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Home My WebLink About213-148Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250723 Well API #PTD #Log Date Log Company AOGCC ESet # END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON T40691 KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE T40692 MPU F-05 50029227620000 197074 7/1/2025 READ T40693 MPU J-02 50029220710000 190096 5/21/2025 YELLOWJACKET T40694 MPU R-106 50029238160000 225033 6/8/2025 HALLIBURTON T40695 MPU R-107 50029238190000 225049 7/11/2025 YELLOWJACKET T40696 ODSK-41 50703205850000 208147 6/13/2025 HALLIBURTON T40697 ODSN-02 50703206710000 213046 6/13/2025 HALLIBURTON T40698 ODSN-16 50703206200000 210053 6/14/2025 HALLIBURTON T40699 ODSN-17 50703206220000 210093 6/14/2025 HALLIBURTON T40700 ODSN-24 50703206620000 212178 6/15/2025 HALLIBURTON T40701 ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON T40702 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON T40703 PBU 07-23C 50029216350300 225043 7/4/2025 HALLIBURTON T40704 PBU 14-18C 50029205510300 225040 6/25/2025 HALLIBURTON T40705 PBU 15-33C 50029224480300 216075 7/3/2025 HALLIBURTON T40706 PBU C-30A 50029217770100 208169 7/1/2025 HALLIBURTON T40707 PBU E-09C 50029204660300 209095 6/30/2025 HALLIBURTON T40708 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON T40709 PBU GNI-02A 50029228510100 206119 7/4/2025 HALLIBURTON T40710 PBU GNI-02A 50029228510100 206119 7/3/2025 HALLIBURTON T40710 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU J-07C 50029202410300 225026 5/30/2025 HALLIBURTON T40712 PBU L-105 50029230750000 202058 6/24/2025 YELLOWJACKET T40713 PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET T40714 PBU NK-25 50029227600000 197068 6/5/2025 YELLOWJACKET T40715 PBU P2-06 50029223880000 193103 6/19/2025 HALLIBURTON T40716 PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET T40717 T40702ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:54:00 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU-05 50283202030000 225037 7/3/2025 YELLOWJACKET T40718 TBU D-08RD 50733201070100 174003 6/4/2025 READ T40719 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:53:40 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Punch, Modify Gas Lift Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 19,329 feet NA feet true vertical 6,377 feet NA feet Effective Depth measured 19,210 feet 11,399, 12,445 feet true vertical 6,371 feet 6,109, 6,336 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.4#, L-80 12,454' 6,337' 2,346' MD Packers and SSSV (type, measured and true vertical depth) See Above 1,993' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Same 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 5,410psi10,387' 2-7/8" HES "NE" TRSV Intermediate 2 7"12,762' 6,358' 7,240psi Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert ryan.rupert@hilcorp.com 907-777-8503 NA Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG N/A measured true vertical Packer MD 1,158' Size 158' 3,452' Length Slotted Liner 2,375' 6,765'4-1/2" Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1,182 Gas-Mcf 1011 9.5 1200591 792 2951.6 312 396 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 213-148 50-703-20676-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0355036, ADL0389950, ADL0389958 OOOGURUK ODSN-28 10,152' 5,556' Casing 11-3/4" OOOGURUK / NUIQSUT OIL Conductor 5,549'Surface Burst NA Collapse Intermediate 1 Plugs Junk measured measured Intermediate 2 16" 9-5/8" 158' 5,549' 4,762' 2-7/8" SLB MRP Packer, 5"x7" HRD-E ZXP LTP TVD 7" (repaired 2017)2,005' NA 3,180psi 5,410psi 7,500psi 5,830psi 5,750psi 7,240psi 8,430psi 3,090psi 6,371' 2,375' 19,210' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:23 pm, Jul 17, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.07.17 14:11:29 - 08'00' Sara Hannegan (2519) RBDMS JSB 072525 DSR-7/21/25JJL 8/12/25 Well Name Rig API Number Well Permit Number Start Date End Date ODSN-28 Slickline / Eline 50-703-20676-00-00 213-148 6/15/2025 6/18/2025 6/15/2025 - Sunday Slickline: ***WELL FLOWING UPON ARRIVAL*** (gas lift-for rate) ATTEMPTED TO RUN FLAPPER CHECKER, SD HIGH @ 70' SLM RAN 5' x 2.25" DD BAILER TO 2,000' SLM (no issues) RAN 2 7/8" BRUSH, 2.25" GAUGE RING TO 500' SLM (brushed 3 1/2" x 2 7/8" xo @ 70') RAN 2.34" NO-GO W/ FLAPPER CHECKER TO 2,331' SLM / 2,346' MD (appears open, restrictions @ 70' & 1,815' slm) ***CONT WSR ON 6/16/25*** 6/16/2025 - Monday Hilcorp Alaska, LLC Weekly Operations Summary Slickline: ***CONT WSR FROM 6/15/25*** (gaslift-for rate) DRIFTED W/ 10' x 2.25" DD BAILER TO DEVIATION @ 12,084' SLM (80*, bailer empty) SET 2 7/8" X-CATCHER IN X-NIPPLE @ 11,567' SLM / 11,562' MD (5' corr) PULLED BK-S/O FROM STA #1 @ 8,925' MD (wheel missing from R.stem) RATTLED MANDRELS W/ 2 7/8" BRUSH, 2.30" GAUGE RING TO X-CATCHER ATTEMPTED TO TAG X-CATCHER W/ BARBELL 2.29" LIB, UNABLE TO PASS SLB GAUGE MANDREL @ 11,204' SLM OPS LOADED IA W/ 250bbls WATER & 64bbls DIESEL SET BK-DGLV IN STA #1 @ 8,925' MD RAN BARBELL 1.85" MAGNET TO TOP OF X-CATCHER @ 11,567' SLM (no recovery) PULLED 2 7/8" X-CATCHER FROM 11,567' SLM (empty) ***CONT WSR ON 6/17/25*** Well Name Rig API Number Well Permit Number Start Date End Date ODSN-28 Slickline / Eline 50-703-20676-00-00 213-148 6/15/2025 6/18/2025 Hilcorp Alaska, LLC Weekly Operations Summary 6/18/2025 - Wednesday Slickline: ***CONT WSR FROM 6/17/25*** (gaslift-for rate) SET 2-7/8" LOWER HIGH-FLOW PACKOFF @ 11,351' SLM. SET 2-7/8" UPPER HIGH-FLOW PACKOFF, 10' SPACER, IM G/L MANDREL w/ 20/64" ORIFICE INSTALLED @ 11,348' SLM. SET 2-7/8" AD-1 TUBING STOP @ 11,334' SLM. TOOLS TEMPORARILY DETAINED @ 700' SLM, PUMP METH TO FREE UP.(hydrates/ice plug) BRUSHED TBG W/ 2-7/8" BRUSH & 2.04" GAUGE RING, TOOLS S/D @ 2,272' SLM. Well Diagnostics: ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** T/I/O = 1120/1376/0. Bleed IAP (cold TIFL) ***PASSED***. IA FL @ 10,800' (534' above tbg punch). Bled IAP to 300 psi. Monitored for 1 hour. IAP & IA FL unchanged. Final WHPs = 1160/301/0. Slickline: ***CONT WSR FROM 6/16/25*** (gaslift-for rate) MADE 2 RUNS W/ BARBELLED 1.85" MAGNET TO DEVIATION @ 12,330' SLM. (no recovery) SET 2-7/8" A2D TUBING STOP(oal-24") @ 11,348' SLM/ 11,343' MD. OPS PERFORMED PASSING MIT-IA TO 2701psi. RD SLICKLINE, RU ELINE AND PERFORM TUBING PUNCH, RD AND RU SLICKLINE DISPLACE WELL WITH GAS ***CONT WSR ON 6/18/25*** ELine: ***CONT FROM SLICKLINE WSR***(gas lift-for rate) RU ELINE (SWAP OVER FROM SLICKLINE) RIH W/ CH-1.375" FN/RLR/WT/WT/WT/CCL/XO/FH/1.56" RTG/DECENT OAL: 28.6' CCL TO TS: 5.5' PUNCH INTERVAL: 11334'-11337' CCL STOP DEPTH: 11328.5' ***RESUME ON SLICKLINE WSR*** 6/17/2025 - Tuesday Oooguruk Field Last Completed: 10/5/2017 PTD: 213-148 API #: 50-703-20676-00-00 Casing 16” 16" A 2 B C 11-3/4"Size ID Top Btm Btm TVD 16”N/A Surface 158' 158' 11-3/4" 10.772" Surface 5,549' 3,452' 9-5/8" 8.835" 5,390' 10,152' 5,556' 7"6.276" Surface 2,375' 2,005' 7"6.276" 2,375' 12,762' 6,358' 4-1/2” 3.958" 12,445' 19,210' 6,371' 1 2-7/8" 2.441" Surface 12,454' 6,337' D No. MD(ft) TVD(ft) Inc A 2,346 1,993' 63 9-5/8"B 4,437 2,941' 63 C 5,402 3,387' 63 E D 9,021 5,037' 62 E 11,203 6,035' 67 0 F G 11,399 6,109' 69 H 11,466 6,134' 70 G I 11,562 6,165' 71 J 12,445 6,336' 86 H K 12,452 6,337' 86 I St. MD (ft) TVD (ft) Inc Valve Latch Port 2 4,337 2,895 62 Dummy BEK NA 1 8,925 4,992 63 Dummy BK-5 0 0 11,341 6,088 68 Orifice NA 20 686,082'11,325F 2-7/8" Flowco IM Gaslift mandrel patch across trubing punch, mid element 11,328' to 11,343' MD, OAL 20.11', set on 6-18-2025 1.000" Intermediate 2 26#, L-80, BTC-M & Hyd 563 Date 10/2/2017 2.426" 2.313" UPPER COMPLETION EQUIPMENT ID Description 12.6#, C-110, Hyd 521 2.313" 4.360" 2-7/8" HES "NE" TRSV 2-7/8" SLB "X" Nipple Production Liner 6/16/2025 Type KBMG KBMG CHEMICIAL INJECTION MANDREL (CIM) 2-7/8" IM 6/18/2025 GAS LIFT MANDRELS 2-7/8" x 1" ODSN-28 Schematic Nuiqsut Producer 11-3/4" 11-3/4" hole, 80 bbls 15.8 ppg Class 'G', date? log shows TOC at ???' MD9-5/8" 5,557' Driven in 24" hole 14-1/2" hole, 590 bbls 11.1 ppg PF 'L', 151 bbls 15.8 ppg Class 'G', TOC at surface Wt/ Grade/ ConnType 7"9-1/2" hole, 115 bbls 15.8 ppg Class 'G', TOC estimated 500' above top of Kuparuk 12,780' CASING DETAIL 4-1/2" Uncemented Frac Sleeves with Swell Packers 19,329' CEMENT DETAIL Cement Details Hole MD 158' 2-7/8" SLB MRP Packer SLB Sliding Sleeve w/X Profile 10,170' TUBING DETAIL 2.313" 2.313" 26#, L-80Intermediate 2 (Repaired 9/13/17) Tubing 6.4#, L-80, IBT-M 40#, L-80, HYD 521Intermediate 1 Surface Conductor 60#, L-80, BTC-M 109#, X-65 NA 2.313" 2.378" 9-5/8" x 11-3/4" Hanger 2-7/8" SLB "X" Nipple 2-7/8" SLB Gauge Mandrel 3.02" 3.625" Self Aligning Guide Shoe, bottom @ 12,454' SLB "X" Nipple 5" x 7" HRD-E ZXP Liner Top Packer CIM 11,269 6,062 67 Dummy BK-5 ?9/15/2017FO-1 J, K WRONG SWELL PACKERS RUN – 4 ½” 13Cr80 13.5 # Swell Packer: Burst = 9,020 psi / Collapse = 8,540 psi Swell Time to Frac @ 6.125" = 62 days / @ 6.500" = 137 days Frac Sleeves (x 11) from 13,315' MD / 6,367' TVD to 19,083' MD / 6,362' TVD Swell Packers (x13) One Ported Pup from 19,198' MD to 19,202' MD 7" 4-1/2" liner to 19,210' MD 70 degree inclination @ ~11,467' X X X ROC CIM SSSV XN X 3', 6spf Tubing, 0е phase punch @ 11,334-11,337' MD (6,086-6,087' TVD) ODSN-28 Schematic 7-17-2025 Last edited by: DH 7/17/2025 ED V STATE OF A ALA.OIL AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS APR 10 2018 1.Operations Abandon U Plug Perforations LJ Fracture Stimulate U Pull Tubing U wn LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Scale Squeeze w/CTQ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Caelus Natural Resources Alaska,LLC Development 0 Exploratory ❑ 213-148 3.Address: 3700 Centerpoint Drive,Suite 500 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-703-20676-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 389950/ADL 389958 ODSN-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Oooguruk- Nuiqsut Oil Pool 11.Present Well Condition Summary: Total Depth measured 19,329 feet Plugs measured N/A feet true vertical 6,371 feet Junk measured N/A feet Effective Depth measured 19,210 feet Packer measured See attached,pg.3 feet true vertical 6,371 feet true vertical See attached,pg.3 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5,506' 11-3/4" 5,549' 3,453' 5,830 psi 3,180 psi Intermediate 4,762' 9-5/8" 10,152' 5,556' 5,750 psi 3,090 psi Int 2 Tie Back 2,337' 7" 2,375' 2,005' 7,240 psi 5,410 psi Intermediate 2 10,387' 7" 12,762' 6,358' 7,240 psi 5,410 psi Liner 6,765' 4-1/2" 19,210' 6,371' 11,590 psi 9,200 psi Perforation depth Measured depth See attached,pg.2 feet SCAB True Vertical depth See attached,pg.2 feet Tubing(size,grade,measured and true vertical depth) 2-7/8",6.4# L-80, IBT-M 12,453'MD 6,337'TVD Packers and SSSV(type,measured and true vertical depth) See attached,pg.3 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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: 932 2,031 0 1,144 454 Subsequent to operation: 863 1,741 0 1,122 445 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory p Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ p WAG p GINJ p SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-039 Authorized Name: Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staf Completion Engineer Contact Email: rami.1asser@caelusenerpy.cot71 Authorized Signature: Date: y-to-i S Contact Phone: 907-343-2182 Form 10-404 Revised 4/2017 RBDMS.1L. APR 1 1 2010Submit Original Only ,-,e, L-/i-,X • • Attachment 2 AOGCC Form 10-404 Sundry Report Box 11 - Perforation Locations Well: ODSN-28 Top (MD) Top (TVD) 4-1/2" SLHT Ball Actuated Sleeve w/seats 13,315 6,367 4-1/2" SLHT Ball Actuated Sleeve w/seats 13,764 6,366 4-1/2" SLHT Ball Actuated Sleeve w/seats 14,469 6,358 4-1/2" SLHT Ball Actuated Sleeve w/seats 15,103 6,357 4-1/2" SLHT Ball Actuated Sleeve w/seats 15,636 6,354 4-1/2" SLHT Ball Actuated Sleeve w/seats 16,248 6,349 4-1/2" SLHT Ball Actuated Sleeve w/seats 16,836 6,342 4-1/2" SLHT Ball Actuated Sleeve w/seats 17,444 6,340 4-1/2" SLHT Ball Actuated Sleeve w/seats 18,051 6,339 4-1/2" SLHT Ball Actuated Sleeve w/seats 18,681 6,335 4-1/2" SLHT Ball Actuated Sleeve w/seats 19,080 6,362 Pre-Perforated Pup 19,198 6,370 • • Attachment 3 AOGCC Form 10-404 Sundry Report Box 11 - Packers & SSSV Well: ODSN-28 SSSV MD TVD 2-7/8" HES "NE" TRSV 2,345 1,991 PACKERS 2-7/8" x 7" Retrievable Packer 11,398 6,109 5" x 7" Baker ZXP Liner Top Packer 12,445 6,336 HES Swell Packer 13,087 6,364 HES Swell Packer 13,127 6,365 HES Swell Packer 13,467 6,367 HES Swell Packer 14,075 6,366 HES Swell Packer 14,777 6,355 HES Swell Packer 15,374 6,355 HES Swell Packer 15,907 6,354 HES Swell Packer 16,516 6,343 HES Swell Packer 17,145 6,344 HES Swell Packer 17,750 6,345 HES Swell Packer 18,358 6,337 HES Swell Packer 18,983 6,355 HES Swell Packer 19,150 6,367 •O Operations SummaryReport Sta • p p - Well Name: ODSN-28 CE State EL S Energy Alaska Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 3/8/2018 3/9/2018 2,351.0 00:00 3/8/18-00:00 3/9/18 (Scale Squeeze) *20:00 pm SLB CT arrived @ ODS with support equipment. *SLB crew&LRS layed herculite in front of ODSN-28. *Completed well handover from Ops to wells. Shut in well. LRS freeze protected tubing w/18 bbls of diesel.(3000') *SLB staged 1.75"reel utilizing 275 ton crane. (88k). *SLB staged Ops cab,tool trailer, BOP stack,coil pump. Rig up high pressure kelly hose from test header to 212 bbl tank. *GE installed 3"secondary gate valve.(WC barriers=TRSV&5k Gate valve) *Rig up 3"water supply line from RSC to SLB coil pump. 3/9/2018 3/10/2018 2,351.0 00:00 3/9/18-00:00 3/10/18(Scale Squeeze) *Rig up all 2"1502 hardline from reel to pump to P-sub. *Flange up SLB BOPs/P-sub to wellhead. *Hook up all electrical cables and transducers for job monitoring. *Hydraulic leak under the OPS cab.Clean up all hydraulic fluid from area. *Re-spot the spooling unit. *Stab coiled tubing into the injector head. Make up CTC and PT nozzle. *Spot cement guideline blocks on north side of well bays. *Make up injector head to BOPs on wellhead.Function test BOPs. *Launch 1.18"drift ball in 1.75"coiled tubing. Pump drift ball through 1.75"coiled tubing w/50 bbls of diesel. *Shell test BOP stack to 250 psi low/4400 psi high.Pull test 20k.Push test 15k. *Recovered 1.18"drift ball in pressure test nozzle. 3/10/2018 3/11/2018 2,351.0 00:00 3/10/18-00:00 3/11/18 (Scale Squeeze) *Make up BHA= 1.75"CTC, DBPV,2.15"MHA(11/16"ball),XO 1.5"MT,20'x 2.20"gauge carrier with CCL/Gamma/Temp and 2.20"nozzle(.625"ID). *RIH with 2.20"carrier with CCL/Gamma/Temp to 3500'ctm. Begin pumping 50 bbls of slick seawater out in front of BHA. *Log SLB CCL/Gamma/Tempt tool from 11,400'ctm to 18,500'ctm @ 60 fpm. Flag pipe. *Log SLB CCL/Gamma/Tempt tool from 18,500'ctm to 11,400'ctm @ 60 fpm. Pull to surface w/BHA. *On surface w/SLB memory tools.Good data.Send raw data to Anchorage team. *Make up BHA=1.75"CTC, 1.75"DBPV, 1.75"stingers,2.125"XO, 1.75"power nozzle. *RIH w/1.75"power nozzle to 3,500'ctm. Pump 50 bbls of slick seawater. Continue running in hole while pumping slick SW down back side. *Depth: 12,000'ctm.Continue running in hole. *SLB freeze protected tubing x 1.75"coiled tubing w/10 bbls of diesel. 3/11/2018 3/12/2018 2,351.0 00:00 3/11/18-00:00 3/12/18 (Scale Squeeze) *Continue RIH with 1.75"'Coiled Tubing and jet swirl nozzle to 18,500'ctm to complete the scale squeeze program. *Reach 18,500'ctm.Pump stage 1 from 18,500'ctm to 17,500'ctm while laying in 8 bbl pre- flush and 60 bbl main treatment. Pump 150 bbl over flush while sitting at 17,500'ctm. *Pump stage 2 from 17,500'to 16,000'while laying in,pump the 8 bbl pre-flush,60 bbl main treatment and 150 bbl over flush. *While pumping the over flush the SLB pump went down and was inoperable. Line up LRS and continue pumping the scale squeeze. *Pump stage 3 from 16,000 to 14,500'while laying in,pump the 8 bbl pre-flush,60 bbl main treatment and 150 bbl over flush. *Pump stage 4 from 14,500'to 13,000'while laying in,pump the 8 bbl pre-flush,60 bbl main treatment and 150 bbl over flush. *Freeze protect the Coiled Tubing with 45 bbls of diesel while POOH. *Pump 10 bbls of diesel down the TBG x Coil Annuli and 5 bbls of diesel down the coil to ensure a good freeze protect. *Encounter a 15K overpull at 1700'ctm,line up LRS and pump 25 bbls of hot diesel. *On surface w/BHA.Unstab injector head from well and drop risers,rack back injector head. *Unflange BOP stack&top gate valve from wellhead and move to ODSN-37. *Winds increasing 35+mph.Begin breaking down hardline and spooling transducer cables. *Rig down 2"1502 return line from test header and move over to ODSN-37. Page 1/1 Report Printed: 4/5/2018 • 0 ODSN-28 Nuiqsut Production Well Completion FINAL 10-05-2017 i I No. Upper Completion Equipment MD(ft) TVD{ft} I A `JetcoG ray Tubing Hanger 74 x• B 3-1,2"9.2 L-80 TC-11 Pin x Pin Pup CD C 3-12"L-8092#tubing joint TC-II BoxxPin(2Johis) i$: 0 3-12"9.2#L-80 TC-9 Box x 2-7/8"&4#BT-M Pin Crossover E 2-7/8"6.40#L-801BT-M Tubing K € 2-718"6.4ft L-86 BT-M 15 t Pup Joint Box x Pin G 2-7/8"HES"NE"TRS V w/2313"Packing Bore 1ST-M Box x Pin GLM#2 X Co 27/8"6.4#L-80 BT-M 15ft Pup Joint Box x Pin 0 Co i11 DGLV 16"Conductor I 2-7/8"6.4O8L-80113T-M Tubing J 2-7/8"6.4#L-80 BT-M 15ft Pup Joint BOX x Pin Packer Fluid mix: K 2718"x1"GLM#2 KB NUIBT-LIBox aPm Inhibited Kill weight L 2-718"6.4#L-8087-M15ftPup Joint Box xpin Brine M 2-7/8"6.43#L-80/87-M Tubing(2 Joints) with 2000'TVD El 15ft2-718"&4#BT-M Box x2-7/8"6.4#ELIE PmL-80Crossover Pup-Joint Bax xPin i ? diesel Cap 0 2-7/8""x"Nipple 312.313"ID)EUE Box xPin --_, - 27.1 P 15ft2-718`&4#EUEBac x2-718"6.4#EIT-MPinL-80Crossover Pup Joint Box xPin Q 2-7/8"6.40#1.8016T-M Tubing R 2418"6.44:L-80 BT-h115ft Pup Join Box x Pit 11-3/4"60#L-80 S 2-718"x 1"GLM#1 KB EC IBT-11.1 Box x Pin ,. -r... BTC Surface T 2718"6.4#1-80 BT-M 15ft Pup Joirt Box x Pin U 2-7/8"6.46#L-BO IBT-M Tubing(2 Joints) 7"Casing Repair: Casing V 15ft27/86A#BT-LI Box x2-718`6.4#EUEPhL-80Crossover Pup Joint Box xPin New 7"Casing from 2,375'MD to @5,549' MD/ .' 2-7/8""X"Nipple#2(2.313"10)EUE Box xPin g_ 1 Surface 3,453'TVD X 15ft 2-718"6.4#EUE Box x2-718'6.4#BT-MPin L-83 Crossrarer Pup Joint Box x Pin cemented to V 2-7/7'6.40#L-80187-61Tubirg(1 Joints) Z 27/8"6.4#L-80 BT-M 15ft Pup Joint Btxt x Boat rrrr surface AA 2-7IS"Pvesture/Temperature gauge 2-7/8":BT.M Pnx Po with l-w re toswfa ce 11202 +039 BB 2718"6.4»1-80 13T-PA 1511 Pup Joint Bit x PM 9-5/8"40#L-80 CC 2-7/8 6.40#L-80187-M Tubing(1 Joi ts) Hydril 521 6D 2-7/8"6.414 °. EE 2-7/8"Chemical Injection Mandrel with corvtrallne to surface v,/I8T-P.1Box xPkn 112,2 __ I Intermediate 1 FF 2-718"6.4:L-80 BT-P.115ft Pup Joint Box x Pin GLM#1 A 4J S•:' Casing GG 2.7/8"6.40#L-80187-M Tubing it Joints) 5/16"OV I @10,152' MD/ HH 15ft2-718`6.4#BT-MBoxx2-71r6.4#ELIEPinL-83CrossoverPupJointBoxxPin ® V`1 H 2-7/8"x7'Retrievable Packer 2-7/8"6.4#EUE Boxx Pin 11398 5,556'TVD JJ 15ft2-718"6.4#EUEBox x2-7/8'6.4#BT-M Pit L-0 CrossoverPupJointBoxxPh LiI I m Cemented 500' IOC 2.7/8"6.40#1-80187-M Tubing 12 Joints) above shoe LL 15ft2-7(8'6.4#BT--MBarx2-718"6.4#EUEPinL-80Crossover Pup Joint Box xPh •I® 2.7/a"Sliding Sleeve w/'x'Nipple Profile 2.313°1.0.WE 8 RD Box x Pin Run in Closed f Sleeve Shifts R1 11 x CD Down to Open) 11466 •-i2 NN 15ft 2-718"6.4#FOE Box x2-718"6.4#BT-MPn L-80 Crossover PUDJaint Bax x Pin 00 2-7/8"6.410 L-80IBT-M Tubing MM e PP 15ft2-7/8"6.4#BT-MBox x2-7/8"6.4#EUEPin L-80Crossover PUO Joint BctxxPin 2-7/8"6.4#L-80 00 2-7/8""'x"fiipp ,,leifif2.313"ID)ELIEBoxxPinw/RI-ICPiug ,- . t'i ---> 0 ilii IBT-M TubingRR 15ft 2-718"6.4#EUE Box X2-718'6.4#BT-M Pin L-80CrossoverPup Joint Box PinMii *i SS 2-7/8"6.40#L-80187-M Tubing Ni (Upper Completion) TT 4"Auto Entry Mu le ShoelBT-M Boxup bucked up to 1 joint of 2-7/8"6.404+1-801ST-h1 Tubing ,.......... r iiii End of Assembly 12453 6337 TOC Estimated 500'above top of Kuparuk •0 `:::�f WRONG SWELL PACKERS RUN-4'/x"13Cr80 13.5#Swell Packer: Burst=9,020 psi/Collapse=8,540 psi 6-1/8" Hole TD // 25 Swell Time to Frac @ 6.125"=62 days!@ 6.500"=137 days @ 19,329' MD/6,371'TVD 7"26# L-80 \ �t ®0 -- 43 - so -- 57 - 64O 7B -85- -9z s9 G BTC-M & Hydril 563 �;\ ,�® - - ):(1- - - - ® - _ -- Intermediate 2 Casing _ _ r _ _ _ _ _ 0, 2,@ 12,762' MD/6,358'TVD .\,�`--- --- --- - --- -- £y1--- 100 -_" 4-t/"Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve • 4111 • ODSN-28 Nuiqsut Production Well Completion FINAL 10-05-2017 iiiiii I 1iiiii No Lower Completion(All eq ulp merit m.lithan 10,000p9 rated) MD[it) Tvb(ft) 13 --5-', :ri z FC. T _ rJT•.. .r Fw Ce Cst6.�n 3ndFleetock rq;:.r 12445 1331 19 4,V 326s/ftC 110 Hydra 5/1!suer 1011 i��J 20 4h'12.6efft Ft i521-6'Pup with slide on 4biart centralizers zl " ',man Swell Ars ler 14-14"130801359 Hydlg g1}00365'-(9020 iwi Bunt/11540 pot Collapse)9 m0Mlong oil activated 13687 6364 with slide on Volant centralizers pin end i• -.,. '.'••"13080133R H,d0521}DOS.S'-{9020 p1180nt/15mp6i Co8.apse)9mHe7 long activated 13127 6365 �\K j(� centralizers pin end J [i)) 23 4•y"1204,TtC 130 kyd,1521 Iweo 24 Remu n Cart ler Sub[Job 1 21847-31 211:05779/RWS-536] 13274 6367 GLM#2 IL M.64-1/2'UHT Sal Actuated Sleeve(3.1109 bail/z.955Sat) 13315 6367 ID iii•. 20 Reiman[angel S b[JOb V 21647-11-1 X5778/RW5-834( 13347 6367 DGLV Ai 'i` -' 16"Conductor 27 4.1,1'12.6apt C-110 Hyd152114.0 __ 4.34'2264/Ft Hldli 521-6'Pup wtths8deon%0tart centralizers Packer Fluid mix: Ha3Mstml Swell Aacher(4-X'7ryddi 521)C 385"-9metabngdacl6rated dementwith side on Valant Ce t,aBeers Pb,end 13467 6367 iiiii Inhibited Kill weight Brine 3,7 4X"12641ft C-130 Hydra 521 Liner 31 Resman Cartler3b[)0 6 1 21847-16 2 R05777/RW5-8331 13723 6367 with 2000'TVD 32 M84-1/2'SLHTSal Acteted Sleeve(z925baii/z.867Seat) 13764 6356 33 Resew%Cartier Sub[Jobe 21847-101 R05m/RW1-833) 13795 6366 \iiii , diesel cap 34 4-X'126tatC-130 Hydra 321 Liner 35 4JS'1268/kHearn 321-6'Pup with slide onsobs centralizers 36 fla3ed b,etOn Swell limier(4X'Hydr11527)Q75-85"-9zneta long ell w ii I 1 ril:••;•••••:••11 .. activated denautfthslde on Want cent,a&ers pM end 14075 6366 11-3/4"60#L 80 37 a x'1261bTic-17%7 Hydra szl user BTC Surface 38 Rosman OfrlerSrb[lobs 21647-9-2 1403-776/RWS-8321 14627 6358 39 1-1184-1/2'StHT Pal Actuated Sleeve(2362 bail/2786 Seat) 14469 6358 7"Casing Repair: Casing 40 Reiman Carrier Sub[AMR z1847-9-1RO5-776/RWS-832) 14500 6357 New 7"Casing I @5,549' MD/ 41 61'4'12.641/ft C-1708 OA5213Mr from 2,375'MD to I 42 Ala'12 W.6sft Hydra 6'Pwith slide on%blare centralizers 3,453'TVD Surface13 Hallburtn5well Packer 4-34'aryddi521)m5.5-9 meter long of aclNated deme+tweb slide en Yola:nt rn+tra&es pin end 14777 6355 cemented to 44 4.11'12.6e/ft C-110 Hydra 521 liner T P surface 45 Rein n Cartier Sub[Jobs 21847-8-2905-775/RW5131) 15062 6357 46 19.64-164 S3"T Sal Actuated Sleeve(2.761 bai l/2.706 Seat) 15103 6357 47 Resman Cartier Sb[Job 521847-8-1 R05-775/RW5-531) 15135 657 9-5/8"40#L-80 46 All'1264/ftC-170Hydra 521Liner Hydril 521 49 4.14'12.66/FtH,dni 321-6'Pup with Skit on Velars centralizers 50 Han 500194019 4-14"Hyddi521)005.85"-9 meta bng o8 activated element slide en Yount centralizers pun end 15374 6355 Intermediate 1 GLM#1 _,1 s Casing 51 a-x'1265/ItC-11Hydra 5uLiner 5/16"OV52 ResmanCarrier Sub[lobe 71847-7-21105-774/RWS-630J 15595 6355 O '• W @ 10,152' MD/ 53 21184-112`SUIT Sal Actuated Sleeve(Zb8l ban/2.616 seat} 15636 6354 5,556'TVD 54 Rearms Carrier Sub(Jobe 21347-7-13965-774/RWS-630] 15668 6354 55 4-k 12.66ft C-110 Hydra321 Ur. LiI AA Cemented 500' 55 4-V L'SS TtHdp n3521-6'PwW rs slide on Vo acentrablas above shoe CDEE Z ® M 2-7/8"6.4#L-80 °°• A IBT-M Tubing IiiII iii 1.0 (Upper Completion) TOC Estimated 500'above top of Kuparuk 1iiii :iii, iiii 'ii',er IP 0 WRONG SWELL PACKERS RUN—4%"13Cr80 13.5#Swell Packer: /".11*, Burst Burst=9,020 psi/Collapse=8,540 psi 6-1/8"Hole TD 25 Swell Time to Frac @ 6.125"=62 days/@ 5.500"=137 days 19,329'MD/6,371'TVD 7"26# L-80 ®, '00 43 50 57 64 ® 78 85 92 gg BTC-M&Hydril 563 �! ® r- -■--- - - - - - - - a - Intermediate 2 Casing ® � ��-, g_I_ J. I- _ I_r - (_ _T _ NI= o @ 12,762' MD/6,358'TVD \ 4-'/2" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve 0 411 a ODSN-28 Nuiqsut Production Well Completion FINAL 10-05-2017 i 57 I59e7 6354 naliuRan Sled Amite r(45Y Hydra 52000565'-9meter' ,.sated dement with side on Vo lent centralizers pin end --- 58 4Y!'1.268/ft 0-110 MEW 521 Urea. 59 Re5man Carriersui[lob*218472 R0S-773/R05-291 16208 650 KJG�..-.- 60 X1841/2.5187 Gil Actu4Ded Sleeve(2.603 bee/2592Seat) 16248 6349 61 ResmanCarrierSllb[lob 021847-4-1 RC6-7731RWS-829] 16277 6348 62 4-h"126611 C-110Hyd^'M1.L re:- -,,>O':: 63 41f1260/ft Hydra S21-6"Ptipxth soon VWantcentralners 64 Mike Ron Swill Packer(41'i"Mydd 571)0D 585'-9meiel long Oiactivaled dement with sideon Voladcentrafzers pen end E6535 6343 GLM#2i 0 65 YC1z6*Jtc-uaHymsc xl . o °i DGLV I'i:;ii ' , 4 16"Conductor 66 R'"'"Carrier 5431'°b*n847-5-2 RC6-772111006$281 16796 643 67 NtB4f/Y SLUT Bal Actuated Sleeve(2527 ban/Z4775eat) 16636 6342 68 ResrnanCafierSab[bb 621647-5-1 RO6-772/8005-826j 16867 6342 Packer Fluid mix: fa 4C 1-164,4)c-110, 52112,.991nC 70 4-!'1264fit Hydra 521-6 Pup with sada on Veart cent:.Tzar Inhibited Kill weight Brine 71 Hafbu Ron Swill Pad er(4 ,65251 34 116500665'-9meter long oia activated dement with m h side anV loot centralizers pe ed 17145 6-0-04 With 2000'TVD rz 4/1'1z60/ft C-110Illtla 521 firer 73 Resmaii Canier5rb'lob*21847-42 R[6-771/MA6-827) 17404 6330 diesel cap 74 FRB 4-1/2'SIM EDI Actuated Skew(2.452 ball/Z444 Yat) 17444 6340 75 Resman CanierSub[lob*21847-4-11105-771/11145.827] 17473 041 76 4-1t"1268r7t 5-110521-.6"Pun a n with side an Vo%a er 77 414'126*/1X-4'$41- ,em cenbalaets 11 3/4"60#L-80 76 Hakbo Ron Swell Packer(4-1i'Hydd 521)005.85'-9meter longoi activated dement nidi side on Vobrd centrainers pen end 17750 05 BTC Surface 79 4-Ye 12640t C-11.01rybi416ne- 7"Casing Repair: Casing 80 ResmanC3nierStb[lob*21847-3-2 R05-770/R365-8261 19010 6339 New?"Casing 81 X184-1/2'SUIT Bav a8ActuatedSlee(Z379ball/2332Seat) 16051 639 from 2,375'MD to @ 5,549'MD/ 82 Resman Cartier Sob[lob*216447-3.1 RCS-770/0005-626) 16083 639 3453'TVD 83 4-}i"4-}i"1z6*JFt 0-110 H)466 52i tires , Surface 84 431'1266/7t Mydti521-6'Pup with 85de on Votam centralises cemented to es surface Ham"nal Swell Packer[4-35*Hydd 521)0D 5a5'-9meter long of activated dement with side on Volad centralizers pin endTM e*ass 637 86 411'126*/ft 0-110 Hydra 521 Graf �3 87 Rpsman Cartier Sub[bb*21847-2-2 ROS-769/0005-825) 18639 6335 Y 9-5/8"40#1-80 rti 88 r1e41/r Stift Bal Act tinted Sleeve(1307 ball/2261 Seat) 18681 6335 ... 1.1 89 ResmanCierSlb(lob 8 21847-2-1 1115-769/R05-625) 18713 6336 Hydril 521 90 a-54 126*/lt C-110 Hydra 521 liner 91 4-1r 126x/ft Hyde3 RI with Side on Votamcentaizer1 ' Intermediate 1 GLM#1 A _� s Casing 92 HaliwRon Swell Padter(4-x'Hydd521)00565'-9meterl�nitactivated demerdwithsideonVolantcentraizers pin end 19983 5/16"OV ' 93 4d5'126*/ft C-110Hyere5211:m IMI ' w p@ 10,152MD/ 94 ResmanCarrier Sub[lob 021847-1-2RO5-768/0365-6241 19040 659 5,556'TVD 95 X1841/2'SLUT Bal Actuated Sleeve 12.236 ball/1192 Seat) 19900 662 '[—� 96 Resman Cartier Stb1106621847-1-1 ROS-766/641-8241 19111 6364 LI,J<I Q Cemented 500' 97 4-54"126*,RtC-110Hyi`541Cm., I I above shoe 96 4$4'126*/ft Hydril 521-6'Pup*lb z-rte on VOEint ceta3la5 -'® 19150 657 Malibu Ron Swell Packer 14-1.{-Hy::.tL.,03dement5°-9meter long el activated dent with side en Volantceltakers pin end II Q 0 100 Pte-Perforated Pup with 416'126*1ft 0-11014yd5521 Pup above and below 19198 670 101 Eccen0ic0we with Float 54b 19209 671 MM HI(I Bottom of Shoe 19210 674 2-7/8"6.4#L-80 °Q•i MN iiiiIBT M Tubing (Upper Completion) TOO Estimated 500'above top of Kuparuk 0 - �'i •iit.r V'® WRONG SWELL PACKERS RUN—4%"13Cr80 13.5#Swell Packer: /jam_/ Burst=9,020 psi/Collapse=8,540 psi 6-1/8" Hole TD / 25 Swell Time to Frac @ 6.125"=62 days/@ 6.500"=137 days @ 19,329' MD/6,371'TVD 7"26# L-80 - " 0 a3 so s� rvi . ® ,,,$7t___78 as ez 9s r BTC-M& Hydril 563 4! ,� ® r IO _ •® _ _ E. _ _ ® _ - -- Intermediate 2 Casing ® �, _ '_ _ _ _ _ : o >I @ 12,762' MD/6,358'TVD ® - Ji 4-1/2" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve 0 0 11 3148 29157 .. CAE1_US LETTER OF TRANSMITTAL Energy Alaska DATE: March 23, 2018 FROM: TO: Shannon Koh AOGCC Caelus Energy Alaska Attn: Makana Bender 3700 Centerpoint Dr., Suite 500 333 W. 7th Avenue, Suite 100 Anchorage, AK 99503 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps 111 CD-R ® Other— Log ❑ Agreement DETAIL QTY DESCRIPTION ODSN-28 (50-703-20676-0000) 1 CD Memory TEMP-GRCCL CD contains DLIS, LAS, PDF 1 Memory GR/CCL/TEMP log RECEIVED MAR 2 8 2018 AOGCC CANNED u Received by: AIAL ,�flid, It Date: 31'z L re3 PIe: - 'gn and return one copy to: Caelus Energy Alaska ATTN: Shannon Koh 3700 Centerpoint Dr., Suite 500, Anchorage, AK 99503 907-343-2193 fax 907-343-2128 phone shannon.kohcaelusenergy.com P ot- w \\I%%y4's THE STAT • Alaska Oil and Gas N�`�►�� Of T � /®\ ,C) � � Conservation Commission rS _ & 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .1433 SP MFax 907.276.7542ain: 9 www.aogcc.alaska.gov Rami Jasser Senior Staff Completion Engineer Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-28 SCANNED rEB I`E2OJ Permit to Drill Number: 213-148 Sundry Number: 318-039 Dear Mr. Jasser: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Ji1 - Hollis S. French Chair DATED this day of February, 2018. REL-VS rc;s, RECEIVED • etpid pck STATE OF ALASKA — JAN 3 0 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate El Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate El Other Stimulate ❑ Pull Tubing ❑ Change g Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:Scale Squeeze❑• 2.Operator Name: 4.Current Well Class: '9 5.Permit to Drill Number: Caelus Natural Resources Alaska,LLC, l 41 j C 7` Exploratory Development 121 213-148 ' 3.Address: 3700 Centerpoint Drive,Suite 500 ❑ 6.API Number. Stratigraphic ❑ Service Anchorage,AK 99503 50-703-20676-00-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' ODSN-28 Will planned perforations require a spacing exception? Yes ❑ No 0 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389950/ADL 389958 t Oooguruk-Nuiqust Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 19,329' 6,371' ' 19,210' ., 6,371' r 1,300 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5506' 11-3/4" 5,549' 3,453' 5,830 psi 3,180 psi Intermediate 4,762' 9-5/8" 10,152' 5,556' 5,750 psi 3,090 psi Int 2 Tie Back 2,337' 7" 2,375' 2,005' 7,240 psi 5,410 psi Intermediate 2 10,387' 7" 12,762' 6,358' 7,240 psi 5,410 psi Liner 6,765' 4-1/2" 19,210' 6,371' 11,590 psi 9,200 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attached,pg.2 < See attached,pg.2 2-7/8",6.4# L-80,IBT-M 12,453'MD Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): See attached,pg.3 See attached,pg.3 12.Attachments: Proposal Summary ❑ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for . 15.Well Status after proposed work: M Commencing Operations: I t/Aa.GN 2e 2.018 OIL 0 ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Rami Jasser.\ Contact Name: Rami Jasser Authorized Title: Senior Staff c•m e.I-tion En.ineer Contact Email: ramL iasser( caeluseneray.com Contact Phone: 907-343-2182 Authorized Signature: 41. i /44 Date: 0 12.018 COMMI SION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 313 - 03°1 Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No El REMMS ((--- F- - 7 2018 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /o ....... 41 0 L( APPROVED BY Approved by: alli.i . COMMISSIONER THE COMMISSION Date:Z It le, Pit Vaific‘ , %W/3 -tel/ —� SubmitFormand Form 10-403 Revised 4/2017 Approved application QRiiNAL a ate of approval. Attachments in Duplicate • cAELus Energy Alaska Caelus Natural Resources Alaska,LLC 3700 Centerpoint Drive,Anchorage,AK 99503 Tel:(907)277-2700 Fax:(907)343-2190 January 29, 2018 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: ODSN-28 Sundry Application for Scale Squeeze Treatment REF: Approved Permit to Drill #213-148 Caelus Natural Resources Alaska, LLC. (CNRA) hereby submits an Application for Sundry to perform a Scale Squeeze Treatment across the production lateral. The treatment is requested as a preventative measure, with no current water cut while on production. Please see the proposed plan attachment and supporting documentation. Sincerely, IN Rami Jassett� � ''" Senior Staff Completion Engineer Attachments: Form 10-403 Supporting information cc: ODSN-28 Well File • • Attachment 2 AOGCC Form 10-403 Sundry Application Box 11 - Perforation Locations Well: ODSN-28 Top(MD) Top(TVD) 4-1/2" SLHT Ball Actuated Sleeve w/seats 13,315 6,367 4-1/2" SLHT Ball Actuated Sleeve w/seats 13,764 6,366 4-1/2" SLHT Ball Actuated Sleeve w/seats 14,469 6,358 4-1/2" SLHT Ball Actuated Sleeve w/seats 15,103 6,357 4-1/2" SLHT Ball Actuated Sleeve w/seats 15,636 6,354 4-1/2" SLHT Ball Actuated Sleeve w/seats 16,248 6,349 4-1/2" SLHT Ball Actuated Sleeve w/seats 16,836 6,342 4-1/2" SLHT Ball Actuated Sleeve w/seats 17,444 6,340 4-1/2" SLHT Ball Actuated Sleeve w/seats 18,051 6,339 4-1/2" SLHT Ball Actuated Sleeve w/seats 18,681 6,335 4-1/2" SLHT Ball Actuated Sleeve w/seats 19,080 6,362 Pre-Perforated Pup 19,198 6,370 • • Attachment 3 AOGCC Form 10-403 AMR Sundry Application Box 11 - Packers & SSSV Well: ODSN-28 SSSV MD TVD 2-7/8" HES "NE" TRSV 2,345 1,991 PACKERS 2-7/8" x 7" Retrievable Packer 11,398 6,109 5" x 7" Baker ZXP Liner Top Packer 12,445 6,336 HES Swell Packer 13,087 6,364 HES Swell Packer 13,127 6,365 HES Swell Packer 13,467 6,367 HES Swell Packer 14,075 6,366 HES Swell Packer 14,777 6,355 HES Swell Packer 15,374 6,355 HES Swell Packer 15,907 6,354 HES Swell Packer 16,516 6,343 HES Swell Packer 17,145 6,344 HES Swell Packer 17,750 6,345 HES Swell Packer 18,358 6,337 HES Swell Packer 18,983 6,355 HES Swell Packer 19,150 6,367 • Oooguruk Wells Group • CAELLS Energy Alaska OD SN-2 8 Coil Tubing — Scale Squeeze Treatment 1-30-2018 Version 1 Prepared: Date: Rami Jasser Completions Engineer Reviewed: Date: Keith Lopez Production Engineer ODSN-28 Coil Tubing Scale Squeeze Treatment—version 1 (1/30/2018) • Oooguruk Wells Group • Obiective: ODSN-28 sustained production at -1260 BOPD with no current water cut while on production, decision has been made to utilize Coil Tubing during the ice road season to lay scale treatment evenly across the production lateral as a preventative measure. Scale Squeeze Design: Baker Petrolite recommends the following scale squeeze design and operational procedure to protect ODSN-28 from barium sulfate and calcium carbonate precipitation: • 32 barrel pre-flush containing 50% WAW5206 o 660 gallons WAW5206 & 8 barrels seawater 66z5/ , , = /I I • 242 barrel main treatment containing 13% SCW4004 o 1320 gallons SCW4004 & 105 barrels seawater 13 za - 3), /14/5 • 600 est. barrel seawater formation over-displacement (0.5 ft. OD). • 12 hour shut in • Use recommended maximum injection pressures and rates. • Please be aware that SCW4004 is not compatible with methanol. • Obtain QA/QC concentration samples during job. Slickline: 1. Coordinate with Operations to shut in well. 2. Record WH, IA, and OA pressures. Shoot and record fluid levels on Tubing, IA, and OA. If the OA is bled, measure and record H2S level. Send results to Anchorage team. 3. Complete handover from Operations to Wells. 4. Conduct pre-job safety meeting with Wells Group Supervisor, Operations, and all service companies involved in the job scope. 5. MIRU HES Slick-line. Pick up lubricator, tool string, and 2.35" gauge. 6. Pressure test PCE as per HES policy and procedure. ' 7. RIH w/ 2.35" gauge ring to XXO TRSV @ 2,345' MD while holding 5,000 psi max on the TRSV control line to hold flapper open. 8. Drift w/ 2' of weight bar, and 2.35" gauge ring to X nipple @ 11,562' MD. 9. RDMO HES Slickline. 10.Prepare to rig up coil tubing unit. ODSN-28 Coil Tubing Scale Squeeze Treatment—version 1 (1/30/2018) • Oooguruk Wells Group • Coiled Tubing Gamma Ray / CCL / Temp Loq: • The objective of running the Gamma Ray/ CCL Log to identify the source of water. 1. MIRU 1 3/4" coil tubing unit and associated equipment. Nipple up 4-1/16" 10k Quad BOP's and required cross-over spools. 2. A crane is needed for lifting operations, verify with crane operator, weight of every component to be lifted during rigging up/rigging down procedures. 3. Conduct Pre Job Safety Meeting (PJSM) in rigging up Coiled Tubing Unit (CTU) along with associated surface equipment. Mitigate all hazards discussed. 4. The Well Site Supervisor and the Coiled Tubing Unit Supervisor should agree to contingencies to follow in the event of a tubing failure during operations. 5. High pressure areas should be recognized and posted. Make an all call prior to testing lines alerting personnel to stay away from high pressure. Consider site control measures during the cleanout operations 6. Ensure that the IA is shut-in and both IA & OA pressures are monitored throughout the job. NOTE: Ensure that IA is always higher pressure than the OA (maintain a 500 psi differential). 7. Ensure that all tanks and lines are clean and all fluids filtered before entering the CT pump. 8. Rig up Schlumberger (SLB) 2" 1502 hardline from the manifold on the swivel joint side of the coiled tubing reel. NOTE: Ensure the Micro Motion (MM) is calibrated with water and will record in both direction of flow. 9. Conduct HSE walk through with Schlumberger's CTU supervisor and CEA Well Site Supervisor. c .P 10.Conduct BOP pressure test using Diesel. Re: Schlumberger's Seven Day BOP Test Guidelines and Procedure for CTS Operations date 10/31/11. Also pressure test all associated equipment Release pressure and un-stab. 11.Verify OD, ID, length of all tools and that any fishing equipment is available if needed. Ensure that the CTU operator is aware of all restrictions in the well and has a plan to slow down prior to running BHA thru the restrictions. 12.Make-up (MU) BHA. Install roll-on Coiled Tubing Connector (CTC) (refer to SLB SOP's on CTC installation) and pull test to 10k. Both the CTU and Well Site Supervisor must pre-approve the BHA. 13.Make-up (MU) BHA, Install the 1-11/16" Gamma Ray Logging BHA. ODSN-28 Coil Tubing Scale Squeeze Treatment—version 1 (1/30/2018) • Oooguruk Wells Group • 14.All BHA items run in the hole dimensions will be measured and posted by Well Site Supervisor and CTU Supervisor in the Op's Cab. 15.Pick up the required lubricator and stab on well. Line up and pressure test the BOP body to 250/4000 psi. Line up to diesel out of SLB pumps truck. Pressure up on the lubricator to equal the Well Head Pressure (WHP) and open the lower FV, count and record turns. Open the upper FV slowly and count and record turns. NOTE: Open bottom valve first and with low pressure differential between wellbore and lubricator, open top FV slowly to reduce any possible erosion of bottom FV gate. 16.RIH not pumping (dry) to 3,500ft MD. 17.Pump friction reducer at 1 BPM running at coil speed of 50 fpm until reach coil lockup depth. 18.RIH at the SLB Coiled Tubing Memory Gamma Ray Tool and follow Schlumberger running procedure per tool specialist. NOTE: If unable to reach a desired deepest depth consult with the Anchorage team and discuss plan forward. 19.POOH while logging at recommended logging parameters as per SLB Memory. 20.Once on surface download and notify the Caelus Energy LLC team on logging results for a plan forward. Scale Squeeze Treatment: 1. Make-up (MU) BHA, Install a Jet Swirl BHA. 2. All BHA items run in the hole dimensions will be measured and posted by Well Site Supervisor and CTU Supervisor in the Op's Cab. 3. Pick up the required lubricator and stab on well. Line up and pressure test the BOP body to 250/4000 psi. Line up to diesel out of SLB pumps truck. Pressure up on the lubricator to equal the Well Head Pressure (WHP) and open the lower FV, count and record turns. Open the upper FV slowly and count and record turns. NOTE: Open bottom valve first and with low pressure differential between wellbore and lubricator, open top FV slowly to reduce any possible erosion of bottom FV gate. 4. RIH not pumping (dry) as deep as possible. ODSN-28 Coil Tubing Scale Squeeze Treatment—version 1 (1/30/2018) • Oooguruk Wells Group • 5. Begin laying in the treatment as per the table below: Down Coil Back Side Coil Zone (MD)ft. Fluid Type Volume (bbl.) Pump Rate Pump Rate (BPM) Max Depth Pre-Flush 8 Scale Squeeze 60 Over Flush 150 16000 — 17500 Pre-Flush 8 0.25 BPM Scale Squeeze 60 Max Rate not to exceed While pumping Over Flush 150 down coil 14500 — 16000 Pre-Flush 8 2,000 psi coil x tubing tubing Scale Squeeze 60 annulus WHP simultaneously 7 Over Flush 150 13000 — 14500 Pre-Flush 8 Scale Squeeze 60 Over Flush 150 6. POOH to surface. 7. RDMO SLB Coiled Tubing. 8. Allow a minimum of 12 hours shut-in time for treatment. ODSN-28 Coil Tubing Scale Squeeze Treatment—version 1 (1/30/2018) • Oooguruk Wells Group • Fluff and Stuff Contingency: 1. Make-up (MU) BHA.Install roll-on Coiled Tubing Connector (CTC) (refer to SLB SOP's on CTC installation) and pull test to 10k. Both the CTU and Well Site Supervisor must pre-approve the nozzle selection. 2. All BHA items run in the hole dimensions will be measured and posted by Well Site Supervisor and CTU Supervisor in the Op's Cab. 3. Pick up the required lubricator and stab on well. Line up and pressure test the BOP body to 250/4000 psi. Line up to diesel out of SLB pumps truck. Pressure up on the lubricator to equal the Well Head Pressure (WHP) and open the lower FV, count and record turns. Open the upper FV slowly and count and record turns. NOTE: OPEN BOTTOM VALVE FIRST AND WITH LOW PRESSURE DIFFERENTIAL BETWEEN WELLBORE AND LUBRICATOR, OPEN TOP FV SLOWLY TO REDUCE ANY POSSIBLE EROSION OF BOTTOM FV GATE. 4. Clear all reel depth counters. 5. If injectivity will allow, proceed to RIH with choke closed pumping at minimum rate. Control well pressure by opening choke while RIH if unable to inject. 6. Perform regular weight checks at 2000' intervals. 7. Once reaching 10,000', increase pump rate to between 1.5 and 2.0 BPM and perform weight checks. 8. Begin running in hole at 15' to 20' per minute. Open coil tubing by production tubing annulus valve and pump down coil with seawater. 9. Rig-up LRS to pump down coil x tubing annulus with diesel. 10.Once 11,200' (200' bites) is reached. Pull up hole 50' to disperse sand and ensure sand is strung out and not collecting around the bottom hole assembly. 11.Continue taking 200' bites and pulling up hole 50' while watching run in hole (RIH) weights and pull up hole (PUH) weights. Repeat these steps until desired depth is accomplished or signs that the well is starting to flow. If a break through event happens the well may see a sudden increase in pressure. 12.Be mindful of sudden increases or decreases over time in Coiled Tubing Pressure (CTP) and Well Head Pressure (WHP) which may indicate sand bridging off the flow path to formation and we also need to maintain a close eye on the Coiled Tubing (CT) pull out of hole (POOH) and run in hole (RIH) weights if a significant change is noted pull up hole (PUH) to above the uppermost frac sleeve to ensure sand is dispersed behind the coiled tubing (CT). 13.POOH to surface and notify the Anchorage team on results for a plan forward. Post Scale Squeeze: 1. Perform a Closure test and monitor for 15 min. ODSN-28 Coil Tubing Scale Squeeze Treatment—version 1 (1/30/2018) • Oooguruk Wells Group • ODSN-28 Nuiqsut Production Well Completion FINAI 10-05.-7o17 1 1 ..ting Ma rye- __orint__.._-.,..-..d_.,..__.-__. ....<,,._..,- ..y,_... 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F81 15 8.2.7;7&MEM Box a 2.7Ar EA.ET-M Pen La Cmssoi r PuaJei t Bata Pin MM oO� 00 2.7/7640,L-801ST-MTuting ' FP 15 4-2.74"6Y ETV Boa a2-74-ES EUE Fin L4)Crossover PtoJoit Box x Pin 2-7/8"6.4#L-80 Ch/ 2-718''X'People t 1(2313'ID)EUE Som x Pin w✓RNC Plug �� E©3 IBT-M TubingRR 154.2-7,-r64PEUE eax2.74-C#Er-MPnL-&JCrossoverPtplantBatxPin ^... .. u 2-7/s.64a-410,5'-M Tutag (Upper Completion) TT 4'Auto Entry Mule Shoe F1-N15osupbucket(uotoljo,.tof2-7/8'64a1-W15T-M Tubing , ,, fad ofAssembly 12453 6337 TOC Estimated 500'above top of Kuparuk 0 -4, 0 WRONG SWELL PACKERS RUN-4'Vt"13Cr80 13.5#Swell Packer: ,r Burst=9,020 psi/Collapse=8,540 psi 6-1/8"Hole TD ®�y 0Swell Time to Frac @ 6.125"=62 days/@ 6.500"=137 days @ 19,329'MD/6,371'TVD 7"26# L-80 ' •// 4" Q ® ® s7 71 7E O s2 w BTC-M&Hydril 563 ,�® �--� - -- __e__ _w-,-- -- --� Intermediate 2 Casing 0 — — _ _ _ - P�- 101 2'; @12,762'MD/6,358'TVD ® ��``IL-�IL_I __ _— --E—_i_—�E--� 2 __ 4'/z"Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve ODSN-28 Coil Tubing Scale Squeeze Treatment—version 1 (1/30/2018) • Oooguruk Wells Group • ODSN-28 Nuiqsut Production Well Completion FINAL 10-05-2017 1 I - L2-3,47'7015.3333431l2m333.32t3ea32ea73w33,233.rpt} NEit4 wen% I 12 Saxer s!i-X7'Z331wer74pPecker ire 1417.tlA.latest eV Fart Lac 11fp,3p 1:143 53'01 ii 15 4'4'II.54l1:C-110+304u32 Lax+ 20 4-'325301 o..)13-4 321-I Rp ret+arae on wn,ncatr.2e3 WO 11111 2: J 41.9oi.+,rx 3.1943e,.414.330.93 0334 Irmo 21}CeS95'7 0720 pa I crst/954,03s0ea t}0o ow.mm{71 6.1630ed ... e,e7.11 on,:Aft am 97777727777177.777 777 777 21 77447771777 17777 aswe=I*'r 1301017/4 771;Ms SS'-1103014+9 Fit/S R.,c,o4427i 7M+1e777037777777173 C) 04:431 7.2477 777477707777777737st7+t 2327 1... �� 2.3 4:s•20IRC-I10NytM321 J!' — ig iii24 163.704 Owner**Ube 02134741-230S-771//1e543ai 13374 0367 GLM#2 "" 23 Ka41/rsurrrAcmeteaStew 1am35rl23Sx tl 534726 Se.mr.Genet**Dee 0114 ] .11.1 Rrn /1 6 Q5- / .54341 13347 67 DGLV :>i; 16"Conductor 27 4W 26.•+717.130..1tSit321:M, 29 4'e-263,4t955-o321-614..9ri3 Dee m*Oft certre4353 Packer Rum mix• 23 ' p.$355 (*k Fwrsa)00Sir-9maul*see.aY.e4e eaMnmitds.ceea.wles ta t.(ntetr:ata 13467 7161 iiIii Jnhihited Kill weight Brine 30 4'S-264,•t2C-110 ntd321.ne- 31 Selma Corot 44Lob 3219440.7503.771/#.954331 13773 6367 with 2000'TVf1 32 /1641/2 Sufi wAawted Senn 12423.r/2314se.t} 13754 6366 . . lli /1iecel ran 33 *5%0C5ner5rLei.7134140-1005777/5554331 13796 6366 34 '•-26471 C-11077an321:nem : 33 477.•120:71+,10,4321-5' Ti eve e,max cat-.les 3d Ne3:4,rtam 5.03 Packer 4-.f 1401 64521)013 Sir-9 mdaloos 33 Winked tlatatote IQ tee%IN tots taftersps a6 1402 133E A,:.' '!!I 11-3/4"60#L-80 17 4.1.12316.+1C-110.34.521, r BTC Surface 33 Se"""Gorier**Dee 421.43-2 R05-776/11133432.1 14427 6353 7"Casing Repair: 05 Ka 41/2 Suir*0A4twteo Sartre(2.622'r/2.7KSe.t) 14W/ 6359 Casing K Seoma Caner**toe 3233414-130*M//1554321 1600 6357 New 7"Casing @ 5,549'MD/ 4 4,32a.71C-1303503u14. from 2,375'MD to ' 42 4A 2 45+ ,1 -10 3-, 1-6.,5.50 0'marlcomas 3,453TVD Surface 43 Iba477174 Snell 3a0ur14-r 1474452110051e•-9eider k.sair.050000 sone twee sree.Valet teffi.l3.YR p c es d 14777 0310 cemented to 44 415.2.6441C-110*yor321 Low surface K xs,+...c44ti>S+LOS sns4a2w.775//1555311 MR 6357 I..41/r sw7WAdwtt. } 1510; [157 4467 tan,ma ram<r5M 1a.e2134733.9"730512-7-6177547110453212-'4664°1 15135 6357 9-5/8"40#L-80 a 43 264710.110 rye.3211.000. Hydril 521 46 3 2toners 1076 sbe n wpnn nnCey ii> Intermediate 1 5D Natvet"'%aIftO[rt*W 001,7521)00 5.15,5 md52 gw r.mat.4t Ode ea NMtc.9.fleespi cad 15374 Ian GLM#1 I P s 31 4h'1254,1C-110.036 321 Lner • Casing 52 *550'Owner 5.71751021117777-200777777//155+71 5155 5116"OV 0 J� @ 10,152'MD/ 33 NW 4313 Suer6WAcemted 154w12.411.1/2 4215541} y 35 ff w 435 6354 5,556'TVD 64 Ilesenee Cae'er54 is.021347-7.1005.774/w"S4301 1555* 6354 33 44-2Sett C-110ner,321::x¢- LI...I ci Cemented 500' 36 ,-26011.r1-,311•6nr-n.e . peerwe tcee-. a above shoe n � 4: D 2:r21 MM Eli 2-7/8"6.4#L-80 0;D: IBT-M Tubing (Upper Completion) TOC Estimated 500'above top of Kuparuk ''i:0 TT ; '' 10/`® WRONG SWELL PACKERS RUN-4 Y2"13Cr80 13.5#Swell Packer: Burst=9,020 psi/Collapse=8,540 psi 6-1/8"Hole TD �o Swell Time to Frac @ 6.125"=62 days/@ 6.500"=137 days @ 19,329'MD/6,371'TVD 7"26# L-80 \t� ® °___®__®_-0-_® 71 /e O O w BTC-M 8 Hydril 563 «./ wt.-- ® — — --� Intermediate 2 Casing �• \ _ __ I:—�-- 4'1A"Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve ODSN-28 Coil Tubing Scale Squeeze Treatment—version 1 (1/30/2018) • Oooguruk Wells Group • ODSN-28 Nuiqsut Production Well FINAL q Completion 10-05-2017 I 57 ( 'eYbrres Swed''139[453'93'331x11 o05.3S'•9 rtst9fiig wFCMMserrert ria 10-39 a.vawtm.vsmPtaa 7a 0-5"12f1=5C•110'ryRa321Lrer 59 Re9&Y 01"ier5e pill 62134644 0.75-773/13541291 16206 6 362 60 11140r SUN 140.46144191 Stem 12303 Fa/2352 Serle162a 6"349 61 Rama6 .tier 549 1eea0-41 IO5.773/1145-6291 ' 16277 6341 62 4"•,-12Y,RSC-330wori722L,.- '"�"l C) a Lr 12.13445550-4521-6 150 armee.wan anis as Y I � a iS51', 61109 Sal 14039t4 ,6,i sn)oosss•9,eewg>etasur aertext gill lieraatmtrwsepe elle GLM#2 , ® ( , a 4 e•123R7tC310.rys'R1L1'9 DGLV I 16"Conductor u 'r""'a"'as'° n p+'eaa°•saps'n2/'WS'S) 13796 63.63 37 iti 43/2-Riff So Acc.ree Slee*11527 ee/247755.11 16N36 634 SS Rr0rse C454e6510 pb 0=2180.53'05-772 I'35.6231 16967 634: Packer Fluid mix n :.'+'136=,-c310- In'-"e- 70 a-a'126.;R,7eaal-664:50,36040,604.5cartivars Inhibited Kill weight Bine ,,x cutaa Sal haw(4:1"'1r1Sri 3Z)00511.9 xrett,toil 64l#arte4 arrest wit 0.44 a va54t00e Tea with 2000'TVD 72 4-9-1211 SC•110.9655-1Lrer 73 Ramo 03.54 6560 not*2130-0-30.75-711/1354271 17404 6340 ` I diesel can 74 '6645/2-91311 YR 997763 Steele 17.452 8 S 93/2, 65990 17444 630 75 Rms.Carew SO tbe32130-44'05-771 13353271 17473 6341 ® I X 44-12.614/75C310+53t Rl:nr L-80 77 44'32649 rry37521-664•t3n90'0aa .`t ,t3Ny •S. 11-3/4"60#L-80 , M, orbs twee ie30rs;r wort S21100S.SS'-9,350 1715' ''--15 ( bellerw esti tea x33933 tut xee rm uo-filre�v6sm pzr elle BTC Surface X 1-s-12 Wit C41074e6 3211.05' 7"Casing Repair: Casing !0 Rana.brraS10 8ss'a3-2roS-770/'1sc01 11010 33» Ig New?"Casing a1 410-1/r33.MActened Deese 3X PMIZ3325000 12011 6339@ 5,549'MD/ 32 Pease OtearSrei.13112.114/-3-1105-760/tessoMI 1320 6339 from 2,375'MD to 3453'TVD 13 4,4-12 6. C-110..13.3ma i , Surface 34 4.4"12.63;'"-.?=713.1664115304 on.bat 09,911 ars cemented to 3s 1v53 6337 MrLiCsrim 3.300 391.9(4 it 0,154 521100515'-9 rtetaYil o4*Sated ameet wf 5149 09 vatatantribe6 P eM surface Si 4,4-12.0101C410591663211.659 *7 R:0'0.Ca ier3a61.110 0 2130.2-2105-;9/13!33351 13639 6335 9-5/8"40#L-80 33 Mt 4-1/2-suesomt eta Sleeve f2.307 al/2.261540 33030 3333 • 129 191393 t4.:ers3*Dorf=2180-1.1105-769/935846 13713 3330 Hydril 521 90 u34ec 10.773521:39• iil _ '1' Intermediate 1 93 4.1264: ...6,Xer 521-6"3 wt. aeon 3.. or-ro 5 GLM#1 AI 5 ;, Casing s' <="16r swel h0.14.5'Mbt1521)OOSJS"3metes tote oil samba 0ertest r0 356e ea Vant3aakees at 9r nis.3 ass 5/16"OV92 3 323yRC310'g11a321U,er 0 @ 10,152'MD/ 94 7301993 43333339173912130-13301713/6333241 19040 6351 5,556'TVD 95 .313-2/2-329/1 Sul Ac9e00be0,e12231133/2.19253311 19040 tau II 96 Wave CYitl5e01001213014804763/'3'5841 19111 364 L Cemented 500' 97 4 1233,12110.313521.ner above shoe 9a 1269°.y,3_'21-6►f•.nseea"',w°1rrs'.•xes n leabrtt tVat 6atee[4'R'MyO35 1 520 00 5 .-9 treted rittel .11419 [9 derma610c•vele ttearitur,pmca D 19150 $ ,• ® 100 X3310 9142 6-1411,47312dVRC-110 min 321933 eat aro tear 15191 031 101 6<a-r<3o3 w1,rcN 377 19229 6377 MM 000 810e31.156.9 197.163 6371 2-7/8"6.4#L-80 C:',C IBT-M Tubing (Upper Completion) TOC Estimated 500'above top of Kuparuk ii s"'e-' 0 WRONG SWELL PACKERS RUN-4'/1"13Cr80 13.5#Swell Packer: ,.s Burst=9,020 psi/Collapse=8,540 psi 6-1/8"Hole TD 'Ji ®Swell Time to Frac @ 6.125"=62 days/@ 6.500"=137 days @ 19,329'MD/6,371'TVD 7"26# L 80 ` O 3.7 ® 7i 7& O 3.z ss BTC 26# L-80 Hydril 563 r'' IV 0 ---C14-3)-� - - -- - - c) Intermediate 2 Casing 0 '017, - - - I- _ _ _ _ of 2 @12,762'MD/6,358'TVD ® �--`1r-i 1a; _ - - E ( i 4-W Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve ODSN-28 Coil Tubing Scale Squeeze Treatment-version 1 (1/30/2018) • STATE OF ALASKA ,r AL KA OIL AND GAS CONSERVATION COM ION6 ' REPORT OF SUNDRY WELL OPERATIONS ;, g„ Cot-,. 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing LI Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other:7"Casing Repair/Run GL El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Caelus Natural Resources Alaska,LLC Development 0 Exploratory❑ 213-148 3.Address: 3700 Centerpoint Drive,Suite 500 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-703-20676-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 389950/ADL 389958 ODSN-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Oooguruk-Nuiqsut Oil Pool 11.Present Well Condition Summary: Total Depth measured 19,329 feet Plugs measured N/A feet true vertical 6,371 feet Junk measured N/A feet Effective Depth measured 19,210 feet Packer measured See attachment,pg.3 feet true vertical 6,371 feet true vertical See attachment,pg.3 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5,506' 11-3/4" 5,549' 3,453' 5,830 psi 3,180 psi Intermediate 4,762' 9-5/8" 10,152' 5,556' 5,750 psi 3,090 psi Int 2 Tie Back 2,337' 7" 2,375' 2,005' 7,240 psi 5,410 psi Intermediate 2 10,387' 7" 12,762' 6,358' 7,240 psi 5,410 psi Liner 6,765' 4-1/2" 19,210' 6,371'CANNED 11,590 psi 9,200 psi Perforation depth Measured depth See attachment,pg.2 feet �)frkPt .� 4 c/,,: True Vertical depth See attachment,pg.2 feet Tubing(size,grade,measured and true vertical depth) 2-7/8",6.4# L-80,IBT-M 12,453'MD 6,337'TVD Packers and SSSV(type,measured and true vertical depth) See attachment,pg.3 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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: 2,460 4,370 0 804 452 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development p El Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil LI Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-247 Authorized Name: Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Sta 6s; pletion Engineer Contact Email: rami.iasser(c�caelusenergy.com Authorized Signature: ',44,1 Date: 10/12-0" Contact Phone: 907-343-2182 Form 10-404 Revised 4/2017 vtit �?Y`� /�'r� j ? - l7 RBDros ., , Submit Original Only U4/ V • • Attachment 2 AOGCC Form 10-404 Sundry Report Box 11 - Perforation Locations ... w.:4,%Gi.,. O ,rkuZ.Fad ,�,. i„ ,L ,. ,,,...,.;a�/Oa xwdnnm^nanrvttwrvunim e✓,,m�k:.rom,�a.+rnnmsxue+P< e em.!n t.,.,imv'See Well: ODSN-28 Top (MD) Top (TVD) 4-1/2" SLHT Ball Actuated Sleeve w/seats 13,315 6,367 4-1/2" SLHT Ball Actuated Sleeve w/seats 13,764 6,366 4-1/2" SLHT Ball Actuated Sleeve w/seats 14,469 6,358 4-1/2" SLHT Ball Actuated Sleeve w/seats 15,103 6,357 4-1/2" SLHT Ball Actuated Sleeve w/seats 15,636 6,354 4-1/2" SLHT Ball Actuated Sleeve w/seats 16,248 6,349 4-1/2" SLHT Ball Actuated Sleeve w/seats 16,836 6,342 4-1/2" SLHT Ball Actuated Sleeve w/seats 17,444 6,340 4-1/2" SLHT Ball Actuated Sleeve w/seats 18,051 6,339 4-1/2" SLHT Ball Actuated Sleeve w/seats 18,681 6,335 4-1/2" SLHT Ball Actuated Sleeve w/seats 19,080 6,362 Pre-Perforated Pup 19,198 6,370 • Attachment 3 AOGCC Form 10-403 Sundry Report Box 11 - Packers & SSSV Well: ODSN-28 SSSV MD TVD 2-7/8" HES "NE" TRSV 2,345 1,991 PACKERS 2-7/8" x 7" Retrievable Packer 11,398 6,109 5" x 7" Baker ZXP Liner Top Packer 12,445 6,336 HES Swell Packer 13,087 6,364 HES Swell Packer 13,127 6,365 HES Swell Packer 13,467 6,367 HES Swell Packer 14,075 6,366 HES Swell Packer 14,777 6,355 HES Swell Packer 15,374 6,355 HES Swell Packer 15,907 6,354 HES Swell Packer 16,516 6,343 HES Swell Packer 17,145 6,344 HES Swell Packer 17,750 6,345 HES Swell Packer 18,358 6,337 HES Swell Packer 18,983 6,355 HES Swell Packer 19,150 6,367 • • Operations Summary Report- State Well Name: ODSN-28 warAE LU S 'A(as'kt Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 8/23/2017 8/24/2017 0.0 00:00 8/23/17-00:00 8/24/17 (Pre RWO S/L) *Shut in well at 07:00 in and take control of well from OPS-Wells. *Freeze protect ODSN-28 via LRS with 50 bbls of LVT/Diesel mix. *Drift to the FXE SSSV at 2,264'slm(XXO Nipple @ 2,297'md). L *Pull the FXE SSSV from 2,264'slm(XXO Nipple @ 2,297'md). *Drift to the XN nipple,tagat 11,352'slm/11,363'md). *Set he 4 5"HES Evo Trieve as Der program at 11 324'slm(COE) Good indication of set. *Lay down HES Slickline for the night. 8/24/2017 8/25/2017 0.0 00:00 8/24/17-00:00.8/45/17 (Pre RWO S/L) *MIRU HES Slickline to complete the Pre RWO S/L program *RIH w/4.5"catcher sub and set on top of the Evo Trieve set at 11,318'slm. *Pump 50 bbls of LVT/Diesel mix down the TBG to ensure an overbalance of pressure on the TBG to begin pulling valves. *RIH w/KJ w/4.5"OK-1 and 1.25"JDC.Pull GLM#1 from 11,275'slm.Jar for 20 min and valve pulls free. *RIH w/KJ OK-6 and 1.25"JDC.Able to locate but unable to latch.POOH and inspect tools. *RIH w/KJ OK-1 and 1.25"JDC,Locate,latch and pull 5/16"OV from 6,588'slm. *RIH w/KJ OK-1 and 1"DV,set DGLV in GLM#2 at 6,588'slm.Good set. *RIH w/4.00"GS and pull the catcher sub from the Evo Trieve at 11,318'slm. *Stand by for LRS to MIRU after complete with the OPS projects. *MIRU LRS to pump 385 bbls of treated seawater followed by 120 bbls of diesel. *Pump away 65 bbls of seawater as of 23:59. ****GLM#1 empty,no GLV w/4.5"Evo Trieve set at 11,324'(30'above XN)**** 8/25/2017 8/26/2017 0.0 00:00 8/25/17-00:00 8/26/17 (Pre RWO S/L) *Circulate 445 bbl of treated seawater followed by 120 bbls of diesel.Pump down the IA while taking returns from the TBG. *U tube from IA to TBG to ensure a sufficient freeze protect to 2500'TVD. *Perform apassing Combo MIT on the TBG and IA to 2500 psi. *Attempt to set a BPV into he TBG hanger profile.Unable to set the BPV due to damaged TBG hanger profile. *Consult with the Anchorage team and decision is made to MIRU HES Slickline to set a FXE SSSV as a third barrier. *Notify NAnuq to begin situating island materials to get the Slickline unit to the southside of the island. 8/26/2017 8/27/2017 0.0 00:00 8/26/17-00:00 8/27/17 *MIRU HES Slickline to set a 4.5"FXE in the XXO nipple. *Set the 4.5"FXE in the XXO nipple at 2,264'slm. *Perform a closure test from 500 psi to 0 pis.Watch for 30 min,good test. *RDMO HES Slickline. *Continue to bleed gas off of TBG&IA as it migrates to surface. ***Nabors 19 AC Well Satus:Evo-Trieve RBP set @ 11,324'slm,T x IA freeze protected w/diesel to 2500',treated seawater 2,500'-11,324',GLM#1 has empty pocket at 11,275'slm,GLM#2-3 Dummy GLVs,BPV profile damaged,A 4.5"FXE is set inthe XXO nipple at 2,264'slm.*** Page 1/5 Report Printed: 10/11/2017 • Operations Summary Report- State Well Name: ODSN-28 • At�.. S Akaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ibh3al) Summary 9/7/2017 9/8/2017 0.0 8.50 Rig accepted on ODSN-28 RWO 00:00.Allow diesel to finish U-Tube through jumper line on N- 29.Vetco Gray set TWC.R/D lubricator. Install tree cap.Hold PJSM w/rig crew&CCU for rig move.RDMO ODSN-29 RWO.R/U rig on ODSN-28 RWO.R/U circulating lines to tree. Circ diesel freeze protect out of Tubing and IA w/seawater.Take returns to flow back tank. Monitor well for 30 min. N/D Frac tree. Install test dart.N/U BOP stack,choke&kill lines.P/U&R/U test equipment.Fill stack w/8.5 ppg seawater.Begin testing BOPE with 4"&4-1/2"Test joints as per AOGCC&PTD: -Test annular w/to 250 psi low/2500 psi high. -Test upper and lower VBR to 250/3,500. -- Upper VBR door bonnet hydraulic seal leaking. ---Call for VBR bonnet replacement f/Deadhorse. , -Test upper and lower!BOP valves to 250 psi low/3500 psi high. l c r -Test all floor valves to 250 psi low/3500 psi high. fa -Test 14 choke manifold valves to 250 psi low/3500 psi high. -All tests charted and all tests held for 5 min. -All tests performed with 8.5 ppg seawater. ***Jeff B.Jones Inspector with AOGCC waived BOPE witness at 10:00 hrs 9/7/17.*** ***Provided 24 hour notice to AOGCC for BOPE test on 09-07-2017 1:00 PM.*** 9/8/2017 9/9/2017 0.0 8.50 Drain BOPE stack.Hold PJSM to remove Ram Door on BOPE stack.Remove&L/D Ram door I Bonnet w/leaking seal. Install replacement Ram door/Bonnet. Finish testing BOPE with 4"&4-1/2"Test joints as per AOGCC&PTD: -Retest upper VBR to 250/3,500. -All tests charted and all tests held for 5 min. -All tests performed with 8.5 ppg seawater. -Perform draw down test on Koomey. *Initial system psi:3000;2100 after closure;200 psi=27 sec,full pressure 127 sec. -BOPE testing complete. ***Jeff B.Jones Inspector with AOGCC waived BOPE witness at 10:00 hrs 9/7/17.*** ***Provided 24 hour notice to AOGCC for BOPE test on 09-07-2017 1:00 PM.*** Pull test dart&L/D Vetco Gray test jt.Pump two drums BaraKlean FL well cleaner fluid w/420 bbls seawater down tubing.R/U Expro slick line.RIH w/4.5 GS&6.5'of equalizing prong.Sit down on SSSV @ 2297'slm.Unable to latch up.Circulate fluid down tubing while taking returns up IA to verify flapper on SSSV is open.Still unable to latch.POOH to inspect tools.GS not sheared,small metal marks on bottom of prong.Remove prong.RIH w/4.5 GS,circulate 5 bbls down tubing&up IA to verify flapper on SSSV is open.Latch&pull SSSV @ 2297'slm.POOH w/4.5 SSSV.RIH w/KJ,2.80"cent,3'of 1.5"weight bar,1.75"bow spring centralizer,and 2-3/8" GR.Pressure up tubing to 300 psi.Latch 4.5"Evo-Trieve RBP @ 11,350'slm.Jar down to equalize Evo-Trieve RBP.Tubing pressure dropped to zero then went on a vac.Let plug equalize for 30 minutes.Begin jarring up lightly&Evo-Trieve slips released.Pull out of hole with 4.5"Evo- Trieve RBP.R/D slick line.Bullhead 150 bbls seawater down tubing.Monitor well for 30 min.Well on vacuum.Pull 4-1/2"frac completion hanger.Unseat hanger w/70K P/U.Unsting seal assembly w/175K P/U.R/U to POOH w/4 1/2"Frac String. 9/9/2017 9/10/2017 0.0 8.50 Continue R/U to POOH w/4 1/2"Frac String.Hold PJSM.POOH w/4 1/2"Frac String f/12,432' to surface.R/D Liner Running Tools,Function rams.Flush BOPE stack. Retrieve junk basket. Clean&clear rig floor.P/U 7"Lockset retrievable bridge plug BHA per Baker Rep.Gregory Crew performed kick while tripping drill. 9/10/2017 9/11/2017 0.0 8.50 M/U 7"Lockset retrievable bridge plug BHA per Baker Rep.RIH w/RBP BHA on 4"DP stands U 11495'. Set RBP per Baker Rep.Confirm RBP set w/250K P/U,120K S/O.RBP top set @ 11495'. Release running tool w/left turn per Baker Rep.Rack back 1 stand t/11425'.Fill pipe.Pressure test RBP to 2,500psi/10 mins.Chart same.Good test.P/U w/running tool U 11482'.Spot Baracarb per Baroid Mud Eng procedure.P/U t/11202'while laying out additional 3 bbls Baracarb pill.Stop pumps&allow pill to settle for 15 min.RIH slowly pushing Baracarb pill to btm.Tag solid Baracarb @ 11480'.15'min Baracarb on top of RBP.POH w/RBP Running tool f/ 11480't/surface.Check pump through running tool @ 11140'.Verify DP clear of Baracarb pill. Clean&clear rig floor.Stage Clean Out BHA.M/U Clean out BHA per Baker Rep f/surface t/ 426'. Page 2/5 Report Printed: 10/11/2017 • • CALLUSOperations Summary Report- State Well Name: ODSN-28 Alaska Start Depth FootMeters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 9/11/2017 9/12/2017 0.0 2,351.00 8.50 Finish M/U Clean out BHA f/426'U 791'. TIH w/Clean out BHA on 4"DP f/791'U 11468'.Tag top of Baracarb solids© 11468'.27'Baracarb solids on top of RBP.Reciprocate scraper 6 x across packer setting depth @ 11,362'.TOH U 11266'.Circulate 1 x B/U.Slip&cut drilling line. TOH w/Clean out BHA f/11266't/62'.L/D Clean out BHA f/62'U surface. P/U 7"Baker Multi Cutter BHA tper Baker Rep.TIH w/7"Baker Multi Cutter BHA f/11'U 2420'.Establish c5Y parameters prior to 7"casing cut per Baker Rep.Locate collar @ 2374.7'.L/D top(x2)jts.R/U ++ pressure control manifold from OA to flow back tank.Cut 7"casing per Baker Rep l 2351'.OA _ t‘ increase f/50 psi U—180 psi. Drop 1 7/8"dart to open circ sub.Shear circ sub w/1400 psi.P/U U 2349'to verify cutter free.Close annular.Pump down 7"casing taking OA diesel freeze protect X returns to flow back tank.Pump 55 bbls baraclean pill&chase with sea water.Use pressure C" reduction schedule through pressure control manifold off OA.Stage down f/400 psi w/diesel U 180 psi w/320 bbls clean seawater away. St 9/12/2017 9/13/2017 2,351.0 8.50 Continue pump total 400 bbls down 7"casing taking OA diesel freeze protect returns to flow back tank.Shut down pumps.Monitor well 30 mins.Static.TOH w/7"Baker Multi Cutter BHA f/2349' U surface.UD same. Swap upper rams from 2-7/8"x 5"VBR's to 7".Test 7"upper rams Low 250psi,High 3500psi,Failed.Re-M/U multiple leaking connections on test joint.Re-test 7"upper rams Low 250psi,High 3500psi, Passed.LD 7"BOPE test joint,RU to pull test plug.Pull 7"pack -off with>5klbs.LD 7"pack-off pulling joint.PU&MU 7"landing joint.Pull 7"hanger with 95klbs. Inspect&UD hanger&landing jt.POH&L/D 7"26#L-80 Hyd 563 csg.Clean&clear rig floor. P/U&M/U Back off BHA per Baker Rep U 463'. ***Provided 24 hour notice to AOGCC for BOPE test on 09-13-2017 7:00 PM.*** 9/13/2017 9/14/2017 2,351.0 8.50 Continue P/U&M/U Back off BHA.RIH U 2855'.Ratchet Dutchman per Baker Rep.P/U on back- out tool to free anchors.Drop ball and pressure up 3800 psi to shear circ sub.Tool failed to cycle 3 times.POOH wet with Dutchman back-off tool from 2812'to surface.PU&RIH with spear on 4"DP from surface to 2362'.Spear into Dutchman.POOH with spear from 2362'to surface. 22.30'Dutchman retrieved with pin looking down..P/U&M/U Baker Triple connect on Jt#1 -7" 26#L-80 Hyd 563 csg. Multiple attempts to RIH w/Baker Triple connect.Stack out @ 37.55'. Wellhead Min ID 9.93"per Vetco Gray.Max OD 10.125"on Baker Triple connect.Phone conference w/CEA Anchorage team&Rig team.--Decision to send Triple connect to Baker to turn down U 9.6875".Back off&L/D Baker Triple connect&7"csg Jt#1.Set Vetco Gray test plug.R/U BOPE test equipment. 9/14/2017 9/15/2017 2,351.0 8.50 Testing BOPE with 2-7/8",4",&7"Test joints as per AOGCC&PTD: -Test annular w/to 250 psi low/2500 psi high. -Test 2-7/8"x 5"VBR in Lower Ram Body with 2-7/8"&4"test joints to 250/3,500 -Test 7"Ram in Upper Ram Body with 7"test joint to 250/3,500. -- Upper 7"Ram door bonnet seal leaking. -Test upper and lower IBOP valves to 250 psi low I 3500 psi high. -Test all floor valves to 250 psi low/3500 psi high. -Test 14 choke manifold valves to 250 psi low/3500 psi high. All tests charted and all tests held 5 min. -All tests performeddwith 8.5.5ppg seawater. Provided 24 hour notice to AOGCC for BOPE test on 09-13-2017 6:40 PM. (2—'11.74) C.' Guy Cook Inspector with AOGCC waived BOPE witness at 9-13-2017 7:00 PM. RD BOPE test equipment.RU 7"casing running equipment.Hold PJSM.Run 7"26#L-80 Hydril 563 casing from surface to 2368' Obtain base line PU,SO,RW,&rotating TO readings.W/ annular preventer closed;Pump 150 bbls diesel freeze protect down OA.Rotate Triple Connect @ 8 rpm over stump.Screw into 7"casing stub at 2375'.Torque up to 9800 ft-lbs @ Triple Connect.Open annular.Hold 12200 TQ&stage U 100 K over.Reciprocate pipe to work 12200 TQ to btm connection.Release all tension&work out all TQ.Pressure test 7"casing to 2500 psi for 30 mins. Page 3/5 Report Printed: 10/11/2017 •G CAELUSOperations Summary Report- State Well Name: ODSN-28 Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 9/15/2017 9/16/2017 2,351.0 8.50 Prepare to lift BOPE stack&cut 7"casing.Hold PJSM.Lift stack and well head per Vetco Gray. P/U 115K,slack off&set emergency slips.M/U Wachs cutter.Cut 7"csg.LD 7"csg stub.Dress 7"casing cut and set pack-off.Set BOPE down on wellhead.Test pack-off to 4300psi. Replace 7"rams in upper ram body with 2-7/8"x 5"VBR's.Test 2-7/8"x 5"VBR's in upper ram body to 250psi low/3500 psi high.Passed. Install 6-3/8"wear bushing. P/U RBP retrieving BHA. RIH from surface t/11474'.Screw into stand#112.RIH&tag Baracarb @11474'.Reverse circ Baracarb out of hole w/annular preventer closed and kill line open.Tag top of RBP @11495'. P/U 5'.R/U to pump down DP.Pump 54bbls @ 3bpm w/62 psi.Wash down to RBP @ 11495'. Lost pump pressure&returns.Set down&latch on to plug.Pull 10k over.--RPB latched.Slack off 110K.P/U to 160K previous R/W.Rotate&release plug per Baker Rep. POH w/RBP while L/D 4"DP to pipe shed f/11495't/10974'. 9/16/2017 9/17/2017 2,351.0 8.50 POOH w/RBP while L/D 4"DP to pipe shed 10974'to surface.LD RBP retrieving tool and RBP. Remove wear ring.Install junk basket and flush stack.R/U to run 2-7/8"Upper Completion.-(2 7/8"6.4#L-80 IBT-M Tubing.)Hold pre job safety meeting.RIH w/ 2-7/8"Upper Completion f/ surface t/1200'. 9/17/2017 9/18/2017 2,351.0 8.50 RIH w/2-7/8"Upper Completion f/1200'U 12456"(2 7/8"6.4#L-80 IBT-M Tubing)Tag top of liner @ 12456'.Calculate space out.Vetco Gray M/U hanger.Begin connect feed thru TRSSSV Control Line,Chemical injection line&Pressure/Temp gauge. 9/18/2017 9/19/2017 2,351.0 8.50 Finish connect,terminate&test feed thru Control lines.Land tbg hanger per Vetco Gray. Maintain 4500 psi on TRSSSV.RILDS.Test upper and lower Hanger seals to 5000 psi/10 min. R/U Expro slickline.Test lubricator to 500 psi.RIH w/ball and rod&set @ 11584'WLM.R/D Expro slickline.Pump 25bbls BARACOR packer fluid down 2-7/8"x 7"IA.Set SLB packer. Pressure test SLB packer to 3500 psi for 30min.Charted.Bleed 2-7/8"tubing pressure from 3500psi to 1500psi.Pressure test 2-7/8"x 7"IA to 2500psi for 30min.Charted.Dump 2-7/8" tubing pressure from 1500 psi to 0 psi to shear-out valve in GLM#2.Confirm shear by pumping 5bbls both directions.Remove 4"landing joint.Set TWC on dry rod.Pressure test TWC from below to 1500psi.Passed.R/D completion running equipment. N/D BOPE.N/U Production Tree. Test tree void 5k/10min.Vetco Gray install lubricator.Remove TWC.Ops&Little Red begin freeze protect well w/diesel. Release rig from ODSN-28 at 23:59 on 9-18-2017 MIRU on ODSN-04 at 00:00 on 9-19-17. 10/2/2017 10/3/2017 2,351.0 8.50 00:00 10/2/17-00:00 10/3/17(Post RWO S/L) *MIRU HES Slickline. *Take control of ODSN-28 from OPS-Wells). *Nabors 19AC utilizing the GE Vetco Gray lubricator to pull the TWC from the wellhead.Standby for the Lubricator to be free. *Wind seeds in excess of 30 mph,this hinders the ability to utilize the HES crane. *Crane speed maximums are 30 MPH as per HES policy. *Nabors 19AC in progress of killing ODSN-17,keep close contact with the Drilling Supervisor for timing on GE Vetco Gray tools/Personnel. 10/3/2017 10/4/2017 2,351.0 8.50 00:00 10/3/17-00:00 10/4/17(Post RWO S/L) *MIRU HES Slickline. *MIRU GE Vetco Gray to remove the TWC set in the wellhead. *Pull the ball and rod from 11,552'slm. *Pull DGLV from GLM#1 at 8,922'slm. *Lay down HES Slickline in preparation to MIRU on Nabors 19AC to assist on the RWO. *Stand by for Nabors 19AC. Page 4/5 Report Printed: 10/11/2017 • 411 CAELUS r r rAtaskae c;v Operations Summary Report- State Well Name: ODSN-28 Start Depth Foot/Meters Dens Last Start Date End Date (EKE) (ft) Mud(tbigal) Summary 10/4/2017 10/5/2017 2,351.0 8.50 00:00 10/4/17-00:00 10/5/17(Post RWO S/L) *MIRU HES Slickline. *Set 1"OV w/5/16"orifice in GLM#1 at 8,942'slm.Good set. *Pull 1"DCK SOV from GLM#2 4,340'slm.Valve on surface. *Set 1"DGLV in GLM#2 at 4,340'slm.Good set. *Run the Ball and Rod on a 2"RS to land in the RHC-M set in the X nipple at 11,555slm.Stay on ball and rod.Pressure test the TBG to 3500 psi.IA does no track.Monitor for 15 min.All GLV are holding. *Unseat the ball and rod after bleeding pressure to 1000 psi.pressure falls to 30 psi.POOH to surface. *Once on surface it is found that the ball and rod portion un swiveled from the roller stem.2 Welds of this thread were broken off the stem and it is confirmed the fish is a 3.12'rod and ball with a 5/8"shaft looking up. *Make a fishing BHA and confirm with the Wells Superintendent. *Make 2 attempts at fishing the rod with the second attempt being a modified bell guide O'bannon overshot.On the second attempt 300#over pull was witnessed with the TBG pressure going from 450 psi to a vac.POOH to surface. *Fish on surface. *Lay down HES Slickline for the night. 10/5/2017 10/6/2017 2,351.0 8.50 00:00 10/5/17-00:00 10/6/17(Post RWO S/L) *MIRU HES Slickline. *Pull the RHC-M from the X nipple at 11,563'slm. *RDMO HES Slickline. *Hand well over Wells-OPS. Page 5/5 Report Printed: 10/11/2017 • 0 ODSN-28 Nuiqsut Production Well Completion FINAL 10-05-2017 I No. Upper Com pietio n.Egi;ipment NOIR{ Wrfiftl • A 'datc olray Tubing Harp: c B 3-112"9. #L84TClI1 C 3-1.12"1.40 8.294 11.1b-: D 3-112"8.2Pl:8n ' E 27/8 E=.. 5--.,. '�/ F 2 7 ♦I ,--r ' 3 HES 'NE T6SV r./2._. king Ewe IBT-M Box.,• 2345 .._.. GLM#29 a=L-80 BT-4411 Mt P„..,o Iorl Box x Pn DGLV , , 16"Conductor l =-:.eL-8OlBT-MTub,ng J :. -L-80 83T-@.11tft Pup Joht Box x Pin Packer Fluid mix' K :•14 2 KBr,t IBT4.1 Box x Pin 333. Inhibited Kill weight a 0T-M15ft Pup Joni Box xPin • Brine M E 187-MT _:cintsj with2000'TVD N 15ft2-71 6T-L i'6.4#EUEs- 1Box xPin 0 2-7/8'"}: =a 31: E Bait x Pin 4436 2931 diesel cap P 15ft 2-7=3' •EBE B - 6.4#UT-MF. .... . et'Pup Joint Box xPin 0 2-7/8"6.4}*L-SDiET-MTutirg R 2-7/8"6.4#1-80 BT-M 15ft Pup Joint Box x Pin l Iat. 11-3/4"60#L-80 S 2-7/8"x 1"Mlle 1 KBf.0 1ST 4.1 Bat x Pin 8924 SODD BTC Surface T 2-7/8"6.4#L-80 BT-R115tt Pup Jost Box x Pin U 2-7/8"6:428 L-801ST-M Tubing 12 Joints) 7"Casing Repair: Casing V 15ft2-7/8'6.4C113T-MBoxtx2-778'6.43 EUE Pin LAOCrossover Pup Joint Box xPin New 7"Casing I @ 5,549'MD/ w 2-7/8'"X"Nipple*2 12.313"ID)EUE Box x Pin 9021 5037 from 2,375'MD to I 3,453'TVD X 1556 2-718"644/EUE Box x2-718"6.4#ET-MPn L-80CrossoverPupJaintBox x Pin Surface cemented to r 2-7/8^6.42x1-$0187-MTubing(1 Joints) Z 2-758"6.4#L-80 1374M 1515 Pup Joint Box x Box surface Rh 2-7/8"Pmx,ure/Temperature gauge 2-J/8"IBT-M Pe x Pe with 1 wire to surface 11202 6035 BB 2-7:8"6.4#L-80 1371,11 Pup Jont Bax x Pin 9-5/8"40#L-80 CC 2-7/8''6.434LSO IET-MTubing11Joints) Hyd ri 1521 DD 2-7/8"6.44 L-80 UT-M 15ft Pup Jo:tt Box x Pin EE 2-7/8"Chem ical Injection Mandrel wthcontroi lite to surf ace w/IBT-M Box x Pin 11263 6061 Intermediate 1 rr 2aB /s"6.4#L-84 T-M 15ft Pup Ja1N Box x Pin GLM#1 I "�,i `' Casing GG 2-7/8`6.46*L-801ST-M Tubing 11 Joints) 5/16"OVI @ 10,152'MD/ BB 15ft 2-7/8"844137-MBmx2-758`6.4#E UE Pin L-80Cr soverPupJointBoxxPn 0 - W ii 2-7/8"x 7"Retrievable Packer 2-7/8"6.4*EUE Boxx Pen 11395 6109 5,556'TVD JJ 15ft 2-718"6.4#EUE Box x2-758'6.4#BT-ftPnL-80Crossover Pup Joint Box xPin L I ., Cemented 500' Kx 2-7/8"6.40*L-80113T-M Tubing[2 Joints) above shoe L1 15ft 2-7/3"544 IBT-MBoxx2-r8"6.436122 Pit L-8DCrossover PuniJoi Box x Pe •® 2-7/8"Sliding Sleevew/'X'Npple Profie 2.313"10.ELLE 8130 Box x Pin Run in Closed{Sleeve Shits MM Down to Open) 11466 6133 II _ ►_. hit 15ft2-718"64#EDEBea x2-7?8"6.4#13T-MPin L-80Crossover PupJointBox xPin 00 2-7/8"6.40*1-801BT-M Tubing MM 000 PP 15ft2-1/8'641BT-M Box x2-7/8"6.4#En Pia 1430Crrvec%arPupJotntBox xPn 2-7/8"6.4#L-80 0Q 2-7/8" X"Nipple*1{2.313"ID)EUE Box x Pin yr/RHC Plug 11562 6165 RR 15ft2-7/8"54#EUEBel.x2-7/8"6.4#BT-MPnL-80Crossover PupJlettBox xPin °, © IBT M Tubing SS 2-7/8"6.4781-80113T-M Tubing (Upper Completion) 11 4"Auto Entry Muleshoe l8T-MRosins bucked upto1p:,tof2-7/8"6.4081-8018T-M Tubing 12444 6331 End of Assembly 12453 6332 :i: TOC Estimated 500'above top of Kuparuk % 0 WRONG SWELL PACKERS RUN-4'/:"13Cr80 13.5#Swell Packer: Burst=9,020 psi/Collapse=8,540 psi 6-1/8" Hole TD ./ 2s Swell Time to Frac @ 6.125"=62 days/@ 6.500"=137 days @ 19,329'MD/6,371'TVD 7"26# L-80 \ A-� 00 0- 57 0 71 78 85--- 92 - 0 Lei , ® �--E----II---&Hydril 563 _ _ _ Intermediate 2 Casing /° I_- _ _ I_' _ _ '_ _1 _ 1°12: @12,762'MD/6,358'TVD ®\.'. 4-W Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve • • ODSN-28 Nuiqsut Production Well Completion FINAL 10-05-2017 I 1 1 No. 10 We con•pletlonIAli equip mens must be no less than 12,200 psi rated} MD(ft) TVD(ft) 1 15 ENO: _ E33E 3 s 0 ,, X3 63:_ ._twatad 131.:.7 63'.:: ..5-534. 13274 6367 O , 25 0164 ._ _ ___. - ;35 58]±j 13315 6367 A El26 R 5-534' 13314 6367 16"Conductor 2- ..- _1- _ Packer Fluid mix. 29 it' 13467 6367 Inhibited Kill weight Brine Rem.32 .6'4_..64,',111131}0"521 L:r0' 31 n Cartier Sub)0b421817-10-2 R05-777/RW5-533'; 13723 6367 with 2000'TVn 32 HL54-1/2 SLOT Bal Actuated Sleeve(2925 ball/2.867Seat[ 13764 6366 Iti diesel cap 33 Realty n Cartier Sub[bb 421547-10.1 RD5-777/RW5-533( 13796 6366 / 34 655"12.64,052-112 ftydn.521 L-8• 35 4.17 _w 1 lft N)dnISll-6'F'sp'.vt'.:..5 .:i3:_'t-3:a Ha6burton 5,165 Packet(4.34'Hyd,115211 OD 5.55'-3 mete io,03 t nt rale,E,21 (at ad 14675 6355 I11 3/4"60#L 80 - 611"12.64Rt E-110 Hydrf 521 Liner BTC Surface 38 Re3nan Eagle,Sub[Job 6 21847-9-2 R05-775/RW5-6321 14427 6355 7"CasingRepair 59 MB 4-1/2`SUIT Bal Actuated sleeve(2612 ball!1.7565!65) 14469 6358 P Casing 43 Re3nanCarrier Sub[lob 4211147-9-1RO5-7761RWS-B32( 14504 6357 New 7"Casing@ 5,549' MD/I ._ 44-,s^12-64:1tc-112Hydra-521Ltae, from 2,375'MD to 42 .2 45 ' a '," '5_-_-_P.p xath slide an vv?aat cenuadizers 3,453'TVD Surface I 43 •"Hyc41d523}m5.83-9 meta beg al attivated element WRh 611.^, _ 14777 6355 cemented to 43 y';-12..64,353-112 Rya,521 Litter surface 45 Resman Carrier Sub Debit218474-2R135-775/RWs-M1( 15062 6357 46 1664-1/2'S141 Bal Actuated Sleeve(2.761 bald/2.786 Seat) 15103 6357 47 Revnan Earlier Sub(Sob.21847-8-1 R05-775/RWS-831( 15135 6357 ''t 9-5/8"40#L-80 4R 611"12.64,1t C-110Hydri 5211mcr • Hydril 521 4? 41,`12.6611 H1,411521-6'Pup with sbde on Wart cenbabers Intermediate 1 52 nalib'orton Swel Packer(4-54'lJyd/1511)OD5.85°-9 meta long 64aetbateed eteenentxdtdso4de envala5t ce4tralze1p,••rand 15374 6355 GLM#1 , —,1 s Casing 51 4'1.`122..64RtC-110Nveld521Loner 5/16"OV I 52 Rev»dnCarder Srb[Job S21847-7-21205-774/RW5-830) 15595 6355 EN @ 10,152'MD/ 53 1664-1n'SUIT Bal Actuated sleeve(2661 ball/2.6285edt) 15636 6354 54 Reiman Can ler Sub[10b1121547-7-1 R05-774/RW5-830) 15668 6354 _. 55 TVD 55 411"12.64,05E-110 Hydra 521 Lrar LaoCemented 500' 55 4-17]2.0M5k00 ydnI 521-6'Pu64- 04340 Vol0rt ent7414,s above shoe C)ECD - MM 000 2-7/8"6.4#L-80 ooIBT-M Tubing (Upper Completion) TOC Estimated 500'above top of Kuparuk Iliii -4WRONG SWELL PACKERS RUN–4%"13Cr80 13.5#Swell Packer: fy Burst=9,020 psi/Collapse=8,540 psi 6-1/8" Hole TD ' Swell Time to Frac @ 6.125"=62 days/@ 6.500"=137 days @ 19,329' MD/6,371'TVD 7"26# L-80 *4P, �;®®� -ai sl , 7, - 7e _ all - ssBTC M&Hydril 563 / l 1 Intermediate 2 Casing 22 0; / _ _ _ ! -I .:11_ _ _�® _ .r o @ 12,762' MD/6,358'TVD , ir, rr r+ -- o0 4-'W Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve • • ODSN-28 Nuiqsut Production Well Completion FINAL 10-05-2017 l 5' - I I 635.3 `:: I . 4-7° C)O 59 Re5man Canner Saab Deb 6 20847-6-2 RCS-773/RIAS-8291 15246 5350 59 I1.861/2"SUIT Bal Actuated Sleeve 15603 bag/5552 Seat) 15249 6349 51 Resmao Carrier Sub Deb 8216+' 1RCK-773/R613-8291 16277 6345 52 4-5t"1251,5: 1103W'-- - J K 53 4"h'1564.11 Nye 521-5- :29: 3 -_:3: HAI,577 Su43 P3-t- 155'14 534. GLM#: A ®x CD , €5 655 12_6479 UC : DGLV 16"Conductor 66 306",4"143516 sAb[ r. '2'Rn5-626 16725 6343 67 8184 R 3/2°SU8146 a.. =.: _'14141.'2,477 _'. 15635 6342 1543.3 5347 Packer Fluid mix - Inhibited Kill weight 71 17145 5344 IBrine 4 p 1, Hydra 521302355 with 2000'IVO -=- Cr", E:1 6' . 73 alTtEr5613116b47-4-21639-7711R515.8231 17467 5340 ` ••• diesel cap 74 FILE31{2'SUNT Ball Actuated Sleeoe11452 ba!/240456140) 17444 6546 75 Fk.Srnan artier Sub[Deb 921847-4-1R36-7711 R666-6271 17473 6341 ?€ 4-56`tZ51;ft-110954 321 '7 443:17_6a/rt 5' 521-5'F _ .2_ 11 3/4"60#L 80 76 II alb Mae569I Packer j4-56 r - - -- 17750 S043 BTC Surface 73 4-}Y'12.64,112-110 r'''',C521Lne 7"Casing Repair Casing60 305man Carner5ab pub 1218473-2R65-770/RM68261 18010 6339 New 7"Casing I 81 #1543/2'SUIT f�Actuated 5185ve15579 ball/5332 Seat) 13051 6339 @ 5,549' MD/ 62 Reamuaat CarierSub pub 821847-3-1 R05-770/RM6-8251 16093 6339 from 2,375'MD tc, 53 4-13 12.64,it,.u095&521 Cm- Surface I 3,453 TVD 54 4-w1Z6,fitrrydr;sl-6'Pv6Tech site onvoraetcertarbe•5 cemented to 65 1635:8 - surface 11a-hu ran SAc4X !Packert4- 'Hydro 521102 585"-901eter keg ad activated dement with rade 266 Vo/ant centra&zers pan end 86 4-6"1264;32 C-11013,0+*-5211....2127 87 Herman arierSub[lob#21847-2-2 R05-759 f R18S-8251 18639 6335 9-5/8"40#L-80 Rs ItB4,-1/2"Sure Balt Actuated Sleeve[2347 ball/Z261 Seat) 18681 6335 119 3060535 anierSub Dab 621847-2-1806-769/11186-925] 18713 6336 Hydrll 521 90 445''1254.%32C 110ty55521ire- �{ I Intermediate 1 91 445'12Na,1t Heer.521-s'1736716-6,5:4e or`.0372 ceetra•ems GLM#1 �* Casing 92 Mabel,6313 SAA1Packer 14-5S`Nara 5'="102585 9,mete:124g 62 ativat2d 42men5 wl3.h sad par 1464 5/16"OV I 93 4-55'125452"-110 HOC' 5211:5E" ® S ... X @ 10,15 2'M D/ 94 Re6min arierSlh Il b 3 21847-1-2 RD6-768/11385-3241 19:47 6359 5,556'TVD 95 11113' 2'SUIT 839 Actuated Skee'e[2236 beer 219236821 19680 6362 96 Re5mat arierSub[Job 421547-1-1 gib-758/RIA6-824[ 19111 5564 Cemented 500' 97 6h"1264/51 C-11099345 521116' L 98 6k1'1Z6e/3t ,7521-6'Pu w-'s:a-::- above shoe "d F.^I cenress, •® 99 Haex34 ram swell Packer14-36 Hydra 521}1[ _- _ _ - 9 - E. 11 100 055-PerferatedPupwrthL%'i2HF/ftc-11044- :: - ,_ 101 555606-1 Shoe v.th/tat 5313 'e 71 MM I 0 0 Bottum of Shoe 19610 6371 2-7/8"6.4#L-80 °° • IBT-M Tubing (Upper Completion) TOC Estimated 500'above top of Kuparuk TT e fir @� ® WRONG SWELL PACKERS RUN-4'/1"13Cr80 13.5#Swell Packer: n Burst=9,020 psi/Collapse=8,540 psi 6-1/8" Hole TD `'4'/ zs Swell Time to Frac @ 6.125"=62 days/@ 6.500"=137 days @ 19,329'MD/6,371'TVD : 7"26# L-80 I :; ®® -43-- 50 147 -sa- 0) 0 ss sz °- BTC-M&Hydril 563 \ I)�� = _ = _ _ '- " - �I Intermediate 2 Casing 22 '' ; /W/3 _ _i = �' _ _ _ _ IoI m @ 12,762' MD/6,358'TVD ki 2_ , i ,4 6 s� a, ai 4-1/2" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve • OF ro yy,�s� THE STATE Alaska Oil and Gas 00. of LAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFA S Fax: 907.276.7542 www.aogcc.alaska.gov Rami Jasser Senior Staff Completion Engineer a .-11J1-, 0 6 2-°17 Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-28 Permit to Drill Number: 213-148 Sundry Number: 317-247 Dear Mr. Jasser: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P-411 `41- Cathy P Foerster �,�pp�� Chair DATED this thay of June, 2017. RBDIVIS 0./ JUN 2 6 2017 • • RECEIVED STATE OF ALASKA JUN 1 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSIONcr G 1201! APPLICATION FOR SUNDRY APPROVALSAOGCC 20 MC 25.280 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate ❑ Repair Well El Operations shutdown❑ Suspend Cl Perforate ❑ Other Stimulate El Pull Tubing 0 Change Approved Program❑ Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well El Alter Casing D Other:7"Casing Repair f Run Gas Lift a 2.Operator Name: 4.Current Well Class: 5 Permit to Drill Number: Caelus Natural Resources Alaska,LLC Exploratory ❑ Development 0• 213-148 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3700 Centerpoint Drive,Suite 500,Anchorage,AK 99503 50-703-20676-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ODSN-28 Will planned perforations require a spacing exception? Yes ❑ No 0 7 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389950/ADL 389958 1 Oooguruk-Nuiqsut Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 19,329' 6,371', 19,210' , 6,371' , 1,647 psi . N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5,506' 11-3/4" 5,549' 3,453' 5,830 psi 3,180 psi Intermediate 1 4,762' 9-5/8" 5,390'-10,152' 3,382'-5,556' 5,750 psi 3,090 psi Intermediate 2 12,719' 7" 12,762' 6,358' 7,240 psi 5,410 psi Liner 6,765' 4-1/2" 12,445'-19,210' 6,336'-6,371' 11,590 psi 9,200 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attachment pg.2 t See attachment pg.2 4-1/2" 12.6#,C-110,Hyd 521 12,472' Packers and SSSV Type: See attachment pg.3 Packers and SSSV MD(ft)and TVD(ft): See attachment pg.3 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development El ' Service El 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/8/2017 OIL 0 WINJ ❑ WDSPL El Suspended Cl 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staff Corn•I�'.n En.ineer Contact Email: rami.iasser(U caeluseneray.com Contact Phone: 907-343-2182 Authorized Signature: % . Date: GY"IL I:3- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - 2 Plug Integrity ❑ BOP Test I Mechanical Integrity Test El Location Clearance 1:1t *- t 'a 1,4 Other: 3500 ids t 60 0 7 L Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: I/w . '-t Oil RBDMS LL, JUN 2 6 2017 /9 APPROVED BY / Approved by: 4COMMISSIONER THE COMMISSION Date: (� -t/7 'Kt) 6/il 117— el'—i7-- 1r�� ®art,GZIALid Submit Form and orm 1 0 Revise 4/2017 for 12 months from the d e of approval. Attachments in Duplicate • • CG CAEL1JS June 8, 2017 RECEIVED JUN 1 3 2Ui7 State of Alaska � �� Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: ODSN-28 Sundry Application to repair 7" casing and replace 4-1/2" Frac/Gas Lift Upper Completion with a 2-7/8" Gas Lift Upper Completion REF: Approved Permit to Drill #213-148 Caelus Natural Resources Alaska, LLC. (CNRA) submits an Application for Sundry to fix 7" Casing due to a shallow casing IA x OA leak and Replace 4-1/2" Frac/ Gas Lift Upper Completion string'with a 2-7/8" Gas Lift Upper Completion string on ODSN-28, Please see the proposed plan attachments and supporting documentation. Sincerely, fail \ Ail Rami Jasser Senior Staff Completion Engineer Attachments: Form 10-403 Supporting Information cc: ODSN-28 Well File • 2 ODSN-28 Procedure Summary: Pre-Rig: 1. Set EVO-trieve above deep XN nipple or PXN plug in XN nipple 2. Pull OV from GLM#2, Install DV in GLM#2 3. Pull DV from GLM#1 4. Fluid pack tubing and IA with treated/filtered seawater v' 5. Freeze protect tubing and IA to 2,500' TVD with diesel 6. Combo Test Tubing x IA to 3500 psi C.../4 7. Set BPV 8. Test Pack-offs to 5000psi 9. Lube and bleed Tubing and IA to ensure fluid packed • Rig Work: 1. MIRU N19AC 2. Install test dart • 3. ND Tree/ NU BOPS 4. Test BOPE to 250psi low/3500psi high; Annular to 2500psi 5. Circulate out diesel freeze protect with treated/filtered seawater 6. Circulate IA to tubing at high rate with surfactants to clean IA 7. SL - Install DV in GLM#1 8. SL - Pull EVO-trieve or PXN plug 9. Monitor fluid level in tubing, establish loss rate 10, Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 11. BOLDS 12. Pull seals from SBFS 13. Monitor fluid level in tubing and IA, establish loss rate 14, Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 15. POOH with 4-1/2" Frac I GL string and LD 16. PU and RIH with 7" RBP, set at 11,500' MD 17. Fluid pack 7" casing with treated seawater, Pressure test RBP to 3500psi 18. Dump sand on top of RBP 19. POOH with RBP setting tool 20. RIH with bit, scraper and magnets to 11,450' MD, tag top of sand 21. Circulate clean 22. POOH Cleanout BHA 23. PU and RIH with 7" mechanical casing cutter -,? es 24. Locate 7" collars at depth and cut casing mid joint, -3,420' MD (2500' TVD) 25. Circulate casing and IA (7"x11-3/4") to seawater, ensure IA is dead 26. POOH with casing cutter 27. BOLDS on 7" casing hanger 28. Break hanger free, POOH and LD 7" casing - identify leak point ? 29. PU and RIH with Back-off tool 30. Engage 7" stub, back off 7" dutchman, POOH and LD 31. Contingency fishing run for dutchman if needed 32. PU Triple Connect Screw-in sub and RIH on new 7" casing 33. Place diesel FP in IA, close Annular protector 34. Screw into 7" casing at depth, work appropriate torque into string 35. Ensure IA dead 36. Break BOPE and lift 37. Pull tension in 7" casing and set casing slips, RILDS 38. Rough cut 7" casing, LD stub • • e O I- 39. Set back BOPE on stump 40. WACHS cut 7" '� . d.� 41. Install 7" PO's and test 42. NU BOPE and test breaks 43. RIH with RBP retrieving tool, circulate sand from RBP 44. Release RBP, establish loss rate 45. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 46. POOH and LD RBP and tools 47. PU and RIH with 2-7/8" Gas Lift upper completion string as per attached schematic 48. Drop Ball-Rod 49. Place inhibited packer fluid in tubing and IA with diesel freeze protect to 2,500' TVD 50. Set packer 51. Pressure test tubing to 3500psi, Pressure test IA to 3500psi 1,A'.1 52. Shear SOV in GLM#2 53. Close ScSSSV 54. Set BPV 55. ND BOPE/NU Tree 56. RDMO Naborsl9AC Post Rig (Slick-line): 1. Pull Ball-Rod 2. Pull SOV from GLM#2 3. Set DV in GLM#2 4. Pull DV from GLM#1 5. Install OV in GLM#1 6. Pull RHC r > j: 'f- V c 5 ,€,.- • S 4 Reservoir Pressures: Nuiqsut Pressure: 2,282 psi at 6,350' TVD after 30 days of shut-in = 0.36 psi/ft. = 6.9 ppge Maximum surface pressure: 2,282 psi at 6,350' TVD reservoir pressure with 0.1 psi/ft. gas gradient = 1,647 psi MASP ODSN-28 Nuiqsut Bottomhole Pressure Build Up 3,500 -2014 Initial Pressure 3,000 Seawater(8.55 ppge) 2,500 -LVT/Diesel(6.8 ppge) 00 N us 11/29/16 PBU 2,000 a -01/08/17 PBU 3 y 1,500 • •• Expected Pressure Build Up a w ea W 1,000 u 0 500 0 0 5 10 15 20 25 30 Shut-in Time,Days 0 5 Original Well Schematic: FINAL 8-13-2015 ODSN-28 Nuiqsut Production Well Completion No- Utas Canp4tonlMRr lep� nentm �mthan ulkai40mpsirldt MD(hi NDIItI IUpper 1 -.aw ,anae- 34 34 Completion 2 3--i u614•f.1-110'-,4.s21'.7,a 3 1 1-. abut: laC1 5,1h of 3373"-X-p-dzk RT53t ;- .r - ._ _;3,3 . Landed with ,_ e s s _ - le- ,ter-•. „.3 u, 1 40,000 lbs 4 4.v'12.6r't C-s'1.,-a-r� :_:0. 521-.P ne -- :r3 k.5%33.+ 3]c I I slackoff 6 6'S 1:.61;11 C-1x«7, 5:1-.2,0 7 Ics"r Nipple i 91r 3621 sot I j a 1-1"1264't1-1:C.+y7- 521-.7,6 5 4 - ::',L'.' 5v3.1."yx,'521 ,x;:23 2334 ,. I I .,.., 1c 4.'s-.2-6i4'h 1101+,? 521".3 1g I 16"Conductor 11 _ . .- .P..T,u,_ --. �. 12 vS-12..6e:'t 2 ,,,4r 521-.7 n4- I I Packer Fluid mlX 13 11[6Wlair(1775*NoGo1-111Aae oaf rets*ft*wets/ 11363 3096 I j 11 1'3 1261.'4:C-1=3+,7 521-.21e Inhibited Kill weight 1; 612 w,1c„rt_<,RCC er.Car,er 33/Encap.urtatede3r,etos.:r.,z 123:; 6329 I I Brine 161'i 1?611.'6 C.-11C3+yr 521-.7 n4- 4.5"FXE set I ,I C with 2000'TVD 17 i.9et Seat Ata. *k e*It9SeW-Abensne Mule Sloe 6137 in SSSV diesel cap9etsanolvae 11245247: 633e 1 _No. ower Cone/etion Al calprtptt nwstbc no less then 14000yd quill 9OIft) N01h) 1 13 k.,e•5 ir 7 233,e-erT -Psi.er w:tn ', aBa;;eete ream^71 K.,:2,Ha-cer 12::3 6336 166 11-3/4"60#L-80 19 4- 12.64'6 C.1.1.0,3+rt 521L nen. BTC Surface Zr ay 1264'111114 521-6 P,Q wt,s.de art‘,.2 ant:nt-e:es Casing 21 itekbutan Shea S Packer 14.V 13Cr901352143s6a t 6211 on 5sm-(9020 pa 9arst/9590 psi 133187 636: 'E dlaptel a niers til o3weeabbe des**13th Onfeten Natentcntnekea onerd GLM#3 DV s GL it @ 5,549'MD/ l Hpdas 421 1355 S-$9710 p4 Bunt/ #psi 'Halibuts*Swd i tater 423,3"13438013 S4- 7 © 3,453'TVDX2 <dttptel9naet<anneabsrtveteddementvote a;dtere VekarKtcntr eeepnend 13127 6364 cemented to 23 4-,126+:'t1:4:Cw,. 521L.le, surface 24 Rm ea*Cane Sub Deb 3 21047-11-2 Rt7S-77611t145t134[ 13274 6367 25 1494-1/2"5/141 WI Actuated 5leewt 13009 bail/19 5Seet1 13315 6367 26 Re:men Career Sub Mata 2194711.1ROS-778/R 'S-34l 13347 6367 GLM#2 GL Il 9-5/8"40#L-80 27 s•;12_641: 1..C1.,* 521L le- 5/16"OV C j Hydril 521 za 4•y 12614't.wr 521.5P:Pvet,s der',Pant_:,-- :es 27 13667 (0767 Nal sbuton swell Pecker s-HIon ci (4.7pal 5211 OD 9 sneer Ion a lament Ai* Intermediate 1 Bede an Veteran rera6 Bets pi n e rd A h1 Casing 3C b`S•1266' C-110Hy, S211,e- @10,152'MD/ 31 Raman Cane Sub flab a 21347-104305-777130058331 13723 6367 32 bat 41/2"SLHT Nil**sated Sleeve 12.925 ba//2J67Seat) 13764 6196 5,556'TVD 33 Raman Caner Sub(lob a21947-19.1804777/FANS d331 13796 6366 ICemented 500' 14 15 1-611;#c-11c1+,7 s211.ne. -Wire 35 3- 126 't w.f.,-a 521-6 P.es w.o,a de 7n V4-est ce:o:ens Splice @ above shoe 36 tiastuton&wetIPscavlo-:5"H,H571)00535-9 meter tare alamvatedei,n ,t Iseth 14075 3366 7722'MD a de oniolateedn6Bers pieced 37 3—12.84'6 C-11CH,7 5211.,e 33 RcnvnCaner Sub 1.1136 321137-9.2 R05-776/Ib4S-a321 14427 6358 39 NL941/2"YNTYIAmuatedSleeve 12278 ba•/2.796Seat1 14M 635/ 4-1/2" 12.6#C-110 40 R=^vn Cares Sub Gab a21947-41ROs-776/f6VS-632[ 1.'530 63577 41 3-s'126eitc-170Hya- 5211,e GLM#1 DV GL Hydril 521 42 4•` 1214/11663!^'d521-6Paset"iaex1,'aarenen les 0 I Tubing lei abutonSwdIPackel3:• Hpard521)OD535-9rneterlanenil*mated element wth 14777 . 5 I (Upper Completion) Ode on Vahan meet-Aaen pnerd ® 44 Sri 12614'11 C-11C14 rt 5211 nen I 45 SubRamanSi 11362 6357 16 11941/2'SIH?ill*muted Sleeve(2761b /27065eat1 15103 6357 0 R. 47 Res man Cane Sub(lab a 21947-8-1905-725/1WS-331) 15135 6357 46 4•*S 12.63'6C•11CH,r 5211,e- TOC Estimated 49 4..v 1260,434-- 521-6 R ens,s=de en 1,a are cntv:rs 500'above top of i- s..tu,Swe1Poi' 4—,;-/ap335n)ODs1 9-lets r3maa'a edeleme,t.ad, Kuparuk 3d<anvalxt:ere:site::an end SO 153?< ul. 51 4. 12614't.C-1344+r4^ 5211.nen S2 Ra man Caner Sub lb*a21337-7-2 RO5-774111V118301 15595 6355 527 It941/2"Stiff WLAGua ed Wes*12.683 bell l26285eat' 15676 5716 4 WRONG SWELL PACKERS RUN—4'/z"13Cr80 13.5#Swell Packer: .-4, , Burst=9,020 psi/Collapse=8,540 psi 4...,,,Swell Time to Frac @ 6.125"=62 days/@ 6.500"=137 days 6-1/8"Hole TD @ 19,329'MDI 6,371'TVD 7"26# L-80 " 4 4-3 so s7 64 71 74- >s sz ss BTC-M&Hydril 563 4 ■-- O —O— O — -O-O O- 4 Intermediate 2 Casing 0 , 4i - - - - - o >j @ 12,762'MD/6,358'TVD 4 ' - - -� - I 4-1/2"Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve • • 6 Proposed Well Schematic: ODSN-28 Nuiqsut Production Well Completion DRAFT 5-1-2017 II Fm r r,5`,� ; 13 A '•:etcaG•av .b me-wee- ear 31 54 � 11GSy ,0 h`� B 27,'afi40t:BDH'-M'}nt .. 2-714'KS �4E'7I6V 42313'9w-6 re Bore J..354 2�p Ri+rei -1,�� 3f�� 2.7/r 643101.-83ss-M-s#ns !�`CC�J 40 7 E 2-7/6'x 1•SLB GLIM 3.1'15 PupTopd Bottsrn 434 2597 I a— a 2.7,x610,0.-BO 6--1‘-ub:ng(2.ont11 C C' '4'P.pp'e W t2313't 2-7/8-w/15"Rep Top&Bottom 414: 2943 - SL5G1 1 ed15 PupTop 8 Borten 931; 50C<s K :r•F. 5 4) -80 6--M-ubirgi2lerts' GLM#2 0 0 \ I ., 313-lt12 70'r.4115 P.otou^$4. 9x22 5137 SOV I 16"Conductor to 5 5.42e..3C 8--M'stimi1.4inra !i j 7/6-P,r. Temderature Rs„A'e uN'-.v., 3 Pun Teo 4.' 1121:, Packer Fluid mix o 2-7/r64CP.-3J B--M'ubng{17o ntr Inhibited Kill weight ` 2-7/1-cr- ;rete M era 3 - P.4,Tcae. 112 0 2-7/1r5.404 32 B--M'tt 1.a-t4, Brine R BeterH, 'r a- 11362 with 2000'TVD s 2-7;,0617 Bo s-M-b re;2-o-te diesel cap 'y 6 56eSknewf-X'1:pp4er D.a�.. 146 iii 6L, L K r.ase 2-7. Fl45 Ay Ted 8 Hattan 115E2 6.1..11-3/4"60#L-80 A z .r 6X1 50 B'-M-_b ex BTC Surface x 6'Auto Entre Mu,Shoe 2111 ,:37 End of Astern Gly 13160 6337 Casing @ 5,549'MD/ 1.NS Weer ca,0o 1654 :pease! estbaneetaa then w tn:amA _..___. trleitat TVDtftl 3,453'ND 18 &ter S'4'ATwu..e,Top Plater with l.YtTreSae ertereonandFlee loci lismer 12445 e.5 cemented to 154.4'121a<,hC --114-rd- 521.ne- surface 20 4.5'175,0--.,- 5_1 :.•t.:=ecr._a^tx-t: es 9-5/8"40#L-80 13064 63E4 Hydnl 521 z2 ^,, ,a B�l65A ps nal ' 41,5 :1 I Intermediate 1 co - .' e t.tn.1 dee uero-Ytrenwa ies Pie Old A 23 4-r'ast...c-iic,-,,.. ---..4e- GLM#1 e- GLM#1 4 =,.1 J Casing 24 Rem.nCaner 54611a-be 21547-11-214-0S-778/RAS-6011 13774 6367 DV — @ 10,152'MD/ 25 KB4112-SL111 Bea Actuated Sieve 13039 eat/2%Sett) 13315 e67 © L 5,556'ND RemenC :ars buffbx21847LI-iRosns/Rwssat 13317 6367 �''T P 4'4'12.,4C-110-re--..521..ee• LI-I" ? Cemented 500' 25 4•V1260,R-ie- R1-6 dup well*de on bean dented era I ' N lie G bvnton Swell Pecker t#-%'Mpdr4524005.85'-9m iter Iongaf retested demett with above shoe 29 13 e d ede on Valent centralizers pi n end O ' 30 64'12.8,0/4C-#10.4.....,.521_<re4 29 31 Resman Canner Sub;Joba 21647.5992 ROS-777/RW'5-8331 13723 6367 32 111.34 lir SUM Ball Actuated peeve 12.925311/2./VSeet) 13164 6666 O T l o l 33 Rieman Caner Sub Yob*21847101 ROS-777/Rw'S-8331 13796 6366 RHC-M 2-7/8"6.4#L-80 34 4% 12a<r4c-uo»,a�sl - Plug re IBT-M Tubing35 Gt„stanSwellPatteri-12 PA nrcinl 52 1-aPun"Heel5 e en 1)OD55nt:nsr a: (i-'4^11yd152210D53-4meter sone ail activated dente 4,2h 14075 eri6c Installed (Upper Completion) dile on Vurnt centralizes/anent! 37 455'32 13i4C-110eyd-741:ine• 38 Reese.Carrier Sub;lob*21847-42R03-776/MN S-8321 14127 6En8 • 34 11.841/2-SUM Ball Actuated Sleeve 12!42 311 22.78614M) 1440) 6365 46 Raman Carnet Sub Dob a 21547-¢1 RDS-775/RW 5-323 moo 6357 41 451'128R14C-110«61-,.521.,w- TOC Estimated 42 4-k-1249i4rryd44521.6 Pu:pwth side orsvoant cent•eJsrs 500'above top of 43 seatenSwell Pecker OA.Mlydr1523)OD 383-9nttier tom el activated dement with Kuparuk 414/eon Votive centrdaersrinend 14777 635 44 451'12.BE*tC-110444521:.ne• 45 Raman Carer Sub L'ob a 2154742 805.775:Rei S-5311 15062 6867 46 1341./?SUM Ball Actuated peeve 12761 311/2.706Seat) 15106 6867 CO 47 R earn Caner Sub Ikea 21847-81 R05-775/RW 56311 15135 1857 48 4.V 126,0,41C-110-yd^-.i 521...ne- O iY4. 411 4-V•129y4'ydr-521.6 ds.preth s'de do VDant ae ntz"s•s 0 WRONG SWELL PACKERS RUN-4 1/2"13Cr80 13.5#Swell Packer: Burst=9,020 psi/Collapse=8,540 psi 6-1/8"Hole TD Swell Time to Frac @ 6.125"=62 days/@ 6.500"=137 days @ 19,329'MD/6,371 ND 7"26# L-80 \ 0 ® so57 e ® sz e 71 ® ss BTC-M&Hydnl 563 �� ® ® -- - Intermediate 2 Casing - - - - - - >1 @12,762'MD/6,358'TVD ® �` ` 'h< —1EL-�_ 4 '— t�� — - - Pa4 —_4 o 1 4-'/2"Hydnl 521C-110 Liner with Halliburton Ball Actuated Sleeve • • Attachment 2 AOGCC Form 10-403 Sundry Application Box 11 - Perforation Locations Well: ODSN-28 Top (MD) Top (TVD) 4-1/2" SLHT Ball Actuated Sleeve w/seats 13,315 6,367 4-1/2" SLHT Ball Actuated Sleeve w/seats 13,764 6,366 4-1/2" SLHT Ball Actuated Sleeve w/seats 14,469 6,358 4-1/2" SLHT Ball Actuated Sleeve w/seats 15,103 6,357 4-1/2" SLHT Ball Actuated Sleeve w/seats 15,636 6,354 4-1/2" SLHT Ball Actuated Sleeve w/seats 16,248 6,349 4-1/2" SLHT Ball Actuated Sleeve w/seats 16,836 6,342 4-1/2" SLHT Ball Actuated Sleeve w/seats 17,444 6,340 4-1/2" SLHT Ball Actuated Sleeve w/seats 18,051 6,339 4-1/2" SLHT Ball Actuated Sleeve w/seats 18,681 6,335 4-1/2" SLHT Ball Actuated Sleeve w/seats 19,080 6,362 Pre-Perforated Pup 19,198 6,370 • • Attachment 3 AOGCC Form 10-403 Application for Sundry Box 11 - Packers & SSSV Well: ODSN-28 SSSV MD TVD 4-1/2" Halliburton 'XXO' SVLN 2,297 1,969 PACKERS 5" x 7" Baker ZXP Liner Top Packer 12,445 6,336 HES Swell Packer 13,087 6,364 HES Swell Packer 13,127 6,365 HES Swell Packer 13,467 6,367 HES Swell Packer 14,075 6,366 HES Swell Packer 14,777 6,355 HES Swell Packer 15,374 6,355 HES Swell Packer 15,907 6,354 HES Swell Packer 16,516 6,343 HES Swell Packer 17,145 6,344 HES Swell Packer 17,750 6,345 HES Swell Packer 18,358 6,337 HES Swell Packer 18,983 6,355 HES Swell Packer 19,150 6,367 • • 0 0 g g g g 0 A A A A A A Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-28 PN3 50703206760000 Sperry Drillino Services Definitive Survey Report 03 January, 2014 HALLIBURTON Sperry Drilling Services • le Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-28 Well Position +N/-S 0.00 usft Northing: 6,031,113.39usfl Latitude: 70°29'45.87 N +EI-W 0.00 usft Easting: 469,928.86 usft Longitude: 150°14'45.21 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 13.50 usft Wellbore ODSN-28 PN3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) IGRF200510 12/23/2013 20.24 80.81 57,924 Design ODSN-28 PN3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From(ND) +N/-5 +E/-W Direction (usft) (usft) (usft) (0) 42.70 0.00 0.00 9.08 Survey Program Date 1/3/2014 From To Survey (usft) (usft) Survey(Wellbore) Tool Name Description Start Date 144.00 826.00 ODSN-28 PN3(ODSN-28 PN3) SRG-SS Surface readout gyro single shot 11/04/2013 869.58 19,219.58 ODSN-28 PN3(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/07/2013 5,558.11 10,118.10 ODSN-28 PN3(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/07/2013 10,135.09 12,749.74 ODSN-28 PN3(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/07/2013 12,773.00 19,219.58 ODSN-28 PN3(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/07/2013 Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,113.39 469,928.86 0.00 0.00 UNDEFINED 144.00 0.53 29.05 144.00 87.80 0.41 0.23 6,031,113.80 469,929.09 0.52 0.44 SRG-SS(1) 166.00 0.75 85.91 166.00 109.80 0.51 0.42 6,031,113.90 469,929.28 2.91 0.57 SRG-SS(1) 261.00 3.57 130.54 260.92 204.72 -1.37 3.29 6,031,112.01 469,932.14 3.24 -0.83 SRG-SS(1) 356.00 6.16 133.58 355.57 299.37 -6.81 9.23 6,031,106.55 469,938.06 2.74 -5.26 SRG-SS(1) 447.00 9.29 123.84 445.74 389.54 -14.27 18.87 6,031,099.05 469,947.67 3.72 -11.11 SRG-SS(1) 541.00 12.10 111.67 538.11 481.91 -22.13 34.33 6,031,091.12 469,963.10 3.82 -16.44 SRG-SS(1) 637.00 13.42 103.37 631.75 575.55 -28.42 54.52 6,031,084.75 469,983.26 2.35 -19.46 SRG-SS(1) 731.00 16.41 92.54 722.59 666.39 -31.54 78.41 6,031,081.54 470,007.14 4.34 -18.77 SRG-SS(1) 826.00 18.65 80.77 813.20 757.00 -29.69 106.82 6,031,083.27 470,035.55 4.40 -12.46 SRG-SS(1) 1/3/2014 11:40:43AM Page 2 COMPASS 5000.1 Build 61 • S Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) () () (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 869.58 18.60 74.78 854.50 798.30 -26.75 120.41 6,031,086.16 470,049.15 4.39 -7.41 MWD+IFR2+MS+sag(2) 963.07 17.39 71.02 943.42 887.22 -18.29 148.01 6,031,094.50 470,076.78 1.79 5.30 MWD+IFR2+MS+sag(2) 1,058.72 19.12 67.40 1,034.25 978.05 -7.62 175.99 6,031,105.06 470,104.80 2.16 20.25 MWD+IFR2+MS+sag(2) 1,152.91 23.30 66.03 1,122.04 1,065.84 5.88 207.27 6,031,118.43 470,136.13 4.47 38.52 MWD+IFR2+MS+sag(2) 1,248.35 23.63 63.90 1,209.59 1,153.39 21.96 241.69 6,031,134.37 470,170.62 0.95 59.83 MWD+IFR2+MS+sag(2) 1,344.09 27.40 62.46 1,295.98 1,239.78 40.60 278.47 6,031,152.86 470,207.47 3.99 84.04 MWD+IFR2+MS+sag(2) 1,438.02 30.17 62.61 1,378.29 1,322.10 61.45 318.60 6,031,173.55 470,247.68 2.95 110.96 MWD+IFR2+MS+sag(2) 1,534.36 34.72 62.24 1,459.58 1,403.38 85.38 364.40 6,031,197.29 470,293.56 4.73 141.82 MWD+IFR2+MS+sag(2) 1,631.54 37.05 62.23 1,538.30 1,482.11 111.92 414.80 6,031,223.62 470,344.07 2.40 175.98 MWD+IFR2+MS+sag(2) 1,720.15 40.62 60.56 1,607.32 1,551.12 138.54 463.56 6,031,250.04 470,392.93 4.20 209.96 MWD+IFR2+MS+sag(2) 1,820.10 45.03 60.91 1,680.61 1,624.41 171.74 522.82 6,031,283.00 470,452.31 4.42 252.09 MWD+IFR2+MS+sag(2) 1,914.58 48.82 59.82 1,745.12 1,688.92 205.87 582.78 6,031,316.89 470,512.41 4.10 295.27 MWD+IFR2+MS+sag(2) 2,009.49 50.66 59.76 1,806.46 1,750.26 242.32 645.37 6,031,353.07 470,575.14 1.94 341.13 MWD+IFR2+MS+sag(2) 2,102.74 54.30 58.88 1,863.24 1,807.04 280.06 708.96 6,031,390.55 470,638.87 3.97 388.43 MWD+IFR2+MS+sag(2) 2,197.98 56.36 56.97 1,917.42 1,861.22 321.66 775.31 6,031,431.88 470,705.39 2.72 439.99 MWD+IFR2+MS+sag(2) 2,292.47 60.95 56.30 1,966.56 1,910.36 366.04 842.69 6,031,475.98 470,772.94 4.90 494.44 MWD+IFR2+MS+sag(2) 2,388.44 63.76 55.08 2,011.08 1,954.88 413.97 912.89 6,031,523.62 470,843.33 3.14 552.85 MWD+IFR2+MS+sag(2) 2,478.79 62.44 54.45 2,051.96 1,995.76 460.45 978.70 6,031,569.83 470,909.32 1.59 609.13 MWD+IFR2+MS+sag(2) 2,575.73 60.97 54.91 2,097.91 2,041.71 509.80 1,048.35 6,031,618.89 470,979.16 1.57 668.85 MWD+IFR2+MS+sag(2) 2,669.09 62.10 56.14 2,142.41 2,086.21 556.25 1,116.01 6,031,665.07 471,047.00 1.68 725.40 MWD+IFR2+MS+sag(2) 2,764.66 59.41 57.01 2,189.10 2,132.90 602.19 1,185.59 6,031,710.72 471,116.76 2.92 781.74 MWD+IFR2+MS+sag(2) 2,861.03 58.61 57.19 2,238.71 2,182.51 647.06 1,254.95 6,031,755.30 471,186.30 0.85 837.00 MWD+IFR2+MS+sag(2) 2,954.24 59.42 54.32 2,286.71 2,230.51 692.03 1,320.99 6,031,800.00 471,252.51 2.78 891.82 MWD+IFR2+MS+sag(2) 3,049.93 62.15 54.54 2,333.41 2,277.21 740.60 1,388.92 6,031,848.29 471,320.63 2.86 950.51 MWD+IFR2+MS+sag(2) 3,144.85 63.31 56.29 2,376.90 2,320.70 788.48 1,458.38 6,031,895.89 471,390.28 2.04 1,008.76 MWD+IFR2+MS+sag(2) 3,239.88 61.43 57.06 2,420.97 2,364.77 834.74 1,528.72 6,031,941.86 471,460.80 2.10 1,065.53 MWD+IFR2+MS+sag(2) 3,335.69 64.95 58.76 2,464.18 2,407.98 880.14 1,601.17 6,031,986.96 471,533.41 4.00 1,121.80 MWD+IFR2+MS+sag(2) 3,429.55 64.27 59.67 2,504.43 2,448.23 923.54 1,674.01 6,032,030.06 471,606.43 1.14 1,176.15 MWD+IFR2+MS+sag(2) 3,524.98 64.50 60.19 2,545.68 2,489.48 966.66 1,748.48 6,032,072.87 471,681.06 0.55 1,230.48 MWD+IFR2+MS+sag(2) 3,619.98 63.78 61.17 2,587.12 2,530.92 1,008.52 1,823.01 6,032,114.43 471,755.76 1.20 1,283.58 MWD+IFR2+MS+sag(2) 3,715.39 63.48 61.08 2,629.50 2,573.30 1,049.80 1,897.87 6,032,155.40 471,830.77 0.33 1,336.15 MWD+IFR2+MS+sag(2) 3,810.21 64.76 59.29 2,670.89 2,614.69 1,092.22 1,971.88 6,032,197.52 471,904.94 2.17 1,389.72 MWD+IFR2+MS+sag(2) 3,904.86 65.14 59.24 2,710.96 2,654.76 1,136.04 2,045.58 6,032,241.04 471,978.81 0.40 1,444.63 MWD+IFR2+MS+sag(2) 4,000.82 66.53 58.87 2,750.24 2,694.04 1,181.06 2,120.67 6,032,285.75 472,054.08 1.49 1,500.93 MWD+IFR2+MS+sag(2) 4,096.11 66.20 56.40 2,788.45 2,732.25 1,227.79 2,194.39 6,032,332.17 472,127.99 2.40 1,558.70 MWD+IFR2+MS+sag(2) 4,190.77 64.62 56.50 2,827.84 2,771.64 1,275.36 2,266.13 6,032,379.44 472,199.90 1.67 1,617.00 MWD+IFR2+MS+sag(2) 4,285.93 61.50 57.77 2,870.95 2,814.75 1,321.39 2,337.37 6,032,425.19 472,271.32 3.49 1,673.70 MWD+IFR2+MS+sag(2) 4,382.06 62.50 58.30 2,916.08 2,859.88 1,366.33 2,409.37 6,032,469.82 472,343.50 1.15 1,729.44 MWD+IFR2+MS+sag(2) 4,476.82 63.81 58.66 2,958.87 2,902.67 1,410.53 2,481.45 6,032,513.73 472,415.75 1.42 1,784.46 MWD+IFR2+MS+sag(2) 4,572.11 62.87 57.51 3,001.63 2,945.43 1,455.54 2,553.73 6,032,558.45 472,488.20 1.46 1,840.31 MWD+IFR2+MS+sag(2) 1/3/2014 11:40:43AM Page 3 COMPASS 5000.1 Build 61 • • Pioneer Natural Resources Definitive Survey Report Company: Weil Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nt-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I1001 (ft) Survey Tool Name 4,667.21 63.25 57.47 3,044.71 2,988.51 1,501.11 2,625.23 6,032,603.72 472,559.88 0.40 1,896.59 MWD+IFR2+MS+sag(2) 4,762.03 62.08 56.19 3,088.25 3,032.05 1,547.19 2,695.73 6,032,649.51 472,630.56 1.72 1,953.22 MWD+IFR2+MS+sag(2) 4,857.07 61.47 56.72 3,133.20 3,077.00 1,593.46 2,765.52 6,032,695.49 472,700.53 0.81 2,009.93 MWD+IFR2+MS+sag(2) 4,952.91 61.78 57.10 3,178.75 3,122.55 1,639.50 2,836.17 6,032,741.24 472,771.36 0.48 2,066.54 MWD+IFR2+MS+sag(2) 5,045.42 61.61 57.77 3,222.61 3,166.41 1,683.34 2,904.81 6,032,784.80 472,840.17 0.66 2,120.66 MWD+IFR2+MS+sag(2) 5,140.64 62.49 57.88 3,267.24 3,211.04 1,728.13 2,976.01 6,032,829.29 472,911.54 0.93 2,176.13 MWD+IFR2+MS+sag(2) 5,237.31 63.33 58.02 3,311.27 3,255.07 1,773.80 3,048.96 6,032,874.66 472,984.66 0.88 2,232.74 MWD+IFR2+MS+sag(2) 5,331.89 62.17 58.50 3,354.57 3,298.37 1,818.03 3,120.46 6,032,918.60 473,056.34 1.31 2,287.70 MWD+IFR2+MS+sag(2) 5,426.11 63.08 58.75 3,397.89 3,341.69 1,861.59 3,191.90 6,032,961.87 473,127.94 0.99 2,341.99 MWD+IFR2+MS+sag(2) 5,508.18 63.80 58.77 3,434.59 3,378.39 1,899.66 3,254.66 6,032,999.68 473,190.86 0.88 2,389.49 MWD+IFR2+MS+sag(2) 5,558.11 64.39 55.61 3,456.41 3,400.21 1,924.00 3,292.40 6,033,023.86 473,228.69 5.81 2,419.47 MWD+IFR2+MS+sag(3) 5,653.18 63.93 58.28 3,497.85 3,441.65 1,970.67 3,364.10 6,033,070.24 473,300.58 2.57 2,476.87 MWD+IFR2+MS+sag(3) 5,746.81 62.76 58.66 3,539.85 3,483.65 2,014.43 3,435.43 6,033,113.70 473,372.07 1.30 2,531.34 MWD+IFR2+MS+sag(3) 5,842.84 62.69 57.85 3,583.86 3,527.66 2,059.33 3,508.01 6,033,158.31 473,444.83 0.75 2,587.14 MWD+IFR2+MS+sag(3) 5,938.43 62.37 57.14 3,627.96 3,571.76 2,104.91 3,579.54 6,033,203.59 473,516.53 0.74 2,643.43 MWD+IFR2+MS+sag(3) 6,033.93 62.02 58.06 3,672.50 3,616.30 2,150.17 3,650.86 6,033,248.56 473,588.03 0.93 2,699.38 MWD+IFR2+MS+sag(3) 6,127.16 62.31 59.46 3,716.04 3,659.84 2,192.92 3,721.35 6,033,291.03 473,658.68 1.36 2,752.72 MWD+IFR2+MS+sag(3) 6,221.98 62.51 59.83 3,759.95 3,703.75 2,235.39 3,793.86 6,033,333.20 473,731.36 0.41 2,806.10 MWD+IFR2+MS+sag(3) 6,318.33 62.64 61.73 3,804.33 3,748.13 2,277.14 3,868.50 6,033,374.64 473,806.15 1.76 2,859.10 MWD+IFR2+MS+sag(3) 6,412.86 62.77 62.82 3,847.68 3,791.48 2,316.22 3,942.86 6,033,413.41 473,880,66 1.03 2,909.43 MWD+IFR2+MS+sag(3) 6,507.91 63.08 60.87 3,890.95 3,834.75 2,356.15 4,017.47 6,033,453.04 473,955.43 1.86 2,960.64 MWD+IFR2+MS+sag(3) , 6,602.94 63.07 60.86 3,933.98 3,877.78 2,397.40 4,091.48 6,033,493.99 474,029.60 0.01 3,013.05 MWD+IFR2+MS+sag(3) 6,697.95 63.13 59.58 3,976.97 3,920.77 2,439.49 4,165.02 6,033,535.77 474,103.30 1.20 3,066.21 MWD+IFR2+MS+sag(3) 6,793.17 63.12 58.25 4,020.01 3,963.81 2,483.34 4,237.75 6,033,579.32 474,176.20 1.25 3,120.99 MWD+IFR2+MS+sag(3) 6,888.29 63.00 57.59 4,063.11 4,006.91 2,528.37 4,309.60 6,033,624.06 474,248.23 0.63 3,176.80 MWD+IFR2+MS+sag(3) 6,983.26 62.71 57.93 4,106.44 4,050.24 2,573.46 4,381.08 6,033,668.85 474,319.88 0.44 3,232.60 MWD+IFR2+MS+sag(3) 7,078.48 62.57 57.18 4,150.20 4,094.00 2,618.83 4,452.45 6,033,713.93 474,391.42 0.71 3,288.67 MWD+IFR2+MS+sag(3) 7,173.18 62.44 56.74 4,193,92 4,137.72 2,664.63 4,522.87 6,033,759.44 474,462.02 0.43 3,345.01 MWD+IFR2+MS+sag(3) 7,266.95 62.42 56.54 4,237.32 4,181.12 2,710.34 4,592.29 6,033,804.86 474,531.63 0.19 3,401.10 MWD+IFR2+MS+sag(3) 7,362.35 62.17 56.60 4,281.67 4,225.47 2,756.87 4,662.78 6,033,851.10 474,602.30 0.27 3,458.17 MWD+IFR2+MS+sag(3) 7,457.02 62.24 57.75 4,325.82 4,269.62 2,802.26 4,733.16 6,033,896.21 474,672.84 1.08 3,514.10 MWD+IFR2+MS+sag(3) 7,552.70 62.38 56.96 4,370.28 4,314.08 2,847.96 4,804.49 6,033,941.62 474,744.36 0.75 3,570.49 MWD+IFR2+MS+sag(3) 7,646.98 62.65 57.42 4,413.79 4,357.59 2,893.28 4,874.79 6,033,986.65 474,814.83 0.52 3,626.34 MWD+IFR2+MS+sag(3) 7,741.81 62.73 57.02 4,457.30 4,401.10 2,938.90 4,945.63 6,034,031.97 474,885.85 0.38 3,682.56 MWD+IFR2+MS+sag(3) 7,837.31 62.87 55.74 4,500.96 4,444.76 2,985.93 5,016.36 6,034,078.71 474,956.76 1.20 3,740.16 MWD+IFR2+MS+sag(3) 7,933.93 62.95 56.57 4,544.96 4,488.76 3,033.84 5,087.80 6,034,126.32 475,028.39 0.77 3,798.75 MWD+IFR2+MS+sag(3) 8,028.01 63.27 56.34 4,587.51 4,531.31 3,080.21 5,157.74 6,034,172.40 475,098.50 0.40 3,855.57 MWD+IFR2+MS+sag(3) 8,122.18 63.40 57.72 4,629.77 4,573.57 3,126.00 5,228.34 6,034,217.91 475,169.28 1.32 3,911.93 MWD+IFR2+MS+sag(3) 8,218.06 63.47 55.54 4,672.65 4,616.45 3,173.17 5,299.95 6,034,264.78 475,241.08 2.03 3,969.81 MWD+IFR2+MS+sag(3) 8,311.57 63.30 56.39 4,714.55 4,658.35 3,219.96 5,369.23 6,034,311.29 475,310.54 0.83 4,026.95 MWD+IFR2+MS+sag(3) 1/3/2014 11:40:43AM Page 4 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development ND Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1001 (ft) Survey Tool Name 8,406.95 63.27 57.30 4,757.42 4,701.22 3,266.56 5,440.56 6,034,357.59 475,382.05 0.85 4,084.21 MWD+IFR2+MS+sag(3) 8,501.96 63.35 57.11 4,800.10 4,743.90 3,312.53 5,511.91 6,034,403.27 475,453.58 0.20 4,140.88 MWD+IFR2+MS+sag(3) 8,597.00 63.05 57.46 4,842.95 4,786.75 3,358.38 5,583.29 6,034,448.83 475,525.13 0.46 4,197.41 MWD+IFR2+MS+sag(3) 8,692.43 62.92 57.88 4,886.30 4,830.10 3,403.85 5,655.12 6,034,494.00 475,597.15 0.42 4,253.65 MWD+IFR2+MS+sag(3) 8,787.54 62.83 58.76 4,929.66 4,873.46 3,448.30 5,727.16 6,034,538.16 475,669.35 0.83 4,308.91 MWD+IFR2+MS+sag(3) 8,883.31 62.86 57.29 4,973.37 4,917.17 3,493.43 5,799.44 6,034,582.98 475,741.81 1.37 4,364.88 MWD+IFR2+MS+sag(3) 8,978.15 62.55 58.37 5,016.87 4,960.67 3,538.30 5,870.78 6,034,627.56 475,813.32 1.06 4,420.45 MWD+IFR2+MS+sag(3) 9,073.73 62.23 58.24 5,061.16 5,004.96 3,582.80 5,942.84 6,034,671.77 475,885.56 0.36 4,475.76 MWD+IFR2+MS+sag(3) 9,168.46 62.39 58.21 5,105.18 5,048.98 3,626.97 6,014.15 6,034,715.64 475,957.04 0.17 4,530.63 MWD+IFR2+MS+sag(3) 9,263.28 62.22 58.99 5,149.25 5,093.05 3,670.71 6,085.81 6,034,759.09 476,028.87 0.75 4,585.14 MWD+IFR2+MS+sag(3) 9,359.16 62.67 59.27 5,193.61 5,137.41 3,714.33 6,158.77 6,034,802.41 476,102.00 0.54 4,639.72 MWD+IFR2+MS+sag(3) 9,453.94 63.13 60.19 5,236.78 5,180.58 3,756.85 6,231.64 6,034,844.63 476,175.03 0.99 4,693.21 MWD+IFR2+MS+sag(3) 9,548.78 63.14 59.44 5,279.64 5,223.44 3,799.39 6,304.78 6,034,886.87 476,248.33 0.71 4,746.76 MWD+IFR2+MS+sag(3) 9,644.53 62.86 59.87 5,323.11 5,266.91 3,842.49 6,378.40 6,034,929.67 476,322.12 0.50 4,800.94 MWD+IFR2+MS+sag(3) 9,740.25 62.72 59.00 5,366.88 5,310.68 3,885.78 6,451.70 6,034,972.66 476,395.59 0.82 4,855.25 MWD+IFR2+MS+sag(3) 9,834.46 62.59 58.10 5,410.15 5,353.95 3,929.44 6,523.09 6,035,016.03 476,467.14 0.86 4,909.63 MWD+IFR2+MS+sag(3) 9,929.75 62.79 55.38 5,453.88 5,397.68 3,975.87 6,593.88 6,035,062.16 476,538.11 2.54 4,966.65 MWD+IFR2+MS+sag(3) 10,024.35 62.72 53.42 5,497.19 5,440.99 4,024.83 6,662.26 6,035,110.84 476,606.69 1.84 5,025.79 MWD+IFR2+MS+sag(3) 10,118.10 62.56 49.48 5,540.29 5,484.09 4,076.70 6,727.36 6,035,162.44 476,671.99 3.74 5,087.28 MWD+IFR2+MS+sag(3) 10,135.09 62.48 49.24 5,548.13 5,491.93 4,086.52 6,738.80 6,035,172.21 476,683.46 1.34 5,098.78 MWD+IFR2+MS+sag(4) 10,186.81 62.59 47.67 5,571.98 5,515.79 4,116.95 6,773.14 6,035,202.50 476,717.93 2.70 5,134.26 MWD+IFR2+MS+sag(4) 10,230.39 62.31 45.68 5,592.14 5,535.94 4,143.46 6,801.25 6,035,228.90 476,746.14 4.10 5,164.87 MWD+IFR2+MS+sag(4) 10,282.00 61.72 42.91 5,616.36 5,560.16 4,176.08 6,833.07 6,035,261.38 476,778.09 4.88 5,202.10 MWD+IFR2+MS+sag(4) 10,327.07 61.19 40.32 5,637.90 5,581.70 4,205.67 6,859.36 6,035,290.86 476,804.50 5.18 5,235.47 MWD+IFR2+MS+sag(4) 10,376.12 62.02 38.83 5,661.23 5,605.03 4,238.93 6,886.85 6,035,324.01 476,832.12 3.16 5,272.65 MWD+IFR2+MS+sag(4) 10,419.68 62.36 37.18 5,681.55 5,625.35 4,269.29 6,910.57 6,035,354.27 476,855.96 3.44 5,306.37 MWD+IFR2+MS+sag(4) 10,470.62 61.84 34.15 5,705.39 5,649.19 4,305.85 6,936.82 6,035,390.72 476,882.35 5.35 5,346.62 MWD+IFR2+MS+sag(4) 10,515.76 61.14 31.76 5,726.94 5,670.74 4,339.13 6,958.40 6,035,423.91 476,904.06 4.90 5,382.89 MWD+IFR2+MS+sag(4) 10,565.11 61.31 29.96 5,750.70 5,694.50 4,376.26 6,980.58 6,035,460.95 476,926.40 3.22 5,423.05 MWD+IFR2+MS+sag(4) 10,611.76 61.62 27.60 5,772.99 5,716.79 4,412.18 7,000.31 6,035,496.78 476,946.27 4.49 5,461.63 MWD+IFR2+MS+sag(4) 10,661.71 62.20 25.92 5,796.51 5,740.31 4,451.53 7,020.15 6,035,536.04 476,966.26 3.19 5,503.62 MWD+IFR2+MS+sag(4) 10,706.63 62.86 24.00 5,817.23 5,761.03 4,487.66 7,036.96 6,035,572.10 476,983.22 4.07 5,541.95 MWD+IFR2+MS+sag(4) 10,756.67 63.08 22.10 5,839.97 5,783.77 4,528.67 7,054.41 6,035,613.04 477,000.84 3.41 5,585.20 MWD+IFR2+MS+sag(4) 10,802.02 62.94 19.79 5,860.56 5,804.36 4,566.41 7,068.86 6,035,650.71 477,015.43 4.55 5,624.74 MWD+IFR2+MS+sag(4) 10,851.48 63.34 17.85 5,882.90 5,826.70 4,608.17 7,083.09 6,035,692.41 477,029.83 3.59 5,668.23 MWD+IFR2+MS+sag(4) 10,897.31 63.17 15.99 5,903.53 5,847.33 4,647.32 7,095.00 6,035,731.51 477,041.90 3.64 5,708.77 MWD+IFR2+MS+sag(4) 10,990.67 63.33 13.03 5,945.56 5,889.36 4,728.02 7,115.89 6,035,812.12 477,063.11 2.84 5,791.75 MWD+IFR2+MS+sag(4) 11,086.03 65.06 8.18 5,987.09 5,930.89 4,812.37 7,131.65 6,035,896.40 477,079.21 4.92 5,877.54 MWD+IFR2+MS+sag(4) 11,181.39 66.34 3.65 6,026.35 5,970.15 4,898.79 7,140.59 6,035,982.77 477,088.50 4.53 5,964.28 MWD+IFR2+MS+sag(4) 11,276.50 67.45 359.70 6,063.68 6,007.48 4,986.21 7,143.13 6,036,070.17 477,091.40 3.99 6,051.01 MWD+IFR2+MS+sag(4) 1/3/2014 11:40:43AM Page 5 COMPASS 5000.1 Build 61 • • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development ND Reference: 42.7+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting OLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 01001 (ft) Survey Tool Name 11,373.01 68.55 356.14 6,099.84 6,043.64 5,075.61 7,139.87 6,036,159.58 477,088.50 3.60 6,138.78 MWD+IFR2+MS+sag(4) 11,467.35 69.56 352.76 6,133.58 6,077.38 5,163.29 7,131.35 6,036,247.28 477,080.33 3.51 6,224.01 MWD+IFR2+MS+sag(4) 11,561.98 71.38 349.09 6,165.22 6,109.02 5,251.33 7,117.27 6,036,335.37 477,066.61 4.13 6,308.73 MWD+IFR2+MS+sag(4) 11,655.82 73.08 345.31 6,193.87 6,137.67 5,338.45 7,097.46 6,036,422.56 477,047.15 4.24 6,391.63 MWD+IFR2+MS+sag(4) 11,751.29 75.00 341.05 6,220.13 6,163.93 5,426.28 7,070.89 6,036,510.49 477,020.94 4.74 6,474.16 MWD+IFR2+MS+sag(4) 11,846.91 75.32 336.58 6,244.63 6,188.43 5,512.44 7,037.50 6,036,596.77 476,987.90 4.53 6,553.97 MWD+IFR2+MS+sag(4) 11,941.00 76.90 330.80 6,267.23 6,211.03 5,594.27 6,997.02 6,036,678.75 476,947.76 6.19 6,628.39 MWD+IFR2+MS+sag(4) 12,037.28 79.50 325.98 6,286.93 6,230.73 5,674.49 6,947.62 6,036,759.17 476,898.69 5.59 6,699.81 MWD+IFR2+MS+sag(4) 12,132.12 81.12 322.59 6,302.90 6,246.70 5,750.37 6,893.06 6,036,835.26 476,844.44 3.92 6,766.13 MWD+IFR2+MS+sag(4) 12,227.80 82.87 321.25 6,316.22 6,260.02 5,824.95 6,834.62 6,036,910.07 476,786.31 2.30 6,830.55 MWD+IFR2+MS+sag(4) 12,322.87 85.16 320.44 6,326.14 6,269.94 5,898.26 6,774.92 6,036,983.61 476,726.92 2.55 6,893.52 MWD+IFR2+MS+sag(4) 12,417.58 85.53 320.50 6,333.82 6,277.62 5,971.07 6,714.84 6,037,056.66 476,667.13 0.40 6,955.94 MWD+IFR2+MS+sag(4) 12,511.06 85.53 320.85 6,341.11 6,284.91 6,043.16 6,655.78 6,037,128.98 476,608.37 0.37 7,017.81 MWD+IFR2+MS+sag(4) 12,606.17 85.72 320.44 6,348.36 6,292.16 6,116.49 6,595.65 6,037,202.54 476,548.54 0.47 7,080.72 MWD+IFR2+MS+sag(4) 12,701.63 86.28 320.10 6,355.02 6,298.82 6,189.72 6,534.78 6,037,276.02 476,487.98 0.69 7,143.44 MWD+IFR2+MS+sag(4) 12,749.74 87.64 319.14 6,357.57 6,301.37 6,226.32 6,503.66 6,037,312.74 476,457.00 3.46 7,174.66 MWD+IFR2+MS+sag(4) 12,773.00 88.48 319.17 6,358.36 6,302.16 6,243.91 6,488.45 6,037,330.38 476,441.87 3.61 7,189.63 MWD+IFR2+MS+sag(5) 12,869.95 89.47 320.49 6,360.10 6,303.90 6,317.97 6,425.93 6,037,404.69 476,379.65 1.70 7,252.90 MWD+IFR2+MS+sag(5) 12,966.50 88.54 317.58 6,361.77 6,305.57 6,390.86 6,362.65 6,037,477.83 476,316.67 3.16 7,314.89 MWD+IFR2+MS+sag(5) 13,062.81 88.85 317.84 6,363.97 6,307.77 6,462.09 6,297.86 6,037,549.31 476,252.18 0.42 7,375.00 MWD+IFR2+MS+sag(5) 13,158.57 89.29 316.90 6,365.52 6,309.32 6,532.53 6,233.01 6,037,620.01 476,187.63 1.08 7,434.32 MWD+IFR2+MS+sag(5) 13,255.39 89.66 318.21 6,366.41 6,310.21 6,603.97 6,167.67 6,037,691.71 476,122.59 1.41 7,494.56 MWD+IFR2+MS+sag(5) 13,351.75 89.84 317.45 6,366.83 6,310.63 6,675.39 6,102.99 6,037,763.38 476,058.19 0.81 7,554.87 MWD+IFR2+MS+sag(5) 13,448.75 89.88 318.20 6,367.07 6,310.87 6,747.28 6,037.86 6,037,835.52 475,993.37 0.77 7,615.58 MWD+IFR2+MS+sag(5) 13,544.95 89.57 316.17 6,367.53 6,311.33 6,817.84 5,972.48 6,037,906.34 475,928.28 2.13 7,674.94 MWD+IFR2+MS+sag(5) 13,641.08 90.40 317.83 6,367.55 6,311.35 6,888.14 5,906.93 6,037,976.90 475,863.02 1.93 7,734.02 MWD+IFR2+MS+sag(5) 13,737.01 90.77 318.36 6,366.57 6,310.37 6,959.53 5,842.86 6,038,048.54 475,799.24 0.67 7,794.40 MWD+IFR2+MS+sag(5) 13,831.84 89.35 317.58 6,366.47 6,310.27 7,029.97 5,779.37 6,038,119.23 475,736.05 1.71 7,853.94 MWD+IFR2+MS+sag(5) 13,930.56 89.53 316:04 6,367.44 6,311.24 7,101.94 5,711.81 6,038,191.46 475,668.79 1.57 7,914.34 MWD+IFR2+MS+sag(5) 14,026.93 90.89 317.52 6,367.08 6,310.89 7,172.16 5,645.82 6,038,261.95 475,603.09 2.09 7,973.27 MWD+IFR2+MS+sag(5) 14,123.21 91.57 318.11 6,365.02 6,308.82 7,243.49 5,581.18 6,038,333.52 475,538.74 0.93 8,033.50 MWD+IFR2+MS+sag(5) 14,219.30 91.36 317.84 6,362.56 6,306.36 7,314.84 5,516.87 6,038,405.13 475,474.73 0.36 8,093.82 MWD+IFR2+MS+sag(5) 14,316.91 90.95 316.25 6,360.59 6,304.39 7,386.27 5,450.38 6,038,476.82 475,408.53 1.68 8,153.85 MWD+IFR2+MS+sag(5) 14,412.45 91.20 316.50 6,358.80 6,302.60 7,455.41 5,384.47 6,038,546.22 475,342.91 0.37 8,211.73 MWD+IFR2+MS+sag(5) 14,507.74 91.39 316.13 6,356.65 6,300.45 7,524.30 5,318.67 6,038,615.37 475,277.40 0.44 8,269.37 MWD+IFR2+MS+sag(5) 14,605.41 90.89 314.66 6,354.70 6,298.50 7,593.83 5,250.10 6,038,685.17 475,209.12 1.59 8,327.20 MWD+IFR2+MS+sag(5) 14,700.78 90.09 315.26 6,353.89 6,297.69 7,661.21 5,182.62 6,038,752.82 475,141.92 1.05 8,383.10 MWD+IFR2+MS+sag(5) 14,796.96 88.67 315.00 6,354.93 6,298.73 7,729.37 5,114.77 6,038,821.24 475,074.35 1.50 8,439.69 MWD+IFR2+MS+sag(5) 14,893.14 89.66 315.82 6,356.33 6,300.13 7,797.86 5,047.26 6,038,889.99 475,007.12 1.34 8,496.67 MWD+IFR2+MS+sag(5) 14,990.39 90.03 316.77 6,356.59 6,300.39 7,868.16 4,980.07 6,038,960.56 474,940.22 1.05 8,555.48 MWD+IFR2+MS+sag(5) 1/3/2014 11:40:43AM Page 6 COMPASS 5000.1 Build 61 • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development ND Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +Ei-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 15,085.78 89.59 317.21 6,356.91 6,300.71 7,937.91 4,915.00 6,039,030.57 474,875.44 0.65 8,614.09 MWD+IFR2+MS+sag(5) 15,181.10 90.86 320.02 6,356.54 6,300.34 8,009.42 4,851.99 6,039,102.32 474,812.73 3.23 8,674.76 MWD+IFR2+MS+sag(5) 15,279.73 90.21 319.21 6,355.62 6,299.42 8,084.54 4,788.09 6,039,177.70 474,749.14 1.05 8,738.86 MWD+IFR2+MS+sag(5) 15,374.65 90.15 321.82 6,355.32 6,299.12 8,157.79 4,727.74 6,039,251.18 474,689.09 2.75 8,801.67 MWD+IFR2+MS+sag(5) 15,470.42 89.97 319.92 6,355.22 6,299.02 8,232.08 4,667.30 6,039,325.71 474,628.96 1.99 8,865.48 MWD+IFR2+MS+sag(5) 15,565.80 90.40 319.45 6,354.91 6,298.71 8,304.81 4,605.59 6,039,398.68 474,567.55 0.67 8,927.56 MWD+IFR2+MS+sag(5) 15,661.86 90.71 319.99 6,353.98 6,297.78 8,378.08 4,543.49 6,039,472.20 474,505.75 0.65 8,990.12 MWD+IFR2+MS+sag(5) 15,760.65 89.97 320.19 6,353.39 6,297.19 8,453.86 4,480.11 6,039,548.22 474,442.69 0.78 9,054.95 MWD+IFR2+MS+sag(5) 15,854.61 89.66 319.27 6,353.70 6,297.50 8,525.55 4,419.38 6,039,620.15 474,382.25 1.03 9,116.15 MWD+IFR2+MS+sag(5) 15,951.17 90.09 318.55 6,353.91 6,297.71 8,598.33 4,355.91 6,039,693.17 474,319.09 0.87 9,178.00 MWD+IFR2+MS+sag(5) 16,047.43 90.93 317.92 6,353.05 6,296.85 8,670.12 4,291.80 6,039,765.22 474,255.27 1.09 9,238.78 MWD+IFR2+MS+sag(5) 16,143.68 91.08 316.77 6,351.36 6,295.16 8,740.89 4,226.59 6,039,836.25 474,190.36 1.20 9,298.38 MWD+IFR2+MS+sag(5) 16,241.35 91.51 316.08 6,349.15 6,292.95 8,811.64 4,159.29 6,039,907.26 474,123.34 0.83 9,357.61 MWD+IFR2+MS+sag(5) 16,336.99 91.82 315.94 6,346.37 6,290.18 8,880.42 4,092.89 6,039,976.30 474,057.23 0.36 9,415.05 MWD+IFR2+MS+sag(5) 16,433.71 91.39 317.59 6,343.67 6,287.47 8,950.85 4,026.67 6,040,046.99 473,991.30 1.76 9,474.15 MWD+IFR2+MS+sag(5) 16,531.06 89.29 317.00 6,343.09 6,286.89 9,022.38 3,960.65 6,040,118.79 473,925.58 2.24 9,534.37 MWD+IFR2+MS+sag(5) 16,626.60 90.03 317.66 6,343.66 6,287.46 9,092.63 3,895.89 6,040,189.29 473,861.12 1.04 9,593.51 MWD+IFR2+MS+sag(5) 16,722.84 90.40 318.00 6,343.29 6,287.09 9,163.96 3,831.28 6,040,260.87 473,796.80 0.52 9,653.75 MWD+IFR2+MS+sag(5) 16,818.92 90.77 317.26 6,342.31 6,286.11 9,234.94 3,766.54 6,040,332.10 473,732.35 0.86 9,713.62 MWD+IFR2+MS+sag(5) 16,915.51 90.83 316.93 6,340.96 6,284.76 9,305.68 3,700.79 6,040,403.10 473,666.89 0.35 9,773.11 MWD+IFR2+MS+sag(5) 17,012.87 88.67 316.86 6,341.39 6,285.19 9,376.76 3,634.26 6,040,474.44 473,600.66 2.22 9,832.79 MWD+IFR2+MS+sag(5) 17,109.45 88.98 317.21 6,343.37 6,287.17 9,447.42 3,568.45 6,040,545.36 473,535.15 0.48 9,892.18 MWD+IFR2+MS+sag(5) 17,162.75 89.47 316.38 6,344.09 6,287.89 9,486.27 3,531.97 6,040,584.35 473,498.82 1.81 9,924.78 MWD+IFR2+MS+sag(5) 17,205.62 91.45 315.92 6,343.75 6,287.55 9,517.18 3,502.27 6,040,615.38 473,469.25 4.74 9,950.62 MWD+IFR2+MS+sag(5) 17,301.71 91.26 315.79 6,341.47 6,285.27 9,586.11 3,435.36 6,040,684.58 473,402.63 0.24 10,008.13 MWD+IFR2+MS+sag(5) 17,397.33 90.52 316.78 6,339.99 6,283.79 9,655.21 3,369.29 6,040,753.94 473,336.85 1.29 10,065.94 MWD+IFR2+MS+sag(5) 17,445.80 88.54 314.71 6,340.39 6,284.19 9,689.93 3,335.47 6,040,788.79 473,303.17 5.91 10,094.88 MWD+1FR2+MS+sag(5) 17,494.60 87.68 314.77 6,342.00 6,285.80 9,724.26 3,300.83 6,040,823.25 473,268.67 1.77 10,123.32 MWD+IFR2+MS+sag(5) 17,590.85 89.04 316.17 6,344.75 6,288.55 9,792.84 3,233.36 6,040,892.10 473,201.49 2.03 10,180.39 MWD+IFR2+MS+sag(5) 17,686.68 90.27 316.32 6,345.33 6,289.13 9,862.06 3,167.09 6,040,961.58 473,135.50 1.29 10,238.28 MWD+IFR2+MS+sag(5) 17,783.89 90.83 317.77 6,344.39 6,288.19 9,933.20 3,100.86 6,041,032.98 473,069.56 1.60 10,298.08 MWD+IFR2+MS+sag(5) 17,879.60 92.19 318.80 6,341.87 6,285.67 10,004.61 3,037.19 6,041,104.65 473,006.20 1.78 10,358.56 MWD+IFR2+MS+sag(5) 17,977.20 90.46 319.01 6,339.62 6,283.42 10,078.15 2,973.06 6,041,178.43 472,942.37 1.79 10,421.04 MWD+IFR2+MS+sag(5) 18,073.14 89.90 318.91 6,339.31 6,283.11 10,150.51 2,910.07 6,041,251.04 472,879.67 0.59 10,482.56 MWD+IFR2+MS+sag(5) 18,169.25 90.89 319.19 6,338.65 6,282.45 10,223.10 2,847.08 6,041,323.87 472,816.99 1.07 10,544.30 MWD+IFR2+MS+sag(5) 18,265.44 90.21 318.31 6,337.73 6,281.53 10,295.41 2,783.66 6,041,396.44 472,753.87 1.16 10,605.70 MWD+IFR2+MS+sag(5) 18,362.71 90.58 318.25 6,337.06 6,280.86 10,368.01 2,718.93 6,041,469.29 472,689.44 0.39 10,667.17 MWD+IFR2+MS+sag(5) 18,457.25 89.90 316.73 6,336.66 6,280.46 10,437.70 2,655.05 6,041,539.23 472,625.84 1.76 10,725.91 MWD+IFR2+MS+sag(5) 18,554.92 90.71 317.13 6,336.14 6,279.94 10,509.05 2,588.35 6,041,610.84 472,559.44 0.92 10,785.83 MWD+IFR2+MS+sag(5) 18,650.73 91.14 316.56 6,334.59 6,278.40 10,578.93 2,522.83 6,041,680.98 472,494.21 0.75 10,844.50 MWD+IFR2+MS+sag(5) 1/3/2014 11:40:43AM Page 7 COMPASS 5000.1 Build 61 • • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development ND Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting OLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 18,712.21 87.00 316.57 6,335.59 6,279.39 10,623.56 2,480.57 6,041,725.78 472,452.14 6.73 10,881.90 MWD+IFR2+MS+sag(5) 18,747.24 87.06 317.60 6,337.41 6,281.21 10,649.18 2,456.75 6,041,751.49 472,428.43 2.94 10,903.44 MWD+IFR2+MS+sag(5) 18,841.39 85.30 317.21 6,343.68 6,287.48 10,718.33 2,393.18 6,041,820.89 472,365.14 1.91 10,961.70 MWD+IFR2+MS+sag(5) 18,938.10 85.58 317.28 6,351.37 6,295.17 10,789.12 2,327.73 6,041,891.94 472,299.99 0.30 11,021.27 MWD+IFR2+MS+sag(5) 19,027.99 86.01 317.20 6,357.96 6,301.76 10,854.94 2,266.87 6,041,958.00 472,239.39 0.49 11,076.66 MWD+IFR2+MS+sag(5) 19,124.02 85.51 317.82 6,365.06 6,308.86 10,925.56 2,202.18 6,042,028.87 472,175.00 0.83 11,136.18 MWD+IFR2+MS+sag(5) 19,219.58 86.88 318.28 6,371.40 6,315.20 10,996.47 2,138.44 6,042,100.03 472,111.56 1.51 11,196.15 MWD+IFR2+MS+sag(5) 19,329.00 86.88 318.28 6,377.36 6,321.16 11,078.02 2,065.73 6,042,181.87 472,039.18 0.00 11,265.20 PROJECTED to TD 1/3/2014 11:40:43AM Page 8 COMPASS 5000.1 Build 61 ... _..._..__.. O�o�un�l� ©tsw-2$ PFJ ZI3 i43 Regg, James B (DOA) From: Keith Lopez <Keith.Lopez@caelusenergy.com> b/SI+� Sent: Thursday, June 04, 2015 8:55 AM To: Regg, James B (DOA) Cc: David Hart; Oooguruk ProdSuper; Gary Ross; Keith Lopez Subject: ODSN-28 (PTD 2131480) OA Operating Limit Exceeded Attachments: 150601 N28 OA Pressure Excursion.pptx Mr. Regg, On June 1st, 2015 the OA pressure on ODSN-28 (free flowing producer) exceeded the 1,000 psi operating limit for 21 minutes to a maximum of 1025 psi before being bled down. The increase in pressure was caused by thermal expansion of diesel as we were increasing the flow rate of the well from 1,200 bopd to 3,700 bopd. This was confirmed by bleeding 1.8 barrels of diesel to reduce the OA pressure. Attached are the TxIAxOA trends. This well has a known IAxOA leak to gas and we recently replaced an orifice with a leaking check valve in the tubing string. As you can see from the plots, there are no tubing integrity concerns and since we loaded both the IA and OA with fluid during the SL work they have been holding a differential with no signs that there is a leak to fluid. The well is now flowing stable at 3,700 bopd and the OA pressure has stabilized. We are currently investigating what failed in our process between alarm, alarm acknowledgement, communicating alarm, and operator bleeding the OA. We will pass along the results of the investigation. Please let me know if you need any additional information. Thanks. Keith Lopez SCANNED JUL 0 22015 Production Engineer, Subsurface Direct 907.343.2142 I Cell 907.903.5432 Caelus Energy Alaska 3700 Centerpoint Dr I Ste 500 I Anchorage, AK 99503 Keith.Lopez@caelusenergy.com I www.CaelusEnergy.com +� CAE LI. S 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. r ry u, • M. CA N 4 N n ifA v N E. .1--I i7 v A v r E A �i ,n m ,() M Ol Ol J _ — x i o v r,+ o o ,> a N .-, r, > N C6 ,n Q A O ; N CU aJ H X X W a) 1 § § § § - $ ,. OS8gg Egggg O Ndi kr>co 0000 00v s 0 _8 etet N N N N M Q LL 0 - NJ � w � � NN N N Q t Ol 01 Ol Of I— ryry N Q % % % C o gg 00 3 M Nr p I _ -.-n Z 0 0 0 0 Z i° 0 4 4616. p )0" jill _� z z z z U, C, u Qlir _ N C 00 H d Q ,4 0+ N J 3• a .Q v YO t t 0) 60) 8 W 03 00 N N N N N ZZZZ Com) ▪ ,, W 0)vA oo. 0 t'siy N'N1 N'N1 C d 2 6. d Z A 1 � ' a000 Wallace, Chris D (DOA) From: Keith Lopez <Keith.Lopez@caelusenergy.com> Sent: Wednesday, April 22, 2015 4:20 PM To: Wallace, Chris D (DOA) Cc: Regg,James B (DOA); David Hart; Keith Lopez Subject: FW: ODSN-04 (PTD 2130370) 8 (PTD 2131480)IAxOA Comm Diagnostics Attachments: image001.png We have conducted the bleed diagnostics on the ODSN-04 and ODSN-28 IAxOA communication. Results below. ODSN-28 OA was bled and built back the ^'650 psi in 6 days. The IA pressure did drop slightly as the OA's pressure was coming back up. The IA was then bled and the OA pressure fell to equalize with it in 2-1/2 days. The OA gas did not test positive for H2S. Over the past couple of weeks we have observed the IA and OA re-pressurizing at a very slow but consistent rate of 10 psi/day. We then conducted diagnostics and monitored the surface lift gas piping and confirmed those closed valves were not leaking by. Our next plan is to get into the well with slickline and remove the orifice valve at 11,287' and replace with a dummy. The most likely case is that we have a leaking check valve in this orifice. This should be completed in the next couple of days. ODSN-04 OA was bled and built back the—650 psi in 28 hours. The IA pressure did drop slightly as the OA's pressure was coming back up. The IA was then bled and the OA pressure fell to equalize with it in 14 hours. Both annuli have remained stable and have not shown any significant pressure increases since bleeding. We do not expect we will need to manage the OA pressure by bleeding until the point that the well requires lift gas. The OA gas did not test positive for H2S. Let me know if you would like any additional information. Keith Lopez APR 2 '7 20 15 ,I Production Engineer, Subsurface Direct 907.343.2142 I Cell 907.903.5432 Caelus Energy Alaska 3700 Centerpoint Dr I Ste 500 I Anchorage, AK 99503 Keith.Lopez@caelusenergy.com I www.CaelusEnergy.com CGCELIJIS From: allace, Chris D (DOA) Sent: We. , I. April 01, 2015 3:17 PM To: 'keith.lopez@cae us- - - •m' Cc: Regg, James B (DOA) Subject: RE: ODSN-04 &28 IAxOA Comm Diagnos 1 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday,April 01, 2015 3:22 PM To: 'keith.lopez@caelusenergy.com' Cc: Regg, James B (DOA) Subject: RE: ODSN-04 (PTD 2130370) &28 (PTD 2131480)IAxOA Comm Diagnostics Attachments: image001.png Keith, Also please include the Permit to Drill (PTD numbers for each well in the subject line—it makes it easier for our crosschecking and filing. I 1.-04 (PTD 2130370) _ ODSN-28 PTD 21314: Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wallace, Chris D (DOA) Sent: Wednesday, April 01, 2015 3:17 PM To: 'keith.lopez@caelusenergy.com' Cc: Regg, James B (DOA) Subject: RE: ODSN-04 &28 IAxOA Comm Diagnostics Keith, Your plans including pressure limits for ODSN-04 and ODSN-28 are approved. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov 1 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Keith Lopez [mailto:Keith.Lopez@caelusenergy.com] Sent: Wednesday, April 01, 2015 10:40 AM To: Regg, James B (DOA) Cc: David Hart; Gary Ross Subject: ODSN-04 &28 IAxOA Comm Diagnostics Mr. Regg, We have two free-flowing producers that we have been watching the IA and OA pressure tracking and would like to conduct some further diagnostics. O DS N-04 We have recognized the IA and OA pressure tracking and conducted bleed diagnostics in November 2014 on the OA. The IA was displaced with lift gas during frac flowback operations in March 2014,though the well is currently free flowing without lift gas. We did not test the OA gas for H2S which would have confirmed that the gas came from the IA. We have not had to bleed the OA or IA to remain under 1,000 psi or 2,000 psi pressure limits respectively. The annuli are currently sitting together at 914 psi with a tubing pressure of 703 psi. ODSN-28 The IA and OA pressures began tracking around November 1St 2014. This is also a free flowing producer without lift gas. We have not conducted any diagnostics at this point and have not had to bleed the OA or IA to remain under 1,000 psi or 2,000 psi pressure limits respectively. The annuli are currently sitting together at 963 psi with a tubing pressure of 632 psi. We would like to do further diagnostics as follows: 1) Bleed the OA down to^'300 psi and test the gas for H2S. Monitor the buildup. 2) Bleed the IA down to^'300 psi and monitor. 3) Review data for future remediation planning. Keith Lopez Production Engineer, Subsurface Direct 907.343.2142 I Cell 907.903.5432 Caelus Energy Alaska 3700 Centerpoint Dr I Ste 500 I Anchorage, AK 99503 Keith.Lopez@caelusenergy.com I www.CaelusEnergv.com CECAELIJS 2 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. 3 RECEIVED STATE OF ALASKA JAN 2 8 Zpy t 4 ALASKA OIL AND GAS CONSERVATION COMMISSION la.WelISgWEoLL COMPLETION OR1eRECOMPLETION eREPORTI AND�r ❑ ❑ ❑ ❑ ❑ ❑ 20MC 25.105 20MC 25.110 Development 0 • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _One Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or pt/, Number 12.Permit to Drill Pioneer Natural Resources Alaska, Inc. Aband.: 1/1/2014 ��./V 213-148 • 3.Address: 700 G Street,Suite 600 6.Date Spudded: Af> a 13.API Number. Anchorage,AK 99501 JJJ5f201'5-- 1/.'7/1 50-703-20676-00-00 ' 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2997'FSL, 1070'FEL, Sec. 11,T13N, R7E,Umiat ' 12/20/2013 • ODSN-28 ' Top of Productive Horizon: 8.KB(ft above MSL): 56.2'. 15.Field/Pool(s): 3952'FSL,4999'FEL,Sec.6,T13N, R8E,Umiat GL(ft above MSL): 13.5' ' Total Depth: 9.Plug Back Depth(MD+TVD): Oooguruk-Nuiqsut Oil Pool • 3516'FSL,4274'FEL,Sec. 36,T14N, R7E,Umiat N/A 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x- 469905.67 Y- 6031136.46 • Zone-Asp 4 A 19,329 MD/6,377 TVD • ADL 355036/ADL 389950/ADL:389958 TPI: x- 476449.52 Y- 6037322.86 Zone-nsp4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 472039.18 Y- 6042181.87 Zone-AsP4 2297'MD/1969"TVD 417497 18.Directional Survey: Yes Q No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/Th/D: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 935 MD/815 TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drili/Lateral Top Window MD/TVD: Gyro,MWD/LWD,DIR,DDSr,DDS,DDS-HCIM,DGR,EWR,PWD,GABI,X-BAT,ALD,CTN,Geo-Tap N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 100.9 X65 Surface 158' Surface _ 158' 24" Driven _ 11-3/4" 60# t eo Surface 5549' Surface 3452' 14-1/2" 760 sx,11.1 ppg PF'L'; BTC-M 700 sx,15.8 ppg Class'G' 9-5/8" 40# HYD 1. 521 5390' 10152' 3382' 5556' 11-3/4" 386 sx, 15.8 ppg Class"G" 7" 26# x-50 BTGM Surface 12762' Surface 6358' 9-1/2" 555 sx, 15.8 ppg Class'G' 4-1/2" 12.6# HYD 521 12445' 19210' 6336' 6371' 6-1/8" Uncemented 24.Open to production or Injection? Yes 2 No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+ND of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MOITVD) Size and Number): 4-1/2", 12.6#, I C-110, Hyd 521 12472' See Attachment,pg.5 If Z//Li. .; 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. See Attachment, pg.4 , '-'314...- Was hydraulic fracturing used during completion? Yes n No n DEPTH INTERVAL TIM) AMOUNT AND KIND OF IVIIi l'EKl1aCUSE'U 2303' Freeze Protect w/150 bbls diesel 2692' Freeze Protect 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 Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑., . 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 . RBC MS MAR 21 2i'LTr Form 10-407 Revised 10/2012 CONTINUED ON REVERSE u Submit originall only G. l'��lc{ 2) VV,`` . /I 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ^! Yes [±1 No • If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 868' • 853' and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1803' 1668' Top West Sak 3275' 2437' Cretaceous Tuffs 4764' 3089' Brookian 2B 7590' 4388' None • Top Torok 9382' 5204' Top HRZ 10777' 5849' Kalubik 11224' 6043' Top Kuparuk C 11340' 6088' BCU 11912' 6261' Top Nuiqsut 12700' 6355' Formation at total depth: 31. List of Attachments: Summary of Daily Drilling Operations,Well Schematic Diagram, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alex Vaughan, 343-2186 Email: alex.vaughanpxd.corn Printed Name: Alex Vau•han Title: Sr. Drilling Engineer Signatur Phone: 343-2186 Date: \f 2,124.1ik. Well Name/Number:OD. Per.- o Drill:213-148 Prepared By:Kimberly Pape,343-2130 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 1b: 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 ODSN-28 Nuiqsut Production Well Completion FINAL 1-13-2014 I No. Upper Completion(All equipment must be no less than 10,000 psi rated) MD(ft) TVD(ft) 1 Tubing Hanger 43 43 I 2 4-K"12.6#/ft C-110 Hydril 521 Tubing 3 434"Halliburton'XXO'SVLN w/3.813""X"profile RTS-8 with single1/4"x 0.049" 2297 1969 s/s control line.Cannon Cross-coupling clamps on every joint 4 4-1A"12.6#/ft C-110 Hydril 521 Tubing 5 4-34"x 1"GLM,KBMG Hydril 521 w/SOV 3306 2451 I 6 4-'/:"12.6#/ftC-110Hydril 521 Tubing 7 HES"X"Nipple 3.813" 3421 2501 i8 VA"12.6#/ftC-110HydriIS21Tubing A9 4h"x 1"GLM,KBMG Hydril 521 w/DV 6603 3934 ?:?:? I ., 16"Conductor 10 4-1/:"12.6#/ft C-110 Hydril 521 Tubing I ••• 11 4h"x 1"GIN,KBMG Hydril 521 w/DV 11287 6068 • € Packer Fluid mix: 12 VA"12.6#/ftC-110Hydri1521Tubing ( i is Inhibited Kill weight 13 HES XN3.813"(3.725"NoGo)-with RHC Plug(Max inclination 68 degrees) 11363 6096 ;;;i Brine 14 4-'/:"12.6#/ftC-110Hydri1521Tubing :. with 20 0'TVD 15 41/2"Halliburton'ROC'Gauge Carrier w/Encapsulated a-line to Surface 12342 6328 °:°:°: FIii:• ,`• 16 4-%"12.6#/ftC-ilOHydril_521Tubing ` {I diesel cap 17 Bullet Seal Assembly with HLB Self-Aligning Mule Shoe 12456 6337 Bottom of Shoe 12472 6338 11 3/4"60#L-80 No. Lower Completion(All equipment must be no less than 10,000 psi rated) MD(ft) TVD(ft) BTC Surface 18 Baker 5-'/,"X7"ZXPLine rTop Packer with 15ft Tie Back extension and Flex Lock Hanger 6336 Casing 5 GL 19 4''A"12.6#/ft C-110 Hydril 521 Liner @ 5,549' MD/ 20 4-14"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers ' X 3,453' TVD Halliburton Swell Packer(4-Y" 13Cr8013.5#Hydril 521)OD 5.85'-(9020 psi Burst/8540 psi 7 cemented to 21 Collapse)9 meter long oil activated element with slide on Volant centralizers pin end 13087 6364 surface Halliburton Swell Packer(4-14" 13Cr80 13.59 Hydril 521)OD 5.85'-(9020 psi Burst/8540 psi 13127 6365 Collapse)9 meter long oil activated element with slide on Volant centralizers pin end • 23 4-14"12.6#/ft C-110 Hydril 521 Liner GL 9-5/8"40# L80 24 Resman Carrier Sub[Job#21847-11-2R05-778/RWS-834] 13274 6367 I Hydril 521 25 HLB 4-1/2"SLHT Ball Actuated Sleeve(3.009 ball/2.95 Seat) 13315 6367 Intermediate 1 26 Re sma n Carrier Sub[Job#21847-11-1 R05-778/RWS-834] 13347 6367 Casing 27 4-h"12.6#/ftC-110 Hydril 521 Liner 28 4-11/:"12.6#/ft Hydril 521-6'Pup with slide on Vol ant centralizers 10,152' MD @ Halliburton Swell Packer(4Y:"Hydril 521)OD 5.85'-9 meter long oil activated element with 29 13467 6367 5,556'TVD slide on Volant centralizers pin end Cemented 500' 30 4-'/"12.6#/ft C-110 Hydril 521 Liner I above shoe 31 ResmanCarrier Sub[Job#21847-10.2R05-777/RWS-833] 13723 6367 32 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.925 ball/2.867 Seat) 13764 6366 33 Resman Carrier Sub[Job#21847-10-1 ROS-777/RWS-8331 13796 6366 34 4-%"12.6#/ft C-110 Hydril 521 Liner Ny 35 4-%"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers (� Halliburton Swell Packer(4-3"Hydril 521)OD 5.85'-9 meter long oil activated element with 14075 6366 4 1/2" 12.6#C-110 slide on Volant centralizers pin end tiiii iiiii H dril521 % 'iousGL y 37 4- "12.6#/ft C-110 Hydril 521 Liner IC' MP I € Tubing 38 Resman Carrier Sub[Job#21847-9-2R05-776/RWS-832] 14427 6358 i (Upper Completion) 39 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.842 ball/2.786 Seat) 14469 6358 0 rXN iiN 40 Resman Carrier Sub[Job#21847-9-1ROS-776/RWS-832] 14500 6357 iiii • 41 4-K"12.6#/ft C-110 Hydril 521 Liner Rte. ii$• 42 4-''A"12.64/ft Hydril 521-6'Pup with slide on Volant centralizers -, _- Halliburton Swell Packer(4-34"Hydril 521)OD 5.85'-9 meter long oil activated element with43 14777 6355 TOC Estimated slide on Volant centralizers pin end ii 500'above top of 4h"12.6#/ftC-110 Hydril 521 Liner Kuparuk 45 ResmanCarrier5ub[Job#21847-82R05-775/RWS831] 15062 6357 46 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.761 ball/2.706 Seat) 15103 6357 47 Resman Carrier Sub[Job#21847-8-1RO5-775/RWS-831J 1.5135 6357 '': 48 4-%"12.6#/ft C-110 Hydril 521 Liner .. � 4- "12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers i /\ I': :;: 49 50 AHalliburton Swell Packer(4-X"Hydril 521)OD 5.85'-9 meter long oil activated element with 15374 6355 .:iiii: slide on Volant centralizers pin end 6-1/8" Hole TD zs @ 19,329' MD/6,371'TVD 7"26# L-80 4r/ '4)0 Q 43 50 57 O 71 78 85 92 99 Go BTC-M & Hydril 563 v/,�®®T - I a _ _ 0 _ _ _ Intermediate 2 Casing 22 _ '_' _ _ _ o 2 _ r_ @ 12,762' MD/6,358'TVD -'_�- c 4-W Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve ODSN-28 Nuiqsut Production Well Completion FINAL 1-13-2014 I j 51 4-'A"12.6#/ft C-110 Hydril 521 Liner 52 Resman Cartier Sub[Job#21847-7-2 R05 774/RWS-8301 15595 6355 iiii 53 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.681 ball/2.628 Seat) 15636 6354 54 Resman Carrier Sub[Job#21847-7-1 ROS-774/RWS-830] 15668 6354 55 4-A"12.6#/ft C-110 Hydril 521 Liner i 56 4-%"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4W'Hydril 521)OD 5.85'-9 meter long oil activated element with 57 15907 6354 slide on Volant centralizers pin end 58 4-A"12.6#/ft C-110 Hydril 521 Liner '''• I 59 Resman Carrier Sub[Job#21847-6.2 ROS-773/RWS-8291 16208 6350 Aiiiii I 1 lililikk 16"Conductor 60 HLB4-1/2"SLHT Ball Actuated Sleeve(2.603 ball/2.552 Seat) 16248 6349 61 Resman Carrier Sub[Job#21847-6-1 ROS-773/RWS-8291 16277 6348 62 4-A"12.6#/ft C-110 Hydril 521 Liner jTill Packer Fluid mix: 63 4-"A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers iiiiii Inhibited Kill weight Halliburton Swell Packer(4-A Hydril 521)OD 5.85'-9 meter long oil activated element with 64 j € Brine slide on Volant centralizers pin end 16515 6343 s with 2000'TVD 65 4-i""12.6#/ft C-110 Hydril 521 Liner ti* ,.• CS'i'?' 66 Resman Carrier Job#21847-5-2 ROS-772 RWS-828 16796 6343 Hill ` i"aj :::::: diesel cap [ / 1 67 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.527 ball/2.477 Seat) 16836 6342 I.:':' 6111111 68 Resman Cartier Sub[Job#21847-5-1 ROS 772/RWS 828] 16867 6342 69 4-A"12.6#/ft C-110 Hydril 521 Liner Iiiiils 11-3/4"60# L-80 70 4-'A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers BTC Surface Halliburton Swell Packer(4W'Hydril 521)OD 5.85'-9 meter long oil activated element with 17145 6344 Casing slide on Volant centralizers pin end 5 GL @ 5,549' MD/ 72 4-A"12.6#/ft C-110 Hydril 521 Liner -- 3,453' TVD 73 Resman Carrier Sub[Job#21847-4-2ROS-771/RWS-827] 17404 6340 7 X 74 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.452 ball/2.404 Seat) 17444 6340 cemented to 75 Resman Carrier Sub[Job#21847-4-1ROS-771/RWS-827] 17473 6341 il rill surface 76 4-"A"12.6#/ft C-110 Hydril 521 Liner •• I 77 4-A"12.6#/ftHydri1521-6'Pup with slide on Vol ant centralizers _ liGL 9 5/8"40# L 80 78 Halliburton Swell Packer(4.14""Hydril 521)OD 5.85'-9 meter long oil activated element with 17750 6345 I Hydril 521 slide on Volant centralizers pin end Eiii 79 4-A"12.6#/ft C-110 Hydril 521 Liner iii Intermediate 180 Resman CarrierSub[Job#21847-3-2ROS-770/RWS-826] 18010 6339 I & Casing 81 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.379 ball/2.332 Seat) 18051 6339 @ 10,152' MD/ 82 Resman Carrier Sub[Job#21847-3-1 ROS-770/RWS-8261 18083 6339 5,556' TVD 83 4-A"12.6#/ft C-110 Hydril 521 Liner 84 4-A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Cemented 500' Halliburton Swell Packer(4A4"Hydril 521)OD 5.85'-9 meter long oil activated element with above shoe 85 slide on Volant centralizers pin end 18358 6337 86 4-1.4"12.6#/ft C-110 Hydril 521 Liner 87 Resman Carrier Sub[Job it 21847-2-2 ROS-769/RWS-8251 18639 6335 88 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.307 ball/2.261 Seat) 18681 6335 89 Resman Cartier Sub[Job R21847-2-1 ROS-769/RWS-8251 18713 6336 j 4-1/2" 12.6#C-110 90 4-r"12.6#/ftC-110Hydri1521 Liner 111. jiii Hydril 521 91 4-'/"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 0 Tubing Halliburton Swell Packer(4-''A""Hydril 521)OD 5.85'-9 meter long oil activated element with I '?� g 92 18983 6355 ®j (Upper Completion) slide on Volant centralizers pin end ® 93 4-'/:"12.6#/ft C-110 Hydril 521 Liner I 94 Resman Carrier Sub[Job#21847-1-2 R05-768/RWS-824] 19040 6359 95 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.236 ball/2.192 Seat) 19080 6362 0 96 Resman Carrier Sub[Job#21847-1-1 ROS-768/RWS-824] 19111 6364 TOC Estimated 97 4-A"12.6#/ft C-110 Hydril 521 Liner 500'above top of 98 4-'/,"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Kuparuk % Halliburton Swell Packer(4-A"Hydril 521)OD 5.85'-9 meter long oil activated element with 19150 6367 slide on Volant centralizers pin end 100 Pre-Perforated Pup with 4-'A"12.6#/ft C-110 Hydril 521 Pup above and below 19198 6370 ' 101 Eccentric Shoe with Float Sub 19209 6371 intik.?'•� Bottom of Shoe 19210 6371 ''tiiE•i!1 - 21 6-1/8" Hole TD -- ze @ 19,329' MD/6,371'TVD I. -- 43 50 57 64 cl78 85 92 99 _j 7" 26# L-80 CO ,* _ - :111:_ -Ir = _ _ _ _ 2 BTC M & H dril 563I - '-I� -r -_ - _ _ �ol Hydril i •,• Intermediate 2 Casing @ 12,762' MD/6,358' TVD 4-W Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve Pioneer Natural Resources Alaska Inc. ODSN-28 Page 4 Form 10-407, Well Completion or Recompletion Report and Log Box #24 - Attachment Open to production or injection 4-'/2", 12.6#, C-110, Hyd 521 Uncemented Liner 4-1/2" SLHT Ball Actuated Sleeves w/seats: MD ND 13,315' — 13,318' 6367' — 6367' 13,764' — 13,767' 6366' — 6366' 14,469' — 14,472' 6358' — 6358' 15,103' — 15,106' 6357' — 6357' 15,636' — 15,639' 6354' —6354' 16,248' — 16,250' 6349' —6349' 16,836' — 16,838' 6342' —6342' 17,444' — 17,446' 6340' — 6340' 18,051' — 18,054' 6339' — 6339' 18,681' — 18,683' 6335' — 6335' 19,080' — 19,083' 6362' — 6362' Perforated Pup joint w/6, 1/2" holes: MD ND 19,198' — 19,202' 6370' — 6370' Pioneer NaLural Resources Alaska Inc. ODSN-28 Page 5 AOGCC Form 10-407, Well Completion or Recompletion Report and Log Box# 25 - Attachment Packers 5" x 7" HRD-E ZXP Packer MD TVD 12,445' 6,336' HES OM Swell Packers MD ND 13,087' - 13,116' 6,364' - 6,365' 13,127' - 13,156' 6,365' - 6,366' 13,467' - 13,497' 6,367' - 6,367' 14,075' - 14,105' 6,366' - 6,366' 14,777' - 14,807' 6,355' - 6,355' 15,374' - 15,404' 6,355' - 6,355' 15,907' - 15,936' 6,354' - 6,354' 16,516' - 16,545' 6,343' - 6,343' 17,145' - 17,175' 6,344' - 6,344' 17,750' - 17,780' 6,345' - 6,345' 18,358' - 18,388' 6,337' - 6,337' 18,983' - 19,012' 6,355' - 6,357' 19,150' - 19,180' 6,367' - 6,369' Pioneer Natural Resources CASING&CEMENTING REPORT Lease&Well No. 50-703-20676-00-00 ODSN-28 Date 14-Nov-13 County USA State Alaska Supv. CASING RECORD-Surface casino TD 5557'MD/3465'TVD Shoe Depth: 5549'MD PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe/it F.Collar/jt L Hanger landing jt Totals Csg Wt.On Hook: Type Float Collar: Halliburton No.Hrs to Run: Csg Wt.On Slips: Type of Shoe: Halliburton Casing Crew: Fluid Description: Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: one per joint from TD to 1800'(base of Permafrost) CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer Ill Density(ppg) 10 Volume pumped(BBLs) 100 Lead Slurry Type: Permafrost L Blend Yield(Ft3 -ck): 4.36 ft3/sk Density(ppg) 11.1 ppg Volume (BBLs/sacks): 590 bbl- 760 sack Mixing/Pumping Rate(bpm): 5bpm Tail Slurry Type: Premium G Blend Yield(Ft 1.18 ft3/sk Density(ppg) 15.8 ppg Volume (BBLs/sacks): 151 bbl- 700 sacks ixing/Pumping Rate(bpm): 3.5 bpm Post Flush(Spacer) ‘1111,11.- Type: Type:Seawater Density(ppg) 8.5 ppg Rate(bpm): 4 bpm Volume: 20 bbl Displacement: Type: Mud Density(ppg) 9.6 ppg Rate(bpm): 10 bpm Volume(actual/calculated): 596.5/590 FCP(psi): Pump used for disp: Rig pumps Plug Bumped? Yes X No Bump press 0 Casing Rotated? Yes X No Reciprocated? _Yes X No %Returns during job 100 - Cement returns to surface? X Yes_No Spacer returns? X Yes_No Vol to Surf: 324 bbl cmt Cement In Place At: 14:30 Date: 11/14/2013 Estimated TOC: Surface 'Method Used To Determine TOC: 10.9 ppg Cement sample taken&weighed @ surface Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Post Flush(Spacer) Type: Density(ppg) Rate(bpm): Volume: Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job Cement returns to surface? Yes_No Spacer returns? Yes_No Vol to Surf: Cement In Place At: Date: Estimated TOC: 'Method Used To Determine TOC: Remarks: PIONEER 'perations Summary Report - Sta Well Name: ODSN-28 NATURAL RESOURCES Well Name: ODSN-28 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: ORIG DRILL&COMPLETE Start Date: 11/4/2013 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 11/4/2013 11/5/2013 0.0 RDMO Nabors 19AC from ODSN-04 to ODSN-28. Rig accepted on ODSN-28 11/04/13 at 00:01 hrs. 11/5/2013 11/6/2013 0.0 MIRU onto ODSN-28&complete post rig move checklists.NU spacer spool&16"di ry rterva n along with 21-1/4"2K Annular Preventer onto 16"wellhead(16"conductor at 158'MD/158' TVD). AOGCC Inspector Jeff Jones granted waiver for witness of diverter test at 09:13 hrs on 11/03/2013. 11/6/2013 11/7/2013 67.0 158.00 8.90 Change out IBOP,saver sub&bell guide to 5"on Top Drive.PU&rack in derrick 192 joints of 5" Drillpipe, 14 joints of 5"HWDP And 7-3/4"WFD hydraulic jars. Perform diverter test. -AOGCC Inspector Jeff Jones granted waiver for witness of diverter test at 09:13 hrs on 11/03/2013 RU Gyro equipment.Clean out conductor pipe to 158'&drill ahead 1/225'. POOH. 11/7/2013 11/8/2013 225.0 1,485.00 9.10 Continue POOH. PU&MU 14-1/2"MTR/MWD/LWD BHA.Trip to bottom. Rotate/slide drill ahead f/25' t/1,710' while running Gyro surveys every stand t/826'.Receiving good MWD signals f/826'. 11/8/2013 11/9/2013 1,710.0 721.00 9.10 Continue directional drilling/sliding new 14-1/2"surface hole f/1,710' t12,431'.CBU 2.5x.POOH f/2,241' t/158'(BHA)while pumpiung 2 bpm.Stand back DC's. Download MWD.Dial mud motor bend down from 1.83°to 1.15°.PU string stabilizer.Upload MWD.RIH t/1,200'. CBU.Continue to RIH f/1,200' 112,431. 11/9/2013 11/10/2013 2,431.0 1,082.00 9.10 Continue to work pipe down f/1,865' U2,065' w/170 gpm,500 psi.Taking weight and making no progress f/2,065'.Increase flow rate to 450 gpm to obtain toolface.Wash pipe down f/2,065' U2,340' w/450 gpm,no rotation.Wash&ream last stand down f/2,340' 1/2,431 w/450 gpm, 1150 psi,80 rpm,7k tq. Drill last 4'of stand f/2,431' U2,435'.Continue to circulate to obtain BU before connection.Drill new 14-1/2"surface hole f/2,435' 1/2,981'.CBU 3x.Drill surface hole f/2,981' 1/3,513'. 11/10/2013 11/11/2013 3,513.0 1,220.00 9.40 Continue to drill new 14-1/2"surface hole f/3,513' U4,733'. • 11/11/2013 11/12/2013 4,733.0 824.00 9.40 Drill new 14-1/2"surface hole f/4,733' 1/5,557'(14-1/2"TD).Circulate hole clean while standing back 1 stand every BU.Lubricate out of hole f/4,907' 111,580'. 11/12/2013 11/13/2013 5,557.0 0.00 9.45 Continue to lube out of hole w/2 bpm f/1,580' U160'.Stand back DC's.Clean stabilizers (packed w/clay). Inspect bit-OK. RIH 111,675'.Wash down f/1,675' U2,625' w/4 bpm.CBU while working pipe f/2,625' 112,720'.RIH on elevators f/2,720' U4,622'.Wash&ream f/4,622' 1/5,557'.CBU 3.5x while standing back stands 1/4,717'.RIH to TD.CBU 1x. POOH f/5,557' 1/5,191'. Lube out of hole w/2 bpm f/5,191' 1/1,105'. 11/13/2013 11/14/2013 5,557.0 0.00 9.45 Continue to lube out of hole w/2 bpm f/1,580' 11800'.POOH on elevators f/800'-Stand back HWDP.Download MWD.Clean&LD BHA.Mud Motor.Clean&clear floor.RU and RIH w/11- 3/4"60#L-80 BTC casing U2,703'.CBU 2x and work through tight spot f/2,703' 112,733'. Continue to RIH w/11 3/4"casing f/2,733' U4,975'.PU TAM Port Collar.Continue to RIH w/11- 3/4"casing U5,505'. *AOGCC was given notice of upcoming BOP Test via website at 09:30 hrs on 11/12/2013* Page 1/8 Report Printed: 1/28/2014 P10NEER ,perations Summary Report - Sta Well Name: ODSN-28 ATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 11/14/2013 11/15/2013 5,557.0 0.00 9.60 PU Vetco Gray 11 3/4"hanger&landing joint. Land casing in wellhead placing shoe at 5549'- Final SOW=105k.Break circulation w/2 bpm-Stage up to 9 bpm,280 psi.Continue to circulate&condition for cement job(targeting a 20-22 YP).RD Tesco Casing equipment.RU HES Cement Head. Break circulation and circulate while trouble shooting HES Cementers computer. Line up Halliburton Cementers: -Pump 10 bbls seawater-Test lines to 4000 psi.-Drop 1st bottom plug. -Pump 100 bbls of Tuned spacer at 10.0 ppg. -Pump 590 bbls of Permafrost type"L"Lead cement at 11.1 ppg(4.51 yield)+0.25%D-Air 5000P -Drop 2nd bottom plug. -Pumped 151 bbls of"G"Tail cement at 15.8 ppg(1.18 yield)+0.2%CFR-3&1%Calcium Chloride. -Drop top plug&kick out w/20 bbls of seawater. Line up rig pumps and displace cement w/9.6 ppg WB mud. -10 bpm,2050 to 2500 psi-At 450 bbls away,slow to 9 bpm,2150 to 2400 psi. -At 278 bbls(2750 stks)away,good cement to surface(10.7 ppg). -At 587 bbls(5812 stks)away,slow rate to 3 bpm,960 psi. -Pumped calculated strokes+1/2 shoe track volume(596.5 bbls). -Did not bump plug-CIP @ 14:30 hrs. -Received 324 bbls of 10.7 ppg cement to surface. -Full returns throughout cement &displacement pumping operations. - RD cement head&lines. LD landing jt. Flush diverter stack.ND annular diverter.ND diverter line &knife valve. ND surface riser. *AOGCC Rep.Bob Noble waived right to witness upcoming BOP Test at 10:28 hrs.on 11/14/2013. 11/15/2013 11/16/2013 5,557.0 9.60 Continue to ND Diverter system. NU riser&spacerspools. NU drilling adapter&lower drilling riser.Test adapter seals. NU BOP stack and upper flow riser.Level rig. RU test tools.Install test plug and fill stack w/seawater. Test BOPE per AOGCC PTD: *Test upper and lower VBR w/5"test joint to 250/4500. *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. *Initial system psi:3100--2050 after closure;200 psi=20 sec,full pressure 107 sec. **Note: Upper Kelly valve failed low test.Replaced valve and re-test.Good test. **AOGCC Rep.Bob Noble waived right to witness test at 10:28 hrs on 11/14/13. RD Test equipment.PU BHA#3 to 536'.RIH PU 5"DP f/536'to 4495'. 11/16/2013 11/17/2013 5,557.0 0.00 9.60 Continue to RIH w/BHA#3 while PU 5"DP f/4495'to 5353'.Break circulation.Wash&ream to 5373'w/200 gpm,20 rpm.CBU.Close top rams&test 11 3/4"casing to 3500 psi f/30 charted min.Good test.Stand back 2 stands.PU last 6 joints of DP f/pipeshed.Drilling plugs/cement to 5461'(5'above FC).CBU x2.Test casing to 3500 psi f/5 min.Good test. Drill FC and clean out shoe track to 11 3/4"shoe at 5549'.Drill shoe and clean out 11 3/4"rathole to 5557'.CBU. POH f/5557'to 5192'. Pump dry job.Service rig. POH f/5192'to 536'(BHA).LD BHA#3.PU RSS BHA#4 to 180'. 11/17/2013 11/18/2013 5,557.0 159.00 10.00 RIH w/jars&HWDP to 638'-RIH w/BHA#4 to 5399'.Fill pipe. Blow down Top Drive.Cut&slip drilling line.Service rig.Wash&ream f/5399'to TD at 5557'.Displace well from 9.6 ppg WBM to 10.0 ppg. Drill new formation f/5557'to 5577'.CBU.Perform FIT to 12.5 ppg EMW w/450 psi at 3464'TVD and 10.0 ppg MW. Drilling f/5577'to 5716'to bury Weatherford reamer below casing shoe.Drop reamer opening tags and begin pumping down.Observed washout in high pressure mud line in pump room.Stop pumps.POH f/5716'to 5495'(54'inside casing).Remove washed out mud line and begin repairs on same. Page 2/8 Report Printed: 1/28/2014 PI O N E E R Iperations Summary Report - St2 Well Name: ODSN-28 ATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 11/18/2013 11/19/2013 5,716.0 359.00 10.00 Continue to build new HP mud line-Install mud line&pressure test same to 4500 psi. RIH to 5685'placing reamer blades at 5558'(9'below shoe).Continue pumping opening tags down.PU and observe a 10k overpull at 11 3/4"shoe.Slack off and set down 15k at 5559'reamer depth (original 14 1/2"TD at 5557'). Reaming/opening hole f/5686'bit depth to 5716'.Drilling 10 5/8" x 11 3/4"hole f/5716'to 5720'.Close reamer. POH to shoe for CCU repairs. RIH f/5495'to 5720'.Drilling f/5720'to 5779'w/reamer closed.Open reamer.Backream to 5720'.Drilling f/ 5779'to 5929'.Shut down while CCU switched to secondary cuttings line(Primary plugged off). Drilling f/5929'to 6075'.Stop drilling while CCU repairs Geo Pump.POH to shoe.install floor valve&monitor well while CCU repairing Geo Pump.RIH to 6075'.Drilling f/6075'to 6115'. 11/19/2013 11/20/2013 6,075.0 1,215.00 10.00 Drilling f/6115'to 6159'.Service rig.Drilling f/6159'to 7260'.Lubricate out of hole w/1 bpm f/ 7260'to 6662'while CCU making repairs on Geo Pump. RIH to 7230'.Fill pipe.Wash down to TD at 7260'.Drilling f/7260'to 7290'. 11/20/2013 11/21/2013 7,290.0 1,020.00 10.00 Continue drilling 10 5/8"x 11 3/4"hole f/7290'to 7856'. Replace Top Drive Encoder.Drilling f/ 7856'to 8310'. 11/21/2013 11/22/2013 8,310.0 933.00 10.00 Drilling 10 5/8"x 11 3/4"Intermediate) f/8310'to 8917'.Change Pop-Off on Mud Pump. Drilling f/8917'to 8946'.Change swab on MP#2. Drilling ff 8946'to 9243'. 11/22/2013 11/23/2013 9,243.0 887.00 10.00 Drilling 10 5/8"x 11 3/4"Intermediate) f/9243'to 9962'.Service rig. Drilling f/9962'to 10130'. *Performed BOPE function test per AOGCC weekly requirement. 11/23/2013 11/24/2013 10,130.0 40.00 10.00 Drilling 10 5/8"x 11 3/4"Intermediate) f/10130'to 10170'(TD).Perform quadrant ream of 10 5/8"hole per Directional Driller f/10170' to top of 10 5/8"hole at 10040'.Continue to circulate hole clean while working pipe f/10040'to 9962'.Packed off at 9962'. Break circulation and stage pumps up in 1/2 bpm increments to 468 gpm. Packed off.PU f/9962'to 9910'.Break circulation and stage pumps up to 490 gpm. Lubricate out of hole w/1-2 bpm f/9910'to 7458'.Pulled tight &packed off at 7458'.Slack off to 7490'.Break circulation and stage pumps up to 365 gpm. Stage rotary up to 60 rpm.Attempt to backream stand f/7490'.Packed off.Slack off to 7490'. Break circulation and stage pumps up to 700 gpm.Stage rotary up to 80 rpm.CBU x 1.25.Lube out of hole f/7490'to 7015'. 11/24/2013 11/25/2013 10,170.0 0.00 10.00 Continue to lube out of hole w/1-2 bpm f/7015'to 5743'.Break circ.&step rate up in 1 bpm increments to 800 gpm,3600 psi-80 rpm.At 10300 stks,observed packoff-Stop Pumps& bleed off. POH f/5743'to 5650'(placing reamer inside casing)-Observing 50-70k overpull in casing. Drop closing tags(7)and pump down w/150 gpm, 150 psi f/1200 stks.Stage up to 1250 psi-Stop pumps and drop reamer below casing.Stage pumps up to 550 gpm 2400 psi-Pull reamer into casing w/2400 psi-No overpull observed at shoe.Observed packoff-Stop pumps. Drop reamer below shoe-Stage pumps up to 475 gpm w/no packoffs observed. RIH f/5682'to 6223'.Attempt to break circ.w/1/2 bpm.Several attempts w/no success.Attempt to break circulation several times while POH f/6223'to 5847'. Break circulation at 5847'w/1/2 bpm. Stage up to 800 gpm.Lubricate out of hole w/2 bpm f/5825'to 5520'. Establish circulation and stage up to 800 gpm.Back ream to clean casing f/5520'to 1313'. 11/25/2013 11/26/2013 10,170.0 0.00 10.00 Circulate casing clean at 1313'w/2X BU.POH f/1313'to surface. LD BHA.Clear rig floor. Flush stack,kill&choke lines. Drain stack.PU 9 5/8"test joint. Install test plug.Change lower pipe rams from 2 7/8"x 5"vbrs to 9 5/8".Fill stack w/water.Test 9 5/8"rams to 250 psi low,4500 psi high for 5 charted minutes each test.RD test equipment. RU Tesco&other casing equipment. RIH w/9 5/8"40#L-80 Hydril 521 liner f/surface to 4036'(circulate annular volume at 1507'& 2997'). 11/26/2013 11/27/2013 10,170.0 0.00 10.00 Pick Up&RIH w/9-5/8"40#L-80 Hydril 521 Drilling Liner From 4036'to 5535'.Make Up Baker HRD-E Liner Hanger/Packer. Break Circulation at 11-3/4"Surface Casing Shoe.Trip In Hole With 9-5/8"Drilling Liner On 5"Drill Pipe to 9462'. Page 3/8 Report Printed: 1/28/2014 PI O N E E R `perations Summary Report - Sta Well Name: ODSN-28 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 11/27/2013 11/28/2013 10,170.0 0.00 10.00 Trip In Hole With 9-5/8"Drilling Liner On 5"DP From 9462'to 10,152'(18 Ft From Bottom). Attempt To Work Liner Through Tight Spot at 10,152'With No Success.Set 9-5/8"x 11-3/4" Hanger at 5402'. Perform Cement Job As Per Halliburton Pump Schedule. -Pump 60 Bbls Tuned Spacer at 11.0 ppg. -Mix&Pump 386 Sxs(451 CuFt-80 Bbls)of Class"G"Cement+Halad 344+CFR-3 +SCR-100 at 15.8 ppg(Yield 1.17 CuFt/Sk). -Drop Top Plug,Pump 20 Bbls of Seawater,Displace Same With 427 Bbls of 10.0 ppg MOBM. -Bump Plug, Increase Pressure Up to 3500 psi For 5 Minutes(1600 Hrs), Bleed Off Pressure&Check Float Equipment(Good). -No Returns Through Out Cement Job. -Total lift pressure after cement enters annulus calculated at 128.5psi. -Lift calculations put TOC at 9088ft MD. Set 9-5/8"x 11-3/4"Packer(TOL at 5392). Pull Out of Hole Laying Down 5"Drill Pipe From 5375' 11/28/2013 11/29/2013 10,170.0 0.00 10.00 Finish Laying Down Liner Running Tools.Nipple Down BOP. Remove Drilling Spool. Install Multi Bowl Spools(Casing&Tubing Spools).Nipple Up Spacer Spools,BOP Stack,MPD RCD Housing, Bell Nipple And Flowline.Change 9-5/8"Rams to 2-7/8"x 5"VBR's.Test MPD Connections. Pressure Test BOPE As Per AOGCC Permit to Drill. -Install Test Plug&Make Up 5"Test Joint. -Test Upper&Lower VBR Against 5"Test Joint at 250/4500 psi. -Test Upper&Lower IBOP Valves at 250 psi Low/4500 psi High. -Test Annular Preventer Against 5" Test Joint at 250 /2500 psi. -Test All Floor Valves at 250 psi Low/4500 psi High. -Test All 14 Choke Manifold Valves to 250 psi Low/4500 psi High. -All Tests Charted And All Tests Held For 5 Minutes Each. -Initial System psi:3000 psi--2150 psi After Closure;200 psi=21 sec,Full Pressure 92 sec. **Note:AOGCC Jeff Turkington Waived Witness For BOPE Test at 1139 Hrs On 11/28/2013.** -Pressure Test 9-5/8"Liner x 11-3/4"Surface Casing to 3500 psi For 30 Minutes On Chart (Good Test). 11/29/2013 11/30/2013 10,170.0 20.00 10.20 Make Up&Trip In Hole With 8-1/2"Mill Tooth Cleanout Assembly to 9-5/8"Landing Collar at 10027'.Drill Cement&Float Equipment To 10152'.Wash&Ream 18 Ft Rat Hole to 10170'. Flow Check Well(Static). Drill 20 Ft of New Formation While Displacing 10.0 ppg MOBM With 10.2 ppg LSND. Perform FIT to 13.5 ppg EMW. 11/30/2013 12/1/2013 10,190.0 179.00 10.20 Pull Out of Hole With Cleanout Assembly to 9380'.Circulate 1-1/2x Bottom Up.Continue Pull Out of Hole to 410'.Lay Down Cleanout Assembly to 98'. Pick Up&Trip In Hole With 12 Jts of 5" HWDP.Circulate 1-1/2x Drill String Volume. Pull Out of Hole Racking HWDP In Derrick.Lay Down Remaining Cleanout Assembly.Make Up Geo-Pilot, PDC Bit&MWD/LWD Without Sources.MU Weatherford Underreamer&Surface Test Same.Replace Blanks With Nozzles x3. Pick Up&Load Nukes.Finish MU 8-1/2"RSS BHA With 9-1/2"Weatherford RFID Activated Underreamer.Perform Shallow Pulse Test-Function Test BOPE.Trip In Hole to 9218'. 12/1/2013 12/2/2013 10,369.0 625.00 10.20 Trip In Hole With 8-1/2" RSS x 9-1/2"Wford RFID Activated Underreamer From 9218'to 10123'. Slip&Cut Drill Line, Install RCD.Wash Down To Bottom at 10190'.Drill 8-1/2"Intermediate Hole 2 to 10326'.Activate Weatherford RFID Underreamer.Drill 8-1/2"x 9-1/2"Intermediate 2 Hole to 10358'. Pull Up Inside 9-5/8"Liner.Change Out Electrical Clamp On Top Drive Encoder.Trip In Hole to Bottom. Drill to 10369'.Trouble Shoot LWD Tool(Failed LWD Tool).Pull Out of Hole. Lay Down Resistivity Tools. 12/2/2013 12/3/2013 10,369.0 625.00 10.20 Make Up New EWR&DGR Collars(Resistivity Tools).Function Test Underreamer.Load Nukes. Trip In Hole With 8-1/2"RSS x 9-1/2"Wford RFID Activated Underreamer to 10072'.Install RCD. Trip In Hole to Bottom At 10369'.Activate&Pull Test Underreamer Against Shoe.Drill Intermediate 2 Hole to 10601'.Retrieve Sample Catcher Pan/Screen Which Was Accidently Dropped In CCU Hopper.Drill Intermediate 2 Hole With 8-1/2"RSS x 9-1/2"Wford RFID Activated Underreamer to 10994'. 10.2 ppg MW with 13.0 ppg ECD via MPD. Page 4/8 Report Printed: 1/28/2014 operations Summary Report - Sta Well Name: ODSN-28 Pi0 �1EER ATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 12/3/2013 12/4/2013 10,994.0 505.00 10.20 Drill Intermediate 2 Hole With 8-1/2"RSS x 9-1/2"Wford RFID Activated Underreamer From 10994'to 11499'.10.2 ppg MW with 13.0 ppg ECD via MPD. 12/4/2013 12/5/2013 11,499.0 1,045.00 10.20 Drill Intermediate 2 Hole With 8-1/2"RSS x 9-1/2"Wford RFID Activated Underreamer From 11499'to 11594'.Change Out Packer Element For RCD.Drill Intermediate 2 Hole With 8-1/2" RSS x 9-1/2"Wford RFID Activated Underreamer From 11594'to 12544'.10.2 ppg MW with 13.0 ppg ECD via MPD. 12/5/2013 12/6/2013 12,544.0 236.00 10.20 Drill Intermediate 2 Hole With 8-1/2"RSS x 9-1/2"Wford RFID Activated Underreamer From 12544'to 12780'(Intermediate 2 Total Depth). Pump Hi-Vis Sweep&Perform Geo-Pilot Quadrant Ream Over Bottom 141'Of Hole To Enlarge 8-1/2"Hole Between Bit&Underreamer. Deactivated Underreamer.Shut Down While Changing Out Turbine On Hi-Line Power at OTP. Change Out Packer Element For RCD. Finish Quadrant Ream While Circulating&Conditioning Mud.Lubricate Out of Hole From 12780'to 10067'(Inside 9-5/8"Liner).Change Out Wash Pipe Packing In Top Drive.Trip In Hole With 8-1/2"RSS Assembly&Deactivated Wford Underreamer From 10067'to Bottom at 12780'. 10.2 ppg MW with 13.0 ppg ECD via MPD. 12/6/2013 12/7/2013 12,780.0 0.00 13.90 Circulate 30 Bbl Hi-Vis Weighted Sweep Around&Continue Circulate 3xBU Until Hole Cleaned Up at 12780'.Displace 10.2 ppg LSND With 12.0 ppg LSND From Well.Lubricate Out of Hole To 10067'(Inside 9-5/8"Liner).Pull Out of Hole On Elevators to 9027'.Displace 116 Bbls of 12.0 ppg LSND Treated With 6%NXS&Displace To Bit.Continue Out of Hole to TOL.Spot 13.9 ppg Hi-Vis Pill From TOL to 4930'.Pull Up Above 13.9 Hi-Vis Pill.Displace 12.0 ppg LSND With 13.9 ppg LSND Kill Pill(EMW On Bottom at 13.0 ppg).Remove RCD&Install Trip Nipple.Pull Out of Hole With 8-1/2"RSS Assembly&Deactivated Wford Underreamer to 2663'. 12/7/2013 12/8/2013 12,780.0 0.00 10.20 Finish POOH&Laydown BHA.Close Blind Rams,Change Out Top VBR With 7"Casing Rams. Set Test Plug&Pressure Test 7"Casing Rams to 250/4500 psi As Per AOGCC PTD. Pick Up &Trip In Hole With 7"26#L80 BTC-Mod Intermediate 2 Casing to 686'. Notify AOGCC Inspector Louis Grimaldi For Upcoming BOPE Test Via Email On 12-7-2013 11:12 AM 12/8/2013 12/9/2013 12,780.0 0.00 10.20 Pick Up&Trip In Hole With 245 Joints of 7"26#L80 BTC-M From 686'to 9847',Continue PU& Trip In Hole With 69 Joints of 7"26#L80 Hydril 563 From 9847'to 12721'. Drain BOP Stack While Picking Up Casing Hanger&Landing Joint/Land The 7"Casing Hanger With 7" Intermediate 2 Shoe at 12762'(18 Ft From Bottom).Rig Down Casing Equipment&Rig Up Cement Head-Establish Circulation. 12/9/2013 12/10/2013 12,780.0 0.00 10.20 Circulate at 12762'With 6 BPM&Full Mud Returns. Cement 7"Intermediate 2 Longstring Casing at 12762'. -Pump 10 Bbls of Water With Cement Unit To Kick Out Bottom Plug#1. a -Test Cement Lines to 4000 psi. -Pump 50 Bbls of Premixed DUAL Spacer at 12.5 ppg. -Kick Out Second Bottom Plug. -Mix&Pump 555 Sx(115 Bbls-649 CuFt)of Class G Cement+Halad 344+SCR-100 at 15.8 ppg(Yield- 1.17 CuFt/Sx). • -Kick Top Plug Out With 20 Bbls of Seawater. -Switch Over to Rig&Displace Cement With 5600 Strokes(473 Bbls at 97%Efficiency)&Bump Plug. -Pressure to 3500 psi&Hold Same For 5 Minutes/Release Pressure&Check Float Equipment (Good). -Monitor Backside For Flow(Static). -Full Mud Returns Through Out Cement Job. Install&Test 7"Pack-Off to 5000 psi(Good Test).Perform Volume Breakdown Through 7"x 11- 3/4"x 9-5/8"Annulus With 10.2 ppg Mud. Laydown 5"Drill Pipe From Derrick Utilizing Mouse Hole In Rotary. Updated AOGCC For Up Coming BOPE Test: Inspected John Crisp Waived Witness For Same at 05:54 12/10/2013 Page 5/8 Report Printed: 1/28/2014 PI O N E E R operations Summary Report - Sta Well Name: ODSN-28 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 12/10/2013 12/11/2013 12,780.0 0.00 10.20 Laydown 5"Drill Pipe From Derrick Utilizing Mouse Hole In Rotary. InstallTest Plug,Change Ram Blocks In Top Pipe Rams From 7"to 2-7/8" x 5"VBR's. Pressure Test BOPE As Per AOGCC Permit to Drill. -Install Test Plug&Make Up 4"Test Joint. -Test Upper&Lower VBR Against 4"Test Joint at 250/4500 psi. -Test Upper&Lower IBOP Valves at 250 psi Low/4500 psi High. -Test Annular Preventer Against 4" Test Joint at 250 /2500 psi. -Test All Floor Valves at 250 psi Low/4500 psi High. -Test All 14 Choke Manifold Valves to 250 psi Low/4500 psi High. -All Tests Charted And All Tests Held For 5 Minutes Each. -Perform Accumulator Draw Down,Initial System psi:3000 psi--1900 psi After Closure;200 psi =26 sec,Full Pressure 115 sec. AOGCC Inspector John Crisp Waived Witness For BOPE Test at 0545 Hrs On 12/10/2013. Pressure Test 7"Intermediate 2 Casing to 3500 psi For 30 Minutes On Chart(Good Test).Slip& Cut Drill Line. Freeze Protection of ODSN-28 Outer Annulus(7'x 11-3/4"x 9-5/8")With 150 Bbls of 6.8 ppg Diesel. 12/11/2013 12/12/2013 12,600.0 180.00 10.20 Pick Up&Trip In Hole With 4"Drill Pipe to 7680'.Circulate 1.5x Drill Pipe Capacityat 7680'. Pull Out of Hole Racking Back 80 Stands of 4"Drill Pipe In Derrick.Pick Up&Make Up 6-1/8" Clean Out Assembly With 1.5°Mud Motor/Bat Sonic.Trip In Hole With Same While Picking Up 4"Drill Pipe to 1086'.Change Out Halliburton's Geo-Span.Trip In Hole With 6-1/8"Clean Out Assembly While Picking Up 4"Drill Pipe to 4874'. 12/12/2013 12/13/2013 12,600.0 - 10.20 Trip In Hole With 6-1/8"Clean Out Assembly While Picking Up 4"Drill Pipe From 4874'to 12,600.00 12412'.Trip In Hole From Derrick to 12600'(Tag Cement w/20K Down). Drill Cement&Float Equipment From 12600'to 12762'.Drill Ratty Cement to 12775'(13 Ft Below Shoe)&Wash/ Ream Last 5 Ft To Bottom.Circulate Bottom Up at 12780'. Perform Bat Sonic Mad Pass From TD to 10971'(131 Ft Below Calculated Top of Cement at 10840'). 12/13/2013 12/14/2013 12,780.0 10.20 Perform Bat Sonic Mad Pass From 10971'to 10540'(300 Ft Above Calculated Top of Cement at 10840').Pull Out of Hole w/Clean Out Assy On Elevators From 10540'to 10252'.Mad Pass 100' Interval Below 9-5/8"Shoe F/10252'to 10152'.(Confirm&Calibrate Bat Sonic Log To Ringing Pipe Through"Non-Cemented"Area).Continue Pull Out of Hole&Laydown BHA(Function Test Blind Rams).Pick Up&Trip In Hole 6-1/8"BHA With 1.5°Bent Housing Mud Motor/DrillDoc/ MWD/LWD&Agitator Plus to 10746'(Function Test Remaining BOPE After Filling Pipe at 1598'). 12/14/2013 12/15/2013 12,780.0 665.00 7.50 Trip In Hole With 6-1/8"BHA With1.5°bh Motor/DrillDoc/MWD/LWD&Agitator Plus From 10746'to 12728'.Slip&Cut Drill Line/Reset Crown&Floor Saver. Install Seal Bearing Package In Rotary Control Device(RCD).Pump 40 Bbl Hi-VisSweep Then Displace10.2 ppg LSND Mud With 7.4 ppg MOBM From Well at 4.8 BPM While Maintaining-9.8 ppg ECD Via MPD at 7" Shoe. Drill 6-1/8"Production Lateral w/Geo-Steering Assembly(1.5 Motor/Drill Doc/MWD/ LWD/Agitator Plus)From 12780'to 12800'(20 Ft).Pull Up Inside 7"Casing&Perform FIT to 12.5 ppg EMW WithTest Pressure at 1653 psi,Test Fluid at 7.5 ppg&Shoe TVD at 6358'.Drill 6 -1/8"Production Lateral w/Geo-Steering Assembly to 13149'. Perform Static Pore Pressure Test Equivalent to 8.8 ppg EMW. Drill 6-1/8"Production Lateral w/Geo-Steering Assembly to 13445'. 12/15/2013 12/16/2013 13,445.0 1,150.00 7.50 Drill 6-1/8"Production Lateral w/Geo-Steering Assembly(1.5 Motor/Drill Doc/MWD/LWD/ Agitator Plus)From 13445'to 14595'(1150 Ft). 12/16/2013 12/17/2013 14,595.0 1,050.00 7.70 Drill 6-1/8"Production Lateral w/Geo-Steering Assembly(1.5 Motor/Drill Doc/MWD/LWD/ Agitator Plus)From 14595'to 15645'(1050 Ft). 12/17/2013 12/18/2013 15,645.0 1,217.00 7.80 Drill 6-1/8"Production Lateral w/Geo-Steering Assembly(1.5 Motor/Drill Doc/MWD/LWD/ Agitator Plus)From 15645'to 16862'(1217 Ft). 12/18/2013 12/19/2013 16,862.0 778.00 7.80 Drill 6-1/8"Production Lateral w/Geo-Steering Assembly(1.5 Motor/Drill Doc/MWD/LWD/ Agitator Plus)From 16862'to 17640'(778 Ft). 12/19/2013 12/20/2013 17,640.0 1,081.00 7.90 Drill 6-1/8"Production Lateral f/17640'to 18449'.Change RCD bearing.Drilling f/18449'to 18721'. Ream&backream to reduce DLS at 18668'. Page 6/8 Report Printed: 1/28/2014 PI O N E E R )perations Summary Report - Sta Well Name: ODSN-28 ATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 12/20/2013 12/21/2013 18,721.0 608.00 8.00 Continue drilling Production Lateral f/18721'to 19329'(6 1/8"TD).POH to 19211'. Backream f/ 19211'to 19025'.Repair MPD charge pump.Continue to backream f/19025'to 18883'. ""Function BOPE per AOGCC weekly requirement** 12/21/2013 12/22/2013 19,329.0 0.00 8.00 Continue to backream 1/18883'to 18160'.Trouble shoot communication issues between MWD& MPD computers.Continue to backream f/18260'to 17003'.CBU x2 while standing back 1 stand every 45 min.Continue to backream f/16513'to 16039'.Service rig.Continue to backream f/ 16039'to 12668'(inside 7"casing shoe).CBU x2. 12/22/2013 12/23/2013 19,329.0 0.00 9.90 Continue to CBU(2.5 x total)-Observe well while servicing rig-Static..RIH on elevators f/ 12668'to 19115"(Fill pipe at 15557').Wash last stand down to 19211'.Displace well f/8.0 ppg MOBM to 9.9 ppg KW MOBM.Observe well.Static.Remove RCD. Install trip Nipple.Lubricate out of hole f/19211'to 12572'(drop 2 3/8"drift at 12765'(stand#128). ""AOGCC was given notice of upcoming BOP test via website at 05:30 hrs on 121/22/13"" 12/23/2013 12/24/2013 19,329.0 0.00 9.90 Continue to lubricate and strap out of hole f/12572'to 1694'. LDDP to 637'.Service rig&repair skate.LDDP&jars to 205'. LD BHA to 138'.Download MWD tools. 12/24/2013 12/25/2013 19,329.0 0.00 9.90 Continue to LD BHA to surface.Clear/Clean Rig Floor.Change Top Drive Saver Sub. PU 4" HWDP for liner run and flush same. POH stand back in derrick.Attempt to pull wear ring. Pulling tool would not go through annular. Inspect annular.Discovered that the element was damaged. ND RCD head and RU to test choke manifold.Test choke manifold&gas alarms while preparing to remove annular element.AOGCC Rep.Lou Grimaldi present to witness test.250 psi low, 4500 psi high f/5 charted minutes each test.Break cap on annular&remove damaged element. Install new element&cap on annular. NU MPD equipment. RU to test BOPE.After installing test plug and opening annulus valve,observed flow out of annulus.Observed 2 bbls flow back. Pull test plug.Drain stack.Well still flowing.Shut well in&monitor for pressure for 15 min.No pressure observed.Open well through choke to pits.Observed a"pencil size"flow at shakers. Shut well in and observe at choke gauge for 30 min.Approximately 10 psi observed.Open well through choke&monitor for 3 hrs.Flow remained the same with approximately 1/2-3/4"diameter stream of flow.After 3 hrs,gained 4.6 bbls(1.5 bbls/hr).Shut well in for 1 hr.Observed 15-20 psi at choke gauge.Open well through choke-Observe 1.3 bbls gain in 1 hr. 12/25/2013 12/26/2013 19,329.0 0.00 10.00 Continue to monitor well.Gained 6 bbls in 1 1/2 hrs.MW out 9.5 ppg.Shut well in and monitor pressure at choke gauge f/1 1/2 hrs.Pressure reading 15-20 psi.Open well through choke. Open blinds.Set wear ring.PU Johnny Whacker,XO's&ported float on 1 stand of HWDP.RIH w/8 stands HWDP.PU jars.RIH w/8 stands of HWDP to±1500'.RIH w/4"DP to 13100'. Displace open hole volume w/10.0 ppg KWM.POH f/13100'to 12762'(7"shoe).Close annular.Circulate 10.0 ppg to surface taking returns through choke.Monitor well f/15 minutes. Static. POH f/12762'to 4485'. 12/26/2013 12/27/2013 19,329.0 0.00 10.00 Continue to POH f/4485'to surface. LD BHA.Monitor well.Static.Drain stack. Pull wear ring. Install test plug. RU to test BOPE. Test BOPE As Per AOGCC Permit to Drill. -Test Upper&Lower VBR Against 4"&4 1/2"Test Joints at 250/4500 psi. -Test Upper&Lower IBOP Valves at 250 psi Low/4500 psi High. -Test Annular Preventer Against 4" Test Joint at 250 /2500 psi. -Test All Floor Valves at 250 psi Low/4500 psi High. -Test All 14 Choke Manifold Valves to 250 psi Low/4500 psi High. -All Tests Charted And All Tests Held For 5 Minutes Each. -Perform Accumulator Draw Down, Initial System psi:3050 psi--2100 psi After Closure; -200 psi=23 sec,Full Pressure 100 sec. AOGCC Inspector Lou Grimaldi was present to witness test.RD test equipment.Pull test plug. Install wear ring.RU and run 4 1/2"12.6#L-80-Hydril 521 liner to 2787'. 12/27/2013 12/28/2013 19,329.0 0.00 10.00 Continue to RIH w/4 1/2"liner f/2787'to 6726'. RD casing equipment.PU liner hanger/packer assembly and 1 stand of 4"DP.Circulate liner volume+25 bbls.RIH w/liner on 4"DP f/6887'to 11123'. Page 7/8 Report Printed: 1/28/2014 PIONEERIperations Summary Report - St2 Well Name: ODSN-28 ATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 12/28/2013 12/29/2013 19,329.0 0.00 10.00 Continue to RIH w/4-1/2"12.6#C-110 HYD 521 liner on 4"DP f/11123'to 12747'(15'above 7" casing shoe). Break circulation and stage up to 2 bpm,850 psi.CBU.Continue to RIH w/liner to 15263'.Repair Top Drive.Continue to RIH w/4 1/2"liner f/15263'to 19210. Pump DP volume. Drop 1 1/2"hanger setting ball and pump down on seat. Pressure up to 1900 psi to set hanger. Liner Top 12445'.Liner Shoe at 19210'. 12/29/2013 12/30/2013 19,329.0 0.00 10.10 Continue to set hanger&release hanger.Set down 50k string weight.Pressure up to 4200 psi to release f/hanger.PU and observe free movement w/210k up wt.Continue to PU to expose setting dogs.Set down 60k string weight to set liner top packer.PU&rotate down w/6 rpm setting down 40k.Close upper rams-Test backside/packer to 3500 psi f/10 charted min- Good test.PU to clear liner running tools&LD 1 jt.of DP. Displace the well V the liner top to surface f/10.0 ppg MOBM to 10.1 ppg brine(Spot corrosion inhibitor from liner top to upper GLM).Observe well.U-tubing.Circulate to balance fluids.Cut& slip drilling line. LDDP f/12390'to surface. Inspect liner running tools&LD same. Remove wear ring.RU Tesco running tools.Run 4 1/2"12.6#C-110 Hydril 521 upper completion to 457'. 12/30/2013 12/31/2013 19,329.0 0.00 10.10 Continue to RIH w/4 1/2"12.6#C-110 Hyd.521 upper completion f/457'to 10701'. 12/31/2013 1/1/2014 19,329.0 0.00 10.10 RIH w/4 1/2"12.6#C-110 Hyd.521 upper completion f/10701'to 12428'.PU jt#310 and enter Liner top at 12445'&no-go down-PU Jt#311 and set down 40k.Take space out measurements.Close annular.Test seals down backside to 200 psi.OK.LD joints#311,310, 309&308-PU space out pups(1.65'&2.67').PU joints#308&309-MU hanger and landing jt. Splice I-Wire and control line through hanger and test same.Orient hanger to centering guide in the tubing bowl.Land hanger in wellhead w/40k down wt.on no-go at 12445'-RILDS.Test hanger seals to 10k psi f/15 minutes.Good Test.RU secondary line to 4 1/2"x 7"annulus.Test backside to 500 psi f/5 min.Drop ball&rod. RU pump-in sub and cement line to pump down tubing.Test tubing to 3500 psi f/30 charted min.Good test.Bleed tubing to 2200 psi.Test 4 1/2" x 7"annulus to 3500 psi f/30 charted min.Good test.Bleed tubing and observe DCK valve shear w/2500 psi differential. Pump 2 bbls through DCK valve each direction to verify fully open. Prep to ND BOPE-Blow down kill line&secondary line in cellar.Drain stack. Pull'VR"plug from tubing valve.Back out landing joint.Discovered that tubing backed out of landing sub leaving it on hanger.Discuss options with Anchorage DE, Halliburton&Vetco Rep.Decision made to BakerLok threads and screw back into landing nipple.Apply BakerLok-Screw tubing into landing nipple&torque to 4200 ft/lbs.Clear rig floor,RD sheaves.Rig maintenance while waiting on BakerLok to set up. 1/1/2014 1/2/2014 19,329.0 0.00 10.10 PJSM. Engage landing joint w/Tesco.Apply 1.5k left hand torque while rattling pipe w/ hammers. Increase torque in stages until connection broke w/6k ft/lbs.Pull to rig floor. Landing joint only.Clean and inspect threads-OK.RIH&MU landing jt to hanger&torque to 4200 ft/lbs. Pull hanger to rig floor.Terminate control line and I-Wire.Break landing nipple out of hanger using rig tongs w/8-10k tq to break out. Inspect threads on hanger.OK.Change seals on hanger.Splice control line and I-Wire.Feed through hanger.Test same.Land hanger w/40k down on liner top.Test hanger seals to 10k psi. LD landing jt. Install TWC.Test annulus to 3500 psi f/30 charted min. RD control line, I-wire spools,casing tongs. RD Tesco.Clean rotary drip pan. ND BOPE and spacer spools. HES terminate I-Wire&control line.NU Vetco 10k psi Frac Tree.Test tree void to 5000 psi f/15 charted min. Install"VR"plug in production outlet. Remove 5M Otis cap&DSA. Install 4"10M test flange.Test tree to 10k psi.Remove test flange. Install DSA and Otis tree cap connection.Pull"VR"plug.RU lubricator.Pull TWC. LD 4"DP from derrick utilizing mousehole(204 jts).Operations freeze protected 4 1/2"tubing&4 1/2"x 7" annulus w/100 bbls diesel to 2000'TVD. ""Released rig from ODSN-28 at 24:00 hrs on 1-1-2014— Page 8/8 Report Printed: 1/28/2014 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-28 PN3 50703206760000 Sperry Drilling Services Definitive Survey Report 03 January, 2014 HALLIBURTON imumminummimmommi Sperry Drilling Services Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-28 Well Position +N/-S 0.00 usft Northing: 6,031,113.39 usfl Latitude: 70°29'45.87 N +EI-W 0.00 usft Easting: 469,928.86 usfl Longitude: 150° 14'45.21 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 13.50 usft Wellbore ODSN-28 PN3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) IGRF200510 12/23/2013 20.24 80.81 57,924 Design ODSN-28 PN3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 42.70 0.00 0.00 9.08 Survey Program Date 1/3/2014 From To Survey (usft) (usft) Survey(Wellbore) Tool Name Description Start Date 144.00 826.00 ODSN-28 PN3(ODSN-28 PN3) SRG-SS Surface readout gyro single shot 11/04/2013 869.58 19,219.58 ODSN-28 PN3(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/07/2013 5,558.11 10,118.10 ODSN-28 PN3(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/07/2013 10,135.09 12,749.74 ODSN-28 PN3(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/07/2013 12,773.00 19,219.58 ODSN-28 PN3(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:lIFR dec&3-axis correction+sag 11/07/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,113.39 469,928.86 0.00 0.00 UNDEFINED 144.00 0.53 29.05 144.00 87.80 0.41 0.23 6,031,113.80 469,929.09 0.52 0.44 SRG-SS(1) 166.00 0.75 85.91 166.00 109.80 0.51 0.42 6,031,113.90 469,929.28 2.91 0.57 SRG-SS(1) 261.00 3.57 130.54 260.92 204.72 -1.37 3.29 6,031,112.01 469,932.14 3.24 -0.83 SRG-SS(1) 356.00 6.16 133.58 355.57 299.37 -6.81 9.23 6,031,106.55 469,938.06 2.74 -5.26 SRG-SS(1) 447.00 9.29 123.84 445.74 389.54 -14.27 18.87 6,031,099.05 469,947.67 3.72 -11.11 SRG-SS(1) 541.00 12.10 111.67 538.11 481.91 -22.13 34.33 6,031,091.12 469,963.10 3.82 -16.44 SRG-SS(1) 637.00 13.42 103.37 631.75 575.55 -28.42 54.52 6,031,084.75 469,983.26 2.35 -19.46 SRG-SS(1) 731.00 16.41 92.54 722.59 666.39 -31.54 78.41 6,031,081.54 470,007.14 4.34 -18.77 SRG-SS(1) 826.00 18.65 80.77 813.20 757.00 -29.69 106.82 6,031,083.27 470,035.55 4.40 -12.46 SRG-SS(1) 1/3/2014 11:40:43AM Page 2 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 869.58 18.60 74.78 854.50 798.30 -26.75 120.41 6,031,086.16 470,049.15 4.39 -7.41 MWD+IFR2+MS+sag(2) 963.07 17.39 71.02 943.42 887.22 -18.29 148.01 6,031,094.50 470,076.78 1.79 5.30 MWD+IFR2+MS+sag(2) 1,058.72 19.12 67.40 1,034.25 978.05 -7.62 175.99 6,031,105.06 470,104.80 2.16 20.25 MWD+IFR2+MS+sag(2) 1,152.91 23.30 66.03 1,122.04 1,065.84 5.88 207.27 6,031,118.43 470,136.13 4.47 38.52 MWD+IFR2+MS+sag(2) 1,248.35 23.63 63.90 1,209.59 1,153.39 21.96 241.69 6,031,134.37 470,170.62 0.95 59.83 MWD+IFR2+MS+sag(2) 1,344.09 27.40 62.46 1,295.98 1,239.78 40.60 278.47 6,031,152.86 470,207.47 3.99 84.04 MWD+IFR2+MS+sag(2) 1,438.02 30.17 62.61 1,378.29 1,322.10 61.45 318.60 6,031,173.55 470,247.68 2.95 110.96 MWD+IFR2+MS+sag(2) 1,534.36 34.72 62.24 1,459.58 1,403.38 85.38 364.40 6,031,197.29 470,293.56 4.73 141.82 MWD+IFR2+MS+sag(2) 1,631.54 37.05 62.23 1,538.30 1,482.11 111.92 414.80 6,031,223.62 470,344.07 2.40 175.98 MWD+IFR2+MS+sag(2) 1,720.15 40.62 60.56 1,607.32 1,551.12 138.54 463.56 6,031,250.04 470,392.93 4.20 209.96 MWD+IFR2+MS+sag(2) 1,820.10 45.03 60.91 1,680.61 1,624.41 171.74 522.82 6,031,283.00 470,452.31 4.42 252.09 MWD+IFR2+MS+sag(2) 1,914.58 48.82 59.82 1,745.12 1,688.92 205.87 582.78 6,031,316.89 470,512.41 4.10 295.27 MWD+IFR2+MS+sag(2) 2,009.49 50.66 59.76 1,806.46 1,750.26 242.32 645.37 6,031,353.07 470,575.14 1.94 341.13 MWD+IFR2+MS+sag(2) 2,102.74 54.30 58.88 1,863.24 1,807.04 280.06 708.96 6,031,390.55 470,638.87 3.97 388.43 MWD+IFR2+MS+sag(2) 2,197.98 56.36 56.97 1,917.42 1,861.22 321.66 775.31 6,031,431.88 470,705.39 2.72 439.99 MWD+IFR2+MS+sag(2) 2,292.47 60.95 56.30 1,966.56 1,910.36 366.04 842.69 6,031,475.98 470,772.94 4.90 494.44 MWD+IFR2+MS+sag(2) 2,388.44 63.76 55.08 2,011.08 1,954.88 413.97 912.89 6,031,523.62 470,843.33 3.14 552.85 MWD+IFR2+MS+sag(2) 2,478.79 62.44 54.45 2,051.96 1,995.76 460.45 978.70 6,031,569.83 470,909.32 1.59 609.13 MWD+IFR2+MS+sag(2) 2,575.73 60.97 54.91 2,097.91 2,041.71 509.80 1,048.35 6,031,618.89 470,979.16 1.57 668.85 MWD+IFR2+MS+sag(2) 2,669.09 62.10 56.14 2,142.41 2,086.21 556.25 1,116.01 6,031,665.07 471,047.00 1.68 725.40 MWD+IFR2+MS+sag(2) 2,764.66 59.41 57.01 2,189.10 2,132.90 602.19 1,185.59 6,031,710.72 471,116.76 2.92 781.74 MWD+IFR2+MS+sag(2) 2,861.03 58.61 57.19 2,238.71 2,182.51 647.06 1,254.95 6,031,755.30 471,186.30 0.85 837.00 MWD+IFR2+MS+sag(2) 2,954.24 59.42 54.32 2,286.71 2,230.51 692.03 1,320.99 6,031,800.00 471,252.51 2.78 891.82 MWD+IFR2+MS+sag(2) 3,049.93 62.15 54.54 2,333.41 2,277.21 740.60 1,388.92 6,031,848.29 471,320.63 2.86 950.51 MWD+IFR2+MS+sag(2) 3,144.85 63.31 56.29 2,376.90 2,320.70 788.48 1,458.38 6,031,895.89 471,390.28 2.04 1,008.76 MWD+IFR2+MS+sag(2) 3,239.88 61.43 57.06 2,420.97 2,364.77 834.74 1,528.72 6,031,941.86 471,460.80 2.10 1,065.53 MWD+IFR2+MS+sag(2) 3,335.69 64.95 58.76 2,464.18 2,407.98 880.14 1,601.17 6,031,986.96 471,533.41 4.00 1,121.80 MWD+IFR2+MS+sag(2) 3,429.55 64.27 59.67 2,504.43 2,448.23 923.54 1,674.01 6,032,030.06 471,606.43 1.14 1,176.15 MWD+IFR2+MS+sag(2) 3,524.98 64.50 60.19 2,545.68 2,489.48 966.66 1,748.48 6,032,072.87 471,681.06 0.55 1,230.48 MWD+IFR2+MS+sag(2) 3,619.98 63.78 61.17 2,587.12 2,530.92 1,008.52 1,823.01 6,032,114.43 471,755.76 1.20 1,283.58 MWD+IFR2+MS+sag(2) 3,715.39 63.48 61.08 2,629.50 2,573.30 1,049.80 1,897.87 6,032,155.40 471,830.77 0.33 1,336.15 MWD+IFR2+MS+sag(2) 3,810.21 64.76 59.29 2,670.89 2,614.69 1,092.22 1,971.88 6,032,197.52 471,904.94 2.17 1,389.72 MWD+IFR2+MS+sag(2) 3,904.86 65.14 59.24 2,710.96 2,654.76 1,136.04 2,045.58 6,032,241.04 471,978.81 0.40 1,444.63 MWD+IFR2+MS+sag(2) 4,000.82 66.53 58.87 2,750.24 2,694.04 1,181.06 2,120.67 6,032,285.75 472,054.08 1.49 1,500.93 MWD+IFR2+MS+sag(2) 4,096.11 66.20 56.40 2,788.45 2,732.25 1,227.79 2,194.39 6,032,332.17 472,127.99 2.40 1,558.70 MWD+IFR2+MS+sag(2) 4,190.77 64.62 56.50 2,827.84 2,771.64 1,275.36 2,266.13 6,032,379.44 472,199.90 1.67 1,617.00 MWD+IFR2+MS+sag(2) 4,285.93 61.50 57.77 2,870.95 2,814.75 1,321.39 2,337.37 6,032,425.19 472,271.32 3.49 1,673.70 MWD+IFR2+MS+sag(2) 4,382.06 62.50 58.30 2,916.08 2,859.88 1,366.33 2,409.37 6,032,469.82 472,343.50 1.15 1,729.44 MWD+IFR2+MS+sag(2) 4,476.82 63.81 58.66 2,958.87 2,902.67 1,410.53 2,481.45 6,032,513.73 472,415.75 1.42 1,784.46 MWD+IFR2+MS+sag(2) 4,572.11 62.87 57.51 3,001.63 2,945.43 1,455.54 2,553.73 6,032,558.45 472,488.20 1.46 1,840.31 MWD+IFR2+MS+sag(2) 1/32014 11:40:43AM Page 3 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°110(r) (ft) Survey Tool Name 4,667.21 63.25 57.47 3,044.71 2,988.51 1,501.11 2,625.23 6,032,603.72 472,559.88 0.40 1,896.59 MWD+IFR2+MS+sag(2) 4,762.03 62.08 56.19 3,088.25 3,032.05 1,547.19 2,695.73 6,032,649.51 472,630.56 1.72 1,953.22 MWD+IFR2+MS+sag(2) 4,857.07 61.47 56.72 3,133.20 3,077.00 1,593.46 2,765.52 6,032,695.49 472,700.53 0.81 2,009.93 MWD+IFR2+MS+sag(2) 4,952.91 61.78 57.10 3,178.75 3,122.55 1,639.50 2,836.17 6,032,741.24 472,771.36 0.48 2,066.54 MWD+IFR2+MS+sag(2) 5,045.42 61.61 57.77 3,222.61 3,166.41 1,683.34 2,904.81 6,032,784.80 472,840.17 0.66 2,120.66 MWD+IFR2+MS+sag(2) 5,140.64 62.49 57.88 3,267.24 3,211.04 1,728.13 2,976.01 6,032,829.29 472,911.54 0.93 2,176.13 MWD+IFR2+MS+sag(2) 5,237.31 63.33 58.02 3,311.27 3,255.07 1,773.80 3,048.96 6,032,874.66 472,984.66 0.88 2,232.74 MWD+IFR2+MS+sag(2) 5,331.89 62.17 58.50 3,354.57 3,298.37 1,818.03 3,120.46 6,032,918.60 473,056.34 1.31 2,287.70 MWD+IFR2+MS+sag(2) 5,426.11 63.08 58.75 3,397.89 3,341.69 1,861.59 3,191.90 6,032,961.87 473,127.94 0.99 2,341.99 MWD+IFR2+MS+sag(2) 5,508.18 63.80 58.77 3,434.59 3,378.39 1,899.66 3,254.66 6,032,999.68 473,190.86 0.88 2,389.49 MWD+IFR2+MS+sag(2) 5,558.11 64.39 55.61 3,456.41 3,400.21 1,924.00 3,292.40 6,033,023.86 473,228.69 5.81 2,419.47 MWD+IFR2+MS+sag(3) 5,653.18 63.93 58.28 3,497.85 3,441.65 1,970.67 3,364.10 6,033,070.24 473,300.58 2.57 2,476.87 MWD+IFR2+MS+sag(3) 5,746.81 62.76 58.66 3,539.85 3,483.65 2,014.43 3,435.43 6,033,113.70 473,372.07 1.30 2,531.34 MWD+IFR2+MS+sag(3) 5,842.84 62.69 57.85 3,583.86 3,527.66 2,059.33 3,508.01 6,033,158.31 473,444.83 0.75 2,587.14 MWD+IFR2+MS+sag(3) 5,938.43 62.37 57.14 3,627.96 3,571.76 2,104.91 3,579.54 6,033,203.59 473,516.53 0.74 2,643.43 MWD+IFR2+MS+sag(3) 6,033.93 62.02 58.06 3,672.50 3,616.30 2,150.17 3,650.86 6,033,248.56 473,588.03 0.93 2,699.38 MWD+IFR2+MS+sag(3) 6,127.16 62.31 59.46 3,716.04 3,659.84 2,192.92 3,721.35 6,033,291.03 473,658.68 1.36 2,752.72 MWD+IFR2+MS+sag(3) 6,221.98 62.51 59.83 3,759.95 3,703.75 2,235.39 3,793.86 6,033,333.20 473,731.36 0.41 2,806.10 MWD+IFR2+MS+sag(3) 6,318.33 62.64 61.73 3,804.33 3,748.13 2,277.14 3,868.50 6,033,374.64 473,806.15 1.76 2,859.10 MWD+IFR2+MS+sag(3) 6,412.86 62.77 62.82 3,847.68 3,791.48 2,316.22 3,942.86 6,033,413.41 473,880.66 1.03 2,909.43 MWD+IFR2+MS+sag(3) 6,507.91 63.08 60.87 3,890.95 3,834.75 2,356.15 4,017.47 6,033,453.04 473,955.43 1.86 2,960.64 MWD+IFR2+MS+sag(3) 6,602.94 63.07 60.86 3,933.98 3,877.78 2,397.40 4,091.48 6,033,493.99 474,029.60 0.01 3,013.05 MWD+IFR2+MS+sag(3) 6,697.95 63.13 59.58 3,976.97 3,920.77 2,439.49 4,165.02 6,033,535.77 474,103.30 1.20 3,066.21 MWD+IFR2+MS+sag(3) 6,793.17 63.12 58.25 4,020.01 3,963.81 2,483.34 4,237.75 6,033,579.32 474,176.20 1.25 3,120.99 MWD+IFR2+MS+sag(3) 6,888.29 63.00 57.59 4,063.11 4,006.91 2,528.37 4,309.60 6,033,624.06 474,248.23 0.63 3,176.80 MWD+IFR2+MS+sag(3) 6,983.26 62.71 57.93 4,106.44 4,050.24 2,573.46 4,381.08 6,033,668.85 474,319.88 0.44 3,232.60 MWD+IFR2+MS+sag(3) 7,078.48 62.57 57.18 4,150.20 4,094.00 2,618.83 4,452.45 6,033,713.93 474,391.42 0.71 3,288.67 MWD+IFR2+MS+sag(3) 7,173.18 62.44 56.74 4,193.92 4,137.72 2,664.63 4,522.87 6,033,759.44 474,462.02 0.43 3,345.01 MWD+IFR2+MS+sag(3) 7,266.95 62.42 56.54 4,237.32 4,181.12 2,710.34 4,592.29 6,033,804.86 474,531.63 0.19 3,401.10 MWD+IFR2+MS+sag(3) 7,362.35 62.17 56.60 4,281.67 4,225.47 2,756.87 4,662.78 6,033,851.10 474,602.30 0.27 3,458.17 MWD+IFR2+MS+sag(3) 7,457.02 62.24 57.75 4,325.82 4,269.62 2,802.26 4,733.16 6,033,896.21 474,672.84 1.08 3,514.10 MWD+IFR2+MS+sag(3) 7,552.70 62.38 56.96 4,370.28 4,314.08 2,847.96 4,804.49 6,033,941.62 474,744.36 0.75 3,570.49 MWD+IFR2+MS+sag(3) 7,646.98 62.65 57.42 4,413.79 4,357.59 2,893.28 4,874.79 6,033,986.65 474,814.83 0.52 3,626.34 MWD+IFR2+MS+sag(3) 7,741.81 62.73 57.02 4,457.30 4,401.10 2,938.90 4,945.63 6,034,031.97 474,885.85 0.38 3,682.56 MWD+IFR2+MS+sag(3) 7,837.31 62.87 55.74 4,500.96 4,444.76 2,985.93 5,016.36 6,034,078.71 474,956.76 1.20 3,740.16 MWD+IFR2+MS+sag(3) 7,933.93 62.95 56.57 4,544.96 4,488.76 3,033.84 5,087.80 6,034,126.32 475,028.39 0.77 3,798.75 MWD+IFR2+MS+sag(3) 8,028.01 63.27 56.34 4,587.51 4,531.31 3,080.21 5,157.74 6,034,172.40 475,098.50 0.40 3,855.57 MWD+IFR2+MS+sag(3) 8,122.18 63.40 57.72 4,629.77 4,573.57 3,126.00 5,228.34 6,034,217.91 475,169.28 1.32 3,911.93 MWD+IFR2+MS+sag(3) 8,218.06 63.47 55.54 4,672.65 4,616.45 3,173.17 5,299.95 6,034,264.78 475,241.08 2.03 3,969.81 MWD+IFR2+MS+sag(3) 8,311.57 63.30 56.39 4,714.55 4,658.35 3,219.96 5,369.23 6,034,311.29 475,310.54 0.83 4,026.95 MWD+IFR2+MS+sag(3) 1/3/2014 11:40:43AM Page 4 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,406.95 63.27 57.30 4,757.42 4,701.22 3,266.56 5,440.56 6,034,357.59 475,382.05 0.85 4,084.21 MWD+IFR2+MS+sag(3) 8,501.96 63.35 57.11 4,800.10 4,743.90 3,312.53 5,511.91 6,034,403.27 475,453.58 0.20 4,140.88 MWD+IFR2+MS+sag(3) 8,597.00 63.05 57.46 4,842.95 4,786.75 3,358.38 5,583.29 6,034,448.83 475,525.13 0.46 4,197.41 MWD+IFR2+MS+sag(3) 8,692.43 62.92 57.88 4,886.30 4,830.10 3,403.85 5,655.12 6,034,494.00 475,597.15 0.42 4,253.65 MWD+IFR2+MS+sag(3) 8,787.54 62.83 58.76 4,929.66 4,873.46 3,448.30 5,727.16 6,034,538.16 475,669.35 0.83 4,308.91 MWD+IFR2+MS+sag(3) 8,883.31 62.86 57.29 4,973.37 4,917.17 3,493.43 5,799.44 6,034,582.98 475,741.81 1.37 4,364.88 MWD+IFR2+MS+sag(3) 8,978.15 62.55 58.37 5,016.87 4,960.67 3,538.30 5,870.78 6,034,627.56 475,813.32 1.06 4,420.45 MWD+IFR2+MS+sag(3) 9,073.73 62.23 58.24 5,061.16 5,004.96 3,582.80 5,942.84 6,034,671.77 475,885.56 0.36 4,475.76 MWD+IFR2+MS+sag(3) 9,168.46 62.39 58.21 5,105.18 5,048.98 3,626.97 6,014.15 6,034,715.64 475,957.04 0.17 4,530.63 MWD+IFR2+MS+sag(3) 9,263.28 62.22 58.99 5,149.25 5,093.05 3,670.71 6,085.81 6,034,759.09 476,028.87 0.75 4,585.14 MWD+IFR2+MS+sag(3) 9,359.16 62.67 59.27 5,193.61 5,137.41 3,714.33 6,158.77 6,034,802.41 476,102.00 0.54 4,639.72 MWD+IFR2+MS+sag(3) 9,453.94 63.13 60.19 5,236.78 5,180.58 3,756.85 6,231.64 6,034,844.63 476,175.03 0.99 4,693.21 MWD+IFR2+MS+sag(3) 9,548.78 63.14 59.44 5,279.64 5,223.44 3,799.39 6,304.78 6,034,886.87 476,248.33 0.71 4,746.76 MWD+IFR2+MS+sag(3) 9,644.53 62.86 59.87 5,323.11 5,266.91 3,842.49 6,378.40 6,034,929.67 476,322.12 0.50 4,800.94 MWD+IFR2+MS+sag(3) 9,740.25 62.72 59.00 5,366.88 5,310.68 3,885.78 6,451.70 6,034,972.66 476,395.59 0.82 4,855.25 MWD+IFR2+MS+sag(3) 9,834.46 62.59 58.10 5,410.15 5,353.95 3,929.44 6,523.09 6,035,016.03 476,467.14 0.86 4,909.63 MWD+IFR2+MS+sag(3) 9,929.75 62.79 55.38 5,453.88 5,397.68 3,975.87 6,593.88 6,035,062.16 476,538.11 2.54 4,966.65 MWD+IFR2+MS+sag(3) 10,024.35 62.72 53.42 5,497.19 5,440.99 4,024.83 6,662.26 6,035,110.84 476,606.69 1.84 5,025.79 MWD+IFR2+MS+sag(3) 10,118.10 62.56 49.48 5,540.29 5,484.09 4,076.70 6,727.36 6,035,162.44 476,671.99 3.74 5,087.28 MWD+IFR2+MS+sag(3) 10,135.09 62.48 49.24 5,548.13 5,491.93 4,086.52 6,738.80 6,035,172.21 476,683.46 1.34 5,098.78 MWD+IFR2+MS+sag(4) 10,186.81 62.59 47.67 5,571.98 5,515.79 4,116.95 6,773.14 6,035,202,50 476,717.93 2.70 5,134.26 MWD+IFR2+MS+sag(4) 10,230.39 62.31 45.68 5,592.14 5,535.94 4,143.46 6,801.25 6,035,228.90 476,746.14 4.10 5,164.87 MWD+IFR2+MS+sag(4) 10,282.00 61.72 42.91 5,616.36 5,560.16 4,176.08 6,833.07 6,035,261.38 476,778.09 4.88 5,202.10 MWD+IFR2+MS+sag(4) 10,327.07 61.19 40.32 5,637.90 5,581.70 4,205.67 6,859.36 6,035,290.86 476,804.50 5.18 5,235.47 MWD+IFR2+MS+sag(4) 10,376.12 62.02 38.83 5,661.23 5,605.03 4,238.93 6,886.85 6,035,324.01 476,832.12 3.16 5,272.65 MWD+IFR2+MS+sag(4) 10,419.68 62.36 37.18 5,681.55 5,625.35 4,269.29 6,910.57 6,035,354.27 476,855.96 3.44 5,306.37 MWD+IFR2+MS+sag(4) 10,470.62 61.84 34.15 5,705.39 5,649.19 4,305.85 6,936.82 6,035,390.72 476,882.35 5.35 5,346.62 MWD+IFR2+MS+sag(4) 10,515.76 61.14 31.76 5,726.94 5,670.74 4,339.13 6,958.40 6,035,423.91 476,904.06 4.90 5,382.89 MWD+IFR2+MS+sag(4) 10,565.11 61.31 29.96 5,750.70 5,694.50 4,376.26 6,980.58 6,035,460.95 476,926.40 3.22 5,423.05 MWD+IFR2+MS+sag(4) 10,611.76 61.62 27.60 5,772.99 5,716.79 4,412.18 7,000.31 6,035,496.78 476,946.27 4.49 5,461.63 MWD+IFR2+MS+sag(4) 10,661.71 62.20 25.92 5,796.51 5,740.31 4,451.53 7,020.15 6,035,536.04 476,966.26 3.19 5,503.62 MWD+IFR2+MS+sag(4) 10,706.63 62.86 24.00 5,817.23 5,761.03 4,487.66 7,036.96 6,035,572.10 476,983.22 4.07 5,541.95 MWD+IFR2+MS+sag(4) 10,756.67 63.08 22.10 5,839.97 5,783.77 4,528.67 7,054.41 6,035,613.04 477,000.84 3.41 5,585.20 MWD+IFR2+MS+sag(4) 10,802.02 62.94 19.79 5,860.56 5,804.36 4,566.41 7,068.86 6,035,650.71 477,015.43 4.55 5,624.74 MWD+IFR2+MS+sag(4) 10,851.48 63.34 17.85 5,882.90 5,826.70 4,608.17 7,083.09 6,035,692.41 477,029.83 3.59 5,668.23 MWD+IFR2+MS+sag(4) 10,897.31 63.17 15.99 5,903.53 5,847.33 4,647.32 7,095.00 6,035,731.51 477,041.90 3.64 5,708.77 MWD+IFR2+MS+sag(4) 10,990.67 63.33 13.03 5,945.56 5,889.36 4,728.02 7,115.89 6,035,812.12 477,063.11 2.84 5,791.75 MWD+IFR2+MS+sag(4) 11,086.03 65.06 8.18 5,987.09 5,930.89 4,812.37 7,131.65 6,035,896.40 477,079.21 4.92 5,877.54 MWD+IFR2+MS+sag(4) 11,181.39 66.34 3.65 6,026.35 5,970.15 4,898.79 7,140.59 6,035,982.77 477,088.50 4.53 5,964.28 MWD+IFR2+MS+sag(4) 11,276.50 67.45 359.70 6,063.68 6,007.48 4,986.21 7,143.13 6,036,070.17 477,091.40 3.99 6,051.01 MWD+IFR2+MS+sag(4) 1/32014 11:40:43AM Page 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100.) (ft) Survey Tool Name 11,373.01 68.55 356.14 6,099.84 6,043.64 5,075.61 7,139.87 6,036,159.58 477,088.50 3.60 6,138.78 MWD+IFR2+MS+sag(4) 11,467.35 69.56 352.76 6,133.58 6,077.38 5,163.29 7,131.35 6,036,247.28 477,080.33 3.51 6,224.01 MWD+IFR2+MS+sag(4) 11,561.98 71.38 349.09 6,165.22 6,109.02 5,251.33 7,117.27 6,036,335.37 477,066.61 4.13 6,308.73 MWD+IFR2+MS+sag(4) 11,655.82 73.08 345.31 6,193.87 6,137.67 5,338.45 7,097.46 6,036,422.56 477,047.15 4.24 6,391.63 MWD+IFR2+MS+sag(4) 11,751.29 75.00 341.05 6,220.13 6,163.93 5,426.28 7,070.89 6,036,510.49 477,020.94 4.74 6,474.16 MWD+IFR2+MS+sag(4) 11,846.91 75.32 336.58 6,244.63 6,188.43 5,512.44 7,037.50 6,036,596.77 476,987.90 4.53 6,553.97 MWD+IFR2+MS+sag(4) 11,941.00 76.90 330.80 6,267.23 6,211.03 5,594.27 6,997.02 6,036,678.75 476,947.76 6.19 6,628.39 MWD+IFR2+MS+sag(4) 12,037.28 79.50 325.98 6,286.93 6,230.73 5,674.49 6,947.62 6,036,759.17 476,898.69 5.59 6,699.81 MWD+IFR2+MS+sag(4) 12,132.12 81.12 322.59 6,302.90 6,246.70 5,750.37 6,893.06 6,036,835.26 476,844.44 3.92 6,766.13 MWD+IFR2+MS+sag(4) 12,227.80 82.87 321.25 6,316.22 6,260.02 5,824.95 6,834.62 6,036,910.07 476,786.31 2.30 6,830.55 MWD+IFR2+MS+sag(4) 12,322.87 85.16 320.44 6,326.14 6,269.94 5,898.26 6,774.92 6,036,983.61 476,726.92 2.55 6,893.52 MWD+IFR2+MS+sag(4) 12,417.58 85.53 320.50 6,333.82 6,277.62 5,971.07 6,714.84 6,037,056.66 476,667.13 0.40 6,955.94 MWD+IFR2+MS+sag(4) 12,511.06 85.53 320.85 6,341.11 6,284.91 6,043.16 6,655.78 6,037,128.98 476,608.37 0.37 7,017.81 MWD+IFR2+MS+sag(4) 12,606.17 85.72 320.44 6,348.36 6,292.16 6,116.49 6,595.65 6,037,202.54 476,548.54 0.47 7,080.72 MWD+IFR2+MS+sag(4) 12,701.63 86.28 320.10 6,355.02 6,298.82 6,189.72 6,534.78 6,037,276.02 476,487.98 0.69 7,143.44 MWD+IFR2+MS+sag(4) 12,749.74 87.64 319.14 6,357.57 6,301.37 6,226.32 6,503.66 6,037,312.74 476,457.00 3.46 7,174.66 MWD+IFR2+MS+sag(4) 12,773.00 88.48 319.17 6,358.36 6,302.16 6,243.91 6,488.45 6,037,330.38 476,441.87 3.61 7,189.63 MWD+IFR2+MS+sag(5) 12,869.95 89.47 320.49 6,360.10 6,303.90 6,317.97 6,425.93 6,037,404.69 476,379.65 1.70 7,252.90 MWD+IFR2+MS+sag(5) 12,966.50 88.54 317.58 6,361.77 6,305.57 6,390.86 6,362.65 6,037,477.83 476,316.67 3.16 7,314.89 MWD+IFR2+MS+sag(5) 13,062.81 88.85 317.84 6,363.97 6,307.77 6,462.09 6,297.86 6,037,549.31 476,252.18 0.42 7,375.00 MWD+IFR2+MS+sag(5) 13,158.57 89.29 316.90 6,365.52 6,309.32 6,532.53 6,233.01 6,037,620.01 476,187.63 1.08 7,434.32 MWD+IFR2+MS+sag(5) 13,255.39 89.66 318.21 6,366.41 6,310.21 6,603.97 6,167.67 6,037,691.71 476,122.59 1.41 7,494.56 MWD+IFR2+MS+sag(5) 13,351.75 89.84 317.45 6,366.83 6,310.63 6,675.39 6,102.99 6,037,763.38 476,058.19 0.81 7,554.87 MWD+IFR2+MS+sag(5) 13,448.75 89.88 318.20 6,367.07 6,310.87 6,747.28 6,037.86 6,037,835.52 475,993.37 0.77 7,615.58 MWD+IFR2+MS+sag(5) 13,544.95 89.57 316.17 6,367.53 6,311.33 6,817.84 5,972.48 6,037,906.34 475,928.28 2.13 7,674.94 MWD+IFR2+MS+sag(5) 13,641.08 90.40 317.83 6,367.55 6,311.35 6,888.14 5,906.93 6,037,976.90 475,863.02 1.93 7,734.02 MWD+IFR2+MS+sag(5) 13,737.01 90.77 318.36 6,366.57 6,310.37 6,959.53 5,842.86 6,038,048.54 475,799.24 0.67 7,794.40 MWD+IFR2+MS+sag(5) 13,831.84 89.35 317.58 6,366.47 6,310.27 7,029.97 5,779.37 6,038,119.23 475,736.05 1.71 7,853.94 MWD+IFR2+MS+sag(5) 13,930.56 89.53 316.04 6,367.44 6,311.24 7,101.94 5,711.81 6,038,191.46 475,668.79 1.57 7,914.34 MWD+IFR2+MS+sag(5) 14,026.93 90.89 317.52 6,367.08 6,310.89 7,172.16 5,645.82 6,038,261.95 475,603.09 2.09 7,973.27 MWD+IFR2+MS+sag(5) 14,123.21 91.57 318.11 6,365.02 6,308.82 7,243.49 5,581.18 6,038,333.52 475,538.74 0.93 8,033.50 MWD+IFR2+MS+sag(5) 14,219.30 91.36 317.84 6,362.56 6,306.36 7,314.84 5,516.87 6,038,405.13 475,474.73 0.36 8,093.82 MWD+IFR2+MS+sag(5) 14,316.91 90.95 316.25 6,360.59 6,304.39 7,386.27 5,450.38 6,038,476.82 475,408.53 1.68 8,153.85 MWD+IFR2+MS+sag(5) 14,412.45 91.20 316.50 6,358.80 6,302.60 7,455.41 5,384.47 6,038,546.22 475,342.91 0.37 8,211.73 MWD+IFR2+MS+sag(5) 14,507.74 91.39 316.13 6,356.65 6,300.45 7,524.30 5,318.67 6,038,615.37 475,277.40 0.44 8,269.37 MWD+IFR2+MS+sag(5) 14,605.41 90.89 314.66 6,354.70 6,298.50 7,593.83 5,250.10 6,038,685.17 475,209.12 1.59 8,327.20 MWD+IFR2+MS+sag(5) 14,700.78 90.09 315.26 6,353.89 6,297.69 7,661.21 5,182.62 6,038,752.82 475,141.92 1.05 8,383.10 MWD+IFR2+MS+sag(5) 14,796.96 88.67 315.00 6,354.93 6,298.73 7,729.37 5,114.77 6,038,821.24 475,074.35 1.50 8,439.69 MWD+IFR2+MS+sag(5) 14,893.14 89.66 315.82 6,356.33 6,300.13 7,797.86 5,047.26 6,038,889.99 475,007.12 1.34 8,496.67 MWD+IFR2+MS+sag(5) 14,990.39 90.03 316.77 6,356.59 6,300.39 7,868.16 4,980.07 6,038,960.56 474,940.22 1.05 8,555.48 MWD+IFR2+MS+sag(5) 1/3/2014 11:40:43AM Page 6 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 15,085.78 89.59 317.21 6,356.91 6,300.71 7,937.91 4,915.00 6,039,030.57 474,875.44 0.65 8,614.09 MWD+IFR2+MS+sag(5) 15,181.10 90.86 320.02 6,356.54 6,300.34 8,009.42 4,851.99 6,039,102.32 474,812.73 3.23 8,674.76 MWD+IFR2+MS+sag(5) 15,279.73 90.21 319.21 6,355.62 6,299.42 8,084.54 4,788.09 6,039,177.70 474,749.14 1.05 8,738.86 MWD+IFR2+MS+sag(5) 15,374.65 90.15 321.82 6,355.32 6,299.12 8,157.79 4,727.74 6,039,251.18 474,689.09 2.75 8,801.67 MWD+IFR2+MS+sag(5) 15,470.42 89.97 319.92 6,355.22 6,299.02 8,232.08 4,667.30 6,039,325.71 474,628.96 1.99 8,865.48 MWD+IFR2+MS+sag(5) 15,565.80 90.40 319.45 6,354.91 6,298.71 8,304.81 4,605.59 6,039,398.68 474,567.55 0.67 8,927.56 MWD+IFR2+MS+sag(5) 15,661.86 90.71 319.99 6,353.98 6,297.78 8,378.08 4,543.49 6,039,472.20 474,505.75 0.65 8,990.12 MWD+IFR2+MS+sag(5) 15,760.65 89.97 320.19 6,353.39 6,297.19 8,453.86 4,480.11 6,039,548.22 474,442.69 0.78 9,054.95 MWD+IFR2+MS+sag(5) 15,854.61 89.66 319.27 6,353.70 6,297.50 8,525.55 4,419.38 6,039,620.15 474,382.25 1.03 9,116.15 MWD+IFR2+MS+sag(5) 15,951.17 90.09 318.55 6,353.91 6,297.71 8,598.33 4,355.91 6,039,693.17 474,319.09 0.87 9,178.00 MWD+IFR2+MS+sag(5) 16,047.43 90.93 317.92 6,353.05 6,296.85 8,670.12 4,291.80 6,039,765.22 474,255.27 1.09 9,238.78 MWD+IFR2+MS+sag(5) 16,143.68 91.08 316.77 6,351.36 6,295.16 8,740.89 4,226.59 6,039,836.25 474,190.36 1.20 9,298.38 MWD+IFR2+MS+sag(5) 16,241.35 91.51 316.08 6,349.15 6,292.95 8,811.64 4,159.29 6,039,907.26 474,123.34 0.83 9,357.61 MWD+IFR2+MS+sag(5) 16,336.99 91.82 315.94 6,346.37 6,290.18 8,880.42 4,092.89 6,039,976.30 474,057.23 0.36 9,415.05 MWD+IFR2+MS+sag(5) 16,433.71 91.39 317.59 6,343.67 6,287.47 8,950.85 4,026.67 6,040,046.99 473,991.30 1.76 9,474.15 MWD+IFR2+MS+sag(5) 16,531.06 89.29 317.00 6,343.09 6,286.89 9,022.38 3,960.65 6,040,118.79 473,925.58 2.24 9,534.37 MWD+IFR2+MS+sag(5) 16,626.60 90.03 317.66 6,343.66 6,287.46 9,092.63 3,895.89 6,040,189.29 473,861.12 1.04 9,593.51 MWD+IFR2+MS+sag(5) 16,722.84 90.40 318.00 6,343.29 6,287.09 9,163.96 3,831.28 6,040,260.87 473,796.80 0.52 9,653.75 MWD+IFR2+MS+sag(5) 16,818.92 90.77 317.26 6,342.31 6,286.11 9,234.94 3,766.54 6,040,332.10 473,732.35 0.86 9,713.62 MWD+IFR2+MS+sag(5) 16,915.51 90.83 316.93 6,340.96 6,284.76 9,305.68 3,700.79 6,040,403.10 473,666.89 0.35 9,773.11 MWD+IFR2+MS+sag(5) 17,012.87 88.67 316.86 6,341.39 6,285.19 9,376.76 3,634.26 6,040,474.44 473,600.66 2.22 9,832.79 MWD+IFR2+MS+sag(5) 17,109.45 88.98 317.21 6,343.37 6,287.17 9,447.42 3,568.45 6,040,545.36 473,535.15 0.48 9,892.18 MWD+IFR2+MS+sag(5) 17,162.75 89.47 316.38 6,344.09 6,287.89 9,486.27 3,531.97 6,040,584.35 473,498.82 1.81 9,924.78 MWD+IFR2+MS+sag(5) 17,205.62 91.45 315.92 6,343.75 6,287.55 9,517.18 3,502.27 6,040,615.38 473,469.25 4.74 9,950.62 MWD+IFR2+MS+sag(5) 17,301.71 91.26 315.79 6,341.47 6,285.27 9,586.11 3,435.36 6,040,684.58 473,402.63 0.24 10,008.13 MWD+IFR2+MS+sag(5) 17,397.33 90.52 316.78 6,339.99 6,283.79 9,655.21 3,369.29 6,040,753.94 473,336.85 1.29 10,065.94 MWD+IFR2+MS+sag(5) 17,445.80 88.54 314.71 6,340.39 6,284.19 9,689.93 3,335.47 6,040,788.79 473,303.17 5.91 10,094.88 MWD+IFR2+MS+sag(5) 17,494.60 87.68 314.77 6,342.00 6,285.80 9,724.26 3,300.83 6,040,823.25 473,268.67 1.77 10,123.32 MWD+IFR2+MS+sag(5) 17,590.85 89.04 316.17 6,344.75 6,288.55 9,792.84 3,233.36 6,040,892.10 473,201.49 2.03 10,180.39 MWD+IFR2+MS+sag(5) 17,686.68 90.27 316.32 6,345.33 6,289.13 9,862.06 3,167.09 6,040,961.58 473,135.50 1.29 10,238.28 MWD+IFR2+MS+sag(5) 17,783.89 90.83 317.77 6,344.39 6,288.19 9,933.20 3,100.86 6,041,032.98 473,069.56 1.60 10,298.08 MWD+IFR2+MS+sag(5) 17,879.60 92.19 318.80 6,341.87 6,285.67 10,004.61 3,037.19 6,041,104.65 473,006.20 1.78 10,358.56 MWD+IFR2+MS+sag(5) 17,977.20 90.46 319.01 6,339.62 6,283.42 10,078.15 2,973.06 6,041,178.43 472,942.37 1.79 10,421.04 MWD+IFR2+MS+sag(5) 18,073.14 89.90 318.91 6,339.31 6,283.11 10,150.51 2,910.07 6,041,251.04 472,879.67 0.59 10,482.56 MWD+IFR2+MS+sag(5) 18,169.25 90.89 319.19 6,338.65 6,282.45 10,223.10 2,847.08 6,041,323.87 472,816.99 1.07 10,544.30 MWD+IFR2+MS+sag(5) 18,265.44 90.21 318.31 6,337.73 6,281.53 10,295.41 2,783.66 6,041,396.44 472,753.87 1.16 10,605.70 MWD+IFR2+MS+sag(5) 18,362.71 90.58 318.25 6,337.06 6,280.86 10,368.01 2,718.93 6,041,469.29 472,689.44 0.39 10,667.17 MWD+IFR2+MS+sag(5) 18,457.25 89.90 316.73 6,336.66 6,280.46 10,437.70 2,655.05 6,041,539.23 472,625.84 1.76 10,725.91 MWD+IFR2+MS+sag(5) 18,554.92 90.71 317.13 6,336.14 6,279.94 10,509.05 2,588.35 6,041,610.84 472,559.44 0.92 10,785.83 MWD+IFR2+MS+sag(5) 18,650.73 91.14 316.56 6,334.59 6,278.40 10,578.93 2,522.83 6,041,680.98 472,494.21 0.75 10,844.50 MWD+IFR2+MS+sag(5) 1/3/2014 11:40:43AM Page 7 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-28 North Reference: True Wellbore: ODSN-28 PN3 Survey Calculation Method: Minimum Curvature Design: ODSN-28 PN3 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section (usft) ( ) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18,712.21 87.00 316.57 6,335.59 6,279.39 10,623.56 2,480.57 6,041,725.78 472,452.14 6.73 10,881.90 MWD+IFR2+MS+sag(5) 18,747.24 87.06 317.60 6,337.41 6,281.21 10,649.18 2,456.75 6,041,751.49 472,428.43 2.94 10,903.44 MWD+IFR2+MS+sag(5) 18,841.39 85.30 317.21 6,343.68 6,287.48 10,718.33 2,393.18 6,041,820.89 472,365.14 1.91 10,961.70 MWD+IFR2+MS+sag(5) 18,938.10 85.58 317.28 6,351.37 6,295.17 10,789.12 2,327.73 6,041,891.94 472,299.99 0.30 11,021.27 MWD+IFR2+MS+sag(5) 19,027.99 86.01 317.20 6,357.96 6,301.76 10,854.94 2,266.87 6,041,958.00 472,239.39 0.49 11,076.66 MWD+IFR2+MS+sag(5) 19,124.02 85.51 317.82 6,365.06 6,308.86 10,925.56 2,202.18 6,042,028.87 472,175.00 0.83 11,136.18 MWD+IFR2+MS+sag(5) 19,219.58 86.88 318.28 6,371.40 6,315.20 10,996.47 2,138.44 6,042,100.03 472,111.56 1.51 11,196.15 MWD+IFR2+MS+sag(5) 19,329.00. 86.88 318.28 6,377.36 6,321.16 11,078.02 2,065.73 6,042,181.87 472,039.18 0.00 11,265.20 PROJECTED to TD 1/3/2014 11:40:43AM Page 8 COMPASS 5000.1 Build 61 2 '5;68 RECEIVED PIONEER DATA LOGGED FEB 0 6 2014 2./7/2014 NATURAL RESOURCES ALASKA MK BENDER AOGCC Letter of Transmittal Date: February 5, 2014 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Makana Bender 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter o Maps X Report X Other—Logs ❑ Agreement DETAIL QTY DESCRIPTION Well Name: ODSN-28(50-703-20676-0000) 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. Received by: 6.4 Date: 217 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 RECEIVED PIONEER JAN 282014 NATURAL RESOURCES ALASKA AOGCC Letter of Transmittal DATALQQGGGED MK BENDER Date: January 27, 2014 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Makana Bender 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED o Letter ❑ Maps X Report X Other—Logs ❑ Agreement DETAIL QTY DESCRIPTION Well Name: ODSN-04 (50-703-20670-0000) ODSN-04 PB1 (50-703-20670-7000) 2 CD-Roms ODSN-28 (50-703-20676-0000) 14 Well Logs See Details Below We request that all data be treated as confidential information. Thank you. Received by: r? (5-10Ged...C1. Date: k 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 0. January 27, 2014 QTY DESCRIPTION ODSN-04 (50-703-20670-0000) 1 CD Digital Graphic Logs—Digital Data 6 Well Logs DGR, EWR-Phase 4, ABG, ALD, CTN, Horizontal Presentation (1:240, 1:600) MD; ROP, DGR,ABG, ALD,XBAT(1:240, 1:600) MD; ROP, DGR, EWR-Phase 4, ABG, ALD, CTN Horizontal Presentation(1:240, 1:600) ODSN-04 PB1 (50-703-20670-7000) 4 Well Logs DGR, EWR-Phase 4, ABG,ALD, CTN, Repeat Presentation(1:240, 1:600)TVD; ROP, DGR, EWR-Phase 4, ABG, ALD, CTN Horizontal Presentation Repeat Presentation(1:240, 1:600) MD ------------- ODSN-28 (50-703-20676-0000) 1 CD Digital Graphic Logs—Digital Data 4 Well Logs ROP, DGR, EWR-Phase 4, ABG, ALD, CTN Horizontal Presentation(1:240, 1:600) MD DGR, EWR-Phase 4, ABG, ALD, CTN, Reverted Section(1:240, 1:600)TVD • Page 2 STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I.Suprv,-.1 (- 1i �t,4rA I _ u BOPE Test Report Comm ao� It- L7�Sti � Contractor/Rig No.: Nabors 19AC PTD#: 2131480 - DATE: 12/26/2013 ' Inspector Lou Grimaldi - Insp Source Operator: PIONEER NATURAL RESOURCES ALA Operator Rep: Klepzig/Haberthur Rig Rep: Ashley/Finkbiner Inspector Type Operation: DRILL Rams: Annular: Valves: Inspection No: bopLG131227193502 Type Test: BIWKLY Test Pressure: 250/4500 - 250/2500- 250/4500 - Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F 1 Location Gen.: P Trip Tank P _ P System Pressure 3050 _ P Housekeeping: P _ Pit Level Indicators P P Pressure After Closure 2100 - P _ PTD On Location P Flow Indicator P P 200 PSI Attained 23 P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 100 - P Well Sign P H2S Gas Detector P P - ! Blind Switch Covers: _ _P Drl.Rig P - MS Misc NA NA Nitgn. Bottles(avg): 5 x 1850 - P - Hazard Sec. P ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 1 P _' Stripper 0 None NA No.Valves 14 P Lower Kelly 1 P - Annular Preventer 1 11" - FP Manual Chokes 1 P - Ball Type 1 P #1 Rams 1 2 7/8" x 5" P Hydraulic Chokes 1 P Inside BOP 1 P #2 Rams 1 11" blind P CH Misc 0 NA FSV Misc 0 NA #3 Rams 1 2 7/8" x 5" P #4 Rams 0 None NA #5 Rams 0 None NA INSIDE REEL VALVES: #6 Rams 0 None NA (Valid for Coil Rigs Only) Choke Ln.Valves 1 3 1/8 5M P Quantity P/F HCR Valves 2 3 1/8 5M p . Inside Reel Valves 0 NA Kill Line Valves 2 3 1/8&2"5M P Check Valve 0 None NA BOP Misc 0 None NA Number of Failures: 1 - Test Results Test Time 4 Remarks: Test spanned three days due to well control problem during test.When test was resumed it was started over and all BOPE were tested again without failure.Annular failure is due to element visually bad and changed out_prior to test beginning.Very good test procedure and good recognition of well control issue followed by proper procedure to bring well back under control. ._...... . .. ....... ?-r6 � ►3 - i4`� RECEIVED PIONEER `EL 272013 NATURAL RESOURCES ALASKA AOGCC Letter of Transmittal Date: December 26, 2013 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Makana Bender 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report X Other— Dry samples ❑ Agreement DETAIL QTY DESCRIPTION Well Name: ODSN-28 (50-703-20676-0000) 4 Boxes of Well Cutting Samples Details on next page We request that all data be treated as confidential information. Thank you. Received by: C1d0 , - Date: \L I Z -( "2-o\ 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 Prj GI3 - Iy`g O 0 O `T) a) 2 - zLa • Orn N J E N N HCO N E Z — �' N ca ._ 1— W M u) L C 7 (A 00 0 O O o N U • (B c N 0 (n .t6 J -p C C C N O p N OU N C O D p O 0 co co co co N N N N Z 0 0 0 0 O 0 0 0 d 0 Z � 0 .y O CO co CO N C W CO CO CO N- L CD N 0. co = cn d O O O O) 10 O O N CD CO 0) 0 r r 0 W O LO CD O CD W O O 0) CO CO CNI W r s- c- c- r O C ~ d E O CL O WZO' ce a) Q Loo m Y M N O O O O E pip — N Co • la ' N X �)Z � O 0 O Lij y,ruie- LDS?? -z PT1 213i4�3<) Regg, James B (DOA) From: OoogurukDrillingSupervisor[Oooguruk.DrillingCompanyMan@pxd.com] Sent: Thursday, December 26, 2013 9:32 AM To: DOA AOGCC Prudhoe Bay I`e' i(t.,(lit Subject: Nabors 19AC BOPE closure for Well Control Z Gentlemen; Date, Time of BOPE Use: 12/24/2014, 1900 hrs. Well/Location/PTD #: ODSN-28/PNR-ODS/213148. Rig Name: Nabors Rig 19AC. - Operator Contact: Rodney Klepzig, PNR Senior Drilling Supervisor. Tel#907-670-6606. Operations Summary: After installing BOPE test plug the lower annulus outer valve was opened to monitor the wellbore during the BOPE test. At this time a small amount of fluid observed coming out of the annulus valve being caught in a 5 gal bucket. The fluid amount was monitored to determine if it was residual from the wellhead. After 2 bbls flowed back BOPE's were drained and test plug was removed. Well continued to flow at%2-1 bbl per hr. Well was shut in to monitor any pressure build up. No pressure built up so well was opened back up for monitoring purposes. The thought at this time it was due to mud lost to hole during the drilling process and the formation was ballooning back. BOPE Used: Blind Rams. Reason of BOPE Use: Well flowing. Action Taken/To Be Taken: Continued to monitor well for 3 hrs. until 2200 hrs with a gain of 4.5 bbls (1.5 bph). Shut the well in with the blind rams at this time. After 1 hr at 2300 hrs the pressure built up to 20 psi. Open well back up and gained another 1.5 bbls after 1 hr. Continued to monitor well until 0300 hrs on 12/25/14. Gained another 6 bbls. Well was shut in with 15-20 psi on the choke gauge. The decision was made to RIH with a circulating assembly and circulate 10.0 ppg MOBM surface to surface. During the trip in the well quit flowing. We think this was due to the surge from the downward movement of the drill string creating higher ECD's. Circulated 10.0 ppg mud surface to surface through rig choke manifold. Final shut in pressure 0 psi. Opened up the well and observed the well for 15 minutes for a static condition. After 30 minutes fluid in the wellbore dropped 2'. Decision was made to POH. Complete BOPE test to be completed prior to commencing operations. Rdretc i4zi PIONEER NATURAL RESOURCES Senior Drilling Supervisor Office# 907-670-6606 Cell # 907-854-9815 1 E a x#907-670-6673 E-Mail rod.klepzig@pxd.com This email was sent on 12/26/13 at 9:31 AM 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. 2 w w\ or Tit �l // s THE STATE Alaska Oil and Gas f?; " �' ' °fALAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue LASy6•P Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Alex Vaughan Sr. Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-28 Pioneer Natural Resources Alaska, Inc. Permit No: 213-148 revised Surface Location: 2997' FSL, 1070' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 3807' FSL, 4523' FEL, SEC. 36, T14N, R7E, UM Dear Mr. Vaughan: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated October 9, 2013. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this 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 AOGCC 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 AOGCC 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 AOGCC order,or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ds#4. Cathy P. oerster Chair DATED this W day of December, 2013. RECEIVED STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMMI• IN DEC 16 20'i3 PERMIT TO DRILL Nh 20 AAC 25.005 —A- LSSA,— 04 AL G co 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑., • Service- Wiinj 0 Single Zone ❑✓ , 1 c.Specify if well is proposed for: Drill Q • Lateral 0 Stratigraphic Test 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas ❑ Gas Hydrates 0 Redril 0 Reentry 0 Exploratory 0 Service- WAG ❑ Service-Disp 0 Geothermal ❑ Shale Gas 0 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 • ODSN-28 ' 3.Address: 700 G Street, Suite#600 6.Proposed Depth: 12.Field/Pool(s): Anchorage,AK 99501 MD: 19,727' • ND: 6345' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): , Oooguruk-Nuiqsut Oil Pool • Surface: 2997'FSL, 1070' FEL, Sec. 11,T13N, R7E, UM ADL 355036/ADL 389950/ADL 389958 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3950'FSL,4969'FEL,Sec.6,T13N, R8E, UM 417497 11/4/2013 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3807'FSL,4523'FEL,Sec. 36,T14N, R7E, UM 5760+2533+2560 • 189' 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-469928.86 - y-6031113.39 . Zone-ASP 4 - GL Elevation above MSL: . 13.5 feet to Same Pool: 374'away from ODSN 02 1 16.Deviated wells: Kickoff depth: 250 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91.11 degrees . Downhole: 3240 ' Surface: 2541 ' 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 6-1/8" 4-1/2" 12.6# C-110 Hyd 521 7,118 ' 12,609 6356' 19,727 6,345 Uncemented 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural 158' 16" Driven 158' 158' Surface 5,506' 11-3/4" 760 sx PF'L';700 sx Class'G' 5,549 3,452' Intermediate 1 4762' 9-5/8" 386 sx,15.8 ppg,Class'G' 10,152' 5,556 Intermediate 2 12,719' 7" 529 sx 15.8 ppg, Class'G' 12,762' 6,358 Perforation Depth MD(ft): N/A Perforation Depth ND(ft): N/A 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot 0 Shallow Hazard Analysis Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan, 343-2186 Email alex.vaughanCa pxd.com Printed Name Alex Vau han Title Sr. Drilling Engineer Prepared By:Alex Vaughan,343-2186 Signature Phone 343-2186 Date 12/16/2013 Commission Use Only Permit to Drill �l API Number: _ Permit Approval (}-� See cover letter for other Number: a 1,5 8 t 3_ 50- 71-b3-02,O(Q�`(y2 -00 —00 Date: t`f'\a 0 ✓ requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: lil Other: 'TZ-S-4--- TSSamples req'd: Yes 0 No Mud log req'd:Yes❑ Nora/Lig-60S` PO t GG ,4- H2S measures: Yes 0 No Directional svy req'd:Yes U"No❑ .SSpacing exception req'd: Yes 0 NoE " Inclination-only svy req'd:Yes 0 No� ru��v 1 r l.- CT • F F . CT APPROVED BY Approved b 7! ((-4, COMMISSIONER THE COMMISSION Date: f t---- Z? (t-to-i f 1 Rclf4In4ili.jjie / < l31 1 �75ubmitForthand Form 10401(Revised 10/2 ) This pe t s date of approval(20 AAC 25.00519)) Attachments in Duplicate PIONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel:(907)277-2700 Fax:(907)343-2190 December 16th, 2013 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: Re-Permit to Drill ODSN-28 (Previous PTD#213-148) Surface Location: 2997' FSL, 1070' FEL, Sec. 11, T13N, R7E, UM X = 469928.86, Y = 6031113.39, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies to Re-Permit the ODSN-28 production well which was previously approved by the AOGCC on October 9th, 2013 under PTD #213-148. PNRA has opted to extended the production hole section from a depth of: 18,823' MD / 6,326' TVD to a depth of: 19,727' MD 6,345' ND. r Other than the lengthening of the production hole section ODSN-28 will be drilled and completed as previously permitted under PTD#213-148. Alaska Oil & Gas Consen,_.,on Commission December 16th, 2013 Page 2 of 2 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 Greg Griffin, Operations Geologist (20 AAC 25.071) 907.343.2141 greg.griffin@pxd.com If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, Alex aughan Senior Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSN-28 Well File T'y THE STATEr,"—Or .;I�% �A Alaska Oil and Gas e,,,,,,.,„...,,, °fALASKA ,,,,,....___:w Conservation Commission �7 GOVERNOR SEAN PARNELL 333 West Seventh Avenue CliA ^i " b. Anchorage,Alaska 99501-3572 ALAB� Main: 907.279.1433 Fax:907.276.7542 Alex Vaughan Sr. Drilling Engineer Pioneer Natural Resources Alaska,Inc. 700 G Street, Suite 600 Anchorage,AK 99501 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-28 Pioneer Natural Resources Alaska,Inc. Permit No: 213-148 Surface Location: 2997' FSL, 1070' FEL, Sec. 11, T13N,R7E,UM Bottomhole Location: 3140' FSL, 3911' FEL, Sec. 36, T14N,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. Pioneer Natural Resources Alaska, Inc. request to waive Diverter System is DENIED. Diverter system must meet requirement as set forth in 20 AAC 25.035(c). 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, 14 Cathy . Foerster Chair, Commissioner DATED this / day of October, 2013. • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRiLL 20 AAC 25.005 SEP 2 l 2 013 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑f Service- Win) 0 Single Zone ❑' 1c.Speciry.lf vtyll Ig,prgjosed for: Drill Q Lateral 0 Stratigraphic Test 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Coalb0.tea 0 0934-lydrates 0 Redrill 0 Reentry 0 Exploratory ❑ Service- WAG 0 Service-Disp 0 Geothermal 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket ❑✓ Single Weil❑ 11.Well Name and Number: Pioneer Natural Resources Alaska,Inc. Bond No. 103655283 ODSN-28 3.Address: 700 G Street,Suite#600 6.Proposed Depth: 12.Field/Pool(s): Anchorage,AK 99501 MD: 18,823' TVD:6326' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Oooguruk-Nuigsut 011 Pool Surface: 2997'FSL,1070'FEL,Sec.11,T13N,R7E,UM ADL 355036/ADL 389950/ADL 389958 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4200'FSL,4830'FEL,Sec.6,T13N,R8E,UM 417497 10/27/2013 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3140'FSL,3911'FEL,Sec.36,T14N,R7E,UM 5760+2533+2580 326' 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-489928.86 y-8031113.39 Zone-ASP 4 GL Elevation above MSL: 13.5 feet to Same Pool: 1218'away from ODSN-02 18.Deviated wells: Kickoff depth: 250 feet 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 91.11 degrees Downhole: 3240 Surface: 2541 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (Including stage data) 24" 16" 109# H-40 Welded 115' Surface Surface 158' 158' Driven ' 14-1/2" 11-3/4" 60# L-80 BTC-MHyd, 5460' Surface Surface 5503' 3441' 604 sx PF'L;682 sx Clas'G- 11-3/4" 9-5/8" 40# L-80 Hyd 521 4804' , 5353' 3373' 10,157' 5557' 153 sx Class'G' 8-1/2' 7" 26# L-80 95115563 12,785' Surface Surface 12,828' 6358' 523 sx Class'G' 6-1/8" 4-1/2" 12.6# C-110 Hyd 521 6145' _ 12,678' _ 6350' '18,823' 6326' 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 Intermediate Production _ Liner Perforation Depth MD(ft): N/A Perforation Depth TVD(ft): N/A 20. Attachments: Property Plat Q BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 MC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing Is true and correct. Contact Alex Vaughan,343-2186 Email Plex.VauohantThDxd.Com Printed Name Alex Vaughan Title Sr.Drilling Engineer Prepared By:Kathy Campoamor,343-2183 Signature - — Phone 343-2186 Date 9/26/2013 Commission Use Only Permit to Drill t1 U API Number. Permit Approval (t See cover letter for other Number. Q 1 3I 1 50- 7'Q 3— aO(o�—co—CO Date: 16 lot\ '1 requirements. Conditions of approval: If box Is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained In shales: ." r1r [� Other -� frt.. 7 f P - Samples req'd: Yes❑ No Mud log req'd:Yes No 13' H2S measures: Yes 0 No Directional svy req'd:Yes[ No❑ , a _,r+G' ✓�-1 ..„...E.,-e Spacing exception req'd: Yes 0 No inclination-only svy req'd:Yes 0 No(� * a.Sc-cytcLv7 r q �(� v e4 6isr 11 .4. f ac rnp.Qv'c Dns. U APPROVED BY Approved by: /47, COMMISSIONER THE COMMISSION Date: f(7-9 -/3 Du J E36Af€r24 SubmitFormand Form 10-401(Rsvlaed months from the date of approval(20 MC 25.005(8)) Attachments In Duptkate Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-28 ODSN-28 PN3 Plan: ODSN-28 PN3 wp16 Standard Proposal Report 29 October, 201R HALLIBURTON Sperry Drilling Services 0000 F-N- 1M- r co oma' o I "0 N N Oal Oai 22 2� Vl > > > > >1 ♦.r N(+y +N co co co co N co co co co NN C e e 0&' F Z Z Z Z Z Z Z Z Z Z Z w 22 N Cill o�j�oc o -83 0 3333 s... oovvrnvo;.isoVV:7-vW!.32a$M22,9v`48, `81`v°NQM80.CO8-NO 000,-000 0....'" 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CIA z EWWWWWWWWWWW (u snOOOZ)Ulde4I�!Yan l 4 NN,VNNNNNNNNN ZZZZZZZZZZZZ O • Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well(Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32 usft Latitude! 70°29'46.24 N From: Map Easting: 469,920.45usft Longitude: 150° 14'45.46 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.23° Well ODSN-28 Well Position +N/-S 0.00 usft Northing: 6,031,113.39 usfl Latitude: 70°29'45.87 N +EI-W 0.00 usft Easting: 469,928.86 usfl . Longitude: 150°14'45.21 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 13.50 usft Wellbore ODSN-28 PN3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) IGRF200510 3/8/2007 23.23 80.81 57,644 Design ODSN-28 PN3 wp16 Audit Notes: Version: Phase: PLAN Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 42.70 0.00 0.00 9.08 10/29/2013 10:10:26AM Page 2 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTO J Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 0.00 0.00 0.06 0.00 242.70 0.00 0.00 242.70 186.50 0.00 0.00 0.00 0.00 0.00 0.00 396.55 5.00 130.00 396.35 340.15 -4.31 5.14 3.25 3.25 0.00 130.00 571.82 8.00 90.00 570.56 514.36 -9.23 23.20 3.00 1.71 -22.82 -77.46 2,442.86 62.84 58.19 2,043.80 1,987.60 468.27 934.88 3.00 2.93 -1.70 -34.38 9,963.54 62.84 58.19 5,477.03 5,420.83 3,994.83 6,621.44 0.00 0.00 0.00 0.00 12,348.89 85.00 319.49 6,333.05 6,276.85 5,925.74 6,793.09 4.60 0.93 -4.14 -98.45 12,648.89 85.00 319.49 6,359.20 6,303.00 6,152.96 6,91:IR.A6 0.00 0.00 0.00 0.00 12,790.05 88.53 317.14 6,367.17 6,310.97 6,258.19 6,505.25 3.00 2.50 -1.66 -33.65 12,965.19 88.53 317.14 6,371.67 6,315.47 6,386.54 6,386.17 000 0.00 0.00 0.00 13,035.11 90.60 317.50 6,372.20 6,316.00 6,437.94 6,338.78 3.00 2.96 0.52 9.89 13,035.12 90.60 317.50 6,372.20 6,316.00 6,437.95 6,338.77 3.00 2.99 0.20 3.81 13,417.75 90.60 317.50 6,368.22 6,312.02 6,720.06 6,080.31 0.00 0.00 0.00 0.00 13,420.28 90.52 317.50 6,368.20 6,312.00 6,721.92 6,078.60 3.00 -2.99 -0.20 -176.19 13,420.40 90.52 317.50 6,368.20 6,312.00 6,72.01 6,078.52 3.00 -2.99 0.18 176.50 14,178.23 90.52 317.50 6,361.37 6,305.17 7,280.72 5,566.55 0.00 0.00 0.00 0.00 ' 14,192.01 90.93 317.47 6,361.20 6,305.0R 7,290.87 5,557.24 3.00 2.99 -0.18 -3.50 14,192.02 90.93 317.47 6,361.20 6,305.00 7,290.88 5,557.24 3.00 -2.97 -0.40 -172.31 15,728.63 90.93 317.47 6,336.31 6,280.11 8,423.18 4,518.75 0.00 0.00 0.00 0.00 15,734.87 91.11 317.50 6,336.20 6,280.00 8,427.77 4,514.53 3.00 2.97 0.40 7.69 15,734.90 91.11 317.50 6,336.20 6,280.00 8,427.80 4,514.51 3.00 3.00 0.00 0.00 16,499.26 91.11 317.50 6,321.33 6,265.13 8,991.23 3,998.21 0.00 0.00 0.00 0.00 16,506.71 90.89 317.50 6,321.20 6,265.00 8,996.73 3,993.18 3.00 -3.00 0.00 -180.00 16,506.79 90.89 317.50 6,321.20 6,265.00 8,996.78 3,993.13 3.00 2.83 -1.00 -19.45 17,267.94 90.89 317.50 6,309.34 6,253.14 8,557.88 3,478.95 0.00 0.00 0.00 0.00 17,278.51 90.59 317.60 6,309.20 6,253.00 9,565.68 3,471.82 3.00 -2.83 1.00 160.55 17,279.82 90.63 317.61 6,309.19 6,252.99 9,566.65 3,470.93 3.00 2.92 0.69 13.25 17,632.59 90.63 317.61 6,305.29 6,249.09 9,827.19 3,233.14 0.00 0.00 0.00 0.00 17,664.41 89.70 317.39 6,305.20 6,249.00 9,850.66 3,211.64 3.00 -2.92 -0.69 -166.75 17,668.13 89.81 317.39 6,305.22 6,249.02 9,853.39 3,209.12 3.00 2.99 -0.22 -4.22 i 17,996.80 89.81 317.39 6,306.28 6,250.08 10,095.27 2,986.60 0.00 0.00 0.00 0.00 18,050.24 88.22 317.50 6,307.20 6,251.00 10,134.63 2,950.46 3.00 -2.99 0.22 175.78 18,031.51 88.18 317.51 6,307.24 6,251.04 10,135.57 2,949.60 3.00 -2.98 0.37 172.99 18,404.29 88.18 317.51 6,318.46 6,262.26 10,395.57 2,711.43 0.00 0.00 0.00 0.00 18,435.57 89.11 317.39 6,319.20 6,263.00 10,418.61 2,690.28 3.00 2.98 -0.37 -7.01 18,821.44 89.11 317.39 6,325.20 6,269.00 10,702.58 2,429.11 0.00 0.00 0.00 0.00 18,841.44 NM 317.39 6,325.51 6,269.31 10,717.30 2,415.57 0.00 0.00 0.00 0.00 16,945.07 86.00 317.39 6,329.93 6,273.73 10,793.50 2,345.49 3.00 -3.00 0.00 180.00 19,093.70 86.00 317.39 6,340.30 6,284.10 10,902.63 2,245.12 0.00 0.00 0.00 0.00 19,227.03 90.00 317.39 6,344.95 6,288.75 11,000.69 2,154.93 3.00 3.00 0.00 0.00 19,727.03 90.00 317.39 6,344.95 6,288.75 11,368.70 1,816.46 0.00 0.00 0.00 0.00 10/29/2013 10.10:26AM Page 3 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting RLS Vert Section (usft) (°) (0) (usft) usft (usft) (usft) (usft) (usft) -13.90 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,113.39 469,928.86 0.00 0.00 100.00 0.00 0.00 100.00 43.80 0.00 0.00 6,031,113.39 469,928.86 0.00 0.00 200.00 0.00 0.00 200.00 143.80 0.00 0.00 6,031,113.39 469,928.86 0.00 0.00 242.70 0.00 0.00 242.70 186.50 0.00 0.00 6,031,1122.39 469,928.86 0.00 0.00 250.00 0.24 130.00 250.00 193.80 -0.01 0.01 6,031,113.38 469,928.87 3.25 -0.01 Start Dir 3.25°/100':250'MD,250'TVD:130°RT TF 300.00 1.86 130.00 299.99 243.79 -0.60 0.71 6,031,112.79 469,929.57 3.25 -0.48 396.55 5.00 130.00 396.35 340.15 -4.31 5.14 6,031,109.06 469,933.98 3.25 -3.45 400.00 5.02 128.84 399.79 343.59 -4.50 5.37 6,031,108.86 469,934.21 3.00 -3.60 403.80 5.05 127.59 403.58 347.38 -4.71 E.68 6,031,108.66 469,934.47 3.00 -3.76 Start Dir 3°/100':403.8'MD,403.7'TVD 500.00 6.43 101.84 499.31 443.11 -8.4e 14.26 6,031,104.93 469,943.09 3.00 -6.04 571.82 8.00 90.00 570.56 514.36 -9.23 23.20 6,031,104.07 469,952.02 3.00 -5.45 600.00 8.71 86.85 598.44 542.24 -9.-1 27.29 6,021,104.17 469,956.11 3.00 -4.69 700.00 11.38 78.93 696.90 640.70 -6.80 44.54 6,031,106.41 469,973.37 3.00 0.32 800.00 14.18 74.05 794.42 738.28 -1.54 66.01 6,031,111.59 469,994.85 3.00 8.90 860.87 15.92 71.92 853.20 797.00 3.10 81.12 6,031,116.17 470,009.98 3.00 15.86 Top of Permafrost 900.00 17.05 70.77 890.72 834.52 6.66 91.64 6,031,119.68 470,020.51 3.00 21.03 1,000.00 19.96 68.42 989.54 929.34 17.77 121.35 6,031,130.66 470,050.27 3.00 36.69 1,100.00 22.89 66.64 1,078.62 1,022.42 31.76 155.08 6,031,144.52 470,084.05 3.00 55.83 1,200.00 25.83 65.25 1,169.71 1,113.51 48.59 192.73 6,031,161.20 470,121.76 3.00 78.39 1,300.00 28.79 64.19 1,258.56 1,202.36 68.23 234.18 6,031,180.66 470,163.29 3.00 104.32 1,400.00 31.75 63.20 1,344.92 1,288.72 90.60 279.34 6,031,202.85 470,208.54 3.00 133.54 1,500.00 34.72 62.41 1,428.55 1,372.35 115.66 328.07 6,031,227.71 470,257.37 3.00 165.98 1,600.00 37.69 61.73 1,509.23 1,453.03 143.34 380.25 6,031,255.17 470,309.65 3.00 201.53 ' 1,700.00 40.67 61.14 1,586.74 1,530.54 173.55 435.73 6,031,285.16 470,365.24 3.00 240.12 1,800.00 43.65 60.62 1,660.86 1,604.66 206.21 494.35 6,031,317.58 470,423.99 3.00 281.63 1,810.17 43.95 80.57 1,665.20 1,612.00 209.67 500.48 6,031,321.01 470,430.13 3.00 286.01 Base of Permafrost 1,900.00 46.63 60.15 1,731.39 1,675.19 241.25 555.96 6,031,352.36 470,485.73 3.00 325.94 2,000.00 49.61 59.72 1,798.14 1,741.94 278.55 620.39 6,031,389.40 470,550.31 3.00 372.94 2,100.00 52.60 59.33 1,860.93 1,804.73 318.02 687.45 6,031,428.59 470,617.53 3.00 422.50 2,195.81 55.46 58.99 1,917.20 1,861.00 357.77 754.02 6,031,468.07 470,684.25 3.00 472.25 Ugnu D 2,200.00 55.58 58.97 1,919.57 1,863.37 359.55 756.98 6,031,469.84 470,687.21 3.00 474.48 2,300.00 58.57 58.64 1,973.92 1,917.72 403.02 828.77 6,031,513.02 470,759.17 3.00 528.74 2,400.00 61.56 58.32 2,023.81 1,967.61 448.32 902.63 6,031,558.02 470,833.21 3.00 585.12 2,442.86 62.84 58.19 2,043.80 1,987.60 468.27 934.88 6,031,577.83 470,865.53 3.00 609.91 2,451.50 62.84 58.19 2,047.75 1,991.55 472.32 941.41 6,031,581.85 470,872.08 0.00 614.94 End Dir:2451.5'MD,1995.5'TVD 2,500.00 62.84 58.19 2,069.89 2,013.69 495.06 978.08 6,031,604.44 470,908.84 0.00 643.18 2,600.00 62.84 58.19 2,115.54 2,059.34 541.95 1,053.69 6,031,651.02 470,984.63 0.00 701.41 2,700.00 62.84 58.19 2,161.19 2,104.99 588.85 1,129.31 6,031,697.60 471,060.43 0.00 759.65 2,800.00 62.84 58.19 2,206.84 2,150.64 635.74 1,204.92 6,031,744.19 471,136.22 0.00 817.88 10/29/2013 10.10:26AM Page 4 COMPASS 5000.1 Build 61 • Pioneer Natural Resources HALLIBURTOr Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting 13LS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 2,196.29 2,900.00 62.84 58.19 2,252.49 2,196.29 682.63 1,280.53 6,031,790.77 471,212.01 0.00 876.12 3,000.00 62.84 58.19 2,298.14 2,241.94 729.52 1,356.14 6,031,837.35 471,287.81 0.00 934.35 3,100.00 62.84 58.19 2,343.79 2,287.59 776.41 1,431.76 6,031,883.R3 471,363.60 0.00 992.58 3,200.00 62.84 58.19 2,389.44 2,333.24 823.30 1,507.37 6,031,43(.51 471,439.40 0.00 1,050.82 3,212.61 62.84 58.19 2,395.20 2,339.00 829.22 1,516.90 6,031,936.38 471,448.96 0.00 1,058.16 Top West Sak 3,300.00 62.84 58.19 2,435.09 2,378.89 870.20 1,582.98 6,031,977.09 471,515.19 0.00 1,109.05 3,400.00 62.84 58.19 2,480.74 2,424.54 917.09 1,658.58 6,032,023.67 471,590.98 0.00 1,167.29 3,500.00 62.84 58.19 2,526.39 2,470.19 963.98 1,734.20 6,032,070.25 471,666.78 0.00 1,225.52 3,600.00 62.84 58.19 2,572.04 2,515.84 1,010.87 1,8R8.88 6,032,116.83 471,742.57 0.00 1,283.75 3,700.00 62.84 58.19 2,617.69 2,561.49 1,057.76 1,885.43 6,032,163.41 471,818.37 0.00 1,341.99 3,800.00 62.84 58.19 2,663.34 2,607.14 1,104.65 1,961.04 6,032,209.99 471,894.16 0.00 1,400.22 3,900.00 62.84 58.19 2,708.99 2,652.79 1,151.54 2,036.65 6,032,256.57 471,969.95 0.00 1,458.46 4,000.00 62.84 58.19 2,754.64 2,698.45 1,198.44 2,112.27 6,022,303.15 472,045.75 0.00 1,516.69 4,100.00 62.84 58.19 2,800.30 2,744.10 1,245.33 2,187.88 6,032,349.73 472,121.54 0.00 1,574.92 4,200.00 62.84 58.19 2,845.95 2,789.98 1,292.22 2,263.49 6,032,396.31 472,197.34 0.00 1,633.16 4,300.00 62.84 58.19 2,891.60 2,935.40 1,339.11 2,339.10 6,032,442.90 472,273.13 0.00 1,691.39 4,400.00 62.84 58.19 2,937.25 2,881.05 1,a86.00 2,414.72 6,032,489.48 472,348.92 0.00 1,749.63 4,500.00 62.84 58.19 2,982.90 2,926.70 1,432.89 2,490.33 6,032,536.06 472,424.72 0.00 1,807.86 4,600.00 62.84 58.19 3,028.55 2,972.35 1,479.78 2,565.94 6,032,582.64 472,500.51 0.00 1,866.09 4,680.29 62.84 58.19 3,O65.20 3,009.00 1,517.43 2,626.65 6,032,620.04 472,561.37 0.00 1,912.85 Cret tuffs 4,700.00 62.84 58.19 3,074.20 3,018.00 1,526.68 2,641.55 6,032,629.22 472,576.31 0.00 1,924.33 4,800.00 62.84 98.19 3,119.85 3,063.65 1,573.57 2,717.16 6,032,675.80 472,652.10 0.00 1,982.56 i 4,900.00 62.84 58.19 3,165.50 3,109.30 1,620.46 2,792.78 6,032,722.38 472,727.89 0.00 2,040.80 5,000.00 62.84 58.19 3,211.15 3,154.95 1,667.35 2,868.39 6,032,768.96 472,803.69 0.00 2,099.03 5,100.00 62.84 58.19 3,256.80 3,200.60 1,714.24 2,944.00 6,032,815.54 472,879.48 0.00 2,157.26 5,200.00 62.84 58.19 3,302.45 3,246.25 1,761.13 3,019.61 6,032,862.12 472,955.27 0.00 2,215.50 5,300.00 62.84 58.19 3,348.10 3,291.90 1,808.03 3,095.23 6,032,908.70 473,031.07 0.00 2,273.73 5,400.00 62.84 58.19 3,393.75 3,337.55 1,854.92 3,170.84 6,032,955.28 473,106.86 0.00 2,331.97 5,446.99 62.84 58.19 3,415.20 3,359.00 1,876.95 3,206.37 6,032,977.17 473,142.48 0.00 2,359.33 Hue 2 shale 5,500.00 62.84 58.19 3,439.40 3,383.20 1,901.81 3,246.45 6,033,001.86 473,182.66 0.00 2,390.20 5,512.26 62.84 58.19 3,445.00 3,388.80 1,907.56 3,255.73 6,033,007.58 473,191.95 0.00 2,397.34 11 3/4" 5,600.00 62.84 58.19 3,485.05 3,428.85 1,948.70 3,322.06 6,033,048.44 473,258.45 0.00 2,448.43 5,700.00 62.84 58.19 3,530.70 3,474.50 1,995.59 3,397.68 6,033,095.02 473,334.24 0.00 2,506.67 5,800.00 62.84 58.19 3,576.35 3,520.15 2,042.48 3,473.29 6,033,141.60 473,410.04 0.00 2,564.90 5,90(.00 62.84 58.19 3,622.00 3,565.80 2,089.37 3,548.90 6,033,188.19 473,485.83 0.00 2,623.14 6,000.00 62.84 58.19 3,667.65 3,611.45 2,136.27 3,624.51 6,033,234.77 473,561.63 0.00 2,681.37 6,100.80 62.84 58.19 3,713.30 3,657.10 2,183.16 3,700.13 6,033,281.35 473,637.42 0.00 2,739.61 6,200.00 62.84 58.19 3,758.95 3,702.75 2,230.05 3,775.74 6,033,327.93 473,713.21 0.00 2,797.84 6,300.00 62.84 58.19 3,804.60 3,748.40 2,276.94 3,851.35 6,033,374.51 473,789.01 0.00 2,856.07 6,400.00 62.84 58.19 3,850.25 3,794.05 2,323.83 3,926.96 6,033,421.09 473,864.80 0.00 2,914.31 6,500.00 62.84 58.19 3,895.90 3,839.71 2,370.72 4,002.57 6,033,467.67 473,940.60 0.00 2,972.54 10/29201310:10:26AM Page 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-yy Northing Easting aLS Vert Section (usft) (°) (0) (usft) usft (usft) (usft) (usft) (usft) 3,885.36 6,600.00 62.84 58.19 3,941.56 3,885.36 2,417.62 4,078.19 6,033,514.25 474,016.39 0.00 3,030.78 6,700.00 62.84 58.19 3,987.21 3,931.01 2,464.51 4,153.80 6,033,560.83 474,092.18 0.00 3,089.01 6,800.00 62.84 58.19 4,032.86 3,976.66 2,511.40 4,229.41 6,033,607.41 474,167.98 0.00 3,147.24 6,900.00 62.84 58.19 4,078.51 4,022.31 2,558.29 4,305.02 6,033,65 .99 474,243.77 0.00 3,205.48 7,000.00 62.84 58.19 4,124.16 4,067.96 2,605.18 4,380.64 6,033,700.57 474,319.57 0.00 3,263.71 7,100.00 62.84 58.19 4,169.81 4,113.61 2,652.07 4,456.25 6,033,747.15 474,395.36 0.00 3,321.95 7,200.00 62.84 58.19 4,215.46 4,159.26 2,698.96 4,531.86 6,033,793.73 474,471.15 0.00 3,380.18 7,300.00 62.84 58.19 4,261.11 4,204.91 2,745.86 4,607.43 6,033,840.31 474,546.95 0.00 3,438.41 7,400.00 62.84 58.19 4,306.76 4,250.56 2,792.75 4,683.09 6,033,886.89 474,622.74 0.00 3,496.65 7,500.00 62.84 58.19 4,352.41 4,296.21 2,839.64 4,i68.7A 6,033,933.48 474,698.53 0.00 3,554.88 7,565.26 62.84 58.19 4,382.20 4,326.00 2,870.24 4,808.04 6,033,963.87 474,748.00 0.00 3,592.88 Brookian 2B 7,600.00 62.84 58.19 4,398.06 4,341.86 2,886.53 4,834.31 6,033,980.06 474,774.33 0.00 3,613.12 7,700.00 62.84 58.19 4,443.71 4,387.51 2,933.4g2 4,909.92 6,024,026.64 474,850.12 0.00 3,671.35 7,800.00 62.84 58.19 4,489.36 4,433.16 2,980.31 4,985.54 6,034,073.22 474,925.92 0.00 3,729.58 7,900.00 62.84 58.19 4,535.01 4,478.61 3,027.21 5,061.15 6,034,119.80 475,001.71 0.00 3,787.82 8,000.00 62.84 58.19 4,580.66 4,524.46 3,074.10 5,136.76 6,034,166.38 475,077.50 0.00 3,846.05 8,100.00 62.84 58.19 4,626.31 4,570.11 3,120.99 5,212.37 6,034,212.96 475,153.30 0.00 3,904.29 8,200.00 62.84 58.19 4,671.96 4,615.76 3,167.88 5,287.98 6,034,259.54 475,229.09 0.00 3,962.52 8,300.00 62.84 58.19 4,717.61 4,661.41 3,214.77 5,363.60 6,034,306.12 475,304.89 0.00 4,020.75 8,400.00 62.84 58.19 4,7.63.26 4,707.06 3,261.66 5,439.21 6,034,352.70 475,380.68 0.00 4,078.99 8,500.00 62.84 58.19 4,808.91 4,7522.71 3,308.55 5,514.82 6,034,399.28 475,456.47 0.00 4,137.22 8,600.00 62.84 58.19 4,854.56 4,798.36 3,355.45 5,590.43 6,034,445.86 475,532.27 0.00 4,195.46 8,700.00 62.84 58.19 4,900.21 4,844.01 3,402.34 5,666.05 6,034,492.44 475,608.06 0.00 4,253.69 8,800.00 62.84 58.19 4,945.86 4,889.66 3,449.23 5,741.66 6,034,539.02 475,683.86 0.00 4,311.92 8,900.00 62.84 58.19 4,991.51 4,935.31 3,496.12 5,817.27 6,034,585.60 475,759.65 0.00 4,370.16 9,000.00 82.84 58.19 5,037.17 4,980.97 3,543.01 5,892.88 6,034,632.19 475,835.44 0.00 4,428.39 9,100.00 62.84 58.19 5,082.82 5,026.62 3,589.90 5,968.50 6,034,678.77 475,911.24 0.00 4,486.63 9,200.00 62.84 58.19 5,128.47 5,072.27 3,636.79 6,044.11 6,034,725.35 475,987.03 0.00 4,544.86 9,300.00 62.84 58.19 5,174.12 5,117.92 3,683.69 6,119.72 6,034,771.93 476,062.83 0.00 4,603.09 9,365.90 62.84 58.19 5,204.20 5,148.00 3,714.59 6,169.55 6,034,802.62 476,112.77 0.00 4,641.47 Top Torok Saud 9,400.00 62.84 58.19 5,219.77 5,163.57 3,730.58 6,195.33 6,034,818.51 476,138.62 0.00 4,661.33 9,500.00 62.84 58.19 5,265.42 5,209.22 3,777.47 6,270.94 6,034,865.09 476,214.41 0.00 4,719.56 9,600.00 62.84 58.19 5,311.07 5,254.87 3,824.36 6,346.56 6,034,911.67 476,290.21 0.00 4,777.80 3,700.00 62.84 58.19 5,356.72 5,300.52 3,871.25 6,422.17 6,034,958.25 476,366.00 0.00 4,836.03 9,800.00 62.84 58.19 5,402.37 5,346.17 3,918.14 6,497.78 6,035,004.83 476,441.79 0.00 4,894.26 9,9(0.00 62.84 58.19 5,448.02 5,391.82 3,965.04 6,573.39 6,035,051.41 476,517.59 0.00 4,952.50 9,913.54 62.84 58.19 5,454.20 5,398.00 3,971.38 6,583.63 6,035,057.72 476,527.85 0.00 4,960.38 Base Torok Sand 9,963.54 62.84 58.19 5,477.03 5,420.83 3,994.83 6,621.44 6,035,081.01 476,565.75 0.00 4,989.50 9,967.30 62.82 58.03 5,478.74 5,422.54 3,996.60 6,624.28 6,035,082.76 476,568.60 4.00 4,991.69 Start Dir 4°/100':9967.3'MD,5421.7'TVD 10,000.00 62.63 56.57 5,493.73 5,437.53 4,012.30 6,648.74 6,035,098.36 476,593.11 4.00 5,011.06 10,100.00 62.17 52.09 5,540.07 5,483.88 4,063.95 6,720.71 6,035,149.72 476,665.29 4.00 5,073.42 10/292013 10:10:26AM Page 6 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting ULS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 5,495.00 10,123.79 62.08 51.02 5,551.20 5,495.00 4,077.03 6,737.18 6,035,162.73 476,681.81 4.00 5,088.93 Torok 1 Shale 10,134.04 62.04 50.55 5,556.00 5,499.80 4,082.75 6,744.19 6,035,168.42 476,688.84 4.00 5,095.69 9 5/8" 10,200.00 61.85 47.57 5,587.03 5,530.83 4,120.89 6,788.16 6,035,206.38 476,732.96 4.00 5,140.28 10,300.00 61.68 43.03 5,634.36 5,578.16 4,182.83 6,850.76 6,035,268.06 476,795.81 4.00 5,211.32 10,400.00 61.66 38.49 5,681.83 5,625.63 4,249.47 6,908.21 6,035,334.46 476,853.52 4.00 5,286.20 10,500.00 61.79 33.95 5,729.22 5,673.02 4,320.50 6,960.23 R,ff35,405.27 476,905.82 4.00 5,364.54 10,600.00 62.07 29.43 5,776.30 5,720.10 4,395.55 7,006.56 6,035,480.13 476,952.45 4.00 5,445.96 10,700.00 62.50 24.94 5,822.83 5,766.63 4,474.27 7,046.5114 6,035,558.68 476,993.18 4.00 5,530.08 10,744.28 62.73 22.96 5,843.20 5,787.00 4,510.20 7,062.94 6,035,594.54 477,009.28 4.00 5,568.08 Top HRZ 10,800.00 63.07 20.48 5,868.59 5,812.39 4,556.28 7,081.29 6,035,640.54 477,027.82 4.00 5,616.47 10,900.00 63.77 16.08 5,913.35 5,857.15 4,641.-7 7,109.32 6,0,:,5,725.30 477,056.19 4.00 5,704.72 11,000.00 64.61 11.74 5,956.90 5,900.70 4,728.53 7,130.94 6,015,812.57 477,078.16 4.00 5,794.40 11,003.03 64.64 11.61 5,958.20 5,902.0R 4,731.21 7,131.49 6,035,815.25 477,078.73 4.00 5,797.13 Base HRZ(Top Kalubik Sh) 11,100.00 65.58 7.46 5,999.03 5,942.83 4,1E17.94 7,146.04 6,035,901.90 477,093.63 4.00 5,885.07 11,200.00 66.66 3.25 6,039.52 5,983.32 4,908.95 7,154.55 6,035,992.87 477,102.50 4.00 5,976.28 11,234.81 67.07 1.80 6,053.20 5,997.00 4,940.93 7,155.96 6,036,024.84 477,104.04 4.00 6,008.08 Kalubik Marker 11,300.00 67.86 359.11 6,078.19 6,021.99 5,001.13 7,156.43 6,036,085.04 477,104.75 4.00 6,067.60 11,395.39 69.09 355.22 6,113.20 6,057.00 4,089.74 7,152.03 6,036,173.65 477,100.71 4.00 6,154.41 Top Kuparuk C 11,400.00 69.16 355.04 6,114.84 6,058.64 5,094.03 7,151.66 6,036,177.94 477,100.36 4.00 6,158.59 11,417.97 69.40 354.32 6,121.20 6,065.00 5,110.76 7,150.10 6,036,194.68 477,098.87 4.00 6,174.87 LCU(Top Miluveach Sh) 11,500.00 70.55 351.04 5,149.30 6,093.10 5,187.19 7,140.28 6,036,271.14 477,089.36 4.00 6,248.78 11,600.00 72.02 347.12 6,181.39 6,125.19 5,280.16 7,122.33 6,036,364.17 477,071.79 4.00 6,337.76 11,700.0€ 73.58 343.26 6,210.97 6,154.77 5,372.49 7,097.90 6,036,456.59 477,047.74 4.00 6,425.08 11,800.00 75.20 339.47 6,237.88 6,181.68 5,463.73 7,067.12 6,036,547.94 477,017.33 4.00 6,510.32 11,900.00 76.89 335.73 6,262.00 6,205.80 5,553.43 7,030.13 6,036,637.78 476,980.70 4.00 6,593.06 11,900.87 76.91 335.70 6,262.20 6,206.00 5,554.20 7,029.78 6,036,638.56 476,980.36 4.00 6,593.77 BCU(Top Kingak Sh) 12,000.00 78.63 332.04 6,283.21 6,227.01 5,641.15 6,987.12 6,036,725.67 476,938.05 4.00 6,672.90 12,100.00 80.41 328.40 6,301.40 6,245.20 5,726.47 6,938.28 6,036,811.19 476,889.56 4.00 6,749.45 12,200.00 82.23 324.80 6,316.49 6,260.29 5,808.98 6,883.87 6,036,893.90 476,835.49 4.00 6,822.33 12,300.00 84.09 321.23 6,328.40 6,272.20 5,888.27 6,824.14 6,036,973.42 476,776.09 4.00 6,891.21 12,348.89 85.00 319.49 6,333.05 6,276.85 5,925.74 6,793.09 6,037,011.02 476,745.19 4.00 6,923.31 12,352.90 85.00 319.49 6,333.40 6,277.20 5,928.78 6,790.50 6,037,014.07 476,742.61 0.00 6,925.90 End air.12352.9'MD,6276.9'TVD 12,400.00 85.00 319.49 6,337.51 6,281.31 5,964.45 6,760.02 6,037,049.86 476,712.28 0.00 6,956.32 12,500.00 85.00 319.49 6,346.22 6,290.02 6,040.19 6,695.31 6,037,125.85 476,647.88 0.00 7,020.90 12,600.00 85.00 319.49 6,354.94 6,298.74 6,115.93 6,630.59 6,037,201.85 476,583.48 0.00 7,085.48 10/292013 10:10:26AM Page 7 COMPASS 5000.1 Build 61 - Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting IlLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,303.00 12,648.89 85.00 319.49 6,359.20 6,303.00 6,152.96 6,598.96 6,037,239.00 476,552.00 0.00 7,117.05 Top Nuiqsut-N28 V11 T1 12,686.91 85.95 318.86 6,362.20 6,306.00 6,181.65 6,574.18 6,037,267.28 476,527.34 3.00 7,141.47 Nuiqsut 1 12,700.00 86.28 318.64 6,363.09 6,306.89 6,191.46 6,565.57 6,037,277.63 476,518.77 3.00 7,149.80 12,758.98 87.75 317.66 6,366.16 6,309.96 6,235.33 6,526.27 6,037,321.65 476,479.65 3.00 7,186.92 7" 12,790.05 88.53 317.14 6,367.17 6,310.97 6,258.19 6,505.25 6,637,344.59 476,458.73 3.00 7,206.18 12,794.00 88.53 317.14 6,367.27 6,311.07 6,261.09 6,502.57 6,037,347.50 476,456.06 0.00 7,208.61 Start Geo Steering As Per Geologist 12,800.00 88.53 317.14 6,367.42 6,311.22 6,265.48 6,498.49 6,037,351.91 476,452.00 0.00 7,212.31 12,900.00 88.53 317.14 6,369.99 6,313.79 6,338.77 6,430.49 6,037,425.46 476,384.31 0.00 7,273.95 12,965.19 88.53 317.14 6,371.67 6,315.47 6,386.84 6,386.17 6,037,473.41 476,340.18 0.00 7,314.13 13,000.00 89.56 317.32 6,372.25 6,316.05 6,412.69 6,362.54 6,037,499.06 476,316.65 3.00 7,335.63 13,035.11 90.60 317.50 6,372.20 6,316.00 6,437.94 6,338.78 6,0.17,525.00 476,293.00 3.00 7,357.41 N28 V11 T2 13,035.12 90.60 317.50 6,372.20 6,316.00 6,437.95 6,338.77 6,037,525.01 476,292.99 3.00 7,357.42 13,100.00 90.60 317.50 6,371.53 6,315.33 6,485.78 6,294.95 6,037,573.01 476,249.37 0.00 7,397.74 13,200.00 90.60 317.50 6,370.49 6,314.29 6,559.51 6,227.40 6,037,647.01 476,182.12 0.00 7,459.89 13,300.00 90.60 317.50 6,369.45 6,313.25 6,633.24 6,159.85 6,037,721.00 476,114.88 0.00 7,522.04 13,400.00 90.60 317.50 6,368.41 6,312.21 6,706.97 6,092.30 6,037,795.00 476,047.63 0.00 7,584.18 13,417.75 90.60 317.50 6,368.22 6,312.02 6,720.06 6,080.31 6,037,808.13 476,035.70 0.00 7,595.22 1 13,420.28 90.52 317.5P 6,368.20 6,312.00 6,721.92 6,078.60 6,037,810.00 476,034.00 3.00 7,596.78 N28 V11 T3 13,420.40 90.52 317.50 6,368.2(1 6,312.00 6,722.01 6,078.52 6,037,810.09 476,033.92 3.00 7,596.86 13,500.00 90.52 317.50 6,367.48 6,311.28 6,780.69 6,024.74 6,037,868.99 475,980.38 0.00 7,646.33 13,600.00 90.69 317.50 6,366.58 6,310.38 6,854.42 5,957.19 6,037,942.98 475,913.13 0.00 7,708.47 1 13,610.00 90.52 317.50 6,366.49 6,310.29 6,861.79 5,950.43 6,037,950.38 475,906.41 0.00 7,714.68 IFB Blue 1 Fault 13,700.00 90.52 317.50 6,365.68 6,309.48 6,928.14 5,889.63 6,038,016.97 475,845.88 0.00 7,770.61 13,800.00 90.52 317.50 6,364.78 6,308.58 7,001.87 5,822.07 6,038,090.96 475,778.63 0.00 7,832.75 13,900.00 90.52 317.50 6,363.88 6,307.68 7,075.59 5,754.52 6,038,164.95 475,711.38 0.00 7,894.90 14,000.00 90.52 317.50 6,362.98 6,306.78 7,149.32 5,686.96 6,038,238.94 475,644.13 0.00 7,957.04 14,100.00 90.52 317.50 6,362.08 6,305.88 7,223.04 5,619.40 6,038,312.93 475,576.88 0.00 8,019.18 14,178.23 90.52 317.50 6,361.37 6,305.17 7,280.72 5,566.55 6,038,370.81 475,524.26 0.00 8,067.80 14,192.01 90.93 317.47 6,361.20 6,305.00 7,290.87 5,557.24 6,038,381.00 475,515.00 3.00 8,076.35 N28 V1114 14,192.02 90.93 317.47 6,361.20 6,305.00 7,290.88 5,557.24 6,038,381.01 475,514.99 3.00 8,076.36 14,200.00 90.93 317.47 6,361.07 6,304.87 7,296.76 5,551.84 6,038,386.91 475,509.62 0.00 8,081.32 14,300.00 90.93 317.47 6,359.45 6,303.25 7,370.45 5,484.26 6,038,460.86 475,442.34 0.00 8,143.42 14,400.00 90.93 317.47 6,357.83 6,301.63 7,444.14 5,416.68 6,038,534.82 475,375.07 0.00 8,205.52 14,500.00 90.93 317.47 6,356.21 6,300.01 7,517.82 5,349.09 6,038,608.77 475,307.79 0.00 8,267.62 14,600.00 90.93 317.47 6,354.59 6,298.39 7,591.51 5,281.51 6,038,682.72 475,240.51 0.00 8,329.72 14,700.00 90.93 317.47 6,352.97 6,296.77 7,665.20 5,213.93 6,038,756.68 475,173.23 0.00 8,391.83 14,800.00 90.93 317.47 6,351.35 6,295.15 7,738.89 5,146.34 6,038,830.63 475,105.96 0.00 8,453.93 10/29/2013 10.10:26AM Page 8 COMPASS 5000.1 Build 61 • • Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk ND Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting ms Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,293.53 1 14,900.00 90.93 317.47 6,349.73 6,293.53 7,812.58 5,078.76 6,038,904.59 475,038.68 0.00 8,516.03 15,000.00 90.93 317.47 6,348.11 6,291.91 7,886.26 5,011.18 6,038,978.54 474,971.40 0.00 8,578.13 15,100.00 90.93 317.47 6,346.49 6,290.29 7,959.95 4,943.59 6,039,052.99 474,904.12 0.00 8,640.23 15,200.00 90.93 317.47 6,344.87 6,288.67 8,033.64 4,876.01 6,039,12E.45 474,836.85 0.00 8,702.34 15,300.00 90.93 317.47 6,343.25 6,287.05 8,107.33 4,808.43 6,039,200.40 474,769.57 0.00 8,764.44 15,400.00 90.93 317.47 6,341.63 6,285.43 8,181.02 4,740.85 6,039,274.3 474,702.29 0.00 8,826.54 15,500.00 90.93 317.47 6,340.01 6,283.81 8,254.70 4,673.26 6,039,348.31 474,635.01 0.00 8,888.64 15,600.00 90.93 317.47 6,338.39 6,282.19 8,328.39 4,605.65 6,039,422.26 474,567.74 0.00 8,950.74 15,700.00 90.93 317.47 6,336.77 6,280.57 8,402.08 4,538.10 6,039,496.21 474,500.46 0.00 9,012.85 15,728.63 90.93 317.47 6,336.31 6,280.11 8,423.18 4,f18.9g 6,039,517.39 474,481.20 0.00 9,030.63 15,734.87 91.11 317.50 6,336.20 6,280.00 8,427.77 4,514.53 6,039,522.00 474,477.00 3.00 9,034.50 N28 V11 T5 15,734.90 91.11 317.50 6,336.20 6,280.00 8,427.50 4,514.51 6,039,522.03 474,476.98 3.00 9,034.52 15,800.00 91.11 317.50 6,334.93 6,278.73 8,475. 9 4,470.54 6,029,570.18 474,433.20 0.00 9,074.97 15,900.00 91.11 317.50 6,332.99 6,276.79 8,549.50 4,402.99 6,029,644.16 474,365.96 0.00 9,137.10 16,000.00 91.11 317.50 6,331.04 6,274.51 8,623.21 4,335.45 6,039,718.14 474,298.72 0.00 9,199.23 16,100.00 91.11 317.50 6,329.10 6,772.90 8,696.92 4,267.90 6,039,792.12 474,231.48 0.00 9,261.37 16,200.00 91.11 317.50 6,327.15 6,270.95 8,770.64 4,200.35 6,039,866.10 474,164.24 0.00 9,323.50 16,300.00 91.11 317.50 6,325.21 6,269.01 8,844.35 4,132.80 6,039,940.08 474,097.00 0.00 9,385.63 16,400.00 91.11 317.50 6,323.26 6,267.06 8,918.06 4,065.26 6,040,014.05 474,029.76 0.00 9,447.77 16,499.26 91.11 317.50 6,321.33 6,265.13 8,991.23 3,998.21 6,040,087.48 473,963.02 0.00 9,509.44 16,500.00 91.09 317.50 6,321.32 6,265.12 8,991.78 3,997.71 6,040,088.03 473,962.51 3.00 9,509.90 16,506.71 90.89 317.50 6,321.20 6,265.00 8,996.73 3,993.18 6,040,093.00 473,958.00 3.00 9,514.07 N28 V11 76 16,506.79 90.89 317.50 6,321.20 6,265.00 8,996.78 3,993.13 6,040,093.05 473,957.95 3.00 9,514.11 16,600.00 90.89 317.50 6,319.75 6,263.55 9,065.49 3,930.16 6,040,162.02 473,895.27 0.00 9,572.03 16,700.00 95.89 317.50 6,318.19 6,261.99 9,139.21 3,862.61 6,040,236.00 473,828.02 0.00 9,634.17 16,800.00 90.89 317.50 6,316.63 6,260.43 9,212.93 3,795.05 6,040,309.98 473,760.77 0.00 9,696.31 16,900.00 90.89 317.50 6,315.07 6,258.87 9,286.65 3,727.50 6,040,383.96 473,693.53 0.00 9,758.44 17,000.90 90.89 317.50 6,313.51 6,257.31 9,360.36 3,659.95 6,040,457.95 473,626.28 0.00 9,820.58 17,100.00 90.89 317.50 6,311.95 6,255.75 9,434.08 3,592.40 6,040,531.93 473,559.03 0.00 9,882.71 17,200.00 50.89 317.50 6,310.40 6,254.20 9,507.80 3,524.84 6,040,605.91 473,491.79 0.00 9,944.85 17,267.94 90.89 317.50 6,309.34 6,253.14 9,557.88 3,478.95 6,040,656.17 473,446.10 0.00 9,987.06 17,278.51 90.59 317.60 6,309.20 6,253.00 9,565.68 3,471.82 6,040,664.00 473,439.00 3.00 9,993.64 N28 V11 T7 17,279.82 90.63 317.61 6,309.19 6,252.99 9,566.65 3,470.93 6,040,664.97 473,438.12 3.00 9,994.46 17,300.00 90.63 317.61 6,308.96 6,252.76 9,581.55 3,457.33 6,040,679.93 473,424.58 0.00 10,007.03 17,400.00 90.63 317.61 6,307.86 6,251.66 9,655.41 3,389.92 6,040,754.05 473,357.47 0.00 10,069.32 17,50(.00 90.63 317.61 6,306.76 6,250.56 9,729.27 3,322.51 6,040,828.17 473,290.37 0.00 10,131.62 17,650.00 90.63 317.61 6,305.65 6,249.45 9,803.12 3,255.10 6,040,902.30 473,223.27 0.00 10,193.92 17,632.99 90.63 317.61 6,305.29 6,249.09 9,827.19 3,233.14 6,040,926.45 473,201.40 0.00 10,214.22 17,664.41 89.70 317.39 6,305.20 6,249.00 9,850.66 3,211.64 6,040,950.00 473,180.00 3.00 10,234.00 N28 V11 78 ' 17,668.13 89.81 317.39 6,305.22 6,249.02 9,853.39 3,209.12 6,040,952.75 473,177.49 3.00 10,236.30 1 17,700.00 89.81 317.39 6,305.32 6,249.12 9,876.85 3,187.54 6,040,976.28 473,156.01 0.00 10,256.06 10/29/2013 10:10:26AM Page 9 COMPASS 5000.1 Build 61 Pioneer Natural Resources H A LL I B LI R TO N Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Fasting QLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 6,249.44 17,800.00 89.81 317.39 6,305.64 6,249.44 9,950.44 3,119.84 6,041,050.14 473,088.61 0.00 10,318.05 17,900.00 89.81 317.39 6,305.97 6,249.77 10,024.03 3,052.13 6,041,124.00 473,021.21 0.00 10,380.04 17,996.80 89.81 317.39 6,306.28 6,250.08 10,095.27 2,986.60 6,041,195.€0 472,955.97 0.00 10,440.04 18,000.00 89.72 317.39 6,306.29 6,250.09 10,097.63 2,984.43 6,041,193.86 472,953.82 3.00 10,442.02 18,050.24 88.22 317.50 6,307.20 6,251.00 10,134.63 2,950.46 6,041,235.00 472,920.00 3.00 10,473.21 N28 V11 T9 18,051.51 88.18 317.51 6,307.24 6,251.04 10,135.57 2,949.60 6,041,235.94 472,919.15 3.00 10,474.00 18,100.00 88.18 317.51 6,308.78 6,252.58 10,171.30 2,916.83 6,041,271.81 472,886.56 0.00 10,504.12 18,200.00 88.18 317.51 6,311.96 6,255.76 10,245.01 2,849.35 6,041,345.77 472,819.35 0.00 10,566.25 18,300.00 88.18 317.51 6,315.14 6,258.94 10,318.71 2,381.81 6,041,419.74 472,752.14 0.00 10,628.37 18,400.00 88.18 317.51 6,318.32 6,262.12 10,392.41 2,714.33 6,041,493.70 472,684.93 0.00 10,690.50 18,404.29 88.18 317.51 6,318.46 6,262.26 10,395.57 2,711.43 6,041,496.88 472,682.05 0.00 10,693.16 18,435.57 89.11 317.39 6,319.20 6,263.00 10,418.EE1 2,690.28 6,041,520.00 472,661.00 3.00 10,712.58 N28 V11 T10 18,500.00 89.11 317.39 6,320.20 6,264.00 10,466.02 2,646.68 6,041,567.59 472,617.59 0.00 10,752.52 18,600.00 89.11 317.39 6,321.76 6,265.56 10,539.62 2,578.99 6,041,641.45 472,550.21 0.00 10,814.51 18,700.00 89.11 317.39 6,323.31 6,267.11 10,613.21 2,511.30 6,041,715.31 472,482.82 0.00 10,876.51 18,800.00 89.11 317.39 6,324.87 6,268.67 10,686.81 2,443.62 6,041,789.17 472,415.44 0.00 10,938.50 18,821.44 89.11 317.39 6,325.20 6,269.00 11,702.58 2,429.11 6,041,805.00 472,401.00 0.00 10,951.79 N28 V11 T11 18,841.44 89.11 317.39 6,325.51 6,269.31 10,717.30 2,415.57 6,041,819.77 472,387.52 0.00 10,964.19 18,900.00 87.35 317.39 6,327.32 6,271.12 10,760.38 2,375.95 6,041,863.01 472,348.08 3.00 11,000.48 18,945.07 86.00 317.311 6,329.93 6,273.73 10,793.50 2,345.49 6,041,896.25 472,317.76 3.00 11,028.37 19,000.00 86.00 317.39 6,333.76 6,277.56 10,833.83 2,308.39 6,041,936.72 472,280.83 0.00 11,062.35 19,093.70 86.00 317.39 6,340.30 6,284.10 10,902.63 2,245.12 6,042,005.77 472,217.84 0.00 11,120.30 19,100.00 86.19 317.39 6,340.73 6,284.53 10,907.26 2,240.86 6,042,010.41 472,213.60 3.00 11,124.20 19,200.00 89.19 317.39 6,344.76 6,288.56 10,980.79 2,173.23 6,042,084.22 472,146.28 3.00 11,186.14 19,227.03 90.00 317.39 6,344.95 6,288.75 11,000.69 2,154.93 6,042,104.18 472,128.06 3.00 11,202.90 19,300.00 90.00 317.39 6,344.95 6,288.75 11,054.40 2,105.54 6,042,158.08 472,078.89 0.00 11,248.14 19,400.10 90.00 317.39 6,344.95 6,288.75 11,128.00 2,037.84 6,042,231.95 472,011.50 0.00 11,310.14 19,5410.00 90.00 317.39 6,344.95 6,288.75 11,201.60 1,970.15 6,042,305.82 471,944.11 0.00 11,372.14 19,600.00 90.00 317.39 6,344.95 6,288.75 11,275.21 1,902.45 6,042,379.69 471,876.72 0.00 11,434.14 19,700.00 90.00 317.39 6,344.95 6,288.75 11,348.81 1,834.76 6,042,453.56 471,809.33 0.00 11,496.15 19,727.03 90.00 317.39 6,344.95 6,288.75 11,368.70 1,816.46 6,042,473.53 471,791.11 0.00 11,512.90 Total Depth:19727.03'MD,6344.95'TVD-4 1/2" 10/29/2013 10:10:26AM Page 10 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) N28 V11 T3 0.00 0.00 6,368.20 6,721.92 6,078.60 6,037,810.00 476,034.00 -plan hits target center -Point N28 V11 T11 0.00 0.00 6,325.20 10,702.58 2,429.11 6,041,805.00 472,401.00 -plan hits target center -Point N28 V1 0.00 0.00 6,359.20 6,152.96 6,598.96 6,037,239.00 476,552.00 -plan hits target center -Point N28 V11 T9 0.00 0.00 6,307.20 10,134.63 2,950.46 6,041,235.00 472,920.00 -plan hits target center -Point N28 V1 0.00 0.00 6,361.20 7,290.87 5,557.24 6,038,381.00 475,515.00 -plan hits target center -Point N28'./1 1 _. 0.00 0.00 6,336.20 8,427.77 4,514.53 6,039,522.00 474,477.00 -plan hits target center -Point N28 V11 T2 0.00 0.00 5,372.20 6,437.94 6,338.78 6,037,525.00 476,293.00 • -plan hits target center -Point N28 V11 T6 0.00 0.00 6,321.20 8,996.73 3,993.18 6,040,093.00 473,958.00 -plan hits target center -Point N28 V11 T7 0.00 0.00 6,309.20 9,565.68 3,471.82 6,040,664.00 473,439.00 -plan hits target center -Point N28 V11 TF 0.00 0.00 6,305.20 9,850.66 3,211.64 6,040,950.00 473,180.00 -plan hits target center -Point N28 V11 T.' 0.00 0.00 6,319.20 10,418.61 2,690.28 6,041,520.00 472,661.00 -plan hits target center -Point 5,512.26 3,445.00 11 3/4" 11-3/4 13-1/2 19,727.03 6,344.95 4 1/2" 4-1/2 6-1/8 10,134.04 5,556.00 9 5/8" 9-5/8 11-3/4 12,758.98 6,366.16 7" 7 8-1/2 10/292013 10:10:26AM Page 11 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp16 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (°) 5,446.99 3,415.20 Hue 2 shale 860.87 853.20 Top of Permafrost 12,686.91 6,362.20 Nuiqsut 1 1,810.17 1,668.20 Base of Permafrost 12,648.89 6,359.20 Top Nuiqsut 11,900.87 6,262.20 BCU(Top Kingak Sh) 9,913.54 5,454.20 Base Torok Sand 13,610.00 6,366.49 IFB Blue 1 Fault 0.00 0.00 11,003.03 5,958.20 Base HRZ(Top Kalubik Sh) 11,234.81 6,053.20 Kalubik Marker 11,417.97 6,121.20 LCU(Top Miluveach Ali) 10,744.28 5,843.20 Top HRZ 2,195.81 1,917.20 Ugnu D 3,212.61 2,395.20 Top West Sak 9,365.90 5,204.20 Top Torok Sand 11,395.39 6,113.20 Top Kuparuk C 7,565.26 4,382,20 Brookian 2B 10,123.79 5,551.20 Torok 1 Shale 4,680.29 3,065.20 Cret tuffs Plan Annotations Measured Vertical Local Coordinates i Depth Depth +N/4 +E/-W (usft) (usft) (usft) (usft) Comment 250.00 250.00 -0.01 0.01 Start Dir 3.25°/100':250'MD,250'TVD: 130°RT TF 403.80 403.58 -4.71 5.63 Start Dir 3°/100':403.8'MD,403.7'TVD 2,451.50 2,047.75 472.32 941.41 End Dir:2451.5'MD, 1995.5'TVD 9,967.30 5,478.74 3,996.60 6,624.28 Start Dir 4°/100':9967.3'MD,5421.7'TVD 12,352.90 6,333.40 5,928.78 6,790.50 End Dir: 12352.9'MD,6276.9'TVD 12,794.00 6,367.27 6,261.09 6,502.57 Start Geo Steering As Per Geologist 19,727.03 6,344.95 11,368.70 1,816.46 Total Depth:19727.03'MD,6344.95'TVD 10/29/2013 10:10:26AM Page 12 COMPASS 5000.1 Build 61 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-28 ODSN-28 PN3 ODSN-28 PN3 wp16 Anticollision Summary Report 29 Octolier, 2013 Immimm======.. aiimg a 2 i i P 0 ii '. ��` N . � Z � n gg7 :$'V'.V. 42.$R3$rSS�83 8sar$m$P.m 88RHH �� == y � � . gg (9 ;7; N w n Z o : §88>88ffi8Sm8aS88�,85888:8SRS2F88.8888H Op �, '- III I� ul O` kS„3$oeaod,fd aeSm 'ffiT=Ka,oegadds , O z ❑ Nm g ,71 yUj Z - /i/ �g1isa .11'N�,i ,: �� -.4Ap A,AL, ).1, O "s 8.; - 8ab>;SSm�BF�R0m.,24 Aa4�mRRsffi SR 4 3 -,I11A. 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G O a z Z w , , Y / o / 1 / i y 14 z Za ZC g z z ° o _ G z N ZnG 81 O2 p0000ZO O O 0 O 000 0 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp16 Offset TVD Reference: Offset Datum Reference ODSN-28 PN3 wp16 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 42.70 to 1,000.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 2,168.43usf Error Surface: Elliptical Conic Survey Tool Program Date 10/29/2013 From To (usft) (usft) Survey(Wellbore) Tool Name Description 42.70 850.00 ODSN-28 PN3 wp16(ODSN-28 PN3) SRG-SS Surface readout gyro single shot 850.00 5,512.00 ODSN-28 PN3 wp16(ODSN-28 PN3) MWD+IRR2+MS+sag Fixed:v2:IIFR dec S 3-axis correction+sag 5,512.00 10,136.00 ODSN-28 PN3 wp16(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10,136.00 12,758.00 ODSN-28 PN3 wp16(ODSN-28 PN3) M'. +IFR2+MS+sag Fixed:v2:1IFR dec&3-axis correction+sag 12,758.00 19,727.03 ODSN-28 PN3 wp16(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/292013 10:47:26AM Page 2 of 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp16 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSDW1-44-ODSDW1-44 Disposal-ODSDW1 373.75 375.00 146.85 7.30 139.59 Pass-Major Risk ODSK-13-ODSK-13-ODSK-13 323.19 325.00 92.45 7.22 85.23 Pass-Major Risk ODSK-13-ODSK-13A-ODSK-13A wp01 323.19 325.00 92.45 7.22 85.23 Pass-Major Risk ODSK-13-ODSK-13PB1 -ODSK-13PB1 323.19 325.00 92.45 7.22 85.23 Pass-Major Risk ODSK-13-ODSK-13PB2-ODSK-13PB2 323.19 325.00 92.45 7.22 85.23 Pass-Major Risk ODSK-14-ODSK-14-ODSK-14 KupB 298.58 300.00 100.22 6.72 93.50 Pass-Major Risk ODSK-14-ODSK-14 PB1 -ODSK-14 PB1 KupB 298.58 300.00 100.22 6.72 93.50 Pass-Major Risk ODSK-14-ODSK-14 PB2-ODSK-14 PB2 KupB 298.58 300.00 100.22 6.72 93.50 Pass-Major Risk ODSK-33-ODSK-33 KupA-ODSK-33 KupA 397.92 400.00 47.94 8.84 39.10 Pass-Major Risk ODSK-33-ODSK-33 PB1 KupA-ODSK-33 PB1 i 397.92 400.00 47.94 8.84 39.10 Pass-Major Risk ODSK-35Ai-ODSK-35 KupB-ODSK-35 KupB Si 399.10 400.00 60.71 8.83 51.89 Pass-Major Risk ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Suns 399.10 400.00 60.71 8.83 51.89 Pass-Major Risk ODSK-38i-ODSK-38i KupD-ODSK-38i KupD Si 397.59 400.00 95.58 8.88 86.70 Pass-Major Risk ODSK-41 -ODSK-41 KupF-ODSK-41 KupF Suri 420.84 425.00 117.47 9.39 108.08 Pass-Major Risk ODSK-41 -ODSK-41 PB1 KupF-ODSK-41 PB1 I. 420.84 425.00 117.47 9.48 108.00 Pass-Major Risk ODSK-42i-ODSK-42Ai-ODSK-42Ai 349.18 350.00 122.77 7.94 114.84 Pass-Major Risk ODSK-42i-ODSK-42i KupG-ODSK-42i KupG 349.18 350.00 122.77 7.94 114.84 Pass-Major Risk ODSK-7i-ODSN-7i Ivik Kup-ODSN-7i Ivik Kup w 298.86 300.00 46.44 6.70 39.75 Pass-Major Risk ODSN-1 -ODSN-1 KE3-ODSN-1 KE3 274.44 275.00 38.89 6.07 32.82 Pass-Major Risk ODSN-1 -ODSN-1 KE3 PB1 -ODSN-1 KE3 P61 274.44 275.00 38.89 6.07 32.82 Pass-Major Risk ODSN-10-ODSN-10 PS12-ODSN-10 PS12 wp1 298.81 300.00 62.79 6.74 56.05 Pass-Major Risk ODSN-11 i-ODSN-11 i IS11 -ODSN-11 i IS11 wp1 249.83 250.00 69.14 5.50 63.64 Pass-Major Risk ODSN-12-ODSN-12 PS10-ODSN-12 RF1G wp1 323.21 325.00 75.52 7.30 68.22 Pass-Major Risk ODSN-15i-ODSN-15i-ODSN-15i IN12 949.80 250.00 106.40 5.67 100.74 Pass-Major Risk ODSN-16-ODSN-16-ODSN-18 PN13 Surveys 274.22 275.00 112.16 5.99 106.17 Pass-Major Risk ODSN-16-ODSN-16L1 -ODSN-16L1 PN13 274.22 275.00 112.16 5.99 106.17 Pass-Major Risk ODSN-17-ODSN-17-ODSN-17 PN13 Mid Surve 396.55 400.00 117.07 8.91 108.16 Pass-Major Risk ODSN-17-ODSN-17 L1 -OWSN-17 L1 PN13 396.55 400.00 117.07 8.91 108.16 Pass-Major Risk ODSN-18-ODSN-18-ODSN-18 PN11 322.95 325.00 125.30 7.14 118.16 Pass-Major Risk ODSN-18-ODSN-1E PBS-ODSN-18 PN11 PB5 322.95 325.00 125.30 7.14 118.16 Pass-Major Risk ODSN-18-ODSN-18 PB1-ODSN-18 PN11 PB1 322.95 325.00 125.30 7.14 118.16 Pass-Major Risk ODSN-18-OIISN-18 PB2-ODSN-18 PN11 PB2 322.95 325.00 125.30 7.14 118.16 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18_PB2 322.95 325.00 125.30 6.54 118.77 Pass-Major Risk ODSN-18-ODSN-18 PB3-ODSN-18 PN11 PB3 322.95 325.00 125.30 7.14 118.16 Pass-Major Risk ODSN-18-ODSN-18 PB4-ODSN-18 PN11 PB4 322.95 325.00 125.30 7.14 118.16 Pass-Major Risk ODSN-19i-ODSN-19i 34ext-ODSN-19i 34 ext K 298.34 300.00 142.80 6.74 136.07 Pass-Major Risk ODSN-2-ODSN-82 PN3 ext-ODSN-02 PN3 ext 174.99 175.00 36.34 3.81 32.54 Pass-Major Risk ODSN-2-ODSN-02 PN3 ext-ODSN-02 PN3 ext 174.99 175.00 36.34 3.81 32.54 Pass-Major Risk ODSN-2-ODSN-2 PN3 ext PB1-ODSN-2 PN3 e 174.99 175.00 36.34 3.81 32.54 Pass-Major Risk ODSN-20-ODSDW2-20 Disposal-ODSDW2-20 347.11 350.00 149.59 7.80 141.79 Pass-Major Risk ODSN-21 -ODSN-21 PS13-ODSN-21 PS13 wp0 224.97 225.00 156.24 5.00 151.24 Pass-Major Risk OILSN-22i-ODSN-22i IS14-ODSN-22i IS14 wp0 322.89 325.00 162.93 7.27 155.66 Pass-Major Risk ODSN-23i-ODSN-23i-ODSN-23i IN14 149.99 150.00 169.93 3.24 166.69 Pass-Major Risk ODSN-23i-ODSN-23i PB1 -ODSN-23i IN14 PB1 149.99 150.00 169.93 3.24 166.69 Pass-Major Risk (QDSN-23i-ODSN-23i PB2-ODSN-23i IN14 PB2 149.99 150.00 169.93 3.24 166.69 Pass-Major Risk ODSN-24-ODSN-24 KE5-ODSN-24 KE5 199.99 200.00 177.13 4.36 172.77 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB1 -ODSN-24 PB1 199.99 200.00 177.13 4.36 172.77 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB2-ODSN-24 KE5 P 199.99 200.00 177.13 4.36 172.77 Pass-Major Risk ODSN-25-ODSN-25-ODSN-25 KE1 199.99 200.00 21.45 4.34 17.11 Pass-Major Risk ODSN-25-ODSN-25 PB1 -ODSN-25 PB1 199.99 200.00 21.45 4.34 17.11 Pass-Major Risk ODSN-25-ODSN-25 PB2-ODSN-25 KE1 PB2 199.99 200.00 21.45 4.34 17.11 Pass-Major Risk ODSN-25-ODSN-25 PB3-ODSN-25 KE1 PB3 199.99 200.00 21.45 4.34 17.11 Pass-Major Risk ODSN-25-ODSN-25 PB4-ODSN-25 KE1 PB4 199.99 200.00 21.45 4.34 17.11 Pass-Major Risk 10/29/1013 10:47:26AM Page 3 of 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp16 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSN-26i-ODSN-26i KE2-ODSN-26i KE2 350.07 350.00 15.25 7.86 7.39 Pass-Major Risk ODSN-26i-ODSN-26i KE2 PB1 -ODSN-26i KE2 350.07 350.00 15.25 7.86 7.39 Pass-Major Risk ODSN-26i-ODSN-26i KE2 PB2-ODSN-26 KE2 350.07 350.00 15.35 7.86 7.39 Pass-Major Risk ODSN-27i-ODSN-27i 1N4-ODSN-27i IN4 349.95 350.00 5.40 3.90 1.50 Pass-Minor Risk 1/200 ODSN-29-ODSN-29 PN5-ODSN-29 PN5 325.01 325.00 8.27 7.19 1.08 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB1 -ODSN-29 PN5 F 325.01 325.00 8.27 7.19 1.08 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB2-ODSN-29 PN5 F 325.01 325.00 8.27 7.19 1.08 Pass-Major Risk ODSN-30-ODSN-30 PS5-ODSN-30 PS5 wp02 349.79 350.00 14.72 7.62 7.10 Pass-Major Risk ODSN-31 -ODSN-31 -ODSN-31 PN6 Surveys 399.30 400.RR 33.30 9.00 24.29 Pass-Major Risk ODSN-31 -ODSN-31 PB1 -ODSN-31 PB1 PN6 St 399.30 400.00 33.30 9.00 24.29 Pass-Major Risk ODSN-32i-ODSN-32i IN7-ODSN-32i IN7 Surve' 374.61 375.00 40.61 8.47 32.14 Pass-Major Risk ODSN-32i-ODSN-32iPB1 IN7-ODSN-321PB1 IN 374.61 375.00 40.61 8.47 32.14 Pass-Major Risk ODSN-34i-ODSN-34 IN9-ODSN-34i IN9 Survey 398.99 400.00 54.96 8.87 46.09 Pass-Major Risk ODSN-34i-ODSN-341 PB2-ODSN-34iPB2 IN9 398.99 400.00 54.96 8.87 46.09 Pass-Major Risk ODSN-34i-ODSN-34i PB3-ODSN-34iPB3 IN9 398.99 400.00 54.96 8.87 46.09 Pass-Major Risk ODSN-34i-ODSN-34iPB1 -ODSN-34iPB1 IN9 398.99 400.00 54.96 8.87 46.09 Pass-Major Risk ODSN-36-ODSN-36 L1 -ODSN-36a wp08 399.12 400.00 66.97 8.12 58.85 Pass-Major Risk ODSN-36-ODSN-36 PB1 -ODSN-36 PB1 PN10 399.12 400.00 66.97 8.21 58.76 Pass-Major Risk ODSN-36-ODSN-36 PB2-ODSN-36 PB2 PN10 399.12 400.00 66.97 8.21 58.76 Pass-Major Risk ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Eur 399.12 400.00 66.97 8.21 58.76 Pass-Major Risk ODSN-37-ODSN-37-ODSN-37 PN8 398.77 400.00 86.96 9.04 77.92 Pass-Major Risk ODSN-37-ODSN-37 L1 -ODSN-37 L1 usp01 398.77 400.00 86.96 8.95 78.01 Pass-Major Risk ODSN-3i-ODSN-3i 1N4 ext-ODSN-3i IN4 wp07 224.99 225.00 34.20 5.02 29.18 Pass-Major Risk ODSN-4-ODSN-04 PN5 ext-ODSIN-04 PN5 ext 174.99 175.00 33.55 3.76 29.79 Pass-Major Risk ODSN-4-ODSN-4 PN5 ext PB1 -ODSN-4 PN5 e 174.99 175.00 33.55 3.76 29.79 Pass-Major Risk ODSN-40-ODSN-40 PN12-CQDSN-40 PN12 Sur 372.90 375.00 108.95 8.37 100.58 Pass-Major Risk ODSN-40-ODSN-40PB1 PP12-ODSN-40PB1 P 372.90 375.00 108.95 8.37 100.58 Pass-Major Risk ODSN-40-ODSN-40PB2 PN12-ODSN-40PB2 P 372.90 375.00 108.95 8.37 100.58 Pass-Major Risk ODSN-43-ODSN-43 PS15-OIGSN-43 PS15 wp0 374.03 375.00 139.46 8.28 131.19 Pass-Major Risk ODSN-48-ODSN-4>E Western ERD-ODSN-48 l: 249.94 250.00 173.51 5.56 167.95 Pass-Major Risk ODSN-5i-ODSNI-5i IS3-ODSN-5i IS3 wp09 274.40 275.00 33.73 6.17 27.56 Pass-Major Risk ODSN-6-ODSN-6 PS4-ODSN-6 PS4 wp01 274.39 275.00 35.85 5.91 29.94 Pass-Major Risk ODSN-8-t2DSN-8 PS8-ODSN-8 PS8 wp08-8K 298.84 300.00 51.51 6.65 44.86 Pass-Major Risk ODSN-9i-ODSN-9i IS9-ODSN-9I wp12-8k horz 274.34 275.00 56.68 6.08 50.61 Pass-Major Risk ODST-39-ODSN-39i IN11-ODSN-39i IN11 374.33 375.00 101.87 8.42 93.45 Pass-Major Risk ODST-39-ODST-39 Torok D-ODST-39 Torok D 374.30 375.00 101.87 8.42 93.45 Pass-Major Risk ODST-39-ODST-39 Torok D PB1 -ODST-39 Tor 374.30 375.00 101.87 8.42 93.45 Pass-Major Risk ODST-45-ODSN-45i PB1 IN13-ODSN-45i PB1 374.02 375.00 154.41 8.61 145.80 Pass-Major Risk ODST-45-ODST-45A-ODST-45A Surveys 374.02 375.00 154.41 8.61 145.80 Pass-Major Risk ODST-46i-ODST-461-ODST-46i Torok C 174.98 175.00 159.90 3.78 156.13 Pass-Major Risk ODST-46i-ODST-46i PB1 -ODST-46i Torok C P 174.98 175.00 159.90 3.78 156.13 Pass-Major Risk OIEST-46i-ODST-46i PB2-ODST-46i Torok C P 174.98 175.00 159.90 3.78 156.13 Pass-Major Risk ODST-46i-ODST-46i Torok C PB3-ODST-46i P 174.98 175.00 159.90 3.78 156.13 Pass-Major Risk ODST-47-ODST-47-ODST-47 299.53 300.00 166.71 6.62 160.09 Pass-Major Risk 10/29/2013 10:47:26AM Page 4 of 5 COMPASS 5000.1 Build 61 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-28 ODSN-28 PN3 ODSN-28 PN3 wp16 Anticollision Summary Report 29 October, 2013 • c ,,,/ ♦ ,,`,,,,,, R SEg�PPPPPPPPP PP o m M � OIN0. � ``o ,�' ' ffins7 $v.es<q $«Rog„ss�$a”$$s7,8 .v A$ $ q§iii ^mF $$ iiRsSdSogRCN N I'=Z Z 1881RWI$8go8w888:,88888.V881e«$�$Ss888888 O o #��, _ 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N CL O Y (4 Z G 0 o 0 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp16 Offset TVD Reference: Offset Datum Reference ODSN-28 PN3 wp16 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 1,000.00 to 18,841.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 2,168.43usf Error Surface: Elliptical Conic Survey Tool Program Date 10/29/2013 From To (usft) (usft) Survey(Wellbore) Tool Name Description 42.70 850.00 ODSN-28 PN3 wp16(ODSN-28 PN3) SRG-SS Surface readout gyro single shot 850.00 5,512.00 ODSN-28 PN3 wp16(ODSN-28 PN3) MWD+IRR2+MS+sag Fixed:v2:IIFR dec 813-axis correction+sag 5,512.00 10,136.00 ODSN-28 PN3 wp16(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10,136.00 12,758.00 ODSN-28 PN3 wp16(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12,758.00 19,727.03 ODSN-28 PN3 wp16(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/29/2013 11:08:21 AM Page 2 of 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp16 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSDW1-44-ODSDW1-44 Disposal-ODSDW1 1,016.42 1,100.00 284.53 20.22 265.24 Pass-Major Risk ODSK-13-ODSK-13-ODSK-13 1,017.71 1,100.00 279.62 20.75 259.85 Pass-Major Risk ODSK-13-ODSK-13A-ODSK-13A wp01 1,017.71 1,100.00 279.62 20.75 259.85 Pass-Major Risk ODSK-13-ODSK-13PB1 -ODSK-13PB1 1,017.71 1,100.00 279.62 20.75 259.85 Pass-Major Risk ODSK-13-ODSK-13PB2-ODSK-13PB2 1,017.71 1,100.00 279.62 20.75 259.85 Pass-Major Risk ODSK-14-ODSK-14-ODSK-14 KupB 1,013.73 1,100.00 291.91 24.71 268.96 Pass-Major Risk ODSK-14-ODSK-14 PB1 -ODSK-14 PB1 KupB 1,013.73 1,100.00 291.91 24.71 268.96 Pass Major Risk ODSK-14-ODSK-14 PB2-ODSK-14 PB2 KupB 1,013.73 1,100.80 291.91 24.71 268.96 Pass-Major Risk ODSK-33-ODSK-33 KupA-ODSK-33 KupA 1,012.76 1,075.00 216.65 23.55 194.65 Pass-Major Risk ODSK-33-ODSK-33 PB1 KupA-ODSK-33 PB1 i 1,012.76 1,075.00 216.65 23.55 194.65 Pass-Major Risk ODSK-35Ai-ODSK-35 KupB-ODSK-35 KupB Si 1,000.00 1,050.00 191.04 21.38 170.78 Pass-Major Risk ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Sury 1,000.00 1,050.00 191.04 21.38 170.78 Pass-Major Risk ODSK-38i-ODSK-38i KupD-ODSK-38i KupD Si 1,013.96 1,075.00 215.69 21.61 195.16 Pass-Major Risk ODSK-41 -ODSK-41 KupF-ODSK-41 KupF Sury 1,009.04 1,075.00 232.19 20.41 212.62 Pass-Major Risk ODSK-41 -ODSK-41 PB1 KupF-ODSK-41 PB1 I. 1,009.04 1,075.00 232.19 20.50 212.54 Pass-Major Risk ODSK-42i-ODSK-42Ai-ODSK-42Ai 1,000.00 1,075.00 258.41 23.69 235.92 Pass-Major Risk ODSK-42i-ODSK-42i KupG-ODSK-42i KupG 1,000.00 1,075.00 258.41 23.69 235.92 Pass-Major Risk ODSK-7i-ODSN-7i Ivik Kup-ODSN-7i Ivik Kup% 1,006.09 1,050.00 194.63 23.73 171.64 Pass-Major Risk ODSN-1 -ODSN-1 KE3-ODSN-1 KE3 1,011.14 1,075.00 258.11 22.89 236.54 Pass-Major Risk ODSN-1 -ODSN-1 KE3 PB1 -ODSN-1 KE3 PBI 1,011.14 1,075.00 258.11 22.89 236.54 Pass-Major Risk ODSN-10-ODSN-10 PS12-ODSN-10 PS12 wp1 1,014.40 1,075.00 224.90 23.99 202.43 Pass-Major Risk ODSN-11 i-ODSN-11 i IS11 -ODSN-11 i IS11 wp1 1,014.06 1,150.00 404.95 28.92 381.24 Pass-Major Risk ODSN-12-ODSN-12 PS10-ODSN-12 R&1Q wp1 1,016.32 1,100.00 273.60 22.87 252.07 Pass-Major Risk ODSN-15i-ODSN-15i-ODSN-15i IN12 1,008.40 1,100.00 307.92 22.14 287.24 Pass-Major Risk ODSN-16-ODSN-16-ODSN-15 PN13 Surveys 1,016.54 1,125.00 342.47 24.93 319.92 Pass-Major Risk ODSN-16-ODSN-16L1 -ODSN-16L1 PN13 1,016.54 1,125.00 342.47 24.93 319.92 Pass-Major Risk ODSN-17-ODSN-17-ODSN-17 PN13 Mid Surve 1,013.74 1,100.00 288.33 23.91 266.01 Pass-Major Risk ODSN-17-ODSN-17 L1 -OU SN-17 L1 PN13 1,013.74 1,100.00 288.33 23.91 266.01 Pass-Major Risk ODSN-18-ODSN-18-ODSN-18 PN11 1,000.00 1,100.00 315.94 23.49 294.13 Pass-Major Risk ODSN-18-ODSN-11r PB5-ODSN-18 PN11 PB5 1,000.00 1,100.00 315.94 23.49 294.13 Pass-Major Risk ODSN-18-ODSN-18 PB1-ODSN-18 PN11 PB1 1,000.00 1,100.00 315.94 23.49 294.13 Pass-Major Risk ODSN-18-O0/SN-18 PB2-ODSN-18 PN11 PB2 1,000.00 1,100.00 315.94 23.49 294.13 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18_PB2 1,000.00 1,100.00 315.94 21.28 296.07 Pass-Major Risk ODSN-18-ODSN-18 PB3-ODSN-18 PN11 PB3 1,000.00 1,100.00 315.94 23.49 294.13 Pass-Major Risk ODSN-18-ODSN-18 PB4-ODSN-18 PN11 PB4 1,000.00 1,100.00 315.94 23.49 294.13 Pass-Major Risk ODSN-19i-ODSN-19i 34ext-ODSN-19i 34 ext K 1,009.94 1,200.00 499.71 23.88 478.16 Pass-Major Risk ODSN-2-ODSN-12 PN3 ext-ODSN-02 PN3 ext 18,806.32 13,225.00 229.28 305.35 42.80 Pass-Major Risk ODSN-2-ODSN-2 PN3 ext PB1-ODSN-2 PN3 e 1,009.40 1,050.00 254.96 22.99 232.39 Pass-Major Risk ODSN-20-ODSDW2-20 Disposal-ODSDW2-20 1,007.93 1,150.00 412.11 27.39 387.89 Pass-Major Risk ODSN-21-ODSN-21 PS13-ODSN-21 PS13 wp0 1,011.13 1,200.00 511.22 26.49 488.41 Pass-Major Risk ODSN-22i-ODSN-22i IS14-ODSN-22i IS14 wp0 1,011.37 1,150.00 414.38 22.53 393.08 Pass-Major Risk OMSN-23i-ODSN-23i-ODSN-23i 1N14 1,000.00 1,225.00 572.93 22.20 552.95 Pass-Major Risk ODSN-23i-ODSN-23i PB1 -ODSN-23i IN14 PB1 1,000.00 1,250.00 606.42 23.77 586.08 Pass-Major Risk ODSN-23i-ODSN-23i PB2-ODSN-23i IN14 PB2 1,000.00 1,225.00 572.93 22.20 552.95 Pass-Major Risk ODSN-24-ODSN-24 KE5-ODSN-24 KE5 1,000.00 1,175.00 489.63 21.82 469.82 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB1 -ODSN-24 PB1 1,000.00 1,175.00 489.63 21.82 469.82 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB2-ODSN-24 KE5 P 1,000.00 1,175.00 489.63 21.82 469.82 Pass-Major Risk ODSN-25-ODSN-25-ODSN-25 KE1 1,004.83 1,025.00 207.10 21.46 185.64 Pass-Major Risk ODSN-25-ODSN-25 PB1 -ODSN-25 PB1 1,004.83 1,025.00 207.10 21.46 185.64 Pass-Major Risk ODSN-25-ODSN-25 PB2-ODSN-25 KE1 PB2 1,004.83 1,025.00 207.10 21.46 185.64 Pass-Major Risk ODSN-25-ODSN-25 PB3-ODSN-25 KE1 PB3 1,004.83 1,025.00 207.10 21.46 185.64 Pass-Major Risk ODSN-25-ODSN-25 PB4-ODSN-25 KE1 PB4 1,004.83 1,025.00 207.10 21.46 185.64 Pass-Major Risk ODSN-26i-ODSN-26i KE2-ODSN-26i KE2 1,010.98 1,025.00 123.43 21.17 102.59 Pass-Major Risk 10/29/2013 11:08:21 AM Page 3 of 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp16 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSN-26i-ODSN-26i KE2 PB1 -ODSN-26i KE2 1,010.98 1,025.00 123.43 21.17 102.59 Pass-Major Risk ODSN-26i-ODSN-26i KE2 PB2-ODSN-26 KE2 1,010.98 1,025.00 123.43 21.17 102.59 Pass-Major Risk ODSN-27i-ODSN-27i IN4-ODSN-27i IN4 1,010.97 1,025.00 76.20 21.70 55.85 Pass-Major Risk ODSN-29-ODSN-29 PN5-ODSN-29 PN5 1,004.83 1,025.00 192.99 22.03 81.01 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB1 -ODSN-29 PN5 F 1,004.83 1,025.00 102.99 22.03 81.01 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB2-ODSN-29 PN5 F 1,004.83 1,025.00 102.99 22.03 81.01 Pass-Major Risk ODSN-30-ODSN-30 PS5-ODSN-30 PS5 wp02 1,015.99 1,050.00 142.37 23.07 120.73 Pass-Major Risk ODSN-31 -ODSN-31 -ODSN-31 PN6 Surveys 1,017.65 1,050.90 130.65 23.92 107.78 Pass-Major Risk ODSN-31 -ODSN-31 PB1 -ODSN-31PB1 PN6 Si 1,017.65 1,050.AR 130.65 23.92 107.78 Pass-Major Risk ODSN-32i-ODSN-32i IN7-ODSN-32i IN7 Surve, 1,010.62 1,050.00 155.86 23.79 133.27 Pass-Major Risk ODSN-32i-ODSN-32iPB1 IN7-ODSN-32iPB1 IN 1,010.62 1,050.00 155.86 23.79 133.27 Pass-Major Risk ODSN-34i-ODSN-34 IN9-ODSN-34i IN9 Survey 1,007.80 1,050.00 162.85 23.45 140.36 Pass-Major Risk ODSN-34i-ODSN-34i PB2-ODSN-34iPB2 IN9 1,007.80 1,050.00 162.85 23.45 140.36 Pass-Major Risk ODSN-34i-ODSN-34i PB3-ODSN-34iPB3 IN9 1,00180 1,050.00 162.85 23.45 140.36 Pass-Major Risk ODSN-34i-ODSN-34iPB1 -ODSN-34iPB1 IN9 1,007.80 1,050.00 162.85 23.45 140.36 Pass-Major Risk ODSN-36-ODSN-36 L1 -ODSN-36a wp08 1,006.84 1,050.00 167.50 19.93 148.17 Pass-Major Risk ODSN-36-ODSN-36 PB1 -ODSN-36 PB1 PN10 1,006.84 1,050.00 167.50 20.01 148.08 Pass-Major Risk ODSN-36-ODSN-36 PB2-ODSN-36 PB2 PN10 1,006.84 1,050.00 167.50 20.01 148.08 Pass-Major Risk ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Sur 1,006.84 1,050.00 167.50 20.01 148.08 Pass-Major Risk ODSN-37-ODSN-37-ODSN-37 PN8 1,018.93 1,075.00 203.34 23.76 180.67 Pass-Major Risk ODSN-37-ODSN-37 L1 -ODSN-37 L1 wp01 1,018.93 1,075.00 203.34 23.67 180.76 Pass-Major Risk ODSN-3i-ODSN-3i IN4 ext-ODSN-3i I1‘14 wp07 1,007.91 1,075.00 307.24 25.18 283.88 Pass-Major Risk ODSN-4-ODSN-04 PN5 ext-ODSN-04 RN5 ext 1,010.16 1,150.00 412.95 23.95 391.46 Pass-Major Risk ODSN-4-ODSN-4 PN5 ext PB1 -UDSN-4 PN5 e 1,010.16 1,150.00 412.95 23.93 391.47 Pass-Major Risk ODSN-40-ODSN-40 PN12-ODEN-40 PN12 Sur 1,007.18 1,075.00 240.43 22.23 218.96 Pass-Major Risk ODSN-40-ODSN-40PB1 PN12-ODSN-40PB1 P 1,007.18 1,075.00 240.43 22.23 218.96 Pass-Major Risk ODSN-40-ODSN-40PB2 P1i12-ODSN-40PB2 P 1,007.18 1,075.00 240.43 22.23 218.96 Pass-Major Risk ODSN-43-ODSN-43 P915-ODSN-43 PS15 wp0 1,010.77 1,100.00 304.57 23.76 281.20 Pass-Major Risk ODSN-48-ODSN-48 We stem ffRD-ODSN-48 15 1,000.00 1,250.00 592.25 24.06 571.09 Pass-Major Risk ODSN-5i-ODSN-5i IS3-ODSN-5i IS3 wp09 1,019.67 1,050.00 161.30 24.00 138.08 Pass-Major Risk ODSN-6-ODSN-6 PS4-ODSN-6 PS4 wp01 1,018.42 1,050.00 139.35 22.75 118.00 Pass-Major Risk ODSN-8-ODSN-8 PS8-ODSN-8 PS8 wp08-8K 1,000.00 1,050.00 193.13 23.58 170.83 Pass-Major Risk ODSN-9i-GDSN-9i IS9-ODSN-91 wp12-8k horz 1,000.00 1,075.00 267.10 23.35 245.09 Pass-Major Risk ODST-39-ODSN-39i IN11-ODSN-39i IN11 1,013.64 1,075.00 223.38 21.24 202.92 Pass-Major Risk ODST-39-ODST-39 Torok D-ODST-39 Torok D 1,013.62 1,075.00 223.37 21.24 202.91 Pass-Major Risk ODST-39-ODST-39 Torok D PB1 -ODST-39 Tor 1,013.62 1,075.00 223.37 21.24 202.91 Pass-Major Risk ODST-45-ODSN-45i PB1 IN13-ODSN-45i PB1 1,012.42 1,100.00 302.73 21.03 282.45 Pass-Major Risk ODST-45-ODST-45A-ODST-45A Surveys 1,012.42 1,100.00 302.73 21.03 282.45 Pass-Major Risk ODST-46i-ODST-46i-ODST-46i Torok C 1,009.58 1,150.00 437.11 21.19 415.91 Pass-Major Risk ODST-46i-ODST-46i PB1 -ODST-46i Torok C P 1,009.58 1,150.00 437.11 21.19 415.91 Pass-Major Risk ODST-46i-ODST-46i PB2-ODST-46i Torok C P 1,009.58 1,150.00 437.11 21.19 415.91 Pass-Major Risk OLLST-46i-ODST-46i Torok C PB3-ODST-46i P 1,009.58 1,150.00 437.11 21.19 415.91 Pass-Major Risk ODST-47-ODST-47-ODST-47 1,011.67 1,175.00 466.83 22.52 445.55 Pass-Major Risk Oooguruk Offset Wells Ivik 1-Ivik 1-Ivik 1 9,987.59 5,475.00 432.47 193.10 239.49 Pass-Major Risk 10/29/2013 11:08:21AM Page 4 of 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp16 Offset TVD Reference: Offset Datum Reference Depths are relative to 42.7'+13.5'@ 56.20usft(Nabors Coordinates are relative to:ODSN-28 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.00 W° Grid Convergence at Surface is:-0.23° Ladder Plot 4:1i I A% 11, I'r Ii .` .I/ IJ .. J ' ___ - ___J---- J I J S) 1650 ! i�1. � ` I. �,� C J J - -J- - - -_1---- J o ,� ;{'�,t' t D• - I I, 11 I 1 ,19!1 A' I 1 LI ca ' <a a =i;. �t 1 �,, \V °' 1100 .p / VI 1 a� Ilt<.. , =�II E. 1 s /� il,,*,; J .I SIJ__4• 4' J_ J J_ o o i LEG D N DiaposatO (144, ‘, l N-1' OfISN-18PR3,O •ut 18"..•11 PR3 / -6- 0 N-34iiCD.SN.14iP-3,ODSN-3 13V0 U k- _- -e- ODSN-18,OOSN-18P44,09.1. 18PA11 ' 0 $ O''.N34iODSN34iPB1,ODSN3• I :13A1A.p01V0 k ♦- ODSN-19i,ODSN-19i34ext,ODSN-19":4 iKE4wp01V0 --- OP. -,DDSN36L1,CDSN3&a' SK-13PB1 VO - �yk ---- -6- ODSN-2,ODSN-02 PN3extODSN-02 1 c e tV0 - -I -4---ops .,s 8.N36-PB11ODSN-36 Sk-13PB2VO I" * ODSN-2,ODSN-2PN3extPB1,ODSN•2PN3 ext PB1VO - ODSN36,ODSN36PB21ODSN36 14KupBVO , - ODSN-20,C DSDW2-20Disposal,ODSD 2-20wp01 VO -9- ODSN36,ODSN36PN10,ODSM-3 )S<-14PB1Ku VO I $ ObSN-21,0SN-21PS13,ODSN->-1PS13wp09V0 -- IOL)SN-3/,OUSN3/,t)L1SN-37PNE )S<-14 PB2 KupB03 3500$. ODSN-227&V N-22i IS14,OD.5PSIS14 wp07b Vd 4000 -42N-37,ODSN-PDSN-3 L 'DSK33KupAVO -a- ODSN-23i,ODSNM, 1/010500usftln) $ ODSN-3i3ODSN-3i1N4ext ODSM-3 AODSK33PB1KupAVO -II- ODSN-23i,ODSN-23i PB1,ODSN-23iIN14 PB1 VO -A- ODSN-4,ODSN-04PN5ext.ODSN- OOSK35KupBSuneysVO $ ODSN-23i,ODSN-23i PB2,ODSN-23i IN14 PB2 VO -B- ODSN-4,ODSN-4PN5extPB1,CD: SK-35Ai KupH Sun,eysVO - -- ODSN-24,ODSN-24 KE5,ODSN-24 KE5 VO -E ODSN40,ODSN40PN12,ODSf44 DDSK-38iKupDSuneysVO -9- ODSN•24,ODSN-24KE5 PB1,ODSN-24PB1 V0 $ ODSN-40,ODSN-40PB1 PN12,ODE ,DSK41 KupFSurveysVO $ ODSN-24,ODSN-24 KE5 PB2,ODSN-24 KE5 PB2 VO ODSN40,ODSN40PB2 PN12,0 7E )F ODSK41 PB1 KupF V O ODSN-25,ODSN-25,ODSN-25 KE1 VO ODSN43,ODSN43 PS15,ODSN4: K42AiV0 -F' ODSN-25,ODSN-25PB1,ODSN-25PB1 VO -e- ODS N-48,ODS N48Western ERD,C DDSK42i KupG VO - - ODSN-25,ODSN-25 PB2,ODSN-25 KE1 PB2 V0 -9(-- ODSN-5i,ODSN-5i IS3,ODSN-5i S: ODSN-7ikik Kupwp01 V0 ' ODSN-25,ODSN-25 PB3,ODSN-25KE1 PB3V0 ODSN-6,ODSN-6 PS4,ODSN-6 PS IN-1 KE3 VO - ODSN-25,ODSN-25 PB4,ODSN-25 KE1 PB4 V0 ODSN-8,ODSN-8 PS8,ODSN-8 E ODSN-1 KE3 PB1 V0 -s 4• ODSN-26i,ODSN-26i KE2,ODSN-26i KE2 VO -6-- ODSN-9i,ODSN-9i IS9,ODSN-91 n¢ )LAN-TUT' 1LWPTi-urk mrizvu - UUJN-LbI,ULAN-LbI KtL VIJ I,VUSN-LbI KtL VLSI VU - UUJI-J ,OL) N-.5 I IN11,OWN-3 k10/29/2013 11:08:21AM Page 5 of 5 COMPASS 5000.1 Build 61 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-28 ODSN-28 PN3 ODSN-28 PN3 wp16 Anticollision Summary Report 29 October, 2013 41,_......._,...., °' a cv N 'i 'g 'i 'i _ _ _ _ __ M M co'�_ ``' ry N �� o N a , ' `` mssV4;�my� gVa:<� xy�xx2x2a` g8xasxag„sm8a xxx '-'', �1i��' nrrrn3��&x %I MI &x58So88o8W��'�" Z A ~ z , ,,' ',, ,` ` Z o p ;88{8r8g88„80'888,..,88 81t 8 A8R88S888888 Z .E g 4 o M , ,#,��,,,♦,,, c ��x,;'Fc�ta3da�d�'eR c,.00gmdgmdgyaR�o�oo�ddd ,,,� ,#### "li � ` •W8888888888.88888888888888888888888888M Lo f •- N a $e,;oo,�:Moon�o,��.,o,,,,e.,.,o.,� ,��o,�„o�„e,;oo,� ti c E ,, ' ` ,, ,, a y 388�RSffi£R#g$m�8��g8nr �%.'&�4�x'Sx"d.9�h°dtS;& a o QgratIti oasanamxxxffis„0mmi �a��egxsax� ffie� n e $aialx B� oo mono 0 U � '” in wpm �� rung z 88 RIMS R � P, Wm o ASS o ° �RY888RC RRpggMggR R$R Ra °g g9ggggrygRrymRRymgxgx%gg�� U gr 68gHJR�d �d� II96R8id fdEf��E6fdeg88\ 40.mo. `�� 4� �x��q N. , ,, _ - c �888SS888"�i.”�t.$$�8G8�'&�',��8gg3�8'�Rggpoo 8$88 0 4 5417441 ...001 ��I N zoo�m��ggg�xxx��wmm��x��$$m��xxx a .„ ...................... : %...._ ,........... ........,,, :P L.,—,..,...-..',..-..R-.NALAAMA87,gAXMiXAV; 0 M N r Y i � 0 W N 0 CO Z U M V 0o O C 9 ^` c0 0 V C u y Z W c O O p O 8 O pQ O ppp S0 0 0 p 0 0 0 0 E N O O O O h G Op N Op N O N O N O N S O O O S S S r N F Q N N A 000 g S g N a u m - N O N O - N - O N N A S N N A RO G O O 0p0 WO y (n V u 1 (n F N N A N N N N M M M M N 10 A F.c `N ' a' ZO I ! 11111 . 111111111 UE- O rn vE"° °o Q _C V C D y 0 428282828 `a85', 82820888888888888888888 C H y r.t H O C E O L N N A O c c O N N A O N N A pp O O O O O 8 .2g ' 0 0 0 0 0 0 0 0 0 0 0 % ill X u W co 0 M N— Z V a.Nu), W o (7 Z .... \\\ 0p �_ N co 46 O \\ 0�_` E E C� \ ``••#,�� ` N N r ao M `��S``I I �� o o 0)010101 0 ��0 � �t = ocl, _= _ y +Nye �/� in _ o CO N `dll�j O J �r 2NWus Nq yLLLL u_NNNN u_ `' % I i '4'! 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Q D A 0 ON ON co .';':'; _4:0;,;1 ° m c mlo z 3 Q c7r Q 0 p to m romp O "�I��' v,,,,� c ,C�° ,�.Il, � rwillim , N A T U C c C Cp.p.p.p. 1��ra 3333 I ;�r��;, 0. wol w ::'.::v >- o cZzzzz cp i� ��l �� U a �ddw� > o maaaaa e IIQ�Ir6I �� N N re z0�-o OD aO 00 aD CO i.�,�I�,, I � Q pip, C W G N..�p yN ZtA/ncnmrn � �,,/� `� ,' r z cM ��' H yZZZZZ __ ' L" _cou d_ 000000 �� Z 10 g dN NU L 2 M C V r ‘1 lim. c O a E, F-00000 �/� N c0 N(7OSN A •co Oa aDNAA Z O `.,, 7 '9 o O O O O O o � '♦ +$ "A0000 Q �==�N N Ll'V LL')NOo71Wfi QM 0 m o tL 0rs M N Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp16 Offset TVD Reference: Offset Datum Reference ODSN-28 PN3 wp16 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 18,841.00 to 19,727.03usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 2,168.43usf Error Surface: Elliptical Conic Survey Tool Program Date 10/29/2013 From To (usft) (usft) Survey(Wellbore) Tool Name Description 42.70 850.00 ODSN-28 PN3 wp16(ODSN-28 PN3) SRG-SS Surface readout gyro single shot 850.00 5,512.00 ODSN-28 PN3 wp16(ODSN-28 PN3) MWD+IRR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 5,512.00 10,136.00 ODSN-28 PN3 wp16(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10,136.00 12,758.00 ODSN-28 PN3 wp16(ODSN-28 PN3) MVVD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12,758.00 19,727.03 ODSN-28 PN3 wp16(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/292013 11:05:56AM Page 2 of 4 COMPASS 5000.1 Build 61 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp16 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSK-13-ODSK-13-ODSK-13 Out of range ODSK-14-ODSK-14-ODSK-14 KupB Out of range ODSK-14-ODSK-14 PB2-ODSK-14 PB2 KupB Out of range ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Sury Out of range ODSK-7i-ODSN-7i Ivik Kup-ODSN-7i Ivik Kup In 19,705.04 16,500.00 697.79 385.80 315.25 Pass-Major Risk ODSN-1 -ODSN-1 KE3-ODSN-1 KE3 Out of range ODSN-1 -ODSN-1 KE3 PB1 -ODSN-1 KE3 PB1 Out of range ODSN-15i-ODSN-15i-ODSN-15i IN12 Out of range ODSN-16-ODSN-16-ODSN-16 PN13 Surveys Out of range ODSN-16-ODSN-16L1 -ODSN-16L1 PN13 Out of range ODSN-18-ODSN-18-ODSN-18 PN11 Out of range ODSN-18-ODSN-18 PB5-ODSN-18 PN11 PB5 Out of range ODSN-18-ODSN-18 PB2-ODSN-18 PN11 PB2 Out of range ODSN-18-ODSN-18 PB2-ODSN-18 PB2 Out of range ODSN-18-ODSN-18 PB3-ODSN-18 PN11 PB3 Out of range ODSN-18-ODSN-18 PB4-ODSN-18 PN11 PB4 Out of range ODSN-19i-ODSN-19i 34ext-ODSN-19i 34 ext K Out of range ODSN-2-ODSN-02 PN3 ext-ODSN-02 PN3 ext 19,708.93 14,150.00 253.42 113.10 142.13 Pass-Minor Risk 1/500 ODSN-23i-ODSN-23i-ODSN-23i IN14 Out of range ODSN-24-ODSN-24 KE5-ODSN-24 KE5 Out of range ODSN-24-ODSN-24 KE5 PB2-ODSN-24 KE5 P Out of range ODSN-25-ODSN-25-ODSN-25 KE1 Out of range ODSN-25-ODSN-25 PB1 -ODSN-25 P,S] Out of range ODSN-25-ODSN-25 PB3-ODSN-25 KE1 PB3 Out of range ODSN-25-ODSN-25 PB4-ODSK-25 KE1 PB4 Out of range ODSN-26i-ODSN-26i KE2-C*DSN-26i KE2 Out of range ODSN-26i-ODSN-26i KE2 PB1-ODSN-26i KE2 Out of range ODSN-26i-ODSN-26i KE2 PB2-ODSN-26 KE2 F Out of range ODSN-27i-ODSN-27i 1N4-ODSN-27i 1N4 19,268.16 17,150.00 1,738.36 414.79 1,323.58 Pass-Major Risk ODSN-29-ODSN-24 PN5-ODSN-29 PN5 Out of range ODSN-29-ODS/4-29 PN5 PB2-ODSN-29 PN5 P Out of range ODSN-31 -OOSN-31 -ODSN-31 PN6 Surveys Out of range ODSN-31 -(CDSN-31 PB1-ODSN-31 PB1 PN6 Out of range ODSN-32i-ODSN-32i 1N7-ODSN-32i IN7 Surve) Out of range ODSN-34i-(GDSN-34 1N9-ODSN-34i IN9 Survey Out of range ODSN-34i-ODSN-34i PB2-ODSN-34iPB2 IN9 Out of range G1DSN-36-ODSN-36 L1-ODSN-36a wp08 Out of range ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Sur Out of range ODSN-37-ODSN-37-ODSN-37 PN8 Out of range ODSN-37-ODSN-37 L1 -ODSN-37 L1 wp01 Out of range ODSN-3i-ODSN-3i IN4 ext-ODSN-3i IN4 wp07 19,727.03 12,375.00 1,692.33 357.11 1,342.31 Pass-Major Risk OIESN-4-ODSN-04 PN5 ext-ODSN-04 PN5 ext Out of range ODSN-4-ODSN-4 PN5 ext PB1 -ODSN-4 PN5 e Out of range ODSN-40-ODSN-40 PN12-ODSN-40 PN12 Sur Out of range ODSN-48-ODSN-48 Western ERD-ODSN-48 IS Out of range ODST-46i-ODST-46i-ODST-46i Torok C Out of range 10/29/2013 11:05:56AM Page 3 of 4 COMPASS 5000.1 Build 61 o� 0 o0o / 00o 00 •-•,..) 0 r_....----) / IIIto—:M d 0 4 ii in LO Lxa. 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E a p ...-MMM G a •Y Y Y n a uN a 0 Y Y.sbL �i0. m 0 _ry-n n P-m 6 0.0'2 2 0.0.m m z F F m 0 ffi 1 H O O 'Z-'9'-'?.:19- M M M ry r r n n ry •A ry N ry m r9 M�1 m m A A A m A A r�m G G rA R h r zii fizz i z iz• $ -^ >i X11 P0000 ,000.0.00.0.00-00.0.00-0-000.0.0--...8,8,80,80.0.2 0000-0000000000000000000000000000o000000000000000000 Ezzzz -�zzz� zii 5555iizizziziiziz�zzizizii izithNNNth thGNth� $ 0 0 000,00... 00 0 0 00 0 00 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 00 0 00 0 00 0 0 0 0 00 0 o i xli 1 x+}+$ 0100+1+004++ +1+4i DDK *$41 4 L.00000 000 0000000 000 0<+4000011111:0‹ El Tx+}+J❑0*4 0+144 TRANSMITTAL LETTER CHECKLIST WELL NAME: UO0 (AI tAIC C)nJS/v'a� PTD: ,0 i S 1 Li Kevelopment Service Exploratory Stratigraphic Test Non-Conventional FIELD: 00O ta-4& POOL: 0o lnJ 44 / I V(til ys&i 0i-) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by / (Company Name) in the attached application, the following well logs are t// Well Lo In also required for this well: gg g Requirements /Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 To (I) m a u�) o o� w n W O a) •@ 7 a) Q U uj 0 o � 0 co _co Q� >� o N 0 U) N C > m a) °J c. 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Permit No: 213-148 Surface Location: 2997' FSL, 1070' FEL, Sec. 11, T13N, R7E, UM Bottomhole Location: 3140' FSL, 3911' FEL, Sec. 36, T14N, 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. Pioneer Natural Resources Alaska, Inc. request to waive Diverter System is DENIED. Diverter system must meet requirement as set forth in 20 AAC 25.035(c). 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, CP/4 - 1(. 7(71-1—__ P Cathy 7 Foerster Chair, Commissioner DATED this / day of October, 2013. STATE OF ALASKA 1n RECEIVED P' oSKA OIL AND GAS CONSERVATION COMM SION PERMIT TO DRILL ,SEP 2 1 20 20 AAC 25.005 1a.Type of Work: 1 b.Proposed Well Class: Development-Oil 0, Service- Winj ❑ Single Zone O• 1c.Specifyit, for: Drill . 2Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed C3a� mates ❑ Redrill❑ Reentry ❑ Exploratory 0 Service- WAG 0 Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q• Single Well ❑ 11.Well Name and Number: Pioneer Natural Resources Alaska,Inc. Bond No. 103655283' ODSN-28• _ 3.Address: 700 G Street,Suite#600 6.Proposed Depth: 12.Field/Pool(s): Anchorage,AK 99501 MD: 18,823' • TVD: 6326'• 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Oooguruk-Nuiqsut Oil Pool• Surface: 2997'FSL, 1070'FEL,Sec.11,T13N,R7E,UM^ ADL 355036/ADL 389950/ADL 386958 _ Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4200'FSL,4830'FEL,Sec.6,T13N,R8E,UM • 417497 10/27/2013 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3140'FSL,3911'FEL,Sec.36,T14N,R7E,UM • 5760+2533+2560 • 326' 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-469928.86 y-6031113.39 Zone-ASP 4. GL Elevation above MSL: , 13.5 feet to Same Pool: 1218'away from ODSN-02 16.Deviated wells: Kickoff depth: •250 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: , 91.11 degrees Downhole: 3240' Surface: 2541' • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length _ MD TVD MD TVD (including stage data) 24" 16" 109# H-40 Welded 115' Surface Surface 158' 158' Driven 14-1/2" 11-3/4" 60# L-80 IBTC-;Hyd 5460' Surface Surface 5503' 3441' 604 sx PF'L';682 sx Clas'G' 52 11-3/4" 9-5/8" 40# L-80 Hyd 521 4804' 5353' 3373' 10,157' 5557' 153 sx Class'G' 8-1/2" 7" 26# L-80 851185 Hyd 12,785' Surface Surface 12,828' 6358' 523 sx Class'G' _ 6-1/8" 4-1/2" 12.6# C-110 Hyd 521 6145' 12,678' 6350' 18,823' 6326' 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 Intermediate Production • Liner Perforation Depth MD(ft): N/A Perforation Depth TVD(ft): N/A 20. Attachments: Property Plat Q BOP Sketch ❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan,343-2186 Email alex.vaughan@oxd.com Printed Name Alex Vaughan Title Sr.Drilling Engineer Prepared By:Kathy Campoamor,343-2183 Signature Phone 343-2186 Date 9/26/2013 _ C_. --i Commission Use Only Permit to Drill q API Number: Permit Approval (� r/) See cover letter for other Number: r. 3 )Lig 50-703- a QC T(0 —C)0-00 Date: \O I A '•I requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed meth-ne,gas hydrates,or gas contained in shales: [� Other: . 1--/S700 r5 EC)Y 7:7;1— Samples req'd: Yes❑ No Ei Mud log req'd:Yes❑ No❑ T // H2S measures: Yes❑ No[Zi Directional svy req'd:Yes[l No❑ Y L�IVGr iz r t< (i'G7 cc.t Scing exception req'd: Yes❑ No[Jt Inclination-only svy req'd:Yes❑ No 2k .Sutra-(- µ:7 rL yU5 ,-c..,r_.9 60.-1 ��b- �r v p-Q- r .'n.s, APPROVED BY Approved by: f7 COMMISSIONER THE COMMISSION Date:49...- 9 --73 Submit Form and Form 10-401(Revised 10/2012) This Is valid for 24 months from the date of approval(20 AAC 25.005(9)) Attachments in Duplicate ORIGINM. ; .g•,3 � 1 , ?\CA/4\ PIONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel:(907)277-2700 Fax:(907)343-2190 September 26th, 2013 RECEIVED SEP 2 .1 2013 State of Alaska AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSN-28 Surface Location: 2997' FSL, 1070' FEL, Sec. 11, T13N, R7E, UM X=469928.86, Y= 6031113.39, 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 a production well in the Oooguruk-Nuiqsut formation. PNRA requests the Permit To Drill based on approved Pool Rules. As indicated in the attachments, the drilling and well construction program includes the following: • Surface Hole: o Drill 14-1/2" to -5,503' MD/3,441' ND and set 11-3/4" casing. • Intermediate Hole 1: o Drill 10-5/8" and under-ream while drilling (UWD) to 11-3/4" to -10,157' MD / 5,557' TVD. Run and set a 9-5/8" drilling liner. • Intermediate Hole 2: o Drill 8-1/2" and under-ream while drilling (UWD) to 9-1/2" to -12,828' MD/6,358' TVD and set 7" Intermediate casing into the top of the Oooguruk-Nuiqsut formation. • Lateral Hole: o Drill 6-1/8" horizontally to -18,823' MD / 6,326' 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: o 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. Alaska Oil & Gas Cons€ ,on Commission September 26th, 2013 Page 2 of 3 PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the Intermediate 2 section and the Lateral hole section as outlined below. • Intermediate 2 shoe to TD o Use -9.8-10.5 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: • Nuiqsut Sands, -9.8 ppg Pore Pressure • Kuparuk Sands, -9.8 ppg Pore Pressure • Lateral shoe to TD o Use -7.2-8.2 ppg fluid while using MPD to control pressure from the surface to -9.8-10.2 ppg EMW at the bottom of the hole during connections and while tripping. Q %v./ Based on information previously submitted to the AOGCC and included in he 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. A map showing location of the ODSN-28 surface casing point relative to surrounding wells has been included. 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 MC 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 MC 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 MC 25.030. d. A summary of the drilling operations. e. A summary of drilling hazards per 20 MC 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 Conse, In Commission September 26th, 2013 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 Greg Griffin, Operations Geologist (20 AAC 25.071) 907.343.2141 greg.griffin©pxd.com The anticipated spud date for this well is October 27th, 2013. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. I'I Sincerely, .:ted Alex Vaughan Senior Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSN-28 Well File Permit to Drill Well Plan Summary ODSN-28 Oooguruk — Nuiqsut Single Lateral Production Well Surface TD @ 5,503' MD / 3,441' TVD Drilling Liner TD @ 10,157' MD / 5,557' TVD Intermediate TD @ 12,828' MD / 6,358' TVD Lateral TD @ 18,823' MD / 6,326' TVD Surface Location: 2997' FSL, 1070' FEL, Sec. 11, T13N, R7E, UM ASP 4 (NAD27)projection X=469928.86 Y=6031113.39 Target: Oooguruk-Nuiqsut 4200' FSL, 4830' FEL, Sec. 6, T13N, R8E, Umiat, (ADL389950) X=476617.78 Y=6037570/2 6358'TVDrkb Bottom Hole Location 3140' FSL, 3911' FEL, Sec. 36,T14N, R7E, Umiat, (ADL389958) X=472401.30 Y=6041805.03 6326' TVDrkb AFE Number:TBA Est. Start Date: October 27th, 2013 Rig: Nabors 19AC Operating days: 65 days to Drill and Complete Objective&Well Type Nuiqsut Development Well Well Design: Modified Slimhole(11-3/4"x 9-5/8" liner x 7"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:September 23rd,2013 ODSN-28 Permit To Drill Page 1 of 12 Well Control: Well Section Pressure Depth psi TVD Basis 14-1/2" Surface Section Maximum anticipated BHP 1539 3441 Based on seawater gradient of 0.4472 psi/f Maximum surface pressure 1160 ✓ Surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 10-5/8"x 11-3/4" Drilling Liner Hole Section Maximum anticipated BHP 2485 5557 (Based on seawater gradient of 0.4472 psi/ft) Maximum surface pressure 1874 / Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 8-1/2"x 9-1/2"Intermediate Casing Hole Section Maximum anticipated BHP 3240 6358 Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) Maximum surface pressure 2541 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 6-1/8" Lateral Hole Section Maximum anticipated BHP 3224 6326 Based on 9.8 ppg Oooguruk-Nuiqsut pore pressure) Maximum surface pressure 2528 ✓ Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Maximum casing pressure: 3500 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:September 23`d,2013 ODSN-28 Permit To Drill Page 2 of 12 Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 11-3/4" Surface Shoe Rathole+20' to 50'from shoe LOT 12.5 ppg 9-5/8" Drilling Liner Shoe Rathole+20'from shoe FIT 13.5 ppg • 7" Intermediate Shoe Rathole + 20'from shoe FIT 12.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 14-1/2" hole Spud Mud Interval Density(ppg) Viscosity(secs) YP PV 10 sec gel 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 Drilling Liner Mud Properties: 10-5/8"x 11-3/4" hole MOBM Interval Density(ppg) Viscosity(secs) . YP PV HTHP 0/W Initial to TD 9.5- 10.5 ppg• 55-80 12-25 15-30 800-2000 <4 (-13.0 ppg via MPD) Intermediate Hole Mud Properties: 8-1/2"x 9-1/2" hole LSND Interval Density(ppg) Viscosity(secs) YP PV MBT API FL Initial to TD 9.8- 10.5ppg • 50-70 15-25 15-25 < 10 3-5 (-13.0 ppg via (8-10 MPD) HTHP) Lateral Hole Mud Properties: 6-1/8" hole MOBM Interval Density(ppg) Viscosity(secs) YP PV HTHP O/W Initial to TD • 7.2-8.2ppg 55-80 12-25 10-20 <6 94/6 (-9.8- 2 pg via MPD Pioneer Natural Resources Last Revised:September 23`d,2013 ODSN-28 Permit To Drill Page 3 of 12 Formation Markers: Formation Tops MD (ft) TVDrkb(ft) Pore Press. EMW Comments (psi) (PP9) Base of Permafrost 1885 1724 Top West Sak 3190 2390 8.65 Base of fluvial sands Tuffaceous Shales 4664 3060 Hue2 tuff 5437 ' 3411 11-3/4" casing point 5503 3441 Brook 2B 7566 4379 Top Torok Sand 9386 5207 2342 8.65 Base Torok Sand 9926 5452 Torok Shale 1 10146 5552 9-5/8"casing point 10157 5557 Top HRZ 10782 5843 Base HRZ(Top Kalubik Sh) 11048 5958 Kalubik Mkr / 11279 6050 Top Kuparuk C 11443 6110 - 3114 9.8 LCU (Top Miluveach Sh) 11467 6118 BCU (Top Kingak Sh) 11953 6256 Top Nuiqsut ,/ 12698 6351 - 3236 9.8 Nuiqsut 1 12727 6354 Production Zone 7"casing point 12828 6358 3240 9.8 ODSN-28 TD 18823 6326 3224 9.8 Pioneer Natural Resources Last Revised:September 23"1,2013 ODSN-28 Permit To Drill Page 4 of 12 Logging Program: 14-112"Section: Drilling: Dir/GR Open Hole: N/A Cased Hole: N/A 10-5/8"x 11-314" Section: Drilling: Mud Logging Dir/GR/Res Open Hole: N/A Cased Hole: N/A 8-1/2" Section: Drilling: Mud Logging Dir/GR/Res/AzDens/Neut Open Hole: N/A Cased Hole: 6-1/8" Section: Drilling: Mud logging Dir/GR/ Res/AzDens/Neut /PWD Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised:September 23rd,2013 ODSN-28 Permit To Drill Page 5 of 12 Casing Program: Hole Casing/ Weight Grade Conn. Casing Csg/Tbg Hole Btm Size Tubing Length Top MDrkb/TVDrkb MDrkb 24" 16" 109# H-40 Welded 115 Surface 158 158 14-1/2" 11-3/4" 60# L-80 BTC-M 5460 Surface 5503 3441 11-3/4" 9-5/8" 40# L-80 Hydril 521 4804 5353 10157 5557 8-1/2" 7" 26# L-80 BTC-M & 12785 Surface 12828 6358 Hydril 563 6-1/8" 4-1/2" 12.6# C-110 Hydril 521 6145 12678 18823 6326 Tubing 4-1/2" 12.6# C-110 Hydril 521 12600 Surface 12643 6347 Casing Properties Size Weight Grade ID Drift Conn. Internal Collapse Tensile Strength ID Yield (psi) (psi) Joint Body 16" 109# H-40 14.67" 14.5" Welded Conductor casing 11-3/4" 60# L-80 10.772" 10.62" Hydril 521 5830 3180 1384M 1384M 9-5/8" 40# L-80 8.835' 8.75" Hydril 521 5750 3090 916 M 916 M 7" 26# L-80 6.276" 6.151 Hydril 563 7240 5410 604 M 604 M 7" 26# L-80 6.276" 6.151 BTC-M 7240 5410 604 M 604 M 4-1/2" 12.6# C-110 3.958" 3.833" Hydril 521 11590 9200 263 M 396 M Pioneer Natural Resources Last Revised:September 23rd,2013 ODSN-28 Permit To Drill Page 6 of 12 Cement Calculations: Casing Size: 11-3/4"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: 4,032' MD-500' MD above 3000'TVD Total Cement Volume: Preflush 10 bbl water Spacer 100 bbl 10.0 ppg Tuned Spacer Lead 469 bbls/604 sx of 10.92 ppg Type"L" Permafrost Cement. /sk, 20.0 gps water req. Tail 143 bbls/682 sx of 15.9 ppg Premium"G"+ adds. 1.18 cf/ k, 5.23 gps water req. Displ 594 bbls Mud Temp BHST-55° F, BHCT-60° F estimated 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: 9-5/8" Intermediate 1 -Drilling Liner-single stage Basis: TOC: 9,657' MD-500' MD above casing point 1 60%excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water i/ Spacer 60 bbl 10 p Dual Spacer Primary 32 bbls 053 4 Premium"G" +adds. 1.17 cf/sk "O Displ 453 bbls mud Temp BHST- 135° F, BHCT-110° F (oft°D i Casing Size: 4,: t rmediate 2-single stage Basis: TOC: 5'19)-500' MD above the top of the Kuparuk 40%excess, p"lus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 12.5 Dual Spacer Primary 109 bbls/5)sx Premium"G"+adds 1.17 cf/sk' Displ 488 bbls mud Temp BHST- 165° F, BHCT-135° F This well is outside the 112 mile radius around ODSN-DWI at the intersection with the Torok disposal zone. Disposal: Annular Iniection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal✓ well, ODSDWI-44.,- - Fluid 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, ODSDWI-44.,/ Pioneer Natural Resources Last Revised:September 23"',2013 ODSN-28 Permit To Drill Page 7 of 12 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre-Rio Work 1. 16"Conductors have been set and the Well Bay modules have been placed. Rig Activity: Drill and Complete 1. MIRU Nabors 19AC over pre-installed 16"conductor casing. 2. Nipple up spacer spools and riser. >-D,uf 3. MU 14-1/2" Directional Drilling, MWD/LWD assembly. Drill surface hole to the casing point, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 11-3/4" surface casing. Bump the plug and bring the pressure up to 3500 psi—chart and hold for 30 minute pressure test. Send chart to ODE. Note: A Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC if needed. 6. ND Riser, NU Drilling Spool and BOPE and test. Test BOPE to 250/4500 psi-Notify AOGCC 48 hours in advance of test. 7. MU 10-5/8"x 11-3/4" RSS, MWD/LWD RUMPD trip nipple. ✓ 8. RIH and cleanout casing to landing collar. Displace well over to Intermediate 1 drilling fluid. 9. Drill through surface shoe, rathole+20' of new hole and perform LOT to a minimum of 12.5 ppg. 10. RD MPD trip nipple and RU bearing assembly. 11. Drill 10-5/8"x 11-3/4" Intermediate 1 to casing point. 12. Change one set of pipe rams to 9-5/8"and test BOPE as required. 13. Run 9-5/8"drilling liner on 5" DP. Set liner hanger, release from liner and cement. 14. Bump the plug, increase pressure to 3500 psi and hold pressure for 5 minutes • This will provide a quick integrity test of the 9-5/8" liner • Note the pressure test in the morning report 15. Release pressure and ensure floats are holding • This will check the integrity of the floats to ensure there isn't a flow path through the liner shoe 16. Set liner top packer and test the liner top to 3500 psi for 5 minutes • This will check the integrity of the liner top packer to ensure isolation between the liner and the surface casing • Note the pressure test of the liner top in the morning report 17. POOH w/5" DP. 18. ND BOPE, ND Drilling spool, NU Mulitbowl Wellhead, &NU BOPE and test to 250/4500 psi- Notify AOGCC 48 hours in advance of test. • Ensure integrity of the liner and the liner top has been verified by a pressure test prior to performing this step 19. MU 8-1/2"x 9-1/2" RSS, MWD/LWD on 5" DP.SRU MPD trip nipple. 20. RIH and cleanout casing to landing collar. 21. Close pipe rams and combo pressure test the Drilling Liner and the Surface Casing to 3500 psi for 30 minutes--chart and send to ODE. 22. Drill through drilling liner shoe+ 20' of new hole and perform FIT to 13.5 ppg,_ 23. RD MPD trip nipple and RU bearing assembly. 24. Drill 8-1/2" Intermediate 2 to casing point. Pioneer Natural Resources Last Revised:September 23r1,2013 ODSN-28 Permit To Drill Page 8 of 12 25. Circulate and condition the well to run 7" intermediate casing. Displace the well over to-12.0 ppg mud for shale stability. RD the MPD bearing assembly and RU MPD trip nipple. POOH. 26. Change one set of pipe rams to 7"and test BOPE as required. 27. Run and cement the 7"26#L-80 BTC-M&Hydril 563 intermediate casing. 28. Bump the plug and bring the pressure up to 3500 psi-hold for 5 minute pressure test Release pressure and ensure floats are holding. 29. LD 5"DP 30. RU MPD trip nipple& PU 4" DP as needed to TD the lateral hole section. 31. RIH to landing collar and w/4" DP & mill tooth cleanout bit. 32. Change pipe rams to 4"and test BOPE to 250/4500 psi-Notify AOGCC 48 hours in advance of test. 33. Pressure test casing to 3500 psi-chart and hold for 30 minute pressure test unless previously done in Option #2. Send chart to ODE. 34. Drill through Intermediate 2 shoe and POOH w/cleanout assembly. 35. MU 6-1/8" RSS, MWD/LWD drilling assembly on 4" DP and RIH. 36. RD MPD trip nipple and RU bearing assembly. 37. Displace to drill-in-fluid for lateral hole. 38. Drill rathole +20'of new hole and perform FIT to 12.5 ppg. 39. Drill 6-1/8" lateral lateral hole to TD. 40. Circulate and condition hole to run liner. 41. POH to intermediate shoe and set heavy weight balance brine pill. 42. RD MPD bearing assembly and RU MPD trip nipple. Cont POH to surface. 43. Change one set of pipe rams to 4-1/2"and test BOPE as required. 44. RIH w/4-1/2" production liner w/Baker MultiPoint frac system from 150' inside the intermediate shoe to TD. 45. Release from the liner and set the liner top packer. Displace the well over to completion brine and POOH. 46. Run 4-1/2"fracture stimulation string to top of 4-1/2" liner seal bore. 47. Reverse circulate corrosion inhibited brine or diesel to freeze protect the well to-2000'TVD, 48. Sting 4-1/2" fracture stimulation string into the 4-1/2" liner seal bore. 49. 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:September 23'1,2013 ODSN-28 Permit To Drill Page 9 of 12 PNRA will submit a sundry prior to executing the following program Post Rig Operation: Fracture Stimulation - S r) a u - 1. Fracture stimulate well o 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 well. Rig Activity: ESP Completion 1. Rig up over well. 2. Install BPV and nipple down tree. 3. Pull 4'A"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 Y."OV in same. 4. Retrieve RHCM plug body 5. Rig down slickline Pioneer Natural Resources Last Revised:September 23rd,2013 ODSN-28 Permit To Drill Page 10 of 12 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:September 23`d,2013 ODSN-28 Permit To Drill Page 11 of 12 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre-reservoir meeting to outline heightened awareness for kick detection and lost circulation. o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. ✓ Lost Circulation/Breathing/Formation Stability/Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN-40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN-36 across this same interval. Review the DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK-33 well, an un-centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. • There is a small section of formation above the Top of the HRZ that is volcanic in nature (TUFFS)and can either have"glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK-33 and ODSN-45. Kick Tolerance/Integrity Testing Kick Tolerance/Integrity Testing Summary Table Casing set/ Maximum Mud Weight Exp Pore Min LOT/FIT Interval Influx Volume Press 11-3/4" Surface I 615 bbls 9.5- 10.5 ppg 2485 12.5 ppg (LOT) 10-5/8"x 11-3/4" (-13.0 ppg via MPD) 9-5/8" Drilling Liner/ 9.8-10.5 ppg 8-1/2"x 9-1/2" Infinite (13.0 EMW w/MPD) 3240 13.5 ppg (FIT), 7" Intermediate/ Infinite 7.2-8.2 ppg 3224 12.5 ppg (FIT) 6-1/8" (9.8-10.2 EMW w/MPD) 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 string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H2S site, however Standard Operating / Procedures for H2S precautions should be followed at all times. Faults • Seismic faults with expected throws of 15-40' 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:September 23"1,2013 ODSN-28 Permit To Drill Page 12 of 12 ODSN-28 Nuiqsut Pr action Well Completion•Proposed Updated 9-23-2013 WP 14 ■ i i _ No., Upper Completion(All equipment must be no less than 10.000 psi rated). _ MD(ft) ND(ft) 1 Tubing Hanger 43 43 _ 2 434"12.6#/ft C-110 Hydril 521 Tubing 3 41i"Halllburton'XXO'SVLN w/3.813""X"profile RTS-8 with single1/4"x 0.049" 2350 2005 _ HP' s/s control line.Cannon Cross-coupling clamps on every joint i(PI 4 4-X"12.6#/ftC-110Hydri 1521 Tubing — I 5 4X"x 1"GLM,KBMG Hydril 521 w/SOV ....... A 1111111 ; 6 44"12.6#/ftC-110Hydri 1521 Tubing ill it'll 16"Conductor 7 HES"X"Nipple 3.813" 3500 2531 41 8 4-24"12.6#/ftC-110 Hydril 521 Tubing fri:i 114ii j {�' 9 4X"x 1"GLM,KBM Y Hydril 521 w/DV 6600 3940 = li 1 Packer Fluid mix: 10 4r"12.6#/ftC-110H dri1521Tubin I i'..:i Inhibited Kill weight 11 4-Y,"x 1"GLM,KBMG Hydril 521w/DV 11200 6020 I 1,11; Brine 12 4/:"12.6#/ftC-110 Hydril 521 Tubing - ??? C! I with 2000'TVD 13 HES XN 3.813"(3.725"NoGo)-with RHC Plug(Max inclination 68 degrees) 11300 6058 ns l i, 14 4-X"12.6#/ft C-110 Hydril 521 Tubing i ilii ; ;;i;yl:' ,; I I, diesel cap 15 41 2 Halliburton'ROC'Gauge Carrier Encapsulated a-line to Surface 12528 6337 i it;i; f# it /" B / ps L;i i:• ,?.:; 16 4Y:"12.6#/ftC-110Hydri1521 Tubing Mil tl;`4 ilial,: 17 Bullet Seal Assembly with HLB Self-Aligning Mule Shoe 12628 6345 I t.. ;:.•• :? L u7 Bottom of Shoe 12643 6347 I IZ.r 11-3/4"60# L-80 N4, Lower Completion(All equipment must be no less than 10.000 psi rated) MD(ft) ND(ft) 5GL i Hydril 521 & BTC-M 18 Baker 5-Y."X 7"ZXP Liner Top Packer with iSft Tie Back extension and Flex lock Hanger 12628 6345 j Surface Casing 7 x j @ 5,503' MD/ 3,441' TVD 19 4-Y."12.6#/ftC-110Hydri 1521 Liner 20 4X"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers cemented to surface Halliburton Swell Palter(4X"Hydril 521)OD 5.85'-9 meter long oil activated element with i 21 slide on Volant centralizers pin end 12978 6358 iii __ 22 4-14"12.6#/ft C-110 Hydril 521 Liner Gt. I 9-5/8"40# L-80 23 HLB 4-1/2"SLHT Ball Actuated Sleeve(3.009 ball/2.95 Seat) 13241 6357 .___:.- n Hydril 521 24 4-34"12.6#/ft C-110 Hydril 521 Liner Intermediate 1 25 4-X"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-Yr"Hydril 521)OD 5.85'-9 meter long crit activated element with L. Casing 26 slide on Volant centralizers pin end 13504 6355 IS. I @ 10,157' MD/ 27 4-X"12.6#/ftC-110Hydri 1521 Liner Lo� I 5,557' TVD 28 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.925 ball/2.867 Seat) 13767 6353 Cemented 500' 29 434"12.6#/ftC-110 Hydril 521 Liner 30 4-24"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers i above shoe Halliburton Swell Packer(4X"Hydril 521)OD 5.85'-9 meter long oil activated element with 31 14029 6351 slide on Volant centralizers pin end 32 4-Y:"12.6#/ft C-110 Hydril 521 Liner i 33 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.842 ball/2.786 Seat) 14292 6349 34 4-Y:"12.6#/ft C-110 Hydril 521 Liner 4-1/2" 12.6#C-110 35 434"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers iiiiii i •:' Hydril 521 36 Halliburton Swell Packer(4X"Hydril 521)OD 5.85'-9 meter long oil activated element with 14555 6347 . _-_ .•:-::: Tubing slide on Volant centralizers pin end l (Upper Completion) III; •l1 fr -;b.N. TOC Estimated /' �t 500'above top of (mob Kuparuk 0 •' '0k%' e'!€ill;i' 2-S Go-r'�gly' i1121 6-1/8" Hole TD @ 18,823' MD/ 31 36 41 46 51 sr 56 61 66 71 c 6,326'ND ® 78 _ 0 2BTC-M & Hydril 511/563 - - Intermediate 2 Casing ■ ■ II ■ 1_ 111__ IIII 77 @ 12,828' MD/6,358' TVD 4-W Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve 1 ODSN-28 Nuiqsut Prc .ction Well Completion roposed Updated 9-23-2013 ti ' q p WP 14 • I _ I 37 4-Y"12.6#/ft C-110 Hydril 521 Liner jiA 38 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.761 ball/2.706 Seat) 14818 6346 _ ;:?ii I i 39 4-'/="12.6#/ft C-110 Hydril 521 Liner - ?;( 40 4-!12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers ``"': I Halliburton Swell Packer(41"Hydril 521)OD 5.85'-9 meter long oil activated element with I ,:::: 41 slide on Volant centralizers pin end 150B1 6343 Ilii 42 4-Y"12.6#/ftC-110 Hydril 521 Liner _ • I 43 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.681 ball/2.628 Seat) 15344 6340 _ 44 4-'!:"12.6#/ft C-110 Hydril 521 Liner ii sill I 16"Conductor 45 4-Y"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-34"Hydril 521)OD 5.85'-9 meter long oil activated element with I 46 15607 6317 Packer Fluid mix: slide on Volant centralizers pin end I Inhibited Kill weight 47 a-Y"12.6#/ft C-110 Hydril 521 Liner I Brine 48 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.603 ball/2.552 Seat) 15870 6333 3 :!::_ with 2000'TVD 49 4-Y"12.6#/ftC-110 Hydril 521 Liner 50 4-X"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers o;,� i diesel cap Halliburton Swell Packer(4x"Hydril 521)OD 585'-9 meter long oil activated element with :re: aluwnu ....;... ii':•j I ki 51 slide on Volant centralizers pin end 16132 6328 :':: • 52 4-%i'12.6#/ft C-110 Hydril 521 Liner 1 IL 53 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.527 ball/2.477 Seat) 16395 6323 54 4-'4"12.6#/ft C-110 Hydril 521 Liner _ i 11-3/4" 60# L-80 55 4-Y"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 5 GL J Hydril 521 & BTC-M 56 Halliburton Swell Packer(4X"Hydril 521)OD 5.85'-9 meter long oil activated element with 16656 6318 Surface Casing x slide on Volantcentralizers pin end 4Y 7 441' TVD 57 "12.6#/ftC-110 Hydril 521 Liner 1 I @ 5,503' MD/3 58 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.452 ball/2.404 Seat) 16921 6313 i cemented to surface 59 4-'/:"12.6#/ft C-110 Hydril 521 Liner I 60 4.-W'12.6#/ft Hydril 521-6'Pup with slide on Volant centralizersiiii - Halliburton Swell Packer(4-W'Hydril 521)0D 5.85'-9 meter long oil activated element with '`iii !J 9-5/8"40# L-80 61 slide on Volant centralizers pin end 11184 6310 ,,,s --! Hydril 521 62 4Y"12.6#/ftC-110Hydril 521 Liner Intermediate 1 63 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.379 ball/2.332 Seat) 17447 6307 I 64 4-1/:"12.6#/ft C-110 Hydril 521 Liner AN Casing 65 4-Y"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers I © 10,157' MD/ Halliburton Swell Packer(4X"Hydril 521)OD 5.85'-9 meter long oil activated element with I 5,557' TVD slide on Volant centralizers pin end 1773066 30:M I Cemented 500' 67 4-'4"12.6#/ft C-110 Hydril 521 Liner 68 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.307 ball/2.261 Seat) 17972 6307 I above shoe 69 4-%:"12.6#/ft C-110 Hydril 521 Liner I 70 4Y"12.64/ft Hydril 521-6'Pup with slide on Volant centralizers I 71 Halliburton Swell Packer(4X"Hydril 521)0D 5.85'-9 meter long oil activated element with 18235 6314 I slide on Volant centralizers pin end 72 4-Y"12.6#/ft C-110 Hydril 521 Liner I 4-1/2" 12.6#C-110 73 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.236 ball/2.192 Seat) 18498 6320 '" I . Hydril 521 74 ,4-Y"12.6#/ftC-110 Hydril 521 Liner GL M it IIIIII Tubing 75 444"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-W Hydril 521)OD 5.85'-9 meter long oil activated element with 0 *I •; I:.iii (Upper Completion) 76 slide on Volant centralizers pin end 18761 6324 I iIII 77 Pre-Perforated Pup with 434"12.6#/ft C-110 Hydril 521 Pup above and below -- .1 78 Eccentric Shoe with Float Sub 18811 6325 4,................„ Bottom of Shoe 18813 6325 TOC Estimated 500' above top of Kuparuk ..1 iiiio • • III,. :::. .,iiia. • Ifll:l 21 +LI< 6-1/8" Hole TD 1l:ill:. a@18,823' MD/ .,O O O O e 4 1111 • it 11 El O O O c 6,326'TVD '\ 31 36 41 46 51 56 61 66 71 76 I , 78 7"26# L-80 ® _ _ _ = _ _ _ - _ 2 BTC-M & Hydril 511/563 - - - - - - - e Intermediate 2 CasingIII �.__---■---.-. 1 . _/ _-._1_ _ -1--_.__■ 1 77 @ 12,828' MD/6,358' TVD 4-1/2" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve 2 1/K ti� ® 2 4 :P1' 40 � Ar ;� 0 o 1, 0 00' 4� -® � 07 rsz a n °0Al1 ,,. ; , +�; • OA '` On / p VA it V CO F- N 75I 26; ,, ,. .., I I \ .:;'::',' a \ x 00k.00 0 OO - z Z tib4. g „g gZ Zrb. 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N 4 i ' FWell Planning - Pioneer - Oooguruk Oooguruk Development ti Oooguruk Drill Site t ODSN-28 I ODSN-28 PN3 U 1Plan: ODSN-28 PN3 wp14 q I } Standard Proposal Report 23 September, 2013 I w X ice _ w "4 HALLIBURTON in" Sperry Drilling Services PIONEER HALLIBUATON REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well ODSN-28,True North NATURAL RESOURCES SFr'-,,/ C:•ilt, : Vertical(WD)Reference:42.T+13.5'al56.2Ousft(Nabors l9AC) Measured Depth Reference:42.7'+13.5'01 58.20usft(Nabors 19AC) Calculation Method:Minimum Curvature COMPANY DETAILS: Well Planning-Pioneer-Oooguruk Calculation Method:Minimum Curvature SECTION DETAILS Error System:ethod'ISCWSA Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Scan Method: Tray.Cylinder North 1 42.70 0.00 0.00 42.70 0.00 0.00 0.00 0.00 0.00 Error Stod: Elliptical Conic 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Wammg Method:Rules Based 3 403.85 5.00 130.00 403.65 -4.31 5.14 3.25 130.00 -3.07 -1 4 579.12 8.00 90.00 577.86 -9.23 23.20 3.00 -77.46 -3.86 5 2458.78 62.96 56.46 2057.22 494.58 925.79 3.00 -36.22 687.24 Project: Oooguruk Development 6 10180.59 62.96 56.46 5567.87 4294.28 6658.50 0.00 0.00 5661.67 Site: Oooguruk k Drill Site 7 12395.31 85.00 325.49 6325.05 6129.27 6907.37 4.00 -94.89 7506.23 g 8 12695.31 85.00 325.49 6351.20 6375.55 6738.07 0.00 0.00 7708.93 N28 V10 T1 Well: ODSN-28 9 12873.34 90.31 326.02 6358.47 6522.54 6638.02 3.00 5.69 7830.13 10 13282.21 90.31 326.02 6356.23 6861.60 6409.52 0.00 0.00 8110.20 Wellbore: ODSN-28 PN3 11 13286.63 90.45 326.00 6356.20 6865.26 6407.06 3.00 -10.07 8113.22 N28 V10 T2 Plan: ODSN-28 PN3 wp14 12 13318.84 90.45 325.04 6355.95 6891.81 6388.82 3.00 -89.43 8135.08 13 13571.76 90.45 325.04 6353.94 7099.08 6243.89 0.00 0.00 8305.12 SURVEY PROGRAM 14 13672.91 90.38 322.00 6353.20 7180.39 6183.76 300 -91.32 8371.10 N28V10T3 15 14007.98 90 38 311.95 6350.95 7425.03 5955.42 3.00 -89.98 8559.12 16 15006.88 90.38 311.95 6344.29 8092.73 5212.50 0.00 0.00 9045.81 Date:2013-09-23T00:00:00 Validated:Yes Version: 17 15017.06 90.68 312.00 6344.20 8099.53 5204.93 3.00 9.90 9050.77 N28 V1014 18 15060.50 90.68 313.30 6343.68 8128.96 5172.99 3.00 90.22 9072.39 Depth From Depth To Survey/Plan Tool t9 15673.05 90.68 313.30 6336.44 8549.06 4727.24 0.00 0.00 9383.40 42.70 900.00 ODSN-28 PN3 wp14 SRG-SS 20 15688.45 91.11 313.14 6336.20 8559.60 4716.02 3.00 -20.88 9391.20 N28 V10 T5 900.00 5502.00 ODSN-28 PN3 wp14 MVVD+IFR2+MS+sag 2122 15688.47 91.11 313.14 6336.20 8559.62 4716.01 3.00 -54.75 9391.21 10157.00 16355.02 91.11 313.14 6323.29 9015.29 4229.71 0.00 0.00 9727.93 5502.00 ODSN-28 PN3 wp14 MWD+IFR2+MS+sag 23 16359.96 91.02 313.26 6323.20 9018.67 4226.11 3.00 125.25 9730.43 N28 V10 T6 1 10157.00 12828.00 ODSN-28 PN3 wp14 MWD+IFR2+MS+sag 24 16360.20 91.03 313.26 6323.20 9018.83 4225.94 3.00 13.26 9730.55 12828.00 18822.81 ODSN-28 PN3 wp14 MVVD+IFR2+MS+say 25 17013.64 91.03 313.26 6311.44 9466.58 3750.15 0.00 0.00 10061.87 26 17031.41 90.51 313.14 6311.20 9478.74 3737.20 3.00 -166.74 10070.66 N28 V10 T7 27 17032.33 90.54 313.14 6311.19 9479.37 3736.53 3.00 -3.47 10071.33 - 28 17667.73 90.54 313.14 6305.21 9913.80 3272.89 0.00 0.00 10392.35 12000- 29 17702.82 89.49 313.20 6305.20 9937.81 3247.29 3.00 176.53 10410.10 N28 V10 T8 - 30 17705.57 89.57 313.21 6305.22 9939.69 3245.29 3.00 5.92 10411.48 - ODSN-28/0DSN-28 PN3 wp14 31 17996.03 89.57 313.21 6307.40 10138.55 3033.58 0.00 0.00 10558.55 _ 32 18038.88 88.29 313.08 6308.20 10167.84 3002.33 3.00 -174.08 10580.20 N28 V10 T9 11200- 412" 33 18040.72 8824 313.08 6308.26 10169.11 3000.98 3.00 178.48 10581.13 34 18339.20 88.24 313.08 6317.44 10372.86 2783.07 0.00 0.00 10731.60 _ '; ,' 35 18374.37 89.29 313.05 6318.20 10396.88 2757.38 3.00 -1.52 10749.33 N28 V10 T10 - - 36 18802.81 88.84 312.94 6325.20 10688.99 2444.05 0.11 -165.92 10964.84 N28 V10 T11 "\ I 37 18822.81 88.84 312.94 6325.61 10702.61 2429.41 0.00 0.00 10974.88 10400-- N28 V10TIII - 1 - _ I . IN28 V10 TIOI WELL.DETAILS: ODSN-28 • c_ 9600- • _I ?�. _ (N28 VI ' • , Ground Level 13.50 +N/-S +E/-W Northing Easting latittude Longitude Slot 7 - '�' , _I 0.00 0.00 6031 113.39 469928 86 70°29'45.87 N 150°14'45.21 W C 8800- IN28VIOT8I ,' p O / I , - CASING DETAILS + - IN28 vlo 1-71 ,' , 1 = 8000- ' - TVD MD Name Size t - IN28 VIOT6I ,' ,' 3441.20 5502.90 11 3/4" 11-3/4 _ , l' 5557.20 10157.13 9 5/8" 9-5/8 IN28 VlO T5I ' I 6358.19 12828.00 7" 7 • I" 7200- , - 6325.61 18822.80 41/2" 4-1/2 o - IN28VIOT4I _I 6400- - ', ' - IN28 VIOT3I ' - - IN28vloT2l / 5600- / _ DDI=7.07 4800-- N28 VIO Tl 6000 _ 4000- 9 5/8" 7) 3200- - S.C• so o - 11 3/4" • 2400- ` q, WELLBORE TARGET DETAILS(MAP CO-ORDINATES) -_ ` Name TVD +N/-S +E/-W Northing Easting Shape '! N28 V10 T8 6305.20 9937.81 3247.29 6041037.00 473216.00 Point - 1:. N28 V10 T9 6308.20 10167.84 3002.336041268.00 472972.00 Point 1600- N28 V10 T7 6311.20 9478.74 3737.20 6040576.00 473704.00 Point `q", N28 V10 T10 6318.20 10396.88 2757.38 6041498.00 472728.00 Point _- `b N28 V10 T6 6323.20 9018.67 4226.11 6040114.00 474191.00 Point _ N28 V10 T11 6325.20 10783.25 2343.776041886.00 472316.00 Point 800- .-0, N28 V10 T5 633620 8559.60 4716_02 6039653.00 474679.00 Point - o N28 V10 T4 6344.20 8099.53 5204.93 6039191.00 475166.00 Point - N28 V10 T1 6351.20 6375.55 6738.07 6037461.00 476692.00 Point ib N28 V10 T3 N28 V10 T2 6353.20 7180.39 6183.766038268.00 476141.00 Point o 6356.20 6865.26 6407.066037952.00 476363 00 0- so Point - o r i l I l i I I I 1 i l I 1 i j l /'111--rT T r I 1 l I l i l I I l I l l l l i i l I I ( l 1 l r i r 1 1 I I r 1 I 1 TI r r T i 'I 1 I j I T r l-L I l I I r-1 r r i I I I I j i -800 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000 12800 West(-)/East(+)(2000 usft/in) n True Vertical Depth(2000 usft/in) z z z z z z z z z z z zZ V mo...,,,,,,.., 000000WWmmmW3 D ^I CO a a W N + <<<<<<<<<<G m �� C".... �, 0 0 0 o o o 0 0 0 00000000000 O d 1 ` M; 0 0 0 0 0 0 0 0 0 0 n�iw�a(�i,�rnovmm my E D w r- `'O. 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- < N Z , CO 000 000000 0 000(D IO(0 CO CO CD(D(O m 0 m W m W m J�1 J 7CO m '0 _ t0 J J N N N a a w o 0 o J J J w W o 0 o N w w,- m J N m a 0I < 0 N >.Z 0 -.-.om�o.li-,coov�-s.on, -LNNw oo00o0�Vwwo- CO a '1 0— J O < <_ W W Sm WO W oolm O(wn(wo V 0,Ww+00(O V-.NONmNO W W W V Am 0-m o�Z o co a O < 4 ' O ZZ m ...--1 a zz z z z z z z z z z -i SS (),- - NN N N N N N N N N N N— + mm co m m m co co m m m I O _ << < < G G < G G < < o Oo 0 o 0 0 0 0 o 0 0l I 90 _ .-i4 -1 - -4 1 H W N r Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32 usft Latitude: 70°29'46.24 N From: Map Easting: 469,920.45usft Longitude: 150°14'45.46 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.23° Well ODSN-28 i Well Position +N/-S 0.00 usft Northing: 6,031,113.39 usfl Latitude: 70°29'45.87 N' +E/-W 0.00 usft Easting: 469,928.86 usfl Longitude: 150°14'45.21 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 13.50 usfti Wellbore ODSN-28 PN3 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (') (nT) i IGRF200510 3/8/2007 23.23 80.81 57,644 j Design ODSN-28 PN3 wp14 Audit Notes: Version: Phase: PLAN Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/.S +EJ-W Direction (usft) (usft) (usft) (°) 42.70 0.00 0.00 12.79 9/23/2013 10:28:54AM Page 2 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +Nl-S +EI.W Rate Rate Rate Tool Face (usf) (') (') (usft) usft (usft) (ust) ('1100usft) (1100usft) ('I100usft) (*) 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 193.80 0.00 0.00 0.00 0.00 0.00 0.00 403.85 5.00 130.00 403.65 347.45 -4.31 5.14 3.25 3.25 0.00 130.00 579.12 8.00 90.00 577.86 521.66 -9.23 23.20 3.00 1.71 -22.82 -77.46 2,458.78 62.96 56.46 2,057.22 2,001.02 494.58 925.79 3.00 2.92 -1.78 -36.22 10,180.59 62.96 56.46 5,567.87 5,511.67 4,294.28 6,658.50 0.00 0.00 0.00 0.00 12,395.31 85.00 325.49 6,325.05 6,268.85 6,129.27 6,907.37 4.00 1.00 -4.11 -94.89 12,695.31 85.00 325.49 6,351.20 6,295.00 6,375.55 6,738.07 0.00 0.00 0.00 0.00 12,873.34 90.31 326.02 6,358.47 6,302.27 6,522.54 6,638.02 3.00 2.99 0.30 5.69 13,282.21 90.31 326.02 6,356.23 6,300.03 6,861.60 6,409.52 0.00 0.00 0.00 0.00 j 13,286.63 90.45 326.00 6,356.20 6,300.00 6,865.26 6,407.06 3.00 2.95 -0.52 -10.07 13,318.84 90.45 325.04 6,355.95 6,299.75 6,891.81 6,388.82 3.00 0.03 -2.99 -89.43 13,571.76 90.45 325.04 6,353.94 6,297.74 7,099.08 6,243.89 0.00 0.00 0.00 0.00 13,672.91 90.38 322.00 6,353.20 6,297.00 7,180.39 6,183.76 3.00 -0.07 -3.00 -91.32 14,007.98 90.38 311.95 6,350.95 6,294.75 7,425.03 5,955.42 3.00 0.00 -3.00 -89.98 15,006.88 90.38 311.95 6,344.29 6,288.09 8,092.73 5,212.50 0.00 0.00 0.00 0.00 15,017.06 90.68 312.00 6,344.20 6,288.00 8,099.53 5,204.93 3.00 2.96 0.52 9.90 15,060.50 90.68 313.30 6,343.68 6,287.48 8,128.96 5,172.99 3.00 -0.01 3.00 90.22 15,673.05 90.68 313.30 6,336.44 6,280.24 8,549.06 4,727.24 0.00 0.00 0.00 0.00 15,688.45 91.11 313.14 6,336.20 6,280.00 8,559.60 4,716.02 3.00 2.80 -1.07 -20.88 15,688.47 91.11 313.14 6,336.20 6,280.00 8,559.62 4,716.01 3.00 1.73 -2.45 -54.75 16,355.02 91.11 313.14 6,323.29 6,267.09 9,015.29 4,229.71 0.00 0.00 0.00 0.00 16,359.96 91.02 313.26 6,323.20 6,267.00 9,018.67 4,226.11 3.00 -1.73 2.45 125.25 16,360.20 91.03 313.26 6,323.20 6,267.00 9,018.83 4,225.94 3.00 2.92 0.69 13.26 17,013.64 91.03 313.26 6,311.44 6,255.24 9,466.58 3,750.15 0.00 0.00 0.00 0.00 17,031.41 90.51 313.14 6,311.20 6,255.00 9,478.74 3,737.20 3.00 -2.92 -0.69 -166.74 17,032.33 90.54 313.14 6,311.19 6,254.99 9,479.37 3,736.53 3.00 2.99 -0.18 -3.47 1 17,667.73 90.54 313.14 6,305.21 6,249.01 9,913.80 3,272.89 0.00 0.00 0.00 0.00 17,702.82 89.49 313.20 6,305.20 6,249.00 9,937.81 3,247.29 3.00 -2.99 0.18 176.53 17,705.57 89.57 313.21 6,305.22 6,249.02 9,939.69 3,245.29 3.00 2.98 0.31 5.92 17,996.03 89.57 313.21 6,307.40 6,251.20 10,138.55 3,033.58 0.00 0.00 0.00 0.00 18,038.88 88.29 313.08 6,308.20 6,252.00 10,167.84 3,002.33 3.00 -2.98 -0.31 -174.08 18,040.72 88.24 313.08 6,308.26 6,252.06 10,169.11 3,000.98 3.00 -3.00 0.08 178.48 18,339.20 88.24 313.08 6,317.44 6,261.24 10,372.86 2,783.07 0.00 0.00 0.00 0.00 18,374.37 89.29 313.05 6,318.20 6,262.00 10,396.88 2,757.38 3.00 3.00 -0.08 -1.52 18,802.81 88.84 312.94 6,325.20 6,269.00 10,688.99 2,444.05 0.11 -0.11 -0.03 -165.92 18,822.81 88.84 312.94 6,325.61 6,269.41 10,702.61 2,429.41 0.00 0.00 0.00 0.00 9/23/201310:28:54AM Page 3 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 -- Planned Survey ---- - ---- - - Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (e) (usft) usft (usft) (usft) (usft) (usft) -13.50 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,113.39 469,928.86 0.00 0.00 100.00 0.00 0.00 100.00 43.80 0.00 0.00 6,031,113.39 469,928.86 0.00 0.00 200.00 0.00 0.00 200.00 143.80 0.00 0.00 6,031,113.39 469,928.86 0.00 0.00 250.00 0.00 0.00 250.00 193.80 0.00 0.00 6,031,113.39 469,928.86 0.00 0.00 Start Dir 3.25°/100':250'MD,250'TVD:130°RT TF 300.00 1.63 130.00 299.99 243.79 -0.46 0.54 6,031,112.93 469,929.40 3.25 -0.32 400.00 4.88 130.00 399.82 343.62 -4.10 4.89 6,031,109.27 469,933.73 3.25 -2.92 403.80 5.00 130.00 403.60 347.41 -4.31 5.14 6,031,109.06 469,933.98 3.25 -3.07 Start Dir 3°/100':403.8'MD,403.TTVD 403.85 5.00 130.00 403.65 347.45 -4.31 5.14 6,031,109.06 469,933.98 3.25 -3.07 500.00 6.29 103.36 499.35 443.15 -8.22 13.48 6,031,105.11 469,942.30 3.00 -5.04 579.12 8.00 90.00 577.86 521.66 -9.23 23.20 6,031,104.07 469,952.02 3.00 -3.86 600.00 8.51 87.50 598.52 542.32 -9.16 26.20 6,031,104.13 469,955.02 3.00 -3.13 700.00 11.13 78.84 697.06 640.86 -6.97 43.07 6,031,106.25 469,971.89 3.00 2.74 800.00 13.90 73.52 794.67 738.47 -1.69 64.06 6,031,111.44 469,992.91 3.00 12.54 900.00 16.75 69.96 891.11 834.91 6.66 89.13 6,031,119.69 470,018.01 3.00 26.23 918.92 17.30 69.41 909.20 853.00 8.59 94.33 6,031,121.60 470,023.21 3.00 29.26 Top Perm 1,000.00 19.65 67.41 986.09 929.89 18.06 118.20 6,031,130.97 470,047.12 3.00 43.78 1,100.00 22.57 65.50 1,079.37 1,023.17 32.48 151.19 6,031,145.26 470,080.17 3.00 65.15 1,200.00 25.51 64.01 1,170.69 1,114.49 49.88 188.02 6,031,162.50 470,117.06 3.00 90.26 1,300.00 28.46 62.81 1,259.80 1,203.60 70.21 228.57 6,031,182.67 470,157.69 3.00 119.06 1,400.00 31.42 61.81 1,346.45 1,290.25 93.41 272.74 6,031,205.69 470,201.95 3.00 151.47 1,500.00 34.38 60.98 1,430.40 1,374.20 119.43 320.41 6,031,231.51 470,249.72 3.00 187.39 1,600.00 37.35 60.26 1,511.43 1,455.23 148.18 371.45 6,031,260.05 470,300.87 3.00 226.73 1,700.00 40.33 59.63 1,589.32 1,533.12 179.60 425.72 6,031,291.25 470,355.26 3.00 269.38 1,800.00 43.30 59.07 1,663.84 1,607.64 213.59 483.06 6,031,325.01 470,412.74 3.00 315.23 1,884.73 45.83 58.65 1,724.20 1,668.00 244.34 533.94 6,031,355.54 470,463.73 3.00 356.47 Base Perm 1,900.00 46.28 58.57 1,734.80 1,678.60 250.07 543.33 6,031,361.23 470,473.14 3.00 364.14 2,000.00 49.26 58.12 1,802.00 1,745.80 288.92 606.35 6,031,399.83 470,536.32 3.00 415.98 2,100.00 52.25 57.71 1,865.26 1,809.06 330.06 671.96 6,031,440.69 470,602.08 3.00 470.62 2,188.11 54.88 57.38 1,917.59 1,861.39 368.10 731.77 6,031,478.49 470,662.04 3.00 520.95 Ugnu 2,200.00 55.23 57.33 1,924.40 1,868.20 373.35 739.97 6,031,483.71 470,670.26 3.00 527.89 2,300.00 58.22 56.98 1,979.26 1,923.06 418.69 810.20 6,031,528.76 470,740.67 3.00 587.65 2,400.00 61.20 56.65 2,029.69 1,973.49 465.95 882.46 6,031,575.72 470,813.11 3.00 649.74 2,458.78 62.96 56.46 2,057.22 2,001.02 494.58 925.79 6,031,604.17 470,856.56 3.00 687.24 2,458.80 62.96 56.46 2,057.23 2,001.03 494.59 925.81 6,031,604.18 470,856.57 0.00 687.25 End Dir:2458.8'MD,2057.2'TVD 2,500.00 62.96 56.46 2,075.96 2,019.76 514.86 956.39 6,031,624.33 470,887.23 0.00 713.80 2,600.00 62.96 56.46 2,121.42 2,065.22 564.07 1,030.63 6,031,673.23 470,961 67 0.00 778.22 2,700.00 62.96 56.46 2,166.88 2,110.68 613.28 1,104.87 6,031,722.13 471,036.10 0.00 842.64 2,800.00 62.96 56.46 2,212.35 2,156.15 662.48 1,179.12 6,031,771.03 471,110.53 0.00 907.06 2,900.00 62.96 56.46 2,257.81 2,201.61 711.69 1,253.36 6,031,819.93 471,184.96 0.00 971.48 , 9/23/2013 10:28:54AM Page 4 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 Planned Survey -`- Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) i°) (") (usft) usft (usft) (usft) (usft) (usft) 2,247.08 3,000.00 62.96 56.46 2,303.28 2,247.08 760.90 1,327.60 6,031,868.84 471,259.39 0.00 1,035.90 3,100.00 62.96 56.46 2,348.74 2,292.54 810.10 1,401.84 6,031,917.74 471,333.82 0.00 1,100.32 3,190.09 62.96 56.46 2,389.70 2,333.50 854.44 1,468.72 6,031,961.79 471,400.88 0.00 1,158.36 Top West Sak 3,200.00 62.96 56.46 2,394.21 2,338.01 859.31 1,476.08 6,031,966.64 471,408.26 0.00 1,164.74 3,300.00 62.96 56.46 2,439.67 2,383.47 908.52 1,550.32 6,032,015.54 471,482.69 0.00 1,229.16 3,400.00 62.96 56.46 2,485.13 2,428.93 957.73 1,624.56 6,032,064.44 471,557.12 0.00 1,293.58 3,500.00 62.96 56.46 2,530.60 2,474.40 1,006.93 1,698.80 6,032,113.34 471,631.55 0.00 1,358.00 3,600.00 62.96 56.46 2,576.06 2,519.86 1,056.14 1,773.04 6,032,162.25 471,705.98 0.00 1,422.42 3,700.00 62.96 56.46 2,621.53 2,565.33 1,105.35 1,847.28 6,032,211.15 471,780.41 0.00 1,486.84 3,800.00 62.96 56.46 2,666.99 2,610.79 1,154.56 1,921.52 6,032,260.05 471,854.84 0.00 1,551.26 3,900.00 62.96 56.46 2,712.45 2,656.25 1,203.76 1,995.76 6,032,308.95 471,929.28 0.00 1,615.68 4,000.00 62.96 56.46 2,757.92 2,701.72 1,252.97 2,070.00 6,032,357.85 472,003.71 0.00 1,680.10 4,100.00 62.96 56.46 2,803.38 2,747.18 1,302.18 2,144.24 6,032,406.76 472,078.14 0.00 1,744.53 4,200.00 62.96 56.46 2,848.85 2,792.65 1,351.39 2,218.48 6,032,455.66 472,152.57 0.00 1,808.95 4,300.00 62.96 56.46 2,894.31 2,838.11 1,400.59 2,292.72 6,032,504.56 472,227.00 0.00 1,873.37 4,400.00 62.96 56.46 2,939.77 2,883.57 1,449.80 2,366.96 6,032,553.46 472,301.43 0.00 1,937.79 4,500.00 62.96 56.46 2,985.24 2,929.04 1,499.01 2,441.20 6,032,602.36 472,375.87 0.00 2,002.21 4,600.00 62.96 56.46 3,030.70 2,974.50 1,548.22 2,515.44 6,032,651.26 472,450.30 0.00 2,066.63 4,664.44 62.96 56.46 3,060.00 3,003.80 1,579.93 2,563.29 6,032,682.78 472,498.26 0.00 2,108.14 Cret Tuff 4,700.00 62.96 56.46 3,076.17 3,019.97 1,597.42 2,589.69 6,032,700.17 472,524.73 0.00 2,131.05 4,800.00 62.96 56.46 3,121.63 3,065.43 1,646.63 2,663.93 6,032,749.07 472,599.16 0.00 2,195.47 4,900.00 62.96 56.46 3,167.09 3,110.89 1,695.84 2,738.17 6,032,797.97 472,673.59 0.00 2,259.89 5,000.00 62.96 56.46 3,212.56 3,156.36 1,745.04 2,812.41 6,032,846.87 472,748.02 0.00 2,324.31 5,100.00 62.96 56.46 3,258.02 3,201.82 1,794.25 2,886.65 6,032,895.77 472,822.46 0.00 2,388.73 11 5,200.00 62.96 56.46 3,303.49 3,247.29 1,843.46 2,960.89 6,032,944.68 472,896.89 0.00 2,453.15 5,300.00 62.96 56.46 3,348.95 3,292.75 1,892.67 3,035.13 6,032,993.58 472,971.32 0.00 2,517.57 5,400.00 62.96 56.46 3,394.42 3,338.22 1,941.87 3,109.37 6,033,042.48 473,045.75 0.00 2,581.99 5,436.92 62.96 56.46 3,411.20 3,355.00 1,960.04 3,136.78 6,033,060.53 473,073.23 0.00 2,605.78 Top Hue2 5,500.00 62.96 56.46 3,439.88 3,383.68 1,991.08 3,183.61 6,033,091.38 473,120.18 0.00 2,646.41 5,502.90 62.96 56.46 3,441.20 3,385.00 1,992.51 3,185.77 6,033,092.80 473,122.34 0.00 2,648.28 11 3/4" 5,600.00 62.96 56.46 3,485.34 3,429.14 2,040.29 3,257.85 6,033,140.28 473,194.61 0.00 2,710.83 5,700.00 62.96 56.46 3,530.81 3,474.61 2,089.50 3,332.09 6,033,189.18 473,269.05 0.00 2,775.25 5,800.00 62.96 56.46 3,576.27 3,520.07 2,138.70 3,406.33 6,033,238.09 473,343.48 0.00 2,839.67 5,900.00 62.96 56.46 3,621.74 3,565.54 2,187.91 3,480.57 6,033,286.99 473,417.91 0.00 2,904.10 6,000.00 62.96 56.46 3,667.20 3,611.00 2,237.12 3,554.81 6,033,335.89 473,492.34 0.00 2,968.52 6,100.00 62.96 56.46 3,712.66 3,656.46 2,286.33 3,629.05 6,033,384.79 473,566.77 0.00 3,032.94 6,200.00 62.96 56.46 3,758.13 3,701.93 2,335.53 3,703.29 6,033,433.69 473,641.20 0.00 3,097.36 6,300.00 62.96 56.46 3,803.59 3,747.39 2,384.74 3,777.53 6,033,482.59 473,715.63 0.00 3,161.78 6,400.00 62.96 56.46 3,849.06 3,792.86 2,433.95 3,851.77 6,033,531.50 473,790.07 0.00 3,226.20 6,500.00 62.96 56.46 3,894.52 3,838.32 2,483.16 3,926.01 6,033,580.40 473,864.50 0.00 3,290.62 [ 6,600.00 62.96 56A6 3,939.98 3,883.78 2,532.36 4,000.25 6,033,629.30 473,938.93 0.00 3,355_04 l 9/23/2013 10:28:54AM Page 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 Planned Survey Measured Vertical Map Map • Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,929.25 6,700.00 62.96 56.46 3,985.45 3,929.25 2,581.57 4,074.50 6,033,678.20 474,013.36 0.00 3,419.46 6,800.00 62.96 56.46 4,030.91 3,974.71 2,630.78 4,148.74 6,033,727.10 474,087.79 0.00 3,483.88 6,900.00 62.96 56.46 4,076.38 4,020.18 2,679.98 4,222.98 6,033,776.01 474,162.22 0.00 3,548.30 7,000.00 62.96 56.46 4,121.84 4,065.64 2,729.19 4,297.22 6,033,824.91 474,236.66 0.00 3,612.72 7,100.00 62.96 56.46 4,167.30 4,111.10 2,778.40 4,371.46 6,033,873.81 474,311.09 0.00 3,677.14 7,200.00 62.96 56.46 4,212.77 4,156.57 2,827.61 4,445.70 6,033,922.71 474,385.52 0.00 3,741.56 7,300.00 62.96 56.46 4,258.23 4,202.03 2,876.81 4,519.94 6,033,971.61 474,459.95 0.00 3,805.98 7,400.00 62.96 56.46 4,303.70 4,247.50 2,926.02 4,594.18 6,034,020.51 474,534.38 0.00 3,870.40 7,500.00 62.96 56.46 4,349.16 4,292.96 2,975.23 4,668.42 6,034,069.42 474,608.81 0.00 3,934.82 7,565.85 62.96 56.46 4,379.10 4,322.90 3,007.63 4,717.31 6,034,101.62 474,657.83 0.00 3,977.25 Brook 2B 7,600.00 62.96 56.46 4,394.63 4,338.43 3,024.44 4,742.66 6,034,118.32 474,683.25 0.00 3,999.24 7,700.00 62.96 56.46 4,440.09 4,383.89 3,073.64 4,816.90 6,034,167.22 474,757.68 0.00 4,063.66 7,800.00 62.96 56.46 4,485.55 4,429.35 3,122.85 4,891.14 6,034,216.12 474,832.11 0.00 4,128.09 7,900.00 62.96 56.46 4,531.02 4,474.82 3,172.06 4,965.38 6,034,265.02 474,906.54 0.00 4,192.51 8,000.00 62.96 56.46 4,576.48 4,520.28 3,221.27 5,039.62 6,034,313.92 474,980.97 0.00 4,256.93 8,100.00 62.96 56.46 4,621.95 4,565.75 3,270.47 5,113.86 6,034,362.83 475,055.40 0.00 4,321.35 8,200.00 62.96 56.46 4,667.41 4,611.21 3,319.68 5,188.10 6,034,411.73 475,129.83 0.00 4,385.77 8,300.00 62.96 56.46 4,712.87 4,656.67 3,368.89 5,262.34 6,034,460.63 475,204.27 0.00 4,450.19 8,400.00 62.96 56.46 4,758.34 4,702.14 3,418.09 5,336.58 6,034,509.53 475,278.70 0.00 4,514.61 8,500.00 62.96 56.46 4,803.80 4,747.60 3,467.30 5,410.82 6,034,558.43 475,353.13 0.00 4,579.03 8,600.00 62.96 56.46 4,849.27 4,793.07 3,516.51 5,485.06 6,034,607.34 475,427.56 0.00 4,643.45 8,700.00 62.96 56.46 4,894.73 4,838.53 3,565.72 5,559.31 6,034,656.24 475,501.99 0.00 4,707.87 8,800.00 62.96 56.46 4,940.19 4,883.99 3,614.92 5,633.55 6,034,705.14 475,576.42 0.00 4,772.29 8,900.00 62.96 56.46 4,985.66 4,929.46 3,664.13 5,707.79 6,034,754.04 475,650.86 0.00 4,836.71 9,000.00 62.96 56.46 5,031.12 4,974.92 3,713.34 5,782.03 6,034,802.94 475,725.29 0.00 4,901.13 9,100.00 62.96 56.46 5,076.59 5,020.39 3,762.55 5,856.27 6,034,851.84 475,799.72 0.00 4,965.55 9,200.00 62.96 56.46 5,122.05 5,065.85 3,811.75 5,930.51 6,034,900.75 475,874.15 0.00 5,029.97 9,300.00 62.96 56.46 5,167.51 5,111.31 3,860.96 6,004.75 6,034,949.65 475,948.58 0.00 5,094.39 9,385.75 62.96 56.46 5,206.50 5,150.30 3,903.16 6,068.41 6,034,991.58 476,012.41 0.00 5,149.63 Nuna Top 9,400.00 62.96 56.46 5,212.98 5,156.78 3,910.17 6,078.99 6,034,998.55 476,023.01 0.00 5,158.81 9,500.00 62.96 56.46 5,258.44 5,202.24 3,959.38 6,153.23 6,035,047.45 476,097.45 0.00 5,223.23 9,600.00 62.96 56.46 5,303.91 5,247.71 4,008.58 6,227.47 6,035,096.35 476,171.88 0.00 5,287.66 9,700.00 62.96 56.46 5,349.37 5,293.17 4,057.79 6,301.71 6,035,145.26 476,246.31 0.00 5,352.08 9,800.00 62.96 56.46 5,394.84 5,338.64 4,107.00 6,375.95 6,035,194.16 476,320.74 0.00 5,416.50 9,900.00 62.96 56.46 5,440.30 5,384.10 4,156.21 6,450.19 6,035,243.06 476,395.17 0.00 5,480.92 9,926.40 62.96 56.46 5,452.30 5,396.10 4,169.19 6,469.79 6,035,255.97 476,414.82 0.00 5,497.92 Nuna Base 10,000.00 62.96 56.46 5,485.76 5,429.56 4,205.41 6,524.43 6,035,291.96 476,469.60 0.00 5,545.34 10,100.00 62.96 56.46 5,531.23 5,475.03 4,254.62 6,598.67 6,035,340.86 476,544.04 0.00 5,609.76 10,146.35 62.96 56.46 5,552.30 5,496.10 4,277.43 6,633.08 6,035,363.53 476,578.53 0.00 5,639.62 Torok Shale 1 j 10,157.13 62.96 56.46 5,557.20 5,501.00 4,282.73 6,641.08 6,035,368.80 476,586.56 0.00 5,646.56 I 9 5/8" 9!232013 10:28:54AM Page 6 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBU " TON Standard Proposal Report Database: EDMAKPRD Local Co-ordlnate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) Project Oooguruk Development MD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 Planned Survey Measured Vertical Map Map 1 Depth Inclination Azimuth Depth TVDss +NWS +e-W Northing EastMg DLS Vert Section (usft) r) r) (usft) usft (usft) (usft) (usft) (usft) 5,511.67 10,180.59 62.96 56.46 5,567.87 5,511.67 4,294.28 6,658.50 6,035,380.27 476,604.02 0.00 5,661.67 10,180.60 62.96 56.46 5,567.87 5,511.67 4,294.28 6,658.51 6,035,380.28 476,604.03 0.00 5,661.68 Start Dir 4°1100':10180.6'MD,5567.97VD 10,200.00 62.89 55.59 5,576.70 5,520.50 4,303.93 6,672.84 6,035,389.87 476,618.39 4.00 5,674.27 10,300.00 62.65 51.10 5,622.47 5,566.27 4,356.99 6,744.15 6,035,442.63 476,689.91 4.00 5,741.79 10,400.00 62.55 46.60 5,668.50 5,612.30 4,415.39 6,810.98 6,035,500.76 476,756.97 4.00 5,813.54 10,500.00 62.60 42.09 5,714.58 5,658.38 4,478.84 6,873.01 6,035,563.95 476,819.25 4.00 5,889.15 10,600.00 62.79 37.60 5,760.47 5,704.27 4,547.04 6,929.91 6,035,631.92 476,876.43 4.00 5,968.25 10,700.00 63.13 33.12 5,805.95 5,749.75 4,619.66 6,98144 6,035,704.32 476,928.23 4.00 6,050.47 10,781.81 63.50 29.48 5,842.70 5,786.50 4,682.11 7,019.40 6,035,766.60 476,966.45 4.00 6,119.77 HRZ 10,800.00 63.60 28.68 5,850.80 5,794.60 4,696.34 7,027.32 6,035,780.80 476,974.42 4.00 6,135.40 10,900.00 64.21 24.28 5,894.80 5,838.60 4,776.70 7,067.33 6,035,860.99 477,014.76 4.00 6,222.63 11,000.00 64.95 19.92 5,937.74 5,881.54 4,860.36 7,101.29 6,035,944.50 477,049.05 4.00 6,311.73 11,048.20 65.35 17.85 5,958.00 5,901.80 4,901.74 7,115.44 6,035,985.82 477,063.37 4.00 6,355.22 Base HRZ 11,100.00 65.82 15.63 5,979.41 5,923.21 4,946.91 7,129.02 6,036,030.93 477,077.13 4.00 6,402.27 11,200.00 66.80 11.39 6,019.61 5,963.41 5,035.92 7,150.40 6,036,119.85 477,098.86 4.00 6,493.81 11,278.77 67.66 8.10 6,050.10 5,993.90 5,107.49 7,162.69 6,036,191.36 477,111.44 4.00 6,566.32 Kalubik Marker 11,300.00 67.90 7.22 6,058.13 6,001.93 5,126.97 7,165.31 6,036,210.83 477,114.14 4.00 6,585.90 11,400.00 69.10 3.12 6,094.80 6,038.60 5,219.60 7,173.68 6,036,303.42 477,122.89 4.00 6,678.09 1 ;453:46- 69.65 1.37 6,110.00 6,053.80 5,259.96 7,175.27 6,036,343.76 477,124.64 4.00 6,717.79 KupC ) 11,467.49 69.96 0.39 6,118.40 6,062.20 5,282.79 7,175.62 6,036,366.59 477,125.08 4.00 6,740.14 LCU 11,500.00 70.40 359.09 6,129.42 6,073.22 5,313.38 7,175.48 6,036,397.17 477,125.07 4.00 6,769.93 11,600.00 71.78 355.12 6,161.85 6,105.65 5,407.83 7,170.69 6,036,491.64 477,120.66 4.00 6,860.99 11,700.00 73.25 351.22 6,191.91 6,135.71 5,502.51 7,159.34 6,036,586.35 477,109.69 4.00 6,950.80 11,800.00 74.78 347.38 6,219.46 6,163.26 5,596.95 7,141.49 6,036,680.85 477,092.22 4.00 7,038.94 11,900.00 76.38 343.59 6,244.36 6,188.16 5,690.68 7,117.21 6,036,774.67 477,068.33 4.00 7,124.98 11,952.79 77.25 341.62 6,256.40 6,200.20 5,739.73 7,101.84 6,036,823.77 477,053.16 4.00 7,169.40 BCU 12,000.00 78.04 339.86 6,266.50 6,210.30 5,783.26 7,086.63 6,036,867.36 477,038.13 4.00 7,208.49 12,100.00 79.75 336.17 6,285.77 6,229.57 5,874.23 7,049.90 6,036,958.47 477,001.77 4.00 7,289.07 12,200.00 81.50 332.53 6,302.07 6,245.87 5,963.15 7,007.19 6,037,047.55 476,959.42 4.00 7,366.33 12,300.00 83.28 328.91 6,315.32 6,259.12 6,049.58 6,958.72 6,037,134.18 476,911.31 4.00 7,439.89 12,395.30 85.00 325.50 6,325.05 6,268.85 6,129.26 6,907.38 6,037,214.05 476,860.29 4.00 7,506.22 End Dir:12395.3'MD,6325.1'TVD 12,395.31 85.00 325.49 6,325.05 6,268.85 6,129.27 6,907.37 6,037,214.06 476,860.28 4.00 7,506.23 12,400.00 85.00 325.49 6,325.46 6,269.26 6,133.11 6,904.73 6,037,217.92 476,857.66 0.00 7,509.40 12,500.00 85.00 325.49 6,334.18 6,277.98 6,215.21 6,848.29 6,037,300.23 476,801.56 0.00 7,576.96 12,600.00 85.00 325.49 6,342.89 6,286.69 6,297.30 6,791.86 6,037,382.54 476,745.47 0.00 7,644.53 12,695.31 85.00 325.49 6,351.20 6,295.00 6,375.55 6,738.07 6,037,461.00 476 692.00 0.00 7,708.93 9123201310:28:54AM Page 7 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) Project Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +W-S +E/-W Northing Easting DLS Vert Section (usft) O 11 (usft) usft (ugh) (usft) (cen) lush) 6,295.20 12,697.63 85.07 325.50 6,351.40 6,295.20 6,377.45 6,736.77 6,037,462.90 476,690.70 3.00 7,710.49 Nuiqeut 12,700.00 85.14 325.51 6,351.60 6,295.40 6,379.40 6,735.43 6,037,464.86 476,689.37 3.00 7,712.10 12,726.99 85.95 325.59 6,353.70 6,297.50 6,401.58 6,720.21 6,037,487.10 476,674.24 3.00 7,730.36 Nuigsut 1 12,800.00 88.13 325.81 6,357.48 6,301.28 6,461.81 6,679.12 6,037,547.49 476,633.40 3.00 7,780.00 12,828.00 88.96 325.89 6,358.19 6,301.99 6,484.98 6,663.40 6,037,570.72 476,617.78 3.00 7,799.11 r 12,873.00 90.30 326.02 6,358.48 6,302.28 6,522.26 6,638.21 6,037,608.10 476,592.74 3.00 7,829.90 Start Geo Steering As Per Geologist 12,873.34 90.31 326.02 6,358.47 6,302.27 6,522.54 6,638.02 6,037,608.38 476,592.56 3.00 7,830.13 12,900.00 90.31 326.02 6,358.33 6,302.13 6,544.65 6,623.12 6,037,630.55 476,577.75 0.00 7,848.39 13,000.00 90.31 326.02 6,357.78 6,301.58 6,627.58 6,567.24 6,037,713.69 476,522.20 0.00 7,916.89 13,100.00 90.31 326.02 6,357.23 6,301.03 6,710.50 6,511.35 6,037,796.83 476,466.66 0.00 7,985.38 13,200.00 90.31 326.02 6,356.68 6,300.48 6,793.43 6,455.47 6,037,879.98 476,411.12 0.00 8,053.88 13,282.21 90.31 326.02 6,356.23 6,300.03 6,861.60 6,409.52 6,037,948.33 476,365.45 0.00 8,110.20 13,286.63 90.45 326.00 6,356.20 6,300.00 6,865.26 6,407.06 6,037,952.00 476,363.00 3.00 8,113.22 13,300.00 90.45 325.60 6,356.10 6,299.90 6,876.32 6,399.54 6,037,963.09 476,355.53 3.00 8,122.34 13,318.84 90.45 325.04 6,355.95 6,299.75 6,891.81 6,388.82 6,037,978.62 476,344.87 2.99 8,135.08 13,400.00 90.45 325.04 6,355.30 6,299.10 6,958.32 6,342.31 6,038,045.31 476,298.64 0.00 8,189.64 13,500.00 90.45 325.04 6,354.51 6,298.31 7,040.27 6,285.01 6,038,127.48 476,241.67 0.00 8,256.87 13,571.76 90.45 325.04 6,353.94 6,297.74 7,099.08 6,243.89 6,038,186.45 476,200.79 0.00 8,305.12 13,600.00 90.44 324.19 6,353.72 6,297.52 7,122.10 6,227.53 6,038,209.54 476,184.54 3.00 8,323.95 13,672.91 90.38 322.00 6,353.20 6,297.00 7,180.39 6,183.76 6,038,268.00 476,141.00 3.00 8,371.10 13,700.00 90.38 321.19 6,353.02 6,296.82 7,201.62 6,166.93 6,038,289.30 476,124.26 3.00 8,388.08 13,800.00 90.38 318.19 6,352.35 6,296.15 7,277.87 6,102.24 6,038,365.79 476,059.88 3.00 8,448.11 13,900.00 90.38 315.19 6,351.68 6,295.48 7,350.62 6,033.65 6,038,438.81 475,991.60 3.00 8,503.88 14,000.00 90.38 312.19 6,351.01 6,294.81 7,419.68 5,961.35 6,038,508.16 475,919.58 3.00 8,555.22 14,007.98 90.38 311.95 6,350.95 6,294.75 7,425.03 5,955.42 6,038,513.53 475,913.68 3.00 8,559.12 14,100.00 90.38 311.95 6,350.34 6,294.14 7,486.54 5,886.99 6,038,575.31 475,845.50 0.00 8,603.96 14,200.00 90.38 311.95 6,349.67 6,293.47 7,553.38 5,812.61 6,038,642.45 475,771.40 0.00 8,652.68 14,300.00 90.38 311.95 6,349.01 6,292.81 7,620.22 5,738.24 6,038,709.58 475,697.31 0.00 8,701.40 14,400.00 90.38 311.95 6,348.34 6,292.14 7,687.07 5,663.86 6,038,776.72 475,623.21 0.00 8,750.12 14,500.00 90.38 311.95 6,347.67 6,291.47 7,753.91 5,589.49 6,038,843.86 475,549.11 0.00 8,798.84 14,600.00 90.38 311.95 6,347.01 6,290.81 7,820.75 5,515.11 6,038,911.00 475,475.02 0.00 8,847.57 14,700.00 90.38 311.95 6,346.34 6,290.14 7,887.60 5,440.74 6,038,978.13 475,400.92 0.00 8,896.29 14,800.00 90.38 311.95 6,345.67 6,289.47 7,954.44 5,366.37 6,039,045.27 475,326.83 0.00 8,945.01 14,900.00 90.38 311.95 6,345.01 6,288.81 8,021.28 5,291.99 6,039,112.41 475,252.73 0.00 8,993.73 15,000.00 90.38 311.95 6,344.34 6,288.14 8,088.13 5,217.62 6,039,179.54 475,178.64 0.00 9,042.45 15,006.88 90.38 311.95 6,344.29 6,288.09 8,092.73 5,212.50 6,039,184.16 475,173.54 0.00 9,045.81 15,017.06 90.68 312.00 6,344.20 6,288.00 8,099.53 5,204.93 6,039,191.00 475,166.00 3.00 9,050.77 15,060.50 90.68 313.30 6,343.68 6,287.48 8,128.96 5,172.99 6,039,220.55 475,134.18 3.00 9,072.39 15,100.00 90.68 313.30 6,343.22 6,287.02 8,156.05 5,144.24 6,039,247.76 475,105.54 0.00 9,092.45 15,200.00 90.68 313.30 6,342.03 6,285.83 8,224.63 5,071.48 6,039,316.63 475,033.06 0.00 9,143.22 L 15300.00 90.68 313.30 6,340.85 6,284.65 8,293.21 4,998.71 6,039,385.50 474,960.58 0.00 9,193.99 9/23/201310:28:54AM Page 8 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) Project Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature We More: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NQS +E/-W Northing Easting DLS Vert Section (usft) 1°) (°) (usft) usft (waft) (usft) (uM) (usft) 6,283.47 15,400.00 90.68 313.30 6,339.67 6,283.47 8,361.80 4,925.94 6,039,454.36 474,888.09 0.00 9,244.77 15,500.00 90.68 313.30 6,338.49 6,282.29 8,430.38 4,853.17 6,039,523.23 474,815.61 0.00 9,295.54 15,600.00 90.68 313.30 6,337.30 6,281.10 8,498.96 4,780.40 6,039,592.10 474,743.13 0.00 9,346.31 15,673.05 90.68 313.30 6,336.44 6,280.24 8,549.06 4,727.24 6,039,642.41 474,690.18 0.00 9,383.40 15,688.45 91.11 313.14 6,336.20 6,280.00 8,559.60 4,716.02 6,039,653.00 474,679.00 3.00 9,391.20 15,688.47 91.11 313.14 6,336.20 6,280.00 8,559.62 4,716.01 6,039,653.01 474,678.99 3.00 9,391.21 15,700.00 91.11 313.14 6,335.98 6,279.78 8,567.50 4,707.60 6,039,660.93 474,670.61 0.00 9,397.03 15,800.00 91.11 313.14 6,334.04 6,277.84 8,635.86 4,634.64 6,039,729.58 474,597.94 0.00 9,447.55 15,900.00 91.11 313.14 6,332.10 6,275.90 8,704.22 4,561.68 6,039,798.23 474,525.26 0.00 9,498.07 16,000.00 91.11 313.14 6,330.17 6,273.97 8,772.59 4,488.73 6,039,866.88 474,452.59 0.00 9,548.58 16,100.00 91.11 313.14 6,328.23 6,272.03 8,840.95 4,415.77 6,039,935.53 474,379.92 0.00 9,599.10 16,200.00 91.11 313.14 6,326.29 6,270.09 8,909.31 4,342.81 6,040,004.18 474,307.24 0.00 9,649.62 16,300.00 91.11 313.14 6,324.36 6,268.16 8,977.68 4,269.85 6,040,072.83 474,234.57 0.00 9,700.14 16,355.02 91.11 313.14 6,323.29 6,267.09 9,015.29 4,229.71 6,040,110.60 474,194.59 0.00 9,727.93 16,359.96 91.02 313.26 6,323.20 6,267.00 9,018.67 4,226.11 6,040,114.00 474,191.00 3.00 9,730.43 16,360.20 91.03 313.26 6,323.20 6,267.00 9,018.83 4,225.94 6,040,114.16 474,190.83 3.00 9,730.55 16,400.00 91.03 313.26 6,322.48 6,266.28 9,046.11 4,196.96 6,040,141.55 474,161.96 0.00 9,750.73 16,500.00 91.03 313.26 6,320.68 6,264.48 9,114.63 4,124.15 6,040,210.36 474,089.43 0.00 9,801.44 16,600.00 91.03 313.26 6,318.88 6,262.68 9,183.15 4,051.33 6,040,279.17 474,016.91 0.00 9,852.14 16,700.00 91.03 313.26 6,317.08 6,260.88 9,251.67 3,978.52 6,040,347.97 473,944.38 0.00 9,902.84 16,800.00 91.03 313.26 6,315.28 6,259.08 9,320.19 3,905.71 6,040,416.78 473,871.85 0.00 9,953.55 16,900.00 91.03 313.26 6,313.48 6,257.28 9,388.71 3,832.90 6,040,485.59 473,799.32 0.00 10,004.25 17,000.00 91.03 313.26 6,311.68 6,255.48 9,457.23 3,760.08 6,040,554.40 473,726.80 0.00 10,054.95 17,013.64 91.03 313.26 6,311.44 6,255.24 9,466.58 3,750.15 6,040,563.79 473,716.90 0.00 10,061.87 17,031.41 90.51 313.14 6,311.20 6,255.00 9,478.74 3,737.20 6,040,576.00 473,704.00 3.00 10,070.86 17,032.33 90.54 313.14 6,311.19 6,254.99 9,479.37 3,736.53 6,040,576.63 473,703.33 3.00 10,071.33 17,100.00 90.54 313.14 6,310.55 6,254.35 9,525.64 3,687.15 6,040,623.09 473,654.15 0.00 10,105.52 17,200.00 90.54 313.14 6,309.61 6,253.41 9,594.01 3,614.18 6,040,691.75 473,581.46 0.00 10,156.04 17,300.00 90.54 313.14 6,308.67 6,252.47 9,662.38 3,541.21 6,040,760.41 473,508.78 0.00 10,206.56 17,400.00 90.54 313.14 6,307.73 6,251.53 9,730.75 3,468.24 6,040,829.07 473,436.09 0.00 10,257.08 17,500.00 90.54 313.14 6,306.79 6,250.59 9,799.12 3,395.27 6,040,897.73 473,363.41 0.00 10,307.61 17,600.00 90.54 313.14 6,305.85 6,249.65 9,867.49 3,322.31 6,040,966.39 473,290.72 0.00 10,358.13 17,667.73 90.54 313.14 6,305.21 6,249.01 9,913.80 3,272.89 6,041,012.89 473,241.50 0.00 10,392.35 17,700.00 89.57 313.20 6,305.18 6,248.98 9,935.88 3,249.35 6,041,035.06 473,218.05 3.00 10,408.67 17,702.82 89.49 313.20 6,305.20 6,249.00 9,937.81 3,247.29 6,041,037.00 473,216.00 3.00 10,410.10 17,705.57 89.57 313.21 6,305.22 6,249.02 9,939.69 3,245.29 6,041,038.88 473,214.01 3.00 10,411.48 17,800.00 89.57 313.21 6,305.93 6,249.73 10,004.34 3,176.46 6,041,103.81 473,145.45 0.00 10,459.30 17,900.00 89.57 313.21 6,306.68 6,250.48 10,072.81 3,103.58 6,041,172.56 473,072.85 0.00 10,509.93 17,996.03 89.57 313.21 6,307.40 6,251.20 10,138.55 3,033.58 6,041,238.59 473,003.13 0.00 10,558.55 18,000.00 89.45 313.20 6,307.43 6,251.23 10,141.27 3,030.69 6,041,241.31 473,000.25 3.00 10,560.56 18,038.88 88.29 313.08 6,308.20 6,252.00 10,167.84 3,002.33 6,041,268.00 472,972.00 3.00 10,580.20 18,040.72 88.24 313.08 6,308.26 6,252.06 10,169.11 3,000.98 6,041,269.27 472,970.66 3.00 10,581.13 18,100.00 88.24 313.08 6,310.08 6,253.88 10,209.57 2,957.71 6,041,309.90 472,927.55 0.00 10,611.01 18,200.00 88.24 313.08 6,313.16 6,256.96 10,277.84 2,884.70 6,041,378.46 472,854.82 0.00 10,661.43 18,300.00 88.24 313.08 6,316.23 6,260.03 10,346.11 2,811.69 6,041,447.01 472,782.10 0.00 10,711.84 9/23i2013 10:28:54AM Page 9 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +W-S +E/-W Northing Fasting DLS Vert Section til (') P) 1usf) usft (usft) (usft) Waft) lush) 6,261.24 18,339.20 88.24 313.08 6,317.44 6,261.24 10,372.86 2,783.07 6,041,473.89 472,753.59 0.00 10,731.60 18,374.37 89.29 313.05 6,318.20 6,262.00 10,396.88 2,757.38 6,041,498.00 472,728.00 3.00 10,749.33 18,400.00 89.26 313.04 6,318.52 6,262.32 10,414.37 2,738.65 6,041,515.56 472,709.35 0.11 10,762.24 18,500.00 89.16 313.02 6,319.90 6,263.70 10,482.60 2,665.56 6,041,584.08 472,636.54 0.11 10,812.60 18,600.00 89.05 312.99 6,321.46 6,265.26 10,550.80 2,592.44 6,041,652.57 472,563.70 0.11 10,862.91 18,700.00 88.95 312.96 6,323.21 6,267.01 10,618.95 2,519.29 6,041,721.02 472,490.83 0.11 10,913.19 18,800.00 88.84 312.94 6,325.14 6,268.94 10,687.08 2,446.10 6,041,789.43 472,417.93 0.11 10,963.42 18,802.81 88.84 312.94 6,325.20 6,269.00 10,688.99 2,444.05 6,041,791.35 472,415.88 0.11 10,964.84 18,822.80 88.84 312.94 6,325.61 6,269.41 10,702.60 2,429.42 6,041,805.02 472,401.31 0.00 10,974.87 4112" 18,822.81 88.84 312.94 6,325.61 6,269.41 10,702.61 2,429.41 6,041,805.03 472,401.30 0.00 10,974.88 Total Depth:18822.8VMD,6325.61'TVD 9/23201310:28:54AM Page 10 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Weilbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 Targets Target Name -hlt/miss target Dip Angle Dip Dir. TVD +NI-S +EI W Northing Eastitng -Shape r) r► (usft) Nat) (usft) (usft) Waft) N28 V10 T5 0.00 0.00 6,336.20 8,559.60 4,716.02 6,039,653.00 474,679.00 -plan hits target center -Point N28 V10 T2 0.00 0.00 6,356.20 6,865.26 6,407.06 6,037,952.00 476,363.00 -plan hits target center -Point N28 V10 T4 0.00 0.00 6,344.20 8,099.53 5,204.93 6,039,191.00 475,166.00 -plan hits target center -Point N28 V10 T3 0.00 0.00 6,353.20 7,180.39 6,183.76 6,038,268.00 476,141.00 -plan hits target center -Point N28 V10 T8 0.00 0.00 6,305.20 9,937.81 3,247.29 6,041,037.00 473,216.00 -plan hits target center -Point N28 V10 T6 0.00 0.00 6,323.20 9,018.67 4,226.11 6,040,114.00 474,191.00 -plan hits target center -Point N28 V10 T9 0.00 0.00 6,308.20 10,167.84 3,002.33 6,041,268.00 472,972.00 -plan hits target center -Point N28 V10 T7 0.00 0.00 6,311.20 9,478.74 3,737.20 6,040,576.00 473,704.00 -plan hits target center -Point N28 V10 T10 0.00 0.00 6,318.20 10,396.88 2,757.38 6,041,498.00 472,728.00 -plan hits target center -Point N28 V10 T1 0.00 0.00 6,351.20 6,375.55 6,738.07 6,037,461.00 476,692.00 -plan hits target center -Point N28 V10 T11 0.00 0.00 6,325.20 10,783.25 2,343.77 6,041,886.00 472,316.00 -plan misses target center by 117.62usft at 18822.81usft MD(6325.61 TVD,10702.61 N,2429.41 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (1 5,502.90 3,441.20 11 3/4" 11-3/4 13-1/2 12,828.00 6,358.19 7" 7 8-1/2 18,822.80 6,325.61 4 1/2" 4-1/2 6-1/8 10,157.13 5,557.20 9 5/8" 9-5/8 11-3/4 9123201310:28:54AM Page 11 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-28 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-28 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-28 PN3 Design: ODSN-28 PN3 wp14 Formations _ _ -----_— Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (0) (0) 12,697.63 6,351.40 Nuiqsut 11,278.77 6,050.10 Kalubik Marker 11,952.79 6,256.40 BCU 12,726.99 6,353.70 Nuiqsut 1 1,884.73 1,724.20 Base Perm 0.00 918.92 909.20 Top Perm 0.00 5,436.92 3,411.20 Top Hue2 1 4,664.44 3,060.00 Cret Tuff 2,188.11 1,917.59 Ugnu 11,467.49 6,118.40 LCU 9,926.40 5,452,30 Nuna Base 7,565.85 4,379.10 Brook 2B 9,385.75 5,206.50 Nuna Top 11,443.16 6,110.00 KupC 3,190.09 2,389.70 Top West Sak 10,146.35 5,552.30 Torok Shale 1 11,048.20 5,958.00 Base HRZ 10,781.81 5,842.70 HRZ Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +EI-W (usft) (usft) (usft) (usft) Comment 250.00 250.00 0.00 0.00 Start Dir 3.25°/100':250'MD,250'TVD:130°RT TF 403.80 403.60 -4.31 5.14 Start Dir 3°/100':403.8'MD,403.7'TVD 2,458.80 2,057.23 494.59 925.81 End Dir:2458.8'MD,2057.2'TVD 10,180.60 5.567.87 4.294.28 6.658 51 Start Dir 4°/100':10180.6'MD,5567.9'TVD 12,395.30 6,325.05 6,129.26 6,907.38 End Dir:12395.3'MD,6325.1'TVD 12,873.00 6,358.48 6,522.26 6,638.21 Start Geo Steering As Per Geologist 18,822.81 6,325.61 10,702.61 2,429.41 Total Depth:18822.81'MD,6325.61'TVD 9/23/2013 10:28:54AM Page 12 COMPASS 5000.1 Build 61 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-28 ODSN-28 PN3 ODSN-28 PN3 wp14 Anticollision Summary Report 23 September, 2013 la Q2' TO {ryy o ' o o ` o ` o 0 0 G Y 0 �__' N o ' ? z z P4 codIP8.Z C. w O ,�._-.`` sass gaaep�gsr�c: �sH $a9aesa��S ?$Ra8 rn N O N .1+ p ,�,._-',, ` O C cc"i1P LIZ $" °ICFs ^' a 0 .. o paa O o 5 ^ ^emmaa3 .mmm�saaa �esa Z E c 0 4• da I, #'�RIIMI voi o SSQp3880.78 81.888S�$ 038,1C8Ra88Ssa� v, c ti 0. 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'ai 8 ON OHO N� iS I.��,', •:•►'. _• •r I 1 `\ ` . 0 -O- N £00000 Z N ro' 0y / '' Y I lrY1 ' _ / o J_ 11 `\ •^`e ?o _ r�0000 Z - WW g •mm yy 33 li a Y y ` a F / 4 11 �'31t 2 •S w NO V X00 t� V O O Y„N O . 1 7 H I Z F co. O Cn O R QZ / 1(yj -1 w tQ� 1- O " 0 8 § N Z Z w ~ O v Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp14 Offset TVD Reference: Offset Datum Reference ODSN-28 PN3 wp14 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 42.70 to 1,000.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 2,078.01 usf Error Surface: Elliptical Conic Survey Tool Program Date 9/23/2013 From To (usft) (usft) Survey(Wellbore) Tool Name Description 42.70 900.00 ODSN-28 PN3 wp14(ODSN-28 PN3) SRG-SS Surface readout gyro single shot 900.00 5,502.00 ODSN-28 PN3 wp14(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:llFR dec&3-axis correction+sag 5,502.00 10,157.00 ODSN-28 PN3 wp14(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10,157.00 12,828.00 ODSN-28 PN3 wp14(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12,828.00 18,822.81 ODSN-28 PN3 wp14(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/232013 11:29:38AM Page 2 of 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp14 Offset TVD Reference: Offset Datum Summary ----- --------------__ - Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSDW1-44-ODSDW1-44 Disposal-ODSDW1 398.47 400.00 147.25 7.79 139.50 Pass-Major Risk ODSK-13-ODSK-13-ODSK-13 323.36 325.00 92.31 7.23 85.08 Pass-Major Risk ODSK-13-ODSK-13A-ODSK-13A wp01 323.36 325.00 92.31 7.23 85.08 Pass-Major Risk ODSK-13-ODSK-13P81 -ODSK-13PB1 323.36 325.00 92.31 7.23 85.08 Pass-Major Risk ODSK-13-ODSK-13PB2-ODSK-13PB2 323.36 325.00 92.31 7.23 85.08 Pass-Major Risk ODSK-14-ODSK-14-ODSK-14 KupB 298.76 300.00 100.12 6.73 93.39 Pass-Major Risk ODSK-14-ODSK-14 P81 -ODSK-14 PB1 KupB 298.76 300.00 100.12 6.73 93.39 Pass-Major Risk ODSK-14-ODSK-14 PB2-ODSK-14 PB2 KupB 298.76 300.00 100.12 6.73 93.39 Pass-Major Risk ODSK-33-ODSK-33 KupA-ODSK-33 KupA 398.02 400.00 47.80 8.84 38.96 Pass-Major Risk ODSK-33-ODSK-33 P81 KupA-ODSK-33 PB1 1 398.02 400.00 47,80 8.84 38.96 Pass-Major Risk ODSK-35Ai-ODSK-35 KupB-ODSK-35 KupB St 423.48 425.00 61.06 9.40 51.67 Pass-Major Risk ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Sury 423.48 425.00 61.06 9.40 51.67 Pass-Major Risk ODSK-38i-ODSK-38i KupD-ODSK-38i KupD Si 397.71 400.00 95.48 8.88 86.60 Pass-Major Risk ODSK-41 -ODSK-41 KupF-ODSK-41 KupF Suri 421.29 425.00 117.29 9.39 107.90 Pass-Major Risk ODSK-41 -ODSK-41 PB1 KupF-ODSK-41 PB1 I. 421.29 425.00 117.29 9.48 107.81 Pass-Major Risk ODSK-42i-ODSK-42Ai-ODSK-42Ai 349.25 350.00 122.72 7.94 114.78 Pass-Major Risk ODSK-42i-ODSK-42i KupG-ODSK-42i KupG 349.25 350.00 122.72 7.94 114.78 Pass-Major Risk ODSK-7i-ODSN-7i Ivik Kup-ODSN-7i Ivik Kup w 299.01 300.00 46.27 6.70 39.57 Pass-Major Risk ODSN-1 -ODSN-1 KE3-ODSN-1 KE3 274.57 275.00 38.79 6.08 32.72 Pass-Major Risk ODSN-1 -ODSN-1 KE3 PB1 -ODSN-1 KE3 PB1 274.57 275.00 38.79 6.08 32.72 Pass-Major Risk ODSN-10-ODSN-10 PS12-ODSN-10 PS12 wp1 323.43 325.00 63.18 7.31 55.87 Pass-Major Risk ODSN-11i-ODSN-11i IS11 -ODSN-11i IS11 wp1 249.98 250.00 69.13 5.51 63.63 Pass-Major Risk ODSN-12-ODSN-12 PS10-ODSN-12 PS10 wp1 323.38 325.00 75.35 7.31 68.05 Pass-Major Risk ODSN-15i-ODSN-15i-ODSN-15i IN12 274.35 275.00 106.94 6.24 100.70 Pass-Major Risk ODSN-16-ODSN-16-ODSN-16 PN13 Surveys 274.40 275.00 112.12 6.00 106.12 Pass-Major Risk ODSN-16-ODSN-16L1 -ODSN-16L1 PN13 274.40 275.00 112.12 6.00 106.12 Pass-Major Risk ODSN-17-ODSN-17-ODSN-17 PN13 Mid Surve 419.98 425.00 117.30 9.46 107.85 Pass-Major Risk ODSN-17-ODSN-17 L1 -ODSN-17 L1 PN13 419.98 425.00 117.30 9.46 107.85 Pass-Major Risk ODSN-18-ODSN-18-ODSN-18 PN11 323.14 325.00 125.18 7.15 118.03 Pass-Major Risk ODSN-18-ODSN-18 PB5-ODSN-18 PN11 P85 323.14 325.00 125.18 7.15 118.03 Pass-Major Risk ODSN-18-ODSN-18 PB1 -ODSN-18 PN11 PB1 323.14 325.00 125.18 7.15 118.03 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18 PN11 PB2 323.14 325.00 125.18 7.15 118.03 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18_PB2 323.14 325.00 125.18 6.55 118.65 Pass-Major Risk ODSN-18-ODSN-18 P83-ODSN-18 PN11 P83 323.14 325.00 125.18 7.15 118.03 Pass-Major Risk ODSN-18-ODSN-18 PB4-ODSN-18 PN11 P64 323.14 325.00 125.18 7.15 118.03 Pass-Major Risk ODSN-19i-ODSN-19i 34ext-ODSN-19i 34 ext K 298.54 300.00 142.73 6.75 135.98 Pass-Major Risk ODSN-2-ODSN-02 PN3 ext-ODSN-02 PN3 ext 174.99 175.00 36.34 3.81 32.54 Pass-Major Risk ODSN-2-ODSN-02 PN3 ext-ODSN-02 PN3 ext 174.99 175.00 36.34 3.81 32.54 Pass-Major Risk ODSN-2-ODSN-2 PN3 ext PB1 -ODSN-2 PN3 e 174.99 175.00 36.34 3.81 32.54 Pass-Major Risk ODSN-20-ODSDW2-20 Disposal-ODSDW2-20 371.47 375.00 150.01 8.37 141.65 Pass-Major Risk ODSN-21 -ODSN-21 PS13-ODSN-21 PS13 wp0 224.97 225.00 156.24 5.00 151.24 Pass-Major Risk ODSN-22i-ODSN-22i IS14-ODSN-22i IS14 wp0 323.08 325.00 162.84 7.28 155.56 Pass-Major Risk ODSN-23i-ODSN-23i-ODSN-23i IN14 149.99 150.00 169.93 3.24 166.69 Pass-Major Risk ODSN-23i-ODSN-23i PB1 -ODSN-23i IN14 PB1 149.99 150.00 169.93 3.24 166.69 Pass-Major Risk ODSN-23i-ODSN-23i PB2-ODSN-23i IN14 PB2 149.99 150.00 169.93 3.24 166.69 Pass-Major Risk ODSN-24-ODSN-24 KE5-ODSN-24 KE5 199.99 200.00 177.13 4.36 172.77 Pass-Major Risk ODSN-24-ODSN-24 KE5 P81 -ODSN-24 PB1 199.99 200.00 177.13 4.36 172.77 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB2-ODSN-24 KE5 P 199.99 200.00 177.13 4.36 172.77 Pass-Major Risk ODSN-25-ODSN-25-ODSN-25 KE1 199.99 200.00 21.45 4.34 17.11 Pass- Major Risk ODSN-25-ODSN-25 PB1-ODSN-25 P81 199.99 200.00 21.45 4.34 17.11 Pass-Major Risk ODSN-25-ODSN-25 PB2-ODSN-25 KE1 PB2 199.99 200.00 21.45 4.34 17.11 Pass-Major Risk ODSN-25-ODSN-25 PB3-ODSN-25 KE1 P83 199.99 200.00 21.45 4.34 17.11 Pass-Major Risk ODSN-25-ODSN-25 P84-ODSN-25 KE1 PB4 199.99 200.00 21.45 4.34 17.11 Pass-Major Risk 9/232013 11:29:38AM Page 3 of 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7+13.5'@ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp14 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSN-26i-ODSN-26 KE2 PB2-ODSN-26 KE2 F 350.08 350.00 15.26 7.86 7.40 Pass-Major Risk ODSN-26i-ODSN-26i KE2-ODSN-26i KE2 350.08 350.00 15.26 7.86 7.40 Pass-Major Risk ODSN-26i-ODSN-26i KE2 PB1-ODSN-26i KE2 350.08 350.00 15.26 7.86 7.40 Pass-Major Risk ODSN-27i-ODSN-27i IN4-ODSN-27i IN4 349.96 350.00 5.27 3.91 1.36 Pass-Minor Risk 1/200 ODSN-29-ODSN-29 PN5-ODSN-29 PN5 325.01 325.00 8.33 7.20 1.14 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB1 -ODSN-29 PN5 F 325.01 325.00 8.33 7.20 1.14 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB2-ODSN-29 PN5 F 325.01 325.00 8.33 7.20 1.14 Pass-Major Risk ODSN-30-ODSN-30 PS5-ODSN-30 PS5 wp02 349.82 350.00 14.59 7.63 6.97 Pass-Major Risk ODSN-31 -ODSN-31 -ODSN-31 PN6 Surveys 399.40 400.00 33.12 9.01 24.11 Pass-Major Risk ODSN-31 -ODSN-31 PB1 -ODSN-31 PB1 PN6 Sr 399.40 400.00 33.12 9.01 24.11 Pass-Major Risk ODSN-32i-ODSN-32i IN7-ODSN-32i IN7 Surve, 374.65 375.00 40.53 8.48 32.05 Pass-Major Risk ODSN-32i-ODSN-32iPB1 IN7-ODSN-32iPB1 IN 374.65 375.00 40.53 8.48 32.05 Pass-Major Risk ODSN-34i-ODSN-34 IN9-ODSN-34i IN9 Survey 399.13 400.00 54.81 8.87 45.94 Pass-Major Risk ODSN-34i-ODSN-34i PB2-ODSN-34iPB2 IN9 399.13 400.00 54.81 8.87 45.94 Pass-Major Risk ODSN-34i-ODSN-34i PB3-ODSN-34iPB3 IN9 399.13 400.00 54.81 8.87 45.94 Pass-Major Risk ODSN-34i-ODSN-34iPB1 -ODSN-34iPB1 IN9 399.13 400.00 54.81 8.87 45.94 Pass-Major Risk ODSN-36-ODSN-36 L1 -ODSN-36a wp08 423.52 425.00 67.25 8.56 58.69 Pass-Major Risk ODSN-36-ODSN-36 P61-ODSN-36 PB1 PN10 423.52 425.00 67.25 8.65 58.60 Pass-Major Risk ODSN-36-ODSN-36 PB2-ODSN-36 PB2 PN10 423.52 425.00 67.25 8.65 58.60 Pass-Major Risk ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Sur 423.52 425.00 67.25 8.65 58.60 Pass-Major Risk ODSN-37-ODSN-37-ODSN-37 PN8 422.93 425.00 87.31 9.59 77.72 Pass-Major Risk ODSN-37-ODSN-37 L1 -ODSN-37 L1 wp01 422.93 425.00 87.31 9.50 77.81 Pass-Major Risk ODSN-3i-ODSN-3i 1N4 ext-ODSN-3i IN4 wp07 224.99 225.00 34.20 5.02 29.18 Pass-Major Risk ODSN-4-ODSN-4 PN5 ext-ODSN-4 PN5 ext Su 174.99 175.00 33.55 3.76 29.79 Pass-Major Risk ODSN-4-ODSN-4 PN5 ext-ODSN-4 PN5 ext wp 174.99 175.00 33.55 3.76 29.79 Pass-Major Risk ODSN-40-ODSN-40 PN12-ODSN-40 PN12 Sur 397.76 400.00 109.45 8.94 100.52 Pass-Major Risk ODSN-40-ODSN-40PB1 PN12-ODSN-40PB1 P 397.76 400.00 109.45 8.94 100.52 Pass-Major Risk ODSN-40-ODSN-40PB2 PN12-ODSN-40PB2 P 397.76 400.00 109.45 8.94 100.52 Pass-Major Risk ODSN-43-ODSN-43 PS15-ODSN-43 PS15 wp0 374.11 375.00 139.41 8.28 131.13 Pass-Major Risk ODSN-48-ODSN-48 Western ERD-ODSN-48 P 249.99 250.00 173.59 5.56 168.03 Pass-Major Risk ODSN-5i-ODSN-5i IS3-ODSN-5i IS3 wp09 274.54 275.00 33.62 6.18 27.44 Pass-Major Risk ODSN-6-ODSN-6 PS4-ODSN-6 PS4 wp01 299.05 300.00 36.23 6.49 29.75 Pass-Major Risk ODSN-8-ODSN-8 PS8-ODSN-8 PS8 wp08-8K 299.00 300.00 51.36 6.66 44.70 Pass-Major Risk ODSN-9i-ODSN-9i IS9-ODSN-9i wp12-8k horz 298.98 300.00 56.88 6.66 50.23 Pass-Major Risk ODST-39-ODSN-39i IN11 -ODSN-39i IN11 374.39 375.00 101.82 8.43 93.39 Pass-Major Risk ODST-39-ODST-39 Torok D-ODST-39 Torok D 374.36 375.00 101.81 8.43 93.39 Pass-Major Risk ODST-39-ODST-39 Torok D PB1 -ODST-39 Tor 374.36 375.00 101.81 8.43 93.39 Pass-Major Risk ODST-45-ODSN-45i PB1 IN13-ODSN-45i PB1 374.10 375.00 154.36 8.62 145.74 Pass-Major Risk ODST-45-ODST-45A-ODST-45A Surveys 374.10 375.00 154.36 8.62 145.74 Pass-Major Risk ODST-46i-ODST-46i-ODST-46i Torok C 174.98 175.00 159.90 3.78 156.13 Pass-Major Risk ODST-46i-ODST-46i PB1 -ODST-46i Torok C P 174.98 175.00 159.90 3.78 156.13 Pass-Major Risk ODST-46i-ODST-46i PB2-ODST-46i Torok C P 174.98 175.00 159.90 3.78 156.13 Pass-Major Risk ODST-46i-ODST-46i Torok C PB3-ODST-46i P 174.98 175.00 159.90 3.78 156.13 Pass-Major Risk ODST-47-ODST-47-ODST-47 299.59 300.00 166.69 6.63 160.06 Pass-Major Risk 9/23/2013 11:29:38AM Page 4 of 5 COMPASS 5000.1 Build 61 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-28 ODSN-28 PN3 ODSN-28 PN3 wp14 Anticollision Summary Report 23 September, 2013 o 0 o Z 0� '� 00 � `` baoa s�1nVWainaaossa F �s � ep n F 01110111.11111* ax. rooe47R$ 2* -^ � � 'CICI N 4-. ` o e gaa 7om,,__°e•7ry:2,1,”mno�`n-onaa ° O , exRL_na2y �gm §g aaggioB w c ,' 0 rd 1111i iiiir •oDR ' ` 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A10'gc� A in00000 its \• ;S'IN ��.. - ,:4, 5% + Q p° SPI f0000a o g 0c° 41104N, �i. i. t.%if, -, �� 3o UO ~ONI�mN / 1' � :� +i �. --b N▪ 500- N 2o k. § +O EPOOOO / / . \\ \\--.-„, O t°ON 0 I 2 z// ^ 2 \\h ` Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56 2usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site Error: 0 Ousft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.0usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp14 Offset TVD Reference: Offset Datum Reference ODSN-28 PN3 wp14 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.0usft Error Model: ISCWSA Depth Range: 1,000.0 to 18,822.8usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 2,078.Ousft Error Surface: Elliptical Conic Survey Tool Program Date 9/23/2013 From To (usft) (usft) Survey(Wellbore) Tool Name Description 42.7 900.0 ODSN-28 PN3 wp14(ODSN-28 PN3) SRG-SS Surface readout gyro single shot 900.0 5,502.0 ODSN-28 PN3 wp14(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 5,502.0 10,157.0 ODSN-28 PN3 wp14(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10,157.0 12,828.0 ODSN-28 PN3 wp14(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12,828.0 18,822.8 ODSN-28 PN3 wp14(ODSN-28 PN3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/232013 1:10:12PM Page 2 of 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42 7'+ 13.5'@ 56.2usft(Nabors 19AC) Site Error: 0 Ousft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.0usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp14 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSDW1-44-ODSDW1-44 Disposal-ODSDW1 1,018.0 1,100.0 281.7 21.49 261.7 Pass-Major Risk ODSK-13-ODSK-13-ODSK-13 1,000.0 1,075.0 264.5 21.75 244.2 Pass-Major Risk ODSK-13-ODSK-13A-ODSK-13A wp01 1,000.0 1,075.0 264.5 21.75 244.2 Pass-Major Risk ODSK-13-ODSK-13PB1-ODSK-13PB1 1,000.0 1,075.0 264.5 21.75 244.2 Pass-Major Risk ODSK-13-ODSK-13PB2-ODSK-13PB2 1,000.0 1,075.0 264.5 21.75 244.2 Pass-Major Risk ODSK-14-ODSK-14-ODSK-14 KupB 1,016.0 1,100.0 288.7 25.93 265.0 Pass-Major Risk ODSK-14-ODSK-14 PB1-ODSK-14 PB1 KupB 1,016.0 1,100.0 288.7 25.93 265.0 Pass-Major Risk ODSK-14-ODSK-14 P62-ODSK-14 PB2 KupB 1,016.0 1,100.0 288.7 25.93 265.0 Pass-Major Risk ODSK-33-ODSK-33 KupA-ODSK-33 KupA 1,014.4 1,075.0 213.6 24.82 190.9 Pass-Major Risk ODSK-33-ODSK-33 PB1 KupA-ODSK-33 PB1 I 1,014.4 1,075.0 213.6 24.82 190.9 Pass-Major Risk ODSK-35Ai-ODSK-35 KupB-ODSK-35 KupB SL 1,000.0 1,050.0 188.2 22.65 167.2 Pass-Major Risk ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Sury 1,000.0 1,050.0 188.2 22.65 167.2 Pass-Major Risk ODSK-38i-ODSK-38i KupD-ODSK-38i KupD St. 1,015.2 1,075.0 213.0 22.88 191.8 Pass-Major Risk ODSK-41 -ODSK-41 KupF-ODSK-41 KupF Sury 1,010.3 1,075.0 229.7 21.66 209.4 Pass-Major Risk ODSK-41-ODSK-41 P61 KupF-ODSK-41 PB1 I, 1,010.3 1,075.0 229.7 21.75 209.3 Pass-Major Risk ODSK-42i-ODSK-42Ai-ODSK-42Ai 1,000.0 1,075.0 255.9 24.96 232.6 Pass-Major Risk ODSK-42i-ODSK-42i KupG-ODSK-42i KupG 1,000.0 1,075.0 255.9 24.96 232.6 Pass-Major Risk ODSK-7i-ODSN-7i Ivik Kup-ODSN-7i Ivik Kup w 1,007.9 1,050.0 191.4 25.02 167.6 Pass-Major Risk ODSN-1 -ODSN-1 KE3-ODSN-1 KE3 1,013.5 1,075.0 254.9 24.11 232.4 Pass-Major Risk ODSN-1 -ODSN-1 KE3 PB1 -ODSN-1 KE3 PB1 1,013.5 1,075.0 254.9 24.11 232.4 Pass-Major Risk ODSN-10-ODSN-10 PS12-ODSN-10 PS12 wp1 1,016.2 1,075.0 221.7 25.26 198.5 Pass-Major Risk ODSN-11i-ODSN-11i IS11 -ODSN-11i IS11 wp1 1,000.0 1,125.0 387.3 29.62 363.0 Pass-Major Risk ODSN-12-ODSN-12 PS10-ODSN-12 PS10 wp1 1,018.1 1,100.0 270.6 24.15 248.4 Pass-Major Risk ODSN-15i-ODSN-15i-ODSN-15i IN12 1,010.8 1,100.0 304.7 23.41 283.3 Pass-Major Risk ODSN-16-ODSN-16-ODSN-16 PN13 Surveys 1,000.0 1,100.0 326.8 25.85 303.9 Pass-Major Risk ODSN-16-ODSN-16L1 -ODSN-16L1 PN13 1,000.0 1,100.0 326.8 25.85 303.9 Pass-Major Risk ODSN-17-ODSN-17-ODSN-17 PN13 Mid Surve 1,015.8 1,100.0 285.2 25.16 262.2 Pass-Major Risk ODSN-17-ODSN-17 L1 -ODSN-17 L1 PN13 1,015.8 1,100.0 285.2 25.16 262.2 Pass-Major Risk ODSN-18-ODSN-18-ODSN-18 PN11 1,000.0 1,100.0 312.9 24.75 290.4 Pass-Major Risk ODSN-18-ODSN-18 PB5-ODSN-18 PN11 PB5 1,000.0 1,100.0 312.9 24.75 290.4 Pass-Major Risk ODSN-18-ODSN-18 P61 -ODSN-18 PN11 PB1 1,000.0 1,100.0 312.9 24.75 290.4 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18 PN11 PB2 1,000.0 1,100.0 312.9 24.75 290.4 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18_PB2 1,000.0 1,100.0 312.9 22.52 292.4 Pass-Major Risk ODSN-18-ODSN-18 PB3-ODSN-18 PN11 PB3 1,000.0 1,100.0 312.9 24.75 290.4 Pass-Major Risk ODSN-18-ODSN-18 P84-ODSN-18 PN11 PB4 1,000.0 1,100.0 312.9 24.75 290.4 Pass-Major Risk ODSN-19i-ODSN-19i 34ext-ODSN-19i 34 ext K 1,013.6 1,200.0 496.5 25.01 474.1 Pass-Major Risk ODSN-2-ODSN-02 PN3 ext-ODSN-02 PN3 ext 18,798.5 13,225.0 228.7 292.16 48.4 Pass-Major Risk ODSN-2-ODSN-02 PN3 ext-ODSN-02 PN3 ext 18,798.5 13,225.0 228.7 296.33 43.2 Pass-Major Risk ODSN-2-ODSN-2 PN3 ext PB1 -ODSN-2 PN3 e 1,011.7 1,050.0 252.6 23.99 228.8 Pass-Major Risk ODSN-20-ODSDW2-20 Disposal-ODSDW2-20 1,010.9 1,150.0 408.9 28.47 383.9 Pass-Major Risk ODSN-21-ODSN-21 PS13-ODSN-21 PS13 wp0 1,014.6 1,200.0 507.9 27.63 484.4 Pass-Major Risk ODSN-22i-ODSN-22i IS14-ODSN-22i IS14 wp0 1,013.3 1,150.0 411.7 23.82 389.7 Pass-Major Risk ODSN-23i-ODSN-23i-ODSN-23i IN14 1,000.0 1,225.0 569.8 23.43 549.2 Pass-Major Risk ODSN-23i-ODSN-23i PB1 -ODSN-23i IN14 PB1 1,000.0 1,250.0 603.3 25.01 582.3 Pass-Major Risk ODSN-23i-ODSN-23i PB2-ODSN-23i IN14 PB2 1,000.0 1,225.0 569.8 23.43 549.2 Pass-Major Risk ODSN-24-ODSN-24 KE5-ODSN-24 KE5 1,000.0 1,175.0 486.8 23.10 466.3 Pass-Major Risk ODSN-24-ODSN-24 KE5 P61 -ODSN-24 P81 1,000.0 1,175.0 486.8 23.10 466.3 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB2-ODSN-24 KE5 P 1,000.0 1,175.0 486.8 23.10 466.3 Pass-Major Risk ODSN-25-ODSN-25-ODSN-25 KE1 1,006.6 1.025.0 205.3 22.72 182.6 Pass-Major Risk ODSN-25-ODSN-25 PB1 -ODSN-25 PB1 1,006.6 1,025.0 205.3 22.72 182.6 Pass-Major Risk ODSN-25-ODSN-25 PB2-ODSN-25 KE1 PB2 1,006.6 1,025.0 205.3 22.72 182.6 Pass-Major Risk ODSN-25-ODSN-25 PB3-ODSN-25 KE1 P83 1,006.6 1,025.0 205.3 22.72 182.6 Pass-Major Risk ODSN-25-ODSN-25 PB4-ODSN-25 KE1 P64 1,006.6 1,025.0 205.3 22.72 182.6 Pass-Major Risk 9/232013 1:10:12PM Page 3 of 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-28 Project: Oooguruk Development TVD Reference: 42.7'+13.5'©56.2usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site Error: 0 Ousft North Reference: True Reference Well: ODSN-28 Survey Calculation Method: Minimum Curvature Well Error: 0.0usft Output errors are at 2.00 sigma Reference Wellbore ODSN-28 PN3 Database: EDMAKPRD Reference Design: ODSN-28 PN3 wp14 Offset TVD Reference: Offset Datum Summary ------- ------- ----- - Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSN-26i-ODSN-26 KE2 PB2-ODSN-26 KE2 F 1,012.4 1,025.0 120.7 22.45 98.8 Pass-Major Risk ODSN-26i-ODSN-26i KE2-ODSN-26i KE2 1,012.4 1,025.0 120.7 22.45 98.8 Pass-Major Risk ODSN-26i-ODSN-26i KE2 PB1 -ODSN-26i KE2 1,012.4 1,025.0 120.7 22.45 98.8 Pass-Major Risk ODSN-27i-ODSN-27i IN4-ODSN-27i IN4 1,011.8 1,025.0 73.2 22.96 52.1 Pass-Major Risk ODSN-29-ODSN-29 PN5-ODSN-29 PN5 1,005.2 1,025.0 102.1 23.22 79.0 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB1 -ODSN-29 PN5 F 1,005.2 1,025.0 102.1 23.22 79.0 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB2-ODSN-29 PN5 F 1,005.2 1,025.0 102.1 23.22 79.0 Pass-Major Risk ODSN-30-ODSN-30 PS5-ODSN-30 PS5 wp02 1,017.2 1,050.0 139.3 24.34 117.0 Pass-Major Risk ODSN-31 -ODSN-31-ODSN-31 PN6 Surveys 1,018.5 1,050.0 128.2 25.15 104.5 Pass-Major Risk ODSN-31 -ODSN-31 PB1-ODSN-31 PB1 PN6 Si 1,018.5 1,050.0 128.2 25.15 104.5 Pass-Major Risk ODSN-32i-ODSN-32i IN7-ODSN-32i IN7 Surve, 1,011.7 1,050.0 153.2 25.06 129.9 Pass-Major Risk ODSN-32i-ODSN-32iPB1 IN7-ODSN-32iPB1 IN 1,011.7 1,050.0 153.2 25.06 129.9 Pass-Major Risk ODSN-34i-ODSN-34 IN9-ODSN-34i IN9 Survey 1,008.8 1,050.0 160.4 24.69 137.1 Pass-Major Risk ODSN-34i-ODSN-34i PB2-ODSN-34iPB2 IN9 1,008.8 1,050.0 160.4 24.69 137.1 Pass-Major Risk ODSN-34i-ODSN-34i PB3-ODSN-34iPB3 IN9 1,008.8 1,050.0 160.4 24.69 137.1 Pass-Major Risk ODSN-34i-ODSN-34iPB1-ODSN-34iPB1 IN9 1,008.8 1,050.0 160.4 24.69 137.1 Pass-Major Risk ODSN-36-ODSN-36 L1 -ODSN-36a wp08 1,007.7 1,050.0 165.3 21.17 145.2 Pass-Major Risk ODSN-36-ODSN-36 PB1-ODSN-36 PB1 PN10 1,007.7 1,050.0 165.3 21.26 145.1 Pass-Major Risk ODSN-36-ODSN-36 PB2-ODSN-36 PB2 PN10 1,007.7 1,050.0 165.3 21.26 145.1 Pass-Major Risk ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Sur 1,007.7 1,050.0 165.3 21.26 145.1 Pass-Major Risk ODSN-37-ODSN-37-ODSN-37 PN8 1,020.1 1,075.0 200.8 25.01 177.3 Pass-Major Risk ODSN-37-ODSN-37 L1 -ODSN-37 L1 wp01 1,020.1 1,075.0 200.8 24.93 177.4 Pass-Major Risk ODSN-3i-ODSN-3i IN4 ext-ODSN-3i IN4 wp07 1,010.7 1,075.0 304.6 26.03 280.1 Pass-Major Risk ODSN-4-ODSN-4 PN5 ext-ODSN-4 PN5 ext Su 1,013.6 1,150.0 409.8 25.06 387.4 Pass-Major Risk ODSN-4-ODSN-4 PN5 ext-ODSN-4 PN5 ext wp 1,013.6 1,150.0 409.8 25.06 387.4 Pass-Major Risk ODSN-40-ODSN-40 PN12-ODSN-40 PN12 Sur 1,008.3 1,075.0 238.2 23.50 215.9 Pass-Major Risk ODSN-40-ODSN-40PB1 PN12-ODSN-4OPB1 P 1,008.3 1,075.0 238.2 23.50 215.9 Pass-Major Risk ODSN-40-ODSN-40PB2 PN12-ODSN-40PB2 P 1,008.3 1,075.0 238.2 23.50 215.9 Pass-Major Risk ODSN-43-ODSN-43 PS15-ODSN-43 PS15 wp0 1,011.9 1,100.0 302.4 25.01 278.2 Pass-Major Risk ODSN-48-ODSN-48 Western ERD-ODSN-48 P 1,000.0 1,250.0 606.6 26.42 584.3 Pass-Major Risk ODSN-5i-ODSN-5i IS3-ODSN-5i IS3 wp09 1,021.4 1,050.0 158.0 25.27 133.9 Pass-Major Risk ODSN-6-ODSN-6 PS4-ODSN-6 PS4 wp01 1,019.8 1,050.0 136.0 24.02 114.0 Pass-Major Risk ODSN-8-ODSN-8 PS8-ODSN-8 PS8 wp08-8K 1,003.8 1,050.0 189.9 24.89 166.8 Pass-Major Risk ODSN-9i-ODSN-9i IS9-ODSN-9l wp12-8k horz 1,007.0 1,075.0 255.4 24.50 232.6 Pass-Major Risk ODST-39-ODSN-39i IN11-ODSN-39i IN11 1,014.7 1,075.0 221.1 22.50 199.8 Pass-Major Risk ODST-39-ODST-39 Torok D-ODST-39 Torok D 1,014.7 1,075.0 221.1 22.50 199.8 Pass-Major Risk ODST-39-ODST-39 Torok D PB1 -ODST-39 Tor 1,014.7 1,075.0 221.1 22.50 199.8 Pass-Major Risk ODST-45-ODSN-45i PB1 IN13-ODSN-45i PB1 1,013.7 1,100.0 300.4 22.29 279.3 Pass-Major Risk ODST-45-ODST-45A-ODST-45A Surveys 1,013.7 1,100.0 300.4 22.29 279.3 Pass-Major Risk ODST-46i-ODST-46i-ODST-46i Torok C 1,010.2 1,150.0 435.7 22.37 413.5 Pass-Major Risk ODST-46i-ODST-46i PB1 -ODST-46i Torok C P 1,010.2 1,150.0 435.7 22.37 413.5 Pass-Major Risk ODST-46i-ODST-46i PB2-ODST-46i Torok C P 1,010.2 1,150.0 435.7 22.37 413.5 Pass-Major Risk ODST-46i-ODST-46i Torok C PB3-ODST-46i P 1,010.2 1,150.0 435.7 22.37 413.5 Pass-Major Risk ODST-47-ODST-47-ODST-47 1,013.3 1,175.0 464.5 23.80 442.4 Pass-Major Risk Oooguruk Offset Wells Ivik 1 -Ivik 1-Ivik 1 9,984.1 5,475.0 661.9 191.14 470.8 Pass-Major Risk 9/23/2013 1:10:12PM Page 4 of 5 COMPASS 5000.1 Build 61 >c)z 15 os m _ . o-' F.ate -. (D n . n ; c n Qa `. a p pppp c 4.j ?A p" A 0 • o V e ,P, w O ° ?0 0. ° 4 f5 ? 0 0 19 0 ° gj �6 TeS 0 0 1) id. o 0 1J m 0 0 vv ° ° 79 n > CO x3 a 1T 71 =IZ 0 13 moi Z m o ° - O x? ° Z v, 0 4 to o 3 0 ��J 0 1® C O ��0 gc9' ' o A 0000 0 3,C e J m o 30 3omo O ° oo v_ x a 4 nolag. p 3S 0 o d Q =egg - sr 0 o J 307 o 0 1J 31 0 0' e 1 0 0 00 o I ° �! ar,f,, .,,�5�,,mZ te o L s• _ tiVA'j ?J 0 rel 0 COv � f �J •�. 6.� $ ?s T '42 • • 1 -- O ft r • / Q I1 • .'..e a m 2 �-� , 9p • • o g 1 C m slj �. ?- em= 10 I1° 1 I : i I • a i •Visiriti Boundry j I \ I SE Corner of I ` ,`OOOGURUK SCFE Protracted Section;11 wi 15. �� Coordinates I'll i N 6028111.04 Zl I l i I E 470989.01 i a \\ •1 r l E/ PI- 4 \\ ' Ref. AK BLM . i _ II , CC 3j ♦`• " 0. Harrison. Bay Tract, "A" I ♦ Pl-2a%\ I ReUrci rowing I: 1 , ( » 22 0. i 1 ! • PI-`,2 , ► ., ' i }� �' I �D Offshore Pi I er�D O=5.99WesW 1 ��N .f +'PI-73 b Or *% `\ Nil" -P. J-14 ~~� 4 i••� ..p i_ lUnaro 'mac s i , 1. , DS 3Rt BO.P. ♦ i" Roods to!ala I • y s I Ti Ida pi . yam•, I�PI . � W-7S 3Fl- i, -� EN _ Basis of Location BUC E �,�;� i, .. DS-3H West Monument 7: , . •• •] .A.�]Ltd r♦ o • a.' .. I * Coordinates N 6001016.61 J `" i a 3• E 498081.23 STAKED PI INFORMATION ONLY ,) p �'__`..i �' „ • ! �/ �' Ref. Lownsbury & Assoc. 11 �� A ID :: ! e Drawing No. Dr-, 1 Cr Cr --s' NSK 6.01-d672 Ls. '11% ..:PA.Q ..OF••A�Q �a il ! y 11,17•,fr.sail ajoilip fio i • ilip G.Dais Ili i r '*. 7. 4+II\ No.4110.5 •.a``'dso a _'I-� _ -. Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7-12-07 Umiat Meridion NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location 05204 2 of 4 - - -A:Iaska State I :eolion Llr>a Q.._at r--- _-__ Latitude (N) Longitude (VV) - - Pad Elev, Y X FSL FEL 1 6,031,151.32 _469,920,45 70 29 46.24150 150 14 45,46468 3035 1077 13.50 .T031,-146,35-031,146,35 469,915,52 70 29 46.1925 -160714 45.60922 -3030 1082 13,50 "--37-----6,-0-3-1-,-14-1--,39----4601-0-4-9-TO-4 46.14$54 15014 45,75375 3025 1087 - ... - ---48 "460-.. . ...'...'..---70 29 46.09465 .-..1501 145.89799 - 0 - - --4 6,031,136.46 ,905,67 3020 1092 13.80 5 6,031,131,45 469,900,74 70 29 .46,04538 15014 46,04259 3016 1097 13.50 6 6,031,126,51 459,895,80 70 29 45,99660 15014. 46,16735 3010 1102 13.50 7 6,031,113,73 469,883.13 70 29 45.87039 150 14 46.55879 2997 1115 13,50 8 6,031,108.73 469,878.21 -76-29 45,82102 "160-14 46,7ow 2992 11-210------1--3,50 9 6,031,103.75 469,873,261 70 29 45.77184 150 14 46,84814 2907 1125 13.50 10 0,031,098,79--.._1,098.79-..__469,868,36 70 29 45,72286 150 14 46,99179 2962 1130 13,50 11 6,031,093.84 469,863,30 70 29 45,67398 150 14 47,13750 2977 1135 1350- 12 6,03-1,088,87 469,858.47 -- - 70 29 45,62490 150 14 _4..7,28174 2972 1140 13.50 13 6,031,076,06 469,84.5,61 70 29 45.4.9840 1$0 14 47,65288 2960 1152 13,50 14 6,031,071,09 469,840,87 70 29 45,44932 1501.4.47,79770 2955 1157 13,50 15 6,031,066.15 469,835,96 7029 45 40053 150-14 47,94165 2950 1152 13.50 16 '-6,031,061.18 -469,831,04 70 29 45.35145 150 14 48,o8585 2946 1167 13,5Q- -17 3 5Q17 6,031,056,25 469,626,11 70 29 45,30277 150 14-46:2M2 2940 1172 13.50 18 6031-,06-1.27 469,821.18 70-20-45:2-5359 150 14 48,37495 2935 1177 13:50-- -19 6,031,038,52 469,80t3, 0 702945,12768 150 14. 48,74668 2922 1189 13759- - ..... --- -... � ...----_ __------------------_...._.......----------..__.-...--------------- 20 6,031,033,50 469,603.59 70 29 45,07811 . 150 14 48.89061 2917 1194 - 13.5Q 21 6,031,0203 469,798,62 70 29 45,02903 150 14 49,03632 2912 1199 13,60 22 6,031,023.56 469,793,67 70 29 44,98014 150-14 49,18144 2907 1204 13,60-- 23 6,031,016,57 469,788,76 __70 29 44,93067 150 14 49,32537 2902 1209 13.50 24 6,031,013,60 469,783,84 70 2944,88159 150 14_49,4696.0 2897 1214 13,50 OF 11( 1,1 r;11 Philip G.Davis : o- 414iPA No..�110.5 •o'" .‘/ ' Plates= 1, Devotions are based on SP Mean Sec Level, '"�' "- 2, 0oordinotes ore hosed on Alosko Stgte Piane Nod 27, Zone 4, 3, Ali conductors VC within Protrocted Section 11, Pioneer Notur-ol Resouces JOE NAME: Qoogur-uk Drill site Conductors DRAWN BY: 8L CHECKED BY: Map LOCATION: Protracted Section 11 SCALE' N/A Township 13 North Range 7 East DATE: 7=1207 Limiot Mer-idion _. NANUQ JOB NO. SHEET )E CRIPTION; As-built Coorclingtes 05204 3 of 4 Alaska State Section Line Offset Well No. Latitude (N) Longitude 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 150 14 45.87163 2975 1092 13.50 32 6,031,085.68 469,901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 33 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128 2965 1102 13.50 34 6,031,075.73 469,891.57 70 29 45.49698 150 14 46.30581 2960 1106 13.50 35 6,031,070.76 469,886.60 70 29 45.44789 150 14 46.45152 2955 1111 13.50 36 6,031,065.83 469,881.69 70 29 45.39921 150 14 46.59547 2950 1116 13.50 37 6,031,053.00 469,869.00 70 29 45.27251 150 14 46.96749 2937 1129 13.50 38 6,031,047.99 469,864.14 70 29 45.22304 150 14 47.10995 2932 1134 13.50 39 6,031,043.03 469,859.20 70 29 45.17406 150 14 47.25478 2927 1139 13.50 40 6,031,038.10 469,854.21 70 29 45.12537 150 14 47.40108 2922 1144 13.50 41 6,031,033.05 469,849.29 70 29 45.07551 150 14 47.54530 2917 1149 13.50 42 6,031,028.13 469,844.38 70 29 45.02692 150 14 47.68925 2912 1154 13.50 43 6,031,015.46 469,831.70 70 29 44.90180 150 14 48.06099 2899 1166 13.50 44 6,031,010.49 469,826.79 70 29 44.85272 150 14 48.20493 2894 1171 13.50 45 6,031,005.53 469,821.86 70 29 44.80373 150 14 48.34946 2889 1176 13.50 46 6,031,000.54 469,816.94 70 29 44.75446 150 14 48.49369 2884 1181 13.50 47 6,030,995.50 469,811.98 70 29 44.70469 150 14 48.63910 2879 1186 13.50 48 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.78304 2874 1191 13.50 .. or A��i SURVEYOR'S CERTIFICATE ..... '•�•.l' I HEREBY CERTIFY THAT I AM 0'�•' �� •• ISI PROPERLY REGISTERED AND yt ; S * d LICENSED TO PRACTICE LAND •' SURVEYING IN THE STATE OF �` � rf u c e. . . . / ALASKA AND THAT THIS PLATS �E< ; � '; s. . • / REPRESENTS A SURVEY DONE BY ti- '' ;1k-,_ '1t ' • ilir G.Davis ..� zs�. �, J�• No.4110-5 • ea 40 ME OR UNDER MY SUPERVISION It% N. •.«�•��0 � AND THAT I BELIEVE THAT ALL ' aF wit 1. ROF DIMENSIONS AND OTHER DETAILS � < '`wo �.A��+o ARE CORRECT AS SUBMITTED TO `� ;:t '`. . ME BY NANUQ, INC. AS OF JULY 12TH, 2007. Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD. LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 Eost DATE: 7--12-07 Umiot Meridian NANUQ JOB NO. SHEET DESCRIPTION: As-built Coordinates 05204 4 of 4 TRANSMITTAL LETTER CHECKLIST WELL NAME: Opo (AA) - PTD: ai3iw? /Development Service Exploratory Strati graphic Test Non-Conventional FIELD: tip c t,ut J( POOL: Oooc-u r J I 4)t/..1.-rk+ u h ' Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( PH) and API number (50- ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging also required for this well: Requirements /Pcomposite er Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. f'onetrs I"7 57" -4) (tea-;: %✓c 4-42_ cr is eX) ,0. a1uu.ke-' re- 54ksj GOr Revised 5/2013 (4^- Ze 4,4c Z D 3 S Com) H COCii a o c �, o N 0 .0 L 90 f0 W- Q - 3 C - N' 0 TD C co V 0 Q C) 3 N w n a O c N. v. Ii Z ° o o co cn 3en a)l6 D a- CD ES' cc O L a 0_ a) I N, L. co a °3 L, d 3, aa)) C -J Q 0) - _ CO 3 d0 '8 0, , c o Q 0 0 N C. •c. E •C. 0. c N 0 a >. c. •O U. 9 a). as o a) >, U O O O - I N, O , U a_ .Qy. WV a .- D 0. 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Ucy, NUC F- z > 0 c c 3 3 c °2 o o ° o 3 vv ao ov 10 a E _ 2 'c 5 E' v VOo 00000@@ 0y nc ti . 3 rn c S , 0.) w aNcu " a . -80 a) > E Ea cF' H Hc @ �.J a c Em n 'c6 - a)- a)- 3 V) 0 0 a) UCO -° - o 2 2' 2, t V co' aV = OOw p -° 8-(1), a)i ;mNaa)R, c, p ••••••-•-- o � U c>> Z 0- -Jn co w O O a s U Zr a Uco U UU, U Q - Q. o, c c U (2 2; 1 a 0, co, c, U a W n N- O N M M• l0 COCO O O N M Cr )A COf� CO COO N 01 <f lln c0 r-- co O �• I E _ N M V co h CO 0) - N N N N N N N N N N M M M M M 1 M t-,) fh M O F, U M M M L: - - 0 G p c N N +'. N o o Q: 0 O N O G O G N Oo GS `) wV 'N 0 c Oo--E a) 0 NN >4 00 JN . 0Ic aa o U CO4s ( aa a Q Q Q w Technical Report Title Date Client: Pioneer Natural Resources Field: Oooguruk Development Rig: Nabors 19AC Date: January 8, 2014 Surface Data Logging End of Well Report ODSN-28 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Mud Record 7. Bit Record 8. Morning Reports 9. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: Pioneer Natural resource Rig: Nabors 19 AC Well: ODSN-28 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20676-00-00 Sperry Job Number: AK-AM-0900774793 Job Start Date: 04 November 2013 Spud Date: 06 November 2013 Total Depth: 19329’ MD, 6377’ TVD North Reference: True Declination: 19.465° Dip Angle: 80.974° Total Field Strength: 57619 nT Date Of Magnetic Data: 07 November 2013 Wellhead Coordinates N: North 70° 29’ 46.87” Wellhead Coordinates W: West 150° 14’ 45.21“ Drill Floor Elevation 56.20’ Ground Elevation: 13.5’ Permanent Datum: Mean Sea Level SDL Engineers: Kerry Garner, Todd A. Wilson, Makenzie Jorgensen, Martin Nnaji SDL Sample Catchers: Leif Hammes, Michael LaDouceur, Tyler Dretke Company Geologist: Greg Griffin Company Representatives: Joe Polya, Rodney Klepzig, Tony Deranger, Jerry Haberthur SSDS Unit Number: 123 DAILY SUMMARY 11-4-2013 SDL continues on location from previous well. Moved rig to ODSN-28. 11-5-2013 Rig up gas equipment and calibrate. Check CVE system and prepare for next hole section. 11-6-2013 Pick up 5" handling equipment and bottom hole assembly to rig floor. Pick up 5" drill pipe in mouse hole. Pick up bottom hole assembly, heavy weight pipe, and jars in mouse hole, and racked back in derrick. Cut and slip 76' of drilling line. Service top drive and rigged up GYRO. Pick up surface bottom hole assembly. Drill ahead from surface to 225' MD, and trip out of the hole from 225'MD to surface. Begin making up BHA #1. Gas: The max gas was 33 units from 158’ MD with an average of 26 units. Fluids: There were no losses observed. 11-7-2013 Pick up bottom hole assembly #1 to 69'. Load MWD tools, and pick up bottom hole assembly from 69' to 225'. Drill ahead from 225' MD to 1,441' MD, rig down GYRO sheave, and drill ahead from 1,441 MD' to 1,576 MD'. Service top drive and drill ahead from 1,576' to 1,710' MD. Gas: The max gas was 304 units from 1123’ MD with an average of 156 units. Fluids: There was no losses observed 11-8-2013 Drill ahead from 1,710’ MD to 2,431’ MD. Circulate and condition 2.5 bottoms up. Back ream and pump out of hole from 2,241’ MD to 158’ MD at 2 barrels per minute. Laid down bottom hole assembly #1 and download MWD tools. Dial motor back to 1.15 degrees. Pick up bottom hole assembly #2 from 73’ MD to 256’ MD and shallow pulse test. Begin trip in the hole from 256’ MD to 1,200’ MD. Circulate one bottom up at 4 barrels per minute. Continue trip in the hole from 1,200’ MD to 1,865’ MD. Pump down from 1,770’ MD at 4 barrels per minute. Gas: While circulating max gas was 375 units. While drilling max gas was 257 units from 1826’ MD with an average of 93 units. Fluids: There was 25 bbls lost down hole. 11-9-2013 Ream, wash down, and work pipe from 1,865’ MD to 2,431’ MD. Circulate bottoms up at 2,431’ MD. Drill ahead from 2,431’ MD to 2,981’ MD at 650 gallons per minute. Circulate 3 bottoms up to clean hole while diluting mud system with new mud, which reduced mud weight to 9.1 pounds per gallon. Drill ahead from 2,981’ MD to 3,195’ MD at 700 gallons per minute. Service the top drive. Drill ahead from 3,195’ MD to 3,515’ MD at 700 gallons per minute. Gas: Max gas was trip gas of 296 units. While drilling max gas was 227 units from 2,657’ MD with an average of 127 units. Fluids: There was 110 bbls lost down hole. 11-10-2013 Drill ahead from 3,515' MD to 4,526' MD at 800 gallons per minute. Service the top drive and clean suction screens. Drill ahead from 4,526’MD to 4,733' MD. Gas: Max gas was 271 units from 4,580' MD with an average of 112 units. Fluids: There was 0 bbls lost down hole. 11-11-2013 Continue to rotary drill from 4,733’ MD to 5,557’ MD at 850 gallons per minute. Circulate 5 bottoms up, and rack back a stand every 40 minutes. Work stand at 650 gallons per minute going up, and 800 gallons per minute going down. Pump out of the hole at 2 barrels per minute from 4,907’ MD to 4,432’ MD. Continue to trip out of the hole from 4,432’ MD to 3,766’ MD. Pump out of the hole at 2 barrels per minute from 3,766’ MD to 1,580’ MD. Carbide came back 888 strokes early, indicating an average hole of 13.85". Gas: Max gas was 334 units from 5,194’ MD with an average of 210 units. Fluids: There was 0 bbls lost down hole. 11-12-2013 Continue to trip out of the hole while pumping at 2 barrels per minute from 1,580’ MD to 630’ MD. Set back the heavy wall drill pipe from 630’ MD to 163’ MD. Set back the drill collars and clean clay from the bottom hole assembly. Trip in the hole from surface to 1,675’ MD and took weight. Pump in the hole from 1,675’ MD to 2,625’ MD at 4 barrels per minute. Circulate bottoms up at 630 to 650 gallons per minute from 2,625’ MD to 2,720’ MD. Continue to trip in the hole from 2,720’ MD to 4,622’ MD. Ream and wash down from 4,622’ MD to 5,557’ MD. Circulate 3.5 bottoms up from 5,557’ MD to 4,717’ MD. Ream and wash down from 4,717’ MD to 5,001’ MD. Continue to trip in the hole from 5,001’ MD to 5,476’ MD. Circulate bottoms up, and then begin tripping out of the hole from 5,476’ MD to 5,191’ MD. Pump out of the hole from 5,191’ MD to 1,105’ MD at 2 barrels per minute. Gas: While circulating, max gas was 392 units with an average of 77 units. Fluids: There was 40 bbls lost down hole. 11-13-2013 Continue tripping out of hole. Lay down bottom hole assembly #2. Rig up to run 11.75" casing, Run in hole with casing. Experience a tight spot at 2,703' MD. Continue to run in hole with casing to 5,505' MD. Reduce mud rheology, prepare pits for cement job, and build 100 barrel spacer at RSC. Gas: While circulating, max gas was 139 units with an average of 19 units. Fluids: There was 16 bbls lost down hole. 11-14-2013 Land the 11.75" surface casing. Begin circulating at 9 barrels per minute to condition mud for cement job. Start to rig down the casing equipment. Rig up cement lines and tested to 4,000 pounds per square inch. Pump 100 barrels 10.0 pounds per gallon spacer, 689 barrels 10.7 pounds per gallon cement, and 151 barrels 15.8 pounds per gallon cement. Displace at 10 barrels per minute; 5,959 total strokes. Plug was not bumped, Approximately 300 barrels of cement were returned back to surface. Rig down casing and cement equipment. Begin to rig down the riser and nipple down blow out preventers. Gas: Max gas was trip gas of 317 units. While circulating cement job, max gas was 223 units with an average of 12 units. Fluids: There was 0 bbls lost down hole. 11-15-2013 Continue to rig down the diverter and nipple up the blow out preventers. Tested blow out preventers to 4,500 pounds per square inch. Pick up bottom hole assembly #3. Run in the hole to 4,495' MD. Prepare pits for clean out run and upcoming displacement. Gas: While tripping in cemented casing, max gas was 48 units and average gas was 8 units Fluids: There was 0 bbls lost down hole. 11-16-2013 Tagged cement stringers at 5,353’ MD. Ream and wash to 5,373’ MD at 380 gallons per minute. Pressure tested casing at 5,373’ MD to 3500 pounds per square inch. Tag firm cement at 5,380’ MD. Drill out cement to 5,461’ MD at 500 gallons per minute. Pressure tested the casing at 5,461’ MD to 3,500 pounds per square inch. Circulate two bottoms up. Drill out shoe track and float collar/shoe to 5,557’ MD at 750 gallons per minute. Circulate one bottom up. Trip out to surface and lay down bottom hole assembly #3. Pick up bottom hole assembly #4, pressure test Geo-Pilot, and function test reamer. Gas: While in cemented casing, max gas was 125 units and average gas was 10 units. Fluids: There was 0 bbls lost down hole. 11-17-2013 Trip in hole with bottom hole assembly #4 to 5,399’ MD. Cut and slip drill line. Ream from 5,399’ MD to 5,557’ MD. Displace well to 10.0 pounds per gallon mineral oil based mud at 260 gallons per minute (8240 strokes total). Dump 90 barrels of spacer/interface and transferred remaining spud mud for injection. Drill to 5,577’ MD and conducted formation integrity test to 12.5 equivalent mud weight. Drill to 5,717’ MD at 800 gallons per minute. Troubleshoot mud line wash-out in pump room. Gas: The max gas was connection gas of 338 units from 5,686' MD with an average gas of 173 units. Fluids: There was 0 bbls lost down hole. 11-18-2013 Pressure test mud line fix to 4500 pounds per square inch. Trip in from 5495' to 5685'. Circulate at 800 gallons per minute and drill ahead to 5720'. Pack off and complete short trip to shoe. Trip in and drill ahead to 6075' at 800 gallons per minute. Trouble shoot cuttings line pack off. Drill ahead to 6115' at 800 gallons per minute. Gas: While drilling, max gas was 783 units from 5919' with an average gas of 351 units. Fluids: There was 0 bbls lost down hole. 11-19-2013 Drill from 6115’ MD to 6243’ MD at 800 gallons per minute. Flush CCU hopper. Drill from 6243’ MD to 7015’ MD at 800 gallons per minute. Flush CCU hopper. Drill from 7015’ MD to 7259’ MD at 800 gallons per minute. Troubleshoot the GEO pump. Trip out to 6662’ MD. Trip in to 7259’ MD and drill to 7290’ MD at 800 gallons per minute. Gas: While drilling, max gas was 2101 units from 6877’ MD with an average gas of 613 units. Fluids: There was 0 bbls lost down hole. 11-20-2013 Drill from 7290’ MD to 7856’ MD at 800 gallons per minute. Troubleshoot top drive encoder. Troubleshoot CCU GEO pump. Drill from 7856’ MD to 8310’ MD at 800 gallons per minute. Gas: While drilling, max gas was 1426 units from 7613’ MD with an average gas of 688 units. Fluids: There was 0 bbls lost down hole. 11-21-2013 Drill from 8310’ MD to 8917’ MD at 800 gallons per minute. Troubleshoot mud pump #2. Circulate between 8917’ MD and 8820’ MD at 400 gallons per minute. Drill from 8917’ MD to 9201’ MD at 800 gallons per minute. Begin adding STEELSEAL 400 at 9200’ MD. Gas: While drilling, max gas was 218 units from 8898’ MD with an average gas of 91 units. Fluids: There was 0 bbls lost down hole. 11-22-2013 Drill from 9242' MD to 9688' MD at 800 gallons per minute. Dilute active system with 470 bbls 9.8 pounds per gallon mineral oil based mud. Function test BOPs then drilled from 9688' MD to 9962' MD at 800 gallons per minute. Serviced top drive and drilled from 9962' MD to 10130' MD at 800 gallons per minute. Gas: W hile drilling, max gas was 280 units from 9718’ MD with an average gas of 147 units. Fluids: There was 0 bbls lost down hole. 11-23-2013 Drill from 10130' MD to total depth at 10170' MD (Intermediate 1 section) - 800 gallons per minute. Hole was circulated and reamed from 10170' MD to 10040' MD at 800 gallons per minute. Drop tags, pump 2200 strokes and no success on 3 attempts. Circulate and pull out of hole to 9962' MD and observe pack- off, trip to 9910' MD and observe pack-off as well. Trip out of hole from 9910' MD to 7015' MD. Gas: While drilling, max gas was 148 units from 10122’ MD with an average gas of 117 units. Fluids: There was 7 bbls lost down hole. 11-24-2013 Trip out from 7015' MD to 5743' MD. Step up pump rate to 800 gallons per minute and observe pack off at 10300 strokes. Continue trip out to 5657' MD, pump down closing tags and observe pack offs from 5657' MD to 6223' MD. Back-ream and circulate hole from 5847' MD to 1313' MD - 800 gallons per minute permitted. 3/4" -1.5" cuttings observed intermittently over shakers while in casing. Metal shavings observed and collected at the shakers. Gas: Max gas was 121 units with an average gas of 38 units. Fluids: There were 9 bbls lost down hole. 11-25-2013 Circulate 2 bottoms up at 800 gallons per minute, trip out of hole from 1313' MD to surface and lay down BHA #4. Change RAMS and test BOPs. Rig up and run 9 5/8" 40# L-80 liner from surface to 4036' MD. Gas: Max gas was 36 units with an average gas of 28 units. Fluids: There was 13 bbls lost down hole. 11-26-2013 Run 9 5/8" liner from 4036' MD to 6486" MD, tight spot noted at 5915' MD. Continue to run in hole to 9258' MD and attempt to circulate was unsuccessful as very tight spot was encountered. Work pipe free and continue to 9462' MD. Gas: Max gas was 89 units with an average gas of 17 units. Fluids: There was 74 bbls lost down hole. 11-27-2013 Continue to trip into the hole with 9 5/8" liner from 9462' MD to 10152' MD. Attempt to circulate but observed no returns. Set hanger and pump ball down drill pipe at 4 barrels per minute with 806 strokes, pressure up to 4000 pounds per square inch then bled down to 700 pounds per square inch. Well observed breathing. Pressure test cement lines to 4000 pounds per square inch, pump cement and bump plug with 4960 strokes. Apply 3500 pounds per square inch to confirm cement in place. No returns observed during cement job. Rig down cement head and lay down drill pipe. Gas: Max gas was 20 units with an average gas of 16 units. Fluids: There was 521 bbls lost down hole. 11-28-2013 Lay down 3rd party tools. Start to nipple down the BOPs, drilling riser, and spool. Install wellheads, nipple up multi-bowl and test at 5000 pounds per square inch for 10 minutes. Nipple up BOP riser, choke and kill lines. Pick up test tools and install test plug. Change out lower rams from 9 5/8" to 2 7/8" * 5 VBR's. Rig up MPD and test. Test BOPs. Rig down test equipment and blow down lines. Install wear bushing and begin pressure testing casing to 3500 pounds per square inch for 30 minutes. Gas: Max gas was 0 units with an average gas of 0 units. Fluids: There was 0 bbls lost down hole. 11-29-2013 Test casing shoe pressure to 3500 pounds per square inch. Pick up BHA #5 and trip into hole from 410' MD to 7250' MD. Top drive and crown serviced. Trip into hole from 7250' MD to 9952' MD and tag cement. Drill cement shoe and rat hole from 9952' MD to 10170' MD and monitor well for 20 minutes. Drill ahead from 10170' MD to 10190' MD. Displace well to 10.2 pounds per gallon LSND mud. Formation integrity test performed to 13.5 pounds per gallon using 10.2 pounds per gallon LSND mud. Begin trip out of the hole to 10100' MD. Gas: Max gas was trip gas of 380 units with an average gas of 46 units. Fluids: There was 0 bbls lost down hole. 11-30-2013 Trip out of the hole from 10100' MD to 9910' MD and noticed tight spot at 10028' MD. Pump dry job and trip out from 9910' MD to 9055' MD. Circulate 1.5 bottoms up at 620 gallons per minute. Continue trip out of hole from 9055' MD to 8295' MD. Pump dry job and trip out to 410' MD. Lay down BHA #5, pick up BHA #6 and down load MWD tools. Pulse test, load nukes, function test BOPs. Trip into hole to 5605' MD, fill pipe and break in Geo-Pilot. Continue trip into hole from 5606' MD to 9218' MD. Gas: Max gas was trip gas of 280 units with an average gas of 6 units. Fluids: There was 6 bbls lost down hole. 12-01-2013 Trip into hole from 9218' MD to 10073' MD, cut and slip line, install RCD element and trip into hole to 10190' MD. Drill ahead from 10190' MD to 10326' MD; activate reamer, cut ledge and 15k against shoe. Drill ahead from 10326' MD to 10358' MD. Change out clamp on encoder while pulling out of hole to 10075' MD. Begin trip into hole to 1358' MD and drill ahead to 10369' MD. Trouble shoot MWD tool while circulating. Close reamer and begin tripping out of the hole to 10073' MD. Pump dry job and trip out of the hole to BHA. Lay down BHA #6, pull nukes and download MWD tools and inspect bit. Gas: Max gas was 87 units with an average gas of 42 units. Fluids: There was 9 bbls lost down hole. Geology: Cuttings have been predominantly grey to dark grey, fissile, laminate, sub rounded to sub angular shale. Minimal amount sandstone and siltstone, trace pyrite. 12-02-2013 Pick up BHA #7 to 659' MD, load nukes and pulse test. Begin trip into the hole to 10072' MD and install rotating control device element. Trip into hole to 10369' MD, activate reamer and pull test against shoe with 15k to confirm open. Drill from 10369' MD to 10738' MD, service top drive and grease blocks. Drill ahead from 10738' MD to 10994' MD. Gas: Max gas was 1513 units with an average gas of 229 units Fluids: There was 0 bbls lost down hole. Geology: Cuttings have been predominantly shale, sandstone and traces of siltstone also observed 12-03-2013 Drill from 10994' MD to 11369' MD, hit hard spot. Circulate 27 bbls Sapp and WALL-NUT pill downhole. Spot pill with 9 bbls on annulus with bit 1' off bottom. Drill from 11369' MD to 11404' MD, service top drive and grease blocks. Drill ahead from 11404' MD to 11499' MD. Gas: Max gas was 2623 units with an average gas of 288 units Fluids: There was 0 bbls lost down hole. Geology: Samples collected have been shale, grey to dark grey in color, fissile with traces of pyrite. 12-04-2013 Drill ahead from 11499' MD to 11594' MD. Change out RCD element. Drill from 11594' MD to 11689' MD, service top drive and clean suction screens on pumps. Drill ahead from 11689' MD to 12544' MD. Gas: Max gas was 637 units with an average gas of 117 units. Fluids: There was 0 bbls lost down hole. Geology: Cuttings have been dark to light grey fissile shale with relative abundance of pyrite and traces of glauconite. 12-05-2013 Drill from 12544' MD to 12780' MD. Circulate 50 bbls hi-vis sweep downhole. Circulate from 12728' MD to 12639' MD, close reamer. Trip out of the hole from 12639' MD to 10072' MD, pump out at 2 barrels per minute. Service top drive, grease blocks and function test BOPs. Begin trip into the hole from 10072' MD to 12743' MD. Gas: Max gas was 227 units with an average gas of 115 units. Fluids: There was 9 bbls lost down hole. Geology: Noted a significant change in lithology at about 12650' MD from shale to sandstone. Cutting is fine grained, well sorted, unconsolidated with traces of pyrite. 12-06-2013 Circulate and condition from 12734' MD to 12780' MD. Pump 30 bbls hi-vis sweep followed by 2 bottoms up while conditioning mud system. Pump 35 bbls 12 pounds per gallon hi viscosity spacer and chase with 12 pounds per gallon LSND mud and displace well. Begin trip out of the hole from 12780' MD to 9027' MD. Circulate at 9027' MD. Continue trip out of the hole from 9027' MD to 5390' MD; spot 50 bbls 13.9 pounds per gallon hi-vis pill at 4 barrels per minute. Continue trip out of the hole to 4941' MD. Service top drive and grease blocks. Displace to a 13.9 pounds per gallon LSND mud. Observe well for 15 minutes. Install rotating control device trip nipple and begin tripping out of the hole. Gas: Max gas was 283 units with an average gas of 17 units. Fluids: There was 0 bbls lost down hole. 12-07-2013 Continue to trip out of the hole from 2663' MD to 658' MD. Lay down bottom hole assembly from 684' MD to 134' MD. Unload nukes and download monitor while drilling tools. Lay down bottom hole assembly to surface. Attempt to pull wear bushing, however, was unsuccessful. Utilize Weatherford reamer to retrieve wear ring and pull to surface. Found large piece of casing shoe obstructing path and removed it. Service the rig. Make up 7" test tools. Test blow out preventers and rams with 7" casing. Lay down test tools. Rig up to Tesco tools to run casing. Run casing from surface to 686' MD. Gas: Max gas was 0 units with an average gas of 0 units. Fluids: There was 0 bbls lost down hole. 12-08-2013 Continue running into hole with 7" 26# L-80 casing from 686' MD to 12721' MD. Make up hanger and landing joint, land casing at 12762' MD; rig down Tesco tools. Break circulation with minimal returns. Gas: Max gas was 0 units with an average gas of 0 units. Fluids: There was 223 bbls lost down hole. 12-09-2013 Continue circulating at casing, stage up to 6 barrels per minute with 100% returns achieved. Pressure test cement lines to 4000 pounds per square inch, pump 50 bbls 12.5 pounds per gallon dual spacer followed by 110 bbls 15.8 pounds per gallon cement. Bump the plug with 10.2 pounds per gallon LSND mud with 5600 strokes. Hold 3500 pounds per square inch for 5 minutes. Monitor well, no flow. Rig down and blow cement lines. Gas: Max gas was 72 units with an average gas of 7 units. Fluids: There was 179 bbls lost down hole (103 bbls bullheaded). 12-10-2013 Continue to lay down drill pipe and pump 10.2 pounds per gallon mud down outer annulus until break over. Service the top drive and rig up to test blow out preventers. Test blow out preventers and lay down test tools. Pressure test the casing to 3500 pounds per square inch for 30 minutes. Cut and slip drilling line. Service top drive, grease blocks, clean floor and rig. Gas: Max gas was 0 units with an average gas of 0 units. Fluids: There was 33 bbls lost down hole during bull heading. 12-11-2013 Trip out from 7680' MD to surface and lay down Johny Wacker. Pick up bottom hole assembly #8 for clean out run. Run in hole to 228' MD and conduct shallow pulse test at 220 gallons per minute. Continue to run in hole to 4874' MD. Gas: Max gas was 0 units with an average gas of 0 units. Fluids: There was 0 bbls lost down hole. 12-12-2013 Continue to run in the hole from 4874' MD to 12600' MD and tag cement. Drill out cement from 12600' MD to shoe at 12761' MD, at 250 gallons per minute, MAD Pass Logging from 12780' MD to 10971' MD. Gas: Max gas was 22 units with an average gas of 8 units. Fluids: There was 0 bbls lost down hole. 12-13-2013 Continue to conduct measurement after drilling pass from 10971' MD to 10152' MD. Trip out to surface, lay down bottom hole assembly #8. Pick up bottom hole assembly #9. Run Bottom hole assembly to 138' MD and conduct shallow pulse test at 200 gallons per minute. Begin Trip into the hole to a depth of 1598’ MD. Circulate and function test blow out preventers. Continue trip into the hole to 10746' MD. Gas: Max gas was 0 units with an average gas of 0 units. Fluids: There was 0 bbls lost down hole. 12-14-2013 Continue to trip into the hole from 10746' MD to 12668' MD. Cut and slip the drill line. Displace well at 12780' MD to 7.5 parts per gallon mineral oil based mud. Spacer to surface on time at 4941 strokes; take returns to active at 5782 strokes, dumped spacer and interface to CCU. Drill to 12800' MD at 250 gallons per minute and perform formation integrity test. Drill to 13351' MD at 250 gallons per minute and perform a pore pressure test. Drill to 13440' MD at 200 gallons per minute. Gas: Max gas was 1663 units with an average gas of 258 units. Fluids: There was 12 bbls lost down hole during trip in. Geology: The samples collected are clear, unconsolidated, fine grained sandstone. 12-15-2013 Drill from 13440' MD to 14222' MD at 230 gallons per minute. Troubleshoot MWD tool connectivity. Drill to 14499' MD at 240 gallons per minute. Service top drive and drill to 14595' MD at 240 gallons pre minute. Gas: Max gas was 598 units with an average gas of 235 units. Fluids: There was 0 bbls lost down hole. Geology: The samples collected are predominantly clear, unconsolidated, fine grained, well sorted sandstone. 12-16-2013 Drill from 14595' MD to 15462' MD 220 at gallons per minute. Conduct a blowout preventer drill. Service the top drive. Drill ahead to 15560' MD at 220 gallons per minute. Troubleshoot the centrifuge for cause of reduced efficiency. Ship mineral oil based mud to RSC for centrifuging. Gas: Max gas was 365 units with an average gas of 144 units. Fluids: There was 0 bbls lost down hole. Geology: The samples collected are predominantly clear, unconsolidated, fine grained, well sorted sandstone. 12-17-2013 Drill from 15650' MD to 16862' MD at 230 gallons per minute. Mud weight increased at a rate of approximately 0.1 ppg per 1,000 feet. Transfer mineral oil based mud to RSC for centrifuging. Gas: Max gas was 526 units with an average gas of 249 units. Fluids: There was 0 bbls lost down hole. Geology: The samples collected are predominantly clear, unconsolidated, fine grained, well sorted sandstone. 12-18-2013 Drill from 16862' MD to 17640' MD at 235 gallons per minute. Gas: Max gas was 693 units with an average gas of 316 units. Fluids: There was 0 bbls lost down hole. Geology: The samples collected are predominantly clear, unconsolidated, fine grained, well sorted sandstone with traces of siderite. 12-19-2013 Drill from 17640' MD to 18449' MD at 230 gallons per minute. Change the rotating control device element. Drill from 18449' MD to 18660' MD at 235 gallons per minute. Take directional surveys in five foot intervals from 18715' MD to 18655' MD. Gas: Max gas was 972 units with an average gas of 357 units. Fluids: There was 0 bbls lost down hole. Geology: The samples collected are predominantly clear, unconsolidated, fine grained, well sorted sandstone with traces of siltstone. 12-20-2013 Drill from 18721' MD to 19307' MD at 235 gallons per minute. Service rig and function test blowout preventers. Drill to TD at 19329' MD at 235 gallons per minute and encounter 16,000 foot pounds of torque. Back ream to 18833' MD at 175 gallons per minute. Gas: Max gas was 422 units with an average gas of 213 units. Fluids: There was 0 bbls lost down hole. Geology: The samples collected are predominantly clear, unconsolidated, fine grained, well sorted sandstone with traces of siltstone. During the last 39 feet of well, the sample was predominantly grey to brown, well sorted, soft siltstone. 12-21-2013 Trip and pump out from 18833’ MD to 17003’ MD at 175 gallons per minute. Circulate two bottoms up while tripping out to 16513’ MD at 225 gallons per minute. Trip and pump out to 15557’ MD at 175 gallons per minute. Continue to back ream from 15557’ MD to 13100’ MD at 175 gallons per minute. Experience a partial pack-off and torque to 15,000 foot pounds. Work pipe and ream from 13151’ MD to 12668’ MD at 84 gallons per minute. Circulate at shoe two bottoms up at 180 gallons per minute. Gas: Max gas was 60 units with an average gas of 21 units. Fluids: There was 68 bbls lost down hole. 12-22-2013 Trip in hole from shoe to 19211’ MD; circulate 2.5 bottoms up at 225 gallons per minute. Displace 8.0 pounds per gallon mineral oil based mud with 9.9 pounds per gallon; kill weight mineral oil based mud. 9.9 pounds per gallon mud returns to surface at 8250 strokes. Monitor well, remove rotating control device. Trip out from 19211’ MD to 12572’ MD while pumping 2 barrels per minute. No geology samples collected. Gas: Max gas was trip gas of 2307 units. While circulating bottoms up, max gas was 377 units with an average of 39 units. Fluids: There was 0 bbls lost down hole. 12-23-2013 Trip out from 12572' MD to surface, lay down bottom hole assembly, and download nukes. Gas: No significant gas levels detected. Fluids: There was 13 bbls lost down hole. 12-24-2013 Lay down bottom hole assembly from 138' MD to surface. Clear rig floor and service top drive. Pick up 48 joints of drill pipe, flush and rack back. Remove rotating control device head and rig up to test choke manifold. Rig up to test blow out preventers. Observe well flowing at IA. Shut in blinds, pull test joint, and drain stack. Monitor well, no pressure increase observed. Open the choke and take returns to pits. Drain water and shut in for 30 minutes, no pressure increase observed. Open well and observe flow of mineral oil based mud. Monitor well 1900 to 2200 hours and saw 4.6 bbls increase. Shut in well and monitor pressure. Open well and gain 1.4 bbls. Gain a total of 6 bbls from 1900 hrs to 0000 hrs. Gas: No significant gas levels detected. Fluids: There was 6 bbls gained while monitoring the well. 12-25-2013 Monitor well for flow. Observe approximately 4 bbls per hour gain. Shut in well and monitor pressure. Observe 15 pounds per square inch increase. Pick up bottom hole assembly #9 to 1500’ MD. Start to trip in the hole from 1500’ MD to 13100’ MD. Circulate two bottoms up using step rate method at 1/2 bbls per minute. Start trip out of the hole from 13100’ MD to 12762’ MD. Close annular and displace 9.9 pounds per gallon to 10 pounds per gallon mineral oil based mud; taking returns through choke manifold back to pits. Displace using step rate up to 2 bbls per minute. Observe 30 bbls loss during circulation. Open bag and monitor well for 15 minutes. Begin trip out of the hole from 12762’ MD to 4485’ MD. Gas: While circulating max gas was 191 units with an average of 18 units. Fluids: There was 0 bbls lost or gained. 12-26-2013 Continue to trip out of the hole from 4485' MD to 1500' MD. Lay down bottom hole assembly from 1500' MD to surface. Remove wear ring and install test plug. Pick up test tools and test blow out preventers. Lay down test equipment. Rig up to run 4.5" 12.6 pound C-110 production liner. Run from surface to 2787' MD. No returns observed during the first 20 joints, and 1 bbl at joint number 30. Continue to run 4.5" liner. Gas: No significant gas levels detected. Fluids: There was 0 bbls lost or gained. 12-27-2013 Continue to run 4.5" 12.6 pound C-110 liner from 2787' MD to 6887' MD. Make up bumper sub, mag, and install stabbing guide. Circulate one liner volume plus 25 bbls, using step rate method up to 2 bbls per minute. Run liner from 6887' MD to 11,123' on 4" drill pipe. Gas: While circulating max gas was 32 units with an average of 2 units. Fluids: There was 0 bbls lost or gained. 12-28-2013 Continue to run 4.5" 12.6 pound C-110 liner from 11123' MD to 12747' MD. Circulate bottoms up using step up method to 2 bbls per minute. Run liner from 12747' MD to 15263' MD. Experience a tight spot at 15180' MD. Repair top drive. Run liner from 15263' MD to 19210' MD. Experience a tight spot at 18615' MD. Circulate drill pipe volume; stage up to 3 bbls per minute. Drop 1.5" ball and pump at 3 bbls per minute. Set hanger per Baker representative with 1098 strokes at 12445' MD. Gas: While circulating max gas was 52 units with an average of 13 units. Fluids: There was 0 bbls lost or gained. 12-29-2013 Set packer and test to 3500 pounds per square inch and chart for 10 minutes. Displace well from a 10 pound per gallon mineral oil based mud to 10.1 NaCl/NaBr Brine. Cut and slip drill line. Trip out of the hole and lay down drill pipe from 12390’ MD to the bottom hole assembly. Lay down bottom hole assembly and remove wear bushing. Pick up Tesco tool and trip in the hole with 4.5" 12.6 pound C-110 tubing from surface to 144' MD. Make up index mule shoe seal assembly. Begin to trip in the hole from 144' MD to 457' MD. Gas: While circulating max gas was trip gas of 4141 units with an average gas of 536 units. Fluids: There was 8 bbls lost during the trip out. 12-30-2013 Continue to run 4.5" 12.6 pound C-110 liner from 457' MD to 4749' MD. Spliced damaged I-Wire then lay down tools. Run in the hole with 4.5" liner from 4749' MD to 10190' MD. Test control line to 5000 pounds per square inch for 10 minutes. Continue running in the hole from 10190' MD to 10701' MD. Gas: No significant gas levels detected. Fluids: There was 0 bbls lost down hole. 12-31-2013 Run 4.5" 12.6 pound C-110 tubing from 10701' MD to 12445' MD. Conduct well completion activities. Gas: No significant gas levels detected. Fluids: There was 0 bbls lost down hole. 1-01-2014 Conduct well completion activities and nipple down the blowout preventers. Test frac tree, freeze protect well, and begin laying down 4" drill pipe. Gas: No significant gas levels detected. Fluids: There was 0 bbls lost down hole. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 0 5 10 15 20 25 30 35 40 45 50 55 60 65 Me a s u r e d D e p t h Rig Days WELL NAME: ODSN-28 OPERATOR: Pioneer Natural Resources MUD CO: Baroid RIG: Nabors 19 AC SPERRY JOB: AK-AM-0900774793 Days vs. Depth 04 Nov 2013 Sperry SDL Remain on Location from Previous Well LOCATION: North Slope Borough AREA: Oooguruk STATE: Alaska SPUD: 6-Nov-2013 TD: 20-Dec-2013 Commenced 14.5" Surface Hole Section On Bot: 21:02 06 Nov 2013 Landed 11 3/4" Casing 5549' MD, 3452' TVD 14 Nov 2013 TD Surface Hole Section 5557' MD, 3456' TVD Off Bot: 13:39 11 Nov 2013 Commenced 10.369" Intermediate 1 Hole Section On Bot: 10:06 17 Nov 2013 TD Intermediate 1 Hole Section Surface Section 10190' MD, 5573' TVD' Off Bot: 01:16 23 Nov 2013 Landed 9.625 Casing 10170' MD, 5564' TVD 27 Nov 2013 Drill 8.5" hole to12369' POOH to replace MWD 1 Dec 2013 Commenced 8.5" Intermediate 2 Hole Section On Bot: 03:20 01 Dec 2013 Landed 7" Casing 12762' MD, 6358' TVD 08 Dec 2013 TD Intermediate 2 Hole Section 12780' MD, 6358' TVD Off Bot:05:15 5 Dec 2013 Commenced 6.125" Production Hole Section On Bot: 07:16 14 Dec 2013 TD Production Hole Section 19329' MD, 6377' TVD Off Bot:21:02 20 Dec 2013 Landed 4.5" Liner 12445' MD, 6335' TVD 29 Dec 2013 WELL NAME: LOCATION: Oooguruk OPERATOR: AREA: North Slope Borough SPERRY JOB: STATE: Alaska RIG: Nabors 19AC HOLE SECTION: Surface EMPLOYEE NAME: DATE: Sperry Drilling Confidential Document v 3.0 What went as, or better than, planned: Pumps locked up when starting the new well and the pump stroke counters and lag would not calculate, but we were able to fix the problem by resetting each pump. The problem was fixed before we started drilling so no data was lost. Recommendations: Innovations and/or cost savings: Insite and the gas equipment ran with no complications and no data was lost for the entire run. Difficulties experienced: Keeping vent hose on degasser clean will prevent clogging and ensure accurate gas readings. Blowback / Vibrate at every connection. Make sure to reset the pumps at the beginning of every new well, by disabling them and then re-enabling them. Using the vibe and blowback for the suction tube assembly will help insure that the suction tube does not become blocked with mud and cuttings which would result in lost gas data. Pioneer Natural Resources AK-XX-0900774793 Todd A. Wilson 15-Nov-2013 ODSN-28 Surface Data Logging After Action Review WELL NAME:LOCATION:Oooguruk OPERATOR:AREA:North Slope Borough SPERRY JOB:STATE:Alaska RIG:Nabors 19AC HOLE SECTION:Intermediate 1 EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Pioneer Natural Resources AK-XX-0900774793 Todd A. Wilson 23-Nov-2013 ODSN-28 What went as, or better than, planned: The 8800 Gas Analyzer was giving us really high gas readings. Chromatograph data was not matching up, so it was determined that we lost calibration on the 8800. Recommendations: Innovations and/or cost savings: Replaced the flow out sensor, it had been damaged previously and could no longer be calibrated. Difficulties experienced: Removal of the flow out sensor during high pressure tests will likely prevent future damage. N/A Surface Data Logging After Action Review WELL NAME: LOCATION: Oooguruk OPERATOR: AREA: North Slope Borough SPERRY JOB: STATE: Alaska RIG: Nabors 19AC HOLE SECTION Intermediate 2 EMPLOYEE NAME: DATE: What went as, or better than, planned: Water and a high geothermal gradient encountered down-hole while drilling, created a large amount of steam in the returning mud. The resulting water vapor in the gas system was not entirely captured by the drop-out jars, ultimately the water was captured in the filters and the iso-tube. Having backup gas gear on-hand, warmed up and calibrated, allowed for a rapid change out of 8900 while drilling. The switch was done in a mater of minutes while the pumps were off, thus providing continues data collection. Difficulties experienced: Pioneer Natural Resources AK-XX-0900774793 Leif Hammes 6-Dec-2014 ODSN-28 Surface Data Logging After Action Review Sperry Drilling Confidential Document v 3.0 Recommendations: Innovations and/or cost savings: Cool down the drop-out jars so the water vapor will condense faster. Cooled drop-out jars will ultimately result in savings, due to decreased maintenance on the gas system. Surface Data Logging After Action Review WELL NAME: LOCATION: Oooguruk OPERATOR: AREA: North Slope Borough SPERRY JOB: STATE: Alaska RIG: Nabors 19AC HOLE SECTION: Production EMPLOYEE NAME: DATE: What went as, or better than, planned: Mud filled the drop jar and filled sample line several times over a few days. No mud got into gas equipment, and it happened while tripping out so no significant data was lost while blowing mud out of lines and cleaning equipment. No significant moisture problems. No gas gear had to be changed out. Difficulties experienced: Pioneer Natural Resources AK-XX-0900774793 Makenzie Jorgensen 1-Jan-2014 ODSN-28 Surface Data Logging After Action Review Sperry Drilling Confidential Document v 3.0 Recommendations: Innovations and/or cost savings: Mainenance was done and equipment was troubleshot. No obvious signs of cause. May have been due to abrupt changes in flow rates and MPD repeatedly going on and off well. Monitor Degasser RPMs and Drop Jar closely. When Degasser RPMs drop signifiantly mud has likely backed up to the drop jar. A special filter has been engineered and is being shipped to minimize moisture problems experienced in the last section. Surface Data Logging After Action Review WELL NAME:ODSN-28 LOCATION:North Slope Borough OPERATOR:Pioneer Natural Resources AREA:Oooguruk MUD CO:Baroid STATE:Alaska RIG:Nabors 19AC SPUD:6-Nov-2013 SPERRY JOB:AK-XX-0900774793 TD:20-Dec-2013 Marker MD INC AZ TVD TVDSS 14 1/2" Surface Hole Section Top Permafrost 868.0 18.6 75.0 853.0 796.8 Base Permafrost 1,802.5 44.3 60.8 1,668.1 1,611.9 Ugnu D 2,023.0 51.2 59.6 1,815.0 1,758.8 Top West Sak 3,275.0 62.7 57.7 2,437.4 2,381.2 Cretaceous Tuffs 4,764.0 62.1 56.2 3,089.2 3,033.0 Hue 1 Shale 5,098.0 62.1 57.8 3,247.4 3,191.2 Hue 2 Shale 5,450.0 63.3 58.8 3,408.7 3,352.5 11-3/4" SCP 5,549.0 64.3 56.2 3,452.5 3,396.3 10 5/8" Intermediate 1 Hole Section Brookian 2B 7,590.0 62.5 57.1 4,387.5 4,331.3 Top Torok Sand 9,382.0 62.8 59.5 5,204.1 5,147.9 Base Torok Sand 9,922.0 62.8 55.6 5,450.3 5,394.1 Torok 1 Shale 10,145.0 62.5 48.9 5,552.7 5,496.5 9-5/8" ICP1 10,152.0 62.5 48.7 5,555.9 5,499.7 8 1/2" Intermediate 2 Hole Section Possible 10' DTSW Fault 10,483.0 61.6 33.5 5,711.3 5,655.1 Top HRZ 10,777.0 63.0 21.1 5,849.2 5,793.0 Base HRZ (Top Kalubik Sh)11,037.0 64.2 10.7 5,966.1 5,909.9 Kalubik Marker 11,224.0 66.8 1.9 6,043.3 5,987.1 Top Kuparuk C 11,340.0 68.2 357.4 6,087.7 6,031.5 LCU (Top Miluveach Sh)11,370.0 68.5 356.3 6,098.7 6,042.5 BCU (Top Kingak Sh)11,912.0 76.4 332.6 6,260.5 6,204.3 Top Nuiqsut 12,654.0 86.0 320.3 6,351.8 6,295.6 Top Nuiqsut::Nuiq_1 D1 12,700.0 86.3 320.1 6,354.9 6,298.7 7" ICP2 12,762.0 88.1 319.2 6,358.0 6,301.8 6 1/8" Production Hole Section Invert (First)13,595.0 90.0 317.0 6,367.7 6,311.5 Revert (Last)18,667.6 90.0 316.6 6,334.4 6,278.2 Nuiq_1::Nuiq_2 18,845.0 85.3 317.2 6,344.0 6,287.8 Nuiq_2::Nuiq_3 18,862.0 85.4 317.2 6,345.4 6,289.2 Nuiq_3::Nuiq_4 18,925.0 85.5 317.3 6,350.4 6,294.2 Nuiq_4::Nuiq_5 18,990.0 85.8 317.2 6,355.3 6,299.1 TD 6-1/8" Production Lateral 19,329.0 86.9 318.3 6,377.4 6,321.2 Formation Tops ODSN-28 Pioneer Natural Resources Baroid Nabors 19AC AK-XX-0900774793 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 6-Nov 175 8.90 129 22 49 20/29/36 16.8 93/71/62/49/25/22 2/0 3.0 2.5/93.5 0.01 1.80 10.0 0.35/0.80 18000 400 Spud Mud 7-Nov 1525 9.10 122 23 42 27/42/51 12.5 88/65/54/41/24/21 2/0 4.7 2.0/92.5 1.20 1.10 9.8 6.0 0.30/0.70 14000 440 Drill 14.5 surface hole 8-Nov 2431 9.10 120 19 43 26/51/60 10.0 81/62/51/42/24/21 2/0 4.6 2.0/92.5 1.20 0.90 9.8 12.0 0.30/0.70 16000 320 Tripping in the hole 9-Nov 3501 9.10 72 17 34 20/37/43 10.8 68/51/44/34/19/18 2/0 4.7 2.0/92.5 1.20 0.80 9.8 14.0 0.30/0.85 14000 480 Drilling surface hole 10-Nov 4603 9.40 72 13 36 29/45/48 12.2 62/49/41/34/23/22 2/0 7.1 2.0/90.0 1.10 0.70 9.4 20.0 0.30/0.75 16000 560 Drilling surface hole 11-Nov 5557 9.40 68 10 31 27/49/61 12.4 51/41/37/32/24/22 2/0 6.6 2.0/90.5 1.00 0.50 9.1 20.0 0.25/0.75 16000 560 Tripping out of the hole 12-Nov 5557 9.45 60 13 28 25/48/57 12.2 54/41/35/29/19/18 2/0 7.1 1.5/90.5 1.20 0.50 9.2 25.0 0.30/0.80 16500 560 Tripping out of the hole 13-Nov 5557 9.40 50 18 22 13/19/42 11.0 58/40/33/24/11/10 2/0 8.3 1.5/90.0 1.70 -9.7 22.0 0.20/1.00 450 440 Running casing 14-Nov 5557 9.60 50 14 22 15/22/36 11.8 50/36/30/24/16/14 2/0 9.3 1.0/89.5 1.00 -9.0 22.0 0.20/1.00 400 440 Nipple down BOPs 15-Nov 5557 9.60 50 15 23 16/24/36 12.2 53/38/31/23/16/15 2/0 8.2 1.5/89.5 0.50 -9.2 22.0 0.20/1.00 14500 480 Tripping in 16-Nov 5557 9.60 50 15 24 16/28/44 12.6 54/39/32/26/18/16 2/0 8.2 1.0/90.0 1.00 -9.6 22.0 0.20/1.60 15000 520 Tripping in with BHA #4/Spud Mud Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Alka POM Excess Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb ppm ppb ASG 17-Nov 5717 10 140 26 20 13/22/34 3.0 72/46/38/28/12/11 0/2 16.9 65.0/17.0 -4.01 803 1.41 152947 147.53/10.66 2.668 ENVIROMUL 18-Nov 6075 10 145 44 26 14/20/28 3.0 114/70/55/36/13/11 0/2 17.2 64.0/18.0 -5.44 877 1.9 119549 150.65/9.16 2.658 Drilling 19-Nov 7260 10 98 36 26 13/15/26 3.2 98/62/48/32/13/11 0/2 17.2 64.0/18.0 -5.44 747 1.9 119549 150.65/9.16 2.658 Drilling 20-Nov 8154 10 90 39 25 14/18/26 3.2 103/64/49/32/13/11 0/2 17.3 65.0/17.0 -4.92 722 1.41 107109 150.56/11.24 2.671 Drilling 21-Nov 9104 10 82 42 27 14/19/28 3.0 111/69/53/34/13/11 0/2 18.7 67.0/14.0 -4.14 652 0.44 55176 169.71/0.99 2.606 Drilling 22-Nov 10052 10 77 41 26 15/19/27 3.2 108/67/51/34/11/10 0/2 17 69.5/13.0 -4.92 688 0.93 96420 139/25.85 2.765 Drilling 23-Nov 10170 10 110 42 21 10/19/26 3.4 105/63/47/30/9/8 0/2 17.6 70.0/12.0 -2.59 705 0.64 84188 148.26/19.61 2.721 Tripping out of hole 24-Nov 10170 10 100 46 21 12/21/29 3.2 113/67/49/31/10/9 0/2 17.7 71.0/11.0 -3.11 734 1.22 81089 148.29/20.61 2.727 Tripping out of hole 25-Nov 10170 10 97 53 21 15/25/34 3.6 127/74/56/36/10/9 0/2 17.6 71.0/11.0 -3.63 781 1.02 84465 148.00/20.75 2.728 Running 9 5/8" liner 26-Nov 10170 10 107 41 21 10/16/26 3.6 103/62/46/30/8/7 0/2 17.6 71.0/11.0 -3.76 756 0.73 84801 147.73/21.00 2.729 Running 9 5/8" liner 27-Nov 10170 10 109 41 22 11/18/27 3.8 104/63/47/31/10/9 0/2 17.6 71.0/11.1 -3.11 832 0.44 88261 147.35/21.22 2.731 L/D Bumper Sub 28-Nov 10170 10 115 41 23 11/18/28 3.8 105/64/48/34/10/9 0/2 16.6 72.0/11.0 -3.63 832 0.44 85,136 128.33/37.44 3 Pressure Testing Casing/ENVIROMUL Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 29-Nov 10190 10.20 61 12 23 8/11/13 3.0 47/35/29/20/8/7 2/0 7.5 2.5/89.0 0.01 0.80 9.8 1.0 0.35/0.80 18000 840 LSND 30-Nov 10190 10.20 58 13 22 7/8/12 3.0 48/35/29/218/7 2/0 7.5 4.0/87.5 0.01 0.70 9.8 1.0 0.30/0.90 19500 880 Tripping into Hole 1-Dec 10369 10.20 58 14 29 8/10/12 3.6 57/43/35/26/10/8 2/0 8 6.0/85.0 0.01 0.5 9.4 2 0.20/0.60 20000 860 Downloading MWD tools 2-Dec 10914 10.20 62 16 34 12/18/22 3.6 66/50/42/34/13/12 2/0 8.5 6.5/84.0 0.05 0.60 9.7 5.0 0.30/0.80 20000 440 Drilling Ahead 3-Dec 11423 10.20 53 19 35 10/12/14 3.0 73/54/46/38/13/12 2/0 8.9 6.0/84.0 0.01 0.60 9.9 7.5 0.30/0.80 22000 80 Drilling Ahead 4-Dec 12419 10.20 53 16 29 11/18/21 2.4 61/45/38/29/13/12 2/0 9.5 6.5/83.0 0.01 1.00 10.6 10.0 0.50/1.80 20000 160 Drilling Ahead 5-Dec 12780 10.20 54 16 29 8/13/18 3.6 61/45/38/28/10/8 2/0 9.0 6.0/84.0 0.01 0.50 9.4 12.5 0.25/1.80 21000 160 Tripping into hole 6-Dec 12780 13.00 98 28 38 12/21/28 3.0 94/66/53/39/14/12 2/0 21.5 2.0/74.5 0.10 0.40 9.4 1.0 0.30/1.20 48000 560 Tripping out of hole 7-Dec 12780 10.20 66 15 25 8/11/14 3.6 55/40/32/24/10/8 2/0 9.3 5.0/84.5 0.05 0.85 10.2 10.0 .4/1.4 24500 200 Running 7" casing 8-Dec 12780 10.20 54 15 26 8/11/13 3.9 56/41/31/24/9/8 2/0 8.9 5.0/85.0 0.01 0.35 9.6 10.0 0.35/1.60 22000 200 Circulating Casing 9-Dec 12780 10.20 50 14 20 8/11/13 6.4 48/34/28/21/9/8 2/0 9.0 5.0/85.0 0.10 0.30 9.3 7.5 0.30/1.40 19000 200 Laying Down Drill Pipe/LSND 10-Dec 12780 10.20 51 14 20 8/11/12 6.2 48/34/27/22/9/8 2/0 10.0 5.0/84.0 0.01 0.30 9.3 7.5 0.30/1.50 20000 200 Loading shed with 4" pipe 11-Dec 12780 10.20 49 12 20 10/11/12 6.0 44/32/28/20/10/8 2/0 10.0 5.0/84.0 0.05 -9.3 7.0 0.20/1.40 20000 260.000 Tripping in 12-Dec 12780 10.20 54 12 20 11/12/15 6.2 44/32/27/21/10/9 2/0 10.1 5.0/84.1 0.05 -9.8 7.5 .2/1.3 19000 240.000 Trip out/MAD pass 13-Dec 12780 10.20 50 11 20 11/12/14 6.4 42/31/27/28/18/10/8 2/0 10.0 5.0/84.0 0.05 -10 7.5 .2/1.5 20000 240.000 Tripping in WELL NAME:LOCATION:Oooguruk OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:6-Nov-2013 SPERRY JOB:TD:20-Dec-2013 W a t e r a n d O i l B a s e d M u d R e c o r d Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Alka POM Excess Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb ppm ppb ASG 14-Dec 13158 7.50 51 7 12 7/8/11 8.4 26/19/15/11/6/5 0/2 2.2 86.5/11 -2.59 1785.0 1.9 83.458 22.76/-4.57 2.373 Drilling Ahead 15-Dec 14412 7.55 51 10 12 10/12/13 8.2 32/22/18/14/8/7 0/2 2.7 86/11 -4.53 1935.0 2.9 82335 29.84/-8.03 2.280 Drilling Ahead 16-Dec 15470 7.70 50 10 11 10/11/13 8.0 31/21/18/14/8/7 0/2 3.8 86/10 -4.86 1945.0 2.9 79471 38.25/-6.21 2.241 Drilling Ahead 17-Dec 16626 7.80 48 9 11 9/10/13 8.0 29/20/16/12/7/6 0/2 4.8 85/10 -3.88 1792.0 2.9 79471 50.57/-11.38 2.341 Drilling Ahead 18-Dec 17445 7.80 50 9 13 10/12/13 7.8 31/22/18/14/8/7 0/2 5.2 85/9.5 -3.63 1728.0 1.4 77930 58.56/-17.40 2.239 Drilling Ahead 19-Dec 18554 7.90 51 9 12 10/11/13 8.0 30/21/18/14/8/7 0/2 4.7 84/11 -4.66 1703.0 0.9 75060 42.76/-0.04 2.599 Drilling Ahead 20-Dec 19219 8.00 52 12 12 10/12/14 7.6 36/24/20/16/8/7 0/2 4.6 84/11 -3.17 1667.0 0.9 93900 35.24/10.82 2.855 Drilling Ahead 21-Dec 19329 8.00 52 9 12 10/12/15 8.0 30/21/17/11/8/7 0/2 5.2 83.5/11 -3.11 1592.0 0.9 81427 45.27/2.83 2.660 Circulating at shoe 22-Dec 19329 9.90 58 24 16 10/16/21 8.8 64/40/31/21/9/8 0/2 11.7 78/10 -5.83 1642.0 1.8 80837 40.21/107.71 3.598 Tripping out 23-Dec 19329 9.90 77 18 15 11/16/24 8.0 51/33/27/19/9/8 0/2 11.7 78/10 -5.70 1551.0 1.4 84797 39.73/108.02 3.604 Laying down BHA 24-Dec 19329 9.90 87 18 18 12/14/19 9.2 54/36/30/21/12/10 0/2 11.7 77/11 -4.92 1248.0 1.4 84018 40.35/106.55 3.593 Monitoring well 25-Dec 19329 10.00 80 17 19 11/15/20 9.4 53/36/28/20/11/10 0/2 11.1 77.5/11 -3.88 1527.0 0.9 84577 23.51/126.09 3.830 Tripping out of the hole 26-Dec 19329 10.00 89 24 20 12/18/22 9.0 68/44/35/25/12/11 0/2 11.6 75/13 -3.63 1621.0 0.9 85947 34.21/115.02 3.681 Running 4.5" Liner 27-Dec 19329 10.00 81 17 19 11/15/19 9.4 53/36/28/20/10/9 0/2 11.6 77/11 -3.37 1610.0 1.4 93352 33.17/117.5 3.699 Running 4.5" Liner 28-Dec 19329 10.00 70 18 20 12/16/21 9.0 56/38/30/21/11/10 0/2 11.7 77/11 -3.88 1570.0 1.9 83458 33.98/117.15 3.690 Setting Packer 29-Dec 19329 10.10 ----------------Running 4.5' Tubing 30-Dec 19329 10.10 ----------------Running 4.5' Tubing 31-Dec 19329 10.10 ----------------Rig maintenance 1-Jan 19329 10.10 ----------------Laying down 4" drill pipe Casing Record 4.5" Liner @ 12445' MD. 6335'TVD 16" Conductor @ 158' MD, 158'TVD 11.75" Casing @ 5549' MD, 3452'TVD 9.625" Casing @ 10152' MD, 5555'TVD 7" Casing @ 12762' MD, 6358'TVD W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 100 1 Baker/Hughes 14.500 158 2431 2273 30.66 0.700 117.8 30 60 1600 575 2-1-WT-A-E-I-NO-BHA Surface 2 200 1rr1 Baker/Hughes 15.500 2431 5557 3126 103.07 0.700 99.1 34 120 3150 850 3-4-WT-A-E-1-FC-TD Surface 3 300 2 Baker/Hughes 10.625 5557 5557 0 8.49 0.942 -----1-1-CT-C1-E-1-NO-BHA Cleanout Run 4 400 3 HDBS FXG65s 10.625 5557 10170 4613 137.59 1.353 61.4 40 150 4300 800 1-2-LT-S-X-I-CT-TD Intermediate 1 5 500 4 Baker/Hughes 8.500 10170 10190 20 10.85 0.920 -8 60 1100 300 1-4-FC-G-E-1-WT-BHA Cleanout Run 6 600 5 HDBS SFE56 8.500 10190 10369 179 10.24 1.108 30.3 15 100 3925 750 O-O-NO-A-X-I-NO-DFT Intermediate 2 7 700 5rr1 HDBS SFE57 8.500 10369 12780 2411 83.46 1.108 46.7 35 150 4500 750 2-2-CT-A-X-I-NO-TD Intermediate 2 8 800 6 Baker / STX-1 6.125 12780 12780 0 6.42 0.920 -15 30 3150 250 2-1-CT-M-E-I-NO-BHA Cleanout Run 9 900 7 HDBS / MM64 6.125 12780 19329 6549 93.02 0.389 70.4 10 80 3720 250 1-0-BT-N-X-I-ER-TD Production Alaska RIG:Nabors 19AC SPUD:6-Nov-2013 WELL NAME:ODSN-28 LOCATION:Oooguruk OPERATOR:Pioneer Natural Resources AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0900774793 TD:20-Dec-2013 Baroid STATE: B i t R e c o r d . . * 24 hr Recap: Kerry Garner / Martin Nnaji (max) (current) 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 0 0 0 907-670-6636 Unit Phone: Martin Nnaji Report By: 00 Set At Depth Grade Oil/Water N/A N/A N/A cP 28 N/A Ratio C-2 N/A Casing Summary Size N/A N/A Siltst Ss C-5n N/A 0 Date: Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 0' 0' 0' Max @ ft Current N/A N/A J. Polya / T. DeRanger Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Gas Summary 0 0 0 (current) Tuff Gvl Coal Footage TFA AK-AM-900774793 PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Weight 0 Hours C-3 0 Cht Silt C-4i C-4n Sh Clyst 000 0 Sid Brine 19868' Depth in / out Mud Type Lst Type in Minimum Average N/A Chromatograph (ppm) (max) Trip N/A Background Comments 0 RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) WOB 100% Gas In Air =10,000 Units N/A Connection N/A N/A Bit # 13 10.10 10.10 Size Depth Condition Morning Report Report # 1 Customer: Well: Area: Location: 96% Rig Activity: Rig: Oodsn-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary HTHP Avg Min N/A Tools 4-Nov-2013 11:59 PM Current Pump & Flow Data: N/A Max 0 (lb/bbl) Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime Fluids = 0 bbls lost downhole Max Gas = 0 units, Avg Gas = 0 units N/A Units* . . * 24 hr Recap: N/A Units* Fluids = 0 bbls lost downhole Max Gas = 0 units, Avg Gas = 0 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 0 5-Nov-2013 11:59 PM Current Pump & Flow Data: N/A Max @ Mud Data MWD Summary HTHP Avg Min Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Depth Condition Morning Report Report # 2 Customer: Well: Area: Location: 96% Rig Activity: N/A Nabors 19AC Report For: Tools N/A N/A Bit # 13 10.10 10.10 Size WOB 100% Gas In Air =10,000 Units N/A Connection RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) Comments 0 Chromatograph (ppm) (max) Trip N/A Background Average N/A Mud Type Lst Type in Minimum Brine 19868' Depth in / out 000 0 Sid Cht Silt C-4i C-4n Weight 0 Hours C-3 0 AK-AM-900774793 PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Footage TFA Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) 0' 0' 0' Max @ ft Current N/A N/A J. Polya / T. DeRanger C-1 C-5i 0 C-5n N/A 0 Date: Time: SPP (psi) Gallons/stroke Flow In (spm) Depth N/A N/A Siltst Ss Ratio C-2 N/A Oil/Water N/A N/A N/A cP 28 N/A Casing Summary Size Grade 00 Set At Depth 0 0 907-670-6636 Unit Phone: Martin Nnaji Report By: 0 Logging Engineers: Bit Type Maximum Cly 0 Kerry Garner / Martin Nnaji (max) (current) 0 0 Lithology (%) . . * 24 hr Recap: 26 Units* of 26 units. No connection or trip gas. No geology samples collected. to surface. Making up BHA #1 at time of report. Max gas was 33 units from 158' MD with an average and rigged up GYRO. Picked up surface BHA. Drilled ahead from surface to 225'. Tripped out of the hole from 225' weight pipe, and jars in mouse hole, and racked back in derrick. Cut and slipped 76' of drilling line. Serviced top drive Picked up 5" handling equipment and BHA to rig floor. Picked up 5" drill pipe in mouse hole. Picked up BHA, heavy Fluids = 0 bbls lost downhole Max Gas = 33 units, Avg Gas = 26 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 18000 0 6-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max @ Mud Data MWD Summary API FL Avg Min N/A Tools Rig: ODSN-28 ROP ROP (ft/hr) 4.19 Daily Charges: Total Charges: Nabors 19AC Report For: Depth Condition Morning Report Report # 3 Customer: Well: Area: Location: 95% Rig Activity: N/A N/A Bit # 1 3.0 14.500'' 8.90 Tricone 8.90 Size WOB Conductor 158' 100% Gas In Air =10,000 Units N/A Connection New RPM ECD (ppg) ml/30min pH YP (lb/100ft 2) Background 10.00 Comments N/A Chromatograph (ppm) (max) Trip 20 Minimum Average Mud Type Lst Type in Spud Mud 16.8 175'49 Depth in / out 000 0 0 0 158' Cht Silt C-4i C-4n Sh 0 Hours C-3 Clyst 0 Gas Summary Making up BHA #1 PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg Footage TFA 0.700 Tuff Gvl Coal Sid 0 0 (current) 158'0 to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: 182.4 Flow In (gpm) AK-AM-900774793 Date: 0' 226' 226' Max @ ft Current 222'71.0 J. Polya / T. DeRanger C-1 C-5i 0 C-5n Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 22 222' Siltst Ss (ppb Eq) C-2 33 Casing Summary Size 109.0 MBT N/A 0 0 cP 22 129 0.0 Grade 14.67'' Weight 016 Set At Depth 0 18 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 0 Logging Engineers: Bit Type Maximum Cly 24 Kerry Garner / Makenzie Jorgensen (max) (current) 0 0 Lithology (%) . . * 24 hr Recap: Kerry Garner / Makenzie Jorgensen (max) (current) 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 9426 0 3709 907-670-6636 Unit Phone: Kerry Garner Report By: 088 Set At Depth Grade 14.67'' Weight MBT cP 23 122 75.0 (ppb Eq) C-2 304 Casing Summary Size 109.0 2 804 Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 226' 1715' 1489' Max @ ft Current 1625'119.5 R.Klepzig / T. DeRanger to 226' Yesterday's Depth: Current Depth: 24 Hour Progress: 231.0 Flow In (gpm) AK-AM-900774793 Date: 0 0 (current) 1123 0 Tuff Gvl Coal Sid Footage TFA 0.700 Drilling PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 0 Hours C-3 Clyst 0 Gas Summary 0 158' Cht Silt C-4i C-4n Sh 000 0 0 Spud Mud 12.5 1525'42 Depth in / out Mud Type Lst Type in Minimum Average N/A Chromatograph (ppm) (max) Trip 100 Background 9.80 Comments New RPM ECD (ppg) ml/30min pH YP (lb/100ft 2) 6.0 WOB Conductor 158' 100% Gas In Air =10,000 Units 189 Connection N/A N/A Bit # 1 4.7 14.500'' 9.10 Tricone 9.10 Size Depth Condition Morning Report Report # 4 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 4.19 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary API FL Avg Min N/A Tools Directional gamma 7-Nov-2013 12:00 AM Current Pump & Flow Data: 964 Max 0 mg/l 14000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Fluids = 0 bbls lost downhole Max Gas = 304 units, Avg Gas = 156 units 156 Units* an average of 143 units. No geology samples collected 1710' with know issue.Max gas was 304 units from 1123' MD with a average of 156 units. Max connection gas was 189 units with Drilled from 225' to 1489' rig down GYRO sheave. Continued drilling from 1489' to 1576' service top drive. Drilled from 1576' to . . * 24 hr Recap: Todd Wilson / Makenzie Jorgensen (max) (current) 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 1027 0 1716 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 045 Set At Depth Grade 14.67'' Weight MBT 199 47 cP 19 120 0.0 (ppb Eq) C-2 257 Casing Summary Size 109.0 11 2125' Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 1715' 2431' 716' Max @ ft Current 1817'118.6 R.Klepzig / J. Haberther to 226' Yesterday's Depth: Current Depth: 24 Hour Progress: 228.7 Flow In (gpm) AK-AM-900774793 Date: 0 0 (current) 1826'0 Tuff Gvl Coal Sid Footage TFA 0.700 Tripping in the hole PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 0 Hours C-3 Clyst 0 Gas Summary 0 158' Cht Silt C-4i C-4n Sh 000 0 0 Spud Mud 10.0 2431'43 Depth in / out Mud Type Lst Type in Minimum Average 375 Chromatograph (ppm) (max) Trip 30 Background 9.80 Comments New RPM ECD (ppg) ml/30min pH YP (lb/100ft 2) 12.0 WOB Conductor 158' 100% Gas In Air =10,000 Units 196 Connection N/A N/A Bit # 1 4.6 14.500'' 9.10 Tricone 9.10 Size Depth Condition Morning Report Report # 5 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 4.19 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary API FL Avg Min N/A Tools Directional gamma 8-Nov-2013 12:00 AM Current Pump & Flow Data: 566 Max 0 mg/l 16000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Fluids = 25 bbls lost downhole (10 during trip out and 15 during trip in) Max Gas = 375 units, Avg Gas = 93 units While circulating max gas was 375 uniits. While drilling max gas was 257 units from 1826' MD with an average of 93 units. 93 Units* Max connection gas was 196 units with an average of 95 units. No geology samples collected. 4 barrels per minute. Circulated one bottoms up at 4 barrels per minute. Tripped in the hole from 1,200' to 1,865'. Pumped down from 1,770' at Picked up BHA #2 from 73' to 256' and shallow pulse tested. Tripped in the hole from 256' to 1,200'. from 2,241' to 158' at 2 barrels per minute. Laid down BHA #1 and downloaded MWD tools. Dialed motor back to 1.15 degrees. Drilled ahead from 1,710' to 2,431'. Circulated and conditioned 2.5 bottoms up. Back reamed and pumped out of hole . . * 24 hr Recap: 127 Units* Max gas was trip gas of 296 units. While drilling max gas was 227 units from 2,657' MD with an average of 127 units. Serviced top drive. Drilled ahead from 3,195' to 3,515' at 700 gpm. Drilling ahead at report time. reduced mud weight to a 9.1 ppg. Drilled ahead from 2,981' to 3,195' at 700 gpm. from 2,431' to 2,981' at 650 gpm. Circulated 3 bottoms up to clean hole while diluting mud system with new mud, which Reamed, washed down, and worked pipe from 1,865' to 2,431'. Circulated bottoms up at 2,431'. Drilled ahead Fluids = 110 bbls lost downhole Max Gas = 296 units, Avg Gas = 127 units Max connection gas was 196 units with an average of 139 units. No geology samples collected. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 14000 0 9-Nov-2013 12:00 AM Current Pump & Flow Data: 1861 Max 2-1-WT-A-E-I-NO-BHA @ Mud Data MWD Summary API FL Avg Min N/A Tools Directional gamma Rig: ODSN-28 ROP ROP (ft/hr) 4.19 Daily Charges: Total Charges: Nabors 19AC Report For: Depth Condition Morning Report Report # 6 Customer: Well: Area: Location: 95% Rig Activity: N/A N/A Bit # 1 4.7 14.500'' 9.10 Tricone 9.10 Size 14.0 WOB Conductor 158' 100% Gas In Air =10,000 Units 196 Connection New RPM ECD (ppg) ml/30min 54.0 pH 15.0 YP (lb/100ft 2) Background 9.80 Comments 296 Chromatograph (ppm) (max) Trip 45 Minimum Average 2 Mud Type Lst Type in Tricone Spud Mud 10.8 2431' 3501'34 Depth in / out 000 0 0 0 158' Cht Silt C-4i C-4n Sh 0 Hours C-3 Clyst 0 2273' Gas Summary Drilling surface hole PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 14.5 0.700 Footage 30.66 0.00 TFA 2431' 0.700 Tuff Gvl Coal Sid 0 0 (current) 2657'0 to 226' Yesterday's Depth: Current Depth: 24 Hour Progress: 263.1 Flow In (gpm) AK-AM-900774793 Date: 2431' 3518' 1087' Max @ ft Current 3050'109.9 R.Klepzig / J. Haberther C-1 C-5i 0 C-5n Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 13 2757' Siltst Ss (ppb Eq) C-2 227 Casing Summary Size 109.0 MBT 698 165 cP 17 72 3.0 Grade 14.67'' Weight 055 Set At Depth 0 2457 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 0 Logging Engineers: Bit Type Maximum Cly 5271 Todd Wilson / Makenzie Jorgensen (max) (current) 0 0 Lithology (%) . . * 24 hr Recap: 112 Units* Max connection gas was 180 units with an average of 130 units. No trip gas or geology samples collected. Max gas was 271 units from 4,580' MD with an average of 112 units. Drilled ahead from 4,526' to 4,733'. Drilling ahead at report time. Drilled ahead from 3,515' to 4,526' at 800 gpm. Serviced top drive and cleaned suction screens. Fluids = 0 bbls lost downhole Max Gas = 271 units, Avg Gas = 112 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 16000 0 10-Nov-2013 12:00 AM Current Pump & Flow Data: 2661 Max 2-1-WT-A-E-I-NO-BHA @ Mud Data MWD Summary API FL Avg Min N/A Tools Directional gamma Rig: ODSN-28 ROP ROP (ft/hr) 4.19 Daily Charges: Total Charges: Nabors 19AC Report For: Depth Condition Morning Report Report # 7 Customer: Well: Area: Location: 95% Rig Activity: N/A N/A Bit # 1 7.1 14.500'' 9.40 Tricone 9.40 Size 20.0 WOB Conductor 158' 100% Gas In Air =10,000 Units 180 Connection New RPM ECD (ppg) ml/30min 54.0 pH 15.0 YP (lb/100ft 2) Background 9.40 Comments N/A Chromatograph (ppm) (max) Trip 100 Minimum Average 2 Mud Type Lst Type in Tricone Spud Mud 12.2 2431' 4603'36 Depth in / out 000 0 0 0 158' Cht Silt C-4i C-4n Sh 3 Hours C-3 Clyst 0 2273' Gas Summary Drilling Surface hole PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 14.5 0.700 Footage 30.66 0.00 TFA 2431' 0.700 Tuff Gvl Coal Sid 0 0 (current) 4580 0 to 226' Yesterday's Depth: Current Depth: 24 Hour Progress: 217.8 Flow In (gpm) AK-AM-900774793 Date: 3518' 4731' 1213' Max @ ft Current 4148'88.6 R.Klepzig / J. Haberther C-1 C-5i 0 C-5n Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 13 4483 Siltst Ss (ppb Eq) C-2 271 Casing Summary Size 109.0 MBT 812 192 cP 13 72 38.0 Grade 14.67'' Weight 0221 Set At Depth 0 2001 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 0 Logging Engineers: Bit Type Maximum Cly 6254 Todd Wilson / Makenzie Jorgensen (max) (current) 7 0 Lithology (%) . . * 24 hr Recap: Todd Wilson / Makenzie Jorgensen (max) (current) 108 51 Lithology (%) 32 Logging Engineers: Bit Type Maximum Cly 7547 22 4590 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 52882 Set At Depth Grade 14.67'' Weight MBT 0 0 cP 10 68 0.0 (ppb Eq) C-2 334 Casing Summary Size 109.0 11 5309 Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 4731' 5557' 826' Max @ ft Current 5052'100.2 R.Klepzig / J. Haberther to 226' Yesterday's Depth: Current Depth: 24 Hour Progress: 200.4 Flow In (gpm) AK-AM-900774793 Date: 0 0 (current) 5194 0 Tuff Gvl Coal Sid 14.5 0.700 Footage 30.66 0.00 TFA 2431' 0.700 Tripping out of the hole PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 81 Hours C-3 Clyst 25 2273' Gas Summary 12 158' Cht Silt C-4i C-4n Sh 012 0 9 0 Tricone Spud Mud 12.4 2431' 5557'31 Depth in / out 2 Mud Type Lst Type in Minimum Average N/A Chromatograph (ppm) (max) Trip 50 Background 9.10 Comments New RPM ECD (ppg) ml/30min 54.0 pH 15.0 YP (lb/100ft 2) 20.0 WOB Conductor 158' 100% Gas In Air =10,000 Units 309 Connection N/A N/A Bit # 1 6.6 14.500'' 9.40 Tricone 9.40 Size Depth Condition Morning Report Report # 8 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 4.19 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary API FL Avg Min N/A Tools Directional gamma 11-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max 2-1-WT-A-E-I-NO-BHA 8 mg/l 16000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Fluids = 0 bbls lost downhole Max Gas = 334 units, Avg Gas = 210 units Max connection gas was 309 units with an average of 249 units. No trip gas or geology samples collected. 210 Units* Max gas was 334 units from 5,194' MD with an average of 210 units. Carbide came back 888 strokes early, indicating an average hole of 13.85". 4,907' to 4,432'. Tripped out of the hole from 4,432' to 3,766'. Pumped out of the hole at 2 bpm from 3,766' to 1,580'. Worked stand at 650 gpm going up and 800 gpm going down. Pumped out of the hole at 2 bpm from Rotary drilled from 4,733' to 5,557' at 850 gpm. Circulated 5 bottoms up, racking back a stand every 40 min. . . * 24 hr Recap: Todd Wilson / Makenzie Jorgensen (max) (current) 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 0 0 0 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 00 Set At Depth Grade 14.67'' Weight MBT 5557' 0 0 cP 13 60 N/A (ppb Eq) C-2 392 Casing Summary Size 109.0 0 N/A Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 5557' 5557' 0' Max @ ft Current N/A N/A R.Klepzig / J. Haberther to 226' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) AK-AM-900774793 Date: 0 0 (current) N/A 0 Tuff Gvl Coal Sid 14.5 0.700 Footage 30.66 0.00 TFA 2431' 0.700 Tripping out of the hole PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 0 Hours C-3 Clyst 0 2273' Gas Summary 0 158' Cht Silt C-4i C-4n Sh 000 0 0 Tricone Spud Mud 12.2 2431' 5557'28 5557' Depth in / out 2 Mud Type Lst Type in Minimum Average 361 Chromatograph (ppm) (max) Trip 50 Background 9.20 Comments New RPM ECD (ppg) ml/30min 54.0 pH 15.0 YP (lb/100ft 2) 25.0 WOB Conductor 158' 100% Gas In Air =10,000 Units N/A Connection N/A N/A Bit # 1 7.1 14.500'' 9.45 Tricone 9.45 Size Depth Condition Morning Report Report # 9 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 4.19 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary API FL Avg Min N/A Tools Directional gamma 12-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max 2-1-WT-A-E-I-NO-BHA 0 mg/l 16500 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Fluids = 40 bbls lost downhole (12 during morning trip in, 15 during trip out, and 13 during afternoon trip in). Max Gas = 392 units, Avg Gas = 77 units While circulating, max gas was 392 units with an average of 77 units. Max trip gas was 361 units. No geology samples collected. Circulated bottoms up, then began tripping out of the hole from 5,476' to 5,191'. 77 Units* Pumped out of the hole from 5,191' to 1,105' at 2 bpm. 3.5 bottoms up from 5,557 to 4,717'. Reamed and washed down from 4,717' to 5,001'. Tripped in the hole from 5,001' to 5,476'. Tripped in the hole from 2,720' to 4,622'. Reamed and washed down from 4,622' to 5,557'. Circulated Pumped in the hole from 1,675' to 2,625' at 4 bpm. Circulated bottoms up at 630 to 650 gpm from 2,625' to 2,720'. Set back the drill collars and cleaned clay from the BHA. Tripped in the hole from surface to 1,675' and took weight. Tripped out of the hole while pumping at 2 bpm from 1,580' to 630'. Set back the heavy wall drill pipe from 630' to 163'. . . * 24 hr Recap: Todd Wilson / Makenzie Jorgensen (max) (current) 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 0 0 0 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 00 Set At Depth Grade 14.67'' Weight MBT 5557' 216 51 cP 18 50 N/A (ppb Eq) C-2 139 Casing Summary Size 109.0 0 N/A Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 5557' 5557' 0' Max @ ft Current N/A N/A R.Klepzig / J. Haberther to 226' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) AK-AM-900774793 Date: 0 0 (current) N/A 0 Tuff Gvl Coal Sid 14.5 0.700 Footage 30.66 3126' 0.00 TFA 2431' 0.700 Running Casing PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 0 Hours C-3 Clyst 0 2273' Gas Summary 0 158' Cht Silt C-4i C-4n Sh 000 0 0 Tricone Spud Mud 11.0 2431' 5557'22 5557' Depth in / out 2 Mud Type Lst Type in Minimum Average N/A Chromatograph (ppm) (max) Trip 20 Background 9.70 Comments 114 19 New RPM ECD (ppg) ml/30min 54.0 pH 15.0 YP (lb/100ft 2) 22.0 WOB Conductor 158' 100% Gas In Air =10,000 Units N/A Connection N/A N/A Bit # 1 8.3 14.500'' 9.40 Tricone 9.40 Size Depth Condition Morning Report Report # 10 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 4.19 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary API FL Avg Min N/A Tools Directional gamma 13-Nov-2013 12:00 AM Current Pump & Flow Data: 199 Max 2-1-WT-A-E-I-NO-BHA 0 mg/l 450 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Fluids = 16 bbls lost downhole Max Gas = 139 units Avg Gas = 19 units 19 Units* While circulating, max gas was 139 units with an average of 19 units. No trip or connection gas. No geology samples collected. cement job, and built 100 bbl spacer at RSC. Experienced tight spot at 2703'. Continued to run in hole with casing to 5505'. Reduced mud rheology, prepared pits for Continued tripping out of hole. Layed down BHA #2. Rigged up to run 11.75" casing, Ran in hole with casing. . . * 24 hr Recap: Todd Wilson / Makenzie Jorgensen (max) (current) 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 0 0 0 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 00 Set At Depth Grade 14.67'' Weight MBT 5557' 0 0 cP 14 50 N/A (ppb Eq) C-2 317 Casing Summary Size 109.0 0 N/A Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 5557' 5557' 0' Max @ ft Current N/A N/A R.Klepzig / J. Haberther to 226' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) AK-AM-900774793 Date: 0 0 (current) N/A 0 Tuff Gvl Coal Sid 14.5 0.700 Footage 30.66 3126' 0.00 TFA 2431' 0.700 Nipple down BOPs PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 0 Hours C-3 Clyst 0 2273' Gas Summary 0 158' Cht Silt C-4i C-4n Sh 000 0 0 Tricone Spud Mud 11.8 2431' 5557'22 5557' Depth in / out 2 Mud Type Lst Type in Minimum Average 317 Chromatograph (ppm) (max) Trip 0Background 9.00 Comments 114 19 New RPM ECD (ppg) ml/30min 54.0 pH 15.0 YP (lb/100ft 2) 22.0 WOB Conductor 158' 100% Gas In Air =10,000 Units N/A Connection N/A N/A Bit # 1 9.3 14.500'' 9.60 Tricone 9.60 Size Depth Condition Morning Report Report # 11 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 4.19 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary API FL Avg Min N/A Tools Directional gamma 14-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max 2-1-WT-A-E-I-NO-BHA 0 mg/l 400 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Fluids = 0 bbls lost downhole Max Gas = 317 units Avg Gas = 12 units No connection gas. No geology samples collected. 12 Units* Max gas was trip gas of 317 units. While circulating cement job, max gas was 223 units with an average of 12 units. was returned back to surface. Rigged down casing and cement equipment. Rigged down riser and nippled down BOPs. 151 bbl 15.8 ppg cement. Displaced at 10 bpm; 5959 total strokes. Plug was not bumped, Approximatly 300 bbls of cement equipment. Rigged up cement lines and tested to 4,000 psi. Pumped 100 bbl 10.0 ppg spacer, 689 bbl 10.7 ppg cement, and Landed 11.75" surface casing. Began circulating at 9 bpm to condition mud for cement job. Rigged down casing . . * 24 hr Recap: 8 Units* No geology samples collected. While tripping in cemented casing, max gas was 48 units and average gas was 8 units. No connection or trip gas. Ran in hole to 4,495'. Prepared pits for clean out run and upcoming displacement. Rigged down diverter and nipple up BOPs. Tested BOPs to 4500 psi. Picked up BHA #3, Fluids = 0 bbls lost downhole Max Gas = 48 units Avg Gas = 8 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 14500 0 15-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max 2-1-WT-A-E-I-NO-BHA @ Mud Data MWD Summary API FL Avg Min N/A Tools Directional gamma Rig: ODSN-28 ROP ROP (ft/hr) 4.19 Daily Charges: Total Charges: Nabors 19AC Report For: Depth Condition Morning Report Report # 12 Customer: Well: Area: Location: 95% Rig Activity: N/A N/A Bit # 1 8.2 14.500'' 9.60 Tricone 9.60 Size 22.0 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units N/A Connection New RPM ECD (ppg) ml/30min 54.0 pH 15.0 YP (lb/100ft 2) Background 9.20 Comments 114 19 N/A Chromatograph (ppm) (max) Trip 8 Minimum Average 2 Mud Type Lst Type in Tricone Spud Mud 12.2 2431' 5557'23 5557' Depth in / out 000 0 0 0 158' Cht Silt C-4i C-4n Sh 0 Hours C-3 Clyst 0 2273' Gas Summary Tripping in PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 14.5 0.700 Footage 30.66 3126' 0.00 TFA 2431' 0.700 Tuff Gvl Coal Sid 0 0 (current) N/A 0 to 226' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) AK-AM-900774793 Date: 5557' 5557' 0' Max @ ft Current N/A N/A R.Klepzig / J. Haberther C-1 C-5i 0 C-5n Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 0 N/A Siltst Ss (ppb Eq) C-2 48 Casing Summary Size 109.0 MBT 5557' 11.75'' 0 0 cP 15 50 N/A Grade 14.67'' L-80 60.0 Weight 00 Set At Depth 0 0 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 0 Logging Engineers: Bit Type Maximum Cly 0 Todd Wilson / Makenzie Jorgensen (max) (current) Hydril 0 0 Lithology (%) . . * 24 hr Recap: Todd Wilson / Makenzie Jorgensen (max) (current) Hydril 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 0 0 0 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 00 Set At Depth Grade 14.67'' L-80 60.0 Weight MBT 5557' 11.75'' cP 15 50 N/A (ppb Eq) C-2 125 Casing Summary Size 109.0 0 N/A Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 5557' 5557' 0' Max @ ft Current N/A N/A R.Klepzig / J. Haberther to 226' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) AK-AM-900774793 Date: 0 0 (current) N/A 0 Tuff Gvl Coal Sid Footage 8.49 TFA 0.942 Tripping in with BHA #4 PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 0 Hours C-3 Clyst 0 Gas Summary 0 Cht Silt C-4i C-4n Sh 000 0 0 Spud Mud 12.6 5557'24 Depth in / out Mud Type Lst Type in Minimum Average N/A Chromatograph (ppm) (max) Trip 0Background 9.60 Comments 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min pH YP (lb/100ft 2) 22.0 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units N/A Connection N/A N/A Bit # 2 8.2 10.625 9.60 Tricone 9.60 Size Depth Condition Morning Report Report # 13 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary API FL Avg Min N/A Tools Directional gamma 16-Nov-2013 12:00 AM Current Pump & Flow Data: Max 0 mg/l 15000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Fluids = 0 bbls lost downhole Max Gas = 125 units Avg Gas = 10 units While in cemented casing, max gas was 125 units and average gas was 10 units. No connection or trip gas. 10 Units* and function tested reamer. one bottoms up. Tripped out to surface and laid down BHA #3. Picked up BHA #4, pressure tested Geo-Pilot, at 5461' to 3500 psi. Circulated two bottoms up. Drilled out shoe track and float collar/shoe to 5557' at 750 gpm. Circulated Tagged firm cement at 5380'. Drilled out cement to 5461' at 500 gpm. Pressure tested casing Tagged cement stringers at 5353'. Reamed and washed to 5373' at 380 gpm. Pressure tested casing at 5373' to 3500 psi. . . * 24 hr Recap: 173 Units* While drilling, max gas was connection gas of 338 units from 5686' with an average gas of 173 units. No trip gas or geology Troubleshoot mud line wash-out in pump room at time of report. spud mud for injection. Drilled to 5577' and conducted FIT to 12.5 effective mud weight. Drilled to 5717' at 800 gpm. mineral oil based mud at 260 gpm (8240 strokes total). Dumped 90 bbls of spacer/interface and transferred remaining Tripped in hole with BHA #4 to 5399'. Cut and slipped drill line. Reamed from 5399' to 5557'. Displaced well to 10.0 ppg Fluids = 0 bbls lost downhole Max Gas = 338 units Avg Gas = 173 units samples collected. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 4.01 2 17-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max @ Mud Data MWD Summary HTHP Avg Min 11.20 Tools Full service Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: Depth Condition Morning Report Report # 14 Customer: Well: Area: Location: 95% Rig Activity: 10.03 10.46 Bit # 2 16.9 10.625 10.00 Tricone 10.00 Size 79.3/20.7 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units 338 Connection 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) Background 2.668 Comments N/A Chromatograph (ppm) (max) Trip 0 Minimum Average Mud Type Lst Type in ENVIROMUL 3.0 5717'20 Depth in / out 030 0 0 5 Cht Silt C-4i C-4n Sh 56 Hours C-3 Clyst 42 Gas Summary troubleshoot mud line PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg Footage 8.49 TFA 0.942 Tuff Gvl Coal Sid 10 0 (current) 5686'0 to 5557' Yesterday's Depth: Current Depth: 24 Hour Progress: 79.4 Flow In (gpm) AK-AM-900774793 Date: 5557' 5718' 161' Max @ ft Current 5656'60.2 R.Klepzig / J. Haberther C-1 C-5i 0 C-5n Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 30 5576' Siltst Ss Ratio C-2 338 Casing Summary Size 109.0 Oil/Water 11.75'' 789 222 cP 26 140 0.0 Grade 14.67'' L-80 60.0 Weight 01500 Set At Depth 0 3808 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 16 Logging Engineers: Bit Type Maximum Cly 10223 Todd Wilson / Makenzie Jorgensen (max) (current) Hydril 145 0 Lithology (%) . . * 24 hr Recap: Todd Wilson / Makenzie Jorgensen (max) (current) Hydril 202 0 Lithology (%) 37 Logging Engineers: Bit Type Maximum Cly 11996 0 4833 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 033 Set At Depth Grade 14.67'' L-80 60.0 Weight Oil/Water 11.75'' 803 226 cP 44 145 0.0 Ratio C-2 783 Casing Summary Size 109.0 10 5695 Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 5718' 6118' 400' Max @ ft Current 5778'66.2 R.Klepzig / J. Haberther to 5557' Yesterday's Depth: Current Depth: 24 Hour Progress: 84.7 Flow In (gpm) AK-AM-900774793 Date: 15 0 (current) 5919 0 Tuff Gvl Coal Sid Footage 8.49 TFA 0.942 Drilling PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 95 Hours C-3 Clyst 61 Gas Summary 8 Cht Silt C-4i C-4n Sh 011 0 0 0 PDC Long Gauge ENVIROMUL 3.0 5557' 6075'26 Depth in / out 3 Mud Type Lst Type in Minimum Average N/A Chromatograph (ppm) (max) Trip 159 Background 2.658 Comments 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) 78.0/22.0 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units 926 Connection 10.33 10.57 Bit # 2 17.2 10.625 10.00 Tricone 10.00 Size Depth Condition Morning Report Report # 15 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary HTHP Avg Min 10.83 Tools Full service 18-Nov-2013 12:00 AM Current Pump & Flow Data: 3569 Max 6 (lb/bbl) 5.44 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime Fluids = 0 bbls lost downhole Max Gas = 783 units Avg Gas = 351 units 351 Units* with an average of 457 units. No trip gas or geology samples collected. While drilling, max gas was 783 units from 5919' with an average gas of 351 units. Max connection gas was 926 units line pack off. Drilled ahead to 6115' at 800 gpm. Drilling ahead at time of report. Packed off and completed short trip to shoe. Tripped in and drilled ahead to 6075' at 800 gpm. Trouble shoot cuttings Pressure tested mud line fix to 4500 psi. Tripped in from 5495' to 5685'. Circulated at 800 gpm and drilled ahead to 5720'. . . * 24 hr Recap: Todd Wilson / Makenzie Jorgensen (max) (current) Hydril 787 19 Lithology (%) 140 Logging Engineers: Bit Type Maximum Cly 32481 11 8468 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 0486 Set At Depth Grade 14.67'' L-80 60.0 Weight Oil/Water 11.75'' 800 225 cP 36 98 73.0 Ratio C-2 2101 Casing Summary Size 109.0 43 6135 Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 6118' 7293' 1175' Max @ ft Current 7234'73.3 R.Klepzig / J. Haberther to 5557' Yesterday's Depth: Current Depth: 24 Hour Progress: 122.0 Flow In (gpm) AK-AM-900774793 Date: 57 4 (current) 6877 0 Tuff Gvl Coal Sid 10.625 Footage 8.49 TFA 0.942 Drilling PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 312 Hours C-3 Clyst 265 Gas Summary 31 Cht Silt C-4i C-4n Sh 037 1 0 0 PDC Long Gauge ENVIROMUL 3.2 5557' 7260'26 Depth in / out 3 Mud Type Lst Type in Minimum Average N/A Chromatograph (ppm) (max) Trip 500 Background 2.658 Comments 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) 78.0/22.0 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units 1999 Connection 10.36 10.56 Bit # 2 17.2 10.625 10.00 Tricone 10.00 Size Depth Condition Morning Report Report # 16 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary HTHP Avg Min 10.73 Tools Full service 19-Nov-2013 12:00 AM Current Pump & Flow Data: 3878 Max 19 (lb/bbl) 5.44 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime Fluids = 0 bbls lost downhole Max Gas = 2101 units Avg Gas = 613 units 613 Units* with an average of 682 units. No trip gas or geology samples collected. While drilling, max gas was 2101 units from 6877' with an average gas of 613 units. Max connection gas was 1999 units 7259' and drilled to 7290' at 800 gpm. Drilling ahead at time of report. Drilled from 7015' to 7259' at 800 gpm. Troubleshoot the GEO pump. Tripped out to 6662'. Tripped in to Drilled from 6115' to 6243' at 800 gpm. Flushed CCU hopper. Drilled from 6243' to 7015' at 800 gpm. Flushed CCU hopper. . . * 24 hr Recap: 688 Units* with an average of 717 units. No trip gas or geology samples collected. While drilling, max gas was 1426 units from 7613' with an average gas of 688 units. Max connection gas was 971 units 7856' to 8310' at 800 gpm. Drilling ahead at time of report. Drilled from 7290' to 7856' at 800 gpm. Troubleshoot top drive encoder. Troubleshoot CCU GEO pump. Drilled from Fluids = 0 bbls lost downhole Max Gas = 1426 units Avg Gas = 688 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 4.92 43 20-Nov-2013 12:00 AM Current Pump & Flow Data: 3936 Max @ Mud Data MWD Summary HTHP Avg Min 10.74 Tools Full service Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: Depth Condition Morning Report Report # 17 Customer: Well: Area: Location: 95% Rig Activity: 10.34 10.60 Bit # 2 17.3 10.625 10.00 Tricone 10.00 Size 79.3/20.7 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units 971 Connection 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) Background 2.671 Comments N/A Chromatograph (ppm) (max) Trip 400 Minimum Average 3 Mud Type Lst Type in PDC Long Gauge ENVIROMUL 3.2 5557' 8154'25 Depth in / out 15 88 15 78 0 91 Cht Silt C-4i C-4n Sh 443 Hours C-3 Clyst 551 Gas Summary Drilling PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 10.625 Footage 8.49 TFA 0.942 Tuff Gvl Coal Sid 182 39 (current) 7613 44 to 5557' Yesterday's Depth: Current Depth: 24 Hour Progress: 115.5 Flow In (gpm) AK-AM-900774793 Date: 7293' 8310' 1017' Max @ ft Current 7859'63.3 R.Klepzig / J. Haberther C-1 C-5i 3 C-5n Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 114 7648 Siltst Ss Ratio C-2 1426 Casing Summary Size 109.0 Oil/Water 11.75'' 800 225 cP 39 90 55.0 Grade 14.67'' L-80 60.0 Weight 38 6058 Set At Depth 231 8244 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 247 Logging Engineers: Bit Type Maximum Cly 15865 Todd Wilson / Makenzie Jorgensen (max) (current) Hydril 987 389 Lithology (%) . . * 24 hr Recap: Todd Wilson / Makenzie Jorgensen (max) (current) Hydril 465 110 Lithology (%) 98 Logging Engineers: Bit Type Maximum Cly 18687 41 11769 907-670-6636 Unit Phone: Makenzie Jorgensen Report By: 42829 Set At Depth Grade 14.67'' L-80 60.0 Weight Oil/Water 11.75'' 800 225 cP 42 82 50.0 Ratio C-2 218 Casing Summary Size 109.0 32 8981' Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 8310' 9242' 932' Max @ ft Current 8451'55.8 R.Klepzig / J. Haberther to 5557' Yesterday's Depth: Current Depth: 24 Hour Progress: 81.5 Flow In (gpm) AK-AM-900774793 Date: 21 0 (current) 8898'0 Tuff Gvl Coal Sid 10.625 Footage 8.49 TFA 0.942 Drilling PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 304 Hours C-3 Clyst 133 Gas Summary 13 Cht Silt C-4i C-4n Sh 023 1 9 0 PDC Long Gauge ENVIROMUL 3.0 5557' 9104'27 Depth in / out 3 Mud Type Lst Type in Minimum Average N/A Chromatograph (ppm) (max) Trip 70 Background 2.606 Comments 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) 82.7/17.3 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units 156 Connection 10.37 10.58 Bit # 2 18.7 10.625 10.00 Tricone 10.00 Size Depth Condition Morning Report Report # 18 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary HTHP Avg Min 10.87 Tools Full service 21-Nov-2013 12:00 AM Current Pump & Flow Data: 3810 Max 12 (lb/bbl) 4.14 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime Fluids = 0 bbls lost downhole Max Gas = 218 units Avg Gas = 91 units 91 Units* with an average of 99 units. No trip gas or geology samples collected. While drilling, max gas was 218 units from 8898' with an average gas of 91 units. Max connection gas was 156 units Experienced gas equipment failure. Company man and Geo was notificed. Changed out gas equipment. from 8917' to 9201' at 800 gpm. Began adding STEELSEAL 400 at 9200'. Drilling ahead at time of report. Drilled from 8310' to 8917' at 800 gpm. Troubleshoot mud pump #2. Circulated between 8917' and 8820' at 400 gpm. Drilled . . * 24 hr Recap: Todd Wilson / Martin Nnaji (max) (current) Hydril 1132 574 Lithology (%) 328 Logging Engineers: Bit Type Maximum Cly 20350 218 12943 907-670-6636 Unit Phone: Martin Nnaji Report By: 30 11181 Set At Depth Grade 14.67'' L-80 60.0 Weight Oil/Water 11.75'' 800 225 cP 41 77 48.0 Ratio C-2 280 Casing Summary Size 109.0 30 9455 Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 9242' 10130' 888' Max @ ft Current 9374'36.7 R.Klepzig / J. Haberther to 5557' Yesterday's Depth: Current Depth: 24 Hour Progress: 95.8 Flow In (gpm) AK-AM-900774793 Date: 143 37 (current) 9718 6 Tuff Gvl Coal Sid 10.625 Footage 8.49 TFA 0.942 Drilling PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 742 Hours C-3 Clyst 473 Gas Summary 75 Cht Silt C-4i C-4n Sh 28 105 26 57 0 PDC Long Gauge ENVIROMUL 3.2 5557' 10052'26 Depth in / out 3 Mud Type Lst Type in Minimum Average N/A Chromatograph (ppm) (max) Trip 134 Background 2.765 Comments 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) 84.2/15.8 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units 214 Connection 10.37 10.55 Bit # 2 17.0 10.625 10.00 Tricone 9.95 Size Depth Condition Morning Report Report # 19 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary HTHP Avg Min 10.70 Tools Full service 22-Nov-2013 12:00 AM Current Pump & Flow Data: 4264 Max 53 (lb/bbl) 4.92 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime Fluids = 0 bbls lost downhole Max Gas = 280 units Avg Gas = 147 units 147 Units* while drilling. Max connection gas was 214 units with an average of 142 units. No trip gas or geology samples collected. TD'd intermediate 1 hole section as at time of report. Max gas of 280 units at 9718' MD with average gas of 147 units was recorded BOPs then drilled from 9688' MD to 9962' MD at 800 gpm. Serviced top drive and drilled from 9962' MD to 10130' MD at 800 gpm. Drilled from 9242' MD to 9688' MD at 800gpm. Active system diluted with 470 bbls 9.8ppg mineral oil based mud. Function test . . * 24 hr Recap: 117 Units* recorded was a Max circulating gas of 229 units. 9910' MD to 7015' MD. While drilling, a Max gas of 148 units was observed at 10122' MD with an average of 117 units. Also hole to 9962' MD and observed packoff, trip to 9910' MD and observed packoff as well. Trip and lubricate out of hole from 10170' MD to 10040' MD at 800 gpm. Drop tags, pumped 2200 strokes and no success on 3 attempts. Circulate and Pull out of Drilled from 10130' MD to total depth at 10170' MD (Intermediate 1 section) - 800 gpm. Hole was circulated and reamed from Fluids = -7 bbls lost downhole Max Gas = 148 units Avg Gas = 117 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.59 24 23-Nov-2013 12:00 AM Current Pump & Flow Data: 41 Max @ Mud Data MWD Summary HTHP Avg Min 10.57 Tools Full service Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: Depth Condition Morning Report Report # 20 Customer: Well: Area: Location: 95% Rig Activity: 10.40 10.52 Bit # 2 17.6 10.625 10.00 Tricone 10.00 Size 85.4/14.6 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units 120 Connection 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) Background 2.721 Comments N/A Chromatograph (ppm) (max) Trip 38 Minimum Average 3 Mud Type Lst Type in PDC Long Gauge ENVIROMUL 3.4 5557' 10170'21 Depth in / out 20 54 5 37 7 27 Cht Silt C-4i C-4n Sh 264 Hours C-3 Clyst 149 Gas Summary Tripping Out of Hole PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 10.625 Footage 8.49 TFA 0.942 Tuff Gvl Coal Sid 63 20 (current) 10122 24 to 5557' Yesterday's Depth: Current Depth: 24 Hour Progress: 51.0 Flow In (gpm) AK-AM-900774793 Date: 10130' 10170' 40' Max @ ft Current 10150'14.5 R.Klepzig / J. Haberther C-1 C-5i 0 C-5n Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 70 10123 Siltst Ss Ratio C-2 148 Casing Summary Size 109.0 Oil/Water 10170' 11.75'' 43 12 cP 42 110 0.0 Grade 14.67'' L-80 60.0 Weight 18 3313 Set At Depth 94 5218 907-670-6636 Unit Phone: Martin Nnaji Report By: 132 Logging Engineers: Bit Type Maximum Cly 5982 Todd Wilson / Martin Nnaji (max) (current) Hydril 301 183 Lithology (%) . . * 24 hr Recap: Todd Wilson / Martin Nnaji (max) (current) Hydril 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 0 0 0 907-670-6636 Unit Phone: Martin Nnaji Report By: 00 Set At Depth Grade 14.67'' L-80 60.0 Weight Oil/Water 10170' 11.75'' 800 225 cP 46 100 N/A Ratio C-2 121 Casing Summary Size 109.0 2 N/A Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 10170' 10170' 0' Max @ ft Current N/A N/A R.Klepzig / J. Haberther to 5557' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) AK-AM-900774793 Date: 0 0 (current) N/A 0 Tuff Gvl Coal Sid 10.625 Footage 8.49 TFA 0.942 Backream andTrip out PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 0 Hours C-3 Clyst 0 Gas Summary 0 Cht Silt C-4i C-4n Sh 000 0 0 PDC Long Gauge ENVIROMUL 3.2 5557' 10170'21 Depth in / out 3 Mud Type Lst Type in Minimum Average N/A Chromatograph (ppm) (max) Trip 27 Background 2.727 Comments 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) 86.6/13.4 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units N/A Connection N/A N/A Bit # 2 17.7 10.625 10.00 Tricone 10.00 Size Depth Condition Morning Report Report # 21 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary HTHP Avg Min N/A Tools Full service 24-Nov-2013 12:00 AM Current Pump & Flow Data: 2268 Max 0 (lb/bbl) 3.11 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime Fluids = 9 bbls lost downhole Max Gas = 121 units Avg Gas = 38 units 38 Units* casing. Metal shavings observed and collected at the shakers. Max gas observed was 121 units with an average of 38 units. circulate hole from 5847' MD to 1313' MD - 800 gpm permitted. 3/4" -1.5" cuttings observed over shakers intermittently while in Continue trip out to 5657' MD, pump down closing tags and observed pack offs from 5657' MD to 6223' MD. Backream and Trip out of hole from 7015' MD to 5743' MD. Pump rate was stepped up to 800 gpm and pack off observed at 10300 strokes. . . * 24 hr Recap: 28 Units* Rig up and run 9 5/8" 40# L-80 liner from surface to 4036' MD. Max gas of 36 units with an average of 28 units was recorded. Circulate 2 bottoms up at 800 gpm, trip out of hole from 1313' MD to surface and lay down BHA #4. Change RAMS and test BOPs. Fluids = 13 bbls lost downhole Max Gas = 36 units Avg Gas = 28 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3.63 0 25-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max 1-2-LT-S-X-I-CT-TD @ Mud Data MWD Summary HTHP Avg Min N/A Tools Full service Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: Depth Condition Morning Report Report # 22 Customer: Well: Area: Location: 95% Rig Activity: N/A N/A Bit # 2 17.6 10.625 10.00 Tricone 10.00 Size 86.6/13.4 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units N/A Connection 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) Background 2.728 Comments 150 40 N/A Chromatograph (ppm) (max) Trip 5 Minimum Average 3 Mud Type Lst Hydril Type in PDC Long Gauge ENVIROMUL 3.6 5557' 10170'21 10170' Depth in / out 000 0 0 0 5557' Cht Silt C-4i C-4n Sh 0 Hours C-3 Clyst 0 0' Gas Summary Running 9 5/8" Liner. PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 10.625 1.353 Footage 137.59 4613' 8.49 TFA 5557' 0.942 Tuff Gvl Coal 40.0 Sid 0 0 (current) N/A 0 to 5557' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) AK-AM-900774793 Date: 10170' 10170' 0' Max @ ft Current N/A N/A R.Klepzig / J. Haberther C-1 C-5i 0 C-5n Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 22 N/A Siltst Ss Ratio C-2 36 Casing Summary Size 109.0 Oil/Water 10170' 11.75'' 0 0 cP 53 97 N/A Grade L-80 14.67'' 9.625" L-80 60.0 Weight 00 Set At Depth 0 0 907-670-6636 Unit Phone: Martin Nnaji Report By: 0 Logging Engineers: Bit Type Maximum Cly 0 Todd Wilson / Martin Nnaji (max) (current) Hydril 0 0 Lithology (%) . . * 24 hr Recap: Todd Wilson / Martin Nnaji (max) (current) Hydril 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 0 0 0 907-670-6636 Unit Phone: Martin Nnaji Report By: 00 Set At Depth Grade L-80 14.67'' 9.625" L-80 60.0 Weight Oil/Water 10170' 11.75'' 0 0 cP 41 107 N/A Ratio C-2 89 Casing Summary Size 109.0 0 N/A Siltst Ss Time: SPP (psi) Gallons/stroke Flow In (spm) Depth C-1 C-5i 0 C-5n 10170' 10170' 0' Max @ ft Current N/A N/A R.Klepzig / J. Haberther to 5557' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) AK-AM-900774793 Date: 0 0 (current) N/A 0 Tuff Gvl Coal 40.0 Sid 10.625 1.353 Footage 137.59 4613' 8.49 TFA 5557' 0.942 Running 9 5/8" Liner PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 0 Hours C-3 Clyst 0 0' Gas Summary 0 5557' Cht Silt C-4i C-4n Sh 000 0 0 PDC Long Gauge ENVIROMUL 3.6 5557' 10170'21 10170' Depth in / out 3 Mud Type Lst Hydril Type in Minimum Average N/A Chromatograph (ppm) (max) Trip 11 Background 2.729 Comments 150 40 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) 86.6/13.4 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units N/A Connection N/A N/A Bit # 2 17.6 10.625 10.00 Tricone 10.00 Size Depth Condition Morning Report Report # 23 Customer: Well: Area: Location: 95% Rig Activity: Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: @ Mud Data MWD Summary HTHP Avg Min N/A Tools Full service 26-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max 1-2-LT-S-X-I-CT-TD 0 (lb/bbl) 3.76 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime Fluids = 74 bbls lost downhole Max Gas = 89 units Avg Gas = 17 units 17 Units* an average of 17 units was recorded. circulate was unsuccessful as very tight spot was encountered. Work pipe free and continue to 9462' MD. Max gas of 89 units with Run 9 5/8" liner from 4036' MD to 6486" MD, tight spot noted at 5915' MD. Continue to run in hole to 9258' MD and attempt to . . * 24 hr Recap: 16 Units* placement of cement. No returns observed during cement job. Rig down cement head and laying down drill pipe. Pressure test cement lines to 4000 psi, pump cement and bump plug with 4960 strokes. Pressure up to 3500 psi to confirm ball down drill pipe at 4 bpm with 806 strokes, pressure up to 4000 psi then bled down to 700 psi. Well observed breathing. Trip in the hole with 9 5/8" Liner from 9462' MD to 10152' MD. Attempt to circulate but observed no returns. Set hanger and pump Fluids = 521 bbls lost downhole Max Gas = 20 units Avg Gas = 16 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3.11 0 27-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max 1-2-LT-S-X-I-CT-TD @ Mud Data MWD Summary HTHP Avg Min N/A Tools N/A Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: Depth Condition Morning Report Report # 24 Customer: Well: Area: Location: 95% Rig Activity: N/A N/A Bit # 2 17.6 10.625 10.00 Tricone 10.00 Size 86.6/13.4 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units N/A Connection 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) Background 2.731 Comments 150 40 N/A Chromatograph (ppm) (max) Trip 0 Minimum Average 3 Mud Type Lst Hydril Type in PDC Long Gauge ENVIROMUL 3.8 5557' 10170'22 10170' Depth in / out 000 0 0 0 5557' Cht Silt C-4i C-4n Sh 0 Hours C-3 Clyst 0 0' Gas Summary L/ Down Bumper Sub PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 10.625 1.353 Footage 137.59 4613' 8.49 TFA 5557' 0.942 Tuff Gvl Coal 40.0 Sid 0 0 (current) N/A 0 to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) AK-AM-900774793 Date: 10170' 10170' 0' Max @ ft Current N/A N/A Joe Polya/ J. Haberther C-1 C-5i 0 C-5n Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 0 N/A Siltst Ss Ratio C-2 20 Casing Summary Size 109.0 Oil/Water N/A 11.75'' 0 0 cP 41 109 N/A Grade L-80 10152' 14.67'' 9.625" L-80 60.0 Weight 00 Set At Depth 0 0 907-670-6636 Unit Phone: Martin Nnaji Report By: 0 Logging Engineers: Bit Type Maximum Cly 0 Kerry Garner / Martin Nnaji (max) (current) Hydril 0 0 Lithology (%) . . * 24 hr Recap: N/A Units* begin pressure testing casing to 3500 psi for 30 minutes. to 2 7/8" * 5 VBR's. Rig up MPD and test. Test BOPs. Rig down test equipment and blow down lines. Install wear bushing and for 10 minutes. Nipple up BOP riser, choke and kill lines. Pick up test tools and install test plug. Change out lower rams from 9 5/8" Lay down 3rd party tools. Nipple down BOPs, drilling riser and spool. Install wellheads, nipple up multibowl and test at 5000psi Fluids = 0 bbl lost downhole Max Gas = 0 units Avg Gas = 0 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3.63 0 28-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max 1-2-LT-S-X-I-CT-TD @ Mud Data MWD Summary HTHP Avg Min N/A Tools N/A Rig: ODSN-28 ROP ROP (ft/hr) 3.55 Daily Charges: Total Charges: Nabors 19AC Report For: Depth Condition Morning Report Report # 25 Customer: Well: Area: Location: 95% Rig Activity: N/A N/A Bit # 2 16.6 10.625 10.00 Tricone 10.00 Size 86.7/13.3 WOB Conductor 5549' 158' 100% Gas In Air =10,000 Units N/A Connection 1-1-CT-C1-E-1-NO-BHA RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) Background 2.845 Comments 150 40 N/A Chromatograph (ppm) (max) Trip N/A Minimum Average 3 Mud Type Lst Hydril Type in PDC Long Gauge ENVIROMUL 3.8 5557' 10170'23 10170' Depth in / out 000 0 0 0 5557' Cht Silt C-4i C-4n Sh 0 Hours C-3 Clyst 0 0' Gas Summary Testing Casing PV 24 hr Max Pioneer Natural Resources Oooguruk North Slope Job No.: Avg 10.625 1.353 Footage 137.59 4613' 8.49 TFA 5557' 0.942 Tuff Gvl Coal 40.0 Sid 0 0 (current) N/A 0 to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) AK-AM-900774793 Date: 10170' 10170' 0' Max @ ft Current N/A N/A Joe Polya/ J. Haberther C-1 C-5i 0 C-5n Time: SPP (psi) Gallons/stroke Flow In (spm) Depth N/A N/A Siltst Ss Ratio C-2 N/A Casing Summary Size 109.0 Oil/Water N/A 11.75'' 0 0 cP 41 115 N/A Grade L-80 10152' 14.67'' 9.625" L-80 60.0 Weight 00 Set At Depth 0 0 907-670-6636 Unit Phone: Martin Nnaji Report By: 0 Logging Engineers: Bit Type Maximum Cly 0 Kerry Garner / Martin Nnaji (max) (current) Hydril 0 0 Lithology (%) . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 18000.00 0 29-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 26 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Condition 1-2-LT-S-X-I-CT-TD Bit # 3 7.5 10.625 10.20 PDC Long Gauge 10.00 Size 4 Fluids = 0 bbls lost downhole Max Gas = 380 units Avg Gas = 46 units perfomed to 13.5 ppg using 10.2 ppg LSND mud. Trip out of hole to 10100' MD. Max gas noted was a trip gas of 380 units with well for 20 minutes. Drill ahead from 10170' MD to 10190' MD. Displace well to 10.2 ppg LSND mud. Formation integrity test Trip into hole from 7250' MD to 9952' MD and tag cement. Drill cement shoe and rat hole from 9952' MD to 10170' MD and monitor 5549' 158' 100% Gas In Air =10,000 Units N/A Connection 0 Tools API FL Chromatograph (ppm) 40.0 5557' 10170' WOB Conductor N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average 380 Mud Type Lst Hydril Type 150.0 Tricone LSND 3.0 10170' 10190'23 Depth in / out YP (lb/100ft 2) 9.80 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 60.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Tripping out of Hole PV 4613' 8.5 0.920 Footage 137.59 Joe Polya/J.Haberther Sh Clyst Tuff Gvl Coal cP 12 40.0 Gas Summary 0 0 0 (current) Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: 173.0 Flow In (gpm) Flow In (spm) 10170' 10190' 20' Max @ ft Current 10171'21.0 Date: Time: Pressure test casing shoe to 3500 psi. Pick up BHA #5 and trip into hole from 410' MD to 7250' MD. Service top drive and crown. 46 average of 46 units. Tripping out as at report time. in 0 N/A Minimum Depth C-5n N/A 0.0 C-2 380 SPP (psi) Gallons/stroke TFA Bit Type Depth 1.0 61 L-80 MBT N/A pH 1.353 0 0 0 Siltst 11.75'' 0 0 Units* Casing Summary Lithology (%) 00 0 907-670-6636 Unit Phone: 0 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji Set At Size 109.0 Grade L-80 10152' 14.67'' 9.63'' (max) (current) Hydril 0 0 Cly 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 19500.00 0 30-Nov-2013 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 27 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Condition 1-4-FC-G-E-WT-BHA Bit # 4 7.5 8.5 10.20 Tricone 10.20 Size 5 Fluids = 6 bbls lost downhole Max Gas = 280 units Avg Gas = 6 units and break in Geo-Pilot. Trip into hole from 5606' MD to 9218' MD. Max gas noted was a trip gas of 280 units with average of 6 units. BHA #5, pick up BHA #6 and down load MWD tools. Pulse test, load nukes, function test BOPs. Trip into hole to 5605' MD, fill pipe Circulate 1.5 bottoms up at 620 gpm. Trip out of hole from 9055' MD to 8295' MD. Pump dry job and trip out to 410' MD. Lay down 5549' 158' 100% Gas In Air =10,000 Units N/A Connection 0 Tools API FL Chromatograph (ppm) 8.0 10170' 10190' WOB Conductor N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average 280 Mud Type Lst Hydril Type 60.0 PDC LSND 3.0 10190' 10190'22 Depth in / out YP (lb/100ft 2) 9.80 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 60.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Tripping into Hole PV 20' 8.5 1.108 Footage 10.85 Joe Polya/J.Haberther Sh Clyst Tuff Gvl Coal cP 13 40.0 Gas Summary 0 0 0 (current) Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 10190' 10190' 0' Max @ ft Current N/A N/A Date: Time: Trip out of hole from 10100' MD to 9910' MD, tight spot at 10028' MD. Pump dry job and trip out from 9910' MD to 9055' MD. 6 Continue tripping into hole as at report time. in 0 N/A Minimum Depth C-5n N/A N/A C-2 280 SPP (psi) Gallons/stroke TFA Bit Type Depth 1.0 58 L-80 MBT N/A pH 0.920 0 0 0 Siltst 11.75'' 0 0 Units* Casing Summary Lithology (%) 00 0 907-670-6636 Unit Phone: 0 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji Set At Size 109.0 Grade L-80 10152' 14.67'' 9.63'' (max) (current) Hydril 0 0 Cly 0 . . * 24 hr Recap: (max) (current) Hydril 258 101 Cly 5288 Set At Size 109.0 Grade L-80 10152' 14.67'' 9.63'' 907-670-6636 Unit Phone: 2 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji 3534 1658 11.75'' 0 0 Units* Casing Summary Lithology (%) 11 L-80 MBT 10369' pH 0.920 59 21 9 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 2.0 58 C-5n 10358' 0.0 C-2 87 was recorded. Begin picking up BHA #7 at time of report. in 10 10300'Minimum Depth Time: Trip into hole from 9218' MD to 10073' MD, cut and slip line, install RCD element and trip inot hole to 10190' MD. Drill ahead from 42 BHA. Lay down BHA #6, pull nukes and download MWD tools and inspect bit. Max gas of 87 units with average gas of 42 units 10190' 10369' 179' Max @ ft Current 10271'17.6 Date: Avg to 10190' Yesterday's Depth: Current Depth: 24 Hour Progress: 53.0 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 52 9 (current) Joe Polya/J.Haberther Sh Clyst Tuff Gvl Coal cP 14 20' 8.5 1.108 Footage 10.85 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Downloading MWD Tools PV 24 hr Max 60.0 Weight 166 Hours C-3 027 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.40 029 0 60.0 PDC LSND 3.6 10190' 10369'29 10369' Depth in / out Mud Type Lst Hydril Type Average 00Background (max) Trip 12.75 12.99 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service API FL Chromatograph (ppm) 8.0 10170' 10190' WOB Conductor 100% Gas In Air =10,000 Units 57 Connection 142 5 Fluids = 9 bbls lost downhole Max Gas = 87 units Avg Gas = 42 units MWD tool while circulating. Close reamer and begin tripping out of the hole to 10073' MD. Pump dry job and trip out of the hole to clamp on encoder while pulling out of hole to 10075' MD. Trip into hole to 1358' MD and drill ahead to 10369' MD. Trouble shoot 10190' MD to 10326' MD, activate reamer, cut ledge and 15k against shoe. Drill ahead from 10326' MD to 10358' MD. Change out 5549' 158' Condition 1-4-FC-G-E-WT-BHA Bit # 4 8.0 8.5 10.20 Tricone 10.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 13.26 Nabors 19AC Report For: Morning Report Report # 28 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth 1-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 84 Chlorides mg/l 20000.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 20000.00 431 2-Dec-2013 12:00 AM Current Pump & Flow Data: 4295 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 29 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 13.28 Nabors 19AC Report For: Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 8.5 8.5 10.20 PDC 10.25 Size 6 Fluids = 0 bbls lost downhole Max Gas = 1513 units Avg Gas = 229 units traces of siltstone also observed . Max gas recorded is 1513 units at 10829' MD with average of 229 units. Drilling ahead at report drive and grease blocks. Drill ahead from 10738' MD to 10994' MD. Cuttings has been predominantly shale, sandstone and 10369' MD, activate reamer and pull test against shoe with 15k to confirm open. Drill from 10369' MD to 10738' MD, service top 5549' 158' 100% Gas In Air =10,000 Units 381 Connection 1337 Tools Full Service API FL Chromatograph (ppm) 15.0 10190' 10369' WOB Conductor 12.80 13.00 Avg Min Comments RPM ECD (ppg) ml/30min 227 Background (max) Trip Average 0 Mud Type Lst 30 Hydril Type 100.0 PDC LSND 3.6 10369' 10914'34 Depth in / out YP (lb/100ft 2) 9.70 43 158 37 24 86 Cement Cht Silt C-4i C-4n 24 hr Max 60.0 Weight 915 Hours C-3 65 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Drill Ahead PV 179' 8.5 1.108 Footage 10.24 Joe Polya/J.Haberther Sh Clyst Tuff Gvl Coal cP 16 40.0 Gas Summary 16 396 82 (current) Avg to 10369' Yesterday's Depth: Current Depth: 24 Hour Progress: 98.0 Flow In (gpm) Flow In (spm) 10369' 10994' 625' Max @ ft Current 10859'42.0 Date: Time: Pick up BHA #7 to 659' MD, load nukes and pulse test. Trip into hole to 10072' MD and install RCD element. Trip into hole to 229 time. in 18 10699'Minimum Depth C-5n 10829' 75.0 C-2 1513 SPP (psi) Gallons/stroke TFA Bit Type Depth 5.0 62 L-80 MBT pH 1.108 207 160 32 Siltst 11.75'' 751 211 Units* Casing Summary Lithology (%) 59 5 21929 9195 907-670-6636 Unit Phone: 91 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji Set At Size 109.0 Grade L-80 10152' 14.67'' 9.63'' (max) (current) Hydril 3921 399 Cly 133254 . . * 24 hr Recap: (max) (current) Hydril 5641 567 Cly 215466 Set At Size 109.0 Grade L-80 10152' 14.67'' 9.63'' 907-670-6636 Unit Phone: 151 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji 22980 15458 11.75'' 747 210 Units* Casing Summary Lithology (%) 81 L-80 MBT pH 1.108 240 242 35 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 7.5 53 C-5n 11195' 66.0 C-2 2623 in 20 11452'Minimum Depth Time: Drill from 10994' MD to 11369' MD, hit hard spot. Circulate 27 bbls Sapp and WALL-NUT pill downhole. Spot pill with 9 bbls on 288 10994' 11499' 505' Max @ ft Current 11124'21.0 Date: Avg to 10369' Yesterday's Depth: Current Depth: 24 Hour Progress: 186.0 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 34 579 137 (current) Joe Polya/J.Haberther Sh Clyst Tuff Gvl Coal cP 19 179' 8.5 1.108 Footage 10.24 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Drill Ahead PV 24 hr Max 60.0 Weight 993 Hours C-3 95 46 103 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.90 89 238 72 100.0 PDC LSND 3.0 10369' 11423'35 Depth in / out Mud Type Lst 5 Hydril Type Average N/A 302 Background (max) Trip 12.71 13.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service API FL Chromatograph (ppm) 15.0 10190' 10369' WOB Conductor 100% Gas In Air =10,000 Units 379 Connection 1986 6 Fluids = 0 bbls lost downhole Max Gas = 2623 units Avg Gas = 288 units dark grey in color, fissile with traces of pyrite. Drilling ahead at time of report. to 11499' MD. Max gas was 2623 units at 11195' MD with average of 288 units. Samples collected has been shale, grey to annulus with bit 1' off bottom. Drill from 11369' MD to 11404' MD, service top drive and greese blocks. Drill ahead from 11404' MD 5549' 158' Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 8.9 8.5 10.20 PDC 10.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 13.30 Nabors 19AC Report For: Morning Report Report # 30 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth 3-Dec-2013 12:00 AM Current Pump & Flow Data: 4435 Max 505 Chlorides mg/l 22000.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 20000.00 128 4-Dec-2013 12:00 AM Current Pump & Flow Data: 4323 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 31 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 13.26 Nabors 19AC Report For: Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 9.5 8.5 10.20 PDC 10.20 Size 6 Fluids = 0 bbls lost downhole Max Gas = 637 units Avg Gas = 117 units Drilling ahead at report time. an average of 117 units. Cuttings has been dark to light grey fissile shale with relative abundance of pyrite and traces of glauconite. clean suction screens on pumps. Drill ahead from 11689' MD to 12544' MD. Max gas recorded was 637 units from 12093' MD with 5549' 158' 100% Gas In Air =10,000 Units 190 Connection 226 Tools Full Service API FL Chromatograph (ppm) 15.0 10190' 10369' WOB Conductor 12.73 13.00 Avg Min Comments RPM ECD (ppg) ml/30min 79 Background (max) Trip Average N/A Mud Type Lst Hydril Type 100.0 PDC LSND 2.4 10369' 12419'29 Depth in / out YP (lb/100ft 2) 10.60 31 62 22 042 Cement Cht Silt C-4i C-4n 24 hr Max 60.0 Weight 276 Hours C-3 100 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Drilling Ahead PV 179' 8.5 1.108 Footage 10.24 Joe Polya/J.Haberther Sh Clyst Tuff Gvl Coal cP 16 40.0 Gas Summary 0 76 27 (current) Avg to 10369' Yesterday's Depth: Current Depth: 24 Hour Progress: 158.0 Flow In (gpm) Flow In (spm) 11499' 12544' 1045' Max @ ft Current 12525'43.0 Date: Time: Drill ahead from 11499' MD to 11594' MD. Change out RCD element. Drill from 11594' MD to 11689' MD, service top drive and 117 in 14 12409'Minimum Depth C-5n 12093' 39.0 C-2 637 SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 53 L-80 MBT pH 1.108 86 32 16 Siltst 11.75'' 721 203 Units* Casing Summary Lithology (%) 23 7943 4574 907-670-6636 Unit Phone: 32 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji Set At Size 109.0 Grade L-80 10152' 14.67'' 9.63'' (max) (current) Hydril 609 172 Cly 22864 . . * 24 hr Recap: (max) (current) Hydril 740 145 Cly 16742 Set At Size 109.0 Grade L-80 10152' 14.67'' 9.63'' 907-670-6636 Unit Phone: 57 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji 9199 3421 11.75'' 672 189 Units* Casing Summary Lithology (%) 41 L-80 MBT pH 1.108 78 67 14 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 12.5 54 C-5n 12670' 0.0 C-2 227 in 10 12599'Minimum Depth Time: Drill from 12544' MD to 12780' MD. Circulate 50 bbls hi-vis sweep downhole. Circulate from 12728' MD to 12639' MD, close 115 unconsolidated with traces of pyrite. 12544' 12780' 236' Max @ ft Current 12736'19.0 Date: Avg to 10369' Yesterday's Depth: Current Depth: 24 Hour Progress: 141.0 Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 166 53 (current) Joe Polya/J.Haberther Sh Clyst Tuff Gvl Coal cP 16 179' 8.5 1.108 Footage 10.24 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Tripping into Hole PV 24 hr Max 60.0 Weight 413 Hours C-3 15 038 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.40 32 104 30 100.0 PDC LSND 3.6 10369' 12780'29 Depth in / out Mud Type Lst 85 Hydril Type Average 106 0Background (max) Trip 12.75 13.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service API FL Chromatograph (ppm) 15.0 10190' 10369' WOB Conductor 100% Gas In Air =10,000 Units 168 Connection 385 6 Fluids = 9 bbls lost downhole Max Gas = 227 units Avg Gas = 115 units Noted a significant change in lithology at about 12650' MD from shale to sandstone. Cuttings is fine grained, well sorted, BOPs. Trip into hole from 10072' MD to 12743' MD. Recorded a max gas of 227 units at 12670' MD with an average of 115 units. reamer. Trip out of the hole from 12639' MD to 10072' MD, pump out at 2 bpm. Service top drive, grease blocks and function test 5549' 158' Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 9.0 8.5 10.20 PDC 10.25 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 13.16 Nabors 19AC Report For: Morning Report Report # 32 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth 5-Dec-2013 12:00 AM Current Pump & Flow Data: 4427 Max 228 Chlorides mg/l 21000.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) Hydril 153 0 Cly 1075 Set At Size 109.0 Grade L-80 10152' 14.67'' 9.63'' 907-670-6636 Unit Phone: 327.2 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji 32 0 11.75'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 MBT pH 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 1.0 98 C-5n N/A N/A C-2 283 in 0 N/A Minimum Depth Time: up while conditioning mud system. Pump 35 bbl 12ppg hi-vis spacer and chase with 12 ppg LSND mud and displace well. 17 Max gas recorded was a trip gas of 283 units with an average of 17 units. Tripping out at a depth of 2663' MD at report time. 12780' 12780' 0' Max @ ft Current N/A N/A Date: Avg to 10369' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 40.0 Gas Summary 0 0 24.6 (current) Joe Polya/J.Haberther Sh Clyst Tuff Gvl Coal cP 28 179' 8.5 1.108 Footage 10.24 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Tripping out of Hole PV 24 hr Max 60.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.40 31091 42.1 100.0 PDC LSND 3.0 10369' 12780'38 Depth in / out Mud Type Lst Hydril Type Average 283 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service API FL Chromatograph (ppm) 15.0 10190' 10369' WOB Conductor 100% Gas In Air =10,000 Units N/A Connection 42 6 Fluids = 0 bbls lost downhole Max Gas = 283 units Avg Gas = 17 units 13.9 ppg LSND mud. Observe well for 15 minutes. Install RCD trip nipple and begin tripping out of the hole. Spot 50 bbl 13.9 ppg hi-vis pill at 4 bpm. Trip out of the hole to 4941' MD. Service top drive and grease blocks. Displace to a Trip out of the hole from 12780' MD to 9027' MD. Circulate at 9027' MD.Trip out of the hole from 9027' MD to 5390' MD. 5549' 158' Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 21.5 8.5 13.00 PDC 13.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 33 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth 6-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 48000.00 Circulate and condition from 12734' MD to 12780' MD. Pump 30 bbl hi-vis sweep followed by 2 bottoms Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Trip out of the hole from 2663' MD to 658' MD. Lay down BHA from 684' MD to 134' MD, unload nukes and Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 24500.00 0 7-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 2-2-CT-A-X-I-NO-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 34 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 9.3 8.5 11.70 PDC 10.20 Size 6 Fluids = 0 bbls lost downhole Max Gas = 0 units Avg Gas = 0 units Running 7" casing at time of report. Test BOPs and rams with 7". Lay down test tools. Rig up to Tesco tools to run casing. Run casing from surface to 686' MD. retrieve wear ring and pull to surface. Found large piece of casing shoe obstructing path. Service rig. Make up 7" test tools. 10152' 5549' 100% Gas In Air =10,000 Units N/A Connection 0 Tools N/A API FL Chromatograph (ppm) 35 15.0 10190' 10369' WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min N/A Background (max) Trip Average 0 Mud Type Lst Hydril Type 150 100.0 PDC LSND 3.6 10369' 12780'25 12780' Depth in / out YP (lb/100ft 2) 10.20 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Running 7" Casing PV 179' 8.5 1.108 Footage 83.46 2411' 10.24 Joe Polya/J.Haberther Sh Clyst Tuff Gvl Coal cP 15 26.0 Gas Summary 0 0 0 (current) Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 12780' 12780' 0' Max @ ft Current N/A N/A Date: Time: download MWD tools. Lay down BHA to surface. Attempt to pull wear bushing but unsuccessful. Utilize Weatherford reamer to N/A in N/A N/A Minimum Depth C-5n N/A N/A C-2 N/.A SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 66 L-80 MBT N/A pH 1.108 0 0 0 Siltst 9.63'' 0 0 Units* Casing Summary Lithology (%) 00 0 907-670-6636 Unit Phone: 0 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji Set At Size 60.0 L-80 Grade L-80 11.75'' 7.00'' (max) (current) Hydril 0 0 Cly 0 . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji 0 0 9.63'' 47 13 Units* Casing Summary Lithology (%) 0 L-80 MBT N/A pH 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 10.0 54 C-5n N/A N/A C-2 N/.A in N/A N/A Minimum Depth Time: joint, land casing at 12762' MD. Rig down tesco tools. Break circulation with minimal returns. Circulating at time of report. N/A 12780' 12780' 0' Max @ ft Current N/A N/A Date: Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) Joe Polya/J.Haberther Sh Clyst Tuff Gvl Coal cP 15 179' 8.5 1.108 Footage 83.46 2411' 10.24 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Circulating PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.60 000 150 100.0 PDC LSND 3.9 10369' 12780'26 12780' Depth in / out Mud Type Lst Hydril Type Average 0N/A Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools N/A API FL Chromatograph (ppm) 35 15.0 10190' 10369' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 6 Fluids = 223 bbls lost downhole Max Gas = 0 units Avg Gas = 0 units 10152' 5549' Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 8.9 8.5 12.65 PDC 10.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 35 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 2-2-CT-A-X-I-NO-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 8-Dec-2013 12:00 AM Current Pump & Flow Data: 9 Max 0 Chlorides mg/l 22000.00 Continue running into hole with 7" 26# L-80 casing from 686' MD to 12721' MD. Make up hanger and landing Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Continue circulating at casing, stage up to 6 bpm with 100% returns achieved. Pressure test cement lines to Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 19000.00 0 9-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 2-2-CT-A-X-I-NO-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 36 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 9.0 8.5 10.30 PDC 10.20 Size 6 Fluids = 179 bbls lost downhole (103 bbls bullheaded) Max Gas = 72 units Avg Gas = 7 units gas recorded was 72 units with an average of 7 units. Laying down drill pipe at time of report. with 5600 strokes. Hold 3500 psi for 5 minutes. Monitor well, no flow. Rig down and blow cement lines. While circulating, max 10152' 5549' 100% Gas In Air =10,000 Units N/A Connection 0 Tools N/A API FL Chromatograph (ppm) 35 15.0 10190' 10369' WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average 0 Mud Type Lst Hydril Type 150 100.0 PDC LSND 6.4 10369' 12780'20 12780' Depth in / out YP (lb/100ft 2) 9.30 01063 160.7 00 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Laying Down Drill Pipe PV 179' 8.5 1.108 Footage 83.46 2411' 10.24 Joe Polya/Tony Deranger Sh Clyst Tuff Gvl Coal cP 14 26.0 Gas Summary 0 0 58.5 (current) Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 12780' 12780' 0' Max @ ft Current N/A N/A Date: Time: 4000 psi, pump 50 bbls 12.5 ppg dual spacer followed by 110 bbls 15.8 ppg cement. Bump the plug with 10.2 ppg LSND mud 7 in 0 N/A Minimum Depth C-5n N/A N/A C-2 72 SPP (psi) Gallons/stroke TFA Bit Type Depth 7.5 50 L-80 MBT N/A pH 1.108 0 0 0 Siltst 9.63'' 0 0 Units* Casing Summary Lithology (%) 011 0 907-670-6636 Unit Phone: 0 Martin Nnaji Maximum Report By: Logging Engineers: Kerry Garner/Martin Nnaji Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 16 0 Cly 154 . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Kerry Garner/Makenzie Jorgensen 0 0 9.63'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 MBT N/A pH 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 7.5 51 C-5n N/A N/A C-2 0 in 0 N/A Minimum Depth Time: Continued to lay down drill pipe and pumped 10.2 ppg mud down outer annulus until break over. Serviced top drive and rigged up 0 12780' 12780' 0' Max @ ft Current N/A N/A Date: Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) Joe Polya/Tony Deranger Sh Clyst Tuff Gvl Coal cP 14 179' 8.5 1.108 Footage 83.46 2411' 10.24 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Loading shed with 4" pipe PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.30 000 150 100.0 PDC LSND 6.2 10369' 12780'20 12780' Depth in / out Mud Type Lst Hydril Type Average 00Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools N/A API FL Chromatograph (ppm) 35 15.0 10190' 10369' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 6 Fluids = 33 bbls lost downhole (during bullheading) Max Gas = 0 units Avg Gas = 0 units line. Serviced top drive and greased blocks. Cleaned floor and rig. to test BOPs. Tested BOPs, laid down test tools. Pressure tested casing to 3500 psi for 30 min. Cut and slipped drilling 10152' 5549' Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 10.0 8.5 10.20 PDC 10.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 37 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 2-2-CT-A-X-I-NO-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 10-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 20000 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Kerry Garner/Makenzie Jorgensen 0 0 9.63'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 MBT N/A pH 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 7.0 49 C-5n N/A N/A C-2 0 in 0 N/A Minimum Depth Time: Tripped out from 7680' to surface and laid down johny wacker. Picked up BHA #8 for clean out run. Ran in hole to 228' and 0 12780' 12780' 0' Max @ ft Current N/A N/A Date: Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) Joe Polya/Tony Deranger Sh Clyst Tuff Gvl Coal cP 12 179' 8.5 1.108 Footage 83.46 2411' 10.24 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Tripping in PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.30 000 150 100.0 PDC LSND 6.0 10369' 12780'20 12780' Depth in / out Mud Type Lst Hydril Type Average N/A 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools N/A API FL Chromatograph (ppm) 35 15.0 10190' 10369' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 6 Fluids = 0 bbls lost downhole Max Gas = 0 units Avg Gas = 0 units conducted shallow pulse test at 220 gpm. Continue to run in hole to 4874'. 10152' 5549' Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 10.0 8.5 10.20 PDC 10.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 38 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 2-2-CT-A-X-I-NO-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 11-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 20000 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Kerry Garner/Makenzie Jorgensen 0 0 9.63'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 MBT 12780' pH 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 7.5 54 C-5n N/A N/A C-2 22 in 0 N/A Minimum Depth Time: Ran in hole from 4874' to 12600' and tag cement. Drill out cement from 12600' to shoe at 8 12780' 12780' 0' Max @ ft Current N/A N/A Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) Joe Polya/Tony Deranger Sh Clyst Tuff Gvl Coal cP 12 179' 8.5 1.108 Footage 83.46 2411' 10.24 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Trip out/MAD Pass PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.80 000 150 100.0 PDC LSND 6.2 10369' 12780'20 12780' Depth in / out Mud Type Lst Hydril Type Average N/A 4Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Bat sonic API FL Chromatograph (ppm) 35 15.0 10190' 10369' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 6 Fluids = 0 bbls lost downhole Max Gas = 22 units Avg Gas = 8 units 12761', at 250 gpm. MAD Pass Logging from 12780' to 10971' at time of report. 10152' 5549' Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 10.1 8.5 10.20 PDC 10.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 39 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 2-2-CT-A-X-I-NO-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 12-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 19000 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Log from 10971' MD to 10152' MD. Trip out to surface, lay down BHA #8. Pick up BHA #9, run into the hole to 138' MD Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 20000 0 13-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 2-2-CT-A-X-I-NO-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 40 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 10.0 8.5 10.20 PDC 10.20 Size 6 Fluids = 0 bbls lost downhole Max Gas = 0 units Avg Gas = 0 units 10152' 5549' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Full Services API FL Chromatograph (ppm) 35 15.0 10190' 10369' WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average N/A Mud Type Lst Hydril Type 150 100.0 PDC LSND 36557.0 10369' 12780'20 12780' Depth in / out YP (lb/100ft 2) 10.10 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-900774793 Tripping in PV 179' 8.5 1.108 Footage 83.46 2411' 10.24 Joe Polya/Tony Deranger Sh Clyst Tuff Gvl Coal cP 11 26.0 Gas Summary 0 0 0 (current) Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 12780' 12780' 0' Max @ ft Current N/A N/A Date: Time: and conduct shallow pulse test at 200 gpm. Run in hole to 1598' MD, circulate and function test BOPs. Trip in to 10746' MD. 0 in 0 N/A Minimum Depth C-5n N/A N/A C-2 0 SPP (psi) Gallons/stroke TFA Bit Type Depth 7.5 50 L-80 MBT pH 1.108 0 0 0 Siltst 9.63'' 206 58 Units* Casing Summary Lithology (%) 00 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 0 0 Cly 0 . . * 24 hr Recap: (max) (current) Hydril 3835 0 Cly 117650 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 45 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen 5 25234 54 9.63'' 203 57 Units* Casing Summary Lithology (%) 25 L-80 Oil/Water ASG 1.108 0 122 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 86.5/11.0 51 C-5n 13155' 90.0 C-2 1663 unconsolidated, fine grained sandstone. in 8 12781'Minimum Depth Time: to 7.5 ppg mineral oil based mud. Spacer to surface on time at 4941 strokes; took returns to active at 5782 strokes, 258 Max connection gas was 500 units with an average of 300 units. Max trip gas was 92 units. Geology has been predominantly clear, 12780' 13440' 660' Max @ ft Current 13130'77.6 Date: Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: 106.0 Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 228 44 (current) Joe Polya/Tony Deranger Sh Clyst Tuff Gvl Coal cP 7 179' 8.5 1.108 Footage 83.46 2411' 10.24 Ss Ratio C-1 C-5i AK-AM-900774793 Drilling PV 24 hr Max 40.0 Weight 691 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 2.373 249 4 150 100.0 PDC ENVIROMUL 8.4 10369' 13158'12 12780' Depth in / out Mud Type Lst 95 Hydril Type Average 92 350 Background (max) Trip 8.98 9.90 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Services HTHP Chromatograph (ppm) 35 15.0 10190' 10369' WOB Hydril 100% Gas In Air =10,000 Units 500 Connection 1138 6 Fluids = 12 bbls lost downhole (during trip in) Max Gas = 1663 units Avg Gas = 258 units While drilling, max gas was 1663 units from 13155' (lagged from pore pressure test) with an average gas of 258 units. Drill to 13351' at 250 gpm and perform pore pressure test. Drill to 13440' at 200 gpm. dumped spacer and interface to CCU. Drill to 12800' at 250 gpm and perform FIT. 10152' 5549' Condition 0-0-NO-A-X-I-NO-DTF Bit # 5 2.2 8.5 7.50 PDC 7.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 12.32 Nabors 19AC Report For: Morning Report Report # 41 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 2-2-CT-A-X-I-NO-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 14-Dec-2013 12:00 AM Current Pump & Flow Data: 642 Max 222 Lime (lb/bbl) 2.59 Trip in hole from 10746' to 12668'. Cut and slip drill line. Displace well at 12780' Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 4.53 380 15-Dec-2013 12:00 AM Current Pump & Flow Data: 3315 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 42 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 10.23 Nabors 19AC Report For: Condition 2-2-CT-A-X-I-NO-TD Bit # 6 2.7 8.5 7.55 PDC 7.55 Size 7 Fluids = 0 bbls lost downhole Max Gas = 598 units Avg Gas = 235 units Max connection gas was 408 units with an average of 306 units. Geology has been predominantly clear, While drilling, max gas was 598 units from 13570 with an average gas of 235 units. drive. Drill to 14595' at 240 gpm. 10152' 5549' 100% Gas In Air =10,000 Units 408 Connection 402 Tools Full Services HTHP Chromatograph (ppm) 35 10369' 12780' WOB Hydril 9.28 9.91 Avg Min Comments RPM ECD (ppg) ml/30min 140 Background (max) Trip Average N/A Mud Type Lst 95 Hydril Type 150 PDC ENVIROMUL 8.2 12780' 14412'12 Depth in / out YP (lb/100ft 2) 2.280 21 113 24 267 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 924 Hours C-3 Ss Ratio C-1 C-5i AK-AM-900774793 Drilling Ahead PV 2411' 6.125 0.389 Footage 83.46 Joe Polya/Tony Deranger Sh Clyst Tuff Gvl Coal cP 10 26.0 Gas Summary 19 114 24 (current) Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: 238.7 Flow In (gpm) Flow In (spm) 13440' 14595' 1155' Max @ ft Current 13633'86.7 Date: Time: Drill from 13440' to 14222' at 230 gpm. Troubleshoot MWD tool connectivity. Drill to 14499' at 240 gpm. Service top 235 unconsolidated, fine grained sandstone. in 38 14230'Minimum Depth C-5n 13570' 80.0 C-2 598 SPP (psi) Gallons/stroke TFA Bit Type Depth 88.7/11.3 51 L-80 Oil/Water ASG 1.108 141 55 27 Siltst 9.63'' 220 62 Units* Casing Summary Lithology (%) 53 5 23538 2356 907-670-6636 Unit Phone: 24 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 1076 197 Cly 35887 . . * 24 hr Recap: (max) (current) Hydril 1197 178 Cly 28001 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 38 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen 12786 1885 9.63'' 217 61 Units* Casing Summary Lithology (%) 45 L-80 Oil/Water ASG 1.108 147 65 29 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 89.6/10.4 50 C-5n 15311' 50.0 C-2 365 in 22 14641'Minimum Depth Time: Drill from 14595' to 15462' 220 at gpm, conduct BOP drill, and service top drive. Continue drilling ahead to 144 unconsolidated, well sorted, fine grained sandstone. 14595' 15644' 1049' Max @ ft Current 14639'80.8 Date: Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: 165.9 Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 139 34 (current) Joe Polya/Tony Deranger Sh Clyst Tuff Gvl Coal cP 10 2411' 6.125 0.389 Footage 83.46 Ss Ratio C-1 C-5i AK-AM-900774793 Drilling ahead PV 24 hr Max 40.0 Weight 625 Hours C-3 071 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 2.421 20 100 22 150 PDC ENVIROMUL 8.0 12780' 15470'11 Depth in / out Mud Type Lst 100 Hydril Type Average N/A 180 Background (max) Trip 9.59 9.97 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Services HTHP Chromatograph (ppm) 35 10369' 12780' WOB Hydril 100% Gas In Air =10,000 Units 443 Connection 478 7 Fluids = 0 bbls lost downhole Max Gas = 365 units Avg Gas = 144 units Max connection gas was 443 units with an average of 219 units. Geology has been predominantly clear, While drilling, max gas was 365 units from 15311' with an average gas of 144 units. 15560' at 220 gpm. Troubleshoot centrifuge, reduced efficiency, and ship MOBM to RSC for centrifuging. 10152' 5549' Condition 2-2-CT-A-X-I-NO-TD Bit # 6 3.8 8.5 7.70 PDC 7.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 10.18 Nabors 19AC Report For: Morning Report Report # 43 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth 16-Dec-2013 12:00 AM Current Pump & Flow Data: 3079 Max 298 Lime (lb/bbl) 4.86 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3.88 435 17-Dec-2013 12:00 AM Current Pump & Flow Data: 3470 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 44 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 10.34 Nabors 19AC Report For: Condition 2-2-CT-A-X-I-NO-TD Bit # 6 4.8 8.5 7.80 PDC 7.80 Size 7 Fluids = 0 bbls lost downhole Max Gas = 526 units Avg Gas = 249 units Max connection gas was 422 units with an average of 286 units. Geology has been predominantly clear, While drilling, max gas was 526 units from 15974' MD with an average gas of 249 units. Transferring MOBM to RSC for centrifuging. 10152' 5549' 100% Gas In Air =10,000 Units 422 Connection 486 Tools Full Services HTHP Chromatograph (ppm) 35 10369' 12780' WOB Hydril 9.73 10.09 Avg Min Comments RPM ECD (ppg) ml/30min 140 Background (max) Trip Average N/A Mud Type Lst 95 Hydril Type 150 PDC ENVIROMUL 8.0 12780' 16626'11 Depth in / out YP (lb/100ft 2) 2.341 33 133 32 29 86 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 1034 Hours C-3 Ss Ratio C-1 C-5i AK-AM-900774793 Drilling ahead PV 2411' 6.125 0.389 Footage 83.46 Joe Polya/Tony Deranger Sh Clyst Tuff Gvl Coal cP 9 26.0 Gas Summary 5 141 34 (current) Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: 227.1 Flow In (gpm) Flow In (spm) 15644' 16863' 1219' Max @ ft Current 16707'81.0 Date: Time: Drill from 15650' MD to 16862' MD at 230 gpm. Mud weight increasing approximately 0.1 ppg per 1,000 feet. 249 unconsolidated, well sorted, fine grained sandstone. in 46 16049'Minimum Depth C-5n 15974' 86.0 C-2 526 SPP (psi) Gallons/stroke TFA Bit Type Depth 89.5/10.5 48 L-80 Oil/Water ASG 1.108 209 64 36 Siltst 9.63'' 231 65 Units* Casing Summary Lithology (%) 60 23480 4032 907-670-6636 Unit Phone: 35 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 1203 329 Cly 26471 5 . . * 24 hr Recap: Drill from 16862' MD to 17640' MD at 235 gpm. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3.63 430 18-Dec-2013 12:00 AM Current Pump & Flow Data: 3412 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 45 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 10.48 Nabors 19AC Report For: Condition 2-2-CT-A-X-I-NO-TD Bit # 6 5.2 8.5 7.90 PDC 7.80 Size 7 Fluids = 0 bbls lost downhole Max Gas = 693 units Avg Gas = 316 units unconsolidated, well sorted, fine grained sandstone with a trace of siderite. Max connection gas was 564 units with an average of 346 units. Geology has been predominantly clear, 10152' 5549' 100% Gas In Air =10,000 Units 564 Connection 685 Tools Full Services HTHP Chromatograph (ppm) 35 10369' 12780' WOB Hydril 9.74 10.15 Avg Min Comments RPM ECD (ppg) ml/30min 104 Background (max) Trip Average N/A Mud Type Lst 95 Hydril Type 150 PDC ENVIROMUL 7.8 12780' 17445'13 Depth in / out YP (lb/100ft 2) 2.239 32 129 31 038 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 1066 Hours C-3 Ss Ratio C-1 C-5i AK-AM-900774793 Drilling Ahead PV 2411' 6.125 0.389 Footage 83.46 Joe Polya/Tony Deranger Sh Clyst Tuff Gvl Coal cP 9 26.0 Gas Summary 0 187 46 (current) Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: 179.2 Flow In (gpm) Flow In (spm) 16863' 17640' 777' Max @ ft Current 17625'74.9 Date: Time: While drilling, max gas was 693 units from 16998' MD with an average gas of 316 units. 316 in 50 17569'Minimum Depth C-5n 16998' 86.3 C-2 693 SPP (psi) Gallons/stroke TFA Bit Type Depth 89.9/10.1 50 L-80 Oil/Water ASG 1.108 61 86 14 Siltst 9.63'' 235 66 Units* Casing Summary Lithology (%) 57 5 28382 2098 907-670-6636 Unit Phone: 48 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 1887 75 Cly 70130 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 4.66 550 19-Dec-2013 12:00 AM Current Pump & Flow Data: 3600 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 46 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 10.47 Nabors 19AC Report For: Condition 2-2-CT-A-X-I-NO-TD Bit # 6 4.7 8.5 7.90 PDC 7.90 Size 7 Fluids = 0 bbls lost downhole Max Gas = 972 units Avg Gas = 357 units Max connection gas was 458 units with an average of 279 units. Geology has been predominantly clear, While drilling, max gas was 972 units from 18316' MD with an average gas of 357 units. Take directional surveys every 5' from 18715' MD to 18655' MD. 10152' 5549' 100% Gas In Air =10,000 Units 458 Connection 767 Tools Full Services HTHP Chromatograph (ppm) 35 10369' 12780' WOB Hydril 9.95 10.22 Avg Min Comments RPM ECD (ppg) ml/30min 250 Background (max) Trip Average N/A Mud Type Lst 95 Hydril Type 150 PDC ENVIROMUL 8.0 12780' 18554'12 Depth in / out YP (lb/100ft 2) 2.599 38 157 36 043 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 1356 Hours C-3 Ss Ratio C-1 C-5i AK-AM-900774793 Drilling ahead PV 2411' 6.125 0.389 Footage 83.46 R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 9 26.0 Gas Summary 12 198 46 (current) Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: 261.1 Flow In (gpm) Flow In (spm) 17640' 18721' 1081' Max @ ft Current 17717'83.8 Date: Time: Drill from 17640' MD to 18449' MD at 230 gpm. Change RCD element. Drill from 18449' MD to 18660' MD at 235 gpm. 357 unconsolidated, well sorted, fine grained sandstone in 48 17642'Minimum Depth C-5n 18316' 67.0 C-2 972 SPP (psi) Gallons/stroke TFA Bit Type Depth 88.4/11.6 51 L-80 Oil/Water ASG 1.108 82 94 18 Siltst 9.63'' 235 66 Units* Casing Summary Lithology (%) 71 5 33602 2489 907-670-6636 Unit Phone: 53 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 2277 117 Cly 97433 . . * 24 hr Recap: (max) (current) Hydril 1355 21 Cly 40458 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 46 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen 75 18677 694 9.63'' 235 66 Units* Casing Summary Lithology (%) 45 L-80 Oil/Water 19329' ASG 1.108 15 71 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 88.4/11.6 52 C-5n 18764' 29.0 C-2 422 soft siltstone. in 30 19320'Minimum Depth Time: Drill from 18721' to 19307' at 235 gpm. Service rig and function test BOPs. Drill to TD at 19329' at 235 gpm, encountered 213 unconsolidated, well sorted, fine grained sandstone. Bottoms up sample was predominantly grey to brown, well sorted, 18721' 19329' 608' Max @ ft Current 18792'64.9 Date: Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: 127.9 Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 159 43 (current) R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 12 2411' 6.125 0.389 Footage 83.46 Ss Ratio C-1 C-5i AK-AM-900774793 Backreaming PV 24 hr Max 40.0 Weight 751 Hours C-3 013 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 2.855 27 103 25 150 PDC ENVIROMUL 7.6 12780' 19219'12 Depth in / out Mud Type Lst 25 Hydril Type Average N/A 50 Background (max) Trip 9.79 10.27 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Services HTHP Chromatograph (ppm) 35 10369' 12780' WOB Hydril 100% Gas In Air =10,000 Units 400 Connection 523 7 Fluids = 0 bbls lost downhole Max Gas = 422 units Avg Gas = 213 units Max connection gas was 400 units with an average of 294 units. Geology has been predominantly clear, While drilling, max gas was 422 units from 18764' MD with an average gas of 213 units. 16,000 ft-lb torque. Backream to 18833' at 175 gpm. 10152' 5549' Condition 2-2-CT-A-X-I-NO-TD Bit # 6 4.6 8.5 8.00 PDC 8.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 10.62 Nabors 19AC Report For: Morning Report Report # 47 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth 20-Dec-2013 12:00 AM Current Pump & Flow Data: 3692 Max 316 Lime (lb/bbl) 3.17 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 3.11 0 21-Dec-2013 12:00 AM Current Pump & Flow Data: 2829 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 48 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 10.39 Nabors 19AC Report For: Condition 2-2-CT-A-X-I-NO-TD Bit # 6 5.2 8.5 8.00 PDC 8.00 Size 7 Fluids = 68 bbls lost downhole Max Gas = 60 units Avg Gas = 21 units two bottoms up at 180 gpm. partial pack-off and torque to 15,000 ft-lb. Work pipe and ream from 13151' to 12668' at 84 gpm. Circulate at shoe Trip and pump out to 15557' at 175 gpm. Backream from 15557' to 13100' at 175 gpm. Experience 10152' 5549' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Full Services HTHP Chromatograph (ppm) 35 10369' 12780' WOB Hydril 9.50 9.99 Avg Min Comments RPM ECD (ppg) ml/30min 36 Background (max) Trip Average N/A Mud Type Lst Hydril Type 150 PDC ENVIROMUL 8.0 12780' 19329'12 Depth in / out YP (lb/100ft 2) 2.660 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-900774793 Circulating at shoe PV 2411' 6.125 0.389 Footage 83.46 R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 9 26.0 Gas Summary 0 0 0 (current) Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 19329' 19329' 0' Max @ ft Current N/A N/A Date: Time: Trip and pump out from 18833' to 17003' at 175 gpm. Circulate two bottoms up while tripping out to 16513' at 225 gpm. 21 While circulating, max gas was 60 units with an average of 21 units. No significant trip gas. No geology samples collected. in 0 N/A Minimum Depth C-5n N/A N/A C-2 60 SPP (psi) Gallons/stroke TFA Bit Type Depth 88.4/11.6 52 L-80 Oil/Water 19329' ASG 1.108 0 0 0 Siltst 9.63'' 185 52 Units* Casing Summary Lithology (%) 00 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 0 0 Cly 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 5.83 0 22-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 49 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 10.77 Nabors 19AC Report For: Condition 2-2-CT-A-X-I-NO-TD Bit # 6 11.7 8.5 9.90 PDC 9.90 Size 7 Fluids = 0 bbls lost downhole Max Gas = 2307 units Avg Gas = 39 units Max gas was trip gas of 2307 units. While circulating bottoms up, max gas was 377 units with an average of 39 units. Monitor well, remove RCD. Trip out from 19211' to 12572' while pumping 2 barrels per minute. with 9.9 ppg kill weight mineral oil based mud. 9.9 ppg mud returns to surface at 8250 strokes. 10152' 5549' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Full Services HTHP Chromatograph (ppm) 35 10369' 12780' WOB Hydril 9.68 10.26 Avg Min Comments RPM ECD (ppg) ml/30min 10 Background (max) Trip Average 2307 Mud Type Lst Hydril Type 150 PDC ENVIROMUL 8.8 12780' 19329'16 Depth in / out YP (lb/100ft 2) 3.598 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-900774793 Tripping out PV 2411' 6.125 0.389 Footage 83.46 R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 24 26.0 Gas Summary 0 0 0 (current) Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 19329' 19329' 0' Max @ ft Current N/A N/A Date: Time: Trip in hole from shoe to 19211', circulate 2.5 bottoms up at 225 gpm. Displace 8.0 ppg mineral oil based mud 39 No geology samples collected. in 0 N/A Minimum Depth C-5n N/A N/A C-2 2307 SPP (psi) Gallons/stroke TFA Bit Type Depth 88.6/11.4 58 L-80 Oil/Water 19329' ASG 1.108 0 0 0 Siltst 9.63'' 0 0 Units* Casing Summary Lithology (%) 00 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 0 0 Cly 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 5.70 0 23-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 50 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Condition 2-2-CT-A-X-I-NO-TD Bit # 6 11.7 8.5 9.90 PDC 9.90 Size 7 Fluids = 13 bbls lost downhole Max Gas = 0 units Avg Gas = 0 units 10152' 5549' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Full Services HTHP Chromatograph (ppm) 35 10369' 12780' WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average N/A Mud Type Lst Hydril Type 150 PDC ENVIROMUL 8.0 12780' 19329'15 Depth in / out YP (lb/100ft 2) 3.604 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-900774793 Laying down BHA PV 2411' 6.125 0.389 Footage 83.46 R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 18 26.0 Gas Summary 0 0 0 (current) Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 19329' 19329' 0' Max @ ft Current N/A N/A Date: Time: Trip out from 12572' to surface, lay down BHA, and download nukes. No significant gas detected. 0 in 0 N/A Minimum Depth C-5n N/A N/A C-2 0 SPP (psi) Gallons/stroke TFA Bit Type Depth 88.6/11.4 77 L-80 Oil/Water 19329' ASG 1.108 0 0 0 Siltst 9.63'' 0 0 Units* Casing Summary Lithology (%) 00 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 0 0 Cly 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 4.92 0 24-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 1-0-BT-N-X-I-ER-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 51 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Condition 2-2-CT-A-X-I-NO-TD Bit # 6 11.7 8.5 9.90 PDC 9.90 Size 7 Fluids = 6 bbls gained while monitoring well Max Gas = 0 units Avg Gas = 0 units water and shut in for 30 min, no pressure increase. Open well and observe flow of MOBM. Monitor well 1900 to blinds, pull test joint, drain stack. Monitor well, no pressure increase. Open choke and take returns to pits. Drain Remove RCD head and rig up to test choke manifold. Rig up to test BOP's. Observe well flowing at IA. Shut in 10152' 5549' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Full Services HTHP Chromatograph (ppm) 2 35 10369' 12780' WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average N/A Mud Type Lst Hydril Type 76 150 PDC ENVIROMUL 9.2 12780' 19329'18 19329' Depth in / out YP (lb/100ft 2) 3.593 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-900774793 Monitoring well PV 2411' 6.125 0.389 Footage 93.03 6549' 83.46 R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 18 26.0 Gas Summary 0 0 0 (current) Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 19329' 19329' 0' Max @ ft Current N/A N/A Date: Time: Lay down BHA from 138' to surface. Clear floor, service top drive. Pick up 48 joints of drill pipe, flush and rack back. 0 2200 hrs and saw 4.6 bbls increase. Shut in well and monitor pressure. Open well and gain 1.4 bbls. Total gain of 6 bbls from 1900 hrs to 0000 hrs. No significant gas detected. in 0 N/A Minimum Depth C-5n N/A N/A C-2 0 SPP (psi) Gallons/stroke TFA Bit Type Depth 87.5/12.5 87 L-80 Oil/Water 19329' ASG 1.108 0 0 0 Siltst 9.63'' 0 0 Units* Casing Summary Lithology (%) 00 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 0 0 Cly 0 . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen 0 0 9.63'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 19329' ASG 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 87.6 80 C-5n N/A N/A C-2 191 to 4485'. While circulating max gas was 191 units with an average of 18 units. in 0 N/A Minimum Depth Time: Monitor well for flow. Observe approximately 4 bbl/hr gain. Shut in well and monitor psi. Observe 15 psi increase. Pick up BHA #9 18 bpm. Observe 30 bbl loss during circulation. Open bag and monitor well for 15 min. Trip out of the hole from 12762' 19329' 19329' 0' Max @ ft Current N/A N/A Date: Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 17 2411' 6.125 0.389 Footage 93.03 6549' 83.46 Ss Ratio C-1 C-5i AK-AM-900774793 Tripping out of the hole PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 3.830 000 76 150 PDC ENVIROMUL 9.4 12780' 19329'19 19329' Depth in / out Mud Type Lst Hydril Type Average N/A 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Services HTHP Chromatograph (ppm) 2 35 10369' 12780' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 7 Fluids = 0 bbls lost or gained Max Gas = 191 units Avg Gas = 18 units taking returns through choke manifold back to pits. Displace using step rate up to 2 Trip out of the hole from 13100' to 12762'. Close annular and displace 9.9 ppg to 10 ppg MOBM to 1500'. Trip in the hole from 1500' to 13100'. Circulate two bottoms up using step rate method 1/2 bpm. 10152' 5549' Condition 2-2-CT-A-X-I-NO-TD Bit # 6 11.1 8.5 10.00 PDC 10.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 52 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 1-0-BT-N-X-I-ER-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 25-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Lime (lb/bbl) 3.88 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen 0 0 9.63'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 19329' ASG 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 85.2/14.8 89 C-5n N/A N/A C-2 0 in 0 N/A Minimum Depth Time: Trip out of the hole from 4485' to 1500'. Lay down BHA from 1500' to surface. Remove wear ring and install test plug, 0 19329' 19329' 0' Max @ ft Current N/A N/A Date: Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 24 2411' 6.125 0.389 Footage 93.03 6549' 83.46 Ss Ratio C-1 C-5i AK-AM-900774793 Running 4.5" Liner PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 3.681 000 76 150 PDC ENVIROMUL 9.0 12780' 19329'20 19329' Depth in / out Mud Type Lst Hydril Type Average N/A 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Services HTHP Chromatograph (ppm) 2 35 10369' 12780' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 7 Fluids = 0 bbls lost downhole Max Gas = 0 units Avg Gas = 0 units from surface to 2787'. No returns first 20 joints and 1 bbl at joint number 30. Continue running 4.5" liner at report time. Pick up test tools and test BOP's. Lay down test equipment. Rig up to run 4.5" 12.6 pound C-110 production liner. Run 10152' 5549' Condition 2-2-CT-A-X-I-NO-TD Bit # 6 11.6 8.5 10.00 PDC 10.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 53 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 1-0-BT-N-X-I-ER-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 26-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Lime (lb/bbl) 3.63 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen 0 0 9.63'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water 19329' ASG 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 87.5/12.5 81 C-5n N/A N/A C-2 32 in 0 N/A Minimum Depth Time: Continue to run 4.5" 12.6 pound C-110 liner from 2787' to 6887'. Make up bumper sub, mag, and install stabbing guide. 2 19329' 19329' 0' Max @ ft Current N/A N/A Date: Avg to 12780' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 17 2411' 6.125 0.389 Footage 93.03 6549' 83.46 Ss Ratio C-1 C-5i AK-AM-900774793 Running 4.5" Liner PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 3.699 000 76 150 PDC ENVIROMUL 9.4 12780' 19329'19 19329' Depth in / out Mud Type Lst Hydril Type Average N/A 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Services HTHP Chromatograph (ppm) 2 35 10369' 12780' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 7 Fluids = 0 bbls lost downhole Max Gas = 32 units Avg Gas = 2 units drill pipe. While circulating max gas was 32 units with an average of 2 units. Circulate one liner volume plus 25 bbls, using step rate method up to 2 bpm. Run liner from 6887' to 11,123' on 4" 10152' 5549' Condition 2-2-CT-A-X-I-NO-TD Bit # 6 11.6 8.5 10.00 PDC 10.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 54 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 1-0-BT-N-X-I-ER-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 27-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Lime (lb/bbl) 3.37 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen 0 0 9.63'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water ASG 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 87.5/12.5 70 C-5n N/A N/A C-2 52 in 0 N/A Minimum Depth Time: Continue to run 4.5" 12.6 pound C-110 liner from 11123' to 12747'. Circulate bottoms up using step up method to 2 13 While circulating max gas was 52 units with an average ot 13 units. 19329' 19329' 0' Max @ ft Current N/A N/A Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 18 2411' 6.125 0.389 Footage 93.03 6549' 83.46 Ss Ratio C-1 C-5i AK-AM-900774793 Setting Packer PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 3.690 000 76 150 PDC ENVIROMUL 9.0 12780' 19329'20 19329' Depth in / out Mud Type Lst Hydril Type Average N/A 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools HTHP Chromatograph (ppm) 2 35 10369' 12780' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 7 Fluids = 0 bbls lost downhole Max Gas = 52 units Avg Gas = 13 units Set hanger per Baker rep with 1098 strokes at 12445'. Experience tight spot at 18615'. Circulate drill pipe volume; stage up to 3 bpm. Drop 1.5" ball and pump at 3 bpm. bpm. Run liner from 12747' to 15263'. Experience tight spot at 15180'. Repair top drive. Run liner from 15263' to 19210'. 10152' 5549' Condition 2-2-CT-A-X-I-NO-TD Bit # 6 11.7 8.5 10.00 PDC 10.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 55 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 1-0-BT-N-X-I-ER-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 28-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Lime (lb/bbl) 3.88 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen 0 0 9.63'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water ASG 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth C-5n N/A N/A C-2 4141 in 0 N/A Minimum Depth Time: Set packer and test to 3500 psi and chart for 10 min. Displace well from 10 ppg MOBM to 10.1 NaCl/NaBr Brine. Cut and slip drill 536 19329' 19329' 0' Max @ ft Current N/A N/A Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 2411' 6.125 0.389 Footage 93.03 6549' 83.46 Ss Ratio C-1 C-5i AK-AM-900774793 Running 4.5" Tubing PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 000 76 150 PDC Brine 12780' 19329' 19329' Depth in / out Mud Type Lst Hydril Type Average 4141 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools HTHP Chromatograph (ppm) 2 35 10369' 12780' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 7 Fluids = 8 bbls lost downhole (during trip out) Max Gas = 4141 units Avg Gas = 536 units assembly. Trip in the hole from 144' to 457'. While circulating max gas was trip gas of 4141 units with an average gas of 536 units. up Tesco tool and trip in the hole with 4.5" 12.6 pound C-110 tubing from surface to 144'. Make up index mule shoe seal line. Trip out of the hole and lay down drill pipe from 12390 to the BHA. Lay down BHA and remove wear bushing. Pick 10152' 5549' Condition 2-2-CT-A-X-I-NO-TD Bit # 6 8.5 10.10 PDC 10.10 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 56 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 1-0-BT-N-X-I-ER-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 29-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Lime (lb/bbl) Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen 0 0 9.63'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water ASG 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth C-5n N/A N/A C-2 0 in 0 N/A Minimum Depth Time: Continue to run 4.5" 12.6 pound C-110 liner from 457' to 4749'. Spliced damaged I-Wire then lay down tools. 0 19329' 19329' 0' Max @ ft Current N/A N/A Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 2411' 6.125 0.389 Footage 93.03 6549' 83.46 Ss Ratio C-1 C-5i AK-AM-900774793 Running 4.5" Tubing PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 000 76 150 PDC Brine 12780' 19329' 19329' Depth in / out Mud Type Lst Hydril Type Average N/A 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools HTHP Chromatograph (ppm) 2 35 10369' 12780' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 7 Fluids = 0 bbls lost downhole Max Gas = 0 units Avg Gas = 0 units Continue running in the hole from 10190' to 10701'. Run in the hole with 4.5" liner from 4749' to 10190'. Test control line to 5000 psi for 10 min. 10152' 5549' Condition 2-2-CT-A-X-I-NO-TD Bit # 6 8.5 10.10 PDC 10.10 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 57 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 1-0-BT-N-X-I-ER-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 30-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Lime (lb/bbl) Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 0 31-Dec-2013 12:00 AM Current Pump & Flow Data: 0 Max 1-0-BT-N-X-I-ER-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth Morning Report Report # 58 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Condition 2-2-CT-A-X-I-NO-TD Bit # 6 8.5 10.10 PDC 10.10 Size 7 Fluids = 0 bbls lost downhole Max Gas = 0 units Avg Gas = 0 units 10152' 5549' 100% Gas In Air =10,000 Units N/A Connection 0 Tools HTHP Chromatograph (ppm) 2 35 10369' 12780' WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average N/A Mud Type Lst Hydril Type 76 150 PDC Brine 12780' 19329' 19329' Depth in / out YP (lb/100ft 2) 000 00 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-900774793 Rig Maintenance PV 2411' 6.125 0.389 Footage 93.03 6549' 83.46 R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 26.0 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 19329' 19329' 0' Max @ ft Current N/A N/A Date: Time: Run 4.5" 12.6 pound C-110 tubing from 10701' to 12445'. Conduct well completion activities. 0 in 0 N/A Minimum Depth C-5n N/A N/A C-2 0 SPP (psi) Gallons/stroke TFA Bit Type Depth L-80 Oil/Water ASG 1.108 0 0 0 Siltst 9.63'' 0 0 Units* Casing Summary Lithology (%) 00 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' (max) (current) Hydril 0 0 Cly 0 . . * 24 hr Recap: (max) (current) Hydril 0 0 Cly 0 Set At Size 60.0 L-80 Grade L-80 12762' 11.75'' 7.00'' 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Maximum Report By: Logging Engineers: Todd Wilson/Makenzie Jorgensen 0 0 9.63'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 Oil/Water ASG 1.108 0 0 0 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth C-5n N/A N/A C-2 0 in 0 N/A Minimum Depth Time: Conduct well completion activities. Nipple down BOPs. Test frac tree, freeze protect well, and begin laying down 4" drill pipe. 0 19329' 19329' 0' Max @ ft Current N/A N/A Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 26.0 Gas Summary 0 0 0 (current) R. Klepzig/J. Haberther Sh Clyst Tuff Gvl Coal cP 2411' 6.125 0.389 Footage 93.03 6549' 83.46 Ss Ratio C-1 C-5i AK-AM-900774793 Laying down 4" drill pipe PV 24 hr Max 40.0 Weight 0 Hours C-3 00 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 000 76 150 PDC Brine 12780' 19329' 19329' Depth in / out Mud Type Lst Hydril Type Average N/A 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools HTHP Chromatograph (ppm) 2 35 10369' 12780' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 7 Fluids = 0 bbls lost downhole Max Gas = 0 units Avg Gas = 0 units 10152' 5549' Condition 2-2-CT-A-X-I-NO-TD Bit # 6 8.5 10.10 PDC 10.10 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 59 Customer: Well: Area: Location: Rig: ODSN-28 Pioneer Natural Resources Oooguruk North Slope 1-0-BT-N-X-I-ER-TD ROP ROP (ft/hr) 3.55 @ Mud Data Depth 1-Jan-2014 12:00 AM Current Pump & Flow Data: 0 Max 0 Lime (lb/bbl) Density (ppg) out (sec/qt) Viscosity Cor Solids % WELL INFORMATION Created On : Jan 10 2014 Customer :Pioneer Natural Resources Well Name :ODSN-28 Job Number :AK-XX-0900774793 Rig Name :Nabors 19AC Field Name :Oooguruk Country :USA Survey Report DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 42.70 0.00 0.00 42.70 0.00 N 0.00 E 0.00 0.00 144.00 0.53 29.05 144.00 0.41 N 0.23 E 0.44 0.52 166.00 0.75 85.91 166.00 0.51 N 0.42 E 0.57 2.91 261.00 3.57 130.54 260.92 1.37 S 3.29 E -0.83 3.24 356.00 6.16 133.58 355.57 6.81 S 9.23 E -5.26 2.74 447.00 9.29 123.84 445.74 14.27 S 18.87 E -11.11 3.72 541.00 12.10 111.67 538.11 22.13 S 34.33 E -16.44 3.82 637.00 13.42 103.37 631.75 28.42 S 54.52 E -19.46 2.35 731.00 16.41 92.54 722.59 31.54 S 78.41 E -18.77 4.34 826.00 18.65 80.77 813.20 29.69 S 106.82 E -12.46 4.40 869.58 18.60 74.78 854.50 26.75 S 120.41 E -7.41 4.39 963.07 17.39 71.02 943.42 18.29 S 148.01 E 5.30 1.79 1058.72 19.12 67.40 1,034.25 7.62 S 175.99 E 20.25 2.16 1152.91 23.30 66.03 1,122.04 5.88 N 207.27 E 38.52 4.47 1248.35 23.63 63.90 1,209.60 21.96 N 241.69 E 59.83 0.95 1344.09 27.40 62.46 1,295.98 40.59 N 278.46 E 84.03 3.99 1438.02 30.17 62.61 1,378.30 61.45 N 318.59 E 110.96 2.95 1534.36 34.72 62.24 1,459.59 85.38 N 364.38 E 141.81 4.73 1631.54 37.05 62.23 1,538.32 111.91 N 414.79 E 175.97 2.40 1720.15 40.62 60.56 1,607.33 138.53 N 463.54 E 209.95 4.20 1820.10 45.03 60.91 1,680.61 171.73 N 522.80 E 252.09 4.41 1914.58 48.82 59.82 1,745.13 205.87 N 582.77 E 295.26 4.10 2009.49 50.66 59.76 1,806.47 242.31 N 645.35 E 341.12 1.94 2102.74 54.30 58.88 1,863.25 280.05 N 708.94 E 388.42 3.98 2197.98 56.36 56.97 1,917.43 321.65 N 775.29 E 439.97 2.72 2292.47 60.95 56.30 1,966.58 366.03 N 842.67 E 494.43 4.90 2388.44 63.76 55.08 2,011.10 413.95 N 912.87 E 552.83 3.14 2478.79 62.44 54.45 2,051.98 460.44 N 978.69 E 609.12 1.59 2575.73 60.97 54.91 2,097.92 509.79 N 1,048.32 E 668.84 1.57 2669.09 62.10 56.14 2,142.42 556.24 N 1,115.98 E 725.39 1.68 2764.66 59.41 57.01 2,189.11 602.18 N 1,185.58 E 781.73 2.93 2861.03 58.61 57.19 2,238.73 647.05 N 1,254.93 E 836.98 0.85 INSITE V8.0.0 Page 1Job No:AK-XX-0900774793 Well Name:ODSN-28 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2954.24 59.42 54.32 2,286.73 692.02 N 1,320.98 E 891.81 2.78 3049.93 62.15 54.54 2,333.42 740.59 N 1,388.90 E 950.49 2.86 3144.85 63.31 56.29 2,376.92 788.47 N 1,458.36 E 1008.74 2.05 3239.88 61.43 57.06 2,420.98 834.73 N 1,528.71 E 1065.52 2.11 3335.69 64.95 58.76 2,464.18 880.14 N 1,601.15 E 1121.79 4.00 3429.55 64.27 59.67 2,504.43 923.53 N 1,673.99 E 1176.14 1.14 3524.98 64.50 60.19 2,545.68 966.65 N 1,748.46 E 1230.47 0.55 3619.98 63.78 61.17 2,587.12 1,008.51 N 1,822.99 E 1283.57 1.20 3715.39 63.48 61.08 2,629.50 1,049.79 N 1,897.85 E 1336.14 0.32 3810.21 64.76 59.29 2,670.90 1,092.21 N 1,971.86 E 1389.71 2.17 3904.86 65.14 59.24 2,710.97 1,136.03 N 2,045.56 E 1444.61 0.40 4000.82 66.53 58.87 2,750.27 1,181.05 N 2,120.65 E 1500.92 1.49 4096.11 66.20 56.40 2,788.47 1,227.77 N 2,194.37 E 1558.69 2.40 4190.77 64.62 56.50 2,827.86 1,275.34 N 2,266.10 E 1616.98 1.68 4285.93 61.50 57.77 2,870.97 1,321.38 N 2,337.34 E 1673.69 3.48 4382.06 62.50 58.30 2,916.10 1,366.31 N 2,409.35 E 1729.42 1.15 4476.82 63.81 58.66 2,958.89 1,410.51 N 2,481.42 E 1784.44 1.43 4572.11 62.87 57.51 3,001.65 1,455.53 N 2,553.71 E 1840.30 1.46 4667.21 63.25 57.47 3,044.73 1,501.09 N 2,625.20 E 1896.58 0.40 4762.03 62.08 56.19 3,088.28 1,547.18 N 2,695.71 E 1953.21 1.72 4857.07 61.47 56.72 3,133.23 1,593.45 N 2,765.50 E 2009.91 0.81 4952.91 61.78 57.10 3,178.78 1,639.48 N 2,836.15 E 2066.52 0.48 5045.42 61.61 57.77 3,222.65 1,683.32 N 2,904.79 E 2120.64 0.66 5140.64 62.49 57.88 3,267.28 1,728.11 N 2,975.98 E 2176.11 0.93 5237.31 63.33 58.02 3,311.30 1,773.78 N 3,048.93 E 2232.72 0.88 5331.89 62.17 58.50 3,354.60 1,818.02 N 3,120.44 E 2287.68 1.31 5426.11 63.08 58.75 3,397.92 1,861.58 N 3,191.87 E 2341.97 0.99 5508.18 63.80 58.77 3,434.62 1,899.65 N 3,254.63 E 2389.47 0.88 5558.11 64.39 55.61 3,456.44 1,923.98 N 3,292.37 E 2419.45 5.82 5653.18 63.93 58.28 3,497.89 1,970.65 N 3,364.08 E 2476.85 2.57 5746.81 62.76 58.66 3,539.89 2,014.41 N 3,435.40 E 2531.32 1.30 5842.84 62.69 57.85 3,583.90 2,059.32 N 3,507.98 E 2587.12 0.75 5938.43 62.37 57.14 3,627.99 2,104.89 N 3,579.51 E 2643.41 0.74 6033.93 62.02 58.06 3,672.54 2,150.15 N 3,650.83 E 2699.36 0.93 6127.16 62.31 59.46 3,716.07 2,192.91 N 3,721.32 E 2752.71 1.36 6221.98 62.51 59.83 3,759.99 2,235.38 N 3,793.83 E 2806.08 0.41 6318.33 62.64 61.73 3,804.37 2,277.12 N 3,868.47 E 2859.09 1.76 6412.86 62.77 62.82 3,847.72 2,316.20 N 3,942.82 E 2909.41 1.03 6507.91 63.08 60.87 3,890.99 2,356.14 N 4,017.44 E 2960.62 1.86 6602.94 63.07 60.86 3,934.02 2,397.39 N 4,091.45 E 3013.03 0.01 6697.95 63.13 59.58 3,977.01 2,439.47 N 4,164.99 E 3066.19 1.20 6793.17 63.12 58.25 4,020.06 2,483.32 N 4,237.72 E 3120.97 1.25 6888.29 63.00 57.59 4,063.15 2,528.36 N 4,309.57 E 3176.78 0.63 6983.26 62.71 57.93 4,106.49 2,573.44 N 4,381.05 E 3232.58 0.44 7078.48 62.57 57.18 4,150.26 2,618.81 N 4,452.41 E 3288.64 0.71 INSITE V8.0.0 Page 2Job No:AK-XX-0900774793 Well Name:ODSN-28 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 7173.18 62.44 56.74 4,193.97 2,664.61 N 4,522.83 E 3344.98 0.43 7266.95 62.42 56.54 4,237.37 2,710.32 N 4,592.26 E 3401.07 0.19 7362.35 62.17 56.60 4,281.72 2,756.85 N 4,662.75 E 3458.15 0.26 7457.02 62.24 57.75 4,325.86 2,802.25 N 4,733.13 E 3514.08 1.08 7552.70 62.38 56.96 4,370.32 2,847.95 N 4,804.47 E 3570.47 0.75 7646.98 62.65 57.42 4,413.83 2,893.27 N 4,874.77 E 3626.32 0.52 7741.81 62.73 57.02 4,457.33 2,938.89 N 4,945.60 E 3682.54 0.38 7837.31 62.87 55.74 4,500.99 2,985.92 N 5,016.34 E 3740.15 1.20 7933.93 62.95 56.57 4,544.98 3,033.83 N 5,087.78 E 3798.73 0.77 8028.01 63.27 56.34 4,587.53 3,080.20 N 5,157.72 E 3855.56 0.41 8122.18 63.40 57.72 4,629.79 3,125.99 N 5,228.31 E 3911.92 1.32 8218.06 63.47 55.54 4,672.67 3,173.16 N 5,299.93 E 3969.79 2.03 8311.57 63.30 56.39 4,714.56 3,219.95 N 5,369.20 E 4026.93 0.83 8406.95 63.27 57.30 4,757.45 3,266.55 N 5,440.53 E 4084.20 0.85 8501.96 63.35 57.11 4,800.12 3,312.52 N 5,511.89 E 4140.86 0.20 8597.00 63.05 57.46 4,842.97 3,358.37 N 5,583.26 E 4197.40 0.46 8692.43 62.92 57.88 4,886.31 3,403.84 N 5,655.10 E 4253.64 0.42 8787.54 62.83 58.76 4,929.68 3,448.29 N 5,727.14 E 4308.90 0.83 8883.31 62.86 57.29 4,973.39 3,493.42 N 5,799.42 E 4364.87 1.37 8978.15 62.55 58.37 5,016.89 3,538.29 N 5,870.76 E 4420.44 1.06 9073.73 62.23 58.24 5,061.19 3,582.79 N 5,942.82 E 4475.75 0.36 9168.46 62.39 58.21 5,105.21 3,626.95 N 6,014.12 E 4530.61 0.17 9263.28 62.22 58.99 5,149.28 3,670.70 N 6,085.78 E 4585.12 0.75 9359.16 62.67 59.27 5,193.63 3,714.31 N 6,158.75 E 4639.70 0.53 9453.94 63.13 60.19 5,236.81 3,756.84 N 6,231.62 E 4693.20 0.99 9548.78 63.14 59.44 5,279.66 3,799.38 N 6,304.75 E 4746.75 0.71 9644.53 62.86 59.87 5,323.13 3,842.48 N 6,378.38 E 4800.93 0.50 9740.25 62.72 59.00 5,366.90 3,885.77 N 6,451.68 E 4855.24 0.82 9834.46 62.59 58.10 5,410.19 3,929.43 N 6,523.07 E 4909.62 0.86 9929.75 62.79 55.38 5,453.91 3,975.86 N 6,593.85 E 4966.64 2.55 10024.35 62.72 53.42 5,497.22 4,024.81 N 6,662.23 E 5025.77 1.84 10118.10 62.56 49.48 5,540.32 4,076.69 N 6,727.33 E 5087.27 3.74 10135.09 62.48 49.24 5,548.16 4,086.51 N 6,738.77 E 5098.77 1.33 10186.81 62.59 47.67 5,572.02 4,116.94 N 6,773.11 E 5134.24 2.70 10230.39 62.31 45.68 5,592.18 4,143.45 N 6,801.22 E 5164.85 4.10 10282.00 61.72 42.91 5,616.40 4,176.06 N 6,833.05 E 5202.08 4.87 10327.07 61.19 40.32 5,637.94 4,205.65 N 6,859.33 E 5235.45 5.18 10376.12 62.02 38.83 5,661.26 4,238.91 N 6,886.82 E 5272.63 3.17 10419.68 62.36 37.18 5,681.58 4,269.27 N 6,910.54 E 5306.35 3.44 10470.62 61.84 34.15 5,705.43 4,305.84 N 6,936.79 E 5346.60 5.36 10515.76 61.14 31.76 5,726.98 4,339.12 N 6,958.37 E 5382.87 4.90 10565.11 61.31 29.96 5,750.73 4,376.24 N 6,980.55 E 5423.03 3.22 10611.76 61.62 27.60 5,773.02 4,412.16 N 7,000.28 E 5461.61 4.49 10661.71 62.20 25.92 5,796.54 4,451.51 N 7,020.12 E 5503.60 3.18 10706.63 62.86 24.00 5,817.26 4,487.64 N 7,036.94 E 5541.93 4.07 INSITE V8.0.0 Page 3Job No:AK-XX-0900774793 Well Name:ODSN-28 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10756.67 63.08 22.10 5,840.01 4,528.65 N 7,054.38 E 5585.18 3.41 10802.02 62.94 19.79 5,860.59 4,566.39 N 7,068.83 E 5624.72 4.55 10851.48 63.34 17.85 5,882.94 4,608.15 N 7,083.06 E 5668.21 3.59 10897.31 63.17 15.99 5,903.57 4,647.31 N 7,094.97 E 5708.76 3.64 10990.67 63.33 13.03 5,945.59 4,728.00 N 7,115.86 E 5791.74 2.84 11086.03 65.06 8.18 5,987.13 4,812.35 N 7,131.62 E 5877.52 4.92 11181.39 66.34 3.65 6,026.39 4,898.77 N 7,140.56 E 5964.26 4.53 11276.50 67.45 359.70 6,063.72 4,986.19 N 7,143.10 E 6050.98 3.99 11373.01 68.55 356.14 6,099.89 5,075.60 N 7,139.84 E 6138.76 3.61 11467.35 69.56 352.76 6,133.61 5,163.27 N 7,131.32 E 6223.99 3.51 11561.98 71.38 349.09 6,165.25 5,251.32 N 7,117.24 E 6308.71 4.13 11655.82 73.08 345.31 6,193.90 5,338.43 N 7,097.43 E 6391.60 4.24 11751.29 75.00 341.05 6,220.16 5,426.26 N 7,070.86 E 6474.14 4.74 11846.91 75.32 336.58 6,244.67 5,512.43 N 7,037.46 E 6553.96 4.53 11941.00 76.90 330.80 6,267.27 5,594.25 N 6,996.99 E 6628.36 6.20 12037.28 79.50 325.98 6,286.97 5,674.47 N 6,947.60 E 6699.79 5.59 12132.12 81.12 322.59 6,302.94 5,750.36 N 6,893.03 E 6766.11 3.92 12227.80 82.87 321.25 6,316.26 5,824.93 N 6,834.59 E 6830.53 2.29 12322.87 85.16 320.44 6,326.17 5,898.25 N 6,774.89 E 6893.50 2.56 12417.58 85.53 320.50 6,333.85 5,971.05 N 6,714.81 E 6955.92 0.40 12511.06 85.53 320.85 6,341.13 6,043.15 N 6,655.75 E 7017.79 0.37 12606.17 85.72 320.44 6,348.38 6,116.48 N 6,595.61 E 7080.71 0.47 12701.63 86.28 320.10 6,355.05 6,189.71 N 6,534.75 E 7143.42 0.69 12749.74 87.64 319.14 6,357.60 6,226.30 N 6,503.63 E 7174.64 3.47 12773.00 88.48 319.17 6,358.38 6,243.89 N 6,488.42 E 7189.61 3.61 12869.95 89.47 320.49 6,360.11 6,317.96 N 6,425.89 E 7252.88 1.70 12966.50 88.54 317.58 6,361.79 6,390.84 N 6,362.62 E 7314.87 3.16 13062.81 88.85 317.84 6,363.97 6,462.08 N 6,297.82 E 7374.98 0.42 13158.57 89.29 316.90 6,365.53 6,532.52 N 6,232.98 E 7434.31 1.08 13255.39 89.66 318.21 6,366.42 6,603.96 N 6,167.64 E 7494.54 1.41 13351.75 89.84 317.45 6,366.84 6,675.38 N 6,102.95 E 7554.86 0.81 13448.75 89.88 318.20 6,367.08 6,747.26 N 6,037.83 E 7615.56 0.77 13544.95 89.57 316.17 6,367.55 6,817.82 N 5,972.45 E 7674.92 2.13 13641.08 90.40 317.83 6,367.58 6,888.12 N 5,906.89 E 7734.00 1.93 13737.01 90.77 318.36 6,366.60 6,959.52 N 5,842.82 E 7794.39 0.67 13831.84 89.35 317.58 6,366.50 7,029.95 N 5,779.34 E 7853.92 1.71 13930.56 89.53 316.04 6,367.47 7,101.93 N 5,711.77 E 7914.33 1.57 14026.93 90.89 317.52 6,367.11 7,172.15 N 5,645.79 E 7973.25 2.09 14123.21 91.57 318.11 6,365.04 7,243.47 N 5,581.15 E 8033.48 0.93 14219.30 91.36 317.84 6,362.59 7,314.83 N 5,516.84 E 8093.80 0.36 14316.91 90.95 316.25 6,360.62 7,386.25 N 5,450.34 E 8153.83 1.68 14412.45 91.20 316.50 6,358.82 7,455.40 N 5,384.44 E 8211.71 0.37 14507.74 91.39 316.13 6,356.67 7,524.29 N 5,318.64 E 8269.35 0.43 14605.41 90.89 314.66 6,354.73 7,593.81 N 5,250.07 E 8327.18 1.59 14700.78 90.09 315.26 6,353.91 7,661.20 N 5,182.59 E 8383.08 1.05 INSITE V8.0.0 Page 4Job No:AK-XX-0900774793 Well Name:ODSN-28 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14796.96 88.67 315.00 6,354.96 7,729.36 N 5,114.74 E 8439.67 1.50 14893.14 89.66 315.82 6,356.36 7,797.84 N 5,047.23 E 8496.64 1.33 14990.39 90.03 316.77 6,356.63 7,868.14 N 4,980.03 E 8555.46 1.05 15085.78 89.59 317.21 6,356.94 7,937.90 N 4,914.96 E 8614.07 0.65 15181.10 90.86 320.02 6,356.56 8,009.40 N 4,851.96 E 8674.74 3.23 15279.73 90.21 319.21 6,355.63 8,084.52 N 4,788.06 E 8738.84 1.05 15374.65 90.15 321.82 6,355.33 8,157.77 N 4,727.71 E 8801.64 2.75 15470.42 89.97 319.92 6,355.23 8,232.06 N 4,667.27 E 8865.46 1.99 15565.80 90.40 319.45 6,354.93 8,304.79 N 4,605.56 E 8927.54 0.67 15661.86 90.71 319.99 6,354.01 8,378.07 N 4,543.45 E 8990.10 0.65 15760.65 89.97 320.19 6,353.43 8,453.84 N 4,480.08 E 9054.92 0.78 15854.61 89.66 319.27 6,353.74 8,525.53 N 4,419.34 E 9116.13 1.03 15951.17 90.09 318.55 6,353.95 8,598.31 N 4,355.88 E 9177.98 0.87 16047.43 90.93 317.92 6,353.10 8,670.11 N 4,291.76 E 9238.76 1.09 16143.68 91.08 316.77 6,351.42 8,740.88 N 4,226.56 E 9298.35 1.20 16241.35 91.51 316.08 6,349.21 8,811.62 N 4,159.25 E 9357.59 0.83 16336.99 91.82 315.94 6,346.43 8,880.40 N 4,092.85 E 9415.03 0.35 16433.71 91.39 317.59 6,343.73 8,950.84 N 4,026.63 E 9474.13 1.76 16531.06 89.29 317.00 6,343.16 9,022.37 N 3,960.61 E 9534.35 2.24 16626.60 90.03 317.66 6,343.73 9,092.61 N 3,895.86 E 9593.49 1.04 16722.84 90.40 318.00 6,343.37 9,163.94 N 3,831.25 E 9653.73 0.52 16818.92 90.77 317.26 6,342.40 9,234.92 N 3,766.51 E 9713.60 0.86 16915.51 90.83 316.93 6,341.05 9,305.66 N 3,700.76 E 9773.08 0.35 17012.87 88.67 316.86 6,341.48 9,376.74 N 3,634.23 E 9832.77 2.22 17109.45 88.98 317.21 6,343.46 9,447.40 N 3,568.42 E 9892.16 0.48 17162.75 89.47 316.38 6,344.18 9,486.24 N 3,531.94 E 9924.76 1.81 17205.62 91.45 315.92 6,343.84 9,517.16 N 3,502.24 E 9950.60 4.73 17301.71 91.26 315.79 6,341.57 9,586.09 N 3,435.33 E 10008.11 0.24 17397.33 90.52 316.78 6,340.08 9,655.19 N 3,369.26 E 10065.92 1.29 17445.80 88.54 314.71 6,340.47 9,689.91 N 3,335.44 E 10094.86 5.90 17494.60 87.68 314.77 6,342.08 9,724.24 N 3,300.79 E 10123.30 1.78 17590.85 89.04 316.17 6,344.84 9,792.82 N 3,233.33 E 10180.37 2.03 17686.68 90.27 316.32 6,345.41 9,862.04 N 3,167.06 E 10238.26 1.30 17783.89 90.83 317.77 6,344.48 9,933.18 N 3,100.82 E 10298.06 1.60 17879.60 92.19 318.80 6,341.96 10,004.60 N 3,037.16 E 10358.53 1.78 17977.20 90.46 319.01 6,339.70 10,078.13 N 2,973.02 E 10421.02 1.78 18073.14 89.90 318.91 6,339.40 10,150.49 N 2,910.03 E 10482.53 0.59 18169.25 90.89 319.19 6,338.73 10,223.08 N 2,847.04 E 10544.28 1.07 18265.44 90.21 318.31 6,337.80 10,295.39 N 2,783.62 E 10605.67 1.16 18362.71 90.58 318.25 6,337.13 10,367.99 N 2,718.89 E 10667.15 0.39 18457.25 89.90 316.73 6,336.73 10,437.68 N 2,655.01 E 10725.88 1.76 18554.92 90.71 317.13 6,336.21 10,509.03 N 2,588.31 E 10785.81 0.92 18650.73 91.14 316.56 6,334.66 10,578.91 N 2,522.79 E 10844.48 0.75 18712.21 87.00 316.57 6,335.66 10,623.54 N 2,480.54 E 10881.88 6.74 18747.24 87.06 317.60 6,337.48 10,649.16 N 2,456.72 E 10903.42 2.94 INSITE V8.0.0 Page 5Job No:AK-XX-0900774793 Well Name:ODSN-28 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 18841.39 85.30 317.21 6,343.75 10,718.32 N 2,393.14 E 10961.67 1.92 18938.10 85.58 317.28 6,351.44 10,789.10 N 2,327.70 E 11021.24 0.29 19027.99 86.01 317.20 6,358.03 10,854.92 N 2,266.84 E 11076.63 0.49 19124.02 85.51 317.82 6,365.13 10,925.54 N 2,202.15 E 11136.16 0.82 19219.58 86.88 318.28 6,371.47 10,996.45 N 2,138.41 E 11196.12 1.51 19329.00 86.88 318.28 6,377.42 11,078.00 N 2,065.70 E 11265.18 0.00 DIRECTIONAL SURVEY DATA NOTES - 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 9.08 degrees (True) - A total correction of 19.47 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 19,329.00 feet is 11,268.95 feet along 10.56 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. 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 ENERGY SERVICES, INC. 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 THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. 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 ENERGY SERVICES, INC. SERVICES 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 ENERGY SERVICES, INC. INSITE V8.0.0 Page 6Job No:AK-XX-0900774793 Well Name:ODSN-28 Survey Report