 -0.095 A Slope of Net Pressure (psi/min) C B 10 100 Time (min) (0 = 793.066667) Customer: PIONEER NATURAL RESOURCES - EBUS I Job Date: 17 -Mar -2013 I Sales Order #: 900295335 Well Description: ODST47 UW, : 50-703-20642 Net Pressure Plot - Zone 7 - Net Pipe Friction to ROC (psi) A Time NetPr BPC Slope - BH Proppant Conc (Ib/gal) B 50.95 0.000 2.756 0.000 A Slope of Net Pressure (psi/min) C B I lU Time (min) (0 = 784.266667) Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 17 -Mar -2013 Sales Order #: 900295335 Well Description: ODST47 UWI: 50-703-20642 8 6 4 2 0 Net Pressure Plots Page 17 9:00 AM 9:30 AM Morning safety meeting Finished rigging down from the 25 well and moved iron to the 47. They set up containment and Crew rigged off the 25 well, Organized the storage hut, performed general housekeeping on the pad. 9:30 AM 6:00 PM Coil unit is frozen on the ODST-47 9:30 AM 9:30 AM Coil unit frozen on the 47 well. March 15, 2013 6:00 PM 6:00 AM Crew off for sleep 6:00 AM 6:30 AM Morning safety meeting 4:00 PM 6:00 PM Blow air through the surface lines and finish rigging out of the way so that coil could rig up March 18, 2013 6:00 PM 9:00 AM Crew off for rest Finished rigging down from the 25 well and moved iron to the 47. They set up containment and 9:30 AM Morning Safety Meeting. 9:30 AM heaters for the HES MC scale inhibitor. They also built new sample catchers with double stacked ball 11:30 AM 6:30 AM 6:00 PM valves. Chemicals were also sent to town to get reloaded. March 16, 2013 6:00 PM 9:00 AM Crew off for sleep; crew slept later in case coil was finished later in the evening 5:30 PM 9:00 AM 9:30 AM Morning safety meeting 7:10 PM Rig up to the ODST-47 8:48 PM Crew treated tanks with biocide and scale inhibitor. They also performed housekeeping and rigged up Zone 6 8:55 PM as much as they could to the 47 well. They also cleaned up around the movers and refilled 4 9:30 AM 6:00 PM supersacks. Bakersfield crew arrived to location. 6:00 PM 3:00 AM Crew off for rest March 17, 2013 3:00 AM 6:00 AM early crew rigged up to the 47 well after coil was out of the way ODST-47 6:00 AM 6:30 AM Morning safety meeting with remainder of crew. SO# 6:30 AM 8:00 AM Finish Rig -up 900295335 8:00 AM 8:27 AM Cement truck Pressure tested Zone 6 11:07 PM Cement truck attempted to shift the sleeve. Ran low on LVT. Shut down to swap over to frac crew. 8:27 AM 8:57 AM Cement was able to get injectivity at 3.5 bpm and 5400 psi. 9:30 AM 9:55 AM Pre Job Safety Meeting. 9:55 AM 10:25 AM Prime trucks and load ball dropper 10:25 AM 10:30 AM Pressure test with all trucks; no leaks 10:30 AM 10:40 AM Pressure test pop-off; no leaks 10:45 AM 10:55 AM Start pulling on water and hydrating gel. 10:55 AM 11:10 AM Attempt to establish injection rate. 11:10 AM 11:30 AM Reset pop-off to 9000 psi 11:30 AM 12:15 PM Not able to shift sleeve and establish injection rate. 12:15 PM 1:00 PM Blow air through the surface lines Conference call with Pioneerto determine next course of action. Customer requested more attempts 12:30 PM 1:15 PM to get the sleeve to shift. 1:15 PM 1:35 PM Reprime trucks 1:35 PM 3:00 PM Made 4 attempts to shift sleeve; never saw shift. 3:00 PM 4:00 PM Crew used hot water to clean out surface lines since LVT was not available. 4:00 PM 6:00 PM Blow air through the surface lines and finish rigging out of the way so that coil could rig up March 18, 2013 6:00 PM 9:00 AM Crew off for rest 9:00 AM 9:30 AM Morning Safety Meeting. 9:30 AM 11:30 AM Crew changed packing on an HT pump and performed housekeeping 11:30 AM 12:30 PM Supervisor crew change 12:00 PM 5:00 PM Crew off for rest in case job is ready to pump in the evening. 5:00 PM 5:30 PM Crew break for dinner 5:30 PM 6:00 PM Pre -Job Safety Meeting 6:00 PM 7:10 PM Rig up to the ODST-47 7:30 PM 8:30 PM Ak ind. Had a small Diesel spill of approximately .5 to 1 gal. It was reported and cleaned up 7:45 PM 8:40 PM Blockage in the lines; crew worked to find it and fix it. 8:40 PM 8:55 PM Pressure Test 8:42 PM 8:42 PM Pressure Test to 1284 psi; holding steady ODST-47 8:45 PM 8:45 PM Pressure test to 2898 psi; Walked the lines SO# 8:46 PM 8:46 PM Pressure test to 6033 psi; Walked the lines 900295335 8:48 PM 8:55 PM Pressure test to 8638 psi; found a small leak on the missile; bled off to fix. Zone 6 8:55 PM 9:15 PM Fix leak on missile. 9:15 PM 9:55 PM Prime remaining pumps. 9:57 PM 10:05 PM Pressure Test to 8997 psi; Walked the lines 10:05 PM 10:29 PM Pressure test Cement pumper and ball dropper 10:29 PM 10:49 PM Injection Test 10:49 PM 10:53 PM Come offline for ISIP. ISIP = 1528 psi; IFG = .74 psi/ft 10:54 PM 11:07 PM Resumed pumping. Drop Zone 6 Ball. 11:07 PM 11:08 PM Zone 6 Ball seated; kicked out trucks. Pre -seat was 5859 psi; trucks kicked out at 7775 psi. 11:08 PM 11:15 PM Attempting to get ball to seat. Highest pressure observed was 7698 psi. 11:15 PM 11:26 PM Got up to 18 bpm and came offline again. ISIP = 1578 psi; FG: .75 psi/ft March 19, 2013 March 20, 2013 March 21, 201: March 22, 201? March 23, 2013 ODST-47 SO# 900295335 Zones 5-7 11:26 PM 11:35 PM Customer decided to end job and clean up. 11:35 PM 12:10 AM Pumping fluid from the hydro. 12:10 AM 12:40 AM Pump LVT through surface lines. 12:40 AM 3:00 AM Evacuate lines and rig off of the 47 well. 3:00 AM 11:00 AM Crew off for rest. 11:00 AM 11:30 AM Lunch Break 11:30 AM 12:00 PM Morning Safety Meeting 12:00 PM 5:00 PM Work on pumps and blow air through all the surface lines. 5:00 PM 7:00 AM Crew off for rest. 7:00 AM 7:30 AM Morning Safety Meeting 7:30 AM 10:00 AM Waiting on SLB coil to get out of the hole 10:00 AM 10:15 AM Morning Safety Meeting 10:15 AM 11:00 AM Rig up to the ODST-47 11:00 AM 11:20 AM Load LVT onto the growler 11:20 AM 11:38 AM Flood surface lines with LVT. 11:38 AM 11:49 AM Pressure test with 1 truck; no leaks 11:49 AM 12:12 PM Start and Prime up rest of trucks 12:12 PM 12:20 PM Pressure Test all Pumps 12:20 PM 12:37 PM Had to change out a union seal on a piece of iron. 12:37 PM 12:38 PM Pressure test to 8920 psi 12:38 PM 12:55 PM Pressure test cement pumper and ball dropper to 8963 psi 12:55 PM 1:06 PM Injection Test 1:06 PM 1:11 PM ISIP and 5 minute leak off. Started job at 60 bpm; but reduced it to 45 per customer's request. Pressure began to rise during 7.5 ppg stage on formation. Cut sand but trucks kicked out. Could not get back into zone. Left 30,000 lbs 1:11 PM 3:00 PM in the wellbore and 275,000 lbs in formation. 3:00 PM 3:40 PM Used hot water to clean up per customer's request to conserve LVT 3:40 PM 5:00 PM Blow air through all the lines and remove residual water. 5:00 PM 6:00 PM Rig off the 47 well and turned it over to SLB Coil. 6:00 PM 6:00 AM Crew off for rest. 6:00 AM 6:30 AM Morning Safety Meeting Crew replaced 8" tub valve and actuator on the Blender. Checked valves and performed 6:30 AM 6:00 PM housekeeping on location. They also blew air and checked the blender. 6:00 PM 6:00 AM Crew off for rest. 6:00 AM 6:30 AM Morning Safety Meeting Diesel return line broke on the TCC. ACS was immediately notified and the crew cleaned it up after it 6:30 AM 9:30 AM was inspected. They removed the tractor to ensure all of the spill was taken care of. 6:30 AM 5:00 PM Waiting on SLB coil to get off the well. 6:30 AM 5:00 PM Crew got ready for job while waiting for SLB to finish their coil work. 5:00 PM 5:30 PM Pre Job Safety Meeting. 5:30 PM 6:30 PM Rig -up to the 47 well 6:30 PM 7:20 PM Prepare to prime up using 1 pump Could not get pump to prime up; shut down to go through it. Crew had blown air through the lines 7:20 PM 10:40 PM before the job. Found blockage around CBS. 8:00 PM Found sand residual and slush in the primeup line. 8:30 PM Stopped getting flow through PUBO 8:35 PM Break apart PUBO 10:40 PM Customer made decision to shut down for the night and resume the next day. 10:40 PM 11:50 PM All blockages have been removed from the iron; 11:50 PM 1:00 AM Start all trucks to prime them with LVT 1:00 AM 1:30 AM Crew supervisors checked location for proper setup to finish night. 1:00 AM 8:00 AM Crew off for rest. 8:00 AM 8:30 AM Morning Safety Meeting 8:00 AM 8:45 AM Waiting for LVT to be heated to 120 deg F. Remove cold LVT from lines; Set LVT outside overnight to ensure that it would still be liquid in the 8:45 AM 9:45 AM lines. No ice formed in samples 9:45 AM 10:20 AM Prime trucks with hot LVT 10:20 AM 10:30 AM had to change out a suction hose on a pumptruck. 10:30 AM 11:00 AM Pressure test with all trucks; no leaks 10:33 AM Test to 3740 psi 10:35 AM Test to 5897 psi 10:37 AM Test to 7340 psi 10:40 AM Test to 9010 psi 10:42 AM Test Cement to 9000 psi Flood Lines; could not get fluid into hydro; determined that hoses between ADP Blender and Hydro 11:00 AM 12:05 PM were blocked and needed to be replaced. 12:05 PM 12:20 PM Pull on water and hydrate gel. Performed Step -Rate test and analysis. Found indications of high Tortuosity. Customer increased pad volume and added 5,500 lbs of .5 ppg during first part of pad. Customer dropped rate from 50 to 45 bpm and went to sand on schedule. Screened out as sand was on formation; pumped 53,800 lbs of 12:20 PM 1:50 PM proppant. Left 14,200 lbs in the wellbore, placed 39,600 lbs in formation. 2:00 PM 5:00 PM Post Frac Meeting with Pioneer, HES, and Tech Team (Denver) 2:00 PM 2:45 PM Post Frac Cleanup; flood lines with Hot water 2:45 PM 3:45 PM Blew air through the lines. 3:45 PM 4:15 PM Flood surface lines with LVT. 4:15 PM 4:45 PM Blew air through the lines. 4:45 PM 5:00 PM Rig down complete; turned over to SLB Coil Pioneer Natural Resources Treatment Summary ODST-47 - Part 3 Zone 9 Alaska Section 11 Township 13N Range 7E API #: 50-703-20660 Torok 30# Hybor-G April 3, 2013 SO# 900339999 HALLIBURTON Pr- fHALLIBURTON Enhdinctt.n Table of Contents Section Page(s) Cover Sheet 1 TOC 2 Wellbore Information 3 Executive Summary 4-5 Stage Summary 6 Design Worksheet 7 Fann 35 OC 8 Lab C 9 Sand C 10 Treatment Plots 11 Chemical Plots 12 Net Pressure Plots 13 TOC Page 2 Customer Pioneer Natural Resources Formation Torok Lease ODST-47 - Part 3 Zone 9 API 50-703-20660 Date 4/3/2013 Sleeve/Pert HALLIBURTON Ball Hit Time Btm I Zone Sleeve Seat (Peak at Shift Wellbore Information Page 3 Treatment Flowpath Tubular Information Description Tubular Size FUF (gal/ft) Top Btm Volume Frac String 4.5" 12.6# P-110 0.6392 0 11938 ft 7,631 gal Production Liner 4.5' 12.6# P-110 0.6392 11938 17191 ft 3,358 gal ft 0 gal ft 0 gal ft 0 gal ft 0 gal ft o gal Total 10,988 gal Completion Tubular FUF (gal/ft) 4.5'11.6# 0.6392 Total MD 17191 ft at Shift Wellbore Information Page 3 HALLIBURTON Engineering Executive Summary On 04/03/13 a stimulation treatment was performed in the Torok formation on the ODST-47 - Part 3 Zone 9 well. The following information was gathered during the treatment. Sales Order #: 900339999 API#: 50-703-20660 30# Hybor G Volume: 75,003 gal 1786 bbls 30# Water Frac G Volume: 11,475 gal 273 bb/s 10# Water Frac G Volume: 20,650 gal 492 bbls End Hydro Strap Volume: 18,000 gal 429 bbls Total Fluid (Used): 125,128 gal 2979 bb/s Clean Fluid Downhole (No Hydro or LVT): 107,128 gal 2551 bbls Carbolite 16/20 Pumped: 146,900 lbs Formation: Torok Total Stim-Sleeve Zones: 9 Total Zones: 9 Net Pay Interval: 2425 ft Average Rate: 39.8 bpm Average Pressure: 4243 psi Maximum Rate: 41.1 bpm Maximum Pressure: 7763 psi Maximum Horsepower: 0 HHP Average Visc: 31 CP Average pH: 9.7 Average Temp: 86 deg F BE -6 Pre-treated in tanks: 30 lbs (.15 ppt) MC S-2263 Pre-treated in tanks: 50 gal (25 gpt) Prior to pumping the job, Quality Control tests were conducted on location to determine hydration time, crosslink time, and gel viscosity. Chemical concentrations were adjusted, as needed, according to test results, pump times, and onsite water. We appreciate the opportunity to service your well. If you have any questions about the job, or anything else, please call me at (970)-773-0592. Thank you, Drew Mogck Technical Professional Halliburton Energy Services Caitlin McCarthy Technical Professional Halliburton Energy Services Executive Summary Page 4 Treatment Information Executive Summary Page 5 Zone 9 Zone Summary Initial Rate (Breakdown): 5.35 bpm Initial Pressure (Breakdown): 1601 psi Max Rate: 41 bpm Max Pressure: 7,763 psi Average Rate: 40 bpm Average Pressure: 4,243 psi Max Horsepower: 6855 hhp Average Visc: 31 cp Average pH: 10 Average Temp: 86 F I S I P: 1675 psi Initial Fracture Gradient: 0.765 psi/ft Carbolite 16/20: 146,900 lbs Proppant Pumped: 146,900 lbs Proppant in Formation: 109,900 lbs 30# Hybor G Volume: 75,003 gal 1786 bbls 30# Water Frac G Volume: 11,475 gal 273 bbls 10# Water Frac G Volume: 20,650 gal 492 bbls End Hydro Strap Volume: 18,000 gal 429 bbls Comments: Pumped about 11000 gal into stepdown test stage at 40 bpm then lost boost to blender due to hydro being too low — had only loaded hydro with 15000 gal of 10# gel since we were swapping to 30# after to try to minim ize low visc fluid at start of zone. Started pushing gel again after dropping rate and got back up to 40 bpm for another 6000 gal before doing step down. Shut down at 20:30 for 30 mins then shut in well so we could move fluid in the lines to prevent freeze up. Remained down to complete analysis but keep moving fluid to prevent freezing up. After analysis of le akoff and conference call between location, Pio neer Anchorage and HES Denver, decision was ma de to get back in with the following schedule: 150 bbls xlink p ad 150 bbls 0.5 ppg sand 250 bbls xlink pad 100 bbls 1.0 ppg sand 250 bbls linear gel Started pumping again at 22:04 After each of the san d slugs hit bottom pressure dropped off each time and decision was made to start a 400 bbl p ad after the linear stage and then continue with the original design starting with 1 ppg and following the original schedule. Also pu mped 5% LVT in this pad as previously plan ned as a leakoff inhibitor (2 bpm LVT through cement pump up top with frac pum ping at 38 bpm). Shortly after stagin g to the 8 ppg stage the bottom hole gauge pressure started coming up and we cu t the screws and went to flush but scree ned out with only about 25 bbls flushed, which is all part of surface lin a volume. Left approximately 37000 Ib s of proppant in wellbore with 146900 lbs pumped, with about 109900 lbs placed in formation. Executive Summary Page 5 Customer Pioneer Natural Resources Well OOST-47- Part 3Zone 9 MALLIMURTON .......ion Formation Torok � Ennnncemnnc Stage Summaries 9 Planned Actuals Pressure I Rate I Visc I Temp I pH I Pressure I Rate I gal I bbl I gal bbl gal hhl gal hbl gal hhl gal bhl Ibs Ibs 4243 39.78 31 86 9.7 7763 41.08 75,003 1,786 11,475 273 20,650 492 0 0 18,000 429 125,128 2,979 Ig6,900 146,900 Stage Summary Page 6 Customer Pioneer Natural Resources 4/3/2013 API 50-703-20660 Lease ODST-49 - Part 3 Zone 9 MALLI®uwTON E d�mp Fnrmotinn Tnrnk Treatment Interval Stage Number Fluid Description Stage Description Proppant Description Prop Con. (PM) Slurry Rate (bpm Design Clean Volume (0a1) Design Clean Volume (bb Stage Time hh:mmaec Pump Time hh:mm:sec Actual Clean Actual Volume dol) Clear Volume bbl Design Prop Total fibs) Actual Prop Total lbs CL -31 Crosslinker (opt) MO -67 Buffer (cPt) CL -22 UC CLA-Web Crosslinker Clay Control (9Pt) (OPV BE -7 Biocide (9Pt) LoSurf 3ODD Surfadant (Opt) LVT-200 Third Parry Not) OPtlRo-ll Breaker (PPt) SP Breaker (PPI) WG -36 Dry Gel (PPt) 1 1011 Water Frac G Step-down Test 40 12,600 300.0 0:07:30 1:18:39 20,650 491.7 0.50 0.25 1.00 2.00 10.00 2 3011 Hybor G Shut In/Move fluid 0 0.50 0.25 1.00 3 Bop HyborG Pad 40 6,300 150.0 0:03:45 1:1109 6,340 151.0 0.50 0.80 0.90 0.50 0.25 1.00 4.00 1.00 30.00 4 30d HyborG PLF Carbolite 16/20 0.50 40 6,300 150.0 0:03:45 1:07:24 8,423 200.5 3,150 3,675 0.50 0.80 0.90 0.50 0.25 1.00 4.00 1.00 30.00 5 Sop Hybor G Pad 40 10,500 250.0 0:06:15 1:03:39 30,440 248.6 0.50 0.80 0.90 0.50 0.25 1.00 4.00 1.00 30.00 6 304 HyborG PLF Carbolite 16/20 1.00 40 4,200 IOD.O 0:02:30 0:57:24 4,911 116.9 4,200 5,068 0.50 0.80 0.90 0.50 0.25 1.00 4.00 1.00 30.00 7 30p Water Frac Spacer qo 10,500 250.0 0:06:15 0:54:54 10,356 246.6 1 0.50 0.25 1.00 4.00 1.00 30.00 B Sop HyborG Pad 40 16,800400D 01000 0:48:39 15,911 378.8 0.50 0.90 0.90 0.50 0.25 1.00 50.00 4.00 1.00 30.00 9 9 3011 Hybor G PLF Carbolite 16/20 1.00 40 4,827 114.9 0:02:52 0:38:39 4,684 111.5 4,827 5,196 0.50 0.90 0.90 0.50 0.25 1.00 4.00 3.00 30.00 10 30p HyborG PLF Carbolite 16/20 3.00 40 4,451 106.0 0:02:39 0:35:47 4,490 106.9 13,353 14,426 0.50 0.90 0.90 0.50 0.25 1.00 4.00 3.00 30.00 11 30p HyborG PLF Carbolite 16/20 5.00 90 6,883 163.9 0:04:06 0:33:086,952 165.5 34,415 35,390 0.50 0.90 0.90 0.50 0.25 1.00 4.00 3.00 30.00 12 3011 HyborG PLF Carbolite 16/20 7.00 40 11,234 267.5 0:06:411 0:29:02 11,248 267.8 78,638 ]8,1]0 0.50 0.90 0.90 0.50 0.25 1.00 4.00 3.00 30.00 13 3011 Hybor G PLF Carbolite 16/20 BOW 40 7,763 184.8 0:04:37 0:22:21 1,604 38.2 62,104 4,975 0.50 0.90 0.90 0.50 0.25 1.00 4.00 3.00 30.00 14 3011 HyborG PLF Carbolite 16/20 10.00 40 16,033 381.7 0:09:33 0:17:44 160,330 0.50 0.90 0.90 0.50 0.25 1.00 4.00 6.00 30.00 15 3011 Water I` -G Flush 40 6,192 147.4 0:03:41 0:08:11 1,119 26.6 0.50 0.25 1.00-1-1-4.00 6.00 30.00 End Hydro Strap Hydration Tank Volume 18,000 428.6 0.50 0.25 30.00 16 Freeze Protect Flush 20 3,780 90.0 604:30 0:04:30 1000.00 Test# 1 2 HALLIBURTON IE= 1 Gel Hydration 1 Water pH 7.47 7.47 t Min Visc(cP) Temp (F) Base Gel (#) 30 30 30 1 15 Fluid System: 30# Hybor-G 28 28 INFORMATION Testing done by: 3 i. Customer: Pioneer Natural Resources 6.84 Date: 6.84 _ 6 Well Name 80 Base Gel Temp (F)'. 75 75 75 _ i 9 Well Number: ODST-47 - Part 3 Zone 9 10.11 10.11 10.11 F v I 12 Well Location: Torok Crosslink pH 10.32 10.15 10.08 I ND (ft) 1 Final pH 9.35 9.28 9.09 BHST(F)i Test Temp (F) 125 130 130 1 I 1 1 Water Used •: Break Time (hr:min) 2:45 1:15 1:55 1 Test# 1 2 3 4 S Water Analysis: Chemical units 2750 1 Chemical Concentrations Temp (F) 80. S-2263 gpt 0.25 0.25 0.25 pH 7.47' BE -7 gpt 0.25 0.25 0.25 _ Specific Gravity 1.031 Losurf gpt 1.00 1 1.00 Bicarbonates (mg/L) 158 Claweb gpt 0.50 0.5 0.50 Carbonates(mg/L) 0 MO -67 .. gpt 0.70 0.7 0.70 Chlorides (mg/L) 22,730 CL -22 gpt ..._.... 0.90 0.9 0.90 _ Conduc[ivit Y (pS/cm)' 84,091. SP .gpt 1.00 3 1.00 Hardness (mg/L) 7,500 CL -31 gpt 0.30 0.3 0.30 Iron (mg/L) 0 ��. Opti -II ppt__. 4.00 ". 4 4.00 Potassium (mg/L) 2,000 po Resitivity(Dm)` 0 --- Temp5 Sodium (mg/L)- 4,024. 1250 1 40 Sulfates (mg/L) 3,600 _. TDS (mg/L) 55,500; 750 `calculated values Test# 1 2 3 4 5 1 Gel Hydration 1 Water pH 7.47 7.47 747_ Min Visc(cP) Temp (F) Base Gel (#) 30 30 30 1 15 80 .. Base Gel Visc (cP) 28 28 28 3 i. Base Gel PH 6.84 6.84 6.84 _ 6 26 80 Base Gel Temp (F)'. 75 75 75 _ i 9 120 Buffered pH 10.11 10.11 10.11 F v I 12 28 28 _ Crosslink pH 10.32 10.15 10.08 I 3250 1 Final pH 9.35 9.28 9.09 1 Test Temp (F) 125 130 130 1 I 1 1 1 Break Time (hr:min) 2:45 1:15 1:55 1 1 1 Farm Fann 35 Break Chart 1 i 1 I 1 1 1 1 I 4250 1 140 1 1 1 1 t 1 1 1 4000 1 1 1 1 I 1 3750 1 1 1 1 1 1 1 1 120 3500 1 I 1 I 3250 1 1 1 1 1 1 I 1 1 1 100 1 3000 1 1 1 1 1 1 1 1 1 1 1 2750 1 1 1 1 1 1 1 1 1 1 -Vic, 2500 1 1 1 80 VIsc2 I 1 1 1 1 1 1 1 1 2250 1 1 1 1 1 Visc 3 I 1 1 C Visc4 a 20001 1 81 1 _ViscS -Temp 1 1750 60 � - - Temp2 --- Tememp3 1500 po --- Temp5 1250 1 40 1000 750 500 20 250 0 0 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 125 130 135 140 145 150 155 160 165 170 175 180 185 190 195 200 Time (min) Farm 1 i 1 I 1 1 1 1 I 1 1 1 1 1 1 t 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 I 1 I 1 1 1 1 1 1 I 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 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 35 QC Page 8 Lab QC Page 9 JOB INFORMATION AND TESTING CONDITIONS Customer: Pioneer Fluid System: Hybor G Bob Type: B5X ell Name: ODS Main Line Water Source: Source Water Shear Rate (1/sec): 40 Date: 10/19/12 Temp. (*F): 122 Lab Project ID: RS2012-S0196 1 1 MU Test No: 1 2 3 5 7 8 7_c� Water Ana Sls Lot # Chemical units Chemical Concentrations Sample ID:W0136 WG -35 ppt 25.00 25.00 Specific Graxity 1.021 1.oSwf 300D an 1.00 1.00 Temperature ° 71.00 Cla-Web Opt 0.50 0.50 pH 7.27 MCS -2510T Opt 0.50 0.50 Conductivity S/cm) 35000.00 MC B-8630 ppt 025 025 Resistivity (62-m) 0.00 Iron (mg)L) 0.70 CL-22tiC w 0.90 0.90 Potassium ( 370-00 CL31 w 0.30 0.30 Sodium (mg/L)'t 7097.00 MO -67 "t 1.00 1.00 Calcium ( 308.80 Opt. -II pp? 4.00 1 4.00 Magnesium (mgl-) 933.10 SP Bleaker ppt 6.00 3.00 Chloride (mg/L) 13054.00 L 1900.00 mg/L) 0.00 m 1L 152.50 V 23100 alcalaatd --,,- Test No: 1 2 3 5 & 9 10 Gel Hydradm (S1Ls) Water pH 727 737 Mia Viscosity (cP) Temp. (oF): Base Gel (##) 25 25 1 9.0 70 Base Gel Visc (cP) 19.0 19.0 3 16.0 70 Base Gel pH 7.36 7.36 6 18.0 70 Base Gel Temp. (aF) 70 70 9 18.0 70 12 19.0 70 Crosslink pH 1025 10.11 Final pH 9.90 924 Test Temp. (eF) 108 122 Break Time (hr:mm) 7 39 056 Test Dotes: -Ync 1 -Yqc 2 ----Temp t ----Tamp 2 1800 - - _- -- 225 7 1600 200 1400 175 1200 t - y, 1000 !I I50 > 800 125 600------------------•._________-_-_________------.i..--�---- _ 100 400 200 75 I L 0 -------------------- ---- _----------------- ------------------ ------ -_________________________.__.__. 50 0:00 0:15 0:30 0:45 1:00 1:15 1:30 1:0.5 2:00 Elapsed Tf�. Immo Lab QC Page 9 Customer: Pioneer Natural Resources Well: ODST-47 - Part 3 Zone 9 Date: 4/3/2013 Formation: Torok Ticket #: 900339999 Sand Type Carbolite 16/20 ACE Mover - 10961036 HALLISURTON Pan Size Comp 1 Wt. % Comp 2 Wt. % Comp 3 Wt. % Comp 4 Wt. % Comp 5 Wt. 0.0 Pan #12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan #16 4.0 4.5% 4.9 5.5% 5.6 5.7% 5.5 5.5% 3.9 4.3% Pan #18 63.3 70.9% 65.7 73.6% 66.1 67.8% 69.2 69.7% 60.9 67.1% Pan #20 21.5 24.1% 20.3 22.7% 25.2 25.8% 24.4 24.6% 25.2 27.8% Pan #25 0.5 0.6% 0.9 1.0% 0.6 0.6% 0.2 0.2% 0.8 0.9% Pan #30 0.0 0.094 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan 0.0 0.0% 0.0 0.0% 0.0 0.0% 1 0.0 0.0% 0.01 0.0% Total 89.31 100.0%1 91.8 102.8%1 97.51 100.0%1 99.31 100.0% 90.81 100.0% Retained 95.0% 1 96.3% 1 93.6% J94.3% 94.8% Sand Type Carbolite 16/20 Besser 2 - 10193838 Pan SizeComp 1 Wt. 7 % Comp 2 Wt. % Comp 3 Wt. % Comp 4 Wt. Pan #12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.097. Pan #16 5.1 5.6% 6.1 6.1% 8.3 8.3% 5.3 5.3% Pan #18 65.1 71.3% 65.3 65.2% 65.2 64.9% 70.2 70.2% Pan #20 20.6 22.6% 28.3 28.3% 26.3 26.2% 24.3 24.3% Pan #25 0.5 0.5% 0.4 0.4% 0.6 0.6% 0.2 0.2% Pan #30 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.01 0.0% Total 1 91.31 100.0% 1 100.11 100.0% 1 100.41 100.0% 100.0 100.0% Retained 1 93.9% 93.5% 91.1% 94.5% Sand Type Carbolite 16/20 Besser 1- 11566641 Pan Size Comp 1 Wt. % Comp 2 Wt. % Comp 3 Wt. % Comp 4 Wt. Pan #12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan #16 5.8 6.2% 6.0 6.4% 8.0 8.4% 5.1 5.2% Pan #18 70.2 74.8% 66.4 70.3% 60.3 63.1% 63.2 64.8% Pan #20 17.3 18.4% 21.2 22.5% 27.0 28.2% 28.3 29.0% Pan #25 0.6 0.6% 0.8 0.8% 0.3 0.3% 0.9 0.9% Pan #30 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan 0.0 0.0% 0.0 0.07. 0.0 0.0% 0.0 0.0% Total 93.9 100.0% 94.4 100.0% 95.6 100.0% 97.5 100.0% Retained 93.2% 92.8% 91.3 % 93.8% Sand QC Page 10 1 A Treating Chart - Stepdown Test Treating Pressure (psi) A Slurry Rate (bpm) B BH Proppant Conc (lb/gal) C Slurry Proppant Conc (lb/gal) C B Actual BH Ternp (°F) D Gauge BH Pres (psi) A C D 6 x160 H 2 1-120 0 x-100 2020 20:40 21:00 2120 21:40 22.00 4/3/2013 Time4/3/2013 Customer: PIONEER NATURAL RESOURCES -EBUS Job Date: 03 -Apr -2013 Sales Order #: 900339999 INSfiE far131»lon vi.4.0 Well Description: ODST 47 UWI: 50-703-20642 10-J-1310,.32 A 1201 0 1500 Treating Chart - Zone 9 Treating Pressure (psi) A Slurry Rate (bpm) BH Proppant Conc (1b/gal) C Slurry Proppant Conc (Ib/gal) B Actual BH Temp (IF) D Gauge BH Pres (psi) C A C D 6 160 4 140 2 120 0 X100 22:10 22:20 2230 22:40 22:50 23:00 23:10 23:20 4/3/2013 Time 4/3/2013 Customer: PIONEER NATURAL RESOURCES - EBUS I Job Date: 03 -Apr -2013 Sales Order #: 900339999 INSITE far StirnJ�im v4.4.0 Well Description: ODST 47 UWI: 50-703-20642 11 -1 -13 -- Treatment Plots Page 11 Chemical Chart - Zone 9 A 4 3 9 0 MO -67 Cone (gal/Mgal) A Losurf-300D Cone (gal/Mgal) A CLr31 Cone (gaUMgal) A CL.A-Web Cone (gaUMgal) A BE -7 Cone (gaUMgal) B - SP Breaker Conc (]b/Mgal) A W&36 Cone (Ib/Mgal) B 1V AwtA L _ 0 20:00 20:20 20.40 21.00 21:20 21:40 22:00 4/3/2013 Time Customer: PIONEER NATURAL RESOURCES - EBUS Job Date: 03 -Apr -2013 Well Description: ODST 47 UWI: 50-703-20642 22:20 22.40 23:00 4/3/2013 B -50 -40 20 10 C Sales Order #: 900339999 NVSME far Sfi.JMm 1420 05 -Apr. 13 09:67 Chemical Plots Page 12 f Net Pressure Plot - Zone 9 Net Gauge BH Pres (psi) A Time NetPr BPC Slope BH Proppant Conc (Ib/gal) B �1 50.95 0.000 0.000 0.000 A Slope of Net Pressure (psi/min) C B Time (min) (0 = 1103.155496) Custorrer: RONE92 NATURAL RESOURCES - EBUS Job Date: 03 -Apr -2013 Sales Order #: 900339999 W1ell Description: ODST47 UVN: 50-703 20642 irlsrr sti^.naa^wzo Apr -131000 Net Pressure Plots Page 13 Job 6:00 AM 2:00 PM Crew off for rest. 6:00 AM 8:00 AM Rig down ADP blender so that Pioneer could perform tank maintenance. 8:00 AM 12:00 AM Pioneer removing water tanks to redo the support. Rig down from the 25 well and move over to the ODST-47. Crew took a couple pumps to OTP and 2:00 PM 7:00 PM performed housekeeping on the pad. 7:00 PM 5:00 PM SLB Coil Perforated Zone 9 with 6 spf 12,815' to 12830'. Perf Diameter was .36". April 3, 2013 7:00 PM 6:00 AM Crew off for rest. 6:00 AM 6:30 AM Morning Safety Meeting. Crew rigged ADP Blender back in. They blew air through the lines and got as much ready to go as 6:30 AM 5:00 PM possible while waiting for coil to finish their runs. 5:00 PM 6:30 PM Rig up to the ODST-47 well. 6:30 PM 6:45 PM Flood lines with LVT. 6:45 PM 6:50 PM Pressure test 1 truck; no leaks ODST-47 6:50 PM 7:36 PM Start and Prime remaining pumptrucks. SON 900 7:36 PM 7:40 PM Pressure test all surface iron to 9,200 psi; no leaks. Zone 9 7:40 PM 8:00 PM Set pop-off to 8,000 psi 8:01 PM 8:13 PM Open well and fill Hydration tank with 10# Linear gel. 8:13 AM 8:30 PM Performed Step -Rate Test. 8:30 PM 9:00 PM Monitored pressure for analysis. 9:00 PM 10:00 PM Closed wellhead to circulate surface iron to prevent fluid from freezing. Conference call with Pioneer and HES; made decision modify pump schedule to include lower 9:00 PM 10:04 PM concentration proppant. Job screened out towards the end of the stage. Placed 110,000 lbs in formation and left 37,000 lbs in 10:04 PM 11:02 PM the wellbore. Blew crush cap during 5 ppg sand; Approximately 20 gallons of Crosslinked Fluid spilled; reported to 10:45 PM ACS and Cleaned up. Approximately 10 gallons of crosslinked fluid and sand spilled from split discharge hose off of Missile; 10:45 PM reported to ACS and cleaned up. 2013 11:02 PM 1:00 AM Swapped to LVT and pumped it through all surface lines. Performed all post Frac Maintenance. PIONEER-1perations Summary Report - State Well Name: ODST-47 NATI IRAI PpRo l 1prpC Well Name: ODST-47 Contractor: Rig Number: Job Category: POST DRILL Start Date: 3/1/2013 End Date: Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 12/5/2012 12/6/2012 0.0 Hold PJSM. R/U Slickline equip. TP - 0, OAP - 480 psi, IAP - 0. FL @ 1201. M/U. RIH w/ 3.6" Bell guide & 2" RB. Set down @ 2384' SLM. POH. RIH w/ "GR" Latch & latch up on Dummy Insert. POH & UD same. M/U & RIH w/ 3.6" Bell Guide & 2" "RB" Set down @ 11033' SLM. POH & L/D Ball/Rod. M/U 4.5" "GR & latch on RHC @ 11038' SLM. Jar 2x& POH w/ RHC valve. R/D equip & secure well. SDFN. 12/6/2012 12/7/2012 0.0 Hold PJSM. RU W / 5'x 2.125" RLR, KJ, 5'x 2.125" RLR & LSS. RIH W / 4.5" x Line & x Catch. Set Catcher @ 2748' SLM. POOH OOH W / Tools SIBD Catcher Sub is Set. Freeze protect IA. Filled Annulus w/ 6 bbls. Pump add'I 3 bbls of diesel & insure annulus is not frozen. RIH W / 4.5" OK6 & 1.25" JDC LocK & Set down @ 2652' LSM POOH OOH W / Tools SIBD Shear Valve @ Surface RIH W 14.5" OK6 JK Running Tool & 1" DGLV W / JK -4 Hardened Latch Lock & Set down @ 2652' SLM Valve Set POOH. Pressure test IA to 3500 psi for 30 minutes. Lost approximately 50 psi in 30 minutes. Tubing held at 225 PSI throughout test. Once testing was completed IA bled too 600 psi. RIH W / 4.5" GR Latch Catcher @ 2748' SLM POOH / OOH W / Tools SIBD RIH W / 4.5" GS & 4.5 Frac Sleeve Min ID + 3.13" Purged lines with three gallns of Hydraulic Fluid throughcontrol line SD @ 2381' SLM, Begin hand jarring can feel some movement, attempt to get integrity unable continue jarring another 20 minutes. Feel more movement still no integrity work wire for approximately two hours POOH. OOH W / Tools SIBD. RIH W / 4.5 GS Latch Frac Sleeve @ 2381' SLM POOH. Inspected frac sleeve and found that the lower seals showed signs that they they were in the seal bore but no sign the upper seals were not engaged. Stuffing box was in need of re -packing. Re -packing completed crew houred out. R/D equip slickline equipment. Well secured. Approx. 13.5 bbls of diesel pumped for freeze protect and testing. 12/7/2012 12/8/2012 0.0 Hold PJSM. R/U Slickline equip. M/U 3.13" bore Frac Sleeve & RIH to 2381' SLIM depth begin hand jarring. Feel first set of seal packing enter seal bore but could not get second set started. Checked integrity of Frac Sleeve via pumping down control line. Pressure does not hold. POOH without Franc Sleeve. OOH. RIH with 4.5" G -Spear to 2381' and latch and retrieve Frac Sleeve. POOH. OOH with tools. Add 5' of 1.875" stem to tool string and RIH again to 2381' SLM depth begin hand jarring again can feel first set of seals enter seal bore after approximate 20 minutes of working wire. Still could not feel second set of seals enter seal bore. Check integrity pressure will not hold. Line up P-6 to pump down tubing at a starting rate of 1 BPM. Continue jarring frac sleeve, once P-6 achieved 1000 psi we had them hold that pressure while continuing jarring. Still could not get second set of seals into seal bore. Check integrity pressure will not hold. POOH without Frac Sleeve. OOH. Cut 1 00'of wire and re -head. RIH with 4.5" G -Spear to 2381' and latch and retrieve Frac Sleeve. POOH. RIH with 5' of 2.125"OD stem, two 3' of 2.125" OD stem with Brush to brush seal bore area. Make ten passes with the brush from 2367' to 2411' then POOH. OOH with tools. RIH with frac sleeve and 2.125" OD tools and stem to 2381' SLM depth and begin working wire for 20 minutes and checked for integrity. No positive signs of integrity. Have P-6 come on with pump and hold 1000 psi on tubing while working wire. Check integrity after 20 minutes of working wire. Still no integrity. POOH with out Frac Sleeve. OOH make up 4.5" G spear RIH and retrieve Frac Sleeve @ 2382' SLM Depth POOH. Once at surface you could see that all seals were engaged and that their was signs on the Frac Sleeve that it was no going on nipple. New Frac sleeve with new seals will be at OTP tonight and flown to ODS first flight in the morning. Wireline unit layed down all tools and secured well for the night. Page 1/14 ReportPrinted: 12/12/2013 1 PIONEER,perations Summary Report - Stag Well Name: ODST-47 NATI IRAI RFQr)llp :FC Page 2/14 ReportPrinted: 12/12/2013 Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 12/8/2012 12/9/2012 0.0 Hold PJSM. R/U Slick Line equip. P/U Brush assy (10'- 2.125" roller stem, 6'- 2.125" stem, oil jars, long stroke spangs and bristle brush). RIH to 2382' SLM, made several passes pull out of hole. Change out bristle brush with 4.5" GS and 4.5" frac sleeve, TIH with same, set down at 2382' SLM, hand jarred several licks, felt tools fall twice. Attempt to pressure test frac sleeve,would not hold pressure. Continue to hand jar several more times, attempt to pressure test, would not holding pressure. Release from frac sleeve and try to manipulate frac sleeve in place with string weight. Attempt to pressure test, would not hold pressure. Left frac sleeve in place with out control line integrity, giving seals time to expand and possible integrity test at later date. HES taking back up frac sleeve back to the shop to redress. HES released from location due to rig move, drilling will need crane for rig operations. Well secure wire line unit laid down. 12/9/2012 12/10/2012 0.0 Well work operations suspended due to rig moving from ODSN 29 to ODSN 24 12/10/2012 12/11/2012 0.0 Well work operations suspended due to rig moving from ODSN 29 to ODSN 24 1/3/2013 1/4/2013 0.0 Cost Place holder For Expro Rental Split between N -25,N-24, T-47, N-29 1/31/2013 2/1/2013 0.0 Cost Place holder for 1/4 of rental of Expro equipment 2/6/2013 2/7/2013 0.0 cost placeholder for spare 4" vetco valve. 3/1/2013 3/2/2013 0.0 Rig up HES frac crew on ODST 47. Move frac tree from ODSN 29 to ODST 47, install goat head, and rerun lines from same. Expro on location, starting to rig up. 3/2/2013 3/3/2013 0.0 Finish rigging up frac equipment, bucket test blender, heat LVF, frac water, ball drop trailer and cement unit. Pre Job safety meeting with all parties involved with frac. Spot LVT trucks, attempt to circulate across goat head. Was unsuccessful, trouble shoot same. Found ice and proppant plugs in check bleed off stop, 3 chicksan's and 40' joint. Cleared all but 40' joint, replaced same. 3/3/2013 3/4/2013 0.0 Begin Frac job at 00:00. Prime frac pumps, pressure test lines to 9000 psi, set pop off at 8000 psi. Frac well has design. Pressured up on P sleeve to open same, P sleeve open half way pumping with high pressure. abandon zone 3-6. Drop 2.563 ball to open frac sleeve's for zone 9-13, and frac same. Drop 2.625 ball to open frac sleeve's for zone 16-20, and frac same. Drop 2.688 ball to open frac sleeve's for zone 23-27, and frac same. Drop 2.750 ball to open frac sleeve's for zone 30-34, with 65 bbls pumped pumps kicked out due to high pressure. Blow back all frac lines, freeze protect same. Start filling frac tanks used and heat same. 3/10/2013 3/11/2013 0.0 cost placeholder 3/12/2013 3/13/2013 0.0 Rig up CTU # 6 on well. Move up right tanks, Expro lines and reverse manifold. 3/13/2013 3/14/2013 0.0 Spot CTU # 6 on well, put down herculite, spot 3 up right tanks, rig up Expro. Fill 3 up right tanks with 3% KCL slick water. Shut down due to frac job on ODSN 25. 3/14/2013 3/15/2013 0.0 LRS released from frac operations. R/U on coil unit # 6 to test BOP's. Pumped 1.5 bbls pressure built up to 3000 psi. Shut down due to ice plug in coil. R/U heater trunks on coil reel to thaw out coil. Set injector on deck and cover with visquene and heat entire coil. Found ice in the nozzle, cut 16' of coil, still ice, can not cut anymore due to length requirements. Continue to thaw. At 21:00 coil thawed out, circulate diesel through coil. Rig up to test BOP'S. Page 2/14 ReportPrinted: 12/12/2013 PIONEER")perations Summary Report - Stat( Well Name: ODST-47 NATIIRAI RFCr)llp :FC Page 3/14 Report Printed: 12/12/2013 Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 3/15/2013 3/16/2013 0.0 Finish testing BOP's, make up BHA with 2" ice pick nozzle, 2" stinger, cross over, double float check valve, cold roll connector.RIH while pumping pumping Hot diesel, did not tag any Ice, RIH to 3000' POOH, MU BHA with 1.75" reversing nozzle, and 2 stingers, pumping at 1.5 bpm down backside and taking returns up coil getting only about half returns. We discussed how could clean out and what the risks of reversing were and it was decided that we could not clean out by reversing. We attempted to do an injection into well starting at .5 bpm and ramp up at .5 bpm stages in attempt to seat the the ball, at 3 bpm the pressure continued to climb to 3500 psi, shut down the pressure bled off fairly fast, we tried it again in the because of the possibly the ball was on seat, the well pressured up to 4000 psi with no luck of shearing the sleeve. bled pressures off and and started pumping down backside, now getting full returns, continued to RIH at 80'/min to 7000', slowed ROP to 407min at 8477' density started to increase and we started to get proppant back in the fluid. Slowed ROP to 22to 25 ft/min. density was — 8.55 Ib/gal. At 18:00 @ 10,000' IA 562 psi OA 628 psi 23 fpm 1.5 bpm 970 psi. Continue clean out well to 15350' per plan forward. Make weight checks every 500' 3/16/2013 3/17/2013 0.0 At 14,069' IA 896 psi, OA 734 psi, density 9.01, 1.5 bpm, 1300 psi, 12 fpm. Continue clean out well per plan forward. At 15287' coil tubing measurements set down on ball (2.75" ball dropped on frac job). Pick up 40' to 15247' and slack off again to see if we tag at same spot. We tagged up at 15287', pick up 40' and clear coil with 33.7 bbls. While clearing coil we discussed our options, the decision was made to see if we could pump the 2.75" ball through the seat. After coil was cleared, we pressured up to 3500 psi, shut down pumps, pressure bleed to 1500 psi, pressure up to 4000 psi, shut down pumps pressure falling off. Bleed pressure off to 0. Set down 6,000 lbs and pressure up to 4000 psi, pressure still bleeding off. At this time we are waiting on 15% HCL to be delivered to job site, While waiting for acid, decided to try pressuring up again and it appeared, that we sheared the sleeve. injected at 2.5 bpm. It was decided that we would drop the 2.75" ball and chase it with coil with a 2.5" nozzle, pushed the ball on seat and attempted to shear the sleeve, pressured up to 4000 psi, multiple times and could not shear the sleeve, POOH At 18:00 at 13,600' continue POOH, will hold 200-300 psi on well head to try and keep 2.75" ball on seat at 14,975'. Freeze protect coil equipment with diesel, flush all surface with diesel. then blow down all surface equipment with gas. Start rigging down coil unit and support equipment. 3/17/2013 3/18/2013 0.0 Continue rigging down and moving coil unit, and up right tanks. Coil unit and up right tanks staged on ice pending ODST 47 frac. Rig up goat head and frac lines. Fluid pack lines with LVT and pressure test lines from cement unit to well head to 9000 psi. Open up to well and attempt to shift frac sleeve with 6,500 psi. On 3rd attempt to shift sleeve it started injecting at 3 bpm with 5,200 psi. Held frac meeting. Test all lines to 9,000 psi and set pop off at 8,000 psi. Apply 3500 psi to IA and open well. Start breakdown pad and was unable to inject. Attempt to shift frac sleeve with several attempts from 7,500 to 9,000 psi, unable to shift same. Consult with town and Baker. Attempt to shift frac with several attempts from 7,500 - 8,000 psi unable to shift same. Blow down lines and rig down goat head. Spot CTU # 6 and rig up same. And wait on 15% HCL, ETA midnight Page 3/14 Report Printed: 12/12/2013 PIONEER')perations Summary Report - Stat( Well Name: ODST-47 MAT[ IRAI RFSCII IRrFC I Page 4/14 Report Printed: 12/12/2013 Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 3/18/2013 3/19/2013 0.0 Test BOP's and surface lines to 400 psi low, 4000 psi high. Function test BOP's. Open well IA 584 psi, OA 566 psi, WHP 230 psi and TIH to 14975' and acidize balls, (2.75") at 90 FPM. Weight checks at 5,000' 10,6895 lbs - 10,000' 17,600 lbs - 12,000'20,000 lbs - 14,000'22,000'. At 14,900' slow rate to 13 FPM, went through 14975' did not see anything, went through 15,045' did not see anything, went through 15,123' did not see anything. Tag up at 15301', p/u to 15282', go back and re tag at 15301'. P/U 2' and spot 3 bbls of 15% HCL on ball, wait 15 min. P/U for weight check 26800 lbs. S/O went through 15301', tag up again at 15305', p/u 15282' slack off to 15305' with 2000 lbs weight. down and wait 15 min. P/U had 8,000 lbs over pull. Continue POOH to 11,900' for injection rates. Pumped at 2 bpm pressure started to build, Increased the rate to 2.5 pressure continued to rise, would not level out. Lowered rate to 1.5 bpm, rate leveled out at slightly less than 2000 psi, Start POOH, discuss with Anchorage team on next step. Decicision was to drop 2.813" ball and chase it with Coil to the ball seat at 14283' RKB. Dropped ball and tagged up 14277' CTM. Started pump down backside., pumped up to 4000' and let bleed off, bleed off rate increased appeared that we may have sfifted the sleeve RBIH, tag up same at! 4277' CTM, attempted to shift sleave by setting weight on the while pumping, Injection rate leveled out 4.5 bpm at 2800 psi, POOH, Rig down CTU # 6, R/U HES frac crew on well. Held pre -job safety meeting with all paries ionvolved. Pressure test all lines from frac pad to ODST-47 to 8997 psi for 10 minutes. Open welll and start injection test. Pump at 5 - 10 bpm at 4700 psi. increase rate to 15 bpm a 6500 psi. Shut down and drop 2.813" ball, pump at 15 bpm at 6500 psi. ball seated with 183 bbls gone, pressured to 7000 psi , which kicked pumps out. Brought pumps back on line, pressured up 7700 psi again kicking pumps out, Decision was made to acidize balls and pert. 3/19/2013 3/20/2013 0.0 Continue RID HES, freeze protect well, blow down all frac lines and de inventory equipment. Reload frac tanks w/3% KCL. Empty hydro and bleed tank. R/U CTU # 6, Expro and LRS to acidize (2) 2.813" balls with 10 bbls of 15 % HCL. Rig up Coil back up on the well, RIH to 14000', take weight check. Acid transport arrived on location, hooked up and pumped 10 bbls of acid while setting coil on ball at 14277' CTM, Pumped 5 bbls seawater, 10 bbls of acid followed by sea water. When acid hit the nozzle, the coil regained positive weight and RIH to 15062' while displacing the rest of the acid. POOH, cut off the coil connector, pickup extra lubricator. Make up Weatherford MHA, perform pull test to 25k, and PT MHA to 3500 psi. Pickup 10' of 2" Power flow 2006 big hole guns 6 spf , stab on well and PT backside to 2500 psi. RIH, 18:00 RIH at 5533'@ 116 FPM, IA 11 psi, OA 600 psi, with 10' of 2" 6 spf 2006 per guns. 19:30 @ 14541' CTM, p/u to verify stretch in coil. P/U to 14535' had 6' of stretch, S/O to verify once more with same result 6' of stretch in coil. Slack off to 14521' CTM, (tubing tally measurement is 14535'). Flagged the pipe. Measure ball OD to confirm 1/2" OD, load same in coil. 20:00 IA 59 psi, OA 606 psi, Pump ball to seat at 1.5 bpm 2600 psi. With 26 bbls gone slow pump rate to .5 bpm 950 psi. 20:30 Ball on seat with 34 bbis pumped, IA 210 psi, OA 639 psi. Shut in choke and continue pressuring up to fire pert guns. Seen firing head shear at 3019 psi. Pick up to 14370' and get injection rate at 4.5 bpm 1450 psi. IA 293 psi, OA 658 psi. 20:40 Shut down pumps, freeze protect and POOH to P/U second set of guns. I Page 4/14 Report Printed: 12/12/2013 PIONEER')perations Summary Report - Stat( Well Name: ODST-47 NATIIRAI RF4r)llp :FC Page 5/14 ReportPrinted: 12/12/2013 1 Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 3/20/2013 3/21/2013 0.0 OOH, all shots fired and ball retrieved. Break out spent guns. Make BHA ready for next perforating run. Witness 1/2" ball on seat in firing head, test MHA to 3700 psi. MU same to 2" Power flow 2006 big hole pert. guns. Stab on lubricator and test same to1660 psi on backside. Open well, IA 31 psi OA 599 psi. RIH at 100 FPM. At 14538' IA 203 psi, OA 623 psi. Get P/U weight 21,000 lbs. Continue P/U to paint mark, 14523' CTM, P/U 15' from paint mark, guns at 14508' CTM. Actual depth of pert guns is 14520'. Measure ball OD confirm 1/2" ball. Load same in coil and pump to seat at 1.5 bpm 2800 psi. With 26 bbls gone, slow rate to .5 bpm 990 psi. Ball on seat with 33.4 bbls pumped, continue pressuring up to fire guns, at 2880 psi guns fired. P/U to 14400' at get injection rate at 4.5 bpm 1395 psi.POOH, Rig up HES and frac, breakdown 6551 psi, max rate 60 bpm, Avg rate 49 bpm, Max psi 7697, avg psi 5429. Prop pumped 305 k lbs, left in wellbore 30k lbs, screened out on 7.5# prop. 17:00 hrs: RU CTU #6 with 1 3/4" Coil. Install BOP stack. Pull test Coil Connector at 10,000 lbs. Good. Make up BHA as follows: 2 ea MBTs, XO, 2.50" Reverse Nozzle. OAL = 9.017 -ft. Function test BOP Rams. Good. PT lines and Coil at 250/4,000 psi. Good. Open Master Valve and Swab Valve (both valves 23 1/2 turns). WHP = 1,140 psi. 21:00 hrs Start RIH reverse circulating with a 2.50" Nozzle a 60 ft/min,t 1.0 bpm, WHP 1,300 psi, Coil return pressure 5 psi. Nozzle at 2,000 -ft stop for weight check. up wt= 6,200 lbs, down wt = -3,000 lbs. Continue to RIH ai 60 ft/min, 0.9 bpm, WHP = 1,375, CP = 5, Return fluid density - 8.65 ppg, trace of Frac Sand. 22:15 hrs: Found top of Frac Sand at 3,700 -ft. Slow down running speed and begin to reverse through Frac Sand at 18 ft/min, WHP = 1,425, CP 10. Nozzle at 4,000 -ft. Stop for Weight check. Up wt = 9,000 lbs, down wt = -3000 lbs. Continue to reverse through Frac Sand. Increase rate to 1.5 bpm, WHP = 1,955, CP 10. 3/21/2013 3/22/2013 0.0 Nozzle at 7,000 -ft Weight check. Up wt = 12,500 lbs, down wt = -3,000 lbs. Pump rate - 1.5 bpm, WHP = 1,255, CP = 10, Fluid density = 8.5 - 9.5 ppg, running speed 22-ft/min. 5% Frac Sand in returns. Continue to reverse out Frac Sand. Nozzle at 8,000 -ft. Weight check. Up wt = 15,300 lbs, down wt = -3,000 lbs. Pump Rate = 1.5 bpm, WHP = 1,340, CP = 20. Fluid density = 9.1 ppg. 20% Frac Sand in returns, running speed 20 ft/min. Continue to reverse out Frac Sand. Nozzle at 9,000 -ft. Weight check. Up wt = 17,300 lbs, down wt -2,700 lbs, Pump Rate = 1.5 bpm, WHP = 1,190, CP 25. Fluid density 9.2 ppg, 25% Frac Sand in returns. Running speed at 18 ft/min. Continue to reverse out Frac Sand. Nozzle at 11,010 -ft. Weight check. Up wt = 19,800 lbs, down wt = -2,700 lbs, Pump Rate = 1.5 bpm, WHP = 1,850, CP = 75. Fluid density 9.34 ppg, 24% Frac Sand in returns. Running speed 17 ft/min. Continue RIH to reverse out Frac Sand, At 14521', start loosing pressure on backside and rate up coil. Quickly shifted from pumping down backside, to pumping down coil. Cleared the coil of sand and performed injection test. Started pumping down backside and coil, rate was 4.5 bpm at 1000 psi for a short period, then started to rise fairly rapidly then about 2800 psi the slope changed but would never level out, POOH, dropped 2.875" ball and chase to seat, tagged at 13650' CTM. Started Injection. Pressure started to and had a break and level for a short and continued to rise, 4.4 bpm at 3000 psi. RIH tag ball at same spot. The rate appeared to be the same as the earlier injection test, Alternate pressuring up on the well then bleed down in an attempt to weaken the shear screws until 10 bbls of 15% HCL. Pump 10.1 bbls of 15% HCL Acid at 0.5 bpm/675 psi. Spot Acid on ball at 13,660 -ft with 33.6 bbls of SW. Allow Acid to soak. Ball gone. Close choke. Inject Acid into well at 4.5 bpm/2,860 psi. RIH with CT to 14,000 -ft passed perforating depth of 13,810'- 13,814'. POOH. Begin weekly BOP test. Page 5/14 ReportPrinted: 12/12/2013 1 PIONEER1perations Summary Report - Stat( Well Name: ODST-47 NAT[ IRAI RF.qCII IRrp.q Page 6/14 ReportPrinted: 12/12/2013 1 Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (Ib/gal) Summary 3/22/2013 3/23/2013 0.0 Continue with the Weekly Coiled Tubing BOP Test. Perform draw down test. Perform a full BOP body test. Test Upper and Lower Blind Shear Rams at 250/4,000 psi. Test Slip Rams and Pipe Rams at 250/4,000 psi All test charted for 5 minutes each. All test, good. Test Pump Check Valve through the Coil at 4,000 ps x 5 minutes. Good test. Continue to maintain fluid temperature in Frac Tanks. MU Weatherford MHA, Perform pull test to 25K, PT connector to 3500 psi, MU HES 4'2" 6 sp HMX perforating guns and RIH.to 13825'. PU to verify stretch in coil, then correlate the stretch and 8' high that we have consistently hit the balls, PUH to 13805' CTM, 13814 RKB bottom shot. Drop 1/2" aluminum ball, pumped 32.8 bbl, ball on seat pressure up to 3600 psi, guns fired, PUH to 13704', Start injection test at 5 bpm down backside pressure rose to 2750 psi at -90 bbls broke back to 2150 psi and started rise again and rose to 3000 psi at 110 bbls pumped. Pressure broke back again at to 2430 psi and slowly started to drop at 200 bls rate was 4.7 bpm at 2350. Performed hard suht down. ISIP was 1700 psi, It was decided to do a 2 injection test, Test was 5 bpm at 2350 throughout the test with 80 bbls pump, A hard shut down, ISiP was -1700 psi, POOH, it was decided in a conference.call to rig down coil and rig up frac, Schlumberger Perf guns on location and standing by in case more perforations are needed. Prep for the Frac. PJSM. Prime up lines. Attempt to pressure test lines. However, an ice plug developed in one of the frac lines during the pressure test, The remainder of the night was spent isolating the ice plug then thawing same. 3/23/2013 3/24/2013 0.0 Frac aborted from previous day due to time spent on finding and thawing out an ice plug in one of the Frac lines. Crews houred out, Crews returned to work at 8:00, Prime up. Had a hose froze. thawed the hose, started Job, Pumped 100 bbl with 1/2#/gal 16/20 prop as part of the pad. Halliburton started the frac on ODST-47, performed a step up and a step down test, hard shut down. Started 900 bbl pad with the 1st 100 bbls with %# Proppant, 120 bbls 1 ''/#, 238 bbls 3#, and 67.3 bbls 4 'Y4. Cut sand and was able pump 75.8 bbls of flush before screening out, Total Proppant pumped 53,800 lbs, 39,600 # in formation, 14,200# in tubing average Pressure 6860 psi, and average rate 44bpm, MIRU CTU. Install BOP stack. Function test BOPS. Change Pack -offs. Install Coil Connector and pull test at 15,000 lbs. Make up a 2.50" Nozzle. Stab on Well. Pressure test Coil and Lines at 250/4,000 psi. Good. Open Swab Valve (23 1/2 turns). TP = 1,094 psi, IA = 0 psi, OA = 600 psi. Run in with the 2.50" Nozzle. Encountered thick Cross-linked Gel. Reverse circulate through Gel at a slow running seed due to the high WHPs (2,200 - 2850 psi). Weight check at 1,400 -ft. Up Wt = 1,590 lbs. Down Wt = -6175 lbs. Continue to work through Gel. However, WHIP starting to come down. Speed up Coil running speed. Weight check at 3,850 -ft. Up Wt = 5,050 lbs. Down Wt = -3,640 lbs. Also starting to see small amount of Frac Sand every once in a while in the samples. Found Top of Sand at 5,500 -ft. continue to reverse through Frac Sand. 3/24/2013 3/25/2013 0.0 MU and RIH with reverse nozzle, Reversed out crosslinked fluid, Continued in reversing at 1.5 bpm down backside and taking returns up tubing using slickwater. Started hitting hard streaks at 12800 to 13007' CTM, POOH to 12800' and RBIH to 13070' and started hitting hard streaks again was able to make it to 13086' CTM, could not pass through, worked by hitting with CT, worked for about an hour. Then switched from reversing to pumping down coil at 2 bpm.Tagged up at 13035' several times but made it past to 13060' where we tagged up, Picked back up and RBIH while pumping and tagged up hard at 13060' CTM, made multiple attempts and tagged up on hard bottom. POOH, MU 2"JSN, CV, 2 WT Bars, PT 250/3000, RIH,Tag up at 13039', Start jetting on plug at 1.6 bpm, 2000 psi and try to jet through obstruction. PU to 13000', RBIH while Jetting, tag up at same 13039'. Continue to jet through plug and worked down to 13,068 -ft. Short trip back to 12,950 -ft. RBIH. Got down to 13,069.4 ctmd. No further progress. Short trip back to 12,950 -ft. Run back in. However, set down at 12,975 -ft. Pull back to 12,965 -ft. Coil Nozzle stuck between 12,965' and 12,975'. Still have good returns at 2.25 bpm. Continue to work to free Coil. Got free. Pull back up hole to 11,500 -ft. Ease back in hole. Weight check at 12,056 -ft. Up Wt = 26,000 lbs. Down Wt = 700 lbs. Continue to slowly run back in. Weight check at 12,800 -ft. Up Wt = 28,000 lbs. Down Wt = 700 lbs. Circulating pressure 2,475 psi at 1.8 bpm. Continue to slowly run back in. Pass through 12,965'- 12,975'. Continue to run in. However it appears that we are pushing sand bridges. Got down to 13, 028 -ft and set down again with negative Coil weight. Discuss plan forward. Pull out of the hole to exchange Jet Swirl Nozzle for the Reverse Nozzle. Inspect the JSN for a clue to indicate what the down hole obstruction might be. Saw nothing. Page 6/14 ReportPrinted: 12/12/2013 1 PIONEER-1perations Summary Report - StatF Well Name: ODST-47 NATIIRAI RFS(IIIRf:F.q Page 7/14 ReportPrinted: 12/12/2013 1 Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 3/25/2013 3/26/2013 0.0 Make up the 2.50" reverse nozzle. Stab back on the Well. Pressure test at 250/4,000 psi. Good. Start back in thehole. Bring Pump back on at minimum rate. WHP = 160 psi. CP = 5 psi. Weight Check at 5,000 -ft. Up Wt = 10,400 lbs. Down Wt = 500 lbs. Continue running in. Found a sand bridge at 11,100 -ft. Reverse through. Weight check at 11,300 -ft. Up Wt = 19,900 lbs. Down Wt = -3,600 lbs. Rate 1.5 bpm, WHP = 1,620psi, CP = 5 psi, Sample returns 10% Frac Sand, trace of Drilling Mud. Continue Reverse circulating in. At 12,500 -ft. lost all returns. Pull back up hole heavy. Swap flow path and pump down the Coil. Continue pulling up hole. Swap flow path back to reverse circulate. Continue pulling up hole to 11,950 -ft. Starting getting returns back. Park nozzle. Now getting full returns back. Rate 1.5 bpm. WHP 1,350 psi. reverse Coil volume. Returns sample 6% Oil, 1 % Sand. Continue to reverse circulate back in hole. Weight Check at 12,700 -ft. Up Wt = 21,500 lbs. Down Wt = -3,500 lbs. Full returns. Sample 100% KCL, trace of sand. Continue running in. Weight check at 13,025 -ft. Up Wt = 22,000 lbs. Down Wt= -4,400 lbs. Continue in. Set down at 13,040 -ft. Reversed through sand at 1.5 bpm down to 13,058 -ft where forward progressed stopped. Pick up weight = 21,500 lbs. Set back down at 13,058 -ft and increased rate to 2.3 bpm. Started making slow progress down to 13,064 -ft, RIH. Work to 13078' PU, pull 12k pulled free, POOH, and stand back injector for symops with frac on ODSN 24, Crew is standing by. Frac on ODSN-24 completed. Rig back up on Well. 3/26/2013 3/27/2013 0.0 Pressure test at 250/4,000 psi. Good. Stage Vac Trucks. Open Well (23 1/2 turns). Start RIH with a 2" Swirl Nozzle. Pump rate at 0.5 bpm/535 psi. Record weight check as needed. Nozzle at 11,775 -ft. Start a 10 bbl Gel Sweep down the Coil. Continue RIH. Set down solid at 13,065 -ft. Increase pump rate to 2.0 bpm/1,875 psi. Weight check. Up Wt = 23,000 lbs. Drop back down to 13,065 -ft. Make slow progress down to 13,076 -ft. Pump 20 bbl Gel Sweep. No further progress from 13,076 -ft. Short trip up to 10,500 -ft to chase Gel Sweep up hole. Run back down. Tagged solid at 13,045 -ft. Pulled free with 33,000 Ibs.(10,000 lbs over previous weight check). Spot and Ieavel0 bbls of Gel at 13,045 -ft. Start pulling out of the hole while pumping KCL. MU Baker CTC 2.25" OD, DCV 2.13" OD, Bowen up/down jars 2.13" OD, DC (3/4" ball) 2.13", Motor 2 1/8" OPD, Circ sub 2.13", 5 blade Junk Mill. Pull test CTC to 20k. PT connector L/H 250/3700 psi. Stab on well, Fluid pack lubricator, verify motor is working. PT lubricator to 2000 psi, Open well,RIH. take weight checks at 11000'21 K, 12500'23k. and 13000' 24 k. Continue in hole, hit weight bobble 13040' continue RIH, stack up 13064' , PU to 13030, start pumping at 1.5 bbl/min RIH to 13066', no motor work, RIH to 13071' still no motor work clean PU. RiIH to 13075" PU 6k over, pump 5 bbls of GeoVis, Make multiple attempts to go deeper but stacked up at 13076' at the deepest, Each attempt to go down and 13040' there would be a weight bobble and an indication of some motor work. It appear that something was moving as we would set down at different depths past 13045', made one more trip to 13076', it was decided to POOH and discuss the finding with the Anchorage team. The tools got stuck at 12857' appears that the motor is stalled. Pump 10 bbis of Geo vis around the BHA, continue working the coil. Pump 33 bbls (Coil volume) Geo Vis Gel to the nozzle at 0.5 bpm/2,538 psi. Chase up the backside with KCL. 3/27/2013 3/28/2013 0.0 Midnight to 06:00 hrs, 03/27/2013 Update: Continue to work stuck Coil up to 12,804 -ft. However, having to pull near the maximum allowable limit. Pump a Coil volume of Diesel to lighten Coil pick-up load and to freeze protect the Coil. Attempt to pull Coil free. No -joy. Decide to continue pumping Diesel up the backside. Diesel returns to surface. Swap to pump Diesel down the backside. Slack off Coil to negative down weight. Bring pump on at maximum rate. Observe Coil weight on weight indictor go to positive. Pick up on Coil at 20-ft/min. Coil now free. Slow pump rate and continue to pull slowly up to 12,500 -ft. End pumping. Continue to pull of the hole with the BHA. BHA at surface. Close Swab Valve (23 1/2 turns). Blow down lines and lubricator. Lift Lubricator off of the Well. Lower BHA out of Lubricator and inspect tools. Mill had rotational wear on the outside and had several scratches on the side, indicating MITI was working in junk. Rig down and move unit to ice pad to do maintenance on chains. Well is fuid packed with diesel . 3/31/2013 4/1/2013 0.0 Cost place holder for expro equipment 4 well split 4/1/2013 4/2/2013 0.0 cost place holder 4 well split Page 7/14 ReportPrinted: 12/12/2013 1 PIONEER1perations Summary Report - Statr Well Name: ODST-47 NATI1PAI RF4r)llP :F4 Page 8/14 Report Printed: 12/12/2013 1 Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (Ib/gal) Summary 4/2/2013 4/3/2013 0.0 MIRU Schlumberger CTU # 6 with1 3/4". Install BOPs and function same. Good. Hook up lines. Pick up Lubricator. Make up Coiled Tubing connector and pull test to 25,000 lbs. Good. Continue to make up the remainder of the BHA as follows: Dual Back Pressure Valves, Oil Jars, Hydraulic disconnect (5/8" Ball), Centralizer, HippTripper tool, and a solid 3" Ball (with upper ports). Max OD = 3.00". Total BHA length = 16.53 -ft. Stab on Well. Pressure test the Lubricator and lines at 250/4,000 psi. Good. Open Swab Valve (23 1/2 turns). WHP = 450 psi. Start run in the hole with the Hipp Tripper. Perform weight checks as necessary. 4/3/2013 4/4/2013 0.0 Continue to run in the hole with the Hipp Tripper. Stop at 12,500 -ft. Perform and injection test at 1.0 bpm. Final WHP = 2,300 psi. Weight Check, 24,000 lbs. Continue to run in the hole to 12, 671 -ft. Cycle Hipp Tripper Tool 20 times. No luck in shifting the Sleeve. Flag Coil and pull out of the hole while freeze protecting the Coil.Lay down Hipp -Tripper and Jars, Pull test CTC to 25k, PT CTC to 3500 psi. MU 15' of 2" guns 6 spf 60 deg Phasing PF HMX 6.5 gm charge. Stab on well, PT backside UH 250/2500 psi. bleed down to 150 psi, open WH, RIH, At 12830' drop 1/2" ball and circulate down to firing head, at 3200 psi the guns fired. Pull up hole 600' and get injection rate at 4 bpm 2350 psi. POOH and freeze protect coil and all surface lines. All guns were fired, holes shot at 12815'- 12830' Rig down CTU # 6 and send to Deadhorse for service. Rig up HES frac equipment on well. Fluid pack lines w/LVT and test same to 9000 psi, Good test. Set pop off at 8000 psi, and kick out at 7800 psi. Pressure test LRS to 4000 psi, Good test. Open well and put 3500 psi on IA w/LRS. Start pumping 300 bbls of 10 # frac gel, bring rate up to 40 bpm at 6100 psi. Do step down test w/ 29 bpm 4435 psi, 20 bpm 3475 psi, 12 bpm 2573 psi. Shut down with 436 bbls pumped, and wait on results from town. Results of test; pump 150 bbls cross link at 6000 psi, 150 bbls .5ppa proppant 4600 psi, 250 bbls cross link flush 4500 psi, 100 bbls 1 ppa proppant 4160 psi and 250 bbls linear gel 4100 psi. Proppant size 16/20 carbolite. Pump 381 bbls of cross link w/ 19 bbls of LVT at 40 bpm 4100 psi. Pump 114.9 bbls/1 ppa at 40 bpm 3900 psi, pump - 106 bbls / 3 ppa at 40 bpm 3650 psi, pump - 163.9 bbls / 5 ppa at 40 bpm 3800 psi, pump - 267.5 bbls / 7 ppa at 40 bpm 4350 psi. Max recorded bottom hole pressure came up to 11,020 psi, drop pump rate to 30 bpm and swap to flush, pressure increase drop pump rate to 25 bpm. System locked up. Freeze protect all surface lines and de inventory same. 4/9/2013 4/10/2013 0.0 Cost placeholder for GLV's. 4/10/2013 4/11/2013 0.0 Coil operations shut down till high pressure break down is complete on ODSN 23i. CTU # 6 is spotted with mass up, and BOP's on well. At 16:00 SLB crew finish rigging up on well. Test BOP's and injector head. Unit will be doing a reverse clean out and station flush. Replacing rollers on injector head. Changeout packoffs, perform bearing inspection, changeout 7 bearing and 1 gripper block, P/U inj. head, M/U CT connector and pull test to 15K (lbs), test good. R/U reverse out manifold and flow lines, R/U low pressure manifold, stab on well w/BOP stack and lubricator. Begin BOP test. 4/11/2013 4/12/2013 0.0 Pressure test all lines and rams to 250 low/ 4000 high. Pop off stack and P/U two 4' stingers, 6" nozzle w/ 1.75" OD and 15/16" bore. Stab onto well, open well. TBG pressure= 220 psi, IA= 0 psi, OAP= 578 psi. RIH w/coil and tag up @ 2,315' CTMD, P/U and begin to reverse out @ 1.5 (bpm) & 1450 (psi). Wash sand and frac fluid @ 20 ft/min. At 6:00: Coil tubing depth 5268', reversing out at 1.5 bpm, WHP 952 psi, IA 100 psi, OA 736 psi, 11.3 FPM. Doing weight checks every 500'. Adjusting FPM from 5-18 FPM due to WHP, monitoring pressure from 950 psi - 1500 psi. We are taking returns back to Expro. Continue to reverse out @ 1.5 bpm, 2100 psi circulating pressure. Increase to 20 fpm, reverse out to 12,800' CTMD. Final weight check 20,500 (lbs). POOH. UD 1.75" reverese out nozzle. Report after midnight continued below. 4/12/2013 4/13/2013 0.0 M/U 2.5" ball drop swirl nozzle w/ 3/4" ball on seat. Stab on well, PT 250/4000 psi. RIH flush XN nipple at 11,045'. PU and flush GLMs @ 10,944', 8,595', 5,580', 2,674'. Flush X nipple @ 2,776' and HES frac sleeve @ 2,410'. Flushed @ 1 bpm, 1800 psi. Work up and down through each piece of jewlery 3 times. POOH, secure well, R/D SLB CTU #6 @ 04:30 hrs. 4/16/2013 4/17/2013 0.0 Rig up HES wire line on well to start valve swap. Change out tools & inspect wire. Troubleshoot SSSV pump. M/U & RIH w/ 3.84" Gauge Ring, 5'- 1 7/8" Roller Stem, OJ & Spangs. Stab on wellhead & PT to 1000 psi. RIH to 2392' SLM. Engage & pull Frac Sleeve. POOH, Had leaking valve. Vetco serviced valve. Blow down break off lubricator & recover Frac Sleeve. M/U 4 1/2" GS, Stab on well & test lubricator to 1000 psi. Page 8/14 Report Printed: 12/12/2013 1 PIONEER1perations Summary Report - Stat( well Name: ODST-47 IUATIIRAI RFC()IIPr..PC Page 9114 ReportPrinted: 12/12/2013 Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 4/17/2013 4/18/2013 0.0 BHA - 61.875" roller stem w/2.20" OD wheels -Knuckle JT- 10' roller stem w/2.20" OD wheels - Oil jars -Long stroke spangs - GS tool. RIH & set catcher @ 11040' SLM, 11042' MD. POOH and inspect tools. M/U 4 1/2" QC OK6, 1 1/4" JDC. Stab on & PT lubricator to 1000 psi. RIH to 10936'& attempt to pull DGLV. No success. Pull up to station #3 @ 8580' SLM 8593' MD. Locate & jar down & engage DGLV. POOH Blow down & L/D DGLV from 8580' SLM. M/U 4 1/2" QC OK6, 1 1/4" JDC & Knuckle jt. Stab on well & PT. Change BHA to knuckle joint above OK 6. RIH to station4 @ 10936'. No success. POOH to inspect tools. Reconfigure BHA with 3.60" OD centralizer and 3' stem above OK 6 and TIH to station 4 at 10933' SLM, 10942' MD. POOH and inspect tools. No success, we were latching but not good enough to pull valve. Reconfigure BHA took out the 3.60" OD centralizer and 3' stem. TIH to station 4 at 10933' SLM, 10942' MD, locate on valve and work slick line to latch the valve. POOH to inspect tools. Valve was pulled. Lay down lubricator and re pack stuffing box. Crane had pick on other side of Well Bays. R/D & then R/U after pick. Repack stuffing box & check/test wire. Tie new rope socket. M/U Stiff OK6 ,1.25" JDC. Stab on well. PT & RIH to 5560' SLM. Locate, Jar Down & POOH. Bleed off & check tools ... no recovery. Stab on well & PT. RIH w/ same stiff assy to 2658' SLM. Locate & jar. POOH, bleed down & Recover DGLV from station #1 @ 2658' SLM. Redress same stiff assy, Stab on wellhead & PT. RIH & locate @ 5560' SLM jar down & P/U. POOH, Bleed down & recover DGLV from station #2 @ 5560' SLM. R/D lubricator & Secure well. S/D. Crew houred out. Resume operations in the AM. 4/18/2013 4/19/2013 0.0 At 8:30am HES crew back on the unit. Rig up to well. BHA - 5' 1.875" roller stem w/2.20" OD wheels - Knuckle JT - 10' roller stem w/2.20" OD wheels - Oil jars - Long stroke spangs - OK 6 tool. Stab on lubricator and test same to 1000 psi. TBG 275 psi, IA 0 psi, and OA 600 psi. TIH to second station at 5577' MD, 5564' SLM, latch on the dummy valve, and work slick line several times. POOH to inspect tools. Valve was pulled. Trip back into the hole to set 1"-1/4" orifice valve w/tro 1615 psi in station 1 at 2672' MD, 2648' SLM, POOH to inspect tools. Reload OK 6 with station 2 valve. TIH to 5577' MD, 5569' SLM to set 1"-1/4" orifice valve w/tro 1638 psi. POOH to inspect tools. Reload OK 6 with station 3 valve. TIH to set 1"-1/4" orifice valve w/tro 1625 psi, in station 3 at 8593' MD, 8588' SLM, POOH to inspect tools. Redress tools. Stab on wellhead & PT. RIH w/ 4 1/2" OK6, JK, & 1" BK. Locate & set 5/16" OV in station #4 @ 10941' SLM. POOH, bleed off & check tools. Valve set in station #4. Redress tools. Stab on wellhead & PT. RIH w/ 4.5" GR. Tag up, set down & engage catcher @ 11040' SLM. POOH bleed down. Inspect tools. Recovered catcher. R/D Slicklinje equip. Secure well. SDFN. Crew houred out. 4/19/2013 4/20/2013 0.0 HES back on unit. Rigging up to set frac isolation sleeve at 2407' MD. BHA - 15' 1.875" roller stem - long stroke spang - GS tool. Pick up lubricator and make up same and test to 1000 psi. TIH to 2385' SLM, 2407' MD, set frac isolation sleeve in XXO SVLN and test same to 2000 psi. Good test. POOH rig down slick line from well. 4/23/2013 4/24/2013 0.0 Cost place holder for equipment and demob. 5/6/2013 5/7/2013 0.0 Cost placeholder 5/8/2013 5/9/2013 0.0 Vetco made up second swab valve to ODST-47. EXPRO rigging up to ODST47 for flow back activities. 5/9/2013 5/10/2013 0.0 Complete rig up and pressure test of all EXPRO equipment. Open up well ODST-47 and begin flowback to flowback tanks at 12:00, Initial WHP 160 psi. IAP 72 psi3OAP 603 psi, BHP 2224 psi. Start LG at 405 MSCFD. 17:00 WHP - 196 psi / CK -30 / IAP - 1197 psi / BHP 2231 psi / LG —466 mscf /Gas flow -209 mscfd /Cum gas- 7.08 mscf/ BOPD - 388.8 bbls / BWPD —2331.2 bbls / Cum Oil 57.42 bbls/ Cum Wtr — 54,58 bbls / BS&W 46 %/ diesl —54% /H20 -46% TR oil /Sediment -0.%/sand at sand trap 0% open choke to 38/64 24:00 WHP - 80 psi / CK -38 / IAP - 1234 psi / BHP 1793 psi / LG —464 mscf /Gas flow -473 mscfd /Cum gas -175.52 mscf/ BOPD - 128 bbls / BWPD —192.96 bbls / Cum Oil 99.93 bbls / Cum Wtr — 185.07 bbls / BS&W 60 %/ Oil —40% /H20 -60% /Sediment -Trace/ Page 9114 ReportPrinted: 12/12/2013 PIONEER')perations Summary Report - Stat/ Well Name: ODST-47 N4TIIRA1 RFCr)lIPr'r:C Page 10/14 ReportPrinted: 12/12/2013 Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (Ib/gal) Summary 5/10/2013 5/11/2013 0.0 Continue to flow back ODST-47 through EXPRO equipment and into Operations tank farm. 00:00 WHP - 80 psi / CK 42 / IAP - 815 psi / BHP 1793 psi / LG -464 mscf /Gas flow -473 mscfd /Cum gas -175.52 mscf/ BOPD - 128 bbls / BWPD -192.96 bbls / Cum Oil 99.93 bbis / Cum Wtr - 185.07 bbls / BS&W 60 %/ Oil -40% /H20 -60% /Sediment -Trace/ 09:00 HR, WHP 241 psi, Chock 48/64, IA 831 psi, BHP 907 psi, Lift Gas 846,000, BOPD 270 BBL, BWPD 406 BBL, Cum Oil 195 BBL, Cum H2O 406 BBL, BSW 60.00 12:00 WHP - 150 psi / CK -58 / IAP - 1234 psi / BHP 900 psi / LG -1125 mscf /Gas flow -1028 mscfd /Cum gas -594.74 mscf/ BOPD - 52.8 bbls / BWPD -67.20 bbls / Cum Oil 238.81 bbls / Cum Wtr - 403.2 bbls / BS&W 52 %/ Oil -48% /H20 -51.95% /Sediment -.05/ 15:00 WHP - 71 psi / CK -128 / IAP - 635 psi / BHP 815 psi / LG -0 mscf /Gas flow -526 mscfd /Cum gas -710 mscf/ BOPD -1.1 bbls / BWPD -67.2 bbls / Cum Oil 265.95 bbis / Cum Wtr - 483.15 bbls / BS&W 56 %/ Oil -44% /H20 -56% /Sediment -Trace/ Shut off Gas lift, Close in well and let BHP and WHP build up. WHP rose 335 psi, BHP 941 in 3 1/2 hrs, Open well WHP went 0, BHP continued to buiild, Start GL at 500 Mscf/d. 24:00 WHP No flow noted - 12 psi / CK -48 / IAP - 1032 psi / BHP 2057 psi / LG -476 mscf /Gas flow 0 mscfd /Cum gas -d710 mscf/ BOPD -0 bbls / BWPD -0 bbls / Cum Oil 266.85 bbls / Cum Wtr- 483.15 bbls / Preparing for coiled tubing job. Contacted CH2MHill, Schlumberger and Halliburton. Coordinated activities with Nanuq on moving equipment. 5/11/2013 5/12/2013 0.0 ?Continue flowing ODST-47 through EXPRO equipment with solids going to there sparge tank. The rest of the fluids to Operation and there tank farm. Three upright tanks are full with 3% KCL and 4 gallons of DR -204 friction reducer per 290 bbls. Two CH2 325 bbl Vac trucks with 290 bbls of the same on location. CH2 90 bbls Mini Vac on location with 80 bbls GioVis. SLB hand on location at 13:00 hrs with lowboy. Moving SLB equipment. Time: 17:00 WHP: 211 Choke:128 IA: 1137 BHP: 781 UG: 2027 BOPD:31.68 BWPD: 285 CUM Oil:423 CUM H2O: 622 BS&W= 90% H2O, 10% Oil and Trace Sediment Mud just hit surface and is carrying about 1.5% Frac Sand Time: 24:00 WHP: 182 Choke: 128 IA: 1089 BHP: 829 UG: 2038 BOPD:350.88 BWPD: 165 CUM Oil:469.86 CUM H2O: 681.89 BS&W= 32% H2O, 68% Oil, Trace Sediment Sparge sand trap @23:50, API = 23.9 corrected Salinity = 28,000 ppm 5/12/2013 5/13/2013 0.0 Continue to flow well by shuttinglet pressure build and surgeing the well . Prepare SLB equipment for fill cleanout. Time: 06:30 WHP:1464 Choke: 128 IA: 1449 BHP: 2040 Lift:0 BOPD: 0 BWPD: 0 CUM OIL: 521 CUM H2O: 719 BSW: 0 Time: 18:00 WHP:200 Choke: 128 IA: 1152 BHP: 745 UG: 1815 BOPD:80.2 BWPD:721.4 CUM Oil:593 CUM H2O: 778.8 BS&W= 90% H2O, 10% Oil and Trace Sediment Time: 22:00 WHP:196 Choke:128 IA: 1165 BHP: 775 UG: 1635 BOPD: 144.72 BWPD: 820..08 CUM Oil:622.6 CUM H2O: 807.8 BS&W = 84.9%H20,15% Oil and .1 % Sedimen SHUT IN@WH Shut in Gas lift. Schlumberger finishes rigging backside, and prepares to make up BOP and injector for BOP test. Page 10/14 ReportPrinted: 12/12/2013 PIONEER')perations Summary Report - Statt Well Name: ODST-4 NATIIRAI PPROIlPrP.q Page 11/14 ReportPrinted: 12/12/2013 1 Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (Ib/gal) Summary 5/13/2013 5/14/2013 0.0 Time: 0700 5-13-2013 WHP: 1190 Choke: IAP: 995 BHP: 2062 Lift Gas: 0 BOPD: 964 BWPD: 0 BSW: 0 Rig up BOP'S and complete manditory test. Rig back after BOP test was completed and make up cleanout BHA. Rig up to well. 0900 conduct pre -job meeting with Safety, ACS, Wells, Ops, EXPRO, SLB, HES N2, HES slickline, CH2MHILL and LRS. Pressure test coil equipment. MU & RIH CTC 1.90", CV 1.75", 2 ea. Wt bar 1.75" JSN 1.75" total length 10.81' to 600' shut down let crews do change out. Start GL at 500mscf/day, N2 at 300 scf/m, fluid at 1/2 bpm RIH @ 70 fpm, Increase GL to 1000mscf/d, N2 to 500scf. Perform Weight checks every 1000' starting at 6100'. Slow ROP to 50 fpm at 1 1000'continue RIH. slow ROP to 35 fpm at 12000', RIH to 13000', PU 275', PU clean, RBIH, Tag up 13032' CTM, Short trip back to GLM at 10944', Start 10 bbl Gel pill, Time: 24:00 WHP: 123 Choke: 80 IA: 970 BHP: 1184 L/G: 1123 BOPD:328.32 BWPD: 492.48 CUM Oil:715.99 CUM H2O:956 BS&W = 58% H20,40% Oil, 2% Mud and Trace Sediment 5/14/2013 5/15/2013 0.0 RBIH from 10994' RKB, start to take weight at 13026', stack up ,increase pump rate to 1.5 bpm, N2 rate to 600 scf/m attempt to Jet through bridge with the gel, PUH, RBIH, start taking weght at 13026'. Set weight on pull and attempt to wash through, Make several more attempts to wash or jet through with no sucess PU to 13000' shut fluid pump but continue to N2 at 600 scfm for one hour, Start POOH, N2 at 600 scfm until above GLM at 10994' slow N2 rate 1:0 300 scfm. Increase GL to 1500 mmscf/d. continue POOH with coil. At surface stand by for weather to break. Shut in well and build up wellhead then open well and attempt to flow. Begin rig down of EXPRO and SLB Coil and move to ODST-39 for Fill cleanout. 6/12/2013 6/13/2013 0.0 Run hardline to where coil will be spotted and run hoses from RSC tank farm to SLB pump unit. Stab 1-3/4" Coiled Tubing into injector head. Pick up SLB injector head and make up tools for BOP test. Go to ODST-47 and perform BOP test. Rig injector head to the ground and shut down for the night. 6/13/2013 6/14/2013 0.0 Researched well. went over all previous job. 06:45 Pre -job safety meeting with Wells, Operations, SLB, LRS and EV Downhole video. Handed out copies for the program to all in attendance and covered all steps in detail. 07;15 Attended Simops meeting and wentover the job scope for ODST-47. 08:00 Make up BOT tools and condct 3,500 psi test and pull test to 20K. 10:30 Make up coiled tubing to tree. Conduct high and low test (400 psi / 4,000 psi) 11:30 RIH with camera and BOT tools. 11:35 Begin pumping at a minimun rate (.25 BPM) while RIH. W/H 250 psi. Coil Tubing 750 psi. 14:30 Tag bottom at 13,024' increase rate to 1.75 BPM, W/H 250 psi, Coiled Tubing 1,250 psi. 16:00 Shut in to test header and inject @ 1/2" BPM. W/H 750 psi, Coiled Tubing 1500 psi. 17:00 Shut down pumping and continue video. W/H 750 psi, Coil Tubing 250 psi. 18:00 POOH 20:00 Camera out of hole. Begin to retrieve data from camera. 20:20 Watch video and discuss results of footage. 22:00 Make decision to stand coil tubing back and stand by until a further plan is developed. 23:00 Coil tubing off of well. Night cap installed. 6/14/2013 6/15/2013 0.0 00:00 Review video footage. 07:00 Begin rigging down Coiled Tubing. 11:00 Rig down completed and eqipment stagged. Release laittice crane and begin moving to to ODSN-25 to support slick line unit. 15:00 LRS pumped 40 BBL of diesel into tubing for freeze protect. 6/24/2013 6/25/2013 0.0 ODST-47 10/16/2013 10/17/2013 0.0 10/17/2013 10/18/2013 0.0 Page 11/14 ReportPrinted: 12/12/2013 1 PIONEER')perations Summary Report - Stag Well Name: ODST-4 NATIIRAI RF4nIIprp.(z Page 12/14 ReportPrinted: 12/12/2013 Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 10/18/2013 10/19/2013 0.0 10/19/2013 10/20/2013 0.0 10/21/2013 10/22/2013 0.0 10/22/2013 10/23/2013 0.0 10/23/2013 10/24/2013 0.0 10/24/2013 10/25/2013 0.0 10/30/2013 10/31/2013 0.0 11/1/2013 11/2/2013 0.0 11/2/2013 11/3/2013 0.0 11/3/2013 11/4/2013 0.0 11/4/2013 11/5/2013 0.0 11/5/2013 11/6/2013 0.0 11/6/2013 11/7/2013 0.0 11/7/2013 11/8/2013 0.0 11/8/2013 11/9/2013 0.0 11/9/2013 11/10/2013 0.0 11/10/2013 11/11/2013 0.0 11/11/2013 11/12/2013 0.0 11/12/2013 11/13/2013 0.0 11/13/2013 11/14/2013 0.0 11/14/2013 11/15/2013 0.0 Mobilize SLB coil tubing personnel to ODS. Begin rigging up CTU #1 to perform the coil cleanout/camera job scope. Wind blowing 30-38 mph. " Stand by for the wind to subside below the crane operating maximums. • Ready all ground lines and complete any tasks that is possible without the need of the crane. 11/15/2013 11/16/2013 0.0 Continue to rig up coil tubing on ODST-47. • Conduct and witness a BOP test as per SLB policy. * Make up the BHA #1 consisting of the Venturi junk basket. " Stand by for the wind to subside below the crane operating maximums. 11/16/2013 11/17/2013 0.0 RIH with BHA #1 consisting of the Venturi junk basket. • Reached a depth of 12,600' with the BHA. • Pulled back up to 12,000' (upper completion) due to the winds trending up above 30 mph. • Stop coil movement an monitor the wind closely until gusts subside below 30 mph for a minimum of 1 hour. Page 12/14 ReportPrinted: 12/12/2013 PIONEER')perations Summary Report - Stat( Well Name: ODST-47 MATIIRAI RF.q(111pr..FC Page 13/14 ReportPrinted: 12/12/2013 Start Depth Foot(Meters Dens Last Start Date End Date (ftKB) (ft) Mud (Ib/gal) Summary 11/17/2013 11/18/2013 0.0 RIH with BHA #2 consisting of the Tempress tool Venturi junk basket. " Reached a depth of 12,600' with the BHA. • Pulled back up to 12,000' (upper completion) due to the winds trending up above 30 mph. " Stop coil movement an monitor the wind closely until gust subside below 30 mph for a minimum of 1 hour. 11/18/2013 11/19/2013 0.0 RIH with BHA #3 consisting of the EV video camera log. ' SLB coil personnel changing out stripper rubber. • SLB mechanic flown to location with necessary materials to troubleshoot the CTU #1 " Reached a depth of 13,026' with the BHA #3. * Make 3 log passes as per EV video rep program. 11/19/2013 11/20/2013 0.0 Stand by for weather to lay down below the crane operating maximums. Weather subsided at 9 pm. Begin rigging up SLB coil tubing and make up BHA #4 consisting of the Venturi junk basket and Tempress tool. 11/20/2013 11/21/2013 0.0 RIH with BHA #4 consisting of the Venturi junk basket and the Tempress tool to retrieve/cleanout the obstruction. Make up BHA #5 consisting of the EV video camera and run to 13,031'. 11/21/2013 11/22/2013 0.0 Review footage of EV Vldeo camera run #2. Consult with Anchorage on the next run. Conduct BOP test as per SLB policy. RIH with BHA #6 consisting of the mill and motor. 11/22/2013 11/23/2013 0.0 RIH with BHA #6 consisting of the Tempress tool and mill and motor. Ran down to 13031' and tagged hard, pulled up 500' and could only get down to 13021' after working the coil several times without getting any further in the hole we POOH. Once on surface and popping of of the wellhead it was noticed that the Tempress, motor and mill were left downhole. Consult with the Anchorage team. Begin RDMO CTU #1. 11/23/2013 11/24/2013 0.0 Stand by for the wind to subside below 30 mph for a minimum of 60 min. Wind subsided at13:00, begin to RDMO SLB CTU #1 and move the unit to the north side of the well bays. 11/24/2013 11/25/2013 0.0 Mobilize the SLB Mechanic to ODS and change out the BOP ram inserts as per SLB policy and procedure. 11/25/2013 11/26/2013 0.0 MIRU HES slickline on ODST-47. • Latch and pull the frac sleeve at 2382'. • Brush the SVLN while pumping 30 bbls of diesel down the tubing. " Set the ScSSSV at 2480' and obtain a good integrity and draw down test on the valve. • All tests good. • Control line pressure left at 0 psi. 11/26/2013 11/27/2013 0.0 11/27/2013 11/28/2013 0.0 11/28/2013 11/29/2013 0.0 11/29/2013 11/30/2013 0.0 11/30/2013 12/1/2013 0.0 12/1/2013 12/2/2013 0.0 12/2/2013 12/3/2013 0.0 12/3/2013 12/4/2013 0.0 12/4/2013 12/5/2013 0.0 Page 13/14 ReportPrinted: 12/12/2013 PIONEER')perations ATURAL RESOURCES Summary Report - Stat( Well Name: ODST-47 Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 12/5/2013 12/6/2013 0.0 12/6/2013 12/7/2013 0.0 12/7/2013 12/8/2013 0.0 12/8/2013 12/9/2013 0.0 12/9/2013 12/10/2013 0.0 12/10/2013 12/11/2013 0.0 Page 14/14 Report Printed: 12/12/2013 THE STATE J 1WIN, 11-0, GOVERNOR SEAN PARNELL Judy Golding Well Work Supervisor Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Torok Oil Pool, ODST-47 Sundry Number: 313-052 Dear Ms. Golding: l skz 011 and GaF 35nselry tiGn CGMM 5&k(& 1 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this day of February, 2013. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25290 RECEIVED FEB 0 4 2012 AO0-j-) 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 Q— Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5_ Permit to Dell Number. Pioneer Natural Resources Alaska, Inc. Exploratory ❑ Development Stratigraphic ❑ Service ❑ 212-103- 3. Address: 700 G Street, Suite 600 6. API Number Anchorage, AK 99501 50-703-20660-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NIA ODST-47 Will planned perforations require a spacing exception? Yes ❑ No (� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 355036 / ADL 355038 Oooguruk - Torok 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): . 17,245' 5288' 17,188' 5281' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5341' 10-3/4" 5380' 2998' 5210 psi 2470 psi Intermediate 12,100' 7-5/8" 12,138' 5004' 6890 psi 4790 psi Production Liner 5253' 4-1/2" 11,938'- 17,191' 4989'- 5281' 11,590 psi 9210 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment, pg. 2 + See Attachment, pg. 2 4-1/2", 13.5# P-110, HYD 521 11,986' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): See Attachment, pg. 3 - See Attachment, pg. 3 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q , Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/10/2013 Oil ❑ �Gas ❑ WDSPLSuspended❑ WIND ❑ GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact July Golding, 343-2179 Email judy.cloldinclCo�Dxd.com Printed Name Judy Golding Title Well Work Supervisor Prepared By: Kathy Campoamor, 343-2183 Signature Phone Date 343-2179 1/22/2013 � COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: cm3- C 2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: "80MS FEB 21 1� Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 . Ll O 1 / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 0-Rt0N0*L Approved application is valid for 12 months from the date of approval. / 2./a•i3 Submit Form and Attachments in Duplicate Pioneer Natural Resources Alaska Inc. ODST-47 Page 2 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Perforation Depth (MD/TVD) - Attachment 4-1/2", 12.6#, P-110 Hydril 521 Uncemented Liner Frac Sleeves: MD TVD 12,699'- 12,702' 5035'- 5035' 12,857'- 12,860' 5044'- 5044' 12,973'- 12,976' 5051'- 5052' 13,201'- 13,205' 5066'- 5066' 13,317'- 13,321' 5073'- 5074' 13,433'- 13,436' 5083'- 5083' 13,662'- 13,665' 5101'- 5101' 13,778'- 13,781' 5108'- 5108' 13,935'- 13,938' 5119'- 5119' 14,284'- 14,287' 5141'- 5141' 14,483'- 14,487' 5147'- 5147' 14,682'- 14,685' 5152'- 5152' 14,975'- 14,978' 5158'- 5158' 15,049'- 15,053' 5159'- 5159' 15,123'- 15,126' 5160'- 5160' 15,310'- 15,314' 5163'- 5163' 15,467'- 15,471' 5166' - 5166' 15,625'- 15,628' 5168'- 5168' 15,876'- 15,880' 5178'- 5178' 16,034'- 16,038' 5186'- 5186' 16,191'- 16,194' 5194'- 5194' 16,483'- 16,487' 5212'- 5212' 16,599'- 16,603' 5219'- 5220' 16,757'- 16,760' 5236'- 5236' Pressure Activated Sleeves: MD TVD 17,076'- 17,079' 5267' - 5267' 17,089'- 17,091' 5269'- 5269' Pioneer Natural Resources Alaska Inc. ODST-47 Page 3 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Packers and SSSV Type (MD/TVD) - Attachment 'XXO' SVLN MD TVD 2410' 2028' ZXP Liner Top Packer MD TVD 11,938' 4989' ECP Packers M D TVD 12,543'- 12,567' 5027'-5028' 12,586'- 12,609' 5029'-5030' 13,083'- 13,106' 5059'-5061' 13,544'- 13,567' 5092'-5094' 14,088' - 14,111' 5131'- 5133' 14,876'- 14,899' 5157'- 5157' 15,150'- 15,174' 5161'- 5161' 15,778'— 15,801' 5174'— 5175' 16,302'— 16,325' 5199'— 5201' 16,951'— 16,974' 5255'— 5257' PIONEER NATURAL RESOURCES ALASKA ODST-47 Frac Ref: Permit To Drill#: 212-103 Current status: T-47 is presently completed and waiting for a fracture treatment. Procedure: 1. MIRU frac tanks. load tanks with Conoco seawater (estimate 20 tanks per 1MM lbs of sand). 2. Heat and maintain fluids from 100°-120° F. 3. MIT -IA to 3500 psi for 15 minutes. Ensure the test is recorded on the DCS system. (The last MIT on this well was on 12/6/12). 4. MIRU Halliburton frac pumps and associated equipment. S. Rig up goat head with 10K spacer spool to ensure line connections are above the well bay. 6. Rig up treating lines to well and pressure test treating iron. 7. Tie hot oil truck into IA and pressure up IA to 3000 psi. Maintain this pressure during all pumping operations. (Tube move calculations included as 'Attachment A'). S. The well will be fracture stimulated using 2,000,000 lbs of 16/20 ceramic plug proppant in the Halliburton 25# Hybor G -R-21 crosslinked fluid system (A wellbore intersection diagram and modeling for the treatment are included as 'Attachment B' and 'Attachment C'). The fluid system, 25# Hybor G -R is a water based guar gel system with borate crosslinker. The chemical additives include: a. Crosslink enhancer at 0.3 gpt b. Buffer at 0.5 gpt c. Surfactant at 1 gpt d. Breaker at 4-6 ppt e. Clay controller at 0.5 gpt f. Biocide at 0.25 gpt The clean fluid volumes of 724,530 gallons includes 25% pad. The stimulation will target the Torok reservoir in a 8 stage treatment, using the Baker fracpoint system with ECP packers for isolation between the frac sleeves. A combination of 2 segemented sleeves and one solid ball seat are used in each stage. The expected treating pressure is 5961 psi at 60 bpm. 9. The final stage will include 38 bbls of LVT to freeze protect the well to 2,500'. (All chemicals will be included on the Frac Focus Disclosure submittal). 10. Rig down frac equipment. 11. Set TWC and change out 10K tree for a 5K tree. Pressure test tree to 5000 psi. Pull TWC. 12. Rig up flowback equipment and CT. 13. RIH with CT to jet tubing and jewelry using slick water and Flo -pro. 14. RD CT and RU Slickline. 15. Use Slickline to pull the isolation sleeve in SSSV. Install GLV's. 16. RU CT to jet balls with 15% HCL (1000 gal HCL with additives will be used). Returns will be taken through the Expro equipment. a. RIH to the top ball seat at 12,857' and tag up on ball. Jet with acid until coil falls through solid ball seat. Chase acid with neutralizer so that no "hot" fluids are returned to surface. b. Repeat this procedure through the ball seats as long as losses to the formation are less than 70%. c. When losses approach the 70% pull above the last ball seat. Swap to extra slick water and Flo -pro. Nitrify fluids so that it is possible to get returns and jet liner with Flo -pro to clean up any residual sand in the liner. d. Chase final Flo -pro slug out of hole at 80%. e. Stop CT at 2,000' and monitor returns through Expro to ensure the well will continue to flow. 17. Flow back well with gas lift through the Expro testing equipment. (Diagram of equipment is 'Attachment D'). During this clean-up period the goal is to drop the BHP by 200 psi every 24 hrs. This slow drop in BHP should prevent a large influx of frac sand from the formation. 18. When the solids content is below 0.5% for 2 hours, the well can then be diverted into production. 19. SI well and install WR SSSV. General Well Info: MASP - Reservoir pressure/TVD - Wellhead Type/pressure rating Tree Configuration MIT-IA/MIT OA 9500 psi 2200 psi/ 5000TVD Vetco MB 233 /5000 psi Vetco grey 10k dual valve frac tree MIT -IA: Tested to 350012/6/12 MIT -OA: N/A. Open annulus Cement The 7" casing was cemented with 55 bbls (264 sxs) Class 'G' 15.8 ppg slurry with additives. The cement was displaced with 9.8 MOBM mud. The plug was not bumped . Returns during the cement job averaged 10%. After displacing the cement the pressure was bled from the DP and the floats held. ® C -T- ACI., tviw '. mo Well Type Estimated Start Date Completion Engineer Well Site Supervisor Producer March 10, 2013 Tim Crumrine Judy Golding Work 343-2179 Cell 231-0872 judy.golding@pxd.com Name: T-47 sore Name: 1 TUBEMOVETm Completion Design Analysis Rig Name: Run # or Condition Attachment A Nabors 19 AC Frac Top MD Bottom MD Length f Tool Name OD Weight ID 0.00 12,256.00 12,256.00 Surface Casing 7.6261 29.701 6.875 10.00 Tpbin Buckling (in) Ballooning (in) Top MD (ft) I Bottom MD (ft) Length (ft) Type OD (in) Weight (lbs/ft) ID (in) Material Type Yield Strength (psi) w. 0.00 12,000.00 12,000.00 1 Tubing 4.500 12.60 3.958 STEEL 110,000.00 0.261 PAckor Information 0.001 Bottom MD_ PackerType Depth MD (ft) Initiation High Space Out Anch. Yes Pressure (psi) Slack Off(+) Plug MD (ft) Effective Seal (in) or No Tension(-) (Ibf) Dia. (in) ELine1 12,000.001 0.001 0.00 No 40,000.00 0.00 4.750 -- — Maximum i�OD- �0.000 in MD (ft) Packer to Tubing Force (Ibf) 12,000.00 40,000 Packer Type MD (ft) Total (in) Kine 12,000.00 -52.71 Bottom MD Weight 12,000.00 _Fluid 10.00 /Packer Compression (in) Buckling (in) Ballooning (in) Bottom MD Fluid Weight Kine 12,000.00 10.00 0.261 0.051 0.001 Bottom MD_ Temperature 0.66F-40.00 12,000.001 135.00 MD (ft) Packer to Tubing Force (Ibf) 12,000.00 40,000 Packer Type MD (ft) Total (in) Kine 12,000.00 -52.71 12/19/2012 5:25:37 PM Baker Oil Tools InQuest- TUBEMOVE "' v2.0.10000.88 (5f2312012) Copyright 0 2006.2008 Baker Hughes, Inc. Ali Rights Reserved. Page 1 Type MD (ft) /Packer Compression (in) Buckling (in) Ballooning (in) Temperature(m1 Total (in) Kine 12,000.00 62.461 0.261 0.051 0.001 52.71 Tubing Section MD (ft) Force Stress (psi) Tubing Annulus Pressure Pressure US Max Length of a ty actor (Stress vs. (Ibf) (psi) (psi) (dega/100ft) WL Tool (ft) Yield Strength Well head 0.00 -13,684 3,801 0 0 0.00 Infinity 28.94 (3.5°!°) Eline Packer top 12,000.00 49,360 17,722 2,600 2,600 0.00 Infinity 6.21 (16.1°!°) 12/19/2012 5:25:37 PM Baker Oil Tools InQuest- TUBEMOVE "' v2.0.10000.88 (5f2312012) Copyright 0 2006.2008 Baker Hughes, Inc. Ali Rights Reserved. Page 1 BA1 ESR TUBEMOVETM' HUGHES Completion Design Analysis 12/19/2012 5:25:37 PM BCopyright 0 2006.20N Baker Hu hes, IOVEI�v2.0.1000.88 c A11000 is Reserved. Page 2 Hughes, Rights Resented. v Operator Name: Pioneer Field Name: Oooguruk Well Name: T-47 Rig Name: Nabors 19 AC Wellbore Name: 1 Run # or Condition: Frac 12/19/2012 5:25:37 PM BCopyright 0 2006.20N Baker Hu hes, IOVEI�v2.0.1000.88 c A11000 is Reserved. Page 2 Hughes, Rights Resented. Bottom MD Fluid Weight 2,000.001 6.90 12,000.001 10.00 Bottom MD _ _ Fluid Weight 12,000.001 12.80 Bottom MD Temperature 0.00 70.00 12,000.00 100.00 12/19/2012 5:25:37 PM BCopyright 0 2006.20N Baker Hu hes, IOVEI�v2.0.1000.88 c A11000 is Reserved. Page 2 Hughes, Rights Resented. Tel ��V v�J�VlI LJPIG. IL/V/LV IL Attachment C Pioneer Natural Resources Inc. Alaska Asset Fracture Modeling Study - Torok Background The Alaska Oil and Gas Conservation Commission (AOGCC) has requested that fracture modeling is conducted on the Torok reservoir to determine height growth. Height growth of the induced hydraulic fracture is an important parameter to determine whether the fracture grows beyond the defined oil pool confining sedimentary rock layers violating pool rules (Oooguruk-Torok Pool) or Area Injection Order 037 in order to ensure protection of surrounding reserves. Pioneer has contracted a third party, Barree and Associates, LLC to conduct the fracture modeling study using the software program GOHFER. A meeting was held on December 17, 2012 at the AOGCC office in Anchorage, Alaska with AOGCC representatives, Chris Wallace, Guy Schwartz, Patricia Bettis, and Steve Davies, and Pioneer representatives Tim Crumrine, Andy Bond, Pat Foley, and Vern Johnson. The meeting discussion centered on conducting a fracture study that would be inclusive of all potential fracture stimulation rates and pressures, so that each individual well would not be modeled, but instead one model could be built in which the rates and pressures would exceed the capabilities of fracturing equipment hydraulic horsepower on location at the time of the fracture stimulation. This study is intended to cover all hydraulic fracture stimulations in the Torok oil pool, in both producing or water injection wells. The following sections discuss the model input assumptions and the results from the induced hydraulic fracture study. Model Inputs and Assumptions Torok water injection and production wells will be stimulated with two -million lbs. of 16/20 mesh CarboLite ceramic proppant with approximately 200,000 lbs. per stage for a total of 10 stages. Each well completion is set up to be mechanically or dynamically diverted, with some wells having a combination design. The greatest likelihood for a fracture to grow out of its confining intervals comes from a well with a vertical wellbore and a limited entry single perforation near the top or bottom of the interval being stimulated. Pioneer Alaska's wells are horizontal wells with multiple entry points that are landed in the middle of the zone. Essentially fractures in this type of wellbore are much less prone to fracturing out of zone. Each stage will contain approximately 200,000 lbs. of 16/20 mesh CarboLite ramped from 0.5 —10 ppa concentration with a 25 ppt cross-linked borate gel. The hydraulic horsepower on location during a fracture stimulation is approximately 12,000 HHP — based on anticipated pressures and rates. This equates to a rate limit of 60 barrels per minute based on expected pressures. Rates for the fracture modeling study were set at a limit of 65 barrels per minute: well above the available hydraulic horsepower on location. The fracture model geological input parameters were based on the ODSN-45 (later recompleted and renamed to ODST-45A) well log data. Log data from the ODSN-45A well were processed to derive rock mechanical properties and a stress profile for the fracture growth modeling. No tectonic boundary conditions were applied to the stress profile. The Torok zone is shown in the figure below. Two fracture initiation sites were modeled: one just above the middle Torok and one just below the middle Torok. These fracture initiation points are expected to represent any landing point in the zone. 02M—.-___pOWOnR&----- --o Nis 0_-_ --- .__ —__23'X3 p — Paesty(hrlin)—__.___. u19 3;;872 ------ 3567J— Shwa (pd7—•-1101 18811E-06-YGuiQe MDOlA0�0-38787E-06 t.._--.--_Ftrz. Elide ----2 p-___Porcart DdxAe(hection)—_-0.16117 21601&—Pore Peserre 234 20 3766..2N—CFOCfOResare (ptl)-5057 08 ----Yet BGft 08617 4-%07E-01- Pact linuhm(heWa--0.101 Figure 1. ODSN-45 Processed Log Summary Modeling Results The proppant profile (side view) of the created vertical fracture in the upper part of the Torok is shown in the color -filled plot below. See Figure 2. The scale is 0-1.2 lb/ft2, shown at right. The fracture stays contained in the Torok at a maximum 65 bpm pump rate. A near -well concentration of 0.6 —1.2 Ib/ft2 is established, with an effective propped half-length of 500 feet. Vertical node resolution is 5 feet in the grid. i i f ' r 1 ti 1. Figure 1. ODSN-45 Processed Log Summary Modeling Results The proppant profile (side view) of the created vertical fracture in the upper part of the Torok is shown in the color -filled plot below. See Figure 2. The scale is 0-1.2 lb/ft2, shown at right. The fracture stays contained in the Torok at a maximum 65 bpm pump rate. A near -well concentration of 0.6 —1.2 Ib/ft2 is established, with an effective propped half-length of 500 feet. Vertical node resolution is 5 feet in the grid. Proppart Concentration IbM2 27.90 Minutes TY0.11 196411 ..�� 503111 e 523111 o,sa, enn 06744 Figure 2. Proppant profile in the upper Torok Figure 3 is the proppant profile of an additional modeling run with the fracture initiated in the lower part of the Torok. The scale is 0-1.17 Ib/ft2 with a vertical node resolution of 5 feet. The effective fracture half-length is 575 feet. The fracture stays contained in the Torok at a maximum 65 bpm pump rate. ProppeMConcentrdon Ibw -j 26,00NnuDa IVDA awn aicm 0 3 oar am Figure 3. Proppant profile in the lower Torok Conclusion ODSN-45 well log data were processed to derive rock mechanical properties and a stress profile for the fracture growth modeling in the Torok reservoir. Two fracture initiation points were examined: one in the upper and one in lower sections of the Torok formation. A schedule placing 200,000 lbs. of 16/20 CarboLite was run at the "worst-case" for height growth of 65 bpm. The current limitation for the maximum rate is based on the available horsepower on location in which 65 bpm exceeds the capabilities available. In either initiation point the fracture height is contained to the Torok at the maximum specified rate of 65 bpm. The most likely avenue for height growth is downward and this is not predicted to occur under any planned treating conditions. All treatments conducted below the maximum specified rates, pressures, and proppant concentrations are considered a subset of the models presented here in the study. S 2 3 4 5 6 1 8 A J A a� 8�^ S ro � � 5 � 1 1 i B ' _ B 9 � I � 1 1 M i fiR i aB `a C 31 ag a8 � sah � 6 1 1 gg 3 yr � Ile, m g D "s D g g S E E €? AHMAS.uC 7hk REV DATE .C.N. N BY m Inr VAE - IF r oowr w raven Y Date Drawn Res onsl a Engineer STtWART 0 F DEC 2012 /P r iiia WELL TEST EQUIPMENT LAYOUT F of�.19YCr5, PIONEER OOOGURUK ISLAND ® wdb nf� mrl�arr �Rbouf lln pier �wnmwxo Drawing 9 0 S eet No. lRevision e�wm.leeus,ut _ _ _ _ _ t 1 I DR5 t 2 3 4 5 6 7 8 ODST-47 Torok Production Well Completion Updated 10/29/2012 I Upger Completion itLQ ND 16" Conductor 1) Tubing Hanger 43' 43' 2) 4-W' 12.6#/ft Hydril 521 Tubing (2 jts) 3) 4-'/2" 12.6#/ft Hydril 521 Tubing Packer Fluid mix: 4) 4-"/2" Halliburton 'XXO' SVLN w/ 3.813" "X" profile RTS -8 2410' 2028' Inhibited Kill weight with singlet/4" x 0.049" s/s control line. I Brine Cannon Cross -coupling clamps on every joint 4 with 2000' TVD 5) 4-'/Z" 12.6#/ft Hydril 521 Tubing diesel cap 6) 4-'/" x 1" GLM, KBMG Hydril 521 w/ SOV Set at max 68 deg 2674' 2157' 7) 4-'/z' 12.6#/ft Hydril 521 Tubing 8) HES X 3.813" Set at max 68 deg 2776' 220 9) 4-'/" 12.6#/ft Hydril 521 Tubing 10) 4-'/2' x 1" GLM, KBMG Hydril 521 w/ DV 5580' 3062' 11) 4-'/z" 12.6#/ft Hydril 521 Tubing I 12) 4'/" x V GLM, KBMG Hydril 521 w/ DV 8595' 4020' i 10-3/4" 45.5 ppf L-80 BTC 13) 4-'/2' 12.6#/ft Hydril 521 Tubing U Surface Casing 14) 4-%2' x 1" GLM, KBMG Hydril 521 w/ DV 10944' 4766' @ 5380' MD / 2998' TVD 15) 4-"/" 12.6#/ft Hydril 521 Tubing 16) HES XN 3.813" (3.725" NoGo) - with RHC Plug 11045' 4797' i cemented to surface 17) 4-'/2" 12.6#/ft Hydril 521 Tubing 18) 4-1/2" Hall iburton 'ROC' Gauge Carrier w/ 1/4" x 0.049" s/s control line 11849' 4978" 19) 4-'/2' 12.6#/ft Hydril 521 Tubing 20) GBH -22 Locator Tubing Seal Assembly with Auto Entry Mule Shoe 11983' 4993' Bottom of Shoe 11986' 4994' 4-112" 13.5 ppf P-110 Hydril 521 Tubing _ TOC Estimated 500' above top of Kuparuk 7-5/8" 29.7 ppf 85 97 109 121 % L-80 BTC -Mod 23 ss _ -------------- O 0 Casing 29 - - - - - - - - - - - - - - - - - - - - - @ 12,138' MD 5004' TVD _C1 3�D FAILED ECP 4-1/2" Hydril 521 Liner with Baker Hughes Multi -Point Frac Sleeves (3 per stagel) isolated with ECP's + Resman 6-3/4" Hole TD Carriers (2 per stage) at 17,245' 5288'TVD // ODST-47 Torok Production Well Completion Updated 10/29/2012 1 Lower Completion 21) Baker 5-%" X MD PL 7" ZXP Liner Top Packer with Tie Back 11938' 4989' 16" Conductor extension and Flex Lock Hanger 22) 4-/2 12.6#/ft Hydril 521 Liner 23) Baker ECP Packer (4-'/2" Hydril 521) 12543' 5027' Packer Fluid mix: 24) 4-Y2" 12.6#/ft Hydril 521 Liner Inhibited Kill weight 25} Baker ECP Packer (4-'/:" Hydril 521) 12586' 5029' 14 Brine 26) 4-'/z" 12.6#/ft Hydril 521 Liner 27) Baker Multi -Point Frac Sleeve with segmented ball seat (3.000 ball 12.948 Seat) 12699' 5035' with 2000' TVD 28) 4-'/2" 12.6#/ft Hydril 521 Liner diesel ca12 29) 4-Y2" Resman Tracer Carrier w/ 15 ft pups on each side 12773' 5039' 30) 4-%2" 12.6#/ft Hydril 521 Liner 31) Baker Multi -Point Frac Sleeve with segmented ball seat (3.000 ball / 2.948 Seat) 12857' 5044' 1 32) 4-Y2" 12.6#/ft Hydril 521 Liner If 33) 4-1/V Resman Tracer Carrier wl 15 ft pups on each side 12931' 5049' 34) 4-'/2" 12.6#/ft Hydril 521 Liner 35) Baker Multi -Point Frac Sleeve with solid ball seat (3.000 bal 112.948 Seat) 12973' 5051' i 10-3/4" 45.5 ppf L-80 BTC 36) 4-'/2" 12.6#/ft Hydril 521 Liner �� i Surface Casing 37) Baker ECP Packer (4-'/2" Hydril 521) 13083' 5059' s 5380' MD / 2998' ND I @ 38) 4-'/2" 12.6#/ft Hydril 521 Liner 39) Baker Multi -Point Frac Sleeve with segmented ball seat 2.938 ball / 2.885 Seat) 13201' 5066' s x i cemented to surface 40) 4-'/2" 12.6#/ft Hydril 521 Liner a1) 4-'/z" Resman Tracer Carrier wl 15 ft pups on each side 13234' 5068' 42) 4-Y2" 12.6#/ft Hydril 521 Liner I 43) Baker Multi -Point Frac Sleeve with segmented ball seat (2.938 ball / 2.885 Seat) 13317' 5073' i 44) 4-'/2" 12.6#/ft Hydril 521 Liner 45) 4-Y2" Resman Tracer Carrier w/ 15 ft pups on each side 13392' 5080' 10 OL I 46) 4-'/2" 12.6#/ft Hydril 521 Liner 1 47) Baker Multi -Point Frac Sleeve with solid ball seat (2.938 bal I / 2.885 Seat) 13433' 5083' 48) 4-Y2" 12.6#/ft Hydril 521 Liner 49) Baker ECP Packer (4-Y2" Hydrit 521) 13544' 5092' 1 50) 4-'/2" 12.6#/ft Hydril 521 Liner I 51) Baker Multi -Point Frac Sleeve with segmented ball seat (2.875 ball / 2.823 Seat) 13662' 5101' i 52) 4-Y2" 12.6#/ft Hydril 521 Liner GL 4-1/2" 13.5 53) 4-'/2" Resman Tracer Carrier w/ 15 ft pups on each side 13695' 5103' 12 ppf 54) 4-Y2" 12.6#!ft Hydril 521 Liner i P-110 Hydril 55) Baker Multi -Point Frac Sleeve with segmented ball seat (2.875 ball / 2.823 Seat) 13778' 5108' i 521 56) 4-Y2" 12.6#/ft Hydril 521 Liner i Tubing 57) 4-'h" Resman Tracer Carrier w/ 15 ft pups on each side 13894' 5116' 58) 4-'/d' 12.6#/ft Hydril 521 Liner :4i 59) Baker Multi -Point Frac Sleeve with solid ball seat (2.875 ball / 2.823 Seat) 13935' 5119' 1a 60) 4-Y2" 12.6#/ft Hydril 521 Liner 61) Baker ECP Packer (4-V Hydril 521) 14088' 5131' 16 I 'r,' XN 62) 4-Y2" 12.6#/ft Hydril 521 Liner 63) Baker Multi -Point Frac Sleeve with segmented ball seat (2.813 ball 12.760 Seat) 14284' 5141' 64) 4-'/2" 12.6#/ft Hydril 521 Liner 18 Roc' 65) 4-Y2" Resman Tracer Carrier w/ 15 ft pups on each side 14400' 5145' -- TOC Estimated66) 4-'/2" 12.6#/1't Hydril 521 Liner 67) Baker Multi i. 500' above top of -Point Frac Sleeve with segmented ball seat (2.813 ball / 2.760 Seat) 14483' 5147' Kuparuk 68) 4-%" 12.6#tft Hydri! 521 Liner 69) 4-'/2" Resman Tracer Carrier w/ 15 ft pups on each side 14558' 5149' +: 70) 4•'/2" 12.6#/ft Hydril 521 Liner 71) Baker Multi -Point Frac Sleeve with solid ball seat (2.813 ball / 2.760 Seat) 14682' 5152' 21 72) 4 12.6#/ft Hydril 521 Liner 20 73) Baker ECP Packer (4-Y2" Hydril 521) 14876' 5157' 74) 4-'/2" 12.6#1ft Hydril 521 Liner 75) Baker Multi -Point Frac Sleeve with segmented ball seat (2.750 ball / 2.698 Seat) 14975' 5158' YO 76) 4-Y2' 12.6#/ft Hydril 521 Liner 25 77) 4-1/V Resman Tracer Carrier w/ 15 ft pups on each side 15007' 5158' 27 78) 4-%" 12.6#/ft Hydril 521 Liner 37 79) Baker Multi -Point Frac Sleeve with segmented ball seat (2.750 ball / 2.698 Seat) 15049' 5159' 7-5/8" 29.7 ppf ` L-80 as s1 73 s5 s7 los ,2, BTC -Mod 23 -------- --- 55 -------------- O- Casing 2s - - - - - - - - - - - - - - - - - - - @ 12,138' MD 5004' ND --------------------------------------------------------------------- ------------- ---- ---- 132 FAILED ECP 4-1/" Hydril 521 Liner with Baker Hughes Multi -Point Frac Sleeves (3 per stagel) isolated with ECP's + Resman 6-3/4" Hole TD at Carriers (2 per stage) at 17,245' MD / 5288' ND ODST-47 Torok Production Well Completion Updated 10/29/2012 7-5/8" 29.7 ppf L-80 BTG -Mod Casing @ 12,138' MD / 5004' TVD 61 73 85 97 109 55 29 FAILED ECP 4-'/2" Hydril 521 Liner with Baker Hughes Multi -Point Frac Sleeves (3 per stagel) isolated with ECP's + Resman Carriers (2 per stage) 6-3/4" Hole TD at at 17,245' MD / 5288' TVD Lower Completion im IQ j 80) 4-Y:" 12.6#/ft Hydril 521 Liner 16" Conductor 81) 4-Y2" Resman Tracer Carrier w/ 15 ft pups on each side 15082' 5160' I 82) 4-Y2" 12.6#/ft Hydril 521 Liner Packer Fluid mix: 83) Baker Multi -Point Frac Sleeve with solid ball seat (2.750 ball / 2.698 Seat) 15123' 5160' 84) 4-YV 12.6#/ft Hydril 521 Liner Inhibited Kill weight 85) Baker ECP Packer (4-'/V Hydril 521) 15150' 5161' I Brine 86) 4-'/2" 12.6#/ft Hydril 521 Liner 4 with 2000' ND 87) Baker Multi -Point Frac Sleeve with segmented ball seat (2.688 ball / 2.635 Seat) 15310' 5163' diesel cap 88) 4-W 12.6#/ft Hydril 521 Liner 89) 4-Yz" Resman Tracer Carrier w/ 15 ft pups on each side 15384' 5165' 1 90) 4-Y:" 12.6#/ft Hydril 521 Liner 91) Baker Multi -Point Frac Sleeve with segmented ball seat (2.688 ball 12.635 Seat) 15467' 5166' 92) 4-YV 12.6#/ft Hydril 521 Liner 1 93) 4-Yz" Resman Tracer Carrier w/ 15 ft pups on each side 15542' 5167' 94) 4-'/" 12.6#/ft Hydril 521 Liner j 10-3/4" 45.5 ppf L-80 BTC 95) Baker Multi -Point Frac Sleeve with solid ball seat (2.688 bal l / 2.635 Seat) 15625' 5168' I Surface Casing96) 4-'/" 12.6#/ft Hydril 521 Liner j @ 5380' MD / 2998' TVD 97) Baker ECP Packer (4-/2" Hydric 521) 98) 4-%" 12.6#/ft Hydril 521 Liner 15778' 5174' j cemented to surface 99) Baker Multi -Point Frac Sleeve with segmented ball seat (2.625 ball / 2.573 Seat) 15876' 5178' 100) 4-/z 12.6#/ft Hydril 521 Liner I 101) 4-'/" Resman Tracer Carrier w/ 15 ft pups on each side 15951' 5181' 102) 4-'/z" 12.6#/ft Hydril 521 Liner l 103) Baker Multi -Point Frac Sleeve with segmented ball seat (2.625 ball / 2.573 Seat) 16034' 5186' 104) 4-'/:" 12.6#/ft Hydril 521 Liner J 105) 4-%" Resman Tracer Carrier w/ 15 ft pups on each side 16109' 5190' 106) 4-'/" 12.6#/ft Hydril 521 Liner 107) Baker Multi -Point Frac Sleeve with solid ball seat (2.625 ball / 2.573 Seat) 16191' 5194' 108) 4-Yz" 12.6#/ft Hydril 521 Liner l 109) Baker ECP Packer (4-W Hydril 521) 16302' 5199' j 110) 4-'/2' 12.6#/ft Hydril 521 Liner 111) Baker Multi -Point Frac Sleeve with segmented ball seat (2.563 ball / 2.510 Seat) 16483' 5212' 112) 4-Y2" 12.6#/ft Hydril 521 Liner 4-1/2" 13.5 ppf 113) 4-"/" Resman Tracer Carrier w/ 15 ft pups on each side 16516' 5214' j P-110 Hydril 114) 4-'%" 12.6#/ft Hydril 521 Liner 521 115) Baker Multi -Point Frac Sleeve with segmented ball seat (2.563 ball / 2.510 Seat) 16599' 5219' I 116) 4-Yz" 12.6#/ft Hydril 521 Liner i Tubing 117) 4-Yz" Resman Tracer Carrier w/ 15 ft pups on each side 16716' 5231' 118) 4-%" 12.6#/ft Hydril 521 Liner 119) Baker Multi -Point Frac Sleeve with solid ball seat (2.563 ball / 2.510 Seat) 16757' 5236' I 120) 4-'/z" 12.6#/ft Hydril 521 Liner i 121) Baker ECP Packer (4 -YY" Hydril 521) 16951' 5255' iziT 122) 4-'/2" 12.6#/ft Hydril 521 Liner 123) 4-Y2" Resman Tracer Carrier w/ 15 ft pups on each side 17040' 5263' i 124) 4-'W 12.6#1ft Hydril 521 — 10 ft Pup i. TOC Estimated 125) Pressure Activated Sleeve "B" 5,800 psi 17076' 5267' ': 500' above top of 126) 4-1/V 12.6#/ft Hydril 521 — 10 ft Pup "A" is 127) Pressure Activated Sleeve 5,800 psi 17089' 5269' Kuparuk 128) Wellbore Isolation Valve "WIV" 17091' 5269' 129) 4-'/z" 12.6#/ft Hydril 521 — 10 ft Pup 130) 4-Y:" Resman Tracer Carrier w/ 15 ft pups on each side 17120' 5272' 131) 4-W 12.6#/ft Hydril 521 Liner 21 )S) 132) Baker 5-%" EZ Ream Shoe a 17188' 5281' Bottom of Shoe 17191' 5281' 7-5/8" 29.7 ppf L-80 BTG -Mod Casing @ 12,138' MD / 5004' TVD 61 73 85 97 109 55 29 FAILED ECP 4-'/2" Hydril 521 Liner with Baker Hughes Multi -Point Frac Sleeves (3 per stagel) isolated with ECP's + Resman Carriers (2 per stage) 6-3/4" Hole TD at at 17,245' MD / 5288' TVD DGR Dual Gamma Ray BAT Bi -Modal Acoustic 1:1200 /1 :240 Cement Log Q< Company : Pioneer Natural Resources Inc. x V- U Rig Nabors 19AC 10 9 M 2 Well ODST-47 a CO a 10 Field : Oooguruk X Y Country U.S.A. a o y N z `g a API Number 50-703-20660-00-00 • d! 8 a z o a° z Latitude : 70° 29' 44.71" North Other Services o-0 Longitude :150* 14'48.64" West PWD, Geo -Pilot AKSP Zn 04 X = LL 3 O 469,811.98 ft NAD 27 DDSr, ABI, ABG AKSP Zn 04 Y = 6,030,995.50 ft NAD 27 GeoTap o o Permanent Datum Mean Sea Level Elevation : 0.00 ft Elev. KB 0.00 ft Measured From Drill Floor 56.20 It Above Permanent Datum DF 56.20 ft r O o CO Q¢ o O o O Q Q Q¢ U ng Measured From : Drill Floor MD LOG GL 13.50 ft 0o w Coto O m O m— a N N Z Z V F= O o I� N m ao O o z dj .- p ` :A! Z Ud Z 8U Z= U M N WD 0.00 ft co ao m o N N m U} �n a0i to �, Q Z �C Z -' � r co N °' (O N 'S o (O rn Q Z �., M N tfJ r Q ZZ Q Q Z Q Z m M N Q Z Depth Logged : 10,720.00 ft To 12,146.00 ft i Unit No. :123 Job NO.:AK-xx-000se4saa� Date Logged : 17 -Sep -12 To 17 -Sep -12 CO Total Depth MD 17,245.00 ft TVD: 5,287.90 ft Plot Type: Final Spud Date : 15 -Aug -12 Plot Date : 11 -Dec -12 o C c 2 Z �- °' mH — o p g n. 1: N �' C i `o c `4y v �+ DO 9gt� t o L5 1 c e B u C amuo.aU2Aal m S r'I o a E E t°' Q t� L f o S i _a ... a .5 v °.3 E^ I 9 .0i'- M o � a o v� ai0�� e p � O o 9 �' § C �, a �CL I I C aM m F- I 0 y LL ~ CM Borehole Record MD Run No.Size EromRun No. Borehole Record MD 17 T— 1 3 in 1 0 3.007.00 ft 2 13.500 in 3 007.00 ft 5 389.00 ft 3 9.875 i 5 389.00 ft 5 409.00 It 4 9.875 in 5 409.00 ft 12 220.00 ft Casin RewN D 8 6.750 in 12 220.00 ft 17 245.00 ft ize Wei ht From To _ 16.000 in 109 0 b f SURF CE 158.00 Z 10.750 in 45 50 f SU FACE 5 380.0 7 625 i 29.70 Ib f SURFACE 12 38.00 ft Lead MWD Engineer F 'm Customer Representative d,.., , _ya SENSOR INFORMATION I Tool Type Downhole • • • • HCIM Software Version 88.47 Sub Serial Number 11191365 Insert Serial Number 10455878 Date and Time Initialized 15 -Sep -12 14:50 Date and Time Read 18 -Sep -12 06:48 ECMB SW Version N/A Tool Type Sonica Information BAT Distance From Bit (ft) 45.18 Recorded Sample Period (sec) 8 - Sub Serial Number 10499585 Receiver Insert Serial Number 10499545 Transmitter Insert Serial Number 10442003 MIT File R5Max_Run_f6.mi Config File N/A Real -Time Window (uspf) 80-140 Battery Insert Serial Number 10507345 MCM Software Version 20.08 DAQ1/DAQ2 Software Version 20.01 / 20.01 DSM Software Version 36.65 1. ALL DEPTHS ARE MEASURED DEPTHS (MD), UNLESS OTHERWISE NOTED.THESE DEPTHS ARE BIT DEPTHS AND ARE CALLIBRATED TO THE DRILLERS PIPE TALLY. NO DEPTH CORRECTIONS HAVE BEEN MADE FOR PIPE STRETCH OR COMPRESSION. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD), UNLESS OTHERWISE NOTED. 3. ALL DATA PRESENTED IS RECORDED DATA UNLESS OTHERWISE STATED. 4. RUN 6 WAS COMPRISED OF THE DRILLING DYNAMICS SENSOR (DDSr) AND THE BIMODAL ACOUSTIC SENSOR (BAT). 5. THE BAT SENSOR WAS RUN ON A CLEANOUT DRILLNIG ASSEMBLY AND THE CEMENT LOG WAS ACQUIRED WHILE TRIPPING OUT OF THE HOLE AFTER DRILLING OUT. 6. DGRC DATA PRESENTED IS DRILLING DATA FROM RUN 400. 7. WAVEFORM DATA SUGGESTS TOP OF CEMENT TO BE -11,713-M D.THIS IS THE FIRST DISCERNABLE CHANGE IN THE WAVEFORMS BELOW THE 9-5/8" CASING. 8. FROM 11,713'-11,726' THE FIRST ARRIVING WAVES ARE PRESENTBUT DO NOT HAVE AS MUCH ENERGY ASTHE ABOVE RINGING PIPE. THIS SUGGESTS A PARTIAL PHYSICAL CONNECTION WITH THE FORMATION. 9. FROM 11726-11745 THE FIRST ARRIVING WAVES HAVE HIGHER ENERGY LEVEL, SUGGESTING THAT THERE IS NOT A PHYSICAL CONNECTION WITH THE FORMATION. 10. FROM 11745-11763 THE FIRST ARRIVING WAVES HAVEA LOW ENERGY LEVEL AND APPEAR TO ALMOST DISAPPEAR, INDICATING A STRONG PHYSICAL CONNECTION WITH THE FORMATION. 11. FROM 11813-11847 THE FIRST ARRIVING WAVES START TO DISAPPEAR, INDICATING ASTRONG PHYSICAL CONNECTION WITH THE FORMATION. 12. FROM 11847-11975 THE F ARIVING WAVES HAVE A HIGHER ENERGY, S VESTING THATTHERE IS NOT A PHYSICAL CONNECTION WITH THE FORMATION. 13. FROM 11975 —12057 THE FIRST ARRIVING WAVES ARE PRESENT BUT DO NOT HAVE AS MUCH ENERGY AS THE ABOVE RINGING PIPE. THIS SUGGESTS A PARTIAL PHYSICAL CONNECTION WITH THE FORMATION. 14. FROM 12057-12128 THE FIRST ARRIVING WAVES HAVE A HIGHER ENERGY, SUGGESTING THATTHERE IS NOT A PHYSICAL CONNECTION WITH THE FORMATION. 15. IN AREAS THAT SHOW A PARTIAL BOND, HOW MUCH OF THE CASING IS BONDED VS. U NBONDED CANNOT BE DETERMINED WITH THIS TOOL. 16. THE SEMBLANCE PLOTS SHOWN ARE NOT DISPLAYING AN ORIENTED VIEW OF THE CASING AROUNDTHE HOLE, BUT ARE DISPLAYING THE ARRIVAL TIME AND STRENGTH OF THE ACOUSTIC WAVE AT A SPECIFIC DEPTH. THE PRESENCE OF A WEAK COMPRESSIONAL WAVE SUGGESTS THAT THERE IS A PHYSICAL CONNECTION BETWEEN THE CASING AND FORMATION. A STRONG CASING ARRIVAL SUGGESTS POOR BOND. 17. BAT HIGH FREQUNCY MEASUREMENTS WERE FIRED AT 12KHZ DIPOLE, LOW FREQUENCY MEASUREMENTS WERE FIRED AT 5KHZ DIPOLE. LOG MNEUMONICS DGRC = DGR COMBINED GAMMA RAY BTCS =BAT COMPRESSIONAL SLOWNESS ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 1.5 FT EXCEPT DRGC WHICH IS SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SETT03 FT FOR ALL CURVES. LOG MNEUMONICS: 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 PROVIDED BY HALLIBURTON. DGRC BTCS BTCS api 200 240 psec/ft 40 240 Nsec/ft 40 CASING CASING CASING Casing Energy 40 useGft 40 240 Nsec/ft 40 240 Nsec/ft 40 0 BTCS MD 12KHz Mono Front 12KHz Mono Back Casing ft Energy 12KHz Mono Front 12KHZ Mono Back 200 0 200 0 . 40 Nsec/ft 40 240 Nsec/ft 40 240 Nsec/ft 40 0 0.2 Y 1 : 1200 am� 'fit • i I a i'�. —MI— I . ill t � } I 4 1 I ' � i � � �) I I � . � it I' d I I 9 -■ -.I ' 11 1 JII1 �! is I 1 •I�, I pp 4 5 r h ir i r 41 1 ALL-LA&SLiga-ro ....,wwwun North Slope Borough Alaska U.S.A. AK -XX -0009646431 Surveys to 734' are Gyro Surveys. All MWD Surveys are IIFR, MSA and SAG corrected. Final Survey is extrapolated to TD. Measured Vertical Depth Inclination Direction Depth Latitude Departure Vertical Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (degf1001 0.00 42.70 0.00 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 100.00 0.11 64.97 42.70 100.00 0.00 N 0.02 N 0.00 E 0.05 E 0.00 0.00 171.00 264.00 0.40 0.44 315.08 171.00 0.23 N 0.06 W -0.03 -0.22 0.19 0.63 255.05 264.00 0.37 N 0.64 W -0.28 0.45 358.00 451.00 1.89 3.51 210.71 211.62 357.98 1.06S 1.78 W 1.28 1.71 544.00 5.46 208.60 450.87 543.58 4.80S 11.11S 4.05 W 7.66 W 5.27 1.74 639.00 734.00 7.91 12.26 210.76 637.93 20.70S 13.17 W 11.99 22.19 2.11 2.59 215.94 731.44 34.49S 22.44 W 37.03 4.67 782.28 875.78 13.76 16.04 214.78 216.00 778.48 43,36S 28.72 W 46.62 3.15 969.78 16.82 215.04 868.83 958.99 62.94S 84.59S 42.66 W 67.80 2.46 1067.02 1161.88 20.21 214.09 1051.18 110.02S 58.10 W 75.60 W 91.21 118.64 0.88 3.50 22.52 214.98 1139.52 138.48S 95.20 W 149.33 2.46 1254.24 1350.56 24.14 30.42 215.06 214.70 1224.33 168.43S 116.19 W 181.68 1.75 1444.77 32.61 215.53 1309.89 1390.20 204.64S 244.91S 141.41 W 169.75 W 220.77 6.52 1541.16 1638.79 34.97 40.08 215.58 1470.30 288.52S 200.92 W 264.28 311.46 2.37 2.45 214.12 1547.71 337.33S 234.85 W 364.14 5.31 1733.51 1825.98 42.50 48.08 214.36 215.94 1618.87 388.99S 270.02 W 419.81 2.56 1919.22 49.35 218.14 1683.90 1745.43 442.68S 498.59S 307.87 W 350.08 W 477.82 6.15 2015.43 2110.98 49.63 216.13 1807.93 556.90S 394.23 W 538.58 601.97 2.24 1.61 52.96 216.29 1867.67 617.05S 438.28 W 667.18 3.49 2206.27 2301.76 58.17 57.21 215.29 216.94 1921.53 680.79S 484.20 W 736.18 5.54 2395.81 60.42 216.14 1972.57 2021.27 745.99S 810.63S 531.76 W 806.83 1.77 2491.80 2587.25 60.39 214.38 2068.68 878.78S 579.65 W 627.84 W 876.97 950.63 3.49 1.59 61.51 213.68 2115.02 947.93S 674.53 W 1025.09 1.34 2681.99 2778.62 60.95 86.38 214.67 214.91 2160.62 1016.64S 721.17 W 1099.11 1.09 2871.73 70.07 213.98 2203.47 2238.01 1087.73S 1159.03S 770.57 W 819.46 W 1175.84 5.62 2968.21 3059.04 70.18 72.38 218.42 2270.81 1233.16S 871.78 W 1252.71 1332.82 4.07 2.38 215.92 2299.98 1302.60S 922.52 W 1408.09 2.48 3154.76 3249.09 70.65 72.83 215.97 215.08 2330.31 1376.10S 975.81 W 1487.69 1.81 3341.91 71.59 213.67 2359.87 2388.23 1449.01 S 1521.96S 1027.84 W 1077.73 W 1566.55 2.49 3438.78 3533.72 70.91 73.64 212.79 2419.36 1598.69S 1128.00 W 1645.19 1727.61 1.95 1.11 212.34 2448.27 1674.89S 1176.67 W 1809.33 2.91 3629.82 3723.24 75.15 72.10 212.19 213.49 2474.12 1753.16S 1226.08 W 1893.18 1.58 3817.07 72.14 213.29 2500.45 2529.26 1828.46S 1903.02S 1274.67 W 1323.81 W 1973.98 3.53 3913.27 4007.24 73.20 73.43 213.63 2557.91 1979.63S 1374.45 W 2054.12 2136.48 0.21 1.15 213.77 2584.89 2054.52S 1424.39 W 2217.04 0.28 4100.35 4198.36 73.00 73.18 213.34 212.94 2611.78 2128.80S 1473.66 W 2296.92 0.64 4292.16 73.52 212.40 2640.29 2667.17 2207.32S 2282.97S 1524.93 W 1573.43 W 2381.26 0.43 4388.81 4480.68 72.14 72.25 212.87 2695.64 2380.57S 1623.13 W 2462.40 2545.62 0.66 1.50 213.30 2723.79 2434.02S 1670.98 W 2624.49 0.46 4578.31 4673.80 72.46 72.34 213.45 213.21 2753.39 2511.71 S 1722.16 W 2708.00 0.26 4766.95 72.27 213.34 2782.26 2810.57 2587.76S 2661.96S 1772.17 W 1820.86 W 2789.72 0.27 4862.14 4959.42 72.10 72.15 213.16 2839.70 2737.75S 1870.55 W 2869.44 2950.86 0.15 0.25 213.53 2869.55 2815.09S 1921.44 W 3033.98 0.37 5054.11 5149.99 72.86 71.87 213.69 214.84 2898.02 2890.30S 1971.43 W 3114.87 0.77 5244.13 72.04 214.87 2927.07 2956.23 2965.81 S 3039.27S 2022.88 W 2074.03 W 3196.25 1.54 5339.52 5428.02 72.47 71.65 214.91 2985.30 3113.79S 2126.00 W 3275.54 3355.99 0.18 0.45 215.66 3012.56 3182.52S 2174.63 W 3430.28 1.23 5459.73 5554.17 71.26 71.13 215.72 215.67 3022.65 3206.93S 2192.17 W 3456.71 1.24 5648.73 70.81 215.64 3053.09 3083.92 3279.54S 3352.17S 2244.33 W 3535.28 0.15 2296.44 W 3613.88 0.34 5744.43 71.47 ' 94 3114.86 3425.63S 2346, 3693.41 0.75 5839.23 71.85 10 3144.69 3498.46S 2402.25 3772.29 0.41 5934.42 6029.29 71.45 215.72 3174.66 3571.68S 2455.18 W 3851.58 0.50 6124.45 71.97 71.01 213.69 3204.43 3645.73S 2506.46 W 3931.48 2.10 6218.22 71.65 213.48 213.98 3234.64 3264.66 3720.90S 2556.38 W 4012.32 1.03 6314.56 71.86 213.96 3294.82 3794.78S 3870.86 S 2605.71 W 2656.83 W 4091.81 0.85 4173.51 0.22 6408.08 6504.75 71.45 213.65 3324.25 3944.42S 2706.22 W 4252.88 0.54 6599.67 71.08 71.45 214.26 3355.30 4020.36S 2757.35 W 4334.63 0.71 8694.15 71.80 215.30 213.81 3385.79 3415.58 4094.19S 2808.63 W 4414.32 1.11 6788.99 71.65 214.25 3445.32 4168.03S 4242.67S 2859.48 W 2909.88 W 4493.96 4574.33 1.54 0.47 6883.97 71.45 215.07 3475.38 4316.77S 2961.12 W 4654.28 0.85 6978.59 7073.30 71.51 215.40 3505.43 4390.08S 3012.88 W 4733.48 0.34 7169.00 71.78 71.66 214.62 3535.26 4463.68S 3064.45 W 4812.99 0.83 7264.23 71.53 214.69 213.69 3565.27 4538.43S 3116.12 W 4893.64 0.14 3595.34 4613.17S 3166.90 W 4974.16 1.01 7359.68 71.46 212.62 3625.84 4688.95S 3216.40 W 5055.55 1.07 7454.65 71.14 212.44 3656.09 4764.79S 3264.77 W 5136.87 0.38 7549.81 71.25 211.76 3686.76 4841.10S 3312.64 W 5218.58 0.69 7644.91 71.52 211.85 3717.12 4917.69 S 3360.14 W 5300.53 0.30 7740.12 71.58 211.42 3747.25 4994.59S 3407.51 W 5382.76 0.43 7834.54 71.26 213.03 3777.34 5070.30S 3455.23 W 5463.86 1.65 7929.83 71.46 214.00 3807.79 5145.58S 3505.09 W 5544.80 0.99 8023.48 8118.06 70.99 214.29 3837.93 5218.96S 3554.85 W 5623.85 0.58 8211.76 71.80 70.93 214.39 3868.11 5292.97S 3605.42 W 5703.62 0.86 215.95 3898.05 5385.55S 3656.56 W 5782.05 1.83 8308.73 71.34 216.73 3929.41 5439.47S 3710.93 W 5862.20 0.87 8403.17 8499.15 71.79 216.15 3959.27 5511.54S 3784.15 W 5940.38 0.75 8594.07 71.46 71.52 216.49 3989.53 5584.93S 3818.10 W 6019.96 0.48 8688.91 71.27 215.26 214.10 4019.66 5657.86S 3870.84 W 6098.94 1.23 4049.92 5731.78S 3921.99 W 6178.69 1.19 8783.13 8879.15 72.05 214.44 4079.57 5805.68S 3972.35 W 6258.33 0.90 8975.74 71.40 71.66 214.90 4109.68 5880.67S 4024.21 W 6339.24 0.82 9070.93 71.21 214.51 214.23 4140.28 5955.99S 4076.37 W 6420.50 0.47 9165.49 72.12 213.17 4170.59 4200.33 6030.47S 6105.14S 4127.31 W 4177.11 W 6500.79 0.55 6581.12 1.43 9260.65 9352.42 70.80 213.53 4230.59 6180.51S 4226.71 W 6662.12 1.43 9448.84 71.72 71.33 214.06 214.01 4260.07 6252.73S 4275.05 W 6739.83 1.14 9545.11 70.81 214.23 4290.63 4321.86 6328.51 S 6403.90S 4326.23 W 4377.31 W 6821.44 8902.64 0.41 9840.59 71.20 214.32 4352.94 6478.508 4428.15 W 6983.04 0.58 0.42 9735.28 9830.61 72.11 214.97 4382.74 6552.44S 4479.25 W 7062.80 1.16 9925.56 72.17 72.49 213.63 4411.98 6627.40S 4530.38 W 7143.58 1.34 10020.33 71.39 212.70 213.37 4440.80 6703.13S 4579.87 W 7224.93 0.99 10115.67 71.27 213.76 4470.18 4500.70 6778.66S 8853.93S 4626.99 W 4678.92 7306.03 1.34 W 7386.96 0.41 10210.87 10305.60 71.47 71.47 213.74 4531.11 6928.93S 4729.04 W 7467.67 0.21 1040Q.87 70.82 214.36 214.31 4561.21 7003.35S 4779.33 W 7547.81 0.62 10495.17 71.39 214.33 4592.00 4622.54 7077.80S 7151.49S 4830.19 W 4880.49 W 7628.05 7707.47 0.68 10591.16 70.87 215.29 4653.59 7226.08S 4932.34 W 7787.96 0.60 1.09 10684.50 10780.24 71.66 216.50 4683.57 7297.67S 4984.16 W 7865.50 1.49 10874.41 71.70 71.34 215.51 4713.66 7371.19S 5037.59 W 7945.15 0.98 10965.44 71.71 214.22 213.78 4743.51 7444.47S 5088.65 W 8024.26 1.35 11066.02 72.81 211.97 4772.36 4803.01 7516.058 7596,50S 5136.93 W 5188.92 8101.33 0.61 W 8187.67 2.03 11161.06 11255.85 75.91 207.52 4828.64 7675.94S 5234.28 W 8272.18 5.56 11350.84 75.98 76.09 202.30 4851.89 7759.31 S 5273.00 W 8359.75 5.34 11446.01 76.41 196.42 192.97 4874.65 7846.23S 5303.54 W 8449.81 6.01 11541.30 76.92 190.18 4897.27 4919.26 7935.63S 8026.46S 5326.98 W 5345.58 W 8541.45 3.54 8633.90 2.90 11636.48 11731.24 77.86 188.26 4940.04 8118.14S 5360.46 W 8726.72 2.20 11826.64 79.26 81.38 183.76 180.84 4958.84 8210.48S 5370.17 W 8819.55 4.88 11921.58 83.69 177.24 4974.89 4987.22 8304.43S 8398.53S 5373.94 W 5372.35 W 8913.23 9006.38 3.75 12015.78 85.92 173.21 4995.76 8491.99S 5364.54 W 9098.13 4.48 4.87 12111.51 12205.25 86.60 87.41 169.45 5002.00 8586.41S 5350.14 W 9189.99 3.98 12283.73 87.90 168.31 169.04 5008.90 8678.26S 5332.09 W 9278.85 1.49 12379.24 86.30 165.83 5010.11 5014.94 8755.15S 8848.23S 5316.69 W 5295.94 W 9353.19 1.12 12478.18 85.30 164.11 5022.19 8943.538 5270.38 W 9442.94 9534.27 3.75 2.01 12569.25 12671.20 87.53 162.52 5027.89 9030.58S 5244.26 W 9617.36 3.01 497AA na 86.60 A7 90 159.31 5033.11 9126,79S 5210.98 W 9708.63 3.27 46A AA 4MA 97 094A rM S r.47A 40 %A/ 0701 4A q An .cfww.vv W.ca wu,vu J -U- 12862.83 12959.88 85.68 86.67 17 5044.08 a4 w.: Q 9301.82S 4.1� 5134..._ ar aa. 1� 9872.63 c.w 5.44 .38 5050.56 9385.81S 5085.93 W 9949.91 3.83 13055.06 13151.94 85.43 87.22 144.84 143.35 5057.12 9465.08S 5033.68 W 10022.00 3.93 13247.90 86.67 140.45 5063.33 5068.44 9543.38S 9618.78S 4976.99 W 4917.87 W 10092.56 10159.95 2.40 3.07 13343.76 13441.38 84.81 85.86 139.07 139.01 5075.56 9691.75S 4856.12 W 10224.59 2.41 5083.50 9765.22S 4792.34 W 10289.48 1.08 13534.61 13634.00 85.06 85.92 138.32 5090.88 9835.01S 4730.96 W 10351.00 1.13 13730.33 86.91 137.27 137.05 5098.70 5104.72 9908.40S 9978.89S 4664.40 W 4599.03 W 10415.48 1.36 13826.75 85.80 135.82 5110.85 10048.62S 4532.71 W 10477.20 10538.04 1.05 1.72 13921.15 85.43 137.26 5118.07 10116.93S 4467.97 W 10597.70 1.57 14020.24 14115.86 85.30 85.67 137.91 5126.08 10189.85S 4401.35 W 10661.67 0.67 14212.66 88.27 138.32 138.28 5133.50 5138.72 10260.82S 10332.98S 4337.71 W 4273.41 W 10724.09 10787.62 0.58 14304.32 88.46 139.75 5141.34 10402.15S 4213.32 W 10848.69 2.69 1.62 14403.11 87.66 139.94 5144.68 10477.61S 4149.66 W 10915.57 0.83 14497.59 14595.80 88.71 88.77 140.60 5147.67 10550.23S 4089.30 W 10980.04 1.31 14689.83 88.58 140.54 139.78 5149.83 5152.01 10626.07S 10698.25 S 4026.94 W 3966.71 W 11047.45 0.09 14788.65 88.40 141.33 5154.61 10774.53S 3903.95 W 11111.50 11179.31 0.83 1.58 14885.21 89.08 142.08 5156.73 10850.30S 3844.13 W 11246.96 1.05 14979.04 15077.72 89.33 88.89 140.80 5158.04 10923.66S 3785.65 W 11312.41 1.39 15173.22 89.51 140.10 138.61 5159.57 5160.90 10999.74S 11072.19S 3722.82 W 3660.62 W 11380.00 11444.07 0.84 15269.55 88.58 138.25 5162.51 11144.25S 3596.72 W 11507.54 1.69 1.04 15365.29 89.33 137.88 5164.25 11215.46S 3532.74 W 11570.16 0.87 15458.93 15557.53 89.02 89.94 136.87 5165.60 11284.35S 3469.34 W 11630.55 1.13 15656.20 87.47 136.76 134.65 5166.50 5168.73 11366.24S 11426.84S 3401.87 W 3332.99 W 11693.40 0.94 15750.16 87.29 134.72 5173.02 11492.84S 3266.25 W 11754.79 11811.90 3.29 0.21 15841.68 87.97 135.69 5176.61 11557.73S 3201.83 W 11868.19 1.29 15938.50 16039.08 87.66 86.29 137.43 139.32 5180.50 11627.98S 3135.30 W 11929.53 1.82 16136.81 87.22 140.03 5185.81 5191.34 11703.05S 11777.44S 3068.59 W 3005.45 W 11995.64 12061.51 2.32 16233.43 87.72 139.63 5195.60 11851.20S 2943.19 W 12126.88 1.20 0.66 16327.51 85.74 138.56 5200.97 11922.18S 2881.69 W 12189.58 2.39 16424.86 16520.36 85.74 87.10 138.96 5208.20 11995.18S 2817.69 W 12253.97 0.41 16615.84 84.93 138.93 138.36 5214.17 5220.80 12067.06S 12138.55S 2755.09 W 2692.16 W 12317.42 1.42 16713.42 83.26 137.98 5230.84 12210.87S 2627.43 W 12380.45 12444.07 2.35 1.75 16809.44 83.69 138.54 5241.75 12282.05S 2563.92 W 12506.72 0.73 16906.15 17002.19 84.93 84.93 138.10 5251.34 12353.92S 2499.93 W 12570.00 1.36 17098.86 83.44 137.82 137.00 5259.83 5269.62 12424.97S 12495.77S 2435.87 W 2370.79 W 12632.44 0.29 17181.44 82.57 136.25 5279.88 12555.358 2314.50 W 12694.52 12748.56 1.76 1.39 17245.00 82.57 136.25 5287.90 12600.88S 2270.91 W 12786.26 0.00 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 187.21 DEGREES (TRUE) A TOTAL CORRECTION OF 20.19 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 17245.00 FEET IS 12803.87 FEET ALONG 190.22 DEGREES (TRUE) Map System: US State Plane 1927 (Exact Solution) Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 uate rrintea:l 1 December 2012 PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: November 28, 2012 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Howard Okland 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501_1 Anchorage, AK 99501 INFORMATION TRANSMITTED RECEIVE DEC 14 20€t AOGCC ❑ Letter ❑ Maps X Report ❑ Agreement X Other—logs, CD DETAIL Q DESCRIPTION ODST-47 (API:50-703-20660-0000) 1 Report GeoTap Pressure Transient Analysis 1 CD- Rom Digital Graphic Logs, Digital Data 5 Well Logs DGR EWR-Phase 4 CTN ALD (1:240) DGR EWR-Phase 4 CTN ALD (1:600) ROP DGR EWR-Phase 4 CTN ALD Horizontal Presentation (1:240) ROP DGR EWR-Phase 4 CTN ALD Horizontal Presentation (1:600) GeTa Formation Pressure Tester Processed Data We request that all data be treated as confidential information. Thank you. Received by:(�" I� Date: 'Z,N tiL Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax 907-343-2128 phone PIONEER [OtOIAW 4K' NATURAL RESOURCES ALASKA NOV 2 9 2012 Letter of Transmittal AOGCC Date: November 28, 2012 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Howard Okland 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps X Report ❑ Agreement X Other —logs DETAIL G p7 , � a (, q QTY DESCRIPTION ODST-47 (AP1:50-703-20660-0000) 1 Report 1 Report Surface Data Logging End of Well Report 4 Well Logs Surface Data Logging - 2" MD Gas Ratio Log, CVE Gas Extraction (1:600) -- Surface Data Logging 2" MD Formation Evaluation Log, CVE Gas Extraction (1:600) ' Surface Data Logging 2" MD Drilling Engineering Log, CVE Gas Extraction (1:600) Surface Data Logging 5" MD Formation Evaluation Log, CVE Gas Extraction (1:240) We request that all data be treated as confidential information. Thank you. ZReceived by: 0#'—j Date: a, a ►Vs-,�r �� Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax 907-343-2128 phone cZf).—la3 I STATE OF ALASKA �! ALASKA OIL ANn GAS rnWRPRVATInN rr)nAMIQ4Z1r-inl WELL COMPLETION OR RECOMPLETION REPORT AND LOC 1a. Well Status: oil ❑✓ • Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20AAC 25.105 20AAc 25110 Development Q • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No, of Completions: _ One Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.: 10/5/2012 212-103 3. Address: 700 G Street, Suite 600 6. Date Spudded: 13. API Number. Anchorage, AK 99501 8/15/2012- 50-703-20660-00-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number. Surface: 2879' FSL, 1186' FEL, Sec. 11, T13N, WE, UM 9/26/2012 ODST-47• Top of Productive Horizon: 8. KB (ft above MSL): 55,2' 15. Field/Pool(s): 4824' FSL, 1259 FEL, Sec. 22, T13N, WE, UM GL (ft above MSL): 13.5' Total Depth: Oooguruk - Torok Oil Pool 9. Plug Back Depth(MD+TVD): 838' FSL, 3468' FEL, Sec. 23, T13N, R7E, UM WA 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 469811.98 y- 6030995.50 Zone-ASP4 ^ 17,245' MD / 5288' TVD ADL 355036 / ADL 355038 TPI: x- 464432.41 y- 6022404.67 Zone-AsP 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 467490.14 y- 6018405.22 Zone-ASP4 • 2410' MD / 2028' TVD 417497 18. Directional Survey: Yes _ No 19. Water Depth, if Offshore: 20_ Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) WA (ft MSL) - 943' MD / 933' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re drill/Lateral Top Window MDrrVD: Gyro, MWD/LWD, PCDC, DGR, DDSr, DIR, ABG, EWR, PWD, BAT Sonic, ABI, ALD, CTN, Geo -Tap N/A 23. CASING, LINER AND CEMENTING RECORD CASING VVi . PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT TOP BOTTOM TOP BOTTOM FT PULLED 16" 109# H-40 Surface 158' Surface 158' 24" Driven 10-3/4" 45.5# BTL-80 Surface 5380' Surface 2998' 13-1/2" 657 sx PF'L'; 250 sx Class'G' 7-5/8" 29.7# L-eo HYD st t/erc�t Surface 12,138' Surface 5004' 9-78" 264 sx Class'G' 4-1/2" 13.5# HYo 521 11,938' 17,191' 4989' 5281' 6-3/4" Uncemented 24. Open to production or injection? Yes Q, No ❑ 25. TUBING RECORD If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number): 4-1/2-,13.59, P-110 H d 521 11,986' See Attachment, pg. 3 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC_ See Attachment, pg. 2, Was hydraulic fracturing used during completion? Yes 0 No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2000' Freeze protect OA w/ 100 bbls diesel 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for 011 -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period -11111. 1 Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corn): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 8%�� None NOV 06 1[112 rur i iv--rvr r &ViSw iV14U1c CON I INUED ON REVERSE suomlr original only 5W STATE OF ALASKA ALASKA OIL AND GAS CONSFRVATION rnMMIS_qI(1N RECEIVED NSU n s ?� WELL COMPLETION OR RECOMPLETION REPORT 1a. Well Status: oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 [:] VVINJ ❑ WAG ❑ WDSPL [_No. of Completions: _ One 1b. Well a Development ❑ Exploratory F-1GINJ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Pioneer Natural Resources Alaska, Inc. 5. Date Comp., Susp., or Aband.: 10/5/2012 12. Permit to Drill Number: 212-103 3. Address: 700 G Street, Suite 600 Anchorage, AK 99501 6. Date Spudded: 8/15/2012 13. API Number: 50-703-20660-00-00 4a. Location of Well (Governmental Section): Surface: 2879' FSL, 1186' FEL, Sec. 11, T13N, R7E, UM Top of Productive Horizon: 4824' FSL, 1259 FEL, Sec. 22, T13N, R7E, UM Total Depth: 838' FSL, 3468' FEL, Sec. 23, T13N, R7E, UM 7. Date TD Reached: 9/26/2012 14. Well Name and Number: ODST-47 8. KB (ft above MSL): 56.2' GL (ft above MSL): 13.5' 15. Field/Pool(s): Oooguruk - Torok Oil Pool 9. Plug Back Depth(MD+TVD): N/A 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 469811.98 Y- 6030995.50 Zone -ASP 4 TPI: x- 464432.41 y- 6022404.67 Zone -ASP 4 Total Depth: x- 467490.14 y- 6018405.22 Zone -ASP 4 10. Total Depth (MD + TVD): 17,245' MD / 5288' TVD 16. Property Designation: ADL 355036 / ADL 355038 11. SSSV Depth (MD + ND): 2410' MD / 2028' TVD 17. Land Use Permit: 417497 18. Directional Survey: Yes ❑✓ No ❑ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MDITVD: 943' MD / 933' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): Gyro, MWD/LWD, PCDC, DGR, DDSr, DIR, ABG, EWR, PWD, BAT Sonic, ABI, ALD, CTN, Geo -Tap 22-Re-drill/Lateral Top Window MD/TVD: N/A 23. CASING, UNER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16" 109# H-40 Surface 158' Surface 158' 24" Driven 10-3/4" 45.5# L-80 TC M Surface 5380' Surface 2998' 13-1/2" 657 sx PF'L; 250 sx Class'G' 7-5/8" 29.7## Ll HYD 511/BTC-M Surface 12,138' Surface 5004' 9-7/8" 264 sx Class'G' 4-1/2" 12.6# HYD 521 11,938' 17,191' 4989' 5281' F 6-3/4" Uncemented 24. Open to production or injection? Yes No ❑ If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size and Number): See Attachment, pg. 2 25. TUBING RECORD SIZE DEPTH SET (MD) I PACKER SET (MD/TVD) 4-1/2" 126# P-110 H d 521 11,986' See Attachment, pg. 3 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2000' Freeze protect OA w/ 100 bbls diesel 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size:Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate .♦ Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (Gorr): 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑Q Sidewall Cores Acquired? Yes ❑ No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. None o m iU-wdi Revised IOicdiz CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top 860' 854' needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 1803' 1668' West Sak 2990' 2278' Top Cretaceous Tuffs 4906' 2853' Hue 2 6002' 3196' None Brookian 213 9231' 4221' Top Torok 12,053' 4998' Base Nuna (Torok) 17,192' 5281 Formation at total depth: 17,245' 5288' 31. List of Attachments: 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alex Vaughan, 343-2186 Email: a1ex.vau@hanPpxd.com Printed Name: Alex Vaughan Title: Sr. Staff Operations Engineer Signature: Phone: 343-2186 Date: 11/5/2012 %A/ 11 Aln ..IAS. ... L... nn •� Janie �.�rnme .- r Ilt iv unu: t Iz-1ua Prepared By: Kathy Campoamor, 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 10/2012 ODST-47 Torok Production Well Completion Updated 10/29/2012 I 16" Conductor Upper Completion 1) Tubing Hanger IDD 43' ND 43' 2) 4-'/" 12.6#/ft Hydril 521 Tubing (2 its) 3) 4-Y2' 12.6#/ft Hydril 521 Tubing Packer Fluid mix: 4) 4-'/" Halliburton 'XXO' SVLN w/ 3.813" "X" profile RTS -8 2410' 2028' Inhibited Kill weiaht with singlet/4" x 0.049" s/s control line. I Brine Cannon Cross -coupling clamps on every joint 4 with 2000' TVD 5) 4-'/" 12.6#/ft Hydril 521 Tubing I diesel cap 6) 4-'/i' x V GLM, KBMG Hydril 521 w/ SOV Set at max 68 deg 2674' 2157' I 7) 4-'/" 12.6#/ft Hydril 521 Tubing 8) HES X 3.813" Set at max 68 deg 2776' 2202' 9) 4-'/2' 12.6#/ft Hydril 521 Tubing I 10) 4-'/" x 1" GLM, KBMG Hydril 521 w/ DV 5580' 3062' j 10-3/4" 45.5 ppf L-80 BTC 11) 4-'/i' 12.6#/ft Hydril 521 Tubing Surface Casing 12) 4-1/2" x 1" GLM, KBMG Hydril 521 w/ DV 8595' 4020' j @ 5380' MD / 2998' TVD 13) 4-'/" 12.6#/ft Hydril 521 Tubing j cemented to surface 14) 4-Y2' x 1" GLM, KBMG Hydril 521 w/ DV 10944' 4766' 15) 4-%" 12.6#/ft Hydril 521 Tubing j 16) HES XN 3.813" (3.725" NoGo) - with RHC Plug 11045' 4797' 17) 4-'/2' 12.6#/ft Hydril 521 Tubing 18) 4-1/2" Halliburton 'ROC' Gauge Carrier w/ 1/4" x 0.049" s/s control line 11849' 4978' 19) 4-'/i' 12.6#/ft Hydril 521 Tubing 20) GBH -22 Locator Tubing Seal Assembly with Auto Entry Mule Shoe 11983' 4993' Bottom of Shoe 11986' 4994' 4-1/2" 12.6 ppf P-110 Hydril 521 Tubing TOC Estimated 500' above top of Kuparuk 7-5/8" 29.7 ppf ' I',., ` .0 ` 49 61 73 -------------65 --------------- 97 109 L-80 BTC -Mod Casing 29 ` % - - - - - - - - - - - - - 5004' TVD - - - - - - - - - - - - - - - - 4-'/" Hydril 521 Liner with Baker Hughes Multi -Point Frac Sleeves (3 per stagel) isolated with ECP's + Resman 6-3/4" Hole TD at Carriers (2 per stage) at 17,245' MD / 5288' TVD ODST-47 Torok Production Well Completion Updated 10/29/2012 4-'/" Hydril 521 Liner with Baker Hughes Multi -Point Frac 6-3/4" Hole TD at Sleeves (3 per stagel) isolated with ECP's + Resman at 17,245' MD / Carriers (2 per stage) 5288, TVD Lower Completion MD TVD I 21) Baker 5-Yi' X 7" ZXP Liner Top Packer with Tie Back 11938' 4989' 1 16" Conductor extension and Flex Lock Hanger 22) 4-'Y2" 12.6#/ft Hydril 521 Liner 23) Baker ECP Packer (4-%" Hydril 521) 12543' 5027' Packer Fluid mix: 24) 4-Y2" 12.6#/ft Hydril 521 Liner 1 Inhibited Kill weight 25) Baker ECP Packer (4-'/z" Hydril 521) 12586' 5029' i Brine 26) 4-'/z" 12.6#/ft Hydril 521 Liner a 27) Baker Multi -Point Frac Sleeve with segmented ball seat (3.000 ball / 2.948 Seat) 12699' 5035' With 2000' ND 28) 4-'Y2" 12.6#/ft Hydril 521 Liner j diesel car) 29) 4-Yz" Resman Tracer Carrier w/ 15 ft pups on each side 12773' 5039' 30) 4-YV 12.6#/ft Hydril 521 Liner 31) Baker Multi -Point Frac Sleeve with segmented ball seat (3.000 ball / 2.948 Seat) 12857' 5044' 32) 4-'/2" 12.6#/ft Hydril 521 Liner i 33) 4-'h" Resman Tracer Carrier w/ 15 ft pups on each side 12931' 5049' 34) 4-'/2" 12.6#/ft Hydril 521 Liner 35) Baker Multi -Point Frac Sleeve with solid ball seat (3.000 ball / 2.948 Seat) 12973' 5051' j 10-3/4" 45.5 ppf L-80 BTC 36) 4-Y3" 12.6#/ft Hydril 521 Liner j Surface Casing 37) Baker ECP Packer (4-'h" Hydril 521) 13083' 5059' 6 GL @ 5380' MD / 2998' TVD 38) 4-'/V 12.6#/ft Hydril 521 Liner I 39 Baker Multi -Point Frac Sleeve with segmented ball seat 2.938 ball / 2.885 Seat) 13201' 5066' X i cemented to surface 40) 4-'/2" 12.6#/ft Hydril 521 Liner $ 41) 4-'/2" Resman Tracer Carrier w/ 15 ft pups on each side 13234' 5068' 42) 4-'/z" 12.6#/ft Hydril 521 Liner 1 43) Baker Multi -Point Frac Sleeve with segmented ball seat (2.938 ball / 2.885 Seat) 13317' 5073' 1 44) 4-%" 12.6#/ft Hydril 521 Liner 45) 4-1/2" Resman Tracer Carrier w/ 15 ft pups on each side 13392' 5080' 10 GL 46) 4-'/:" 12.6#/ft Hydril 521 Liner I 47) Baker Multi -Point Frac Sleeve with solid ball seat (2.938 ball / 2.885 Seat) 13433' 5083' j 48) 4-%" 12.6#/ft Hydril 521 Liner 49) Baker ECP Packer (4-YI" Hydril 521) 13544' 5092' 50) 4-'/" 12.6#/ft Hydril 521 Liner 51) Baker Multi -Point Frac Sleeve with segmented ball seat (2.875 ball / 2.823 Seat) 13662' 5101' 52) 4-%" 12.6#/ft Hydril 521 Liner GL 4-1/2' 12.6 53) 4-'/.' Resman Tracer Carrier w/ 15 ft pups on each side 13695' 5103' 12 ppf 54) 4-'/" 12.6#/ft Hydril 521 Liner j P-110 Hydril 55) Baker Multi -Point Frac Sleeve with segmented ball seat (2.875 ball / 2.823 Seat) 13778' 5108' j 521 56) 4-'/i' 12.6#/ft Hydril 521 Liner j Tubing 57) 4-W Resman Tracer Carrier w/ 15 ft pups on each side 13894' 5116' 58) 4-'/V 12.6#/ft Hydril 521 Liner 59) Baker Multi -Point Frac Sleeve with solid ball seat (2.875 bal l / 2.823 Seat) 13935' 5119' 14 GL ;,: 60) 4-Y2" 12.6#/ft Hydril 521 Liner I 61) Baker ECP Packer (4-1/V Hydril 521) 14088' 5131' 16 XN I 62) 4-Y" 12.6#/ft Hydril 521 Liner 63) Baker Multi -Point Frac Sleeve with segmented ball seat (2.813 ball / 2.760 Seat) 14284' 5141' 64) 4-'/" 12.6#/ft Hydril 521 Liner 18aoc 65) 4-1/2" Resman Tracer Carrier w/ 15 ft pups on each side 14400' 5145' --- TOC Estimated 66) 4-'/" 12.6#/ft Hydril 521 Liner . 500' above top of 67) Baker Multi -Point Frac Sleeve with segmented ball seat (2.813 ball / 2.760 Seat) 14483' 5147' •`. Kuparuk 68) 4-'/" 12.6#/ft Hydril 521 Liner 69) 4-Y:" Resman Tracer Carrier w/ 15 It pups on each side 14558' 5149' 70) 4-YV 12.6#/ft Hydril 521 Liner 71) Baker Multi -Point Frac Sleeve with solid ball seat (2.813 bal l / 2.760 Seat) 14682' 5152' 21 72) 4-%" 12.6#/ft Hydril 521 Liner 20 73) Baker ECP Packer (4-Yz" Hydril 521) 14876' 5157' 74) 4-Y]" 12.6#/ft Hydril 521 Liner 75) Baker Multi -Point Frac Sleeve with segmented ball seat (2.750 ball / 2.698 Seat) 14975' 5158' 76) 4-'/z" 12.6#/ft Hydril 521 Liner 25 77) 4-Y" Resman Tracer Carrier w/ 15 ft pups on each side 15007' 5158' 78) 4-'/" 12.6#/ft Hydril 521 Liner 27 7-5/8" 'i 37 79) Baker Multi -Point Frac Sleeve with segmented ball seat (2.750 ball / 2.698 Seat) 15049' 5159' 29.7 ppf `� ` L-80 BTC 49 61 73 85 97 109 121 -Mod Casing 29- @12,138'MD/ - - - - - - - - - - - - - - - 5004' TVD _ 4-'/" Hydril 521 Liner with Baker Hughes Multi -Point Frac 6-3/4" Hole TD at Sleeves (3 per stagel) isolated with ECP's + Resman at 17,245' MD / Carriers (2 per stage) 5288, TVD ODST-47 Torok Production Well Completion 16" Conductor Packer Fluid mix: Inhibited Kill weight Brine with 2000' TVD diesel cap I i 10-3/4" 45.5 ppf L-80 BTC j Surface Casing @ 5380' MD / 2998' TVD cemented to surface 4 4-1/2" 12.6 ppf I P-110 Hydril i 521 i Tubing I, TOC Estimated 500' above top of Kuparuk Updated 10/29/2012 Lower Completio[L MID LVD 80) 4-Y:" 12.6#/ft Hydril 521 Liner 81) 4-YV Resman Tracer Carrier w/ 15 ft pups on each side 15082' 5160' 82) 4-Yz" 12.6#/ft Hydril 521 Liner 83) Baker Multi -Point Frac Sleeve with solid ball seat (2.750 bal I / 2.698 Seat) 15123' 5160' 84) 4-Y�' 12.6#/ft Hydril 521 Liner 85) Baker ECP Packer (4-1/2" Hydril 521) 15150' 5161' 86) 4-'/" 12.6#/ft Hydril 521 Liner 87) Baker Multi -Point Frac Sleeve with segmented ball seat (2.688 ball / 2.635 Seat) 15310' 5163' 88) 4-'/" 12.6#/ft Hydril 521 Liner 89) 4-%" Resman Tracer Carrier w/ 15 ft pups on each side 15384' 5165' 90) 4-Yz" 12.6#/ft Hydril 521 Liner 91) Baker Multi -Point Frac Sleeve with segmented ball seat (2.688 ball / 2.635 Seat) 15467' 5166' 92) 4-Y2" 12.6#/ft Hydril 521 Liner 93) 4-Yz" Resman Tracer Carrier w/ 15 ft pups on each side 15542' 5167' 94) 4-'/:" 12.6#/ft Hydril 521 Liner 95) Baker Multi -Point Frac Sleeve with solid ball seat (2.688 ball / 2.635 Seat) 15625' 5168' 96) 4-Y:" 12.6#/ft Hydril 521 Liner 97) Baker ECP Packer (4-'/" Hydril 521) 15778' 5174' 98) 4-Y2" 12.6#/ft Hydril 521 Liner 99) Baker Multi -Point Frac Sleeve with segmented ball seat (2.625 ball / 2.573 Seat) 15876' 5178' 100) 4-'/" 12.6#/ft Hydril 521 Liner 101) 4-Yz" Resman Tracer Carrier w/ 15 ft pups on each side 15951' 5181' 102) 4-'/" 12.6#/ft Hydril 521 Liner 103) Baker Multi -Point Frac Sleeve with segmented ball seat (2.625 ball / 2.573 Seat) 16034' 5186' 104) 4-1/V 12.6#/ft Hydril 521 Liner 105) 4-Yz" Resman Tracer Carrier w/ 15 ft pups on each side 16109' 5190' 106) 4-%" 12.6#/ft Hydril 521 Liner 107) Baker Multi -Point Frac Sleeve with solid ball seat (2.625 ball / 2.573 Seat) 16191' 5194' 108) 4-%" 12.6#/ft Hydril 521 Liner 109) Baker ECP Packer (4-1/2' Hydril 521) 16302' 5199' 110) 4-Y." 12.6#/ft Hydril 521 Liner 111) Baker Multi -Point Frac Sleeve with segmented ball seat (2.563 ball / 2.510 Seat) 16483' 5212' 112) 4-'/" 12.6#/ft Hydril 521 Liner 113) 4-'/" Resman Tracer Carrier w/ 15 ft pups on each side 16516' 5214' 114) 4-W 12.6#/ft Hydril 521 Liner 115) Baker Multi -Point Frac Sleeve with segmented ball seat (2.563 ball / 2.510 Seat) 16599' 5219' 116) 4-'Y2" 12.6#/ft Hydril 521 Liner 117) 4-Yz" Resman Tracer Carrier w/ 15 ft pups on each side 16716' 5231' 118) 4-Y2" 12.6#/ft Hydril 521 Liner 119) Baker Multi -Point Frac Sleeve with solid ball seat (2.563 ball / 2.510 Seat) 16757' 5236' 120) 4-Y2" 12.6#/ft Hydril 521 Liner 121) Baker ECP Packer (4-%" Hydril 521) 16951' 5255' 122) 4-'/:" 12.6#/ft Hydril 521 Liner 123) 4-Y:" Resman Tracer Carrier w/ 15 ft pups on each side 17040' 5263' 124) 4-Yz" 12.6#/ft Hydril 521 — 10 ft Pup 125) Pressure Activated Sleeve "B" 5,800 psi 17076' 5267' 126) 4-Yz" 12.6#/ft Hydril 521 — 10 ft Pup 127) Pressure Activated Sleeve "A" 5,800 psi 17089' 5269' 128) Wellbore Isolation Valve "WIV° 17091' 5269' 129) 4-Y:" 12.6#/ft Hydril 521 — 10 ft Pup 130) 4-'/" Resman Tracer Carrier w/ 15 ft pups on each side 17120' 5272' 131) 4-Yz" 12.6#/ft Hydril 521 Liner 132) Baker 5-%" EZ Ream Shoe 17188' 5281' Bottom of Shoe 17191' 5281' 7-5/8" 29.7 ppf, LJ �� ` . 49 61 73 ------------85 ---------------97--------------109 L-80 BTC -Mod Casing 29 - - - -- - - - - - - - - - 5004' TVD - - - - - - - - - - - - - - 4-%" Hydril 521 Liner with Baker Hughes Multi -Point Frac Sleeves (3 per stagel) isolated with ECP's + Resman Carriers (2 per stage) N 6-3/4" Hole TD at at 17,245' MD / 5288' TVD Pioneer Nawral Resources Alaska Inc. ODST-47 Page 2 AOGCC Form 10-407 Well Completion or Recompletion Report and Log Open to Production or Injection Box #24 - Attachment 24. Open to production or injection 4-'/2", 12.6#, P-110 Hydril 521 Uncemented Liner Frac Sleeves: MD TVD 12,699'- 12,702' 5035'- 5035' 12,857'- 12,860' 5044'- 5044' 12,973'- 12,976' 5051'- 5052' 13,201'- 13,205' 5066'- 5066' 13,317'- 13,321' 5073'- 5074' 13,433'- 13,436' 5083'- 5083' 13,662'- 13,665' 5101'- 5101' 13,778'- 13,781' 5108'- 5108' 13,935'- 13,938' 5119'- 5119' 14,284'- 14,287' 5141'- 5141' 14,483'- 14,487' 5147'- 5147' 14,682'- 14,685' 5152'- 5152' 14,975'- 14,978' 5158'- 5158' 15,049'- 15,053' 5159'- 5159' 15,123'- 15,126' 5160'- 5160' 15,310' - 15,314' 5163'- 5163' 15,467'- 15,471' 5166'- 5166' 15,625'- 15,628' 5168'- 5168' 15,876'- 15,880' 5178'- 5178' 16,034'- 16,038' 5186'- 5186' 16,191'- 16,194' 5194'- 5194' 16,483'- 16,487' 5212'- 5212' 16,599'- 16,603' 5219'- 5220' 16,757'- 16,760' 5236'- 5236' Pressure Activated Sleeves: MD TVD 17,076'- 17,079' 5267'- 5267' 17,089'- 17,091' 5269'- 5269' Pioneer Natural Resources Alaska Inc. ODST-47 Page 3 AOGCC Form 10-407 Well Completion or Recompletion Report and Log Packer Set (MD/TVD), Box #25 - Attachment ZXP Liner Top Packer MD TVD 11,938' 4989' ECP Packers MD TVD 12,543'- 12,567' 5027'-5028' 12,586'- 12,609' 5029'-5030' 13,083'- 13,106' 5059'-5061' 13,544'- 13,567' 5092'- 5094' 14,088' - 14,111' 5131'- 5133' 14,876'- 14,899' 5157'- 5157' 15,150'- 15,174' 5161'- 5161' 15,778'— 15,801' 5174'— 5175' 16,302'— 16,325' 5199'— 5201' 16,951'— 16,974' 5255'— 5257' PIONEEROperations Summary Report - Staf^ Well Name: ODST-47 NATURAL RFSni JRrF4 Well Name: ODST-47 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: ORIG DRILL & COMPLETE Start Date: 8/14/2012 End Date: Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud N/gal) Summary 8/14/2012 8/15/2012 158.0 8.75 NU diverter stack and line. PU 180 jts. of 5" DP utilizing mousehole and stand back in derrick. PU 14 jts. of 5" HWDP and jars and stand back in derrick. **Perform Koomey test -- Initial pressure 3000 psi, After close 1860 psi, 33 seconds for 200 psi pre charge, 148 seconds for full pressure pre charge, 41 seconds for bag to close, 11 seconds for knife valve to open.Test all visual and audio gas alarms. Passed. AOGCC Rep. John Crisp waived right to witness_Diverter function test at 13.00 hrc on 8/14/17 ** Service rig. PU bit, motor and 1 stand of HWDP. Fill hole and check for leaks. 8/15/2012 8/16/2012 158.0 697.00 9.00 Continue to tighten studs on flow riser and tighten threaded connection on kelly hose and MU to Top Drive. Test same. OK. RU Gyro. Clean out conductor t/158'. Drill new 13-1/2" surface hole t/221'. POOH and PU BHA #1. RIH t/221'. Drill f/221' U855'. Take Gyro survey every stand. 8/16/2012 8/17/2012 855.0 1,963.00 9.00 Directional drill new 13-1/2" surface hole f/855' t/1,011'. RD Gyro wireline equipment (MWD receiving clean surveys beginning at 782' MD). Continue Directional drill new surface hole f/1,01 l' t/2,818'. 8/17/2012 8/18/2012 3,007.0 703.00 9.25 Directional drill new surface hole f/2,818' t/3,007'. Pump 11.0 ppg HV sweep to surface - CBU hole clean 3x. POOH wet 5 stands (no swab). Pump dry job. POOH f/2,540' to BHA at 632'. Stand back HWDP and jars. LD TM Hang Off Collar and change out Pulsar. Adjust motor and RIH U3,007'. Directional drill f/3,007' t/3,710'. 8/18/2012 8/19/2012 3,710.0 1,679.00 9.35 Directional drill new surface hole (/3,710' t/5389' (13 1/2" TD). -Pump HV weighted sweep to surface. CBU hole clean 3x total. 8/19/2012 8/20/2012 5,389.0 0.00 9.55 Continue to CBU 3x. Pump carbide bomb after sweep returned to surface. Carbide bomb back at calculated strokes (9180). POOH 6 stands wet. 50-75k overpull first 3 stands. Pump dry job. POOH to surface. Clean Stabilizers and bit. RIH wiping tight spots at various depths. Wash & ream f/4,794' to TD at 5,389'. Pump HV weighted sweep to surface. CBU 3x. Pump Carbide bomb surface to surface. Back ream f/5,389' U4,817'. 8/20/2012 8/21/2012 5,389.0 0.00 9.65 Continue backreaming f/4,722' t/3,012'. CBU x 1.75 while R & R DP. POOH on elevators f/3,012' t/1,681. Pull through tight spot at 1,681'. -Clean up tight spot and POOH f/1,681' to surface. LD BHA. RU and run 10 3/4" 45.5# L-80 BTC -M surface casing t/2,418'. 8/21/2012 8/22/2012 5,389.0 0.00 9.65 Continue to run 10 3/4" casing per tally f/2,418' t/4.891'(121 jts). PU 10 3/4" Tamm Port Collar. Continue to run 10 3/4" casing t/5,336'. PU hanger and landing joint. Land casing. 10 3/4" float shoe at 5,380'. RU HES cement head and lines. Give to Halliburton: -Pump 10 bbls seawater (kick out bottom plug w/ last 2 bbls). -Test lines to 4000 psi - Bleed and load top plug. -Pump 100 bbls tuned spacer at 10.0 ppg - Drop 2nd bottom plug. -Mix and pump 510 bbls (657 sx) type PF "L" lead cement at 10.7 ppg (4.59 yield)+ 0.15% D -Air 3000P + D -Air 5000P. f , -Mix and pump 51 bbis(2_50 ax) of Class a tail cement at 15.8 ppg (1.19 yield)+ 1.0% CaC12 & -Drop Top plug and kick out w/ 20 bbls seawater. -Displace w/ rig pumps using 9.6 ppg water base mud at 10 bpm. ump plug on calculated strokes (4950 stks.). -Pressure up to 2000 psi and observed washout in mud manifold., -Bleed pressure, check floats. Holding - CIP @ 14:40 hrs. -Full returns observed throughout cement job and displacement. -Verified cement to surface (158 bbls). RD cement head and tines. RD Tesco equipment. ND diverter system. ** AOGCC was notified of upcoming BOP test. AOGCC Rep. Jeff Jones waived right to witness test at 13:30 hrs on 08/21/12. I Page 1/7 Report Printed: 11/5/2012 PIONEEROperations Summary Report - Stat^ Well Name: ODST-47 NATIIRAI RF4t'IIIR(:F.q �1 - Start Date End Date Start Depth (ftKB) FoottMeters (ft) Dens Last Mud (Ib/gal) Summary 8/22/2012 8/23/2012 5,389.0 0.00 9.55 Finish ND surface riser. Install VG multi -bowl wellhead and test same to 3500 psi - Good test. NU drilling riser and BOP stack. NU MPD equipment and lines. NU flow line and install trip nipple. 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 14 choke manifold valves to 250 psi low/4500 psi high. All tests charted and all tests held for 5 min. AOGCC Rep. Jeff Jones waived witness at 13:30 hrs on 08/21112. Initial system psi: 3000; 2000 after closure; 200 psi= 28 sec, full pressure 1 min. 57 sec. Install MPD test flange and attempt to test MPD lines to 250 psi low/4500 psi high -- flange leaking at top of annular. Tighten all flange bolts and retest same to 250 psi low/4500 psi high -- Good test. TIH with 75 joints 5" DP f/ surface 02,385'. Flush DP with 70 bbls at 10 bpm with 2100 psi. POOH f/2,385't/ surface racking back clean DP. Test 10 ` 3/4" casing to 3500 psi on chart for 30 min -- Good test. PU BHA #3 and install wear bushing in wellhead on top stab at 68'. 8!23/2012 8/24/2012 5,409.0 20.00 9.55 t Land wear bushing, verify same, and run in LDS as per VG rep. TIH f/68' 05,163'. Drill cement and float equipment f/5,163' 05,389'. Drill new 9-7/8" hole f/5,389' 05,409'. Perform F.I.T. at 5 380' MD/2 997' TVD to470 si with MW of 9.5 p =12.5 ppg EMW. POOH f/5,409' U surface. PU directional BHA and TIH f/ surface 04,637'. 8/24/2012 8/25/2012 5,409.0 1,436.00 9.50 TIH f/4,637' 05,300'. Slip and cut 60' of drill line. Establish MPD parameters, wash and ream down f/5,397' U5,409'. Directional drill new 9-7/8" hole f/5,409' U6,537' using MPD at 11.6 ppg EMW. CBU due to elevated PWD readings. Directional drill f/6,537' 06,845'. 8/25/2012 8/26/2012 6,845.0 2,342.00 9.50 Directional drill from 6,845' to 9,187' maintaining 11.5 ppg EMW using MPD. 8/26/2012 8/27/2012 9,187.0 333.00 9.55 Directional drill f/9,187' 09,250'. Pump 60 bbl hi -vis weighted sweep and CBU hole clean 7x. Rack back 1 stand every bottoms up. POOH (/8,672' 04,447'. TIH f/4,447' 06,632'. Wash and ream f/6,632' 09,198'. Establish circulation using step rate method and wash down f/9,198' 09,250'. Directional drill f9,250' 09,520' maintaining 11.5 ppg EMW using MPD. 8/27/2012 8/28/2012 9,520.0 1,768.00 9.50 Directional drill new intermediate hole f/9,520' 011,003'. Rig down MPD lines in search of obstruction causing pressure uctuatrons -- oun a x 3" piece of unidentified rubber debris in lines. Directional drill f/11,003' 011,098'. Change out RCD head due to a bearing failure. Directional drill f/11,098' 011,288' maintaining 11.5 ppg EMW using MPD. 8/28/2012 8/29/2012 11,288.0 932.00 9.70 Directional drill f/11,288' 012,220' maintaining 11.5 ppg EMW using MPD. CBU hole clean 7X with two 55 bbl hi -vis weighted sweeps. Rack back 1 stand every bottoms up f/12,220' 011,859'. POOH f/11,859' 011,573'. 8/29/2012 8/30/2012 12,220.0 0.00 9.80 POOH f111,573' 04,827'. TIH f/4,827' 05,112' — ran out of slack off weight. Establish circulation using step rate method and circulate casing clean. Wash and ream in the hole f/5,207' t/5,380'. Back ream out the hole 85,380' 01,309'. CBU 2x and reciprocate to clean casing. TIH f/1,309' 05,302'. Pump 30 bbl hi -vis weighted sweep and CBU casing clean 2x. Perform function test on BOP stack while servicing rig and top drive. TIH f/5,302't/7,297'. 8/30/2012 8/31/2012 12,220.0 0.00 9.40 TIH f/7,297' 09,578'. Establish circulation using step rate method and CBU. Rotate in the hole f/9,578' 09,863'. Establish circulation using step rate method and CBU 2x. Ream in the hole f/9,863' 09,958' -- tight hole and pack off events. Break MPD lines in search of obstruction causing pressure fluctuations. Found several large pieces of unidentified rubber debris in lines. Test line to 250 psi low/1000 psi high -- Good test. Ream in the hole f/9,958' U10,433' -- tight hole and pack off events. 8/31/2012 9/1/2012 12,220.0 0.00 9.30 Ream in the hole f/10,433' 010,850'. Break MPD chokes in search of obstruction causing pressure fluctuations. Found large amounts of large cuttings in both A and B chokes. Establish circulation using step rate method and CBU 3x. Ream in the hole f/10,850' 010,908'. Establish circulation using step rate after losing all returns due to pack off. Ream in the hole f/10,908' t/11,003'. Attempt to establish circulation using step rate after losing all returns. Unable to achieve full drilling rate without packing off. POOH f/11,003' 010,587'. Attempt to establish circulation using step rate after losing all returns. Unable to achieve over 275 gpm without packing off. POOH f/10,587' 08,247'. Page 2/7 ReportPrinted: 11/5/2012 1 PIONEEROperations Summary Report - Stat- Well Name: ODST-47 NATIIRAI RF4(IIIRt^f=C 11 Start Date End Date Start Depth (ftKB) Footmeters (ft) Dens Last Mud (lb/gal) Summary 9/1/2012 9/2/2012 12,220.0 0.00 9.40 POOH f/8,247' U5,302'. Change out RCD head due to bearing seal failure. Establish circulation using step rate method and circulate the casing clean. Rotate and lubricate in the hole f/5,390' 06,102'. Attempt to establish circulation using step rate after pack off event -- unable to achieve full drilling rate without packing off. POOH f/6,102' 05,300'. Establish circulation using step rate method and circulate while building 12.8 ppg spacer and weighting up kill mud from 12.1 ppg to 12.8 ppg Note: Gave 24 hr notice of BOP test, Bob Noble waived witness 17:30 hrs 09/1/12. 9/2/2012 9/3/2012 12,220.0 0.00 12.80 POOH f/5,300' 04,880' -- laying 50 bbl hi -vis 12.8 ppg pill in casing. Displace well from 9.3 ppg to 12.8 ppg MOBM. Pull RCD head and install trip nipple. POOH f/4,880' U surface. Test BOPE per AOGCC PTD: Test upper and lower VBR w/ 5" test joint to 250 psi low/4500 psi high. Test upper and lower IBOP valve to 250 psi low/4500 psi high. Upper IBOP did not pass test. 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 14 choke manifold valves to 250 psi low/4500 psi high. All tests charted and all tests held for 5 min. AOGCC Rep. Bob Noble waived witness at 17:30 hrs on 09/01/12. Initial system psi: 3000; 2000 after closure; 200 psi= 19 sec, full pressure 1 min. 44 sec. Change out upper IBOP on top drive. Test upper IBOP valve to 250 psi low/4500 psi high -- on chart held for 5 min. RD testing equipment. TIH f/ surface t/5,179'. 9/3/2012 9/4/2012 12,220.0 0.00 9.40 TIH f/5,179' 05,369'. Remove trip nipple and install RCD head. Pump 30 bbl spacer and displace well from 12.8 ppg to 9.3 ppg MOBM. Ream in the hole f/5,369' 06,182' -- multiple pack off events. Establish circulation using step rate method after full pack off. Ream in the hole f/6,182' t/6,794'-- multiple pack off events. Change out RCD head due to element failure. Ream in the hole f/6,794' 07,110'. 9/4/2012 9/5/2012 12,220.0 9.70 Ream in the hole f/7,110' t/7,296'. Change out RCD head due to element failure. Ream in the hole f/7,296' 08,695'. Break MPD chokes in search of obstruction causing pressure fluctuations -- found 2" x 3" piece of rubber from failed RCD element. Stage up pumps and CBU 1 x. Circulate with #2 mud pump while repairing #1 mud pump. Ream in the hole f/8,695' 08,818'. 9/5/2012 9/6/2012 12,220.0 9.65 Ream in the hole f/8,818' t/8,915'. POOH f/8,915' 08,444' attempting to establish circulation. Establish circulation using step rate method after full pack off. CBU hole clean 11x at full rate. Ream in the hole (/8,444' 08,599'. CBU hole clean 2x. Ream in the hole (/8,599' 08,841'. 9/6/2012 9/7/2012 12,220.0 9.60 Ream in the hole f/8,841' 08,990'. Packed off at 8,990'. Pull 08,940' to regain circulation. Change out valve and seat on #1 pump. Stage up pumps after making pump repairs. Repair wash out on discharge manifold at vibrator hose and test same to 4500 psi -- Good test. Establish circulation with step rate method with multiple pack off events. Ream in the hole f/8,940' 09,076'. Packed off at 9,076'. Pull 08,940' to regain circulation. Establish circulation with step rate method with multiple pack off events. Ream in the hole f/8,940' 09,170'. 9/7/2012 9/8/2012 12,220.0 9.50 Ream in the hole (/9,170' 09,290'. Establish circulation with step rate method with multiple pack off events. Ream in the hole f/9,275' 09,360'. Service rig and top drive while function testing BOPE. Ream in the hole f/9,360' 09,392'. Packed off at 9,392'. Pull 09,370' to regain circulation. Establish circulation with step rate method with multiple pack off events. Ream in the hole f/9,370' 09,860' - Packed off at 9,860'. Pull 09,753' to regain circulation. Attempt to establish circulation with step rate method. Multiple pack off events -- could not achieve full rate. 9/8/2012 9/9/2012 12,220.0 9.50 Attempt to establish circulation with step rate method. POOH f/9,753' 09,361' attempting to circulate. Establish circulation with step rate method with multiple pack off events. Rotate and lubricate in the hole f/9,361' 011,600'. 9/9/2012 9/10/2012 12,220.0 9.60 Rotate and lubricate in the hole f/11,600' U12,148'. POOH f/12,148' 05,364'. Establish circulation with step rate method and pump 50 bbl hi -vis sweep and CBU hole clean 6x. Back ream out the hole f/5,364' 04,610'. 9/10/2012 9/11/2012 12,220.0 12.30 Back ream out the hole f/4,610' 01,376'. Pump 50 bbl hi -vis sweep and circulate until shakers were clean. TIH f/1,376' 07,221'. Spot 100 bbl hi -vis sweep at the bit at 7,221'. POOH 07,221' 05,369' — pumping 20 bbls per stand laying 100 bbl hi -vis 12.3 ppg pill in the hole. Displace well from 9.5 ppg to 12.3 ppg MOBM. Remove RCD head and install trip nipple. POOH f/5,369' 060'. Page 3/7 Report Printed: 11/5/2012 1 PIONEEROperations Summary Report - Stat^ Well Name: ODST-47 NATURAL RESOURCES Page 4/7 Report Printed: 11/5/2012 Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gap Summary 9/11/2012 9/12/2012 12,220.0 9.50 LD remainder of BHA f/60' t/ surface. Drain MOBM from BOP stack, install test plug and change out top pipe rams to 7 5/8" casing rams. RU testing equipment, test top rams to 250 psi low/4500 psi high on chart for 5 min each -- Good test. RU casing equipment and Tesco casing running tool. Run 7 5/8" 29.7# L-80 BTC -M and HYD 511 casing t/7,998'. 9/12/2012 9/13/2012 12,220.0 9.50 Run 7 5/8" 29.7# L-80 HYD 511 casing f/7,998' U11,658' rotating down w/ 5-20 rpm. 9/13/2012 9/14/2012 12,220.0 9.50 Continue to RIH w/ 7 5/8" casing f/11,658't/12,092'(300 total jts). PU hanger and landing jt. '715577-577casing In wellhead wl Shoe at . Attempt to circulate w/ 1/2 bpm and stage up to 1 1/2 bpm w/ minimal returns (<10 %). RD Tesco casing equipment. RU cement head. -Pump 10 bbls seawater- Drop 1st bottom plug -Test lines to 4000 psi -Load top plug in head- -Pump 60 bbls Tuned Spacer III at 11.0 ppg - Dual Spacer Surfactant B @ .65 gal/bbl & Sem-8 @ .65 gal/bbl. -Drop 2nd bottom plug. -Pump 55 bbls 264 sx Premium Class "G" tail cement at 15.8 1.17yield) w/ additives: 0.5% HALAD-344 + 0.15% SCR -100 + 0.2% CFR -3 -Drop top plug and kick out w/ 20 bbls seawater. -Displace w/ rig pumps using 9.5 ppg MOBM. -Pumped calculated strokes + 1/2 shoe volume (555 bbls) - Did not bump plug. -Total losses during cement and displacement = 618 MIS w s mud returned to surface (±10% returns). -Bleed pressure - Check floats - OK - CIP (M 14:00 hrs. Close annular and pump 4 MIS down OA w/ 2 bpm, 800 psi. LD cement head and landing jt. Install 7 5/8" x 10 3/4" packoff. Test same to 5000 psi f/ 5 charted minutes. Freeze protect OA w/ 100 MIS of diesel. LD 5" DP f/ derrick utilizing mouse hole. 9/14/2012 9/15/2012 12,220.0 9.50 Continue to LDDP f/ derrick utilizing mouse hole. Remove 5" saver sub and IBOP f/ Top Drive. Change top pipe rams from 7 5/8" to 2 7/8" x 5" variables. Install 4" saver sub / IBOP on Top Drive. RU and Test BOPE per AOGCC PTD. -Test upper and lower VBR w/ 4" & 4 1/2" test joints to 250 psi low/4500 psi high. -Test upper and lower IBOP valve to 250 psi low/4500 psi high. -Test annular wl 4" 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. -Initial system psi: 3000; 2100 after closure; 200 psi= 22 sec, full pressure 1 min. 34 sec. -AOGCC Rep. Chuck Scheve witnessed test -RD test equipment. Install wear ring. PU 105 jts. of 4" DP from pipeshed. 9/15/2012 9/16/2012 12,220.0 9.50 Continue to PU 4" DP f/ pipeshed t/ ±6,850'. Circulate DP volume x 1 1/4. Cut & slip drilling line. Service rig. POOH f/6,850' t/ surface. PU cleanout BHA t/121'. Secure well and perform Island Evacuation Drill. Continue to PU BHA U367'. RIH PU 4" DP f/ pipeshed t/7,303'. 9/16/2012 9/17/2012 12,220.0 9.55 Continue PU 4" DP f/7,303't/11,444'. POOH stand back 5 stands. RIH PU final 15 jts. 4" DP t/11,444'. RIH w/ stands from derrick f/11,444' U11,845'. Taking weight at 11,845'. Clean out cement stringers f/11,845' 1:/12,049' (7 518" FC at 12,050'). CBU. Clean out shoe track f/12,050' to shoe at 12,138'. Drill shoe and clean out rat hole t/12,141'. Observed 18 bbls gain in pits. PU t/12,115' and perform flow check. Well flowing. Shut well in using top 2 7/8" x 5" variable rams at 11:20 hrs. Total gain of 52 bbis observed. SIDPP = 800 psi - SICP = 450 psi. Bull head 30 strokes (2.5 MIS) down DP to crack open float in drill string. CBU through super choke holding 1400 psi on DP - Casing pressure = 420 psi. Returned 1 MIS in - 1 bbls out w/ a 9.6 ppg MW in/out. No gas or gas cut mud observed w/ bottoms up. Shut well in and observe same. SIDDP 750 psi - SICP 420 psi. Open choke and observe well for flow. Well initially flowing at 35 bph - Slowed to 15 bph next 60 min. Shut well in at 19:30 hrs for 10 minutes - 100 psi SICP observed. Open choke. Observe well - 20:00 - 21:00 hrs = 7.8 bbls gain - 21:00 - 22:00 hrs = 4.8 bbts gain. Shut well in at 22:30 hrs for 10 minutes - 50 psi SICP observed. Open choke. Flow at less than 0.1 bbls/min. Break circulation. Wash and ream f112,138 t/12,175'. Observed 1680 units of gas with bottoms up. Gas fell off to 0 units after bottoms up. **Total gain including initial 52 bbls until BOP"s were opened = 176 bbls (12 hrs.). r f Page 4/7 Report Printed: 11/5/2012 PIONEEROperations Summary Report - Staf^ Well Name: ODST-47 NATIIRAI RFSnIIRrF.q Page 5/7 ReportPrinted: 11/5/2012 1 Start Date End Date Start Depth ^8) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 9/17/2012 9/18/2012 12,220.0 9.75 Continue to clean out rathole t/12,180'. Pull into shoe at 12,138'. Stop pumps & observe well while transferring fluid. Well gave back 16.8 bbls in 45 minutes. Add LVT to suction pit to bring MW down to 9.5 ppg. Break circulation w/ 9.5 ppg in - Observing 9.7-9.8 ppg out. Continue to clean out rathole t/12,216' (kelly down). Circulate to get consistent MW in/out at 9.7 ppg. Stop pumps and pull into shoe. Observe well f/ 30 min. 4.5 bbls gain. Perform FIT to 12.5 ppg EMW. POOH, MAD Pass f/12,183' 011,190'. POOH f/11,190't/9,614'. CBU f/9,614, t/9,517'. POOH f/9,517' 04,988'. 9/18/2012 9/19/2012 12,220.0 9.75 Continue to POOH f/4,988' 02,101' pumping 1 bpm. Hole fill was correct f/4,025' t/2,101'. POOH on elevators (/2,101' to BHA with correct hole fill. LD BHA #6. Pull wear ring. Install test plug. Test upper 2 76/8" x 5" variable rams w/ 4" & 4 1/2" test jts to 250 psi low/4500 psi high. Test choke line HCR and manual valves to 250 psi low/4500 psi high. Choke manifold was tested while POOH to 250 psi low/4500 psi high. All tests charted and all tests held for 5 min. each test. Pull test plug. Install 7" wear ring. PU BHA # 7 0405'. RIH 405't/9,074'. 9/19/2012 9/20/2012 12,220.0 0.00 9.40 Continue to RIH f/9,074' t/12,061' - Fill pipe and wash & ream down to TD at 12,220'. CBU w/ 250 gpm. Observed max 3250 gas at bottoms up. Back to 0 units after BU. Circulate and reduce MW f/ 9.7 ppg to 9.4 ppg MOBM. Service rig. Circulate at 1/2 bpm while observing well. No gain. POOH f/12,056' t/l1,578'. Circulate and trouble shoot Geo -Pilot. POOH f/11,578' V surface. LD BHA #7. PU BHA #8. Service rig. RIH f/405' t/1,272'. 9/20/2012 9/21/2012 12,220.0 322.00 9.50 Continue to RIH (/1,272' 012,061'. Slip & cut drilling line. Wash & ream f/12,061' t/ TD at 12,220'. Displace 9.4 ppg MOBM out of well w/ 9.5 ppg WBM. Drill new formation f/12,220' 012,270'. POOH 012,152'. Perform FIT to 12.5 ppg EMW w/ 800 psi, 9.5 ppg MW/ 5003' TVD. Directional drill new 6-3/4" lateral hole f/12,270'V1 2,542'. Service rig. Circulate and condition for Geo -Tap. 9/21/2012 9/22/2012 12,542.0 579.00 9.65 Continue to MAD Pass and correlate for Geo -Tap. Directional drill new hole f/12,542' t/13,121'. Perform Geo -Tap procedure as directed by Sperry Rep. and Geologists. 9/22/2012 9/23/2012 13,121.0 435.00 9.65 Directional drill new 6-3/4" lateral hole f/13,121' V13,556'. Perform Geo -Tap as directed by Sperry and Geologists. Function test BOPE per AOGCC weekly requirement. 9/23/2012 9/24/2012 13,556.0 784.00 9.80 Continue directional drill new hole f/13,556' 014,340'. Perform Geo -Tap per Rep & Geologists as directed. 9/24/2012 9/25/2012 14,340.0 1,131.00 9.85 Directional drill new hole f/14,340' V15,471'. Perform Geo -Tap as directed by Rep. & Geologists. 9/25/2012 9/26/2012 15,471.0 1,187.00 9.80 Directional drill new lateral hole f/15,471' V16,658'. Perform Geo -Tap as directed by Rep. & Geologists. 9/26/2012 9/27/2012 16,658.0 587.00 9.90 Directional drill new hole f/16,658' 017,245' -- Torok Lateral TD. PU to Base of Torok Sand and pump sweep while backreaming and Mad Passing with HSI {Hole Size Indicator) at 180 fph f/17,191' V17,131' MD. Continue to backream and Mad pass while gradually increasing backreaming rate 40 fph per stand to achieve max backreaming rate at 1 data point per 2 feet @ 340 fph f/17,131' t/16,298'. 9/27/2012 9/28/2012 17,245.0 9.90 Continue to backream and Mad Pass (/16,298' t/14,444'. Pump HV weighted sweep surface to surface. RIH f114,444' t/15,014'. Backream and Mad pass f/15,014' 014,949' to verify hole size indicator working correctly. POOH f/14,949' 014,468' while pumping 40 gpm and rotating 25 rpm. Continue to backream and Mad pass f/14,468'03,987'. 9/28/2012 9/29/2012 17,245.0 9.85 Continue backreaming and Mad passing f/13,987' V12,061' (inside 7 5/8" shoe. Pump HV weighted sweep surface to surface. *'AOGCC was notified of upcoming BOP test. AOGCC Rep. Jeff Jones waived right to witness test at 19:30 hrs on 09/27/12. I Page 5/7 ReportPrinted: 11/5/2012 1 PIONEEROperations Summary Report - Stat— Well Name: ODST-47 I Page 6/7 Report Printed: 11/5/2012 Start Date End Date Start Depth (ftKB) Foot/Meters (ft) Dens Last Mud (Ib/gal) Summary 9/29/2012 9/30/2012 17,245.0 9.85 Continue pumping 11.0 ppg HV sweep to surface w/ 260 gpm, 120 rpm. R & R DP 90' strokes. Monitor well f/ 30 minutes while servicing rig - Static. Pump dry job. Drop - 2 3/8" drift w/ 100' wire tail in stand # 121. POOH f/12,061' t/405' (BHA). Stand back HWDP. LD remainder of BHA. RU to test BOPE. Test BOPE per AOGCC PTD: -Test upper and lower VBR w/ 4" & 4 1/2" test joints to 250 psi low/ 4500 psi high. -Test upper and lower IBOP valve to 250 psi low/4500 psi high. -Test annular w/ 4" 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. -Initial system psi: 3000; 2000 after closure; 200 psi= 29 sec, full pressure 1 min. 56 sec. -AOGCC Rep. Jim Regg granted extension for BOP test which was due on 09/28/2012. -AOGCC Rep. Jeff Jones waived right to witness test at 19:30 hrs on 09/27/2012. -RD test tools. Install wear ring. 9/30/2012 10/1/2012 17,245.0 9.85 PU 21 jts of HWDP f/ pipe shed - Drop 2 3/8" drift while picking up. Circ 1.5 DP volumes. POOH stand back in derrick (8 stds total in derrick). PU eccentric shoe, BakerLok same. PU liner per tally t/5,253'. PU string magnets and bumper sub. RIH w/ liner on 4" DP t/12,035' (±100' above 7 5/8" shoe). CBU 1x. Obtain parameters. 10/1/2012 10/2/2012 17,245.0 9.85 -Continue to RIH w/ 4 1/2" 13.5# P-110 Hyd 521 liner on 4" DP f/12,035' t/l7,190'. Break circulation and pump 486 bbls of drilling mud treated with wetting agent and spot around 4 1/2" liner. Set liner hanger at 11,938'. Pressure up to inflate External Casing Packers # 1 through # 10 using inflation pressure schedule. 10/2/2012 10/3/2012 17,245.0 9.80 Attempt to PU and expose setting dogs from packer. Running tool not released. Pressure up to 4500 psi using rig pumps. PU and expose setting dogs. Slack off and set down 40k and observe shear. PU and rotate down w/ 10 rpm, 7k tq. Set down w/ 40k down weight. Close top rams and test annulus to 3500 psi for 30 charted min - Good test. NOTE: Top of liner at 11,938'. Float shoe at 17,190'. Forego tubing test per Completion Engineer due to leaking ECP #8. PU enough to clear seals f/ liner. Circulate 1x DP volume. Pump dry job - POOH LDDP f/11,938' t/4,468'. RIH w/ DP from derrick f/4,468' t/11,797'. Displace well f/11,797' t/ surface w/ 9.8 ppg brine. POOH LDDP f/11,797' t/7,743'. Cut & slip drilling line. POOH f/7,743' t/ surface. LD BHA and liner running tools. 10/3/2012 10/4/2012 17,245.0 9.80 Remove wear bushing from wellhead. Rig up 4 1/2" tubing equipment, and hang control line sheaves. Unload 4" DP from pipe shed and load tubing jewelry in same. Make 4 1/2" self aligning mule shoe, seal assembly, and ROC gauge t/127'. MU I -Wire to ROC gauge. Test I -Wire communication -- Good test. Tested ROC gauge to 5000 psi held 20 min -- Good test. RIH with 4 1/2" 13.5# P-110 HYD 521 liner f/127' t/8,870'. 10/4/2012 10/5/2012 17,245.0 9.80 RIH with 4 1/2" 13.5# P-110 HYD 521 liner f/8 870' t/11 983'. Tagged with 40k down weight on No -Go sub at 11,983'. Space ouUMU landing joint and tubing hanger per Rep. Perform SSSV control line and kwire feed through hanger. Test control line and I -wire connections to 5000 psi 10 min -- Good tests. Land tubing with 40k slack off on no-go at 11,983'. Verify tubing hanger landed, and run in LDS. Test lower hanger seals to 5000 psi 10 min -- Good test. Attempt to test upper hanger seals to 5000 psi -- No test. Test 7 5/8" x 4 1/2" annulus to 500 psi for 5 min -- Good test. Attempt to test upper hanger seals to 5000 psi -- bled down to 3000 psi and held. Back out LDS and pull hanger to floor. Inspect hanger seals — no evident wear or failure. Change out upper hanger seal and landing joint O-ring. Land hanger at 11,983'. Test lower hanger seals to 5000 psi 10 min -- Good test. Attempt to test upper hanger seals to 5000 psi -- bled to 2900 psi and held. Pump graphite sealant to seal minor leak. Test upper hanger seals to 5000 psi 20 min — Good test. RU lines and chart recorder to test IA and tubing simultaneously. Test 7 5/8" x 4 1/2" annulus to 500 psi for 5 min -- Good test. Test tubing to 3500 psi on chart held 30 min -- Good test. Bleed tubing down to 2200 psi for IA test. Test 7 5/8" x 4 1/2" annulus to 3500 psi on chart held 30 min -- Good test. Bleed down tubing to shear DCK-2 valve at 2500 psi. Pump 2 bbls down tubing taking returns on IA -- verify DCK-2 sheared. Install BPV in tubing hanger and test same from below to 2500 psi held 5 min -- Good test. RD control line and I -wire sheaves and spools. ND and remove MPD head. 10/4/2012 I 10/5/2012 I 17,245.0 I I 9.80 I r— I I Page 6/7 Report Printed: 11/5/2012 PIONEEROperations Summary Report - Staf, Well Name: ODST-47 NATIIRAI RFCr)llP ..FC Page 717 ReportPrinted: 11/5/2012 Start Date End Date Start Depth (ftKB) FooWeters (ft) Dens Last Mud (lb/gal) Summary 10/5/2012 10/6/2012 17,245.0 9.80 Change out annular preventer element. Install and nipple up MPD RCD bowl. ND BOP stack and drilling riser. Prep wellhead for tree, route SSSV control line and I -wire thru same. Test penetrations to 5000 psi for 10 min each -- Good tests. Install and NU production tree. Test void to 5000 psi for 10 minutes -- Good test. Bleed tubing, pull BPV and install TWC. Attempt to test tree 500 psi -- leaking by TWC. Pull TWC and redress same, install TWC back in hanger. Test tree to 500 psi and 5000 psi for 10 min each -- Good tests. Rig down and move Nabors 19AC from ODST-47 to ODST-45A. Spot slick line combo unit on ODST-45A and RU same. **RIG RELEASED AT 23:59 HRS 10/5/12** Page 717 ReportPrinted: 11/5/2012 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODST-47 API No 50-703-20660-00-00 Sperry Drilling services Definitive Survey Report 04 October, 2012 HALLIBURTON Sperry Drilling Services Pioneer Natural Resources Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODST-47 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: ODST-47 North Reference: True Wellbore: ODST-47 Survey Calculation Method: Minimum Curvature Design: ODST-47 Database: EDM Alaska Project Oooguruk Development (ft) (ft) Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) 0.00 Using Well Reference Point Map Zone: Alaska Zone 04 0.00 Using geodetic scale factor Survey (ft) (ft) Survey (Wellbore) Tool Name Well ODST-47 100.00 734.00 ODST-47 Gyro (ODST-47) Well Position +N/ -S 0.00 ft Northing: 6,030,995.50 ft Latitude: 70° 29'44.705 N 5,339.50 ODST-47 MWD (ODST-47) +E/ -W 0.00 ft Easting: 469,811.98 ft Longitude: 150° 14'48.639 W Position Uncertainty 0.00 ft Wellhead Elevation: ft L_ Ground Level: 13.50ft Wellbore Magnetics ODST-47 Model Name Sample Date IGRF200510 12/31/2009 Declination Dip Angle Field Strength (?) (?) (nT) 21.99 80.81 57,759 Design ODST-47 Map Audit Notes: PTD# 2110180 Vertical MD Inc Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 +E/ -W Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction Section (ft) (ft) (ft) (ft) (bearing) (ft) (ft) 42.70 0.00 0.00 187.12 (°/100') Survey Program Date 10/4/2012 42.70 0.00 0.00 From To 0.00 0.00 Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date 100.00 734.00 ODST-47 Gyro (ODST-47) SR -Gyro -SS Fixed:v2:surface readout gyro single shot 08/15/2012 782.28 5,339.50 ODST-47 MWD (ODST-47) MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3 -axis correction + sag 08/16/2012 5,428.02 12,111.51 ODST-47 MWD (ODST-47) MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3 -axis correction + sag 08/16/2012 12,205.25 17,181.44 ODST-47 MWD (ODST-47) MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3 -axis correction + sag 08/16/2012 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,030,995.50 469,811.98 0.00 0.00 UNDEFINED 100.00 0.11 64.97 100.00 43.80 0.02 0.05 6,030,995.52 469,812.03 0.19 -0.03 SR -Gyro -SS (1) 171.00 0.40 315.08 171.00 114.80 0.23 -0.06 6,030,995.73 469,811.92 0.63 -0.22 SR -Gyro -SS (1) 264.00 0.44 255.05 264.00 207.80 0.37 -0.64 6,030,995.87 469,811.34 0.45 -0.28 SR -Gyro -SS (1) 358.00 1.89 210.71 357.98 301.78 -1.06 -1.78 6,030,994.45 469,810.20 1.71 1.27 SR -Gyro -SS (1) 451.00 3.51 211.62 450.87 394.67 -4.80 -4.05 6,030,990.71 469,807.90 1.74 5.27 SR -Gyro -SS (1) 544.00 5.46 208.60 543.58 487.38 -11.11 -7.66 6,030,984.42 469,804.27 2.11 11.98 SR -Gyro -SS (1) 639.00 7.91 210.76 637.93 581.73 -20.70 -13.17 6,030,974.86 469,798.72 2.59 22.17 SR -Gyro -SS (1) 734.00 12.26 215.94 731.44 675.24 -34.49 -22.44 6,030,961.11 469,789.40 4.67 37.01 SR -Gyro -SS (1) 782.28 13.76 214.78 778.48 722.28 -43.36 -28.72 6,030,952.27 469,783.08 3.15 46.58 MWD+IFR2+MS+sag (2) 875.78 16.04 216.00 868.83 812.63 -62.94 -42.66 6,030,932.74 469,769.06 2.46 67.75 MWD+IFR2+MS+sag (2) 1014/1012 3:58:44PM Page 2 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Surrey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODST-47 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: ODST-47 North Reference: True Wellbore: ODST-47 Survey Calculation Method: Minimum Curvature Design: ODST-47 Database: EDM Alaska Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Northing Map Easting DLS Vertical Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 969.78 16.82 215.04 958.99 902.79 -84.59 -58.10 6,030,911.16 469,753.54 0.88 91.13 MWD+IFR2+MS+sag (2) 1,067.02 20.21 214.09 1,051.18 994.98 -110.02 -75.60 6,030,885.80 469,735.94 3.50 118.54 MWD+IFR2+MS+sag (2) 1,161.88 22.52 214.98 1,139.52 1,083.32 -138.48 -95.20 6,030,857.42 469,716.22 2.46 149.21 MWD+IFR2+MS+sag (2) 1,254.24 24.14 215.06 1,224.33 1,168.13 -168.43 -116.19 6,030,827.56 469,695.11 1.75 181.54 MWD+IFR2+MS+sag (2) 1,350.56 30.42 214.70 1,309.89 1,253.69 -204.64 -141.41 6,030,791.46 469,669.75 6.52 220.59 MWD+IFR2+MS+sag (2) 1,444.77 32.61 215.53 1,390.20 1,334.00 -244.91 -169.75 6,030,751.31 469,641.25 2.37 264.06 MWD+IFR2+MS+sag (2) 1,541.16 34.97 215.58 1,470.30 1,414.10 -288.52 -200.92 6,030,707.83 469,609.91 2.45 311.20 MWD+IFR2+MS+sag (2) 1,638.79 40.08 214.12 1,547.71 1,491.51 -337.33 -234.85 6,030,659.16 469,575.78 5.31 363.84 MWD+IFR2+MS+sag (2) 1,733.51 42.50 214.36 1,618.87 1,562.67 -388.99 -270.02 6,030,607.65 469,540.41 2.56 419.46 MWD+IFR2+MS+sag (2) 1,825.98 48.08 215.94 1,683.90 1,627.70 -442.68 -307.87 6,030,554.12 469,502.34 6.15 477.42 MWD+IFR2+MS+sag (2) 1,919.22 49.35 218.14 1,745.43 1,689.23 -498.59 -350.08 6,030,498.39 469,459.91 2.24 538.13 MWD+IFR2+MS+sag (2) 2,015.43 49.63 216.13 1,807.93 1,751.73 -556.90 -394.23 6,030,440.26 469,415.53 1.61 601.47 MWD+IFR2+MS+sag (2) 2,110.98 52.96 216.29 1,867.67 1,811.47 -617.05 -438.28 6,030,380.30 469,371.24 3.49 666.62 MWD+IFR2+MS+sag (2) 2,206.27 58.17 215.29 1,921.53 1,865.33 -680.79 -484.20 6,030,316.75 469,325.06 5.54 735.56 MWD+IFR2+MS+sag (2) 2,301.76 57.21 216.94 1,972.57 1,916.37 -745.99 -531.76 6,030,251.75 469,277.24 1.77 806.15 MWD+IFR2+MS+sag (2) 2,395.81 60.42 216.14 2,021.27 1,965.07 -810.63 -579.65 6,030,187.31 469,229.09 3.49 876.23 MWD+IFR2+MS+sag (2) 2,491.80 60.39 214.38 2,068.68 2,012.48 -878.78 -627.84 6,030,119.37 469,180.64 1.59 949.82 MWD+IFR2+MS+sag (2) 2,587.25 61.51 213.68 2,115.02 2,058.82 -947.93 -674.53 6,030,050.41 469,133.67 1.34 1,024.23 MWD+IFR2+MS+sag (2) 2,681.99 60.95 214.67 2,160.62 2,104.42 -1,016.64 -721.17 6,029,981.90 469,086.75 1.09 1,098.18 MWD+IFR2+MS+sag (2) 2,778.62 66.38 214.91 2,203.47 2,147.27 -1,087.73 -770.57 6,029,911.02 469,037.07 5.62 1,174.85 MWD+IFR2+MS+sag (2) 2,871.73 70.07 213.98 2,238.01 2,181.81 -1,159.03 -819.46 6,029,839.93 468,987.90 4.07 1,251.66 MWD+IFR2+MS+sag (2) 2,968.21 70.18 216.42 2,270.81 2,214.61 -1,233.16 -871.76 6,029,766.01 468,935.31 2.38 1,331.70 MWD+IFR2+MS+sag (2) 3,059.04 72.38 215.92 2,299.96 2,243.76 -1,302.60 -922.52 6,029,696.79 468,884.26 2.48 1,406.90 MWD+IFR2+MS+sag (2) 3,154.76 70.65 215.97 2,330.31 2,274.11 -1,376.10 -975.81 6,029,623.52 468830.68 1.81 1,486.43 MWD+IFR2+MS+sag (2) 3,249.09 72.83 215.06 2,359.87 2,303.67 -1,449.01 -1,027.84 6,029,550.83 468,778.36 2.49 1,565.23 MWD+IFR2+MS+sag (2) 3,341.91 71.59 213.67 2,388.22 2,332.02 -1,521.96 -1,077.73 6,029,478.09 468,728.18 1.95 1,643.80 MWD+IFR2+MS+sag (2) 3,438.78 70.91 212.79 2,419.36 2,363.16 -1,598.68 -1,128.00 6,029,401.57 468,677.61 1.11 1,726.17 MWD+IFR2+MS+sag (2) 3,533.72 73.64 212.34 2,448.26 2,392.06 -1,674.89 -1,176.67 6,029,325.57 468,628.64 2.91 1,807.82 MWD+IFR2+MS+sag (2) 3,629.82 75.15 212.19 2,474.12 2,417.92 -1,753.16 -1,226.08 6,029,247.51 468,578.92 1.58 1,891.61 MWD+IFR2+MS+sag (2) 3,723.24 72.10 213.49 2,500.45 2,444.25 -1,828.46 -1,274.67 6,029,172.42 468,530.02 3.53 1,972.35 MWD+IFR2+MS+sag (2) 3,817.07 72.14 213.29 2,529.26 2,473.06 -1,903.02 -1,323.81 6,029,098.07 468,480.58 0.21 2,052.43 MWD+IFR2+MS+sag (2) 3,913.27 73.20 213.63 2,557.91 2,501.71 -1,979.63 -1,374.45 6,029,021.67 468,429.64 1.15 2,134.72 MWD+IFR2+MS+sag (2) 4,007.24 73.43 213.77 2,584.89 2,528.69 -2,054.52 -1,424.39 6,028,946.99 468,379.40 0.28 2,215.22 MWD+IFR2+MS+sag (2) 4,100.35 73.00 213.34 2,611.78 2,555.58 -2,128.80 -1,473.66 6,028,872.92 468,329.83 0.64 2,295.04 MWD+IFR2+MS+sag (2) 4,198.36 73.18 212.94 2,640.29 2,584.09 -2,207.32 -1,524.93 6,028,794.61 468,278.25 0.43 2,379.31 MWD+IFR2+MS+sag (2) 4,292.16 73.52 212.40 2,667.17 2,610.97 -2,282.97 -1,573.44 6,028,719.17 468 229.44 0.66 2,460.39 MWD+IFR2+MS+sag (2) 4,388.61 72.14 212.87 2,695.64 2,639.44 -2,360.57 -1,623.13 6,028,641.78 468,179.44 1.50 2,543.55 MWD+IFR2+MS+sag (2) 4,480.68 72.25 213.30 2,723.79 2,667.59 -2,434.02 -1,670.98 6,028,568.53 468,131.29 0.46 2,622.36 MWD+IFR2+MS+sag (2) 4,578.31 72.46 213.45 2,753.39 2,697.19 -2,511.71 -1,722.16 6,028,491.06 468,079.80 0.26 2,705.80 MWD+IFR2+MS+sag (2) 4,673.80 I 72.34 213.21 2,782.26 2,726.06 -2,587.76 -1,772.17 6,028,415.22 468,029.49 0.27 2,787.46 MWD+IFR2+MS+sag (2) 10/4/2012 3:58:44PM Page 3 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODST-47 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: ODST-47 North Reference: True Wellbore: ODST-47 Survey Calculation Method: Minimum Curvature Design: ODST-47 Database: EDM Alaska Survey 8,403.17 71.79 216.15 3,959.27 3,903.07 -5,511.54 -3,764.15 6,025,499.85 466,025.86 0.75 5,935.60 MWD+IFR2+MS+sag (3) 10/4/1012 3:58:44PM Page 4 COMPASS 2003.16 Build 42 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,766.95 72.27 213.34 2,810.57 2,754.37 -2,661.96 -1,820.86 6,028,341.23 467,980.50 0.15 2,867.12 MWD+IFR2+MS+sag (2) 4,862.14 72.10 213.16 2,839.69 2,783.49 -2,737.74 -1,870.55 6,028,265.65 467,930.51 0.25 2,948.48 MWD+IFR2+MS+sag (2) 41959.42 72.15 213.53 2,869.55 2,813.35 -2,815.09 -1,921.45 6,028,188.52 467,879.31 0.37 3,031.54 MWD+IFR2+MS+sag (2) 5,054.11 72.86 213.69 2,898.02 2,841.82 -2,890.30 -1,971.43 6,028,113.52 467,829.02 0.77 3,112.37 MWD+IFR2+MS+sag (2) 5,149.99 71.87 214.84 2,927.07 2,870.87 -2,965.81 -2,022.88 6,028,038.23 467,777.28 1.54 3,193.67 MWD+IFR2+MS+sag (2) 5,244.13 72.04 214.87 2,956.23 2,900.03 -3,039.26 -2,074.03 6,027,964.99 467,725.83 0.18 3,272.90 MWD+IFR2+MS+sag (2) 5,339.52 72.47 214.91 2,985.30 2,929.10 -3,113.79 -2,126.00 6,027,890.69 467,673.57 0.45 3,353.29 MWD+IFR2+MS+sag (2) 5,428.02 71.65 215.66 3,012.56 2,956.36 -3,182.51 -2,174.63 6,027,822.17 467,624.66 1.23 3,427.51 MWD+IFR2+MS+sag (3) 5,459.73 71.26 215.72 3,022.65 2,966.45 -3,206.93 -2,192.17 6,027,797.82 467,607.02 1.24 3,453.92 MWD+IFR2+MS+sag (3) 5,554.17 71.13 215.67 3,053.09 2,996.89 -3,279.54 -2,244.33 6,027,725.44 467,554.57 0.15 3,532.43 MWD+IFR2+MS+sag (3) 5,648.73 70.81 215.64 3,083.92 3,027.72 -3,352.17 -2,296.44 6,027,653.02 467,502.18 0.34 3,610.96 MWD+IFR2+MS+sag (3) 5,744.43 71.47 215.94 3,114.86 3,058.66 -3,425.63 -2,349.40 6,027,579.79 467,448.92 0.75 3,690.42 MWD+IFR2+MS+sag (3) 5,839.23 71.85 216.00 3,144.69 3,088.49 -3,498.46 -2,402.26 6,027,507.18 467,395.78 0.41 3,769.23 MWD+IFR2+MS+sag (3) 5,934.42 71.45 215.72 3,174.65 3,118.45 -3,571.68 -2,455.18 6,027,434.18 467,342.56 0.50 3,848.45 MWD+IFR2+MS+sag (3) 6,029.29 71.97 213.69 3,204.43 3,148.23 -3,645.73 -2,506.46 6,027,360.35 467,290.98 2.10 3,928.29 MWD+IFR2+MS+sag (3) 6,124.45 71.01 213.48 3,234.64 3,178.44 -3,720.90 -2,556.38 6,027,285.39 467,240.77 1.03 4,009.07 MWD+IFR2+MS+sag (3) 6,218.22 71.65 213.98 3,264.66 3,208.46 -3,794.78 -2,605.71 6,027,211.72 467,191.14 0.85 4,088.49 MWD+IFR2+MS+sag (3) 6,314.56 71.86 213.96 3,294.82 3,238.62 -3,870.66 -2,656.83 6,027,136.05 467,139.72 0.22 4,170.12 MWD+IFR2+MS+sag (3) 6,408.08 71.45 213.65 3,324.25 3,268.05 -3,944.42 -2,706.22 6,027,062.50 467,090.04 0.54 4,249.44 MWD+IFR2+MS+sag (3) 6,504.75 71.08 214.26 3,355.30 3,299.10 -4,020.36 -2,757.35 6,026,986.78 467,038.60 0.71 4,331.12 MWD+IFR2+MS+sag (3) 6,599.67 71.45 215.30 3,385.79 3,329.59 -4,094.19 -2,808.63 6,026,913.17 466,987.03 1.11 4,410.74 MWD+IFR2+MS+sag (3) 6,694.15 71.80 213.81 3,415.58 3,359.38 -4,168.03 -2,859.48 6,026,839.54 466,935.88 1.54 4,490.32 MWD+IFR2+MS+sag (3) 6,788.99 71.65 214.25 3,445.32 3,389.12 -4,242.66 -2,909.88 6,026,765.12 466,885.19 0.47 4,570.62 MWD+IFR2+MS+sag (3) 6,883.97 71.45 215.07 3,475.38 3,419.18 -4,316.77 -2,961.12 6,026,691.22 466,833.65 0.85 4,650.51 MWD+IFR2+MS+sag (3) 6,978.59 71.51 215.40 3,505.43 3,449.23 -4,390.06 -3,012.88 6,026,618.16 466,781.60 0.34 4,729.64 MWD+IFR2+MS+sag (3) 7,073.30 71.78 214.62 3,535.26 3,479.06 -4,463.68 -3,064.45 6,026,544.75 466,729.73 0.83 4,809.09 MWD+IFR2+MS+sag (3) 7,169.00 71.66 214.69 3,565.27 3,509.07 -4,538.43 -3,116.12 6,026,470.22 466,677.76 0.14 4,889.67 MWD+IFR2+MS+sag (3) 7,264.23 71.53 213.69 3,595.34 3,539.14 -4,613.17 -3,166.90 6,026,395.69 466,626.69 1.01 4,970.13 MWD+IFR2+MS+sag (3) 7,359.68 71.46 212.62 3,625.64 3,569.44 -4,688.95 -3,216.40 6,026,320.13 466,576.89 1.07 5,051.46 MWD+IFR2+MS+sag (3) 7,454.65 71.14 212.44 3,656.08 3,599.88 -4,764.79 -3,264.78 6,026,244.49 466,528.21 0.38 5,132.71 MWD+IFR2+MS+sag (3) 7,549.81 71.25 211.76 3,686.76 3,630.56 -4,841.10 -3,312.64 6,026,168.38 466,480.04 0.69 5,214.36 MWD+IFR2+MS+sag (3) 7,644.91 71.52 211.85 3,717.12 3,660.92 -4,917.69 -3,360.14 6,026,091.99 466,432.23 0.30 5,296.25 MWD+IFR2+MS+sag (3) 7,740.12 71.58 211.42 3,747.25 3,691.05 -4,994.59 -3,407.51 6,026,015.30 466,384.55 0.43 5,378.43 MWD+IFR2+MS+sag (3) 7,834.54 71.26 213.03 3,777.33 3,721.13 -5,070.30 -3,455.24 6,025,939.79 466,336.53 1.65 5,459.47 MWD+IFR2+MS+sag (3) 7,929.83 71.46 214.00 3,807.79 3,751.59 -5,145.58 -3,505.09 6,025,864.72 466,286.38 0.99 5,540.35 MWD+IFR2+MS+sag (3) 8,023.48 70.99 214.29 3,837.93 3,781.73 -5,218.96 -3,554.86 6,025,791.55 466,236.32 0.58 5,619.33 MWD+IFR2+MS+sag (3) 8,118.06 71.80 214.39 3,868.11 3,811.91 -5,292.97 -3,605.42 6,025,717.75 466,185.46 0.86 5,699.04 MWD+IFR2+MS+sag (3) 8,211.76 70.93 215.95 3,898.05 3,841.85 -5,365.55 -3,656.56 6,025,645.39 466,134.03 1.83 5,777.40 MWD+IFR2+MS+sag (3) 8,308.73 71.34 216.73 3,929.41 3,873.21 -5,439.46 -3,710.93 6,025,571.70 466,079.36 0.87 5,857.48 MWD+IFR2+MS+sag (3) 8,403.17 71.79 216.15 3,959.27 3,903.07 -5,511.54 -3,764.15 6,025,499.85 466,025.86 0.75 5,935.60 MWD+IFR2+MS+sag (3) 10/4/1012 3:58:44PM Page 4 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODST-47 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: ODST-47 North Reference: True Wellbore: ODST-47 Survey Calculation Method: Minimum Curvature Design: ODST-47 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ S +E/ -W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,499.15 71.46 216.49 3,989.53 3,933.33 -5,584.93 -3,818.10 6,025,426.69 465,971.62 0.48 6,015.11 MWD+IFR2+MS+sag (3) 8,594.07 71.52 215.26 4,019.66 3,963.46 -5,657.86 -3,870.85 6,025,353.98 465,918.58 1.23 6,094.02 MWD+IFR2+MS+sag (3) 8,688.91 71.27 214.10 4,049.92 3,993.72 -5,731.78 -3,921.99 6,025,280.28 465,867.14 1.19 6,173.70 MWD+IFR2+MS+sag (3) 8,783.13 72.05 214.44 4,079.57 4,023.37 -5,805.68 -3,972.35 6,025,206.58 465,816.49 0.90 6,253.28 MWD+IFR2+MS+sag (3) 8,879.15 71.40 214.90 4,109.68 4,053.48 -5,880.67 -4,024.21 6,025,131.81 465,764.32 0.82 6,334.12 MWD+IFR2+MS+sag (3) 8,975.74 71.66 214.51 4,140.28 4,084.08 -5,955.99 -4,076.37 6,025,056.72 465,711.86 0.47 6,415.32 MWD+IFR2+MS+sag (3) 9,070.93 71.21 214.23 4,170.58 4,114.38 -6,030.47 -4,127.32 6,024,982.45 465,660.62 0.55 6,495.54 MWD+IFR2+MS+sag (3) 9,165.49 72.12 213.17 4,200.33 4,144.13 -6,105.14 -4,177.12 6,024,907.99 465,610.53 1.43 6,575.81 MWD+IFR2+MS+sag (3) 9,260.65 70.80 213.53 4,230.59 4,174.39 -6,180.51 -4,226.71 6,024,832.83 465,560.63 1.43 6,656.74 MWD+IFR2+MS+sag (3) 9,352.42 71.72 214.06 4,260.07 4,203.87 -6,252.72 -4,275.05 6,024,760.82 465,512.00 1.14 6,734.39 MWD+IFR2+MS+sag (3) 9,448.84 71.33 214.01 4,290.63 4,234.43 -6,328.51 -4,326.24 6,024,685.25 465,460.52 0.41 6,815.94 MWD+IFR2+MS+sag (3) 9,545.11 70.81 214.23 4,321.86 4,265.66 -6,403.90 -4,377.32 6,024,610.08 465,409.14 0.58 6,897.07 MWD+IFR2+MS+sag (3) 9,640.59 71.20 214.32 4,352.93 4,296.73 -6,478.50 -4,428.16 6,024,535.69 465,358.00 0.42 6,977.40 MWD+IFR2+MS+sag (3) 9,735.28 72.11 214.97 4,382.74 4,326.54 -6,552.44 -4,479.25 6,024,461.97 465,306.61 1.16 7,057.11 MWD+IFR2+MS+sag (3) 9,830.61 72.17 213.63 4,411.97 4,355.77 -6,627.39 -4,530.38 6,024,387.23 465,255.18 1.34 7,137.82 MWD+IFR2+MS+sag (3) 9,925.56 72.49 212.70 4,440.80 4,384.60 -6,703.13 -4,579.87 6,024,311.70 465,205.38 0.99 7,219.10 MWD+IFR2+MS+sag (3) 10,020.33 71.39 213.37 4,470.18 4,413.98 -6,778.66 -4,628.99 6,024,236.38 465,155.97 1.34 7,300.14 MWD+IFR2+MS+sag (3) 10,115.67 71.27 213.76 4,500.70 4,444.50 -6,853.92 -4,678.93 6,024,161.33 465,105.73 0.41 7,381.01 MWD+IFR2+MS+sag (3) 10,210.87 71.47 213.74 4,531.11 4,474.91 -6,928.93 -4,729.05 6,024,086.53 465,055.31 0.21 7,461.66 MWD+IFR2+MS+sag (3) 10,305.60 71.47 214.36 4,561.21 4,505.01 -7,003.35 -4,779.34 6,024,012.32 465,004.72 0.62 7,541.73 MWD+IFR2+MS+sag (3) 10,400.87 70.82 214.31 4,592.00 4,535.80 -7,077.80 -4,830.19 6,023,938.09 464,953.57 0.68 7,621.91 MWD+IFR2+MS+sag (3) 10,495.17 71.39 214.33 4,622.54 4,566.34 -7,151.48 -4,880.49 6,023 , 864.62 464,902.98 0.60 7,701.26 MWD+IFR2+MS+sag (3) 10,591.16 70.87 215.29 4,653.59 4,597.39 -7,226.06 -4,932.34 6,023,790.26 464,850.83 1.09 7,781.69 MWD+IFR2+MS+sag (3) 10,684.50 71.66 216.50 4,683.57 4,627.37 -7,297.66 -4,984.17 6,023,718.87 464,798.72 1.49 7,859.17 MWD+IFR2+MS+sag (3) 10,780.24 71.70 215.51 4,713.66 4,657.46 -7,371.19 -5,037.60 6,023,645.58 464,745.00 0.98 7,938.75 MWD+IFR2+MS+sag (3) 10,874.41 71.34 214.22 4,743.51 4,687.31 -7,444.47 -5,088.65 6,023,572.51 464,693.65 1.35 8,017.79 MWD+IFR2+MS+sag (3) 10,965.44 71.71 213.78 4,772.36 4,716.16 -7,516.04 -5,136.93 6,023,501.14 464,645.09 0.61 8,094.80 MWD+IFR2+MS+sag (3) 11,066.02 72.81 211.97 4,803.01 4,746.81 -7,596.50 -5,188.92 6,023,420.90 464,592.77 2.03 8,181.08 MWD+IFR2+MS+sag (3) 11,161.06 75.91 207.52 4,828.64 4,772.44 -7,675.94 -5,234.29 6,023,341.65 464,547.09 5.56 8,265.53 MWD+IFR2+MS+sag (3) 11,255.85 75.96 202.30 4,851.69 4,795.49 -7,759.30 -5,273.00 6,023,258.46 464,508.04 5.34 8,353.05 MWD+IFR2+MS+sag (3) 11,350.84 76.09 196.42 4,874.65 4,818.45 -7,846.23 -5,303.54 6,023,171.67 464,477.15 6.01 8,443.09 MWD+IFR2+MS+sag (3) 11,446.01 76.41 192.97 4,897.27 4,841.07 -7,935.63 -5,326.99 6,023,082.37 464,453.35 3.54 8,534.71 MWD+IFR2+MS+sag (3) 11,541.30 76.92 190.18 4,919.26 4,863.06 -8,026.46 -5,345.59 6,022,991.63 464,434.38 2.90 8,627.14 MWD+IFR2+MS+sag (3) 11,636.48 77.86 188.26 4,940.04 4,883.84 -8,118.14 -5,360.47 6,022,900.02 464,419.13 2.20 8,719.95 MWD+IFR2+MS+sag (3) 11,731.24 79.26 183.76 4,958.84 4,902.64 -8,210.48 -5,370.18 6,022,807.73 464,409.05 4.88 8,812.78 MWD+IFR2+MS+sag (3) 11,826.64 81.38 180.84 4,974.88 4,918.68 -8,304.43 -5,373.94 6,022,713.80 464,404.90 3.75 8,906.48 MWD+IFR2+MS+sag (3) 11,921.58 83.69 177.24 4,987.22 4,931.02 -8,398.53 -5,372.36 6,022,619.71 464,406.10 4.48 8,999.65 MWD+IFR2+MS+sag (3) 12,015.78 85.92 173.21 4,995.75 4,939.55 -8,491.99 -5,364.55 6,022,526.23 464,413.53 4.87 9,091.43 MWD+IFR2+MS+sag (3) 12,111.51 86.60 169.45 5,002.00 4,945.80 -8,586.40 -5,350.15 6,022,431.76 464,427.55 3.98 9,183.33 MWD+IFR2+MS+sag (3) 12,205.25 87.41 168.31 5,006.90 4,950.70 -8,678.26 -5,332.09 6,022,339.85 464,445.23 1.49 9,272.24 MWD+IFR2+MS+sag (4) 10/4/2012 3:58:44PM Page 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODST-47 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: ODST-47 North Reference: True Wellbore: ODST-47 Survey Calculation Method: Minimum Curvature Design: ODST-47 Database: EDM Alaska Survey 10/4/2012 3:58:44PM Page 6 COMPASS 2003.16 Build 42 Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/1001) (ft) Survey Tool Name 12,283.73 87.90 169.04 5,010.11 4,953.91 -8,755.14 -5,316.69 6,022,262.90 464,460.31 1.12 9,346.62 MWD+IFR2+MS+sag (4) 12,379.24 86.30 165.83 5,014.94 4,958.74 -8,848.23 -5,295.95 6,022,169.74 464,480.68 3.75 9,436.42 MWD+IFR2+MS+sag (4) 12,478.18 85.30 164.11 5,022.19 4,965.99 -8,943.53 -5,270.36 6,022,074.35 464,505.87 2.01 9,527.81 MWD+IFR2+MS+sag (4) 12,569.25 87.53 162.52 5,027.88 4,971.68 -9,030.58 -5,244.27 6,021,987.20 464,531.61 3.01 9,610.96 MWD+IFR2+MS+sag (4) 12,671.20 86.60 159.31 5,033.10 4,976.90 -9,126.79 -5,210.98 6,021,890.87 464,564.50 3.27 9,702.30 MWD+IFR2+MS+sag (4) 12,768.08 87.29 156.88 5,038.27 4,982.07 -9,216.54 -5,174.89 6,021,800.98 464,600.22 2.60 9,786.88 MWD+IFR2+MS+sag (4) 12,862.83 85.68 151.97 5,044.08 4,987.88 -9,301.82 -5,134.08 6,021,715.55 464,640.68 5.44 9,866.45 MWD+IFR2+MS+sag (4) 12,959.88 86.67 148.38 5,050.56 4,994.36 -9,385.81 -5,085.93 6,021,631.37 464,688.49 3.83 9,943.82 MWD+IFR2+MS+sag (4) 13,055.06 85.43 144.84 5,057.12 5,000.92 -9,465.08 -5,033.69 6,021,551.90 464,740.41 3.93 10,016.00 MWD+IFR2+MS+sag (4) 13,151.94 87.22 143.35 5,063.33 5,007.13 -9,543.38 -4,976.99 6,021,473.37 464,796.78 2.40 10,086.68 MWD+IFR2+MS+sag (4) 13,247.90 86.67 140.45 5,068.44 5,012.24 -9,618.78 -4,917.87 6,021,397.74 464,855.58 3.07 10,154.17 MWD+IFR2+MS+sag (4) 13,343.76 84.81 139.07 5,075.56 5,019.36 -9,691.75 -4,856.12 6,021,324.53 464,917.03 2.41 10,218.92 MWD+IFR2+MS+sag (4) 13,441.38 85.86 139.01 5,083.50 5,027.30 -9,765.22 -4,792.34 6,021,250.81 464,980.50 1.08 10,283.92 MWD+IFR2+MS+sag (4) 13,534.61 85.06 138.32 5,090.88 5,034.68 -9,835.00 -4,730.96 6,021,180.78 465,041.60 1.13 10,345.56 MWD+IFR2+MS+sag (4) 13,634.00 85.92 137.27 5,098.70 5,042.50 -9,908.40 -4,664.40 6,021,107.13 465,107.85 1.36 10,410.13 MWD+IFR2+MS+sag (4) 13,730.33 86.91 137.05 5,104.72 5,048.52 -9,978.89 -4,599.03 6,021,036.37 465,172.93 1.05 10,471.98 MWD+IFR2+MS+sag (4) 13,826.75 85.80 135.82 5,110.85 5,054.65 -10,048.61 -4,532.72 6,020,966.39 465,238.95 1.72 10,532.95 MWD+IFR2+MS+sag (4) 13,921.15 85.43 137.26 5,118.07 5,061.87 -10,116.93 -4,467.98 6,020,897.82 465,303.41 1.57 10,592.71 MWD+IFR2+MS+sag (4) 14,020.24 85.30 137.91 5,126.07 5,069.87 -10,189.85 -4,401.36 6,020,824.64 465,369.72 0.67 10,656.81 MWD+IFR2+MS+sag (4) 14,115.86 85.67 138.32 5,133.60 5,077.40 -10,260.82 -4,337.72 6,020,753.42 465,433.07 0.58 10,719.34 MWD+IFR2+MS+sag (4) 14,212.66 88.27 138.28 5,138.72 5,082.52 -10,332.98 -4,273.42 6,020,681.00 465,497.07 2.69 10,782.98 MWD+IFR2+MS+sag (4) 14,304.32 88.46 139.75 5,141.33 5,085.13 -10,402.15 -4,213.33 6,020,611.60 465,556.87 1.62 10,844.16 MWD+IFR2+MS+sag (4) 14,403.11 87.66 139.94 5,144.68 5,088.48 -10,477.61 -4,149.66 6,020,535.89 465,620.22 0.83 10,911.15 MWD+IFR2+MS+sag (4) 14,497.59 88.71 140.60 5,147.67 5,091.47 -10,550.23 -4,089.30 6,020,463.03 465,680.28 1.31 10,975.74 MWD+IFR2+MS+sag (4) 14,595.80 88.77 140.54 5,149.83 5,093.63 -10,626.07 -4,026.94 6,020,386.94 465,742.33 0.09 11,043.26 MWD+IFR2+MS+sag (4) 14,689.83 88.58 139.78 5,152.00 5,095.80 -10,698.25 -3,966.72 6,020,314.53 465,802.25 0.83 11,107.42 MWD+IFR2+MS+sag (4) 14,788.65 88.40 141.33 5,154.61 5,098.41 -10,774.53 -3,903.96 6,020,238.00 465,864.69 1.58 11,175.33 MWD+IFR2+MS+sag (4) 14,885.21 89.08 142.08 5,156.73 5,100.53 -10,850.30 -3,844.13 6,020,162.00 465,924.20 1.05 11,243.10 MWD+IFR2+MS+sag (4) 14,979.04 89.33 140.80 5,158.03 5,101.83 -10,923.66 -3,785.65 6,020,088.41 465,982.38 1.39 11,308.65 MWD+IFR2+MS+sag (4) 15,077.72 88.89 140.10 5,159.57 5,103.37 -10,999.74 -3,722.83 6,020,012.08 466,044.89 0.84 11,376.35 MWD+IFR2+MS+sag (4) 15,173.22 89.51 138.61 5,160.90 5,104.70 -11,072.19 -3,660.63 6,019,939.39 466,106.79 1.69 11,440.54 MWD+IFR2+MS+sag (4) 15,269.55 88.58 138.25 5,162.51 5,106.31 -11,144.25 -3,596.72 6,019,867.08 466,170.40 1.04 11,504.12 MWD+IFR2+MS+sag (4) 15,365.29 89.33 137.88 5,164.25 5,108.05 -11,215.46 -3,532.75 6,019,795.61 466,234.07 0.87 11,566.85 MWD+IFR2+MS+sag (4) 15,458.93 89.02 136.87 5,165.60 5,109.40 -11,284.35 -3,469.35 6,019,726.47 466,297.19 1.13 11,627.35 MWD+IFR2+MS+sag (4) 15,557.53 89.94 136.76 5,166.49 5,110.29 -11,356.24 -3,401.87 6,019,654.32 466,364.36 0.94 11,690.32 MWD+IFR2+MS+sag (4) 15,656.20 87.47 134.65 5,168.72 5,112.52 -11,426.84 -3,332.99 6,019,583.45 466,432.95 3.29 11,751.84 MWD+IFR2+MS+sag (4) 15,750.16 87.29 134.72 5,173.02 5,116.82 -11,492.84 -3,266.26 6,019,517.18 466,499.41 0.21 11,809.06 MWD+IFR2+MS+sag (4) 15,841.68 87.97 135.69 5,176.80 5,120.60 -11,557.73 -3,201.83 6,019,452.04 466,563.56 1.29 11,865.46 MWD+IFR2+MS+sag (4) 15,938.50 87.66 137.43 5,180.50 5,124.30 -11,627.98 -3,135.31 6,019,381.53 466,629.79 1.82 11,926.92 MWD+IFR2+MS+sag (4) 16,039.08 86.29 139.32 5,185.80 5,129.60 -11,703.05 -3,068.60 6,019,306.19 466,696.19 2.32 11,993.15 MWD+IFR2+MS+sag (4) 10/4/2012 3:58:44PM Page 6 COMPASS 2003.16 Build 42 Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODST-47 Wellbore: ODST-47 Design: ODST-47 Survey Pioneer Natural Resources Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well ODST-47 42.7'+ 13.5'@ 56.20ft (Nabors 19AC) 42.7'+ 13.5'@ 56.20ft (Nabors 19AC) True Minimum Curvature EDM -Alaska 10/42012 3:58:44PM Page 7 COMPASS 2003.16 Build 42 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 16,136.81 87.22 140.03 5,191.34 5,135.14 -11,777.44 -3,005.46 6,019,231.55 466,759.03 1.20 12,059.14 MWD+IFR2+MS+sag (4) 16,233.43 87.72 139.63 5,195.60 5,139.40 -11,851.20 -2,943.19 6,019,157.55 466,820.98 0.66 12,124.61 MWD+IFR2+MS+sag (4) 16,327.51 85.74 138.56 5,200.97 5,144.77 -11,922.18 -2,881.69 6,019,086.32 466,882.19 2.39 12,187.43 MWD+IFR2+MS+sag (4) 16,424.86 85.74 138.96 5,208.20 5,152.00 -11,995.18 -2,817.70 6,019,013.07 466,945.88 0.41 12,251.93 MWD+IFR2+MS+sag (4) 16,520.36 87.10 138.93 5,214.16 5,157.96 -12,067.05 -2,755.10 6,018,940.95 467,008.18 1.42 12,315.49 MWD+IFR2+MS+sag (4) 16,615.84 84.93 138.36 5,220.80 5,164.60 -12,138.55 -2,692.17 6,018,869.21 467,070.81 2.35 12,378.63 MWD+IFR2+MS+sag (4) 16,713.42 83.26 137.98 5,230.84 5,174.64 -12,210.87 -2,627.44 6,018,796.64 467,135.24 1.75 12,442.37 MWD+IFR2+MS+sag (4) 16,809.44 83.69 138.54 5,241.75 5,185.55 -12,282.05 -2,563.93 6,018,725.20 467,198.46 0.73 12,505.13 MWD+IFR2+MS+sag (4) 16,906.15 84.93 138.10 5,251.34 5,195.14 -12,353.92 -2,499.94 6,018,653.08 467,262.15 1.36 12,568.52 MWD+IFR2+MS+sag (4) 17,002.19 84.93 137.82 5,259.82 5,203.62 -12,424.97 -2,435.87 6,018,581.78 467,325.92 0.29 12,631.08 MWD+IFR2+MS+sag (4) 17,098.86 83.44 137.00 5,269.62 5,213.42 -12,495.77 -2,370.79 6,018,510.72 467,390.70 1.76 12,693.27 MWD+IFR2+MS+sag (4) 17,181.44 82.57 136.25 5,279.67 5,223.47 -12,555.35 -2,314.50 6,018,450.92 467,446.75 1.39 12,745.41 MWD+IFR2+MS+sag (4) 17,245.00 82.57 136.25 5,287.89 5,231.69 -12,600.88 -2,270.92 6,018,405.22 467,490.14 0.00 12,785.18 PROJECTED to TD 10/42012 3:58:44PM Page 7 COMPASS 2003.16 Build 42 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, September 18, 2012 2:25 PM To: 'Tirpack, Robert' Cc: Johnson, Vern; Vaughan, Alex Subject: RE: ODST-47 CMT Log (PTD 212-103) Rob, _ As we discussed the BATT Bond log for ODST-47 marginal but should provide adequate isolation for the upcoming hydraulic fracture of the Torok. Assuming you get a good LOT after drill -out you are good to go. I added up at least 150 ft of competent cement above the Torok interval at 12050' md. One thing that could be done to help protect the casing shoe and cemented annulus would be to place a oil (?) sensitive swell packer just below the casing shoe and tie back to the liner packer with solid 4.5" liner. I couldn't remember if you were already running swell packers or not. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Tirpack, Robert [mailto:Robert.Tirpack@pxd.com] Sent: Tuesday, September 18, 2012 1:11 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Vaughan, Alex Subject: FW: ODST-47 CMT Log Importance: High Guy, Please find the attached cement bond log from T-47. This is the 7-5/8" production casing from the top of Torok to surface. The bottom 1000' MD was logged along with two other sections up hole to be sure ringing pipe was encountered for bond interpretation. Ben Schulze with Halliburton provided his opinion on bond below. Basically we have 52' of strong bond and 95' with partial bond for a total of 147' bonding. The cement job was pumped with partial returns (74 bbls total) and the post job cement analysis showed -70 psi of lift pressure. A FIT has not been performed yet. The horizontal drilling BHA is currently being picked up. After the wellbore has been swapped over from OBM to WBM, 20' MD of new formation will be drilled and a FIT to 12.5 ppg EMW will be performed. I will call later today to discuss the cement log. Regards, Rob From: Benjamin Schulze [ma ilto: Benjamin. Schulze@HALLIBURTON.com] Sent: Tuesday, September 18, 2012 12:18 PM To: Tirpack, Robert; Vaughan, Alex Cc: Shawn Polak; Shearer, Eric; Mark Wedman Subject: ODST-47 CMT Log Importance: High 9/18/2012 Page 2 of 2 Hi Guys, It doesn't look very pretty. The first discernible change in waveforms occurs—11713'MD. This suggests top of cement. From 11,713'-11,726' the first arriving waves are present but do not have as much energy as the above ringing pipe. This suggests a partial physical connection with the formation. From 11726-11745 the first arriving waves have a higher energy level, suggesting that there is not a physical connection with the formation. From 11745-11763 the first arriving waves have a low energy level and appear to almost disappear, indicating a strong physical connection with the formation. From 11763 —11818 the first arriving waves have a higher energy, suggesting that there is not a physical connection with the formation. From 11813 —11847 the first arriving waves start to disappear, indicating a strong physical connection with the formation. From 11847 —11975 the first arriving waves have a higher energy, suggesting that there is not a physical connection with the formation. From 11975 —12057 the first arriving waves are present but do not have as much energy as the above ringing pipe. This suggests a partial physical connection with the formation. From 12057 —12128 the first arriving waves have a higher energy, suggesting that there is not a physical connection with the formation. Thank You and Regards, Benjamin Schulze Principal Log Analyst SPERRY DRILLING / HALLIBURTON Anchorage, AK 99518 Office: 907-273-3536 Email: Benjamin.schulze@halliburton.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. 9/18/2012 411 pr qd --TI Li pr qd b ok c F9 r. z 6f t i 4 // __. t� { { yr . ir cari ttrctiL 065—J-4-7 Regg, James B (DOA) PIS Z Iz 1030 From: OoogurukDrillingSupervisor[Oooguruk.DrillingCompanyMan@pxd.com] Sent: Sunday, September 16, 2012 6:12 PM To: DOA AOGCC Prudhoe Bay Cc: Tirpack, Robert; Johnson, Vern; Vaughan, Alex; Polya, Joe; OoogurukDrillingSupervisor; Haberthur, Jerry Subject: Nabors 19AC BOPE Closure on Well Flow 9-16-12 Attachments: NAD19AC BOPE Closure on Well Flow 09-16-12.doc Chuck, We observed no gas cut mud when we got a bottoms up sample. Mud weight 9.6 ppg in & out. Suspect it is mud flowback from our losses during our cement job. Observed minor flow from well bore. Closed in the well with 300Opsi pened the choke back up and bled off 20 bbls. Closed choke back in and observed 200 psi on well. Opened back up and bled off 25 bbls. Closed choke back in and observed 100 psi. Plan forward is to bleed off the pressure and monitor well for 1 to 2 hrs. Senior Drilling Supervisor Pioneer Natural Resources Office # 907-670-6606 Cell # 907-854-9815 Fax # 907-670-6673 This email was sent on 9/16/12 at 6:11 PM by klepzigr. 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. TO: Chuck Scheve, Prudhoe Bay AOGCC Representative. FROM: Rodney Klepzig, Well Site Leader, Oooguruk Drill Site, Pioneer Natural Resources CC: Vern Johnson, Drilling Manager, Pioneer Natural Resources Robert Tirpack, Drilling Superintendent, Pioneer Natural Resources Alex Vaughan, Drilling Engineer, Pioneer Natural Resources Subject: Report of Incident Requiring Use of Upper Drill Pipe Rams to Prevent Flow of Fluids from the Wellbore Date: September 16, 2012 Re: AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well In accordance with the Alaska Oil and Gas Conservation Commission regulations governing secondary well control equipment and procedures, Pioneer is formally reporting that it was necessary to close the annular preventer to stop flow of fluid from the wellbore. Report Timefi-ame: 1300 hrs on 9/16/2012. REPORT CONTENTS: Date _& Time of'130PE L.'Ise__ 9/16/2012 @ 1120 hours. Fell/Loc_ation/11"I'D Number: ODST-47 Oooguruk Drill Site / 212-103. ' Eit Name: Nabors 19AC Operator Contact: Alex Vaughan @ 907-343-2186 Operations Summary( including events leading up to 130PE use): Nabors 19AC drilled the ODST- 47 Intermediate hole section with 9.6ppg MOBM to a depth of 12,220'md/ 5,010' tvd in the absence of the observation of abnormal pressures. 7-5/8" casing was set and cemented with 10% returns at a depth of 12,138md/5,003'tvd. Top of the Torok formation is 12,053'md. While penetrating the 7- 5/8" float shoe with a 9.6 ppg MOBM drilling fluid a 52 bbl fluid influx was observed by the Nabors 19AC Rig Crew necessitating closure of the BOPE's. 13013E.U5ed: Upper 2-7/8" x 5" Variable bore Rams and Choke Manifold. v Reason for BOPE Use: Stop fluid flow from annulus of well. Actions Taken/To Be Taken including the date used B0PE was tested): Circulated 9.6 ppg MOBM surface to surface utilizing the Drillers method. When bottom hole sample was circulated to surface there was an absence of any gas cut fluid. Note: This information should be sent electronically to doa.aogcc.prudhoe.baysa�alaska.,gov. To ensure regulatory compliance, please share this Guidance Bulletin with all appropriate members ofyour organizations. Please direct questions or discussion to Senior Petroleum Engineer James Regg at (907)793-1236. 7T!'N C S SEAN PARNELL, GOVERNOR <r , nA,11 U'Lr U � . ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Alex Vaughan Senior Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Torok Oil Pool, ODST-47 Pioneer Natural Resources Alaska, Inc. Permit No: 212-103 Surface Location: 2879' FSL, 1186' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 161' FSL, 2856' FEL, SEC. 23, T13N, R7E, UM Dear Mr. Vaughan: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, iv /�94 CatFoerster Chair 5 DATED this / day of August, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALS 4 OIL AND GAS CONSERVATION COMMI ON PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: 1b. Proposed Well Class: Development -Oil ❑ Service - Winj Single Zone F] 1c. Specify if well is proposed for: Drill 0 , Redrill ❑ Stratigraphic Test ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 ' ODST-47 3. Address: 700 G Street, Suite 600 6. Proposed Depth: 12. Field/Pool(s): Anchorage, AK 99501 MD: 18,247' TVD: 5281' Oooguruk - Torok Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 2879' FSL, 1186' FEL, Sec. 11, T13N, R7E, UM ADL 355036 / ADL 355038 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4675' FSL, 1323' FEL, Sec. 22, T13N, R7E, UM 417497 August 19, 2012 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 161' FSL, 2856' FEL, Sec. 23, T13N, R7E, UM 5760 604' 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-469811.98 • y- 6030995.50 • Zone- ASP 4 GL Elevation above MSL: to Same Pool: ODST-45A is 2680' 13.5 feet ' away 16. Deviated wells: Kickoff depth: 300 feet - 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 87.94 degrees Downhole: 2307 ' Surface: 1726 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 24" 16" 109# H-40 Welded 115' Surface Surface 158' 158' Driven 13-1/2" 10-3/4" 45.5# L-80 BTC 5573' Surface Surface 5616' 3076' 636 sx PF 'L'; 335 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC -M 12,213' Surface Surface 12,256'. 5023' 1sxClass 'G' SK 6-3/4" 4-1/2" 12.6# L-80 HYD 521 6141' 12,106' 5011' 18,247' 5281 Uncemented 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): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface V BMW Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑✓ BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and correct. Contact Alex Vaughan, 343-2186 Prepared By: Kathy Campoamor, 343-2183 Printed Name Alex Vaughan Title Senior Drilling Engineer Signature � Phone 343-2186 Date 7/25/2012 Commission Use Only Permit to Drill y: i&5) API Number: ' l �(� _ i "t Permit App r �-- See cover letter for other Number: t' 50- ,% tk Date: requirements. Conditions of approval : If box is clicked, well not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: [✓ Other: Ll SCO /15�- t56 r° 1 e-5( Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No ❑ �� ®V ®S ` P7 (,P_ `y •� H2S measures: Yes ❑ NoQ Directional svy req'd: Yes ZNo ❑ 8 -- f - Z APPRO ED BY THE COMMISSION DATE: COMMISSIONER ORIGINAL Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit in Duplicate �� PIONEER NATURAL RESOURCES ALASKA July 24th, 2012 Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277-2700 Fax: (907) 343-2190 State of Alaska 9 IV G Alaska Oil and Gas Conservation Commission JUL 2 5 2012 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 AOGCC RE: Application for Permit to Drill ODST-47 Previous Permit to Drill #211-018 Surface Location: 2879' FSL, 1186' FEL, Sec. 11, T1 3N, R7E, UM X = 469811.98, Y = 6030995.50, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a development well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be an production well in the Oooguruk-Torok formation. PNRA requests the Permit To Drill based on approved Pool Rules. D,Jar44r W4`. Zrof As indicated in the attachments, the drilling and well construction program includes the following: Surface Hole: o Drill 13-1/2" to 5,616' MD / 3,076' TVD and set 10-3/4" casing. • Intermediate Hole: o Drill 9-7/8" directionally to 12,256' MD / 5,023' TVD. Run and set 7-5/8" Intermediate casing into the top of the Oooguruk-Torok formation. • Lateral Hole: o Drill 6-3/4" horizontally to 18,247' MD / 5,281' TVD and set a 4-1/2" liner with a Baker MultiPoint mechanical diversion frac system. • Fracture Stimulation Completion: o 4-1/2" fracture stimulation string with SSSV & Sliding Sleeves. • Fracture Stimulation: ("'yo 2,000,000 lbs of Carboceramics Carbolite proppant pumped in 600,000 gallons of Schlumberger's YF125ST. ESP Completion: o ESP completion string with SSSV & GLM. f Alaska Oil & Gas Conservu,,on Commission July 24th, 2012 Page 2 of 3 PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the Intermediate hole section as outlined below. • From the Surface shoe to Intermediate section TD. o Use -9.5-10.5 ppg fluid while using MPD to control pressure from the surface to -13.0 ppg EMW at the bottom of the hole during connections and while tripping. ■ Open formations: • Torok Sands, -8.4 ppg Pore Pressure Utilizing the MPD process described above allows PNRA to reduce the materials needed for the well, increasing the overall safety of the personnel on the development by handling less material. In addition the lower solids in the production section mud system will reduce formation damage along the sandface of the well. Based on information previously submitted to the AOGCC and included in the AOGCC Oooguruk Field File, PNRA requests an exemption from 20 AAC 25.035 (c) which requires a diverter system be installed on the well while drilling the surface interval. In the future, PNRA may provide information and permitting requesting 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. Alaska Oil & Gas Conserv..,.on Commission July 24th, 2012 Page 3 of 3 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). 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 Alex Vaughan, Senior Drilling Engineer (20 AAC 25.070) 907.343.2186 alex.vaughan@pxd.com 2) Geologic Data and Logs (20 AAC 25.071) Greg Griffin, Operations Geologist 907.343.2141 greg.griffin@pxd.com The anticipated spud date for this well is August 19th, 2012. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, Alex Vaughan Senior Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODST-47 Well File Permit to Drill Well Plan Summary ODST-47 Oooguruk — Torok Single Lateral Production Well Surface TD @ 5,616' MD / 3,076' TVD Intermediate TD @ 12,256' MD / 5,023' TVD Lateral TD @ 18,247' MD / 5,281' TVD Surface Location: 2879' FSL, 1186' FEL, Sec 11, T13N, R7E, UM ASP 4 NAD27projection X = 469811.98 1 Y = 6030995.50 57 days to Drill and Complete Target: Ooo uruk-Torok 4675' FSL, 1323' FEL, Sec. 22, T13N, R7E, Umiat Well Design: Modified Slimhole 10-3/4" x 7-5/8" x 4-1/2" liner Single -Lateral X = 464361.76 1 Y = 6022300.07 5,023' TVDrkb Bottom Hole Location ODST-47 161' FSL, 2856' FEL, Sec. 23, TUN, R7E, Umiat X = 468099.99 1 Y = 6017725.01 5,281' TVDrkb AFE Number: TBA Est. Start Date: August 19th, 2012 Ri : Nabors 19AC Operating days: 57 days to Drill and Complete Objective & Well Type Torok Development Well W 09 Well Design: Modified Slimhole 10-3/4" x 7-5/8" x 4-1/2" liner Single -Lateral 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: 158' MDrkb Pioneer Natural Resources Last Revised: Jul 24th, 2012 ODST-47 Permit To Drill Page 1 of 11 Well Control: Well Section Pressure Depth psi TVD Basis 13-1/2" Surface Section Maximum 1376 3076 Based on seawater gradient of 0.4472 psi/ft anticipated BHP Maximum surface Based on BHP and a full column of gas from TD @ 0.11 1037 Surface pressure psi/ft 9-7/8" Intermediate Hole Section Maximum 2194 5023 Based on seawater gradient of 0.4472 psi/ft anticipated BHP Maximum surface Based on BHP and a full column of gas from TD @ 0.11 1642 Surface pressure psi/ft 6-3/4" Lateral Hole Section Maximum 2307 5281 - Based on seawater gradient of 0.4472 psi/ft anticipate BHP Maximum surface Based on BHP and a full column of gas from TD @ 0.11 1726 Surface pressure 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 Diverter (see attached schematic) — Note: Requesting Diverter Exemption on a Well by Well Basis): Hydril 21-1/4" 2M annular BOP 1 16" full opening knife gate valve, hydraulically actuated 16" diverter line 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 Pioneer Natural Resources Last Revised: Jul 24th, 2012 ODST-47 Permit To Drill Page 2 of 11 Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 10-3/4" Surface Shoe Rathole + 20' to 50' from shoe LOT 12.5 ppg 7-5/8" Intermediate Shoe Rathole + 20' from shoe FIT 12.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 13-1/2" hole Spud Mud Interval Density Viscosity secs YP PV MBT API FL Initial 8.8 150-200 35-50 15-25 10-15 unrestricted Final 9.2-9.6 70-100 25-35 15-25 10-15 <12 Intermediate Hole Mud Properties: 9-7/8" hole MOBM Interval Density Viscosity secs YP PV ES HTHP O / W Initial to TD 9.5 - 10.5 ppg —13.0 ppg via MPD 55-80 12-25 15-30 800-2000 <4 80/20 Production Hole Mud Properties: 6-3/4" hole BARADRIL-N Interval Density Viscosity secs YP PV MBT API FL InitialtoTD 9.3-9.8 ppg 50-70 15-25 15-25 10-12 <8 Pioneer Natural Resources Last Revised: Jul 241h, 2012 ODST-47 Permit To Drill Page 3 of 11 Formation Markers: Formation Tops MD (ft) TVDrkb (ft) Pore P ess.pW Comments Top Permafrost 859 854 N/A Base Permafrost 1804 1,668 West Sak 3122 2,285 Top Cretaceous Tuffs 5207 2,947 Hue 1 Marker 5616 3,076 SCP 5613 3,075 Hue2 Marker 6112 3,234 Brookian 2B 9210 4,217 Top Torok Sand 12145 5,015 2091 8.4 Production Zone ICP 12256 5,015 Mid Torok 13804 5,119 Lower Torok 15122 5,169 2258 8.4 Base Torok 17949 5271 TD 18,247 5,337 Loqqinq Program: 13-1/2" Section: Surface Drilling: Mud Logging Dir / GR Open Hole: N/A Cased Hole: N/A 9-7/8" Section: Intermediate Drilling: Mud Logging Dir/GR/Res/At bit GR Open Hole: N/A Cased Hole: N/A 6-3/4" Section: Lateral Drilling: Mud logging ABI / Dir / GR / EWR / AFR / ALD / Neut / PE / PWD / GeoTa Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised: Jul 24t', 2012 ODST-47 Permit To Drill Page 4 of 11 Casing Program: Hole Size Casing / Tubing Weight Grade Conn. Casing Length Csg/Tbg Top MDrkb Hole Btm MDrkb/TVDrkb 24" 16" 109# H-40 Welded 115 Surface 158 158 13-1/2" 10-3/4" 45.5# L-80 BTC 5573 Surface 5616 3076 9-7/8" 7-5/8" 29.7# L-80 BTC -M 12213 Surface 12256 5023 6-3/4" 4-1/2" 12.6# L-80 H dril 521 6141 12106 18247 5281 Tubing 4-1/2" 12.6# L-80 H dril 521 12063 Surface 12106 5013 Casing Properties Size Weight Grade ID Drift ID Conn. Internal Yield psi Collapse (psi) Tensile Strength Joint Body 16" 109# H-40 14.67" 14.5" Welded Conductor casing 10-3/4" 1 45.5# 1 L-80 1 9.95" 1 9.794" 1 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" H dril 521 na na 289 M 289 M Pioneer Natural Resources Last Revised: Jul 241h, 2012 ODST-47 Permit To Drill Page 5 of 11 Cement Calculations: Casing Size: 10-3/4" Surface Casing - single stage Basis: Lead: 75% excess over gauge hole in permafrost + 50 bbls, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 30% excess, plus 85' shoe track Tail TOC: 4,876' MD Total Cement Volume: Preflush 10 bbl water Spacer 100 bbl 10.0 Ma Tuned Spacer Lead 511 bbls / 636 sx of 11.1 ppg Type "L" Permafrost Cement. 4.51 cf/sk, 22.8 s water req. Tail 70 bbls/335 sx of 15.8 ppg Premium "G" + adds. 1.18 cf/sk, 5.24 gps Displ 532 bbls Mud I Temp I BHST -55° F, BHCT -60° F estimated I Should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar may be run in the casing string and a staged cement job will be performed. In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 7-518" Intermediate - single stage Basis: TOC: -11,645' MD - 500' MD above the top of the Torok. 60% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 12.5 ppQ Dual Spacer Primary 22 bbls /, sx Premium "G" + adds. 1.15cf/sk/4.97gps Dis I 559 bbls mud I f y s" Temp BHST - 165° F. BHCT -135° F This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone. Disposal: Annular Injection: 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, ODSDW 1-44. 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: Jul 24t', 2012 ODST-47 Permit To Drill Page 6 of 11 W i� KW Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Ria Work 1. 16" Conductors have been set and the Well Bay modules have been placed. . Rig Activity: Drill and Complete sr 1. MIRU Nabors 19AC over pre-installed 16" conductor casing. n 2. Nipple up spacer spools and riser. "-�� , ✓t, -_eA" 3. MU 13-1/2" Directional Drilling, MWD/LWD assembly. U 4. Drill surface hole to the casing point. 5. Circulate and condition the hole to run casing. POOH. 6. Run and cement the 10-3/4" surface casing. Bump the plug and bring the pressure up to 3500 psi - chart and hold for 30 minute pressure test. . Note: A Port Collar may be run based on hole conditions at Company Rep discretion. 7. Ensure floats are holding. WOC if needed. 8. ND Riser, NU Drilling Spool and BOPE. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 9. RU MPD trip nipple & MU 9-7/8" RSS, MWD/LWD. 10. RIH and cleanout casing to landing collar. 11. RD MPD trip nipple and RU bearing assembly. Displace well over to Intermediate drilling fluid. 12. Drill through surface shoe, rathole + 20' of new hole and perform LOT to a minimum of 12.5 ppq. 13. Drill Intermediate hole to casing point �/ 14. Change one set of pipe rams to T and est BOPE as required. _ 15. Run and cement the 7-5/8" intermediate casing. .t- &Jl-� J'T 4%� f X35 16. Bump the plug and bring the pressure up to 3500 psi -hold for 5 minute pressure test. Release pressure and ensure floats are holding. 17. Bullhead corrosion inhibited brine or diesel down the 10-3/4" x 7-5/8" annulus to freeze protect the well to --2000' TVD 18. LD 5" DP 19. PU 4" DP as needed to TD the lateral hole section. / 20. RIH to landing collar and w/ 4" DP & 6-3/4" mill tooth cleanout bit. lv 21. Change pipe rams to 4" and test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 22. Pressure test casing to 4500 psi - chart and hold for 30 minute pressure. 23. Drill through Intermediate shoe and POH w/ cleanout assembly. 24. MU 6-3/4" Motor/MWD/LWD drilling assembly on 4" DP and RIH. 25. Displace to drill -in -fluid for production lateral. 26. Drill rathole + 20' of new hole and perform FIT to 12.5 ppg. 27. Drill 6-3/4" lateral production hole to TD. 28. Circulate and condition hole to run liner. POOH. 29. Change one set of pipe rams to 4-1/2" and test BOPE as required. 30. RIH w/ 4-1/2" production liner w/ Baker MultiPoint frac system from 150' inside the intermediate shoe to TD. 31. Release from the liner and set the liner top packer. Displace the well over to completion brine and POOH. Pioneer Natural Resources Last Revised: Jul 24t", 2012 ODST-47 Permit To Drill Page 7 of 11 32. Run 4-1/2" fracture stimulation string to top of 4-1/2" liner seal bore. 33. Reverse circulate corrosion inhibited brine or diesel to freeze protect the well to —2000' TVD. 34. Sting 4-1/2" fracture stimulation string into the 4-1/2" liner seal bore. 35. Pressure test 7-5/8" x 4-1/2" annulus to 3500 psi - chart and hold for 30 minute pressure. Send,✓ chart to ODE. Pioneer Natural Resources Last Revised: Jul 24`h, 2012 ODST-47 Permit To Drill Page 8 of 11 Post Rig Operation: Fracture Stimulation 1. Fracture stimulate well 2,000,000 lbs of 20/40 Carboceramics Carbolite proppant pumped in 600,000 gallons of Schlumberger's YF125ST. The fluid volume includes a pad stage yet to be determined. The stimulation will target the Torok reservoir in a 9 stage treatment using the Baker MultiPoint mechanical diversion system. The expected surface treating pressure at a planned pump rate of 50 barrels per minute is 7000 psi. Maximum proppant concentration is 10 ppa per gallon. The Schlumberger YF125ST is a water based guar gel system with borate crosslinker. The chemical make-up of the YF125ST includes: Seawater base — 983.75 gpt Clay Stabilizer — 2 gpt Polymer — 6.25 gpt Surfactant — 2 gpt Crosslinker — 6 gpt Oxidative Breaker — 0.05 ppt 2. Remove SSSV sleeve and install wireline retrievable SSSV 3. Install live gaslift valves 4. Flowback well with gaslift. 5. RDMO ODST-47 Rig Activity: ESP Completion 1. Rig up over ODST-47 2. Install BPV and nipple down tree. 3. Pull 4'/2" fracture stimulation string. 4. RIH w/ ESP completion w/ Packer & Tubing Retrievable ScSSSV. 5. Space out and land tubing hanger. 6. RILDS and test both the upper and lower tubing hanger body seals to 5000psi. 7. Set BPV, ND BOPE, NU Production Tree 8. Replace BPV w/ TWC & Test Production Tree void to 5000psi & recover TWC 9. Reverse circulate corrosion inhibited brine or diesel to freeze protect the well to --2000' TVD 10. Set packer and test annulus to 3500 psi for 30 min. Post Rig Operations: 1. Rig up slickline 2. Retrieve ball/rod assembly from the RHC -M plug body 3. Pull dummy valve from lower GLM, set'/" OV in same. 4. Retrieve RHCM plug body 5. Rig down slickline Pioneer Natural Resources Last Revised: Jul 241h, 2012 ODST-47 Permit To Drill Page 9 of 11 Casing Shoe Leak Off Test Procedure: 1. After testing BOPE, pick up the drilling assembly and RIH to the float collar. Circulate to consistent mud weight and rheology. 2. Shut in with the pipe rams and test the casing to the required test pressure. Record the volume of mud required and the corresponding pressures in '/ bbl increments. When the design pressure is reached shut in the well and record the shut in pressure for 30 minutes. 3. Bleed off pressure while taking returns to a calibrated tank and record volume recovered. 4. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in/out. Pull up into the casing shoe. 5. Perform a Leak Off Test (or Formation Integrity Test): • Calculate the required test pressure to reach leak off (or formation integrity test limit) with the actual mud weight and the estimated fracture EMW. • Plot the casing test data and the calculated leak off on appropriate scale coordinate paper. As a guide, use the data from the casing test to determine the approximate volume of mud required to reach the calculated LOT/FIT. • Shut the well in. R/U the test pump. • Bring the pump on line at 0.25 — 0.50 bpm. Maintain a constant rate. • Record the pressure for every'/ of a bbl pumped. • Continue pumping until the pressure vs. volume curve breaks over indicating leak off. Note: For FIT, do not take to leak off • Discontinue pumping and shut in the well. Record the shut in pressure in 1 minute increments for 10 minutes or until pressure shows stabilization. • Bleed off the pressure and record the volume of mud recovered. • Plot the data to determine the LOT/FIT pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised: Jul 24th, 2012 ODST-47 Permit To Drill Page 10 of 11 ODST-47 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Torok, hold a pre -reservoir meeting to outline heightened awareness - for kick detection and lost circulation. 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. • 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. Kick Tolerance/Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Maximum Mud Weight Exp Pore Min LOT / FIT Interval Influx Volume Press 10-3/4" Surface / Infinite 9.5 - 10.5 ppg 2307 12.5 ppg (LOT) 9-7/8 —13.0 ppg via MPD 7-5/8" Intermediate / Infinite 9.3 — 9.8 ppg 2307 12.5 ppg (FIT) 6-3/4" NOTE: All LOT / FIT will be taken with a minimum of 20 -ft and a maximum of 50 -ft of new hole drilled outside of the previous casing strip Hydrogen Sulfide Faults • The Oooguruk Drill Site is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. • Sub -seismic faults with expected throws of 20-35' 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: Jul 24`h, 2012 ODST-47 Permit To Drill Page 11 of 11 ODST-47 Torok Prod tion Well Completion - )posed Updated 7/24/2012 16" Conductor Packer Fluid mix: Inhibited Kill weight Brine with 2000' TVD diesel cap i 10-3/4" 45.5 ppf L-80 BTC Surface Casing i @ 5616' MD / 3076' TVD cemented to surface ROC 7-5/8" 29.7 ppf L- 80 BTC -Mod Casing @ 12,256' MD / 5023' TVD 4-1/2" 12.6 ppf L-80 Hydril 521 Tubing TOC Estimated 500' above top of Kuparuk Upper Completion 1) Tubing Hanger 2) 4-'/i' 12.6#/ft Hydril 521 Tubing (2 jts), 3) 4-'/2' 12.6#/ft Hydril 521 Tubing 4) 4'/" Halliburton 'XXO' SVLN 9CR w/ 3.813" "X" profile RTS -8 with singlel/4" x 0.049" s/s control line. Cannon Cross -coupling clamps on every joint 5) 4-'/" 12.6#/ft Hydril 521 Tubing 6) 4'/" x 1" GLM, KBG-2 Hydril 521 w/ DCK2 7) 4-Y2" 12.6#/ft Hydril 521 Tubing 8) 4-'/" x 1" GLM, KBG-2 Hydril 521 w/ DV 9) 4-Yz" 12.6#/ft Hydril 521 Tubing 10) 4-1/2' x 1" GLM, KBG-2 Hydril 521 w/ DV 11) 4-Y�' 12.6#/ft Hydril 521 Tubing 12) HES XN 3.813" (3.725" NoGo) - with RHC Plug Set at 68 deg 13) 4-'/" 12.6#/ft Hydril 521 Tubing 14) 4-1/2" Halliburton 'ROC' Gauge Carrier w/ 1/4" x 0.049" s/s control line 15) 4-Yi' 12.6#/ft Hydril 521 Tubing 16) Bullet Seal assembly w/ Weatherford Ratcheting Mule Shoe V31-111- „, "A _OV CD43 49 55 67 79 91 103 ------ ----------------------- ------------ ----------------------------------------- ----- 127 4-%” Hydril 521 Liner with Baker Hughes Multi -Point Frac 6-3/4" Hole TD at Sleeves (3 per stagel) isolated with ECP's + Resman at 18,247' MD Carriers (2 per stage) 5281' TVD ODST-47 Torok Prot Ition Well Completion - posed Updated 7/24/2012 Lower Comoletion 7-5/8" 29.7 ppf ss s7 7s s, los 115 80 BTC -Mod 49 -- ---------------------------------------------------------- Casing 2s - - - - - - - - - - - - - I -111-111:i - - - - @ 12,256' MD / _ _ _ _ _ III_ _ _ _ _ _ 5023' TVD 4-1/" Hydril 521 Liner with Baker Hughes Multi -Point Frac 6-3/4" Hole TD at Sleeves (3 per stagel) isolated with ECP's + Resman Carriers (2 per stage) at 18,247' / 5281'TVD I 16" Conductor 17) Baker 5-%" X 7" ZXP Liner Top Packer with Tie Back extension and Flex Lock Hanger 18) 4-'/" 12.6#/ft Hydril 521 Liner Packer Fluid mix: 19) Baker ECP Packer (4'/" Hydril 521) Inhibited Kill weight 20) 4-'/2' 12.6#/ft Hydril 521 Liner I Brine 21) Baker Multi -Point Frac Sleeve with segmented ball seat (3.000 ball / 2.948 Seat) 4 With 2000' TVD 22) 4-Y2" 12.6#/ft Hydril 521 Liner 23) 4-'/" Resman Tracer Carrier i diesel caD 24) 4'/" 12.6#/ft Hydril 521 Liner I 25) Baker Multi -Point Frac Sleeve with segmented ball seat (3.000 ball / 2.948 Seat) 26) 4-'/2' 12.6#/ft Hydril 521 Liner 1 27) 4-1/2" Resman Tracer Carrier 28) 4-'/2' 12.6#/ft Hydril 521 Liner 29) Baker Multi -Point Frac Sleeve with solid ball seat (3.000 ball / 2.948 Seat) 10-3/4" 45.5 ppf L-80 BTC 30) 4-1/2" 12.6#/ft Hydril 521 Liner I Surface Casing 31) Baker ECP Packer (4-Yi' Hydril 521) 32) 4-'/2' 12.6#/ft Hydril 521 Liner GL i @ 5616' MD / 3076' TVD 33) Baker Multi -Point Frac Sleeve with segmented ball seat (2.938 ball / 2.885 Seat) 1 cemented to surface 34) 4-1/2" 12.6#/ft Hydril 521 Liner 1 35) 4-Y�' Resman Tracer Carrier 1 36) 4-'/" 12.6#/ft Hydril 521 Liner 37) Baker Multi -Point Frac Sleeve with segmented ball seat (2.938 ball / 2.885 Seat) GL 1 38) 4-'/2' 12.6#/ft Hydril 521 Liner 1 39) 4-'/" Resman Tracer Carrier i 40) 4-'/" 12.6#/ft Hydril 521 Liner 41) Baker Multi -Point Frac Sleeve with solid ball seat (2.938 ball / 2.885 Seat) 1 42) 4-Y2' 12.6#/ft Hydril 521 Liner 1 43) Baker ECP Packer (4-'/" Hydril 521) I 44) 4-'/" 12.6#/ft Hydril 521 Liner 45) Baker Multi -Point Frac Sleeve with segmented ball seat (2.875 ball / 2.823 Seat) I 46) 4-Y2' 12.6#/ft Hydril 521 Liner i 47) 4-Yz" Resman Tracer Carrier i 48) 4-1/2" 12.6#/ft Hydril 521 Liner 4-1/2" 12.6 ppf L-80 49) Baker Multi -Point Frac Sleeve with segmented ball seat (2.875 ball / 2.823 Seat) I Hydril 521 50) 4-'/" 12.6#/ft Hydril 521 Liner i 51) 4-1/2" Resman Tracer Carrier Tubing 52) 4-'/" 12.6#/ft Hydril 521 Liner 1 53) Baker Multi -Point Frac Sleeve with solid ball seat (2.875 ball / 2.823 Seat) 54) 4-'/" 12.6#/ft Hydril 521 Liner 55) Baker ECP Packer (4-'/i' Hydril 521) 56) 4-Yi' 12.6#/ft Hydril 521 Liner 57) Baker Multi -Point Frac Sleeve with segmented ball seat (2.813 ball / 2.760 Seat) 58) 4-'/2" 12.6#/ft Hydril 521 Liner 59) 4-'/2' Resman Tracer Carrier ROC 60) 4-Yz' 12.6#/ft Hydril 521 Liner TOC Estimated 61) Baker Multi -Point Frac Sleeve with segmented ball seat (2.813 ball / 2.760 Seat) 500' above top of 62) 4-'/z" 12.6#/ft Hydril 521 Liner Kuparuk 63) 4-'/i' Resman Tracer Carrier 64) 4-Yz' 12.6#/ft Hydril 521 Liner 65) Baker Multi -Point Frac Sleeve with solid ball seat (2.813 ball / 2.760 Seat) 66) 4-'/2" 12.6#/ft Hydril 521 Liner 17 67) Baker ECP Packer (4-'/" Hydril 521) 16 68) 4-1/V 12.6#/ft Hydril 521 Liner 69) Baker Multi -Point Frac Sleeve with segmented ball seat (2.750 ball / 2.698 Seat) 70) 4-Y2" 12.6#/ft Hydril 521 Liner 1s 71) 4-Y2' Resman Tracer Carrier 72) 4-1/2" 12.6#/ft Hydril 521 Liner 2, _ 73) Baker Multi -Point Frac Sleeve with segmented ball seat (2.750 ball / 2.698 Seat) 7-5/8" 29.7 ppf ss s7 7s s, los 115 80 BTC -Mod 49 -- ---------------------------------------------------------- Casing 2s - - - - - - - - - - - - - I -111-111:i - - - - @ 12,256' MD / _ _ _ _ _ III_ _ _ _ _ _ 5023' TVD 4-1/" Hydril 521 Liner with Baker Hughes Multi -Point Frac 6-3/4" Hole TD at Sleeves (3 per stagel) isolated with ECP's + Resman Carriers (2 per stage) at 18,247' / 5281'TVD ODST-47 Torok Production Well Completion - Proposed Updated 7/24/2012 1 Lower Completion 16" Conductor 74) 4-Y2" 12.6#/ft Hydril 521 Liner 75) 4-'/" Resman Tracer Carrier Packer Fluid mix: 76) 4-1/2" 12.6#/ft Hydril 521 Liner Inhibited Kill weioht 77) Baker Multi -Point Frac Sleeve with solid ball seat (2.750 ball 12.698 Seat) 78) 4-/ 12.6#/ft Hydril 521 Liner I Brine 79) Baker ECP Packer (4-'/i' Hydril 521) 4 with 2000' TVD 80) 4'/i' 12.6#/ft Hydril 521 Liner diesel Cap 81) Baker Multi -Point Frac Sleeve with segmented ball seat (2.688 ball / 2.635 Seat) 1 82) 4-1/2' 12.6#/ft Hydril 521 Liner 1 83) 4-1/2" Resman Tracer Carrier 84) 4-'/" 12.6#/ft Hydril 521 Liner 85) Baker Multi -Point Frac Sleeve with segmented ball seat (2.688 ball / 2.635 Seat) 86) 4-'/2' 12.6#/ft Hydril 521 Liner 10-3/4" 45.5 87) 4-1/2" Resman Tracer Carrier 88) 4-'/2' 12.6#/ft Hydril 521 Liner ppf L-80 BTC 89) Baker Multi -Point Frac Sleeve with solid ball seat (2.688 ball / 2.635 Seat) GL I Surface 90) 4-'/z" 12.6#/ft Hydril 521 Liner 91) Baker ECP Packer (4-'/z' Hydril 521) i Casing 92) 4-%" 12.6#/ft Hydril 521 Liner @ 5616' 93) Baker Multi -Point Frac Sleeve with segmented ball seat (2.625 ball / 2.573 Seat) MD / 3076' 94) 4-1/2' 12.6#/ft Hydril 521 Liner GL 1 TVD 95) 4-'/" Resman Tracer Carrier 96) 4-'/z" 12.6#/ft Hydril 521 Liner cemented to 97) Baker Multi -Point Frac Sleeve with segmented ball seat (2.625 ball / 2.573 Seat) surface 98) 4-'/" 12.6#/ft Hydril 521 Liner 99) 4-1/2" Resman Tracer Carrier 100) 4-'/i' 12.6#/ft Hydril 521 Liner 101) Baker Multi -Point Frac Sleeve with solid ball seat (2.625 ball / 2.573 Seat) 1 102) 4-'/" 12.6#/ft Hydril 521 Liner 103) Baker ECP Packer (4-'/2' Hydril 521) 104) 4%" 12.6#/ft Hydril 521 Liner 105) Baker Multi -Point Frac Sleeve with segmented ball seat (2.563 ball / 2.510 Seat) 521 4-1/2" 12.6 ppf L-80 107) 4-%:" Resm/ft n T arcer Carrlierr 1 Hydril 521 108) a'i° 12.6#/ft Hydril 521 Liner 1 Tubing 109) Baker Multi -Point Frac Sleeve with segmented ball seat (2.563 ball / 2.510 Seat) 1 110) 4-Yz' 12.6#/ft Hydril 521 Liner 111) 4-'/z" Resman Tracer Carrier GL 1 112) 4-'/z" 12.6#/ft Hydril 521 Liner I '•.i's 113) Baker Multi -Point Frac Sleeve with solid ball seat (2.563 ball / 2.510 Seat) 114) 4-'/2' 12.6#/ft Hydril 521 Liner XM 115) Baker ECP Packer (4-1/2' Hydril 521) 116) 4-'/z' 12.6#/ft Hydril 521 Liner ROC i�iii 117) 4-'/z' Resman Tracer Carrier - - TOC Estimated 118) 4-1W' 12.6#/ft Hydril 521 Liner 500' above top of 119) Pressure Activated Sleeve "B" 5,800 psi 120) 4-'/" 12.6#/ft Hydril 521 Liner Kuparuk 121) Pressure Activated Sleeve "A" 5,800 psi 122) 4-1/2" 12.6#/ft Hydril 521 Liner 123) 4-'/z" Resman Tracer Carrier 124) 4-'/i' 12.6#/ft Hydril 521 Liner 16 17 125) Wellbore Isolation Valve "WIV' 126) 4-'/" 12.6#/ft Hydril 521 Liner 127) Baker 5-%" EZ Ream Shoe 7-5/8" 29.7 ppf L- 55 67 79 91 103 115 80 BTC -Mod ------ ----- S -- -------------- ------------- -- Casing- @ 12,256' MD / - - - - 1:111:111:1 - - - - - - - - - - 5023' TVD 4-%" Hydril 521 Liner with Baker Hughes Multi -Point Frac 6-3/4" Hole TD at Sleeves (3 per stagel) isolated with ECP's + Resman at 18,247' MD / Carriers (2 per stage) 5281' TVD Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODST-47 - Slot ODS -47 ODST-47 Plan: ODST-47 wp09.a Standard Proposal Report 20 July, 2012 HALLIBURTON Sperry Drilling Services PIONEER HALLIBURTON NATURAL RESOURCES Sperry Grilling OMPANY DETAR.S: Well planning- pioneer- Oooguruk Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Tray. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based WELL DETAILS: ODST-47 Ground Level: 13.5 +N/ -S +E/ -W Northing Easting Latitude Longitude Slot 0.0 0.0 6030995.50 469811.98 70.496 -150.247 ODS -47 Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODST-47 Wellbore: ODST-47 Plan: ODST-47 wp09.a -1440 -2160 -4320 C -5040 0 00 -5760 r 1; O Z -6480 O h -7200 7920 7-5/8" t I' 5000" -8640 10 3/4" CASING DETAILS REFERENCE INFORMATION TVD MD Name Size o ordinate (N/E) Reference: Well ODST47 - slot ODS -47, True North 3076.2 5616.4 10 3/4" 10-3/4 Inc Vertical (TVD) Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 53.2ft (Nabors 1 5022.9 12255.5 7-5/8" 7-5/8 TFace Neasured Depth Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 552ft (Nabors 1 5281.2 18247.1 41/2" 4-1/2 0.00 Calculation Method: MinfmamCateatare Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODST-47 Wellbore: ODST-47 Plan: ODST-47 wp09.a -1440 -2160 -4320 C -5040 0 00 -5760 r 1; O Z -6480 O h -7200 7920 7-5/8" t I' 5000" -8640 10 3/4" StartDir 2.4°/100': 30d MD, 300TVD: 215.18° RT TP Stmt Dir 3°/100': 550.46' MD, 550TVD End Dir 2734.1 T MD, 2161.73' TVD SURVEY PROGRAM SECTION DETAILS Date 2012-07-19T00:00:00 Validated: Yes Sec MD Inc Azi TVD +N/ -S +E/ -W DLeg TFace VSec Target 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 3 550.5 6.00 215.18 550.0 -10.7 -7.6 2.40 215.18 11.6 4 1779.8 42.88 215.18 1650.0 -019.3 -295.6 3.00 0.00 452.7 5 2734.2 71.50 214.27 2161.7 -1072.3 -746.9 3.00 -1.81 1156.6 6 11061.4 71.50 214.27 4803.8 -7598.6 -5193.2 0.00 0.00 8183.5 7 12086.7 86.00 175.00 5011.1 -8550.9 -5432.7 4.00 -74.18 9158.2 8 12146.7 86.00 175.00 5015.3 -8610.5 -5427.4 0.00 0.00 9216.7 9 13508.5 86.77 140.90 5103.7 -9851.4 -4924.6 2.50 -89.84 10385.7 10 14234.0 87.94 136.00 5137.2-10393.6 -4444.0 0.69 -76.66 10864.2 TorokBV15T1 11 18247.1 87.94 136.00 5281.2 -13278.7 -1658.2 0.00 0.00 13381.8 Torok B V14 T1 StartDir 2.4°/100': 30d MD, 300TVD: 215.18° RT TP Stmt Dir 3°/100': 550.46' MD, 550TVD End Dir 2734.1 T MD, 2161.73' TVD /Stmt Dir 4°/100': 11061.37 MD, 4803.78'IVD 4SDO End Dir: 12086.71' MD, 5011.13' TVD Start Dir 2.5°/100': 12146.71' MD, 5015.32'TVD 1360 Start Dir 0.69°/100': 13508.48' MD, 5103.75'TVD 1080 1 End Dir. 14234.04' MD, 5137.2' TVD Torok B V 12 TI heel rev3 1800 Torok B V l 5 TI mid DDI=6.94 -11520- Total Depth: 18247.11' MD, 5281.20' TVD -12240- 4\,.e /2" -12%0 q1 To_ _ _ _ _ _ _ _ _ _ _ _ ODST-07/ODST-47 wp09.a -5760 -5040 -4320 -3600 -2880 -2160 -1440 -720 0 720 1440 2160 2880 3600 4320 5040 5760 6480 West( -)/East(+) (1800 Win) SURVEY PROGRAM Date 2012-07-19T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool A9.7 800.0 ODST47 wp09.a (ODST47) SR -Gyro -SS 800.0 6133.0 ODST-47 wp09.a (ODST47) 6133.0 12255.0 CDST-47 wp09.a (ODST47) MWD+IFR2+MS+sal 12255.0 18247.1 ODST-47 wp09.a(ODST47) MWD+IFR2+MS+sal MWD+IFR2+MS+sal WELLBORE TARGET DETAILS (MAP CO-ORDINATES AND LAT/LONG) Name TVD +N/ -S +E/ -W Northing Easting Latitude Longitude Shape Torok B V11 T1 heel revj011.2 -8594.1 5592.7 6022425.00 464185.00 70.472 -150.293 Point Torok B V12 T1 Iteel rev%ol5.3 -8610.5 Torok B V15 T1 rvid -5427.4 6022407.98 464350.21 70.472 -150.291 Point 5137.2 -10393.6 Tarok B V14 T1 toe -4444.0 6020621.05 465326.26 70.467 -150.283 Point 5281.2 -13278.7 -1658.2 6017725.00 468100.00 70.459 -150.260 Point /Stmt Dir 4°/100': 11061.37 MD, 4803.78'IVD 4SDO End Dir: 12086.71' MD, 5011.13' TVD Start Dir 2.5°/100': 12146.71' MD, 5015.32'TVD 1360 Start Dir 0.69°/100': 13508.48' MD, 5103.75'TVD 1080 1 End Dir. 14234.04' MD, 5137.2' TVD Torok B V 12 TI heel rev3 1800 Torok B V l 5 TI mid DDI=6.94 -11520- Total Depth: 18247.11' MD, 5281.20' TVD -12240- 4\,.e /2" -12%0 q1 To_ _ _ _ _ _ _ _ _ _ _ _ ODST-07/ODST-47 wp09.a -5760 -5040 -4320 -3600 -2880 -2160 -1440 -720 0 720 1440 2160 2880 3600 4320 5040 5760 6480 West( -)/East(+) (1800 Win) PIONEERHALLIBURTON WELLBORE TARGET DETAILS (MAP CO-ORDINATES AND LAT/LONG) SURVEY PROGRAM CASING DETAILS REFERENCE INFORMATION NATURAL a i�rl Sp®fry Drilling TVD Date: 2 01 2-0 7-1 9700:00:00 Validated: Yes Version: Size Co-ordinate (N/E) Reference: Well ODST47 - Slot ODS -47, True North Vertical (TVD) Reference: 42.7'+ 13.5'@ 56.2ft (Nabors 19AC) Azi 3076.2 Depth From Depth To Survey/Plan Tool Mea -d Depth Reference: 42.7'+13.5' @ 56.2ft(Nabors 19AC) 12255.5 7-5/8" 7-5/8 42.7 42.7 800.0 ODST47 wp09.a (ODST47) SR -Gyro -SS Calculation Method: Minimum Curvature 0.00 0.00 WELL DETAILS. ODST47 800.0 6133.0 ODST-47 wp09.a (ODST47) MWD+IFR2+MS+sag 0.00 300.0 0.0 Lound Level: 13.5 6133.0 12255.0 ODST47 wp09.a (ODST47) MWD+IFR2+MS+sag 3 550.5 +N/ -S +E/ -W Northing Easting Latittude Longitude Slot 12255.0 18247.1 ODST-47 09.a ODS ( T47) MWD+IFR2+MS+sag 215.18 11.6 0.0 0.0 6030995.50 469811.98 70.496 -150.247 ODS47 4 1779.8 42.88 215.18 1650.0 -600 WELLBORE TARGET DETAILS (MAP CO-ORDINATES AND LAT/LONG) Start Dir 2.41/100% 300' MD, 300'TVD: 215.18° RT TF CASING DETAILS SECTION DETAILS TVD MD Name Size Inc Azi 3076.2 5616.4 103/4" 10-3/4 DLeg TFace 5022.9 12255.5 7-5/8" 7-5/8 42.7 0.00 5281.2 18247.1 4 1/2" 4-1/2 -1800 0.00 0.00 0.0 2 300.0 -600 WELLBORE TARGET DETAILS (MAP CO-ORDINATES AND LAT/LONG) Start Dir 2.41/100% 300' MD, 300'TVD: 215.18° RT TF SECTION DETAILS Name TVD +N/ -S +E/ -W Northing Easting Latitude Sec MD Inc Azi TVD +N/ -S +E/ -W DLeg TFace VSec Target 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 2 300.0 000 0.00 300.0 0.0 0.0 0.00 0.00 0.0 3 550.5 6,00 215.18 550.0 -10.7 -7.6 2.40 215.18 11.6 4 1779.8 42.88 215.18 1650.0 419.3 -295.6 3.00 0.00 452.7 5 2734.2 71.50 214.27 2161.7 -1072.3 -746.9 3.00 -1.81 1156.6 6 11061.4 71.50 214.27 4803.8 -7598.6 -5193.2 0.00 0.00 8183.5 7 12086.7 86.00 175.00 5011.1 -8550.9 -5432.7 4.00 -74.18 9158.2 6 12146.7 86.00 175.00 5015.3 -8610.5 -5427.4 0.00 0.00 9216.7 Hue 2 Tuff 9 13508.5 86.77 140.90 5103.7 -9851.4 4924.6 2.50 -89.84 10385.7 4200 10 14234.0 87.94 136.00 5137.2 -10393.6 -4444.0 0.69 -76.66 10864.2 Torok B V15 T1 'd 11 18247.1 87.94 136.00 5281.2 -13278.7 -1658.2 0.00 0.00 13381.8 Torok B V14 T1 If -600 WELLBORE TARGET DETAILS (MAP CO-ORDINATES AND LAT/LONG) Start Dir 2.41/100% 300' MD, 300'TVD: 215.18° RT TF Name TVD +N/ -S +E/ -W Northing Easting Latitude Longitude Shape Torok B V11 T1 heel re16011.2 -8594.1 -5592.7 6022425.00 464185.00 70.472 Torok B V12 T1 heel rev3o'015.3 -150.293 Point 0 -8610.5 -5427.4 6022407.98 464350.21 70.472 Torok B V15 T1 mid 5137.2 -10393.6 -4444.0 6020621.05 465326.26 70.467 -150.291 Point -150.283 Point Q? Start Dir 3°/100': 550.46' MD, 550'TVD Torok 8 V14 T1 toe 5281.2 -13278.7 -1658.26017725.00 468100.00 70.459 -150.260 Point 600 107--------- c_ 25? p 1200- C) End Dir: 2734.17' MD, 2161.73' TVD n a 1800 O k, Start Dir 4°/100': 11061.37' MD, 4803.78'TVD C2400 Top West Sak 10 3/4" End Dir: 12086.71' MD, 5011.13' TVD 4) H 3000 Start Dir 2.5°/100': 12146.71' MD, 5015.32'TVD Tuffacious Shales nV Start Dir 0.691/100': 13508.48' MD, 5103.75'TVD 3600 DDI = 6.94 Hue 2 Tuff End Dir: 14234.04' MD, 5137.2' TVD i � I 4200 MPANYDETAIIS: Well Planning- Pioneer -Ooogu Total Depth: 18247.11' MD, 5281.20'TVD Calculation Method: Minimum Curvature Brook 2B - - d Error System: ISCWSA n obST-47/(DDST-47 wp09.a 4800 Scan Method: Tray. Cylinder North Error Surface: Elliptical Conicco 1� Warning Method: Rules Based 7-5/8" 1 t.. Project: Oooguruk Development Top Torok- - , - 4 1/2" Saoo Site: Oooguruk Drill Site , Well: ODST-47 Middle Torok - Lower Torok Torok B V12 T1 heel re Base Torok 6000 wellbore: ODST-47 Plan: ODST-47 wp09.a Torok B V15 T1 mid Torok B V14 T1 toe 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 1 1 1 12600 13200 13800 Vertical Section at 187.12bearing (1500 ft/in) HALLIBURTON Database: EDM -Alaska Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODST-47 Wellbore: ODST-47 Design: ODST-47 wp09.a Pioneer Natural Resources Standard Proposal Report Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 TVD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f North Reference: True Survey Calculation Method: Minimum Curvature 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 lysing geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70.496 From: Map Easting: 469,920.45ft Longitude: -150.246 Position Uncertainty: 0.0 ft Slot Radius: Grid Convergence: -0.23 ? Well ODST-47 - Slot ODS -47 Well Position +N/ -S 0.0 ft Northing: 6,030,995.50 ft Latitude: 70.496 +E/ -W 0.0 ft Easting: 469,811.98 ft Longitude: -150.247' Position Uncertainty 0.0 ft Wellhead Elevation: ft Bround Level: 13.5ft Wellbore ODST-47 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?► !2) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODST-47 wp09.a Audit Notes: Version: Phase: PLAN Tie On Depth: 42.7 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (ft) (ft) (ft) (bearing) 42.7 0.0 0.0 187.12 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (ft) (?) (bearin (ft) #i (ft) (ft) (7/100ft) (?1100ft) (?/100ft) (?) 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 300.0 0.00 0.00 300.0 243.8 0.0 0.0 0.00 0.00 0.00 0.00 550.5 6.00 215.18 550.0 4938 -10.7 -7.6 2.40 2.40 0.00 215.18 1,779.8 42.88 215.18 1,650.0 1,593.8 -419.3 -295.6 3.00 3.00 0.00 0.00 2,334.2 71.50 214.27 2,161.7 2,105.5 -1,072.3 -746.9 3.00 3.00 -0.10 -1.81 11,061.4 71.50 214.27 4,803.8 4,747.6 -7,598.6 -5,193.2 0.00 0.00 0.00 0.00 12,086.7 86.00 175.00 5,011.1 4,954.9 -8,550.9 -5,432.7 4.00 1.41 -3.83 -74.18 12,146.7 86.00 175.00 5,015.3 4,959.1 -8,610.5 -5,427.4 0.00 0.00 0.00 0.00 13,508.5 86.77 140.90 5,103.7 5,047.5 -9,851.4 -4,924.6 2.50 0.06 -2.50 -89.84 14,234.0 87.94 136.00 5,137.2 5,081.0 -10,393.6 -4,444.0 0.69 0.16 -0.67 -76.66 18,247.1 87.94 136.00 5,281.2 5,225.0 -13,278.7 -1,658.2 0.00 0.00 0.00 0.00 7202012 9:55:42AM Page 2 COMPASS 2003.16 Build 42 HALLIBURTON Database: EDM -Alaska Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODST-47 Wellbore: ODST-47 Design: ODST-47 wp09.a Planned Survey Measured -995.6 Map Vertical 0.00 Depth Inclination Azimuth Depth TVDss (ft) (7) (bearing) (ft) ft 42.7 0.00 0.00 42.7 -13.5 100.0 0.00 0.00 100.0 43.8 200.0 0.00 0.00 200.0 143.8 300.0 0.00 0.00 300.0 243.8 Start Dir 2.40/100': 300' MD, 300'TVD: 215.18° RT TF 400.0 2.40 215.18 400.0 343.8 500.0 4.79 215.18 499.8 443.6 550.5 6.00 215.18 550.0 493.8 Start Dir 30/100': 550.46' MD, 550'TVD 7.37 600.0 7.49 215.18 599.2 543.0 700.0 10.49 215.18 698.0 641.8 800.0 13.49 215.18 795.8 739.6 900.0 16.49 215.18 892.4 836.2 1,000.0 19.49 215.18 987.5 931.3 1,100.0 22.49 215.18 1,080.8 1,024.6 1,200.0 25.49 215.18 1,172.2 1,116.0 1,300.0 28.49 215.18 1,261.3 1,205.1 1,400.0 31.49 215.18 1,347.9 1,291.7 1,500.0 34.49 215.18 1,431.7 1,375.5 1,600.0 37.49 215.11111 1,512.7 1,456.5 1,700.0 40.49 215.18 1,590.4 l ,E34.2 1,779.8 42.88 215.18 1,650.0 1,593.8 1,800.0 43.49 215.15 1,664.7 1,608.5 1,900.0 48.48 215.02 1,735.4 1,679.2 2,000.0 49.48 214.51 1,802.3 1,746.1 2,100.0 52.48 214.80 1,865.3 1,809.1 2,200.0 55.48 214.70 1,924.1 1,867.9 2,300.0 58.48 214.61 1,978.6 1,922.4 2,400.0 61.48 214.52 2,028.6 1,972.4 2,500.0 64.48 214.44 2,074.0 2,017.8 2,600.0 67.48 214.36 2,114.7 2,058.5 2,700.0 70.48 214.29 2,150.6 2,094.4 2,734.2 71.50 214.27 2,161.7 2,105.5 End Dir: 2734.17' MD, 2161.73' TVD 469,234.71 2,800.0 71.50 214.77 2,182.6 2,126.4 2,900.0 71.50 214.27 2,214.3 2,158.1 3,000.0 71.50 214.27 2,246.1 2,189.9 3,100.0 71.50 214.27 2,277.8 2,221.6 3,123.3 71.50 214.27 2,285.2 2,229.0 Top West Salk -1,123.9 -782.0 6,029,874.88 3,200.0 71.50 214.27 2,309.5 2,253.3 3,300.0 71.50 214.27 2,341.3 2,285.1 3,400.0 71.50 214.27 2,373.0 2,316.8 3,500.0 71.50 214.27 2,404.7 2,348.5 3,600.0 71.50 214.27 2,436.4 2,380.2 Pioneer Natural Resources Standard Proposal Report Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 TVD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f North Reference: True Survey Calculation Method: Minimum Curvature -1,437.4 -995.6 Map Map 0.00 1,549.70 +NIS +E/ -W Northing Easting US Vert Section (ft) (ft) (ft) (ft) -13.50 1,718.47 0.0 0.0 6,030,995.50 469,811.98 0.00 0.00 0.0 0.0 6,030,995.50 469,811.98 0.00 0.00 0.0 0.0 6,030,995.50 469,811.98 0.015 0.00 0.0 0.0 6,030,995.50 469,811.98 0.00 0.00 -1.7 -1.2 6,030,993.80 469,810.77 2.40 1.84 -6.8 -4.8 6,030,988.69 469,807.14 2.40 7.37 -10.7 -7.6 6,030,984.82 469,804.39 2.40 11.56 -15.5 -10.9 6,030,980.08 469,801.02 3.00 16.69 -28.2 -19.9 6,030,967.36 469,791.97 3.00 30.48 -45.2 -31.9 6,030,950.43 469,779.94 3.00 48.80 -66.3 -46.8 6,030,929.36 469,764.95 3.00 71.62 -91.6 -64.6 6,030,904.20 469,747.07 3.00 98.86 -120.8 -85.2 6,030,875.02 469,726.32 3.00 130.46 -194.1 -108.6 6,030,841.90 469,702.77 3.00 166.33 -191.1 -134.7 6,030,804.92 469,676.48 3.00 206.37 -232.9 -163.5 6,030,764.20 469,647.52 3.00 250.47 -276.5 -194.9 6,030,719.84 469,615.98 3.00 298.51 -324.5 -228.7 6,030,671.96 469,581.94 3.00 350.35 -375.9 -265.0 6,030,620.69 469,545.49 3.00 405.86 -419.3 -295.6 6,030,577.43 469,514.73 3.00 452.72 -430.6 -303.5 6,030,566.18 469,506.74 3.00 464.89 -488.4 -344.2 6,030,508.52 469,465.88 3.00 527.32 -549.3 -386.7 6,030,447.82 469,423.07 3.00 593.00 -613.1 -431.1 6,030,384.25 469,378.42 3.00 661.77 -679.5 -477.2 6,030,318.00 469,332.06 3.00 733.42 -748.5 -524.9 6,030,249.23 469,284.11 3.00 807.76 -819.8 -574.0 6,030,178.15 469,234.71 3.00 884.59 -893.2 -624.4 6,030,104.94 469,183.98 3.00 963.69 -968.6 -676.0 6,030,029.80 469,132.08 3.00 1,044.86 -1,045.6 -728.7 6,029,952.94 469,079.14 3.00 1,127.87 -1,072.3 -746.9 6,029,926.33 469,060.84 3.00 1,156.61 -1,123.9 -782.0 6,029,874.88 469,025.48 0.00 1,212.16 -1,202.3 -835.4 6,029,796.73 468,971.78 0.00 1,296.55 -1,280.7 -888.8 6,029,718.59 468,918.07 0.00 1,380.93 -1,359.0 -942.2 6,029,640.44 468,864.36 0.00 1,465.32 -1,377.3 -954.7 6,029,622.22 468,851.84 0.00 1,484.99 -1,437.4 -995.6 6,029,562.29 468,810.65 0.00 1,549.70 -1,515.8 -1,049.0 6,029,484.14 468,756.95 0.00 1,634.09 -1,594.2 -1,102.4 6,029,406.00 468,703.24 0.00 1,718.47 -1,672.5 -1,155.8 6,029,327.85 468,649.53 0.00 1,802.86 -1,750.9 -1,209.2 6,029,249.70 468,595.82 0.00 1,887.24 7/2012012 9:55:42AM Page 3 COMPASS 2003.16 Build 42 HALLIBURTON Database: EDM -Alaska Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODST-47 Wellbore: ODST-47 Design: ODST-47 wp09.a Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (ft) (4) (bearing) (ft) ft Pioneer Natural Resources Standard Proposal Report Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 TVD Reference: 42.7'+ 13.5' (copy) (copy) (Copy) (copy) @ 56.2f MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f North Reference: True Survey Calculation Method: Minimum Curvature Map Map +N/ -S +E/ -W Northing Easting DLS Vert Section (ft) (ft) (ft) (ft) 2,411.87 7/202012 9:55:42AM Page 4 COMPASS 2003.16 Build 42 3,700.0 71.50 214.27 2,468.2 2,412.0 -1,829.3 -1,262.6 6,029,171.55 468,542.12 0.00 1,971.63 3,800.0 71.50 214.27 2,499.9 2,443.7 -1,907.6 -1,316.0 6,029,093.41 468,488.41 0.00 2,056.01 3,900.0 71.50 214.27 2,531.6 2,475.4 -1,986.0 -1,369.4 6,029,015.26 468,434.70 0.0111 2,140.40 4,000.0 71.50 214.27 2,563.4 2,507.2 -2,064.4 -1,422.8 6,028,937.11 468,380.99 0.00 2,224.78 4,100.0 71.50 214.27 2,595.1 2,538.9 -2,142.8 -1,476.2 6,028,858.96 468,327.29 0.00 2,309.17 4,200.0 71.50 214.27 2,626.8 2,570.6 -2,221.1 -1,529.5 6,028,780.82 468,273.58 0.00 2,393.56 4,300.0 71.50 214.27 2,658.5 2,602.3 -2,299.5 -1,582.9 6,028,702.67 468,219.87 0.00 2,477.94 4,400.0 71.50 214.27 2,690.3 2,634.1 -2,377.9 -1,636.3 6,028,624.52 468,166.17 0.00 2,562.33 4,500.0 71.50 214.27 2,722.0 2,665.8 -2,456.3 -1,689.7 6,028,546.37 468,112.46 0.00 2,646.71 4,600.0 71.50 214.27 2,753.7 2,697.5 -2,934.6 -1,743.1 6,028,468.23 468,058.75 0.00 2,731.10 4,700.0 71.50 214.27 2,785.4 2,729.2 -2,613.0 -1,796.5 6,028,390.08 468,005.04 0.00 2,815.48 4,800.0 71.50 214.27 2,817.2 2,761.0 -2,691.4 -1,849.9 6,028,311.93 467,951.34 0.00 2,899.87 4,900.0 71.50 214.27 2,848.9 2,792.7 -2,769.7 -1,903.3 6,028,233.78 467,897.63 0.00 2,984.25 5,000.0 71.50 214.27 2,880.6 2,824.4 -2,848.1 -1,956.7 6,028,155.64 467,843.92 0.00 3,068.64 5,100.0 71.50 214.27 2,912.4 2,856.2 -2,926.5 -2,010.1 6,028,077.49 467,790.21 0.00 3,153.02 5,200.0 71.50 214.27 2,944.1 2,887.9 -3,004.9 -2,063.5 6,027,999.34 467,736.51 0.00 3,237.41 5,206.7 71.50 214.27 2,946.2 2,890.0 -3,010.1 -2,067.1 6,027,994.14 467,732.93 0.00 3,243.03 Tuffacious Shales 5,300.0 71.50 214.27 2,975.8 2,919.6 -3,083.2 -2,116.9 6,027,921.19 467,682.80 0.00 3,321.80 5,400.0 71.50 214.27 3,007.5 2,951.3 -3,161.6 -2,170.3 6,027,843.05 467,629.09 0.00 3,406.18 5,500.0 71.50 214.27 3,039.3 2,983.1 -3,240.0 -2,223.7 6,027,764.90 467,575.38 0.00 3,490.57 5,600.0 71.50 214.27 3,071.0 3,014.8 -3,318.4 -2,277.1 6,027,686.75 467,521.68 0.00 3,574.95 5LA,, 5,616.4 71.50 214.27 3,076.2 3,020.0 -3,331.2 -2,285.8 6,027,673.94 467,512.87 0.00 3,588.78 103/4" 5,700.0 71.50 214.27 3,102.7 3,046.5 -3,396.7 -2,330.5 6,027,608.60 467,467.97 0.00 3,659.34 5,800.0 21.50 214.27 3,134.5 3,078.3 -3,475.1 -2,383.9 6,027,530.46 467,414.26 0.00 3,743.72 5,900.0 71.50 214.27 3,166.2 3,110.0 -3,553.5 -2,437.3 6,027,452.31 467,360.55 0.00 3,828.11 6,000.0 71.50 214.27 3,197.9 3,141.7 -3,631.8 -2,490.7 6,027,374.16 467,306.85 0.00 3,912.49 6,100.0 71.50 214.27 3,229.6 3,173.4 -3,710.2 -2,544.1 6,027,296.01 467,253.14 0.00 3,996.88 6,114.4 71.50 214.27 3,234.2 3,178.0 -3,721.5 -2,551.7 6,027,284.78 467,245.42 0.00 4,009.01 Hue 2 Tuff 6,200.0 71.50 214.27 3,261.4 3,205.2 -3,788.6 -2,597.4 6,027,217.87 467,199.43 0.00 4,081.26 6,300.0 71.50 214.27 3,293.1 3,236.9 -3,867.0 -2,650.8 6,027,139.72 467,145.72 0.00 4,165.65 6,400.0 71.50 214.27 3,324.8 3,268.6 -3,945.3 -2,704.2 6,027,061.57 467,092.02 0.00 4,250.03 6,500.0 71.50 214.27 3,356.6 3,300.4 -4,023.7 -2,757.6 6,026,983.42 467,038.31 0.00 4,334.42 6,600.0 71.50 214.27 3,388.3 3,332.1 -4,102.1 -2,811.0 6,026,905.28 466,984.60 0.00 4,418.81 6,700.0 71.50 214.27 3,420.0 3,363.8 -4,180.5 -2,864.4 6,026,827.13 466,930.89 0.00 4,503.19 6,800.0 71.50 214.27 3,451.7 3,395.5 -4,258.8 -2,917.8 6,026,748.98 466,877.19 0.00 4,587.58 6,900.0 71.50 214.27 3,483.5 3,427.3 -4,337.2 -2,971.2 6,026,670.83 466,823.48 0.00 4,671.96 7,000.0 71.50 214.27 3,515.2 3,459.0 -4,415.6 -3,024.6 6,026,592.69 466,769.77 0.00 4,756.35 7,100.0 71.50 214.27 3,546.9 3,490.7 -4,494.0 -3,078.0 6,026,514.54 466,716.06 0.00 4,840.73 7,200.0 71.50 214.27 3,578.6 3,522.4 -4,572.3 -3,131.4 6,026,436.39 466,662.36 0.00 4,925.12 7,300.0 71.50 214.27 3,610.4 3,554.2 -4,650.7 -3,184.8 6,026,358.24 466,608.65 0.00 5,009.50 7,400.0 71.50 214.27 3,642.1 3,585.9 -4,729.1 -3,238.2 6,026,280.10 466,554.94 0.00 5,093.89 7,500.0 71.50 214.27 3,673.8 3,617.6 -4,807.4 -3,291.6 6,026,201.95 466,501.23 0.00 5,178.27 7/202012 9:55:42AM Page 4 COMPASS 2003.16 Build 42 HALLIBURTON Database: EDM -Alaska Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODST-47 Wellbore: ODST-47 Design: ODST-47 wp09.a Planned Survey Measured -7,629.2 -5,213.4 Vertical Depth Inclination Azimuth Depth (ft) (Z) (bearing) (ft) 7,600.0 71.50 214.27 3,705.6 7,700.0 71.50 214.27 3,737.3 7,800.0 71.50 214.27 3,769.0 7,900.0 71.50 214.27 3,800.7 8,000.0 71.50 214.27 3,832.5 8,100.0 71.50 214.27 3,864.2 8,200.0 71.50 214.27 3,895.9 8,300.0 71.50 214.27 3,927.7 8,400.0 71.50 214.27 3,959.4 8,500.0 71.50 214.27 3,991.1 8,600.0 71.50 214.27 4,022.8 8,700.0 71.50 214.27 4,054.6 8,800.0 71.50 214.27 4,086.3 8,900.0 71.50 214.27 4,118.0 9,000.0 71.50 214.27 4,149.7 9,100.0 71.50 214.27 4,181.5 9,200.0 71.50 214.27 4,213.2 9,209.4 71.50 214.27 41,216.2 Brook 2B -5,991.2 -3,825.5 9,300.0 71.50 214.27 4,244.9 9,400.0 71.50 214.27 4,276.7 9,500.0 71.50 214.27 4,308.4 9,600.0 71.50 214.27 4,340.1 9,700.0 71.50 214.27 4,371.8 9,800.0 71.50 214.27 4,403.6 9,900.0 4:11A 214.27 4,435.3 10,000.0 71.50 214.27 4,467.0 10,100.0 71.50 214.27 4,498.8 10,200.0 71.50 214.27 4,530.5 10,300.0 71.50 214.27 4,562.2 10,400.0 71.50 214.27 4,593.9 10,500.0 71.50 214.27 4,625.7 10,600.0 71.50 214.27 4,657.4 10,700.0 71.50 214.27 4,689.1 10,800.0 71.50 214.27 4,720.9 10,900.0 71.50 214.27 4,752.6 11,000.0 71.50 214.27 4,784.3 11,061.4 71.50 214.27 4,803.8 Start Dir 4°/100': 11061.37' MD, 4803.78'ND 11,100.0 71.93 212.70 4,815.9 11,200.0 73.09 208.69 4,846.0 11,300.0 74.33 204.73 4,874.0 11,400.0 75.65 200.82 4,899.9 11,500.0 77.02 196.95 4,923.6 11,600.0 78.45 193.13 4,944.8 Pioneer Natural Resources Standard Proposal Report Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 TVD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f North Reference: True Survey Calculation Method: Minimum Curvature 4,759.7 -7,629.2 -5,213.4 Map Map 4.00 8,216.41 TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section ft (ft) (ft) (ft) (ft) 3,649.36 8,394.22 3,649.4 -4,885.8 -3,345.0 6,026,123.80 466,447.53 0.00 5,262.66 3,681.1 -4,964.2 -3,398.4 6,026,045.65 466,393.82 0.00 5,347.04 3,712.8 -5,042.6 -3,451.8 6,025,967.51 466,340.11 0.06 5,431.43 3,744.5 -5,120.9 -3,505.2 6,025,889.36 466,286.40 0.00 5,515.82 3,776.3 -5,199.3 -3,558.6 6,025,811.21 466,232.70 0.00 5,600.20 3,808.0 -5,277.7 -3,612.0 6,025,733.06 466,178.99 0.00 5,684.59 3,839.7 -5,356.1 -3,665.3 6,025,654.92 466,125.28 0.00 5,768.97 3,871.5 -5,434.4 -3,718.7 6,025,576.77 466,071.58 0.00 5,853.36 3,903.2 -5,512.8 -3,772.1 6,025,498.62 466,017.87 0.00 5,937.74 3,934.9 -5,991.2 -3,825.5 6,025,420.47 465,964.16 0.00 6,022.13 3,966.6 -5,669.5 -3,878.9 6,025,342.33 465,910.45 0.00 6,106.51 3,998.4 -5,747.9 -3,932.3 6,025,264.18 465,856.75 0.00 6,190.90 4,030.1 -5,826.3 -3,985.7 6,025,186.03 465,803.04 0.00 6,275.28 4,061.8 -5,904.7 -4,039.1 6,025,107.88 465,749.33 0.00 6,359.67 4,093.5 -5,983.0 -4,092.5 6,025,029.74 465,695.62 0.00 6,444.06 4,125.3 -6,Oe1.4 -4,145.9 6,0241,951.59 465,641.92 0.00 6,528.44 4,157.0 -6,139.8 -4,199.3 6,024,873.44 465,588.21 0.00 6,612.83 4,160.0 -6,147.2 -4,204.3 6,024,866.06 465,583.14 0.00 6,620.79 4,188.7 -6,218.2 -4,252.7 6,024,795.29 465,534.50 0.00 6,697.21 4,220.5 -6,296.5 -4,306.1 6,024,717.15 465,480.79 0.00 6,781.60 4,252.2 -6,374.9 4,359.5 6,024,639.00 465,427.09 0.00 6,865.98 4,283.9 -6,453.3 -4,412.9 6,024,560.85 465,373.38 0.00 6,950.37 4,315.6 -6,531.6 -4,466.3 6,024,482.70 465,319.67 0.00 7,034.75 4,347.4 -6,610.0 -4,519.7 6,024,404.56 465,265.96 0.00 7,119.14 4,379.1 -6,688.4 -4,573.1 6,024,326.41 465,212.26 0.00 7,203.52 4,410.8 -6,766.8 -4,626.5 6,024,248.26 465,158.55 0.00 7,287.91 4,442.6 -6,845.1 -4,679.9 6,024,170.11 465,104.84 0.00 7,372.29 4,474.3 -6,923.5 -4,733.2 6,024,091.97 465,051.13 0.00 7,456.68 4,506.0 -7,001.9 -4,786.6 6,024,013.82 464,997.43 0.00 7,541.07 4,537.7 -7,080.3 -4,840.0 6,023,935.67 464,943.72 0.00 7,625.45 4,569.5 -7,158.6 -4,893.4 6,023,857.52 464,890.01 0.00 7,709.84 4,601.2 -7,237.0 -4,946.8 6,023,779.38 464,836.30 0.00 7,794.22 4,632.9 -7,315.4 -5,000.2 6,023,701.23 464,782.60 0.00 7,878.61 4,664.7 -7,393.7 -5,053.6 6,023,623.08 464,728.89 0.00 7,962.99 4,696.4 -7,472.1 -5,107.0 6,023,544.93 464,675.18 0.00 8,047.38 4,728.1 -7,550.5 -5,160.4 6,023,466.79 464,621.47 0.00 8,131.76 4,747.6 -7,598.6 -5,193.2 6,023,418.83 464,588.51 0.00 8,183.55 4,759.7 -7,629.2 -5,213.4 6,023,388.32 464,568.16 4.00 8,216.41 4,789.8 -7,711.2 -5,262.1 6,023,306.53 464,519.16 4.00 8,303.81 4,817.8 -7,796.9 -5,305.2 6,023,220.99 464,475.70 4.00 8,394.22 4,843.7 -7,886.0 -5,342.6 6,023,132.11 464,437.97 4.00 8,487.21 4,867.4 -7,977.9 -5,374.0 6,023,040.32 464,406.17 4.00 8,582.32 4,888.6 -8,072.2 -5,399.3 6,022,946.08 464,380.45 4.00 8,679.08 7/20/2012 9:55:42AM Page 5 COMPASS 2003.16 Build 42 Planned Survey Measured Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDM -Alaska Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f Project: Oooguruk Development MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f Site: Oooguruk Drill Site North Reference: True Well: ODST-47 Survey Calculation Method: Minimum Curvature Wellbore: ODST-47 (ft) (ft) Design: ODST-47 wp09.a 11,700.0 79.93 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +E/ -W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 4,907.36 11,700.0 79.93 189.34 4,963.6 4,907.4 -8,168.5 -5,418.5 6,022,849.85 464,360.93 4.00 8,777.03 11,800.0 81.46 185.60 4,979.7 4,923.5 -8,266.4 -5,431.3 6,022,752.08 464,347.71 4.00 8,875.69 11,900.0 83.02 181.88 4,993.2 4,937.0 -8,365.2 -5,437.7 6,022,653.27 464,340.86 4.06 8,974.58 12,000.0 84.60 178.19 5,004.0 4,947.8 -8,464.6 -5,437.8 6,022,553.88 464,340.41 4.00 9,073.22 12,086.7 86.00 175.00 5,011.1 4,954.9 -8,550.9 -5,432.7 6,022,467.62 464,345.19 4.00 9,158.17 End Dir: 12086.71' MD, 5011.13' TVD 12,100.0 86.00 175.00 5,012.1 4,955.9 -8,564.1 -5,431.5 6,022,454.41 464,346.29 0.00 9,171.13 12,145.1 86.00 175.00 5,015.2 4,959.0 -8,608.9 -5,427.6 6,022,409.63 464,350.03 0.00 9,215.07 Top Torok 12,146.7 86.00 175.00 5,015.3 4,959.1 -8,610.5 -5,427.4 6,022,407.98 464,350.17 0.00 9,216.69 Start Dir 2.50/100': 12146.71' MD, 5015.32'TVD 12,200.0 86.00 173.66 5,019.0 4,962.8 -8,663.4 -5,422.2 6,022,355.06 464,355.20 2.50 9,268.53 12,255.5 86.01 172.27 5,022.9 4,966.7 -8,718.4 -5,415.4 6,022,300.07 464,361.76 2.50 9,322.24 7-5/8" 12,300.0 86.02 171.16 5,026.0 4,969.8 $,762.3 -5,409.0 6,022,256.14 464,367.97 2.50 9,365.01 12,400.0 86.04 168.65 5,032.9 4,976.7 -8,8110.5 -5,391.5 6,022,157.88 464,385.05 2.50 9,460.30 12,500.0 86.07 166.15 5,039.8 4,983.6 -8,957.8 -5,369.8 6,022,060.45 464,406.42 2.50 9,554.20 12,600.0 86.11 163.64 5,046.6 4,990.4 -9,054.1 -5,343.8 6,021,964.04 464,432.02 2.50 9,646.55 12,700.0 86.15 161.14 5,053.4 4,997.2 -9,149.2 -5,313.6 6,021,868.84 464,461.81 2.50 9,737.17 12,800.0 86.21 158.63 5,060.0 5,003.8 -9,242.9 -5,279.3 6,021,775.02 464,495.74 2.50 9,825.88 12,900.0 86.26 156.13 5,066.6 5,(10.4 -9,335.0 -5,240.9 6,021,682.78 464,533.74 2.50 9,912.51 13,000.0 86.33 153.62 5,073.0 5,016.8 -9,425.4 -5,198.5 6,021,592.27 464,575.74 2.50 9,996.91 13,100.0 86.40 151.12 5,079.4 5,023.2 -9,513.8 -5,152.3 6,021,503.68 464,621.65 2.50 10,078.91 13,200.0 86.49 148.62 5,085.9 5,029.4 -9,600.1 -5,102.2 6,021,417.18 464,671.39 2.50 10,158.35 13,300.0 86.57 146.11 5,091.6 5,035.4 -9,684.1 -5,048.3 6,021,332.92 464,724.87 2.50 10,235.08 13,400.0 86.67 143.61 5,097.5 5,041.3 -9,765.8 -4,990.9 6,021,251.06 464,781.98 2.50 10,308.96 13,500.1 86.77 441.11 5,103.3 5,047.1 -9,844.8 -4,929.9 6,021,171.78 464,842.62 2.50 10,379.84 13,508.5 86.77 140.90 5,163.7 5,047.5 -9,851.4 -4,924.6 6,021,165.17 464,847.92 2.50 10,385.71 Start Dir 0.690/100': 13508.48' MD, 5103.75'TVD 13,600.0 86.92 141.28 5,108.8 5,052.6 -9,922.0 -4,866.6 6,021,094.35 464,905.65 0.69 10,448.58 13,700.0 87.08 139.60 5,114.0 5,057.8 -9,998.4 -4,802.3 6,021,017.66 464,969.60 0.69 10,516.46 13,800.0 87.24 138.93 5,119.0 5,062.8 -10,074.1 -4,737.1 6,020,941.72 465,034.46 0.69 10,583.48 13,804.9 87.25 138.90 5,119.2 5,063.0 -10,077.8 -4,733.9 6,020,938.02 465,037.66 0.69 10,586.75 Middle Torok 13,900.0 87.40 138.25 5,123.6 5,067.4 -10,149.0 -4,671.1 6,020,866.54 465,100.21 0.69 10,649.64 14,000.0 87.56 137.58 5,128.0 5,071.8 -10,223.2 -4,604.1 6,020,792.13 465,166.86 0.69 10,714.92 14,100.0 87.73 136.91 5,132.1 5,075.9 -10,296.5 -4,536.3 6,020,718.50 465,234.39 0.69 10,779.31 14,200.0 87.89 136.23 5,136.0 5,079.8 -10,369.1 -4,467.6 6,020,645.66 465,302.78 0.69 10,842.80 14,234.0 87.94 136.00 5,137.2 5,081.0 -10,393.6 -4,444.0 6,020,621.05 465,326.26 0.69 10,864.21 End Dir: 14234.04' MD, 5137.2' TVD - Torok B V15 T1 mid 14,300.0 87.94 136.00 5,139.6 5,083.4 -10,441.0 -4,398.2 6,020,573.45 465,371.85 0.00 10,905.59 14,400.0 87.94 136.00 5,143.2 5,087.0 -10,512.9 -4,328.8 6,020,501.29 465,440.97 0.00 10,968.32 14,500.0 87.94 136.00 5,146.7 5,090.5 -10,584.8 -4,259.4 6,020,429.12 465,510.08 0.00 11,031.06 14,600.0 87.94 136.00 5,150.3 5,094.1 -10,656.7 -4,190.0 6,020,356.96 465,579.20 0.00 11,093.80 14,700.0 87.94 136.00 5,153.9 5,097.7 -10,728.6 -4,120.5 6,020,284.79 465,648.32 0.00 11,156.53 7/202012 9:55:42AM Page 6 COMPASS 2003.16 Build 42 HALLIBURTON Database: EDM -Alaska Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODST-47 Wellbore: ODST-47 Design: ODST-47 wp09.a Pioneer Natural Resources Standard Proposal Report Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 TVD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (ft) (Y) (bearing) (ft) ft (ft) (ft) (ft) (ft) 5,101.31 14,800.0 87.94 136.00 5,157.5 5,101.3 -10,800.5 -4,051.1 6,020,212.62 465,717.44 0.00 11,219.27 14,900.0 87.94 136.00 5,161.1 5,104.9 -10,872.4 -3,981.7 6,020,140.46 465,786.55 0.00 11,282.00 15,000.0 87.94 136.00 5,164.7 5,108.5 -10,944.3 -3,912.3 6,020,068.29 465,855.67 0.0G 11,344.74 15,100.0 87.94 136.00 5,168.3 5,112.1 -11,016.2 -3,842.9 6,019,996.13 465,924.79 0.00 11,407.47 15,125.8 87.94 136.00 5,169.2 5,113.0 -11,034.8 -3,824.9 6,019,977.48 465,942.65 0.00 11,423.68 Lower Torok 15,200.0 87.94 136.00 5,171.9 5,115.7 -11,088.1 -3,773.5 6,019,923.96 465,993.91 0.00 11,470.21 15,300.0 87.94 136.00 5,175.4 5,119.2 -11,160.0 -3,704.0 6,019,851.80 466,063.02 0.00 11,532.94 15,400.0 87.94 136.00 5,179.0 5,122.8 -11,231.9 -3,634.6 6,019,779.63 466,132.14 0.00 11,595.68 15,500.0 87.94 136.00 5,182.6 5,126.4 -11,303.7 -3,565.2 6,019,707.47 466,201.26 0.00 11,658.41 15,600.0 87.94 136.00 5,186.2 5,130.0 -11,375.6 -3,495.8 6,019,635.30 466,270.38 0.00 11,721.15 15,700.0 87.94 136.00 5,189.8 5,133.6 -11,447.5 -3,426.4 6,019,563.14 466,339.50 0.00 11,783.88 15,800.0 87.94 136.00 5,193.4 5,137.2 -11,519.4 -3,357.0 6,019,490.97 466,408.61 0.00 11,846.62 15,900.0 87.94 136.00 5,197.0 5,140.8 -11,591.3 -3,287.5 6,019,418.80 466,477.73 0.00 11,909.36 16,000.0 87.94 136.00 5,200.6 5,144.4 -11,663.2 -3,218.1 6,019,346.64 466,546.85 0.00 11,972.09 16,100.0 87.94 136.00 5,204.2 5,148.0 -11,735.1 -3,148.7 6,019,274.47 466,615.97 0.00 12,034.83 16,200.0 87.94 136.00 5,207.2 5,151.5 -11,807.0 -3,079.3 6,019,202.31 466,685.08 0.00 12,097.56 16,300.0 87.94 136.00 9,211.3 5,155.1 -11,878.8 -3,009.9 6,019,130.14 466,754.20 0.00 12,160.30 16,400.0 87.94 136.00 5,214.9 5,158.7 -11,950.8 -2,940.5 6,019,057.98 466,823.32 0.00 12,223.03 16,500.0 87.94 136.00 5,218.5 5,162.3 -12,022.7 -2,871.0 6,018,985.81 466,892.44 0.00 12,285.77 16,600.0 87.94 136.00 5,222.1 5,165.9 -12,094.6 -2,801.6 6,018,913.65 466,961.55 0.00 12,348.50 16,700.0 87.94 136.00 5,225.7 5,169.5 -12,166.4 -2,732.2 6,018,841.48 467,030.67 0.00 12,411.24 16,800.0 87.94 136.00 5,229.3 5,173.1 -12,238.3 -2,662.8 6,018,769.32 467,099.79 0.00 12,473.97 16,900.0 87.94 136.00 5,232.9 5,176.7 -12,310.2 -2,593.4 6,018,697.15 467,168.91 0.00 12,536.71 17,000.0 87.94 136.00 5,236.5 5,180.3 -12,382.1 -2,524.0 6,018,624.98 467,238.03 0.00 12,599.44 17,100.0 9:;.A4 136.00 5,240.0 5,183.8 -12,454.0 -2,454.5 6,018,552.82 467,307.14 0.00 12,662.18 17,200.0 87.94 136.00 9,243.6 5,187.4 -12,525.9 -2,385.1 6,018,480.65 467,376.26 0.00 12,724.92 17,300.0 87.94 136.00 5,247.2 4,191.0 -12,597.8 -2,315.7 6,018,408.49 467,445.38 0.00 12,787.65 17,400.0 87.94 136.00 5,250.8 5,194.6 -12,669.7 -2,246.3 6,018,336.32 467,514.50 0.00 12,850.39 17,500.0 87.94 136.00 5,254.4 5,198.2 -12,741.6 -2,176.9 6,018,264.16 467,583.61 0.00 12,913.12 17,600.0 87.94 136.00 5,258.0 5,201.8 -12,813.5 -2,107.4 6,018,191.99 467,652.73 0.00 12,975.86 17,700.0 87.94 136.00 5,261.6 5,205.4 -12,885.4 -2,038.0 6,018,119.83 467,721.85 0.00 13,038.59 17,800.0 87.94 136.00 5,265.2 5,209.0 -12,957.2 -1,968.6 6,018,047.66 467,790.97 0.00 13,101.33 17,900.0 87.94 136.00 5,268.7 5,212.5 -13,029.1 -1,899.2 6,017,975.50 467,860.08 0.00 13,164.06 17,940.6 87.94 136.00 5,270.2 5,214.0 -13,058.3 -1,871.0 6,017,946.23 467,888.12 0.00 13,189.51 Base Torok 18,000.0 87.94 136.00 5,272.3 5,216.1 -13,101.0 -1,829.8 6,017,903.33 467,929.20 0.00 13,226.80 18,100.0 87.94 136.00 5,275.9 5,219.7 -13,172.9 -1,760.4 6,017,831.16 467,998.32 0.00 13,289.53 18,200.0 87.94 136.00 5,279.5 5,223.3 -13,244.8 -1,690.9 6,017,759.00 468,067.44 0.00 13,352.27 18,247.1 87.94 136.00 5,281.2 5,225.0 -13,278.7 -1,658.2 6,017,725.01 468,099.99 0.00 13,381.82 Total Depth: 18247.11' MD, 5281.20' TVD - Torok B V14 T1 toe 7/202012 9:55:42AM Page 7 COMPASS 2003.16 Build 42 HALLIBURTON Pioneer Natural Resources Standard Proposal Report Database: EDM -Alaska Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2f Project: Oooguruk Development MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) Q 56.2f Site: Oooguruk Drill Site North Reference: True Well: ODST-47 Survey Calculation Method: Minimum Curvature Wellbore: ODST-47 Design: ODST-47 wp09.a +E/ -W Northing Easting Targets (ft) (ft) (ft) Target Name -5,592.7 6,022,425.00 464,185.00 - hit/miss target Dip Angle Dip Dir. TVD - Shape (?) (bearing (ft) Torok B V11 T1 heel rev3 0.00 0.00 5,011.2 plan misses by 163.2ft at 12115.8ft MD (5013.2 TVD, -8579.8 N, -5430.1 E) - Point 4-1/2 6-1/8 Formations Torok B V15 T1 mid 0.00 0.00 5,137.2 plan hits target 11,061.4 Dip Depth Depth Depth SS - Point Start Dir 4°/100': 11061.37' MD, 4803.78'TVD Dip Direction (ft) (ft) ft Torok B V12 T1 heel rev3 0.00 0.00 5,015.3 plan hits target -8,610.5 0.00 13,804.9 5,119.2 Point 5,103.7 0.00 3,123.3 2,285.2 +N/ -S +E/ -W Northing Easting (ft) (ft) (ft) (ft) -8,594.1 -5,592.7 6,022,425.00 464,185.00 -10,393.6 -4,444.0 6,020,621.05 465,326.26 -8,610.5 -5,427.4 6,022,407.98 464,350.21 Torok B V14 T1 toe 0.00 0.00 5,281.2 -13,278.7 -1,658.2 6,017,725.00 468,100.00 plan hits target Point Casing Points Measured Vertical Measured Casing Hole Depth Depth Depth Diameter Diameter (ft) (ft) Name („) (") 5,616.4 3,076.2 10 3/4" (ft) 10-3/4 13-1/2 12,255.5 5,022.6 7-5/8" 0.0 7-5/8 8-3/4 18,247.1 5,781.2 41/2" 550.0 4-1/2 6-1/8 Formations 2,734.2 2,161.7 -1,072.3 Measured Vertical Vertical End Dir: 2734.17' MD, 2161.73' TVD 11,061.4 Dip Depth Depth Depth SS -5,193.2 Start Dir 4°/100': 11061.37' MD, 4803.78'TVD Dip Direction (ft) (ft) ft Nana Lithology (?) (bearing) 6,1141.4 3,234.2 Hue 2 Tuff -8,610.5 0.00 13,804.9 5,119.2 Middle Torok 5,103.7 0.00 3,123.3 2,285.2 Top West Sak 14,234.0 0.00 5,206.7 2,946.2 Tuffacious Shales End Dir: 14234.04' MD, 5137.2' TVD 0.00 17,940.6 5,270.2 Base Torok -1,658.2 0.00 15,125.8 5,169.2 Lower Torok 0.00 12,145.1 5,015.2 Top Torok 0.00 9,209.4 4,216.2 Brook 2B 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (ft) Mi (ft) (ft) Comment 300.0 300.0 0.0 0.0 Start Dir 2.41/100': 300' MD, 300'TVD: 215.18° RT TF 550.5 550.0 -10.7 -7.6 Start Dir 30/100': 550.46' MD, 550'TVD 2,734.2 2,161.7 -1,072.3 -746.9 End Dir: 2734.17' MD, 2161.73' TVD 11,061.4 4,803.8 -7,598.6 -5,193.2 Start Dir 4°/100': 11061.37' MD, 4803.78'TVD 12,086.7 5,011.1 -8,550.9 -5,432.7 End Dir: 12086.71' MD, 5011.13' TVD 12,146.7 5,015.3 -8,610.5 -5,427.4 Start Dir 2.50/100': 12146.71' MD, 5015.32'TVD 13,508.5 5,103.7 -9,851.4 -4,924.6 Start Dir 0.690/100': 13508.48' MD, 5103.75'TVD 14,234.0 5,137.2 -10,393.6 -4,444.0 End Dir: 14234.04' MD, 5137.2' TVD 18,247.1 5,281.2 -13,278.7 -1,658.2 Total Depth: 18247.11' MD, 5281.20' TVD 7/202012 9:55:42AM Page 8 COMPASS 2003.16 Build 42 Well Planning - Oooguruk Oooguruk Development Oooguruk Drill Site ODST-47 ODST-47 ODST-47 wp09.a Pioneer - Anticollision Summary Report 20 July, 2012 SURVEY PROGRAM Well Planning - Pioneer - Oooguruk 2012-07-19T00:00:00 Validated: Yes Version: Calculation Method: Minimum Curvature Error System: ISCWSA Depth From Depth To Survey/Plan Tool Scan Method: Tray. Cylinder North 42.7 800.0 ODST47 wp09.a (ODST-47) SR -Gyro -SS Error Surface: Elliptical Conic 800.0 6133.0 ODST47 wp09.a (ODST47) MWD+IFR2+MS+sa Warning Method: Rules Based 6133.0 12255.0 ODST-47 wpO9.a (ODST47) MWD+IFR2+MS+sa 12255.0 18247.1 ODST47 wpO9.a (ODST47) MWD+IFR2+MS+sag ODSN-113 ISI 1 ODSK-14 ODSN-12 PS10 ODSK-20 KE4 ODSDW2-19 Didposal ODSN-153 ODSN-91 IS9 ODSN 8 PS8 From Color To MD ODSN-21 P513 ODSN4 PN5-ekt ODSN-10 PS12 9 43 250 " 0D6N-17 " ODSN-71 hdk Kup _ X390 - " �ao ODSN-6 PS4 250 500 500 750 ODSN-32iPB1 IN7I 760 1000 ODSK33p$1 KupA1 1000 1250 K35A ODSN-27i IN4 1250 1500 _ �ODSK41 KupODSN37 1500 1750 1750 2000 300 6 ODSK-41 PB1 KupF 2000 2250 ODSN36 PN10 2250 2500 2500 " "" 2750 ODSN39i IN11 2750 3000 3000 3260 -ODST39 Torok 3250 3500 1 IODSN40 PN12 3500 3750 3750 4000 270 4000 --- 5000 ODSK-33 KupA 5000 6000 ODST 6000 - - 7000 5 7000 8000 ODSN-43 PSI 5 8000 9000 9000 10000 10000 11000 1 11000 _ 12000 240 120 12000 - 13000 13000 14000 ODST-46i 14000 -- -- 15000 15 15000 16000 16000 17000 17000 18000 210 150 18000 19000 200 19000 20000 180 20000 25000 Travelling Cylinder Azimuth (TFO+AZI) [bearing] vs Centre to Centre Separation 1100 ft/in] NAD 27 ASP Zone 4: WELL DETAILS: ODST-47 Ground Level: 13.5 +N/ -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6030995.50 469811.98 70.496 -150.247 ODS -47 REFERENCE INFORMATION Coordinate (N/E) Reference: Well ODST47 - Slot ODS -47, True North Vertical (TVD) Reference: 42.7'+ 13.5' @ 56.2R (Nabors 19AC) Section (VS) Reference: Slot -ODS47(O.ON, O.OE) Measured Depth Reference: 42.7' + 13.5' @ 56.2R (Nabors 19AC) Calculation Method: Minimum Curvature ANTI -COLLISION SETTINGS Interpolation Method: MD, interval: 25.0 Depth Range From: 42.7 To 1000.0 Centre Distance: 2020.4 Reference: Plan: ODST47 wp09.a O6 9 9 Disposal •. •. •. . •9 .01 •. �1 i r i, r. , 5 P�� 1 17i� rr �►a�ii � ::-�r� 4 -.r ODSN391 IN11 Cylinder Azimuth (TFO+AZI) [bearing] vs Centre to Centre Separation [50 ft/in] fiat MO Inc 7a' TVD .- .FJ -W .Lag - - T,r t 142.7 0.00 0- 42.7 MO 0.0 0.00 0.00 0.0 2 300.0 0.00 0- 300.0 0.0 O.D 0.00 0.0 DD 3580.5 6.0 215.18 550.0 -1.7 -7.8 2.40 215.18 11.8 4 1779.6 42.88 215.18 1&�i0.0 419.3 -295. 3.O 0.00 452.7 5 2T34.2 71.50 214.27 2161.7 -10n.3 -746.9 3.00 .1.81 1156.6 6 11061.4 71.50 214.27 4903.8-7598.6 51933 ODO O.W 8183.5 7 12096.7 BBDO 175.0 5011.1 5550.9 5432.7 4.00 .74.18 9158.2 9 12146.7 86.0 175.00 5015.3 5610.5 5427.4 0.00 0.00 9216.7 9 13508.5 86.77 140.90 5103.7 58514 4924.6 2.50 59.84 10385.7 1014234.0 87.94 136.00 5137.2 -10393.6 J .0 0.69 -76.66 10864.2 -k B VIS T -d 11 18247.1 87.94 136.00 5281.2-13278.7 4M.2 D.00 0- 13381.8 TIIO BV14T- Pioneer Natural Resources Anticollision Report Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Reference Site: Oooguruk Drill Site Site Error: O.Oft Reference Well: ODST-47 Well Error: 0.0ft Reference Wellbore ODST-47 Reference Design: ODST-47 wp09.a Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well ODST-47 - Slot ODS -47 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nab( 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nabc True Minimum Curvature 2.00 sigma EDM Alaska Offset Datum Reference ODST-47 wp09.a Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referE Interpolation Method: MD Interval 25.0ft Error Model: ISCWSA Depth Range: 42.7 to 1,000.Oft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 2,020.4ft Error Surface: Elliptical Conic Survey Tool Program From (ft) 42.7 800.0 6,133.0 12,255.0 Date 7/20/2012 To (ft) Survey (Wellbore) 800.0 ODST-47 wp09.a (ODST-47) 6,133.0 ODST-47 wp09.a (ODST-47) 12,255.0 ODST-47 wp09.a (ODST-47) 18,247.1 ODST-47 wp09.a (ODST-47) Tool III Description SR -Gyro -SS Fixed:v2:surface readout gyro single shot MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3 -axis correction + sag MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3 -axis correction + sag MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3 -axis correction + sag 7/20/7012 10:07:54AM Page 2 of 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources Anticollision Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 Project: Oooguruk Development ND Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nab( Reference Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nab( Site Error: O.Oft North Reference: True Reference Well: ODST-47 Survey Calculation Method: Minimum Curvature Well Error: O.Oft Output errors are at 2.00 sigma Reference Wellbore ODST-47 Database: EDM Alaska Reference Design: ODST-47 wp09.a Offset ND Reference: Offset Datum Summary Reference Offset Centre to No4o Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) Oooguruk Drill Site ODSDWI-44 - ODSDW1-44 Disposal - ODSDWI 349.6 350.0 20.5 6.01 14.5 Pass - Major Risk ODSDW2-19 - ODSDW2-19 Disposal - ODSDW2 225.0 225.0 43.6 4.16 39.5 Pass - Major Risk ODSK-13 - ODSK-13 - ODSK-13 348.3 350.0 86.4 6.29 80.1 Pass - Major Risk ODSK-13 - ODSK-13PB1 - ODSK-13PB1 348.3 350.0 86.4 6.29 80.1 Pass - Major Risk ODSK-13 - ODSK-131362 - ODSK-13PB2 348.3 350.0 86.4 6.29 80.1 Pass - Major Risk ODSK-14 - ODSK-14 - ODSK-14 KupB 324.2 325.0 81.7 5.97 75.7 Pass - Major Risk ODSK-14 - ODSK-14 P131 - ODSK-14 PB1 KupB 324.2 325.0 81.7 6.01 75.7 Pass - Major Risk ODSK-14 - ODSK-14 P132 - ODSK-14 P132 KupB 324.2 325.0 81.7 6.01 75.7 Pass - Major Risk ODSK-33 - ODSK-33 KupA - ODSK-33 KupA 42.7 42.7 120.0 1.01 119.0 Pass - Major Risk ODSK-33 - ODSK-33 P61 KupA - ODSK-33 P61 F 346.4 350.0 119.7 6.10 113.6 Pass - Major Risk ODSK-35Ai - ODSK-35 KupB - ODSK-35 KupB S( 324.0 325.0 106.1 5.66 100.4 Pass - Major Risk ODSK-35Ai - ODSK-35Ai - ODSK-35Ai KupH Sura 324.0 325.0 106.1 5.66 100.4 Pass - Major Risk ODSK-38i - ODSK-38i KupD - ODSK-38i KupD SL 371.6 375.0 72.6 6.57 66.0 Pass - Major Risk ODSK-41 - ODSK-41 KupF - ODSK-41 KupF Sury 347.7 350.0 50.4 6.33 44.1 Pass - Major Risk ODSK-41 - ODSK-41 P131 KupF - ODSK-41 PB1 Y 347.1 350.0 50.4 6.37 44.0 Pass - Major Risk ODSK-42i - ODSK-42Ai - ODSK-42Ai 373.6 375.0 44.4 5.74 37.6 Pass - Major Risk ODSK-42i - ODSK-42i KupG - ODSK-42i KupG 373.6 375.0 44.4 6.74 37.6 Pass - Major Risk ODSK-7i - ODSN-7i Ivik Kup - ODSN-71 Ivik Ifiip 323.6 325.0 138.2 5.76 132.4 Pass - Major Risk ODSNA - ODSNA KE3 - ODSN-1 KE3 323.2 325.0 190.1 5.74 184.3 Pass - Major Risk ODSNA - ODSWI KE3 PB1 - ODSN-1 KE3 P131 323.2 325.0 190.1 5.74 184.3 Pass - Major Risk ODSNA 0 - ODSNA 0 PS12 - OD$N-10 PS12 wp1 347.7 350.0 118.2 6.44 111.7 Pass - Major Risk ODSNA 1 i - ODSNA I i IS11 - ODSN-11 i ISI 1 wp1 299.9 300.0 111.5 5.48 106.1 Pass - Major Risk ODSN-12 - ODSNA 2 PS10 - ODSN-12 PS10 wp1 347.9 350.0 104.8 6.35 98.5 Pass - Major Risk ODSN-15i - ODSN-15i - ODSN-15i IN12 299.9 31_0.0 75.1 5.65 69.4 Pass - Major Risk ODSN-16 - ODSN-16 - ODSN-16 PN13 Surveys 324.3 325.0 68.9 5.92 63.0 Pass - Major Risk ODSN-16 - ODSN-161_1 - ODSN-161_1 PN13 324.3 325.0 68.9 5.92 63.0 Pass - Major Risk ODSN-17 - ODSNA7 - ODSN-17 PN13 Mid Surve 324.4 325.0 65.0 5.99 59.0 Pass - Major Risk ODSN-17 - OD5N-17 L1 - ODSN-17 L1 PN13 324.4 325.0 65.0 5.99 59.0 Pass - Major Risk ODSN-18 - ODSN-18 - ODSN-18 RN11 324.5 325.0 57.7 5.88 51.8 Pass - Major Risk ODSN-18 - ODSN-18 PB5 - ODSN-18 PN11 13135 324.5 325.0 57.7 5.93 51.8 Pass - Major Risk ODSN-18 - ODSN-18 P81 - ODSN-18 PN11 PB1 324.5 325.0 57.7 5.88 51.8 Pass - Major Risk ODSN-18 - ODSN-18 13132 - ODSN-18 PN11 P132 324.5 325.0 57.7 5.88 51.8 Pass - Major Risk OCSN-18 - ODSN-18 P62 - ODSNA 8_ PB2 324.5 325.0 57.7 5.93 51.8 Pass - Major Risk ODSN-18 - ODSN-18 P133 - ODSN-18 PN11 1383 324.5 325.0 57.7 5.88 51.8 Pass - Major Risk ODSN-18 - ODSN-18 13134 - ODSN-18 PN11 P134 324.5 325.0 57.7 5.88 51.8 Pass - Major Risk ODSN-2 - ODSN-2 PN3 ext - ODSN-2 PN3 ext wp 323.2 325.0 183.2 5.87 177.4 Pass - Major Risk ODSN-20 - ODSK-20 KE4 - ODSN-20 KE4 wp05 ( 225.0 225.0 39.1 4.21 34.9 Pass - Major Risk OIESN-21 - ODSN-21 PS13 - ODSN-21 PS13 wp0 200.0 200.0 36.2 3.73 32.5 Pass - Major Risk ODSN-22i - ODSN-22i IS14 - ODSN-22i IS14 wp0 474.0 475.0 34.8 8.21 26.6 Pass - Major Risk ODSN-23i - ODSN-23i - ODSN-231 IN14 175.0 175.0 33.4 3.18 30.2 Pass - Major Risk ODSN-23i - ODSN-23i PB1 - ODSN-23i IN14 PBI 175.0 175.0 33.4 3.18 30.2 Pass - Major Risk ODSN-23i - aDSN-23i PB2 - ODSN-23i IN14 PB2 175.0 175.0 33.4 3.22 30.2 Pass - Major Risk ODSN-24 - OD5N-24 KE5 - ODSN-24 KE5 wp04 448.8 450.0 30.7 7.88 22.8 Pass - Major Risk ODSN-25 - ODSN-25 - ODSN-25 KE1 200.0 200.0 187.5 3.62 183.8 Pass - Major Risk ODSN-25 - ODSN-29 P131 - ODSN-25 P61 200.0 200.0 187.5 3.62 183.8 Pass - Major Risk ODSN-25 - ODSN-25 P132 - ODSN-25 KE1 P132 200.0 200.0 187.5 3.62 183.8 Pass - Major Risk ODSN-25 - ODSN-25 P133 - ODSN-25 KE1 P63 200.0 200.0 187.5 3.62 183.8 Pass - Major Risk ODSN-25 - ODSN-25 P134 - ODSN-25 KE1 P134 200.0 200.0 187.5 3.62 183.8 Pass - Major Risk ODSN-26i - ODSN-26 KE2 P132 - ODSN-26 KE2 P 300.0 300.0 180.6 5.57 175.1 Pass - Major Risk ODSN-26i - ODSN-26i KE2 - ODSN-26i KE2 300.0 300.0 180.6 5.57 175.1 Pass - Major Risk ODSN-26i - ODSN-26i KE2 P131 - ODSN-26i KE2 300.0 300.0 180.6 5.57 175.1 Pass - Major Risk ODSN-27i - ODSN-27i IN4 - ODSN-27i IN4 346.7 350.0 171.7 6.32 165.4 Pass - Major Risk ODSN-27i - ODSN-27i IN4 - ODSN-27i IN4 wp 15 346.7 350.0 171.7 6.16 165.5 Pass - Major Risk 720/2012 10:07:54AM Page 3 of 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources Anticollision Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nab( Reference Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nab( Site Error: 0.0ft North Reference: True Reference Well: ODST-47 Survey Calculation Method: Minimum Curvature Well Error: O.Oft Output errors are at 2.00 sigma Reference Wellbore ODST-47 Database: EDM Alaska Reference Design: ODST-47 wp09.a Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No4o Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) Oooguruk Drill Site ODSN-28 - ODSN-28 PN3 - ODSN-28 PN3 wp08 323.4 325.0 166.2 5.92 160.3 Pass - Major Risk ODSN-29i - ODSN-29 PN5 - ODSN-29 PN5 wp01 346.9 350.0 159.4 6.01 153.4 Pass - Major Risk ODSN-30 - ODSN-30 PS5 - ODSN-30 PS5 wp01 347.0 350.0 152.5 6.14 146.3 Pass - Major Risk ODSN-31 - ODSN-31 - ODSN-31 PN6 Surveys 347.4 350.0 134.5 6.21 128.3 Pass - Major Risk ODSN-31 - ODSN-31 PB1 - ODSN-31 P131 PN6 S( 347.4 350.0 134.5 6.26 128.2 Pass - Major Risk ODSN-32i - ODSN-32i IN7 - ODSN-32i IN7 Surve, 371.3 375.0 127.1 6.58 120.5 Pass - Major Risk ODSN-32i - ODSN-32iPB1 IN7 - ODSN-32iPBI IN 371.3 375.0 127.1 6.58 120.5 Pass - Major Risk ODSN-34i - ODSN-34 IN9 - ODSN-34i IN9 Survey 347.8 350.0 112.9 6.24 106.6 Pass - Major Risk ODSN-34i - ODSN-34i PB2 - ODSN-34iPB2 IN9 347.8 350.0 112.9 6.24 106.6 Pass - Major Risk ODSN-34i - ODSN-34i PB3 - ODSN-34iPB3 IN9 347.A 350.0 112.9 6.24 106.6 Pass - Major Risk ODSN-34i - ODSN-34iPB1 - ODSN-34iPB1 IN9 347.8 350.0 112.9 6.24 106.6 Pass - Major Risk ODSN-36 - ODSN-36 L1 - ODSN-36 L1 wp01 324.0 325.0 99.9 5.67 94.3 Pass - Major Risk ODSN-36 - ODSN-36 PB1 - ODSN-36 PB1 PN10 324.0 325.0 99.9 5.67 94.3 Pass - Major Risk ODSN-36 - ODSN-36 P132 - ODSN-36 P62 PN10 324.0 325.0 99.9 9.67 94.3 Pass - Major Risk ODSN-36 - ODSN-36 PN10 - ODSN-36 PN10 Sur 324.0 325.0 99.9 5.67 94.3 Pass - Major Risk ODSN-37 - ODSN-37 - ODSN-37 PN8 348.4 350.0 80.5 6.28 74.2 Pass - Major Risk ODSN-37 - ODSN-37 L1 - ODSN-37 L1 wp01 348.4 350.0 80.5 6.28 74.2 Pass - Major Risk ODSN-3i - ODSN-3i IN4 ext - ODSN-3i IN4 wpR3 323.3 325.0 176.3 6.02 170.3 Pass - Major Risk ODSN-4 - ODSN-4 PN5 ext - ODSN-4 fIN5 ext wp 300.0 300.0 169.6 5.35 164.2 Pass - Major Risk ODSN-40 - ODSN-40 PN12 - ODSN-40 PN12 Sur 372.0 375.0 58.6 6.66 52.0 Pass - Major Risk ODSN-40 - ODSN-40PB1 PN12 - CDSN-40PB1 P 372.0 375.0 58.6 6.66 52.0 Pass - Major Risk ODSN-40 - ODSN-40P62 PN12 - ODSN-40PB2 P 372.0 375.0 58.6 6.71 51.9 Pass - Major Risk ODSN-43 - ODSN-43 PS15 - ODSN-43 PS15 wpO 374.1 175.0 28.2 6.57 21.6 Pass - Major Risk ODSN-48 - ODSN-48i IS16 - ODSN-48i IS16 wp0, 200.0 200.0 7.0 2.00 5.0 Pass - Minor Risk 1/200 ODSN-5i - ODSN-5i IS3 - ODSN-5i IS3 wp09 323.4 325.0 163.0 6.02 156.9 Pass - Major Risk ODSN-6 - ODSN-6 FIS4 - ODSN-6 PS4 wp01 346.9 350.0 155.9 6.08 149.9 Pass - Major Risk ODSN-8 - ODSN-8 PS8 - ODSN-8 PS8 wp08 - 8K 347.4 350.0 131.7 6.34 125.3 Pass - Major Risk ODSN-9i - ODSN-9i IS9 - ODSN-9i IS9 wp11 - 8K 347.5 350.0 125.0 7.03 117.9 Pass - Major Risk ODST-39 - ODSN-39i IN11 - ODSN-39i IN11 373.0 375.0 65.7 6.72 59.0 Pass - Major Risk ODST-39 - ODST-39 Torok D - ODST-39 Torok D 373.0 375.0 65.7 6.81 58.9 Pass - Major Risk ODST-39 - ODST-39 Torok D PB1 - ODST-39 Tor 373.0 375.0 65.7 6.81 58.9 Pass - Major Risk ODSIT-45 - ODSN-45i 13131 IN13 - ODSN-45i PBI 374.6 375.0 13.4 6.93 6.5 Pass - Major Risk OUST -45 - ODST-45A - ODST-45A Surveys 374.6 375.0 13.4 6.93 6.5 Pass - Major Risk ODST-46i - ODST-46i - ODST-46i Torok C 224.8 225.0 6.5 4.15 2.4 Pass - Major Risk ODST-46i - ODST-46i P131 - ODST-46i Torok C P 224.8 225.0 6.5 4.15 2.4 Pass - Major Risk ODST-46i - ODST-46i P132 - ODST-461 Torok C P 224.8 225.0 6.5 4.15 2.4 Pass - Major Risk ODST-46i - ODST-46i Torok C P133 - ODST-46i P 224.8 225.0 6.5 4.15 2.4 Pass - Major Risk 7202012 10:07.54AM Page 4 of 5 COMPASS 2003.16 Build 42 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODST-47 ODST-47 ODST-47 wp09.a Anticollision Summary Report 20 July, 2012 SURVEY PROGRAM Well Planning - Pioneer - Oooguruk 2012-07-19T00:00:00 Validated: Yes Version: Calculation Method: Minimum Curvature Error System: ISCWSA Depth From Depth To Survey/Plan Tool Scan Method: Tray. Cylinder North 42.7 800.0 ODST47wpO9.a(ODST-47) SR-Gyro-SS Error Surface: Elliptical Conic 800.0 6133.0 ODST-47wpO9.a (ODST47) MWD+DR2+NIS+sag Warning Method: Rules Based 6133.0 12255.0 ODST47 wpO9.a(ODST47) MWD+HW+MS+sa 12255.0 18247.1 ODST47 wp09.a (ODST47) MWD+E R2+MS+v 270 ODSN-16 \ ODSN-18 � ] ODSN-22i IS14 ODSN-24 KES � ] , m ] 180 Travelling Cylinder Azimuth (TFO+AZn [bearing] vs Centre to Centre Separation 1100 Win] NAD 27 ASP Zone 4: WELL DETAILS: ODST-47 Ground Level: 13.5 +N/ -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6030995.50 469811.98 70.496 -150.247 ODS -47 REFERENCE INFORMATION Coordinate (WE) Reference: Well ODST-47 - Slot ODS -47, True North Vertical (TVD) Reference: 42.7" + 13.5' @ 56.2tt (Nabors 19AC) Section (VS) Reference: Slot - ODS-47(0.ON, O.OE) Measured Depth Reference: 42.7'+ 13.5' @ 56.2R (Nabors 19AC) Calculation Method: Minimum Curvature From Color To MD 43 250 250 - ' 500 500 750 750 1000 1000 1260 1250 1600 1500 1750 1750 2000 2000 2250 2250 2500 2500 -_-""-` 2750 2750 "'" ` 3000 3000 3250 3250 3500 3500 3750 3750 4000 4000 ----' 5000 5000 6000 6000 - 7000 7000 8000 8000 9000 9000 10000 10000 11000 11000 _. -- 12000 12000 13000 13000 14000 14000 15000 15000 16000 16000 17000 17000 18000 18000 19000 19000 20000 20000 25000 ANTI -COLLISION SETTINGS Interpolation Method: MD, interval: 25.0 Depth Range From: 999.0 To 18247.1 Centre Distance: 2020.4 Reference: Plan: ODST-47 wp09.a ODSN-22i IS14 180 90 Cylinder Azimuth (TFO+AZI) [bearing] vs Centre to Centre Separation 150 Win] Sec 27 Inc - ND .w0 +EINJ 0p TO.W Vs.0 Ter9et 1 02.] 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 2 300.0 0.00 0.00 300.0 0.0 0.0 0.w 0.00 3 550.5 6.00 215.18 550.0 -10.7 -7.6 240 215.18 11.6 4172 42.68 215.18 650.0 -295.6 3.00 452.] 5 2]34M .2 71.50 214.27 2161.7 -108.310- -]46.9 3.00 -1.21 1156.6 6 110614 71.50 214.2] 4803.8 -7 .6 51933 0.00 0.00 8183.5 7 12066.] 8W.01]5.00 5011.1 4550W.9 5432.7 4.00 -]4.18 9158.2 612146.7 86.00 1]5.00 5015.3 5610.5 5427.4 0.00 0- 9216.7 9 13508.5 26.77 140.90 5103.7 58514 -4.6 2.50 -09.84 10385.7 1014234.0 87.94 136.00 5137.2-10393.6 -0444.0 0.69 -]6.66 10864.2 Tarok B V15 T1 mid 111824].1 87.94 I- 5281.2-13278.] -1658.2 0.00 0.00 13361.8-BV14T11w Pioneer Natural Resources Anticollision Report Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Reference Site: Oooguruk Drill Site Site Error: 0.0ft Reference Well: ODST-47 Well Error: 0.0ft Reference Wellbore ODST-47 Reference Design: ODST-47 wp09.a Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well ODST-47 - Slot ODS -47 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nab( 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nab( True Minimum Curvature 2.00 sigma EDM Alaska Offset Datum Reference ODST-47 wp09.a Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refere Interpolation Method: MD Interval 25.0ft Error Model: ISCWSA Depth Range: 999.0 to 18,247.1 ft Scan Method: Trav, Cylinder North Results Limited by: Maximum center -center distance of 2,020.4ft Error Surface: Elliptical Conic Survey Tool Program From (ft) 42.7 800.0 6,133.0 12,255.0 Date 7/20/2012 To (ft) Survey (Wellbore) 800.0 ODST-47 wp09.a (ODST-47) 6,133.0 ODST-47 wp09.a (ODST-47) 12,255.0 ODST-47 wp09.a (ODST-47) 18,247.1 ODST-47 wp09.a (ODST-47) Tool Mama Description 9R -Gyro -SS Fixed:v2:surface readout gyro single shot MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3 -axis correction + sag MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3 -axis correction + sag MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3 -axis correction + sag 7/202012 10:05:13AM Page 2 of 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources Anticollision Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 Project: Oooguruk Development ND Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) cQ 56.2ft (Nabr Reference Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nabs Site Error: O.Oft North Reference: True Reference Well: ODST-47 Survey Calculation Method: Minimum Curvature Well Error: O.Oft Output errors are at 2.00 sigma Reference Wellbore ODST-47 Database: EDM Alaska Reference Design: ODST-47 wp09.a Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Qo Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) Oooguruk Drill Site ODSDWI-44 - ODSDW1-44 Disposal - ODSDWI 1,014.6 1,050.0 143.3 17.86 126.8 Pass - Major Risk ODSDW2-19 - ODSDW2-19 Disposal - ODSDW2 1,000.0 1,075.0 260.6 20.81 241.3 Pass - Major Risk ODSK-13 - ODSK-13 - ODSK-13 1,008.2 1,075.0 238.4 17.35 222.0 Pass - Major Risk ODSK-13 - ODSK-13P61 - ODSK-13PB1 1,008.2 1,075.0 238.4 17.35 222.0 Pass - Major Risk ODSK-13 - ODSK-13P62 - ODSK-13PB2 1,008.2 1,075.0 238.4 17.35 222.0 Pass - Major Risk ODSK-14 - ODSK-14 - ODSK-14 KupB 1,012.1 1,075.0 231.0 19.32 212.1 Pass - Major Risk ODSK-14 - ODSK-14 PB1 - ODSK-14 P61 KupB 1,012.1 1,075.0 231.0 19.36 212.1 Pass - Major Risk ODSK-14 - ODSK-14 P132 - ODSK-14 P132 KupB 1,012.1 1,075.0 231.0 19.36 212.1 Pass - Major Risk ODSK-33 - ODSK-33 KupA - ODSK-33 KupA 999.0 42.7 971.7 14.71 958.3 Pass - Major Risk ODSK-33 - ODSK-33 P61 KupA - ODSK-33 P61 F 1,008.7 1,075.0 227.0 18.57 209.7 Pass - Major Risk ODSK-35Ai - ODSK-35 KupB - ODSK-35 KupB Si 1,810.4 1,075.0 229.7 17.48 213.5 Pass - Major Risk ODSK-35Ai- ODSK-35Ai- ODSK-35Ai KupH Sury 1,010.4 1,075.0 229.7 17.48 213.5 Pass - Major Risk ODSK-38i - ODSK-38i KupD - ODSK-38i KupD SL 1,018.6 1,075.0 201.6 17.62 185.2 Pass - Major Risk ODSK-41 - ODSK-41 KupF - ODSK-41 KupF Sury 1,000.0 1,050.0 175.0 17.04 159.0 Pass - Major Risk ODSK-41 - ODSK-41 P131 KupF - ODSK-41 P81 H 1,000.1 1,050.0 175.0 17.08 159.0 Pass - Major Risk ODSK-42i - ODSK-42Ai - ODSK-42Ai 1,011.6 1,050.0 152.1 18.80 134.8 Pass - Major Risk ODSK-42i - ODSK-42i KupG - ODSK-42i KupG 1,011.6 1,050.0 152.1 18.80 134.8 Pass - Major Risk ODSK-7i - ODSN-7i Ivik Kup - ODSN-7i Ivik Wiip uk 1,000.0 1,100.0 327.3 19.85 309.3 Pass - Major Risk ODSN-1 - ODSN-1 KE3 - ODSN-1 KE3 1,009.7 1,125.0 362.3 18.27 344.2 Pass - Major Risk ODSN-1 - ODSN-1 KE3 PB1 - ODSN-1 KE3 PBI 1,009.7 1,125.0 362.3 18.27 344.2 Pass - Major Risk ODSN-10 - ODSN-10 PS12 - ODSN-10 PS12 wp1 1,000.0 1,075.0 251.6 18.97 233.8 Pass - Major Risk ODSN-11i - ODSN-11i IS11 - ODSN-11i IS11 wpi 1,000.0 1,100.0 325.4 23.70 303.2 Pass - Major Risk ODSNA 2 - ODSN-12 PS10 - ODSN-12 PS10 wp1 1,008.7 1,V5.0 235.6 18.69 218.0 Pass - Major Risk ODSN-15i - ODSN-15i - ODSN-15i IN12 1,009.6 1,015.0 242.4 18.10 224.8 Pass - Major Risk ODSN-16 - ODSN-16 - ODSN-16 PN13 Surveys 1,000.0 1,050.0 189.6 19.42 170.4 Pass - Major Risk ODSWI6 - ODSWIEIL1 - ODSWI6L1 PN13 1,000.0 1,050.0 189.6 19.42 170.4 Pass - Major Risk ODSN-17 - ODSN-17 - ODSN-17 PN13 Mid Surve 1,000.0 1,050.0 191.1 18.20 173.7 Pass - Major Risk ODSN-17 - ODSN-17 L1 - ODSN-17 L1 PN13 1,000.0 1,050.0 191.1 18.20 173.7 Pass - Major Risk ODSWI 8 - ODSN-18 - ODSN-18 PN11 1,008.7 1,050.0 170.8 18.89 152.7 Pass - Major Risk ODSN-18 - ODSNA8 P135 - ODSNA8 PN11 P65 1,008.7 1,050.0 170.8 18.93 152.7 Pass - Major Risk ODSN-18 - ODSN-18 13131 - ODSN-18 PN11 P131 1,008.7 1,050.0 170.8 18.89 152.7 Pass - Major Risk ODSN-18 - ODSN-18 P132 - ODSN-18 PN11 P132 1,008.7 1,050.0 170.8 18.89 152.7 Pass - Major Risk ODSNA8 - ODSN-18 P132 - ODSN-18 P132 1,008.7 1,050.0 170.8 18.93 152.7 Pass - Major Risk ODSN-18 - ODSN-18 13133 - ODSN-18 PN11 P133 1,008.7 1,050.0 170.8 18.89 152.7 Pass - Major Risk ODSN-18 - ODSN-18 P64 - ODSN-18 PN11 P64 1,008.7 1,050.0 170.8 18.89 152.7 Pass - Major Risk ODSN-2 - ODSN-2 PN3 ext - ODSN-2 PN3 ext wp 1,012.2 1,200.0 514.2 25.45 495.8 Pass - Major Risk ODSN-20 - ODSK-20 KE4 - ODSN-20 KE4 wp05 L 1,000.0 1,100.0 327.5 19.23 308.9 Pass - Major Risk ODSN-21 - ODSN-21 PS13 - ODSN-21 PS13 wp0 1,014.6 1,075.0 273.9 23.25 252.7 Pass - Major Risk ODSK-22i - ODSN-22i IS14 - ODSN-22i IS14 wp0 1,014.4 1,025.0 63.4 19.21 45.7 Pass - Major Risk ODSN-23i - ODSN-23i - ODSN-231 IN14 1,018.1 1,050.0 231.0 18.26 212.9 Pass - Major Risk ODSN-23i - ODSN-23i PB1 - ODSN-23i IN14 P61 1,019.6 1,050.0 229.8 18.91 211.3 Pass - Major Risk ODSN-23i - aDSN-23i P132 - ODSN-23i IN14 P132 1,018.1 1,050.0 231.0 18.30 212.8 Pass - Major Risk ODSN-24 - OD5N-24 KE5 - ODSN-24 KE5 wp04 1,019.2 1,025.0 104.2 21.66 82.9 Pass - Major Risk ODSN-25 - ODSN-25 - ODSN-25 KE1 1,000.0 1,225.0 573.9 19.70 556.5 Pass - Major Risk ODSN-25 - ODSN-29 P131 - ODSN-25 PB1 1,000.0 1,225.0 573.9 19.70 556.5 Pass - Major Risk ODSN-25 - ODSN-25 P62 - ODSN-25 KE1 PB2 1,000.0 1,225.0 573.9 19.70 556.5 Pass - Major Risk ODSN-25 - ODSN-25 PB3 - ODSN-25 KE1 PB3 1,000.0 1,225.0 573.9 19.70 556.5 Pass - Major Risk ODSN-25 - ODSN-25 P134 - ODSN-25 KE1 13134 1,000.0 1,225.0 573.9 19.70 556.5 Pass - Major Risk ODSN-26i - ODSN-26 KE2 P62 - ODSN-26 KE2 P 1,000.0 1,150.0 437.2 18.18 420.4 Pass - Major Risk ODSN-26i - ODSN-26i KE2 - ODSN-26i KE2 1,000.0 1,150.0 437.2 18.18 420.4 Pass - Major Risk ODSN-26i - ODSN-26i KE2 P61 - ODSN-26i KE2 1,000.0 1,150.0 437.2 18.18 420.4 Pass - Major Risk ODSN-27i - ODSN-27i IN4 - ODSN-27i IN4 1,015.1 1,125.0 358.2 17.88 341.3 Pass - Major Risk ODSN-27i - ODSN-27i IN4 - ODSN-27i IN4 wp 15 1,015.1 1,125.0 358.2 17.72 341.4 Pass - Major Risk 7120/2012 10:05:13AM Page 3 of 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources Anticollision Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODST-47 - Slot ODS -47 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nab( Reference Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5' (copy) (copy) (copy) (copy) @ 56.2ft (Nab( Site Error: 0.0ft North Reference: True Reference Well: ODST-47 Survey Calculation Method: Minimum Curvature Well Error: 0.0ft Output errors are at 2.00 sigma Reference Wellbore ODST-47 Database: EDM Alaska Reference Design: ODST-47 wp09.a Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) Oooguruk Drill Site ODSN-28 - ODSN-28 PN3 - ODSN-28 PN3 wp08 999.0 1,150.0 445.7 23.15 426.6 Pass - bfajor Risk ODSN-29i - ODSN-29 PN5 - ODSN-29 PN5 wp01 1,000.0 1,100.0 333.0 18.75 314.7 Pass - Major Risk ODSN-30 - ODSN-30 PS5 - ODSN-30 PS5 wp01 1,016.6 1,100.0 285.1 18.06 268.4 Pass - Major Risk ODSN-31 - ODSN-31 - ODSN-31 PN6 Surveys 1,016.6 1,100.0 285.5 18.74 267.2 Pass - Major Risk ODSN-31 - ODSN-31 P61 - ODSN-31 P61 PN6 St 1,016.6 1,100.0 285.5 18.78 267.2 Pass - Major Risk ODSN-32i - ODSN-32i IN7 - ODSN-32i IN7 Surve, 1,000.0 1,075.0 253.4 18.78 235.7 Pass - Major Risk ODSN-32i - ODSN-32iPB1 IN7 - ODSN-32iPB1 IN 1,000.0 1,075.0 253.4 18.78 235.7 Pass - Major Risk ODSN-34i - ODSN-34 IN9 - ODSN-34i IN9 Survey 1,006.7 1,075.0 243.8 18.43 226.0 Pass - Major Risk ODSN-34i - ODSN-34i PB2 - ODSN-34iPB2 IN9 1,006.7 1,075.0 243.8 18.43 226.0 Pass - Major Risk ODSN-34i - ODSN-34i P133 - ODSN-34iPB3 IN9 1,009.7 1,075.0 243.8 18.43 226.0 Pass - Major Risk ODSN-34i - ODSN-34iPB1 - ODSN-34iPB1 IN9 1,406.7 1,075.0 243.8 18.43 226.0 Pass - Major Risk ODSN-36 - ODSN-36 L1 - ODSN-36 L1 wp01 1,008.7 1,075.0 239.7 17.59 222.9 Pass - Major Risk ODSN-36 - ODSN-36 PB1 - ODSN-36 P61 PN10 1,008.7 1,075.0 239.7 17.59 222.9 Pass - Major Risk ODSN-36 - ODSN-36 P132 - ODSN-36 P132 PN10 1,008.7 1,075.0 239.7 17.59 222.9 Pass - Major Risk ODSN-36 - ODSN-36 PN10 - ODSN-36 PN10 Sur 1,008.3 1,075.0 239.7 17.59 222.9 Pass - Major Risk ODSN-37 - ODSN-37 - ODSN-37 PN8 1,016.4 1,075.0 211.9 18.44 194.5 Pass - Major Risk ODSN-37 - ODSN-37 L1 - ODSN-37 L1 wp01 1,016.4 1,075.0 211.9 18.44 194.5 Pass - Major Risk ODSN-3i - ODSN-3i IN4 ext - ODSN-3i IN4 wpR8 1,013.9 1,150.0 415.7 20.60 397.6 Pass - Major Risk ODSN-4 - ODSN-4 PN5 ext - ODSN-4 RN5 ext wp 1,008.5 1,125.0 355.6 21.40 334.5 Pass - Major Risk ODSN-40 - ODSN-40 PN12 - ODSN-40 PN12 Sur 1,007.1 1,050.1 166.2 18.09 149.1 Pass - Major Risk ODSN-40 - ODSN-40PB1 PN12 - CDSN-40PB1 P 1,007.1 1,050.1 166.2 18.09 149.1 Pass - Major Risk ODSN-40 - ODSN-40P62 PN12 - ODSN-40PB2 P 1,007.1 1,050.1 166.2 18.14 149.0 Pass - Major Risk ODSN-43 - ODSN-43 PS15 - ODSN-43 PS15 wp0 1,000.0 1,925.0 110.6 19.20 92.2 Pass - Major Risk ODSN-48 - ODSN-48i IS16 - ODSN-481 IS16 wp0, 1,009.3 1,010.0 95.9 23.35 77.6 Pass - Major Risk ODSN-5i - ODSN-5i IS3 - ODSN-5i IS3 wp09 1,012.4 1,125.0 362.2 20.43 344.0 Pass - Major Risk ODSN-6 - ODSN-6 RS4 - ODSN-6 PS4 wp01 1,000.0 1,100.0 317.4 18.13 300.6 Pass - Major Risk ODSN-8 - ODSN-8 PS8 - ODSN-8 PS8 wp08 - 8K 1,013.9 1,100.0 290.5 19.46 272.4 Pass - Major Risk ODSN-9i - ODSIN-9i IS9 - ODSN-91 IS9 wp11 - 8K 1,017.9 1,100.0 279.2 21.89 258.9 Pass - Major Risk ODST-39 - ODSN-39i IN11 - ODSN-391 IN11 1,000.0 1,050.0 183.6 17.46 167.1 Pass - Major Risk ODST-39 - ODST-39 Torok D - ODST-39 Torok D 1,000.0 1,050.0 183.6 17.55 167.0 Pass - Major Risk ODST-39 - ODST-39 Torok D PBI - ODST-39 Tor 1,000.0 1,050.0 183.6 17.55 167.0 Pass - Major Risk ODSIT-45 - ODSN-45i PBI IN13 - ODSN-45i PBI 1,000.0 1,025.0 107.5 17.49 91.1 Pass - Major Risk OAST -45 - ODST-45A - ODST-45A Surveys 1,000.0 1,025.0 107.5 17.49 91.1 Pass - Major Risk ODST-46i - ODST-46i - ODST-461 Torok C 3,198.4 3,275.0 121.1 100.62 57.0 Pass - Major Risk ODST-46i - ODST-46i P61 - ODST-461 Torok C P 3,198.4 3,275.0 121.1 100.62 57.0 Pass - Major Risk ODST-46i - ODST-46i P132 - ODST-461 Torok C P 3,198.4 3,275.0 121.1 100.62 57.0 Pass - Major Risk ODST-461- ODST-46i Torok C P63 - ODST-46i P 3,198.4 3,275.0 121.1 100.62 57.0 Pass - Major Risk 712012012 10:05:13AM Page 4 of 5 COMPASS 2003.16 Build 42 wpO9,a " ODSDW1-44, ODSDWI-44 Disposal, ODSDWI-44 Disposal ... eODSK-13, ODSK-13, ODSK-13 VO -* ODSK-13, ODSK-13PBL ODSK-13PB1 VO eODSK-13, ODSK-13PB2, ODSK-13PB2 VO 4ODSK-14, ODSK-14 PBI, ODSK-14 PB1 KupB VO -iE ODSK-14, ODSK-14 P132, ODSK-14 P82 KupB VO eODSK-14, ODSK-14, ODSK-14 KupB VO ODSK-33, ODSK-33 KupA, ODSK-33 KupAVO AODSK-33, ODSK-33 PB1 KupA, ODSK-33 P131 KupA VO $ODSK-35Ai, ODSK-35 KupB, ODSK-35 KupB Surveys VO eODSK-35Ai, ODSK-35Ai, ODSK-35Ai KupH Surveys VO -EODSK-38i, ODSK-38i KupD, ODSK-38i KupD Surveys VD X ODSK-41, ODSK-41 KupF, ODSK-41 KupF Surveys VO eODSK-41, ODSK-41 PB1 KupF, ODSK-41 PBl KupF VO $ ODSK-42i, ODSK-42A, ODSK-42Ai VO ODSK-42i, ODSK-42i KupG, ODSK-42i KupG VO ODSN-1, ODSN-1 KE3 P81, ODSN-1 KE3 PB1 VO ODSN-1, ODSN-1 KE3, ODSN-1 KE3 VO $ODSN-15i, ODSN-15i, ODSN-15i IN12 VO +ODSN-16, ODSN-16, ODSN-16 PN13 Surveys VO A,ODSN-16, ODSN-16L1, ODSN-16L1 PN13 VO +ODSN-17, ODSN-17 Ll, ODSN-17 Ll PN13 VO $ODSN-17, ODSN-17, ODSN-17 PN13 Mid Surveys VO ,A,ODSN-18, ODSN-18 PBS, ODSN-18 PNll PB5 VO AODSN-18, ODSN-18 P81, ODSN-18 PNll PB1VO eODSN-18, ODSN-18 PB2, ODSN-18 PN11 PB2 VO eODSN-18, ODSN-18 PB2, ODSN-18 PB2 VO $ODSN-18, ODSN-18 PB3, ODSN-18 PN11 PB3 VO ODSN-18, ODSN-18 PB4, ODSN-18 PN11 PB4 VO X ODSN-18, ODSN-18, ODSN-18 PN11 VO eODSN-23i, ODSN-21 P131, ODSN-23i IN14 PB1VO -*ODSN-23i, ODSN-23i PB2, ODSN-23i IN14 PB2 VO ®ODSN-23i, ODSN-23i, ODSN-23i IN14 VO AODSN-25, ODSN-25 PBI, ODSN-25 PBIVO -*ODSN-25, ODSN-25 PB2, ODSN-25 KE1 PB2 VO $ODSN-25, ODSN-25 P93, ODSN-25 KE1 PB3 VO +ODSN-25, ODSN-25 PB4, ODSN-25 KEl PB4 VO eODSN-25, ODSN-25, ODSN-25 KE1VO -1-ODSN-26i, ODSN-26 KE2 PB2, ODSN-26 KE2 P132 VO X ODSN-16i, ODSN-26i KE2 PB1, ODSN-26i KE2 P81 VO AODSN-26i, ODSN-26i KE2, ODSN-26i KE2 VO 4ODSN-27i, ODSN-27i IN4, ODSN-27i IN4VO II c [O' , .. 1 ml am _ -Iol xI o�geIBM MitjjV%'�-ml+I[ rtIfTF�rl&lam If Plan: ODST-47 wpD9.a (ODST-47/ODST-47) -47 wp09.a 4k�)ODSDW1-44, ODSDW1-44 Disposal, ODSDWI-44 Disposal ... AODSK-13, ODSK-13, ODSK-13 VO ODSK-13, ODSK-1313131, ODSK-13PBl VO eODSK-13, ODSK-13PB2, ODSK-13PB2 VO eODSK-14, ODSK-14 P81, ODSK-14 PB1 KupB VO -E ODSK-14, ODSK-14 PBZ, ODSK-14 PB2 KupB VO AODSK-14, ODSK-14, ODSK-14 KupB VO --:�ODSK-33, ODSK-33 KupA, ODSK-33 KupAVO A ODSK-33, ODSK-33 PBI KupA, ODSK-33 1381 KupA VO $ODSK-35Ai, ODSK-35 KupB, ODSK-35 KupB Surveys VO 49ODSK-35,0, ODSK-35Ai, ODSK-35Ai KupH Surveys VO -)EODSK-38i, ODSK-38i KupD, ODSK-38i KupD Surveys VO XODSK-41, ODSK-41 KupF, ODSK-41 KupF Surveys VO e ODSK-41, ODSK-41 PBl KupF, ODSK-41 PB1 KupF VO $ ODSK-42i, ODSK-42A, ODSK-42Ai VO ODSK-42i, ODSK-42i KupG, ODSK-42i KupG VO ODSN-1, ODSN-1 KE3 PBI, ODSN-1 KE3 PBS VO AODSN-1, ODSN-1 KE3, ODSN-1 KE3 VO $ODSN-15i, ODSN-15i, ODSN-15i IN12 VO +ODSN-16, ODSN-16, ODSN-16 PN13 Surveys VO AODSN-16, ODSN-161-1, ODSN-161.1 PN13 V0 +ODSN-17, ODSN-17 Ll, ODSN-17 Ll PN13 VO $ODSN-17, ODSN-17, ODSN-17 PN13 Mid Surveys VO AODSN-18, ODSN-18 PBS, ODSN-18 PN11PB5 VO ,40DSN-18, ODSN-18 PBI, ODSN-18 PNll PBl VO eODSN-18, ODSN-18 PB2, ODSN-18 PNll PB2 VO 49ODSN-18, ODSN-18 PB2, ODSN-18_ PB2 VO $ ODSN-18, ODSN-18 PB3, ODSN-18 PNll PB3 VO ODSN-18, ODSN-18 P84, ODSN-18 PNll PB4 VO X ODSN-18, ODSN-18, ODSN-18 PNll VO 44ODSN-23i, ODSN-23i PB1, ODSN-23i INl4 PBI VO -EODSN-23i, ODSN-23i PB2, ODSN-23i IN14 PB2 VO 49ODSN-23i, ODSN-23i, ODSN-23i IN14 VO AODSN-25, ODSN-25 PBl, ODSN-25 PB1V8 -*ODSN-25, ODSN-25 PB2, ODSN-25 KEl P02 VO $ODSN-25, ODSN-25 PB3, ODSN-25 KEl PB3 VO +ODSN-25, ODSN-25 PB4, ODSN-25 KEl PB4 VO AODSN-25, ODSN-25, ODSN-25 KE1V0 7$=ODSN-26i, ODSN-26 KE2 PB2, ODSN-26 KE2 PB2 VO -X ODSN-26i, ODSN-26i KE2 PBl, ODSN-26i KE2 PB1 V0 AODSN-26i, ODSN-26i KE2, ODSN-26i KE2 VO AODSN-27i, ODSN-27i IN4, ODSN-27i IN4 V0 ;i I]®IIIM (ED 26 Llo-I'I®M IFA%I&EI+II:j+4j,Wr,*-Ia I m- If Plan: ODST-47 wpO9.a (ODST-47IODST-47) m ODSf-47wp08.a -1I1®IIIm(® L L age INIT to J* iiV % & ml + IF:*-.-F%-IFW-F-K1 & 1 m 4 ODSDW1-44, ODSDW1-44 Disposal, ODSDW1-44 Disposal ... eODSK-13, ODSK-13, ODSK-13 VO -bODSK-13, ODSK-13PB1, ODSK-13POlV0 49ODSK-13, ODSK-13PB2, ODSK-13PB2 VO e ODSK-14, ODSK-14 PBI, ODSK-14 PBI KupB VO �E ODSK-14, ODSK-14 PB2, ODSK-14 PB2 KupB VO AODSK-14, ODSK-14, ODSK-14 KupB VO ODSK-33, ODSK-33 KupA, ODSK-33 KupA VO ODSK-33, ODSK-33 PB1 KupA, ODSK-33 PBI KupA VO $ODSK-35Ai, ODSK-35 KupB, ODSK-35 KupB Surveys VO eODSK-35Ai, ODSK-35h, ODSK-35,N KupH Surveys VO �EODSK-38i, ODSK-38i KupD, ODSK-38i KupD Surveys VO X ODSK-41, ODSK-41 KupF, ODSK-41 KupF Surveys VO 44ODSK-41, ODSK-41 PB1 KupF, ODSK-41 PB1 KupF VO $ODSK-42i, ODSK-42A, ODSK-42Ai VO ODSK-42i, ODSK-42i KupG, ODSK-42i KupG VO ODSN-1, ODSN-1 KE3 PB1, ODSN-1 KE3 PB1 VO �ODSN-1, ODSN-1 KE3, ODSN-1 KE3 VO $ODSN-15i, ODSN-15i, ODSN-15i IN12 VO +ODSN-16, ODSN-16, ODSN-16 PN13 Surveys VO AODSN-16, ODSN-161.1, ODSN-161-1 PN13 VO +ODSN-17, ODSN-17 L7, ODSN-17 Ll PN13 VO $ ODSN-17, ODSN-17, ODSN-17 PN13 Mid Surveys VO 4ODSN-18, ODSN-18 PBS, ODSN-18 PN11 PB5 VO -AODSN-18, ODSN-18 Pill, ODSN-18 PNll PB1 VO eODSN-18, ODSN-18 PB2, ODSN-18 PNll PB2 VO eODSN-18, ODSN-18 P82, ODSN-18_ P132 VO $ODSN-18, ODSN-18 PB3, ODSN-18 PNll PB3 VO ODSN-18, ODSN-18 PB4, ODSN-18 PNll PB4V0 X ODSN-18, ODSN-18, ODSN-18 PN11 VO eODSN-23i, ODSN-23i PB1, ODSN-23i IN14 PB1VO -*ODSN-23i, ODSN-23i PB2, ODSN-23i IN14 PB2 VO eODSN-23i, ODSN-23i, ODSN-23i IN14 VO AODSN-25, ODSN-25 P81, ODSN-25 PB1V0 -*ODSN-25, ODSN-25 PB2, ODSN-25 KE1 P82 VO $ODSN-25, ODSN-25 PB3, ODSN-25 KE1 PB3 VO ODSN-25, ODSN-25 PB4, ODSN-25 KE1 PB4 VO ODSN-25, ODSN-25, ODSN-25 KE1 VO ODSN-26i, ODSN-26 KE2 P132, ODSN-26 KE2 PB2 VO XODSN-26i, ODSN-26i KE2 PBl, ODSN-26i KE2 PB1V0 $ ODSN-26i, ODSN-26i KE2, ODSN-26i KE2 VO J60DSN-27i, ODSN-27i BN4, ODSN-27i IN4 VO 00 Co Plan: ODST-47 wpD9.a (ODST-471ODST-47) 00 00 SO Open circle w/ cross @ Hue -1 Open circle w/ yellow fill & cross @ Hue -2 Hue - 41 —725' O DST -47 Prognosed SCP Hue -1 Ope circle w/ cross @ Hue1 Distances approx. ODST-46i moo Hue -1 ;�` - 885' O DST -47 Prognosed SCP Hue -1 T46i TVDss -2900' -FS -3200' T46 i 0 'H 100' 5500' Legend 1 0 As—hullt Conductor 4 GRAPHIC SCALE 10 1s 0 30 (■rm) 11-h - O fL / O O Yy Y ti� e tip o o ti0 ry~ e by Khn., N 4 P.ej�et oatbn •;5 fl• frl •' I.'. is R X N Location Map Notes: Coordinates aro listed on sheets 3 end 4 Alaska Nod 27, Zone 4 JOB NAME: Oooguruk Drill Site LOCATION: Protracted Section 11 Township 13 North Range 7 East Umlat Merldlon DESCRIPTION: Conductor As—built Plan w1 r�FESSIDNAI�-P�r Pioneer Natural Resouces DRAWN BY: BL CHECKED BY: Mdo SCALE: 1 "-3Q' DATE: 7-12-07 05204 I 1 of 4 ti� o o ry~ e by o ryk is e ° o e o kg 0 1� ° k'1 Notes: Coordinates aro listed on sheets 3 end 4 Alaska Nod 27, Zone 4 JOB NAME: Oooguruk Drill Site LOCATION: Protracted Section 11 Township 13 North Range 7 East Umlat Merldlon DESCRIPTION: Conductor As—built Plan w1 r�FESSIDNAI�-P�r Pioneer Natural Resouces DRAWN BY: BL CHECKED BY: Mdo SCALE: 1 "-3Q' DATE: 7-12-07 05204 I 1 of 4 -194-,OR - A /-Basis of Location DS -3H West Monument Coordinates N 6001016.61 E 498081.23 Ref. Lownsbury & Assoc. Drawing No. NSK 6.01-d672 Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL ICHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7-12-07 Umiat Meridian NANUQ JOB N0. ISHEET DESCRIPTION: I Basis of Location 05204 2 of 4 LL LL) co I VWJ i t v I—SE-Corner RUK 9 O Protracted Section 11 Coordinates 1k N 6028111.04 ' i �) PI -254. $ Ref. ! \ Ni AK BLM t Harrison. Bay Trac "A" N41 -2a\ \._ rawing V Ieamul-3.99 WASAll 7 to Pt 20 1� ` Q� I /1 611♦ PJ -2t--- .. i N 17 DSy MP. p Roods ,PI t to -Lola 3H Nry A 9 -19 BU s ETI A 1 STAKED PI INFORMATION ONLY -194-,OR - A /-Basis of Location DS -3H West Monument Coordinates N 6001016.61 E 498081.23 Ref. Lownsbury & Assoc. Drawing No. NSK 6.01-d672 Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL ICHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7-12-07 Umiat Meridian NANUQ JOB N0. ISHEET DESCRIPTION: I Basis of Location 05204 2 of 4 Well IV4. Y - Latitude (M Wngitude ��6L FEL - Pad l=1�v, 1 6,031,151 32 469,920,45 709 4F, 24150 15014 45,4646$ 3035 1077 13,50 2 W, 031,146,35 469, 915, 52 70 28 46,19252 15014 45, 60-92Z_1030 1 M-2 13, 50 3 6,031,141.88 4 7069,910,59 28 46;14354 160 144$,7375 3026 10$7 13,54 4 6,031,136.46 468,905,F�7 _70.29 45:09485 15014 45.89799 3020 9092 1350 5 6,031,131,45 469,940.74 70 29 46,0453$ 15014 46,04 305 1097 13,50 6 6, 031,126, 51 469, 895.80 74 29 45, 99680 15014 46.18735_ 30 9 0 1102 13.50 7 6,031,113,73 469, 8$3.8 70 28 45.$7039 15014 4.6, 55$79 2997 911 S 13, 50 6,031,10$.73 469, 87$.29 7Q 29 45, 82102 TO 16014 46, 303 2992 1120 13,5u— 9 6, 031,103.75 469.87 3.26, 70 2046.77184 1W 14 46,W!4 - 2987 9125 13.50 10 6, 031, 098, 79 469, $68; 36 70 29 45, 72266 1501446; 89179 2982 9134 13, 50 19 6,031,093 84 469,863.39 70 29 45,67399 15014 47,13754 2977 1 �8S 13,50 12 6,031, 068, $7 400'6_68',47_ 70 29 45, 62494 15014 47.28174 2 772 1140 13.50 13 6,031,076,06 469,846,81 70 29 45.49$40 150 14 + 7.652$$ 2960 1152 13,50 14 6,031, 071,09 469,640, $7 70 29 45.44932 150 14 47.79770 2955 1157 13, 5A 15 6, 031, 066.15 _ 469,885, 96 - --70 29 45.40053 15014 47, _90W 2950 1162 13.50 16 6,031, 061,1$ 469, 831. t 70 29 45, 3514a 15074-48-A505 2946 1167 13.50 17 6, 031, 056, 25 469,826,11 70 29 45.30277 16014 48,23(142 2940 1172 13.50 16 $1031,051-27 469,$21.18 70 29 X5.25359 150 14_4$.37485 2936 9177 13, 5Q 19 6, 031, 038, 52 469,8 _0CW -1072-9-4-6-J276-6- 15014 $, 74_66$ 2922 1189 13, 5Q 20 6,031,033,50 469,$03.59 70 2'94 5 07$19 160144$.$9469 2917 1194 13.50 29 6, 031, 028, 53 469,798.62 70 29 45,02903 1$014 49, 08W32 1199 13.50 22 6,031,023,5$ 468,793.67 70 29 44,9$014 150_1_444 9,1$144 _2912 1204 13,50 23 6, 031, 018, 67 469, 78$.76 7Q 29 44.93067 _2907 15014 49, 32537 2902 1209 13,50 24 fr, 031, 013. WO 468, 783,84 70 29 44. $$158 1$914 49,46969 1 2897 1 1214 13.50 ":W711 lb 1611 ;S' OF4 '%4s'�i 9 .iyi m* Voss so vske-A4608 -so -I Philtp G. Davi. �o Ne.4110.5 Jai •.� SJQ I Notes; 1. Elevations ore based on 9P Mean Sea Level. 2. Coordinates ore based on Alaska State Plane Nod 27, Zane 4, 3, All Conductors ore within Protracted Section 11. JCB NAME: 400guruk Drill Site Conductors LOCATION: Protrocted Section 11 TQwnshiP 13 North Ronge 7 East Umiot Meridian DESCRIPTION? As—built Coordinates Pioneer Natural Resguoes DRAWN BY; 81. SCALE: N/A QATE: 7-12-07 NANU4 JOB NO, 05204 CHECKED BY: MJQ SHEET 3of4 Well No. Alaska State Plane Y X Latitude (N) Longitude (W) Section Line Onset FSL FEL Pad Elev. 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 15014 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 1 469,811.98 70 29 44.70469 150 14 48.63910 2879 1 1186 1 13.50 48 6,030,990.58 1 469,807.07 70 29 44.65610 1 150 14 48.78304 2874 1 1191 13.50 � OF A/ t1a_ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY SUPERVISION AND THAT I BELIEVE THAT ALL DIMENSIONS AND OTHER DETAILS 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 ICHECKED 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 V7 TA CF SL; -rrc -T i. -EL &a. ............ . ...... .. .... ......... ............. .... ......... .. ..... ................... T� ----- -------.................... - ------------------ - Page 1 ofi' Schwartz, Guy L (DOA) From: Vaughan, Alex [Alex.Vaughan@pxd.com] Sent: Tuesday, July 31, 2012 2:01 PM To: Schwartz, Guy L (DOA) Subject: RE: ODST-47 ( PTD 212-103) Guy, You are correct about the 7-5/8" cement volumes. Please see the updated volumes below: Casing Size: 7-5/8" Intermediate - single stage Basis: TOC: 11,645' MD - 500' MD above the top of the Torok. 160% excess, lus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 12.5 ppg Dual Spacer Primary 42 bbls / 198 sx Premium "G" + adds. 1.15 cf/sk / 4.97 gps Displ 559 bbls mud Temp BHST - 165° F, BHCT -135° F The original volumes you received were calculated using an 8-3/4" hole not a 9-7/8" as it should have been. Alex Vaughan Senior Drillino Enoineer X Description: PioneerLogoSmall 907.343.2186 (office) 907.748.5478 (mobile) From: Schwartz, Guy L (DOA) [mailto: guy. schwa rtz@alaska.gov] Sent: Tuesday, July 31, 2012 1:36 PM To: Vaughan, Alex Subject: ODST-47 ( PTD 212-103) Alex, A couple of things on the permit. 1) the Diverter waiver was denied. The SC is landed just a bit too far from the cluster of other wells.... Commissioners are erring on the side of caution. 2) The cement volume for the Inter_ 7 5/8" casing seems a little short. Can you relook at your volumes? 3) This PTD will only authorize you to complete the well with the frac string. You will need to submit a separate sundry to hydraulically fracture the well. Tim Crumrine has a good template for the required details for the sundry. You will also need a new sundry to pull the frac string and run ESP. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 7/31 /2012 G4- TRANSMITTAL LETTER CHECKLIST WELL NAME 6T_-47 PTD# k3 °/Development Service Exploratory Stratigraphic Test Non -Conventional /Well FIELD: �u L POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to 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 tar et 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: 9/09/2011 WELL PERMIT CHECKLIST Field & Pool OOOGURUK TOROK OIL - 576175 Well Name: OOOGURUK ODST-47 _ Program DEV Well bore seg PTD#:2121030 Company PIONEER NATURAL RESOURCES ALASKA INC Initial Class/Type DEV / PEND GeoArea 973 Unit 11550 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas conforms to AS31,05.030(j.1.A),02A-D) - - - . _ - - NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . - - - - - - - - Seismic analys_is_of shallow gas_zones_ 1 Permit fee attached NA_ Seabed condition survey (if off -shore) NA 2 Lease number appropriate_ Yes Surface location in ADL 355036; top productive interval & TD in ADL_ 355038_ - - - 3 Unique well -name and number Yes _ 14 Well located in_a_defined pool Yes Oooguruk-Torok Oil Pool,governed by CO.645._ j5 Well located proper distance from drilling unit -boundary_ - - Yes CO 645, Rule 3: There shall be no restrictions as -to well spacing. except that no -pay shall 6 Well located proper distance from other wells_ Yes beopened _in a well _within 500 feet of an external property line where the owners and 7 Sufficient acreage available in drilling unit_ Yes landowners are not _the sa_m_e on both sides of the _line. - 8 -If deviated, is wellbore plat -included Yes 9 Operator only affected party Yes - - - - - - - - - - - - 10 Operator has appropriate_ bond in force _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Appr Date 11 Permit can be issued without conservation order_ - - Yes _ - - - - - - - - - 12 Permit -can be issued without ad_ministrativ_e_approval - - - - - - - - - Yes - - - - - - - - SFD 7/30/2012 13 Can permit be approved before 15-day_wait- Yes 14 Well located within area arid -strata authorized by Injection Order # (put 10# in -comments)- (For NA- - - - - - - - - - - - - - 115 All wells_within 1/4_mile area_of review identified (For service well only_) - - - - - - - NA 16 Pre -produced injector; duration of pre production Less than 3 months_ (For service well_ only) NA - _ - - - - 18 Conductor string -provided - - - - - Yes Conductor driven to 158ft _ Engineering 19 Surface casing -protects all -known USDWs NA_ - - No Aquifers.... 20 CMT vol_ adequate to circulate on conductor & surf csg Yes Surface casing will be fully cemented._ 21 CMT vol_ adequate to tie-in long string to surf csg No TOC for 7 5/8" is planned at 11650 ft and 22 CMT will cover all known -productive horizons - - - Yes slotted liner with frac-ports will be used in the Torok_ Hort. Section. 23 Casing designs adequate for C, T, B & permafrost Yes I24 Adequate tankage or reserve pit Yes Rig has steel pits. All waste to approved disposal wells. 25 If are -drill, has_a 1.0-403 for abandonment been approved - - - - NA_ - - _ . 26 Adequate wellbore separation proposed - Yes - - - - - - Proximity analysis performed. 27 If_diverter required, does it meet_ regulations_ - - - - - - - - - - - - - - Yes - - - - - - Diverter required .. Waiver request denied- - - - - - - - - - - - - - - - - - - Appr Date 28 Drilling fluid_ program schematic & equip list adequate Yes Max formation_ pressure = 2360 psi (_ 8.6 ppg EMW)_ Will drill with 9.3- 9.8 ppgmud._ And use MPD for BHP_ GLS 7/31/2012 29 _BOPEs,_do they meet regulation - - - - Yes 30 BOPE-press rating appropriate; test to _(put psig in comments)_ Yes MASP 1726 psi_ Will Test -BOP to 4500_psi_ 31 Choke -manifold complies w/API_RP-53 (May 84)_ Yes _ 32 Work will occur without operation shutdown_ Yes - - - - 33 Is presence. of H2$ gas_ probable No_ - 1-12S not expected ._Rig has -sensors -and alarms. 34 Mechanical -condition of wells within AOR verified (For service well only) NA_ - - .. _ _ _ _ _ _ - - - - - - - - - - - - - - - _]35 Perm it can be issued w/o hydrogen sulfide measures Yes - _ _ _ _ - None anticipated in_the Torok reservoir based on previous_ drilling at Ooogu_ruk. Well will be _ Geology 36 Data presented on potential overpressure zones Yes mudlogged.-H2_S_monitoring equipment will be employed and H2s_sequ_estering agents will be available. Appr Date 37 Seismic analys_is_of shallow gas_zones_ NA_ - - - - Reservoir expected is 8.4 ppg; production section_will be_d_rilled_using 9.3-9,8 ppg mud and managed SFD 7/30/2012 38 Seabed condition survey (if off -shore) NA pressure drilling- technology to maintain wellbore stability_. - - - - 39 Contact name/phone for weekly_progress reports (exploratory only] NA - - - Geologic Engineering P Grassroots Torok producer well. Will be completed with a frac string. Sundry required to stimulate the well and run ESP. GLS Date: Dateate Commissioner: Commissioner: CoCm ner F I GeoTap Pressure Transient Analysis Client: Pioneer Natural Resources Inc. Well: ODST-47 Field: Oooguruk Rig: Nabors 19AC Country: U.S.A. Logged: 9/25/12 Analyst: S. Kizziar Date: 10/30/12 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 2 Table of Contents Table of Contents .......................................................................................................................................... 2 Overview ....................................................................................................................................................... 6 Log Header .................................................................................................................................................... 7 Test Summary ............................................................................................................................................. 10 Gradients ..................................................................................................................................................... 22 Gradient 1 ............................................................................................................................................... 22 Plots ............................................................................................................................................................ 24 Test No. 1.0; MD: 12434.01 ft; TVD: 5018.74 ft ...................................................................................... 24 Test No. 1.1; MD: 12434.01 ft; TVD: 5018.74 ft ...................................................................................... 25 Test No. 1.2; MD: 12434.01 ft; TVD: 5018.74 ft ...................................................................................... 26 Test No. 1.3; MD: 12434.01 ft; TVD: 5018.74 ft ...................................................................................... 27 Test No. 2.0; MD: 12436.00 ft; TVD: 5018.89 ft ...................................................................................... 28 Test No. 2.1; MD: 12436.00 ft; TVD: 5018.89 ft ...................................................................................... 29 Test No. 2.2; MD: 12436.00 ft; TVD: 5018.89 ft ...................................................................................... 30 Test No. 2.3; MD: 12436.00 ft; TVD: 5018.89 ft ...................................................................................... 31 Test No. 3.0; MD: 12584.01 ft; TVD: 5028.54 ft ...................................................................................... 32 Test No. 3.1; MD: 12584.01 ft; TVD: 5028.54 ft ...................................................................................... 33 Test No. 3.2; MD: 12584.01 ft; TVD: 5028.54 ft ...................................................................................... 34 Test No. 3.3; MD: 12584.01 ft; TVD: 5028.54 ft ...................................................................................... 35 Test No. 4.0; MD: 12723.00 ft; TVD: 5036.01 ft ...................................................................................... 36 Test No. 4.1; MD: 12723.00 ft; TVD: 5036.01 ft ...................................................................................... 37 Test No. 4.2; MD: 12723.00 ft; TVD: 5036.01 ft ...................................................................................... 38 Test No. 4.3; MD: 12723.00 ft; TVD: 5036.01 ft ...................................................................................... 39 Test No. 5.0; MD: 12717.97 ft; TVD: 5035.75 ft ...................................................................................... 40 Test No. 5.1; MD: 12717.97 ft; TVD: 5035.75 ft ...................................................................................... 41 Test No. 5.2; MD: 12717.97 ft; TVD: 5035.75 ft ...................................................................................... 42 Test No. 5.3; MD: 12717.97 ft; TVD: 5035.75 ft ...................................................................................... 43 Test No. 6.0; MD: 12814.98 ft; TVD: 5040.82 ft ...................................................................................... 44 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 3 Test No. 7.0; MD: 12809.01 ft; TVD: 5040.46 ft ...................................................................................... 45 Test No. 8.0; MD: 13041.96 ft; TVD: 5056.09 ft ...................................................................................... 46 Test No. 9.0; MD: 13043.01 ft; TVD: 5056.18 ft ...................................................................................... 47 Test No. 10.0; MD: 13108.00 ft; TVD: 5060.88 ft .................................................................................... 48 Test No. 11.0; MD: 13103.00 ft; TVD: 5060.57 ft .................................................................................... 49 Test No. 11.1; MD: 13103.00 ft; TVD: 5060.57 ft .................................................................................... 50 Test No. 11.2; MD: 13103.00 ft; TVD: 5060.57 ft .................................................................................... 51 Test No. 11.3; MD: 13103.00 ft; TVD: 5060.57 ft .................................................................................... 52 Test No. 12.0; MD: 13099.94 ft; TVD: 5060.37 ft .................................................................................... 53 Test No. 12.1; MD: 13099.94 ft; TVD: 5060.37 ft .................................................................................... 54 Test No. 12.2; MD: 13099.94 ft; TVD: 5060.37 ft .................................................................................... 55 Test No. 12.3; MD: 13099.94 ft; TVD: 5060.37 ft .................................................................................... 56 Test No. 13.0; MD: 13579.97 ft; TVD: 5094.63 ft .................................................................................... 57 Test No. 13.1; MD: 13579.97 ft; TVD: 5094.63 ft .................................................................................... 58 Test No. 13.2; MD: 13579.97 ft; TVD: 5094.63 ft .................................................................................... 59 Test No. 13.3; MD: 13579.97 ft; TVD: 5094.63 ft .................................................................................... 60 Test No. 14.0; MD: 13570.00 ft; TVD: 5093.84 ft .................................................................................... 61 Test No. 14.1; MD: 13570.00 ft; TVD: 5093.84 ft .................................................................................... 62 Test No. 14.2; MD: 13570.00 ft; TVD: 5093.84 ft .................................................................................... 63 Test No. 14.3; MD: 13570.00 ft; TVD: 5093.84 ft .................................................................................... 64 Test No. 15.0; MD: 13568.28 ft; TVD: 5093.70 ft .................................................................................... 65 Test No. 15.1; MD: 13568.28 ft; TVD: 5093.70 ft .................................................................................... 66 Test No. 15.2; MD: 13568.28 ft; TVD: 5093.70 ft .................................................................................... 67 Test No. 15.3; MD: 13568.28 ft; TVD: 5093.70 ft .................................................................................... 68 Test No. 16.0; MD: 13547.98 ft; TVD: 5092.02 ft .................................................................................... 69 Test No. 17.0; MD: 13546.29 ft; TVD: 5091.88 ft .................................................................................... 70 Test No. 18.0; MD: 13674.99 ft; TVD: 5101.46 ft .................................................................................... 71 Test No. 18.1; MD: 13674.99 ft; TVD: 5101.46 ft .................................................................................... 72 Test No. 18.2; MD: 13674.99 ft; TVD: 5101.46 ft .................................................................................... 73 Test No. 18.3; MD: 13674.99 ft; TVD: 5101.46 ft .................................................................................... 74 Test No. 19.0; MD: 13920.00 ft; TVD: 5117.98 ft .................................................................................... 75 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 4 Test No. 19.1; MD: 13920.00 ft; TVD: 5117.98 ft .................................................................................... 76 Test No. 19.2; MD: 13920.00 ft; TVD: 5117.98 ft .................................................................................... 77 Test No. 19.3; MD: 13920.00 ft; TVD: 5117.98 ft .................................................................................... 78 Test No. 20.0; MD: 13935.00 ft; TVD: 5119.18 ft .................................................................................... 79 Test No. 20.1; MD: 13935.00 ft; TVD: 5119.18 ft .................................................................................... 80 Test No. 20.2; MD: 13935.00 ft; TVD: 5119.18 ft .................................................................................... 81 Test No. 20.3; MD: 13935.00 ft; TVD: 5119.18 ft .................................................................................... 82 Test No. 21.0; MD: 14115.00 ft; TVD: 5133.54 ft .................................................................................... 83 Test No. 21.1; MD: 14115.00 ft; TVD: 5133.54 ft .................................................................................... 84 Test No. 21.2; MD: 14115.00 ft; TVD: 5133.54 ft .................................................................................... 85 Test No. 21.3; MD: 14115.00 ft; TVD: 5133.54 ft .................................................................................... 86 Test No. 22.0; MD: 14105.00 ft; TVD: 5132.78 ft .................................................................................... 87 Test No. 22.1; MD: 14105.00 ft; TVD: 5132.78 ft .................................................................................... 88 Test No. 22.2; MD: 14105.00 ft; TVD: 5132.78 ft .................................................................................... 89 Test No. 22.3; MD: 14105.00 ft; TVD: 5132.78 ft .................................................................................... 90 Test No. 23.0; MD: 14490.00 ft; TVD: 5147.50 ft .................................................................................... 91 Test No. 23.1; MD: 14490.00 ft; TVD: 5147.50 ft .................................................................................... 92 Test No. 23.2; MD: 14490.00 ft; TVD: 5147.50 ft .................................................................................... 93 Test No. 23.3; MD: 14490.00 ft; TVD: 5147.50 ft .................................................................................... 94 Test No. 24.0; MD: 14477.99 ft; TVD: 5147.19 ft .................................................................................... 95 Test No. 24.1; MD: 14477.99 ft; TVD: 5147.19 ft .................................................................................... 96 Test No. 24.2; MD: 14477.99 ft; TVD: 5147.19 ft .................................................................................... 97 Test No. 24.3; MD: 14477.99 ft; TVD: 5147.19 ft .................................................................................... 98 Test No. 25.0; MD: 14975.00 ft; TVD: 5157.99 ft .................................................................................... 99 Test No. 25.1; MD: 14975.00 ft; TVD: 5157.99 ft .................................................................................. 100 Test No. 25.2; MD: 14975.00 ft; TVD: 5157.99 ft .................................................................................. 101 Test No. 25.3; MD: 14975.00 ft; TVD: 5157.99 ft .................................................................................. 102 Test No. 26.0; MD: 16325.00 ft; TVD: 5200.79 ft .................................................................................. 103 Test No. 26.1; MD: 16325.00 ft; TVD: 5200.79 ft .................................................................................. 104 Test No. 26.2; MD: 16325.00 ft; TVD: 5200.79 ft .................................................................................. 105 Test No. 26.3; MD: 16325.00 ft; TVD: 5200.79 ft .................................................................................. 106 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 5 Disclaimer .................................................................................................................................................. 107 Drawdown Buildup Analysis ..................................................................................................................... 108 Exact Mobility Analysis .......................................................................................................................... 108 Test Quality Parameters........................................................................................................................ 110 Automatic Test Comments ................................................................................................................... 111 Dual Probe Anisotropy Analysis (Vertical Interference Testing) ........................................................... 112 Anisotropy Dip‐angle Corrections ..................................................................................................... 112 Flow Rate Determination ...................................................................................................................... 113 Automatic Flow Rate Option ............................................................................................................. 113 Manual Flow Rate Option ................................................................................................................. 113 Manual Volume Option ..................................................................................................................... 113 RTS Mobility Drawdown and Buildup Calculation Summary ................................................................ 114 Table 1 PTA Spherical Flow Regime Calculations (Typical Physical Units) ....................................... 114 Table 2 PTA Radial Flow Regime Calculations (Typical Physical Units) ............................................. 114 Table 3 PTA Variables & Constants Using Internal Program (Typical Physical Units) ...................... 115 Table 4 PTA Spherical Flow Regime Calculations (SI Units) .............................................................. 116 Table 5 PTA Radial Flow Regime Calculations (SI Units) ................................................................... 116 Table 6 PTA Variables & Constants Using Internal Program SI Units ................................................ 117 RTS Theory References ......................................................................................................................... 118 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 6 Overview At the request of Pioneer Natural Resources Inc., the GeoTap 4-3/4” tool was run in the ODST-47 well, Oooguruk field, U.S.A. in a 6.75 inch hole for formation pressures and establishes gradients in various formations. Twenty-six pressures were taken. All pressure points were taken while drilling with “pumps on” mode. Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 7 Log Header Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 8 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 9 Test Summary PRESSURE TEST SUMMARYTest Identification Hydrostatic Pres. Eq. Mud Wt.Test Pressures ‐ TemperaturesTest TimesRemarks Test No. File No. MD (ft) TVD (ft) Phyds1 (psia) Phyds2 (psia) EqFmMw (lbs/gal) EqBhMw (lbs/gal) Psdd (psia) Pedd (psia) Pstop (psia) dPob (psia) Temp (degF) dTdd (sec) dTbu (sec) 1.0 800‐1.0 12434.01 5018.74 2810.90 2812.91 0.72 10.78 Dry/Tight Test 1.1 800‐1.1 12434.01 5018.74 2810.90 2812.91 0.71 10.78 3433.63 24.08 185.88 2627.03 111.99 3.20 90.56 Dry/Tight Test 1.2 800‐1.2 12434.01 5018.74 2810.90 2812.91 0.32 10.78 184.28 50.70 84.50 2728.40 112.03 0.80 94.36 Dry/Tight Test 1.3 800‐1.3 12434.01 5018.74 2810.90 2812.91 0.21 10.78 80.33 40.59 53.76 2759.15 111.99 0.80 93.56 Dry/Tight Test 2.0 800‐2.0 12436.00 5018.89 2846.02 2846.40 0.03 10.91 Dry/Tight Test 2.1 800‐2.1 12436.00 5018.89 2846.02 2846.40 0.03 10.91 3683.48 4.76 7.93 2838.47 110.97 21.79 126.35 Dry/Tight Test 2.2 800‐2.2 12436.00 5018.89 2846.02 2846.40 0.02 10.91 7.80 4.18 4.77 2841.63 110.97 19.99 126.95 Dry/Tight Test 2.3 800‐2.3 12436.00 5018.89 2846.02 2846.40 0.01 10.91 4.72 3.44 3.70 2842.70 110.97 19.59 126.95 Dry/Tight Test 3.0 800‐3.0 12584.01 5028.54 2868.27 2862.93 9.79 10.95 Fair Buildup Stability 3.1 800‐3.1 12584.01 5028.54 2868.27 2862.93 9.79 10.95 4127.60 1821.20 2559.30 303.63 113.85 46.39 127.16 Fair Buildup Stability 3.2 800‐3.2 12584.01 5028.54 2868.27 2862.93 9.77 10.95 2557.40 1775.28 2555.31 307.62 113.85 50.58 126.56 Fair Buildup Stability 3.3 800‐3.3 12584.01 5028.54 2868.27 2862.93 9.77 10.95 2552.04 1767.84 2554.23 308.69 113.85 50.79 126.76 Fair Buildup Stability 4.0 800‐4.0 12723.00 5036.01 2908.83 2899.05 8.18 11.07 Low Perm, Still Building 4.1 800‐4.1 12723.00 5036.01 2908.83 2899.05 8.18 11.07 4175.88 457.39 2140.97 758.08 115.29 2.61 126.52 Low Perm, Still Building 4.2 800‐4.2 12723.00 5036.01 2908.83 2899.05 8.60 11.07 2131.96 156.76 2252.76 646.29 115.29 2.01 126.12 Low Perm, Still Building 4.3 800‐4.3 12723.00 5036.01 2908.83 2899.05 10.95 11.07 2250.63 233.45 2866.91 32.14 115.29 2.41 126.12 Low Perm, Still Building 5.0 800‐5.0 12717.97 5035.75 2886.00 2872.95 10.49 10.97 Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 11 PRESSURE TEST SUMMARYTest Identification Hydrostatic Pres. Eq. Mud Wt.Test Pressures ‐ TemperaturesTest TimesRemarks Test No. File No. MD (ft) TVD (ft) Phyds1 (psia) Phyds2 (psia) EqFmMw (lbs/gal) EqBhMw (lbs/gal) Psdd (psia) Pedd (psia) Pstop (psia) dPob (psia) Temp (degF) dTdd (sec) dTbu (sec) 5.1 800‐5.1 12717.97 5035.75 2886.00 2872.95 10.49 10.97 3765.90 729.83 2746.89 126.07 113.63 11.22 126.83 Low Perm, Still Building 5.2 800‐5.2 12717.97 5035.75 2886.00 2872.95 9.90 10.97 2718.97 793.78 2591.92 281.03 113.63 4.21 126.23 Low Perm, Still Building 5.3 800‐5.3 12717.97 5035.75 2886.00 2872.95 9.78 10.97 2591.09 734.89 2559.70 313.25 113.63 4.01 126.23 Low Perm, Still Building 6.0 800‐6.0 12814.98 5040.82 2897.96 2896.35 11.05 11.05 Potential Mud Set 7.0 800‐7.0 12809.01 5040.46 2901.85 2900.93 11.06 11.07 No Seal 8.0 800‐8.0 13041.96 5056.09 2928.86 2914.50 12.45 11.09 Potential Mud Set 9.0 800‐9.0 13043.01 5056.18 2899.78 2893.25 11.00 11.00 No Seal 10.0 800‐10.0 13108.00 5060.88 2922.89 2963.25 10.97 11.26 Aborted Test 11.0 800‐11.0 13103.00 5060.57 2912.92 2884.80 10.99 10.96 Potential Mud Set 11.1 800‐11.1 13103.00 5060.57 2912.92 2884.80 10.99 10.96 2978.84 2865.02 2892.82 ‐8.02 122.40 46.73 127.77 Potential Mud Set 11.2 800‐11.2 13103.00 5060.57 2912.92 2884.80 10.98 10.96 2892.08 2874.96 2889.90 ‐5.10 122.40 50.14 127.97 Potential Mud Set 11.3 800‐11.3 13103.00 5060.57 2912.92 2884.80 10.97 10.96 2883.77 2838.99 2886.73 ‐1.93 122.40 49.54 128.97 Potential Mud Set 12.0 800‐12.0 13099.94 5060.37 2875.55 2869.65 9.90 10.91 Low Perm, Still Building 12.1 800‐12.1 13099.94 5060.37 2875.55 2869.65 9.90 10.91 3861.79 140.20 2605.78 263.87 120.97 2.01 127.30 Low Perm, Still Building 12.2 800‐12.2 13099.94 5060.37 2875.55 2869.65 9.87 10.91 2605.81 548.07 2597.17 272.48 120.97 5.62 123.28 Low Perm, Still Building 12.3 800‐12.3 13099.94 5060.37 2875.55 2869.65 9.86 10.91 2570.18 171.16 2593.24 276.41 120.97 1.81 126.49 Low Perm, Still Building 13.0 800‐13.0 13579.97 5094.63 2875.08 2880.22 8.46 10.87 Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 12 PRESSURE TEST SUMMARYTest Identification Hydrostatic Pres. Eq. Mud Wt.Test Pressures ‐ TemperaturesTest TimesRemarks Test No. File No. MD (ft) TVD (ft) Phyds1 (psia) Phyds2 (psia) EqFmMw (lbs/gal) EqBhMw (lbs/gal) Psdd (psia) Pedd (psia) Pstop (psia) dPob (psia) Temp (degF) dTdd (sec) dTbu (sec) 13.1 800‐13.1 13579.97 5094.63 2875.08 2880.22 8.46 10.87 4170.91 2205.67 2241.38 638.83 125.11 19.63 127.61 Good Buildup Stability 13.2 800‐13.2 13579.97 5094.63 2875.08 2880.22 8.46 10.87 2241.70 2205.78 2241.06 639.15 125.11 20.43 127.61 Good Buildup Stability 13.3 800‐13.3 13579.97 5094.63 2875.08 2880.22 8.46 10.87 2241.47 2204.92 2240.80 639.41 125.11 20.23 127.41 Good Buildup Stability 14.0 800‐14.0 13570.00 5093.84 2871.32 2877.43 8.47 10.86 Excellent Buildup Stability 14.1 800‐14.1 13570.00 5093.84 2871.32 2877.43 8.47 10.86 4075.72 2191.52 2244.39 633.04 124.47 19.83 127.01 Excellent Buildup Stability 14.2 800‐14.2 13570.00 5093.84 2871.32 2877.43 8.47 10.86 2244.46 2190.05 2244.28 633.16 124.47 20.43 127.01 Good Buildup Stability 14.3 800‐14.3 13570.00 5093.84 2871.32 2877.43 8.47 10.86 2244.26 2189.94 2244.21 633.22 124.47 20.43 127.21 Good Buildup Stability 15.0 800‐15.0 13568.28 5093.70 2868.63 2876.27 8.47 10.86 Good Buildup Stability 15.1 800‐15.1 13568.28 5093.70 2868.63 2876.27 8.47 10.86 4357.53 2131.18 2244.39 631.88 123.98 10.07 95.29 Good Buildup Stability 15.2 800‐15.2 13568.28 5093.70 2868.63 2876.27 8.47 10.86 2244.41 2128.87 2244.26 632.01 123.98 10.27 95.89 Good Buildup Stability 15.3 800‐15.3 13568.28 5093.70 2868.63 2876.27 8.47 10.86 2244.41 2125.91 2244.18 632.09 123.98 10.48 95.49 Good Buildup Stability 16.0 800‐16.0 13547.98 5092.02 2866.86 2873.90 3.21 10.85 Dry/Tight Test 17.0 800‐17.0 13546.29 5091.88 2868.47 2872.44 8.50 10.85 Dry/Tight Test 18.0 800‐18.0 13674.99 5101.46 2890.45 2895.21 8.52 10.91 Fair Buildup Stability 18.1 800‐18.1 13674.99 5101.46 2890.45 2895.21 8.52 10.91 3327.71 2215.28 2259.94 635.27 128.34 19.83 126.80 Good Buildup Stability 18.2 800‐18.2 13674.99 5101.46 2890.45 2895.21 8.52 10.91 2260.19 2213.14 2259.44 635.77 128.34 20.03 127.00 Good Buildup Stability 18.3 800‐18.3 13674.99 5101.46 2890.45 2895.21 8.52 10.91 2259.46 2212.06 2259.00 636.21 128.34 20.23 126.80 Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 13 PRESSURE TEST SUMMARYTest Identification Hydrostatic Pres. Eq. Mud Wt.Test Pressures ‐ TemperaturesTest TimesRemarks Test No. File No. MD (ft) TVD (ft) Phyds1 (psia) Phyds2 (psia) EqFmMw (lbs/gal) EqBhMw (lbs/gal) Psdd (psia) Pedd (psia) Pstop (psia) dPob (psia) Temp (degF) dTdd (sec) dTbu (sec) 19.0 800‐19.0 13920.00 5117.98 2928.54 2937.02 10.56 11.04 Fair Buildup Stability 19.1 800‐19.1 13920.00 5117.98 2928.54 2937.02 10.56 11.04 3802.14 355.75 2810.79 126.23 130.62 2.81 127.14 Fair Buildup Stability 19.2 800‐19.2 13920.00 5117.98 2928.54 2937.02 10.55 11.04 2810.58 420.59 2808.64 128.38 130.62 2.41 127.34 Fair Buildup Stability 19.3 800‐19.3 13920.00 5117.98 2928.54 2937.02 10.55 11.04 2808.68 470.95 2808.56 128.46 130.62 2.01 127.14 Fair Buildup Stability 20.0 800‐20.0 13935.00 5119.18 2929.95 2936.33 10.54 11.03 Fair Buildup Stability 20.1 800‐20.1 13935.00 5119.18 2929.95 2936.33 10.54 11.03 3633.08 40.95 2806.58 129.75 129.24 3.82 126.34 Fair Buildup Stability 20.2 800‐20.2 13935.00 5119.18 2929.95 2936.33 10.54 11.03 2806.85 54.50 2806.02 130.31 129.24 1.61 127.14 Fair Buildup Stability 20.3 800‐20.3 13935.00 5119.18 2929.95 2936.33 10.53 11.03 2663.92 212.08 2804.37 131.95 129.24 1.41 126.94 Fair Buildup Stability 21.0 800‐21.0 14115.00 5133.54 2959.47 2962.18 9.99 11.10 Low Perm, Still Building 21.1 800‐21.1 14115.00 5133.54 2959.47 2962.18 9.99 11.10 3839.12 211.00 2666.48 295.70 130.91 2.21 127.14 Low Perm, Still Building 21.2 800‐21.2 14115.00 5133.54 2959.47 2962.18 2.41 11.10 2662.86 19.66 644.24 2317.94 131.11 2.01 127.14 Low Perm, Still Building 21.3 800‐21.3 14115.00 5133.54 2959.47 2962.18 1.90 11.10 647.19 117.88 507.97 2454.21 130.91 1.21 126.74 Low Perm, Still Building 22.0 800‐22.0 14105.00 5132.78 2941.06 2962.62 8.84 11.10 Fair Buildup Stability 22.1 800‐22.1 14105.00 5132.78 2941.06 2962.62 8.84 11.10 3911.23 1406.39 2358.92 603.70 129.13 10.04 159.47 Good Buildup Stability 22.2 800‐22.2 14105.00 5132.78 2941.06 2962.62 8.84 11.10 2358.44 1424.09 2358.12 604.49 129.13 10.04 159.46 Fair Buildup Stability 22.3 800‐22.3 14105.00 5132.78 2941.06 2962.62 8.82 11.10 2358.22 1394.01 2352.86 609.76 129.13 10.64 27.92 Fair Buildup Stability 23.0 800‐23.0 14490.00 5147.50 2952.48 2951.44 9.61 11.03 Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 14 PRESSURE TEST SUMMARYTest Identification Hydrostatic Pres. Eq. Mud Wt.Test Pressures ‐ TemperaturesTest TimesRemarks Test No. File No. MD (ft) TVD (ft) Phyds1 (psia) Phyds2 (psia) EqFmMw (lbs/gal) EqBhMw (lbs/gal) Psdd (psia) Pedd (psia) Pstop (psia) dPob (psia) Temp (degF) dTdd (sec) dTbu (sec) 23.1 800‐23.1 14490.00 5147.50 2952.48 2951.44 9.61 11.03 3192.27 2148.61 2573.54 377.90 135.16 19.86 127.22 Fair Buildup Stability 23.2 800‐23.2 14490.00 5147.50 2952.48 2951.44 9.61 11.03 2574.02 2150.82 2572.46 378.98 135.16 20.47 127.21 Fair Buildup Stability 23.3 800‐23.3 14490.00 5147.50 2952.48 2951.44 9.61 11.03 2559.20 2151.06 2571.66 379.78 135.16 20.07 127.21 Fair Buildup Stability 24.0 800‐24.0 14477.99 5147.19 2927.50 2935.77 9.40 10.97 Fair Buildup Stability 24.1 800‐24.1 14477.99 5147.19 2927.50 2935.77 9.40 10.97 3911.82 1621.90 2516.08 419.69 133.23 20.07 127.21 Fair Buildup Stability 24.2 800‐24.2 14477.99 5147.19 2927.50 2935.77 9.40 10.97 2516.14 1587.32 2514.99 420.78 133.23 20.47 127.41 Fair Buildup Stability 24.3 800‐24.3 14477.99 5147.19 2927.50 2935.77 9.39 10.97 2478.51 1554.82 2514.51 421.26 133.23 20.47 127.21 Fair Buildup Stability 25.0 800‐25.0 14975.00 5157.99 2962.88 2980.89 8.78 11.11 Good Buildup Stability 25.1 800‐25.1 14975.00 5157.99 2962.88 2980.89 8.78 11.11 3983.67 2275.86 2355.90 624.99 138.70 19.67 127.65 Good Buildup Stability 25.2 800‐25.2 14975.00 5157.99 2962.88 2980.89 8.78 11.11 2356.16 2276.71 2355.51 625.38 138.70 20.67 127.25 Good Buildup Stability 25.3 800‐25.3 14975.00 5157.99 2962.88 2980.89 8.78 11.11 2355.51 2275.44 2355.17 625.72 138.70 20.67 127.25 Good Buildup Stability 26.0 800‐26.0 16325.00 5200.79 3009.18 3024.88 10.12 11.18 Fair Buildup Stability 26.1 800‐26.1 16325.00 5200.79 3009.18 3024.88 10.12 11.18 3479.44 85.37 2736.15 288.73 141.44 3.21 127.11 Fair Buildup Stability 26.2 800‐26.2 16325.00 5200.79 3009.18 3024.88 10.10 11.18 2735.51 185.68 2731.47 293.41 141.44 1.61 127.10 Fair Buildup Stability 26.3 800‐26.3 16325.00 5200.79 3009.18 3024.88 10.09 11.18 2731.27 222.94 2728.31 296.57 141.44 1.81 126.90 Fair Buildup Stability Legend: Phyds1: Initial Hydrostatic Pressure Phyds2: Final Hydrostatic Pressure EqFmMw:Equivalent Formation Mud Weight (Pstop / (TVD * Constant)) Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 15 PRESSURE TEST SUMMARYTest Identification Hydrostatic Pres. Eq. Mud Wt.Test Pressures ‐ TemperaturesTest TimesRemarks Test No. File No. MD (ft) TVD (ft) Phyds1 (psia) Phyds2 (psia) EqFmMw (lbs/gal) EqBhMw (lbs/gal) Psdd (psia) Pedd (psia) Pstop (psia) dPob (psia) Temp (degF) dTdd (sec) dTbu (sec) EqBhMw: Equivalent Borehole Mud Weight (Phyds2 / (TVD * Constant)) Psdd: Initial Drawdown Pressure Pedd: Final Drawdown or End Drawdown Pressure Pstop: Final Buildup Pressure Temp: Final Temperature dTdd= Tedd‐Tsdd: Tedd ‐ End of Drawdown Time; Tsdd ‐ Initial Drawdown Time dTbu=Tstop ‐ Tedd:Buildup Time, Tedd ‐ End of Drawdown Time, Tstop ‐ Final Buildup Time dPob= Phyds2 ‐ Pstop: Over Balance Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 16 PRESSURE TRANSIENT SUMMARY Test Identification Buildup StabilityPTA PressurePTA MobilitiesRemarks Test No. File No. MD (ft) TVD (ft) Pumps (on/off) Exposure (psia) ToolFace (psia) Stability (psia/min) Stability (degF/min) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) 1.0 800‐1.0 12434.01 5018.74 ‐999.25 Dry/Tight Test 1.1 800‐1.1 12434.01 5018.74 On 258.10 46.01 62.252 ‐17.431 199.14 9.35 2.87 35.6 Dry/Tight Test 1.2 800‐1.2 12434.01 5018.74 On 258.10 46.01 12.866 ‐17.430 87.68 2.18 3.21 170 Dry/Tight Test 1.3 800‐1.3 12434.01 5018.74 On 258.10 46.01 6.671 ‐0.011 57.54 0.75 4.33 437 Dry/Tight Test 2.0 800‐2.0 12436.00 5018.89 ‐999.25 Dry/Tight Test 2.1 800‐2.1 12436.00 5018.89 On 312.20 37.23 0.686 ‐0.011 8.06 0.19 369 909 Dry/Tight Test 2.2 800‐2.2 12436.00 5018.89 On 312.20 37.23 0.201 ‐0.001 4.82 0.08 >984 * >2880 * Dry/Tight Test 2.3 800‐2.3 12436.00 5018.89 On 312.20 37.23 0.086 0.000 3.80 0.01 >533 * >2880 * Dry/Tight Test 3.0 800‐3.0 12584.01 5028.54 ‐999.25 Fair Buildup Stability 3.1 800‐3.1 12584.01 5028.54 On 313.25 43.08 4.888 ‐0.023 2559.30 11.63 0.780 0.780 Fair Buildup Stability 3.2 800‐3.2 12584.01 5028.54 On 313.25 43.08 7.480 ‐0.019 2555.31 15.71 0.738 0.739 Fair Buildup Stability 3.3 800‐3.3 12584.01 5028.54 On 313.25 43.08 8.322 ‐0.019 2554.23 16.31 0.733 0.733 Fair Buildup Stability 4.0 800‐4.0 12723.00 5036.01 ‐999.25 Low Perm, Still Building 4.1 800‐4.1 12723.00 5036.01 On 246.88 34.30 396.561 66.138 2612.18 21.76 0.041 1.71 Low Perm, Still Building 4.2 800‐4.2 12723.00 5036.01 On 246.88 34.30 545.141 66.129 4562.30 87.69 0.007 1.37 Low Perm, Still Building 4.3 800‐4.3 12723.00 5036.01 On 246.88 34.30 104.723 66.114 3824.78 303.38 0.020 1.09 Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 17 PRESSURE TRANSIENT SUMMARY Test Identification Buildup StabilityPTA PressurePTA MobilitiesRemarks Test No. File No. MD (ft) TVD (ft) Pumps (on/off) Exposure (psia) ToolFace (psia) Stability (psia/min) Stability (degF/min) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) 5.0 800‐5.0 12717.97 5035.75 ‐999.25 Low Perm, Still Building 5.1 800‐5.1 12717.97 5035.75 On 275.25 37.23 183.461 66.034 2781.34 42.97 0.085 0.286 Low Perm, Still Building 5.2 800‐5.2 12717.97 5035.75 On 275.25 37.23 264.466 66.036 2678.20 46.41 0.030 0.320 Low Perm, Still Building 5.3 800‐5.3 12717.97 5035.75 On 275.25 37.23 290.833 66.029 2669.30 49.06 0.026 0.316 Low Perm, Still Building 6.0 800‐6.0 12814.98 5040.82 ‐999.25 Potential Mud Set 7.0 800‐7.0 12809.01 5040.46 ‐999.25 No Seal 8.0 800‐8.0 13041.96 5056.09 ‐999.25 Potential Mud Set 9.0 800‐9.0 13043.01 5056.18 ‐999.25 No Seal 10.0 800‐10.0 13108.00 5060.88 ‐999.25 Aborted Test 11.0 800‐11.0 13103.00 5060.57 ‐999.25 Potential Mud Set 11.1 800‐11.1 13103.00 5060.57 On 521.66 ‐0.82 ‐0.889 71.323 2892.82 1.44 20.7 20.7 Potential Mud Set 11.2 800‐11.2 13103.00 5060.57 On 521.66 ‐0.82 ‐1.723 71.309 2892.19 4.72 18.3 38.5 Potential Mud Set 11.3 800‐11.3 13103.00 5060.57 On 521.66 ‐0.82 ‐0.440 71.297 2886.73 1.79 12.1 12.1 Potential Mud Set 12.0 800‐12.0 13099.94 5060.37 ‐999.25 Low Perm, Still Building 12.1 800‐12.1 13099.94 5060.37 On 551.09 ‐3.75 88.826 71.217 2640.08 100.56 0.075 1.17 Low Perm, Still Building 12.2 800‐12.2 13099.94 5060.37 On 551.09 ‐3.75 8.995 71.214 2597.17 9.20 1.41 1.41 Low Perm, Still Building 12.3 800‐12.3 13099.94 5060.37 On 551.09 ‐3.75 1.143 71.212 2593.24 2.45 0.896 1.19 Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 18 PRESSURE TRANSIENT SUMMARY Test Identification Buildup StabilityPTA PressurePTA MobilitiesRemarks Test No. File No. MD (ft) TVD (ft) Pumps (on/off) Exposure (psia) ToolFace (psia) Stability (psia/min) Stability (degF/min) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) 13.0 800‐13.0 13579.97 5094.63 ‐999.25 Good Buildup Stability 13.1 800‐13.1 13579.97 5094.63 On 379.62 ‐6.68 ‐0.201 66.721 2241.38 0.27 80.7 80.7 Good Buildup Stability 13.2 800‐13.2 13579.97 5094.63 On 379.62 ‐6.68 ‐0.054 71.485 2241.06 0.27 81.6 81.6 Good Buildup Stability 13.3 800‐13.3 13579.97 5094.63 On 379.62 ‐6.68 ‐0.068 71.476 2240.80 0.26 80.3 80.3 Good Buildup Stability 14.0 800‐14.0 13570.00 5093.84 ‐999.25 Excellent Buildup Stability 14.1 800‐14.1 13570.00 5093.84 On 408.88 ‐6.68 0.007 71.432 2244.39 0.10 54.5 54.5 Excellent Buildup Stability 14.2 800‐14.2 13570.00 5093.84 On 408.88 ‐6.68 0.006 71.443 2244.28 0.11 53.1 53.1 Good Buildup Stability 14.3 800‐14.3 13570.00 5093.84 On 408.88 ‐6.68 0.068 71.442 2244.21 0.13 53.1 53.1 Good Buildup Stability 15.0 800‐15.0 13568.28 5093.70 ‐999.25 Good Buildup Stability 15.1 800‐15.1 13568.28 5093.70 On 427.96 ‐6.68 0.089 49.452 2244.39 0.15 25.4 25.4 Good Buildup Stability 15.2 800‐15.2 13568.28 5093.70 On 427.96 ‐6.68 0.123 54.276 2244.27 0.17 25.0 25.0 Good Buildup Stability 15.3 800‐15.3 13568.28 5093.70 On 427.96 ‐6.68 0.081 49.452 2244.18 0.17 24.4 24.4 Good Buildup Stability 16.0 800‐16.0 13547.98 5092.02 ‐999.25 Dry/Tight Test 17.0 800‐17.0 13546.29 5091.88 ‐999.25 Dry/Tight Test 18.0 800‐18.0 13674.99 5101.46 ‐999.25 Fair Buildup Stability 18.1 800‐18.1 13674.99 5101.46 On 408.33 7.96 ‐0.136 71.699 2259.94 0.26 64.5 64.5 Good Buildup Stability 18.2 800‐18.2 13674.99 5101.46 On 408.33 7.96 0.023 71.684 2259.43 0.28 62.2 62.2 Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 19 PRESSURE TRANSIENT SUMMARY Test Identification Buildup StabilityPTA PressurePTA MobilitiesRemarks Test No. File No. MD (ft) TVD (ft) Pumps (on/off) Exposure (psia) ToolFace (psia) Stability (psia/min) Stability (degF/min) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) 18.3 800‐18.3 13674.99 5101.46 On 408.33 7.96 0.061 71.666 2259.00 0.28 61.4 61.4 Good Buildup Stability 19.0 800‐19.0 13920.00 5117.98 ‐999.25 Fair Buildup Stability 19.1 800‐19.1 13920.00 5117.98 On 194.49 13.81 1.863 71.838 2810.79 4.23 0.955 1.17 Fair Buildup Stability 19.2 800‐19.2 13920.00 5117.98 On 194.49 13.81 3.202 71.830 2808.64 8.78 0.876 1.21 Fair Buildup Stability 19.3 800‐19.3 13920.00 5117.98 On 194.49 13.81 3.216 71.819 2808.56 8.68 0.797 1.23 Fair Buildup Stability 20.0 800‐20.0 13935.00 5119.18 ‐999.25 Fair Buildup Stability 20.1 800‐20.1 13935.00 5119.18 On 206.91 7.96 0.871 71.748 2806.58 6.35 0.531 1.04 Fair Buildup Stability 20.2 800‐20.2 13935.00 5119.18 On 206.91 7.96 0.977 71.742 2806.02 4.63 0.301 1.05 Fair Buildup Stability 20.3 800‐20.3 13935.00 5119.18 On 206.91 7.96 0.860 71.741 2804.37 2.74 0.527 1.11 Fair Buildup Stability 21.0 800‐21.0 14115.00 5133.54 ‐999.25 Low Perm, Still Building 21.1 800‐21.1 14115.00 5133.54 On 184.17 19.67 303.595 71.859 2981.94 54.78 0.039 1.17 Low Perm, Still Building 21.2 800‐21.2 14115.00 5133.54 On 184.17 19.67 212.203 ‐0.016 761.29 35.43 0.112 4.61 Low Perm, Still Building 21.3 800‐21.3 14115.00 5133.54 On 184.17 19.67 165.527 ‐0.014 687.39 20.27 0.055 7.38 Low Perm, Still Building 22.0 800‐22.0 14105.00 5132.78 ‐999.25 Fair Buildup Stability 22.1 800‐22.1 14105.00 5132.78 On 227.38 22.59 0.058 71.737 2358.92 0.78 6.05 6.05 Good Buildup Stability 22.2 800‐22.2 14105.00 5132.78 On 227.38 22.59 2.456 71.739 2358.12 1.22 6.17 6.17 Fair Buildup Stability 22.3 800‐22.3 14105.00 5132.78 On 227.38 22.59 19.504 193.475 2352.86 7.27 6.01 6.01 Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 20 PRESSURE TRANSIENT SUMMARY Test Identification Buildup StabilityPTA PressurePTA MobilitiesRemarks Test No. File No. MD (ft) TVD (ft) Pumps (on/off) Exposure (psia) ToolFace (psia) Stability (psia/min) Stability (degF/min) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) 23.0 800‐23.0 14490.00 5147.50 ‐999.25 Fair Buildup Stability 23.1 800‐23.1 14490.00 5147.50 On 230.53 22.59 0.829 72.135 2573.54 2.15 6.78 6.78 Fair Buildup Stability 23.2 800‐23.2 14490.00 5147.50 On 230.53 22.59 1.129 72.120 2572.46 2.61 6.83 6.83 Fair Buildup Stability 23.3 800‐23.3 14490.00 5147.50 On 230.53 22.59 1.159 72.102 2571.66 2.69 6.85 6.85 Fair Buildup Stability 24.0 800‐24.0 14477.99 5147.19 ‐999.25 Fair Buildup Stability 24.1 800‐24.1 14477.99 5147.19 On 259.06 5.03 1.521 72.002 2516.08 2.90 3.22 3.22 Fair Buildup Stability 24.2 800‐24.2 14477.99 5147.19 On 259.06 5.03 2.062 71.997 2514.99 3.67 3.10 3.10 Fair Buildup Stability 24.3 800‐24.3 14477.99 5147.19 On 259.06 5.03 2.134 71.990 2514.51 3.87 3.00 3.00 Fair Buildup Stability 25.0 800‐25.0 14975.00 5157.99 ‐999.25 Good Buildup Stability 25.1 800‐25.1 14975.00 5157.99 On 194.82 5.03 ‐0.131 72.361 2355.90 0.21 36.0 36.0 Good Buildup Stability 25.2 800‐25.2 14975.00 5157.99 On 194.82 5.03 ‐0.155 72.341 2355.51 0.18 36.6 36.6 Good Buildup Stability 25.3 800‐25.3 14975.00 5157.99 On 194.82 5.03 ‐0.076 72.322 2355.17 0.18 36.1 36.1 Good Buildup Stability 26.0 800‐26.0 16325.00 5200.79 ‐999.25 Fair Buildup Stability 26.1 800‐26.1 16325.00 5200.79 On 207.78 72.35 ‐0.761 72.528 2736.15 4.92 0.656 1.09 Fair Buildup Stability 26.2 800‐26.2 16325.00 5200.79 On 207.78 72.35 0.271 72.514 2731.47 7.08 0.422 1.13 Fair Buildup Stability 26.3 800‐26.3 16325.00 5200.79 On 207.78 72.35 0.260 72.500 2728.31 7.22 0.474 1.15 Fair Buildup Stability Legend: Pexact: Projected formation pressure based on exact model. Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 21 PRESSURE TRANSIENT SUMMARY Test Identification Buildup StabilityPTA PressurePTA MobilitiesRemarks Test No. File No. MD (ft) TVD (ft) Pumps (on/off) Exposure (psia) ToolFace (psia) Stability (psia/min) Stability (degF/min) Pexact (psia) Pstdev (psia) Mexact (md/cp) Msdd (md/cp) Pstdev: Standard deviation of actual pressures from exact model Mexact: Spherical Mobility based on exact model Msdd: Spherical Drawdown Mobility *: *High mobility, dPdd<1.00 psia Gradients Gradient 1 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 23 Gradient Group Gradient (psia/ft) Equivalent Fluid Density lbs/gal g/cc Disclaimer: All equivalent fluid densities are calculated from TVD pressure gradients Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 24 Plots Test No. 1.0; MD: 12434.01 ft; TVD: 5018.74 ft GeoTap Pretest File # 800‐1.0 Date: 21‐Sep‐12 01:25:13 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 12434.01 2810.90 2812.91 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 2.00 1.00 0.22 0.15 7.62e‐006 35.00 REMARKS Dry/Tight Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 25 Test No. 1.1; MD: 12434.01 ft; TVD: 5018.74 ft GeoTap Pretest File # 800‐1.1 Date: 21‐Sep‐12 01:25:13 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12434.01 5018.74 24.08 185.88 199.14 2.87 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 3.20 1.00 0.22 0.15 7.62e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 9.35 62.25 ‐17.43 On 258.10 46.01 REMARKS Dry/Tight Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 26 Test No. 1.2; MD: 12434.01 ft; TVD: 5018.74 ft GeoTap Pretest File # 800‐1.2 Date: 21‐Sep‐12 01:25:13 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12434.01 5018.74 50.70 84.50 87.68 3.21 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.80 1.00 0.22 0.15 6.42e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.18 12.87 ‐17.43 On 258.10 46.01 REMARKS Dry/Tight Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 27 Test No. 1.3; MD: 12434.01 ft; TVD: 5018.74 ft GeoTap Pretest File # 800‐1.3 Date: 21‐Sep‐12 01:25:13 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12434.01 5018.74 40.59 53.76 57.54 4.33 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.80 1.00 0.22 0.15 2.18e‐004 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.75 6.67 ‐0.01 On 258.10 46.01 REMARKS Dry/Tight Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 28 Test No. 2.0; MD: 12436.00 ft; TVD: 5018.89 ft GeoTap Pretest File # 800‐2.0 Date: 21‐Sep‐12 02:21:01 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 12436.00 2846.02 2846.40 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.00 0.50 0.22 0.15 3.74e‐006 35.00 REMARKS Dry/Tight Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 29 Test No. 2.1; MD: 12436.00 ft; TVD: 5018.89 ft GeoTap Pretest File # 800‐2.1 Date: 21‐Sep‐12 02:21:01 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12436.00 5018.89 4.76 7.93 8.06 369 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.90 0.50 0.22 0.15 3.74e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.19 0.69 ‐0.01 On 312.20 37.23 REMARKS Dry/Tight Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 30 Test No. 2.2; MD: 12436.00 ft; TVD: 5018.89 ft GeoTap Pretest File # 800‐2.2 Date: 21‐Sep‐12 02:21:01 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12436.00 5018.89 4.18 4.77 4.82 > 984 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.00 0.50 0.22 0.15 1.74e‐002 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.08 0.20 ‐0.00 On 312.20 37.23 REMARKS Dry/Tight Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 31 Test No. 2.3; MD: 12436.00 ft; TVD: 5018.89 ft GeoTap Pretest File # 800‐2.3 Date: 21‐Sep‐12 02:21:01 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12436.00 5018.89 3.44 3.70 3.80 > 533 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.80 0.50 0.22 0.15 7.51e‐002 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.01 0.09 0.00 On 312.20 37.23 REMARKS Dry/Tight Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 32 Test No. 3.0; MD: 12584.01 ft; TVD: 5028.54 ft GeoTap Pretest File # 800‐3.0 Date: 21‐Sep‐12 08:25:09 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 12584.01 2868.27 2862.93 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.60 0.10 0.22 0.15 3.50e‐006 35.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 33 Test No. 3.1; MD: 12584.01 ft; TVD: 5028.54 ft GeoTap Pretest File # 800‐3.1 Date: 21‐Sep‐12 08:25:09 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12584.01 5028.54 1821.20 2559.30 2559.30 0.780 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.64 0.10 0.22 0.15 6.03e‐007 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 11.63 4.89 ‐0.02 On 313.25 43.08 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 34 Test No. 3.2; MD: 12584.01 ft; TVD: 5028.54 ft GeoTap Pretest File # 800‐3.2 Date: 21‐Sep‐12 08:25:09 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12584.01 5028.54 1775.28 2555.31 2555.31 0.738 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 5.06 0.10 0.22 0.15 3.23e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 15.71 7.48 ‐0.02 On 313.25 43.08 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 35 Test No. 3.3; MD: 12584.01 ft; TVD: 5028.54 ft GeoTap Pretest File # 800‐3.3 Date: 21‐Sep‐12 08:25:09 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12584.01 5028.54 1767.85 2554.23 2554.23 0.733 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 5.08 0.10 0.22 0.15 5.84e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 16.31 8.32 ‐0.02 On 313.25 43.08 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 36 Test No. 4.0; MD: 12723.00 ft; TVD: 5036.01 ft GeoTap Pretest File # 800‐4.0 Date: 21‐Sep‐12 11:29:27 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 12723.00 2908.83 2899.05 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.51 0.50 0.22 0.15 3.62e‐006 35.00 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 37 Test No. 4.1; MD: 12723.00 ft; TVD: 5036.01 ft GeoTap Pretest File # 800‐4.1 Date: 21‐Sep‐12 11:29:27 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12723.00 5036.01 457.39 2140.97 2612.18 0.041 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.31 0.50 0.22 0.15 3.62e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 21.76 396.56 66.14 On 246.88 34.30 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 38 Test No. 4.2; MD: 12723.00 ft; TVD: 5036.01 ft GeoTap Pretest File # 800‐4.2 Date: 21‐Sep‐12 11:29:27 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12723.00 5036.01 156.76 2252.76 4562.30 0.007 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.00 0.50 0.22 0.15 4.75e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 87.69 545.14 66.13 On 246.88 34.30 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 39 Test No. 4.3; MD: 12723.00 ft; TVD: 5036.01 ft GeoTap Pretest File # 800‐4.3 Date: 21‐Sep‐12 11:29:27 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12723.00 5036.01 233.45 2866.91 3824.78 0.020 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.20 0.50 0.22 0.15 4.76e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 303.38 104.72 66.11 On 246.88 34.30 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 40 Test No. 5.0; MD: 12717.97 ft; TVD: 5035.75 ft GeoTap Pretest File # 800‐5.0 Date: 21‐Sep‐12 11:51:49 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 12717.97 2886.00 2872.95 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.10 0.10 0.22 0.15 1.23e‐006 35.00 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 41 Test No. 5.1; MD: 12717.97 ft; TVD: 5035.75 ft GeoTap Pretest File # 800‐5.1 Date: 21‐Sep‐12 11:51:49 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12717.97 5035.75 729.83 2746.88 2781.34 0.085 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.12 0.10 0.22 0.15 1.23e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 42.97 183.46 66.03 On 275.25 37.23 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 42 Test No. 5.2; MD: 12717.97 ft; TVD: 5035.75 ft GeoTap Pretest File # 800‐5.2 Date: 21‐Sep‐12 11:51:49 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12717.97 5035.75 793.78 2591.92 2678.20 0.030 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.42 0.10 0.22 0.15 1.44e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 46.41 264.47 66.04 On 275.25 37.23 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 43 Test No. 5.3; MD: 12717.97 ft; TVD: 5035.75 ft GeoTap Pretest File # 800‐5.3 Date: 21‐Sep‐12 11:51:49 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 12717.97 5035.75 734.89 2559.70 2669.30 0.026 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.40 0.10 0.22 0.15 2.14e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 49.06 290.83 66.03 On 275.25 37.23 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 44 Test No. 6.0; MD: 12814.98 ft; TVD: 5040.82 ft GeoTap Pretest File # 800‐6.0 Date: 21‐Sep‐12 20:01:13 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 12814.98 2897.96 2896.35 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.70 0.10 0.22 0.15 2.29e‐005 35.00 REMARKS Potential Mud Set Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 45 Test No. 7.0; MD: 12809.01 ft; TVD: 5040.46 ft GeoTap Pretest File # 800‐7.0 Date: 21‐Sep‐12 20:38:20 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 12809.01 2901.85 2900.92 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.51 0.10 0.22 0.15 1.55e‐005 35.00 REMARKS No Seal Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 46 Test No. 8.0; MD: 13041.96 ft; TVD: 5056.09 ft GeoTap Pretest File # 800‐8.0 Date: 22‐Sep‐12 02:34:15 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13041.96 2928.86 2914.50 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 5.00 0.10 0.22 0.15 2.63e‐004 35.00 REMARKS Potential Mud Set Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 47 Test No. 9.0; MD: 13043.01 ft; TVD: 5056.18 ft GeoTap Pretest File # 800‐9.0 Date: 22‐Sep‐12 03:23:14 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13043.01 2899.78 2893.25 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.71 0.10 0.22 0.15 1.39e‐006 35.00 REMARKS No Seal Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 48 Test No. 10.0; MD: 13108.00 ft; TVD: 5060.88 ft GeoTap Pretest File # 800‐10.0 Date: 22‐Sep‐12 07:33:18 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13108.00 2922.89 2963.25 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.63 0.10 0.22 0.15 6.78e‐005 35.00 REMARKS Aborted Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 49 Test No. 11.0; MD: 13103.00 ft; TVD: 5060.57 ft GeoTap Pretest File # 800‐11.0 Date: 22‐Sep‐12 07:55:19 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13103.00 2912.92 2884.80 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.71 0.10 0.22 0.15 5.17e‐006 35.00 REMARKS Potential Mud Set Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 50 Test No. 11.1; MD: 13103.00 ft; TVD: 5060.57 ft GeoTap Pretest File # 800‐11.1 Date: 22‐Sep‐12 07:55:19 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13103.00 5060.57 2865.02 2892.82 2892.82 20.7 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.67 0.10 0.22 0.15 5.17e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.44 ‐0.89 71.32 On 521.66 ‐0.82 REMARKS Potential Mud Set Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 51 Test No. 11.2; MD: 13103.00 ft; TVD: 5060.57 ft GeoTap Pretest File # 800‐11.2 Date: 22‐Sep‐12 07:55:19 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13103.00 5060.57 2874.95 2889.90 2892.19 18.3 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 5.01 0.10 0.22 0.15 1.85e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 4.72 ‐1.72 71.31 On 521.66 ‐0.82 REMARKS Potential Mud Set Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 52 Test No. 11.3; MD: 13103.00 ft; TVD: 5060.57 ft GeoTap Pretest File # 800‐11.3 Date: 22‐Sep‐12 07:55:19 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13103.00 5060.57 2838.98 2886.73 2886.73 12.1 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.95 0.10 0.22 0.15 1.14e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.79 ‐0.44 71.30 On 521.66 ‐0.82 REMARKS Potential Mud Set Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 53 Test No. 12.0; MD: 13099.94 ft; TVD: 5060.37 ft GeoTap Pretest File # 800‐12.0 Date: 22‐Sep‐12 08:21:55 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13099.94 2875.55 2869.65 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.00 0.50 0.22 0.15 2.37e‐006 35.00 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 54 Test No. 12.1; MD: 13099.94 ft; TVD: 5060.37 ft GeoTap Pretest File # 800‐12.1 Date: 22‐Sep‐12 08:21:55 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13099.94 5060.37 140.20 2605.78 2640.08 0.075 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.00 0.50 0.22 0.15 2.37e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 100.56 88.83 71.22 On 551.09 ‐3.75 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 55 Test No. 12.2; MD: 13099.94 ft; TVD: 5060.37 ft GeoTap Pretest File # 800‐12.2 Date: 22‐Sep‐12 08:21:55 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13099.94 5060.37 548.07 2597.17 2597.17 1.41 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 2.81 0.50 0.22 0.15 5.92e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 9.20 8.99 71.21 On 551.09 ‐3.75 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 56 Test No. 12.3; MD: 13099.94 ft; TVD: 5060.37 ft GeoTap Pretest File # 800‐12.3 Date: 22‐Sep‐12 08:21:55 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13099.94 5060.37 171.16 2593.24 2593.24 0.896 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.90 0.50 0.22 0.15 2.34e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.45 1.14 71.21 On 551.09 ‐3.75 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 57 Test No. 13.0; MD: 13579.97 ft; TVD: 5094.63 ft GeoTap Pretest File # 800‐13.0 Date: 23‐Sep‐12 06:34:56 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13579.97 2875.08 2880.22 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.02 0.50 0.22 0.15 4.46e‐006 35.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 58 Test No. 13.1; MD: 13579.97 ft; TVD: 5094.63 ft GeoTap Pretest File # 800‐13.1 Date: 23‐Sep‐12 06:34:56 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13579.97 5094.63 2205.67 2241.38 2241.38 80.7 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.82 0.50 0.22 0.15 4.46e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.27 ‐0.20 66.72 On 379.62 ‐6.68 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 59 Test No. 13.2; MD: 13579.97 ft; TVD: 5094.63 ft GeoTap Pretest File # 800‐13.2 Date: 23‐Sep‐12 06:34:56 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13579.97 5094.63 2205.78 2241.06 2241.06 81.6 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.22 0.50 0.22 0.15 9.25e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.27 ‐0.05 71.49 On 379.62 ‐6.68 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 60 Test No. 13.3; MD: 13579.97 ft; TVD: 5094.63 ft GeoTap Pretest File # 800‐13.3 Date: 23‐Sep‐12 06:34:56 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13579.97 5094.63 2204.92 2240.80 2240.80 80.3 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.12 0.50 0.22 0.15 1.39e‐004 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.26 ‐0.07 71.48 On 379.62 ‐6.68 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 61 Test No. 14.0; MD: 13570.00 ft; TVD: 5093.84 ft GeoTap Pretest File # 800‐14.0 Date: 23‐Sep‐12 06:57:00 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13570.00 2871.32 2877.43 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.02 0.50 0.22 0.15 4.64e‐006 35.00 REMARKS Excellent Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 62 Test No. 14.1; MD: 13570.00 ft; TVD: 5093.84 ft GeoTap Pretest File # 800‐14.1 Date: 23‐Sep‐12 06:57:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13570.00 5093.84 2191.52 2244.39 2244.39 54.5 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.92 0.50 0.22 0.15 4.64e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.10 0.01 71.43 On 408.88 ‐6.68 REMARKS Excellent Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 63 Test No. 14.2; MD: 13570.00 ft; TVD: 5093.84 ft GeoTap Pretest File # 800‐14.2 Date: 23‐Sep‐12 06:57:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13570.00 5093.84 2190.05 2244.28 2244.28 53.1 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.22 0.50 0.22 0.15 8.47e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.11 0.01 71.44 On 408.88 ‐6.68 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 64 Test No. 14.3; MD: 13570.00 ft; TVD: 5093.84 ft GeoTap Pretest File # 800‐14.3 Date: 23‐Sep‐12 06:57:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13570.00 5093.84 2189.94 2244.21 2244.21 53.1 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.22 0.50 0.22 0.15 8.20e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.13 0.07 71.44 On 408.88 ‐6.68 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 65 Test No. 15.0; MD: 13568.28 ft; TVD: 5093.70 ft GeoTap Pretest File # 800‐15.0 Date: 23‐Sep‐12 07:15:02 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13568.28 2868.63 2876.27 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 5.54 0.50 0.22 0.15 3.30e‐006 35.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 66 Test No. 15.1; MD: 13568.28 ft; TVD: 5093.70 ft GeoTap Pretest File # 800‐15.1 Date: 23‐Sep‐12 07:15:02 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13568.28 5093.70 2131.18 2244.39 2244.39 25.4 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 5.04 0.50 0.22 0.15 3.30e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.15 0.09 49.45 On 427.96 ‐6.68 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 67 Test No. 15.2; MD: 13568.28 ft; TVD: 5093.70 ft GeoTap Pretest File # 800‐15.2 Date: 23‐Sep‐12 07:15:02 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13568.28 5093.70 2128.87 2244.27 2244.27 25.0 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 5.14 0.50 0.22 0.15 4.06e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.17 0.12 54.28 On 427.96 ‐6.68 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 68 Test No. 15.3; MD: 13568.28 ft; TVD: 5093.70 ft GeoTap Pretest File # 800‐15.3 Date: 23‐Sep‐12 07:15:02 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13568.28 5093.70 2125.91 2244.18 2244.18 24.4 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 5.24 0.50 0.22 0.15 4.61e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.17 0.08 49.45 On 427.96 ‐6.68 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 69 Test No. 16.0; MD: 13547.98 ft; TVD: 5092.02 ft GeoTap Pretest File # 800‐16.0 Date: 23‐Sep‐12 07:37:21 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13547.98 2866.86 2873.90 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 2.01 1.00 0.22 0.15 4.14e‐006 35.00 REMARKS Dry/Tight Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 70 Test No. 17.0; MD: 13546.29 ft; TVD: 5091.88 ft GeoTap Pretest File # 800‐17.0 Date: 23‐Sep‐12 07:52:21 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13546.29 2868.47 2872.44 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.60 0.10 0.22 0.15 7.27e‐007 35.00 REMARKS Dry/Tight Test Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 71 Test No. 18.0; MD: 13674.99 ft; TVD: 5101.46 ft GeoTap Pretest File # 800‐18.0 Date: 23‐Sep‐12 11:20:08 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13674.99 2890.45 2895.21 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.02 0.50 0.22 0.15 1.43e‐005 35.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 72 Test No. 18.1; MD: 13674.99 ft; TVD: 5101.46 ft GeoTap Pretest File # 800‐18.1 Date: 23‐Sep‐12 11:20:08 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13674.99 5101.46 2215.28 2259.94 2259.94 64.5 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.92 0.50 0.22 0.15 1.06e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.26 ‐0.14 71.70 On 408.33 7.96 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 73 Test No. 18.2; MD: 13674.99 ft; TVD: 5101.46 ft GeoTap Pretest File # 800‐18.2 Date: 23‐Sep‐12 11:20:08 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13674.99 5101.46 2213.14 2259.43 2259.43 62.2 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.02 0.50 0.22 0.15 6.68e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.28 0.02 71.68 On 408.33 7.96 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 74 Test No. 18.3; MD: 13674.99 ft; TVD: 5101.46 ft GeoTap Pretest File # 800‐18.3 Date: 23‐Sep‐12 11:20:08 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13674.99 5101.46 2212.06 2259.00 2259.00 61.4 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.12 0.50 0.22 0.15 1.01e‐004 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.28 0.06 71.67 On 408.33 7.96 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 75 Test No. 19.0; MD: 13920.00 ft; TVD: 5117.98 ft GeoTap Pretest File # 800‐19.0 Date: 23‐Sep‐12 17:45:36 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13920.00 2928.54 2937.02 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.00 0.50 0.22 0.15 4.80e‐006 35.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 76 Test No. 19.1; MD: 13920.00 ft; TVD: 5117.98 ft GeoTap Pretest File # 800‐19.1 Date: 23‐Sep‐12 17:45:36 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13920.00 5117.98 355.75 2810.79 2810.79 0.955 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.41 0.50 0.22 0.15 4.80e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 4.23 1.86 71.84 On 194.49 13.81 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 77 Test No. 19.2; MD: 13920.00 ft; TVD: 5117.98 ft GeoTap Pretest File # 800‐19.2 Date: 23‐Sep‐12 17:45:36 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13920.00 5117.98 420.59 2808.64 2808.64 0.876 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.21 0.50 0.22 0.15 3.01e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 8.78 3.20 71.83 On 194.49 13.81 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 78 Test No. 19.3; MD: 13920.00 ft; TVD: 5117.98 ft GeoTap Pretest File # 800‐19.3 Date: 23‐Sep‐12 17:45:36 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13920.00 5117.98 470.95 2808.56 2808.56 0.797 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.00 0.50 0.22 0.15 5.01e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 8.68 3.22 71.82 On 194.49 13.81 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 79 Test No. 20.0; MD: 13935.00 ft; TVD: 5119.18 ft GeoTap Pretest File # 800‐20.0 Date: 23‐Sep‐12 18:07:51 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 13935.00 2929.95 2936.33 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.51 0.50 0.22 0.15 3.47e‐006 35.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 80 Test No. 20.1; MD: 13935.00 ft; TVD: 5119.18 ft GeoTap Pretest File # 800‐20.1 Date: 23‐Sep‐12 18:07:51 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13935.00 5119.18 40.95 2806.58 2806.58 0.531 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.91 0.50 0.22 0.15 3.47e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 6.35 0.87 71.75 On 206.91 7.96 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 81 Test No. 20.2; MD: 13935.00 ft; TVD: 5119.18 ft GeoTap Pretest File # 800‐20.2 Date: 23‐Sep‐12 18:07:51 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13935.00 5119.18 54.50 2806.02 2806.02 0.301 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.80 0.50 0.22 0.15 2.32e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 4.63 0.98 71.74 On 206.91 7.96 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 82 Test No. 20.3; MD: 13935.00 ft; TVD: 5119.18 ft GeoTap Pretest File # 800‐20.3 Date: 23‐Sep‐12 18:07:51 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 13935.00 5119.18 212.08 2804.37 2804.37 0.527 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.70 0.50 0.22 0.15 2.50e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.74 0.86 71.74 On 206.91 7.96 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 83 Test No. 21.0; MD: 14115.00 ft; TVD: 5133.54 ft GeoTap Pretest File # 800‐21.0 Date: 23‐Sep‐12 21:59:10 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 14115.00 2959.47 2962.18 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.00 0.50 0.22 0.15 3.49e‐006 35.00 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 84 Test No. 21.1; MD: 14115.00 ft; TVD: 5133.54 ft GeoTap Pretest File # 800‐21.1 Date: 23‐Sep‐12 21:59:10 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14115.00 5133.54 211.00 2666.48 2981.94 0.039 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.10 0.50 0.22 0.15 3.49e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 54.78 303.60 71.86 On 184.17 19.67 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 85 Test No. 21.2; MD: 14115.00 ft; TVD: 5133.54 ft GeoTap Pretest File # 800‐21.2 Date: 23‐Sep‐12 21:59:10 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14115.00 5133.54 19.66 644.24 761.29 0.112 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.00 0.50 0.22 0.15 3.11e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 35.43 212.20 ‐0.02 On 184.17 19.67 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 86 Test No. 21.3; MD: 14115.00 ft; TVD: 5133.54 ft GeoTap Pretest File # 800‐21.3 Date: 23‐Sep‐12 21:59:10 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14115.00 5133.54 117.88 507.97 687.39 0.055 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.60 0.50 0.22 0.15 1.07e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 20.27 165.53 ‐0.01 On 184.17 19.67 REMARKS Low Perm, Still Building Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 87 Test No. 22.0; MD: 14105.00 ft; TVD: 5132.78 ft GeoTap Pretest File # 800‐22.0 Date: 23‐Sep‐12 22:36:16 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 14105.00 2941.06 2962.62 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 11.05 1.00 0.22 0.15 8.54e‐006 35.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 88 Test No. 22.1; MD: 14105.00 ft; TVD: 5132.78 ft GeoTap Pretest File # 800‐22.1 Date: 23‐Sep‐12 22:36:16 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14105.00 5132.78 1406.39 2358.92 2358.92 6.05 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.04 1.00 0.22 0.15 8.54e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.78 0.06 71.74 On 227.38 22.59 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 89 Test No. 22.2; MD: 14105.00 ft; TVD: 5132.78 ft GeoTap Pretest File # 800‐22.2 Date: 23‐Sep‐12 22:36:16 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14105.00 5132.78 1424.09 2358.12 2358.12 6.17 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.04 1.00 0.22 0.15 9.08e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 1.22 2.46 71.74 On 227.38 22.59 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 90 Test No. 22.3; MD: 14105.00 ft; TVD: 5132.78 ft GeoTap Pretest File # 800‐22.3 Date: 23‐Sep‐12 22:36:16 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14105.00 5132.78 1394.01 2352.86 2352.86 6.01 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.64 1.00 0.22 0.15 1.46e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 7.27 19.50 193.47 On 227.38 22.59 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 91 Test No. 23.0; MD: 14490.00 ft; TVD: 5147.50 ft GeoTap Pretest File # 800‐23.0 Date: 24‐Sep‐12 06:09:00 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 14490.00 2952.48 2951.43 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.03 0.50 0.22 0.15 1.03e‐005 35.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 92 Test No. 23.1; MD: 14490.00 ft; TVD: 5147.50 ft GeoTap Pretest File # 800‐23.1 Date: 24‐Sep‐12 06:09:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14490.00 5147.50 2148.61 2573.54 2573.54 6.78 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.93 0.50 0.22 0.15 1.03e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.15 0.83 72.13 On 230.53 22.59 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 93 Test No. 23.2; MD: 14490.00 ft; TVD: 5147.50 ft GeoTap Pretest File # 800‐23.2 Date: 24‐Sep‐12 06:09:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14490.00 5147.50 2150.82 2572.46 2572.46 6.83 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.23 0.50 0.22 0.15 1.23e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.61 1.13 72.12 On 230.53 22.59 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 94 Test No. 23.3; MD: 14490.00 ft; TVD: 5147.50 ft GeoTap Pretest File # 800‐23.3 Date: 24‐Sep‐12 06:09:00 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14490.00 5147.50 2151.06 2571.66 2571.66 6.85 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.03 0.50 0.22 0.15 1.05e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.69 1.16 72.10 On 230.53 22.59 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 95 Test No. 24.0; MD: 14477.99 ft; TVD: 5147.19 ft GeoTap Pretest File # 800‐24.0 Date: 24‐Sep‐12 06:30:41 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 14477.99 2927.50 2935.77 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.03 0.50 0.22 0.15 3.32e‐006 35.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 96 Test No. 24.1; MD: 14477.99 ft; TVD: 5147.19 ft GeoTap Pretest File # 800‐24.1 Date: 24‐Sep‐12 06:30:41 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14477.99 5147.19 1621.90 2516.08 2516.08 3.22 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.03 0.50 0.22 0.15 3.32e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 2.90 1.52 72.00 On 259.06 5.03 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 97 Test No. 24.2; MD: 14477.99 ft; TVD: 5147.19 ft GeoTap Pretest File # 800‐24.2 Date: 24‐Sep‐12 06:30:41 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14477.99 5147.19 1587.32 2514.99 2514.99 3.10 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.23 0.50 0.22 0.15 8.71e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 3.67 2.06 72.00 On 259.06 5.03 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 98 Test No. 24.3; MD: 14477.99 ft; TVD: 5147.19 ft GeoTap Pretest File # 800‐24.3 Date: 24‐Sep‐12 06:30:41 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14477.99 5147.19 1554.82 2514.51 2514.51 3.00 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.23 0.50 0.22 0.15 8.60e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 3.87 2.13 71.99 On 259.06 5.03 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 99 Test No. 25.0; MD: 14975.00 ft; TVD: 5157.99 ft GeoTap Pretest File # 800‐25.0 Date: 24‐Sep‐12 15:18:09 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 14975.00 2962.88 2980.89 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.04 0.50 0.22 0.15 4.29e‐006 35.00 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 100 Test No. 25.1; MD: 14975.00 ft; TVD: 5157.99 ft GeoTap Pretest File # 800‐25.1 Date: 24‐Sep‐12 15:18:09 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14975.00 5157.99 2275.86 2355.90 2355.90 36.0 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.83 0.50 0.22 0.15 4.29e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.21 ‐0.13 72.36 On 194.82 5.03 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 101 Test No. 25.2; MD: 14975.00 ft; TVD: 5157.99 ft GeoTap Pretest File # 800‐25.2 Date: 24‐Sep‐12 15:18:09 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14975.00 5157.99 2276.71 2355.51 2355.51 36.6 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.34 0.50 0.22 0.15 6.30e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.18 ‐0.16 72.34 On 194.82 5.03 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 102 Test No. 25.3; MD: 14975.00 ft; TVD: 5157.99 ft GeoTap Pretest File # 800‐25.3 Date: 24‐Sep‐12 15:18:09 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 14975.00 5157.99 2275.44 2355.17 2355.17 36.1 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.34 0.50 0.22 0.15 4.14e‐005 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.18 ‐0.08 72.32 On 194.82 5.03 REMARKS Good Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 103 Test No. 26.0; MD: 16325.00 ft; TVD: 5200.79 ft GeoTap Pretest File # 800‐26.0 Date: 25‐Sep‐12 19:51:34 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 16325.00 3009.18 3024.88 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.51 0.50 0.22 0.15 4.56e‐006 35.00 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 104 Test No. 26.1; MD: 16325.00 ft; TVD: 5200.79 ft GeoTap Pretest File # 800‐26.1 Date: 25‐Sep‐12 19:51:34 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 16325.00 5200.79 85.37 2736.15 2736.15 0.656 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.61 0.50 0.22 0.15 4.56e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 4.92 ‐0.76 72.53 On 207.78 72.35 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 105 Test No. 26.2; MD: 16325.00 ft; TVD: 5200.79 ft GeoTap Pretest File # 800‐26.2 Date: 25‐Sep‐12 19:51:34 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 16325.00 5200.79 185.68 2731.47 2731.47 0.422 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.80 0.50 0.22 0.15 2.96e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 7.08 0.27 72.51 On 207.78 72.35 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 106 Test No. 26.3; MD: 16325.00 ft; TVD: 5200.79 ft GeoTap Pretest File # 800‐26.3 Date: 25‐Sep‐12 19:51:34 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 16325.00 5200.79 222.94 2728.31 2728.31 0.474 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 0.90 0.50 0.22 0.15 2.71e‐006 35.00 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 7.22 0.26 72.50 On 207.78 72.35 REMARKS Fair Buildup Stability Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 107 Disclaimer DATA, RECOMMENDATIONS, INTERPRETATIONS LIMITATIONS Because of the uncertainty of variable well conditions the necessity of relying on facts and supporting services furnished by others, Halliburton IS UNABLE TO GUARANTEE THE EFFECTIVENESS OF THE PRODUCTS, SUPPLIES OR MATERIALS, NOR THE RESULTS OF ANY TREATMENT OR SERVICE, NOR THE ACCURACY OF ANY CHART INTERPRETATION, RESEARCH ANALYSIS, JOB RECOMMENDATION OR OTHER DATA FURNISHED BY Halliburton. Halliburton personnel will use their best efforts in gathering such information and their best judgment in interpreting it, but Customer agrees that Halliburton shall not be liable for and Customer SHALL RELEASE, DEFEND AND INDEMNIFY Halliburton against any damages or liability arising from the use of such information even if such damages are contributed to or caused by the negligence, fault or strict liability of Halliburton. Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 108 Drawdown Buildup Analysis During the pretest a small amount of fluid is withdrawn from the formation through the snorkel and into the tool at a known rate. This causes the pressure pulse called a pretest drawdown. The combination off low rate and snorkel D determines an effective range of operation. The maximum drawdown pressure pulse can be determined from the well‐known spherical flow equation where Pdd is the final drawdown pressure differential at time t=.       fp pdd dd kr q = P  2696,14 Where: Pdd ............................................................................. drawdown differential pressure (psi) qo .............................................................................................. drawdown flow rate (cc/sec) ks ................................................................................ formation spherical permeability(md)  ....................................................................................................................... viscosity (cp) rp ................................................................................................................ probe radius(cm) p .................................................................................... probe flow coefficient (1.37to0.95) With a 0.10cc/sec to 1.5cc/sec drawdown flow rate and a 1.0cm probe employed, it is possible to test formations ranging from 1000 to 0.5 md with pressure differentials ranging from 2 to 5000 psi. Exact Mobility Analysis By analyzing the drawdown curve and the build‐up curve it is possible to calculate the mobility of the formation. The mobility is defined as the permeability divided by the viscosity (md/cp). Therefore if the viscosity of the fluid being drawn is known, it is also possible to determine the formation permeability. The fluid being drawn into the pretest is normally assumed to be the mud filtrate so if the mud type is known it is possible to estimate the filtrate viscosity. The two methods of determining the mobility are shown by the two equations below. First is the drawdown mobility Mdd that uses the drawdown pressure differential (i.e.,Pdd=Pstop‐Pdd_end) and is the most common method used in the industry. It is normally referred to as the steady‐state spherical method. The second is the exact spherical mobility Mexact that typically uses the buildup curve. A simplified form of the exact method is shown in Figure‐1 which is an exponential with a magnitude of  (pressure, psi) and a time constant of (sec). Both the drawdown and buildup curves can be analyzed but normally the buildup is used. The curve fit parameters alpha  and beta  are used to determine the mobility. Generally these Mdd and Mexact are very similar except in low mobility zones where the mobility is < 1 md/cp. In this case the Exact method yields the most accurate estimate of Mobility. Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 109 Mdd=            p p dd o rP q  2 696,14 Drawdown spherical mobility (md/cp) Mexact=                pt p po er q 12 696,14 Exact spherical mobility (md/cp) Where: tp ................................................................. draw down production time(tdd_end-tdd_start ,sec)  ...................................................................................... Exact curve fit time constant (sec)  ................................................................................ Exact curve fit build up constant (psi) Pressure (psi)Time (sec)tstop Q tdd_end tdd TPdd_end t = T – tdd_end tdd_start  t fbu eP(t)P  * Pdd_start Pdd=Pstop-Pdd_end Pstop Phyds Fig–1 Buildup function where formation pressure (Pf*), Alpha ( ) and beta () are determined from the Exact curve fit and Pf* is normally reported a PExaxt. Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 110 Test Quality Parameters There are two different measurements of test quality. The first is called the sigma which is a measure of how closely the data conforms to the Exact model and is reported in ± pressure units (normally psi). The sigma is determined by calculating the standard deviation of the data from the theoretical curve as follows.  )1( )()(p)( 2   n iPi=P bu bu ........... standard deviation ± pressure units (normally psi) Where: Pbu ........................................................... buildup pressure from Exact curve fit (see Fig. 1) p(i) ............................................................................................. measured buildup pressures i ............................................................................................................... index of data point n .................................................................................. total number of pressure points used The second method of measuring the test quality is the pressure and temperature stability. The “Pressure Stability” and “Temperature Stability are determined using a linear regression over the time period specified (i.e., default of 30 sec) and reported for each selected stop pressure. The stability can be either positive or negative. The stability period can be modified if desired in RTS. The source data for this derivative is the pressure gauge selected by the engineer for formation pressure which is normally the Quartz gauge closest to the probe. There are some exceptions to the stability period during buildups which are outlined below. 1. Start of buildup continue stability calculation until the buildup time reaches the stability period (i.e., 30 default). 2. Reset stability period to 1/3 of the buildup time (10 seconds default). 3. As the buildup progresses increase the stability period using 1/3 of the buildup time until the specified stability time is reached (30 sec default). Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 111 Automatic Test Comments Automatic test comments are generated based on the sigma quality parameter and the logic below. Test are classified by types and are normally Type A, B, C, and D. Any test that is not Type A, B, C or D is type F. The logic below determines the test type automatically but as explained below the RTS analysis can always override these comments and classify the tests as he sees fit. If Abs(Pstop - Phyd2) < 50 psi, “Potential Mud set” If Pstop < 1000 psi and alpha > 30 sec, “Dry/Tight test” If sigma <= 0.1: “Excellent Buildup Stability” (Type A) elseif sigma <= 1.0: “Good Buildup Stability” (Type B) elseif sigma <= 10.0: “Fair Buildup Stability” (Type C) else: if beta > 500 and alpha > 30: “Low Perm, still building” else: “Unstable Buildup (Type D)” The RTS analysts can override these comments based on his discretion, but if the key words Excellent, Good, Fair or Unstable are used the test comments the type associated with these key words used to apply the test type. The color coding to the test types are as follows. Type A Green Type B Orange Type C Pink Type D Red Type F Black Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 112 Dual Probe Anisotropy Analysis (Vertical Interference Testing) When one of the probes is isolated it may be possible to determine the horizontal permeability and anisotropy from the isolated (observation) probe that is spaced at a vertical distance from the source probe (lv) Mh_exact=       v pt v vo v el Q  12 1696,14 Exact Horizontal Mobility (md/cp) 3 _ _      exacth exacts exacth v exact M M k k Exact anisotropy Anisotropy Dip-angle Corrections The calculation for anisotropy assumes the bedding plane is oriented relative to the borehole. The correction chart shown below can be used to find the anisotropy when the relative dip angle is known. Entering the chart from the left hand side with the real‐time anisotropy and following one of the lines to the right determines the correction with increasing dip‐angle. For example, using a real‐time anisotropy of 10 and with a dip‐angle of 700 the corrected anisotropy is slightly less than 0.1. This would be the case of a nearly horizontal well. Notice that as the dip‐angle approaches 450 the lines converge. This means that measurements taken close to a 450 dip‐angle are not very sensitive to anisotropy. 0.00001 0.0001 0.001 0.01 0.1 1 10 100 1000 0 102030405060708090 Dip Angle (deg)Anisotropy (kv/kh)300 100 30 10 1 0.1 0.01 0.001 0.0001 0.00001 Real-Time Anisotropy Fig. 2 Anisotropy Dip‐angle Correction Chart. Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 113 Flow Rate Determination There are three methods of determining the drawdown (and pumping) flow rates which can be selected in the Job Parameters. In the newer tools the flow rate is measured and the “Automatic Method” is the preferred default. In older tools the flow rate or test volume can be specified but the values must be entered manually. With any of these three options it is rare that the volumes and rates exactly match that specified by the engineer since there is variability in the actual execution of a pretest and the rates and volume in RTS are determined from actual events and measured data. Automatic Flow Rate Option The automatic flow rate option determines rate from the measured rate curve(s) directly. For pretesting the averaged rage between the selected starting and ending times of the drawdown is used (i.e., Tstard_dd and Tend_dd). It is possible to select a Tend_dd that may not fall within the drawdown period and still estimate the mobility using the averaged rate for the drawdown period chosen. When this happens the simulated drawdown curve is turned off. For both pumping and pretesting the rate should be determined from the active rate curves. Since some tools like the RDT can have more than one pretest module or pump the total average from all the rate curves are used to for the “Automatic Rate” calculation. Then the volume for the drawdown is determined by using this averaged rate times the drawdown time (i.e., AvgRate/(Tend_dd‐Tstart_dd)). However, the time used to average should not exceed 30 minutes which would apply to pumpouts or miniDST testing and it is desirable to determine the rate just prior to the buildup. In this case the averaged rate would be from Tdd‐30 minutes to Tdd. Also, rates less than 0.02 cc/sec from Meas PT Rate are filtered out (set to 0 values) and rates less than 0.1 cc/sec for Pump Rates are set to 0 before averaging. Manual Flow Rate Option With this option selection in the Job Parameters the rate is fixed to the value entered. The volume of the pretest is determined by multiplying this rate time the drawdown time period selected (i.e., Tstard_dd and Tend_dd). Manual Volume Option With this option selection in the Job Parameters the volume is fixed to the value entered. The rate of the pretest is determined by dividing this volume by the drawdown time period selected (i.e., Tstard_dd and Tend_dd). Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 114 RTS Mobility Drawdown and Buildup Calculation Summary Table 1 PTA Spherical Flow Regime Calculations (Typical Physical Units) Mdd=         p p dd o rP q  2 696,14 ........................................ Drawdown Mobility, Pressure/Time Plot (md/cp) Ms_exact=               pt p po er Q 12 696,14 ........................... Exact Mobility, Pressure/Time Plot (md/cp) Mloglog= 5.1 1 5.2 5.1 4 696,14            dt dpt cV fo  ....................................... FasTest Mobility, Log-Log Plot (md/cp) Mfast= 5.1 1 5.1 4 696,14          fast fo m cV  ............................................. FasTest Mobility, FasTest Plot (md/cp) Msphere= 5.1 1 4 696,14          sphere fo m cq  .................................................. Spherical Mobility, FastPlot (md/cp) Table 2 PTA Radial Flow Regime Calculations (Typical Physical Units) Mdd=                  p wf o dd dd o t rc q hPLambertWhP q 2 4 696,14   ...................... Drawdown Mobility (md/cp) Mloglog=               dt dpth V eLog o 2)(4 696,14  ................................................ FasTest Mobility, Log-Log Plot (md) Mfast=         fast o mh V eLog)(4 696,14  .......................................................... FasTest Mobility, FasTest Plot (md) Mradial=            radial o mh q eLog)(4 696,14  ................................................................ Radial Mobility, FastPlot (md) Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 115 Table 3 PTA Variables & Constants Using Internal Program (Typical Physical Units) qo ................................................................................................................. drawdown flow rate (cc/sec) Vo ........................................................................................................................... drawdown volume(cc) Vs ................................................................................................................................ storage volume(cc)  ................................................................................................................................................... porosity  ........................................................................................................................................... viscosity(cp) cf ..................................................................................................................... fluid compressibility(1/psi) Pdd .................................................................................................. drawdown differential pressure(psi) p ........................................................................................................ prove flow coefficient (1.37to0.95) rp .................................................................................................................................... probe radius(cm) rw .............................................................................................................................. wellbore radius(cm) h ..................................................................................................................................... zone height (cm) T .............................................................................................................................. actual testtime(T,sec) t ..................................................................................................... shut in or buildup time ((tdd_end-T,sec) t’ ......................................................................................... production or drawdown time (tdd_start-T,sec) tp ..................................................................... production or drawdown time period (tdd_end-tdd_start,sec) dp/dt ................................................................................. Log-Log Plot buildup time derivative(psi/sec) mfast .............................................................................................................................. FasTest Plot slope msphere ........................................................................................................................ Spherical Plot slope mradial ............................................................................................................................. Radial Plot slope  ................................................................................................................ Exact Plot time constant (sec)  .................................................................................................................. Exact curve fit constant (psi)  ............................................................................................................................ Eulier’sconstant (1.78) Log(e) ........................................................................................ logbase10conversionconstant (0.43429) Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 116 Table 4 PTA Spherical Flow Regime Calculations (SI Units) Mdd=         p p dd o rP q  2 1013 ........................................... Drawdown Mobility, Pressure/Time Plot (md/cp) Ms_exact=               pt p po er Q 12 1013 .............................. Exact Mobility, Pressure/Time Plot (md/cp) Mloglog= 5.1 1 5.2 5.1 4 1013            dt dpt cV fo ........................................... FasTest Mobility, Log-Log Plot (md/cp) Mfast= 5.1 1 5.1 4 1013         fast fo m cV  ................................................. FasTest Mobility ,FasTest Plot (md/cp) Msphere= 5.1 1 4 1013          sphere fo m cq  ...................................................... Spherical Mobility, FastPlot (md/cp) Table 5 PTA Radial Flow Regime Calculations (SI Units) Mdd=                 p wf o dd dd o t rc q hPLambertWhP q 2 4 1013   ......................... Draw down Mobility (md/cp) Mloglog=            dt dpth Vo 24 1013  .......................................................... FasTest Mobility, Log-Log Plot (md) Mfast=        fast o mh V 4 1013 ................................................................... FasTest Mobility, FasTest Plot (md) Mradial=            radial o mh q eLog)(4 1013  ........................................................... Radial Mobility, FastPlot (md) Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 117 Table 6 PTA Variables & Constants Using Internal Program SI Units qo ................................................................................................................. drawdown flow rate(m2/sec) Vo .......................................................................................................................... drawdown volume(m2) Vs ............................................................................................................................... storage volume(m2)  ................................................................................................................................................... porosity  ................................................................................................................................. viscosity (cp, Pa-s) cf ..................................................................................................................... fluid compressibility(1/Pa) Pdd .................................................................................................. drawdown differential pressure(Pa) p ........................................................................................................ prove flow coefficient (1.37to0.95) rp ...................................................................................................................................... probe radius(m) rw ................................................................................................................................ wellbore radius(m) h ....................................................................................................................................... zone height (m) T ............................................................................................................................ actual test time (T,sec) t ....................................................................................................... shutin or buildup time((tdd_end-T,sec) t’ .......................................................................................... production or drawdown time(tdd_start-T,sec) tp ...................................................................... production or drawdown time period(tdd_end-tdd_start,sec) dp/dt ................................................................................. Log-Log Plot buildup time derivative(Pa/sec) mfast .............................................................................................................................. FasTest Plot slope msphere ........................................................................................................................ Spherical Plot slope mradial ............................................................................................................................. Radial Plot slope  ................................................................................................................ Exact Plot time constant (sec)  .................................................................................................................. Exact curve fit constant (Pa)  ........................................................................................................................... Eulier’s constant (1.78) Log(e) ..................................................................................... logbase 10 conversion constant (0.43429) Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 118 RTS Theory References An Integrated Approach to Reservoir Connectivity and Fluid Contact Estimates by Applying Statistical Analysis Methods to Pressure Gradients, SPWLA 2007_HH paper presented at the 48th Annual Logging Symposium, June 3 - 6, 2007 , Austin, Texas. Formation Pressure Testing in the Dynamic Drilling Environment, SPE 112816 presentation was an SPE Distinguished Lecture during 2006-2007. Formation Testing and Sampling Using an Oval Pad in Al Hamd Field, Egypt, SPE 102366 presented at the SPE Annual Technical Conference and Exhibition, 24-27 September 2006, San Antonio, Texas, USA. Formation Tester While Drilling Experience in Caspian Development Projects, SPE 96719 paper presented at the SPE Annual Technical Conference and Exhibition, 9-12 October 2005, Dallas, Texas. Experience Using the First Commercial Pad and Probe Style Formation Tester While Drilling Service Has Led To Value Creation at the Valhall Flank Development, SPE 92712 paper presented at the SPE/IADC Drilling Conference, 23-25 February 2005, Amsterdam, Netherlands The Influence of Water-Base Mud Properties and Petrophysical Parameters on Mudcake Growth, Filtrate Invasion, and Formation Pressure, Petrophysics Volume 46, Number 1, January - February, 2005. Formation Tester Immiscible and Miscible Flow Modeling for Job Planning Applications, SPWLA 2005-L paper presented at the SPWLA 46th Annual Logging Symposium, 2005 Results of Laboratory Experiments to Simulate the Downhole Environment of Formation Testing While Drilling. SPWLA 2005R paper was presented at the SPWLA 45th Annual Logging Symposium held in Noordwijk, The Netherlands, June 6–9, 2004. Formation Testing In The Dynamic Drilling Environment, SPWLA 2005N paper was presented at the SPWLA 45th Annual Logging Symposium held in Noordwijk, The Netherlands, June 6–9, 2004. Formation Pressure Testing In the Dynamic Drilling Environment. SPE 87090 was presentated at the IADC/SPE Drilling Conference held in Dallas, Texas, U.S.A., 2–4 March 2004. Formation Testing While Drilling, a New Era in Formation Testing. SPE 84087 was presentated at the 2003 SPE Annual Technical Conference and Exhibition held in Denver, Colorado, USA, 5-8 October 2003. Formation Testing While Drilling, a New Technique for Acquiring Pressure Data, Paper presented at the SPE Nigerian Annual International Conference and Exhibition 4-8 August 2003. A New Inversion Technique Determines In-Situ Relative Permeabilities And Capillary Pressure Parameters From Pumpout Wireline Formation Tester Data, Spwla Forty-Fourth Annual Logging Symposium, Galveston, Texas, June 22-25, 2003. Performance Optimization of Perforated Completions Using a New 3D Finite-Element Wellbore Inflow Model and Artificial Neural Network, ExiPet Petroleum Congress, held in Veracruz, Mexico, February 16 - 18, 2003. Well Test Analysis Review, and Future Development, ExiPet Petroleum Congress, held in Veracruz, Mexico, February 16 - 18, 2003. Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 119 Sample Quality Prediction with Integrated Oil and Water-based Mud Invasion Modeling, SPE paper 77964 presented at the SPE Asia Pacific Oil and Gas Conference and Exhibition held in Melbourne, Australia, 8–10 October 2002. Inversion of Multi-Phase Petrophysical Properties Using Pumpout Sampling Data Acquired with a Wireline Formation Tester, SPE paper 77345 presented at the SPE Annual Technical Conference and Exhibition held in San Antonio, Texas, 29 September–2 October 2002. Multiple Factors that Influence Wireline Formation Tester Pressure Measurements and Fluid Contact Estimates, SPE paper 71566 presented at the 2001 SPE Annual Technical Conference and Exhibition held in New Orleans, Louisiana, 30 September–3 October 2001. New Wireline Formation Testing Tool with Advanced Sampling Technology, SPE paper 71317, SPE Reservoir Evaluation and Engineering Journal, April 2001. Testing of Gas Condensate Reservoirs — Sampling, Test Design and Analysis, SPE paper 68668 presented at the SPE Asia Pacific Oil and Gas Conference and Exhibition held in Jakarta, Indonesia, 17–19 April 2001. Advanced Dual Probe Formation Tester with Transient, Harmonic, and Pulsed Time-Delay Testing Methods Determines Permeability, Skin, and Anisotropy, SPE paper 64650 presented at the SPE International Oil and Gas Conference and Exhibition in China held in Beijing, China, 7–10 November 2000 Advanced Permeability and Anisotropy Measurements While Testing and Sampling in Real-time Using a Dual Probe Formation Tester, SPE paper 62919 presented at the 2000 SPE Annual Technical Conference and Exhibition held in Dallas, Texas, 1–4 October 2000. New Dual-Probe Wireline Formation Testing and Sampling Tool Enables Real-Time Permeability and Anisotropy Measurements, SPE paper 59701 presented at the SPE Permian Basin Oil and Gas Recovery Conference held in Midland, Texas, 21–23 March 2000. New Wireline Formation Testing Tool with Advanced Sampling Technology, SPE paper 56711 presented at the 1999 SPE Annual Technical Conference and Exhibition, Houston, Texas, 3–6 October 1999 Exact Spherical Flow Solution with Storage for Early-Time Test Interpretation, SPE Journal of Petroleum Technology, Nov. 1998 New Exact Spherical Flow Solution with Storage and Skin for Early-Time Interpretation, with Applications to Wireline Formation and Early-Evaluation Drillstem Testing, SPE Paper No. 49140, 1998 SPE Annual Technical Conference and Exhibition, New Orleans, La., Sept. 1998 New Exact Spherical Flow Solution for Early-Time Well Test Interpretation with Applications to Wireline Formation Testing and Early-Evaluation Drillstem Testing, SPE Paper No. 39915, SPE Rocky Mountain Regional Meeting/Low Permeability Reservoirs Symposium, Denver, Co., April 1998 New Exact Spherical Flow Solution for Early-Time Well Test Interpretation with Applications to Wireline Formation Testing and Early-Evaluation Drillstem Testing, SPE Paper No. 39768, SPE Permian Basin Oil and Gas Recovery Conference, Midland, Texas, March 1998 Pressure Test Validity Shown by Comparing Field Tests and Simulations, Part II: Formation Pressure Test Tools, Oil & Gas Journal, Jan. 12, 1998 Houston Technology Center 3000 N. Sam Houston Pkwy E., Houston, TX 77032 3 December 2012 Confidential Page 120 Testing System Combines Advantages of Wireline and Drillstem Testers, Part I: Formation Pressure Test Tools, Oil & Gas Journal, Jan. 5, 1998 Low Permeability Interpretation Using a New Wireline Formation Tester ‘Tight Zone’ Pressure Transient Analysis, SPWLA 94 III Paper, presented at the 35th Annual Symposium in Tulsa, Oklahoma, June (1994). Real Time Pressure Transient Analysis Methods Applied to Wireline Formation Test Data, SPE paper 28449, presented at the 69th Annual Technical Conference of SPE in New Orleans, La., Sep. 25-28, 1994. Interpretation of Wireline Formation Tester Pressure Response, Mud Super-charging and Mud Invasion Effects, SPWLA 92 HH Paper, presented at the 33rd Annual Symposium in Oklahoma City, Oklahoma, June (1992). Improved Models for Interpreting the Pressure Response of Formation Testers, SPE paper 22754, presented at the 66th SPE Annual Technical Conference and Exhibition, Dallas, Texas, October 1991 Technical Report Title Date Client: Pioneer Natural Resources Field: Oooguruk Development Rig: Nabors 19AC Date: October 4, 2012 Surface Data Logging End of Well Report ODST-47 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Survey Report 8. Days vs. Depth Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI Backup GENERAL WELL INFORMATION Company: Pioneer Natural Resources AK Rig: Nabors 19AC Well: ODST-47 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20660-00-00 Sperry Job Number: AK-AM-0009646431 Job Start Date: 17 AUG 2012 Spud Date: 14 AUG 2012 Total Depth: 17245’ MD, 5287.9’ TVD North Reference: True Declination: 20.189 Dip Angle: 80.988 Total Field Strength: 57607 nT Date Of Magnetic Data: 20 AUG 2012 Wellhead Coordinates N: North 70° 29’ 44.71” Wellhead Coordinates W: West 150° 14’ 48.64“ Drill Floor Elevation 56.2’ Ground Elevation: 13.5’ Permanent Datum: Mean Sea Level SDL Engineers: David Mckechnie, Kerry Garner Andrew Bongard, Jessica Munsell Company Geologist: England Flecther, Paul Cazma Mindaugas Kuzminskas, Jim Stewart Company Representatives: Rod Klepzig, Joey Cortez, Joe Polya, Jerry Haberthur SSDS Unit Number: 123 DAILY SUMMARY Begin ODST-47 8/17/2012 Loggers arrived on location. Rigged up gas gear. Calibrated gas system. Performed carbide test immediately upon Rig-up. Inconclusive, trouble shot gas gear, issue resolved. Performed another carbide test at 03:15 hrs- 3962' MD 2572' TVD. Returned on time. Gas – Max- 35 Ave- 21 Fluids- 0 bbls Geology – N/A 8/18/2012 Drilled ahead from 4012' to the Total Depth of surface hole at 5389' at 22:51 hrs. Pumped high viscosity- sweep at 2300 hrs. 10% increase noted at shakers. Pumped carbide pill shortly after. Carbide returned 80 strokes late for an average open hole size of 13.56”. Gas – Max- 55 Ave- 26 Fluids – 0 bbls Geology – N/A 8/19/2012Tripped out of the hole to 4,912'. Monitored the well. Pumped a dry job and continued to pull out of the hole to BHA and cleaned the clay off and tripped back in to 4,794'. Wiped tight spots, reamed/washed down to 5,389'. Pumped High viscosity sweep with carbide. Sweep arrived 145 strokes early and carbide arrived 245 strokes late for an average open hole diameter of 13.68". Circulated 3 bottoms up and back reamed from 5,103' to 4,817'. Unable to pull on elevators. Tripped in to 5,389'. Back reaming. Gas – Max- 82 Fluids - 0 bbls Geology – N/A 8/20/2012 Continued back reaming from 3,012'. Circulated 1 1/2 bottom up and tripped out of the hole to 1,588'. Worked through a tight spot at 1,681'. Tripped out to 636 and began laying down BHA. Monitored the well. Static. Laid down MWD tools and rigged up to run 10 3/4" casing. Had issues with casing spiders. Repaired. Continued running the hole. Encountered tight spot at 2,070'. Back reamed and circulated, staging pumps up to 6.5 bbls per min, trip in to in to 4,597' at report time. 15 bbls during casing trip Gas – Max- 16 Ave- 1 Fluids – 3bbls lost to hole Geology – N/A 8/21/2012 Continue tripping in hole with 10.75" casing to 5380'. Made up hanger landing tool, install cement head. Brook circulation increase pumps to 11 bpm. Condition mud to a yield point of 19 while circulating. Pump cement at Halliburton requested program. Changed to rig mud pump bumped plug at 4950’.Pumped Cement Spacer at 2100 strokes. Cement and mud returned 10.5 ppg at 3047 strokes also 11.0 ppg 3350 strokes, and 11.25ppg 3800 strokes. Good cement to surface check floats good, washed out cement line on rig floor. Rig down cement head and Tesco tool, Begin nippling down BOP stack. Gas – No Gas Fluids – 30 bbls lost to hole Geology – N/A 8/22/2012 Continue nippling down BOP stack and riser, also Nipple up Multi bowl per VG and test same. Nipple up BOPs. Riser, Spool, MPD. Installed trip Nipple and begin testing BOPs. Picked up 75 joints of 5" DP. Flush and rack back. Pressure test casing 3500 psi. Remove wear bushing tripped in with clean Out BHA Gas – No Gas Fluids - 0bbls Geology – N/A 8/23/2012 Tripped in with clean Out BHA to 5163', wash and Rotate down. Tag cement at 5296'. Drilled out shoe track to 5389'. Displace well spud mud to 9.55 ppg MOBM. 55 bbls interface dumped. Drill new hole to 5409'.Performed formation integrity test with 12.5 ppg EMW. Tripped out of hole, picked up new Sperry Geo-Pilot BHA. Tripped in hole and shallow test MWD, Tripped in to 3401'. Circulated to Brake in new Geo-Pilot and tested. Tripped in to 5234'. Cut and slip drill line prepared to install MPD RCD. Gas – Max- No Gas Fluids – 0bbls Geology – N/A 8/24/2012 Install MPD RCD bearing an washed from 5397' to 5409' drill ahead holding 11.5ppg EMW with MPD and 9.5 ppg MW in hole, continued drilling to 6537'. Circulated 1 x Bottoms up to reduce ECD. Maintain ECD to 11.5 ppg. Drill to 7089'at 130 fph. Gas – 154 Units Fluids – 8bbls lost to hole Geology – 70% Shale 20%Clay 10 Tuff 8/25/2012 Drill ahead at 140 fph to 9250' holding 11.5 ppg EMW with MPD and 9.5ppg MW in the hole. Notice top of Brookian 2B decision made by Geologist. Pump 55 bbls 12.3 ppg Hi viscosity sweep around, 200% increase of cuttings on sweep return 900 strokes ahead of calculated strokes. Rack back 1 stand begin 7x Bottoms up prior to beginning trip. Gas – 402 Units Fluids – 60 bbls lost to hole Geology – 100% Shale 8/26/2012 Continue circulating 7x bottoms up rack back 1 stand per bottoms up. Maintain 11.5 ppg ECD with MPD. Tripped out of hole to 4447'. Repair instrumentation & iron roughneck on rig and begin tripping in hole to 6632'. Tight spots noted begin reaming & washing to 6726', pack off stop pumps. Begin bringing pumps up slow at 10stks a min and begin washing to 9198'. Step pumps up to 650 gpm and begin drilling ahead @ 135 fph holding 11.5 ppg ECD with MPD to 9673' Gas – 375 Units Fluids- 54bbl lost to hole Geology –100 % Shale 8/27/2012 Drill to 11003’ increase in ECD was noted at 11.55 ppg to 11.68 ppg, reducing rhelogy to 11.75 to 9.875 ranges for possible effect on ECD also noted that hole was not taking correct fill volume and a reduction in cutting at the shakers. At 10602’ noted large cutting size of 2” unloaded at shakers. MPD choke difference in psi jumping noted obstruction in line remove obstruction in MPD flow line test MPD flow line. Drill ahead to 11098' blew RCD bearing pull off bottom and replaced. Drilled ahead at 140 foot per hour holding 11.55 ppg ECD with MPD to11457'. Gas – 212 Units Fluids- 0 bbl Geology –100 % Shale 8/28/2012 Drill ahead to 12049 ‘at 100 feet per hour holding 11.52 ppg ECD with MPD. Begin mixing mud with Baracarb 100' ahead of Torok. Cleared pack-off on RSC hammer mill. Rotated pipe during repair drill to 12220’ to intermediate hole section TD. Pump 55bbls 11.7 ppg Hi viscosity-sweep 100% increase in cuttings with sweep at surface on calculated strokes. Start pump 7 times bottoms up racking back a stand at each bottom up. At 12049' Pump 2nd 50 bbls 11.9ppg Hi viscosity-sweep with 200% increase cuttings with sweep at surface on calculated strokes. Finished circulating bottoms-up. Gas – 150 Units Fluids- 0 bbl Geology –100% Shale 8/29/2012 Trip out of hole with MPD BPP to 4827'. Pull 75/100k over. Swab from 5017' to 4827'. Trip into hole to 5112'. Packing off. Ream, step up circulation .Wash ream from 5112' to 5207'. Pump 25bbl 12.5 ppg Hi viscosity-sweep. 60% increase cuttings. Repair MPD pump. Wash ream down to 5380'. Ream and washed from 5380' to 4922'.Casing cleaning up. Back ream from 4922' to1309'. Circulated until shakers clean. Trip into hole to 5302'. Pump 30 bbl 12.7 ppg Hi viscosity-sweep. No increase cuttings. Slip and cut drill line, tripped in hole from 5302' to 8846' @ report time. Prepared pits to weight up active system to10.0 ppg back on bottom after wiper trip, 74 bbls lost to hole last 24 hrs. Gas – 39 Units Fluids- 74 bbl Geology –100% Shale 8/30/2012 Trip into hole to 9293' no down weight with full pipe rotated while trip into hole to 9578'. Staged pumps to 575 gpm attempt to trip in hole on elevators at 9663' fighting pack-offs. Staged pumps to 600 gpm circulated 2x bottoms-up reamed and washed to 9958' multiple pack-offs. Staged pumps at each pack-off event to 550 gpm. Wash down from 9959' pack-off. Staged pumps to 550 gpm lost circulation. Staged pumps to 610 gpm. Clear MPD flow line of obstructions. Ream and wash to10721’ with 650 / 700 gpm. Fighting multiple pack-offs. Prepare pits to weight up active system to10.0 ppg returned to bottom after wiper trip. Gas – 1,231 Units Fluids- 175 bbl Geology –100% Shale 8/31/2012 Ream and wash to 10908’ fighting multiple pack-offs. Stage pumps to 600 gpm at each pack off event. Circulate bottoms as needed MPD chokes plugged off with large tuff pieces at 10860'. Closed Annular bag Clear MPD chokes. Large tuffs passing through chokes while pumping10908' fighting pack-offs. Attempted to stage pumps up lost total circulation, begin tripping out of hole to 6150' . Gas – 289 Units Fluids- 140 bbl Geology –100% Shale 9/1/2012 Tripped out of hole to 5302' noted 75K over pull at shoe. Swabbing continued from 8247' to 5302'. Change out RCD bearing, staged pumps to 700 gpm and pumped 30bbl 13.8 ppg hi viscosity-sweep. There was 100% increase cuttings, cleared cutting from MPD choke and pumped 30bbl 13.8 ppg hi viscosity-sweep. Shakers unload 1-3" diameter cuttings, circulated shakers, clean and begin trip into hole. Ream and wash as needed to 6102. Fighting multiple pack-offs. Stage pumps each pack-off event. 6102' unable to circulate due to lost circulation. Trip out of hole to 5380' casing shoe. Pump a 40bbl 11.8 ppg sweep two times. Both sweeps returned with a 100% increase in cutting which were about 1-3" in diameter. Preparing pits to displace to 12.8 ppg kill weight mud, pumping 50bbls 12.8ppg Hi viscosity Spacer. Gas – 283 Units Fluids- 125 bbl Geology –100% Shale 9/2/2012 Pumped 50bbls 12.8ppg Hi Viscosity-Spacer. Displaced systems to 12.8 ppg kill weight mud. Monitor well 10 min. Static, Pulled MPD RCD trip out of hole with BHA. Laid down BHA, and down load MWD. Test BOPs, upper IBOP failed, repaired and retested and test proven good. Completed BOP test . Pick up clean out BHA, shallow test MWD and trip in hole to 5300’. Installed MPD RCD, prepared to displace active system back to 9.3+ ppg MOBM. Gas – 76 Units Fluids- 0 bbl Geology –100% Shale 9/3/2012 Installed MPD RCD element. Pumped 60 bbls 12.8 ppg high viscosity-spacer. Chased and displaced with 9.3 ppg mineral oil based mud. Reamed and washed to 5,454'. Lost circulation and pulled to the shoe and re-established circulation. Washed and reamed to 6,182'. Staged up to 700 gpm each stand. Packed off at 6,182. Pumped 30 bbl 12.6 ppg high viscosity-sweep with no increase in cuttings at the shakers. Staged pumps to 700 gpm, reamed and washed to 6,414. Pumped 30 bbls high viscosity-sweep with 50% increase in cuttings. Reamed and washed to 6,794'. Circulated 3 bottoms up with heavy returns at the shakers ranging from 1-3" tuff cuttings. Changed out MPD's RCD bearing. Circulated until the shakers cleared up. Washed and reamed to 7,296’. Changed out another RCD bearing. Washing and Reaming to 7,530' in progress. Gas – 283 Units Fluids- 122 bbls Geology – 100%Shale/Trace: Tuff 9/4/2012 After changing out MPD's RCD bearing we washed and reamed to 8,695'. Cleared MPD's flow line and chokes then staged up pumps to circulate a bottoms up. Washed and reamed to 8,915'. Pumped a 12.6 ppg high viscosity sweep. Gas – 250 Units Fluids- 90 bbls Geology – 100%Shale/Trace: Tuff 9/5/2012 Continued washing and reaming from 8,818' to 8,915' with intermittent pack-offs. Pumped a 30 bbl 12.6 ppg high viscosity-sweep. Pulled out of hole from 8,915' to 8,444'. Establish circulation while stepping rates up to 790 gpm. Continued Washing and reaming. Gas – 385 Units Fluids- 240 bbls Geology – 100%Shale/Trace:Tuff 9/6/2012 Continue washing and reaming from 8841' to 8990', packed- off, pulled out of hole to 8940’ staged up to 800 gpm. Circulated while changing out valve seat on mud pump #1. Staged up to 750 gpm, washout mud pump #2 discharge flange, circulated while changing out flange. Staged up to 775 gpm, packed- off, stage up to 500 gpm. Service rig and trouble shooting mud pump #1, changed valve and seat, stage up to 700 gpm. Washed and reamed from 8932' to 8980', service top drive, washed and reamed from 8980' to 9076' pack-off, pulled out of hole to 8944' and staged to 800 gpm. Circulated at 650 gpm while changing out shaker #2 motor. Staged up to 800gpm, washed and reamed from 8944’ to 9170'. Gas – 385 Units Fluids- 240 bbls Geology – 100%Shale/Trace: Tuff 9/7/2012 Continued to wash and ream from 9,170' to 9,290' and packed off. Staged up pumps to 750 gpm. Wash and ream to 9,360'. Service top drive. Function Test BOPE. Wash and ream to 9,392' and packed off. Staged up pumps to 725 gpm. Wash and ream to 9,860' and packed off. Attempt to stage pumps. Gas – 619 Units Fluids- -91 bbls Geology –100% Shale/Trace: Tuff 9/8/2012 Continued to stage up at 9,753'. Packed off. Pulled out of hole to 9,705'. Staged up pumps to 650 gpm. Packed off. Pulled out of hole to 9,361'. Attempted to stage up pumps to 750 gpm. Circulated. Staged up 1/2 bbl increments to 450 gpm with intermittent pack off. Run in hole from 9,361' to 11,450'. Tight from 11,090' to 11,450'. Circulate 2-3 bpm 25-50 RPM, service top drive, trip in hole from 11,450 to 11,600'. Circulated 2 bpm at 50 RPM. Gas – 137 Units Fluids- -83 bbls Geology – 100%Shale/Trace: Tuff 9/9/2012 Wash and ream from 1, 1600’ to 1, 2148’ - 2 bpm 40-60 RPM. Pull out of hole from 1, 2148’ to 5,364'. Stage pumps to 800 gpm. Circulated bottoms up. Service top drive, trim belt on MP #2. Pump 50 bbls 11.6 ppg Hi-viscosity-sweep - minimal increase in cuttings at shakers. Back reaming from 5,364' to 4,610' -750 gpm 120 RPM. Gas – 160 Units Fluids- -62.3 bbls Geology – 100%Shale/Trace: Tuff 9/10/2012 Continued to back ream in 10 3/4" casing from 4,610' to 3,468'. Circulate bottoms up and increase in cuttings noted. Back ream from 3,648' to 1,376’. Pump 50 bbl Hi-viscosity -sweep - no increase in cuttings. Run in hole from 1,376' to 7,221'. Spot 100 bbls Hi-viscosity 12.3 ppg kill weight mud spacer chased with 12.3 ppg kill weight mud to bit. Pull out of hole from 7,221' to 5,369'. Laying in 12.3 ppg Hi- viscosity spacer and 12.3 ppg kill weight mud - pumped 20 bbls per stand. Calculated hole volume of 12.3 ppg kill weight mud in the casing when shut down pumps, 11.9+ ppg kill weight mud at shakers. Rig down MPD. Pull out of hole with 9 7/8" BHA from 5,369' to 520'. Laid down 9 7/8" BHA. Gas – 74 Units Fluids- 0 bbls Geology – 100%Shale/Trace: Tuff 9/11/2012 Finished laying down 9 7/8" BHA. Changed out upper rams to 7 5/8". Rigged up casing equipment. Running 7 5/8" 29.7# casing at 7998'. Gas – 2 Units Fluids- -5 bbls Geology – 100%Shale/Trace: Tuff 9/12/2012 Continued to run in hole with 7 5/8" casing from 7,998' to 11,658'. Gas – 2 Units Fluids- -115 bbls Geology – 100%Shale/Trace: Tuff 9/13/2012 Finished running in hole with 7 5/8", 29.7 # casing to 12,092'. Made up hanger/landing joint- landed at 12,138'. Rigged down Tesco. Rigged up cement head. Cemented casing. Rigged down cement equipment. Laying down 5" drill pipe in mouse hole. Gas – 2 Units Fluids- -781 bbls Geology – 100%Shale/Trace: Tuff 9/14/2012 Finished laying down 5" drill pipe in mousehole. Changed over 7 5/8" rams to 2 7/8" x 5" variables. Test BOPE. Picking up 216 joints of 4" drill pipe- singling in hole. Gas – 2Units Fluids- 0 bbls Geology – 100%Shale/Trace: Tuff 9/15/2012 Finished picking up 216 joints of 4" drill pipe. Pulled out of hole and racked back 4" drill pipe. Made up 6 3/4" clean-out BHA. Currently running in hole with 4" drill pipe at 7,301'. Gas – 6 Units Fluids- 0 bbls Geology – 100%Shale/Trace: Tuff 9/16/2012 Drill cement/shoe from 12,049' to 12,141'- 18 bbl gain. Flow check well- hard shut-in upper blind rams- final pit strap, 52 bbl gain. Circulated bottoms up through choke hold- drill pipe pressure held to 1400 psi, casing pressure 420 psi- saw no gas. Shut-in with drill pipe, held to 750 psi, casing held to 420 psi. Opened choke and flowed to pits to monitor mud weight flow back- initial flow 35 bph, decreased to 15 bph. Shut in 10 min- 100psi. Continued flow at 5 bph- open well- total gain including 52 bbls initial gain 176.1 bbls by strap. Wash from 12,115' to tag at 12,143'- 1680 units gas at 4000 strokes. Gas – 1680 Units Fluids- +176.1 bbls Geology – 100%Shale/Trace: Tuff 9/17/2012 Clean-out rat hole from 12,175' to 12,179'- added LVT to reduce MW in (pumps off- 16 bbl gain). Clean- out rat hole to 12,216'. Perform formation integrity test to 12.5 ppg (13 bbls pumped, 17 back). Pulled out of hole, and performed Madd Pass from 12,183' to 11,680'- hole swabbing 11 bbls. Continued Madd Pass from 11,680' to 11,252'. Pump out of hole from 11,252' to 9,614' (Madd Pass 11,252' to 11,190 and 10,866' to 10,770'). Hole not taking proper fill- circulate bottoms up at 9,614' - no gas. Pump out of hole from 9,517' to 4,988' (Madd Pass 5,566' to 5,373')- hole taking 2/3 displacement. 24 hour gain- 66 bbls. Gas – 1859 Units Fluids- +66 bbls Geology – 100%Shale/Trace: Tuff 9/18/2012 Continued pumping out of hole from 4,988' to 2,101'. Hole started taking correct displacement. Pulled out of hole from 2,101' to 367'- correct hole fill. Laid down 6 3/4" clean-out BHA. Test choke/upper 2 7/8" x 5" variable rams. Made up 6 3/4" Lateral BHA. Run in Hole with same at 9,074'- filling pipe every 25 stands. Plan forward is to reduce mud weight from 9.7+ ppg to 9.3-9.4 ppg at 7 5/8" shoe with LVT. Total gain past 24 hours- 1 bbl. Gas – 47 Units Fluids- +1 bbls Geology – 100%Shale/Trace: Tuff 9/19/2012 Trip in hole to 12,061'. Fill DP. Ream and wash to 12,216'. Drill cement to 12,220'. Circulate. Reduce active system mud weight to 9.4 ppg. Trip out of hole to 11,578'. Monitor well. Circulate/trouble shoot Geo Pilot. Pull out of hole. Lay down BHA #7. Pick up BHA #8 with changed out Geo Pilot. Trip in hole- at 2,747' at report time. Gas – 3221 Units Fluids- 0 bbls Geology – 100%Shale/Trace: Tuff 9/20/2012 Trip in hole to 10,037'. Fill drill pipe and pulse test per 2,500'. Trip in hole to 12,061'. Cut and slip drill line. Ream and wash to 12,220'. Pump 55 bbl hi vis spacer, and displace active system to 9.5 ppg. Monitor well- static. Drill to 12,270'. Perform formation integrity test to 12.5 ppg EMW. Drill to 12,542'. Prepare for Geo Tap test at report time. Gas – 191 Units Fluids- 10 bbls Geology – 80% Sst, 20% Silst 9/21/2012 Drill to 12,542'. Perform Geo Tap test. Drill to 12,735'. Perform Geo Tap test. Drill to 12,832'. Perform Geo Tap test. Drill to 12,928'. Flow check well for 30 minutes- static. Drill to 12,024'. Perform Geo Tap test. 17 bbls gained due to ballooning in last 24 hours. Gas – 283 Units Fluids- 0 bbls Geology – 80% Sst, 20% Silst 9/22/2012 Drill to 13,217'. Perform Geo Tap test. Drill to 13,313'. Perform Geo Tap test. Function test BOPs. Drop carbide marker at 13,406' - calculated hole size, 7.5". Drill to 13,596' at midnight. Gas – 283 Units Fluids- 0 bbls Geology – 80% Sst, 20% Silst 9/23/2012 Drill to 13,698'. Madd Pass 13,653' to 13,597'. Perform Geo Tap test. Drill to 13,795. Perform Geo Tap test. Drill to 14,084'. Perform Geo Tap test. Drill to 14,277'. Perform Geo Tap test. Currently drilling ahead at 14,468'. Gas – 757 Units Fluids- 5 bbls Geology – 40% Sst, 60% Silst 9/24/2012 Drill to 14,660'. Perform Geo Tap test. Drill to 15,142'. Perform Geo Tap test. Currently drilling ahead at 15,540'. Gas – 934 Units Fluids- 5 bbls Geology – 45% Sst, 55% Silst 9/25/2012 Drill to 15,815'. Flow check well- 1.2 bbls/ 5 min. Flow check for another 5 minutes, and gained 0.5 bbls. Drill to 16,489'. Perform Geo Tap test. Drill to 16,701' at midnight. Gas – 714Units Fluids- 8 bbls Geology – 30% Sst, 70% Silst 9/26/2012 Drill to 17,710'. Pump a sweep- 500% increase in cuttings upon return to shakers. Drill to 17,245'. TD called by geologist. Backream to 17,191'. Pump a sweep- 200% increase in cuttings upon return to shakers. Backream to 16,086' at midnight. Gas – 875 Units Fluids- -48 bbls Geology –20% Sst, 80% Silst 9/27/2012 Backream/Madd Pass from 16,298' to 14,550'. Work pipe/stage pumps for pak offs at 15,380' and 14,650'. Backream/Madd Pass to 14,444'. Pump 50 bbls, 11.5 ppg Hi Vis sweep at 14,550'- 20% increase in cuttings upon return to shakers. Trip in hole to 15,014'. Back Ream/Madd Pass to 14,468'. Pump out from 14,949' to 14,468'. Backream/Madd pass to 13,978' at midnight. Gas – 892 Units Fluids- -15 bbls Geology –20% Sst, 80% Silst 9/28/2012 Backream/Mad Pass from 13,749' to 12,061' inside casing shoe. Work through multiple packoffs while backreaming. Pump 55 bbl, 11 ppg hi vis sweep- 200% increase in cuttings upon return to shakers. Circulating until shakers clean up at report time. Gas – 1150 Units Fluids- -20 bbls Geology –20% Sst, 80% Silst 9/29/2012 Pump 33 bbl dry job. Monitor well. Confirm that the well is breathing, then static. Drop 2 3/8" rabbit. Trip out of hole to 6,600' at 20-30 min. per stand due to swabbing. Trip out of hole to 128'. Monitor well- static. Lay down BHA with nukes. Download MWD data. Rig up and test BOPS. Lay down test tools and test equipment at report time. Last 24 hours: +9.3 bbls. Gas – 70 Units Fluids- +9.3 bbls Geology –20% Sst, 80% Silst 9/30/2012 Pick up 21 joints of 4" heavy-weight drill pipe. Circulate 1.5x downpipe volume. Rig-up to run 4.5" P-110 Hydril 521 Frac Completion Liner. Run in hole with 4.5" liner and jewelry. Run in hole to 5,199'. Make-up hanger/packer. Make-up crossover to 4" drill pipe. Run in hole to 5,389'. Circulate 1x liner volume at 2 bpm/200psi. Run in hole to 12,035'. Circulate 1 bottoms up. Stage pumps to 3 bpm. Good returns at shakers. Run in hole to 14,228' with liner at report time. Gas – 60 Units Fluids- -2 bbls Geology –20% Sst, 80% Silst 10/01/2012 Run in hole to 17,190' with frac liner. Stage pumps to 2.5 bpm. Mud treated with CFS-559 wetting agent. Pressure test cement lines. Pump using Halliburton cement pumps. Drop 1.5" ball. Set hanger/packer per Backer Hughes representative. Ball set at 15:45- test 2,200 psi. Drop second 1.5" ball. Ball on seat at 18:25. Line up on Halliburton cement pumps to inflate 10 external casing packers per Baker Hughes program and representative. All 10 external casing packers set at report time. Gas – 304 Units Fluids- -12 bbls Geology –20% Sst, 80% Silst 10/02/2012 Test packer-casing annulus to 3,500 psi for 30 minutes. Circulate 1X drill pipe volume. Single out of hole and lay down 4" drill pipe. Trip in hole with 4" drill pipe with magnet, scraper, and Baker running tool to 11,787'. Pump 55 bbl Hi Vis BaraKlean/Barascrub sweep. Displace casing to 9.8 ppg KCL/NaCl/NaBr brine. Trip out of hole to 7,743'. Slip and cut drill line. Single out of hole and lay down 4" drill pipe. Clear rig floor. Rig-up upper frac completion tools at report time. Gas – 460 Units Fluids- -1 bbls Geology –20% Sst, 80% Silst 10/03/2012 Continue rig-up to run 4.5" completion string. Run in hole with 4.5", 12.6# completion string. Run in hole with same at report time at 8870'. Gas – 12 Units Fluids- 0 bbls Geology –20% Sst, 80% Silst 10/04/2012 Finish running 4.5", 12.6# completion string to 11,983'. Test lower seals- attempt to test upper seals on hanger. Test annulus. Attempt to test upper seals on hanger. Pull hanger- change-out upper hanger seals/o-rings/flush stack. Land hanger. Test lower seals- attempt to test upper seals on hanger- pump graphite to seal leak- test good. Test tubing at 3500 psi for 30 minutes. Test annulus at 3500 psi for 30 minutes. Install BOP valves. Pull trip nipple. Rig down MPD head. Gas – 52 Units Fluids- 0 bbls Geology –20% Sst, 80% Silst Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Ann Corr Cor Solids (lb/100ft2) 13,000 24 hr Max YP API Filt 9.5040 Tuff Gas Breakdown Avg: SstSd Depth 13.8 Lst 200 Sh H2S Data Sample Line Avg: Chromatograph (ppm) 10.0 Silt Siltst ClystCht 129.05 9.05 Nabors 19AC N/A AK-AM-0009646431 13.5 0.700 (ppb Eq)cP PV Size MBT Pioneer Natural Resources ODST-47 1 8-18-2012 4012 North Slope Daily Charges Avg 47.0 230.0 Gas (units) ml/30min Max:Ambient Air Pit Room 89 N/A pH Chlorides GvlCoal N/A Min N/A Avg % N/A 4.6 mg/l N/A AvgMin Max Max 2734 4.1900 N/A 749 80 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1,004 Drilling Ahead Joe Polya/Jerry Hab 35 3963' Flow In (gpm) Current Pump & Flow Data: N/A 124.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)26 21 3910' Depth md Trouble shot gas gear. Issue resolved. Performed another carbide test at 03:15 hrs- 3962' MD 2572' TVD. Returned on time. PWD Drilling All Circ Avg Diam Loggers arrived on location. Rigged up gas gear. Performed carbide test immediately upoon Rig-up. Inconclusive. 10 bbls 13.50'' Max: Hole Condition On Bot Hrs 4012'9.6 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Ann Corr Cor Solids (lb/100ft2) 13,000 24 hr Max YP API Filt 9.5040 Tuff Gas Breakdown Avg: SstSd Depth 13.8 Lst 200 Sh H2S Data Sample Line Avg: Chromatograph (ppm) 10.0 Silt Siltst ClystCht 129.05 9.05 Nabors 19AC N/A AK-AM-0009646431 13.5 0.700 (ppb Eq)cP PV Size MBT Pioneer Natural Resources ODST-47 1 8-18-2012 4012 North Slope Daily Charges Avg 47.0 230.0 Gas (units) ml/30min Max:Ambient Air Pit Room 89 N/A pH Chlorides GvlCoal N/A Min N/A Avg % N/A 4.6 mg/l N/A AvgMin Max Max 2734 4.1900 N/A 749 80 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1,004 Drilling Ahead Joe Polya/Jerry Hab 35 3963' Flow In (gpm) Current Pump & Flow Data: N/A 124.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)26 21 3910' Depth md Trouble shot gas gear. Issue resolved. Performed another carbide test at 03:15 hrs- 3962' MD 2572' TVD. Returned on time. PWD Drilling All Circ Avg Diam Loggers arrived on location. Rigged up gas gear. Performed carbide test immediately upoon Rig-up. Inconclusive. 10 bbls 13.50'' Max: Hole Condition On Bot Hrs 4012'9.6 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 7 bbls 13.56'' Max: Hole Condition On Bot Hrs 5389'16.16 Drilled ahead from 4012' MD. TD'd surface hole at 5389' MD at 2251 hrs. Pumped high visc sweep at 2300 hrs. 10% increase noted at shakers. Pumped carbide pill shortly after. Carbide returned 80 strokes late for an average open hole size PWD Drilling All Circ Avg Diam md of 13.56". N/A Max @ ft Current R.O.P. (ft/hr) Gas (units)026 4536' Depth 1377 TD'd Surface Hole Joe Polya/Jerry Hab 55 5293' Flow In (gpm) Current Pump & Flow Data: N/A N/A N/A N/A N/A N/A Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % N/A 6.9 mg/l N/A AvgMin Max MaxN/A pH Chlorides GvlCoal N/A Min N/A Avg Gas (units) ml/30min Max:Ambient Air Pit Room 65 North Slope Daily Charges Avg 61.0 240.0 Pioneer Natural Resources ODST-47 2 8-19-2012 5389 Nabors 19AC N/A AK-AM-0009646431 13.5 0.700 (ppb Eq)cP PV Size MBT 89.35 9.35 41.15 11.8 Silt Siltst ClystCht Chromatograph (ppm) H2S Data Sample Line Avg: 5389' ShSd Depth 11.6 Lst 200 Sst 27 Tuff Gas Breakdown Avg: API Filt 9.70 Ann Corr Cor Solids (lb/100ft2) 13,500 24 hr Max YP Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 7 bbls 13.68'' Max: Hole Condition On Bot Hrs 5389'0 Tripped out of the hole to 4,912'. Monitored the well. Pumped a dry job and continued to pull out of the hole to BHA and cleaned the clay off and tripped back in to 4,794'. Wiped tight spots, reamed/washed down to 5,389'. Pumped High viscosity sweep with PWD Drilling All Circ Avg Diam md carbide. Sweep arrived 145 strokes early and carbide arrived 245 strokes late for an average open hole diameter of 13.68". Circulated 3 bottoms up and backreamed from 5,103' to 4,817'. Unable to pull on elevators. Tripped in to 5,389'. Back reaming.p N/A Max @ ft Current R.O.P. (ft/hr) Gas (units)713 N/A Depth 0 Washing/Reaming Joe Polya/Jerry Hab 82 N/A Flow In (gpm) Current Pump & Flow Data: N/A N/A N/A N/A N/A N/A Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % N/A 8.3 mg/l N/A AvgMin Max MaxN/A pH Chlorides GvlCoal N/A Min N/A Avg Gas (units) ml/30min Max:Ambient Air Pit Room 62 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 3 8-20-2012 5389 Nabors 19AC N/A AK-AM-0009646431 13.5 0.700 (ppb Eq)cP PV Size MBT 119.55 9.55 41.15 13.0 Silt Siltst ClystCht Chromatograph (ppm) H2S Data Sample Line Avg: 5389' 2381' ShSd Depth 11.8 Lst 3,008'200 Sst 31 Tuff Gas Breakdown Avg: API Filt 9.40 Ann Corr Cor Solids (lb/100ft2) 13,500 24 hr Max YP Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air Ann Corr Cor Solids (lb/100ft2) 13,500 24 hr Max YP API Filt 9.4033 Tuff Gas Breakdown Avg: SstSd Depth 11.4 Lst 240 Sh H2S Data Sample Line Avg: Chromatograph (ppm) 13.0 Silt Siltst ClystCht 10.750" Casing 149.65 9.65 Nabors 19AC N/A AK-AM-0009646431 10.75 (ppb Eq)cP PV Size MBT Pioneer Natural Resources ODST-47 4 8-21-2012 5389 North Slope Daily Charges Avg N/A N/A Gas (units) ml/30min Max:Ambient Air Pit Room 63 N/A pH Chlorides GvlCoal N/A Min N/A Avg % N/A 9.1 mg/l N/A AvgMin Max Max N/A N/A N/A N/A N/A Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0 Running 10 3/4" Casing Joe Polya/Jerry Hab 16 N/A Flow In (gpm) Current Pump & Flow Data: N/A N/A Max @ ft Current R.O.P. (ft/hr) Gas (units)01 N/A Depth md Ave Gas- 1 Max Gas- 16 Midnight losses- 3 bbls Back reamed and circulated, staging pumps up to 6.5 bbls/min. Running in to 4,597' at report time. p PWD Drilling All Circ Avg Diam 5:00 AM Losses- 28.5 bbls a tight spot at 1,681'. Tripped out to 636 and began laying down BHA. Monitored the well. Static. Laid down MWD tools and rigged up to run 10 3/4" casing. Had issues with casing spiders. Repaired. Continued running the hole. Encountered tight spot at 2,070'. Continued back reaming from 3,012'. Circulated 1 1/2 bottoms up and tripped out of the hole to 1,588'. Worked through 7 bbls 13.68'' Max: Hole Condition On Bot Hrs 5389'0 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:* 10000 units = 100% Gas In Air 7 bbls 13.68'' Max: Hole Condition On Bot Hrs 5389'0 4:00 AM Losses- 15.0 bbls head. Nippling down BOP stack at report time. Continued to run in hole with 10.75" csg to 5380' MD. Installed cement head, pumped cement, rigged down cement PWD Drilling All Circ Avg Diam md Ave Gas- 1 Max Gas- 16 Midnight losses- 0 bbls p N/A Max @ ft Current R.O.P. (ft/hr) Gas (units)010 N/A Depth 0 Nipple up BOP Joe Polya/Jerry Hab 28 N/A Flow In (gpm) Current Pump & Flow Data: N/A N/A N/A N/A N/A N/A Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % N/A 8.3 mg/l N/A AvgMin Max MaxN/A pH Chlorides GvlCoal N/A Min N/A Avg Gas (units) ml/30min Max:Ambient Air Pit Room 45 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 5 8-22-2012 5389 Nabors 19AC N/A AK-AM-0009646431 (ppb Eq)cP PV Size MBT N/A 119.55 9.55 12.0 Silt Siltst ClystCht Chromatograph (ppm) H2S Data Sample Line Avg: ShSd Depth 12.3 Lst 240 Sst 20 Tuff Gas Breakdown Avg: API Filt 9.30 Ann Corr Cor Solids (lb/100ft2) 13,500 24 hr Max YP Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Tripped in the hole with clean BHA to 5163'. Washed and rotated down. Drilled shoe track to 5389'. Displaced spud mud to 9.55 Mineral Oil Based mud. Drilled out to 5409' and performed an FIT to 12.5 ppg estimated mud weight. Tripped out of the hole and laid down BHA. Picked up Geo Pilot and BHA for run 400. Shallow pulse tested MWD tools. Broke in Geo Pilot at 3401'. Tripped in to 5234' without issue. Slipped and cut drill line. Removed trip nipple and installed MPD's RCD Element. Preparing to drill ahead at report time. Max Gas = 0 U , 0 bbls lost down hole 4am - 4am. PWD Drilling All Circ Avg Diam 10 bbls 9.875 Max: Hole Condition On Bot Hrs 5409'N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)0 N/A N/A N/A Depth Ann Corr 0' TIH R.Klepzig/J.Cortez N/A N/A Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft N/A N/A N/A N/AN/A Avg N/A N/A Total Charges: 13.6 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 6 08/24/2012 5409' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 0.32 5409' 70.7/14.0 HDBS FX65 5409' 149.55 9.55 84 400 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ David Mckechnie (lb/100ft2) 31.9 Min N/A Avg 14 ASG N/A % 24 hr Max YP AgNO3 0.09 0Avg: C3C2 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Once MPD's RCD was installed, we began drilling ahead with an 11.5 ppg EMW with MPD and 9.5 ppg mud weight Drilled out to 6,537' and circulated a bottoms up to reduce ECD. Drilling ahead to 7180' at report time. Max Gas = 161 U , 8 bbls lost down hole 4am - 4am. PWD Drilling All Circ Avg Diam 10 bbls 9.875 Max: Hole Condition On Bot Hrs 7180'17.07 161 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)143 N/A 90 5694' Depth Ann Corr 1771' Drilling Ahead R.Klepzig/J.Cortez 161 7100' Flow In (gpm) Current Pump & Flow Data: 12.15 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3340 3.517 N/A 12.1511.13 Avg 653 184 Total Charges: 13.1 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room 202 Chromatograph (ppm) 8 C4n 6 0 09 Pioneer Natural Resources ODST-47 Oooguruk 7 08/25/2012 7180' North Slope 7100 Daily Charges Avg N/A 236.0 11.55 Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 5409' 70.7/14.4 HDBS FX65 7180' 339.50 9.50 72 400 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ David Mckechnie (lb/100ft2) 2.6493.5 Min 11.13 Avg 20 ASG 11.55 % 24 hr Max YP AgNO3 0.08 0Avg: 90 17832 C3C2 10 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: 9010 C3C2 11.55 % 24 hr Max YP AgNO3 0.80 (lb/100ft2) 2.6283.7 Min 11.16 Avg 21 ASG Kerry Garner/ David Mckechnie C5iC4iC5n Tuff 0 GrvlCoal Max: 70.0/15.0 HDBS FX65 9250'319.50 9.90 77 400 5409' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water 11.56 North Slope Daily Charges Avg 135.0 288.0 Pioneer Natural Resources ODST-47 Oooguruk 8 08/26/2012 9250' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 13.2 N/A 11.8411.16 Avg 650 185 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3689 3.517 2070' Reaming/Short Trip J. Polya/J.Cortez 404 8116' Flow In (gpm) Current Pump & Flow Data: 11.93 159 7500' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)84 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 9250'18.23 24 hr Recap: Drilled ahead from 7,180' to 9,250' with 11.5 ECD, to the top of the Brookian 2B. Pumped a 55 bbls high visc sweep at 00:52. Sweep arrived 900 strokes early with a 200% increase in cuttings. Performing check trip to the shoe at report time. Max Gas = 404 U , 60 bbls lost down hole 4am - 4am. PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Performed check trip. Washed through a tight spot at 6,726' and packed off. Washed down to 9,198' and staged pumps up to 650 GPM. 26 bbls lost over the shakers resulting from cold viscous mud. Drilling ahead to 9942' at report time Max Gas = U , 54 bbls lost down hole 12am - 12am. PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 9942'7.04 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)84 125.0 131 9868' Depth Ann Corr 692' Reaming/Short Trip J. Polya/J.Cortez 376 9275' Flow In (gpm) Current Pump & Flow Data: 11.76 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3689 3.517 N/A 11.7211.21 Avg 650 185 Total Charges: 13.7 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 9 08/27/2012 9942' North Slope Daily Charges Avg 85.0 192.0 11.50 Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 5409' 69.5/15 HDBS FX65 9942' 309.55 9.60 80 400 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ David Mckechnie (lb/100ft2) 2.6013.9 Min 11.21 Avg 13/19/26 ASG 11.51 % 24 hr Max YP AgNO3 0.90 0Avg: 100 C3C2 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: 100 C3C2 11.70 % 24 hr Max YP AgNO3 0.80 (lb/100ft2) 2.6143.5 Min 11.63 Avg 17 ASG Kerry Garner/ David Mckechnie C5iC4iC5n Tuff tr 0 GrvlCoal Max: 69.9/15.0 HDBS FX65 11600' 279.50 9.50 70 400 5409' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water 10.58 North Slope Daily Charges Avg 70.0 211.0 Pioneer Natural Resources ODST-47 Oooguruk 10 08/28/2012 11600' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 13.3 N/A 11.9311.63 Avg 645 184 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4000 3.517 1658' Reaming/Short Trip J. Polya/J.Cortez 212 11384' Flow In (gpm) Current Pump & Flow Data: 11.93 90 10246' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)115 145.0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 11600'18.94 24 hr Recap: Drilled ahead from 9,942' to 11095. Changed out MPD's RCD element. Drilling ahead to 11,600' at 145 ROP with a background gas of 115 units at report time. Max Gas = 212 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Drilled ahead from 11,210' until a problem was encountered with the Hammer Mill. Repaired and drilled ahead to T.D. at 12,220'. Pumped High Visc/High Weight Sweep. Returned on time with 100% increase in cuttings. Circulated 7 bottoms up until the shakers were clean and mud properties stabilized. Pumped 3 stands out of the hole circulating 1 bottoms up for each stand. Pumped another High visc/High weight Sweep at 12,037'. Returned 90 Strokes early with 200+% increase in cuttings at the shakers. Will continue circulating until midnight and beging tripping out to the shoe. Max Gas = 212 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'10.33 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)115 34.0 90 11390' Depth Ann Corr 620' Reaming/Short Trip J. Polya/J.Cortez 212 11383' Flow In (gpm) Current Pump & Flow Data: 11.99 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4120 3.517 N/A 11.7811.56 Avg 647 185 Total Charges: Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 11 08/28/2012 12220' North Slope Daily Charges Avg 123.0 187.0 11.01 Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 5409' HDBS FX65 12220' 9.80 9.80 400 C5iC4iC5n Tuff tr 0 GrvlCoal Max: Kerry Garner/ David Mckechnie (lb/100ft2) Min 11.55 Avg ASG 11.26 % 24 hr Max YP AgNO3 0Avg: 100 C3C2 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: 100 C3C2 11.70 % 24 hr Max YP AgNO3 (lb/100ft2) Min 11.63 Avg ASG Kerry Garner/ David Mckechnie C5iC4iC5n Tuff tr 0 GrvlCoal Max: HDBS FX65 11210' 9.50 9.50 400 5409' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water 10.58 North Slope Daily Charges Avg 66.0 211.0 Pioneer Natural Resources ODST-47 Oooguruk 10 08/28/2012 11210' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids N/A 11.9311.63 Avg 645 184 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4000 3.517 1268' Reaming/Short Trip J. Polya/J.Cortez 150 10796' Flow In (gpm) Current Pump & Flow Data: 11.93 82 10246' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)82 140.0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 11210'15.92 24 hr Recap: Drilled ahead from 9,942' to 11095. Changed out MPD's RCD element. Drilling ahead to 11,210' at 140 ROP with a background gas of 82 units at report time. Max Gas = 150 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Began tripping out of the hole on elevators. Pumped a sweep inside casing at 5,060'. 60% increase in cuttings noted at the shakers. Continued pumping out of the hole to 1302. Began trip back to the casing shoe and pumped another sweep with no increase seen at the shakers. Cirulated the sweep out of the hole and slip/cut drill line. Function tested BOP's from 22:25 to 22:50. Resumed tripping into the hole. Currently tripping in on elevators at report time. Max Gas = 39 U , 74 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)11 N/A 14 N/A Depth Ann Corr 0' TIH on Elevators J. Polya/J.Cortez 39 Circ Flow In (gpm) Current Pump & Flow Data: 18.11 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4120 3.517 N/A N/AN/A Avg N/A N/A Total Charges: 13.4 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 12 08/28/2012 12220' North Slope Daily Charges Avg N/A N/A 11.50 Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 5409' 69.8/15.0 HDBS FX65 12220'279.80 9.88 71 400 C5iC4iC5n Tuff tr 0 GrvlCoal Max: Kerry Garner/ David Mckechnie (lb/100ft2) 2.8703.4 Min 13.14 Avg 16 ASG N/A % 24 hr Max YP AgNO3 0.80 0Avg: 100 C3C2 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: 100 C3C2 11.26 % 24 hr Max YP AgNO3 0.80 (lb/100ft2) 2.8103.6 Min 11.55 Avg 15 ASG Kerry Garner/ David Mckechnie C5iC4iC5n Tuff tr 0 GrvlCoal Max: 70.0/15.0 HDBS FX65 12220' 299.80 9.80 69 400 5409' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water 11.01 North Slope Daily Charges Avg 123.0 187.0 Pioneer Natural Resources ODST-47 Oooguruk 11 08/28/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 13.2 N/A 11.7811.56 Avg 647 185 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4120 3.517 620' Reaming/Short Trip J. Polya/J.Cortez 212 11383' Flow In (gpm) Current Pump & Flow Data: 11.99 90 11390' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)14 34.0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'10.33 24 hr Recap: Drilled ahead from 11,210' until a problem was encountered with the Hammer Mill at 12044. Repaired and drilled ahead to T.D. at 12,220'. Pumped High Visc/High Weight Sweep. Returned on time with 100% increase in cuttings. Circulated 7 bottoms up until the shakers were clean and mud properties stabilized. Pumped 3 stands out of the hole circulating 1 bottoms up for each stand. Pumped another High visc/High weight Sweep at 12,037'. Returned 90 Strokes early with 200+% increase in cuttings at the shakers. Continued circulating until 23:35. Currently tripping out on elevators to the shoe. Max Gas = 212 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.70 (lb/100ft2) 2.7793.6 Min 11.84 Avg 18 ASG Kerry Garner/ David Mckechnie C5iC4iC5n Tuff tr 0 GrvlCoal Max: 74.5/12.0 HDBS FX65 12220'199.40 9.40 65 400 5409' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water 10.22 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 13 08/30/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 12.0 N/A N/AN/A Avg 604 172 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3647 3.517 0' Reaming/Short Trip R. Klepzig/J.Cortez 1231 Circ Flow In (gpm) Current Pump & Flow Data: 13.24 90 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)94 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Tripped into the to 9,293'. Began rotated while tripping to 9,578' Staging pumps up to 575 GPM while fighting pack-offs. Staged up to 600 GPM and circulated 2 bottoms up. Ramed/washed down to 9,958' fighting multiple pack-offs- Lost circulation. Staged pumps up to 610 GPM and cleared an ubstruction in MPD's flow line. Reaming and washing down to 10,721 fighting pack-offs at report time. Max Gas = 21,231 U , 175 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.70 (lb/100ft2) 2.7793.6 Min 11.84 Avg 18 ASG Kerry Garner/ David Mckechnie C5iC4iC5n Tuff 0 GrvlCoal Max: 74.5/12.0 HDBS FX65 12220'199.40 9.40 65 400 5409' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water 10.22 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 13 08/30/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 12.0 N/A N/AN/A Avg 604 172 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3647 3.517 0' Reaming/Short Trip R. Klepzig/J.Cortez 1231 Circ Flow In (gpm) Current Pump & Flow Data: 13.24 90 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)94 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Tripped into the hole to 9,293'. Began rotating while tripping to 9,578' Staging pumps up to 575 GPM while fighting pack-offs. Staged up to 600 GPM and circulated 2 bottoms up. Reamed/washed down to 9,958' fighting multiple pack-offs- Lost circulation. Staged pumps up to 610 GPM and cleared an obstruction in MPD's flow line. Reamed and washed down to 10,836'. MPD maintenance at report time. Max Gas = 1,231 U , 175 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Tripped into the hole to 9,293'. Began rotating while tripping to 9,578' Staging pumps up to 575 GPM while fighting pack-offs. Staged up to 600 GPM and circulated 2 bottoms up. Reamed/washed down to 9,958' fighting multiple pack-offs- Lost circulation. Staged pumps up to 610 GPM and cleared an obstruction in MPD's flow line. Reamed and washed down to 10,836'. MPD maintenance at report time. Max Gas = 1,231 U , 175 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)94 N/A 90 N/A Depth Ann Corr 0' Reaming/Short Trip R. Klepzig/J.Cortez 1231 Circ Flow In (gpm) Current Pump & Flow Data: 13.24 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3647 3.517 N/A N/AN/A Avg 604 172 Total Charges: 12.0 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 13 08/31/2012 12220' North Slope Daily Charges Avg N/A N/A 10.22 Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 5409' 74.5/12.0 HDBS FX65 12220'199.40 9.40 65 400 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ David Mckechnie (lb/100ft2) 2.7793.6 Min 11.84 Avg 18 ASG N/A % 24 hr Max YP AgNO3 0.70 0Avg: C3C2 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.30 (lb/100ft2) 2.6744.4 Min 11.65 Avg 19 ASG Kerry Garner/ David Mckechnie C5iC4iC5n Tuff 0 GrvlCoal Max: 76.0/10.0 HDBS FX65 12220' 329.30 9.30 84 400 5409' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water 9.53 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 14 09/1/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 12.7 N/A N/AN/A Avg N/A N/A Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft N/A 3.517 0' Trip out to shoe R. Klepzig/J.Cortez 289 Circ Flow In (gpm) Current Pump & Flow Data: 13.19 62 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)9 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Reamed and washed down to 10,908'. Fought multiple pack-offs. Staged pumps up to 600 GPM after each pack-off event. Circulated bottoms up as needed. Closed annular bag to free up blockage in MPD chokes. Got MPD back online. Attempted to stage pumps back up and lost total circulation. Tripped out inside the shoe to 5,234'. Replacing RCD element at report tim Max Gas = 289 U , 140 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Tripped out of the hole to 5,302'. 75K overpull at the shoe. Swabbed 8,247' to 5,302'. Staged pumps up to 700 GPM. Pumped 30 bbl 13.8 ppg high viscosity sweep at 06:00 with 100% increase at the shakers, unloading 1-3" cuttings. Circulated until the shakers were clean. Tripped in the hole and reamed/washed as needed to 6,102' fighting multiple pack-offs.Staged pumps up after each pack-off event. Lost circulation. Tripped out to the casing shoe at 5,380' and pumped 2 11.8 ppg sweeps. Both sweeps returned with 100% increase in 1-3" cuttings. with 12.8 ppg kill weight mud, pumped a 500 12.8 ppg high viscosity spacer. Removed RCD element and installed the trip nipple. Tripping out of the hole at report time. Max Gas = 283 U , 125 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)0 N/A 62 N/A Depth Ann Corr 0' Trip out hole R. Klepzig/J.Cortez 283 Circ Flow In (gpm) Current Pump & Flow Data: 14.00 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft N/A 3.517 N/A N/AN/A Avg N/A N/A Total Charges: 12.7 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 14 09/2/2012 12220' North Slope Daily Charges Avg N/A N/A 11.22 Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 5409' 76.0/10.0 HDBS FX65 12220' 259.40 9.40 80 400 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ David Mckechnie (lb/100ft2) 2.7774.3 Min 12.59 Avg 16 ASG N/A % 24 hr Max YP AgNO3 0.05 0Avg: C3C2 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Pumped 50 bbl high viscosity spacer and displaced system to 12.8 kill weight mud and monitored the well for 10 minutes. Static. Pulled MPD's RCD element and tripped out of the hole. Laid down BHA and downloaded MWD tools. Tested BOPs. Picked up BHA for a clean-out run. Shallow tested MWD. Tripped in the hole to 5,300. Installed MPD's RCD element. Washing/Reaming in the hole at report time at 550 GPM. Max Gas = 76 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)19 N/A 9 N/A Depth Ann Corr 0' Washing/Reaming R. Klepzig/J.Cortez 76 Circ Flow In (gpm) Current Pump & Flow Data: 14.50 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft N/A 3.517 18 N/A N/AN/A Avg 550 157 Total Charges: 0-0-NO-A-X-I-NO-TD 21.1 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 15 09/3/2012 12220' North Slope Daily Charges Avg 9.875 2.663 N/A N/A 12.20 Nabors 19AC N/A AK-AM-0009646431 9.875 1.178 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 500 MXL-1 12220' 6811'5409' 62.0/15.0 HDBS FX65 12220' 12220' 3012.80 12.80 70 400 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ David Mckechnie (lb/100ft2) 3.8344.0 Min 12.76 Avg 21 ASG N/A % 24 hr Max YP AgNO3 0.50 140 0Avg: C3C2 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.10 (lb/100ft2) 2.8004.0 Min 12.43 Avg 21 ASG Kerry Garner/ David Mckechnie C5iC4iC5n Tuff 0 GrvlCoal Max: 74.3/12.0 MXL-1 12220' 299.40 9.40 80 500 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water 11.18 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 16 09/4/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 12.1 N/A N/AN/A Avg 645 184 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft N/A 3.517 0' Washing/Reaming R. Klepzig/J.Cortez 283 Circ Flow In (gpm) Current Pump & Flow Data: 14.17 27 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)45 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Installed MPD's RCD element. Pumped 60 bbls 12.8 ppg high visc spacer. Chased and displaced with 9.3 ppg mineral oil based mud. Reamed and washed to 5,454'. Lost circulation and pulled to the shoe and re-established circulation. Washed and reamed to 6,182'. Staged up to 700 gpm each stand. Packed off at 6,182. Pumped 30 bbl 12.6 ppg high vis sweep with no increase in cuttings at the shakers. Staged pumps to 700 gpm, reamed and washed to 6,414. Pumped 30 bbls high vis sweep with 50% increase in cuttings. Reamed/Washed to 6,794'. Circulated 3 bottoms up with heavy returns at the shakers ranging from 1-3" tuff cuttings. Changed out MPD's RCD bearing Circulated until the shakers cleared up. Washed/reamed to 7,296' . Changed out another RCD bearing. Washing/Reaming to 7,530' at report time. Max Gas = 283 U , 122 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: After changing out MPD's RCD bearing we washed and reamed to 8,695'. Cleared MPD's flow line and chokes then staged up pumps to circulate a bottoms up. Washed and reamed to 8,915'. Pumping 12.6 ppg high viscosity sweep at report time. Max Gas = 250 U , 90 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)80 N/A 67 N/A Depth Ann Corr 0' Washing/Reaming R. Klepzig/J.Cortez 250 Circ Flow In (gpm) Current Pump & Flow Data: 13.53 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft N/A 3.517 N/A N/AN/A Avg 600 171 Total Charges: 13.3 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 17 09/5/2012 12220' North Slope Daily Charges Avg N/A N/A 11.63 Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 69.7/15.0 MXL-1 12220' 879.70 9.70 87 500 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ David Mckechnie (lb/100ft2) 2.8024.0 Min 12.41 Avg 21 ASG N/A % 24 hr Max YP AgNO3 0.05 0Avg: C3C2 Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.45 (lb/100ft2) 2.7412.5 Min 11.90 Avg 27 ASG Kerry Garner/ David Mckechnie C5iC4iC5n Tuff 0 GrvlCoal Max: 72.0/12.5 MXL-1 12220' 389.65 9.65 94 500 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water 11.01 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 18 09/6/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 13.9 N/A N/AN/A Avg 420 120 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft N/A 3.517 0' Washing/Reaming R. Klepzig/J.Cortez 385 Circ Flow In (gpm) Current Pump & Flow Data: 14.45 56 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)102 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Continued washing and reaming from 8,818' to 8,915' with intermittent pack-offs. Pumped a 30 bbl 12.6 ppg high viscosity sweep. Pulled out of the hole from 8,915' to 8,444'. Establish circulation while stepping rates up to 790 gpm. Washing and reaming to 8,940 at report time Max Gas = 385 U , 240 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer: Report #: Well: Date: Area: 04:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Continued to wash/ream from 8,841-8,990' and packed off. Pulled out of the hole to 8,940. Staged up pumps to 800 gpm. Circulated while repairing #1 mud pump. Packed off. Staged up to 500 gpm. Serviced top drive and washing/reaming to 9,275' at report time. Max Gas = 285 U , 46 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)17 N/A 28 N/A Depth Ann Corr 0' Washing/Reaming R. Klepzig/J.Cortez 285 Circ Flow In (gpm) Current Pump & Flow Data: 16.62 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft N/A 3.517 N/A N/AN/A Avg 739 211 Total Charges: 14.3 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 19 09/7/2012 12220' North Slope Daily Charges Avg N/A N/A 11.22 Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 71.5/13.0 MXL-1 12220' 369.60 9.60 107 500 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ David Mckechnie (lb/100ft2) 2.6920.9 Min 11.83 Avg 24 ASG N/A % 24 hr Max YP AgNO3 0.40 0Avg: C3C2 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.35 (lb/100ft2) 2.6240.6 Min 11.73 Avg 23 ASG Kerry Garner/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 72.5/12.0 MXL-1 12220'349.50 9.50 108 500 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water 11.27 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 20 09/8/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 14.7 N/A N/AN/A Avg 350 100 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 1520 3.517 0' Washing/Reaming R. Klepzig/J.Cortez 619 Circ Flow In (gpm) Current Pump & Flow Data: 14.05 36 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)15 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Continued to wash/ream from 9,170' - 9,290' and packed off. Staged up pumps to 750 gpm. Wash/ream to 9,360'. Service TD. Function Test BOPE. Wash/ream to 9,392' and packed off. Staged up pumps to 725 gpm. Wash/ream to 9,860' and packed off. Attempt to stage pumps. Max Gas = 619 U , 91 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.30 (lb/100ft2) 2.6340.5 Min 11.53 Avg 24 ASG Kerry Garner/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 73.0/11.5 MXL-1 12220'409.50 9.50 130 500 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water 0.00 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 21 09/9/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 14.9 N/A N/AN/A Avg 84 24 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 850 3.517 0' RIH to TD R. Klepzig/J.Cortez 137 Circ Flow In (gpm) Current Pump & Flow Data: 12.80 21 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)66 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Continued to stage up at 9,753'. Packed off. Pulled out of hole to 9,705'. Staged up pumps to 650 gpm. Packed off. Pulled out of hole to 9,361'. Atempted to stage up pumps to 750 gpm. Circulated. Staged up 1/2 bbl increments to 450 gpm with intermittent pack off. Run in hole from 9,361' to 11,450'. Tight from 11,090' to 11,450'. Circulate 2-3 bpm 25-50 RPM. Service top drive. Run in hole from 11,450 to 11,600'. Circulated 2 bpm 50 RPM. Run in hole at report time. Max Gas = 137 U , 83 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Wash/ream from 1,1600' to 1,2148' - 2 bpm 40-60 RPM. Pull out of hole from 1,2148' to 5,364'. Stage pumps to 800 gpm. Circulated bottoms up. Service top drive - trim belt on MP #2. Pump 50 bbls 11.6 ppg Hi-vis sweep - minimal increase in cuttings at shakers. Backreaming from 5,364' to 4,610' -750 gpm 120 RPM. Max Gas = 160 U , 62.3 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)6 N/A 39 N/A Depth Ann Corr 0' Backreaming R. Klepzig/J.Cortez 160 Circ Flow In (gpm) Current Pump & Flow Data: 13.24 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2511 3.517 N/A N/AN/A Avg 743 211 Total Charges: 15.3 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 22 09/10/2012 12220' North Slope Daily Charges Avg N/A N/A 12.26 Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 72.0/12.0 MXL-1 12220'389.50 9.60 107 500 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ Andrew Bongard (lb/100ft2) 2.6510.5 Min 12.71 Avg 20 ASG N/A % 24 hr Max YP AgNO3 0.25 0Avg: C3C2 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Continued to backream in 10 3/4" casing from 4,610' to 3,468'- circulate bottoms up- increase in cuttings. Backream from 3,648' to 1,376' - pump 50 bbl Hi-vis sweep - no increase in cuttings. Run in hole from 1,376' to 7,221'. Spot 100 bbls Hi-vis 12.3 ppg KWM spacer chased with 12.3 ppg KWM to bit. Pull out of hole from 7,221' to 5,369' - laying in 12.3 ppg Hi-vis spacer and 12.3 ppg KWM - pumped 20 bbls/std. Pump calculated hole volume of 12.3 ppg KWM in the casing when shut down pumps 11.9+ ppg KWM at shakers. Rig down MPD. Pull out of hole with 9 7/8" BHA from 5,369' to 520'. Laid down 9 7/8" BHA at report time. Max Gas = 74 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)0 N/A 11 N/A Depth Ann Corr 0' Pull out of hole R. Klepzig/J.Cortez 74 Circ Flow In (gpm) Current Pump & Flow Data: 18.81 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 6 3.517 N/A N/AN/A Avg 0 0 Total Charges: 23.2 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 23 09/11/2012 12220' North Slope Daily Charges Avg N/A N/A 12.90 Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 4.4 MXL-1 12220'5212.35 12.30 224 500 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ Andrew Bongard (lb/100ft2) 3.4110.6 Min 14.87 Avg 25 ASG N/A % 24 hr Max YP AgNO3 0.15 0Avg: C3C2 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.20 (lb/100ft2) 2.6450.5 Min N/A Avg 18 ASG Kerry Garner/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 73.5/11.0 MXL-1 12220'349.50 9.50 128 500 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water N/A North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 24 09/12/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 14.8 N/A N/AN/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 40 3.517 0' Running 7 5/8" Csg R. Klepzig/J.Cortez 2 Circ Flow In (gpm) Current Pump & Flow Data: N/A 0 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)0 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Finished laying down 9 7/8" BHA. Changed out upper rams to 7 5/8". Rigged up casing equipment. Running 7 5/8" 29.7# casing at report time at 7998'. Max Gas = 2 U , 5 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Continued to run in hole with 7 5/8" casing from 7,998' to 11,658' at report time. Max Gas = 2 U , 115 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)0 N/A 0 N/A Depth Ann Corr 0' Running 7 5/8" Csg R. Klepzig/J.Cortez 2 Circ Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 40 3.517 N/A N/AN/A Avg 0 0 Total Charges: 15.4 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 25 09/13/2012 12220' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 73.0/11.0 MXL-1 12220'429.50 9.55 128 500 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ Andrew Bongard (lb/100ft2) 2.6280.4 Min N/A Avg 20 ASG N/A % 24 hr Max YP AgNO3 0.15 0Avg: C3C2 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.15 (lb/100ft2) 2.6280.4 Min N/A Avg 20 ASG Kerry Garner/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 73.0/11.0 MXL-1 12220'359.55 9.55 156 500 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water N/A North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 26 09/14/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 15.4 N/A N/AN/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.517 0' Lay down 5" DP R. Klepzig/J. Haberthur 51 Circ Flow In (gpm) Current Pump & Flow Data: N/A 2 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)0 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Finished running in hole with 7 5/8", 29.7 # casing to 12,092'. Made up hanger/landing joint- landed at 12,138'. Rigged down Tesco. Rigged up cement head. Cemented casing. Rigged down cement equipment. Laying down 5" drill pipe in mouse hole at report time. Max Gas = 51 U , 781 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Finished laying down 5" drill pipe in mousehole. Changed over 7 5/8" rams to 2 7/8" x 5" variables. Test BOPE. Picking up 216 joints of 4" drill pipe- singling in hole at report time. Max Gas = 2 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 15 bbls 9.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)0 N/A 0 N/A Depth Ann Corr 0' Pick up 4" DP R. Klepzig/J. Haberthur 2 Circ Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.517 N/A N/AN/A Avg 0 0 Total Charges: 15.3 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 27 09/15/2012 12220' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009646431 9.875 2.663 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 73.0/11.0 MXL-1 12220'399.55 9.55 196 500 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ Andrew Bongard (lb/100ft2) 2.6270.5 Min N/A Avg 23 ASG N/A % 24 hr Max YP AgNO3 0.15 0Avg: C3C2 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.15 (lb/100ft2) 2.6470.5 Min N/A Avg 19 ASG Kerry Garner/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 73.5/11.0 Mill Tooth 12220'309.55 9.50 189 600 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 6.75 0.746 cP PV Size NAP/Water N/A North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 28 09/16/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 14.8 N/A N/AN/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 10 3.517 0' RIH w/ 6 3/4" Clean-out BHA R. Klepzig/J. Haberthur 6 Circ Flow In (gpm) Current Pump & Flow Data: N/A 1 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)0 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Finished picking up 216 joints of 4" drill pipe. Pulled out of hole and racked back 4" drill pipe. Made up 6 3/4" clean-out BHA. Currently running in hole with 4" drill pipe at 7,301' at report time. Max Gas = 6 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 0 bbls 6.875 Max: Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Drill cement/shoe from 12,049' to 12,141'- 18 bbl gain. Flow check well- hard shut-in upper blind rams- final pit strap, 52 bbl gain. Circulated bottoms up through choke hold- drill pipe pressure held to 1400 psi, casing pressure 420 psi- saw no gas. Shut-in with drill pipe, held to 750 psi, casing held to 420 psi. Open choke and flowed to pits to monitor mud weight flow back- initial flow 35 bph, decreased to 15 bph. Shut in 10 min- 100psi. Continued flow at 5 bph- open well- total gain including 52 bbls initial gain 176.1 bbls by strap. Wash from 12,115' to tag at 12,143'- 1680 units gas at 4000 strokes. Max Gas = 1680 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 0 bbls 6.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)87 N/A 9 N/A Depth Ann Corr 0' Wash/Ream R. Klepzig/J. Haberthur 1680 Circ Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3505 3.517 N/A N/AN/A Avg 248 70 Total Charges: 14.2 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 29 09/17/2012 12220' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009646431 6.75 0.746 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 68.0/17.0 Mill Tooth 12220'359.60 9.55 210 600 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ Andrew Bongard (lb/100ft2) 2.6870.5 Min N/A Avg 21 ASG N/A % 24 hr Max YP AgNO3 0.15 0Avg: C3C2 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.15 (lb/100ft2) 2.7180.5 Min N/A Avg 19 ASG Kerry Garner/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 66.5/17.5 Mill Tooth 12220'379.70 9.75 189 600 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 6.75 0.746 cP PV Size NAP/Water N/A North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 30 09/18/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 15.2 N/A N/AN/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4 3.517 0' Pulling out of hole R. Klepzig/J. Haberthur 1859 Circ Flow In (gpm) Current Pump & Flow Data: N/A 44 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)6 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Clean-out rat hole from 12,175' to 12,179'- added LVT to reduce MW in (pumps off- 16 bbl gain). Clean-out rat hole to 12,216'. Perform formation integrity test to 12.5 ppg (13 bbls pumped, 17 back). Pulled out of hole, and performed Madd Pass from 12,183' to 11,680'- hole swabbing 11 bbls. Continued Madd Pass from 11,680' to 11,252'. Pump out of hole from 11,252' to 9,614' (Madd Pass 11,252' to 11,190 and 10,866' to 10,770'). Hole not taking proper fill- circulate bottoms up at 9,614' - no gas. Pump out of hole from 9,517' to 4,988' (Madd Pass 5,566' to 5,373')- hole taking 2/3 displacement. 24 hour gain- 66 bbls. Max Gas = 1859 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 0 bbls 6.875 Max: Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Continued pumping out of hole from 4,988' to 2,101'. Hole started taking correct displacement. Pulled out of hole from 2,101' to 367'- correct hole fill. Laid down 6 3/4" clean-out BHA. Test choke/upper 2 7/8" x 5" variable rams. Made up 6 3/4" Lateral BHA. Run in Hole with same at 9,074'- filling pipe every 25 stands. Plan forward is to reduce mud weight from 9.7+ ppg to 9.3-9.4 ppg at 7 5/8" shoe with LVT. Total gain past 24 hours- 1 bbl. Max Gas = 47 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 0 bbls 6.875 Max: Hole Condition On Bot Hrs 12220'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)6 N/A 7 N/A Depth Ann Corr 0' RIH w/ 6 3/4" Lateral BHA R. Klepzig/J. Haberthur 47 Circ Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4 3.517 N/A N/AN/A Avg 0 0 Total Charges: 15.2 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 31 09/19/2012 12220' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009646431 6.75 0.746 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 66.5/17.5 Tercel XR+ 12220'389.70 9.75 167 700 C5iC4iC5n Tuff 0 GrvlCoal Max: Kerry Garner/ Andrew Bongard (lb/100ft2) 2.7180.5 Min N/A Avg 18 ASG N/A % 24 hr Max YP AgNO3 0.15 0Avg: C3C2 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 0.20 (lb/100ft2) 2.6200.5 Min 10.67 Avg 18 ASG Kerry Garner/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 68.5/17.0 Tercel XR+ 12220'339.40 9.40 165 700 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 6.75 0.746 cP PV Size NAP/Water 10.13 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 32 09/20/2012 12220' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 13.7 N/A N/AN/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4 3.517 0' TIH w/ Geo-Tap BHA J. Polya / J. Haberthur 3221 Circ Flow In (gpm) Current Pump & Flow Data: 11.51 47 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)5 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 12220'0 24 hr Recap: Trip in hole to 12,061'. Fill DP. Ream and wash to 12,216'. Drill cement to 12,220'. Circulate. Reduce active system mud weight to 9.4 ppg. Trip out of hole to 11,578'. Monitor well. Circulate/trouble shoot Geo Pilot. Pull out of hole. Lay down BHA #7. Pick up BHA #8 with changed out Geo Pilot. Trip in hole- at 2,747' at report time. Max Gas = 3221 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 0 bbls 6.875 Max: Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Trip in hole to 10,037'. Fill drill pipe and pulse test per 2,500'. Trip in hole to 12,061'. Cut and slip drill line. Ream and wash to 12,220'. Pump 55 bbl hi vis spacer, and displace active system to 9.5 ppg. Monitor well- static. Drill to 12,270'. Perform formation integrity test to 12.5 ppg EMW. Drill to 12,542'. Prepare for Geo Tap test at report time. Max Gas = 191 U , 10 bbls lost down hole PWD Drilling All Circ Avg Diam 12 bbls 6.875 Max: Hole Condition On Bot Hrs 12542'8.92 191 Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)111 71.8 63 12359' Depth Ann Corr 322' Drilling 6.75" Lateral J. Polya / J. Haberthur 191 12538' Flow In (gpm) Current Pump & Flow Data: 11.78 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 1807 3.517 N/A 11.0410.88 Avg 262 47 Total Charges: 4.8 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room 1123 Chromatograph (ppm) 779 C4n 385 0 133157 Pioneer Natural Resources ODST-47 Oooguruk 33 09/21/2012 12,542' North Slope 12538 Daily Charges Avg 52.4 133.9 10.40 Nabors 19AC N/A AK-AM-0009646431 6.75 0.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 5.0/86.7 HDBS FXG55 12542'109.55 9.50 45 800 C5iC4iC5n Tuff 0 GrvlCoal Max: Jessica Munsell/ Andrew Bongard (lb/100ft2) 2.649 Min 10.90 Avg 19 ASG 10.59 % 24 hr Max YP AgNO3 0Avg: 13846 C3C2 80 Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: 6457 C3C2 80 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft2) 2.660N/A Min N/A Avg 24 ASG Jessica Munsell/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 6.5/84.0 HDBS FXG55 13158'149.55 9.65 46 800 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 6.75 0.464 cP PV Size NAP/Water N/A North Slope 12727 Daily Charges Avg 23.7 150.2 Pioneer Natural Resources ODST-47 Oooguruk 34 09/22/2012 13158' 0 108115 0 Ambient Air Pit Room 605 Chromatograph (ppm) 518 C4n 296 Min Max Max THTS Cor Solids 5.9 N/A N/AN/A Avg 272 77 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2846 3.517 661' Drilling 6.75" Lateral J. Polya / J. Haberthur 283 12727' Flow In (gpm) Current Pump & Flow Data: N/A 143 12554' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)56 90.0 Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 13158'13.26 283 24 hr Recap: Drill to 12,542'. Perform Geo Tap test. Drill to 12,735'. Perform Geo Tap test. Drill to 12,832'. Perform Geo Tap test. Drill to 12,928'. Flow check well for 30 minutes- static. Drill to 12,024'. Perform Geo Tap test. 17 bbls gained due to ballooning in last 24 hours. Max Gas = 283 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 12 bbls 6.875 Max: Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Drill to 13,217'. Perform Geo Tap test. Drill to 13,313'. Perform Geo Tap test. Function test BOPs. Drop carbide marker at 13,406' - calculated hole size, 7.5". Drill to 13,596' at midnight. Max Gas = 283 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Hole Condition On Bot Hrs 13596'17.13 283 Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)34 21.0 93 13317' Depth Ann Corr 438' Drilling 6.75" Lateral J. Polya / J. Haberthur 283 13217' Flow In (gpm) Current Pump & Flow Data: 15.88 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2760 3.517 N/A 11.4911.26 Avg 257 73 Total Charges: 6.3 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room 1227 Chromatograph (ppm) 805 C4n 353 108 112142 Pioneer Natural Resources ODST-47 Oooguruk 35 09/23/2012 13596' North Slope 13217 Daily Charges Avg 18.3 178.5 1.87 Nabors 19AC N/A AK-AM-0009646431 6.75 0.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 7.0/83.3 HDBS FXG55 13158'129.65 9.65 45 800 C5iC4iC5n Tuff 0 GrvlCoal Max: Jessica Munsell/ Andrew Bongard (lb/100ft2) 2.609N/A Min 11.20 Avg 24 ASG 10.91 % 24 hr Max YP AgNO3 N/A 0Avg: 15946 C3C2 80 Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Drill to 13,698'. Madd Pass 13,653' to 13,597'. Perform Geo Tap test. Drill to 13,795. Perform Geo Tap test. Drill to 14,084'. Perform Geo Tap test. Drill to 14,277'. Perform Geo Tap test. Currently drilling ahead at 14,468'. Max Gas = 757 U , 5 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Hole Condition On Bot Hrs 14468'15.72 757 Depth Gas (units) 60 H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)256 84.0 297 14439' Depth Ann Corr 872' Drilling 6.75" Lateral J. Polya / J. Haberthur 757 14124' Flow In (gpm) Current Pump & Flow Data: 15.87 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3043 3.517 N/A 11.5611.27 Avg 260 74 Total Charges: 6.9 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room 4879 Chromatograph (ppm) 2836 C4n 961 194 249432 Pioneer Natural Resources ODST-47 Oooguruk 36 09/24/2012 14468' North Slope 14124 Daily Charges Avg 37.8 212.9 0.04 Nabors 19AC N/A AK-AM-0009646431 6.75 0.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 7.3/82.5 HDBS FXG55 14468'149.65 9.80 47 800 C5iC4iC5n Tuff 0 GrvlCoal Max: David Mckechnie/ Andrew Bongard (lb/100ft2) 2.762N/A Min 10.53 Avg 23 ASG 10.93 % 24 hr Max YP AgNO3 N/A 0Avg: 62302 C3C2 40 Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: 23017 C3C2 45 11.13 % 24 hr Max YP AgNO3 N/A (lb/100ft2) 2.675N/A Min 11.22 Avg 23 ASG David Mckechnie/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 7.5/81.5 HDBS FXG55 14468'109.85 9.85 45 800 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 6.75 0.464 cP PV Size NAP/Water 5.76 North Slope 14372 Daily Charges Avg 47.0 212.9 Pioneer Natural Resources ODST-47 Oooguruk 37 09/25/2012 15540' 144 163218 0 Ambient Air Pit Room 1917 Chromatograph (ppm) 1259 C4n 523 Min Max Max THTS Cor Solids 7.7 N/A 11.6211.45 Avg 259 74 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2765 3.517 1072' Drilling 6.75" Lateral J. Polya / J. Haberthur 934 14372' Flow In (gpm) Current Pump & Flow Data: 14.80 324 14439' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)422 57.4 Depth Gas (units) 55 H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 15540'16.47 934 24 hr Recap: Drill to 14,660'. Perform Geo Tap test. Drill to 15,142'. Perform Geo Tap test. Currently drilling ahead at 15,540'. Max Gas = 934 U , 5 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: 51074 C3C2 30 11.16 % 24 hr Max YP AgNO3 N/A (lb/100ft2) 2.771N/A Min 11.42 Avg 20 ASG David Mckechnie/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 7.0/82.8 HDBS FXG55 16701'139.75 9.80 46 800 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 6.75 0.464 cP PV Size NAP/Water 0.63 North Slope 16393 Daily Charges Avg 49.2 224.5 Pioneer Natural Resources ODST-47 Oooguruk 38 09/26/2012 16701' 172 210357 0 Ambient Air Pit Room 3712 Chromatograph (ppm) 2207 C4n 798 Min Max Max THTS Cor Solids 6.7 N/A 11.7111.50 267 76 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3521 3.517 1161' Drilling 6.75" Lateral J. Polya / J. Haberthur 714 16393' Flow In (gpm) Current Pump & Flow Data: 12.65 218 15521' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)441 76.0 Depth Gas (units) 70 H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 16701'17.96 714 24 hr Recap: Drill to 15,815'. Flow check well- 1.2 bbls/ 5 min. Flow check for another 5 minutes, and gained 0.5 bbls. Drill to 16,489'. Perform Geo Tap test. Drill to 16,701' at midnight. Max Gas = 714 U , 8 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: 73827 C3C2 20 11.50 % 24 hr Max YP AgNO3 N/A (lb/100ft2) 2.757N/A Min 11.85 Avg 22 ASG David Mckechnie/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 7.0/80.9 HDBS FXG55 17245'169.85 9.90 53 800 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 6.75 0.464 cP PV Size NAP/Water 11.21 North Slope 17048 Daily Charges Avg 23.3 216.1 Pioneer Natural Resources ODST-47 Oooguruk 39 09/27/2012 17245' 201 255412 0 Ambient Air Pit Room 4617 Chromatograph (ppm) 2559 C4n 935 Min Max Max THTS Cor Solids 6.9 N/A 12.0911.84 Avg 258 74 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3101 3.517 544' Drilling 6.75" Lateral J. Polya / J. Haberthur 875 17048' Flow In (gpm) Current Pump & Flow Data: 12.25 417 17026' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)87 0.0 Depth Gas (units) 80 H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 17245'12.31 875 24 hr Recap: Drill to 17,710'. Pump a sweep- 500% increase in cuttings upon return to shakers. Drill to 17,245'. TD called by geologist. Backream to 17,191'. Pump a sweep- 200% increase in cuttings upon return to shakers. Backream to 16,086' at midnight. Max Gas = 875 U , 48 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft2) 2.790N/A Min 11.61 Avg 21 ASG David Mckechnie/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 6.0/83.3 HDBS FXG55 17245'149.90 9.90 47 800 12220' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 6.75 0.464 cP PV Size NAP/Water 10.48 North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 40 09/28/2012 17245' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 7.3 N/A N/AN/A Avg 253 72 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2840 3.517 0' Backreaming J. Polya / J. Haberthur 892 13983' Flow In (gpm) Current Pump & Flow Data: 12.24 110 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)151 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 17245'0 24 hr Recap: Backream/Madd Pass from 16,298' to 14,550'. Work pipe/stage pumps for pak offs at 15,380' and 14,650'. Backream/Madd Pass to 14,444'. Pump 50 bbls, 11.5 ppg Hi Vis sweep at 14,550'- 20% increase in cuttings upon return to shakers. Trip in hole to 15,014'. Back Ream/Madd Pass to 14,468'. Pump out from 14,949' to 14,468'. Backream/Madd pass to 13,978' at midnight. Max Gas = 892 U , 15 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Backream/Mad Pass from 13,749' to 12,061' inside casing shoe. Work through multiple packoffs while backreaming. Pump 55 bbl, 11 ppg hi vis sweep- 200% increase in cuttings upon return to shakers. Circulating until shakers clean up at report time. Max Gas = 1150 U , 20 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Hole Condition On Bot Hrs 17245'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)46 N/A 190 N/A Depth Ann Corr 0' Backreaming J. Polya / J. Haberthur 1150 13245' Flow In (gpm) Current Pump & Flow Data: 12.38 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2482 3.517 N/A N/AN/A Avg 255 73 Total Charges: 7.8 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 41 09/29/2012 17245' North Slope Daily Charges Avg N/A N/A 10.57 Nabors 19AC N/A AK-AM-0009646431 6.75 0.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 6.0/83.0 HDBS FXG55 17245'1210.00 9.85 47 800 C5iC4iC5n Tuff 0 GrvlCoal Max: David Mckechnie/ Andrew Bongard (lb/100ft2) 2.645N/A 11.34 19 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: C3C2 Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Pump 33 bbl dry job. Monitor well. Confirm that the well is breathing, then static. Drop 2 3/8" rabbit. Trip out of hole to 6,600' at 20- 30 min. per stand due to swabbing. Trip out of hole to 128'. Monitor well- static. Lay down BHA with nukes. Download MWD data. Rig up and test BOPS. Lay down test tools and test equipment at report time. Last 24 hours: +9.3 bbls. Max Gas = 70 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Hole Condition On Bot Hrs 17245'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)0 N/A 6 N/A Depth Ann Corr 0' Testing BOP J. Polya / J. Haberthur 70 302' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 1 3.517 N/A N/AN/A Avg 0 0 Total Charges: 7.3 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 42 09/30/2012 17245' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009646431 6.75 0.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 12220' 5.0/84.2 HDBS FXG55 17245'99.80 9.85 42 800 C5iC4iC5n Tuff 0 GrvlCoal Max: David Mckechnie/ Andrew Bongard (lb/100ft2) 2.661N/A N/A 16 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: C3C2 Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Pick up 21 joints of 4" heavy-weight drill pipe. Circulate 1.5x downpipe volume. Rig-up to run 4.5" P-110 Hydril 521 Frac Completion Liner. Run in hole with 4.5" liner and jewelry. Run in hole to 5,199'. Make-up hanger/packer. Make-up crossover to 4" drill pipe. Run in hole to 5,389'. Circulate 1x liner volume at 2 bpm/200psi. Run in hole to 12,035'. Circulate 1 bottoms up. Stage pumps to 3 bpm. Good returns at shakers. Run in hole to 14,228' with liner at report time. Max Gas = 60 U , 2 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Hole Condition On Bot Hrs 17245'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)16 N/A 1 N/A Depth Ann Corr 0' Run Frac Completion J. Polya / J. Haberthur 60 12032' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 628 3.517 N/A N/AN/A Avg 127 36 Total Charges: 7.7 Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 43 10/01/2012 17245' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009646431 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 4.5/84.517245'99.85 9.85 47 840 C5iC4iC5n Tuff 0 GrvlCoal Max: David Mckechnie/ Andrew Bongard (lb/100ft2) 2.610N/A N/A 17 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: C3C2 Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft2) 2.684N/A N/A 19 ASG David Mckechnie/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 5.0/84.317245'89.85 9.85 48 840 Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 cP PV Size NAP/Water N/A North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 44 10/02/2012 17245' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 7.2 N/A N/AN/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.517 0' Circulating J. Polya / J. Haberthur 304 17181' Flow In (gpm) Current Pump & Flow Data: N/A 12 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)3 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 17245'0 24 hr Recap: Run in hole to 17,190' with frac liner. Stage pumps to 2.5 bpm. Mud treated with CFS-559 wetting agent. Pressure test cement lines. Pump using Halliburton cement pumps. Drop 1.5" ball. Set hanger/packer per Backer Hughes representative. Ball set at 15:45- test 2,200 psi. Drop second 1.5" ball. Ball on seat at 18:25. Line up on Halliburton cement pumps to inflate 10 external casing packers per Baker Hughes program and representative. All 10 external casing packers set at report time. Max Gas = 304 U , 12 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Test packer-casing annulus to 3,500 psi for 30 minutes. Circulate 1X drill pipe volume. Single out of hole and lay down 4" drill pipe. Trip in hole with 4" drill pipe with magnet, scraper, and Baker running tool to 11,787'. Pump 55 bbl Hi Vis BaraKlean/Barascrub sweep. Displace casing to 9.8 ppg KCL/NaCl/NaBr brine. Trip out of hole to 7,743'. Slip and cut drill line. Single out of hole and lay down 4" drill pipe. Clear rig floor. Rig-up upper frac completion tools at report time. Max Gas = 460 U , 1 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Hole Condition On Bot Hrs 17245'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)5 N/A 23 N/A Depth Ann Corr 0' Lay Down 4" DP J. Polya / J. Haberthur 460 17162' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.517 N/A N/AN/A Avg 0 0 Total Charges: N/A Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 45 10/03/2012 17245' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009646431 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht N/A17245'N/A9.80 9.80 28 840 C5iC4iC5n Tuff 0 GrvlCoal Max: David Mckechnie/ Andrew Bongard (lb/100ft2) N/AN/A N/A N/A ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: C3C2 Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 0Avg: C3C2 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft2) N/AN/A N/A N/A ASG David Mckechnie/ Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: N/A17245'N/A9.80 9.80 28 840 Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009646431 cP PV Size NAP/Water N/A North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODST-47 Oooguruk 46 10/04/2012 17245' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids N/A N/A N/AN/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.517 0' Run 4.5" Frac Comp. J. Polya / J. Haberthur 12 5504' Flow In (gpm) Current Pump & Flow Data: N/A 4 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)3 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 17245'0 24 hr Recap: Continue rig-up to run 4.5" completion string. Run in hole with 4.5", 12.6# completion string. Run in hole with same at report time at 8870'. Max Gas = 12 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Customer:Report #: Well:Date: Area:00:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Finish running 4.5", 12.6# completion string to 11,983'. Test lower seals- attempt to test upper seals on hanger. Test annulus. Attempt to test upper seals on hanger. Pull hanger- change-out upper hanger seals/o-rings/flush stack. Land hanger. Test lower seals- attempt to test upper seals on hanger- pump graphite to seal leak- test good. Test tubing at 3500 psi for 30 minutes. Test annulus at 3500 psi for 30 minutes. Install BOP valves. Pull trip nipple. Rig down MPD head. Max Gas = 52 U , 0 bbls lost down hole PWD Drilling All Circ Avg Diam 24.5 bbls 7.490 Max: Hole Condition On Bot Hrs 17245'0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Current R.O.P. (ft/hr) Gas (units)0 N/A 4 N/A Depth Ann Corr 0' R/D MPD Head- C/O Bag J. Polya / J. Cortez 52 9756' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.517 N/A N/AN/A Avg 0 0 Total Charges: N/A Min Max Max THTS Cor Solids 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODST-47 Oooguruk 47 10/05/2012 17245' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009646431 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht N/A17245'N/A9.80 9.80 28 840 C5iC4iC5n Tuff 0 GrvlCoal Max: David Mckechnie/ Andrew Bongard (lb/100ft2) N/AN/A N/A N/A ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: C3C2 WELL NAME:ODS T 47LOCATION:OoogurukOPERATOR:Pioneer Natural ResourcesAREA:North SlopeMUD CO:BaroidSTATE:AlaskaRIG:Nabors 19ACSPUD:10-Aug-12SPERRY JOB:AK-AM-0009646431TD:26-Sep-12BIT RECORDBHA # Bit # Bit Type Bit SizeDepth In Depth OutFootage Bit HoursTFA AVG ROPWOB (max)RPM (max)SPP(max)FLOW GPM (max)Bit Grade Remarks1 1 Baker/MXL-1X 13.5 158.00 3007.00 2284.00 38.310.6995 76 25 60 1950 650 0-1-WT-G-E-1-NO-BHA -2 1rr1 Baker/MXL-1X 13.5 3007.00 5389.00 2382.00 81.120.6995 40 40 80 2950 800 0-3-CT-G-E-2-NO-TD -3 2 Baker/MXL-1X 9.8 5389.00 5409.00 20.00 6.65 1.0523 16.37 10 50 1820 550 1-2-WT-H-E-1-FC-BHA -4 3 HDBS/FX65 9.875 5409.00 12220.00 6811.00 170.5 1.1781 72 18 140 4200 700 0-0-NO-A-X-I-NO-TD T.D. 1st Intermediate5 2rr2 Baker/MXL-1X 9.88 12220 12220 -163.00 2.6630 - - - - - 1-2-WT-H-E-2-FC-TD Clean Out Run6 4 XR+/FDB2265 6.75 12220 12220 - 18.72 0.7455 - - - - - 2-3-FC-G-E-I-NO-BHA Clean Out Run/BAT Sonic7 5 HDBS/FXG55 6.75 12220 12220 - 7.08 0.4640 - - - - - 0-0-NO-A-X-I-NO-DTF POH for MWD tool failure8 5rr1 HDBS/FXG55 6.750 12220 17245 5025 200.88 0.4640 50 25 130 3450 270 0-0-NO-A-X-I-NO-TD T.D. Production Zone WELL NAME:ODST-47LOCATION:OoogurukOPERATOR:Pioneer Natural ResourcesAREA:North SlopeMUD CO:BaroidSTATE:AlaskaRIG:Nabors 19ACSPUD:14-Aug-12SPERRY JOB:AK-AM-0009646431TD:26-Sep-12 Water and Oil Based Mud RecordDate Depth Wt Vis PV YP Gels FiltR600/R300/R200/R100/R6/R3Cake SolidsOil/WaterSd Pm pH MBT Pf/Mf Chlor Hard Remarksft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds % % % ppb Eqv mg/l Ca++18-Aug 5297 9.35 65 8 27 22/26/34 11.6 43/35/31/28/22/21 2/0 6.9 1.5/90.9 0.25 - 9.7 11.8 0.30/0.70 13500 220 Drilling 13.5" Surface Hole19-Aug 5389 9.55 62 11 31 28/36/39 11.8 53/42/39/35/28/26 2/0 8.3 1.3/89.7 0.25 - 9.4 13.0 0.20/0.75 13500 220 TD'd Surface Hole20-Aug 5389 9.50 63 14 33 30/38/0 11.4 61/47/41/36/25/22 2/0 9.1 1.3/88.9 0.20 - 9.4 13.0 .25/1.0 13500 220 Run 10 3/4" Casing21-Aug 5389 9.55 45 11 20 18/25/32 12.3 42/31/26/21/12/11 2/0 8.3 1.0/89.9 0.15 - 9.3 12.0 0.20/0.85135000 260 Nipple down BOP22-Aug 5389 9.55 46 10 21 17/23/30 12.2 41/31/26/20/11/10 2/0 8.2 1.0/90.0 0.10 - 9.2 12.0 0.10/0.80 135000 260 TIH w/clean Out BHA20-Sep 12542 9.50 45 10 19 8/10/13 2.9 39/29/26/20/9/8 1/0 4.8 5.0/86.7 0.05 - 9.5 1.0 0.15/0.30 69000 860 Drilling 6.75" Lateral21-Sep 13158 9.65 46 14 24 12/14/19 3.0 52/38/34/27/13/11 2/0 5.9 6.5/84.0 0.05 - 9.5 1.3 0.10/0.20 72000 880 Drilling 6.75" Lateral22-Sep 13596 9.65 45 12 24 10/13/17 2.8 48/36/30/23/11/9 1/0 6.3 7.0/83.3 0.10 - 9.9 3.5 0.10/0.20 71000 440 Drilling 6.75" Lateral23-Sep 14468 9.80 47 14 23 9/14/17 2.5 51/37/31/23/10/9 1/0 6.9 7.3/82.5 0.10 - 10.0 4.5 0.20/0.90 70000 440 Drilling 6.75" Lateral24-Sep 15540 9.85 45 10 23 9/14/19 2.3 43/33/26/20/10/9 2/0 7.7 7.5/81.5 0.10 - 10.1 4.0 0.10/0.20 69000 440 Drilling 6.75" Lateral25-Sep 16701 9.80 46 13 20 9/14/18 2.7 46/33/27/21/9/8 1/0 6.7 7.0/82.8 0.10 - 9.5 2.0 0.10/0.15 71000 280 Drilling 6.75" Lateral26-Sep 17245 9.90 53 16 22 11/14/19 2.4 54/38/33/24/11/10 1/0 6.9 7.0/80.9 0.10 - 9.9 5.0 0.10/0.20 71000 320 Backreaming27-Sep 17245 9.90 47 14 21 10/15/19 2.4 49/35/29/23/11/9 1/0 7.3 6.0/83.3 0.10 - 9.6 5.5 0.10/0.25 70000 220 Backreaming28-Sep 17245 9.85 47 12 19 8/12/17 2.4 43/31/25/19/9/8 1/0 7.8 6.0/83.0 0.10 - 9.7 8.0 0.10/0.25 66000 260 Backreaming29-Sep 17245 9.85 42 9 16 8/12/17 2.2 34/25/21/16/8/7 1/0 7.3 5.0/84.2 0.10 - 10.0 4.0 0.10/0.25 70000 220 Testing BOP30-Sep 17245 9.85 47 9 17 9/14/18 2.2 35/26/21/16/9/7 1/0 7.7 4.5/84.5 0.10 - 10.1 4.0 0.10/0.25 67000 220 Running Frac Completion1-Oct 17245 9.85 48 8 19 8/15/18 2.1 35/27/22/17/8/7 1/0 7.2 5.0/84.3 0.10 - 9.7 5.0 0.10/0.30 70000 220 Circulating2-Oct 17245 9.80 - - - - - - - - - - - - - - - Lay Down 4" Drill Pipe3-Oct 17245 9.80 - - - - - - - - - - - - - - - - Run 4.5" Frac Comp.4-Oct 17245 9.80 - - - - - - - - - - - - - - - - R/D MPD Head- C/O BagDate Depth Wt Vis PV YP Gels HTHPR600/R300/R200/R100/R6/R3Cake SolidsOil/WaterAlka POMExcess LimeElec StabCaCl2 WPS LGS/HGS ASG Remarksft - MD ppg sec lb/100lb/100ft2m/30m Rheometer 32nds % % ml ppb volts ppb ppm ppb23-Aug 5409 9.55 84 14 14 9/14/16 4.8 42/28/22/15/8.0/7.0 0/2 13.6 70.7/14 0.05 4.79 779 7.2 268,173 120.85/4.95 2.640 Slip and cut drill line24-Aug 5743 9.50 76 15 16 12/15/18 4.2 46/31/86/53/25/18 .2 13.3 83.5/16.5 0.50 5.05 1193 6.3 266,379 116.0/5.94 2.649 Drlg 9.875" Intermediate hole25-Aug 7737 9.50 75 20 22 16/22/27 3.9 62/42/35/26/12/11 2 13.0 83.5/16.5 0.10 5.18 1001 6.3 266,071117.80/3.37 2.628 Pumping Sweep26-Aug 9250 9.50 71 19 19 16/22/28 2.8 57/38/32/24/13/12 2 13.2 82.4/17.6 0.10 5.31 1013 7.2 267,348 124.50/0.13 2.601 Drilling Ahead27-Aug 11397 9.50 70 27 17 10/16/232.8 71/44/34/23/11/9 0/213.3 69.9/15.0 - 5.18 972 6.3 266071 119.72/1.75 2.614 Drilling Ahead28-Aug 12220 9.70 69 29 15 10/14/19 3.2 73/44/33/22/10/9 0/2 13.2 70.0/15.0 - 4.92 831 6.3 266,071 104.16/25.42 2.810 Wiper Trip to Shoe29-Aug 12220 9.80 71 27 16 10/12/19 3.3 70/43/22/19/11/10 0/2 13.4 69.5/15 - 4.53 1059 6.3 266,071 101.16/33.20 2.870 TIH to Bottom30-Aug 12220 9.40 65 19 18 11/15/19 3.3 56/37/30/20/9/8 0/2 12.0 74.5/12- 3.24 819 5.3 266,494 95.97/22.05 2.799 Reaming to bottom31-Aug 12220 9.30 84 32 19 10/18/25 3.4 83/51/37/23/9/8 0/2 12.7 76.0/10.0 - 3.11 921 1.4 264,775 110.39/8.682.674 TOH to Casing Shoe1-Sep 12220 9.40 80 25 16 11/21/293.5 66/41/30/20/8/7 0/212.7 76.0/10.0 - 2.20 931 N/A 266,825 102.55/20.59 2.777Displace @ casing shoe to 12.8 KWM2-Sep 12220 12.80 70 30 21 12/23/39 2.9 81/51/34/24/9/8 0/2 21.1 62.0/15.0 - 4.92 937 3.4 264,437 43.95/239.513.834 Displace to 9.3 Run in hole3-Sep 12220 9.40 80 29 21 14/19/33 2.7 79/50/39/27/13/12 0/2 12.1 74.3/12.0 - 6.60 1197 N/A 266,825 96.33/22.26 2.800 Ream/Wash to Bottom4-Sep 12220 9.70 87 34 21 15/33/44 2.1 89/55/43/29/14/12 0/2 13.3 69.7/15.0 - 3.24 1057 N/A 266,825 105.76/24.63 2.802 Wash and Ream to Bottom5-Sep 12220 9.65 94 38 27 18/44/59 1.8 103/65/50/34/15/14 0/2 13.9 72.0/12.5 - 2.59 1045 2.9 264,437 115.61/18.05 2.741 Wash and Ream to Bottom6-Sep 12220 9.60 110 33 24 19/45/70 2.0 90/57/44/30/12/11 0/2 14.0 72.0/12.0 - 2.33 1036 2.4 264473 118.82/13.65 2.706 Wash and Ream to Bottom7-Sep 12220 9.50 108 34 23 14/38/61 1.8 91/57/44/30/12/11 0/2 14.7 72.5/12 - 2.98 1025 1.9 157,185 132.23/3.31 2.624 Ream and Wash to Bottom8-Sep 12220 9.50 108 34 23 17/41/72 2.0 91/57/43/29/11/10 0/2 14.8 73/11.5 - 2.72 883 2.9 149,236 133.25/3.35 2.620 Wash and Ream to BottomPage 1 of 2 WELL NAME:ODST-47LOCATION:OoogurukOPERATOR:Pioneer Natural ResourcesAREA:North SlopeMUD CO:BaroidSTATE:AlaskaRIG:Nabors 19ACSPUD:14-Aug-12SPERRY JOB:AK-AM-0009646431TD:26-Sep-12 Water and Oil Based Mud RecordDate Depth Wt Vis PV YP Gels HTHPR600/R300/R200/R100/R6/R3Cake SolidsOil/WaterAlka POMExcess LimeElec StabCaCl2 WPS LGS/HGS ASG Remarksft - MD ppg sec lb/100lb/100ft2m/30m Rheometer 32nds % % ml ppb volts ppb ppm ppb9-Sep 12220 9.60 107 38 20 9/18/26 1.8 96/58/44/29/9/8 0/2 15.3 72.0/12.0 - 2.46 848 0.9 132,983 135.42/7.192.651 Running 7 5/8" Csg10-Sep 12220 12.30 224 52 25 13/21/27 1.8 129/77/59/38/12/11 0/2 23.2 62.0/14.0 - 2.20 800 - 139,346 104.06/172.86 3.411 Running 7 5/8" Csg11-Sep 12220 9.50 128 34 18 8/16/22 1.8 86/52/40/26/8/7 0/2 14.8 73.5/11.0 - 1.81 712 0.4 143,829 131.39/6.082.645 Laying Down 5" Drill Pipe12-Sep 12220 9.55 128 42 20 9/18/24 2.0 104/62/47/30/9/8 0/2 15.4 73.0/11.0 - 1.68 827 - 130,332 137.78/3.96 2.628 Pick Up 4" Drill Pipe13-Sep 12220 9.55 196 35 20 11/19/23 2.0 90/55/42/28/10/9 0/2 15.4 73.0/11.0 - 1.68 797 - 130,332 137.78/3.96 2.628 RIH w/ 6 3/4" Clean-out BHA14-Sep 12220 9.55 196 39 23 121/18/28 2.0 101/62/48/33/12/10 0/2 15.3 73.0/11.0 - 1.68 713 - 144,273137.19/3.83 2.627 Wash/Ream15-Sep 12220 9.50 189 30 19 9/16/21 2.0 79/49/37/25/9/8 0/2 14.8 73.5/11.0 - 1.68 872 - 144,273 131.0/6.42 2.647 POOH 16-Sep 12220 9.60 210 35 21 11/17/0 2.0 91/56/44/30/11/10 0/2 12.4 68.0/17.0 - 2.33 656 -108,109 122.63/11.36 2.687 RIH w/ 6 3/4" Lateral BHA17-Sep 12220 9.70 189 37 19 10/16/26 2.0 93/58/43/29/10/9 0/2 15.2 66.5/17.5 - 2.33 630 105,346 128.54/16.51 2.718 TIH w/ Geo-Tap BHA18-Sep 12220 9.75 167 38 18 9/17/262.0 94/56/43/28/10/9 0/2 15.2 66.5/17.5 - 2.33 626 - 105,346 128.54/16.51 2.718Remarks19-Sep 12220 9.40 165 33 18 9/17/242.0 84/51/38/26/9/8 0/213.7 68.5/17.0 - 2.33 837 0.4 107,797 123.67/2.57 2.620Date Depth Wt Vis PV YP Gels FiltR600/R300/R200/R100/R6/R3Cake SolidsOil/WaterSd Pm pH MBT Pf/Mf Chlor HardDrilling 6.75" Lateral ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds % % % ppb Eqv mg/l Ca++Drilling 6.75" Lateral 20-Sep 12542 9.50 45 10 19 8/10/132.9 8/10/13/39/29/26/201 4.8 5.0/86.7 0.05 - 9.5 - 0.15/0.30 69000.0 860 Drilling 6.75" Lateral 21-Sep 13158 9.65 46 14 24 12/14/193.0 52/38/34/27/13/11 2 5.9 6.5/84 0.05 - 9.5 1.30 0.10/0.20 72000.0 880 Drilling 6.75" Lateral 22-Sep 13596 9.65 45 12 24 10/13/172.8 48/36/30/23/11/9 1 6.3 7.083.3 0.10 - 9.9 3.50 .10/0.20 71000.0 440 Drilling 6.75" Lateral 23-Sep 14468 9.80 47 14 23 9/14/172.5 51/37/31/23/10/9 1 6.9 7.3/82.5 0.10 - 10.0 4.50 0.2/0.90 70000.0 440 Drilling 6.75" Lateral 24-Sep 15540 9.85 45 10 23 9/14/19 2.3 43/33/26/20/10/9 2 7.7 7.5/81.5 0.10 -10.1 4.00 0.10/0.20 69000.0 440 TD Lateral Backreaming25-Sep 16701 9.80 46 13 20 9/14/18 2.7 46/33/27/21/9/8 1 6.7 7.0/82.8 0.10 - 9.5 2.00 0.10/0.15 71000.0 280 Backreaming26-Sep 17245 9.90 53 16 22 11/14/19 2.4 54/38/33/24/11/10 1 6.9 7.0/80.9 0.10 - 9.9 5.00 0.10/0.20 71000.0 320 Backreaming/Pumping Sweep27-Sep 17245 9.90 47 14 21 10/15/19 2.4 49/25/29/23/11/9 1 7.3 6.0/83.3 0.10 - 9.6 5.50 0.10/0.25 70000.0 220 Testing B.O.P.28-Sep 17245 9.85 47 12 19 8/12/17 2.4 43/31/25/19/9/8 1 7.8 6.0/83.0 0.10 - 9.7 8.00 0.10/0.25 66000.0 260 Running Frac Completion29-Sep 17245 9.85 42 9 16 8/12/17 2.2 34/25/21/16/8/7 1 7.3 5.0/84.2 0.10 - 10.0 4.00 0.10/0.25 70000.0 220 Circulating30-Sep 17245 9.85 47 9 17 9/14/18 2.2 35/26/21/16/9/7 1 7.7 4.5/84.5 0.10 - 10.1 4.00 0.10/0.25 67000.0 220 Laying Down 4" Drill Pipe1-Oct 17245 9.85 48 8 19 8/15/18 2.1 35/27/22/17/8/7 1 7.2 5.0/84.3 0.10 - 9.7 5.00 .10/0.30 70000.0 220 Running Frac Completion2-Oct 17245 9.80 28 - - - - - - - - - - - - - - - R/D MPD Head - Change out bagPage 2 of 2 Marker MD INC AZ TVD TVDSS Top Permafrost 860.40 15.70 215.80 854.00 797.80 Base Permafrost 1802.50 46.70 215.50 1668.00 1611.80 West Sak 2990.00 70.70 216.30 2278.10 2221.90 Top Cretaceous Tuffs 4906.00 72.10 213.30 2853.20 2797.00 SCP (10-3/4" Shoe)5380.00 72.10 215.20 2997.60 2941.40 Hue 1 Marker 5472.00 71.20 216.00 3026.60 2970.40 Hue 2 Marker 6002.00 71.70 214.50 3196.00 3139.80 Brookian 2B Marker 9231.00 71.20 213.40 4220.90 4164.70 Kalubik Fault Ext na na na na na Top Torok SS T1 12053.00 86.20 171.70 4998.30 4942.10 ICP (7")12138.00 86.80 169.10 5003.50 4947.30 Mid Nuna (Torok)13500.00 85.40 138.60 5088.00 5031.80 Lower Nuna (Torok)14121.00 85.80 138.30 5134.00 5077.80 Base Nuna (Torok)17192.00 82.60 136.30 5281.00 5224.80 TD 17245.00 82.60 136.30 5287.90 5231.70 ODST-47 Interpolated Tops Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODST-47 ODST-47 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODST-47 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODST-47 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Development Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODST-47 ft ft 0.00 0.00 6,030,995.50 469,811.98 13.50Wellhead Elevation:ft0.00 70° 29' 44.705 N 150° 14' 48.639 W Wellbore Declination (?) Field Strength (nT) Sample Date Dip Angle (?) ODST-47 Model NameMagnetics IGRF200510 12/31/2009 21.99 80.81 57,759 Phase:Version: Audit Notes: Design ODST-47 1.0 ACTUAL PTD# 2110180 Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (bearing) +E/-W (ft) Tie On Depth:42.70 187.120.000.0042.70 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 10/4/2012 Survey Start Date SR-Gyro-SS Fixed:v2:surface readout gyro single shot100.00 734.00 ODST-47 Gyro (ODST-47)08/15/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag782.28 5,339.50 ODST-47 MWD (ODST-47)08/16/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag5,428.02 12,111.51 ODST-47 MWD (ODST-47)08/16/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag12,205.25 17,181.44 ODST-47 MWD (ODST-47)08/16/2012 MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.70 0.00 0.00 42.70 0.00 0.00-13.50 6,030,995.50 469,811.98 0.00 0.00 UNDEFINED 100.00 0.11 64.97 100.00 0.02 0.0543.80 6,030,995.52 469,812.03 0.19 -0.03 SR-Gyro-SS (1) 171.00 0.40 315.08 171.00 0.23 -0.06114.80 6,030,995.73 469,811.92 0.63 -0.22 SR-Gyro-SS (1) 264.00 0.44 255.05 264.00 0.37 -0.64207.80 6,030,995.87 469,811.34 0.45 -0.28 SR-Gyro-SS (1) 358.00 1.89 210.71 357.98 -1.06 -1.78301.78 6,030,994.45 469,810.20 1.71 1.27 SR-Gyro-SS (1) 451.00 3.51 211.62 450.87 -4.80 -4.05394.67 6,030,990.71 469,807.90 1.74 5.27 SR-Gyro-SS (1) 544.00 5.46 208.60 543.58 -11.11 -7.66487.38 6,030,984.42 469,804.27 2.11 11.98 SR-Gyro-SS (1) 639.00 7.91 210.76 637.93 -20.70 -13.17581.73 6,030,974.86 469,798.72 2.59 22.17 SR-Gyro-SS (1) 734.00 12.26 215.94 731.44 -34.49 -22.44675.24 6,030,961.11 469,789.40 4.67 37.01 SR-Gyro-SS (1) 782.28 13.76 214.78 778.48 -43.36 -28.72722.28 6,030,952.27 469,783.08 3.15 46.58 MWD+IFR2+MS+sag (2) 875.78 16.04 216.00 868.83 -62.94 -42.66812.63 6,030,932.74 469,769.06 2.46 67.75 MWD+IFR2+MS+sag (2) 10/4/2012 3:58:44PM COMPASS 2003.16 Build 42 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODST-47 ODST-47 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODST-47 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODST-47 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 969.78 16.82 215.04 958.99 -84.59 -58.10902.79 6,030,911.16 469,753.54 0.88 91.13 MWD+IFR2+MS+sag (2) 1,067.02 20.21 214.09 1,051.18 -110.02 -75.60994.98 6,030,885.80 469,735.94 3.50 118.54 MWD+IFR2+MS+sag (2) 1,161.88 22.52 214.98 1,139.52 -138.48 -95.201,083.32 6,030,857.42 469,716.22 2.46 149.21 MWD+IFR2+MS+sag (2) 1,254.24 24.14 215.06 1,224.33 -168.43 -116.191,168.13 6,030,827.56 469,695.11 1.75 181.54 MWD+IFR2+MS+sag (2) 1,350.56 30.42 214.70 1,309.89 -204.64 -141.411,253.69 6,030,791.46 469,669.75 6.52 220.59 MWD+IFR2+MS+sag (2) 1,444.77 32.61 215.53 1,390.20 -244.91 -169.751,334.00 6,030,751.31 469,641.25 2.37 264.06 MWD+IFR2+MS+sag (2) 1,541.16 34.97 215.58 1,470.30 -288.52 -200.921,414.10 6,030,707.83 469,609.91 2.45 311.20 MWD+IFR2+MS+sag (2) 1,638.79 40.08 214.12 1,547.71 -337.33 -234.851,491.51 6,030,659.16 469,575.78 5.31 363.84 MWD+IFR2+MS+sag (2) 1,733.51 42.50 214.36 1,618.87 -388.99 -270.021,562.67 6,030,607.65 469,540.41 2.56 419.46 MWD+IFR2+MS+sag (2) 1,825.98 48.08 215.94 1,683.90 -442.68 -307.871,627.70 6,030,554.12 469,502.34 6.15 477.42 MWD+IFR2+MS+sag (2) 1,919.22 49.35 218.14 1,745.43 -498.59 -350.081,689.23 6,030,498.39 469,459.91 2.24 538.13 MWD+IFR2+MS+sag (2) 2,015.43 49.63 216.13 1,807.93 -556.90 -394.231,751.73 6,030,440.26 469,415.53 1.61 601.47 MWD+IFR2+MS+sag (2) 2,110.98 52.96 216.29 1,867.67 -617.05 -438.281,811.47 6,030,380.30 469,371.24 3.49 666.62 MWD+IFR2+MS+sag (2) 2,206.27 58.17 215.29 1,921.53 -680.79 -484.201,865.33 6,030,316.75 469,325.06 5.54 735.56 MWD+IFR2+MS+sag (2) 2,301.76 57.21 216.94 1,972.57 -745.99 -531.761,916.37 6,030,251.75 469,277.24 1.77 806.15 MWD+IFR2+MS+sag (2) 2,395.81 60.42 216.14 2,021.27 -810.63 -579.651,965.07 6,030,187.31 469,229.09 3.49 876.23 MWD+IFR2+MS+sag (2) 2,491.80 60.39 214.38 2,068.68 -878.78 -627.842,012.48 6,030,119.37 469,180.64 1.59 949.82 MWD+IFR2+MS+sag (2) 2,587.25 61.51 213.68 2,115.02 -947.93 -674.532,058.82 6,030,050.41 469,133.67 1.34 1,024.23 MWD+IFR2+MS+sag (2) 2,681.99 60.95 214.67 2,160.62 -1,016.64 -721.172,104.42 6,029,981.90 469,086.75 1.09 1,098.18 MWD+IFR2+MS+sag (2) 2,778.62 66.38 214.91 2,203.47 -1,087.73 -770.572,147.27 6,029,911.02 469,037.07 5.62 1,174.85 MWD+IFR2+MS+sag (2) 2,871.73 70.07 213.98 2,238.01 -1,159.03 -819.462,181.81 6,029,839.93 468,987.90 4.07 1,251.66 MWD+IFR2+MS+sag (2) 2,968.21 70.18 216.42 2,270.81 -1,233.16 -871.762,214.61 6,029,766.01 468,935.31 2.38 1,331.70 MWD+IFR2+MS+sag (2) 3,059.04 72.38 215.92 2,299.96 -1,302.60 -922.522,243.76 6,029,696.79 468,884.26 2.48 1,406.90 MWD+IFR2+MS+sag (2) 3,154.76 70.65 215.97 2,330.31 -1,376.10 -975.812,274.11 6,029,623.52 468,830.68 1.81 1,486.43 MWD+IFR2+MS+sag (2) 3,249.09 72.83 215.06 2,359.87 -1,449.01 -1,027.842,303.67 6,029,550.83 468,778.36 2.49 1,565.23 MWD+IFR2+MS+sag (2) 3,341.91 71.59 213.67 2,388.22 -1,521.96 -1,077.732,332.02 6,029,478.09 468,728.18 1.95 1,643.80 MWD+IFR2+MS+sag (2) 3,438.78 70.91 212.79 2,419.36 -1,598.68 -1,128.002,363.16 6,029,401.57 468,677.61 1.11 1,726.17 MWD+IFR2+MS+sag (2) 3,533.72 73.64 212.34 2,448.26 -1,674.89 -1,176.672,392.06 6,029,325.57 468,628.64 2.91 1,807.82 MWD+IFR2+MS+sag (2) 3,629.82 75.15 212.19 2,474.12 -1,753.16 -1,226.082,417.92 6,029,247.51 468,578.92 1.58 1,891.61 MWD+IFR2+MS+sag (2) 3,723.24 72.10 213.49 2,500.45 -1,828.46 -1,274.672,444.25 6,029,172.42 468,530.02 3.53 1,972.35 MWD+IFR2+MS+sag (2) 3,817.07 72.14 213.29 2,529.26 -1,903.02 -1,323.812,473.06 6,029,098.07 468,480.58 0.21 2,052.43 MWD+IFR2+MS+sag (2) 3,913.27 73.20 213.63 2,557.91 -1,979.63 -1,374.452,501.71 6,029,021.67 468,429.64 1.15 2,134.72 MWD+IFR2+MS+sag (2) 4,007.24 73.43 213.77 2,584.89 -2,054.52 -1,424.392,528.69 6,028,946.99 468,379.40 0.28 2,215.22 MWD+IFR2+MS+sag (2) 4,100.35 73.00 213.34 2,611.78 -2,128.80 -1,473.662,555.58 6,028,872.92 468,329.83 0.64 2,295.04 MWD+IFR2+MS+sag (2) 4,198.36 73.18 212.94 2,640.29 -2,207.32 -1,524.932,584.09 6,028,794.61 468,278.25 0.43 2,379.31 MWD+IFR2+MS+sag (2) 4,292.16 73.52 212.40 2,667.17 -2,282.97 -1,573.442,610.97 6,028,719.17 468,229.44 0.66 2,460.39 MWD+IFR2+MS+sag (2) 4,388.61 72.14 212.87 2,695.64 -2,360.57 -1,623.132,639.44 6,028,641.78 468,179.44 1.50 2,543.55 MWD+IFR2+MS+sag (2) 4,480.68 72.25 213.30 2,723.79 -2,434.02 -1,670.982,667.59 6,028,568.53 468,131.29 0.46 2,622.36 MWD+IFR2+MS+sag (2) 4,578.31 72.46 213.45 2,753.39 -2,511.71 -1,722.162,697.19 6,028,491.06 468,079.80 0.26 2,705.80 MWD+IFR2+MS+sag (2) 4,673.80 72.34 213.21 2,782.26 -2,587.76 -1,772.172,726.06 6,028,415.22 468,029.49 0.27 2,787.46 MWD+IFR2+MS+sag (2) 10/4/2012 3:58:44PM COMPASS 2003.16 Build 42 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODST-47 ODST-47 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODST-47 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODST-47 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,766.95 72.27 213.34 2,810.57 -2,661.96 -1,820.862,754.37 6,028,341.23 467,980.50 0.15 2,867.12 MWD+IFR2+MS+sag (2) 4,862.14 72.10 213.16 2,839.69 -2,737.74 -1,870.552,783.49 6,028,265.65 467,930.51 0.25 2,948.48 MWD+IFR2+MS+sag (2) 4,959.42 72.15 213.53 2,869.55 -2,815.09 -1,921.452,813.35 6,028,188.52 467,879.31 0.37 3,031.54 MWD+IFR2+MS+sag (2) 5,054.11 72.86 213.69 2,898.02 -2,890.30 -1,971.432,841.82 6,028,113.52 467,829.02 0.77 3,112.37 MWD+IFR2+MS+sag (2) 5,149.99 71.87 214.84 2,927.07 -2,965.81 -2,022.882,870.87 6,028,038.23 467,777.28 1.54 3,193.67 MWD+IFR2+MS+sag (2) 5,244.13 72.04 214.87 2,956.23 -3,039.26 -2,074.032,900.03 6,027,964.99 467,725.83 0.18 3,272.90 MWD+IFR2+MS+sag (2) 5,339.52 72.47 214.91 2,985.30 -3,113.79 -2,126.002,929.10 6,027,890.69 467,673.57 0.45 3,353.29 MWD+IFR2+MS+sag (2) 5,428.02 71.65 215.66 3,012.56 -3,182.51 -2,174.632,956.36 6,027,822.17 467,624.66 1.23 3,427.51 MWD+IFR2+MS+sag (3) 5,459.73 71.26 215.72 3,022.65 -3,206.93 -2,192.172,966.45 6,027,797.82 467,607.02 1.24 3,453.92 MWD+IFR2+MS+sag (3) 5,554.17 71.13 215.67 3,053.09 -3,279.54 -2,244.332,996.89 6,027,725.44 467,554.57 0.15 3,532.43 MWD+IFR2+MS+sag (3) 5,648.73 70.81 215.64 3,083.92 -3,352.17 -2,296.443,027.72 6,027,653.02 467,502.18 0.34 3,610.96 MWD+IFR2+MS+sag (3) 5,744.43 71.47 215.94 3,114.86 -3,425.63 -2,349.403,058.66 6,027,579.79 467,448.92 0.75 3,690.42 MWD+IFR2+MS+sag (3) 5,839.23 71.85 216.00 3,144.69 -3,498.46 -2,402.263,088.49 6,027,507.18 467,395.78 0.41 3,769.23 MWD+IFR2+MS+sag (3) 5,934.42 71.45 215.72 3,174.65 -3,571.68 -2,455.183,118.45 6,027,434.18 467,342.56 0.50 3,848.45 MWD+IFR2+MS+sag (3) 6,029.29 71.97 213.69 3,204.43 -3,645.73 -2,506.463,148.23 6,027,360.35 467,290.98 2.10 3,928.29 MWD+IFR2+MS+sag (3) 6,124.45 71.01 213.48 3,234.64 -3,720.90 -2,556.383,178.44 6,027,285.39 467,240.77 1.03 4,009.07 MWD+IFR2+MS+sag (3) 6,218.22 71.65 213.98 3,264.66 -3,794.78 -2,605.713,208.46 6,027,211.72 467,191.14 0.85 4,088.49 MWD+IFR2+MS+sag (3) 6,314.56 71.86 213.96 3,294.82 -3,870.66 -2,656.833,238.62 6,027,136.05 467,139.72 0.22 4,170.12 MWD+IFR2+MS+sag (3) 6,408.08 71.45 213.65 3,324.25 -3,944.42 -2,706.223,268.05 6,027,062.50 467,090.04 0.54 4,249.44 MWD+IFR2+MS+sag (3) 6,504.75 71.08 214.26 3,355.30 -4,020.36 -2,757.353,299.10 6,026,986.78 467,038.60 0.71 4,331.12 MWD+IFR2+MS+sag (3) 6,599.67 71.45 215.30 3,385.79 -4,094.19 -2,808.633,329.59 6,026,913.17 466,987.03 1.11 4,410.74 MWD+IFR2+MS+sag (3) 6,694.15 71.80 213.81 3,415.58 -4,168.03 -2,859.483,359.38 6,026,839.54 466,935.88 1.54 4,490.32 MWD+IFR2+MS+sag (3) 6,788.99 71.65 214.25 3,445.32 -4,242.66 -2,909.883,389.12 6,026,765.12 466,885.19 0.47 4,570.62 MWD+IFR2+MS+sag (3) 6,883.97 71.45 215.07 3,475.38 -4,316.77 -2,961.123,419.18 6,026,691.22 466,833.65 0.85 4,650.51 MWD+IFR2+MS+sag (3) 6,978.59 71.51 215.40 3,505.43 -4,390.06 -3,012.883,449.23 6,026,618.16 466,781.60 0.34 4,729.64 MWD+IFR2+MS+sag (3) 7,073.30 71.78 214.62 3,535.26 -4,463.68 -3,064.453,479.06 6,026,544.75 466,729.73 0.83 4,809.09 MWD+IFR2+MS+sag (3) 7,169.00 71.66 214.69 3,565.27 -4,538.43 -3,116.123,509.07 6,026,470.22 466,677.76 0.14 4,889.67 MWD+IFR2+MS+sag (3) 7,264.23 71.53 213.69 3,595.34 -4,613.17 -3,166.903,539.14 6,026,395.69 466,626.69 1.01 4,970.13 MWD+IFR2+MS+sag (3) 7,359.68 71.46 212.62 3,625.64 -4,688.95 -3,216.403,569.44 6,026,320.13 466,576.89 1.07 5,051.46 MWD+IFR2+MS+sag (3) 7,454.65 71.14 212.44 3,656.08 -4,764.79 -3,264.783,599.88 6,026,244.49 466,528.21 0.38 5,132.71 MWD+IFR2+MS+sag (3) 7,549.81 71.25 211.76 3,686.76 -4,841.10 -3,312.643,630.56 6,026,168.38 466,480.04 0.69 5,214.36 MWD+IFR2+MS+sag (3) 7,644.91 71.52 211.85 3,717.12 -4,917.69 -3,360.143,660.92 6,026,091.99 466,432.23 0.30 5,296.25 MWD+IFR2+MS+sag (3) 7,740.12 71.58 211.42 3,747.25 -4,994.59 -3,407.513,691.05 6,026,015.30 466,384.55 0.43 5,378.43 MWD+IFR2+MS+sag (3) 7,834.54 71.26 213.03 3,777.33 -5,070.30 -3,455.243,721.13 6,025,939.79 466,336.53 1.65 5,459.47 MWD+IFR2+MS+sag (3) 7,929.83 71.46 214.00 3,807.79 -5,145.58 -3,505.093,751.59 6,025,864.72 466,286.38 0.99 5,540.35 MWD+IFR2+MS+sag (3) 8,023.48 70.99 214.29 3,837.93 -5,218.96 -3,554.863,781.73 6,025,791.55 466,236.32 0.58 5,619.33 MWD+IFR2+MS+sag (3) 8,118.06 71.80 214.39 3,868.11 -5,292.97 -3,605.423,811.91 6,025,717.75 466,185.46 0.86 5,699.04 MWD+IFR2+MS+sag (3) 8,211.76 70.93 215.95 3,898.05 -5,365.55 -3,656.563,841.85 6,025,645.39 466,134.03 1.83 5,777.40 MWD+IFR2+MS+sag (3) 8,308.73 71.34 216.73 3,929.41 -5,439.46 -3,710.933,873.21 6,025,571.70 466,079.36 0.87 5,857.48 MWD+IFR2+MS+sag (3) 8,403.17 71.79 216.15 3,959.27 -5,511.54 -3,764.153,903.07 6,025,499.85 466,025.86 0.75 5,935.60 MWD+IFR2+MS+sag (3) 10/4/2012 3:58:44PM COMPASS 2003.16 Build 42 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODST-47 ODST-47 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODST-47 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODST-47 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,499.15 71.46 216.49 3,989.53 -5,584.93 -3,818.103,933.33 6,025,426.69 465,971.62 0.48 6,015.11 MWD+IFR2+MS+sag (3) 8,594.07 71.52 215.26 4,019.66 -5,657.86 -3,870.853,963.46 6,025,353.98 465,918.58 1.23 6,094.02 MWD+IFR2+MS+sag (3) 8,688.91 71.27 214.10 4,049.92 -5,731.78 -3,921.993,993.72 6,025,280.28 465,867.14 1.19 6,173.70 MWD+IFR2+MS+sag (3) 8,783.13 72.05 214.44 4,079.57 -5,805.68 -3,972.354,023.37 6,025,206.58 465,816.49 0.90 6,253.28 MWD+IFR2+MS+sag (3) 8,879.15 71.40 214.90 4,109.68 -5,880.67 -4,024.214,053.48 6,025,131.81 465,764.32 0.82 6,334.12 MWD+IFR2+MS+sag (3) 8,975.74 71.66 214.51 4,140.28 -5,955.99 -4,076.374,084.08 6,025,056.72 465,711.86 0.47 6,415.32 MWD+IFR2+MS+sag (3) 9,070.93 71.21 214.23 4,170.58 -6,030.47 -4,127.324,114.38 6,024,982.45 465,660.62 0.55 6,495.54 MWD+IFR2+MS+sag (3) 9,165.49 72.12 213.17 4,200.33 -6,105.14 -4,177.124,144.13 6,024,907.99 465,610.53 1.43 6,575.81 MWD+IFR2+MS+sag (3) 9,260.65 70.80 213.53 4,230.59 -6,180.51 -4,226.714,174.39 6,024,832.83 465,560.63 1.43 6,656.74 MWD+IFR2+MS+sag (3) 9,352.42 71.72 214.06 4,260.07 -6,252.72 -4,275.054,203.87 6,024,760.82 465,512.00 1.14 6,734.39 MWD+IFR2+MS+sag (3) 9,448.84 71.33 214.01 4,290.63 -6,328.51 -4,326.244,234.43 6,024,685.25 465,460.52 0.41 6,815.94 MWD+IFR2+MS+sag (3) 9,545.11 70.81 214.23 4,321.86 -6,403.90 -4,377.324,265.66 6,024,610.08 465,409.14 0.58 6,897.07 MWD+IFR2+MS+sag (3) 9,640.59 71.20 214.32 4,352.93 -6,478.50 -4,428.164,296.73 6,024,535.69 465,358.00 0.42 6,977.40 MWD+IFR2+MS+sag (3) 9,735.28 72.11 214.97 4,382.74 -6,552.44 -4,479.254,326.54 6,024,461.97 465,306.61 1.16 7,057.11 MWD+IFR2+MS+sag (3) 9,830.61 72.17 213.63 4,411.97 -6,627.39 -4,530.384,355.77 6,024,387.23 465,255.18 1.34 7,137.82 MWD+IFR2+MS+sag (3) 9,925.56 72.49 212.70 4,440.80 -6,703.13 -4,579.874,384.60 6,024,311.70 465,205.38 0.99 7,219.10 MWD+IFR2+MS+sag (3) 10,020.33 71.39 213.37 4,470.18 -6,778.66 -4,628.994,413.98 6,024,236.38 465,155.97 1.34 7,300.14 MWD+IFR2+MS+sag (3) 10,115.67 71.27 213.76 4,500.70 -6,853.92 -4,678.934,444.50 6,024,161.33 465,105.73 0.41 7,381.01 MWD+IFR2+MS+sag (3) 10,210.87 71.47 213.74 4,531.11 -6,928.93 -4,729.054,474.91 6,024,086.53 465,055.31 0.21 7,461.66 MWD+IFR2+MS+sag (3) 10,305.60 71.47 214.36 4,561.21 -7,003.35 -4,779.344,505.01 6,024,012.32 465,004.72 0.62 7,541.73 MWD+IFR2+MS+sag (3) 10,400.87 70.82 214.31 4,592.00 -7,077.80 -4,830.194,535.80 6,023,938.09 464,953.57 0.68 7,621.91 MWD+IFR2+MS+sag (3) 10,495.17 71.39 214.33 4,622.54 -7,151.48 -4,880.494,566.34 6,023,864.62 464,902.98 0.60 7,701.26 MWD+IFR2+MS+sag (3) 10,591.16 70.87 215.29 4,653.59 -7,226.06 -4,932.344,597.39 6,023,790.26 464,850.83 1.09 7,781.69 MWD+IFR2+MS+sag (3) 10,684.50 71.66 216.50 4,683.57 -7,297.66 -4,984.174,627.37 6,023,718.87 464,798.72 1.49 7,859.17 MWD+IFR2+MS+sag (3) 10,780.24 71.70 215.51 4,713.66 -7,371.19 -5,037.604,657.46 6,023,645.58 464,745.00 0.98 7,938.75 MWD+IFR2+MS+sag (3) 10,874.41 71.34 214.22 4,743.51 -7,444.47 -5,088.654,687.31 6,023,572.51 464,693.65 1.35 8,017.79 MWD+IFR2+MS+sag (3) 10,965.44 71.71 213.78 4,772.36 -7,516.04 -5,136.934,716.16 6,023,501.14 464,645.09 0.61 8,094.80 MWD+IFR2+MS+sag (3) 11,066.02 72.81 211.97 4,803.01 -7,596.50 -5,188.924,746.81 6,023,420.90 464,592.77 2.03 8,181.08 MWD+IFR2+MS+sag (3) 11,161.06 75.91 207.52 4,828.64 -7,675.94 -5,234.294,772.44 6,023,341.65 464,547.09 5.56 8,265.53 MWD+IFR2+MS+sag (3) 11,255.85 75.96 202.30 4,851.69 -7,759.30 -5,273.004,795.49 6,023,258.46 464,508.04 5.34 8,353.05 MWD+IFR2+MS+sag (3) 11,350.84 76.09 196.42 4,874.65 -7,846.23 -5,303.544,818.45 6,023,171.67 464,477.15 6.01 8,443.09 MWD+IFR2+MS+sag (3) 11,446.01 76.41 192.97 4,897.27 -7,935.63 -5,326.994,841.07 6,023,082.37 464,453.35 3.54 8,534.71 MWD+IFR2+MS+sag (3) 11,541.30 76.92 190.18 4,919.26 -8,026.46 -5,345.594,863.06 6,022,991.63 464,434.38 2.90 8,627.14 MWD+IFR2+MS+sag (3) 11,636.48 77.86 188.26 4,940.04 -8,118.14 -5,360.474,883.84 6,022,900.02 464,419.13 2.20 8,719.95 MWD+IFR2+MS+sag (3) 11,731.24 79.26 183.76 4,958.84 -8,210.48 -5,370.184,902.64 6,022,807.73 464,409.05 4.88 8,812.78 MWD+IFR2+MS+sag (3) 11,826.64 81.38 180.84 4,974.88 -8,304.43 -5,373.944,918.68 6,022,713.80 464,404.90 3.75 8,906.48 MWD+IFR2+MS+sag (3) 11,921.58 83.69 177.24 4,987.22 -8,398.53 -5,372.364,931.02 6,022,619.71 464,406.10 4.48 8,999.65 MWD+IFR2+MS+sag (3) 12,015.78 85.92 173.21 4,995.75 -8,491.99 -5,364.554,939.55 6,022,526.23 464,413.53 4.87 9,091.43 MWD+IFR2+MS+sag (3) 12,111.51 86.60 169.45 5,002.00 -8,586.40 -5,350.154,945.80 6,022,431.76 464,427.55 3.98 9,183.33 MWD+IFR2+MS+sag (3) 12,205.25 87.41 168.31 5,006.90 -8,678.26 -5,332.094,950.70 6,022,339.85 464,445.23 1.49 9,272.24 MWD+IFR2+MS+sag (4) 10/4/2012 3:58:44PM COMPASS 2003.16 Build 42 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODST-47 ODST-47 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODST-47 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODST-47 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 12,283.73 87.90 169.04 5,010.11 -8,755.14 -5,316.694,953.91 6,022,262.90 464,460.31 1.12 9,346.62 MWD+IFR2+MS+sag (4) 12,379.24 86.30 165.83 5,014.94 -8,848.23 -5,295.954,958.74 6,022,169.74 464,480.68 3.75 9,436.42 MWD+IFR2+MS+sag (4) 12,478.18 85.30 164.11 5,022.19 -8,943.53 -5,270.364,965.99 6,022,074.35 464,505.87 2.01 9,527.81 MWD+IFR2+MS+sag (4) 12,569.25 87.53 162.52 5,027.88 -9,030.58 -5,244.274,971.68 6,021,987.20 464,531.61 3.01 9,610.96 MWD+IFR2+MS+sag (4) 12,671.20 86.60 159.31 5,033.10 -9,126.79 -5,210.984,976.90 6,021,890.87 464,564.50 3.27 9,702.30 MWD+IFR2+MS+sag (4) 12,768.08 87.29 156.88 5,038.27 -9,216.54 -5,174.894,982.07 6,021,800.98 464,600.22 2.60 9,786.88 MWD+IFR2+MS+sag (4) 12,862.83 85.68 151.97 5,044.08 -9,301.82 -5,134.084,987.88 6,021,715.55 464,640.68 5.44 9,866.45 MWD+IFR2+MS+sag (4) 12,959.88 86.67 148.38 5,050.56 -9,385.81 -5,085.934,994.36 6,021,631.37 464,688.49 3.83 9,943.82 MWD+IFR2+MS+sag (4) 13,055.06 85.43 144.84 5,057.12 -9,465.08 -5,033.695,000.92 6,021,551.90 464,740.41 3.93 10,016.00 MWD+IFR2+MS+sag (4) 13,151.94 87.22 143.35 5,063.33 -9,543.38 -4,976.995,007.13 6,021,473.37 464,796.78 2.40 10,086.68 MWD+IFR2+MS+sag (4) 13,247.90 86.67 140.45 5,068.44 -9,618.78 -4,917.875,012.24 6,021,397.74 464,855.58 3.07 10,154.17 MWD+IFR2+MS+sag (4) 13,343.76 84.81 139.07 5,075.56 -9,691.75 -4,856.125,019.36 6,021,324.53 464,917.03 2.41 10,218.92 MWD+IFR2+MS+sag (4) 13,441.38 85.86 139.01 5,083.50 -9,765.22 -4,792.345,027.30 6,021,250.81 464,980.50 1.08 10,283.92 MWD+IFR2+MS+sag (4) 13,534.61 85.06 138.32 5,090.88 -9,835.00 -4,730.965,034.68 6,021,180.78 465,041.60 1.13 10,345.56 MWD+IFR2+MS+sag (4) 13,634.00 85.92 137.27 5,098.70 -9,908.40 -4,664.405,042.50 6,021,107.13 465,107.85 1.36 10,410.13 MWD+IFR2+MS+sag (4) 13,730.33 86.91 137.05 5,104.72 -9,978.89 -4,599.035,048.52 6,021,036.37 465,172.93 1.05 10,471.98 MWD+IFR2+MS+sag (4) 13,826.75 85.80 135.82 5,110.85 -10,048.61 -4,532.725,054.65 6,020,966.39 465,238.95 1.72 10,532.95 MWD+IFR2+MS+sag (4) 13,921.15 85.43 137.26 5,118.07 -10,116.93 -4,467.985,061.87 6,020,897.82 465,303.41 1.57 10,592.71 MWD+IFR2+MS+sag (4) 14,020.24 85.30 137.91 5,126.07 -10,189.85 -4,401.365,069.87 6,020,824.64 465,369.72 0.67 10,656.81 MWD+IFR2+MS+sag (4) 14,115.86 85.67 138.32 5,133.60 -10,260.82 -4,337.725,077.40 6,020,753.42 465,433.07 0.58 10,719.34 MWD+IFR2+MS+sag (4) 14,212.66 88.27 138.28 5,138.72 -10,332.98 -4,273.425,082.52 6,020,681.00 465,497.07 2.69 10,782.98 MWD+IFR2+MS+sag (4) 14,304.32 88.46 139.75 5,141.33 -10,402.15 -4,213.335,085.13 6,020,611.60 465,556.87 1.62 10,844.16 MWD+IFR2+MS+sag (4) 14,403.11 87.66 139.94 5,144.68 -10,477.61 -4,149.665,088.48 6,020,535.89 465,620.22 0.83 10,911.15 MWD+IFR2+MS+sag (4) 14,497.59 88.71 140.60 5,147.67 -10,550.23 -4,089.305,091.47 6,020,463.03 465,680.28 1.31 10,975.74 MWD+IFR2+MS+sag (4) 14,595.80 88.77 140.54 5,149.83 -10,626.07 -4,026.945,093.63 6,020,386.94 465,742.33 0.09 11,043.26 MWD+IFR2+MS+sag (4) 14,689.83 88.58 139.78 5,152.00 -10,698.25 -3,966.725,095.80 6,020,314.53 465,802.25 0.83 11,107.42 MWD+IFR2+MS+sag (4) 14,788.65 88.40 141.33 5,154.61 -10,774.53 -3,903.965,098.41 6,020,238.00 465,864.69 1.58 11,175.33 MWD+IFR2+MS+sag (4) 14,885.21 89.08 142.08 5,156.73 -10,850.30 -3,844.135,100.53 6,020,162.00 465,924.20 1.05 11,243.10 MWD+IFR2+MS+sag (4) 14,979.04 89.33 140.80 5,158.03 -10,923.66 -3,785.655,101.83 6,020,088.41 465,982.38 1.39 11,308.65 MWD+IFR2+MS+sag (4) 15,077.72 88.89 140.10 5,159.57 -10,999.74 -3,722.835,103.37 6,020,012.08 466,044.89 0.84 11,376.35 MWD+IFR2+MS+sag (4) 15,173.22 89.51 138.61 5,160.90 -11,072.19 -3,660.635,104.70 6,019,939.39 466,106.79 1.69 11,440.54 MWD+IFR2+MS+sag (4) 15,269.55 88.58 138.25 5,162.51 -11,144.25 -3,596.725,106.31 6,019,867.08 466,170.40 1.04 11,504.12 MWD+IFR2+MS+sag (4) 15,365.29 89.33 137.88 5,164.25 -11,215.46 -3,532.755,108.05 6,019,795.61 466,234.07 0.87 11,566.85 MWD+IFR2+MS+sag (4) 15,458.93 89.02 136.87 5,165.60 -11,284.35 -3,469.355,109.40 6,019,726.47 466,297.19 1.13 11,627.35 MWD+IFR2+MS+sag (4) 15,557.53 89.94 136.76 5,166.49 -11,356.24 -3,401.875,110.29 6,019,654.32 466,364.36 0.94 11,690.32 MWD+IFR2+MS+sag (4) 15,656.20 87.47 134.65 5,168.72 -11,426.84 -3,332.995,112.52 6,019,583.45 466,432.95 3.29 11,751.84 MWD+IFR2+MS+sag (4) 15,750.16 87.29 134.72 5,173.02 -11,492.84 -3,266.265,116.82 6,019,517.18 466,499.41 0.21 11,809.06 MWD+IFR2+MS+sag (4) 15,841.68 87.97 135.69 5,176.80 -11,557.73 -3,201.835,120.60 6,019,452.04 466,563.56 1.29 11,865.46 MWD+IFR2+MS+sag (4) 15,938.50 87.66 137.43 5,180.50 -11,627.98 -3,135.315,124.30 6,019,381.53 466,629.79 1.82 11,926.92 MWD+IFR2+MS+sag (4) 16,039.08 86.29 139.32 5,185.80 -11,703.05 -3,068.605,129.60 6,019,306.19 466,696.19 2.32 11,993.15 MWD+IFR2+MS+sag (4) 10/4/2012 3:58:44PM COMPASS 2003.16 Build 42 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODST-47 ODST-47 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODST-47 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODST-47 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 16,136.81 87.22 140.03 5,191.34 -11,777.44 -3,005.465,135.14 6,019,231.55 466,759.03 1.20 12,059.14 MWD+IFR2+MS+sag (4) 16,233.43 87.72 139.63 5,195.60 -11,851.20 -2,943.195,139.40 6,019,157.55 466,820.98 0.66 12,124.61 MWD+IFR2+MS+sag (4) 16,327.51 85.74 138.56 5,200.97 -11,922.18 -2,881.695,144.77 6,019,086.32 466,882.19 2.39 12,187.43 MWD+IFR2+MS+sag (4) 16,424.86 85.74 138.96 5,208.20 -11,995.18 -2,817.705,152.00 6,019,013.07 466,945.88 0.41 12,251.93 MWD+IFR2+MS+sag (4) 16,520.36 87.10 138.93 5,214.16 -12,067.05 -2,755.105,157.96 6,018,940.95 467,008.18 1.42 12,315.49 MWD+IFR2+MS+sag (4) 16,615.84 84.93 138.36 5,220.80 -12,138.55 -2,692.175,164.60 6,018,869.21 467,070.81 2.35 12,378.63 MWD+IFR2+MS+sag (4) 16,713.42 83.26 137.98 5,230.84 -12,210.87 -2,627.445,174.64 6,018,796.64 467,135.24 1.75 12,442.37 MWD+IFR2+MS+sag (4) 16,809.44 83.69 138.54 5,241.75 -12,282.05 -2,563.935,185.55 6,018,725.20 467,198.46 0.73 12,505.13 MWD+IFR2+MS+sag (4) 16,906.15 84.93 138.10 5,251.34 -12,353.92 -2,499.945,195.14 6,018,653.08 467,262.15 1.36 12,568.52 MWD+IFR2+MS+sag (4) 17,002.19 84.93 137.82 5,259.82 -12,424.97 -2,435.875,203.62 6,018,581.78 467,325.92 0.29 12,631.08 MWD+IFR2+MS+sag (4) 17,098.86 83.44 137.00 5,269.62 -12,495.77 -2,370.795,213.42 6,018,510.72 467,390.70 1.76 12,693.27 MWD+IFR2+MS+sag (4) 17,181.44 82.57 136.25 5,279.67 -12,555.35 -2,314.505,223.47 6,018,450.92 467,446.75 1.39 12,745.41 MWD+IFR2+MS+sag (4) 17,245.00 82.57 136.25 5,287.89 -12,600.88 -2,270.925,231.69 6,018,405.22 467,490.14 0.00 12,785.18 PROJECTED to TD 10/4/2012 3:58:44PM COMPASS 2003.16 Build 42 Page 7 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 0 153045Measured DepthRig Days Days vs. Depth ODST-47 TD'd Surface Hole 18 August 2012 5389' MD 3000' TVD TIH to clean out casing and perform FIT.POOH for BOP test.Picked up 6 3/4 production BHA SDL on location - 17 August 2012 while Drilling Surface Hole T.D. production zone at 17,245' MD 5,287' TVD 9/26/2012 16:00 Ran 4 1/2" production liner 9/30/2012 Ran 103/4 casing. Pipe management, test Bops,Drill Shoe Track and 9 5/8 New Hole. Peform Fit to 12.5 PPG.POOH pick up drilling BHA TIH begin drilling ahead POOH Wiper Trip from 9200' to 4440'Service Rig TD intermediate hole section at 12220'. TIH for clean out run, layed down BHA, TIH for additional clean in run. Ran 7 5/8 csg Surface Data Logging After Action Review Employee Name: David Mckechnie Date: 10-30-12 Well: ODST-47 Hole Section: Production What went as, or better than, planned: ODST-47 is the first well this mudlogger has been involved in without the involvement of MPD and their Correolis flow sensor. This was a little difficult, as we didn't have a flowout sensor of our own and had to rely on the Rig Floor's readings, with questionable accuracy. That being the case, we had to reinforce the readings we were seeing in real time with checks and balances provided by Pit Watchers, CCU and RSC. Difficulties experienced: The most difficult part of the process was departing from a system of flow out sensors with undisputabable accuracy and being able to report fluid loss events immediately; to a much more involved process that required time, coordination and extensive communication to verify events in the midst of solids control, losses and tranfers to the RSC/CCU. Recommendations: Get a flowout sensor installed in the most reliable postion of the flowline available to better combat potential well control situations. Innovations and/or cost savings: N/A