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215-054
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: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' 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: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: ODSN-22 path forward Date:Sunday, October 26, 2025 11:10:10 PM Attachments:image002.png Staic temp_ODSK-33(9-11-25)SHALLOW.pdf Staic temp_ODSK-33(9-11-25)ALL.pdf From: Ryan Rupert <ryan.rupert@hilcorp.com> Sent: Friday, October 24, 2025 10:32 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Patrick Stewart - (C) <Patrick.Stewart@hilcorp.com>; Mike Grubb - (C) <Mike.Grubb@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Joshua Zuber <Joshua.Zuber@hilcorp.com> Subject: ODSN-22 path forward Mel- Per our conversation, please see below for events to date for in progress ODSN-22 HWO. Given the mechanical challenges with getting the completion to planned depth, Hilcorp would like to request a waiver to AOGCC regulation 20 AAC 25.265.G.2, and plan to set the SSSV above the base permafrost. Hilcorp believes due to the observed static temperature gradient, and the relatively hot anticipated production stream, that setting the SSSV above the base permafrost will still allow for robust well control, and functioning SVS. Planned completion Top liner: 14,449’ MD (-5796’ ssTVD) End of ESP completion / screens: 15,200’ MD (-5977 ssTVD) Packer: 3775’ MD (-2243’ ssTVD) Biggest and longest completion component at 5.99” OD x 11’ long Running inside 6.276” ID casing (6.151” drift) TRSSSV: 3600’ MD (-2189’ ssTVD) Base permafrost: 1975’ MD (-1611’ ssTVD) No shallow logs in ODSN-22 We’re pulling together logs/map currently and can send those over shortly Events thus far Ran completion to 13,246’ MD (-5364’ ssTVD) Placed packer at 1765’ MD (-1499’ ssTVD) Placed SSSV at 1590’ MD (-1384’ ssTVD) Unable to move down or up at 80% max pull Pumped 5 lube pills over previous day Unable to go down, but have successfully pulled completion ~325’ uphole Stopped there, and standing by for path forward See below for shallow deviation survey Challenging DLS from 1700-2100’ MD Proposal Plan to set completion where it’s at currently Attempt to work back to previous depths if practical, but don’t want to unnecessarily stress the packer any more. This would put SSSV at 1590’ MD (-1384’ ssTVD) This places SSSV within 230’ ssTVD of base permafrost Reservoir pressure in ODSN-22 is no greater than 2050psi at -6350’ TVDss (<6.3ppg) See attached for offset static temp log from ODSK-33 (shut in for 10+ years) Proposed set depth will be >32F Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. ͏͔͏͏͐͏͏͏͔͐͏͏͑͏͏͏͔͑͏͏͒͏͏͏͏ ͔ ͐͏ ͔͐ ͑͏ ͔͑ ͒͏ ͔͒ ͓͏ ͓͔ ͔͏ ͔͔ ͕͏ ͕͔ ͖͏ ͖͔ ͗͏"ôŕťēώϼ«"ŜŜϽôıŕôŘÍťŪŘôώϼîôČŘôôŜώ>Ͻi"Xϱ͒͒ώťÍťĖèώôıŕώ[ĺČώϼ͘ϱ͐͐ϱ͔͑ϽťÍťĖèώôıŕώϼ>Ͻ[ĺČČôîώÍŜôώôŘıÍċŘĺŜťώЬώϱ͕͐͐͐ώŜŜ«"īÍIJIJôîώ«ώŜôťώîôŕťēώÍťώϱ͓͐͒͗ώŜŜ«"͒͑> ͏͐͏͏͏͑͏͏͏͒͏͏͏͓͏͏͏͔͏͏͏͕͏͏͏͖͏͏͏͏ ͑͏ ͓͏ ͕͏ ͗͏ ͐͏͏ ͐͑͏ ͓͐͏ ͕͐͏"ôŕťēώϼ«"ŜŜϽôıŕôŘÍťŪŘôώϼîôČŘôôŜώ>Ͻi"Xϱ͒͒ώťÍťĖèώťôıŕώīĺČώϼ͘ϱ͐͐ϱ͔͑Ͻ 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: HWO: GL to ESP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 22,208 NA Casing Collapse Conductor NA Surface 3,180psi Intermediate 3,090psi Intermediate 5,410psi Liner 9,200psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Ryan Rupert Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 158 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355036, ADL0355037 215-054 OOOGURUK ODSN-22 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-703-20708-00-00 OOOGURUK Hilcorp Alaska, LLC Length Size Proposed Pools: 6,197 22,205 6,197 1,415 NUIQSUT OIL Same 6,548 158 C-110 TVD Burst 15,449 11,590psi Tubing Size: 7" MD NA 7,240psi 10,950 5,830psi 5,750psi 3,211 4,915 6,077 11,717 See Schematic 6,1974-1/2" 110 16" 11-3/4" 9-5/8" 6,276 6,776 15,663 See Schematic 907-777-8503 ryan.rupert@hilcorp.com Operations Manager September 19, 2025 4-1/2" Perforation Depth MD (ft): NA ZXP Liner Top Packer, HES "XXO" SV Landing Nipple 15,449' MD / 6,056' TVD, 2,882' MD / 2,002' TVD NA 22,204 15,699 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:47 pm, Sep 05, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.09.05 11:16:09 - 08'00' Sara Hannegan (2519) 325-546 A.Dewhurst 10SEP25 DSR-9/10/25 10-404 * BOPE pressure test to 2000 psi. 48 hour notice. * State witness SSV and SSSV performance test within 5 days of POP. 48 hour notice to AOGCC. MGR10SEP2025JLC 9/11/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.11 08:37:05 -08'00'09/11/25 RBDMS JSB 091125 ESP Swap HWO Well: ODSN-22 Well Name:ODSN-22 API Number:50-703-20708-00-00 Current Status:Online GL producer Permit to Drill Number:215-054 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Keith Lopez (907) 903-5432 (c) Regulatory Contact:Darci Horner (907) 777-8406 Max Expected BHP:2050psi at 6350’ TVDss (6.3ppg) 4/8/22 SBHP (98 days SI) Max. Potential Surface Pressure: 1415 psi 0.1psi/ft to surface Brief Well Summary ODSN-22 is an online Nuiqusit producer. The well was drilled and completed as a multistage frac’d producer in 2016. Standard Nuiqusit completion strategy was to install a 4-1/2” GL completion string post-drill, and execute the frac down that string. Then free-flow the well initially, and switch to GL when needed. Most producers were eventually recompleted with smaller tubing ESP completions for better drawdown. The 3-phase Oooguruk subsea export line is hydraulically bottlenecked, and converting this well from GL to ESP will also alleviate some of that bottleneck. As part of the pre-RWO screening the well passed a CMIT-TxIA in September of 2025. The goal of this project is to convert the well from GL to ESP and increase drawdown Pertinent wellbore information: - SVLN at 2882’ MD: usually has an FXE WL-SSSV set - Deviation o Goes >71 degrees at 14,900’ MD (close to XN-nipple) o Sail angle: 71 degrees from 2600 – 14,900’ MD o Max deviation above top liner = 85 degrees at top liner - Min ID in tubing: 3.725” at XN-nipple at 14,867’ MD - Recent History o September-2025 SL set TTP in XN-profile at 14,867’ MD Well PASSED a CMIT-TxIA to 2000psi o 2016: Drill and Complete MIT-T to 3500psi PASSED and MIT-IA to 4000psi PASSED Multi stage frac completed passed a CMIT-TxIA in September of 2025. ESP Swap HWO Well: ODSN-22 HWO Conditions x Traditional well control approach will be implemented x KWF will be a barrier at all times during HWO operations x No snubbing operations will be conducted x BOPE in attachment will be used. This stack is currently in service at Spy island as of August-2025 x TSI Rig #102 will be new to the slope and new to the state. The rig is not fully winterized. x Hilcorp will conduct HWO operations with TSI #102 NO later than 10/31/25 RWO Procedure 1. MIRU TSI Hydraulic Workover rig #102 2. Circulate / kill well: a. Work over fluid will be injection water (8.33ppg or heavier) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing + Liner volume to top frac port = 245bbls d. IA volume = 275bbls 3. Set BPV/TWC, ND tree, NU BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC 5. BOLDS and unseat hanger 6. POOH laying down existing 4-1/2” GL completion from 15,445’ MD 7. Pickup and RIH with 3-1/2” x 2-7/8” ESP / GL completion a. Plan to run a shroud and ±400’ of 4-1/2” screens below ESP b. Bottom ESP to be set at ±14,800’ MD c. Equip well with Packer, SSSV, and Packer Vent Valve (PVV) all set below permafrost d. Well to be equipped for backup GL as well 8. Land ESP / GL completion 9. Drop Ball and rod and set packer 10. Set BPV/TWC, ND BOP 11. NU tree and test, pull BPV/TWC 12. RDMO TSI #102 Lubricate BPV is risk of trapped pressure. - mgr ESP Swap HWO Well: ODSN-22 Post RWO Procedure 1. MIRU SL 2. PT PCE to 250psi low / 2500psi high 3. Pull B&R and catcher sub 4. RDMO Operations 1. Return well to production 2. Within 5 days of stabilized production, test SSV and SSSV per state guidelines (give 48hr witness notification) 3. TIFL to prove integrity of Packer Vent Valve (PVV) a. Can be conducted with well online or offline. Thermally stable is most important b. Ensure IA FL is at 500’ MD or deeper. Depress with GL, if necessary c. Close in IA at surface d. Close PVV e. Shoot IA FL and note SI IAP f. Bleed IAP down at least 200psi below shut-in IAP g. Monitor IA pressures and fluid level every hour for at least 2 hours i. Shut in IAP would be expected to build, but PVV will prevent this ii. Should be no increase in FL beyond thermal expansion / degassing or foaming effects iii. Pass / fail criteria 1. IA fluid level should inflow no more than 500’ MD over the 2 hours, and show a stabilizing trend (decreasing height gain every hour) 2. Shut in IA pressure should increase no more than 100psi over the 2 hours and show a stabilizing trend (decreasing pressure gain every hour) 4. Open PVV, open IA at surface and return well to production Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. BOPE schematic (TSI) 4. Fluid Flow Diagram (TSI) 5. Rig stabilization Diagram (TSI) Oooguruk Field Last Completed: 6/2/2015 PTD: 215-054 API #: 50-703-20708-00-00 Casing Hole MD 16”158' 16" 9-5/8"11,720' A 3 4-1/2"22,208' B Size ID Top Btm Btm TVD 16” N/A Surface 158' 158' C 11-3/4" 10.772" Surface 6,548' 3,211' 9-5/8" 8.835" 6,391' 11,717' 4,915' 11-3/4" 7" 6.276" Surface 15,699' 6,077' 4-1/2” 3.958" 15,430' 22,205' 6,197' 4-1/2" 3.958" Surface 15,449' 6,055' 2 D No. MD(ft) TVD(ft) Inc ID A 2,882 2,002' 71 3.813" B 3,599 2,244' 70 3.813" C 6,391 3,158' 71 9.625" D 9,040 4,034' 71 3.813" E 12,342 5,122' 71 3.813" 9-5/8"F 14,509 5,838' 72 3.813" G 14,657 5,884' 72 3.842" H 14,757 5,916' 72 3.813" EI14,867 5,950' 71 3.725" J 15,445 6,056' 85 3.44" 1 K 15,449 6,055' 85 5.25" L 15,488 6,059' 85 4.250" F St. MD (ft) TVD (ft) Inc Valve Latch Port 3 3,481 2,205 71 Dummy BEK NA G 2 8,921 3,995 71 Dummy BK-4 NA 1 14,390 5,800 71 OV BK-4 16 H I J, K L 4-1/2" liner from 15,430' MD (6,054' TVD) to 22,205' MD (6,197' TVD) Resman Internally Vented Carrier (x4) 7" Swell Packers (x13) Ball Actuated Sleeves (x 11) One Ported Pup @ 22,147' MD (6,195' TVD) GAS LIFT MANDRELS 4-1/2" x 1" Well Fractured 2/1/2016 6/2/2015 6/2/2015 2.813" KBG-4.5 KBG-4.5 Date KBG-4.5 6/2/2015 Date Complete Jun 2015 Event Drilled & Completed Surface Intermediate 1 Intermediate 2 Production Liner 100#, X-65 60#, L-80, BTC-M 40#, L-80, HYD 521 26#, L-80, HYD 563 12.6#, C-110, Hyd 521 Conductor Wt/ Grade/ ConnType 12-1/4" hole, 42 bbls (200 sx) 15.8 ppg Premium 'G'. Losses during cement job. TOC unknown. CEMENT DETAIL 15,726' CASING DETAIL 7" 8-3/4" hole, 1st stage: 78 bbls (365 sx) 15.7 ppg Premium 'G'. Experienced losses while pumping. TOC @ 14,512' MD from 5/14/15 BAT sonic log. 2nd stage: 53 bbls (255 sx) 15.8 ppg Premium 'G'. Full returns. TOC logged up to 11,700' MD. 6-1/8" Open Hole, Uncemented Ball Actuated Sleeves and Swell Packers TUBING DETAIL Description HES "X" Nipple HES "X" Nipple HES "X" Nipple Tubing 12.6#, C-110, Hyd 521 UPPER COMPLETION EQUIPMENT 9-5/8" X 11-3/4" Liner Top Packer 4-1/2" HES "XXO" SV Landing Nipple ES Cementer ODSN-22 Schematic Nuiqsut Producer 11-3/4"6,558'14-1/2" hole, 648 bbls (931sx) 11.3 ppg Permafrost 'L' plus 121 bbls (580 sx) of 15.8 ppg tail. Returns to surface. Driven in 24" hole Cement Details 4-1/2" Halliburton 'ROC' Gauge Carrier Bottom of Baker (CRA) 20' 4.25" Seal Bore Extension HES "XN" Nipple 3.813" (3.725" NoGo) Bullet Seal Assembly plus Half Mule Shoe SLB "APCV" Sliding Sleeve w/ 3.813"X" Profile (Up to Open) ZXP Liner Top Packer, Flex-Lock Liner Hanger and Tie-Back Extension 70 degree inclination @ 2,409' MD (1,843' TVD) X Gauge SSSV X XN X ODSN-22 Schematic 9-5-2025 Last edited by: DH 9/5/2025 325 Oooguruk Field Last Completed: 6/2/2015 PTD: 215-054 API #: 50-703-20708-00-00 Casing Hole MD 16”158' 16" 9-5/8"11,720' A 3 4-1/2"22,208' B C Size ID Top Btm Btm TVD 2 16”N/A Surface 158' 158' 11-3/4" 10.772" Surface 6,548' 3,211' D 9-5/8"8.835" 6,391' 11,717' 4,915' 7"6.276" Surface 15,699' 6,077' E 4-1/2”3.958" 15,430' 22,205' 6,197' 11-3/4"3-1/2"2.992" Surface 3,350' 2,164' 2-7/8"2.441" 3,350' 3,470' 2,202' 3-1/2"2.992" 3,470' 14,100' 5,704' 2-7/8"2.441" 14,100' 14,665' 5,887' No. MD(ft) TVD(ft) Inc ID 9-5/8"A3,1702,100' 70 B3,3502,164' 70 F C3,3602,167' 70 D3,4402,193' 72 1 E 3,500 2,211' 71 F 14,100 5,704' 70 G 14,630 5,876' 72 G H 14,665 5,887' 72 I 14,775 5,921' 72 J 14,780 5,923' 71 H K 15,449 6,055' 85 5.25" St. Size MD (ft)TVD (ft)Inc GLM Type Valve Latch Port 3 3-1/2" 3,290 2,143 69 TBD Shear TBD NA I 2 2-7/8" 3,400 2,181 71 TBD Dummy TBD NA 1 2-7/8" 14,150 5,720 71 TBD OV TBD TBD J K 4-1/2" liner from 15,430' MD (6,054' TVD) to 22,205' MD (6,197' TVD) Resman Internally Vented Carrier (x4) 7" Swell Packers (x13) Ball Actuated Sleeves (x 11) One Ported Pup @ 22,147' MD (6,195' TVD) 3-1/2" x 2-7/8" XO ZXP Liner Top Packer, Flex-Lock Liner Hanger and Tie-Back Extension ESP Pump Assembly, Discharge gauge with shroud Bottom of ESP Assembly, Centralizer 2-7/8" "XN" Nipple Screens below shroud, 400' long, bottom @ ~ 15,180' ODSN-22 Proposed Schematic Nuiqsut Producer 11-3/4"6,558'14-1/2" hole, 648 bbls (931sx) 11.3 ppg Permafrost 'L' plus 121 bbls (580 sx) of 15.8 ppg tail. Returns to surface. Driven in 24" hole Cement Details TUBING DETAIL Description 3-1/2" x 2-7/8" XO 2-7/8" "X" Nipple 2-7/8" x 3-1/2" XO Tubing 9.2#, L-80, EUE UPPER COMPLETION EQUIPMENT 7" x 2-7/8" ESP Packer with Packer Vent Valve 3-1/2" TRSSSV with control line to surface Tubing 6.4#, L-80, W533 Tubing 9.2#, L-80, EUE Tubing 6.4#, L-80, W533 Wt/ Grade/ ConnType 12-1/4" hole, 42 bbls (200 sx) 15.8 ppg Premium 'G'. TOC ? CEMENT DETAIL 15,726' CASING DETAIL 7" 8-3/4" hole, 1st stage: 78 bbls (365 sx) 15.7 ppg Premium 'G'. Experienced losses while pumping. TOC @ 14,512' MD from 5/14/15 BAT sonic log. 2nd stage: 53 bbls (255 sx) 15.8 ppg Premium 'G'. Full returns. TOC logged up to 11,700' MD. 6-1/8" Open Hole, Uncemented Ball Actuated Sleeves and Swell Packers Surface Intermediate 1 Intermediate 2 Production Liner 100#, X-65 60#, L-80, BTC-M 40#, L-80, HYD 521 26#, L-80, HYD 563 12.6#, C-110, Hyd 521 Conductor GAS LIFT MANDRELS Well Fractured 2/1/2016 TBD TBD Date TBD Date Complete Jun 2015 Event Drilled & Completed 70 degree inclination @ 2,409' MD (1,843' TVD) X SSSV XN ES Cementer Base of Torok 0000 0 0 ODSN-22 Proposed Schematic 9-4-2025 Last edited by: DH 9/5/2025 TEAM SNUBBINGINTERNATIONALSP-12BOP Stack Drawing54.13"33.8"33.8"24.0"13 5/8"00 PSI Annular5000 PSI Single Ga e VBR:2 7/8" - 5 1/2"5000 PSI Single Ga eBlinds5000 PSI Flow Cross5000 PSI Riser5013 5/8" 13 5/8" 13 5/8" 13 5/8" /D E^/KE^ΘdK> ZE ^ϭΣ&Zd/KE>E'h>ZϬ͘ϬϬ͘ϬϬϬ͘ϬϬϬцϬ͘ϬϯϬϬ͘ϬϭϱϬ͘ϬϬϱццццϭͬϭϲцϬ͘ϬϬϬϬ Ϭ͘ϬϬϭ(1(5*<6(59,&(6,&21ϬΗ'ZKhE> s >ϭϲ͘ϬϬĨƚϭϵϮΗϲϳ͘ϱϭĨƚϴϭϬΗtKZ<&>KKZZϱϰΖ'hz'hz'hz'hz'hz 'hz&'hz''hz,>K<^>K<^ D>DW^ D>DW^EKd ͗Z & ZdKK D^W ^&KZ'hz'/EWK> 'hzZ Yh/Z D Ed^ϯϵΣϱϬΣDy^ d/KEͲEKd ͗E,KZ>K<^Dh^d W> KE^K>/'ZKhEt/d,E,KZ> d^ D /E^K/>͘Z KDD E D/E/DhDE,KZt /',dϭϴ͕ϬϬϬ>EKd ͗>/E >K^^^hD ^dZhdhZ /^&h>>z E>K^ &KZt/E>K/E''hzt/Z ^W ^ yW d >Kd E^/KEϵ͕ϬϬϬ>^ KEϭ͕ϬϬϬ>WZ Ͳd E^/KE͘ϯͬϰ/tZ /W^ϲyϭϵt/Z ZKW 'hzϴϱ&d'hzϴϱ&d'hzϴϱ&d'hzϴϱ&d'hz ϲϱ&d'hz&ϲϱ&d'hz'ϲϱ&d'hz,ϲϱ&dZ s͗$5&+&' E Z>EKd ^͗ϭ͘h͘E͘K͘>>&/>> dt >^dK ϭͬϰΗKEd/EhKh^͘Ϯ͘h͘E͘K͘>>hddt >^dK ϭͬϰΗKEd/EhKh^͘ϯ͘^ >t >>>dh/E'͘ϰ͘^d/<E&>hyͲKZ t >/E'WZK hZ ^Z /Ed Z,E'> KEE Yh/s> Ed^/^͘ϱ͘KEKd^> Zt/E'͘ϲ͘/&/EKhd^<͘Z/'ηZtE͗d ͗DW/Z h^dKD Z͗&/> ͗d/d> ͗d D^Eh/E'^, dd/d> ͗' E Z>^^zd^ϭϬϭt'η͗ϱϬϮϯϵ͘ϵ>td͗325- RECEIVED 2.1G - 06t4 JUN 15 2Olii Yep(ace. 10 2Col22CQ CAELLJ S LETTER OF TRANSMITTAL Energy Alaska RECEIVED JUN 152016 SCANNED JAN 0 5 2011 AOGCC DATE: June 13, 2016 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 CD-R • Other- Logs ❑ Agreement DETAIL QTY DESCRIPTION O DS N-022(50-703-20708-0000) 1 CD Digital graphic logs, digital log data, definitive surveys 4 Well Logs DGR, PCG, EWR-Phase 4, ADR, ALD, CTN, Invert/Revert Sections (1:240, 1:600)TVD; ROP, DGR, PCG, EWR-Phase 4, ADR, ALD, CTN Horizontal Presentation (1:240, 1:600) MD RESUBMISSION with corrected Neutron Porosity Curves e ` 1 1 0 Received by: AIL" • Date: Pleas= sign and return one copy to: aelus Energy Alaska ATTN: Shannon Koh 3700 Centerpoint Dr., Suite 500, Anchorage, AK 99503 907-343-2193 fax 907-343-2128 phone shannon.kohcaelusenergy.com STATE OF ALASKAi u ALAI,OIL AND GAS CONSERVATION COMMI•N MAR 1 1 2016 REPORT OF SUNDRY WELL OPERATIONS �j 1.Operations Abandon ❑ Plug Perforations H Fracture Stimulate ��o u ❑ Pull Tubing ❑ Opera ions shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Caelus Natural Resources Alaska,LLC 4.Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ 215-054 3.Address: 3700 Centerpoint Drive,Suite 500,Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-703-20708-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036,ADL 355037 ODSN-22 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 22,208 feet Plugs measured N/A feet true vertical 6,197 feet Junk measured N/A feet Effective Depth measured 22 205 feet Packer measured See attachment feet pg 3 true vertical 6 197 feet true vertical See attachment feet pg 3 Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 6,276' 11-3/4" 6,548' 3,211' 5,830 psi 3,180 psi Intermediate 1 10,950' 9-5/8" 11,717' 4,915' 5,750 psi 3,090 psi Intermediate 2 15,663' 7" 15,699' 6,077' 7,240 psi 5,410 psi Production 6,776 4-1/2" 22,204' 6,197' 11,590 psi 9,200 psi Perforation depth Measured depth See attachment feet pg.2 9001 APR 2 2 2016 True Vertical depth See attachment feet pg.2 Tubing(size,grade,measured and true vertical depth) 4-1/2", 12.6# C-110,Hyd 521 15,449'MD 6,055'TVD Packers and SSSV(type,measured and true vertical depth) See attachment,pg 3 12.Stimulation or cement squeeze summary: Intervals treated(measured): SEE ATTACHED POST JOB REPORTS FROM VENDOR 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: 0 0 0 15 16 Subsequent to operation: 6319 1 3776 434 1640 699 14.Attachments(required per 20 AAc 25.070,25.071,&25.283)) 15.Well Class after work: Daily Report of Well Operations Li Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Li Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data Q 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: 315-753 / Contact Jack Kralick,343-2185 Email jack.kralicktc'i caelusenergy.com Printed Name Jack Kralick Title Wells Superintendent Signature 116.4 Phone 907-343-2185 Date 3/11/2016 P 1A d Ravic�fl 9M 5 �iand n3ina n y 4 /0A y-sI� RBDMS L L- MAR 1 4 2016 °�""' • • Attachment 2 AOGCC Form 10-403 ARNdWM°tM..,'kR 4aue4xw�TA%dY 5'i:a tt6W8AEeftr.MMl.°4yf8M.roan wwvzvxivcmw,auw u:.w,E - Application for Sundry Box 11 - Perforation Locations Well: ODSN-22 Top(MD) Bottom(MD) Top(TVD) Bottom (TVD) 4-1/2" RapidStage Sleeve#11 16,087 16,090 6,111 6,112 4-1/2" RapidStage Sleeve#10 16,690 16,692 6,134 6,134 4-1/2" RapidStage Sleeve#9 17,265 17,268 6,139 6,139 4-1/2" RapidStage Sleeve#8 17,842 17,845 6,146 6,146 4-1/2" RapidStage Sleeve#7 18,402 18,405 6,155 6,156 4-1/2" RapidStage Sleeve#6 19,048 19,051 6,164 6,164 4-1/2" RapidStage Sleeve#5 19,658 19,661 6,174 6,174 4-1/2" RapidStage Sleeve#4 20,113 20,116 6,180 6,180 4-1/2" RapidStage Sleeve#3 20,801 20,803 6,177 6,177 4-1/2" RapidStage Sleeve#2 21,360 21,362 6,179 6,179 4-1/2" RapidStage Sleeve#1 21,929 21,932 6,191 6,191 Pre-Perforated Pup 22,147 22,152 6,195 6,195 • Attachment 3 AOGCC Form 10-403 Application for Sundry Box 11 - Packers & SSSV Well: ODSN-22 SSSV MD TVD 4-1/2" Halliburton 'XXO' SVLN 2,882' 2,002' PACKERS 5" x 7" Baker ZXP Liner Top Packer 15,449' 6,055' HES Swell Packer#13 15,771' 6,083' HES Swell Packer#12 15815' 6,086' HES Swell Packer#11 16,397' 6,131' HES Swell Packer#10 16,975' 6,135' HES Swell Packer#9 17,553' 6,142' HES Swell Packer#8 18,114' 6,149' HES Swell Packer#7 18,718' 6,161' HES Swell Packer#6 19,358' 6,169' HES Swell Packer#5 19,890' 6,177' HES Swell Packer#4 20,386' 6,177' HES Swell Packer#3 21,073' 6,178' HES Swell Packer#2 21,596' 6,183' HES Swell Packer#1 22,114' 6,195' • 110 Operations Summary Report - State Well Name: ODSN-22 emo AEUJ S Alaska Well Name: ODSN-22 Contractor: Rig Number: Job Category: FRAC Start Date: 2/11/2016 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 2/11/2016 2/12/2016 22,208.0 00:00 2/11/16-00:00 2/12/16 *Drifted w/3.84"gauge ring to SVLN @ 2,860'slm. *Pulled 4.5"FXE SSSV from SVLN @ 2,860'slm. *LRS fluid packed tubing w/diesel. *Drifted w/3.80"centralizer&sample bailer to XN nipple @ 14,854'slm. *OOH winds are above 30-37 mph.Lay down equipment. 2/12/2016 2/13/2016 22,208.0 00:00 2/12/16-00:00 2/13/16 *Set 4.5"Evo-trieve RBP(3.66"OD,7500 psi rated)©14,818'slm. *LRS pressured up tubing to 2000 psi.Evo-Trieve holding solid. *HES Slickline installed tree cap&secured well.RDMO HES Slickline. *Vetco installed secondary 10k gate valve&1002 flange. *HES Slickline standby for high winds 40+mph. *SLB will MIT-Tubing in the morning. 2/13/2016 2/14/2016 22.208.0 00:00 2/13/16-00:00 2/14/16 *HES Slickline standby for high winds 40-50+mph. *Caelus ice road conditions phase 2. 2/14/2016 2/15/2016 22,208.0 00:00 2/14/16-00:00 2/15/16 *HES Slickline standby for high winds 40-50+mph. *Caelus ice road conditions phase 2. 2/15/2016 2/16/2016 22.208.0 00:00 2/15/16-00:00 2/16/16 e( *MIRU SLB Cement unit w/2"1502 hardline.Pressure test lines to 7000 psi. *Conduct MIT-Tubina to 6100 osi for 30 minutes Test charted *RDMO SLB Cement unit. *MIRU HES Slickline w/.125 wire. *Pulled 4.5"Evo-Trieve RBP from 14,818'slm. *Drifted w/3.25"centralizer&sample bailer to 15,197'slm.Tools stopped due to deviation. Sample bailer empty. *Drift 4.5"Frac Isolation Sleeve on surface w13.009"Ball.Witnessed by Wells Group Supervisor. *Set 4.5 Frac Isolation Sleeve(3.12"ID)in SVLN @ 2,860'slm.Unable to establish control line integrity. 2/16/2016 2/17/2016 22,208.0 00:00 2/16/16-00:00 2/17/16 *Drift 4.5"Frac Isolation Sleeve on surface w/3.009"Ball.Witnessed by Wells Group Supervisor. *Set 4.5 Frac Isolation Sleeve(3.12"ID)in SVLN @ 2,860'slm.Establish control line integrity to 5000 psi. *RDMO HES Slickline Combo Unit. *Vetco installed hydraulic frac Surface Safety Valve w/4"1002 connection on wellhead. *LRS MIT-IA to 4000 psi back on 9/16/15.No gas lift work has been done since 6/8/15. ***VR Plug Installed,2-10k gate valves on wellhead*** 2/18/2016 2/19/2016 22,208.0 00:00 2/18/16-00:00 2/19/16 *Loaded all frac the frac tanks via Nanuq and Operations. *LRS Lake Heater has three tanks to heat at midnight. *SLB rig down the broad band pump and send in for re build. *Start running the treatment line to the well head. *GE test the void on the tree 10,000 psi. *Moved 212 tank and PRV Skid and containment from Well Bay 4 south side to Well Bay 1 north side. 2/19/2016 2/20/2016 22,208.0 00:00 2/19/16-00:00 2/20/16 *LRS Lake Heater completed heating frac tanks. *Nanuq Frac Crew continue with set up and clean up for frac support equipment on both the north and south sides of the Well Bays. Page 1/4 Report Printed: 3/11/2016 S. • Operations Summary Report - State Well Name: ODSN-22 eue CAE LU r,:,r Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 2/20/2016 2/21/2016 22,208.0 00:00 2/20/16-00:00 2/21/16 *LRS Hot Oil Unit completed heating SLB diesel tanker to 95+degrees. *Nanuq Frac crew completed removing steam hoses from the upright containment and taking it down to the truck shop to thaw out. *LAS equipment sent to Deadhorse SLB off for repairs. *Repairs are completed and LAS equipment will be on site in the AM. 2/21/2016 2/22/2016 22,208.0 00:00 2/21/16-00:00 2/22/16(FRAC STAGES *Nanuq Frac Pad Crew completed repairs on hoses. *LRS Heater SLB diesel transport to temp. *SLB completed Frac pumping operations. *Nanuq and Operations started loading frac tanks. *SLB started loading proppant into Sand Chief. ky *Shut down loading Frac tanks Operations drag valve has issues. 9 -. *Instrument tech on site to assist with trouble shooting Drag Valve. *Vetco GE personnel preparing tree for slick line activities. *HES Combo unit rigging up to pull Frac sleeve. *Swap to diesel.Pumped 45 bbls down the TBG for freeze protect *Total proppant per load sheets 606,600 lbs. *Total slurry pumped 6260 bbls. *Final SIP;TBG 1480 psi-IA 2842 psi-OA 5 psi. 2/22/2016 2/23/2016 22,208.0 00:00 2/22/16-00:00 2/23/16 *Resume Loading Frac water via Operations and Nanuq personnel. *HES set down @2,860'slm worked wire down and saw 1'of travel. *PUH saw over pull and came free POOH pressured up on Control line to 5000 psi. *At surface still holding 5000 psi on the control line. *RDMO Combo unit and Crane. *CH2 emptied 212 bbl tank. *Continue to heat Frac tanks via LRS Lake Heater. *GE will rig down the 4"x 10k valve and install the 4"x 10k flange. *Rig up the SLB stand pipe to the well head. *Send the diesel transport to Prudhoe to reload with ULSD diesel. *Chemical reload. *Re load the sand chiefs for zones 5-8. *Continue filling and heating frac water tanks. 2/23/2016 2/24/2016 22,208.0 00:00 2/23/16-00:00 2/24/16 *LRS Lake Heater completed heating Frac tanks. *Diesel transport returns from Prudhoe Bay with ULSD. *Begin final preparation for Zones 5-8. t *Cnmpletad pumping Frac 7ones 5-8. *Swap to diesel,pumped 43 bbls down the TBG for freeze protect. L *Total proppant per load sheets 864,000 lbs. �7 *Total slurry pumped 6972 bbls *Final SIP;TBG 1450 psi-IA 500 psi-OA 12 psi *Begin loading and heating Frac tanks via Nanuq,Operations&LRS. *MIRU the HES Combo unit and LRS to conduct Frac Sleeve removal. *Remove Frac Sleeve no apparent damage to sleeve.(No 0-Rings) *HES made brush and flush run. 2/24/2016 2/25/2016 22,208.0 00:00 2/24/16-00:00 2/25/16 *Nanuq loading Frac water into Frac tank and LRS Lake Heater heating the same Frac tanks. *Frac Sleeve set and pressure tested via control line to 5000 psi.Good test.(5 Gallons of hyd. fluid pumped through control line before setting Frac sleeve) *Rig down Combo equip and relocate to the staging area. *Reload the sand chiefs-chemicals for Zones 9-12 *Inspect and rebuild all frac support equipment. Page 2/4 Report Printed: 3/11/2016 • Operations Summary Report - State Well Name: ODSN-22 CAVUS r y Alaska Start Depth Foot/Meters Dens Last Start Date End Date (EKE) (ft) Mud(Iblgal) Summary 2/25/2016 2/26/2016 22,208.0 00:00 2/25/16-00:00 2/26/16 *Prep Up Right equipment for possible clean out operations. *LRS heated up SLB diesel transport. *Frac zones 9-12 tf *Total proppant per load sheets 947,200 lbs *Total slurry pumped 6921 bbls *Due to lock up event approx 11,000 lbs of sand left in the well bore. (\I *Total proppant pumped in the well 2,416,817 lbs *Freeze protect the TBG with 14 bbls of diesel. *Shut in for 15 min. *Final SIP;TBG 2930 psi-IA 400 psi-OA 13 psi *Vetco/GE installed Flowcross and removed VR plug well. *Expro rigging up from flowcross to flowback unit. *SLB CTU backed in and raising mast. *Nanuq has loaded Frac tanks 18-13. 2/26/2016 2/27/2016 22,208.0 00:00 2/26/16-00:00 2/27/16 *MIRU Schlumberger coiled tubing equipment. *LRS Hot Oil Unit assist with BOP test of SLB equip. *Expro completed rigging up flow back equip. *SLB conducting mandatory BOP test. *M/U slim hole BHA(1.75") *RIH to clean out got to 3000'no ice. *Continue reverse clean out from 12,400'. 2/27/2016 2/28/2016 22,208.0 00:00 2/27/16-00:00 2/28/16 *Continue with reverse cleanout as per program. *Reverse clean out to 16,061'ctm.Good clean returns.POOH *Freeze protect coil tubing and lay in freeze protect from 3,500'ctm. *Rig coil tubing off well and secure well with tree cap. 2/28/2016 2/29/2016 22,208.0 00:00 2/28/16-00:00 2/29/16 *Completed rigging back BOP stack to back deck. *SLB installed 4"10k flange x Otis and secure well with tree cap. *Standby for weather(winds 45 to 55 mph)to lay down mast. 2/29/2016 3/1/2016 22,208.0 00:00 2/29/16-00:00 3/1/16 *Waiting on weather to begin Slick Line operations.(Winds 40 to 44 mph) *Removed Frac Sleeve from SVLN @ 2882'MD. *Drift to"X"Nipple @ 9025'slm. *Set"X"Plug(Without packing)into the"X"Nipple @ 9025'slm. *Pumped 78 bbls diesel in support of HES Slick Line. 3/1/2016 3/2/2016 22,208.0 00:00 3/1/16-00:00 3/2/16 *RIH and pulled DMV from GLM#2 @ 8911'slm. *RIH to set 1"OV with 5/16"Port. *Second trip to set bottom latch OV with 5/16"Port no luck POOH. *RIH with pocket brush and brush GLM#2. *RIH with second top latch OV with 5/16"Port. *OOH with OV with 5/16"Port. 3/2/2016 3/3/2016 22,208.0 00:00 3/2/16-00:00 3/2/16 *Set the Bottom Latch OV with 5/16"Port in GLM#2 at 8,911'slm.Good set. *Pull the Frac isolation sleeve in the XXO SVLN at 2,862'slm.Good set. *Begin unloading the IA as per OPS group policy and procedure. *Prep the ODSN-22 well to begin the Expro flowback. 3/3/2016 3/4/2016 22,208.0 Post frac well flow test per Operations team program. *OPS group displacing the IA with lift gas. *Well shut in until proper parameters to begin the flowback. *OPS group began injecting gas down the TBG and IA at 11:00 am simultaneously. *Continue to stand by for the gas to reach the 5/16"OV in GLM#2. Page 3/4 Report Printed: 3/11/2016 IP • Za•C Operations Summary Report - State Well Name: ODSN-22 AELU S Energy Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 3/4/2016 3/5/2016 22,208.0 Post frac well flow test per Operations team program. 00:00-06:00 3/4/16 *Continue to displace the IA with lift gas. *Well shut in until flowback pressure parameters are achieved. *Open well and begin the flowback at 13:14 *Well unloading water. *Receive a dissolvable ball at 20:30 pm in the ball catcher. *Continue flowback operations.well is feeding slight to moderate sand returns. 3/5/2016 3/6/2016 22,208.0 00:00 3/5/16-00:00 3/6/16 Post frac well flow test per Operations team.Two balls recovered from Expro ball catcher. *Continue to monitor and record all pressures,rates and sand returns. *Adjusting well accordingly to maintain the 5-10 psi per hour drawdown on the BHP. *Please refer to the Expro report for all flowback specifics. 3/6/2016 3/7/2016 22,208.0 00:00 3/6/16-00:00 3/7/16 Post frac well flow test per Operations team.Two balls recovered from Expro ball catcher. *Continue to monitor and record all pressures,rates and sand returns. *Adjusting well accordingly to maintain the 5-10 psi per hour drawdown on the BHP. *Maximum choke setting of 68/64ths. *Well is flowing through Expro and into the production line via OPS. 3/7/2016 3/8/2016 22,208 0 00:00 3/7/16-00:00 3/8/16 *Continue flowback operations. *Continue to walk the choke open to maintain the 5-10 psi per hour drawdown on the BHP. *Increased choke setting to 128/64ths(full open). *Oil returns are 98-99%with 0.1-0.3%of sediment. *Continue to monitor the flowback via Expro. 3/8/2016 3/9/2016 22,208.0 00:00 3/8/16-00:00 3/9/16 *Continue flowback operations. *Choke setting 128/64ths(full open). *Continue to monitor the flowback via Expro. *All fluid returns are being diverted to the production line via Expro. 3/9/2016 3/10/2016 22,208.0 00:00 3/8/16-00:00 3/9/16 *Continue flowback operations. *Choke setting at 128/64ths(full open). *Oil returns are 98-99%with 0.1 -0.3 percent of sediment. *Shut in the well and build the TBG pressure up to surge the well.Open to 60/64ths and bring on the well. *Continue to monitor the flowback via Expro. *Shut the well in at 19:30 and freeze protect to set the SSSV utilizing HES Slickline. *Freeze protect Expro and begin RDMO. *Wind speeds rise rapidly once the crane was needed to move forward. *Monitor wind. 3/10/2016 3/11/2016 22,208.0 00:00 3/10/16-00:00 3/11/16 *MIRU HES Slickline *Drifted w/3.83"gauge ring to XXO nipple @ 2,863'slm. *Pulled 4.5 Frac Isolation Sleeve(3.12"ID)from 2,863'slm.Frac sleeve missing top o-ring. *Drifted w/4.5 braided line brush&3.80"gauge ring to 3,500'slm.Brushed SVLN.Did not recover lost o-ring. *Set 4.5 FXE SSSV in XXO nipple @ 2,863'slm. *Perform closure test on SSSV.Closure test good. *Vetco removed 10k secondary gate valve from wellhead.Installed 7"5k tree cap flange w/otis connection. *RDMO HES Slickline. *Complete well handover from Wells Group to Operations. Page 4/4 Report Printed: 3/11/2016 • • 03-01-2016 ODSN-22 Nuiqsut Production Well Completion FINAL No. Upper Completion;- N1D(ft) 'TVD(ft) I Land Upper 1 Tubing Hanger 34 34 2 4-%"12.6#/ft C-110 Hydri15217ubing I I Completion 3 4'/:"Halliburton'XXO'SVLN w/3.813""X"profile with singlel/4"x 0.049"s/s Control line. 2882 2002 I I with 40,000 lbs Cannon Cross-coupling clamps on every joint w/15ft Pup BxP Top&Bottom • iii Slack-Off 4 4-%"12.6#/ft C-110 Hydril 521 Tubing I I 5 4%"x 1"GLIM#3,KBG-4-5 Hydril 521 w/15ft Pup BxP Top&Bottom 3481 2206 I l 6 4-'/:"12.6#/ft C-110 Hydril S21 Tubing(2Joints) _ 4.5"FXE 7 HES"X"Nipple 3.813"w/15ft Pup BxP Top&Bottom 3599 2245 Installed I I • 8 4-%"12.6#/ft C-110 Hydril S21 Tubing ::; 4% I© 16"Conductor 9 4'/::"x 1'GLM#2,KBG-4-5 Hydril 521 w/15ft Pup BxP Top&Bottom 8921 3995 10 4,A"12.6#/ft C-110 Hydril 521 Tubing(2 Joints) Packer Fluid mix' 11 HES"X"Nipple 3.813"w/15ft Pup BxP Top&Bottom 9040 4034 Inhibited Kill 12 4-%"12.6#/ft C-110 Hydril 521 Tubing I weight Brine 13 4%"x l"GLM#1,KBG-4-5 Hydril 521 w/15ft Pup BxP Top&Bottom 14390 5800 GLM#3 14 4%"12.6#/ft C-110 Hydril 521 Tubing DGLV O GL 11 with 2000' ao D 15 HES"X"Nipple 3.813"w/15ft Pup BxP Top&Bottom 14509 5838 Installed I 16 4-A:"12.6#/ft C-110 Hydril 521 Tubing 7,000 psi 17 4-1/2"Halliburton'ROC'Gauge Carrier w/Encapsulated e-line to Surface w/15ft Pup BxP Top& 14657 5884 Max rated x I 11-3/4"60#L-80 Bottom I . BTC Surface Casing 18 4-''/,"12.6#/ft C-110 Hydril 521 Tubing(Zits) I'.. t< -:- @ 6,548'MD/ 41/2"APCV II Non-Elastomeric Sliding Sleeve,125ksi Frac Harden Body&Inner Sleeve 3.813" 3,211'TVD 19 PDX Profile W/4 1/2"12.60#Hyd 521 Box X Pin,Opens Up,10,000 Psi w/15ft Pup BxP Top& 14757 5916 Bottom cemented to surface 20 4-14"12.6#/ft C-110 Hydril 521 Tubing(2jts) 21 HES XN 3.813"(3.725"NoGo)-w/15ft Pup BxP Top&Bottom 14867 5951 I 22 4-%"12.6#/ft C-110 Hydril 521 Tubing I TOC 23 4-1/2"x4"Crossover P-110 Locator with a 5.66'long 4-1/2"handling pup on top,4"Spacer Pup w/ 15449 6055 I Estimated Bullet Seal Assembly+Auto Entry Guide Shoe GLM#2 Bottom of Shoe 15485 6058 5/16 0V I @ 500 ft Installed 0 GL ,J above 9-5/8" No. Lower Completion' MD(ft) TVD(ft) 7,000 psi ',ilk Shoe 24a 20 ft 5.25"Tie Back extension 15430 6054 Max rated X IBaker 5"X 7"ZXP Liner Top Packer with Flex Lock Hanger/20 ft 4.25"Seal Bore Recepticle 246 Below Hanger 15449 6055 9-5/8"40#L-80I 25 4-''/:"12.6#/ft Hydril 521 C-110 Liner Hydril 521 26 ResmanInternallyVentedCarrier#4ROS-1368/RWS-1395 w/15ft Pup BxP Top&Bottom 15,691 6076 I Intermediate 1 27 4-%"12.6#/ft Hydril 521 C-110 Liner I I 7,-. Casing Halliburton Swell Packer#13(4-V,'Hydril 521)OD 5.85'-9 meter long oil activated with Slide on I @ 11,717'MD/ 28 Volant Centralizer Pin End and 6ft Pup 41/2"12.6#/ft P-110 Hydril 521 Box zein w/Slide On 15,771 6,083 4,915'TVD Volant Centralizer on Top of Swell Packer IHalliburton Swell Packer#12(4,A"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on I 29 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.64/ft P-110 Hydril 521 Box x Pin w/Slide On 15,815 6,086 GLM#1 , ES Cementer Volant Centralizer on Top of Swell Packer DGLV I 30 4-%"12.6#/ft Hydril 521 C-110 Liner Installed® GL ,11 Base Torok HLB 4-1/2"RapidStage Ball Actuated Sleeve#11(3.009 ball/2.95 Seat)w/15ft 4-1/2"P-110 Pup 4- 7,000 psi® 31 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 16,087 6,111 Max rated X I 32 4-V,'12.6#/ft Hydril 521 C-110 Liner l Halliburton Swell Packer#11(4%"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on J 7"Stage 2 TOC 33 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 16,397 6,131 17 ROC J Estimated Volant Centralizer on Top of Swell Packer Sliding @ 500 ft above 34 4-%"12.6#/ft Hydril 521 C-110 Liner Sleeve !: HLB 4-1/2"RapidStage Ball Actuated Sleeve#SO(2.925 ball/2.867 Seat)w/15ft 4-1/2"P-110 Pup Torok Sand Closed 19 000 35 41/2"12.6#/ft P-110 Hydril 521 Box Pin 16,690 6,134 (Up to Open) Package 36 4-V,'12.6#/ft Hydril 521 C-110 Liner Halliburton Swell Packer#10(4-Y2"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on ® ;XN 37 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 16,975 6,135 Volant Centralizer on Top of Swell Packer 7"Stage 1 TOC 38 4-%"12.6#/ft Hydril 521 C-110 Liner Estimated HLB 4-1/2"RapidStage Ball Actuated Sleeve#9(2.842 ball/2.786 Seat)w/15ft 4-1/2"P-110 Pup 4 17,265 6,139 @ 500 ft above 1/z"12.6#/ft P-110 Hydril 521 Box x Pin 40 4-A:"12.6#/ft Hydril 521 C-110 Liner Kuparuk 41 Resman Internally Vented Carrier#3 ROS-1367/RWS-1394w/15ft Pup BxP Top&Bottom 17,391 6,142 42 4-V:"12.6#/ft Hydril 521 C-110 Liner Halliburton Swell Packer#9(4-%"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on ®� \4F . 2a 43 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 17,553 6,142 ^:;; Volant Centralizer on Top of Swell Packer • ) 44 4-%"12.6#/ft Hydril 521 C-110 Liner <!ff Z� 0 HLB 4-1/2"RapidStage Ball Actuated Sleeve#8(2.761 ball/2.706 Seat)w/15ft 4-1/2"P-110 Pup 4 \\ © 45 17,842 6,146 7"26# L-80 BTC-M%,\* 1/2"12.6#/ft P-110 Hydril 521Box x Pin &Hydril 563 i/`r , ,® 46 a-%°12.6#/ft Hydril 521 C-110 Liner Intermediate 2 �® 0 - O--0 --®OO-_O_O-OO _O_0-- \ < q3 57 61 65 71 75 79 Casing @ 15,699'MD/ e�r® _ _ ' _ 55 _ >� : �� _s9 -y _ �a _ :' 83 6,077'TVD 26 I r _ - - _ _ _ _ _ I CL 'o449 53 59 u ' @ 63 67 fi# 77 0 81 -- 4-V2' Hydril 521 /C-110 Liner with Halliburton Ball Actuated 6-1/8"Hole TD Sleeves,& Swell Packers @ 22,208 MD / 6,197'TVD • 0 03-01-2016 ODSN-22 Nuiqsut Production Well Completion FINAL I I Land Upper No. Lower Completion MD(ft) TVD(ft) S Uiui\.YWt. t,v.n< N6��ix ffyUil f,a..,tir.C. i;i v ..iii I Completion 47 Volant Centralizer Pin End and 6ft Pup 4-1/2"126#/ftP-110Hydril 521Box xPin w/Slide On I I with 40,000 lbs Volant Centralizer on Top of Swell Packer Slack-Off 48 4-X"12.6#/ft Hydril 521 C-110 Liner HLB 4-1/2"RapidStage Ball Actuated Sleeve#7(2.681 ball/2.628 Seat)w/15ft 4-1/2"P-110 Pup 4- '7 I I 49 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 18,402 6,155 4.5' �� Ins' I I 50 4-X"12.6#/ft Hydril 521 C-110 Liner I 1 6"Conductor Halliburton Swell Packer#7(4-W Hydril 521)OD5.85'-9meter long oil activated with Slide on A ': -65,.: 3 51 Volant Centralizer Pin End and 6ft Pup 4-1/2"126#/ft P-110 Hydril 521 Box x Pin w/Slide On 18 = I Packer Fluid mix: Volant Centralizer on Top of Swell Packer Inhibited Kill 52 4-X"12.6#/ft Hydril 521 C-110 Liner weight Brine53 HLB4-1/2"RapidStageBallActuatedSleeve#6(2.603 ball/2.552 Seat)w/15ft41/2"P-110 Pup 4- 19,048 6,164 GIAL, with 2000'TVD 1/Y'12.6#/ft P-110 Hydril 521 Box Pin DGLV © GL I diesel cap 54 4-X"12.6#/ft Hydril 521 C-110 Liner Installed 1 55 ResmanInternally Vented Carrier#2ROS-1366/RWS-1393 w/15ft Pup BxP Top&Bottom 19,117 6,165 7,000 psi 0 .)x I 56 4-X"12.6#/ft Hydril 521 C-110 Liner Max r ' 11-3/4"60#L-80 Halliburton Swell Packer#6(4W'Hydril 521)OD5.85'-9meter long oil activated with Slide on BTC Surface Casing 57 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 19,358 iiii: I ►n @ 6,548'MD/ Volant Centralizer on Tbp of Swel. 3,211'TVD 58 4-X"12.6#/ft Hydril 521 C-110 Liner cemented to surface 4 59 HLB4-1/2"RapidStage Ball Actuated Sleeve#5(2527 ball/2.477 Seat)w/15ft 4-1/2"P-110 Pup19,658 6,174 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 60 4-%"12.6#/ft Hydril 521 C-110 Liner TOC Halliburton Swell Packer#S(4-X"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on ('-1 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ftP-l10 ti h,dril 521 Box x Pin w/Slide On 7^,890 GLM#2 I Estimated Volant Centralizer on Top of Swell Packer 5/16 OV I @ 500 ft 62 4-'4"12.61f/ft Hydril 521 C-110 Liner Installed 0 GL above 9-5/8" HLB4-1/2"RapidStage Ball Actuated Sleeve#4(2.452ball/2.404Seat)w/15ft4-1/2"P-110 Pup 4- 7,000 psi Shoe 63 1/2"12.6#/ft P-110 Hydri I 521 Box x Pin 20,113 6,180 Max rated 11 ''I x I`. 64 4-/,"12.6#/ft Hydril 521 C-110 Liner Halliburton Swell Packer#4(4X'Hydril 521)OD 5.85'-9 meter long oil activated with S 9-5/8"40#L-80 65 Volant Centralizer Pin End and 6ft Pup 4-1./2"126#/ftP-110Hydril 521 Box x Pin w/Slide On 20,386 • Hydril 521 Volant Centralizer on Top of Swell Packer Intermediate 1 66 4-'/="12.6#/ft Hydril 5210-110 Liner PCasing HL8 4-1/2"RapidStage Ball Actuated Sleeve#3(1379 ball/2.332 Seat)w/15ft 4-1/2"P-130 Pup 4 I ,r7 @ 11,717'MD/ 67 ig'12.6#/ft P-110 Hydril 521Box xPin 4,915'TVD 68 4-W 12.6#/ft Hydril 521 C-110 Liner 20,801 6,177 69 Resman Internally Vented Carrier#1 ROS-1365/RWS-1392 w/15ft Pup BxP Top&Bottom 20,994 6,178 GLM#1 • 70 4-'''/"12.6#/ft Hydril 521 C-110 Liner DGLV I ES Cementer Halliburton Swell Packer 83(4-W'Hydri1521)OD&85'-9meter long oil activated with Slide on Installed® Base Torok 71 Volant Centralizer Pin End and 6ft Pup 4-1/2"126#/ftP-110Hydril 521Box xPin w/Slide On 21.073 9,178 7,000 psi® • Volant Centralizer on Top of Swell Packer Max rated x I 72 4-X"12.6#/ft Hydril 521 C-110 Liner I 73 HLB4-1/2"RapidStage Ball Actuated Sleeve(2.307 ball/1261 Seat)w/15ft 4-1/2"P-110 Pup 4 - 21,359 6,1790 7"Stage 2 TOC 1/z ]2.6#/ftP-110 Hydril Rx Estimated 74 4-X"12.6#/ft Hydril 521 C-110 Liner Sliding Sleeve @ 500 ft above Halliburton Swell Packer#2(4X"Hydril 521)ODS.85'-9meter long oil activated with Slide on Closed 000 Torok Sand 75 Volant Centralizer Pin End and 6ft Pup 4-1/2"126#/ft P-110 Hydril 521 Box x Pin w/Slide On 21,596 6,183 (Up to Package Volant Centralizer on Top of Swell Packer - 76 4-'/,"12.6#/ft Hydril 521 C-110 Liner 77 HLB4-1/2"RapidStage Ball Actuated Sleeve(2.236ball/1192Seat)w/15ft41/2"P-110 Pup 4 2 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 1'929 6,191 'stimated tage 1 TOC 78 4-X"12.6#/ft Hydril 521 C-110 Liner Halliburton Swell Packer#1(4-W Hydril 521)OD5.85'-9meter long oil activated with Slide on 00 ft above 79 Volant Centralizer Pin End and 6ft Pup 41/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 22,114 6,195 K Lipa r u k Volant Centralizer on Top of Swell Packer 80 4-St' 12.6#/ft Hydril 521 C-110 Liner 81 Pre-perforated Pup w/4-55"12.6#/ft Hydril 521 w/lSft 4-1/2"P-110 Pup BxP Top&Bottom 22,147 6,195 82 4-'',"12.6#/ft Hydril 521 C-110 Liner 83 4-'/:"Hydril 521 Eccentric Shoe with Float Collar 22,204 6,197 Bottom of Assembly 22,205 6,197 \ 0 7"26# L-80 BTC-M </i# �� 0 &Hydril 563 ���% 33 Intermediate 2 r ® ' c±_ .-- - - oo--o-o-o®-0-0--caCasing �, �� • a7 s, s7 s1ss71 7s7s�� 55 69 83 @ 10,699' MD/ 2s ®�:\ ss. I- ® -I -I I- - M I- M - - I-I e / 6,077'TVD � f`' , 45 M a9 53 s9 N s3 N 67 'a, e 77 N 81 -- 4-W Hydril 521 /C-110 Liner with Halliburton Ball Actuated 6-1/8" Hole TD Sleeves, & Swell Packers @ 22,208 MD / 6,197'TVD • • Schlumberger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States FracCAT Treatment Report Well :ODSN-22i,Stages 1-4 Field :Oooguruk Formation : Nuiqsut Prepared for Client :Caelus Energy Alaska Client Rep :Mike Martin Date Prepared :02/24/16 Prepared by Name :Scott Leahy Division :Schlumberger Phone :907-330-4595 Pressure(All Zones) Initial Wellhead Pressure(psi) 654 Initial BHP at Gauge(psi) 3,153 Final Surface ISIP(psi) 1,670 Final ISIP at Gauge(psi) 4,150 Surface Shut in Pressure(psi) 1,500 BH Shut in Pressure(psi) 3,954 Maximum Treating Pressure(psi) 8,692 BH Gauge at 14,657'MD,5,884'TVD Treatment Totals(All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant)(bbls) 6,265 Total YF127ST Past Wellhead(bbls) 4983 Total WF125 Past Wellhead(bbls) 589 Total Freeze Protect Past Wellhead 43 (bbls) Total Proppant Pumped(lbs.) 606,617 Total Proppant in Formation(lbs.) 606,617 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103(gal) 243 243 M275(lbs.) 84 83 L065(gal) 483 483 J218(lbs.) 220 220 J580(lbs.) 6,508 6,485 J475(lbs.) 1,348 1,348 J922(mgal) 210 210 J134(lbs.) 9 0 J510(bbls) 0 1.2 Freeze Protect 0 43 D206(gal) 0 2.5 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • • Schiumberger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuigsut District:Prudhoe Bay Country:United States SUMMARY On February 21,2016,Schlumberger finished stages 1-4 for the ODSN-22 well.The treatment consisted of 4 stages with 3 Rapidball DM and 1 Rapidball DM-XT ball drops. Approximately 606,617 lbs of proppant in 6,265 bbl of slurry was pumped during this treatment.And the end of the treatment, a 2.452"Rapidball DM-XT was dropped to complete stage 4 and open port 4 for Stage 5 on the next fracture treatment day. The job was delayed at the start by an hour due to an ice plug within the 8"hose connecting the POD to the PCM. At the end of the treatment,just as the final ball was seating,the network dropped out to the FracCAT computer and acquisition for slurry rate was lost. The well was freeze protected using physical straps from the freeze protect transport. All stages were pumped as designed and the summary for the totals is noted below. Materials Actual (Design) Slurry Volume-All Volumes(bbl) 6,265(6,377) Clean Fluid-All Volumes(bbl) 5,636(5,720) Proppant,lbs. 606,617(604,632) Treating Pressure Pressure Test — BHP Caetus Energy Alaska - Annulus Pressure ODSN-22 Stages 1d 02-21-2016 — Slurry Rate 10000 - Pro>Con 50 PCM Viecodty — 0000 8000 40 a ]000 y 8000 30 S 5000 1>° 4000 20 N 3000 _ 3 2000- .I 10 1000 ELE 1222:02 12:30:22 12:38.42 12:47:02 12.5522 Time-hh:mm:ss ®Schlumbemer 1994-2015 Schlumberger • • Prop Con-PPA&Rate-bbl/min C 0 0 Oo 0 0 0 7,- OA ai C 111 as Y a us•ct E R ... d Coll wNo ,I y 3ZN 1' y0N _ 1 V O o 2-----,...r ...--4 , tt ____ ip IC i v INN6. L ,_Y ` d NO. aCD Q OI N a O Noi , c 3 �U 5,wN .-m � a C = o0 2 c a. _ - rmav> a a In .=O •- ,-0oz� >. II III I eCfl n c CO N E 15 o U LLo m z > E _ th ._ ._ 1 d - .\\L. 1 co__ J ' ! LC ,. 4C ii 4,, O N .4- 0 1111 0 f 1 i C = _ 1 ..- 1:11 :22:1-.1 1 yr I O as N 011. a3 Gal • NM NM 0:1 z--; a i N a CD CID o0 0 0 o 0 0 o o o W m r f0 N O No Lo = co !ad-a�nssaid al= • • Schiumberger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Stage 1 Stage 1 consisted of a PAD,8 proppant steps(1-8PPA),a ball drop and a flush. A total of 403.1 bbls of slurry was pumped during this stage with 41,443 lbs of proppant.The maximum treating pressure for stage 1 was 8,536 psi..Flush at the WH was called at 738 bbls and the 2.236"Rapidball DM ball was dropped at 765 bbls to open Port 1 for Stage 2. The ball seated at 1,077 bbls of total slurry. Summary of Pressures When Ball Seats 2.236" Ball Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure N/A 4,270 3,050 Bottomhole Pressure N/A 5,522 4,760 Summary of Stage 1 Total Proppant Pumped(Ib) 41,443 Max pumping Rate(bpm) 40.4 Total Proppant in Formation(Ib) 41,443 Average Pumping Rate(bpm) 30.9 Total Slurry Pumped(bbl) 765.6 Maximum Treating Pressure(psi) 8,536 YF127ST Pumped(bbl) 360.2 Average Treating Pressure(psi) 6,476 WF127 Pumped(bbl) 362.5 Average Viscosity of WF127(cP) 20.95 Freeze Protect 0 Stage 1 — Treating Pressure 9 — BHP Caelus Energy Alaska Annulus Pressure ODSN-22 Stages 1d 02.21.2016 - Slurry Rate 10000 - Prop Con 50 0000 PCM Viscosity 6000 -401 40 r000 �i�` 161111111111111111 / i. r "111 4 ‘ o I m 6000 1,1 4IA5 j 30 V 5000 a 4000 1 20 P 3000 C 3 S 000 m 1000 ,_J ` 15:52.4, 15:59 21 16'.00:01 16.12:41 10:19 21 Time-hh:mm:ss • ©Schlumberger 1994-2015 Schlumberger • • Schlombepger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Stage 2 Stage 2 consisted of a PAD,8 proppant steps(1-8PPA),a ball drop and a flush. A total of 1,347 bbls of slurry was pumped during this stage with 145,234 lbs of proppant.The maximum treating pressure for stage 2 was 8,587 psi. Flush at the WH was called at 2,087 bbls and the 2.307"Rapidball DM ball was dropped at 2,113 bbls to open Port 2 for Stage 3. The ball seated at 2,417 bbls of total slurry. Summary of Pressures When Ball Seats 2.307" Ball Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure 2,955 5,552 N/A Bottomhole Pressure 4,710 6,992 N/A Summary of Stage 2 Total Proppant Pumped(Ib) 145,234 Max pumping Rate(bpm) 39.4 Total Proppant in Formation(Ib) 145,234 Average Pumping Rate(bpm) 36.0 Total Slurry Pumped(bbl) 1347 Maximum Treating Pressure(psi) 8587 YF127ST Pumped(bbl) 1197 Average Treating Pressure(psi) 7279 WF127 Pumped(bbl) 0 Average Viscosity of WF127(cP) 20.11 - Treating Pressure Stage 2 — BHP Caelus Energy Alaska - Annulus Pressure ODSN-22 Stages 1-4 02-21-2016 — Slurry Rate 10000 - Proo coo 50 PCM Viscosity 9000 0000 40 000 Y a° n I 6000 - I 30 i 5000 1 a a4000 - ----- _ -__ ___ _ ----- ,4 ----- Sai 10 1 3000 3 2000 S.10 1000 ,-- -i l 45 16'.11 16 16:2].41 10'.36'.06 10'.46:31 16:56'.56 Time-hh:mm:ss S Schlumberger 1594-2016 Schlumberger • • Schiuntherger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Stage 3 Stage 3 consisted of a PAD, 8 proppant steps(1-8PPA),a ball drop and a flush stage. A total of 1854 bbls of slurry was pumped during this stage with 213,539 lbs of proppant.The maximum treating pressure for stage 3 was 8,449 psi.Flush at the WH was called at 3,937 bbls and the 2.379"Rapidball DM ball was dropped at 5,778 bbls to open Port 3 for Stage 4. The ball seated at 4,263 bbls of total slurry. Summary of Pressures When Ball Seats 2.379" Ball Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure 3,135 5,838 N/A Bottomhole Pressure 4,800 6,944 N/A Summary of Stage 3 Total Proppant Pumped(Pb) 213,539 Max pumping Rate(bpm) 40.9 Total Proppant in Formation(Ib) 213,539 Average Pumping Rate(bpm) 37.0 Total Slurry Pumped(bbl) 1,854 Maximum Treating Pressure(psi) 8,449 YF127ST Pumped(bbl) 1,633 Average Treating Pressure(psi) 7,251 WF127 Pumped(bbl) 0 Average Viscosity of WF127(cP) 19.37 Stage 3 = Treating Pressure Caelus Energy Alaska - Annulus Pressure ODSN-22 Stages 1-4 02-21-2016 — Slurry Rate 10000 '— Prov Cont 50 — PCM Viscosity 9000- i' .'- ' ,_ I 8000 ao 1000` --''''./ki 1 5000 0 S 6000 20 F 3000— n— L,_____ ___,-,' 3000 10 1000 I. 1 -/ r 16 50.40 17.07:20 n:ze.oe 174'0.06 n.5r:z0 Time-hh:mm:ss ©Schlumberaer 1994-2015 Schlumberger • • Sch1omheger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Stage 4 Stage 4 consisted of a PAD, 8 proppant steps(1-8PPA),a ball drop and a flush stage. A total of 2,298 bbls of slurry was pumped during this stage with 206,400 lbs of proppant.The maximum treating pressure for stage 4 was 8,692 psi. Flush at the WH was called at 5,801 bbls and the 2.452"Rapidball DM-XT ball was dropped at 5,831 bbls to open Port 4 for Stage 5 which would be pumped on another day. The ball seated at 6,115 bbls of total slurry. Summary of Pressures When Ball Seats 2.452" Ball Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure 3,400 3,558 3,330 Bottomhole Pressure 5,070 5,144 4,770 Summary of Stage 4 Total Proppant Pumped(Ib) 206,400 Max pumping Rate(bpm) 41.0 Total Proppant in Formation(lb) 206,400 Average Pumping Rate(bpm) 36.8 Total Slurry Pumped(bbl) 2,298 Maximum Treating Pressure(psi) 8,692 YF127ST Pumped(bbl) 1,793 Average Treating Pressure(psi) 7,021 WF127 Pumped(bbl) 227 Average Viscosity of WF127(cP) 19.18 Freeze Protect 65 Stage 4 — Treating Pressure 9 — BHP Caelus Energy Alaska Annulus Pressure ODSN-22 Stages 1d 02.21-2016 Slurry Rate 10000 - Pros Con, 50 soon PCM Viscosity Lost (work E:::::$ S 9 30 i Back on Network 9 1000 a r � e. A a 1000, -._—_.—_.-..^-_•-- - ——, __- --�-- ~v —rv- 20 3000 E 4,J E 1000 10 1000 / . 1 n 37 s e 1,51308 181'818 18 0'018 19.01.18 Time-hh:mm:ss ©Schlumberger 1994-2015 Schlumberger • • c ' banger Client:Caelus Energy Alaska !" Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Stage 1 : As Measured Pump Schedule As Measured Pump Schedule Step Step Slurry Slurry Pump Fluid MaxrProp # Name Volume Rate Time Fluid Name Volume Proppant Name Cone Mass (bbl) (bbl/min) (min) (gal) (PPA) (lb) Breando 1 362.5 26.3 20.1 WF127 15223 0.0 0 2 SPAp 1 88.9 27.7 4.1 YF127ST 3734 CarboLite w/5%ScaleGuard 0.0 2 16/20 3 1.0 PPA 20.0 40.3 0.5 YF127ST 822 CarboLite w/5%ScaleGuard 0.9 379 16/20 4 2.0 PPA 30.0 39.5 0.8 YF127ST 1169 CarboLite w/5%ScaleGuard 2.0 2062 16/20 5 3.0 PPA 40.0 39.1 1.0 YF127ST 1494 CarboLite w/5%ScaleGuard 3.0 4243 16/20 6 4.0 PPA 40.0 38.8 1.0 YF127ST 1437 CarboLite w/5%ScaleGuard 4.0 5556 16/20 7 5.0 PPA 40.0 38.7 1.0 YF127ST 1385 CarboLite w/5%ScaleGuard 5.1 6769 16/20 8 6.0 PPA 40.0 37.9 1.1 YF127ST 1332 CarboLite w/5%ScaleGuard 6.6 8001 16/20 9 7.0 PPA 30.0 32.2 0.9 YF127ST 969 CarboLite w/5%ScaleGuard 7.1 6687 16/20 10 8.0 PPA 25.0 31.9 0.8 YF127ST 782 CarboLite w/5%ScaleGuard 8.1 6148 16/20 11 Clear 22.9 32.4 0.7 YF127ST 898 CarboLite w/5%ScaleGuard 8.0 1591 Surface 16/20 12 Spacer 23.4 28.3 0.9 YF127ST 981 CarboLite w/5%ScaleGuard 0.0 4 16/20 13 Ball 3.0 21.6 0.1 YF127ST 126 -0.0 0 2.236" Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Breakdown 26.3 40.4 5160 7122 928 2 Stage 1 PAD 27.7 40.3 4784 7099 1240 3 1.0 PPA 40.3 40.4 7181 7236 7104 4 2.0 PPA 39.5 40.0 7247 7296 7223 5 3.0 PPA 39.1 39.2 7401 7484 7296 6 4.0 PPA 38.8 39.1 7560 7667 7484 7 5.0 PPA 38.7 38.9 7846 8068 7667 8 6.0 PPA 37.9 38.5 8082 8349 7007 9 7.0 PPA 32.2 33.3 6939 7130 6833 10 8.0 PPA 31.9 32.0 7291 7409 7145 11 Clear Surface 32.4 33.5 7640 7955 7410 12 Spacer 28.3 33.8 6223 7992 4664 13 Ball 2.236" 21.6 21.6 4776 4928 4682 • • Scb1umIieger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Stage 1 : Job Messages Message Log Message Treating Annulus Stage 1 Slurry Rate Prop.Conc. # Time Pressure Pressure Slurry (psi) (psi) (bbl) (bbl/min) (PPA) 1 6:00:11 Arrived on location 0 0 0.0 0.0 0.0 2 6:22:23 Waiting on LAS unit from Deadhorse,caught 0 0 0.0 0.0 0.0 behind rig move 3 10:10:30 LAS unit arrived on location 0 0 0.0 0.0 0.0 4 10:14:11 LAS Being fueled 0 0 0.0 0.0 0.0 5 10:24:24 Rigging LAS in 0 0 0.0 0.0 0.0 6 11:40:04 Bringing up blender pressure 8 -9 0.0 0.0 0.0 7 11:44:05 1"open back to blender,priming pumps 40 -9 0.0 0.0 0.0 8 12:10:36 All pumps primed,warming lines 45 -9 0.0 4.3 0.0 9 12:11:28 Setting popoff pressure to 11k psi 63 -9 0.0 0.0 0.0 10 12:13:47 LRS bringing IA to 2500psi 49 -9 0.0 0.0 0.0 11 12:24:35 Low pressure stall 191 2493 0.0 0.3 0.0 12 12:28:21 Walking pressure up to 7k psi 2082 2464 0.0 0.0 0.0 13 12:30:44 Pumps down,brakes set 7035 2455 0.0 0.0 0.0 14 12:32:46 bumping ball dropper van pressure 7268 2450 0.0 0.0 0.0 15 12:33:08 clear all around,coming up to 9500 psi 7213 2449 0.0 0.0 0.0 16 12:35:21 Equalizing ball dropper van pressure,going to 9278 2444 0.0 0.0 0.0 9500psi 17 12:38:04 pumps down,brakes set 9580 2440 0.0 0.0 0.0 18 12:44:28 Pressure test successful,bleeding pressure to 9109 2421 0.0 0.0 0.0 zero 19 12:45:52 Gathering for safety meeting 4 2418 0.0 0.0 0.0 20 13:11:35 pump 7 shut high and low 27 2360 0.0 0.0 0.0 21 13:17:39 safety meeting done 17 2348 0.0 0.0 0.0 22 13:17:52 batching up gel 17 2348 0.0 0.0 0.0 23 13:41:56 Hydraulic Valve Open 246 2301 0.0 0.0 0.0 24 13:42:13 Swab Open 23.5 Turns 242 2301 0.0 0.0 0.0 25 13:42:20 Equalizing Wellhead 324 2299 0.0 0.6 0.0 26 13:43:22 Master Open 23.5 Turns 667 2296 0.0 0.0 0.0 27 13:45:53 Displacing Line Volumes 846 2313 0.0 1.5 0.0 28 13:55:34 Surface Lines Displaced.Shutdown for 10minutes 1354 2189 0.0 0.0 0.0 29 14:05:45 Start Breakdown Automatically 1267 2248 0.0 0.0 0.0 30 14:05:45 Started Pumping 1267 2248 0.0 0.0 0.0 31 14:05:56 Start pump check 1349 2254 0.0 1.0 0.0 32 14:07:32 Activated Extend Stage 6591 2712 22.9 23.8 0.0 33 14:15:51 Troubleshooting POD,unable to balance rates 1473 2292 124.1 0.0 0.0 34 14:35:10 preparing to go downhole 1391 2395 124.1 0.0 0.0 35 14:36:54 Pumps down,brake set. 1455 2404 126.6 0.0 0.0 36 14:37:21 investigating possible flow restriction in PCM 1441 2402 126.6 0.0 0.0 discharge 37 14:38:30 Displacing lines,warming iron 1395 2402 126.6 0.0 0.0 38 14:42:30 Rolling fresh fluid through all pumps 2366 2459 154.8 10.1 0.0 39 14:43:02 pumps down,brakes set 1331 2355 158.0 0.0 0.0 40 15:34:39 Moving fluid through 8"PCM hose 1075 2355 158.0 0.0 0.0 0 • ScIi1umLieger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Message Log Message Treating Annulus Stage 1 Slurry Rate Prop.Conc. # Time Pressure Pressure Slurry (psi) (psi) (bbl) (bbl/min) (PPA) 41 15:37:16 _coming up to rate 4737 2611 193.0 23.6 0.0 42 15:41:50 Stage at Perfs:Breakdown 6225 2553 358.7 40.4 0.0 43 15:47:04 Bringing IA up to 3,100psi 1258 2523 362.5 0.0 0.0 44 15:47:17 adjusting popoff pressure to 9300psi 1253 2596 362.5 0.0 0.0 45 15:49:10 2.236"ball loaded 1249 3173 362.5 0.0 0.0 46 15:52:57 getting ready all around 1240 3167 362.5 0.0 0.0 47 15:54:06 Start Stage 1 PAD Manually 1240 3167 362.5 0.0 0.0 48 15:56:26 Zero'd densitometer in PAD 3190 3290 392.5 19.4 0.0 49 15:56:32 _coming up to rate 3579 3286 394.6 22.7 0.0 50 15:58:05 Started Pumping Prop 7099 3557 447.3 40.3 0.0 51 15:58:11 Start 1.0 PPA Manually 7126 3557 451.4 40.4 0.0 52 15:58:41 Start 2.0 PPA Automatically 7236 3556 471.5 39.8 0.9 53 15:59:27 Start 3.0 PPA Automatically 7296 3550 501.7 39.2 2.0 54 16:00:23 XL sample-good 7493 3602 538.2 39.0 3.0 55 16:00:28 Start 4.0 PPA Automatically 7493 3600 541.4 39.1 3.0 56 16:01:30 Start 5.0 PPA Automatically 7694 3622 581.5 38.9 4.0 57 16:02:32 Start 6.0 PPA Automatically 8102 3658 621.4 38.5 4.9 58 16:03:36 _Start 7.0 PPA Automatically 6856 3522 661.4 32.8 6.4 59 16:04:32 Start 8.0 PPA Automatically 7172 3550 691.4 32.1 7.0 60 16:05:19 Start Clear Surface Automatically 7447 3580 716.4 31.8 8.0 61 16:05:23 Activated Extend Stage 7465 3582 718.6 31.8 7.9 62 16:05:27 Stage at Perfs:Stage 1 PAD 7479 3585 720.7 31.4 6.7 63 16:06:01 Deactivated Extend Stage 7978 3635 739.2 33.7 -0.0 64 16:06:01 Start Spacer Manually 7978 3635 739.2 33.7 -0.0 65 16:06:36 Activated Extend Stage 4723 3411 756.0 22.8 -0.0 66 16:06:54 Deactivated Extend Stage 4778 3411 762.6 21.6 -0.0 67 16:06:54 Start Ball 2.236" Manually 4778 3411 762.6 21.6 -0.0 Stage 2: As Measured Pump Schedule As Measured Pump Schedule Ste Ste Slurry Slurry Pump Fluid MaxrProp p p Volume Rate Time Fluid Name Volume Proppant Name p Mass / Name c (bbl) )bbl/min) (min) (gal) PPA) (Ib) 1 Stage 2 303.0 34.9 8.8 YF127ST ) 12726 CarboLite w/5%ScaleGuard 0.0 0 PAD 16/20 SlSeafor 2 31.2 18.8 2.2 YF127ST 1310 0.0 0 ResumPAD a 3 36.3 25.9 1.5 YF127ST 1525 0.0 0 4 1.0 PPA 80.0 36.5 2.2 YF127ST 3234CarboLite w/5%ScaleGuard 1.0 2892 16/20 5 2.0 PPA 110.0 37.9 2.9 YF127ST 4257 CarboLite w/5%ScaleGuard 2.0 8313 16/20 6 3.0 PPA 135.0 38.4 3.5 YF127ST 5016 CarboLite w/5%ScaleGuard 3.1 15004 16/20 7 4.0 PPA 135.0 37.8 3.6 YF127ST 4827 CarboLite w/5%ScaleGuard 4.2 19360 16/20 • • Schlumberger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Step Step Volume Rate Time Fluid Name Volume Proppant Name Prop Mass # Name c (bbl) (bbl/min) (min) (gal) PPA) (Ib) ) 8 5.0 PPA 134.3 38.8 3.5 YF127ST 4630 CarboLite w/5%ScaleGuard 5.1 23223 16/20 9 6.0 PPA 135.0 38.3 3.5 YF127ST 4488 CarboLite w/5%ScaleGuard 6.1 27167 16/20 10 7.0 PPA 110.0 37.1 3.0 YF127ST 3536 CarboLite w/5%ScaleGuard 7.1 24905 16/20 11 8.0 PPA 90.0 36.5 2.5 YF127ST 2801 CarboLite w/5%ScaleGuard 8.2 22506 16/20 12 Clear 23.8 36.7 0.6 YF127ST 924 CarboLite w/5%ScaleGuard 8.0 1857 Lines 16/20 13 Spacer , 20.7 27.4 0.9 YF127ST 870 CarboLite w/5%ScaleGuard 00 7 16/20 14 Ball 3.0 19.5 0.2 YF127ST 126 CarboLite w/5%ScaleGuard 0.0 0 2.307" 16/20 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Stage 2 PAD 34.9 38.3 7671 8436 4888 2 Slow for Sea 18.8 36.8 4013 7035 3135 3 _Resume PAD 25.9 36.5 5078 6284 3268 4 1.0 PPA 36.5 37.1 6512 6682 6284 5 2.0 PPA 37.9 38.3 6960 7062 6614 6 3.0 PPA 38.4 38.6 6997 7094 6765 7 4.0 PPA 37.8 38.5 7135 7371 6705 8 5.0 PPA 38.8 39.3 7910 8168 7429 9 6.0 PPA 38.3 39.2 8158 8202 8092 10 7.0 PPA 37.1 37.8 8200 8294 8124 11 8.0 PPA 36.5 36.9 8352 8404 8298 12 Clear Lines 36.7 37.6 8447 8550 8390 13 Spacer 27.4 37.7 5460 8495 2961 14 Ball 2.307" 19.5 20.0 4406 4532 4288 Stage 2: Job Messages Message Log Message Treating Annulus Stage 2 Slurry Rate Prop.Conc. # Time Pressure Pressure Slurry (psi) (psi) (bbl) (bbl/min) (PPA) 1 16:07:03 Start Stage 2 PAD Automatically 4980 3434 0.0 21.5 -0.0 2 16:07:55 Stopped Pumping Prop 7598 3641 22.4 31.5 -0.0 3 16:08:35 Stage at Perfs:1.0 PPA 8193 3632 44.2 34.3 0.0 4 16:09:10 Stage at Perfs:2.0 PPA 7950 3542 64.5 34.1 0.0 5 16:09:12 slow to seat 2.307"ball at 1068 8010 3557 65.7 34.1 0.0 6 16:09:39 walking down rate,riding pressure 7905 3557 81.0 34.0 0.0 7 16:10:03 Stage at Perfs:3.0 PPA 7831 3571 94.6 34.0 0.0 • • Schiumlierger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuigsut District:Prudhoe Bay Country:United States Message Log Message Treating Annulus Stage 2 Slurry Rate Prop.Conc. # Time Pressure Pressure Slurry (psi) (psi) (bbl) (bbl/min) (PPA) 8 16:11:13 Stage at Perfs:4.0 PPA 7209 3576 134.1 32.8 0.0 9 16:12:23 Stage at Perfs:5.0 PPA 8079 3641 174.2 36.4 0.0 10 16:12:52 XL pH=8.6 8344 3637 192.4 38.1 0.0 11 16:13:14 2.307"ball is loaded 8257 3600 206.4 38.3 0.0 12 16:13:26 Stage at Perfs:6.0 PPA 8188 3596 214.1 38.3 0.0 13 16:14:29 Stage at Perfs:7.0 PPA 7877 3596 254.2 38.2 0.0 14 16:15:17 Stage at Perfs:8.0 PPA 7181 3485 284.0 36.8 0.0 15 16:15:48 Start Slow for Sea Automatically 6994 3492 303.0 36.8 0.0 16 16:15:59 Stage at Perfs:Clear Surfac 3913 3305 309.0 26.6 0.0 17 16:16:21 Activated Extend Stage 3693 3176 315.1 12.0 0.0 18 16:17:46 Stage at Perfs:Spacer 3290 3232 331.6 11.8 0.0 19 16:17:58 Deactivated Extend Stage 3506 3243 334.0 11.7 0.0 20 16:17:58 Start Resume PAD Manually 3506 3243 334.0 11.7 0.0 21 16:18:09 bringing rate back to 40 bpm 3972 3264 336.5 15.5 0.0 22 16:18:58 Stage at Perfs:Ball 2.236" 5204 3357 355.3 27.3 0.0 23 16:19:05 Stage at Perfs:Stage 2 PAD 5813 3415 358.7 31.2 0.0 24 16:19:05 Activated Extend Stage 5813 3415 358.7 31.2 0.0 25 16:19:25 Deactivated Extend Stage 6325 3466 370.3 36.6 0.0 26 16:19:25 Start 1.0 PPA Manually 6325 3466 370.3 36.6 0.0 27 16:19:27 Started Pumping Prop 6302 3464 371.5 36.6 0.0 28 16:21:37 Start 2.0 PPA Automatically 6692 3524 450.6 36.3 1.0 29 16:24:31 Start 3.0 PPA Automatically 7044 3545 560.5 38.4 2.0 30 16:24:35 XL pH=8.6 7049 3548 563.0 38.3 2.0 31 16:27:51 Stage at Perfs:Resume PAD 7076 3496 688.4 38.5 3.0 32 16:28:02 Start 4.0 PPA Automatically 7104 3518 695.4 38.4 3.0 33 16:28:48 Stage at Perfs:1.0 PPA 7159 3495 724.8 38.3 4.0 34 16:30:21 Dropping rate on pump 5 7058 3450 783.8 37.2 3.9 35 16:30:55 Stage at Perfs:2.0 PPA 7067 3473 805.2 37.9 4.0 36 16:31:06 Middle chief bin 4 empty 6687 3443 811.9 35.5 4.2 37 16:31:15 Transferring J532to LAS 6920 3447 817.3 36.3 3.9 38 16:31:37 Start 5.0 PPA Automatically 7470 3485 830.9 38.1 3.9 39 16:33:48 Stage at Perfs:3.0 PPA 8092 3510 915.3 39.1 5.0 40 16:35:04 Start 6.0 PPA Automatically 8170 3521 964.9 39.0 5.0 41 16:35:48 pressurizing van to 5,000psi 8175 3521 993.4 38.8 6.1 42 16:36:49 adjusting rates for pressure 8216 3522 1032.5 38.2 6.0 43 16:37:17 Stage at Perfs:4.0 PPA 8120 3521 1050.3 37.9 6.0 44 16:38:36 Start 7.0 PPA Automatically 8211 3531 1100.0 37.9 6.0 45 16:40:54 Stage at Perfs:5.0 PPA 8253 3507 1185.5 37.0 7.0 46 16:41:34 Start 8.0 PPA Automatically 8307 3517 1210.1 36.9 6.9 47 16:44:02 Start Clear Lines Automatically 8399 3517 1300.0 36.0 8.0 48 16:44:34 Stage at Perfs:6.0 PPA 8527 3535 1319.6 37.6 -0.0 49 16:44:40 Start Spacer Manually 8459 3539 1323.4 37.7 -0.0 50 16:45:34 Start Ball 2.307"Manually 4403 3269 1344.1 19.4 -0.0 • . SChlUinherger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Stage 3: As Measured Pump Schedule As Measured Pump Schedule Step Step Slurry Slurry Pump Fluid Prop Prop # Name Volume Rate Time Fluid Name Volume Proppant Name Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (lb) 1 Stage 3 295.0 37.4 8.0 YF127ST 12390 -0.0 0 PAD Slow for 2 12.3 18.2 0.9 YF127ST 518 0.0 0 Seat ResumePAD 3 125.0 36.8 3.6 YF127ST 5250 0.0 0 4 1.0 PPA 120.0 38.4 3.1 YF127ST 4844 CarboLite w/5%ScaleGuard 1.0 4481 16/20 5 2.0 PPA 160.0 38.8 4.1 YF127ST 6186 CarboLite w/5%ScaleGuard 2.1 12261 16/20 6 3.0 PPA 199.3 38.7 5.1 YF127ST 7404 CarboLite w/5%ScaleGuard 3.0 22250 16/20 7 4.0 PPA 200.0 38.6 5.2 YF127ST 7148 CarboLite w/5%ScaleGuard 4.1 28750 16/20 8 5.0 PPA 200.0 38.4 5.2 YF127ST 6889 CarboLite w/5%ScaleGuard 5.1 34711 16/20 9 6.0 PPA 200.0 38.2 5.2 YF127ST 6646 CarboLite w/5%ScaleGuard 6.1 40295 16/20 10 7.0 PPA 160.0 37.8 4.2 YF127ST 5140 CarboLite w/5%ScaleGuard 7.1 36316 16/20 11 8.0 PPA 130.0 36.8 3.5 YF127ST 4039 CarboLite w/5%ScaleGuard 8.1 32646 16/20 12 Clear 23.1 36.9 0.6 YF127ST 897 CarboLite w/5%ScaleGuard 8.0 1828 Lines 16/20 13 Spacer 26.0 28.9 1.0 YF127ST 1092 0.0 14 Ball 3.0 21.1 0.1 YF127ST 126 0.0 0 2.379" Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Stage 3 PAD 37.4 38.9 7587 8372 4581 2 Slow for Seat 18.2 36.7 3461 5025 2540 3 Resume PAD 36.8 40.8 6749 7401 3876 4 1.0 PPA 38.4 40.4 6883 7218 6431 5 2.0 PPA 38.8 40.4 6818 7195 6330 6 3.0 PPA 38.7 39.2 6986 7097 6637 7 4.0 PPA 38.6 38.7 7238 7355 7099 8 5.0 PPA 38.4 38.6 7541 7703 7346 9 6.0 PPA 38.2 38.4 7890 8015 7703 10 7.0 PPA 37.8 38.2 8167 8303 8001 11 8.0 PPA 36.8 37.6 8272 8353 8147 12 Clear Lines 36.9 37.8 8342 8436 8285 13 Spacer 28.9 38.0 5659 8436 3794 14 Ball 2.379" 21.1 21.1 4395 4528 4334 • • Schlumherger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuigsut District:Prudhoe Bay Country:United States Stage 3: Job Messages Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 16:45:44 Start Stage 3 PAD Automatically 4668 3275 0.0 20.3 0.0 2 16:45:44 Start Propped Frac Automatically 4668 3275 0.0 20.3 0.0 3 16:45:44 Start Stage 3(Por Automatically 4668 3275 0.0 20.3 0.0 4 16:45:57 Stopped Pumping Prop 4581 3279 4.4 20.5 -0.0 5 16:46:36 On tank 13 6701 3407 21.9 31.5 0.0 6 16:46:50 2.379"Ball away at 2113 bbls 7493 3404 29.6 35.4 0.0 7 16:47:07 Slow for ball seat Q 2408 bbls 8349 3556 40.0 38.0 0.0 8 16:48:52 Stage at Perfs:7.0 PPA 8051 3527 107.4 38.6 0.0 9 16:51:43 Stage at Perfs:8.0 PPA 7470 3485 217.7 38.5 0.0 10 16:52:14 XL pH=8.6 7433 3489 237.6 38.7 0.0 11 16:53:43 Start Slow for Sea Automatically 3400 3221 294.7 27.6 0.0 12 16:55:24 2.379"Ball seat 2417 bbls 6010 3431 324.2 33.3 0.0 13 16:56:12 Stage at Perfs:Stage 3 PAD 7053 3478 354.5 39.3 0.0 14 16:57:24 Coming out of pump 4 7062 3495 402.6 39.7 0.0 15 16:58:11 Start 1.0 PPA Automatically 6454 3442 432.5 36.5 0.0 16 16:58:14 Started Pumping Prop 6568 3456 434.3 36.6 0.0 17 16:59:04 Going to 38bpm 6769 3457 464.6 36.9 1.0 18 16:59:22 On tank 12 7017 3500 476.1 38.7 1.0 19 17:00:24 Preparing to bring pump 7 online 6916 3494 516.2 38.8 1.0 20 17:01:18 Start 2.0 PPA Automatically 7186 3517 552.4 40.4 1.0 21 17:01:44 Pressure lined out,closing pump 7 high and low 7163 3518 569.8 40.2 2.1 22 17:03:31 Stage at Perfs:Slow for Sea 6687 3495 640.9 38.0 2.1 23 17:03:45 Coming out of pump 5,getting into 7 6568 3488 649.6 37.2 2.0 24 17:03:50 Stage at Perfs:Resume PAD 6252 3469 652.7 37.2 2.0 25 17:05:26 Start 3.0 PPA Automatically 6783 3488 712.1 37.7 1.9 26 17:06:34 Out of pump 5 6962 3506 756.1 38.7 3.0 27 17:07:09 Stage at Perfs:1.0 PPA 6953 3514 778.7 38.8 3.0 28 17:10:12 XL pH=8.6 7081 3539 896.8 38.8 3.0 29 17:10:14 Stage at Perfs:2.0 PPA 7085 3541 898.1 38.8 3.0 30 17:10:35 Start 4.0 PPA Automatically 7104 3546 911.7 38.6 3.0 31 17:14:23 Stage at Perfs:3.0 PPA 7323 3501 1058.2 38.6 4.0 32 17:15:46 Start 5.0 PPA Automatically 7355 3512 1111.5 38.5 4.0 33 17:15:53 On tank 11 7360 3510 1116.0 38.6 4.1 34 17:19:34 Stage at Perfs:4.0 PPA 7630 3526 1257.6 38.4 5.0 35 17:20:59 Start 6.0 PPA Automatically 7712 3483 1311.9 38.4 5.0 36 17:24:48 Stage at Perfs:5.0 PPA 7987 3485 1457.6 38.1 6.1 37 17:25:28 Troubleshooting oiler issues on pump 1 8005 3480 1483.0 38.0 6.0 38 17:26:13 Start 7.0 PPA Automatically 8028 3480 1511.6 38.2 6.0 39 17:29:10 Ball dropper van pressured up 8257 3454 1623.3 37.8 7.0 40 17:30:05 Stage at Perfs:6.0 PPA 8289 3448 1658.0 37.8 7.0 41 17:30:27 Start 8.0 PPA Automatically 8248 3439 1671.7 37.6 7.1 42 17:33:59 Start Clear Lines Automatically 8344 3485 1801.6 36.3 8.0 43 17:34:36 Start Spacer Manually 8385 3489 1824.4 38.0 -0.0 • • Schiunibergar Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Stage 4: As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Step Step Prop Volume Rate Time Fluid Name Volume Proppant Name one Mass # Name (bbl) (bbl/min) (min) (gal) PPA) (Ib) 1 Stage 4 286.0 37.9 7.7 YF127ST 12015 CarboLite w/5%ScaleGuard 0.0 0 PAD 16/20 Slow for 2 50.0 24.3 2.5 YF127ST 2100 0.0 0 Seat ResumPAD a 3 134.0 39.5 3.4 YF127ST 5628 0.0 0 4 1.0 PPA 120.0 38.7 3.1 YF127ST 4843 CarboLite w/5%ScaleGuard 1.0 4500 16/20 5 2.0 PPA 160.0 38.3 4.2 YF127ST 6188 CarboLite w/5%ScaleGuard 2.0 12206 16/20 6 3.0 PPA 199.3 38.2 5.2 YF127ST 7403 CarboLite w/5%ScaleGuard 3.1 22266 16/20 7 4.0 PPA 200.0 38.0 5.3 YF127ST 7149 CarboLite w/5%ScaleGuard 4.1 28743 16/20 8 5.0 PPA 200.0 37.8 5.3 YF127ST 6887 CarboLite w/5%ScaleGuard 5.1 34760 16/20 9 6.0 PPA 200.0 37.4 5.3 YF127ST 6648 CarboLite w/5%ScaleGuard 6.1 40272 16/20 10 7.0 PPA 160.0 36.9 4.3 YF127ST 5138 CarboLite w/5%ScaleGuard 7.1 36367 16/20 11 8.0 PPA 120.1 35.7 3.4 YF127ST 3862 CarboLite w/5%ScaleGuard 8.1 27285 16/20 12 Clear 7.3 36.2 0.2 YF127ST 305CarboLite w/5%ScaleGuard 0.1 0 Lines 16/20 13 Spacer 26.0 27.3 1.1 YF127ST 1093 CarboLite w/5%ScaleGuard 0.0 0 16/20 14 2.452" 3.0 20.9 0.1 YF127ST 126 CarboLite w/5%ScaleGuard 0.0 0 Ball 16/20 15 XL Flush 141.0 34.5 4.2 YF127ST 5922 CarboLite w/5%ScaleGuard 0.0 0 16/20 16 LG Flush 135.0 38.5 3.6 WF127 5670 0.0 0 17 SlSeat 50.0 36.4 1.5 WF127 2100 0.0 0 Seat ow 18 MT PCM 41.6 34.8 2.5 WF127 1747 0.0 0 19 Freeze 65.0 20.2 1.6 Freeze Protect 2730 0.0 0 Protect Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Stage 4 PAD 37.9 39.4 7477 8408 2608 2 Slow for Seat 24.3 39.3 4919 6431 3029 3 Resume PAD 39.5 41.0 6876 7291 6440 4 1.0 PPA 38.7 39.3 6704 6847 6609 5 2.0 PPA 38.3 38.6 6545 6605 6499 6 3.0 PPA 38.2 38.3 6600 6735 6518 • • Schiumberger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 7 4.0 PPA 38.0 38.2 6981 7209 6733 8 5.0 PPA 37.8 38.0 7488 7686 7204 9 6.0 PPA 37.4 37.7 7864 8005 7685 10 7.0 PPA 36.9 37.2 8194 8320 8045 11 8.0 PPA 35.7 36.6 8300 8431 8253 12 Clear Lines 36.2 36.3 8338 8367 8326 13 Spacer 27.3 36.4 5497 8326 4201 14 2.452"Ball 20.9 20.9 4517 4617 4352 15 XL Flush 34.5 38.5 7506 8344 4632 16 LG Flush 38.5 39.9 7242 8111 2407 17 Slow for Sea 36.4 39.2 3543 4609 2498 18 MT PCM 34.8 39.2 2982 3524 2769 19 Freeze Protect 20.2 20.2 3286 3345 1281 Stage 4: Job Messages Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 17:35:46 Start Stage 4 PAD Automatically 4673 3243 0.0 21.0 -0.0 2 17:35:46 Start Propped Frac Automatically 4673 3243 0.0 21.0 -0.0 3 17:35:57 Stage at Perfs:7.0 PPA 4828 3222 3.9 22.2 0.0 4 17:37:52 Stopped Pumping Prop 8065 3486 73.5 39.0 -0.0 5 17:40:11 Stage at Perfs:8.0 PPA 7612 3465 164.1 39.1 0.0 6 17:41:08 XL pH=8.6 7461 3451 201.3 39.1 0.0 7 17:43:29 Start Slow for Sea Automatically 3071 3175 285.8 13.3 0.0 8 17:45:56 Start Resume PAD Automatically 6463 3391 335.8 39.4 0.0 9 17:46:11 Stage at Perfs:Stage 4 PAD 6692 3410 345.6 39.4 0.0 10 17:49:12 Started Pumping Prop 6829 3420 464.8 39.3 0.0 11 17:49:20 Start 1.0 PPA Automatically 6847 3425 470.1 39.3 0.0 12 17:52:26 Start 2.0 PPA Automatically 6595 3486 589.9 38.6 1.0 13 17:56:37 Start 3.0 PPA Automatically 6508 3468 750.2 38.3 2.0 14 17:56:58 Pump side chief empty 6541 3469 763.6 38.1 3.0 15 17:58:07 Stage at Perfs:1.0 PPA 6536 3449 807.5 38.3 3.0 16 18:01:04 XL pH=8.62 6705 3469 920.0 38.1 3.0 17 18:01:16 Stage at Perfs:2.0 PPA 6724 3468 927.7 38.2 3.0 18 18:01:50 Start 4.0 PPA Automatically 6737 3452 949.3 38.1 3.0 19 18:05:29 Stage at Perfs:3.0 PPA 7117 3457 1088.0 38.0 4.0 20 18:05:49 Tanks side chief,bin 4 going empty going to bin 3 7149 3449 1100.6 38.0 4.0 21 18:07:06 Start 5.0 PPA Automatically 7195 3430 1149.3 38.0 4.0 22 18:07:35 On tank 4 7236 3454 1167.6 37.7 5.1 23 18:10:44 Stage at Perfs:4.0 PPA 7607 3463 1286.6 37.6 5.1 24 18:12:24 Start 6.0 PPA Automatically 7690 3449 1349.5 37.7 5.0 25 18:16:04 Stage at Perfs:5.0 PPA 7941 3439 1486.7 37.4 6.0 26 18:17:44 Start 7.0 PPA Automatically 7996 3443 1549.0 37.4 6.0 27 18:21:27 Stage at Perfs:6.0 PPA 8307 3468 1686.9 36.8 7.0 • III Schiumbarger Client:Caelus Energy Alaska Well:ODSN-22 Formation:Nuiqsut District:Prudhoe Bay Country:United States Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 28 18:22:04 Start 8.0 PPA Automatically 8289 3469 1709.5 36.6 7.0 29 18:25:25 Start Clear Lines Manually 8349 3468 1829.1 36.1 0.0 30 18:25:37 Start Spacer Manually 8321 3480 1836.3 36.4 -0.0 31 18:26:41 Start 2.452"Ball Automatically 4554 3228 1862.7 20.9 0.0 32 18:26:49 Start XL Flush Automatically 4632 3227 1865.4 20.8 0.0 33 18:27:32 Stage at Perfs:7.0 PPA 4952 3248 1886.5 25.5 0.0 34 18:27:38 Stopped Pumping Prop 4709 3210 1888.9 23.9 0.0 35 18:29:21 2 pumps tripped,getting back up to rate 8010 3489 1945.6 36.8 0.0 36 18:30:58 Start LG Flush Automatically 8111, 3500 2006.4 38.7 0.0 37 18:31:03 Cutting XL ads 811 3500 2009.6 38.8 0.0 38 18:32:01 Stage at Perfs:8.0 PPA 7699 3474 2047.1 38.8 0.0 39 18:32:43 Stopped mixing gel in PCM 7374 3448 20744 39.0 0.0 40 18:34:15 switched to FPC 6422 3425 2134.6 40.0 0.0 41 18:34:37 Start Slow for Sea Automatically 2801 3169 2141.5 12.2 0.0 42 18:35:37 Stage at Perfs:Clear Lines 3583 3216 2166.a 39.2 0.0 43 18:35:49 Stage at Perfs:Spacer 3455 3181 2174.1 39.2 0.0 44 18:35:54 pump at 12bpm 3469, 3185 2177. 39.2 0.0 45 18:36:16 Start MT PCM Automatically 319 4 3150 2191.8 39.2 0.0 46 18:36:24 Lost acquisition on POD,PCM,FPC 3080 3138 2197.0 39.2 0.0 47 18:37:59 still pumping 12 bpm 2773 3098 2250.9 0.0 0.0 48 18:38:29 5 pumps rolling at 20 bpm 3487 3149 2250.9 0.0 0.0 49 18:41:27 pumping down PCM 3290 3094 2250.9 0.0 0.0 50 18:41:47 feathering in freeze protect 3235 3085 2250.9 0.0 0.0 51 18:42:24 on freeze protect 3203 3076 2250.9 0.0 0.0 52 18:42:46 90bbls remaining in transport 3121 3059 2250.9 0.0 0.0 53 18:43:22 seeing freeze protect at WH 3126 3045 2259.5 20.2 0.0 54 18:43:58 Start Freeze Prote Automatically 3268 3036 2271.6 20.1 0.0 55 18:44:12 60bbls remaining 3268 3027 2276.3 20.2 0.0 56 18:44:46 50bbls remaining 3309 3005 2287.7 20.1 0.0 57 18:45:21 40bbls remaining 3336 2979 2299.5 20.1 0.0 58 18:45:30 Shutdown-35 bbls remaining,65 total pumped,43 2466 2944 2302.5 20.2 0.0 past WH 59 18:46:18 watching pressure until 19:00 and then bleeding off 1674 2844 2303.2 0.0 0.0 • • Sch1umbegerWell:ODSN-22 Stages 5-8 Formation:Nuigsut District:Prudhoe Bay,AK Country:United States FracCAT Treatment Report Well :ODSN-22i,Stages 5-8 Field :Oooguruk Formation :Nuiqsut Prepared for Client :Caelus Energy Alaska Client Rep : Mike Martin Date Prepared :03/04/16 Prepared by Name :Alexander Martinez Division :Schlumberger Phone :561-389-5006 Pressure(All Zones) Initial Wellhead Pressure(psi) 654 Initial BHP at Gauge(psi) 3,153 Final Surface ISIP(psi) 1,766 Final ISIP at Gauge(psi) 4,245 Surface Shut in Pressure(psi) 1,455 BH Shut in Pressure(psi) 3,917 Maximum Treating Pressure(psi) 8,683 BH Gauge at 14,657'MD,5,884'TVD Treatment Totals(All Zones As Per FracCAT) Total Slurry Pumped 6,972 Total YF127ST Past Wellhead(bbls) 5,753 (Water+Adds+Proppant)(bbls) Total WF127 Past Wellhead(bbls) 549 Total Freeze Protect Past Wellhead 45 (bbls) Total Proppant Pumped(lbs.) 864,000 Total Proppant in Formation(lbs.) 864,000 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103(gal) 256 256 M275(lbs.) 84 81 L065(gal) 530 530 J218(lbs.) 231 231 J580(lbs.) 6879 6879 J475(lbs.) 1540 1540 J922(mgal) 229 229 J134(lbs.) 2 0 J510(bbls) 0 1.2 Freeze Protect 0 45 D206(gal) 0 2.0 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. - •Sc • • h u b Pge Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Summary On February 23,2016,Schlumberger finished stages 5-8 for the ODSN-22 well.The treatment consisted of 4 stages with 3 Rapidball DM ball drops and one DMXT ball drop. Approximately 864,000 lbs of proppant in 6,973 bbl of slurry was pumped during this treatment.The well was freeze protected using physical straps from the freeze protect transport and it was determined that 45 bbls of freeze protect fluid made it into the well. During the treatment,wireless acquisition at the WH would momentarily drop and can be seen in the WH treating pressure and annulus pressure parameters in the plots below.After this job all wireless parameters were connected via cables.All stages were pumped as designed and the summary for the totals is noted below. Materials Actual (Design) Slurry Volume-All Volumes(bbl) 6,973(6,942) Clean Fluid-All Volumes(bbl) 6,069(6,030) Proppant,lbs. 864,000(862,600) Pressure Test — Treating Pressure Caelus Energy Alaska BHP ODSN-22 Stages 8-8 amaiii Annulus Pressure 02-23-2016 Slurry Rate Prep Corr 10000 • — PcM viscosity • 50 9000 45 • 8000 -40 7000 '35 •g 6000• 30 F • 5000 25 • ply} 4000 20 3000 15 3, 2000 10 1000 5 �►s- 0-, , -0 09:49:24 09:5514 10:01:04 10:06:54 10:12:44 Time-hh:mm:ss ©Schlumberger 1994-2016 Schlumberger • • Prop Con-PPA&Rate-bbUmin r• G. o in o in O in o in o 0D R In co . Nr 1- M M N N •- .- Lc) O� CM RLO In CD Iin L1 W N D yNN 111yNN yION ►000 - IF-4 \! NO N Nr Rcn Le,y Y IL4Ir o z a i Z. IF s 3 12 , ‘.,, ,,,,,,...:,,,,, ,,.., . EE y g hill kik a ) N L �. Ctj III II : MIIIIIMI i — a) } t t 1111 1 t S k 111 tM t N N } \-4 r N, t t i a 1 cd l N G s / O L �� 0) CO 11 4 Cam 03 IIc �� r• lC I N d aa o 12r . to 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 or, c.i ON 3 E OOOO00OOOOU) OOOO = ._ 0 1111.11. = rad-aJnssam Chi • • Sclilumbei'ger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 5 Stage 5 consisted of a PAD,6 proppant steps(1-10PPA), a ball drop and a flush. A total of 1761 bbls of slurry was pumped during this stage with 201,678 lbs of proppant.The maximum treating pressure for stage 5 was 8,683 psi. Flush at the WH was called at 1732 bbls and the 2.527"Rapidball DM ball was dropped at 1760 bbls to open Port 5 for Stage 6. The ball seated at 2,038 bbls of total slurry. Summary of Pressures When Ball Seats 2.527" Ball Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure 3,249 5,955 3,254 Bottomhole Pressure 4,797 6,385 4,733 Summary of Stage 5 Total Proppant Pumped(Ib) 201,678 Max pumping Rate(bpm) 40.6 Total Proppant in Formation(Ib) 201,678 Average Pumping Rate(bpm) 36.5 Total Slurry Pumped(bbl) 1761 Maximum Treating Pressure(psi) 8,683 YF127ST Pumped(bbl) 1248 Average Treating Pressure(psi) 7,178 WF127 Pumped(bbl) 302 Average Viscosity of WF127(cP) 18.99 Freeze Protect 0 Stage 5 — Treating Pressure Caelus Energy Alaska - BHP ODSN-22 Stages 6-8 - Annulus Pressure 02-23-2016 - Slurry Rate 10000 - PCM viscosity 50 9000 45 8000 ^ 40 7000prilillar..- 35 1 1 6000 -.. am r�1 _ 30 5000 25 4000 I�-- _ i g 3000 15 i 2000 ............. -10 1000 5 11:42:36 1 1:59:16 12:15:56 12:32:36 12:49:16 Time-hh:mm:ss Schlumberger ©Sehlumherger 1984-2015 • • SChIUMberger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 6 Stage 6 consisted of a PAD,6 proppant steps(1-10PPA), a ball drop and a flush. A total of 1,300 bbls of slurry was pumped during this stage with 171,442 lbs of proppant.The maximum treating pressure for stage 6 was 8,404 psi.Flush at the WH was called at 3,032 bbls and the 2.603"Rapidball DM ball was dropped at 3,060 bbls to open Port 6 for Stage 7. The ball seated at 3,331 bbls of total slurry. Summary of Pressures When Ball Seats 2.603" Ball Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure 3,025 5,465 2,687 Bottomhole Pressure 4,581 6,632 4,462 Summary of Stage 6 Total Proppant Pumped(lb) 171,422 Max pumping Rate(bpm) 40.6 Total Proppant in Formation(Ib) 171,422 Average Pumping Rate(bpm) 36.8 Total Slurry Pumped(bbl) 1,300 Maximum Treating Pressure(psi) 8,404 YF127ST Pumped(bbl) 1,121 Average Treating Pressure(psi) 7,174 WF127 Pumped(bbl) 0 Average Viscosity of WF127(cP) 18.43 Freeze Protect 0 , Stage 6 — Treating Pressure Caelus Energy Alaska - BHP ODSN-22 Stages 5-8 Annulun Pressure 02-23-2016 - Slurry Rate - Prop Con 10000 pcM v....ay • 50 9000 45 8000 7 -�� /--- 40 7000 .4 35 1 .p 6000 — 30 yg? O. 5000 25 9, 4000 L 'V - 20 3000 1 A....''111 15 g, 2000- f �+ - 10 1000 _5 12:32:21 12:44:51 12:57:21 13:09:51 13:22:21 Time-hh:mm:ss ©scninn n.rye r 1994-2015 Schlumberger • • Sch1umbeger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 7 Stage 7 consisted of a PAD, 6 proppant steps(1-10PPA), a ball drop and a flush. A total of 1,957 bbls of slurry was pumped during this stage with 270,314 lbs of proppant.The maximum treating pressure for stage 6 was 8,541 psi.Flush at the WH was called at 4,989 bbls and the 2.681"Rapidball DM ball was dropped at 5,017 bbls to open Port 7 for Stage 8. The ball seated at 5,278 bbls of total slurry. Summary of Pressures When Ball Seats 2.681" Ball Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure 3,633 6,060 3,176 Bottomhole Pressure 5,108 6,852 4,765 Summary of Stage 7 Total Proppant Pumped(Ib) 270,314 Max pumping Rate(bpm) 40.5 Total Proppant in Formation(Ib) 270,314 Average Pumping Rate(bpm) 36.6 Total Slurry Pumped(bbl) 1,957 Maximum Treating Pressure(psi) 8,541 YF127ST Pumped(bbl) 1,674 Average Treating Pressure(psi) 7,322 WF127 Pumped(bbl) 0 Average Viscosity of WF127(cP) 19.25 Freeze Protect 0 Stage 7 — Treating Pressure Caelus Energy Alaska - BHP ODSN-22 Stages 6-8 se Annulus Pressure 02-23-2016 - slurry Rate •vim Prop Con 10000 - PcM Viseo9ry 50 9000 45 8000 / J :.r- 4140111111111 t,p , P1 40 7000 35 1 G 6000 5000 25 p. a000 .... ._.,..s_..,..._.,........._......:41.''.\___------________. 20 _ _ T _ 3000 15 ;• 2000- r-1,11 "--1. t -10 1 000 ,.. 5 r r �- 0 13:10:05 13:26:45 13:43:25 14:0b:05 14:16:45 Time-hh:mm:ss Schlumberger ®Schlumberger 1994-2015 • • SchIumbeger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 8 Stage 8 consisted of a PAD,7 proppant steps(1-12PPA),a ball drop,flush and a freeze protect stage. A total of 1,955 bbls of slurry was pumped during this stage with 220,565 lbs of proppant.The maximum treating pressure for stage 6 was 8,582 psi.Flush at the WH was called at 6,509 bbls and the 2.761"Rapidball DM-XT ball was dropped at 6,538 bbls to open Port 8 for Stage 9. The ball seated at 6,791 bbls of total slurry. Summary of Pressures When Ball Seats 2.761" Ball _ Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure 3,025 5,465 2,687 Bottomhole Pressure 4,581 6,632 4,462 Summary of Stage 8 Total Proppant Pumped(Ib) 220,565 Max pumping Rate(bpm) 40.9 Total Proppant in Formation(Ib) 220,565 Average Pumping Rate(bpm) 36.1 Total Slurry Pumped(bbl) 1,955 Maximum Treating Pressure(psi) 8,582 YF127ST Pumped(bbl) 1,408 Average Treating Pressure(psi) 7,138 WF127 Pumped(bbl) 247 Average Viscosity of WF127(cP) 19.06 Freeze Protect 69 Stage 8 — Treating Pressure Caelus Energy Alaska - BHP ODSN-22 Stages 6-8 - Annulus Pressure 02-23-2016 essee Slurry Rate 10000 - PC/JIviscosity 50 9000 45 8000 1 " — < _,............1/4_,....4r 40 7000 ���" '"'���� y 35 a PN •pl 6000 30 9g —'.-----------"r 5000 '„�-� 25 D 4000 �— - 20 3000 t - 15 a 7 .4 2000- /` M 10 1000 f f d _.. -5 J / t . 0 14:01:33 14:18:13 14:34:53 14:51:33 15:08:13 Time-hh:mm:ss u,Schlumberger 19942015 Schlumberger • . Schlumberger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 5: As Measured Pump Schedule As Measured Pump Schedule Step Step Slurry Slurry Pump Fluid Prop Prop Prop # Name Volume Rate Time Fluid Name Volume Proppant Name Conc Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (lb) Pump 1 Check 301.8 38.3 8.6 WF127 12677 0 0 0 2 Stage PADS 351 38.4 9.8 YF127ST 14742 0 0 0 3 1.0 PPA 151 39.6 3.8 YF127ST 6098 CarboLite w/5%ScaleGuard 1.3 1.0 5518 16/20 4 3.0 PPA 149.9 39.4 3.8 YF127ST 5583 CarboLite w/5%ScaleGuard 3.1 3.0 16229 16/20 5 5.0 PPA 209.9 39 5.4 YF127ST 7238 CarboLite w/5%ScaleGuard 5.1 5.0 35857 16/20 6 7.0 PPA 189.8 38.3 5 YF127ST 6104 CarboLite w/5%ScaleGuard 7.2 7.0 42537 16/20 7 9.0 PPA 189.8 36.4 5.2 YF127ST 5715 CarboLite w/5%ScaleGuard 9.2 9.0 51383 16/20 8 10.0 PPA 164.8 34.9 4.7 YF127ST 4806 CarboLite w/5%ScaleGuard 10.1 10.0 48199 16/20 9 Clear 24.9 35.2 0.7 YF127ST 968 CarboLite w/5%ScaleGuard 10 0 1955 Lines 16/20 10 Spacer 25 30.5 0.9 YF127ST 1050 0 0 0 11 Ball 2.527 3 21.3 0.1 YF127ST 126 0 0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Pump Check 38.3 41.2 6876 8134 1139 2 Stage 5 PAD 38.4 40.5 6212 7351 1244 3 1.0 PPA 39.6 40.0 7135 7378 6985 4 3.0 PPA 39.4 39.7 6931 7003 6879 5 5.0 PPA 39.0 39.4 7323 7657 6953 6 7.0 PPA 38.3 38.9 7983 8230 7630 7 9.0 PPA 36.4 37.8 8264 8330 8188 8 10.0 PPA 34.9 35.5 8342 8399 8271 9 Clear Lines 35.2 36.3 8482 8651 8381 10 Spacer 30.5 36.4 6377 8605 3991 11 Ball 2.527 21.3 21.3 4568 4708 4467 • • SchIurnbeger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuigsut District:Prudhoe Bay,AK Country:United States Stage 5: Job Messages Message Log Message Treating Annulus Stage Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 8:40:35 Priming POD on FP 0 0 0.0 0.0 0.0 2 8:43:48 Arrived on location 05:30 4 2 0.0 0.0 0.0 3 8:44:21 Regenning POD Road side before putting fluid in 4 2 0.0 0.0 0.0 lines 4 9:14:34 preparing to prime blender with freeze protect 4 2 0.0 0.0 0.0 fluid 5 9:22:19 Recirc line open,priming pumps 45 2 0.0 0.0 0.0 6 9:36:13 shutting in recirc line on POD 45 2 0.0 0.0 0.0 7 9:37:48 Getting clear all around,starting low pressure stall 49 2 0.0 0.0 0.0 8 9:39:27 verified hydraulic WH valve is closed. 45 2 0.0 0.0 0.0 9 9:41:09 Preparing to warm lines 72 2 0.0 0.0 0.0 10 9:48:04 Clear all around,start low pressure stall 342 2 0.0 1.3 0.0 11 9:51:17 begin high PT 562 2 0.0 0.0 0.0 12 9:57:12 Lines inspected,all clear,coming up to 9,500psi 6225 2 0.0 0.0 0.0 13 10:00:07 pumps down,brakes set,hold for PT 9452 2 0.0 0.0 0.0 14 10:05:21 PT successful,bleeding pressure down 8788 2 0.0 0.0 0.0 15 10:08:36 Shutting in pump 7 27 2 0.0 0.0 0.0 16 10:08:49 Gathering up for safety meeting 27 2 0.0 0.0 0.0 17 10:40:18 Safety Meeting done,getting in place to pump 4 2 0.0 0.0 0.0 18 10:42:55 Batching up gel -1 2 0.0 0.0 0.0 19 10:51:39 Opened up IA line to transducer -5 2992 0.0 0.0 0.0 20 11:05:57 Good 27#gel -10 2950 0.0 0.0 0.0 21 11:06:04 Priming POD on gel -10 2950 0.0 0.0 0.0 22 11:09:46 Hydraulic Valve Open,Swab Open 23.5 turns 40 2940 0.0 0.0 0.0 23 11:10:43 Putting 1000psi on lines to open WH 40 2937 0.0 0.0 0.0 24 11:11:19 Opening Master WH valve 960 2936 0.0 0.0 0.0 25 11:12:04 Master Open 23.5 Turns 809 2930 0.0 0.0 0.0 26 11:12:34 Displacing Surface Lines 800 2927 0.0 0.0 0.0 27 11:33:12 Started Pumping 1295 2946 0.0 0.0 0.0 28 11:41:33 Activated Extend Stage 5538 3488 290.9 41.3 0.0 29 11:41:56 Shutdown 1212 3198 301.8 0.1 0.0 30 11:48:34 Deactivated Extend Stage 1249 3209 301.8 0.0 0.0 31 11:48:34 Start Stage 5 PAD Manually 1249 3209 301.8 0.0 0.0 32 11:50:30 Stage at Perfs:Pump Check 4426 3458 327.3 28.7 0.0 33 11:53:02 Good XL pH 8.6 6092 3522 425.9 40.3 0.0 34 11:54:51 2.527"ball loaded 6554 3477 499.0 40.2 0.0 35 11:58:06 Stage at Perfs:Stage 5 PAD 7191 3470 629.5 40.1 0.0 36 11:58:39 Started Pumping Prop 7365 3513 651.5 40.0 0.0 37 11:58:42 Start 1.0 PPA Automatically 7387 3527 653.5 40.0 -0.0 38 12:02:30 Start 3.0 PPA Automatically 7003 3446 803.9 39.7 1.0 39 12:06:19 Start 5.0 PPA Automatically 6966 3475 954.1 39.4 3.0 40 12:07:01 Stage at Perfs:1.0 PPA 7039 3475 981.5 39.1 5.1 41 12:09:06 XL pH=8.6 7355 3486 1062.8 39.0 4.9 42 12:10:52 Stage at Perfs:3.0 PPA 7603 3435 1131.5 38.9 5.0 43 12:11:42 Start 7.0 PPA Automatically 7657 3437 1163.9 38.8 5.0 44 12:14:46 Stage at Perfs:5.0 PPA 8129 3438 1281.7 38.1 7.0 45 12:16:40 Start 9.0 PPA Automatically 8239 3443 1353.8 37.8 7.1 . Sck1uinbager Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Message Log Message Treating Annulus Stage Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 46 12:20:25 Stage at Perfs:7.0 PPA 8271 3423 1491.5 36.0 9.0 47 12:21:53 Start 10.0 PPA Automatically 8330 3420 1543.7 35.5 8.9 48 12:25:50 Stage at Perfs:9.0 PPA 8390 3414 1681.7 34.6 10.0 49 12:26:36 Start Clear Lines Automatically 8394 3406 1708.2 34.6 10.1 50 12:27:18 Start Spacer Manually 8541 3466 1733.0 36.4 0.0 51 12:28:13 Start Ball 2.527 Automatically 4613 3208 1758.3 21.3 0.0 • • hlumbevge Client Caelus energy Alaska ��r1Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 6: As Measured Pump Schedule As Measured Pump Schedule Ste StepSlurry Slurry Pump Fluid Prop Prop Prop p Volume Rate Time Fluid Name Volume Proppant Name p Conc Mass # Name (bbl) (bbl/min) (min) (gal) PPA) (PPA) (Ib) 1 Stage PAD6 268 38.4 7.1 YF127ST 11256 0 0 0 Slow for 2 50 24.5 2.4 YF127ST 2100 0 0 0 Seat ResumPAD a 3 30 40.5 0.7 YF127ST 1260 0 0 0 4 1.0 PPA 130 40.1 3.2 YF127ST 5244CarboLite w/5%ScaleGuard 1 1.0 4839 16/20 5 3.0 PPA 129.9 40 3.3 YF127ST 4842CarboLite w/5%ScaleGuard 3.1 3.0 13877 16/20 6 5.0 PPA 179.9 39.9 4.5 YF127ST 6205 CarboLite w/5%ScaleGuard 5.1 5.0 30482 16/20 7 7.0 PPA 159.9 39.6 4 YF127ST 5145CarboLite w/5%ScaleGuard 7.2 7.0 35460 16/20 8 9.0 PPA 159.8 37.8 4.2 YF127ST 4815CarboLite w/5%ScaleGuard 9.3 9.0 42897 16/20 9 10.0 PPA 139.8 35.6 3.9 YF127ST 4078 CarboLite w/5%ScaleGuard 10.1 10.0 40588 16/20 10 Clear 24.8 34.7 0.7 YF127ST 959 CarboLite w/5%ScaleGuard 10 0 2077 Lines 16/20 11 Spacer 25 27.5 1 YF127ST 1050 0 0 0 12 Ball 3 21.4 0.1 YF127ST 126 0 0 0 2.603" Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Stage 6 PAD 38.4 40.3 7694 8449 2485 2 Slow for Seat 24.5 39.5 4670 6170 2485 3 Resume PAD 40.5 40.6 6283 6524 6179 4 1.0 PPA 40.1 40.4 6645 6705 6545 5 3.0 PPA 40.0 40.2 6608 6628 6463 6 5.0 PPA 39.9 40.2 7097 7525 6605 7 7.0 PPA 39.6 40.0 7910 8303 7525 8 9.0 PPA 37.8 39.3 8332 8385 8289 9 10.0 PPA 35.6 36.6 8325 8385 8253 10 Clear Lines 34.7 35.6 8046 8257 7873 11 Spacer 27.5 35.8 5298 8156 3918 12 Ball 2.603" 21.4 21.4 4298 4460 4188 i 1• ScIi1umLieger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 6: Job Messages Message Log Message Treating Annulus Stage Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) Ibbl/min) (PPA) 1 12:28:21 Start Stage 6 PAD Automatically 4828 3228 0.0 21.2 0.0 2 12:29:10 2.527"Ball away at 1760 total slurry 8097 3441 23.2 36.4 0.0 3 12:31:26 Stage at Perfs:10.0 PPA 8111 3478 110.2 39.4 0.0 4 12:33:54 Ball 2.603"loaded 7552 3480 209.3 40.3 0.0 5 12:35:27 Start Slow for Sea Automatically 2778 3130 268.1 15.3 0.0 6 12:35:56 Stage at Perfs:Clear Lines 3213 3193 274.3 12.1 0.0 7 12:36:31 2.527"Ball seat at 2038 3336 3156 281.3 12.0 0.0 8 12:36:38 Coming backup to 40bpm 3959 3225 282.7 14.0 0.0 9 12:37:51 Start Resume PAD Automatically 6229 3379 318.0 40.1 0.0 10 12:38:01 Stage at Perfs:Ball 2.527 6179 3365 324.7 40.6 0.0 11 12:38:05 Stage at Perfs:Stage 6 PAD 6234 3374 327.4 40.6 0.0 12 12:38:32 Started Pumping Prop 6545 3449 345.7 40.4 0.0 13 12:38:36 Start 1.0 PPA Automatically 6586 3454 348.4 40.3 0.0 14 12:41:50 Start 3.0 PPA Automatically 6623 3460 478.0 40.3 1.0 15 12:45:05 Start 5.0 PPA Automatically 6600 3443 607.8 40.1 3.0 16 12:46:36 Stage at Perfs:1.0 PPA 6957 3444 668.3 39.7 5.0 17 12:49:36 Start 7.0 PPA Automatically 7543 3451 788.2 39.9 5.0 18 12:49:51 Stage at Perfs:3.0 PPA 7570 3452 798.2 40.0 6.5 19 12:53:08 Stage at Perfs:5.0 PPA 8266 3446 928.0 39.5 7.1 20 12:53:38 Start 9.0 PPA Automatically 8298 3444 947.7 39.2 7.0 21 12:57:53 Start 10.0 PPA Automatically 8349 3390 1107.8 36.6 9.0 22 12:57:54 Stage at Perfs:7.0 PPA 8344 3391 1108.5 36.6 9.1 23 13:01:49 Start Clear Lines Automatically 8257 3402 1247.7 34.7 10.0 24 13:02:01 Activated Extend Stage 7873 3367 1254.5 34.2 1.7 25 13:02:16 Stopped Pumping Prop 8074 3376 1263.2 35.0 -0.0 26 13:02:24 Stage at Perfs:9.0 PPA 8179 3385 1267.9 35.5 0.0 • 0 Scbluiiiberger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-B Formation:Nuigsut District:Prudhoe Bay,AK Country:United States Stage 7: As Measured Pump Schedule As Measured Pump Schedule Step Step Slurry Slurry Pump Fluid Prop Prop Prop # Name Volume Rate Time Fluid Name Volume Proppant Name Conc Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (Ib) 1 SPAp7 259 38.4 6.9 YF127ST 10878 0 0 0 Slow for 2 50 24.4 2.4 YF127ST 2100 0 0 0 Seat ResumePAD 3 171 40.2 4.3 YF127ST 7182 0 0 0 4 1.0 PPA 205 39.9 5.1 YF127ST 8261 CarboLite w/5%ScaleGuard 1 1.0 7908 16/20 5 3.0 PPA 204.9 40 5.1 YF127ST 7624 CarboLite w/5%ScaleGuard 3.1 3.0 22332 16/20 6 5.0 PPA 279.8 40 7 YF127ST 9646 CarboLite w/5%ScaleGuard 5.1 5.0 47923 16/20 7 7.0 PPA 254.8 38.4 6.6 YF127ST 8186 CarboLite w/5%ScaleGuard 7.1 7.0 57244 16/20 8 9.0 PPA 254.7 34.8 7.3 YF127ST 7742 CarboLite w/5%ScaleGuard 10.2 9.0 67327 16/20 9 10.0 PPA 224.7 34.1 6.6 YF127ST 6548 CarboLite w/5%ScaleGuard 10.2 10.0 65864 16/20 10 Clear 24.9 33.8 0.7 YF127ST 979 CarboLite w/5%ScaleGuard 9.9 0 1716 Lines 16/20 11 Spacer 25 27.4 1 YF127ST 1050 0 0 0 12 Ball 3 21.3 0.1 YF127ST 126 0 0 0 2.681" Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Minimum Treating Step# Step Name Rate Rate Pressure Treating Pressure (bbl/min) (bbl/min) (psi) Pressure (psi) (psi) 1 Stage 7 PAD 38.4 40.3 7537 8285 2196 2 Slow for Seat 24.4 38.3 4402 5595 2306 3 Resume PAD 40.2 40.3 6482 6595 5607 4 1.0 PPA 39.9 40.3 6505 6595 6458 5 3.0 PPA 40.0 40.1 6619 6811 6481 6 5.0 PPA 40.0 40.1 7547 8037 6815 7 7.0 PPA 38.4 39.9 8291 8404 8024 8 9.0 PPA 34.8 37.1 7962 8417 6884 9 10.0 PPA 34.1 35.1 8322 8445 8166 10 Clear Lines 33.8 35.1 8178 8408 7946 11 Spacer 27.4 35.2 5687 8404 4174 12 Ball 2.681" 21.3 21.3 4642 4749 4554 • 0 Schiumbarger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 7: Job Messages Message Log Message Treating Annulus Stage Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 13:03:39 Start Stage 7 PAD Automatically 4577 3158 0.0 21.3 0.0 2 13:04:10 2.603"Ball away at 3060 bbls 6779 3266 13.4 31.9 0.0 3 13:07:08 Stage at Perfs:10.0 PPA 7960 3443 127.6 40.1 0.0 4 13:09:19 ball 2.681"loaded 7268 3385 215.4 40.2 0.0 5 13:10:31 Start Slow for Sea Automatically 2796 3049 259.0 13.7 0.0 6 13:11:48 2.603"Ball seat 3331 bbls total slurry 3959 3126 275.0 16.9 0.0 7 13:13:13 Stage at Perfs:Stage 7 PAD 6037 3252 320.0 40.2 0.0 8 13:17:12 Start 1.0 PPA Automatically 6600 3457 480.3 40.3 0.0 9 13:17:12 Started Pumping Prop 6600 3457 480.3 40.3 0.0 10 13:22:20 Start 3.0 PPA Automatically 6499 3411 685.4 40.2 1.0 11 13:24:59 Stage at Perfs:1.0 PPA 6623 3374 791.0 40.0 3.0 12 13:27:10 XL pH=8.6 6788 3481 878.4 40.0 3.0 13 13:27:28 Start 5.0 PPA Automatically 6815 3476 890.5 40.0 3.0 14 13:30:07 Stage at Perfs:3.0 PPA 7525 3502 996.4 40.0 5.0 15 13:34:28 Start 7.0 PPA Automatically 8047 3487 1170.2 39.8 5.1 16 13:35:15 Stage at Perfs:5.0 PPA 8079 3478 1201.3 39.4 7.1 17 13:41:06 Start 9.0 PPA Automatically 8330 3504 1424.8 37.1 7.0 18 13:42:38 Stage at Perfs:7.0 PPA 8321 3472 1481.2 36.2 9.0 19 13:46:08 struggling with prop at the blender,dropping rate 7026 3391 1603.6 31.9 10.1 to compensate 20 13:46:39 Grating on POD cleaned out,issue resolved 7113 3375 1620.0 31.8 8.9 21 13:46:58 walking rate backup to 40 bpm 7154 3369 1630.1 31.7 9.0 22 13:48:26 Start 10.0 PPA Automatically 8312 3412 1679.3 35.0 9.1 23 13:50:04 Stage at Penis:9.0 PPA 8303 3525 1735.9 34.6 9.9 24 13:55:02 Start Clear Lines Automatically 8298 3516 1904.4 33.3 9.4 • • Schlumberger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 8: As Measured Pump Schedule As Measured Pump Schedule Ste Ste Slurry Slurry Pump Fluid Drax Prop Prop p Name Volume Rate Time Fluid Name Volume Proppant Name Conc Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (lb) 1 SPApB 250 37.7 6.8 YF127ST 10500 0 0 0 Slow Sea for 2 50 23.6 2.5 YF127ST 2100 0 0 0 ResumPAD a 3 30 40.5 0.7 YF127ST 1260 0 0 0 4 1.0 PPA 136 40.1 3.4 YF127ST 5486 CarboLite w/5%ScaleGuard 1 1.0 5105 16/20 5 2.0 PPA 153 40.1 3.8 YF127ST 5916 CarboLite w/5%ScaleGuard 2 2.0 11557 16/20 6 4.0 PPA 173.9 40 4.3 YF127ST 6229 CarboLite w/5%ScaleGuard 4.1 4.0 24441 16/20 7 6.0 PPA 173.9 39.9 4.4 YF127ST 5792 CarboLite w/5%ScaleGuard 6.2 6.0 34364 16/20 8 8.0 PPA 173.8 38 4.6 YF127ST 5407 CarboLite w/5%ScaleGuard 8.3 8.0 43124 16/20 9 10.0 PPA 173.8 35.3 4.9 YF127ST 5072 CarboLite w/5%ScaleGuard 10.4 10.0 50715 16/20 10 12.0 PPA 159.3 34.5 4.6 YF127ST 4449 CarboLite w/5%ScaleGuard 12.4 12.0 51210 16/20 11 Clear 16.9 34.6 0.5 YF127ST 710 CarboLite w/5%ScaleGuard 3 0 47 Lines 16/20 12 Spacer 25 29.6 0.9 YF127ST 1050 0 0 0 13 Ball 3 21.8 0.1 YF127ST 126 0 0 0 2.761" 14 XL Flush 120 36 3.4 YF127ST 5040 0 0 0 15 LG Flush 120 39.9 3 WF127 5040 0 0 0 16 SlSeaor 50 17.9 3.1 WF127 2100 0 0 0 17 MT PCM 77 22.1 3.6 WF127 3234 0 0 0 18 Freeze 68.9 22.1 3.1 Freeze Protect 2893 0 0 0 Protect Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Stage 8 PAD 37.7 40.4 7743 8523 2741 2 Slow for Seat 23.6 39.0 4649 5719 3332 3 Resume PAD 40.5 40.9 5919 6152 5735 4 1.0 PPA 40.1 40.8 6387 6472 6197 5 2.0 PPA 40.1 40.2 6349 6399 6293 6 4.0 PPA 40.0 40.2 6803 7232 6399 7 6.0 PPA 39.9 40.0 7859 8335 7236 8 8.0 PPA 38.0 39.9 8343 8422 8253 9 10.0 PPA 35.3 36.6 8331 8381 8294 • • Scb1umbeger Client:Caelus energy Alaska Well:ODSN-22 Stages 5-8 Formation:Nuigsut District:Prudhoe Bay,AK Country:United States Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 10 12.0 PPA 34.5 34.8 8317 8358 7822 11 Clear Lines 34.6 35.7 8062 8349 7822 12 Spacer 29.6 36.6 6078 8527 4490 13 Ball 2.761" 21.8 21.9 4682 4721 4645 14 XL Flush 36.0 39.2 7468 8005 4819 15 LG Flush 39.9 40.3 6979 7593 4261 16 Slow for Sea 17.9 35.0 3391 4595 2407 17 MT PCM 22.1 22.1 3303 3428 3148 18 Freeze Prote 22.1 22.1 3166 3290 1267 Stage 8: Job Messages Message Log Message Treating Annulus Stage Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 13:56:54 Start Stage 8 PAD Automatically 4870 3296 0.0 21.3 0.0 2 13:56:54 Start Propped Frac Automatically 4870 3296 0.0 21.3 0.0 3 13:56:54 Start Stage 8(Por Automatically 4870 3296 0.0 21.3 0.0 4 13:58:00 Stage at Perfs:10.0 PPA 8010 3498 33.2 35.8 0.0 5 13:59:13 2.681'Ball away 5017 bbls slurry 8088 3505 77.8 37.4 0.0 6 14:02:05 2.761"ball loaded 7758 3491 191.6 40.4 0.0 7 14:03:42 Start Slow for Sea Automatically 3606 3214 249.7 12.4 0.0 8 14:04:23 Stage at Perfs:Clear Lines 3634 3230 258.0 12.1 0.0 9 14:04:56 2.681 ball seat 5279 bbls total slurry 3606 3220 264.7 12.2 0.0 10 14:05:03 coming back up to 40 bpm 4156 3244 266.3 14.7 0.0 11 14:06:13 Start Resume PAD Automatically 5771 3319 299.8 39.6 0.0 12 14:06:29 Stage at Perfs:Stage 8 PAD 5891 3351 310.6 40.8 0.0 13 14:06:51 Started Pumping Prop 6133 3426 325.6 40.9 0.0 14 14:06:58 Start 1.0 PPA Automatically 6270 3456 330.4 40.8 -0.1 15 14:10:21 Start 2.0 PPA Automatically 6335 3522 466.1 40.0 1.0 16 14:14:10 Start 4.0 PPA Automatically 6403 3481 619.0 40.2 2.0 17 14:14:29 Stage at Perfs:1.0 PPA 6422 3479 631.6 39.9 3.8 18 14:17:52 Stage at Perfs:2.0 PPA 7126 3456 767.1 39.9 3.9 19 14:18:31 Start 6.0 PPA Automatically 7250 3455 793.0 40.1 4.0 20 14:21:42 Stage at Perfs:4.0 PPA 8202 3456 920.1 39.8 6.0 21 14:22:52 Start 8.0 PPA Automatically 8340 3450 966.6 39.9 6.0 22 14:26:11 Stage at Perfs:6.0 PPA 8330 3453 1093.9 37.1 8.0 23 14:27:27 Start 10.0 PPA Automatically 8394 3432 1140.4 36.5 8.0 24 14:31:02 Stage at Perfs:8.0 PPA 8321 3458 1267.4 34.7 10.2 25 14:32:23 Start 12.0 PPA Automatically 8307 3418 1314.2 34.8 10.0 26 14:32:39 Activated Extend Stage 8312 3412 1323.5 34.7 11.2 27 14:36:04 Stage at Perfs:10.0 PPA 8358 3441 1441.3 34.5 12.0 28 14:37:00 Deactivated Extend Stage 7809 3391 1473.3 33.6 0.6 29 14:37:00 Start Clear Lines Manually 7809 3391 1473.3 33.6 0.6 30 14:37:29 Start Spacer Manually 8513 3433 1490.2 36.3 0.0 31 14:38:33 Start XL Flush Automatically 5016 3204 1518.5 21.6 0.0 • Sch1umbeger CnWell:ODSN-22 Stages 5-8 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Message Log Message Treating Annulus Stage Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 32 14:39:22 2.761"Ball away at 6538bbls total slurry 7305 3355 1540.8 35.1 0.0 33 14:41:20 Stage at Perfs:12.0 PPA 7690 3426 1615.3 38.8 0.0 34 14:41:56 Start LG Flush Automatically 7580 3430 1638.7 39.3 0.0 35 14:42:08 XL ads cut 7520 3426 1646.5 39.3 0.0 36 14:47:52 Ball seat 6791 3405 3198 1804.8 22.0 0.0 37 14:48:02 Start MT PCM Automatically 3432 3194 1808.5 22.0 0.0 38 14:48:02 Pumping PCM volume down 3432 3194 1808.5 22.0 0.0 39 14:51:31 feathering in freeze protect 3153 3125 1885.4 22.1 0.0 40 14:51:36 Start Freeze Prote Manually 3153 3127 1887.2 22.1 0.0 41 14:51:39 Activated Extend Stage 3148 3125 1888.3 22.1 0.0 42 14:53:59 Stage at Perfs:LG Flush 3268 3058 1939.8 22.1 0.0 43 14:54:47 Shutdown.Pumps down,brakes set. 1958 2965 1954.1 0.0 0.0 44 14:55:28 Final freeze protect volume=65 bbls 1734 2918 1954.1 0.0 0.0 45 15:18:16 Master Shut 23.5 Turns -15 1070 1954.1 11.0 0.0 46 15:19:45 Swab Shut 23.5 Turns -10 629 1954.1 11.1 0.0 47 15:19:52 Hydraulic valve shut -10 598 1954.1 11.1 0.0 • • Sch1umbeger Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States FracCAT Treatment Report Well :ODSN-22,Stages 9-12 Field :Oooguruk Formation :Nuiqsut Prepared for Client :Caelus Energy Alaska Client Rep :Mike Martin Date Prepared :03/1/16 Prepared by Name :Alexander Martinez Division :Schlumberger Phone :561-389-5006 Pressure(All Zones) Initial Wellhead Pressure(psi) 805 Initial BHP at Gauge(psi) 3,171 Final Surface ISIP(psi) Screenout Final ISIP at Gauge(psi) N/A Surface Shut in Pressure(psi) 2,924 BH Shut in Pressure(psi) 5,245 Maximum Treating Pressure(psi) 8,967 BH Gauge at 14,657'MD,5,884'TVD Treatment Totals(All Zones As Per FracCAT) Total Slurry Pumped 6,925 Total YF127ST Past Wellhead(bbls) 5,535 (Water+Adds+Proppant)(bbls) Total WF127 Past Wellhead(bbls) 360 Total Freeze Protect Past Wellhead 13 (bbls) Total Proppant Pumped(lbs.) 947,200 Total Proppant in Formation(lbs.) 931,400 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103(gal) 245 245 M275(lbs.) 54 83 L065(gal) 501 501 J218(lbs.) 220 220 J580(lbs.) 6510 6510 J475(lbs.) 1595 1595 J922(mgal) 233 233 J134(lbs.) 11 0 J510(bbls) 0 0.6 Freeze Protect(bbls) 0 13 D206(gal) 0 1.5 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that maybe achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • . SchloIflbePger Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Summary On February 25,2016,Schlumberger finished stages 9-12 for the ODSN-22 well.The treatment consisted of 4 stages with 3 Rapidball DM ball drops. The first stage had a proppant concentration that reached 10 PPA while the last three stages reached 12 PPA. All stages were pumped as per design but during the last stage,the well screened out leaving approximately 48.5 bbls of slurry within the wellbore(—15,800 lbs of proppant). Freeze protect fluid had been started at surface prior to screenout and 13 bbls of freeze protect made it past the wellbore. During the treatment,acquisition with the downstream(missile)densitometer faltered and was found to be a loose cable connection on the densitometer itself. Materials Actual (Design) Slurry Volume-All Volumes(bbl) 6,925(6,949) Clean Fluid-All Volumes(bbl) 5,928(5,948) Proppant,lbs. 947,200(946,650) Pressure Test — Treating Pressure BHP Caelus Energy Alaska ODSN-22 Stages 9-12 — Annulus Pressure 02-25-2016 - Slurry Rate 10000 Prgo Con • 50 9000 - PCM Viscosity 45 8000 40 - 0 7000 35 C-) 0 6000 30 ' a -o CD 5000 25 h � 0 a. 4000 20 N 3000- 15 cr 3 2000 10 0 1000 5 0, r.... ,.....,, L 0 09:53:02 10:03:27 10:13:52 10:24:17 10:34:42 Time-hh:mm:ss ©Schlumberger 1994-2015 Schlumberger • . Prop Con - PPA& Rate - bbl/min N C (CI 0� 0 N 0- OCV � 0 r tz O • O Q y LU a., A m .0 L =(%1 --2 .7 CV O - G>NN Ca It 0 N It V � N I o rn 1 O an y y >, % ti Y in H r+ / �,,. > a, Q ti O H C.,) m a) 03 C V „,°'cN .-din C CO r4O COLir _ rr t. �o e e s 0 C.)C) CI) i 3 a' U E Z o2 2.Y Z F- m N Ct. C t E I\ i E �` o = [.........\if t a N r CD i / rial.::1_, N 1 1 1 4.0 ....... .c.....\4.21 tN C5 rim ra N 'OZ 1 I L O- CM I— Com a� N °' cu 1 O sID E , ( ‘t E E O O O O O O� t EIPPPN O O Co O O CI O N LO N O CO M ca Go Isd - eanssaad • • Schiunibeger Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 9 Stage 9 consisted of a PAD,6 proppant steps(1-10PPA), a ball drop and a flush. A total of 1912 bbls of slurry was pumped during this stage with 225,081 lbs of proppant.The maximum treating pressure for stage 9 was 8,394 psi.. Flush at the WH was called at 1,884 bbls and the 2.842"Rapidball DM ball was dropped at 1,912 bbls to open Port 9 for Stage 10. The ball seated at 2,157 bbls of total slurry. Summary of Pressures When Ball Seats 2.824" Ball Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure N/A 5,650 3,048 Bottomhole Pressure N/A 5,957 4,723 Summary of Stage 9 Total Proppant Pumped(Ib) 225,081 Max pumping Rate(bpm) 40.7 Total Proppant in Formation(Ib) 225,081 Average Pumping Rate(bpm) 37.1 Total Slurry Pumped(bbl) 1,912 Maximum Treating Pressure(psi) 8,394 YF127ST Pumped(bbl) 1,396 Average Treating Pressure(psi) 6,925 WF127 Pumped(bbl) 280 Average Viscosity of WF127(cP) 19.22 Freeze Protect 0 Stage 9 — Treating Pressure 9 BHP Caelus Energy Alaska ODSN-22Stages 9-12 — Annulus Pressure 02-25-2016 — Slurry Rate 10000 "" • 50 9(1(10 PCM Viscosity 8000 r'`---- 1. em-0-- - - V �u 40 'o 7000 0 0 m o. 6000 /^, 30 ' V 3• 5000 oe oe to tS 73 c. (1.-. 4000 \—_.-._.___ --- 20 iD c 3000 3 2000 -10 0 1000— r_____L--r a 11:34:43 11:51:23 12:08:03 12:24:43 12:41:23 Time-hh:mm:ss ©Schlumberger 1994-2015 Schlumberger • • Sch1ombeger Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuiqsut District Prudhoe Bay,AK Country:United States Stage 10 Stage 2 consisted of a PAD,7 proppant steps(1-12PPA),a ball drop and a flush. A total of 1,534 bbls of slurry was pumped during this stage with 225,632 lbs of proppant.The maximum treating pressure for stage 10 was 8,394 psi. Flush at the WH was called at 3,418 bbls and the 2.925"Rapidball DM ball was dropped at 3,447 bbls to open Port 10 for Stage 11. The ball seated at 3,684 bbls of total slurry. Summary of Pressures When Ball Seats 2.925" Ball Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure 3,080 5,725 3,322 Bottomhole Pressure 4,609 6,298 5,199 Summary of Stage 10 Total Proppant Pumped(Ib) 225,632 Max pumping Rate(bpm) 40.5 Total Proppant in Formation(Ib) 225,632 Average Pumping Rate(bpm) 36.8 Total Slurry Pumped(bbl) 1,534 Maximum Treating Pressure(psi) 8,394 YF127ST Pumped(bbl) 1,297 Average Treating Pressure(psi) 7,053 WF127 Pumped(bbl) 0 Average Viscosity of WF127(cP) 18.23 Stage 10 — Treating Pressure 9 — BHP Caelus Energy Alaska — ODSN-22 Stages 9-12 Annulus Pressure 02-25-2016 — Slurry Rate 10000 Pr,pC"" , 50 9000 — PCM Viscosity 8000 .1 `..� !,rali 40 7000 . _ n 0 0 6000 '�+ ,nima llg\30 v = is , 5000 90 a 4000 ••` -- - - �1 20 m _ m 3000 c II 3 2000 f :: 10 ; 1000 12:24:41 12:37:11 12:49:41 13:02:11 13:14:41 Time-hh:mm:ss ©Schlumberger 1994-2015 Schlumberger • I Sck1ombeger C Wet:ODSN-22 Stages 9-12 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 11 Stage 11 consisted of a PAD, 7 proppant steps(1-12PPA), a ball drop and a flush stage. A total of 1,685 bbls of slurry was pumped during this stage with 252,811 lbs of proppant.The maximum treating pressure for stage 11 was 8,349 psi.Flush at the WH was called at 5,104 bbls and the 3.009"Rapidball DM ball was dropped at 5,131 bbls to open Port 11 for Stage 12. The ball seated at 5,358 bbls of total slurry. Summary of Pressures When Ball Seats 3.009" Ball Before Ball Hit(psi) When Ball Hit(psi) After ball Hit(psi) Wellhead Pressure 3,143 5,611 2,604 Bottomhole Pressure 4,696 6,248 4,545 Summary of Stage 11 Total Proppant Pumped(Ib) 252,811 Max pumping Rate(bpm) 40.4 Total Proppant in Formation(Ib) 252,811 Average Pumping Rate(bpm) 37.3 Total Slurry Pumped(bbl) 1,685 Maximum Treating Pressure(psi) 8,349 YF127ST Pumped(bbl) 1,418 Average Treating Pressure(psi) 6,951 WF127 Pumped(bbl) 0 Average Viscosity of WF127(cP) 18.36 —Stage 11 TreatingHPtPressure Caelus Energy Alaska — ODSN-22 Stages 9-12 — Annulus Pressure 02-25-2016 — Slurry Rate 10000 " " 50 9000 — PCM Viscosit 8000, MEMM�40 -a 7000 , _ o, 6000(�A _____ '�iI__30 3 5000 i I i i' Ro to Wxi a. 4000 l•1111_. ip 1 cm 20 mo 1 3000 'I'_ g 2000' f""'"� +s 10 �. 1000 r 0 f 13:07:46 13:20:16 13:32:46 13:45:16 13:57:46 Time-hh:mm:ss ©Schlumberger 1994-2015 Schlumberger 0 . Scb1umbager Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuigsut District:Prudhoe Bay,AK Country:United States Stage 12 Stage 12 consisted of a PAD, 7 proppant steps(1-12PPA),and a flush stage. A total of 1,794 bbls of slurry was pumped during this stage with 243,585 lbs of proppant.The maximum treating pressure for stage 12 was 8,967 psi as the well pressured-out. Approximately 94%of the proppant was pumped into the formation before the pumps tripped leaving—15,800 lbs of proppant in the tubing.Pressure broke over shortly afterwards and the decision was made to try and push more freeze protect past the WH,however the well quickly pressured-out again. Flush at the WH was called at 6,726 bbls(POD at 6,707 bbls)and freeze protect fluid started at 6890.Approximately 33 bbls of freeze protect fluid was pumped out of the transport with 11 bbls making it past the WH. Summary of Stage 12 Total Proppant Pumped(Ib) 243,585 Max pumping Rate(bpm) 40.5 Total Proppant in Formation(Ib) 227,785 Average Pumping Rate(bpm) 37.7 Total Slurry Pumped(bbl) 1,793 Maximum Treating Pressure(psi) 8,967 YF127ST Pumped(bbl) 1,425 Average Treating Pressure(psi) 7,124 WF127 Pumped(bbl) 80 Average Viscosity of WF127(cP) 18.26 Freeze Protect 33 Stage 12 - TreatingHPtPressure Caelus Energy Alaska —- Annulus Pressure ODSN-22 Stages 9-12 02-25-2016 — Slurry Rate 12000 '"-• Prnp r"" , 1 50 PCM Viscosity 10000 "" "1......,r"""n.."" -40 -u 8 o 8000 0 o -30 -o 3 6000 1 PoD a �`_ ' _ -20 m 4000 c _ c c . 2000 �."—...� t_ -10 ' 0 r ! II • 0 13:49:08 14:05:48 14:22:28 14:39:08 14:55:48 Time-hh:mm:ss ©Schlumberger 1994-2015 Schlumberger • • Schlumberger Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuigsut District:Prudhoe Bay,AK Country:United States Stage 9: As Measured Pump Schedule As Measured Pump Schedule Ste Ste Slurry Slurry Pump Fluid Prop Prop Prop p p Volume Rate Time Fluid Name Volume Proppant Name p Conc Mass # Name (bbl) (bbl/min) (min) (gal) PPA) (PPA( (lb) BreN,arkdo 1 280 38.1 8.1 WF127 11759 0 0 0 2 Stage PAD 9 395 39 10.6 YF127ST 16590 0 0 0 3 1.0 PPA 170 39.6 4.3 YF127ST 6857 CarboLite w/5%ScaleGuard 1.3 0.2 6375 16/20 4 3.0 PPA 170 40.1 4.2 YF127ST 6329 CarboLite w/5%ScaleGuard 3.1 1.8 18295 16/20 5 5.0 PPA 235 39.9 5.9 YF127ST 8107 CarboLite w/5%ScaleGuard 5.1 1.9 39843 16/20 6 7.0 PPA 210 39.3 5.3 YF127ST 6753 CarboLite w/5%ScaleGuard 7.2 3.5 46737 16/20 7 9.0 PPA 210 37.2 5.7 YF127ST 6321 CarboLite w/5%ScaleGuard 9.3 1.8 56520 16/20 8 10.0 PPA 190 35.7 5.3 YF127ST 5540 CarboLite w/5%ScaleGuard 10.2 1 55196 16/20 9 Clear 24.4 35.5 0.7 YF127ST 940 CarboLite w/5%ScaleGuard 10 0 2115 Lines 16/20 10 Spacer 25 27.7 1 YF127ST 1050 0 0 0 11 Ball 3 21 0.1 YF127ST 126 0 0 0 2.842" Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Breakdown 38.1 40.5 6393 7488 1322 2 Stage 9 PAD 39.0 40.6 5720 6545 1317 3 1.0 PPA 39.6 40.2 6409 6545 6339 4 3.0 PPA 40.1 40.3 6570 6751 6422 5 5.0 PPA 39.9 40.3 7337 7708 6756 6 7.0 PPA 39.3 39.8 8122 8372 7662 7 9.0 PPA 37.2 38.9 8341 8381 8289 8 10.0 PPA 35.7 36.3 8332 8376 8303 9 Clear Lines 35.5 36.5 8130 8312 7937 10 Spacer 27.7 36.8 5246 8289 3542 11 Ball 2.842" 21.0 21.0 4119 4224 4073 • 0 Schb ge Client:Caelus energy Alaska ��!!" iiYYWell:ODSN-22 Stages 9-12 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 9: Job Messages Message Log Message Treating Annulus Stage Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 05:30:45 Arrived on location 0 0 0 0 0 2 08:46:39 Priming pumps 59 2 0 5.7 0 3 08:59:55 Pumps primed,pushing fluid up over top 45 2 0 0 0 4 09:07:15 Lines warmed,pumps down,brakes set 54 2 0 0 0 5 09:09:35 Starting low pressure stall 45 2 0 0 0 6 09:29:19 Investigating source of pressure loss in ball 8 0 0 0 0 dropper van 7 09:32:05 Shutting in 2",low PT stall on ball dropper van 4 0 0 0 0 8 09:44:48 Going through G-Head on ball dropper van -1 0 0 0 0 9 09:56:20 PT'ing H-Head -5 -2 0 0 0 10 09:56:56 Bumping van pressure to 5,500psi -1 -2 0 0 0 11 10:00:35 PT on ball dropper van H-Head-Good -1 -2 0 0 0 12 10:01:50 Going for low pressure stall on main treating line 786 -2 0 0 0 13 10:02:18 Pumps down,brakes set. 1066 -2 0 0 0 14 10:03:33 Bringing pressure up to 6k 1002 -2 0 0.3 0 15 10:05:44 Pumps down,brakes set. 6023 -2 0 0 0 16 10:06:57 Clear all around,coming up to 9,500psi 5854 -2 0 0.1 0 17 10:15:08 PT successful 9026 -2 0 0 0 18 10:17:30 Gathering for safety meeting 114 -2 0 0 0 19 10:44:36 Safety meeting done 8 11 0 0 0 20 10:44:43 Mixing up first boat of gel 8 11 0 0 0 21 10:45:32 Bringing IA to 3,000psi 8 11 0 0 0 22 11:01:12 WH hydraulic valve open 136 2892 0 0 0 23 11:02:01 Bringing up main line to open well 928 2887 0 0 0 24 11:02:32 Master valve open-WH Open 800 2879 0 0 0 25 11:03:01 Displacing lines 947 2885 0 2.1 0 26 11:12:25 Pumps down,brakes set.Holding for 10 mins 1656 2771 0 0 0 27 11:22:43 Ready all around,starting pump check 1409 2750 0 0 0 28 11:22:47 Started Pumping 1409 2750 0 0 0 29 11:33:30 2.842"ball loaded 1386 3120 280 0 0 30 11:36:08 Start Stage 9 PAD Manually 1317 3111 280 0 0 31 11:42:41 XL pH=8.6 on PAD 5918 3513 506.2 40.1 0 32 11:44:21 Stage at Perfs:Stage 9 PAD 6312 3497 572.9 39.9 0 33 11:46:50 Started Pumping Prop 6541 3450 672.2 40 0 34 11:46:55 Start 1.0 PPA Automatically 6545 3450 675.6 40.1 0 35 11:51:12 Start 3.O PPA Automatically 6449 3458 845.1 40.1 1 36 11:54:17 Stage at Perfs:1.0 PPA 6655 3456 968.4 40.2 3 37 11:55:27 Start 5.0 PPA Automatically 6765 3447 1015.4 40.2 3 38 11:55:54 3PPA XL pH=8.6 6806 3444 1033.5 40.1 5 39 11:58:32 Stage at Perfs:3.0 PPA 7479 3427 1138.5 40 5 40 12:01:20 Start7.0 PPA Automatically 7717 3394 1250.2 39.7 5 41 12:02:49 Stage at Perfs:5.0 PPA 7996 3458 1308.8 39.4 6.9 42 12:06:41 Start 9.0 PPA Automatically 8394 3394 1460.3 38.9 7 43 12:08:52 Stage at Perfs:7.0 PPA 8312 3416 1543.2 37.2 9.1 44 12:11:52 Ball dropper van pressured up to 5,300psi 8372 3363 1653.1 36.3 9.1 45 12:12:20 Start 10.0 PPA Automatically 8376 3351 1670.1 36.3 9 • , Scbluiiiberger Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Message Log Message Treating Annulus Stage Slurry Slurry Rate Prop.Conc. Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 46 12:14:39 Stage at Perfs:9.0 PPA 8321 3448 1753.3 35.7 9.9 • • c iu b r Se1 Client:Caelus energy Alaska �! Well:ODSN-22 Stages 9-12 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 10: As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Step Volume Rate Time Fluid Name Volume Proppant Name Prop Cone Mass # Name Conc (bbl) )bbl/min) (min) (gal) (PPA) (PPA) (lb) PA 1 Stage 10 232 38.7 6.1 YF127ST 9744 0 0 0 Slow for 2 50 24.6 2.5 YF127ST 2100 0 0 0 Seat ResumePAD 3 30 40.2 0.7 YF127ST 1260 0 0 0 4 1.0 PPA 140 39.7 3.5 YF127ST 5647 CarboLite w/5%ScaleGuard 1 0.8 5249 16/20 5 2.0 PPA 160 40 4 YF127ST 6188 CarboLite w/5%ScaleGuard 2 1.9 12002 16/20 6 4.0 PPA 180 39.9 4.5 YF127ST 6449 CarboLite w/5%ScaleGuard 4 2.2 25105 16/20 7 6.0 PPA 180 40 4.5 YF127ST 5996 Carbo Lite w/5%ScaleGuard 6.1 1.5 35348 16/20 8 8.0 PPA 180 38.8 4.6 YF127ST 5597 CarboLite w/5%ScaleGuard 8.2 7.1 44377 16/20 9 10.0 PPA 180 36.6 4.9 YF127ST 5254 CarboLite w/5%ScaleGuard 10.2 4.9 52146 16/20 10 12.0 PPA 150 35 4.3 YF127ST 4126 CarboLite w/5%ScaleGuard 12.4 5.1 49162 16/20 11 Clear 24.1 34.8 0.7 YF127ST 921 CarboLite w/5%ScaleGuard 12 0 2243 Lines 16/20 12 Spacer 25 27.3 1 YF127ST 1050 0 0 0 13 Ball 3 21 0.1 YF127ST 126 0 0 0 2.925' Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Stage 10 PAD 38.7 40.5 7289 8303 2279 2 Slow for Seat 24.6 40.1 4559 5877 2805 3 Resume PAD 40.2 40.3 5917 6197 5767 4 1.0 PPA 39.7 40.2 6148 6280 6078 5 2.0 PPA 40.0 40.2 6116 6156 6037 6 4.0 PPA 39.9 40.1 6514 6902 6129 7 6.0 PPA 40.0 40.1 7550 8044 6907 8 8.0 PPA 38.8 39.9 8263 8353 8047 9 10.0 PPA 36.6 37.9 8313 8353 8248 10 12.0 PPA 35.0 35.9 8285 8349 8234 11 Clear Lines 34.8 35.8 8169 8362 7937 12 Spacer 27.3 35.9 5273 8312 3766 13 Ball 2.925' 21.0 21.1 4163 4296 4110 • • hSelumbergerCWell:ODSN-22 Stages 9-12 Formation:Nuigsut District:Prudhoe Bay,AK Country:United States Stage 10: Job Messages Message Log Message Treating Annulus Stage Slurry Rate Prop.Conc. # Time Pressure Pressure Slurry (psi) (psi) (bbl) (bbl/min) (PPA) 1 12:19:29 Start Stage 10 PAD Automatically 4357 3152 0.0 21.0 -0.0 2 12:20:02 2.925"Ball away 1912 Total Slurry 7177 3296 14.3 33.9 0.0 3 12:20:59 Stage at Perfs:10.0 PPA 8317 3426 50.5 40.0 -0.0 4 12:26:17 Stage at Perfs:Clear Lines 3039 3093 240.0 12.1 0.0 5 12:26:55 2.925"Ball seat 2157 total slurry 3098 3131 247.7 12.2 0.0 6 12:27:06 Bringing rate backup to 40bpm 4293 3139 250.3 16.6 0.0 7 12:28:06 Start Resume PAD Automatically 5762 3215 282.1 40.2 0.0 8 12:28:51 Start 1.0 PPA Automatically 6234 3384 312.3 40.1 0.0 9 12:32:23 Start 2.0 PPA Automatically 6147 3452 452.4 40.1 1.0 10 12:34:27 1 PPA XL pH=8.6 6060 3427 534.9 39.9 2.0 11 12:35:58 Stage at Perfs:1.0 PPA 6151 3415 595.7 40.1 2.0 12 12:36:23 Start 4.0 PPA Automatically 6129 3403 612.5 40.1 2.0 13 12:39:29 Stage at Perfs:2.0 PPA 6724 3416 736.2 40.0 4.0 14 12:40:53 Start 6.0 PPA Automatically 6916 3395 792.2 39.9 4.0 15 12:43:29 Stage at Perfs:4.0 PPA 7763 3452 896.0 40.0 6.0 16 12:45:23 Start 8.0 PPA Automatically 8065 3436 972.0 39.9 6.0 17 12:48:02 Stage at Perfs:6.0 PPA 8298 3403 1076.1 38.6 8.0 18 12:50:02 Start 10.0 PPA Automatically 8335 3456 1152.4 37.9 8.1 19 12:52:50 Stage at Perfs:8.0 PPA 8303 3391 1255.9 36.3 10.0 20 12:53:22 Bringing ball dropper van up to 5,300psi 8330 3438 1275.2 36.1 10.0 21 12:54:57 Start 12.0 PPA Automatically 8335 3436 1332.1 35.9 9.9 22 12:57:54 Stage at Perfs:10.0 PPA 8271 3374 1435.9 34.8 12.1 • • Schluanberger Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuigsut District:Prudhoe Bay,AK Country:United States Stage 11 : As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Ste#p Name Step Prop Volume Rate Time Fluid Name Volume Proppant Name Conc Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (lb( 1 Stage 11 224 38.2 6 YF127ST 9408 0 0 0 PAD Slow for 2 50 23.1 2.6 YF127ST 2100 0 0 0 Seat ResumPAD a 3 56 40.1 1.4 YF127ST 2352 0 0 0 4 1.0 PPA 155 39.8 3.9 YF127ST 6256 CarboLite w/5%ScaleGuard 1 0.5 5712 16/20 5 2.0 PPA 175 40.1 4.4 YF127ST 6767 CarboLite w/5%ScaleGuard 2 0.8 13161 16/20 6 4.0 PPA 200 40 5 YF127ST 7162 CarboLite w/5%ScaleGuard 4.1 1.5 27962 16/20 7 6.0 PPA 200 40.1 5 YF127ST 6660 CarboLite w/5%ScaleGuard 6.1 0.8 39338 16/20 8 8.0 PPA 200 39.4 5.1 YF127ST 6218 CarboLite w/5%ScaleGuard 8.3 2.6 49316 16/20 9 10.0 PPA 199 37.6 5.3 YF127ST 5808 CarboLite w/5%ScaleGuard 10.3 5 57677 16/20 10 12.0 PPA 175 36.1 4.9 YF127ST 4812 CarboLite w/5%ScaleGuard 12.3 3.4 57404 16/20 11 Clear 24.5 35.5 0.7 YF127ST 939 CarboLite w/5%ScaleGuard 12.2 0 2243 Lines 16/20 12 Spacer 23 28.7 0.9 YF127ST 966 0 0 0 13 Ball 3 21.1 0.1 YF127ST 126 0 0 0 3.009" Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Stage 11 PAD 38.2 40.5 7253 8257 2444 2 Slow for Seat 23.1 39.4 4511 5785 2444 3 Resume PAD 40.1 40.2 5941 6074 5712 4 1.0 PPA 39.8 40.2 5884 6032 5849 5 2.0 PPA 40.1 40.2 5864 5913 5794 6 4.0 PPA 40.0 40.2 6410 6811 5918 7 6.0 PPA 40.1 40.4 7489 7918 6815 8 8.0 PPA 39.4 40.2 8194 8344 7891 9 10.0 PPA 37.6 38.8 8297 8326 8253 10 12.0 PPA 36.1 36.9 8263 8312 8225 11 Clear Lines 35.5 36.5 8070 8239 7868 12 Spacer 28.7 36.8 5370 8216 3588 13 Ball 3.009" 21.1 21.1 4150 4266 4055 • 0 Schiumberger Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 11 : Job Messages Message Log Message Treating Annulus Stage Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 13:01:04 Start Stage 11 PAD Automatically 4439 3233 0.0 21.0 0.0 2 13:01:30 2.925"Ball away 3447 total slurry 5996 3304 10.2 27.7 0.0 3 13:03:25 Stage at Perfs:12.0 PPA 7873 3477 81.9 39.5 0.0 4 13:06:58 Ball 3.009"loaded 2352 3128 222.6 19.1 0.0 5 13:08:30 2.925"Ball seat 3684 total slurry 3913 3210 241.6 12.2 0.0 6 13:08:38 Bringing rate back up to 40 bpm 4439 3249 243.5 16.6 0.0 7 13:11:03 Start 1.0 PPA Automatically 6023 3470 330.1 40.2 0.0 8 13:14:57 Start 2.0 PPA Automatically 5845 3445 485.3 40.1 1.0 9 13:17:56 Stage at Perfs:1.0 PPA 5895 3418 604.8 40.1 2.0 10 13:19:19 Start 4.0 PPA Automatically 5918 3394 660.2 40.0 2.0 11 13:21:49 Stage at Perfs:2.0 PPA 6472 3452 760.2 40.0 4.0 12 13:24:19 Start 6.0 PPA Automatically 6820 3438 860.2 40.0 4.0 13 13:26:12 Stage at Perfs:4.0 PPA 7493 3447 935.3 40.1 6.1 14 13:29:18 Start 8.0 PPA Automatically 7937 3442 1060.0 40.1 6.0 15 13:31:11 Stage at Perfs:6.0 PPA 8239 3438 1134.9 39.7 8.0 16 13:34:23 Start 10.0 PPA Automatically 8307 3400 1260.2 38.7 8.0 17 13:35:39 Bringing up ball dropper van pressure 8280 3467 1308.8 37.9 10.0 18 13:36:21 Stage at Perfs:8.0 PPA 8312 3458 1335.2 37.6 10.0 19 13:39:41 Start 12.0 PPA Automatically 8312 3392 1459.3 36.8 10.0 20 13:41:46 Stage at Perfs:10.0 PPA 8257 3462 1535.1 36.2 12.1 ! 0 Schlumberger l Berger Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuiqsut District:Prudhoe Bay,AK Country:United States Stage 12: As Measured Pump Schedule As Measured Pump Schedule Step Step Slurry Slurry Pump Fluid Prop Prop Prop Name Volume Rate Time Fluid Name Volume Proppant Name Conc Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (Ib) 1 StageD12PA 215 38.2 5.8 YF127ST 9030 0 0 0 Slow for 2 50 23.4 2.6 YF127ST 2100 0 0 0 Seat ResumPAD a 3 50 40 1.2 YF127ST 2100 0 0 0 4 1.0 PPA 150 39.4 3.8 YF127ST 6049 CarboLite w/5%ScaleGuard 1 0.9 5647 16/20 5 2.0 PPA 170 39.9 4.3 YF127ST 6575 CarboLite w/5%ScaleGuard 2 0.9 12751 16/20 6 4.0 PPA 190 40 4.8 YF127ST 6806 CarboLite w/5%ScaleGuard 4.1 1.2 26517 16/20 7 6.0 PPA 190 40.1 4.7 YF127ST 6328 CarboLite w/5%ScaleGuard 6.2 4.1 37330 16/20 8 8.0 PPA 190 39.6 4.8 YF127ST 5913 CarboLite w/5%ScaleGuard 8.3 6.3 46727 16/20 9 10.0 PPA 190 37.8 5 YF127ST 5546 CarboLite w/5%ScaleGuard 10.3 1.2 55039 16/20 10 12.0 PPA 200.2 36 5.5 YF127ST 5782 CarboLite w/5%ScaleGuard 12.5 0 59666 16/20 11 Spacer 23 37.3 0.6 YF127ST 966 0 0 0 12 XL Flush 63 39.1 1.6 YF127ST 2646 0 0 0 13 LG Flush 86 35.9 2.6 WF127 3612 0 0 0 14 Freeze 26.2 18.8 2.3 Freeze Protect 1100 0 0 0 Protect Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Stage 12 PAD 38.2 40.3 7016 8060 2439 2 Slow for Seat 23.4 38.8 4419 5850 2938 3 Resume PAD 40.0 40.1 6098 6316 5877 4 1.0 PPA 39.4 40.0 6065 6312 5950 5 2.0 PPA 39.9 40.2 6017 6064 5904 6 4.0 PPA 40.0 40.1 6472 6864 6037 7 6.0 PPA 40.1 40.2 7427 7787 6866 8 8.0 PPA 39.6 40.1 8105 8321 7740 9 10.0 PPA 37.8 39.3 8291 8321 8243 10 12.0 PPA 36.0 36.8 8234 8303 7941 11 Spacer 36.7 36.9 8294 8298 8275 12 Spacer 37.3 37.5 8205 8262 8179 13 XL Flush 39.1 40.1 8184 8275 7969 14 LG Flush 35.9 40.4 6617 7964 3524 15 Freeze Protect 18.8 21.1 4747 8596 3290 • • Sch1umbeger Client:Caelus energy Alaska Well:ODSN-22 Stages 9-12 Formation:Nuigsut District:Prudhoe Bay,AK Country:United States Stage 12: Job Messages Message Log Message Treating Annulus Stage Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 13:46:15 Start Stage 12 PAD Automatically 4339 3177 0.0 20.9 0.0 2 13:46:25 3.009"Ball away 5131 total slurry 4664 3181 3.5 21.8 0.0 3 13:47:44 Stage at Perfs:12.0 PPA 8060 3423 49.4 39.4 0.0 4 13:53:17 3.009"Ball seat 5358 total slurry 2979 3081 230.3 12.1 0.0 5 13:53:25 Bringing rate back up to 40 bpm 3213 3105 231.9 12.1 0.0 6 13:54:50 Stage at Perfs:Stage 12 PAD 5904 3331 274.5 40.1 0.0 7 13:55:51 Start 1.0 PPA Automatically 6312 3477 315.2 40.0 0.0 8 13:55:51 Started Pumping Prop 6312 3477 315.2 40.0 0.0 9 13:59:40 Start 2.0 PPA Automatically 5941 3398 465.5 39.4 1.0 10 14:02:34 Stage at Perfs:1.0 PPA 6064 3455 581.1 40.1 2.0 11 14:03:55 Start 4.0 PPA Automatically 6042 3459 635.2 40.0 2.0 12 14:06:19 Stage at Perfs:2.0 PPA 6559 3438 730.9 40.0 4.0 13 14:08:40 Start 6.0 PPA Automatically 6879 3419 825.1 40.0 3.9 14 14:10:34 Stage at Perfs:4.0 PPA 7442 3423 901.0 40.2 6.0 15 14:13:25 Start 8.0 PPA Automatically 7790 3418 1015.4 40.2 6.0 16 14:15:19 Stage at Perfs:6.0 PPA 8115 3421 1090.8 39.8 8.0 17 14:18:13 Start 10.0 PPA Automatically 8317 3412 1205.4 39.3 8.0 18 14:20:11 Stage at Perfs:8.0 PPA 8317 3398 1281.1 37.9 10.0 19 14:23:14 Start 12.0 PPA Automatically 8294 3435 1395.0 36.7 10.1 20 14:25:20 Stage at Perfs:10.0 PPA 8253 3435 1471.4 36.0 12.2 21 14:29:25 Start XL Flush Automatically 8179 3363 1618.2 37.6 0.0 22 14:30:31 Stage at Perfs:12.0 PPA 8207 3395 1660.9 40.1 0.0 23 14:31:02 Start LG Flush Automatically 7923 3391 1681.6 40.1 0.0 24 14:33:48 On freeze protect 6890 bbls total slurry 3950 3169 1770.9 21.1 0.0 25 14:34:00 Planned shutdown at 6965 bbls total slurry 4014 3174 1775.1 21.0 0.0 26 14:37:23 Pressured out,lines are clear,13 bbls of freeze 6376 2834 1789.8 0.0 0.0 protect past W 27 14:40:54 Trying to get back into it 3583 2478 1789.8 1.2 0.0 28 14:53:54 WH closed,23.5 turns on master valve 2929 2304 1793.3 0.0 0.0 29 14:54:14 Bleeding surface lines 13 21391 1793.3 0.0 0.0 30 14:58:41 Fanning pumps -5 520 1793.3 29.7 0.0 • • Client: Caelus Energy Alaska Schlumberger Wein ODSN-22 u (ji {v{�j Basin/Field: Oooguruk State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Post-Job Well Completed: 2/25/2016 Date Prepared: 3/2/2016 3:21 PM Report ID: RPT-41684 Fluid Description(s) YF127ST:WF127 733,641 Gal Contains:Water,Antifoam Agent,SCALEGUARD®IV,Surfactant,Breaker,Crosslinker,Gelling Agent,Scale Inhibitor, Additive,Bactericide,Propping Agent The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction - Water(Including Mix Water Supplied by Client)* 71.19235 % 56-81-5 1,2,3-Propanetriol 0.09772 % 64-19-7 Acetic acid(impurity) 0.00001 % 67-63-0 Propan-2-ol 0.01361 % 107-21-1 Ethylene glycol 0.03541 % 111-46-6 2,2"-oxydiethanol(impurity) 0.00036% 111-76-2 2-butoxyethanol 0.01361 % 112-42-5 1-undecanol 0.00109 % 127-08-2 Acetic acid,potassium salt 0.00004% 533-74-4 Tetrahydro-3,5-dimethyl-1,3,5-thiadiazine-2-thione <0.00001 % 1303-96-4 Sodium tetraborate decahydrate 0.07980 % _ 1310-58-3 Potassium hydroxide 0.01413 % 1310-73-2 Sodium hydroxide(impurity) 0.00466% 1338-41-6 Sorbitan stearate 0.00001 % 2634-33-5 1,2-benzisothiazolin-3-one <0.00001 % 2682-20-4 2-methyl-2h-isothiazol-3-one 0.00004% 7447-40-7 Potassium chloride(impurity) 0.00011 % 7631-86-9 Non-crystalline silica(impurity) 0.00058 % 7632-00-0 Sodium nitrite <0.00001 % 7647-14-5 Sodium chloride 0.00669 % 7727-54-0 Diammonium peroxidisulphate 0.05061% 7786-30-3 Magnesium chloride 0.00013 % 9000-30-0 Guar gum 0.23216 % 9002-84-0 poly(tetrafluoroethylene) 0.00012% 9003-35-4 Phenolic resin 0.03535 % 9004-32-4 Sodium carboxymethylcellulose <0.00001 % 9005-65-6 Sorbitan monooleate,ethoxylated <0.00001 % 10043-52-4 Calcium Chloride 0.00338% 10377-60-3 Magnesium nitrate 0.00026 % 11138-66-2 Xanthan Gum <0.00001 % 14464-46-1 Cristobalite 0.00003 % 14807-96-6 Magnesium silicate hydrate(talc) 0.00028% 14808-60-7 Quartz,Crystalline silica 0.00003 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer 0.00927 % _ 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one 0.00014% 34398-01-1 Alcohol,C11 linear,ethoxylated 0.01250 % 36089-45-9 2-Propenoic acid,2-ethylhexyl ester,polymer with 2-hydroxyethyl 2-propenoate 0.00001 % 63148-62-9 Dimethyl siloxanes and silicones 0.00010% 66402-68-4 Ceramic materials and wares,chemicals 28.10467 % 67762-90-7 Siloxanes and silicones,dimethyl,reaction products with silica 0.00006 % 68131-39-5 C12-15 alcohol ethyoxylated 0.00678% 68308-89-4 Fatty acids,C18-unsatd.,dimers,ethoxylated propoxylated 0.00001 % 68715-83-3 2-Butenedioic acid(2Z)-,polymer with sodium 2-propene-l-sulfonate 0.06363 % 68937-55-3 Siloxanes and Silicones,di-Me,3-hydroxypropyl Me,ethoxylated propoxylated 0.00001 % 91053-39-3 Diatomaceous earth,calcined 0.00130% 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate 0.03312 % Total 100% Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may hove been added to the water by third-parties. O Schlumberger 2016.Used by Caelus Energy Alaska by permission. Page:1/1 • 1 I 1? .g t fti 2 a 0, 0 ze 3 a 1' Ge< 1. .., t kiLl 11 z I4, ,. rri' 41 i4t '16' 1 br -4, '',-ii.-41 I -J $ 0 0 .1 0 it, ,-., . . UI X '8 ,-, 0 Cr N 0 N 0 Cf4 4-4 0 (.11 a) co .F.,4, c• --„ -4, ..., --.. ch --4. 01 cN --.. D " A ''' C0 .-4 01 ,I CT 0 0 CI iii et --... Cl --.. N -- 11' -... 0" 0 1_,a- U_ 0 W (0 cn • .cr ..-1 o cn --1 Cl ClU. f-4 0 01 .41 01 0 0 1(1 01 UICO •.=i cd rO ko i. . nr 0.. 0 1 co 111 N 04 s0 N f,-I 41 tO '0 1 CO n 0 W C 4i9 0 h 1 cCD 0 CP CV U 0 ..6 '0 0 0 0 — = 0 v.) 40 •:. UI in CL cr) fs in f f-4 .-1 fr4 ...4 If V 0 •-t 0 0 0 0 If fi (14 0 (N 0 t-.4 '.. , -... N N 01 04 04 -.. N -4 04 •••-• N 04 N --.. e-1 CV 0 '',- 07 et — - .--.- - N —'N -.... rn Cl i Ct 40 in if 11 et4 ..0 r-i 141 1-4 141 4-4 tt ,.4 4-4 0 0 0 0 1 i 0 11 C Alt "kii 0 ('4--.. N 04 4,..., - 4-I N 00 -"11. ..iii N --.. 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In t cu as CD 0 -cli 0/ his• i* 4.) ra 0 so ra ra LI. kn E U U U U U U LI • , , ( = v) 2 0 0 0 0 W 0 0 ar 0 0 41) W NM LIN 13 '3 'X To Iii 3 = S' 0 0 0al 0 a 8 116' , .03 w isn OM --) -- 11:1 ... , .0 Ts, .0 d *4. tol c cL, LU LU U..1 2 LW I a. 1 2trj-05�{ OF 7 11/7 "'-s, THE STATE Alaska Oil and Gas i? ~_s= � , ofA T /r, sKA Conservation Commission x= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF * �, Main: 907.279.1433 ALAS'- Fax: 907.276.7542 www.aogcc.alaska.gov Jack Kralick Wells Superintendent _ O Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive, Suite 500 ,,. Anchorage, AK 99503 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-22 Permit to Drill Number: 215-054 Sundry Number: 315-753 NE) VIL Vii' :01 Dear Mr. Kralick: 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, Cathy P. oerster Chair DATED this 3 day of February, 2016. RBDMS 0- FEB 0 4 2016 RECEIVED Ill STATE OF ALASKA • DEC 16 20 ALASKA OIL AND GAS CONSERVATION COMMISSION 0S 3//6 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate Q • Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Caelus Natural Resources Alaska, LLC Exploratory ❑ Development Q • 215-054 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3700 Centerpoint Drive,Ste.500,Anchorage,AK 99503 50-703-20708-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ODSN-22 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036, ADL 355037 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): 22,208' • 6,197' • 22,205' 6,197' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 6,276' 11-3/4" 6,548' 3,211' 5,830 psi 3,180 psi Intermediate 1 10,950' 9-5/8" 11,717' 4,915' 5,750 psi 3,090 psi Intermediate 2 15,663' 7" 15,699 6,077' 7,240 psi 5,410 psi Production 6,776' 4-1/2" 22,204' 6,197' 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 See attachment pg.2 4-1/2", 12.6# C-110,Hyd 521 15,449' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): See attachment pg.3 See attachment pg.3 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work 2/11/2016 Commencing Operations: OIL ❑i . 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. Contact Jack Kralick,907-343-2185 Email)ack.kralickZcaeluseneray.com Printed Name Title Jack Kralick Wells Superintendent Signature Phone pate --- 16'(' , 907-343-2185 lz1i1)5 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315-- 753 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ 9 Y ❑ Location Clearance i, ✓ Ir Other: , b1".tS5.c`'• Ze) 4'4G AS- z- 3 (c) I I�C G Lg j w C Post Initial Injection MIT Req'd? Yes EI No Spacing Exception Required? Yes ❑ No Subsequent Form Required: /O" `f Oy RBDMS I(-- FEB 0 4 2016 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: L -3 — /4 Submit Form and Form 10-403 R A11/2015 11/2015 A isa r 12 months from the date o�proval. Attas in Duplica�-/ 4(p W 2/int , • • Attachment 2 AOGCC Form 10-403 Application for Sundry Box 11 - Perforation Locations Well: ODSN-22 Top (MD) Bottom(MD) Top (TVD) Bottom (TVD) 4-1/2" RapidStage Sleeve #11 16,087 16,090 6,111 6,112 4-1/2" RapidStage Sleeve #10 16,690 16,692 6,134 6,134 4-1/2" RapidStage Sleeve #9 17,265 17,268 6,139 6,139 4-1/2" RapidStage Sleeve#8 17,842 17,845 6,146 6,146 4-1/2" RapidStage Sleeve#7 18,402 18,405 6,155 6,156 4-1/2" RapidStage Sleeve#6 19,048 19,051 6,164 6,164 4-1/2" RapidStage Sleeve#5 19,658 19,661 6,174 6,174 4-1/2" RapidStage Sleeve #4 20,113 20,116 6,180 6,180 4-1/2" RapidStage Sleeve #3 20,801 20,803 6,177 6,177 4-1/2" RapidStage Sleeve#2 21,360 21,362 6,179 6,179 4-1/2" RapidStage Sleeve#1 21,929 21,932 6,191 6,191 Pre-Perforated Pup 22,147 22,152 6,195 6,195 • • Attachment 3 AOGCC Form 10-403 Application for Sundry Box 11 - Packers & SSSV Well: ODSN-22 SSSV MD TVD 4-1/2" Halliburton 'XXO' SVLN 2,882' 2,002' PACKERS 5" x 7" Baker ZXP Liner Top Packer 15,449' 6,055' HES Swell Packer#13 15,771' 6,083' HES Swell Packer#12 15815' 6,086' HES Swell Packer#11 16,397' 6,131' HES Swell Packer#10 16,975' 6,135' HES Swell Packer#9 17,553' 6,142' HES Swell Packer#8 18,114' 6,149' HES Swell Packer#7 18,718' 6,161' HES Swell Packer#6 19,358' 6,169' HES Swell Packer#5 19,890' 6,177' HES Swell Packer#4 20,386' 6,177' HES Swell Packer#3 21,073' 6,178' HES Swell Packer#2 21,596' 6,183' HES Swell Packer#1 22,114' 6,195' • s CAELJS Ener, Alaska ODSN-22 Sundry Application Requirements (1) Affidavit of Notice —Attachment A • (2) Plat showing well location, as well as 'A mile radius around well with all well penetrations, fractures, and faults within that radius —Attachment B (3) Identification of freshwater aquifers within I/2 mile radius — no freshwater aquifers in this area (4) Plan for freshwater sampling — no freshwater wells, therefore no sampling planned • (5) Detailed casing and cementing information —Attachment C (6) Assessment of casing and cementing operations ODSN-22 11-3/4" surface cement job was pumped with 53.3% calculated open hole excess factor. A successful 3500 psi surface casing test was held for 30 min and charted. A subsequent 12.5 EMW FIT was achieved below the surface shoe. The 9-5/8" Intermediate 1 cement job was pumped with 332 bbls corrected losses throughout cement job. A successful 3500 psi pressure test was held for 30 min and charted. The FIT below the 9-5/8" shoe was // held to 13.0 EMW. The 7" Intermediate 2 cement job was Pumped in two stales., Stage 1 pv/ ty was pumped with 96% calculated losses. The stage 1 plug bumped on stokes and a 2335 �/// psi pressure test for 5 min. Stage 2 was pumped with 100% returns. A cement bond log is on file with the AOGCC. A successful 4000 psi pressure test was held for 30 min and charted. The FIT below the 7" shoe was held to 12.5 EMW. (7) Casing and tubing pressure test information Date Void Tested Pressure Duration Charted 5/14/2015 7" Casing 4000 psi 30 min Yes 4-1/2" Tubing 3500 psi 30 min Yes 6/1/2015 IA 4000 psi 30 min Yes (8) Pressure ratings for wellbore, wellhead, BOPE and treating head —Attachment D & I i . (9) a — d Lithological and geological descriptions of each zone —Attachment E e. Estimated fracture pressure for each zone Pump Held IA Trip Pressure IA PRV GORV Pressure (psi) (psi) (psi) (psi) Stages 1-4 3500 3700 9300 9000 Stages 5-8 3500 3700 9300 9000 Stages 9-12 3500 3700 9300 9000 MD Perf TVD Pen Max Frac Frac 1/2 Max Max Max Prop Depth Depth Height Length Rate Pressure Conc Stage (feet) (feet) (feet) (feet) (bpm) (psi) (ppa) 1 22150 6195 137 158 40 7470 8.0 2 21932 6191 143 300 40 7950 8.0 3 21362 6179 146 351 40 8090 8.0 4 20804 6177 146 348 40 7890 8.0 5 20116 6180 137 315 40 7940 10.0 6 19661 6174 148 251 40 7890 10.0 7 19051 6164 139 366 40 7750 10.0 8 18405 6155 133 323 40 7820 12.0 9 17845 6146 133 355 40 8010 10.0 10 17268 6139 127 320 40 7920 10.0 11 16693 6134 127 340 40 7820 12.0 12 16090 6111 130 312 40 7860 12.0 (10) Mechanical condition of wells transecting the confining zones - Attachment F (11) Location of faults and fractures in wellbore 1/2 mile radius —Attachment B (12) Detailed proposed fracturing program - Attachments G and H (13) Flowback procedure —Attachment I Section (b) We will not be treating through production or intermediate casing strings ODSN-22 10-403 Sundry App. For Fracture Stimulation October 12,2015 Page 2 of 3 Section (c) Attachment I and below: SLICKLINE PROCEDURES Pre Fracture Stimulation - Slickline Program: 1. Record Tubing, IA, and OA pressures. Record BHP and Temp. Note on Wellview Report. 2. Complete well handover form from Operations to Wells Group. 3. Conduct a pre-job safety meeting with HES, Wells Group Supervisor, and all personnel involved in the job scope. 4. MIRU HES Combo Unit w/.125 wire. Hang load cell, and necessary sheaves. 5. Pick up lubricator, toolstring, and 3.83" gauge ring. 6. Make up lubricator to wellhead and pressure test as per HES policy & procedure. (1.5 times expected WH pressure) 7. RIH w/ 3.83" gauge ring to "XXO" SVLN @ 2,882' MD. 8. RIH w/4.5 GS to 4.5" FXE SSSV in SVLN @ 2,882' MD. 9. LRS to load tubing w/230 bbls of diesel to XN nipple @ 14,867' MD. 10. RIH w/3.80" gauge ring(3/4" Internal SR), 2' weight bar, and 4.5 BLB to XN nipple @ 14,867' MD. 11. Make up HES DPU w/4.5 Evo-Trieve RBP. Set travel & still time as per HES recommendation. 12. RIH w13.5" GR, 3.5" bait sub, HES 2.75" Downhole Power Unit, and 3.66" Evo-Trieve RBP w/3.75 cent to XN nipple @ 14,867' MD. Set 3.66" Evo-Trieve RBP © 14,860' MD. . 9 ..4 112 . 12.80 -`G-11 1467 Mo 14,.= .4 61b' 9 Joint NES 3813" 4 734 1260 C•110 Yes 1.47 No 14,66617 61808' wI 3.726-No SNc304324 TubIng Pup 4 02 12-60 C-110 Yes 14.30 No 14,8622 832 78 13. Perform MIT-T to ?D6L'psi for 30 minutes. Record results in Wellview Report. Bleed tubing pressure to zero: - /-1(--/c- 14. Perform MIT-IA to 4000 psi for 30 I`ninutes. Record results in Wellview Report. Bleed IA to zero. 15. Report MIT results to Anchorage team before proceeding w/program. 16. RIH w/3.5 barbell assembly & 2-3/8" GR to 3.66" Evo-Trieve RBP © 14,860' MD. Equalize & pull plug. 17. Purge control line w/3 gallons of hydraulic oil. RIH w/ 4-1/2" GS & 4.5" Frac Isolation Sleeve SSS (3.12" ID) to "XXO" SVLN © 2,882' MD. Set frac sleeve & establish control line integrity to 4000 psi. 18. RIH w/KJ, 2' weight bar, and 3.00" Swage to as deep as possible to verify tubing is free of any obstructions. Note final depth in Wellview report. 19. RDMO HES Slickline. Wells Group will keep possession of well handover during Frac operations. Section (d) High Pressure Line Pressure Relief Valve (PRV) Rig Up -Attachment J Final Wellbore Schematic-Attachment K �y • ut) ODSN-22 10-403 Sundry App. For Fracture Stimulation October 12,2015 Page 3 of 3 7SL • • CE CAELLS AIA5ka Mr. Guy Schwartz AOGCC- PE Re: ODSN-22 PTD: 215-054 Dear Mr. Schwartz, Caelus Energy Alaska would like to request a variance to the pressure testing guidelines for the ODSN-22 tubing pressure test pre-frac. The area that is not exposed to the internal tubing pressure test is from the 'XN' nipple @ 14867' MD where the pressure test plug will be set, to the top of the linertop packer @ 15449' MD. We believe that a test from the 'XN' to the surface would give us the confidence that the lower untested section would also pass the test. In summary we would like to request the variance for the internal tubing pressure test for the area from 14867'MD to 15449' MD. With the 9000 psi maximum pressure during the frac job and a 8500 psi pump trip pressure the calculation is: (9000-3500) *1.1 = 6050 psi on the internal tubing test. The area will be tested externally by the MITIA pressure test to 3500 psi. Sincerely, Jack Kralick Caelus Wells Superintendent 907 343-2185 office • AFFIDAVIT STATE OF ALASKA ) ss. THIRD JUDICIAL DISTRICT Rachel Davis, being duly sworn, states: 1. That I am the Engineering Technician for Caelus Natural Resources Alaska, LLC, ("Caelus"), Operator of the Oooguruk Unit, with offices at 3700 Centerpoint Dr., Suite 500, Anchorage, Alaska, 99503, and am acquainted with the facts associated with the drilling of the ODSN-22 well ("Well"). 2. That all owners, landowners, surface owners, and operators within one-half mile radius of the • current wellbore trajectory have been provided a Notice of Operations that is in compliance with the requirements of 20 AAC 25.283.A copy of the notice is attached hereto. 3. I have reviewed the Application for Sundry Approvals for the proposal that the Well be stimulated by hydraulic fracturing as defined 20 AAC 25.283 (m). 4. On December 15, 2015, pursuant to 20 AAC 25.283 (1) Caelus sent a copy of the Notice Letter by . electronic mail to the last known address of all owners, landowners, surface owners and operators within a one half mile radius of the current proposed trajectory providing Caelus' contact information and stating that upon request Caelus will make a complete copy of the application available. These names and addresses are set forth on Attachment A attached to Caelus' Application for Sundry Approvals under 20 AAC 25.283 dated December 15, 2015. I, Rachel Davis, swear under penalty of perjury that to the best or my knowledge and belief that the foregoing is true. Rachel Davis, Engineering Technician THIS IS TO CERTIFY that on the /5i'v' day oIc—b.eA- , 2015, at Anchorage,Alaska before me, a notary public in and for the State of Alaska, duly commissioned and sworn as such, personally appeared Rachel Davis, known to be the individual named herein, who acknowledged to me that she executed the foregoing instrument freely and voluntarily for the uses and purposes mentioned therein, and that the same was her act. IN WITNESS WHEREOF I have hereunto set my hand and official seal on the day and year above written. JOY J. TORO Notary Public in and for Alaska Notary Public �` M StateAlaskaMy commission expires: I ��12C)f My Commission Exx pireires OOct 25,2019 ATTACHMENT A • • From: Rachel Davis To: 'Dickenson.HAK(DNR)";"Kim Kruse(kim.kruse(@alaska.gov)";"Nina Brudie(nina.brudie(@alaska.gov)";"Saree Timmons(saree.timmonsPalaska.gov)";'Temple Davidson(temole.davidson(aalaska.gov)" Subject: CNRA,LLC ODSN-22 Notice of Upcoming Operations Date: Tuesday,December 15,2015 1:38:00 PM RE: ODSN-22 AOGCC API 50-703-20708-00 Oooguruk Unit—Tracts 13 and 14 Lease Numbers ADL 355036 and ADL 355037 Pursuant to the requirements set forth by 20 AAC 25.283, I am hereby notifying you that Caelus Natural Resources Alaska, LLC plans to commence operations to perform a Fracture Stimulation on ODSN-22 beginning February 11, 2016. If you would like to review the complete AOGCC 10-403 Sundry Application for these operations, please contact me at the address below, or via a return email. Please also respond if you do not want to be included on the distribution of this notice for additional activities. Thanks, Rac.ke 1. Da%rL Engineering Technician Caelus Energy Alaska LLC 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct: 907-343-2159 rachel.davisPcaelusenergy.com ATTACHMENT A W H z w 1 E CSN N c 7/--- 1 I 41 Cr) 0) Li - W C a.W N� ////c/..1.141!./. Qo C - �U O _ 1 411.0 D — o o Z iiiii,,,-0 Akori ir , , o z......."1,,,,:e4.0 _ 0 c'.4 ` •0 Z x" > - i4 O 4 D.- £ + ./ Ys UJ e- M O Y Z ❑ __.. O r c q // Z _ • li ❑ ,lt L.,c,• Z i- O N C1 Z O O❑ O 0 CV N M O �-1 0 0 Ocn O ❑ p • N N 67 • 1 N ❑ Z -....__. W C O_ N N Q. • 0 Caelus Energy Alaska CASING&CEMENTING REPORT Lease 8 Well No. ODSN-22i Date 8-May-15 County North Slope Borough State Alaska Supv. CASING RECORD-Intermediate#2 TD 15726.70 Shoe Depth: 15699.30 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Float Shoe 7.000 26 L-80 Hydril 563 HES 2.74 15,699.30 15,696.56 (1-2)Casing 7.000 26 L-80 Hydril 563 79.29 15,696.56 15,617.27 Float Collar 7.000 26 L-80 Hydril 563 HES 2.65 15,617.27 15,614.62 (3-4)Casing 7.000 26 L-80 1-lydril563 80.84 15,614.62 15,533.78 Baffle Adapter 7.000 26 L-80 Hydril 563 HES 2.08 15,533.78 15,531.70 (5-83)Casing 7.000 26 L-80 Hydril 563 HES 3,189.50 15531.70 12,342.20 Stage Tool 7.000 26 L-80 Hydril 563 HES 3.42 12,342.20 12,338.78 (84-386)Casing 7.000 26 L-80 Hydri1563 12,255.50 12,338.78 83.28 PupJoint 7.000 26 L-80 Hydril 563 9.83 83.28 73.45 (387)Casing 7.000 26 L-80 Hydril 563 36.80 73.45 36.65 RKB 7.000 26 L-80 Hydri1563 36.65 36.65 0.00 Totals 15,699.30 Csg Wt.On Hook: Type Float Collar Halliburton SSII No.Hrs to Run: 33 Csg Wt.On Slips: Type of Shoe: HES Comp.Eccent. Casing Crew: TESCO Fluid Description: Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 1 per Joint-15,699.3-14,320.6,1 per Joint 12,382.6-11,285.9 CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer Ill Density(ppg) 11.5 Volume pumped(BBLs) 60 Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume(BBL5/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: HalCem IPT Yield(Ft3/sack): 1.17 aDensity(ppg) 15.69 Volume(BBLs/sacks): 78.4/365 Mixing/Pumping Rate(hpm): 2.6 LI Post Flush(Spacer) ',7) Type:SeaWater Density(ppg) 8.53 Rate(bpm): 3.0 Volume: 20 E Displacement: Type: LSND Density(ppg) 10.1 Rate(bpm): 4.49 Volume(actual/calculated): 575.63/574.47 FCP(psi): 1,842 Pump used fordisp: Rig pumps Plug Bumped? X Yes No Bump press 2,335 Casing Rotated? _Yes X No Reciprocated? Yes X No %Returns during jobNo Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: 22:11 Date: 5/8/2015 Estimated TOC: 14,512 `'' • Method Used To Determine TOC: BATSonic Log Preflush(Spacer) Type: Tuned Spacer Ill Density(ppg) 11 Volume pumped(BBLs) 60 Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume(BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: HalCem IPT Yield(Ft3/sack): 1.2 FDensity(ppg) 15.8 Volume(BBLs/sacks): 52.68/255 Mixing/Pumping Rate(bpm): 2.79 N Post Flush(Spacer) ./ o Type:SeaWater Density(ppg) 8.5 Rate(bpm): 4.03 Volume: 20 w Displacement: co Type: MOBM Density(ppg) 10.1 Rate(bpm): 4.87 Volume(actual/calculated): 452.37/452.60 FCP(psi): 710 Pump used for disp: Rig pumps Plug Bumped? X Yes No Bump press 2,342 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? _Yes X No Spacer returns? _Yes X No Vol to Surf: - Cement In Place Al: 12:06 Date: 5/9/2015 Estimated TOC: 11,100 Method Used To Determine TOC: Cement volume pumped with full returns during cement job Remarks: ATTACHMENT C • • Operations Summary Report- State Well Name: ODSN-22 CS CAE LU „,:,-„y Alaska Start Depth Foot/Meters Dens Last Start Date End Date (EKE) (ft) Mud(154al) Summary 5/4/2015 5/5/2015 15,481.0 245.00 10.20 Drill 8-1/2"x 9-1/2"Intermediate#2 hole f/15,481'11 15,709'. Stop drilling to change out top drive encoder. Drill 8-1/2"x 9-1/2"Intermediate#2 hole f/15,709't'15,726',the TD of the interval. Pump down RFID tags&close RipTide reamer. Perform Sperry Drilling quadrant ream procedure to enlarge the 8-1/2"hole beneath the under reamer while circulating the hole clean. Pumped a 25 bbl 12.2 ppg sweep while circulating a total of 6.5x bottoms up. Lubricate w/ rotation out of the hole while utilizing low energy parameters f/15,726't/11,649'. Service rig while inside the 9-5/8"liner. 5/5/2015 5/6/2015 15,726.0 0 00 12.30 TIH f/11,649't/15,726'. Stage up pumps utilizing the step rate method to 650 GPM. Circulate the hole clean prior to performing mud displacement. Pump 25 bbl 12.3 ppg(2.1 ppg over MW) high viscosity sweep and a total of 3.5x bottoms up at full rate. Displace wellbore from 10.2 ppg LSND to 12.3 ppg LSND. Stopped circulation w/12.1 ppg LSND at surface,performed flow check,then removed MPD RCD&installed the trip nipple. Completed displacement w/12.3 ppg back to surface. Lubricate w/rotation out of the hole f/15,276't/11,649'. ***Perform weekly function test of BOP equipment as per AOGCC&PTD requirements.*** 5/6/2015 5/7/2015 15,726.0 0.00 12 30 Pull 5 stands on elevators f/11,649't/11,174'on elevators. Good displacement&no swabbing. Pump dry job. POOH on elevators f/11,174'1/604'. UD BHA#6 f/604'to surface. Change upper rams from 2-7/8"x5"VBR to 7". Test 7"rams against 7"test ioint according to AOGCC&PTD requirements. -250 PSI low&4500 PSI high test. -Hold each test for 5 min.&chart same. -Tests performed with 8.5 ppg seawater. R/D test equipment. R/U Tesco casing equipment. Run 7"26#L-80 H,riril 56'3 g fr;m surface to 1675'. Fill 7"casing w/10.1 ppg LSND. 5/7/2015 5/8/2015 15,726.0 0.00 10.10 Run 7"26#L-80 Hydril 563 casing from 1675'to 14,242'. Rotated 7"casing down f/14,243't/ 14,276 w/20-30 RPM. Fill 7"casing w/10.1 ppg LSND. 5/8/2015 5/9/2015 15,726.0 0.00 10.10 Rotated 7"casing down f/14,276't/15,699 w/25-30 RPM. Fill 7"casing w/10.1 ppg LSND. R/D Tesco Casing Drive System. R/U Halliburton cement head. Establish circulation utilizing the step rate method to 6 BPM. Just before initiating cementing operations,experienced a 1000 PSI pressure increase/pack-off. Attempt to re-establish full circulation unsuccessful--assumed packed-off at the HRZ. Zero to 20%returns was the best achievable. Perform 7"casing Intermediate#2 first stage cement job. -Fill lines&pump 10 bbls of 8.5 ppg seawater. -Test lines to 4500 PSI. -Pump 60 bbls of 11.5 ppg Tuned Spacer at 1 to 3 BPM. -Mix&pump 78.4 bbls of 15.69 ppq Premium G cement, 365 sacks,1.17 fte3/sack yield at 3 BPM. -Drop shut-off plug. -Pump 20 bbls of 8.5 ppg seawater at 3 BPM. -Displace utilizing rig pumps&10.1 ppg LSND at 5 BPM. --Observe lift as cement turned the corner @ 5944 stokes. Halliburton calculated 216 PSI of lift pressure. ** 263'TVD of fill for calculated TOC at 14,512'. ** 570'above Kuparuk C marker. -Slow to 3 BPM to bump plug at 6870 strokes. -CIP@22:11. -Pressure up to 2335 PSI&hold for 5 min. -Bleed off&check floats-holding. -725 bbls lost of 750 bbls pumped. Pressure up to shift the Halliburton ES cementer open @ 12,339'. Establish circulation utilizing the step rate method from 2 BPM to 5 BPM. Page 5/9 Report Printed: 10/12/2015 • • Operations Summary Report - State Well Name: ODSN-22 CAELU Alaska Start Depth FootlMeters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gaI) Summary 5/9/2015 5/10/2015 15,726.0 0.00 10.15 Circulate 10.1 ppg LSND at 5 BPM. Displace wellbore through ES cementer @ 12,339'from 10.1 ppg LSND to 10.1 ppg MOBM. Continue to circulate while preparing for second stage cement job. Perform 7"casing Intermediate#2 second stage cement job. -Fill lines&pump 10 bbls of 11.0 ppg Tuned Spacer III at 1 BPM,425 PSI. -Test lines to 3500 PSI-good test. -Pump 50 bbls of 11.0 ppg Tuned Spacer III at 3 BPM,650 PSI. -Shut down and mix cement. -Drop bottom plug. -Pump 52.7 bbls of 15.8 ppg Premium G cement, 255 sacks, 1.17 ft^3/sack yield at 3 BPM,475 PSI. -Drop top plug. -Pump 20 bbls of 8.5 ppg seawater at 5 BPM,325 PSI. -Displace utilizing rig pumps&10.1 ppg LSND. /1 --5 BPM,700 PSI start. V A p/ --5 BPM,1100 PSI end. --Observed bottom plug rupture @ 4756 strokes. -Bumped plug @ 5350 strokes,452.6 bbls(95.9%efficiency). -Pressure up to 2500 PSI,the pressure dropped immediately to 2325 PSI&held for 5 minutes-- good test. -CIP @ 12:06. -Full returns throughout entire job. Re-pressured casing to 2600 psi and held at 2550 for 5 minutes—good test. Closed Annular. Lined up returns to trip tank and bleed 7"casing to verify ES Cementer closed—6.2 bbls returned and no flow. Open kill line and no pressure and no flow from annulus—open annular and verified no flow. Remove trip nipple,break Vetco Gray multi-bowl well head between the casing and tubing spools. Hoist BOP stack&tubing spool. Install Vetco Gray emergency slips with 122K tension. Cut 7"casing as per Vetco Gray specification. Install 10-1/8"x7"pack-off. Lower&re-install BOP stack&tubing spool. Test 10-1/2"x7"pack-off&void between Vetco Gray tubing&casing spools. Test to 4300 PSI for 10 min.&chart same-good test. Set test plug with 4"test joint. Change upper pipe rams from 7"to 2-7/8"x5"VBR. 5/10/2015 5/11/2015 15,726.0 0.00 10.10 Finish changing upper rams from 7"to 2-7/8"x5"VBR,C/O IBOP from 4-1/2"IF to XT-39 and install XT-39 saver sub. R/U test equipment. -Test upper&lower 2-7/8"x 5"pipe rams-good tests. -Test TIW floor safety valve-failed. --Mobilize new TIW floor safety valve to the rig floor. -Test floor safety valves,upper IBOP&lower IBOP-good tests. -Tests performed to 250 PSI low&4500 PSI high. -All tests performed w/8.5 ppg seawater. -All tests held for 5 min.&charted. -Attempted to test annular preventer-failed high pressure test. Remove test joint&test plug. Change out annular preventer element. Install test plug&4"test joint. -Test the annular preventer to 250 PSI low/2500 PSI high. --Tests held for 5 min.each&charted. --Tests performed w/8.5 ppg seawater. R/D test equipment&install Vetco Gray wear bushing. L/D 183 joints of 5"drill pipe from the derrick. ""Provided 48 hour notification of BOP test request to the AOGCC @ 11:56 on 10 May 2015 for expected test @ 11:50 on 12 May 2015.... 5/11/2015 5/12/2015 15,726.0 0.00 10.10 UD 67 stands(201 joints)of 5"drill pipe from the derrick in the mousehole. MU Muleshoe and Tih with 60 joints of 4"drill pipe. Slip and Cut 96'of drill line. Cont to Tih while PU additional 226 joints of 4"drill pipe to 9148'md. Rig Crew conducted BOP Drill. Page 6/9 Report Printed: 10/12/2015 ATTACHMENT C • 0 .16 GE Oil&Gas Mk 4-1/16 10,000 PSI [—I 23.8" WIU.11 U-91.1J 4,'I_Z I r 2-1/16 10,000 PSI IfdTI R1ltfTl I 95.6' /e�� 7 141/4 ! O .0 4-1/16 10,000 PSI 7yir7, 71.8" _i'41114-11"/", \4-1116 10,000 PSI I tii kSr - OII ,; O. In r•,r -"_ '-,..1 -t_ --_J- _ iii is fa aim M112R 5000 PSH -KM iL) MM alin iii 1 i ii. .ill - LTJ 11 • • , ,0 -7._ :• J NNNNNNNNN. ) ` yl !" '•3-1/8 5000 PSI ! •• 37.1" ■ _`�__� inn ■ Viiiif I mm•2-1/16 5066 PSI �,.' 'NM 11 5000 PSI MOD FLG •• , r • W/102 VGRS L4 111J - ■ Il .1 'N 4 *I • 26.7" 2-1/16 5000 PSI N _I1 �1 1:G■ I- I_ !I ii ALL DIMENSIONS ARE APPROXIMATE Thls drawing Is the property of GE ON 6 Gas Pressure Control LP and Is considered confidential.UNess othenvlse approved In writing, CAELUS neither It nor Its contents may be used,coded,transmitted or reproduced except for the sae purpose of GE Oil Gas Pressure Contra LP. Oooguru k FRAC MB-233 Conventional Multibowl Assembly, DRAWN CR 17SEP15 With MB-233 4-1/2"Tubing Hanger, APP RF KN 17SEP15 FOR REFERENCE ONLY With 4-1/16"10M x 4-1/16"10M Spacer Spool DRAWING NO. HP150203 ATTACIIMENT D • • W H Z w U d H Z) ,� H {d�� 'Ili a o a) o C d L'qr i f �FVJlk14P1 . .1 H ^ +' L 'O t !' 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Joe Polya-Company Man Jose Mota-Halliburton Supervisor CASING RECORD-Intermediate 2 Casing TD 14,54T MD Shoe Depth: 14,534'MD PBTD: n/a MD/n/a TVD Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe/jt 7 BTC-M Ray Oil Tool 1.97 14,534.00 14,532.03 Joints 1-2 7 26 L-80 BTC-M 82.11 14,532.03 14,449.92 Float Collar 7 26 L-80 BTC-M Halliburton 1.00 14,449.92 14,448.92 Joints 3-246 7 26 1-80 BTC-M 9,830.52 14,448.92 4,618.40 Joint 247 7 26 L-80 BTC-M 19.46 4,618.40 4,598.94 XO Joint 248 7 26 L-80 HYD 563 41.55 4,598.94 4,557.39 Joints 249-361 7 26 L-80 HYD 563 4,515.94 4,557.39 41.45 Casing Pup it XO 7 26 L-80 HYD 563 2.93 41.45 38.52 7"Hanger 7 60 L-80 HYD 563 0.63 38.52 37.89 Landing Joint 7 60 L-80 HYD 563 37.89 37.89 0.00 Totals 14,534.00 Csg Wt.On Hook: Type Float Collar: Halliburton SSII No.Hrs to Run: Csg Wt.On Slips: Type of Shoe: Ray Silver Bullet Casing Crew: TESCO Fluid Description: 10.2 ppg LSND Liner hanger Info(Make/Model): N/A Liner top Packer?: Yes X No Liner hanger test pressure: N/A Centralizer Placement: 7"x 8-1/4"SVR w/o set screws 1-per joint TD to 500'above LCU(13,609') CEMENTING REPORT Preflush(Spacer) Type: Dual Spacer Density(ppg) 12.5 Volume pumped(BBLs) 50 Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume(BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: Premium G Cement Yield(Ft3/sack): 1.17 tV Density(ppg) 15.8 Volume(BBLs/sacks): 63/300 Mixing/Pumping Rate(bpm): 4 Post Flush(Spacer) w Type:SeaWater Density(ppg) 8.6 Rate(bpm): 4.5 Volume: 20 a Displacement: Type: Mud Density(ppg) 10.2 Rate(bpm): 6 bpm Volume(actual/calculated): 529/532 FCP(psi): 1568 Pump used for disp: Rig pumps Plug Bumped? X Yes No Bump press 3335, Casing Rotated? _Yes X No Reciprocated? _Yes X No %Returns during job 100 +/ Cement returns to surface? Yes X No Spacer returns? _Yes X No Vol to Surf: 0 Cement In Place At: 0:00 Date: 3/3/2014 Estimated TOC: 12,779 Method Used To Determine TOC: Incermental Hydrostatic Loss Method 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 w Type: Yield(Ft3/sack): F Density(ppg) Volume(BBLs/sacks): Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: w 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: ATTACHMENT F I 410 Casing & Cement Well Name: ODSN-23i Cc cAELus For String: 7"Intermediate 2 Tie-back Eno rsy Alaska Casing Detail: Casing Description Run Date Set Depth(ftK13) Wellbore Centralizers Scratchers Proposed Run? 7"Intermediate 2 Tie-back 7/2/2011 23:15 11,493.6 Sidetrack 2 1st 10 joints. No Casing Components Joints Item Description Icon OD Nominal(in) ID(in) Wt(Ib/ft) Grade Top Thread Length(ft) Top Depth(ftKB) Bottom Depth(ftKB) 1 7"casing cut off jt. 7 6.276 26.00 L-80 BTC-M 37.28 43.1 80.4 Joints Item Description 'Icon OD Nominal(in) ID(in) Wt(lb/ft) Grade Top Thread Length(ft) Top Depth(ftKB) Bottom Depth(ftKB) 4 Casing Pup Joint 7 6.276 26.00 L-80 BTC-M 36.46 80.4 116.9 Joints Item Description Icon OD Nominal(in) ID(in) Wt(lb/ft) Grade Top Thread Length(ft) Top Depth(ftKB) Bottom Depth(ftKB) 277 Casing 7 6.276 26.00 L-80 BTC-M 11,292.51 116.9 11,409.4 Joints Item Description Icon OD Nominal(in) ID(in) Wt(lb/ft) Grade Top Thread Length(ft) Top Depth(ftKB) Bottom Depth(ftKB) 1 HES Float collar w/orifice 7 6.276 26.00 L-80 BTC-M 1.02 11,409.4 11,410.4 Joints Item Description Icon OD Nominal(in) ID(in) Wt(lb/ft) Grade Top Thread Length(ft) Top Depth(ftKB) Bottom Depth(ftKB) 2 Casing 7 6.276 26.00 L-80 BTC-M 82.27 11,410.4 11,492.7 Joints Item Description Icon OD Nominal(in) ID(in) Wt(lb/ft) Grade Top Thread Length(ft) Top Depth(ftKB) Bottom Depth(ftKB) 1 BR Locator(No-Go) 7 6.276 26.00 L-80 0.92 11,492.7 11,493.6 Leak Off and Formation Integrity Tests Test Date Depth(ftKB) P Surf Applied(psi) Dens Fluid(L.. Leak off? Vol Pumped(.. Last Casing String Run P LeakOff(psi) Dens Fluid(I... Comment Cementing Job Details: Description Type String Wellbore 7"Tie-back Casing 7"Intermediate 2 Tie-back, Sidetrack 1 11,493.6ftKB Cementing Start Date Cementing End Date Cementing Company 7/2/2011 21:00 7/2/2011 23:15 Halliburton Energy Services Comment Bumped plug with 413.3 bbls away(same as calculated. Cement Stage#1 Description: Stage Number Top Depth(ftKB) Bottom Depth(ftKB) Cement Volume Return(bbl) 1 10,413.0 11,488.0 Float Failed? Plug Failed? Full Return? Pipe Reciprocated? Pressure Held(psi) No No Yes No 3,500.0 Top Plug? Bottom Plug? Initial Pump Rate(bbl/min) Final Pump Rate(bbl/min) Yes Yes Avg Pump Rate(bbl/min) Final Pump Pressure(psi) Plug Bump Pressure(psi) Pressure Release Date 950.0 3,500.0 10.0 ppg Hi Visc.MOBM Fluid Details for Stage#1 : Fluid Type Fluid Description Amount(sacks) Class Volume Pumped(bbl) 10.0 ppg Hi Visc.MOBM 40.0 Estimated Top M(S) Estimated Bottom Depth(ftKB) Yield)ft/sack) Mix H20 Ratio(gal/sack) Free Water(%) 0.0 0.0 Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hr) 1st Compressive Strength(psi) 10.00 Comment Additive Details Add Conc Conc Units 10.0 ppg MOBM Fluid Details for Stage#1 : Fluid Type Fluid Description Amount(sacks) Class Volume Pumped(bbl) 10.0 ppg MOBM 550.0 Estimated Top(ftKB) Estimated Bottom Depth(ftKB) Yield(ft/sack) Mix H20 Ratio(gal/sack) Free Water(%) 0.0 10,413.0 Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hr) 1st Compressive Strength(0) 10.00 Comment Additive Details Add Conc Conc Units Page 1/2 Report Printed: 11/13/2015 ATTACHMENT F • Casing & Cement Well Name: ODSN-23i Co CAELUS ,; .P- .,p l g�� For String: 7"Intermediate 2 Tie-back Cement Fluid Details for Stage#1 : Fluid Type Fluid Description Amount(sacks) Class Volume Pumped(bbl) Cement 176 Class G 34.0 Estimated Top(EKB) Estimated Bottom Depth(ftKB) Yield(ft'/sack) Mix H2O Rato(gal/sack) Free Water(%) 10,413.0 11,488.0 Density(lb/gal) Plastic Viscosity(cp) Thickening Time(hr) 1st Compressive Strength(pd) 15.80 Comment Additive Details Add Conc Conc Units Page 2/2 Report Printed: 11/13/2015 ATTACHMENT F • • Sc blum ber FracCADE STIMULATION PROPOSAL Operator : Caelus Energy Alaska Well : ODSN-22 Field : Oooguruk Formation : Nuiqsut ,4 Well Location : Oooguruk County : North Slope State : Alaska Country : United States Prepared for : Mike Martin Service Point : Prudhoe Bay,AK eD Business Phone : 1 907 659 2434 Date Prepared : 10-05-2015 FAX No. : 1 907 659 2538 Prepared by : Scott Leahy Phone : 907-330-4595 E-Mail Address : SLeahy©slb.com *Mark of Schlumberger Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no mare accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Attachment G • 0 Client : Caelus energy Alaska Well : ODSN-22 SChhffilterger Formation : Nuiqsut District : Prudhoe Bay,AK Zone Data(Stage 1) Formation Mechanical Properties Zone Name Top TVD Zone Frac lnsitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) (psi/ft) (psi) (psi) SHALE 6051.0 100.0 0.750 4576 5.000E+5 0.33 1000 Nuiqsut Zone 1 6151.0 58.0 0.650 4017 1.600E+6 0.25 1200 Nuiqsut Zone 2 6209.0 6.0 0.700 4348 2.000E+6 0.29 1000 Nuiqsut Zone 3 6215.0 13.0 0.670 4168 2.000E+6 0.33 700 Nuiqsut Zone 4 6228.0 10.0 0.700 4363 2.000E+6 0.29 1000 Nuiqsut Zone 5 6238.0 41.0 0.650 4068 1.600E+6 0.22 1200 SHALE 6279.0 100.0 0.800 5063 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. (ft( Height (md) )%) Pressure (ft) (psi) SHALE 6051.0 1.0 0.001 1.0 2855 Nuiqsut Zone 1 6151.0 58.0 2.000 16.0 2892 Nuiqsut Zone 2 6209.0 6.0 0.100 10.0 2907 34 Nuiqsut Zone 3 6215.0 13.0 0.500 12.0 2912 13 Nuiqsut Zone 4 6228.0 10.0 0.200 10.0 2917 <` Nuiqsut Zone 5 6238.0 41.0 2.000 15.0 2960 CD SHALE 6279.0 1.0 0.001 1.0 2962 Propped Fracture Schedule (Stage 1) Pumping Schedule Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) Stage 1 PAD 36.0 YF125ST 90 25.0 0.00 1.0 PPA 36.0 YF125ST 19 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 2.0 PPA 36.0 YF125ST 28 25.0 CarboLite w/5% 2.00 ScaleGuard 16/20 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 Schlumbelier Formation : Nuigsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) 3.0 PPA 35.0 YF125ST 35 25.0 CarboLite w/5% 3.00 ScaleGuard 16/20 4.0 PPA 35.0 YF125ST 34 25.0 CarboLite w/5% 4.00 ScaleGuard 16/20 5.0 PPA 35.0 YF125ST 33 25.0 CarboLite w/5% 5.00 ScaleGuard 16/20 6.0 PPA 32.0 YF125ST 32 25.0 CarboLite w/5% 6.00 ScaleGuard 16/20 7.0 PPA 32.0 YF125ST 23 25.0 CarboLite w/5% 7.00 ScaleGuard 16/20 8.0 PPA 32.0 YF125ST 18 25.0 CarboLite w/5% 8.00 ScaleGuard 16/20 Flush 40.0 YF125ST 333 25.0 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. Cr, Fluid Totals 644 bbl of YF125ST c, Proppant Totals 41100 lb of CarboLite w/5%ScaleGuard 16/20 a CD Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (Ib) (Ib) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) Stage 1 90 90 90.0 90.0 0 0 7112 2.5 2.5 PAD 1.0 PPA 19 109 20.0 110.0 804 804 7112 0.6 3.1 2.0 PPA 28 137 30.0 140.0 2315 3120 7170 0.8 3.9 3.0 PPA 35 172 40.0 180.0 4450 7569 7240 1.1 5.0 4.0 PPA 34 206 40.0 220.0 5710 13280 7257 1.1 6.2 5.0 PPA 33 239 40.0 260.0 6879 20159 7270 1.1 7.3 6.0 PPA 32 270 40.0 300.0 7966 28125 7287 1.3 8.6 7.0 PPA 23 293 30.0 330.0 6735 34860 7303 0.9 9.5 8.0 PPA 18 312 25.0 355.0 6205 41066 7322 0.8 10.3 Flush 333 644 332.7 687.7 0 41066 6826 8.3 18.6 Attachment G • . Client Caelus energy Alaska h1l1 1 1 Well : ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 1) - The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Fracture Plane 1 MD 22150.0 ft Initial Fracture Top TVD 6151.0 ft Initial Fracture Bottom TVD 6209.0 ft Propped Fracture Half-Length 157.9 ft EOJ Hyd Height at Well 136.5 ft Average Propped Width 0.112 in Average Gel Concentration 329.6 Ib/mgal Average Gel Fluid Retained Factor. 0.38 Net Pressure 284 psi Efficiency 0.496 Effective Conductivity 3200 md.ft Effective Fcd 10.1 Max Surface Pressure 7472 psi Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped ' Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (lb/mgal) (md.ft) (PPA) (1b/f12) 0.0 39.5 8.0 0.143 127.3 1.27 252.8 3466 39.5 78.9 7.0 0.134 125.4 1.21 265.8 3051 78.9 118.4 5.6 0.108 106.2 1.00 302.5 2182 118.4 157.9 10.2 0.071 86.5 070 497.5 1209 Attachment G 0 0 Client : Caelus energy Alaska � ��� Well : ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Zone Data (Stage 2) Formation Mechanical Properties Zone Name Top ND Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) (psi/ft) (psi) (psi) SHALE ' 6041.0 100.0 0.750 4568 5.000E+5 0.33 1000 Nuiqsut Zone 1 6141.0 58.0 0.650 4010 1.600E+6 0.25 1200 Nuiqsut Zone 2 6199.0 6.0 0.700 4341 2.000E+6 0.29 1000 Nuiqsut Zone 3 6205.0 13.0 0.670 4162 2.000E+6 0.33 700 Nuiqsut Zone 4 6218.0 10.0 0.700 4356 2.000E+6 0.29 1000 Nuiqsut Zone 5 6228.0 41.0 0.650 4062 1.600E+6 0.22 1200 SHALE 6269.0 100.0 0.800 5055 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top ND Net Perm Porosity Res. )ft) Height (md) )%) Pressure CP (ft) (psi) SHALE 6041.0 1.0 0.001 1.0 2851 .11 Nuiqsut Zone 1 6141.0 58.0 2.000 16.0 2888 Nuiqsut Zone 2 6199.0 6.0 0.100 10.0 2903 Nuiqsut Zone 3 6205.0 13.0 0.500 12.0 2907 g Nuiqsut Zone 4 6218.0 10.0 0.200 10.0 2912 , Nuiqsut Zone 5 6228.0 41.0 2.000 15.0 2960 SHALE 6269.0 1.0 0.001 1.0 2957 Propped Fracture Schedule (Stage 2) Pumping Schedule Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) Stage 2 PAD 40.0 YF125ST 289 25.0 0.00 Slow for 12.0 YF125ST 60 25.0 0.00 Seat Resume 40.0 YF125ST 50 25.0 0.00 PAD 1.0 PPA 40.0 YF125ST 77 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 Salliffilb eller Formation : Nuiqsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) 2.0 PPA 36.0 YF125ST 101 25.0 CarboLite w/5% 2.00 ScaleGuard 16/20 3.0 PPA 36.0 YF125ST 119 25.0 CarboLite w/5% 3.00 _ ScaleGuard 16/20 4.0 PPA 33.0 YF125ST 115 25.0 CarboLite w/5% 4.00 ScaleGuard 16/20 5.0 PPA 33.0 YF125ST 111 25.0 CarboLite w/5% 5.00 ScaleGuard 16/20 6.0 PPA 32.0 YF125ST 107 25.0 CarboLite w/5% 6.00 ScaleGuard 16/20 7.0 PPA 32.0 YF125ST 84 25.0 CarboLite w/5% 7.00 ScaleGuard 16/20 8.0 PPA 32.0 YF125ST 66 25.0 CarboLite w/5% 8.00 ScaleGuard 16/20 Flush 40.0 YF125ST 329 25.0 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. CP E Fluid Totals 1508 bbl of YF125ST Proppant Totals n 143100 lb of CarboLite w/5%ScaleGuard 16/20 74 Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (lb) (lb) Pressure (min) (min) (bbl) (bbl) (bbl( (psi) Stage 2 289 289 289.0 289.0 0 0 6910 7.2 7.2 PAD Slow for 60 349 60.0 349.0 0 0 6908 5.0 12.2 Seat Resume 50 399 50.0 399.0 0 0 6881 1.3 13.5 PAD 1.0 PPA _ 77 476 80.0 479.0 3218 3218 6963 2.0 15.5 2.0 PPA 101 577 110.0 589.0 8489 11707 5413 3.1 18.5 3.0 PPA 119 696 135.0 724.0 15018 26725 3889 3.8 22.3 4.0 PPA 115 811 135.0 859.0 19272 45996 7438 4.1 26.4 5.0 PPA 111 921 135.0 994.0 23217 69214 7471 4.1 30.5 6.0 PPA 107 1028 135.0 1129.0 26887 96100 7357 4.2 34.7 7.0 PPA 84 1112 110.0 1239.0 24696 120797 7460 3.4 38.1 8.0 PPA I 66 1178 90.0 1329.0 22338 143135 7523 2.8 40.9 Flush 329 1508 329.4 1658.4 0 143135 6627 8.2 49.2 Attachment G • • Client : energy Alaska Schlumberger Well ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 2) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 2 MD 21932.0 ft Initial Fracture Top TVD 6141.0 ft Initial Fracture Bottom TVD 6199.0 ft Propped Fracture Half-Length 299.5 ft - E0J Hyd Height at Well 143.2 ft Average Propped Width 0.199 in Average Gel Concentration 328.5 lb/mgal Average Gel Fluid Retained Factor 0.42 Net Pressure 361 psi gip` Efficiency 0.415 Effective Conductivity 6236 md.ft Effective Fcd 10.4 Max Surface Pressure 7949 psi g g Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (lb/mgal) (md.ft) _ (PPA) (Ib/ft2) 0.0 74.9 8.1 0.227 97.8 2.00 314.9 5543 74.9 149.7 7.3 0.220 130.7 1.95 323.3 5301 149.7 224.6 6.8 0.204 123.4 1.82 316.7 4967 224.6 299.5 3.3 0.157 101.6 1.39 359.1 3917 Attachment G • • Client Caelus energy Alaska I a�1 � Well : ODSN-22 Formation : Nuigsut District : Prudhoe Bay,AK Zone Data(Stage 3) Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness )ft) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) Ipsi/ft) (psi) (psi) SHALE 6030.0 100.0 0.750 4560 5.000E+5 0.33 1000 Nuiqsut Zone 1 6130.0 58.0 0.650 4003 1.600E+6 0.25 1200 Nuiqsut Zone 2 6188.0 6.0 0.700 4334 2.000E+6 0.29 1000 Nuiqsut Zone 3 6194.0 10.0 0.670 4153 2.000E+6 _ 0.33 700 Nuiqsut Zone 4 6204.0 13.0 0.700 4347 2.000E+6 0.29 1000 Nuiqsut Zone 5 6217.0 41.0 0.650 4054 1.600E+6 0.22 1200 SHALE 6258.0 100.0 0.800 5046 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. )ft) Height Imd) (%) Pressure cn (ft) (psi) SHALE 6030.0 1.0 0.001 1.0 2845 `t Nuiqsut Zone 1 6130.0 58.0 2.000 16.0 2882 Nuiqsut Zone 2 6188.0 6.0 0.100 10.0 2897 Nuiqsut Zone 3 6194.0 10.0 0.500 12.0 2901 Nuiqsut Zone 4 6204.0 13.0 0.200 10.0 2907 • Nuiqsut Zone 5 6217.0 41.0 2.000 15.0 2960 SHALE 6258.0 1.0 0.001 1.0 2952 Propped Fracture Schedule (Stage 3) Pumping Schedule Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) Stage 3 PAD 40.0 YF125ST 285 25.0 0.00 Slow for 12.0 YF125ST 60 25.0 0.00 Seat Resume 40.0 YF125ST 125 25.0 0.00 PAD _ 1.0 PPA 40.0 YF125ST 115 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 Attachment G s s Clie : Caelus ODSN-22 gy Alaska Schlumberger Well ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) 2.0 PPA 38.0 YF125ST 147 25.0 CarboLite w/5% 2.00 ScaleGuard 16/20 3.0 PPA 38.0 YF125ST 177 25.0 CarboLite w/5% 3.00 ScaleGuard 16/20 4.0 PPA 35.0 YF125ST 170 25.0 CarboLite w/5% 4.00 ScaleGuard 16/20 5.0 PPA 35.0 YF125ST 164 25.0 CarboLite w/5% 5.00 ScaleGuard 16/20 6.0 PPA 33.0 YF125ST 158 25.0 CarboLite w/5% 6.00 ScaleGuard 16/20 7.0 PPA 33.0 YF125ST 122 25.0 CarboLite w/5% 7.00 ScaleGuard 16/20 8.0 PPA 31.0 YF125ST 96 25.0 CarboLite w/5% 8.00 ScaleGuard 16/20 Flush 40.0 YF125ST 326 25.0 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. -3 2 Fluid Totals 1944 bbl of YF125ST mm Proppant Totals 24 210400 lb of CarboLite w/5%ScaleGuard 16/20 r Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (lb) (lb) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) Stage 3 285 285 285.0 285.0 0 0 6791 7.1 7.1 PAD Slow for 60 345 60.0 345.0 0 0 6784 5.0 12.1 Seat Resume 125 470 125.0 470.0 0 0 6749 3.1 15.3 PAD 1.0 PPA 115 585 120.0 590.0 4827 4827 6747 3.0 18.3 2.0 PPA 147 732 160.0 750.0 12348 17175 5287 4.2 22.5 3.0 PPA 177 908 200.0 950.0 22249 39423 7178 5.3 27.7 4.0 PPA 170 1078 200.0 1150.0 28550 67974 7457 5.7 33.4 5.0 PPA 164 1242 200.0 1350.0 34396 102369 7702 5.7 39.2 6.0 PPA 158 1400 200.0 1550.0 39832 142202 7645 6.1 45.2 7.0 PPA 122 1522 160.0 1710.0 35922 178124 7809 4.8 50.1 8.0 PPA 96 1619 130.0 1840.0 32266 210390 7642 4.2 54.3 Flush 326 1944 325.7 2165.7 0 210390 6777 8.1 62.4 Attachment G • 0 Client : energyAlaska Schlumberger Well ODSN-22ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 3) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 3 MD 21362.0 ft Initial Fracture Top TVD 6130.0 ft Initial Fracture Bottom TVD 6188.0 ft Propped Fracture Half-Length 350.7 ft EOJ Hyd Height at Well 145.9 ft Average Propped Width 0.247 in Average Gel Concentration 313.5 lb/mgal Average Gel Fluid Retained Factor, 0.42 Net Pressure 398 psi Efficiency 0.431 Effective Conductivity 8224 md.ft Effective Fcd 11.7 Max Surface Pressure 8091 psi Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (lb/mgal) (md.ft) (PPA) (Ib/ft2) 0.0 87.7 8.1 0.278 99.2 2.46 300.7 7184 87.7 175.4 7.4 0.272 133.1 2.40 301.4 7012 175.4 263.0 7.3 0.262 125.7 2.33 301.5 6784 263.0 350.7 3.7 0.189 98.1 1.70 350.5 4914 Attachment G • • Client : Caelus energy Alaska � , Well : ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Zone Data(Stage 4) Formation Mechanical Properties Zone Name Top ND Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) (psi/ft) (psi) (psi) SHALE 6028.0 100.0 0.750 4558 5.000E+5 0.33 1000 Nuiqsut Zone 1 6128.0 58.0 0.650 4002 1.600E+6 0.25 1200 Nuiqsut Zone 2 6186.0 6.0 0.700 4332 2.000E+6 0.29 1000 Nuiqsut Zone 3 6192.0 13.0 0.670 4153 2.000E+6 0.33 700 Nuiqsut Zone 4 6205.0 10.0 0.700 4347 2.000E+6 0.29 1000 Nuiqsut Zone 5 6215.0 41.0 0.650 4053 1.600E+6 0.22 1200 SHALE 6256.0 100.0 0.800 5045 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top ND Net Perm Porosity Res. Ift) Height (md1 I%) Pressure 0 (ft) (psi) SHALE 6028.0 1.0 0.001 1.0 2844 fria: Nuiqsut Zone 1 6128.0 58.0 2.000 16.0 2881 Nuiqsut Zone 2 6186.0 6.0 0.100 10.0 2896 Nuiqsut Zone 3 6192.0 13.0 0.500 12.0 2901 Nuiqsut Zone 4 6205.0 10.0 0.200 10.0 2906 ',- ' Nuiqsut Zone 5 6215.0 41.0 2.000 15.0 2960 fa SHALE 6256.0 1.0 0.001 1.0 2951 Propped Fracture Schedule (Stage 4) Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (Ib/mgal) (PPA) Stage 4 PAD 40.0 YF125ST 277 25.0 0.00 Slow for 12.0 YF125ST 60 25.0 0.00 Seat Resume 40.0 YF125ST 133 25.0 0.00 PAD 1.0 PPA 40.0 YF125ST 115 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 2.0 PPA 38.0 YF125ST 147 25.0 CarboLite w/5% 2.00 ScaleGuard 16/20 Attachment G 0 , Client : Caelus energy Alaska Well : ODSN-22 SChliMlbarger Formation : Nuigsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) 3.0 PPA 38.0 YF125ST 177 25.0 CarboLite w/5% 3.00 ScaleGuard 16/20 4.0 PPA 35.0 YF125ST 170 25.0 CarboLite w/5% 4.00 ScaleGuard 16/20 5.0 PPA 35.0 YF125ST 164 25.0 CarboLite w/5% 5.00 ScaleGuard 16/20 6.0 PPA 33.0 YF125ST 158 25.0 CarboLite w/5% 6.00 ScaleGuard 16/20 7.0 PPA 33.0 YF125ST 122 25.0 CarboLite w/5% 7.00 ScaleGuard 16/20 8.0 PPA 31.0 YF125ST 96 25.0 CarboLite w/5% 8.00 ScaleGuard 16/20 Flush 40.0 WF125 312 30.2 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. CP 0 Fluid Totals m 1619 bbl of YF125ST 312 bbl of WF125 r„ Proppant Totals 210400 lb of CarboLite w/5%ScaleGuard 16/20 tv FS Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (Ib) (Ib) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) Stage 4 277 277 277.0 277.0 0 0 6656 6.9 6.9 PAD Slow for 60 337 60.0 337.0 0 0 6643 5.0 11.9 Seat Resume 133 470 133.0 470.0 0 0 6609 3.3 15.3 PAD 1.0 PPA 115 585 120.0 590.0 4827 4827 4420 3.0 18.3 2.0 PPA 147 732 160.0 750.0 12348 17175 5245 4.2 22.5 3.0 PPA 177 908 200.0 950.0 22249 39423 7059 5.3 27.7 4.0 PPA 170 1078 200.0 1150.0 28550 67974 7281 5.7 33.4 5.0 PPA 164 1242 200.0 1350.0 34396 102369 7476 5.7 39.2 6.0 PPA 158 1400 200.0 1550.0 39832 142202 7501 6.1 45.2 7.0 PPA 122 1522 160.0 1710.0 35922 178124 7615 4.8 50.1 8.0 PPA 96 1619 130.0 1840.0 32266 210390 7452 4.2 54.3 Flush 312 1931 312.2 2152.2 0 210390 5613 7.8 62.1 Attachment G 0 i Client : energyAlaska Sc l fiber er Well DDSN-22ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 4) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 4 MD 20804.0 ft Initial Fracture Top TVD 6128.0 ft Initial Fracture Bottom TVD 6186.0 ft Propped Fracture Half-Length 347.6 ft EOJ Hyd Height at Well 145.6 ft Average Propped Width 0.250 in Average Gel Concentration 311.2 lb/mgal Average Gel Fluid Retained Factor 0.42 Net Pressure 396 psi Efficiency 0.431 ' Effective Conductivity 8486 md.ft Effective Fcd 12.2 74, Max Surface Pressure 7889 psi Z Simulation Results by Fracture Segment cp- From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (lb/mgal) (md.ft) (PPA) _ (Ib/ft2) 0.0 86.9 8.1 0.280 135.2 2.47 297.4 7222 86.9 173.8 _ 7.4 0.275 _ 134.3 2.43 300.9 7138 173.8 _ 260.7 7.3 0.266 _ 127.8 2.37 302.5 6940 260.7 347.6 3.7 0.191 121.2 1.71 344.0 4961 Attachment G 0 0 Client : Caelus energy Alaska Well : ODSN-22 SChIUMberger Formation : Nuigsut District : Prudhoe Bay,AK Zone Data(Stage 5) Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.ino.5) (ft) (psi/ft) (psi) (psi) _ SHALE 6029.0 100.0 0.750 4559 5.000E+5 0.33 1000 Nuiqsut Zone 1 6129.0 53.0 0.650 4001 1.600E+6 0.25 1200 Nuiqsut Zone 2 6182.0 6.0 0.700 4329 2.000E+6 0.29 1000 Nuiqsut Zone 3 6188.0 12.0 0.670 4150 2.000E+6 0.33 700 Nuiqsut Zone 4 6200.0 8.0 0.700 4343 2.000E+6 0.29 1000 Nuiqsut Zone 5 6208.0 41.0 0.650 4049 1.600E+6 0.22 1200 SHALE 6249.0 100.0 0.800 5039 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. If-t) Height Imd) (%) Pressure (ft) (psi) SHALE 6029.0 1.0 0.001 1.0 2845lc Nuiqsut Zone 1 6129.0 53.0 2.000 16.0 2881 Nuiqsut Zone 2 6182.0 6.0 0.100 10.0 2895 cc tc Nuiqsut Zone 3 6188.0 12.0 0.500 12.0 2899 Nuiqsut Zone 4 6200.0 8.0 0.200 10.0 2903 ` Nuiqsut Zone 5 6208.0 _ 41.0 2.000 15.0 2960c. SHALE 6249.0 1.0 0.001 1.0 2948 Propped Fracture Schedule (Stage 5) Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) Stage 5 PAD 40.0 YF125ST 360 25.0 0.00 1.0 PPA 40.0 YF125ST 144 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 3.0 PPA 37.0 YF125ST 132 25.0 CarboLite w/5% 3.00 ScaleGuard 16/20 5.0 PPA 35.0 YF125ST 172 25.0 CarboLite w/5% 5.00 ScaleGuard 16/20 7.0 PPA 34.0 YF125ST 145 25.0 CarboLite w/5% 7.00 ScaleGuard 16/20 9.0 PPA 32.0 YF125ST 136 25.0 CarboLite w/5% 9.00 ScaleGuard 16/20 Attachment G • • Client : energy Alaska WSchh aal gel Well ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. )bbl/min) (bbl) (lb/mgal) (PPA) 10.0 PPA 30.0 YF125ST 118 25.0 Carbolite w/5% 10.00 ScaleGuard 16/20 Flush 40.0 YF125ST 302 25.0 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. Fluid Totals 1509 bbl of YF125ST Proppant Totals 202400 lb of CarboLite w/5%ScaleGuard 16/20 Job Execution tis tn Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (Ib) (Ib) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) m Stage 5 360 360 360.0 360.0 0 0 6502 9.0 9.0 PAD 1.0 PPA 144 504 _ 150.0 510.0 6033 6033 6467 3.8 12.8 w_ 3.0 PPA 132 636 150.0 660.0 16687 22720 6610 4.1 16.8 5.0 PPA 172 808 210.0 870.0 36115 58835 7373 6.0 22.8 7.0 PPA 145 953 190.0 1060.0 42657 101492 7578 5.6 28.4 9.0 PPA 136 1089 190.0 1250.0 51375 152868 7771 5.9 34.3 10.0 PPA 118 1207 170.0 1420.0 49509 202376 7551 5.7 40.0 Flush 302 1509 301.7 1721.7 0 202376 6162 7.5 47.5 Attachment G • 0 Client : Caelus energy Alaska c h19111 r r Well : ODSN-22 Formation : Nuigsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 5) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 5 MD 20116.0 ft Initial Fracture Top TVD 6129.0 ft Initial Fracture Bottom TVD 6182.0 ft Propped Fracture Half-Length 315.3 ft E0J Hyd Height at Well 137.4 ft Average Propped Width 0.285 in Average Gel Concentration 256.2 lb/mgal Average Gel Fluid Retained Factor. 0.45 Net Pressure 398 psi cel Efficiency 0.433 , Effective Conductivity 10252 md.ft Effective Fcd 16.3 Max Surface Pressure 7939 psi Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (lb/mgal) (md.ft) (PPA) (Ib/ft2) 0.0 78.8 10.6 0.316 93.8 2.80 235.3 9362 78.8 157.7 10.5 0.314 120.7 2.77 239.1 9366 157.7 236.5 10.1 0.303 117.8 2.68 238.3 9118 236.5 315.3 4.5 0.219 94.5 1.97 312.0 6354 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 Schluffiterger Formation : Nuiqsut District : Prudhoe Bay,AK Zone Data(Stage 6) Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) (psi/ft) (psi) (psi) SHALE 6023.0 100.0 0.750 4555 5.000E+5 0.33 1000 Nuiqsut Zone 1 6123.0 50.0 0.650 3996 1.600E+6 0.25 1200 Nuiqsut Zone 2 6173.0 6.0 0.700 4323 2.000E+6 0.29 1000 Nuiqsut Zone 3 6179.0 12.0 0.670 4144 2.000E+6 0.33 700 Nuiqsut Zone 4 6191.0 _ 8.0 0.700 4336 2.000E+6 0.29 1000 Nuiqsut Zone 5 6199.0 41.0 0.650 4043 1.600E+6 0.22 1200 SHALE 6240.0 100.0 0.800 5032 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. ((t( Height Imdl (%( Pressure r) (ft) (psi) a. SHALE 6023.0 1.0 0.001 1.0 2842 Nuiqsut Zone 1 6123.0 50.0 2.000 16.0 2877 Nuiqsut Zone 2 6173.0 6.0 0.100 10.0 2890 Nuiqsut Zone 3 6179.0 12.0 0.500 12.0 2895 Nuiqsut Zone 4 6191.0 8.0 0.200 10.0 2899 Nuiqsut Zone 5 6199.0 41.0 2.000 15.0 2960 SHALE 6240.0 1.0 0.001 1.0 2944 Propped Fracture Schedule (Stage 6) Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) Stage 6 PAD 40.0 YF125ST 260 25.0 0.00 Slow for 12.0 YF125ST 60 25.0 0.00 Seat Resume 40.0 YF125ST 50 25.0 0.00 PAD 1.0 PPA 40.0 YF125ST 124 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 SChingerger Formation : Nuiqsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (Ib/mgal) (PPA) 3.0 PPA 37.0 YF125ST 115 25.0 CarboLite w/5% 3.00 ScaleGuard 16/20 5.0 PPA 35.0 YF125ST 147 25.0 CarboLite w/5% 5.00 ScaleGuard 16/20 7.0 PPA 34.0 YF125ST 122 25.0 CarboLite w/5% 7.00 ScaleGuard 16/20 9.0 PPA 32.0 YF125ST 114 25.0 CarboLite w/5% 9.00 ScaleGuard 16/20 10.0 PPA 31.0 YF125ST 97 25.0 CarboLite w/5% 10.00 ScaleGuard 16/20 Flush 40.0 YF125ST 295 25.0 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. Fluid Totals 1385 bbl of YF125ST Proppant Totals 170600 Ib of CarboLite w/5%ScaleGuard 16/20 o Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (Ib) (Ib) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) Stage 6 260 260 260.0 260.0 0 0 6406 6.5 6.5 PAD Slow for 60 320 60.0 320.0 0 0 6398 5.0 11.5 Seat Resume 50 370 50.0 370.0 0 0 6405 1.3 12.8 PAD 1.0 PPA 124 494 130.0 500.0 5229 5229 6449 3.3 16.0 3.0 PPA 115 609 130.0 630.0 14462 19690 3619 3.5 19.5 5.0 PPA 147 757 180.0 810.0 30956 50647 6721 5.1 24.7 7.0 PPA 122 879 160.0 970.0 35922 86568 7497 4.7 29.4 9.0 PPA 114 993 160.0 1130.0 43263 129832 7648 5.0 34.4 10.0 PPA 97 1090 140.0 1270.0 40772 170604 7498 4.5 38.9 Flush 295 1385 294.8 1564.8 0 170604 6077 7.4 46.2 Attachment G • • Client Caelus energy Alaska �j h ��r r Well : ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 6) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 6 MD 19661.0 ft Initial Fracture Top TVD 6173.0 ft Initial Fracture Bottom TVD 6179.0 ft Propped Fracture Half-Length 251.4 ft . EOJ Hyd Height at Well 147.7 ft Average Propped Width 0.279 in Average Gel Concentration 244.9 lb/mgal Average Gel Fluid Retained Factor 0.51 Net Pressure 63 psi Efficiency 0.503 (-s Effective Conductivity 9721 md.ft Effective Fcd 386.6 Max Surface Pressure 7890 psi = Simulation Results by Fracture Segment s From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (lb/mgal) (md.ft) (PPA) (Ib/ft2) 0.0 62.9 12.5 0.301 90.2 2.62 237.6 8773 62.9 125.7 11.1 0.310 125.1 2.70 237.5 8968 125.7 188.6 7.2 0.287 125.2 2.49 237.3 8268 188.6 251.4 1.6 0.236 105.6 2.12 267.4 6821 Attachment G • . Client : Caelus energy Alaska Well : ODSN-22 Sallilidlrger Formation : Nuiqsut District : Prudhoe Bay,AK Zone Data (Stage 7) Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.ino.5) (ft) (psi/ft) (psi) (psi) SHALE 6023.0 100.0 0.750 4555 5.000E+5 0.33 1000 Nuiqsut Zone 1 6123.0 52.0 0.650 3997 1.600E+6 0.25 1200 Nuiqsut Zone 2 6175.0 6.0 0.700 4325 2.000E+6 0.29 1000 Nuiqsut Zone 3 6181.0 12.0 0.670 4145 2.000E+6 0.33 700 Nuiqsut Zone 4 6193.0 8.0 0.700 4338 2.000E+6 0.29 1000 Nuiqsut Zone 5 6201.0 41.0 0.650 4044 1.600E+6 0.22 1200 SHALE 6242.0 100.0 0.800 5034 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. Ift) Height (md) (%) Pressure co r. (ft) (psi) SHALE 6023.0 1.0 0.001 1.0 2842 Nuiqsut Zone 1 6123.0 52.0 2.000 16.0 2878 Nuiqsut Zone 2 6175.0 6.0 0.100 10.0 2891 m Nuiqsut Zone 3 6181.0 12.0 0.500 12.0 2896 Nuiqsut Zone 4 6193.0 8.0 0.200 10.0 2900 Nuiqsut Zone 5 6201.0 41.0 2.000 15.0 2960 ca SHALE 6242.0 1.0 0.001 1.0 2945 Propped Fracture Schedule (Stage 7) Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) Stage 7 PAD 40.0 YF125ST 250 25.0 0.00 Slow for 12.0 YF125ST 60 25.0 0.00 Seat Resume 40.0 YF125ST 170 25.0 0.00 PAD 1.0 PPA 40.0 YF125ST 192 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 3.0 PPA 38.0 YF125ST 177 25.0 CarboLite w/5% 3.00 ScaleGuard 16/20 Attachment G s I Client : Caelus energy Alaska Well : ODSN-22 SC llinbergell Formation : Nuiqsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (Ib/mgal) (PPA) 5.0 PPA 36.0 YF125ST 233 25.0 CarboLite w/5% 5.00 ScaleGuard 16/20 7.0 PPA 34.0 YF125ST 195 25.0 CarboLite w/5% 7.00 ScaleGuard 16/20 9.0 PPA 34.0 YF125ST 182 25.0 CarboLite w/5% 9.00 ScaleGuard 16/20 10.0 PPA 34.0 YF125ST 156 25.0 CarboLite w/5% 10.00 ScaleGuard 16/20 Flush 40.0 YF125ST 286 25.0 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. Fluid Totals 1900 bbl of YF125ST CP Proppant Totals _ 271000 lb of CarboLite w/5%ScaleGuard 16/20 zi eD Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. <` w Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (Ib) (Ib) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) Stage 7 250 250 250.0 250.0 0 0 6256 6.3 6.3 PAD Slow for 60 310 60.0 310.0 0 0 6237 5.0 11.3 Seat Resume 170 480 170.0 480.0 0 0 6207 4.3 15.5 PAD 1.0 PPA 192 672 200.0 680.0 8044 8044 4875 5.0 20.5 3.0 PPA 177 848 200.0 880.0 22249 30293 6385 5.3 25.8 5.0 PPA 233 1082 285.0 1165.0 49014 79307 7167 7.9 33.7 7.0 PPA 195 1276 255.0 1420.0 57250 136557 7490 7.5 41.2 9.0 PPA 182 1459 255.0 1675.0 68951 205508 7429 7.5 48.7 10.0 PPA 156 1615 225.0 1900.0 65527 271035 7569 6.6 55.3 Flush 286 1900 285.5 2185.5 0 271035 6780 7.1 62.4 Attachment G • • Client : Caelus energy Alaska c I� Yr Ur Well : ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 7) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 7MD 19051.0ft Initial Fracture Top TVD 6123.0 ft Initial Fracture Bottom TVD 6175.0 ft Propped Fracture Half-Length 365.8 ft EOJ Hyd Height at Well 139.0 ft Average Propped Width 0.329 in Average Gel Concentration 251.7 lb/mgal Average Gel Fluid Retained Factor. 0.45 Net Pressure 433 psi cm Efficiency 0.444 Effective Conductivity 11646 md.ft Effective Fcd 15.9 Max Surface Pressure 7752 psi 7 Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (Ib/mgal) (md.ft) (PPA) (Ib/ft2) 0.0 91.4 10.3 0.356 93.1 3.17 242.4 10451 91.4 182.9 10.0 0.357 122.1 3.15 239.1 10701 182.9 274.3 9.8 0.364 119.1 3.25 230.8 11031 274.3 365.8 5.2 0.250 97.5 2.24 294.4 7346 Attachment G • . Client : Caelus energy Alaska Well : ODSN-22 SChhilliberger Formation : Nuiqsut District : Prudhoe Bay,AK Zone Data(Stage 8) Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) (psi/ft) (psi) (psi) SHALE 6014.0 100.0 0.750 4548 5.000E+5 0.33 1000 Nuiqsut Zone 1 6114.0 50.0 0.650 3990 1.600E+6 0.25 1200 Nuiqsut Zone 2 6164.0 6.0 0.700 4317 2.000E+6 0.29 1000 Nuiqsut Zone 3 6170.0 12.0 0.670 4138 2.000E+6 0.33 700 Nuiqsut Zone 4 6182.0 7.0 0.700 4330 2.000E+6 0.29 1000 Nuiqsut Zone 5 6189.0 40.0 0.650 4036 1.600E+6 0.22 1200 SHALE 6229.0 100.0 0.800 5023 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. Ift) Height (md) (%) Pressure 57 (ft) (psi) SHALE 6014.0 1.0 0.001 1.0 2838 Nuiqsut Zone 1 6114.0 50.0 2.000 16.0 2873 Nuiqsut Zone 2 6164.0 6.0 0.100 10.0 2886 $'1.6' Nuiqsut Zone 3 6170.0 12.0 0.500 12.0 2890 27, Nuiqsut Zone 4 6182.0 7.0 0.200 10.0 2895 Nuiqsut Zone 5 6189.0 40.0 2.000 15.0 2960o o SHALE 6229.0 1.0 0.001 1.0 2939 Propped Fracture Schedule (Stage 8) Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) Stage 8 PAD 40.0 YF125ST 240 25.0 0.00 Slow for 12.0 YF125ST 60 25.0 0.00 Seat Resume 40.0 YF125ST 50 25.0 0.00 PAD 1.0 PPA 40.0 YF125ST 134 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 2.0 PPA 40.0 YF125ST 138 25.0 CarboLite w/5% 2.00 ScaleGuard 16/20 4.0 PPA 37.0 YF125ST 149 25.0 CarboLite w/5% 4.00 ScaleGuard 16/20 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 SChIUM belle!' Formation : Nuiqsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) IPPA) 6.0 PPA 35.0 YF125ST 138 25.0 CarboLite w/5% 6.00 ScaleGuard 16/20 8.0 PPA 35.0 YF125ST 129 25.0 CarboLite w/5% 8.00 ScaleGuard 16/20 10.0 PPA 35.0 YF125ST 121 25.0 CarboLite w/5% 10.00 ScaleGuard 16/20 12.0 PPA 35.0 YF125ST 101 25.0 CarboLite w/5% 12.00 ScaleGuard 16/20 Flush 40.0 YF125ST 276 25.0 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. Fluid Totals 1536 bbl of YF125ST CP o Proppant Totals 222500 Ib of CarboLite w/5%ScaleGuard 16/20 5- C, r Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (Ib) (Ib) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) Stage 8 240 240 240.0 240.0 0 0 6103 6.0 6.0 PAD Slow for 60 300 60.0 300.0 0 0 6062 5.0 11.0 Seat Resume 50 350 50.0 350.0 0 0 6046 1.3 12.3 PAD 1.0 PPA 134 484 140.0 490.0 5631 5631 5060 3.5 15.8 2.0 PPA 138 622 150.0 640.0 11576 17207 3451 3.8 19.5 4.0 PPA 149 771 175.0 815.0 24982 42189 6581 4.7 24.2 6.0 PPA 138 909 175.0 990.0 34853 77042 7293 5.0 29.2 8.0 PPA 129 1038 175.0 1165.0 43435 120478 7395 5.0 34.2 10.0 PPA 121 1160 175.0 1340.0 50965 171443 7487 5.0 39.2 12.0 PPA 101 1261 155.0 1495.0 51039 222482 7721 4.4 43.7 Flush 276 1536 275.7 1770.7 0 222482 6815 6.9 50.6 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 SChNffiberger Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 8) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 8 MD 18405.0 ft Initial Fracture Top TVD 6114.0 ft Initial Fracture Bottom TVD 6164.0 ft Propped Fracture Half-Length 323.4 ft EOJ Hyd Height at Well 133.0 ft Average Propped Width 0.311 in Average Gel Concentration 257.4 lb/mgal Average Gel Fluid Retained Factor, 0.46 Net Pressure 440 psi Efficiency 0.467 Effective Conductivity 11356 md.ft Effective Fcd 17.6 Max Surface Pressure 7816 psi Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (Ib/mgal) (md.ft) (PPA) (1b/ft2) 0.0 80.9 11.7 0.380 90.2 3.38 211.7 12311 80.9 161.7 10.3 0.357 116.8 3.15 228.0 11103 161.7 242.6 8.9 0.327 114.0 2.88 230.1 10161 242.6 323.4 3.9 0.203 91.6 1.83 359.8 5381 Attachment G • • Clie : Caelus ODSN-22 gy Alaska Schlumlie ge Well ODSN-22 u�+ Formation : Nuiqsut District : Prudhoe Bay,AK Zone Data (Stage 9) Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.ino.5) (ft) (psi/ft) (psi) (psi) SHALE 6008.0 100.0 0.750 4543 5.000E+5 0.33 1000 Nuiqsut Zone 1 6108.0 49.0 0.650 3986 1.600E+6 0.25 1200 Nuiqsut Zone 2 6157.0 6.0 0.700 4312 2.000E+6 0.29 1000 Nuiqsut Zone 3 6163.0 12.0 0.670 4133 2.000E+6 0.33 700 Nuiqsut Zone 4 6175.0 5.0 0.700 4324 2.000E+6 0.29 1000 Nuiqsut Zone 5 6180.0 40.0 0.650 4030 1.600E+6 0.22 1200 SHALE 6220.0 100.0 0.800 5016 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. (ft( Height (md) (%( Pressure (ft( (psi) --,Y' SHALE 6008.0 1.0 0.001 1.0 2835 Nuiqsut Zone 1 6108.0 49.0 2.000 16.0 2870 Nuiqsut Zone 2 6157.0 6.0 0.100 10.0 2883 Nuiqsut Zone 3 6163.0 12.0 0.500 12.0 2887 Nuiqsut Zone 4 6175.0 5.0 0.200 10.0 2891 Nuiqsut Zone 5 6180.0 40.0 2.000 15.0 2960 7.4 SHALE 6220.0 1.0 0.001 1.0 2934 eo Propped Fracture Schedule (Stage 9) Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) Stage 9 PAD 40.0 YF125ST 400 25.0 0.00 1.0 PPA 40.0 YF125ST 163 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 3.0 PPA 40.0 YF125ST 150 25.0 CarboLite w/5% 3.00 ScaleGuard 16/20 5.0 PPA 38.0 YF125ST 192 25.0 CarboLite w/5% 5.00 ScaleGuard 16/20 7.0 PPA 37.0 YF125ST 160 25.0 CarboLite w/5% 7.00 ScaleGuard 16/20 9.0 PPA 35.0 YF125ST 150 25.0 CarboLite w/5% 9.00 ScaleGuard 16/20 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 SC lkirdarger Formation : Nuiqsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (Ib/mgal) (PPA) 10.0 PPA 34.0 YF125ST 132 25.0 CarboLite w/5% 10.00 ScaleGuard 16/20 Flush 40.0 YF125ST 267 25.0 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. Fluid Totals 1615 bbl of YF125ST Proppant Totals 225400 lb of CarboLite w/5%ScaleGuard 16/20 il":"': Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (Ib) (lb) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) Stage 9 400 400 400.0 400.0 0 0 5935 10.0 10.0 ' PAD 1.0 PPA 163 563 170.0 570.0 6838 6838 5914 4.3 14.3 3.0 PPA 150 713 170.0 740.0 18911 25749 6043 4.3 18.5 5.0 PPA 192 905 235.0 975.0 40415 66164 6973 6.2 24.7 7.0 PPA 160 1066 210.0 1185.0 47147 113311 7625 5.7 30.4 9.0 PPA 150 1216 210.0 1395.0 56783 170094 7880 6.0 36.4 10.0 PPA 132 1348 190.0 1585.0 55333 225428 7637 5.6 41.9 Flush 267 1615 267.1 1852.1 0 225428 6491 6.7 48.6 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 Schlumberger Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 9) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 9 MD 17845.0 ft Initial Fracture Top TVD 6108.0 ft Initial Fracture Bottom TVD 6157.0 ft Propped Fracture Half-Length 355.1 ft • EOJ Hyd Height at Well 132.6 ft Average Propped Width 0.294 in Average Gel Concentration 263.7 lb/mgal Average Gel Fluid Retained Factor, 0.45 Net Pressure 421 psi Efficiency 0.450 `•,' Effective Conductivity 10181 md.ft 17 Effective Fcd 14.3 Max Surface Pressure 8014 psi v Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (lb/mgal) (md.ft) (PPA) (Ib/ft2) 0.0 88.8 10.3 0.325 89.3 2.90 236.3 9576 88.8 177.6 9.9 0.330 116.5 2.90 237.5 9870 177.6 266.3 9.5 0.325 113.6 2.89 232.9 9766 266.3 355.1 4.5 0.205 91.7 1.83 348.0 5767 Attachment G i ! Client : Caelus energy Alaska Well : ODSN-22 SChliffilterger Formation : Nuiqsut District : Prudhoe Bay,AK Zone Data (Stage 10) Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) (psi/ft) (psi) (psi) SHALE 5998.0 100.0 _ 0.750 4536 5.000E+5 0.33 1000 Nuiqsut Zone 1 6098.0 46.0 0.650 3979 1.600E+6 _ 0.25 1200 Nuiqsut Zone 2 6144.0 6.0 0.700 4303 2.000E+6 0.29 1000 Nuiqsut Zone 3 6150.0 17.0 0.670 4126 2.000E+6 0.33 700 Nuiqsut Zone 4 6167.0 1.0 0.700 4317 2.000E+6 0.29 1000 Nuiqsut Zone 5 6168.0 37.0 0.650 4021 1.600E+6 0.22 1200 SHALE 6205.0 100.0 0.800 5004 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. Ift) Height (md) I%) Pressure (ft) (psi) SHALE 5998.0 1.0 0.001 1.0 2830 Nuiqsut Zone 1 6098.0 46.0 2.000 16.0 2865 Nuiqsut Zone 2 6144.0 6.0 0.100 10.0 2877 - Nuiqsut Zone 3 6150.0 17.0 0.500 12.0 2882 Nuiqsut Zone 4 6167.0 1.0 0.200 10.0 2886 Nuiqsut Zone 5 6168.0 37.0 2.000 15.0 2960 lu SHALE 6205.0 1.0 0.001 1.0 2927 Propped Fracture Schedule (Stage 10) Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (Ib/mgal) (PPA) Stage 10 40.0 YF125ST 224 25.0 0.00 PAD Slow for 12.0 YF125ST 60 25.0 0.00 Seat Resume 40.0 YF125ST 116 25.0 0.00 PAD 1.0 PPA 40.0 YF125ST 163 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 3.0 PPA 40.0 YF125ST 150 25.0 CarboLite w/5% 3.00 ScaleGuard 16/20 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 Schlumberger Formation : Nuiqsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (Ib/mgal) (PPA) 5.0 PPA 38.0 YF125ST 192 25.0 CarboLite w/5% 5.00 ScaleGuard 16/20 7.0 PPA 37.0 YF125ST 160 25.0 CarboLite w/5% 7.00 ScaleGuard 16/20 9.0 PPA 37.0 YF125ST 150 25.0 CarboLite w/5% 9.00 ScaleGuard 16/20 10.0 PPA 37.0 YF125ST 132 25.0 CarboLite w/5% 10.00 ScaleGuard 16/20 Flush 40.0 YF125ST 263 25.0 0.00 Fluid Totals 1611 bbl of YF125ST Proppant Totals 225400 lb of CarboLite w/5%ScaleGuard 16/20 022 Job Execution rD az Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (lb) (lb) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) Stage 10 224 224 224.0 224.0 0 0 5775 5.6 5.6 PAD Slow for 60 284 60.0 284.0 0 0 5774 5.0 10.6 Seat Resume 116 400 116.0 400.0 0 0 5776 2.9 13.5 PAD 1.0 PPA 163 563 170.0 570.0 6838 6838 3945 4.3 17.8 3.0 PPA 150 713 170.0 740.0 18911 25749 5347 4.3 22.0 5.0 PPA 192 905 235.0 975.0 40415 66164 6864 6.2 28.2 7.0 PPA 160 1066 210.0 1185.0 47147 113311 7405 5.7 33.9 9.0 PPA 150 1216 210.0 1395.0 56783 170094 7653 5.7 39.5 10.0 PPA 132 1348 190.0 1585.0 55333 225428 7854 5.1 44.7 Flush 263 1611 263.4 1848.4 0 225428 7047 6.6 51.3 Attachment G • S Client : energyAlaska Schlumberger Well ODSN-22ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 10) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 10 MD. 17268.0 ft Initial Fracture Top TVD 6098.0 ft Initial Fracture Bottom TVD 6144.0 ft Propped Fracture Half-Length 320.4 ft 1 EOJ Hyd Height at Well 127.0 ft Average Propped Width 0.338 in Average Gel Concentration 253.3 lb/mgal Average Gel Fluid Retained Factor, 0.45 Net Pressure 476 psi Efficiency 0.484 ° Effective Conductivity 12131 md.ft Effective Fcd 18.9 Max Surface Pressure 7915 psi CZ Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (Ib/mgal) (md.ft) (PPA) (Ib/ft2) 0.0 80.1 10.1 0.392 106.0 3.50 219.1 12312 80.1 160.2 9.5 0.388 113.3 3.42 225.9 12147 160.2 240.3 8.3 0.382 109.7 3.39 230.5 11713 240.3 320.4 2.9 0.230 107.0 2.04 337.7 6444 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 Schlumtarger Formation : Nuiqsut District : Prudhoe Bay,AK Zone Data (Stage 11) Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness (ft) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) (psi/ft) (psi) (psi) SHALE 5994.0 _ 100.0 0.750 4533 5.000E+5 0.33 1000 Nuiqsut Zone 1 6094.0 46.0 0.650 3976 1.600E+6 0.25 1200 Nuiqsut Zone 2 6140.0 6.0 0.700 4300 2.000E+6 0.29 1000 Nuiqsut Zone 3 6146.0 12.0 0.670 4122 2.000E+6 0.33 700 Nuiqsut Zone 4 6158.0 6.0 0.700 4313 2.000E+6 0.29 1000 Nuiqsut Zone 5 6164.0 37.0 0.650 4019 1.600E+6 0.22 1200 SHALE 6201.0 100.0 0.800 5001 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. (ft( Height (mdl (%( Pressure (ft) (psi) SHALE 5994.0 1.0 0.001 1.0 2829 iii Nuiqsut Zone 1 6094.0 46.0 2.000 16.0 2863 Nuiqsut Zone 2 6140.0 6.0 0.100 10.0 2875 t ct Nuiqsut Zone 3 6146.0 12.0 0.500 12.0 2879 Nuiqsut Zone 4 6158.0 6.0 0.200 10.0 2883 Nuiqsut Zone 5 6164.0 37.0 2.000 15.0 2960 SHALE 6201.0 1.0 0.001 1.0 2925 Propped Fracture Schedule (Stage 11) Pumping Schedule Job Description Step l Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) Stage 11 40.0 YF125ST 215 25.0 0.00 PAD Slow for 12.0 YF125ST 60 25.0 0.00 Seat Resume 40.0 YF125ST 55 25.0 0.00 PAD 1.0 PPA 40.0 YF125ST 148 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 Attachment G • 0 Client : Caelus energy Alaska Iillll{Ewr � Well : ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (Ib/mgal) (PPA) 2.0 PPA 40.0 YF125ST 161 25.0 CarboLite w/5% 2.00 ScaleGuard 16/20 4.0 PPA 40.0 YF125ST 170 25.0 CarboLite w/5% 4.00 ScaleGuard 16/20 6.0 PPA 37.0 YF125ST 158 25.0 CarboLite w/5% 6.00 ScaleGuard 16/20 8.0 PPA 37.0 YF125ST 148 25.0 Carbolite w/5% 8.00 ScaleGuard 16/20 10.0 PPA 37.0 YF125ST 139 25.0 CarboLite w/5% 10.00 ScaleGuard 16/20 12.0 PPA 37.0 YF125ST 114 25.0 CarboLite w/5% 12.00 ScaleGuard 16/20 Flush 40.0 YF125ST 250 25.0 0.00 Please note thatthis pumping schedule is under-displaced by 5.0 bbl. Fluid Totals 1618 bbl of YF125ST Proppant Totals 253600 lb of CarboLite w/5%ScaleGuard 16/20 Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (lb) (Ib) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) Stage 11 215 215 215.0 215.0 0 0 5616 5.4 5.4 PAD Slow for 60 275 60.0 275.0 0 0 5653 5.0 10.4 Seat Resume 55 330 55.0 330.0 0 0 5664 1.4 11.8 PAD 1.0 PPA 148 478 155.0 485.0 6234 6234 5663 3.9 15.6 2.0 PPA 161 639 175.0 660.0 13506 19740 4826 4.4 20.0 4.0 PPA 170 809 200.0 860.0 28550 48290 6205 5.0 25.0 6.0 PPA 158 967 200.0 1060.0 39832 88123 7112 5.4 30.4 8.0 PPA 148 1115 200.0 1260.0 49641 137763 7437 5.4 35.8 10.0 PPA 139 1254 200.0 1460.0 58246 196009 7515 5.4 41.2 12.0 PPA 114 1368 175.0 1635.0 57625 253634 7722 4.7 45.9 Flush 250 1618 249.6 1884.6 0 253634 6857 6.2 52.2 Attachment G • • Client : Caelus 0DSN-energy Alaska �� YY� 1 Well : ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 11) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 11 MD 16693.0 ft Initial Fracture Top TVD 6094.0 ft Initial Fracture Bottom TVD 6140.0 ft Propped Fracture Half-Length 340.1 ft EOJ Hyd Height at Well 127.0 ft Average Propped Width 0.357 in Average Gel Concentration 241.1 lb/mgal Average Gel Fluid Retained Factor. 0.46 Net Pressure 490 psi Efficiency 0.497 r Effective Conductivity 13306 md.ft Effective Fcd 19.6 Max Surface Pressure 7823 psi 7 CD Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (Ib/mgal) (md.ft) (PPA) (Ib/ft2) 0.0 85.0 11.6 0.429 105.8 3.82 199.8 14402 85.0 170.1 10.0 0.406 111.4 3.59 211.9 13303 170.1 255.1 8.8 0.384 107.5 3.43 219.2 12091 255.1 340.1 4.4 0.232 105.5 2.12 333.6 6196 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 SChlffillberger Formation : Nuiqsut District : Prudhoe Bay,AK Zone Data(Stage 12) Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness Ift) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) (psi/ft) (psi) (psi) SHALE 5984.0 100.0 0.750 4525 5.000E+5 0.33 1000 Nuiqsut Zone 1 6084.0 52.0 0.650 3971 1.600E+6 0.25 1200 Nuiqsut Zone 2 6136.0 5.0 0.700 4297 2.000E+6 0.29 1000 Nuiqsut Zone 3 6141.0 12.0 0.670 4118 2.000E+6 0.33 700 Nuiqsut Zone 4 6153.0 6.0 0.700 4309 2.000E+6 0.29 1000 Nuiqsut Zone 5 6159.0 37.0 0.650 4015 1.600E+6 0.22 1200 SHALE 6196.0 100.0 0.800 4997 5.000E+5 0.35 1000 Formation Transmissibility Properties Zone Name Top ND Net Perm Porosity Res. (ft( Height (old) (%( Pressure tr` (ft) (psi) SHALE 5984.0 1.0 0.001 1.0 2824zz Nuiqsut Zone 1 6084.0 52.0 2.000 16.0 2859 Nuiqsut Zone 2 6136.0 5.0 0.100 10.0 2873 , Nuiqsut Zone 3 6141.0 12.0 0.500 12.0 2877 Nuiqsut Zone 4 6153.0 6.0 0.200 10.0 2881 Nuiqsut Zone 5 6159.0 37.0 2.000 15.0 2960 zo SHALE 6196.0 1.0 0.001 1.0 2923 Propped Fracture Schedule (Stage 12) Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. )bbl/min) (bbl) (lb/mgal) (PPA) Stage 12 40.0 YF125ST 205 25.0 0.00 PAD Slow for 12.0 YF125ST 60 25.0 0.00 Seat Resume 40.0 YF125ST 50 25.0 0.00 PAD 1.0 PPA 40.0 YF125ST 144 25.0 CarboLite w/5% 1.00 ScaleGuard 16/20 Attachment G • • Client : Caelus energy Alaska Well : ODSN-22 SCNIIM belle') Formation : Nuiqsut District : Prudhoe Bay,AK Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (bbl) (lb/mgal) (PPA) 2.0 PPA 40.0 YF125ST 152 25.0 CarboLite w/5% 2.00 ScaleGuard 16/20 4.0 PPA 40.0 YF125ST 161 25.0 CarboLite w/5% 4.00 ScaleGuard 16/20 6.0 PPA 38.0 YF125ST 150 25.0 CarboLite w/5% 6.00 ScaleGuard 16/20 8.0 PPA 38.0 YF125ST 140 25.0 CarboLite w/5% 8.00 ScaleGuard 16/20 10.0 PPA 38.0 YF125ST 132 25.0 CarboLite w/5% 10.00 ScaleGuard 16/20 12.0 PPA 38.0 YF125ST 108 25.0 CarboLite w/5% 12.00 ScaleGuard 16/20 Flush 40.0 WF125 240 30.2 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. P o Fluid Totals 1302 bbl of YF125ST 240 bbl of WF125 en Proppant Totals 13 71. 240600 lb of CarboLite w/5%ScaleGuard 16/20 m. Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (bbl) Volume Volume (Ib) (Ib) Pressure (min) (min) (bbl) (bbl) (bbl) (psi) Stage 12 205 205 205.0 205.0 0 0 5479 5.1 5.1 PAD Slow for 60 265 60.0 265.0 0 0 5501 5.0 10.1 Seat Resume 50 315 50.0 315.0 0 0 5504 1.3 11.4 PAD 1.0 PPA 144 459 150.0 465.0 6033 6033 3770 3.8 15.1 2.0 PPA 152 610 165.0 630.0 12734 18767 4427 4.1 19.3 4.0 PPA 161 772 190.0 820.0 27123 45890 6026 4.8 24.0 6.0 PPA 150 922 190.0 1010.0 37841 83731 6893 5.0 29.0 8.0 PPA 140 1062 190.0 1200.0 47159 130889 7353 5.0 34.0 10.0 PPA 132 1194 190.0 1390.0 55333 186223 7557 5.0 39.0 12.0 PPA 108 1302 165.0 1555.0 54332 240555 7751 4.3 43.3 Flush 240 1542 240.4 1795.4 0 240555 5937 6.0 49.4 Attachment G le 0 Client : Caelus DDSN-energy Alaska S hIiI YUr � Well : ODSN-22 Formation : Nuiqsut District : Prudhoe Bay,AK Propped Fracture Simulation (Stage 12) The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Stage 12 MD 16090.0 ft Initial Fracture Top TVD 6084.0 ft Initial Fracture Bottom TVD 6136.0 ft Propped Fracture Half-Length 311.9 ft - EOJ Hyd Height at Well 129.6 ft Average Propped Width 0.356 in Average Gel Concentration 237.3 lb/mgal Average Gel Fluid Retained Factor 0.47 Net Pressure 480 psi Efficiency 0.505 `: Effective Conductivity 13473 md.ft Effective Fcd 21.6 Max Surface Pressure 7856 psi Simulation Results by Fracture Segment From To Prop.Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (lb/mgal) (md.ft) _ (PPA) (Ib/ft2) 0.0 _ 78.0 11.6 0.440 92.4 3.92 196.3 15188 78.0 156.0 9.9 0.410 113.6 3.63 _ 211.4 _ 13534 156.0 234.0 8.4 0.369 111.1 3.25 226.8 11755 234.0 311.9 3.8 0.231 95.7 2.09 314.5 6279 Attachment G • • Client: Caelus Energy Alaska Schlumberger Wein ODSN-22 Basin/field: Oooguruk State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: 2/20/2016 Date Prepared: 10/9/2015 11:54 AM Report ID: RPT-39613 Fluid Description(s) YF125ST:WF125 735,714 Gal Contains:Water,SCALEGUARD®IV,Surfactant,Breaker,Crosslinker,Gelling Agent,Scale Inhibitor,Additive, Bactericide,Propping Agent The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)* ^'71 % 66402-68-4 Ceramic materials and wares,chemicals -28% 9000-30-0 Guar gum <1% 56-81-5 1,2,3-Propanetriol <0.1% 1303-96-4 Sodium tetraborate decahydrate <0.1% 68715-83-3 2-Butenedioic acid(2Z)-,polymer with sodium 2-propene 1 sulfonate <0.1% 7727-54-0 Diammonium peroxidisulphate <0.1% 9003-35-4 Phenolic resin <0.1% 107-21-1 Ethylene glycol <0.1 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1% 1310-58-3 Potassium hydroxide <0.1% 111-76-2 2-butoxyethanol <0.1 % 67-63-0 Propan-2-ol <0.1 % 34398-01-1 Alcohol,C11 linear,ethoxylated <0.1 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.01 % 68131-39-5 C12-15 alcohol ethyoxylated <0.01 % 7647-14-5 Sodium chloride <0.01 % 1310-73-2 _ Sodium hydroxide(impurity) <0.01 % 10043-52-4 Calcium Chloride <0.01 %_ 91053-39-3 Diatomaceous earth,calcined <0.01 % 112-42-5 1-undecanol <0.01 % 7631-86-9 Non-crystalline silica(impurity) <0.001 % 111-46-6 2,2"-oxydiethanol(impurity) <0.001 % 10377-60-3 Magnesium nitrate <0.001 % 14807-96-6 Magnesium silicate hydrate(talc) <0.001 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001 % - 7786-30-3 Magnesium chloride <0.001 % 9002-84-0 poly(tetrafluoroethylene) <0.001 % 7447-40-7 Potassium chloride(impurity) <0.001 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 127-08-2 Acetic acid,potassium salt <0.0001 % 14464-46-1 Cristobalite <0.0001 % 14808-60-7 Quartz,Crystalline silica <0.0001 % 64-19-7 Acetic acid(im.uri ) <0.0001 % Total i00'� •Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. ATTACHMENT H 0 Schlumberger 2015.Used by Caelus Energy Alaska by permission. Page:1/1 • s AE s ' Alaska ODSN- 22 Pre-Post Fracture Stimulation Wellwork Program Date -10/13/15 AFE Number Wireline GenSub Wellhead Work GenSub Prepared: Date: Eli Wilson Wells Group Supervisor Reviewed: Date: Chad Gueco Wells Group Supervisor Reviewed: Date: Jack Kralick Wells Superintendent ATTACHMENT I • • Basic Well Data: Well Number: ODSN- 22 Well Type: Nuiqsut Producer TD Depth: 22,208' MD / 6,197' TVD Casing/ Tubing Data: Top Bottom Hole Csg/ Tbg Wt I.D. Drift Burst Collapse Hole Section Depth Depth Size Size (Ib/ft) Grade Connection (inch) (inch) (psi) (psi) (ft) (ft) (inch) (inch) Surface 63,211 MD 43 MD 3,221111 TVD 14-1/2 11-3/4 60 H-40 BTC 10.772 10.616 5830 3180 Intermediate 1 6,548 MD 11,717 MD 11-3/4 9-5/8 40 L-80 Hydril 521 8.835 8.679 5750 3090 3,211 TVD 4,915 TVD Intermediate 2 43 MD 15,699 MD 8-1/2 7 26 L-80 Hydril 563 6.276 6.151 7240 5410 6,077 TVD Lateral 15,699 MD 22,700 MD 6-1/8 4-1/2 12.6 C-110 Hydril 521 3.958 3.833 11590 9200 6,077 TVD 6,288 TVD Upper Completion 43 MD 15,450 MD - 4-1/2 12.6 C-110 Hydril 521 3.958 3.833 11590 9200 (Tubing) 6,055 TVD Tubular and Annular Capacity Data: Tubing size Weight I.D. Capacity Capacity Annulus Annular Annular (inch) (Ib/ft.) (inch) (bbls/ft) (cu ft/ft) Volume Volume (bbls/ft) (cu ft/ft) 4-1/2 12.6 3.958 0.01522 0.08544 4-1/2"x 7"26# 0.0186 0.1044 Well Status • 4.5" Frac String Assembly stabbed into 4.5" Liner Top @ 15,449' MD/6,055' TVD • Frac string is set in 40 kips compression. • Dummy GLV's with hardened latches are set in GLM's @ 3,481' MD, 8,921' MD, and 14,390' MD. • 4.5" FXE SSSV is set in SVLN @ 2,882' MD. NOTE: See attached schematic for exact jewelry depths and current well status. Wellhead Assembly • Vetco Gray-4-1/16" 10k. ATTACHMENT I • • Pre Fracture Stimulation - Slickline Program: 1) Record Tubing, IA, and OA pressures. Record BHP and Temp. Note on Wellview Report. 2) Complete well handover form from Operations to Wells Group. 3) Conduct a pre-job safety meeting with HES, Wells Group Supervisor, and all personnel involved in the job scope. 4) MIRU HES Combo Unit w/.125 wire. Hang load cell, and necessary sheaves. 5) Pick up lubricator, toolstring, and 3.83" gauge ring. 6) Make up lubricator to wellhead and pressure test as per HES policy & procedure. (1.5 times expected WH pressure) 7) RIH w/ 3.83" gauge ring to "XXO" SVLN © 2,882' MD. 8) RIH w/4.5 GS to 4.5" FXE SSSV in SVLN © 2,882' MD. 9) LRS to load tubing w/230 bbls of diesel to XN nipple @ 14,867' MD. 10) RIH w/3.80" gauge ring(3/4" Internal SR), 2' weight bar, and 4.5 BLB to XN nipple © 14,867' MD. 11) Make up HES DPU w/4.5 Evo-Trieve RBP. Set travel & still time as per HES recommendation. 12) RIH w13.5" GR, 3.5" bait sub, HES 2.75" Downhole Power Unit, and 3.66" Evo-Trieve RBP w/3.75 cent to XN nipple @ 14,867' MD. Set 3.66" Evo-Trieve RBP © 14,860' MD. Tubing Pup 4 112 12.60 C-110 Yes 14.67 Na 14,868.4 616.61 Joint HES 3.813" 4.734 12.60 C-110 Yes 1.47 No 14,866.9 618.08 "XN"Nipple WI 3.725"No -Go SNC304320 Tubing Pup 4 1/2 12.60 C-110 Yes 14.70 No 14,852.2 632.78 Joint 13) Perform MIT-T to,..241efor 30 minutes. Record results in Wellview Report. Bleed tubing pressure to zero. (,'c)c) 14) Perform MIT-IA to 4000 psi for 30 minutes. Record results in Wellview Report. Bleed IA to zero. 15) Report MIT results to Anchorage team before proceeding w/program. 16) RIH w/3.5 barbell assembly & 2-3/8" GR to 3.66" Evo-Trieve RBP @ 14,860' MD. Equalize & pull plug. 17) Purge control line w/3 gallons of hydraulic oil. RIH w/4-1/2" GS &4.5" Frac Isolation Sleeve (3.12" ID) to "XXO" SVLN @ 2,882' MD. Set frac..sleeve&establish control line integrity to 4000 psi. 18) RIH w/KJ, 2' weight bar, and 3.00" Swage to as deep as possible to verify tubing is free of any obstructions. Note final depth in Wellview report. ATTACHMENT I • 19) RDMO HES Slickline. Wells Group will keep possession of well handover during Frac operations. Post Fracture Stimulation - Slickline Program: 20) Record Tubing, IA, and OA pressures. Record BHP and Temp. Note on Wellview Report. 21) Conduct a pre-job safety meeting with HES, Wells Group Supervisor, and all personnel involved in the job scope. 22) MIRU HES Combo Unit w/.125 wire. Hang load cell, and necessary sheaves. 23) Pick up lubricator, toolstring, and 3.83" gauge ring. 24) Make up lubricator to wellhead and pressure test as per HES policy & procedure. (1.5 times expected WH pressure) 25) RIH w/3.83" gauge ring to "XXO" SVLN @ 2,882' MD. 26) RIH w/4.5 GS to 4.5" Frac Isolation Sleeve in SVLN @ 2,882' MD. 27) RIH w//3.80" gauge ring(3/4" Internal SR), 2'weight bar, and 4.5 BLB to XN nipple © 14,867' MD. 28) RIH w/4.5" GS (3/16" brass pin) &4.5" Keyless RHC plug to XN nipple @ 14,867' MD. 29) RIH w/4.5" OK6 w/1-1/4" JDS to GLM # 1 @ 14,390' MD. Locate & pull 1" DGLV(BK). 30) RIH w/4.5" OK6 w/1" Orifice GLV(5/16" ports, BK-4)to GLM # 1 @ 14,390' MD. Locate & set valve. 31) RIH w/4.5" GS to 4.5" RHC plug body in XN nipple @ 14,867' MD. 32) Purge control line w/3 gallons of hydraulic oil. 33) On surface, drift 4.5" Frac Isolation Sleeve(3.12" ID)with 3.009"frac ball. 34) RIH w/4.5" GS &4.5" Frac Isolation Sleeve(3.12" ID)to SVLN ©2,882' MD. 35) Establish control line integrity to 4000 psi. Hang tag on control line to identify sleeve is installed. 36) RDMO HES Slickline. MIRU Expro flowback equipment. Expro Flowback Goals and Objectives 1. Conduct PJSM w/Wells Group Supervisor, Expro, Operations team, ACS, and all personnel relevant to the job scope. No Injuries. No Spills. No HSE Incidents. 2. Establish fluid production types and rates (Oil, Gas, Water). 3. Uninterrupted flow for first 96 hours, i.e. no shutdowns, or significant slowdowns. ATTACHMENT I • • 4. Conduct a seamless switch between Expro testing and Caelus Energy LLC operations. 5. Meet CPAI requirements for sales as directed by Caelus Energy LLC Production Supervisor. 6. The well was fracture stimulated using a Halliburton RapidStage Ball Actuated system. The balls are dissolvable in brine, but ball fragments may return and should be caught in the ball catcher. A list of ball sizes can be found at the end of the program. NOTE. Please state all aluminum balls that were left in the well between frac stages. Pre-Flowback Operations 1. Confirm HAZOP actions and P&ID walk through of flowback equipment spread. 2. Ensure data acquisition systems are functional and recording. 3. Record initial pressures and temperatures (BHP, OA, IA, tubing). 4. Review flowback operations and expected duration during morning SimOps meeting. 5. Verify wind direction and speed prior to and during flowback. Minimum 5 mph wind required for all unloading and transfer operations. Wind break effect of surrounding structures need to be considered in order to prevent lay down of heavy hydrocarbon vapors in low lying spots and wind protected areas. Wind needs to be carrying any gas vapors to a safe location away from operating equipment and ignition sources. Well Clean-Up and Diagnostic Flow Test Using Lift Gas: 1. Collect and send samples periodically to KRU lab for API gravity validation. 2. Verify Lift Gas Header pressure is greater than Fluid Column Hydrostatic Pressure above. 3. If WHP is greater than production header pressure bleed WHP down until they're equal. 4. Initial choke setting should be 30/64ths This choke setting should be sufficient to generate an increase in surface temperature on the wellhead flowline. 5. Start methanol injection into IA; just upstream of the LG choke if possible. ATTACHMENT I • • 6. Slowly start lift gas injection into the IA at 300 Mscf/day (as low as possible). Keep the rate slow enough such that IA pressure increases no more than 50 psi every 60 minutes after the initial lift gas injection rate. Increase should be slow and steady to avoid fluid-cutting the valves. No more than 1 bpm of liquid should pass thru a gas lift valve. There should be a slow, steady increase in both IA and BH pressures. Monitor these pressures using DCS trends and/or the Trend Tool. 7. Maintain this low LG rate and IA pressure increase until fluid level is pushed down to the top valve and gas is injected into the tubing. This will be indicated in the following ways: a. Both IA and BH pressures will decrease suddenly b. Well will start producing aerated fluids 8. Each time a new GLV is uncovered there should be a corresponding decrease in IA pressure; although it will not be as great as that seen when uncovering the first valve. 9. Continue at the current LG rate until fluid level is at the OV. If necessary, shoot fluid level to confirm. 10.With fluid level at the OV, begin opening choke in 2/64ths increments and monitor BHP and returns for 2X tubing volumes. If BHP is fairly stable and solids content is <1% repeat this procedure. (Tbg volume to OV @ 14,390' MD = 219 bbls) 11.1f BHP stays stable and solids content is low after a total of 20/64ths choke increase from the initial setting, then more aggressive choke changes can be made by 4/64ths increments. Monitor BHP and returns 2X tubing volumes. The goal is to work the choke open as quickly as possible following the above guidelines. Slugging should be first be mitigated by adjusting the lift gas rate, not the choke. Once the choke is open it should remain open. Note: It is imperative that the well is allowed to flow uninterrupted for a minimum of 96 hours. Any shut-ins tend to cause plugging when the proppant falls out of the fluid stream. 12.LG rates can be increased at the discretion of the Production Supervisor. 13.As a check, IA pressure is an indicator as to whether LG valves above the OV are closed. IA pressure must be less than the closing pressures listed in the gas lift design tables in the post frac slickline procedures above for them to be closed. 14.Once PPSA criteria are met with sufficient sampling approved by the KRU lab, production can be turned over to sales. A pre-job meeting with the Well Work Supervisor, Production Operations and Expro should be held to ensure everyone is ATTACHMENT I • • aware of the process and that shutting in the well may create a problem leading to limited flow potential. 06-09-2015 • ODSN-22 Nuiqsut Production Well Completion FINAL , 1 .. tvp.ramplati. MOH ' 1V11111) I I Land Upper . 1 otnne Haney 34 34 Completion I 4-1V*Hall:Awry, 2881 2002 with 40,000 lbs annon Cross,.,. t w/1.5ft Pup 0 000Uo, Slack-Off 4 4-15^12.6a/ftC-113 HO,,521 I ug S 441"or Gum#3,KIIG-44 HydOl 521 sof 1Sft P611 Sa.8. '. 1481 2206 I 6 441"12,617ft C-110 Hydol 521 Tubing(210480) 4 I 7 *es"r 714010 SA13"w/1Sft Pup 141.Top&bottom 1399 2240 8 &V 12.611/ft C-110Hyddl 521 Tubing I C 16°Conductor 9 441.9 1'ULM 4 2,1311-4,0Hydol 521 so/1,571 Pup BO Top&Bottom 8921 9995 la 10 &V 1204/1,C.110 Hydr1 521 Tubing(21 oint.0 I A oh,Packer Fluid mix. u. Hu'P"tepple 1.1113*or/1181 Pup IMP top&&Atom WO 4034 I Inhibited Kill t' 4-11'12.6ot/ft t-110 tarddl 521 TUbi nil I weight Brine 13 4-fY`4 1'0110 I 1,88G-4 5 Hydril 521 w/1Sft Pop(HP Too&Sodom 14390 6/100 GLM#314 4-8"1240/ft C-110 Had,V 521 ty0k ng with 2000'TVD DGLV 5 01 J 15 H45 le'14111661 ME w/15ft VW so Top&&atom USW SDP Installed i ie cap cap 16 4-h'12,6lifft C-110 Hydost 521 Tubing . 7,000 psi Li i, 4-tir Hallthorton'PtX 0 Hoge Carder w/Encapwlated...Dna to Soot ate w/134t Puo 114P Top& ssm Max raid , 11-3/4"60#1-80 Bottom r BTC Surface Casing is 4-h"12.61511 C-110 WWI S71 Tubing(MO 0 @ 6,548'MD/ 4 In"APO'S ftewElasulawic Slidlog Veto&12Sksi frac Hardoo body&loner Steove 3.813" PCW Proftle WI 4 wr 11,600149d Sit Pot it Pin,Owens Up,1(11100 PO w/1511 Pup SO Top& WS7 3211'IVO 5916 Botta. shh.cemented to surface 20 441"12.67071 C-110 l&dol S71 Tutu%Post 21 1415W stir(1.775'114oGo),-w/WI Pup SuP Top&Bottom Wel 5951 22 412.17//ft C-110 ftwirl S.71 Tubing h 11,/ror Orossoret P-1.10 WOW with a 5.66.long 4.1/2" andling pup on top,4"Space,Pow.2 TOC 23 144,411 605S Late Sial Assembly.WOO 1.90940Hk 9,04 GLM#2 Estimated &Mom of Shoe 19116 WM DGLV (4'500 ft Installed 0 Gt. above 9-5/8" wa bauag,eywuplyabun •.,,W,,,',-,',,...4,1!..1. 7,000 PsiI Shoe 244 20 tt 5 25 1 te Back extentlon 33430 6054 " Max rated 0 tali Bolow S"X r DP tinor Top Poclow'with flex took Nonow I 20914,25"SW toot Sweptide 74b ISK9 8053 Wow H411441 9-5/8'401#L-80 .: 25 4..8"12.84011+01n1521C-1100)ner I - Hydrii 521 26 nesmad tentmely Vented Canasta 41054368/RWS-1395w/15ft Pup lot Top&Bottom 11,691 6014 I Intermediate 1 n 4-li^12,6194097979 571 C.-110 tmer .: . . I Casing Hallibudon Swell PAcke,5 13)4-02 Hydra 521)OD 5.96'•gavial'long oil gebyeted with Silde on ©11,717'MDI 28 Volant Centre/Her Pm End and aft Pup 4-1/2"12.619113,110 Hodoil 521.Box a Pin se/Slide On 50Th 5,063 4,915'TVD Velma Cantrant erod Top of Swell Packet I Halliburton Swell Packer It 12)4-02 Hydra S21)005.85'-9 meter long oil actvated with 50140 on 21 Volt Centralizer lho god and Oft Pup 4-1f2 1/64/1t P...1111 HOW 521 Boa a Pn w./SIlde Oe 15.815 6.086 GLM#1 l',, i Volant Centralizer on Top of Swell Packer DGLV as% 1• ES Cementer 30,4-h"12 616`ft Wyddl 521 C-1101„ner Installed 14110 C'I- 1-1 Base Torok NIB aux"sapoiscsei Sall&WW1 Wove/1 11(3,009 be/215 Soot)w/1.511&Ur P-110 Pup 4 ' 31 16,0197 113 700(1 7,000 psiana . . r/3"Lt(44,4hP-110 Hydoll SZ1 Box x Pin Max rated"".:" LA' 32 4-02 12 tatfis Helot 521 C-1101,ner Hadlborton Swell Padaerg 11)4-50"Hydril 125)000.45'-°Mete long oil actooded with Mete on c) 7"Stage 2 TOC 13 Volent Centratlyernin frod and 6ft Ilw&lir 11.60ft P-110 16011511 box 4 PM wf Slide On 15091 6„131 Estimated Voted Centranter on Top of Swell Packet Sliding ,i. 34 4-51"12 beff:HydnI 521 C-110 tywor ' (a,500 ft above Sleeve .•.', HO 4.1/2"RapidStace Sall atcboated5leatee NI:012.921ban/23162 Sean ea/15ft 4-1/2"P-110 Pup Closed dm Hi; Torok Sand # 41/2"it 9/imp-u.Hydr0 SX1 1120 0 Pio 16.690 4,134 (Lip to Open) Package 36 4-14`12 60 5 Hodn.1 51100-1100,0.5 dallobudon Swell Packer 4 10)4.14"Hyddi 521I.On S 85-91,616f tcolg oil activated woth Vide on Ox,. 31 Volant Centralizer Pn End and 68*Pup 4.1/10 12 64/ft P-110 Hyddl 521 Boa x Pn ve,Slide On 16,175 6,031 Volant Centralate on Top of Soon Packet 7"Stage 1 TOC 38 4-02 12 641t Had&521 C-110 tater Estimated ei 114.11 44/2"RapidStaga&Pi&WW1 Sleeve/4(21W ball/2.7/165o01l w/1.5114-1/2'1,110 Pup& ,500 ft above 12265 &LW Ur 1.27609ft 1,110 Wydril 52111o:x Pin (al 40 4-0212.6x/ft Hydn1 521 C..110t,net Kuparuk 41 Rosman Internally Vented Card.9 3 805-1367/RWS-1391 w/131*Pup OuP top&Bottom 17191 4,142 42 4-.7.12 61,7ft 99991 5210,110 Loot Haladoton Swell Pada,a 914-h"ftwitil 5.21S 00 0 05.9 meter long nit activated with 10044 on CP,' 0 43 Volant C entvadter PH End and 6ft Pop 4-1/2'LI WM f,110 Hydod 521 go.Pm w/984 00 17,553 6,142 11W ',',. '-',i, 44 4-h"UVolgot C ento ante,on top of Swell Puke r be/ft HydnI 521 C410 Lner .<;,\,r4 0 45 HIS&yr Itapidaia,go Sill Amato&Stoove It$77.761 bah/LIM Soot)w/1Sft 44/r PAU/Pup 4, ,812 &VW 7-26# L-80 BTC M'.:: .. „1" 0 xer 12111/ft',up room sat sox.Pin 17 r- &HydrIl 563 , / () 46 4.51.I461642 Hydn I WIC:510 Uner Intermediate 2 ' ' W 6-3') Os c;) c) 67)„ — CD_0,0 0 7® CD Casing W ilf-- • W if— i - _ - - 1E1 E I 1E1 2 0-®/I-C)-111(2)-- --(ii)._1.®10.___110NOW 0— li " 4-1/2”Hydril 521/C-110 Liner with Halfiburton Ball Actuated 6-1/8Hole TD Sleeves,&Swell Packers 6.197'TVD ATTACHMENT I I • 06-09-2015 ODSN-22 Nuiqsut Production Well Completion FINAL Mo. Lower Corrapletion MOW IVO(ft) Land Upper Completion 4, Vol,t,ert,lil,l,Pir Lod 4ro oft Pt.p t 14 ottrt1 0 110 Hyonl 521BUA Fn.'t 181.11' c i t) with 40,000 lbs V plant Centralizer on Top of Swell Pack Slack-Off 48 4.5"12.6Pift ROM 521 C-110 liner mal-wr Rapiditage Bail Actuated Sleeve 8 7(2.631 bail/WI Seat)re/151141/Y P-1HIPtip 4- 49 18,402 6,155 vr askitt P-110*Orli 521 Boa a Pin I, 1 SO 441'12.6a/ft Hydril 521 C-110 Line, 'll 12 C r., 16 Conductor !allotted Kill Halliburton Swell Packer 0 7(11-H'Hydril 521)OD 585'-9 meter long oil activated with Slide o - SiSI Volant Centralizer Pin End and 611 Pup 4-1/2'12.611/11 P-110 HOW 521 BC..a Pin wi Slide On Vol ant Centralizer on Top of Swell Packer 52 4 11-12.610 t Hydril 521 C.110 Li ner 16,718 6,161 I k Packer Fluid mix. weight Brine HU 4-1Ir ItapidSkage Ball Actuated SlimSlima 6(1603 bail/2552 Seat)l 1511 a/ 41/2"P-110 Pap 4- GLMe 3 Valli 2000'NO s3 vr .61/0 P-110 Hydril 521 Sox a Pin 19,0U 6,164 DGLV 54 411'12.611/f t Hydril 521 C.I10 Liner Installed III 1 diesel cap 55 Batman Internally Vented Canier 4 2 R0S-1366/RWS-1.393 vs/L511 Pup BaP Top&Bottom 19,117 6,165 7,000 psi vs i 56 4-$i"12.60/it Hydril 521 C-110 Liner Max rate K-''' 11-3/4'60#L-80 Halliburton Swell Packer 4 6(411'Hydril 521)Of)5.35-9 meter long oil activated with Slide on BTC Surface Casing 57 vol,,Centralizer Pin End and at Pup 4-1X 12.64/ft P-110 Hyddl 571 So,,Pin wi Slide Ort 19,358 6,169 IY4 @ 6,548'MD/ V ol ant Centralizer on Top of Swell Padier 3,211'TVD 58 4-h'12.611/1t Hydril 521 C.110 ki ner A 66 cemented to surface s9 HIS 4-1/2"Rapicritage BdI Actuated Heave 15(2.527bat/2.477 Seat)w/1.5814-ift P-120,..pi: 6,174 ur 12.611/1t P-110*Orli 62180a a Pin CO 441"12,64/R110rd 521 C-110 liner IOC Halliburton Swell Packer115(441"14yeldl 521)005AS'.9 meter long oil activated with Hide on 61 Volans Centralizer Pin End and 611 Pup 4.1/2-12,60/ft P-110 Hydill 521 Son■PM w/Slide On 19.890 6,177 GLM#2 Estimated Velem Centralizer on Top of Swell Paler DGLV 0 500 ft 62 4-h"12,61991.14ydril 521 C-110 One, Installed 0 , above 9-618" 111344/2"ItipidStage Bail Actuated Heaved 4(1.452 ball/2.484 Seal)44 1511 4.1/2-1,110 Pup e 7,000 psi „sin, am I Shoe 63 1/2"12.66/ISP-SW likdr11523.los it Pin 20.113 6.1110 Max rated'IIIIIP r I 64 4-51'L2.611/1t Hydril 521 C-110 liner ,:41 9-5/8"40#L-80 Halliburton Swell Packer$4(0-1,5"Hydril 521)005,85'-5 meter long oil activated with Slide on 65 Voter-it Centralizer Pin End and lit Pup 4-112-1.361/H P-110 Hydril 521 Boa a Pin w/Hide On 20,386 6,171 Hydril 521 V olant Centralizer on Top of Swell Packer Intermediate I 66 4-h"12.61/It MOM 521 C.,110 liner - Casing WI 4-1/T RapidStage 141 Actuated Slaws if 3(2.379 bail/L132 Seat)w/1511 44/2"P-I.10 hap 4. 67 @ 11,71T MD/ ur 12.4411t P-110 legcliril 521 Box a Pin 20801 6177 4,915'TVD 68 4,1"12611/it Hydra 521 C.110 tine, A . . = 69 Resnwn internaliv Vented Carrier$1 ROS-1365/RWS-1392 w/1.5tt Pup BaP Top A Boman 10,994 6,173 GLIM 1 70 4-11"12 6It/it Hydra 521 C-110 Liner ' DGLV gni HaPiborton Swell Packer I 314-3i"Hvrin I 52110D 5,89-9 rne to r long oll activated whh Slide on Installed mid' ant Base Torok 71 VolCentralizer Pin End and 66t Pup 4-1/7"12.64/11 P.110 Hydril 521 Boa a Pin wf Slide On 21,6173 6,178 7,000 psi ,5 SES Cementer ill Volant Centralizer on Top of Swell Packer Max rated 72 441 12 Wit Hydril 521 C-110 Liner 7"Stage 2 TOC 73 0 NW 44/2'napidStage Ball Actuated Reeve(2.307 ball/2261 Seat).1 150t4ifr P-UO Pup 4- ' ing 24359 A179 1/2"17-611/11P-130 Nedra YI1 boa el Pin Estimated 74 4-)1*12 6a/it Hydrit 521 C-110 U ire, Slid , . a 500 ft above Hailiburkon Swell Fader 53(4-11'NOM¶21)905.85.9 meter long oil activated with Hide on Sleeve .. Torok Sand 75 V ol ant Centralizer Pin End and 6ft Pup 4-5/2'12.611/ft 1,110 Hydril SII Bon a Plow/Slide On 21,596 6,183 Closed (Uaik 10 O V olant Centralizer on Top of Swell Packer pen NI" Package p MI 76 4-h"12 611/14 Hydra 531 C-110 Li ner 4) r, 77 111114.1/1"ItaradiSlage 841 Actuated Sleeve(1236 bail/1192 Seat)w/1$114-1/2'P-110 Pm 4- 21.920 4.191 112'L114/1t P-150*OM=box ii Pin 7"Stage 1 TOC 78 4)6"1.2611/11Hydril 521 C-110 Oriel Estimated Hall I burton Swell Packer IS(#W Hydril 511)01)585'-9 meter long oil activated with Slide on @ SOO ft above 79 Volant Centralizer Pin End and 611 Pup 4-1/2'12.14/11 P-110 894.11 521 Box i Pin tv/Slide On 22.114 6,195 Kuparuk Volant Centralizer on Top of Swell Packer 80 4-11''12.6a/it Hydril 521 C-110 liner 111 Pre-perforetad Pup w/4-h'12.66/ft Helm 521 w/1511 44/r 1,110 Pup Ifae Top I Ilancien 22,147 6.195 0 D 83 82 4.11-12 611/11Hydril 521 C-110 Liner 4 ''. ,, ....,,Hydrti 521 Eccentric Shoe with Float Collar 23204 4197 ' k.', Bottom 44 Immo* 22,2C6 9,197 ••• •,//.\ . 7"26# L-80 BTC-M \1410 -Na 2"g &Hydril 563 abl. ',..,...0 Intemiediate 2 ,,, .. 0 0 0 0 O® ®0 C) 0 0 Casing ©15,699'MDI 0 0 #' : : _ _ _ _ _ _ _ _ _ - _ . 6,077'TVD .„ _ , - _ _ - - - l (Ts) i --- -_) (-)11-e-to- --®--lic)Ro---1® 'O icp- ".11., 6-1/8"Hole TD 4-'/2"Hydril 5211C-110 Liner with Halliburton Ball Actuated @ 22,208 MD! Sleeves,&Swell Packers 6,197'TVD ATTACHMENT I • • C -77)c o o a c a C HN c o N 0 To U U Y -0 4— Ov N c (O N OS O O o W v4 C Z n N 0< I- < auil MOD dH „E 0— D D �/� V co J O ;� <dwnd woJJ IL- W N bD L � L -I U 0 \ I /� VL 2 — Q� 1: V pea411aM�l m 0 U ro O .) N�"NN N ITDC � � N N N v O v O a ro m N • • 06-09-2015 ODSN-22 Nuiqsut Production Well Completion FINAL .,. .. ... .. ... •• ... .. .... No. Upper Completion MD(ft) WON .•.... .• .. .. .. -.•. .. Land Upper 1 Tubing Hanger 34 34 ••• .. pp I 2 ,4-%"12.6#/ft C-110 Hydril 521 Tubing Completion 445"Halliburton'XXOSVLN w/3.813•"r profile with single1/4"x 0049"s/s control line. :iiii I •• 3 2882 2002 with 40,000 lbs Cannon Cross-coupling clamps on every joint w/15ft Pup BxP Top&Bottom Slack-Off 4 4,A"12.6#/ft C-110 Hydril 521 Tubing 5 4,A"x 1"GLM#3,KBG-4-5 Hydril 521 w/15ft Pup BxP Top&Bottom 3481 2206 :•:.:. 6 4,A"12.6#/ft C-110 Hydril 521 Tubing(2 Joints) 4.5"FXE II:i I --- 7 HES"X"Nipple 3.813"w/15ft Pup BxP Top&Bottom 3599 2245 Installed iii: I .•.. ...• .... 8 4,A"12.6#/ft C-110 Hydril 521 Tubing .. .. ...... La.....a...'-',. 411 16"Conductor 9 4-%".r.G LM#2,KBG-4-5 Hydril 521 w/15ft Pup BxP Top&Bottom 8921 3995 •.• .., ... ... ... X I W Packer Fluid mix: 10 4-X"12.64/ft C-110 Hydril 521 Tubing(2loints) .•.• . .. III 11 HES"X"Nipple 3.81x.wi 15ft Pup BxP Top&Bottom 9040 4034 12 4,.A"12.6#/ft C-110 Hydril 521 Tubing Inhibited Kill A .. weight Brine 13 4- "x 1"GLM X 1,KBG-4-5 Hydril 521 w/15ft Pup BxP Top&Bottom 14390 5800 _ GLM#3 .. " with 2000'TVD 14 4,A"12.6#/ft C-110 Hydril 521 Tubing DGLV 0 GL II II15 HES"X"Nipple 3.813"w/15ft Pup BxP Top&Bottom 14509 5838A Installed —1 .... .. diesel cao 16 4,"12.6#/ft C-110 Hydril 521 Tubing .. 7,000 psico ix 1 ...• ..„ 17 4-1/2"Halliburton'ROC'Gauge Carrier w/Encapsulated e-line to Surface w/15ft Pup BxP Top& 14657 5884 Max rate .1]i 11-3/4"60#L-80 Bottom A .1: BTC Surface Casing .. .... .... 18 4,A"12.6#/ft C-110 Hydril 521 Tubing(2jts) .. . I .... .•.•..... .': ']': @ 6,548'MD/ 41/2"APCV II Non-Elastomeric Sliding Sleeve,1251csi Frac Harden Body&Inner Sleeve 1813" ... . I 3211TVD 19 PDX Profile W/4 1/2"12.60#Hyd 521 Box X Pin,Opens Up,10,000 Psi w/15ft Pup BxP Top& 14757 5916 ... . , Bottom ii : I .. cemented to surface 20 4,A"12.69/ft C-110 Hydril 521 Tubing(2jts) I 21 HES XN 3.813"(3.725"NoGo)-w/15ft Pup BuP Top&Bottom 14867 5951 22 4-1A"12.6#/ft C-110 Hydril 521 Tubing I TOC 23 4-1/2"x4"Crossover P-110 Locator with a 5.66'long 4-1/2"handling pup on top,4"Spacer Pup w/ 15449 6055 ; 1 Bullet Seal Assembly+Auto Entry Guide Shoe GLM#2 Estimated Bottom of Shoe 15485 6058 i DGLV @ 500 ft Installed 0 GL ,i..1 above 9-5/8" No. LowerCompletion MD(ft) TVD(ft) 7,000 psi 4.„' I Shoe 24a 20 ft 5.25"Tie Back extension 15430 6054 Max rated MP I x I 1 286 Baker 5"X 7"ZXP Liner Top Packer with Flex Lock Hanger/20 ft 4.25"Seal Bore Recepticle 15449 6055 Below Hanger . I 9-5/8"40#L-80 • 25 4,A"12.6#/ft Hydril 521 C-110 Liner Hydril 521 26 Resman Internally Vented Carrier#4 ROS-1368/RWS-1395 w/15ft Pup BxP Top&Bottom 15,691 6076 . I Intermediate 1 27 4-1A"12.6#/ft Hydril 521 C-110 Liner I Casing Halliburton Swell Packer#13(4-1A"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on ! : @ 11,717'MD/ 28 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Bonn Pin w/Slide On 15,771 6,083 Volant Centralizer on Top of Swell Packer I iL.. .:'.• 4,915'TVD i mi• Halliburton Swell Packer#12(VA"Hydril 521)OD 5.85'.9 meter long oil activated with Slide on 29 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-11.0 Hydril 521 Box x Pin w/Slide On 15,815 6,086 GLM#1 . 1 . ES Cementer Volant Centralizer on Top of Swell Packer DGLV I 30 4,A"12.6#/ft Hydril 521 C-110 Liner Installed 410 GL TI Base Torok HLB 41/2"RapidStage Ball Actuated Sleeve#11(3.009 ball/2.95 Seat)w/15ft 4-1/2"P-110 Pup 4- 31 16,087 6,111 7,000 psi41) 1/2"12.6#/ft P-110 Hydril 521 Box x Pin Max rated :: XII , 32 4,A"12.6#/ft Hydril 521 C-11.0 Liner . 1 Halliburton Swell Packer#11(4,A"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on 7"Stage 2 TOC 33 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 16,397 6,131 Liz) ,..,,E-_ri Estimated Volant Centralizer on Top of Swell Packer Sliding ---- @ 500 ft above 34 4,A"12.6#/ft ldydril 521 C-110 Liner Sleeve HLB 4-1/2"RapidStage Ball Actuated Sleeve#10(2.925 ball/2.867 Seat)w/15ft 4-1/2"P-110 Pup Torok Sand 35 Closed r.T4* 1:11:11 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin 16,690 6,134 (Up to Open)".2e" Package 36 4-'4"12.6#/ft Hydril 521 C-110 Liner Halliburton Swell Packer#10(44."Hydril 521)OD 5.85'-9 meter long oil activated with Slide on .. . 0 XN 37 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-1W Hydril 521 Box x Pin w/Slide On 16,975 6,135 Volant Centralizer on Top of Swell Packer 7"Stage 1 TOC 38 4,A"12.6#/ft Hydril 521 C-110 Liner Estimated 39 HLB 4-1/2"RapidStage Ball Actuated Sleeve#9(2.842 ball/2.786 Seat)w/15ft 4-1/2"P-110 Pup 4- 17,265 6,139 @ 500 ft above 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 40 4,A"12.6#/ft Hydril 521 C-110 Liner Kuparuk 41 Resman Internally Vented Carrier#3 ROS-1367/RWS-1394 w/15ft Pup BxP Top&Bottom 17,391 6,142 %. 42 4,A"12.6#/ft Hydril 521 C-110 Liner Halliburton Swell Packer#9(4,A"Hydril 521)OD S.85'-9 meter long oil activated with Slide on .:OA.N43 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-1W Hydril 521 Box x Pin w/Slide On 17,553 6,142 i . ' •'-''''' Volant Centralizer on lop of Swell Packer 44 4,A"12.6#/ft Hydril 521 C-110 Liner /\''''''-0HLB 4-1/2"RapidStage Ball Actuated Sleeve#8(2.761 ball/2.706 Seat)w/15ft 4-1/2"P-110 Pup 4- r 26# L80 BTC M s. (. , '\\* 7.\ 45 vr 1168/ft' i• ' .1168/ftt F.-110 Hydril 521 Boon Pin 17842 6146 'i , &Hydril 563 4i,1•:•\ i ' ii! 46 4,A"12.6#/ft Hydril 521 C-110 Liner Intermediate 2 Casing -,, Wif 0 C 6,077'TVD - - 0 CD‘ 0 (2\0 e 0 I ::: ..... .. a - 11M711B.T1M - E : 1 : _ .. _ .: . ....4 _ OH_C)_NO__ 0000_ W .:'ONCD, 6-1/8" Hole TD 444" Hydril 521 /C-110 Liner with Halliburton Ball Actuated @ 22,208 MD/ Sleeves, &Swell Packers 6,197'TVD ATTACHMENT K 06-09-2015 ODSN-22 Nuiqsut Production Well Completion FINAL No. LowerCompletion MD(ft) TVD(ft) Land Upper Halliburton Swell Packer#8(4-'/:"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on Completion 47 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 18114' 6,149 With 40,000 lbs VolantCentralizeronTopofSwellPacker Slack-Off 48 4-4"12.6#/ft Hydril 521C-110 Liner HLB 41/2"RapidStage Ball Actuated Sleeve#7(2.681 ball/2.628 Seat)w/15ft 41/2"P-110 Pup 4 iiiii 4.5' �iEE • I 49 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 18,402 6,155 Ins ,kid I • 4- 55°1 12.6#/ft Hydril 521 C-110 Liner 16"Conductor Halliburton Swell Packer#7(4''h"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on -';ig I 3 51 Volant Centralizer Pin End and Eft Pup 41/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 18,718 6,161 IllikAti "Th_ := I Packer Fluid mix: Volant Centralizer on Top of Swell Packer ni Inhibited Kill 52 4-r"1z.6#/ft Hydril 521C-110 Liner GLM#3 I weight Brine 53 HLB 4-1/2"RapidStage Ball Actuated Sleeve#6(2.603ball/2.552Seat)w/15ft41/2"P-110Pup4 19,048 6,164 With 2000'TVD 1/2"12.6#/ft P-110 Hydril 521 Box x Pin IDG CD V GL I diesel cao 54 4-''/:"12.6#/ft Hydril 521 C-110 Liner 55 Resman Internally Vented Carrier#2 ROS-1366/RWS-1393 w/15ft Pup BxP Top&Bottom 19,117 6,165 7,000 psi� s -4"12.6#/ft Hydril 521 C-110 Liner Max rated x I 11-3/4"60#L-80 Halliburton Swell Packer#6(4-'/:"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on I ' :::BTC Surface Casing 57 Volant Centralizer Pin End and 6ft Pup 41/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 19,358 6,169 l@ 6,548'MD/ Volant Centralizer on Top of Swell Packer 11101 13,211'TVD 58 4-i"12.6#/ft Hydril 521 C-110 Liner I ' 116, cemented to surface 59 HLB 41/2"RapidStage Ball Actuated Sleeve#5(2.527 ball/2.477 Seat)w/15ft 41/2"P-110 Pup 4 19,658 6,174 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 60 4-''/:"12.6#/ft Hydril 521 C-110 Liner I ' TOC Halliburton Swell Packer#5(4-''/:"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on Estimated 61 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 19,890 6,177 GLM#2 Volant Centralizer on Top of Swell Packer DGLV @ 500 ft 62 4-r"12.6#/ft Hydril 521 C-110 Liner Installed 0 GL I above 9-5/8" HLB 41/2"RapidStage Ball Actuated Sleeve#4(2.452 ball/2.404 Seat)w/15ft 41/2"P-110 Pup 4- 7,000 psi Aomk• I Shoe 63 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 20,113 6,180 Max rated Ur x I 64 4-%"12.6#/ft Hydril 521 C-110 Liner l 9 5/8"40#L 80 Halliburton Swell Packer#4(4-15"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on • Hydril 521 65 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 20,386 6,177 • Volant Centralizer on Top of Swell Packer l Intermediate 1 66 4-h"12.6#/ft Hydril 521 C-110 Liner Casing HLB 41/2"RapidStage Ball Actuated Sleeve#3(2.379 ba11/2.332 Seat)w/15ft 41/2"P-110 Pup 4 iii @ 11,717'MD/ 67 1/2"12.6#/ft P-110 Hydril 521Box xPin 20,801 6,177 4,915'TVD 68 4-'A"12.6#/ft Hydril 521 C-110 Liner 69 Resman Internally Vented Carrier#1 ROS-1365/RWS-1392 w/15ft Pup BxP Top&Bottom 20,994 6,178 GLM#1 M I 70 4-i"12.6#/ft Hydril 521 C-110 Liner DGLV I . ES Cementer Halliburton Swell Packer#3(4-%"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on Installed 0 Cl- Base Torok 71 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 21,073 6,178 7,000 psi® . Volant Centralizer on Top of Swell Packer Max rated : I 72 4-Y"12.6#/ft Hydril 521C-110 Liner l 7"Stage 2 TOC 73 HLB 41/2"RapidStage Ball Actuated Sleeve(2.307 ball/2.261 Seat)w/15ft 4-1/2"P-110 Pup 4 21,359 6,179 17 Estimated1/2"12.6#/ft P-110 Hydril 521 Box x Pin Sliding 74 4-'A"12.6#/ft Hydril 521 C-110 Liner Sleeve @ 500 ft above Halliburton Swell Packer#2(4-'/:"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on Closed Torok Sand 75 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 21,596 6,183 (Up to Open 19 OOO Package Volant Centralizer on Top of Swell Packer . 76 4-'/"12.6#/ft Hydril 521 C-110 Liner ® n HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.236 ball/2.192 Seat)w/15ft 4-1/2"P-110 Pup 4- 1/2" 21,929 6,191 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 7"Stage 1 TOC 78 4-'A"12.6#/ft Hydril 521 C-110 Liner Estimated Halliburton Swell Packer#1(4-34"Hydril 521)0D 5.85'-9 meter long oil activated with Slide on @ 500 ft above 79 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 22,114 6,195 Kuparuk Volant Centralizer on Top of Swell Packer 80 4-14"12.6#/ft Hydril 521 C-110 Liner 81 Pre-perforated Pup w/441"12.6#/ft Hydril 521 w/15ft 4-1/2"P-110 Pup BxP Top&Bottom 22,147 6,195 :0 `0 82 4-'/"12.6#/ft Hydril 521 C-110 Liner i_:_, \lib . 83 4-''/"Hydril 521 Eccentric Shoe with Float Collar 22,204 6,197 Bottom of Assembly 22,205 6,197 . ..a.'\ ' 7"26# L-80 BTC M' ,. &Hydril 563 ''''••4,.----„,c3 Intermediate 2 1' ``O O O O O O O O O O t{ 37 43 47 51 57 61 65 71 75 79 Casing ® a IN ' 55 ® It--- 69 M NI ® 83 @ 15,699'MD/ 2e ® _ _ _ _ _ _ _ _ _ 6,077'TVD I_I _ _ I_I _ ' 35 --_ 39 41 -- 45 - - 49 - 53 -- --O ® 00;.<ow 81' Hole TD 4-Y" Hydril 521 /C-110 Liner with Halliburton Ball Actuated @ 22,208 MD/ Sleeves, & Swell Packers 6,197'TVD ATTACHMENT K • • RECEIVED cAELus JAN 2 8 2016 Energy Alaska A0 r` ""-' 4E1 IIIMENOME, Caelus Natural Resources Alaska,LLC 3700 Centerpoint Drive,Anchorage,AK 99503 Tel:(907)277-2700 Fax:(907)343-2190 January 28, 2016 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: ODSN-22 Application for Sundry (#315-753) Caelus Natural Resources Alaska, LLC. (CNRA) hereby submits their response to requests for the ODSN-22 Sundry Application #315-753. Sincerely, clack alick Wells Superintendent 907 343-2185 office cc: ODSN-22 Well File ORtGINAL CUD CAELU S Er ,r Alaska ODSN-22 Sundry Application (#315-753) Response to Requests (1) Did Caelus provide Eni with a copy of the Notice of Operations? Yes, as shown in Attachment 1, ENI has been notified. (2) Please provide the final directional survey for the well in either ASCII table or Excel spreadsheet format. Attachment 2 shows that the electronic txt file was emailed 1/26/16. ,S� ` (3) Please provide a copy of the digital well log data (specifically gamma ray, SP (if available), caliper, resistivity, and porosity) recorded in the well. Attachment 3 references the signed log transmittal showing electronic logs were delivered. 9/3/2015. (4) Please provide a list of fault-cuts (MD, TVDSS and vertical displacement) that have been observed within the well and well branches within and near the AOR. A possible small displacement fault is interpreted at 16,300' MD, 6,128' TVDss in the Nuiqsut lateral section of N22. No losses or pressure anomalies were seen while drilling this interval or elsewhere along the lateral. Attachment 4 shows the 2,640 ft. (1/2 mile) AOR and a 350 ft. fracture half-length polygon (the average modeled half-length is 312 ft.) around the N22 Nuiqsut lateral. Attachment 5 shows the interpreted 8 ft. displacement of the fault at 16,300' MD in the lateral. (5) Discuss any occurrences of lost circulation in the well and well branches that occurred while drilling. While drilling the lateral there was a cumulative loss of 198 barrels of mud from the start of drilling at 15,699' MD to laying down the drilling assembly after reaching TD of 22,208' MD over 10 days. These losses were not related to any fault or specific lost circulation zone but were normal seepage losses associated with drilling of the Nuiqsut formation. (6) Please provide estimates of the horizontal distances from the ends of the projected fracture wings to any nearby faults. If any of these fracture wings are likely to intersect or even closely approach a fault, please discuss why that fault will not provide a pathway for injected fluids to migrate out of the pool Attachment 4 depicts the 2,640 ft. (1/2 mile) AOR lateral and a 350 ft. fracture half-length polygon (the average modeled half-length is 312 ft.) around the N22 Nuiqsut lateral. Attachment 5 shows a possible 8 ft. fault at 16,300' MD in the lateral. The well is oriented parallel to the minimum stress thus the fracture wings will be transverse or perpendicular to the wellbore. The 350 ft. transverse fracture wings may intersect two mapped north-south • faults near the wellpath: (1) along the lateral at 16,300' MD, as discussed previously, and (2) at approximately 18,500' MD into the lateral and 300 ft. beyond the estimated fracture wing. These faults are not considered possible pool containment leak points because: • To-date there is no evidence that hydraulic fracturing or sustained injection pressures above parting pressure in the Nuiqsut wells have developed pathways through the confining layers. The average bottomhole fracturing pressure of 4,700 psi is well below the sustained average injection well bottomhole pressure of 5,500 psi; additionally, the fracture treatment is of very short duration compared to the years of injection at 5,500 psi. These data are consistent with presence of the known thick, ubiquitous shale confining layers providing large seal capacities despite numerous mapped faults. • In the process of drilling 35 development wells (Kuparuk and Nuiqsut)and conducting 253 Nuiqsut hydraulic fracturing treatments, no anomalous reservoir pressure or fracture performance data have been observed that would indicate vertical communication between the Nuiqsut and adjacent stratigraphic intervals outside the pool. The data are consistent with three-dimensional modeling conducted by Barree & Associates in support of AIO 34 in 2007, their Nuiqsut fracturing program modeling from 2009 thru 2012, and consistent with the Schlumberger modeling submitted with the Application for Sundry Approval for this work. (7) Discuss the thickness and competence of the top seal for the Oooguruk-Nuiqsut Oil Pool within the AOR and how any faults within the AOR that cut this top seal will not affect the ability of that top seal to confine injected fluids to the pool. Attachment 6 shows that there is 50 ft. to 100 ft. of Kingak and Milluveach shale overlying the Nuiqsut in the N22 area acting as a top seal below the LCU. As discussed above, drilling and ongoing reservoir performance data indicate that these shales are competent vertical barriers. Hydraulic fracture modeling suggests a frac height of 75 ft. and that ten ft. of shale ' stops vertical fracture growth. Also, most faults that cut the Nuiqsut do not extend up to the LCU. However, the faults that do extend up to the LCU have shown no indications of lateral or vertical fluid/pressure transmissibility prior to and subsequent to development of the Nuiqust. (8) Discuss any mitigation plans Caelus may have should any of the fracture wings appear to intersect a fault during fracturing operations. During fracturing operations should the fracture half wing intersect a conductive fault the fluid leak-off, likely into the porous Nuiqsut sands along the fault, will be so rapid that the fractures will quickly close, i.e. the treatment will screen-out, thus limiting any further propagation; additionally, if a fault is encountered and proppant is placed in the confining zone, conductivity will be very limited or non-existent due to rapid embedment of the proppant into the confining shales, thus effectively closing off any potential pathways. To-date, if losses are incurred while drilling a Nuiqsut lateral, and they are believed to be associated with a fault in the well path, the interval will be either isolated with blank pipe and swell packers, opened to production but not fracture stimulated, or treated with a conservative fracture treatment; these mitigation measures are focused on reservoir ODSN-22 10-403 Sundry App. For Fracture Stimulation Response to Requests January 25,2016 Page 2 of 3 • • management of the Nuiqsut pool not because of concerns the faults will provide pathways through the confining zones. (9) Doesn't the Colville Delta No. 1 exploratory well (API 50-103-20038-00-00) fall within the AOR for ODSN-22? How about any other older exploratory or delineation wells? If so, please provide casing and cementing records, an analysis of well integrity and cement isolation, fault-cut information, and fracture-wing distances for this well (or these wells) too. The Colville Delta No. 1 (PTD #84-149), Colville Delta No. 1A (PTD #85-65) and the Sikumi — 1 (PTD #212-008) exploratory wells are outside the AOR for the N22 lateral (Attachment 4). A review of the individual AOGCC well construction and abandonment reports indicate the three wellbores have sufficient mechanical isolation of the Nuiqsut interval from other strata to prevent migration of fluids (Attachment 7). The fracture wing distances to these wells are in excess of 2,640' MD (Attachment 4) and no faults appear to cut the well paths at the Nuiqsut level. ODSN-22 10-403 Sundry App. For Fracture Stimulation Response to Requests January 25,2016 Page 3 of 3 • • From: Rachel Davis To: robert.orovince(@enioetroleum.corn Cc: Dale Hoffman Subject: FW:CNRA,LLC ODSN-22 Notice of Upcoming Operations Date: Monday,January 18,2016 10:06:00 AM From: Rachel Davis Sent: Tuesday, December 15, 2015 1:38 PM To: 'Dickenson, HAK(DNR)'; 'Kim Kruse(kim.kruse@alaska.gov)'; 'Nina Brudie (nina.brudie@alaska.gov)'; 'Saree Timmons(saree.timmons@alaska.gov)'; 'Temple Davidson (temple.david son @alaska.gov)' Subject: CNRA, LLC ODSN-22 Notice of Upcoming Operations RE: ODSN-22 AOGCC API 50-703-20708-00 Oooguruk Unit—Tracts 13 and 14 Lease Numbers ADL 355036 and ADL 355037 Pursuant to the requirements set forth by 20 AAC 25.283, I am hereby notifying you that Caelus Natural Resources Alaska, LLC plans to commence operations to perform a Fracture Stimulation on ODSN-22 beginning February 11, 2016. If you would like to review the complete AOGCC 10-403 Sundry Application for these operations, please contact me at the address below, or via a return email. Please also respond if you do not want to be included on the distribution of this notice for additional activities. Thanks, Ra.c k L Engineering Technician Caelus Energy Alaska LLC 3700 Centerpoint Drive, Suite 500 Anchorage,AK 99503 Direct: 907-343-2159 rachel.davisPcaelusenergy.com ATTACHMENT 1 • S From: Rachel Davis To: "steve.davies(aalaska.gov";"oatricia.bettisCa�alaska.gov";"guv.schwartz(@alaska.gov" cc: Jack Kralick Subject: FW:ODSN-22(PTD#215-054,Sundry Application #315-753)-Application to Hydraulically Fracture-Requests Date: Tuesday,January 26,2016 9:10:00 AM Attachments: ODSN-22 PSW2 DEFINITIVE.txt Morning, Please see attached the txt file of the definitive survey for ODSN-22 as requested in item 2 below. All other requested data will be submitted via duplicate hardcopy. Thanks, Ra41-a Da v-i y Engineering Technician Caelus Energy Alaska LLC 3700 Centerpoint Drive,Suite 500 Anchorage, AK 99503 Direct: 907-343-2159 rachel.davisPcaelusenergy.com From: Davies, Stephen F(DOA) [mailto:steve.davies(a�alaska.gov] Sent: Tuesday, December 29, 2015 1:59 PM To: Jack Kralick Cc: Bettis, Patricia K(DOA) Subject: ODSN-22 (PTD#215-054, Sundry Application #315-753) -Application to Hydraulically Fracture - Requests Jack, I'm reviewing Caelus's Sundry Application to hydraulically fracture ODSN-22, and I have a few questions and requests that I've consolidated into a single email. 1. Did Caelus provide Eni with a copy of the Notice of Operations? 2. Please provide the final directional survey for the well in either ASCII table or Excel spreadsheet format. 3. Please provide a copy of the digital well log data (specifically gamma ray, SP (if available), caliper, resistivity, and porosity) recorded in the well. 4. Please provide a list of fault-cuts(MD, TVDSS and vertical displacement) that have been observed within wells and well branches within and near the AOR. 5. Discuss any occurrences of lost circulation in those wells and well branches that occurred while drilling. 6. Please provide estimates of the horizontal distances from the ends of the projected fracture wings to any nearby faults. If any of these fracture wings are likely to intersect or even closely approach a fault, please discuss why that fault will not provide a pathway for injected fluids to migrate out of the pool. ATTACHMENT 2 21 505 4 26226 CE CAELU S LETTERF DA9TA LOGGED O TRANSMITTAL lq�zols Energy Alaska K.BENDER RECEIVED SEP 03lur AOGCC DATE: September 1, 2015 FROM: TO: Shannon Koh AOGCC Caelus Energy Alaska Attn: Meredith Guhl 3700 Centerpoint Dr., Suite 500 333 W. 7th Avenue, Suite 100 Anchorage, AK 99503 Anchorage, AK 99501 INFORMATION TRANSMITTED I Letter I I Maps CD-R MI Other—Logs El Agreement DETAIL QTY DESCRIPTION ODSN-22 (API: 50-703-20708-0000) 1CD Digital Graphic Logs. Digital Log Data, Definitive Survey 4 Logs DGR, PCG, EWR-Phase 4,ADR, ALD, CTN, Invert/Revert Presentation (1:600, 1:240) ROP, DGR, PCG, EWR-Phase 4,ADR,ALD, CTN, Horizontal Presentation (1:600, 1:240) Received by: ,AL k," (3._e4'i4 Date: Please sign 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.koh a@caelusenergy.corn ATTACHMENT 3 . / w w\ :''''''\\ ,n f ` �%c Q a.s 1 M m V z % . . 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O 4-- U L v L Lil co J �(ryry N 1110 • Attachment 7 Colville Delta No. 1 (PTD#84-149) Colville Delta No. 1A(PTD#85-65) Sikumi — 1 (PTD#212-008) AOGCC Well Construction and Abandonment Reports K ALASKA Q.,_ANDGAS CONSERVATION CO;>...IISSION CON tDEIAI WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1.Status of Well Classification of Service Well -7431 OIL❑ GAS 0 - SUSPENDED❑ ABANDONED IN SERVICE❑ /'ifA 2.Name of Operator 7.Permit Number Texaco Inca 84-149 3.Address 8.API Number 550 W. 7th Ave., #1320, Anchorage, Alaska 99501 50-103-20038 4.Location of well at surface 1029' North and 1599' East from the south- 9-Unit or Lease Name west corner of Section 17, T13N, R7E, U.M. Colville Delta At Top Producing Interval LOCATIONS 10.Well Number Vertical hole VERIFIED #1 At Total Depth Surf 1.10 11.Field and Pool B.H. fI Exploratory 5.Elevation in feet(indicate KB,OF,etc.) 6.Lease Designation and Serial No. Reference KB - 35.5' AMSL ADL 355037 12.Date Spudded 13.Date T.D.Reached 14.Date Comp.,Susp.or Abend. 15.Water Depth,if offshore 16.No.of Completions 1/29/85 3/14/85 4/7/85 -- feet MSL None 17.Total Depth(MD+TVD) 18.Plug Back Depth(MDI-TVD) 19.Directional Survey 20.Depth where SSSV set 21.Thickness of Permafrost 9457' (9457') 4730' (4730') YEs❑ Non -- feet MD 1550' 22.Type Electric or Other Logs Run Surface - 2500': GR-DIL-CAL-BHCS; 7624' - 25001: DIFL-BRCS-CAL-GR- SPEC-CNL-CDL-SWS-DIP; 9457' - 7450': DIFL-GR-SP-CAL-DT-CNL-FDC-SPEC-DIP-VSP. 23. CASING,LINER AND CEMENTING RECORD - SETTING DEPTH MD CASING SIZE WT.PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 3U" 234# B - L.Y. Surface 86' 36" 6 Yds. Cold-Set -- 20" 106.5# J-55 Surface 390' 26" 1800 Sx Permafrost 13-3/8" 72# N-80 Surface 2500' 171" 4300 Sx Permafrost 9-5/8" 47# N-80 Surface_ 7542' 121/2" 2200 Sx Class "G" 7" 29# N-80 7139' 9454' 81" 875 Sx "G" & 6% KCL 24.Perforations open to Production(MD+TVD of Top and Bottom and 25. TUBING RECORD terval,sizeandnumber) Test Intervals Only SIZE DEPTH SET(MD) PACKER SET(MD) 9380'-9218': 49' @ 4 HPF, DST #1 Squeezed None 8500'-8460': 40' @ 4 HPF, DST #2 Squeezed 8122'-8015': 58' @ 4 HPF, DST #3 Squeezed 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. - 7592'-7578': 14' @ 8 HPF, DST #4 Squeezed DEPTH INTERVAL IMO) AMOUNT&KIND OF MATERIAL USED 6366'-6328':38' -@ 12 HPF, DST #5'Squeezed ' 6226' - 6158' Frac with 25,200 Lbs. sand 6295'-6253': 42' @ 12 HPF, DST #6 Squeezed and 360 Bbls. Diesel. 6226'-6158':,68' @ 4 HPF, DST #7 Squeezed Squeezed All DST Intervals See Section #24. 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) 4/1/85 Nitrogen lift and flowing after frac. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/3/85 39 . TESTPERIOD♦ 443 335 -0- 9/64-32/64 +500 - 600 Flow Tubing Casing Pressure IfULATEDOIL-EBL GAS-MCF WATER-BBL QIL GRAVATY-API)corr) Press.321. . ' 0 . 24-HouRfinrb* 1075 391 -0- 25 28. CORE DATA Brief description of Ethology,porosity,fractures,apparent dips and presence of oil,gas or water.Submit core chips. Core #1: 7880' - 7940'',. Sadlerochit Sandstone, Siltstone & Shale, Tight, No Oil. Core #2: 8718' - 8756', Echooka Sandstone, Shale andChertyCherty Limestone. EE^'s"*T rr A'B'3 Ir'', ;. ' ', 3..1:T L.1985 ggi ,lUNi be _ s a efds Culls Commission 1.l nldtka 511 A A11G11u1E a Form 10-407 /. �s1 t t ubmit in duplicate Her.7-1-80 CONTINUED ON REVERSE SIDE CONF!DF TIA} C }NFJDENTIAL 4r 29. - .. .30. . GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested,pressure data,all fluids recovered and gravity, MEAS.DEPTH TRUE VERT.DEPTH GOR,and time of each phase. West Sak 4636' -4600' SS Kingak 6170' -6135' SS See History or Section 27 Sag River 7580' -7545' SS Ivishak 7902' -7867' SS Lisburne 8752' ! -8717' SS Endicott 9227' -9122' SS 31.LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 6,p�- k_ Title District Manager pate 6/13/85 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. Item 1: Classification of Service Wells: Gas injection,water injection,steam injection,air injection,salt water disposal,water supply for injection,observation,injection for in-situ combustion. Item 5: Indicate which elevation is used as reference(where not otherwise shown)for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 16,and in item 24 show the producing intervals for only the interval reported in item 27.Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval. Item 21:Indicate whetherfrom round level(G L)or other elevation(DF,KB,etc.). FI1T1t tal records for this well should show the details of any multiple stage cement- hgT•• a I r�{ h ``rr nting tool. Jt i Wlh f raan: Flowing, Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water In- t-1 Other-explain. Item 28:If no cores taken,indicate"none". CONElDENTIM. • • • -1- CONr5DFNTIAI COLVILLE DELTA WELL #1 WELL HISTORY oA/„ Al DEPTH (FT) I /V_' 74 DAY MUD WEIGHT (PPG) ACTIVITY 1-29-85 Spudded at 10:00 P.M., Yukon standard time. 1-30-85 190 Drilled 26" hole to 190'. Kelly 8.9 bushing to ground measurement: 31.55' 1-31-85 390 Drilled, surveyed 26" hole to 390'. Ran 9.3 10 jts., 20", 106.5#, J-55 buttress casing. 2-1-85 390 Cemented 20" with 1800 sx, 14.9 ppg 9.3 permafrost cement; observed returns. Began welding 20" casing head. 2-2-85 390 Finished welding 20" casing head; began 9.3 installation of diverter system. 2-3-85 783 Finished installation of diverter system; -)—rEIVED 9,3 tested diverter system; test was witnessed, approved by representative of JUN 14 1985 Alaskan Oil and Gas Conservation Commission (AOGCC). Performed pressure mask, , ., cons. Commission integrity leak off test (PILOT) to vAncorage 12.5 ppg equivalent mud weight at depth of 410'. 2-4-85 1,355 Drilled 17-1/2" hole to 1,208'. 9.2 Surveyed, tripped for a bit change; drilled ahead. 2-5-85 1,400 Drilled 17-1/2" hole to 1,360'; �gq encountered boulder zone in permafrost. rMif? Lr-ITA 1 POH, leaving one cone in hole. RIH 14" yi GG6 ..',. ‘.1 R`}' magnet - no recovery. RIH 17-1/2" bit, "o M1" -,.11-. ',. `z1 drilled on junk, POH. RIH 17-1/2" mill, �({^ljE ), •' ` & milled on lost cone. y9&uk �i X 2-6-85 2,510 POH mill. RIH 17-1/2" bit, drill to 9.2 1,979'. Tripped for bit change. Drilled to 2,510'; conditioned hole for logging. 2-7-85 2,510 Ran GR-DIL-CAL and GR-BHCS. Conditioned 9.2 hole, began running 13-3/8" casing. 11111 1111 -2- CONFIDENT. DEPTH (FT) DAY MUD WEIGHT (PPG) ACTIVITY 2-8-85 2,510 Ran 13-3/8", 72#, N-80 buttress casing 9.3 with shoe at 2,500'. Cemented casing with 4,300 sx. permafrost cement; observed returns. Set slips, began removing 20" BOPE. 2-9-85 2,510 Removed 20" BOPE. Installed casing head, 9.3 tested to 1,870 psig. Installed 5,000 psig ROPE. 2-10-85 2,510 Nippled up 13-5/8" x 5,000 psig BOPE; 9.3 began testing. 2-11-85 2,737 Tested ROPE to 5,000 psig, Hydril to 9.1 2,500 psig; tests witnessed and approved by representative of AOGCC. RIH 12-1/4" r? r .A. bit, tagged cement at 2,446'. Tested 13-3/8" casing to 1,800 psig. Drilled to t! 2,515'; ran PILOT to 13.4 ppg equivalent mud weight; drilled ahead. 1:dot Drilled, surveyed to 3,447'. Tripped for 9.4 a bit change; changed swivel packing; drilled ahead. 2-13-85 4,358 Drilled to 4,358'; pulled up to shoe. 9.4 Repaired mud pumps and swivel; 9-5/8" casing arrived at well site. 2-14-85 5,316 Completed mud pump repair. RIH 12-1/4" 9.8 bit, drilled to 5,068'; tripped for a bit change; drilled ahead. 2-15-85 5,814 Drilled to 5,472', pulled up to shoe. 10.0 Packed swivel; RIH, drilled to 5,814'. Circulated, surveyed, POH to shoe; waited for arrival of new Kelly hose. 2-16-85 6,311 Installed Kelly hose, repaired mud pumps. 10.1 RIH, drilled to 6,311'; surveyed, PON. 2-17-85 6,833 Tripped for bit change, drilled 12-1/4" 10.2 hole to 6,833', surveyed. 1111 -3- CONFIDENTIAt DEPTH (FT) DAY MUD WEIGHT (PPG) ACTIVITY 2-18-85 7,025 Drilled to 6,856'. POH; tested HOPE, 10.3 manifold. RIH 12-1/4" bit, drilled ahead. 2-19-85 7,243 Drilled 12-1/4" hole to 7,214'; 10.2 circulated, surveyed. Tripped for bit change, cut drilling line, drilled ahead. 2-20-85 7,493 Drilled to 7,493'; 15 stand wiper trip. 10.3 Circulated, measured out for logs. 2-21-85 7,624 Finished measuring out of hole. Ran 10.4 DIFL, BHCS-CAL-GR from 7,158'-2,500'. RIH, cleaned out bridge at 7,150'; reamed, washed to bottom. Drilled 12-1/4" hole to 7,624'; conditioned hole for additional logs. 2-22-85 7,624 Finished conditioning hole, including 10.4 10 stand wiper trip. Ran DIFL; began running spectra log-CNL-CDL. 2-23-85 7,624 Continued logging: Spectralog-CNL-CDL, 10.4 DIL, Dipmeter. Repaired dipmeter, replaced line head; reran dipmeter. 2-24-85 7,624 Shot sidewall cores: total of 10.4 100 sidewall samples taken in 2 runs, lost 1 sample. RIM to 7,608', conditioned mud, shut down pump. Hole filled at rate of 18' in 10 min; cleaned out fill; circulated and made wiper trip. 2-25-85 7,624 Completed 15 stand wiper trip. Cleaned 10.4 out 18' of fill. Circulated viscous sweep and spotted soltex/gel pill. Surveyed, POH. Ran 190 jts., 9-5/8", N-80/S-95 combination string buttress r3 rP ` a 3� at7419 casing Circulated with shoe at 542',startedapipellar ar `; '" cementation. 9 8 1111 f -4- CONF DEN l IAt DEPTH (FT) DAY MUD WEIGHT (PPG) ACTIVITY 2-26-85 7,624 Cemented 9-5/8" casing with 2,200 sx., 10.0 15.8 ppg, Class "G" slurry having 1% CFR-2, 0.1% HR-7. Bumped plug, set slips with 300,000 lbs. weight. Installed, tested casing spool and ROPE. AOGCC waived right to witness tests. Began RIH. Pumped 500 bbls waste mud down 13-3/8" x 9-5/8" annulus at 400 psig, 5 bpm. 2-27-85 2,,7g3 ¢ RIH 8-1/2" bit to 2,500', cut drilling ;rad�A�'y 9' a,' b s line. Tagged cement at 7,413', drilled oa 7 '+ '.�� ' '„ out float collar, shoe, cement to 7,553'. 1-t1Cleaned out fill to 7,624'. Drilled to ary ) i! 7,789', pulled up to 9-5/8" shoe and a repacked swivel. 2-28-85 7,895 Drilled, surveyed 8-1/2" hole to 7,880'. 9.9 Tripped for core barrel; cored to 7,895'. 3-1-85 7,955 Continued coring to 7,940', FOB, 9.9 recovered 60' core. Checked ROPE, RIH 8-1/2" bit, drilled ahead. 3-2-85 8,436 Continued drilling 8-1/2" hole. 9.9 3-3-85 8,718 Drilled to 8,718', began POH. 10.0 3-4-85 8,756 Drilled 8-1/2" hole to 8,756'. Tripped 10.0 for a bit change. 3-5-85 9,000 Continued drilling 8-1/2" hole. 10.0 3-6-85 9,269 Continued drilling 8-1/2" hole. 9.9 3-7-85 9,457 TD Drilled to 9,457'; circulated, made wiper 10.0 trip to 9-5/8" shoe. Conditioned hole for logs, surveyed, began POB. 3-8-85 9,457 TD POH. Tested ROPE. Ran 10.0 DIFL-GR-SP-CAL-DT. Began log run #2. • 411 -5- CONFH)ENTW DEPTH (FT) DAY MUD WEIGHT (PPG) ACTIVITY 3-9-85 9,457 TD Finished log run #2: CAL-CNL-FDC- 10.0 spectralog. Ran DIL-GR, dipmeter, velocity log from 9,450'-7,450'. 3-10-85 9,457 TD Completed running velocity log. Shot 9.9 sidewall cores. Cut drilling line at 9-5/8" shoe. Conditioned hole for additional logging by another logging company. Began POH. 3-11-85 9,457 TD Ran DIL-BHC, Sonic-GR, LDT, CNL-GR in 9.9 2 runs by additional logging company. RIH to 9,457', conditioned hole for liner. Picked up 7" liner, associated equipment. 3-12-85 9,457 TD Ran 62 jts., 7", 29#, N-80 buttress liner 9.9 with top at 7,139', shoe at 9,454', float collar at 9,377', landing collar at 9,341'. Circulated bottoms up. Cemented T1s 3 liner with 875 sx., 15.8 ppg Class G slurry having 1% CFR-2, 3% KC1, 0.3% HA-22, 0.4% HR-5. Bumped plug, lost returns at liner hanger. POH, RIB with 8-1/2" bit, casing scraper to TOL - found no cement. Circulated bottoms up, recovered cement-cut mud, green cement. Prepared to POB. 3-13-85 9,457 TD POH. Laid down DC's, HWDP, Jars, excess 9.9 DP. Left 5,000' DP in derrick. Installed 3-1/2" rams, test BOPE. PU 4-3/4" DC's, 3-1/2" DP. 3-14-85 9,457 TD RIH 3-1/2" DP, cut drilling line. Tagged 9.9 cement at 9,316'; drilled out cement, landing collar, float collar to 9,390'. Circulated; tested liner lap to 3,000 psig. POH; RIH and ran CBL-GR from 9,388'-2,500'. DRILLING OPERATIONS COMPLETED. NML pro/x5 STATE OF ALASKA r~VA,N`g n,rrt ALASKA•AND GAS CONSERVATION C. AMISSION ° ,''"€• SUNDRY NOTICES AND REPOIkTS O/N WELLS `44 /1- DRILLING WELL d1X COMPL*yFXD WE(k,.., 7/'"FD OTHER❑ 2.Name Of Operator O,/ 4478 ?d Permit No. Texaco Inc. q�c�%pie 84-149/85-65 3.Address hiy vo,eit API Number 550 W. 7th Ave., #1320, Anchorage, Alaska 99501 *v6,103-20038 4.Location of Well 9.Unit or Lease Name 1029' North and 1599' East from the SW corner of Section 17, Colville Delta T13N, R7E, U.M. Straight hole. 10.Wen Number lA (R/D #1) BLH: 748' North and 1181' East of Southwest corner of 11.Field and Pool Section 17, T13N, R7E, U.M. Exploratory 5.Elevation in feet(indicate KB,OF,etc.) 6.Lease Designation and Serial No. KB is 35.5' above sea level ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate 0 Alter Casing 0 Perforations 0 Altering Casing ❑ Stimulate 0 Abandon 0 Stimulation 0 Abandonment K1 Repair Well ❑ Change Plans 0 Repairs Made ❑ Other 0 Pull Tubing ❑ Other ❑ Pulling Tubing 0 (Note:Report multiple completions on Form 10407 with a submitted Form 10407 far each completion./ 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-170). Plug #1: 200 cu. ft. of class G with 1% CFR-2 and 0.3% Halad 22-A, balanced open-hole plug; displaced thru OEDP at 6540'. CIP at 1:10 PM 4-23-85. Plug #2: 400 cu. ft. of class G with 2% CaCl2 and 0.75% CFR-2, balanced plug across 9-5/8" shoe; displaced thru OEDP at 4910'. CIP at 3:30 PM 4-23-85. Located top of plug at 4272' (witness by Harold Hawkins, AOGCC). Plug #3: 57 cu. ft. Permafrost "C" balanced, cased hole plug; displaced thru OEDP at 2550'. CIP at 5:45 AM 4-23-85 (witnessed by Harold Hawkins, AOGCC). Plug #4: 350 cu. ft. Permafrost "C" downsqueezed thru 9-5/8" X 13-3/8" casing annulus and displaced to 1500' with mud. CIP 5:15 PM 4-24-85. Plug #5: 93 cu. ft. Permafrost "C" circulated to surface in 9-5/8" X 13-3/8" annulus and 9-5/8" casing thru perforations in 9-5/8" casing at 140' MD (approx. 105' below surface):, After final surface cement plug in place welded steel plate over casing stubs. Bead- welded the following on cover plate (see pictures attached): Texaco ADL 355037 Colville Delta #1 KWK:bjs 1029' N & 1599' E of SW corner of Sec. 17, T13N, R7E, UM 14.I hereby certify that the foregoing is tru nand correct to the best of my knowledge. signedk.J,J 5� `s-1`�a.a { /M� Title District Manager Date 5/20/85 WW1 The space shoes of Approval, Commission use r q,,'` n a,ya I Conditions of Approval,it any' 1 lr. °1 I d h D h 1, i}p)). 4 1 _ d Approved by COMMISSIONER the Commission Date__ ___ _ Form 10403 Submit"Intentions in Triplicate 't ee } Rev.7-180 1fF#':(k"�y;�� `1"4 v and"Subsequent Reports"in Duplicate i2q.3n.C111 VE,:rm - r6.Pe.V 0 c.. mt. STU? 10 em MRS" s s E 1:> . • - .• • 14 . • • 41/4.1.v. . . .-• „- •• , 4 -- • ; /: • •• • • • • • • . . r • r r_ r r - • t T- - • • 0 k it•E _ , STATE OF ALASKA ' ALASOIL AND GAS CONSERVATION r „V1MISSION SUNDRY NOTICES AND REPORtS ON WELLS v 1. DRILLING WELL 0P COMPLETED WELL 0 (//� OTHER 0 q 2.Name of Operator 7.Permit TM./�/ a !/�%J'`/ Texaco Inc. 84-149"f /1j/_ I 3.Address 8.API Number v /1/� 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 50-103-20038 /Y/ 4.Location of Well 9.Unit or Lease Name 1029' North and.1599' East from Southwest corner Colville Delta Section 17, T.13N, R.7E, U.M. 10.Wel/Number -1-A (VD-1M i Bottom Hole Location: 707' North and 1011' East from 11.Field and Pool Southwest corner Section 17. T.13N, R.7F, U M Exploratory 5.Elevation in feet(indicate KB,OF,etc.) 6.Lease Designation and Serial No. KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ❑ Alter Casing 1t[❑[..vv Perforations ❑ Altering Casing 0 Stimulate 0 Abandon L`f( Stimulation 0 Abandonment 0 Repair Well ❑ Change Plans 0 Repairs Made 0 Other 0 Pull Tubing ❑ Other ❑ Pulling Tubing ❑ .h (Note:Report multiple completions on Form 10407 with a submitted Form 10407 for each completion.) ti/rik A 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimate ate of(ta y proposed work,for Abandonment see 20 AAC 25.105-1701. '!¢w) 1p4) Present Conditions: MTD 6640' TVD 6437' °f, s Casing: 9-5/8" window at 4730' (Est. top of cement at 3300'). 4 40 *rots 13-3/8", 72#, N-80, Buttress, to 2500', cement to surface. 424'40 . Proposed Operations: !w 1. Complete open hole drill stem test of interval from 6545' to 6288'. 2. Plug and abandon as follows: Plug #1, test interval; open hole, balanced plug through drill pipe from ±6545' to• ±6100' using 175 sacks Class "G", 1% CFR-2 and .3% Halad 22-A. Plug #2, 9-5/8" shoe; open hole & casing balanced through drill pipe from 4900' to 4630', using 350 sacks Class "G" plus .75% CFR-2 and 2% CaC12. AOGCC representative to witness top of plug. Plug #3, inside 9-5/8" casing from 2550' to 2450'; balanced plug through drill pipe using 50 sacks Permafrost "C". Plug #4, 13-3/8" X 9-5/8" annulus; downsqueeze 13-3/8" X 9-5/8" annulus with 375 sacks Permafrost C . Displace with mud to 1500'. Plug #5, surface plug; circulate 75 sacks Permafrost "C" through four perforations to be jetted in 9-5/8" casing at 100'. This will fill 9-5/8"and 13-3/8" casing from 100' to surface. 3. Cut off 13-3/8" and 9-5/8" casing at 4' below original ground level (7' below pad level) and weld steel plate over 13-3/8" & 9-5/8" casing stubs. Steel plate will be labeled "Texaco Colville Delta #1, Sec. 17, T13N, R7E, UM." Cement abandonment procedure verbally approved by Harold Hedlund to Karl KolthnffAj22/85. 14.I hereby certify that the foregoing is true and correct to the best of my knowledge. KWK:bjs Signed ��.. Tie District Manager Date .4/23/85 The space below for Commission use ,, ,7.-1,r,„1- -rR 1 Conditions of Approval,if any: P ^ Approved Copy r, I etvrned L. IRICIAAE SICIIEB µ.�h3/85 =f 9yy / � BY I.RRRIE C. SIM By Order of IY e E /7g+ ya "�" 1.', Approved by COMMISSIONER the Commission Date -112 airs.? 0, Form 10-403 Submit"Intentions"in Triplicate Rev.7-1-80 and"Subsequent Reports"in Duplicate ® (cp —.75'' 7) -7 f T- ''''--,1) rf� .”ewr7 l rte �. E I yam Texaco USA 3350 Wilshire Boulevartl 2 2 PO Box 37,56 APR 198 Los Angelos CA 90051 A'...,- i! !;. Gas Cons. Commission T R A N S M I T T A 7, Anchorage DATE: March 27, 1985 TO: STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 't, I= j� ---` 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA ''.,'` "r'. t/y 3(rf .UDJECT TEXACO „U _S The following information is enclosed for your file. leP ase ' acknowledge and return the duplicate copy. 1- BL AND1-.SEPIA j ,� OG TYPE RUN RUN 2 RUN 3 COMPOSITE "/ 5" Prolog 7 .2-24-85 7 -- ,5700-7632 .5700-7632 / 5" Prolog / 0- 2 2- d- -/ 76 5700-7632 f 5" Pro g 3-9-85 / j 76Qo 9444 Di og 5" 2-23=85 3-7-85 / 2_498,7,624 75V-9457 5" 4 Arm Caliperlog 2-6-85 238-2510 / Dielectric / 2-22-85 3- 85yes 4578-7624 ;7542-9157 5"- Speetralog / 2-22-85 3-7-85 yes 2498-7,6.24 7542-9457 5"- DIF4 2-6-85 2-21-85 3-7-85 Y 318-2510 2498-7624 7542-9457 5"- DHC 2-6-85 2-21-85 3-7-85 yes 318-251. 2498-7624 7542-• 57 5"- CDL 2-22-85 3- 85 yes 2498-7624 ,42-9451 5'- e L 2-22-85 3-7-85 ycrr R a1' .TP i q■ 2498-7624 7447-9457 1 ' .�ly ;i 2 w ! _ �L Y ®�v • • .—'---- _--'— --Texaco USA 3350 WJshrtv Oovlvvm0 Dow V�tos Angelos ---- • CA 00051 � APR 22198S t115 ea$Cons. Commisston DATE: March 27, 1985 "JiCno;age TO: STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA SUBJECT: TEXACO, U.S.A. COLVILLE DELTA #1 /- The following information is enclosed for your file. lease acknowledge and return the duplicate Copy. 1- BL AND 1- SEPIA • • LOG TYPE RUN 1 RUN 2 RUN 3 COMPOSITE 2 I iper 2-G-8`' 230-2,10 DIF—'2" 2-G-85 2-21-85 . 3-7-85 318-2510 2498-7 1 75112-9457 1C;2„ u� 3 2-6-85 2 - 85 3-7-85 yc: , 318-2510 198-76211 7542-91.17 2"-Computed 4-Arm Dipl-.g �o.-� 4"-Computed 4-Arm Di•- og - e krico L,b��, T — c—c—R),/ , � '-oAN7—D—obi—aaa-9soo -��17) 77 7Y 7 it. D. DIE'! fj ' .. t' (2LOGICAI. MANAGER i ,,, .:,f:"t'lON: IdILDCA'i' COORDINATOR Rask; :ir.clo:;ures • !i_CI:IV1?D BY DATE '• � / • STATE OF ALASKA r . ',7r- a .1 J �1 S5 ALASKA A_AND GAS CONSERVATION C(�'MISSION � V" MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1.Drilling well X1( Workover operation 0 GO 2.Name of operator 7.Permit No. � Texaco Inc. 84-149 ///��� (J 3.Address 0/9/ 84-149 8.API Number 550 W. 7th Ave., #1320, Anchorage, Alaska 99501 (7 50-103-20038 G7 4.Location of Well /' Lease Name sy/ at surface ]� Colville Delta 1029' North and 1599' East from the southwest corner 10.Well No. of Section 17, T13N, R7E, U.M. Straight hole #1 11.Field and Pool Exploratory 5.Elevation in feet(indicate KB,DF,etc.) 6.Lease Designation and Serial No. KB is 35.5' above sea level ADL 355037 RECEIVED For the Month of March ,19 85 APR 1 6 1985 Alaska OB& Gas Cons. Commission 12.Depth at end of month,footage drilled,fishing jobs,directional drilling problems,spud date,remarks Anchorage • Continued drilling 82" open hole from 7940' to 9457' (1517' drilled during the month of March). TD reached on 3/7/85. Ran logs, set and cemented 7" casing and commenced cased hole testing operations. 13.Casing or liner run and quantities of cement,results of pressure tests 7", 29#, N-80, Buttress, liner from 7139' to 9454' (2315' or 62 Jts.): Cemented with. 875 sacks of Class G mixed with 1% CFR-2, 3% KCL, 0.3% Haled 22A and 0.4% HR-5. Pressure tested liner lap and liner to 3,000 PSI, OK. 14.Coring resume and brief description Core #2: 8718' to 8756, recovered 32' out of 38' cut; Echooka sandstone, shale and cherty limestone. 15.Logs run and depth where run 83t" OH logs from 9457' to 7542': Dresser Atlas DIFL/SP/GR/CAL/DT-BHC/Acoustilog- Spectralog-Dielectric/GR-Diplog-Corgun-VSP. Schlumberger DIL/SFL/BHCS/GR-LDT/CNL/GR. 7"/9-5/8" cased hole CBL: 9388' to 2500'. 16.DST data,perforating data,shows of H=S,miscellaneous data DST#1: 9380' to 9218' (49' at 4 HPF in four intervals). No recovery. Squeezed interval with 75 sacks cement. DST #2: 8460' to 8500' (40' at 4 HPF in two intervals). Recovered 2915 Bbls. mud and water. Squeezed interval with 75 sacks cement. �lgK:bis (See Attached f I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED�I °.. �� TITLE District Manager DATE 4/lfj/85 NOTE—Report on this form is require.e or each calendar month,regardless of the status of operations,and must be filed ill duihlicAi with the Alaska a Oil and Gas Conservation Commission by the 15th of the succeeding month,unless otherwise directed. Form 10-404 {F ',}; `.f;'_ittye .Spbmit in duplicate • • • CONFIDENTIAL Alaska Oil and Gas Conservation Commission Monthly Report of Drilling and Workover Operations, Colville Delta #1, March, 1985 #16. (Continued) DST.#3: 8015' to 8122' (58' at 4 HPF in five intervals). Lifted with nitrogen, recovered 70 Bbls. mud and water, small amount of gas and trace oil. Squeezed interval with 75 sacks cement. DST #4 and #4A: 7592' to 7578' (14' shot twice at 4 HPF). Tested twice, recovered total of ±31/2 Bbls. rat hole fluid. Squeezed with 175 sacks cement. DST #5 and #5A: 6328' to 6366' (38' at 12 HPF). Recovered 17 Bbls. crude then acidized and recovered an additional 761i Bbls. fluid (25 Bbls. crude). DST #6 and #6A: 6253' to 6295' (42' at 12 HPF). Recovered 10 Bbls, fluid (8 Bbls. crude) with N2 lift, then acidized and recovered 108 Bbls. fluid (40 Bbls. crude). Testing continuing at end of month. RECEIVED APR 1 61985 Alaska Oil & vas Cons.Commission Anchorage /j 7 t3 4 STATE OF ALASKA ALASKA IL GAS CONSERVATION C AMISSION SUNDRY NOTICES AND REPORTS ON WELLS a`e' 1. DRILLING WELL IQ COMPLETED WELL 0 OTHER 0 t ✓ 2.Name of Operator 7.Permit No. �/ , Texaco Inc. 84-149 l/`7/ 3.Address 8.API Number I 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 so-103-20038 q/ pill 4.Location of Well 9.Unit or Lease Name /t *14/ 1029' North and 1599' East from Southwest corner Colville Delta Section 17, T.13N, R.7E, U.M. Straight hole 10.Well Number #1 11.Field and Pool Exploratory 5 Elevation in feet(indicate KB,13F,etc.) a. Dgand Serial No. K 35 MSL Lease 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: I (Submit in Triplicate) (Submit in Duplicate) Perforate 0 Alter Casing 0 Perforations 0 Altering Casing 0 Stimulate 0 Abandon 0 Stimulation 0 bando t. �l Repair Well 0 Change Plans ❑ Repairs Made ❑ OtheTara�l ons ❑ Pull Tubing ❑ Other ❑ Pulling Tubing 0 (Note:Report multiple completions on Form 10.407 with a submitted Form 10407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-1701. Present Conditions: TD 9457', PB TD 5942' (wireline retainer with 50' cement cap) Casing: 20" conductor 390', cemented to surface. 13-3/8", 72#, N-80, Buttress, surface to 2500', cemented to surface. 9-5/8", 47#, N-80, Buttress, surface to 7542', cemented w/2200 Sx of Class G. 7", 29#, N-80, Buttress, liner from 7139' to 9454', cemented w/875 Sx of Class G mixed with 1% CFR-2, 3% KCL, .3% Halad 22A and .4% HR-5. I1 Completed Operations: Set retainer at 5992', squeezed 150 sacks cement, Class G, with I 1% CFR-2 and 0.4% HR-7 through retainer. Picked up 90' above retainer allowing approximately 25 sacks of cement to fall on top of retainer prior to reversing.. This abandonment of Kuparuk perforation witnessed by Ed Sipple, AOGCC. RECEIVED R 0 Alaska 0111°:::15 Cons.1985 Commission Anchorage 14�JS`ereby/�certify that thefore is true and correct to the best of my knowledge. Kgned 65 . • '=Y Title District Manager Date 4/8/85 The space below for Commission use Conditions of Approval,if any: By Order of ..„•.p Approved by COMMISSIONER the Commission. Date____._ Form 10403 Submit"Intentions"in Triplicate Rev.7-1-80 •. and"Subsequent Reports'in Duplicate 1 MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: C. V. CYa�rton DATE: April 9, 1985 Chair�,t7,_A-' FILE NO: D.EWS.27 THRU: Lonnie C. Smith 7,,,cy Commissioner TELEPHONE NO: FROM. Edgar W. Sipple, Jr,� _ SUBJECT: Witness Petroleum Inspecto , Ibrdsztettelsen Plug on Texaco's Colville Delta #1, Permit No. 84-149, Sec. 17, T13N,R7E,UM, Brinkerhof Rig 84. Saturday, April 6, 1985: I traveled this date from ARCO's Hemi Springs #3, (subject of another report) to Texaco's Colville Delta #1 to witness a hydrocarbon isolation plug in the 9 5/89" casing. The E-Z Drill retainer was set at a depth of 5,992' above the perfs at 6,158' to 6,226'. There was 175 sacks of "G" cement with 1% CFR's and 4/10 of 1% of RH7, squeezed below the retainer. The pressure build up to 1,400 pounds, when the squeeze was finished there was 1,000 pounds trapped under the retainer. There was approximately 61 feet of cement on top of the retainer. There was approximately 1/2 bbl of cement returns when it was reversed out. Attached to this report is drawings of the perfs and retainers set in this hole. I witnessed the retainer set at 5,992 and squeezed with 175 sacks of cement into the perfs at 6,158' to 6,226'. Attachment ( -p, A R e"" 1 " Co i ui(k. ULI(4 d4, '— Scc ,7 r'3& A.- cc" Bnw1C�(,AFF I L gc( Ar44,rNn 84 —Jiff §s Hyffa)1, 6/ .1.1CE"11wi li �i A- f Acz M 3-112.nN ,7 or �:..�rP,04,N- Lop 75 Sks £Z i i t t /7r - ( 1 5-3 4,17' 4 6144 kcio 7.1 22 ?e iL7. f l�„f x_6244 - EL Dritl Cs253 yz (+295 (03/0 — £ Z Deft( GSz� 33' ‘,34/}��T�q A F 5 70 Z BRn( TATE OF ALASKA ALASKA.SIL GAS CONSERVATION CL..vIMISSION a . SUNDRY NOTICES AND REPORTS ON WELLS I. DRILLING WELL IO COMPLETED WELL 0 O 1§K m 2.Name of Operator 7.Permit No. 6%A, Texaco Inc. 84-149 (/ 3.Address 8.API Number 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 so-103-20038 4.Location of Well 9.Unit or Lease Name 1029' North and 1599' East from Southwest corner Colville Delta Section 17, T.13N, R.7E, U.M. Straight hole 10.Well Number #1 11.Field and Pool Exploratory 5.Elevation in feet(indicate KB,DF,etc.) 6.Lease Designation and Serial No. KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate 0 Alter Casing 0 Perforations 0 Altering Casing 0 Stimulate ❑ Abandon M Stimulation ❑ Abandonment ❑ Repair Well 0 Change Plant 0 Repairs Made 0 Other ❑ Pull Tubing 0 Other 0 Pulling Tubing ❑ (Note:Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-1701. Present Conditions: TD 9457'. PB TD 6244' (wireline bridge plug) Open perforations 6158' - 6226'. Well flowing oil and test fluids. Casing: 20" conductor 390', cemented to surface. 13-3/8", 72#, N-80, Buttress, surface to 2500', cemented to surface. 9-5/8", 47#, N-80, Buttress, surface to 7542', cemented w/2200 Sx of Class G. 7", 29#, N-80, Buttress, liner from 7139' to 9454', cemented w/875 Sx of Class G mixed with 1% CFR-2, 3% KCL, .3% Halad 22A and .4% HR-5 Proposed Operations: Set retainer at 6000' (158' above top perforations), squeeze through retainer with 175 sacks cement, class G, with 1% CFR-2 and 0.4% HR-7, to abandon Kuparuk zone and prepare to redrill above 4750'. RECEIVED APR 4 1915 Alaska Un 8 Gas Cons. Commission Anchorage 14.I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .111 zNAi a Title District Manager Date y F The space below for Commission use II Conditions of Approval,if an r h v +.pproyed Copy C. Returned A AOGCC representative will witnesss the cement plug. 'F-Yom--' •� n^7 ;1!VNAI Sie!E® -----+ ..mow RT I "s'IE E. SMITA By Order of (� Lliss.sie4 u Z Approved by COMMISSIONER the Commission Date ` _ _ 3__ 1 Forte 10403 Submit"Intentions'in Triplicate Rev 7-tA0 and'Subseeuent Reports"in Duplicate e STATE OF ALASKA ALASKA vIOD GAS CONSERVATION CUIvIMISSION Ot SUNDRY NOTICES AND REPORTS ON WELLS �1 I. DRILLING WELL 03 COMPLETED WELL❑ 0,9 OTHER❑ r/ 2.Name of Operator 7.Permit No.�/j /r� Texaco Inc. 84-149 717 3.Address 8.API Number IP 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 50-103-20038 4.Location of Well 9.Unit or Lease Name 1029' North and 1599' East from Southwest corner Colville Delta Section 17. T.13N, R.7E, U.M. Straight hole 10.Well Number #1 11.Field and Pool Exploratory 5.Elevation in feet(indicate KB,DF,etc.) 6.Lease Designation and Serial No. KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate 0 Alter Casing ❑ Perforations 0 Altering Casing 0 Stimulate 0 Abandon ❑ Stimulation 0 Abandonment 0 Repair Well ❑ Change Plans ❑ Repairs Made 0 Other Pull Tubing 0 Other ❑ Pulling Tubing 0 Plug Back & (Note:Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.) Perforations 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-170). Present Conditions: TD=9457', PB TD=7024' (Retainer above perforations). Casing: 20" conductor 390', cemented to surface. 13-3/8", 72#, N-80, Buttress, surface to 2500', cemented to surface. 9-5/8", 47#, N-80, Buttress, surface to 7542', cemented w/2200 Sx of Class G. 7", 29#, N-80, Buttress, liner from 7139' to 9454', cemented w/875 Sx of Class G mixed with 1% CFR-2, 3% KCL, .3% Hales 22A and .4% HR-5. Summary of Completed Operations: Perforated 7', 29# liner from 7578' to 7592' and 7564' to 7578' with 4 HPF with tubing conveyed guns. Completed DST #4 & #4RR. Set 9-5/8" retainer at 7024'. Squeezed 175 sacks of Class G, 1% CFR-2, .3% Haled 22A and .4% HR-5 through retainer. Maximum squeeze pressure 3100 PSI at 1 Bbl. per minute. RECEIVED MAR 2 61985 0IaSKa Gu S Gas Cons. Commission Anchorage „4[hereby certify that the foregoing i e an. orrect to the best of my knowledge. Signed i4. aiL7?f % Title District Manager Date 3/25/85 The space below for Commission use - Conditions of Approval,if any: f'-i„7 9 AAI a ''l f. By Order of Approved by COMMISSIONER the Commission 1 Date- i t$_ Form 10-403 d: : . .Submit-"Intentions"in Triplicate Rev.7-180 and'Sdtis$gdent Aepdttf=is,Ddplicate STATE OF ALASKA ALASKA ND GAS CONSERVATION C( .I MISSION SUNDRY NOTICES AND REPORTS ON LLS 1. DRILLING WELL COMPLETED WELL ID (�4:),^ OTHER ID • 2.Name of Operator 7.Permit No.G 1 , 60 Texaco Inc. 8PI N49um 9< v./iS. 3.Address 8.API Number i' ��0/7//J 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 so-103-20038 4.Location of Well B.Unit or Lease Name 1029' North and 1599' East from Southwest corner Colville Delta Section 17, T.13N, R.7E, U.M. Straight hole 10.Well Number #1 11.Field and Pool 5.Elevation in feet(indicate KB,DF,etc.) 6.Leese Designation and Serial No. Expl oratory KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate 0 Alter Casing ❑ Perforations ❑ Altering Casing 0 Stimulate 0 Abandon ❑ Stimulation 0 Abandonment 0 Repair Well 0 Change Plans ❑ Repairs Made ❑ Other ❑ Pull Tubing ❑ Other Plug Back It Pulling Tubing 0 (Note:Report multiple completions on Form 10407 with a submitted Form 10407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of netting any proposed work,for Abandonment see 20 AAC 25.105-170). Present Conditions: T0=9457', PB 111=7024' (Retainer above perforations). Casing: 20" conductor 390', cemented to surface. 13-3/8", 72#, 8-80, Buttress, surface to 2500', cemented to surface. 9-5/8", 47#, N-80, Buttress, surface to 7542', cemented w/2200 Sx of Class G. 7", 29#, 8-80, Buttress, liner from 7139' to 9454', cemented w/875 Sx of Class G mixed with 1% CFR-2, 3% KCL, .3% Halad 22A and .4% HR-5. Open Perforations: 632_8' - 6366' Proposed Work: After completion of DST #5 (perforations from 6328' to 6366'), it is intended to abandon the above perforations by setting a 9-5/8" bridge at 6310'. After) completion of drill stem testing of the remainder of the Kuparuk intervals (6295' to 6253' and 6226' to 6158'), the top Kuparuk interval will be squeezed with cement thru a retainer. Note: Abandonment procedure verbally approved by Harold Hedlund to Karl Kolthoff on 3/24/85. RECEIVED MAR 2 61985 14.I hereby certify that the foregain a d correct to the best of my knowledge. AlasKa Oil & Gas Cons.Colllnlistlo0 \,� Anchorage resigned Title District Manager oar. 3/25/85 The space below for Commission use A 3'r'qa 77 i ft 1 ConAtion,of Approval,if any: Approved Copy _t "' IIRISIIIL VIM9eturnedi _3 db-Y� t BV Order of frr�`'�u1 t 5�i 6 .Approved by COMMISSIONER the Commission Date J:1- �o 6 � _ Form 10403 Submit"Intentions'in Triplicate Rev.7-1$0 and'Subsequent Reports"in Duplicate STATE OF ALASKA ALASKA,ALO GAS CONSERVATION C(...,1MISSION Cf SUNDRY NOTICES AND REPORTS ON WELLS if 1. DRILLING WELL IX] COMPLETED WELL❑ /'/�/}�� OTHER❑ I�(� 2.Name of Operator 7.PJerNir f •r-V Texaco Inc. 84-1' 3.Address 8.API Numb 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 so— 103-20�(/ I/ 4.Location of Well 9.Unit or Lease Name\ 1029' North and 1599' East from Southwest corner Colville Delta Section 17, T.13N, R.7E, U.M. Straight hole 10.Well Number #1 11.Field and Pool Exploratory 5.Elevation in feat(indicate KB,OF,etc.) 6.Lease Designation and Serial No. KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: I (Submit in Triplicate) (Submit in Duplicate) Perforate ❑ Alter Casing ❑ Perforations ❑ Altering Casing ❑ Stimulate ❑ Abandon ❑ Stimulation 0 Abandonment 0 Repair Well ❑ Change Plans ❑ Repairs Made ❑ Other 0 Pull Tubing 0 Other Plug Back 2 Pulling Tubing 0 (Note:Report multiple completions on Form 10407 with a submitted Form 10407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-170). Present Conditions: TD=9457', PB TD=7890' (Retainer above perforations). Casing: 20" conductor 390', cemented to surface. 13-3/8", 72#, N-80, Buttress, surface to 2500', cemented to surface. 9-5/8", 47#, N-80, Buttress, surface to 7542', cemented w/2200 Sx of Class G. 7", 29#, N-80, Buttress, liner from 7139' to 9454', cemented w/875 Sx of Class G mixed with 1% CFR-2, 3% KCL, .3% Halad 22A and .4% HR-5. Open Perforations: 7578' - 7592' Proposed Work: After completion of DST #4, it is intended to abandon the above perfora- I tions by setting a 9-5/8" EZ Drill retainer at 7030' and squeezing 175 sacks Class G, I mixed with 1% CFR-2, 0.3% Halad 22A and .4% HR-5 through retainer, leaving cement across open perforations and above 7" liner lap. Note: ,Abandonment procedure verbally approved by Harold Hedlund to Karl Kolthoff on 3/21/85. RECEIVED MAR 2 61985 Alaska Oil & Gas Cons. Commissior Anchnra p 14 116 certify that the foregoin aan. orrect to the hest of my knowledge. sg* ��i/ii/ p Title District Manager Date 3/22/85 The space below for Commission useq } ,. r Conditions of Approval,if any: /a},fN"anaq Guf� r OotornVC / /DI6:IAL SISIfD yy 8T LONNIE C. SHITE By Order of i t o qq �1 E,it' ' -Approved by COMMISSIONER the Commission Date J1 Form 10403 Submit'Intentions"in Triplicate • Rev.7-180 and"Subsequent Reports"'In Duplicate OF ALASKA • K ALASKA k!L•STATE GAS CONSERVATION COIIMISSION tcs SUNDRY NOTICES AND REPORTS ON TELLS t. DRILLING WELL OB COMPLETED WELL 0 /9jV OTHER❑ 2.Name of Operator 7.Permit No. f///q� / Texaco Inc. 84-149 3.Address 8.API Number 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 50-103-20038 4.Location of Wall 9.Unit or Lease Name 1029' North and 1599' East from Southwest corner Colville Delta Section 17, T.13N, R.7E, U.M. Straight hole 10.Well Number #1 11.Field and Pool Exploratory 5.Elevation in feet(indicate KB,DF,etc.) 6.Lease Designation and Serial No. KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: I (Submit in Triplicate) (Submit in Duplicate) Perforate ❑ Alter Casing 0 Perforations 0 Altering Casing 0 Stimulate ❑ Abandon 0 Stimulation ❑ Abandonment 0 Repair Well 0 Change Plans ❑ Repairs Made 0 Other (, Pull Tubing 0 Other Plug Back fit Pulling Tubing ❑ (Note:Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state ell pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-170). Present Conditions: TD=9457', PB TD=8340' (Retainer above perforations). Casing: 20" conductor 390', cemented to surface. 13-3/8", 72#, N-80, Buttress, surface to 2500', cemented to surface. 9-5/8", 47#, N-80, Buttress, surface to 7542', cemented w/2200 Sx of Class G. 7", 29#, N-80, Buttress, liner from 7139' to 9454', cemented w/875 Sx of Class G mixed with 1% CFR-2, 3% KCL, .3% Halad 22A and .4% HR-5. Open Perforations: 8015' - 8030', 8045' - 8065', 8085' - 8093', 8102' - 8110', 8115' - 8122'. Proposed Work: After completion of DST-#3, it is intended to abandon the above perfora- tions by setting an EZ Drill retainer at +7890' and squeezing 75 sacks Class G, mixed with 1% CFR-2, 0.3% Halad 22A and .4% HR-5 through retainer. Note: Abandonment procedure verbally discussed with Blair Wondzell. j CEIVEDI MAR 2 z 1985 Rlaska Oil& h Cons. Comm) AncOO horage 14.I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. L_-i_. -. Title District Manager D t 3/21/85 The space below for Commission use - ..%PM 1 r Q a r a -:.,?:*1 Conditions of Approval,if any ,3: Approved Cuc�1,� ��" AAIBl E Stint —36P "ryf -2/-� . I! LONNIE A. SiLIil i I A 1 "•'m By Order of �/5 Approved by _.. COMMISSIONER the Commission Date .3 .a,L- — Form 10-403 Submit"Intentions"in Triplicate Rev.7-1-80 and"Subsequent Reports"in Duplicate STATE OF ALASKA ALASK,.JIL D GAS CONSERVATION C,VMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WE It T D LL❑ OTHER❑ /,{�f�/'',/ T.Name of Operator 7.Permit Texaco Inc. 84-149/p/ , r� 3.Address B.API Number _/� 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 so-103-2003 / 4.Location of Well 9.Unit or Lease Name 1029' North and 1599' East from Southwest corner Colville Delta"r/ Section 17, T.13N, R.7E, U.M. Straight hole 10.Well Number 11.Field and Pool 5.Elevation in feet(indicate KB,OF,etc.) 6.Lease Designation and Serial No. Exploratory KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: , ISubmit in Triplicate) (Submit in Duplicate) Perforate ❑ Alter Casing 0 Perforations 0 Altering Casing 0 Stimulate 0 Abandon ❑ Stimulation 0 Abandonment 0 Repair Well 0 Change Plans 0 Repairs Made ❑ Other KJ Pull Tubing ❑ Other ❑ Pulling Tubing ❑ Plug Back & (Note:Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.) Perforations 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-1701. Present Conditions: TD-9457', PB TD=8340' (Retainer above perforations). Casing: 20" conductor 390', cemented to surface. 13-3/8", 72#, N-80, Buttress, surface to 2500', cemented to surface. 9-5/8", 47#, N-80, Buttress, surface to 7542', cemented w/2200 Sx of Class G. 7", 29#, N-80, Buttress, liner from 7139' to 9454', cemented w/875 Sx of Class G mixed with 1% CFR-2, 3% KCL, .3% Halad 22A and .4% HR-5. Summary of Completed Operations: Perforated 7", 29# liner from 8460' to 8520' at 4 HPF with tubing conveyed guns. Completed DST #2. Set retainer at 8340'. Squeezed 75 sacks of Class G, 1% CFR-2, .3% Halad 22A and .4% HR-5 through retainer. Maximum squeeze pressure 1100 PSI at 1 Bbl. per minute. RCU V9 ,i R 2 i.ase A dsxa Uil& Gas Cons.CommlSSi011 pnch0ta96 14.I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed�•�. j ,i ��— Title District Manager Date 3/21/85 The,pace below for commission us "`t#1\--4/6. -- Conditions of of Approval,if any: By Order of • Approved by COMMISSIONER the Commission- Date _ _ Farm 10403 - ' Submit"Intentibns"in Triplicate Rev.7-140 and"Subsequent Reports"in Duplicate STATE OF ALASKA ALASKA OIL D GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL LCI COMPLETED WELL❑ ''OTl✓ER 0 v 4 . :2.Name of Operator 7.Permit No. �!!� Texaco Inc. 84-149 l 3.Address 8.API Number _— 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 so-103-20038 4.Location of Well 9.Unit or Lease Name 1029' North and 1599' East from Southwest corner Colville Delta Section 17, T.13N, R.7E, U.M. Straight hole 10.Well Number #1 11.Field and Pool Exploratory 5.Elevation in feet(indicate KB,DF,etc.) 6.Lease Designation and Serial No. _KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate 0 Alter Casing ❑ Perforations M Altering Casing 0 Stimulate ❑ Abandon 0 Stimulation 0 Abandonment 0 Repair Well 0 Change Plans ❑ Repairs Made ❑ Other Plug Back(111 Pull Tubing 0 Other 0 Pulling Tubing 0 (Note:Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.1051701. . Present Conditions: TD=9457', PB TD=9100' CRetainer above perforations). Casing: 20" conductor 390', cemented to surface. 13-3/8", 72#, N-80, Buttress, surface to 2500', cemented to surface. 9-5/8", 47#, N-80, Buttress, surface to 7542', cemented w/2200 SX of Class G. 7", 29#, N-80, Buttress, liner from 7139' to 9454', cemented w/875 SX of 1 Class G mixed w/1% CFR-2, 3% KCL, .3% Halad 22A and .4% HR-5. Summary of Completed Operations: Perforated 7", 29#, liner from 9380'-65', 9330'-20', 9300'-9286' and 9228'-9218' with tubing conveyed guns at 4 holes per foot during DST #1. Completed DST #1 and set 7" retainer at 9100', established injection rate of 2.5 BPM at 2600 PSI and squeezed 75 sacks of class"G", 1% CFR-2, .3% Halad 22A and .4% HR-5 through retainer. Pulled out of retainer, checked for flow and POH. Note: Above plug back procedure verbally approved by Blair Wondzell to Karl Kolthoff on 3/15/85. RECEIVED MAR 1 8 1985 Alaska 011&Gas Cons.Commission Anchorage h'reby certify that the foregoing rue a d correct to the best of my knowledge. \,fTrt f�, , ►��•� Title District Manager Date 3/18/85 iT�he space below for Commission use ro Conditions of Approval,if any: 9 p '� n p'yk. By Order of Ih 1 -, . Approved by COMMISSIONER the Commission Date Form 10403 Submit"Intentions"in Triplicate Rev.7-1.80 and"Subsequent Reports'in Duplicate • STATE OF ALASKA 410a€'1. ALASKA.ND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS ^ 1. DRILLING WELL IX COMPLETED WELL❑ O4j OTHER 0 1� • 2.Name of Operator 7.Permit No.�jv Texaco Inc. 84-149 3.Address 8.API Number A !,:i 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 so-103-20038 `/ 4.Location of Well _ 9.Unit or Lease Name 1029' North and 1599' East from Southwest corner Colville Delta Section 17, T.13N, R.7E, U.M. Straight hole 10.Well Number #1 11.Field and Pool Exploratory 5.Elevation in feet(indicate KB,OF,etc.) 6.Lease Designation and Serial No. KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data • NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ❑ Alter Casing 0 Perforations C Altering Casing 0 Stimulate 0 Abandon Perfs X Stimulation C Abandonment ❑ Repair Well ❑ Change Plans 0 Repairs Made ❑ Other 0 Pull Tubing 0 Other 0 Pulling Tubing 0 (Note:Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any Proposed work,for Abandonment see 20 AAC 25.105-1701. Present Conditions: TD=9457', PB TD=9100' (Retainer above perforations). Casing: 20" conductor 390', cemented to surface. 13-3/8", 72#, N-80, Buttress, surface to 2500', cemented to surface. 9-5/8", 47#, N-80, Buttress, surface to 7542', cemented w/2200 Sx of Class G. 7", 29#, N-80, Buttress, liner from 7139' to 9454', cemented w/875 Sx of Class G mixed with 1% CFR-2, 3% KCL, .3% Halad 22A and .4% HR-5. Proposed Work: After completion of DST #2, 8550'-20' and 8480'-60', we propose to set 7" retainer at 8340' and squeeze 75 sacks Class "G" cement mixed with 1% CFR-2, .3% Halad 22A and .4% HR-5 through the retainer. RECEIVED IVED MAR 181985 Alaska 011 & Gas Cons. Commission Anchorage 14.Ighe eby certify that th= going e an. orrect to the best of my knowledge. " T p 1 -1. 1.):./,,! Title District Manager ,te,..3•f-78 8f t` a ( 6 The space below for Commission use > - Conditions of Approval,if any. APProvsd Cop,' S5IIII Hur $BIB hL SIENEO .�� $ PI- 01 LONNIE C. SMIII v By Order of 1 Approved by COMMISSIONER the Commission Date �_/ S _ Farm 10-403 Submit"Intentions"in Triplicate Rev.7-180 and"Subsequent Reports"in Duplicate STATE OF ALASKA el'4K- ALASKA,IL ND GAS CONSERVATION CL.AMISSION as SUNDRY NOTICES AND REPORTS ON WEyS �- 1. DRILLING WELL 1X1 COMPLETED WELL 0 /TT''/G,THER❑O 2.Name of Operator 7.Permit No. �(� il Texaco Inc. 84-149 j /� 3.Address 8.API Number < 550 W. 7th Avenue, Suite 1320, Anchorage, Alaska 99501 50103-20038 4.Location of Well 9.Unit or Lease Name 1029' North and 1599' East from Southwest corner Colville Delta Section 17, T.13N, R.7E, U.M. Straight hole 10.Well Number #1 11.Field and Pool 5.Elevation in feet(indicate KB,OF,etc.) 6.Lease Designation and Serial No. Exploratory KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: !Submit in Triplicate) (Submit in Duplicate) Perforate M Alter Casing ❑ Perforations ❑ Altering Casing ❑ Stimulate 0 Abandon 0 Stimulation 0 Abandonment ❑ Repair Well ❑ Change Plans 0 Repairs Made ❑ Other ❑ Pull Tubing ❑ Other 0 Pulling Tubing 0 (Note:Report multiple completions on Form 10-407 with a submitted Form 10.407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-170). Present condition of well: Total depth 9457'. 13-3/8', 72#, N-80, buttress casing from surface to 2500'. Cemented to surface, tested to 1800 psi 9-5/8", 47#, N-80, buttress casing from surface to 7542', cemented with 2200 sacks, tested to 3325 psi. 7", 29#, N-80, buttress liner with shoe at 9454', top at 7139', cemented with 875 sacks class G, 1% CFO, 3% KCL, .3% Halad 22, .4% HR5. We propose to test through perforations in casing the following intervals (this will be our maximum program): Test #1: 9365-80, 9320-30, 9286-300, 9218-28. Test #2: 8550-20, 8460-80 8340-75. Test #3: 8015-30, 8045-65, 8085-93, 8102-10, 8115-22. Test #4: 7578-92. Test #5: 6328-66. Test #6: 6253-95. Test #7: 6158-226. We will use the GeoVann system, where the casing guns are run in the hole below drill pipe, a packer is set above the test interval ,l then the casing is perforated below the packer. Test fluid will be normal drilling mud at a weight of 9.9 ppg. In addition to the rat hole mud, additional nitrogen cushion will be' built up in the drill pipe string. As each test is completed, we intend to set a retainer) above those perforations and cement below the retainer. I RECEIVED MAR 1 31985 AInnka 011 666 Gas Coils. Commisslof Anchorage 14.I hereby certify' tha,)the foregoing u true and correct to the best of my knowledge. Signe. 110 W ryl l Title District Manager Date March 13, 1985 The space below for Comrnissio El-'��'Ye 4,.---.. yI� Conditions of Approval,if any. N g y.1 r 0 a f 3 I Ap eturd Ctap�n S ' ....:J.. ?R►CIAAL R�turmd AV LONNIE C. SMIIN y$ S �7 Approved by — COMMISSIONER teS CCodinn, on 1 t� 3.'41.4-.-!-''';,-.';, �sf`S_ Form 10-403 Submit"Intentions"in Triplicate Rev.7-150 and"Subsequent Reports"in Duplicate TATE OF ALASKAEL-- ti g-- ALASKA _AAGASCONSERVATION CCrMISSIONCOSJFIDEN y MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS-(1 1 1.Drilling well IX Workover operation CIR fry L' 2.Name of operator 7.Permit No Texaco Inc. 84-14® f� 3.Address 8.API Num //� 550 W. 7th Ave., #1320, Anchorage, Alaska 99501 so- 103-2 4/ 44 4.Location of Well 9.Unit or Lease at surface Colville DeY 1029' North and 1599' East from the southwest corner 10.Well No. .1/ of Section 17, T13N, R7E, U.M. Straight hole #1 l/ 11.Field and Pool Exploratory 5.Elevation in feet(indicate KB,DF,etc.) 6.Lease Designation and Serial No. KB is 35.5' above sea level ADL 355037 For the Month of February ,1e 85 12.Depth at end of month,footage drilled,fishing jobs,directional drilling problems,spud date,remarks • Drilled 17," hole to 2510' & ran 13-3/8" surface pipe. Drilled 12$" hole to 7624' & ran 9-5/8" production casing. 2/28/85: Depth 7940'. Drilling 81/2" hole. 13.Casing or liner run and quantities of cement,results of pressure teats 13-3/8", 72#, N-80, Buttress, surface pipe from surface to 2500' (61 jts.). Cemented to the surface with 4300 sx permafrost cement. Tested casing to 1800 PSI. 9-5/8" 47#, N-80 Buttress, intermediate casing from 7542' to surface. Cemented with 2200 Sly class G w)1% CFR2 & .1% HR7. Tested casing to 3325 PSI. 14.Coring resume and brief description Core #1: 7880' - 7940', recovered 60' sandstone, shale, siltstone (full description to follow). a a-•q 15.Logs run and depth where run ! •t t 71!5 1 2510': DIFL-SP-BHC Acoustic-GR-Caliper-BGT. 7623'-2498': DIFL-SP-LSAL-GR-CAL-CDL-CNL-SPEC-Dielectric-DIP-SWS. saw a 16.DST data,perforating data,shows of HyS,miscellaneous data RECEIVED None MAR 0 7 1985 Alaska oil&Gas Cons.Commission Anchorage 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED �• 4,, %<' Id '. TITLE District Manager DATE March 5, 1985 NOTE—Report on this form is requirelir each calendar month,regardless of the status of operations,end must be filed in duplicate with the Alaska Oil and Gas Conservation Commission b the 15th of the succeeding month,unless otherwise directed. Form 10404 rfmca n0%17!Submit it duPlieene TATE OF ALASKA __ ALASKA.—,L GAS CONSERVATION CC_,MISSION SUNDRY NOTICES AND REPORTS ON WELLS w-(,�� 1. DRILLING WELL F'� COMPLETED WELL 0 OTHER❑ ,,,��Cyyyppp'''t .2.Name of Operator 7.Permit No. �"/� Texaco Inc. 84-149 /"!�%y 3.Address 8.API Number 550 W. 7th Ave., #1320, Anchorage, AK 99501 50_103-20038 4.Location of Well 9.Unit or L e 1029' North and 1599' East from the Southwest corner of Colvielta Section 17, T13N, R7E, U.M. Straight hole. 10. 1 Numb r/ 11.Field and Pool 614 ExploratoryY 5.Elevation in feet(indicate KB,DF,etc.) 6.Lease Designation and Serial No. KB 35.5' MSL ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate 0 Alter Casing ❑ Perforations 0 Altering Casing 0 Stimulate ❑ Abandon ❑ Stimulation 0 Abandonment 0 • Repair Well 0 Change Plans 1 Repairs Made 0 Other 0 • Pull Tubing ❑ Other ❑ Pulling Tubing 0 (Note:Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-170). Casing status: 13 3/8", 72#, N-80, buttress casing from surface to 2500'. Cemented to the surface with 4300 sx permafrost cement, tested to 1800 psi. - 9 5/8", 47#, N-80, buttress casing from surface to 7542'. Cemented with 2200 sx class G with 1% CFR-2 & 0.1% HR7. Tested to 3325 psi. Drilling ahead at 9269' at 6a.m. today, March 6, 1985. Permitted depth is 9300'. - We propose to deepen from 9300' to 9800' in order to ensure evaluation of the entire sedimentary section. Per telephone contact with Commissioner N.W. Kugler at 9a.m. this morning, we have received verbal approval to proceed with deepening operations. RECEIVED MAR 0 6 1985 Alaska 011 & Gas Cons. Commission Anchorage 14.I hereby certify that the foregoing is tru lid c rrect to the best of my knowledge. Signed Title 7 District Manager Date March 6, 1985 a The space below for Commission use , I, T 2 �.. Conditions of Approval,if any Approved Cop; . - Roturrsed, 1 - - 8r1iIlNAl MU 3.-(o_g6 B! iN$lI ;, gp!T By Order of �IN7 iii) L'e ar �pp-c,.�,i Approved by _ _ COMMISSIONER the Commission Date '.-9_�—_— Form 10403 Submit"Intentions'in Triplicate Rev.7-1-80 and"Subsequent Reports"in Duplicate MEMORA•UM State of Alask• ALASKA OIL AND GAS CONSERVATION COMMISSION To: C. Vt tfrton DATE February 11, 1985 Chair FLENO: D.BDF.12 THRU: Lonnie C. Smith-f')' Commi s s ioner TELEPHONE No: FHom: Bobby Foster) - SUBJECT: Witness ROPE Test on Petroleum Inspector Texaco's Colville Delta 11, Sec. 17, T13N,R7E,UM, Permit No. 84-149. Sunday, February 10, 1985: The ROPE test began at 7:00 am and was concluded at 2:30 pm. As the attached BOPE test report shows there was three failures all of which was repaired and tested. In summary, I witnessed the BOPE test on Texaco's Colville Delta 11. Attachment 02 10x91 111/1 GaG 04 • 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date lJ- /i - 6 3 Inspector - /vJ/ L /e Well�p ///4 7)P / Operator .A, .i Representativ f elfe.0)G‹2_ Well Permit�,� 8 ,j / 9 Location: Sec /7 /T/,1 1R7E M (J /A5Casing Set @ 1 ft. Drillin: Contractor„G, _,i I - Ri: ll_;„ Re.resentative .L ,. Location, General �,e' Well SignO0t. ACCUMULATOR SYSTEM General Housekeeping e, Rig 42,,t/ Full Charge Pressure 0 /0-0 psig Reserve Pit ' Pressure After Closure /..5-50 psig Mud S stems Visual Audio Pump incr. clos. pres. 200 psig - min,55 sec. Trip Tank v I Full Charge Pressure Attained: ,_5 mine.5-5-sec. Pit Gauge ✓ N .2 &il ao7.Z0 2 psig Flow Monitor L- I Controls: Master (�e Gas Detectors Remote /e S_Blinds switch cover ye:: Kelly and Floor Safety Valves BOPE Stack Test Pressure Upper Kelly J Test Pressure if-e-o-a Annular Preventer / 05 5c-co Lower Kelly / Test Pressure Sire-e, Rams .rLG7er0 Ball Type / Test Pressure o57-zs.+ Blind Rams / ,5 a-i' Inside BOP / Test Pressure �2.-a Choke Line Valves / L.57-Pa-w Choke Manifold Lies Test Pressure 6-6-+-n _ H.C.R. Valve / -+c No. Valves / 3. Kill Line Valves 7 y�r--.-z, No. flanges .„5... Check Valve — — Adjustable Chokes Hvdrauicall o.erated choke Test Results: Failures ' Test Time ;7A 'hrs. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. �i Remarks: /�ef /- /6",;///''��/ 4:4,8. /���OiC �e 5�I ./.ted a 7, /✓'e_. rr Distribution - orig. - AO&GCC cc - Operator / /r cc - Supervisor Inspector/_J .J . /.....' ' - r . STATE OF ALASKA CONi ALASKF 1L AND GAS CONSERVATION C,. .AMISSION 9AL SUNDRY NOTICES AND REPORTS ON WELLS Q �di 1. DRILLING WELLKX COMPLETED WELL 0 O ''t-fit [�/`///'7y//sM 2.Name of Operator 7.Permit No. '�` (4 Texaco Inc. 84-149 .'57 3.Address 8.API Number 550 W. 7th Ave., #1320, Anchorage, Alaska 99501 50-103-20038GP 4.Location of Well 9.Unit or Lease Name 1029' North and 1599' East from the southwest corner Colville Delta of Section 17, T13N, R7E, U.M. Straight Hole. 10.Well Number #1 11.Field and Pool 5.Elevation in feet(indicate KB,DF,etc.) 6.Lease Designation and Serial No. Exnl oratory KB is 35.5' above sea level ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ❑ Alter Casing ❑ Perforations 0 Altering Casing 0 Stimulate 0 Abandon ❑ Stimulation ❑ Abandonment 0 Repair Well ❑ Change Plans XX Repairs Made ❑ Other ❑ Pull Tubing ❑ Other 0 Pulling Tubing 0 (Note:Report multiple completions on Form 10-407 with a submitted Form 10.407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-1701. Present Conditions This well spud on 1/29/85. 30" structural pipe has been set at 86' KB, and 20" conductor at 390' KB. Both strings have been cemented to the surface. Proposed Change of Plan It is proposed to dispose of used drilling mud, completion fluid and waste fluids into permeable formations via the 9-5/8" X 13-3/8" annulus. Disposal will commence only after running and cementing the 13-3/8" surface casing from 2500' to surface and the 9-5/8" production casing from +7100' to ±3500', as per our original drilling permit. Proposed injection path is shown on the attached drawing. We believe this method is environmentally superior to surface disposal, as the waste fluids would be permanently sealed into underground formations. No significant fresh- water aquifers have been found below 2500' in 4 other wells within an 8-mile radius of the Colville well. On abandonment, the 9-5/8" X 13-3/8" casing annulus will be down- squeezed with permafrost cement to afford a permanent seal above 2500', ,t F_IVED ' FEB 071985 KWK:bjs 14.I herebyAl..,.., lel m his Cons.Commiss On certify that the forego"r_is tr a and correct to the best of my knowledge. _ �`' Anchorage Signed i$' a • �i�: Title District Manager 1[ 5, ‘ a 1 The space below for Commission use , t a,R r"'�I ;a;(3 1_ Ri Conditions of Approval,if any. ` 7 f ..+ . tt�,{ , Approved Copy Vo ^ j 1 t � ,enlff{I ff R tur.d t l A �. 2217.i.' 7 8S ', BCCI it LONNIE el NY# _ eii t�� ig ri. Approved by the Order is c_21,918:5��� _._ COMMISSIONER the Commission Oete Form 10-403 -- Rev.7-1$0 Submit"Intentions"in Triplicate f�c1 4�l��t�a a s and"Subsequent Reports"in Duplicate • • 'TExAcA I NC. Fifa p. Col.Vlll.E DELTA 111` I viEt.L. Sec, ll- 13M-1E10..1'A, .14A1/411441 30. 14 85 SK1lta SNOWING. PetiroSeD A $uuws DL- METI{oD (clot' TO scAt-E) SCA"casing (NAME' using anulus PLUIOSS `f - 13 „ 8C . i 5 cevA t ° O 0 Forru"1 ia% - p o O ' a' • • p o. / O ' O C 0it . /% N2.coor ice Fo e-MATI ON ,r,'" 0 y9�i / / 3, 00 �, i Vo. o• .,Lei ,o e • .o / FazMattoN o 0 0. ° 7-. RECEIVED o• . p �: set.3:0 Q 71985 /11 O 0. Alaska Uil cement &gnas C°ns. Commission NF4, choraga STATEOF ALASKAr l� ALASKA( D GAS CONSERVATION CO—'MISSION LL F + 4 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1.Drilling well XIX Workover operation D ^/'/��y'_'1 a( 2.Name of operator 7.Permit No. /! /4 Texaco Inc. 84IN49um / n/� 3.Address e.API Number C� 550 W. 7th Ave., #1320, Anchorage, Alaska 99501 m-103-20038 4.Location of Well 9.Unit or Lease Name el at surface Colville Delta 1029' North and 1599' East from the southwest corner 10.Well No. of Section 17, T13N, R7E, U.N. Straight hole #1 11.Field and Pool Exploratory 5.Elevation in feet(indicate KB,OF,etc.) 6.Lease Designation and Serial No. KB is 35.5' above sea level ADL 355037 For the Month of January 19 85 12.Depth at end of month,footage drilled,fishing jobs,directional drilling problems,spud date,remarks Drilled 36" hole, ran and cemented 55' of structural pipe on 1/1/85. Moved in drilling rig and spud hole at 2200 Hrs. 1/29/85. Drilled 26" hole to 390', set and cemented 20" conductor. 13.Casing or liner run and quantities of cement,results of pressure tests 30", 234#, Grade B, L.P., structural pipe to 86' KB. Cemented to surface with 6 yards Cold-Set cement. 20", 106.5#, J-55, buttress, conductor to 390'. Cemented to surface with 1800 SX permafrost cement. 14.Coring resume and brief description None 15.Logs run and depth where run None 16.DST data,perforating data,shows of HoS,miscellaneous data RECEIVED ECEIVED None 11'71 6 FEB Q, 1985 aaska Oil$ Gas Cons, Commies on Anchorage 17.I hereby certify that the foregoing is tr a and correct to the best of rhykpowledgei *?SIGNED ({�• A7� "i: TITLE District Manager DATE 2/1/85 V NOTE--Report on this form is required forh calendar month,regardless of the status of operations,and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month,unless otherwise directed. Form 10404 CCM f o. RTg a a Submit in duplicate • PLUGGING & LOCATION CLEARANCE REPORT State of Alaska .ALASKA OIL E GAS CONSERVATION COMMISSION • PTD No. 8.S-oo6S Lease ADL 35-So34 Memorandum To File: API;No. 1o'3-Zoo;B- 00 Well Name cnl-vluE --ra I-A Operator TEt.{k 1aG - Location 54.4. i�-713N-mooaE Abnd Date <}�zblgq Spud: 41l18T TD: 1,1,4o. • Completed gI2.61AS Note casing size, wt, depth, cmt vol, &procedure. Sfc cog: 1;3/3 rt-so @ ZSoo "/430o SX Long Cag: 5/9 -Ro '13 oo' w/7 Liner: ^I:^'Dow C.i�.Ai yF73-0- 82'-,Z3Tc/opr cmr LAID, SIDE/Lacy..k0A 7H(2U WINDov.) rot.1 A Perf intervals - tops: Norte` Review the well file, and comment on plugging, well head status, and location clearance - provide loc. clear. code. Plugs: zoe CAW,' Anc.off PWC+Te,: e.UP A-1 bS40'..4eo cUc'I 6a c.PWG Ac.aosS'Ir/&TN q� DEAF At 491°' TOP Ar 4Llz-wIr'E?•SEo Hy H•HAIJKINS• LUFf Pwo Tnau atop Ar zSSo-wIT $.o 6yH•Ha�u.le1.1soc�c"r Dow.,saVa Tip-9 /�fi131/0g4 UI [0 PM/MvoT.JSoo., WE:.DE,D STGtL Pu.TE °JEAN[fl.14N6-S7✓AS• WFC S.sr I+9901,1351g a 9518/Sax PES AT/90• Well head cut off: �E.S Marker post or plate: 1ES- Location Clearance: INSPicThA Ay A.AMeS 1.12L'P,.c- Li-E-AaPwu Conclusions: kbEEm V-i t-y P C.,CD - Code 6, Signed .1.0•e."cls(v o&_— Date c3100/4. 1110 1110 July 30, 1985 Mr. Burlin Whiteley District Manager Texaco Inc. 550 W. Seventh Avenue, Suite 1320 Anchorage, Alaska 99501-3575 Re: Final Abandonment, Colville Delta No. 1A, Sec. 17, T13N, R7E, UM. Dear Mr. Whiteley: On June 20, 1985 our representative verified the satisfactory filling, leveling and clean-up of subject location utilized for your abandoned wells, Colville Delta Nos. 1 and 1A. Our representatives have previously witnessed or verified that all downhole and wellhead abandonment work was satisfactorially performed for both wells. Consequently, final abandonment of this location is approved. Sincerely, Lonnie C. Smith Commissioner be:1.S.23 • MEMORANL)UM State of Alaska ALAS OIL AND GAS CONSERVATION COMMISSION D kpxTO: C. atterton DATE, July 29, Cha n � AAtt .� / � ( FILENO D.ADA.32 //�' 7 / TNRU: Lonnie C. Smith Commissioner TELEPHONE NO'. FROM. Doug Amos ' suBJECT-. Clean-up Inspection Petroleum Inspector Texaco's Colville Delta /1 & lA Wells Permit No. 85-65 Exploratory Thursday, June 20, 1985: I traveled this date from Conoco's Milne Pt. B-15 Well to Texaco's Colville Delta No. 1 and lA wells to conduct the final clean-up inspection. As the attached photographs show, the location is very clean and level, no debris remains and all pit areas are filled. I recommend that the commission approve this location for final abandonment. In summary, I conducted the final clean-up inspection for the abandonment of Texaco's Colville Delta No. 1 Well. Attachment azoa,a�Ae.,o„s� STATE OF ALASKA CONFIDENTIAL ALASKA .._..ND GAS CONSERVATION CC. AISSION WELL COMPLETION OR RECOMPLETION REPORT/ ff� AND LOQ , a 1.Status of Well ClassificaLl✓✓ e ice Well -1 'fir/ /i// OIL 0 GAS 0 SUSPENDED 0 ABANDONED XI SERVICE 0 /G/ 'v/e1 2.Name of Operator 7.Permit Number 474 6iTexaco Inc. 85-65 YYY 3.Address 8.API Number 550 W. 7th Ave., #1320, Anchorage, Alaska 99501 50- 103-20038 - 4.Location of well at surface 1029' North and 1599' East from the south- 9.Unit or Lease Name west cogg>E of Section 17, T13N, R7E, U.N. Colville Delta Atrop:aX 6 611 interni 751' North and 1142' East from the southwest 10.Well Number corner of Section 17, T13N, R7E, U.N. #1-A (R/D #1) T._ - AtTotalDepth 698' North and 984' East from the southwest corner 11.Field and Pool vorFA. of Section 17, T13N. R7E. U.N. Exploratory 5.Elevation in feet(indicate KB,DF,etc.) 6.Lease Designation end Serial No. aSurf._�_i Reference is KB - 35.5' AMSL , ADL 355037 e.H._ _._i 12.[late Spudded 13.Date T.D.Reached 14.Date Comp.,Susp.or Abend. 15.Water Depth,if offshore 16.No.of Completions 4/7/85 4/21/85 4/26/85 fees MSL 17.Total Depth(MD+TV DI 18.PIug Back DepthlMDcNDI 19.Directional Survey 20.Depth where SSSV set 21.Thickness of Permafrost 6640'(6490'TVD YES I] NO❑ feet MD 1550' 22.Type Electric or Other Logs Run DIFL - DT; FDC-CNL 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT.PER FT. GRADE TOP _ BOTTOM HOLE SIZE CEMENTING RECORD 30" 234# B - L.P. Surface 86' 36" 6 Yds. Cold-Set From Colville Delta #. GO- • 106.5# J-55 Surface 390' 26" 1800 Sx Permafrost " 13-3/8" 72# N-80 Surface 2500' 172" 4300 Sx Permafrost " " " 9-5/8" 47# N-80 Surface 124" Window cut at 47i0' to 4789' 24.Perforations open to Production(MD+TVD of Top and Bottom and 25. TUBING RECORD interval,size and number) SIZE DEPTH SET IMO) PACKER SET IMDI None None pO t ,, ,S A 3191 �' k 1 26. ACID,F R ACTURE,CEMENT SQUEEZE,ETC. i,1. e `5 DEPTH INTERVAL(MDI AMOUNT&KIND OF MATERIAL USED ii4s��� None r, 27. PRODUCTION TEST -..1.1 Date First Production Method of Operation(Flowing,gas lift,etc.) None •%''. u-1 J Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GA,$-OlL f}ATIO TEST PERIOD♦ Flow Tubing Casing Pressure CALCULATED ., OIL•BBL . GAS-MCP WATER-BBL OIL GRAVITY-API lcorrl Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology,porosity,fractures,apparent dips and presence of oil,gas or water.Submit core chips. Core #1: (First 2 cores in original hole): 6255' - 6266'; recovered 8'; siltstone. Core #2: 6266'-6292'; recovered 30.5' (12'fill), shale, fine sandstone, siltstone &mudstone. Core #3: 6292'-6322'; recovered 30' fine sandstone, siltstone and mudstone. Core #4: 6322'-6349'; recovered 262' of fine sandstone, siltstone and mudstone. Core #5: 6349'-6388'; recovered 38' of fine sandstone, siltstone. Core #6: 63885-6449';•recovered 61' of sandstone and siltstone. •Core #7: 6449'-6481'; recovered 29' of fine sandstone and siltstone. Core #8: 6481'-6541'; recovered 60' of fine sandstone and siltstone. DETAILED CORED DESCRIPTION ATTACHED Form 10-407 C.Oh Submit in duplicate Rev.7-1-80 CONTINUED ON REVERSE SIDE NF'DENT A� COHf 6DENTIAi 0 • - 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME ' Include interval tested,pressure data.all fluids recovered and gravity. MEAS.DEPTH TRUE VERT.DEPTH GOR,and time of each phase. Top Jurassic .6292' 6185' DST #1: Open hole straddle packers from Kingak 6288' to 6545' (257'), recovered (Kuparuk?) i 7.7 Bbls. rat hole mud and gas at rate of less than 50 MCF/D. P me 7, =-'.‘..7‘11 MI cc) 31.LIST b ATTACHMENTS �� 32. I hereby cArthy that the foregoing is true and correct to the best of my knowledge Signed I` -�"lf�:�// TitieDistrict Manager Date 6/13/85 • 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. Item 1: Classification of Service Wells: Gas injection, water injection,steam injection,air injection,salt water disposal,water supply for injection,observation,injection for in-situ combustion. Item 5: Indicate which elevation is used as reference(where not otherwise shown)for depth measurements given in other spaces on this form and in any attachments, Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion),so state in item 16,and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval. Item 21: Indicate whether from ground level(GL)or other elevation(DF,KB,etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water In- jection,Gas Injection,Shut-in,Other-explain. Item 28: If no cores taken,indicate"none". CONFIDENTIAL 10-407 .. . . • • -1- • COLVILLE DELTA WELL #1A CONf!C �)l.N 41 WELL HISTORY l/ Depth (ft.) Day Mud Wt.(ppg) Activity 4-7-85 5,992 RET Reversed out } bbl cement. Laid down 10.2 31" DP, 4-3/4" DCs; installed 5" rams. Tested BODE. RIH BHA on 5" DP; milled 9-5/8" casing from 4730' to 4743'. 4-8-85 5,992 RET Milled 9-5/8" casing to 4,769'. POH, 10.2 changed rams, RIH. Tagged 4' fill; could not clean out. Tripped for 83" taper mill, cleaned out fill to 4,830'. Tripped for BHA consisting of taper mill, strapped to section mill at bottom. 4-9-85 5,992 RET Milled 9-5/8" casing to 4,789'. Under 10.2 reamed 59' section, 121" x 16". RIH OEDP to 4,845', laid cement plug with 212 sx class G slurry having 1% CaC12, 1% CFR-2. Pulled up to 3,890', laid down excess DP, POH. 4-10-85 4,700 PBTD RIH 8i" bit to cement at 4,525'; cleaned 10.2 out cement to 4,700'. Pumped surface mud down 13-3/8" x 9-5/8" annulus. Cleaned mud tanks. 4-11-85 4,730 PBTD Completed cleaning mud tanks. Mixed 10.0 RC1-Drispac mud system. Drilled hard cement to 4,730', circulated, POH. RIH dyna-drill to commence redrill #1, a directional hole to a new bottom hole location 4-11-85 4,888 Completed RIH with directional assembly, 9.9 drilled to 4,859'. Tripped to change bent sub, drilled ahead. Survey: 4,819' MD 4,818.82' TVD VS: 4.8' 6° 30' S-68-W 5-2.42' W-4.36' 4-13-85 5,380 Dyna-drilled to 5,012'. Tripped to 10.0 change BHA; drilled, surveyed to 5,057'. Survey: 5,057' MD 16° 5-48-W S-67.96' W-84.66' 4-14-85 B4 .t, Drilled to 5,644'. POH, tested ROPE. Cleaned out metal shavings from BOPE, retested HOPE. RIH, drilled, surveyed ahead. Survey: 5,707 MD Alasi<a Uii Y U (ri WInSS1022° 15' S-54-W S-166.87' W-207.71' suchor.�; i -2 4111 - Colville Delta Well $1A CONFI1ENTIA;_ May 10, 1985 Page 2 Depth (ft.) Day Mud Wt. (ppg) Activity 4-15-85 6,255' Drilled to 6,213', pulled up to 3,600', 10.0 laid down bad jt. DP, RIH. Drilled, surveyed to 6,255'. RIH 30' core barrel. Survey: 6,210' MD VS: 474.84' 29° S-68-W 5-266.92' W-397.94' 4-16-85 6,266 RIH core barrel #1, circulated, dropped 10.0 survey tool but could not core. Tripped, circulated to bottom. Cored 6,255'-6,266', POH, recovered 8', 100% shale core. RIH core barrel $2. 4-17-B4 6,322 Cored 6,266'-6,292', POH, recovered 10.0 30.5' core including 1.5' fill. RIH core barrel $3. Cored 6,292'-6,322', POH, recovered 30'. PU core barrel $4, cut drilling line. 4-18-85 6,377 Cored 6,322'-6,349', POH, recovered 10.1 26.5'. RIH, washed, reamed 6,093'-6,349', circulated, POH. RIH 60' standard (non-oriented) core barrel. 4-19-85 6,449 Core $5 from 6,371-6,388', recovered 10.1 38.5'. RIH core barrel $6, cored 6,388-6,449', POH, recovered 61'. RIH core barrel $7. 4-20-85 6,523 Cut drilling line, cored 6,449'-6,481', 10.1 recovered 29'. RIB core barrel $8, cored 6,481'-6,523'. 4-21-65 6,640 TD Continued core $E to 6,541', POE, 10.1 recovered 61'. RIB 83" bit, drilled to 6,640', made wiper trip to shoe. Ran multishot survey, POH. Began logging. Survey: 6,578' MD 6,437.25' TVD VS: 644.07' 28° 0' S-73-Ii 5-322.44' W-587.92' 4-22-E5 6,640 TO Completed running DIFL-DT; ran FDC-CNL, 10.1 tools stopped at 6,630'. Tripped, conditioned hole, POH. Tested BOPE. RIB DST $E. NNL ` JM5/g6 • • -4- !oNf DFNTlM COLVILLE DELTA WELL #1A ABANDONMENT Depth (ft.) Day Mud Wt. (ppg) Activity 4-24-85 PB to Surface RIH OEDP to 6,540'; conditioned hole, 10.2 waited 2 hrs. for approval to abandon. Set cement plug #1 with 200 cubic ft. class G slurry having 1% CFR-2, 0.3% HA-22A. Pulled up to 4,910'. Set cement plug #2 with 400 cubic ft. class G slurry having 2% CaC122, 0.75% CFR-2. Pulled up, laid down HWDP, 3DCs. RIH to 4,000', tagged plug at 4,272'; witnessed and approved by AOGCC representative. POH, RIH OEDP to 2,550'. Set cement plug #3 with 57 cubic ft. permafrost cement. Began laying down DP. 4-25-85 PB to surface Completed laying down DP. Abandoned 13-3/8" x 9-5/8" annulus with 375 sxs. permafrost cement displaced to 1500'. Shot 4 x 3/8" holes in 9-5/8" casing at 140'. Circulated 100 sxs. permafrost cement to surface. Removed BOPE, began removing drilling spool. 4-26-85 PB to Surface Removed wellhead equipment. Cut off casing at cellar floor. Welded plate between 13-3/8", 9-5/8" strings and on top of 9-5/8" string. Welded 16" OD plate, containing well description, on top of 9-5/8" stub; stub is located 8' below pad level, 5' below original ground level. Photographed by T. Young. Began cleaning mud tanks. Released rig at 8:00 am, YST. .i • J1_5/vE • CONFIDENTIAL -5- COLVILLE DELTA 67ELLSITE ABANDONMENT Day Activity 4-27-85 Began rigging down. Laid down mast, moved out 7 loads. Hauled contaminated cuttings to Deadhorse landfill. Ice road began deterioration. 4-28-85 Continued rigging down, moving out. 4-29-85 Rigged down communications tower, continued moving out. Prepared to remove cellar. Reparied pot holes in ice road, marked weak areas for detours. 4-30-85 Continued moving out; removed cellar, filled in space with gravel. Removed 4/6' x 100' x 200' gravel layer from pad and hauled gravel to Deadhorse landfill to ensure removal of all possibly contaminated material. 5-1-95 Continued moving out and hauling gravel to Deadhorse landfill. Removed road markers from ice road; ice road continued deterioration. 5-2-85 Continued moving out, removing road markers. Sand bars showed through ice road layers, bladed snow across road to further insulate road from sun. Soft spots occurred in gravel pad; trucks needed assistance to cross location. 5-3-85 Continued moving out, removing road markers. Closed camp, began final clean up of location. 5-4-85 Continued moving out, cleaned and leveled grave] pad. Completed haul of all possibly contaminated gravel to Deadhorse landfill. 5-5-E5 Moved last load off site. Removed all trash and debris along road and site. Installed snow berm across ice road ; mi. from wellsite and across road to mud and cuttings dump site. NML JM5/k9 .., IIISTATE OF ALASKAlik ALASKA viL GAS CONSERVATION CUtv1MISSION .. . ,;K SUNDRY NOTICES AND REPORTS ON'WELLS • 1. DRILLING WELL 81X COMPLETED VBA:it(/ r, UTJ-IER 0 , ft 2.Name of Operator q4 �/� .,,.-196,„!✓7.Permit No. I4 Texaco Inc. a3'ka OU B ; 84-149/85-65 I �V 3.Address QJ Cons B.API Number r/�/� 550 W. 7th Ave., #1320, Anchorage, Alaska 99501 An`h0idvj° r0Nin) ,A,- 103-20038 ���J('61�I1 4.Location of Well 9.Unit or Lease Name 1029' North and 1599' East from the SW corner of Section 17, Colville Delta T13N, R7E, U.M. Straight hole. 10.Well Number I lA (R/D #1) BLH: 748' North and 1181' East of Southwest corner of It.Field and Pool i Section 17, T13N, R7E, U.M. Exploratory 5.Elevation in feet(indicate KB,DF,etc.) 6.Lease Designation and Serial No. KB is 35.5' above sea level ADL 355037 12. Check Appropriate Box To Indicate Nature of Notice,Report,or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate 0 Alter Casing 0 Perforations ❑ Altering Casing 0 • Stimulate ❑ Abandon 0 Stimulation 0 Abandonment KX Repair Well 0 Change Plans ❑ Repairs Made 0 Other ❑ Pull Tubing ❑ Other 0 Pulling Tubing 0 (Note:Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13.Describe Proposed or Completed Operations(Clearly state all pertinent details and give pertinent dates,including estimated date of starting any proposed work,for Abandonment see 20 AAC 25.105-170). Plug #1: 200 cu. ft. of class G with 1% CFR-2 and 0.3% Haled 22-A, balanced open-hole plug; displaced thru OEDP at 6540'. CIP at 1:10 PM 4-23-85. Plug #2: 400 cu. ft. of class G with 2% CaC12 and 0.75% CFR-2, balanced plug across 9-5/8" shoe; displaced thru OEDP at 4910'. CIP at 3:30 PM 4-23-85. Located top of plug at 4272' (witness by Harold Hawks s, AOGCC). Plug #3: 57 cu. ft. Permafrost "C" balanced, cased hole plug; displaced thru OEDP at 2550'. CIP at 5:45 AM 4-23-85 (witnessed by Harold Hawkins, AOGCC). Plug #4: 350 cu. ft. Permafrost "C" downsqueezed thru 9-5/8" X 13-3/8" casing annulus and displaced to 1500' with- mud CIP 5:15 PM 4-24-85. Plug #5: 93 cu. ft. Permafrost "C" circulated to surface in 9-5/8" X 13-3/8" annulus and 9-5/8" casing thru perforations in 9-5/8" casing at 140' MD (approx. 105' below surface): After final surface cement plug in place welded steel plate over casing stubs. Bead- welded the following on cover plate (see pictures attached): Texaco ADL 355037 Colville Delta #1 KWK:bjs 1029' N & 1599' E of SW corner of Sec. 17, T13N, R7E, UM 14.I hereby certify that the foregoing is tru and correct to the best of rev knowledge. Signed . C:s._ .5 1. -/FGA Title District Manager _ Da„ 5/20/85 The space below for Commission use Conditions of Approval,if any: By Order of I Approved by COMMISSIONER the Commission Date Form 10403 Submit"Intentions'in Triplicate Rev.7-1-Ba - , and"Subseguenl Reportf"'in Duplicate t r • STATE 01=ALASKA 'ALASKA .40 GAS CONSERVATION C ✓1ISSION �'►` MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1.Drilling well Workover operation O 2.Name of operator 7.Permit No. Texaco Inc. `• 84-149'/85-65 l/lyf 3.Address 8.API Number 550 W. 7th Ave.L#1320, Anchorage, Alaska 99501 50- 103-20038--'1I 4.Location of Well 9.Unit or Lease Name /1 at surface 1029' North and 1599' East from the southwest Colville Delta corner of Section 17, T13N, R7E, U.M. Straight hole. 10.Well No. BHL: 748' North and 1181' East of Southwest corner of #1 A (R/D #1) and Pool Section 17, T13N, R7E, U.M. 11.Field Exxplplorraa Etory 5.Elevation in feet(indicate KB,OF,etc.) 6.Lease Designation and Serial No. KB is 35.5' above sea level ADL 355037 For the Month of April ,1 g 85 12.Depth at end of month,footage dulled,fishing jobs,directional drilling problems,spud date,remarks After completion and abandonment of the cased hole drill stem test intervals a window was cut in the 9 5/8" casing from 4730' to 4788'. 235 cuft class "G" cement was laid accross the window and on 4-11-85 the hole was kicked off to the above BHL. 81/2' hole was drilled and cored to 6640' MD (6437' TVD). 1910' drilled during month of April 85. 13.Casing or liner run and quantities of cement,results of pressure.tests None - No new casing strings. / qtp G;, yp 14.Coring resume and brief description J c ALL CORING DURING MONTH WERE TAKEN FROM 81" O.H. SECTION OF REDRILL #1 �yE, Core #3: (First two cores in original hole): 6255' to 6266'; recovered 8'; shale. Core #4: 6266' to 6292'; recovered 30.5' (11/2 fill), shale, fine sandstone, siltstone and claystone. (See Attached) 15.Logs run and depth where run 81" O.H. logs from 6630' to 4724': DIFL/SP/GR/CAL/DT-BHC Acoustilog and CN/CDL/GR. pa r1 L n o:—!1""-•p> 16.DST data,perforating data,shows of HaS,miscellaneous data a DST #7 and 7A. 6158' to 6226' of original 9 5/8" cased hole (u8 ea' t4 HPF'): RA'6/ered 2 bbls mud and oil with N2 lift, then fractured and recovered 1003 bbls of fluid (336 bbls diesel, 637 crude oil). DST #8: In 81/2' open hole of redrill from 6288' to 6545', open hole straddle-pack DST. No recovery. 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED r L — District Manager DATE 5-17-85 NOTE--Report on this form is required for each lender month,regardless of the status of operations,and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month,unless otherwise directed. Form 10-404 Submit in duplicate . Rev.7-1-80 . . 11111 Alaska Oil and Gas Conservation Commission Monthly Report of Drilling and Workover Operations, Colville Delta #1, April„ 1985 #14. (Continued) Core #5: 6292' to 6322'; recovered 30' fine sandstone, siltstone and claystone. Core #6: 6322' to 6349'; recovered 261/2' of fine sandstone, siltstone and claystone. Core #7: 6349' to 6388'; recovered 38" of fine sandstone, siltstone. Core #8: 6388' to 6449'; recovered 61' of sandstone and siltstone. Core #9: 6449' to 6481'; recovered 29' of fine sandstone and siltstone. Core #10: 6481' to 6546'; recovered 60' of fine sandstone and siltstone. (Complete core description to follow). RECEIVED MAN'. ,, Ha us flans. l;onniiissian h.l'iC Yor Lige MEMORA•UM State of Alask• ALASKA OIL AND GAS CONSERVATION COMMISSION TO. C. Vet. .tterton DATE' April 30, 1985 Chai y 0 FILE NO: D.HRH.31 THRU: Lonnie C. Smith / TELEPHONE NO: Commissioner FR°"': Harold R. Hawkins / SUBJECT: Witness PSA Petroleum Inspector : ? Texaco Inc., Colville Delta No. 1-A Surf. Loc. 1,029' N, 1,599' E, SW Cor., Sec. 17, T13N,R7E,UM, Bottomhole 550' N, 1,120'E, SW Cor., Sec. 17, T13N,R7E,UM. Tuesday, April 23, 1985: I left ARCO's Kuparuk Well No. 3B-3, subject of another report, to Texaco's Colville Delta 1-A to witness a P&A. I was to witness the balance plug set from open hole at the West Sak formation at 4,910' up to and inside the 9 5/8" casing at 4,630'. The balance plug was placed at 3:30 pm, with 350 sacks 15.8 lb Class "G", 2% CaC12, 3/4% CFR2. We waited on cement to set up eight hours. Wednesday, April 24, 1985: I witnessed the top of the cement plug tagged at 4,273' at 12:45 am. This plug was 457' up inside 9 5/8" casing from open hole. I filled out an AOGCC report which is attached. In summary, I witnessed the successful plug from 4,910' in open hole at the West Sak up to 4,273' inside the 9 1/8" casing for Texaco Inc. Attachment • '). 0,001A(Rev.101]91 S O&G #6 STATE OF ALASKA 4/80 AL7� s OIL & GAS CONSERVATION COMMI� iN Plug & Abandonment Report CDate Aig/i4 2/f,/9Y5 Operator 7-F x LMO re) /i it Well I`6 viz L A(' ,01:1 T/- juJ C/� < i%4 �/o Company Repr � y'Of/ Drilling Permit # ff - Lease No. Well No. ,..Z -/4 Sec. T-R ,56' /7)r//3/5)R7 / V/.1 Total Depth Elevation Mud Wt. /3; sr--- Casing:Casing: Drive Pipe "O.D. Set at Ft. w/ Pene. Conductor "O.D. @ Ft. Surface "O.D. @ - Ft. Intermediate 1�/"O.D. @ A/7;62 Ft. Production "O.D. @ Ft. Plugging Data: jJ ^7 1. Open hole plugs: T Y J Q V/' _TQ -4/ 2. 73 / J� / / _ . G -7 f/- Oa' a A/ 0 /. rASV.° a, /NW 9 2. Open hole isolation plug: 3. Perforation plugs (if any): • 4. Annulus plugs (if any): 5. Casing stub plugs: 6. Surface plug: Casing removal: "casing cut at "casing cut at "casing cut at REMARKS: 7-111.1 Q A,. f 4114 / s AL f Ld/Tiltff .e r/T/J figdTE[T. Inspector/s: ‘9,1,/y14"te CON $ ENTJ I L • ~ CONFIDEN l IA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION tWEp❑ ❑ ❑ WELL COMPLETION ORer ❑ Abandoned ❑ RECOMPLETIONnREPORT dedIl I AND LOG la.Well Staas ass: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory Q GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: One Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number. Pioneer Natural Resources Alaska,Inc. Abend.: 4/13/2012 212-008/312-106/312-118 3.Address: 700 G Street,Suite 600 8.Date Spudded: 13.API Number: Anchorage,AK 99501 3/9/2012 50-703-20654-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4581'FSL,1170'FEL,Sec. 16,T13N,R7E,UM 3/30/2012 Sikuml-1 Top of Productive Horizon: 8.KB(ft above MSL): 39,54' 15.Field/Pool(s): 4574'FSL,1229'FEL,Sec. 16,T13N,R7E,UM GL(ft above MSL): 5.9' Total Depth: 9.Plug Back Depth(MD+TVD): Undefined 4574'FSL, 1229'FEL,Sec.16,T13N, R7E,UM 67'MD/67'TVD 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 18.Property Designation: Surface: x- 459258.00 y-6027468.00 Zone-Asp 4 8500'MD/8499'ND ADL 355037 TPI: x- 459198.45 y- 6027461.31 Zone-Asp 4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 459198.45 y-6027461.31 Zone-Asp 4 N/A 417497 18.Directional Survey: Yes d No ❑ 19.Water Depth,If Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 MC 25.050) N/A (ft MSL) 909'MD/909'TVD 21.Logs Obtained(List all logs here and submit electronic and printed Information per 20AAC25.071): 22.Re-drill/Lateral Top Window MDfTVD: MWD/LWD, DM,DGR, EWR,PWD,DDS,ALD, CTN,BAT N/A 23. _ CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 120' Surface 120' 20" Driven 51' 13-3/8" 68# BTC Surface 1945' Surface 1945' 16" 445 sx PF'L';250 sx Class'G' 59' 9-5/8" 40# HYD 521 Surface 6363' Surface 6362' 12-1/4" 168 sx 12.5 ppg Class'G'; 160' 388 sx 15.8 ppg Class'G' 7" 26# BCM 6053' 6200' 6052' 6199' L-80 8-1/2" 975 sx Class'G' 3-1/2" 9.2# TC-I1 6200' 8490' 6199' 8489' 24.Open to production or injection? Yes Li No LJ If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top 8 Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MDITVD) N/A ZXP Flex III Liner Top Pkr @ 8053'MD/8052'ND None 28. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 200'-2000' 13-3/8"x 9-5/8"Annulus Cement Down-Squeeze w/Freeze Protect 265' Bridge Plug 67'-265' Surface Cement Plug w/150 sx PF'C' 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for '011-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period m..0. Flow Tubing Casing Press: Calculated 011-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate y 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No❑' Sidewall Cores Acquired? Yes ❑ No❑✓ If Yes to either question,Ilst 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 MC 25.071. None Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only • • COF1BEMT1 M. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Q Yes E No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top 637' 637' needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1546' 1546' West Sak 2057' 2057' Cret Tuff 2726' 2726' Hue 2 Shale 3090' 3090' Refer to attached document: Brook 2B 4194' 4193' Intertek Top Torok 4900' 4899' "Bottom Hole Sample Validation Study",dated 05/08/12 Top HRZ 5735' 5734' Nuigsut 6111' 6110' Sag River 7387' 7386' Ivishak 7760' 7759' Kavik 8442' 8441' Formation at total depth: 8500' 8499' 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: Dustin Bruce, 343-2173 Printed Name: Dustin Bruce Title: Exploration Project Engineer Slgnature:kit ;yl �1. �00 1 �/�US1I/4 b U - Phone: 343-2173 Date: 5/13/2012 Well Name:Sikumi 1 ff Perm! No.:212-008" /312-106/312-118 Prepared By:Kathy Campoamor,343-2183 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design Is changed. Item 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 12/2009 • • Sikumi #1 P&A Schematic Mud Line Cut 13-3/8"casing &20"conductor 5' --'� below ML(59'&51' rkb) CONpn O `'':'`ti`::::•::: Set CIBP @ 265' £111,? r Cut 9-5/8"casing @ 160' rkb. 9.8 ppg Brine -s ' Set 200'plug in 9-5/8" (100'inside�' 9- 5/8"casing, 100'above cut) I TOC @-60' rkb 11-______. 13-3/8"surface casing cemented to F surface (03/18/12) 0 .. .... :c ti < 1 13-3/8"x 9-5/8"annulus down 10.5 ppg drilling fluid . a 1 "-� squeezed from 200'to 2,000' (03/27/12) a) c co 9-5/8"intermediate casing cemented a to 4,300' (03/26/12) a la o Casing/Tubing Top Bot Item # Item MD(ft) TVD(ft) 1 20"94# H40 Conductor: 19.124"ID(18.936"Drift) 0 120 2 I3-3/8"68#L-80 BTC(12.25"ID,12.25"Drift): 16" 0 1,945 i`i'iiii..0 3 9-5/8"40#L.80 Hydril 521(8.835"ID,8.679"Drift):12-1/4" 0 6,362 04 7"26#L-80 BTC-M Liner(6.276"ID,6.151"Drift):8-1/2" - 6,053 6,199 0 5 3-1/2 9.3#L-80 TC-11(2.992"ID,2.867"Drift) 6,200 8,489 Misc. Well Equipment I Tools item # Item MD(ft) TVD(ft) 6 ZXP Flex III Liner Hanger/Top Plcr 6,053 6,052 0: PIONEERDate: Revision By: DBB Comments 03-26-12 Sikumi PM 05-13-12 KLC Sikumi Schematic-Final Sikumi #1 NATURAL RESOURCES ALASKA Well Schematic • • VD Ln � Ul � V) � � ci a) c-I a--I ei a-I e-I a'-1 e-I e-I N ! a o000 00 00 0N00000o c-I j E LL N N N N N N N N N co N N N N Le) N Ni co IV eN-I T—I eN-I cN—I ri eN-I 1--I e•-•1 1 a) u_ OJ _ a I 4A O O c 4 A E .... I O Cha N i ~ +�+ tv aL_+ 'i �N « .Y •"""'..,. I +r J .-• - ^ aJ Lvi ro Q) E 3 U U Q L V M as c a) •_c n' Q v v 0 COLc° 4_, a)` a+L O 3 a) Nco x c c�9 ` `� O N �O a. .0 N a) ▪ a) i M O v a•te-, 'V ..0 I- N r-I O ., �^ a 3 co Q v , CO o o o Co a) Al f° -o a co c "3 I° a) v a) co cr 0 Q E a L L OO• Y N a) „�, C L , L _c a ++ a) as O N▪ Q Oa O ICO-I cvL° to C 0 o = CO m m c V `� p� E QV +64- ''1 N - v) Q = In— O 0 L N c c s p i CU ++ ro O O s •0 +, -a t- r-, v E L p (° 3 3 v t° m o 0 Q • v u Q v -o a 00 Q � a`) a. 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Cr) 4 N v a v c N i a, � �� 0 V i z aH � LA z a a v a O o c o .c a, N Z O v •t cv) 0. 0 .a 1O ; o v, o ai V H ,., a Q +r a a o I �, 3 r CC 0 3 �, o v .� al c � I Q O -10 0a („D ,L) 0 ��, Z i 0 Ov I U Li, i trz, u a � aN c v n n . o 0ti N v to0 -. w ° �' 0 0^ z -0 L. 4. a 0 `a a 3 . co a 1,1 va 0' aIA go, C ` ou W 131 ti a o Q. y a v Hv o cv vc cQ v o � Ro ov o t c — 0 a a E 0 ; , to O Q • • Davies, Stephen F (DOA) From: Jack Kralick <Jack.Kralick@caelusenergy.com> Sent: Monday,January 11, 2016 9:51 AM To: Davies, Stephen F (DOA) Subject: RE: ODSN-22 (PTD#215-054, Sundry Application #315-753) -Application to Hydraulically Fracture - Requests Sorry Steve, We're trying to get info together. The individuals to do this were not available. We'll be getting back on this as soon as possible. Thanks, Jack From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, January 11, 2016 9:00 AM To: Jack Kralick Cc: Bettis, Patricia K (DOA) Subject: FW: ODSN-22 (PTD #215-054, Sundry Application #315-753) - Application to Hydraulically Fracture - Requests Jack, Following up: The application to hydraulically fracture ODSN-22 still lacks the information requested in my email dated December 29th, below. Please submit this information so that this application can continue through the AOGCC's review process. Thank you for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Tuesday, December 29, 2015 1:59 PM To: jack.kralick@caelusenergy.com Cc: Bettis, Patricia K(DOA) Subject: ODSN-22 (PTD #215-054, Sundry Application #315-753) -Application to Hydraulically Fracture - Requests Jack, 1 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday,January 11, 2016 9:00 AM To: jack.kralick@caelusenergy.com Cc: Bettis, Patricia K(DOA) Subject: FW: ODSN-22 (PTD#215-054, Sundry Application#315-753) -Application to Hydraulically Fracture - Requests Jack, Following up: The application to hydraulically fracture ODSN-22 still lacks the information requested in my email dated December 29th, below. Please submit this information so that this application can continue through the AOGCC's review process. Thank you for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F(DOA) Sent: Tuesday, December 29, 2015 1:59 PM To:jack.kralick@caelusenergv.com Cc: Bettis, Patricia K(DOA) Subject: ODSN-22 (PTD #215-054, Sundry Application #315-753) -Application to Hydraulically Fracture - Requests Jack, I'm reviewing Caelus's Sundry Application to hydraulically fracture ODSN-22,and I have a few questions and requests that I've consolidated into a single email. 1. Did Caelus provide Eni with a copy of the Notice of Operations? 2. Please provide the final directional survey for the well in either ASCII table or Excel spreadsheet format. 3. Please provide a copy of the digital well log data (specifically gamma ray,SP(if available), caliper, resistivity, and porosity) recorded in the well. 4. Please provide a list of fault-cuts (MD,TVDSS and vertical displacement)that have been observed within wells and well branches within and near the AOR. 5. Discuss any occurrences of lost circulation in those wells and well branches that occurred while drilling. 1 • 410 6. Please provide estimates of the horizontal distances from the ends of the projected fracture wings to any nearby faults. If any of these fracture wings are likely to intersect or even closely approach a fault, please discuss why that fault will not provide a pathway for injected fluids to migrate out of the pool. 7. Discuss the thickness and competence of the top seal for the Oooguruk-Nuiqsut Oil Pool within the AOR and how any faults within the AOR that cut this top seal will not affect the ability of that top seal to confine injected fluids to the pool. 8. Discuss any mitigation plans Caelus may have should any of the fracture wings appear to intersect a fault during fracturing operations. 9. Doesn't the Colville Delta No. 1 exploratory well(API 50-103-20038-00-00)fall within the AOR for ODSN- 22? How about any other older exploratory or delineation wells? If so, please provide casing and cementing records,an analysis of well integrity and cement isolation,fault-cut information, and fracture-wing distances for this well (or these wells)too. Thank you for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 • • Davies, Stephen F (DOA) From: Davies, Stephen F(DOA) Sent: Tuesday, December 29, 2015 1:59 PM To: jack.kralick@caelusenergy.com Cc: Bettis, Patricia K(DOA) Subject: ODSN-22 (PTD#215-054, Sundry Application#315-753) - Application to Hydraulically Fracture - Requests Jack, I'm reviewing Caelus's Sundry Application to hydraulically fracture ODSN-22,and I have a few questions and requests that I've consolidated into a single email. 1. Did Caelus provide Eni with a copy of the Notice of Operations? 2. Please provide the final directional survey for the well in either ASCII table or Excel spreadsheet format. 3. Please provide a copy of the digital well log data(specifically gamma ray,SP(if available), caliper, resistivity, and porosity) recorded in the well. 4. Please provide a list of fault-cuts (MD,TVDSS and vertical displacement)that have been observed within wells and well branches within and near the AOR. 5. Discuss any occurrences of lost circulation in those wells and well branches that occurred while drilling. 6. Please provide estimates of the horizontal distances from the ends of the projected fracture wings to any nearby faults. If any of these fracture wings are likely to intersect or even closely approach a fault, please discuss why that fault will not provide a pathway for injected fluids to migrate out of the pool. 7. Discuss the thickness and competence of the top seal for the Oooguruk-Nuiqsut Oil Pool within the AOR and how any faults within the AOR that cut this top seal will not affect the ability of that top seal to confine injected fluids to the pool. 8. Discuss any mitigation plans Caelus may have should any of the fracture wings appear to intersect a fault during fracturing operations. 9. Doesn't the Colville Delta No. 1 exploratory well (API 50-103-20038-00-00)fall within the AOR for ODSN- 22? How about any other older exploratory or delineation wells? If so, please provide casing and cementing records,an analysis of well integrity and cement isolation,fault-cut information, and fracture-wing distances for this well (or these wells)too. Thank you for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 1 • 0 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable b direct inspection of the file. c: rg- O5ij-. Well History File Identifier Organizing(done) ❑ Two-sided E Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: s: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: CO- /S /s/ of Project Proofing BY: MOSDate: 13 i $ /s/ 16(P 1 Scanning Preparation x 30 = q 0 + a. = TOTAL PAGES 701.1 ` Count does not include cosheet) BY: ACM Date: /J /s/1 Vy Production Scanning 9 Stage 1 Page Count from Scanned File: 73 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: deM Date: a I L /5 ' /s/ (VP / 7 T Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 0 NO TOTAL PAGES: V J Digital version appended by: MeredithlA6Michal Date: 9/314(is- Is/ Final Page Count: Stage I + Stage 2: TOTAL PAGES: 1, 4.6 a., Scanning is complete at this point unless rescanning is required. 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G ~ N N N N N N C ' re Ty in CO CO CO (C (C) (o W E n I O d N N N N N N N m0) O W N 4) a 4) cc 0 C u) E N •> E a 4) •E CO E '',U z0 m Y H 0 0 6 c o N III o Z Q o cc 2 Z o o w-+ C C N U U U U U U N .0 - J N aa)i •a a) @ U h U O ° o 0. a E a �O IL 2 4) EE Q a 2 LU OW LU °W WW 3 z o a 0 0 0 C 0 0 21 5054 26226 cE CAEL1JS LETTER OF TRANSMITTAL "9A9°2o s K.BENDER Alaska RECEIVEL SEP 03 Ui AOGCC DATE: September 1, 2015 FROM: TO: Shannon Koh AOGCC Caelus Energy Alaska Attn: Meredith Guhl 3700 Centerpoint Dr., Suite 500 333 W. 7th Avenue, Suite 100 Anchorage, AK 99503 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter [' Maps CD-R II Other— Logs Agreement DETAIL QTY DESCRIPTION ODSN-22 (API: 50-703-20708-0000) 1CD Digital Graphic Logs. Digital Log Data, Definitive Survey 4 Logs DGR, PCG, EWR-Phase 4, ADR, ALD, CTN, Invert/Revert Presentation (1:600, 1:240) ROP, DGR, PCG, EWR-Phase 4, ADR, ALD, CTN, Horizontal Presentation (1:600, 1:240) Received by:PJ (i) 6_60.4Date: Please sign 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.koh(�caelusenergy.com 21 5054 16031 CAELIJ S LETTER OF TRANSMITTAL 'Energy Alaska DATA LOGGED 7 i11i2oiS :.i.K.BENDER RECEIVED JUL 08 2U1t AOGCC DATE: July 6, 2015 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 CD-R [ Other— Logs, report ❑ Agreement DETAIL QTY DESCRIPTION Well Name: ODSN-22 (50-703-20708-0000) 1 Report Surface Data Logging—End of Well Report 4 Well Logs Surface Data Logging-2" MD Gas Ratio Log, CVE g 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) Received by:"Lget-fruk.4) Date: Please sign 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.koh(a�caelusenergy.com RECEIVFO JUN 23 2O1a STATE OF ALASKA Aflfl(ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil - Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.1 10 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: Caelus Natural Resources Alaska,LLC Aband.: . 6/2/2015 215-054 • 3.Address: 7. Date Spudded: 15.API Number: 3700 Centerpoint Drive,Suite 500,Anchorage,AK 99503 .4/5/2015 50-703-20708-00-00- 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2908'FSL, 1204'FEL,Sec. 11,T13N, R7E,UM .5/24/2015 ODSN-22 Top of Productive Interval: 9. KB(ft above MSL): 56.2 17.Field/Pool(s): 5217'FSL,4150'FEL,Sec. 16,T13N, R7E,UM GL(ft above MSL): 13.5 Oooguruk-Nuiqsut Oil Pool . Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 3327'FSL,5099'FEL,Sec. 17,T13N, R7E,UM N/A ADL 355036/ADL 355037 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 469,793.67 y- 6,031,023.58 Zone- ASP-4 .22,208'MD/6,197'TVD 417497 TPI: x- 456,280.15 y- 6,028,120.44 Zone- ASP-4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- March 6,3132 y- 6,026,269.56 Zone- ASP-4 2,882'MD/2,002'TVD 1,107'MD/815'TVD 5.Directional or Inclination Survey: Yes (a si Ached) No ❑ 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A • 22.Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation testar,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary PC P G1 ci e 1 D D S Q. we., Q W D, Pc 81 fAB6 r PC.ci�Pc t)9-I f�L-D 1 cm) !3 PST cSvaAc- MAG e. ..l 7/t s 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16" 100.2# X-65 Surface 158' Surface 158' 24" Driven 11-3/4" 60# L-80 BTC Surface 6,548' Surface 3,211' 14-1/2" 931 sks(3.91 ft3/sk)PermL 9-5/8" 40# L-80 Hyd 6,391' 11,717' 3,158' 4,915' 12-1/4" 200 sks(1.17 yld)Prem G 521 _ 7" 26# L-80 BTC-M Surface 15,699' Surface 6,077' 8-3/4" 365 sks(1.17y1d)Prem G 255 sks(1.0y1d)Prem G - ' - 4-1/2" 12.6# C-110 Hyd 15,430' 22,204' 6,054' 6,197' 6-1/8" Uncemented 521 24.Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation Size SIZE DEPTH SET(MD) PACKER SET(MD/TVD) and Number): 4-1/2", 12.6#C-110 Hyd 15,485' 15,449'MD/6,055'TVD 521 119111MMIti 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. �; Was hydraulic fracturing used during completion? Yes I] No Ei ` Per 20 AAC 25.283(i)(2)attach electronic and printed information See attached DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period —♦ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate —► 7---(S--1 ark �)1���S Form 10-407 Revised 5/2015 17CONTINUED ON PAGE 2 RBDMS JUL - 1 2015 ORIGINIAL only G 28.CORE DATA Conventional Core(s): Yes Li No El Sidewall Cores: Yes No 0 If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No E Permafrost-Top 870' 853' If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1977' 1668' Attach separate pages to this form, if needed,and submit detailed test Ugnu D 2090' 1721' information, including reports,per 20 AAC 25.071. Top West Sak 3720' 2283' Cretaceous Tuffs 5386' 2820' Brookian 2B 9663' 4237' Top Torok Sand 11835' 4955' Torok 1 Shale 13006' 5341' Top HRZ 14242' 5751' Base HRZ 14643' 2880' Kalubik Marker 14865' 5950' Top Kup C Not Present Not Present LCU 15018' 5996' BCU 15270 6040' Top Nuiqsut 15647 6073' Formation at total depth: 22208' 6197' 31. List of Attachments: Summary or daily operations,well schematic diagram, Definitive survey(s),casing cementing reports Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kimberly Pape Email: kimberly.pape(a,caelusenergy.com Printed Name: Kimberly Pape Title: Engineering Analyst Signature: Phone: 343-2130 Date: (42.0N INSTRUCTIONS General: This form and the)equired attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each Item 1b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection, Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and Form 10-407 Revised 5/2015 Submit ORIGINAL Only AOGCC Form 10-407 Well Completion Report Box 24 - Perforation Locations Well: ODSN-22 Top(MD) Bottom(MD) Length (ft) Top (TVD) Bottom (TVD) 4-1/2" RapidStage Sleeve#11 16,087 16,090 2.95 6,111 6,112 4-1/2" RapidStage Sleeve#10 16,690 16,692 2.71 6,134 6,134 4-1/2" RapidStage Sleeve#9 17,265 17,268 2.71 6,139 6,139 4-1/2" RapidStage Sleeve#8 17,842 17,845 2.71 6,146 6,146 4-1/2" RapidStage Sleeve#7 18,402 18,405 2.71 6,155 6,156 4-1/2" RapidStage Sleeve#6 19,048 19,051 2.71 6,164 6,164 4-1/2" RapidStage Sleeve#5 19,658 19,661 2.71 6,174 6,174 4-1/2" RapidStage Sleeve#4 20,113 20,116 2.71 6,180 6,180 4-1/2" RapidStage Sleeve#3 20,801 20,803 2.71 6,177 6,177 4-1/2" RapidStage Sleeve#2 21,359 21,362 2.71 6,179 6,179 4-1/2" RapidStage Sleeve#1 21,929 21,932 2.71 6,191 6,191 Eccentric Shoe 22,204 22,205 1.23 6,197 6,197 06-09-2015 ODSN-22 Nuiqsut Pi eduction Well Completion FINAL No. Upper Completion MD(ft) TVD(ft) Land Upper 1 Tubing Hanger 34 34 ..... .... :,:•: • 2 4-'/:"12.6#/ft C-110 Hydril 521 Tubing • Completion 1 3 4X"Halliburton'XXO'SVLN w/3.813""X"profile with singlel/4"x 0.049"s/s control line. 2882 2002 iii with 40,000 lbs Cannon Cross-coupling clamps on every joint w/15ft Pup BxP Top&Bottom 1 Slack-Off 4 4-''/z"12.6#/ft C-110 Hydril 521 Tubing 5 4-'/."x 1"GIM#3,KBG-4-5 Hydril 521 w/15ft Pup BxP Top&Bottom 3481 2206 iiIii i_p 6 4-'/,"12.6#/ft C-110 Hydril 521 Tubing(2 Joints) 4.5"FXE .• ••• 7 HES"X"Nipple 3.813"w/15ft Pup BXP Top&Bottom 3599 2245 Installed I • 8 4-%"12.6#/ft C-110 Hydril 521 Tubing I 16"Conductor 9 4%"u1"GLM#2,KBG-4-S Hydril 521 w/LSft Pup BxP Top&Bottom 8921 3995 I © •• 10 4-'/,"12.6#/ft C-110 Hydril 521 Tubing(2 Joi nts) Packer Fluid mix. 11 HES"X"Nipple3.813"w/15ft Pup BxP Top&Bottom 9040 4034 Inhibited Kit 12 4-'A"12.6#/ft C-110 Hydril 521 Tubing I weight Brine 13 4-A"x1"GLM#1,KBG-45 HydriI 521w/15ft Pup BxP Top&Bottom 14390 5800 GLM#3 14 4-'/:"12.6#/ftC-110 Hydril 521 Tubing iiiii with 2000'TVD • DGLV O GL '1.1 15 HES"X"Nipple 3.813"w/15ft Pup BxP Top&Bottom 14509 5838 Installed I diesel cap 16 4-A"12.6#/ft C-110 Hydril 521 Tubing 7,000 psi� 17 4-1/2"Halliburton'ROC'Gauge Carrier w/Encapsulated e-line to Surface w/15ft Pup BxP Top& 14657 5884 Max rated�J 'x'I 11-3/4"60#L-80 Bottom I .. BTC Surface Casing is 4-/12.6#/ft C-110 Hydril 821 Tubing(2jts) ' @ 6,548'MD/ 41/2"APCV II Non-Eiastomeric Sliding Sleeve,125ksi Frac Harden Body&Inner Sleeve 3.813" ilii: i 3,211'TVD 19 PQXProfile W/41/2"12.60#Hyd 521Box XPin,Opens Up,10,000Psi w/15ftPup BxP Top& 14757 5916 Bottom cemented to surface 20 4-A"12.6#/ft C-110 Hydril 521 Tubing(2jts) I 21 HES XN 3.813"(3.725"NoGo)-w/15ft Pup BXP Top&Bottom 14867 5951 22 4-%"12.6#/ft C-110 Hydril 521 Tubing ' 4-1/2"x4"Crossover P-110 Locator with a 5.66'long 4-1/2"handling pup on top,4"Spacer Pup w/ • TOC • Estimated 23 Bullet Seal Assembly+Auto Entry Guide Shoe 15449 6055 GLM#2 I Bottom of Shoe 15485 6058 DGLV @ 500 ft Installed 0 GL J above 9-5/8" No. Lower Completion MD(ft) TVD(ft) 7,000 psi I Shoe 24a 20 ft 5.25"Tie Back extension 15430 6054 Max rated x E I Baker 5"X 7"ZXP Liner Top Packer with Flex Lock Hanger/20 ft 4.25"Seal Bore Recepticle 24b 15449 6055 Below Hanger I 9-5/8"40#L-80 • 25 4-%"12.6#/ft Hydril 521 C-110 Liner • I Hydril 521 26 Resman Internally Vented Carrier#4 ROS-1368/RWS-1395 w/15ft Pup BxP Top&Bottom 15,691 6076 • • I Intermediate 1 27 4-A:"12.6#/ft Hydril 521 C-110 Liner 1 Casing Halliburton Swell Packer#13(4-A"Hydril 521)OD5.85'-9 meter long oil activated with Slide on 01 © 11,717' MD/ 28 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 15,771 6,083 1 i ''" Volant Centralizer on Top of Swell Packer i :ligi 4,915'TVD Halliburton Swell Packer#12(4-A"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on 29 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 15,815 6,086 GLM#1 . I f Volant Centralizer on Top of Swell Packer DGLV ES Cementer Y: 30 4- "12.6#/ft Hydril 521 C-110 Liner Installed® Base Torok HLB 4-1/2"RapidStage Ball Actuated Sleeve#11(3.009 ball/2.95 Seat)w/15ft 4-1/2"P-110 Pup 4- 31 16,087 6,111 7,000 psi® 1/2"12.6#/ft P-110 Hydril 521 Box x Pin Max rated �x'I - 32 4-K"12.6#/ft Hydril 521 C-110 Liner I i Halliburton Swell Packer#11(4-%"Hydril 521)00 5.85'-9 meter long oil activated with Slide on 7"Stage 2 TOC 33 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 16,397 6,131 17 Ra�- ` Estimated Volant Centralizer on Top of Swell Packer Sliding - 34 4-%"12.6#/ft Hydril 521 C-110 Liner @ 500 ft above SleeveKB 4-1/2"RapidStage Ball Actuated Sleeve#10(2.925 ball/2.867 Seat)w/15ft 4-1/2"P-110 Pup • 00o Closed 00oTorok Sand 35 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin 16,690 6,134 (Up to Open) Package 36 4-75"12.6#/ft Hydril 521C-110Uner Halliburton Swell Packer#10(4-%"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on ® XN 37 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box xPin w/Slide On 16,975 6,135 Volant Centralizer on Top of Swell Packer 7"Stage 1 TOC ( 38 4-%"12.6#/ft Hydril 521 C-110 Liner Estimated 39 HLB 4-1/2"RapidStage Ball Actuated Sleeve#9(2.842 ball/2.786 Seat)w/15ft 4-1/2"P-110 Pup 4- 1/2"12.6#/ft P-110 Hydril 521 Boxx Pin 17,265 6,139 500 ft above 40 4-%"12.6#/ft Hydril 521 C-110 Liner uparuk 41 Resman Internally Vented Carrier#3 ROS-1367/RWS-1394 w/15ft Pup BxP Top&Bottom 17,391 6,142 42 4-A"12.6#/ft Hydril 521 C-110 Liner • 0 Halliburton Swell Packer#9(4-%"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on �� ?4 43 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 17,55+ 6,142 ik ,�,, Volant Centralizer on Top of Swell Packer Pi.: 44 4-%"12.6#/ft Hydril 521 C-110 Liner 'I.�/�\ 0 45 HLB 4-1/2"RapidStage Ball Actuated Sleeve#8(2.761 ball/2.706 Seat)w/15ft 4-1/2"P-110 Pup 4- 17,842 6,146 7"26# L-80 BTC-M \. 9 1/2"12.6#/ft P-110 Hydril 521 Box x Pin &Hydril 563 �/ i/'1, 3s 46 4-'/,"12.6#/ft Hyd ri 1521 C-110 Liner Intermediate 2 i as a s1 ss s7 Cps ss 6s 71 7s 7s RI Ed a3 Casing �r1. ® ® b� @ 15,699'MD/ 28 ®,� - - - - - - - " /r -II -I I-I - - I-I - . - - 6,077'TVD IyI 35 39 a1- _011_0_.5C)-- 59 --® 63 ®- 67 ----®- 73 -CI 0101 81 4-Y2" Hydril 521 /C-110 Liner with Halliburton Ball Actuated 6-1/8" Hole TD Sleeves, & Swell Packers @ 22,208 MD/ 6,197'TVD 06-09-2015 ODSN-22 Nuiqsut Production Well Completion FINAL No. Lower Completion MO(ft) TVD(ft) Land Upper Halliburton Swell Packer#8(4-x"Hydril 521)OD 5.85'-9 meter long oil activated with ..az- Completion 47 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On with 40,000 lbs Volant Centralizer on Top of Swell Packer Slack-Off 48 4-%"12.6#/ft Hydril 521 C-110 Liner HLB 4-1/2"RapidStage Ball Actuated Sleeve#7(2.681 ball/2.628 Seat)w/15ft 4-1/2"P-110 Pup 4- I� I 49 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 18,402 6,155 4.5'EE~ Ins** I 50 4-A"12.6#/ft Hydril 521 C-110 Liner i ii I 16"Conductor Halliburton Swell Packer#7(4-34"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on ii•::E .M. • 51 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 18.1 t 1,, 111111 I .k Packer Fluid mix: Volant Centralizer on Top of Swell Packer Inhibited Kill 52 4-x"12.6#/ft Hydril 521 C-110 Liner weight Brine 53 HLB 4-1/2"RapidStage Ball Actuated Sleeve#6(2.603 ball/2.552 Seat)w/15ft 4-1/2"P-110 Pup4 19,048 6,164 GLM#3 with 2000'TVD 1/2"12.6#/ft P-110 Hydril 521 Box x Pin _ I DG Vd0 I • diesel cap 54 4-A"12.6#/ft Hydril 5210-110 Liner 55 Resman Internally Vented Carrier#2 ROS-1366/RWS-1393 w/15ft Pup BxP Top&Bottom 19,117 6,165 7,000 psi 7 56 4- "12.6#/ft Hydril 5210-110 Liner Max rated� x 11 3/4"60#L St) Halliburton Swell Packer#6(4x"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on iii N BTC Surface Casing 57 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 19,358 6,169 iiii 1111 @ 6,548' MD/ Volant Centralizer on Top of Swell Packer : 3,211'TVD 58 4-x"12.6#/ft Hydril 521 C-110 Liner cemented to surface 59 HLB 4-1/2"RapidStage Ball Actuated Sleeve#5(2.527 ball/2.477 Seat)w/15ft 4-1/2"P-110 Pup 4 19,658 6,174 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 60 4-A"12.6#/ft Hydril 521 C-110 Liner " TOC Halliburton Swell Packer#5(4-x"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on . Estimated 61 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On GLM#2 Volant Centralizer on Top of Swell Packer DGLV @ 500 ft 62 4-x"12.6#/ft Hydril 521 C-110 Liner Installed 0 I above 9-5/8" HLB 4-1/2"RapidStage Ball Actuated Sleeve#4(2.452 ball/2.404 Seat)w/15ft 4-1/2"P-110 Pup 4- ■ 63 20,113 6,180 7,000 psi I Shoe 1/2"12.6#/ft P-110 Hydril 521 Box x Pin Max rated m I 64 4-x"12.6#/ft Hydril 521 C-110 Liner I 9 5/8"40#L 80 Halliburton Swell Packer#4(4'/:"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on I Hydril 521 65 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On • Volant Centralizer on Top of Swell Packer Intermediate 1 66 4:A"12.6#/ft Hydril 521 C-110 Liner Casing HLB 4-1/2"RapidStage Ball Actuated Sleeve#3(2.379 ball/2.332 Seat)w/15ft 4-1/2"P-110 Pup 4 111 Ili @ 11,717'MD/ 67 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 20,801 6,177 4,915'TVD 68 4-''A"12.6#/ft Hydril 521 C-110 Liner 69 Resman Internally Vented Carrier#1 ROS-1365/RWS-1392 w/15ft Pup BxP Top&Bottom 20,994 6,178 GLM#1 M I 70 4-1A"12.614/ft Hydril 521 C-110 Liner DGLV I ES Cementer Halliburton Swell Packer#3(45"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on Installed® e Base Torok 71 Volant Centralizer Pin End and 6ft Pup 41/2"12.6#/ft P-1.1.0 Hydril 521 Box x Pin w/Slide On 21,073 6,178 7,000 psi® - : Volant Centralizer on Top of Swell Packer Max rated : I : 72 4-A"12.6#/ft Hydril 521 C-110 Liner 7"Stage 2 TOC 73 HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.307 ball/2.261 Seat)w/15ft 4-1/2"P-110 Pup 4 21,359 6,179 9 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 7 Estimated 74 4-%"12.6#/ft Hydril 521 C-110 Liner Sliding1/4• @ 500 ft above Halliburton Swell Packer#2(4'/:"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on Sleeve Torok Sand 75 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 21,596 6,183 Closed is M (Up to Open) . Package Volant Centralizer on Top of Swell Packer 76 4-A"12.6#/ft Hydril 521 C-110 Liner ® 77 HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.236 ball/2.192 Seat)w/15ft 4-1/2"P-110 Pup 4- 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 21,929 6,191 'stimated tage 1 TOC 78 4-x"12.6#/ft Hydril 5210-110 Liner Halliburton Swell Packer#1(4-34"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on 00 ft above 79 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On Kuparuk Volant Centralizer on Top of Swell Packer 80 4-x"12.6#/ft Hydril 521 C-110 Liner 81 Pre-perforated Pup w/445"12.6#/ft Hydril 521 w/15ft 4-1/2"P-110 Pup BxP Top&Bottom 22,147 6,195 82 4-A"12.6#/ft Hydril 521 C-110 Liner ® 83 4-34"Hydril 521 Eccentric Shoe with Float Collar 22,204 6,197 Bottom of Assembly 22,205 6,197 7"26# L-80 BTC-M1:;::. \. zs &Hydril 563 'iii �^ ��4% 33 IntermediateCasi2 �® ,i 37 a3 a7 si ss s7 CD ss se P 7s e3 Fil @ 15,699'MD/ 6-, ®,. _ = ® _ _ ® _ isa ( CD/� _ _ 6,077'TVD _ _ _ _ _ _ _ _ • y) 35 9 41 -- 45 ®- 49 -� s3 __ 59 _® 83 ®O ®- 73 -P+t 4101. 81 4-1/z" Hydril 521 /C-110 Liner with Halliburton Ball Actuated 6-1/8" Hole TD Sleeves, & Swell Packers @ 22,208 MD/ 6,197'TVD Operations Summary Report- State Well Name: ODSN-22 CC- CAELUS F 1.0,y Ataska Well Name: ODSN-22 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: ORIG DRILL&COMPLETE Start Date: 4/3/2015 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 4/3/2015 4/4/2015 0.0 MIRU f/ODSN-3i U ODSN-22.N/U surface annular preventer.Begin R/U diverter line. ***Rig Accepted on ODSN-22 from ODSN-03ii 4-03-2015.*** ***AOGCC representative Bob Noble waived witness of diverter test on 4-3-15 @ 07:30 pm*** 4/4/2015 4/5/2015 158.0 0.00 8.80 P/U 201 Jts 5"DP,14 Jts 5"HWDP&stand back in derrick.Transfer 600 bbls 8.8 ppg spud mud toRig pits.Slip&Cut Drilling Line.Function test diverter&knife valve per AOGCC regulations. R/U Sperry Gyro.PJSM.P/U Clean Out BHA.Clean out conductor T/158'MD. Function test diverter&knife valve per AOGCC regulations. -Systems Pressure:3000 psi. i4 -Pressure After Closure:1800 psi. -200 psi Recharge Time:28 psi. -Full Recharge Time:158 psi. -Annular Closed Time:27 sec. -Knife Valve Open Time:8 sec. ***AOGCC representative Bob Noble waived witness of diverter test on 4-3-15 @ 07:30 pm.*** 4/5/2015 4/6/2015 158.0 1,199.00 9.00 Drill 14.5"Surface hole f/158'U 193'.POOH.P/U&M/U 14.5"Surface BHA.Drill f/193' U 1357'. Gyro surveys each connection to1006'. 4/6/2015 4/7/2015 1,357.0 1,263.00 9.25 Drill 14.5"Surface hole f/1357'U 2620'.Circ 3 x B/U.Backream out of hole f/2620' U 721'. 4/7/2015 4/8/2015 2,620.0 986.00 9.25 Backream out of hole f/721'U 160'.LID BHA#1,P/U BHA#2,TIH U 2,520'.P/U Ghost Reamer. Wash down from f/2,520'-U 2,620'.Drill 14.5"Surface hole f/2620' U 3606'. 4/8/2015 4/9/2015 3,606.0 1,380.00 9.30 Drill 14.5"Surface hole f/3606' U 4986'. 4/9/2015 4/10/2015 4,986.0 1,251.00 9.45 Drill 14.5"Surface hole f/4986' U 6237'. 4/10/2015 4/11/2015 6,237.0 321.00 9.30 Drill 14.5"Surface hole f/6237'U 6558'.(14.5"TD)Backream out of hole f/6558'U 6237'.BR 1st 3 stds while pumping 700 bbl dilution w/3 x B/U.Backream out of hole f/6237 U 2532'. L/D Ghost reamer.Backream out of hole ft 2532'U 2057'. POH on elevators f/2057'to 1758'. Pulled tight @ 1690'.Lubricate out of hole f/1758'U 253'. 4/11/2015 4/12/2015 6,558.0 0.00 9.30 LD 14.5"BHA#2 f/253'to Surface.Clear/clean rig floor.R/U to run 11.75"60#L-80 BTC surface casing.PJSM.RIH w/Jt#1 (Float Shoe Jt).While making up Jt#2,galled threads on pin end of Jt#2 and Box of Jt#1.CIO Jt#1  w/spare shoe track jts.M/U Secondary Shoe Track.Run 11 3/4"60#L-80 BTC-M casing U 1549'.Stacked up w/50K over. Rotate&pump through f/1549'U 2031'w/1 BPM,20 RPM.Run 11 3/4"60#L-80 BTC-M casing f/2031' U 2765'. ***Notified AOGCC for 48 hr.BOP test @ 14:00 hrs on 4/11/15.*** *AOGCC Rep.Jeff B.Jones waived witness of test 11 April 2015. 4/12/2015 4/13/2015 6,558.0 0.00 9.50 Run 11 3/4"604 L-80 BTC-M casing f/2765' U 6509'.Land casing in wellhead placing 11 3/4" shoe at 6548'.Verify hanger landed.Break circulation&stage pumps to 8 bpm.RD Tesco Casing tools. ***Notified AOGCC for 48 hr.BOP test @ 14:00 hrs on 4/11/15.*** *AOGCC Rep.Jeff B.Jones waived witness of test 11 April 2015. Page 1/9 Report Printed: 6/22/2015 Operations Summary Report - Stats Well Name: ODSN-22 CE CABLU S F<,cr-.9, Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 4/13/2015 4/14/2015 6,558.0 0.00 9.65 Finish R/D Tesco Casing tools.R/U HES Cement Head. Install cement lines.Circulate @ 5 bpm while holding PJSM with all involved in upcoming cement job.Line up to Halliburton. Pump surface cement as follows. -Pump 10 bbls Seawater(Dropped 1st Btm plug w/last 2.0 bbls pumped). -Test lines to 4000 psi, -Bled pressure and load top plug in cement head, -Pumped 100 bbls of 10.0 ppg Tuned Spacer III @ 5 bpm/640 psi. -Mix&Pump 931 sxs(648.3 bbls)11.34 ppg Lead Type"L"Permafrost cement w/3.91 yield @ 5 bpm/650 psi, -Shut down&drop 2nd Btm plug, -Mix&Pump total of 580 sxs(121.8 bbls)15.8 ppg Tail Premium"G"Cement w/1.1853 yield @ 5 bpm w/1100 psi.(Note;Shut down after pumping 59 bbls Tail cmt due to wash out on rig / cement line. R/U high pressure hose to by-pass line). l)� -Shut down&Drop top plug, -Displace with 20 bbls seawater followed by 713.2 bbls 9.3 ppg mud(Total of 733.2 bbls- Includes'Ashoe track)@ 8 bpm 1850 psi for first 600 bbls, --Slowed rate to 4 bpm-Lift pressure from 1080 psi to 1400 psi while Tail rounded shoe. --Slowed rate to 2 bpm for last 15 bbls in anticipation of bumping plug.Did not bump plug -Bleed pressure&check floats-Holding. -CIP @ 11:15 hrs. -Had 60.8 bbls good 11.0 ppg cement to surface. -Had good to fair returns w/total loss of 89 bbls to hole throughout cement job. -Monitor well for 30 minutes-Static -Drain&flush drilling riser&diverter stack. RD cement head&manifold.Clean&send down same.Pull landing joint Install 5"elevators. PU"Johnny Whacker"&flush risers&annular diverter. Clean under rotary table.Clean out flow box.Pump out stack.ND&set back annular preventer. Remove drilling nipple.Clean out knife valve&T riser.Begin unbolt knife valve. ***Notified AOGCC for 48 hr.BOP test @ 14:00 hrs on 4/11/15.*** *AOGCC Rep.Jeff B.Jones waived witness of test 11 April 2015. 4/14/2015 4/15/2015 6,558.0 0.00 9.60 Finish N/D Diverter system.NU BOPs.R/U to test BOPE. 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. /17*Test 14 choke manifold valves to 250 psi low 14500 psi high. *All tests charted and all tests held for 5 min. * All tests performed with fresh water *Initial system psi:3000;2000 after closure;200 psi=27 sec,full pressure 1 min.55 sec. ***Notified AOGCC for 48 hr.BOP test @ 14:00 hrs on 4/11/15.*** ***AOGCC Rep.Jeff B.Jones waived witness of test 4/11115.*** R/D&UD test tools.B/D lines.P/U&M/U Cleanout BHA#3 f/surface to 626'. P/U 171 jts of 5" DP f/pipe shed f/626'U 5950'.Service Top Drive.TIH w/stds from derrick f/5950'to 6330'. 4/15/2015 4/16/2015 6,558.0 20.00 10.00 Circulate bottoms up @ 6330'. Slip&cut drilling line. Calibrate top drive torque vs.load cell. _ Perform 3500 PSI pre.S.Syre test of 11-3/4"60#L-80 casing,hold for 30 min.&chart same-good z- test. Drill cement&11-3/4"casing shoe track f/6370'U 6548'. Displace f/9.6 ppg LSND U 10.0 ppg MOBM while drilling cement. Clean out 14-1/2"rat hole f/6548'U 6558'. Drill 20'of new 10- 5/8"hole f/6558'U 6578'. Circulate 2x bottoms up. Perform FIT U 12.5 Dog EMW w/10 n ppg MOBM @ 6548'MD/3211'TVD w/424 psi applied at surface. POOH f/6548'U 538'. UD BHA #3 f/538'U surface. Service rig. Begin picking up BHA#4 U 25',M/U Geo-Pilot to the bit. 4/16/2015 4/17/2015 6,578.0 370.00 10.00 P/U BHA#4,Geo-Pilot assembly w/RipTide reamer f/25'U 648'. TIH w/5"drill pipe out of the derrick while installing Cuttings Bed Impellers f/648'U 6578'. Drill 10-5/8"Intermediate#1 hole ft 6578'U 6709'. Obtain four MWD checkshot surveys. Pump down RFID opening tags to open RipTide reamer. Pull test reamer against the 11-3/4"shoe @ 6548'w/10K overpull to confirm blade opening. Drill 10-5/8"x 11-3/4"Intermediate#1 hole f/6709'U 6775'. Obtain five more MWD checkshot surveys. Drill 10-5/8"x 11-3/4"Intermediate#1 hole f/6775'U 6948'. Page 2/9 Report Printed: 6/22/2015 Operations Summary Report- State Well Name: ODSN-22 CAEI_LS F rCr';'y Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud db/gal) Summary 4/17/2015 4/18/2015 6,948.0 1,236.00 10.05 Drill 10-5/8"x 11-3/4"Intermediate#1 hole f/6948'U 8184'. 4/18/2015 4/19/2015 8,184.0 1,234.00 10.00 Drill 10-5/8"x 11-3/4"Intermediate#1 hole f/8184'U 9418'. 4/19/2015 4/20/2015 9,418.0 1,142.00 10.00 Drill 10-5/8"x 11-3/4"Intermediate#1 hole f/9418'U 10329'. Geo-Pilot appeared to not be rotating. During troubleshooting,Geo-Pilot resumed proper operation. Drill 10-5/8"x 11-3/4" Intermediate#1 hole f/10329't/10560'. 4/20/2015 4/21/2015 10,560.0 1,110.00 10.00 Drill 10-5/8"x 11-3/4"Intermediate#1 hole f/10560'U 10906'. Repair hydraulic hose on top drive. Drill 10-5/8"x 11-3/4"Intermediate#1 hole f/10906'U 11670'. 4/21/2015 4/22/2015 11,670.0 50.00 10.00 Drill 10-5/8"x 11-3/4"Intermediate#1 hole f/11670't/11720',TD of Intermediate#1 as picked by geology. Close reamer blades on Weatherford RipTide reamer. ***Perform weekly function test of BOP equipment as per AOGCC&PTD requirements.*** Perform Sperry quadrant ream f/11590'U 11720'while circulating eight bottoms up. Lubricate out of the hole w/low energy reaming f/11575'U 6750'. Lubricate into the shoe w/o rotation f/ 6750'U 6385'. Stage up the mud pumps f/84 GPM U 550 GPM. Shakers running over,so shut down to change shaker screens. 4/22/2015 4/23/2015 11,720.0 0.00 10.00 Finish staging up pump rate f/500 GPM U 750 GPM. Circulate 1.5x bottoms up. Backream in the 11-3/4"casing f/6385'U 3706'. Circulate 2x bottoms up. Continue to backream f/3706'U 648'. L/D BHA#4 f/648'U surface. P/U 18 joints of 5"HWDP,circulate HWDP volume and POOH&rack back in the derrick. Install 9-5/8"test joint&test plug. Change lower pipe rams f/ 2-7/8"x5"VBR U 9-5/8". ***Test 9-5/8"rams as per AOGCC&PTD requirements.*** -250 PSI low&4500 PSI high tests. -Tests held for 5 min.each&charted. -All test performed w/8.4 ppg seawater. 4/23/2015 4/24/2015 11,720.0 0.00 10.00 R/D test equipment. R/U to run 9-5/8"liner. Run 9-5/8"40#L-80 Hydril 521 liner f/surface U 2009'. Circulate lx bottoms up to condition mud. Run 9-5/8"404 L-80 Hydril 521 liner f/2009'U 4002'. Circulate lx bottoms up to condition mud. Run 9-5/8"404 L-80 Hydril 521 liner f/4002'U 5290'. R/D Tesco casing drive system&R/U hydraulic power tongs. M/U Baker 9-5/8"x11-3/4" Inline Liner Hanger Packer. R/D Tesco casing equipment. RIH w/Baker LHP f/5290'U 5325'. RIH w/9-5/8"404 L-80 Hydril 521 liner on 5"drill pipe f/5325'U 5448'. Fill pipe&obtain torque &drag values. 4/24/2015 4/25/2015 11,720.0 0.00 10.05 Pump 20 bbls through liner hanger packer assembly. Run 9-5/8"40#L-80 Hydril 521 liner on 5" drill pipe f/5448'U 6491'. Circulate the liner volume,401 bbls @ 4 BPM. Run 9-5/8"40#L-80 Hydril 521 liner on 5"drill pipe f/6491't17038'where the assembly stacked out. Wash/ream f/ 7038'U 7441'. Continue to run 9-5/8"40#L-80 Hydril 521 liner on 5"drill pipe f/7441'U 11602'. R/U cement head&lines then RIH f/11602'&tag bottom @ 11720'. P/U&place 9-5/8"liner shoe @ 11717'. Establish circulation f/0.5 BPM U 4.5 BPM&experienced a pack-off. Stage up from 0.5 BPM U 3 BPM. Set Baker 9-5/8"x11-3/4"Inline hanger. Establish circulation f/0.5 BPM U 2 BPM. 4/25/2015 4/26/2015 11,720.0 0.00 10.10 Continue to stage up pumps f/2 BPM U 4 BPM with 140 BPH losses. Reduce flow to 2 BPM while preparing for cement job. Perform 9-5/8"Intermediate 1 liner cement job. -Pump 65 bbls 11.0 ppg Tuned Spacer III,2.85 BPM,786 PSI. -Pump 41 bbls 15.8 Premium G cement,200 sks,1.17 yield,2.94 BPM,602 PSI. -Pump 20 bbls 8.5 ppg seawater,3.65 BPM,570 PSI. -Displace w/10.05 ppg MOBM w/rig pumps @ 4 BPM,1330 PSI. --Slow to 3 BPM,1230 PSI as spacer exited shoe @ 4120 stks. --Slow to 2 BPM, 1075 PSI as cement exited shoe @ 4830 stks. --Slow to 1 BPM,940 PSI for last 10 bbls of displacement as per Halliburton request. --Bumped plug @ 5623 stks.@ 04:53. -Pressure up to 3500 PSI,hold for 5 min.&chart same-good test. Bleed off pressure&check floats-holding. Set Baker 9-5/8"x11-3/4"ZXP packer. Pressure test packer to 3500 PSI for 5 min.&chart same-good test. Unsting from liner&circulate the 11-3/4"casing clean. POOH w/ Baker liner running tool. L/D Baker running tool. N/D BOP stack, riser&drilling spool adapter. N/U Vetco Gray Multi-Bowl wellhead. ***AOGCC notified at 16:48 on 25 April 2015 of upcoming BOP estimated to occur 12:30 on 27 April 2015.*** Page 3/9 Report Printed: 6/22/2015 I Operations Summary Report- State Well Name: ODSN-22 CC- CA.BLU S Fnc'ry;y Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud Ob/gal) Summary 4/26/2015 4/27/2015 11,720.0 0.00 10.20 Install riser&N/U BOP equipment. Install test plug&5"test joint. C/O lower pipe rams from 9- 5/8"to 2-7/8"x5"VBR. Test 2-7/8"x5"VBR as per AOGCC&PTD requirements. -250 PSI low&4500 PSI high tests. -Hold each test for 5 min.&chart same-good tests. -Both test performed against 5"test joint w/8.5 ppg seawater. R/D test equipment,pull test plug&install wear bushing. M/U BHA#5,8-1/2"mill tooth bit w/ mud motor to 504'. TIH w/117 singles of 5"drill pipe f/504'U 4207'. TIH w/5"drill pipe from the derrick f/4,207'U 11,325'. Wash down f/11329'U 11,585'&tag top cement plug on top of landing collar. Circulate lx bottoms up. Pressure up for 9-5/8"x11-3/4"liner/casing pressure test to 3500 PSI. Pressure test continues into the next report period. 4/27/2015 4/28/2015 11,720.0 20.00 10.20 Hold 3500 PSI for 30 min.for pressure test on 9-5/8"x11-3/4"liner/casing-good test. Drill 9-5/8" liner shoe track f/11,585'U 11,717'and cleanout 11-3/4"rathole f/11,717'U 11,720'. Displace wellbore from 10.2 ppg MOBM to 10.2 LSND mud. Drill 20'of new 8-1/2"hole f/11,720'U 11,740'. Circulate lx bottoms up. Perform FIT @ 9-5/8"shoe @ 11,717'MD/4,915'TVD. Apply 716 PSI @ surface w/10.2 ppg LSND mud for 13.0 ppg EMW FIT. POOH&L/D BHA#5. Prepare to perform bi-weekly BOP test. 4/28/2015 4/29/2015 11,740.0 0.00 10.20 Remove Vetco Gray wear bushing&install Vetco Gray test plug w/5"test joint. Test BOPE per AOGCC PTD:. *Test upper and lower 2-7/8"x5"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. *All tests performed with fresh water *Initial system psi:3000;1900 after closure;200 psi=27 sec,full pressure 2 min.08 sec. ***AOGCC notified of BOP test at 16:48 on 25 April 2015.*** ***AOGCC Inspector Johnnie Hill waived witness @ 15:59 on 26 April 2015. *** R/D test equipment&install wear bushing. M/U BHA#6 f/surface U 78'. Verify torque output of EZ-torque&found 28%discrepancy. Torque BHA components to correct torque w/top drive& iron roughneck. M/U remainder of BHA#6 f/78'U 604'. TIH w/BHA#6 f/604'U 10,573'. 4/29/2015 4/30/2015 11,740.0 1,060.00 10.20 TIH f/10,573'U 11,522'. Wash&ream f/11,522'V 11,740'. Drill f/11,740'U 11,850'. Open Riptide reamer&pull test w/10K overpull against 9-5/8"shoe. Ream 8-1/2"hole f/11,725' reamer depth U bottom. Drill the 8-1/2"x9-1/2"Intermediate#2 hole f/11,850'U 12,800'. 4/30/2015 5/1/2015 12,800.0 337.00 10.20 Drill the 8-1/2"x9-1/2"Intermediate#2 hole f/12,800'U 13,137'. Circulate 1x bottoms up. Lubricate w/rotation f/13,137'U 12,328'. Spot planned 68 bbls of 50 ppb LCD pill across the Torok sand&into the 9-5/8"casing shoe. Trip 12,328'U 11,428'on elevators into the 9-5/8" casing above the LCM pill. Perform LCM squeeze treatment by pressuring to 13.1 ppg EWM. Service rig&repair top drive handler lock. Slip&cut drilling line. Trip f/11,428'U 11,717'. Lubricate w/rotation into the hole f/11,717'U 13,137'. Stage up pumps to 600 GPM. 5/1/2015 5/2/2015 13,137.0 855.00 10.20 Circulate 5x bottoms up to condition mud. Remove MPD RCD&install trip nipple to investigate high ECD. Drill 8-1/2"x 9-1/2"Intermediate#2 hole f/13,137'U 13,232'. Remove trip nipple&re -install MPD RCD. Drill 8-1/2"x 9-1/2"Intermediate#2 hole f/13,232'V 13,992'. 5/2/2015 5/3/2015 13,992.0 729.00 10.20 Drill 8-1/2"x 9-1/2"Intermediate#2 hole f/13,992'U 14,372'. Began experiencing losses at 14,372'@ 60 bbls/hr. Continued to drill f/14,372'U 14,483'to place under reamer below the top of the loss zone. After losing 404 bbls,shut down to build more mud volume. Build 600 bbls of 10.2 ppg mud on the rig&at the RCS. Resume drilling f/14,483'U 14,721'. Losses decreased to 10 bbls/hr.after resuming drilling and are manageable. 5/3/2015 5/4/2015 14,721.0 760.00 10.25 Drill 8-1/2"x 9-1/2"Intermediate#2 hole f/14,721'U 15,038'. Observed a 482 PSI reduction in SPP indicating a washout. Formulate a plan to find the washout. POOH f/15,038'V 14,753' looking for the washout. The washout was found 285'below the rotary table. Replace washed out joint&trip back to bottom. Stage up pumps to the drilling rate. Drill 8-1/2"x 9-1/2" Intermediate#2 hole f/15,038'U 15,481'. Page 4/9 Report Printed: 6/22/2015 Operations Summary Report- State Well Name: ODSN-22 Co: AELL En rqy Alaska Start Depth EooVMeters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 5/4/2015 5/5/2015 15,481.0 245.00 10.20 Drill 8-1/2"x 9-1/2"Intermediate#2 hole f/15,481'U 15,709'. Stop drilling to change out top drive encoder. Drill 8-1/2"x 9-1/2"Intermediate#2 hole f/15,709't'15,726',the TD of the interval. Pump down RFID tags&close RipTide reamer. Perform Sperry Drilling quadrant ream procedure to enlarge the 8-1/2"hole beneath the under reamer while circulating the hole clean. Pumped a 25 bbl 12.2 ppg sweep while circulating a total of 6.5x bottoms up. Lubricate w/ rotation out of the hole while utilizing low energy parameters f/15,726'U 11,649'. Service rig while inside the 9-5/8"liner. 5/5/2015 5/6/2015 15,726.0 0.00 12.30 TIH f/11,649'U 15,726'. Stage up pumps utilizing the step rate method to 650 GPM. Circulate the hole clean prior to performing mud displacement. Pump 25 bbl 12.3 ppg(2.1 ppg over MW) high viscosity sweep and a total of 3.5x bottoms up at full rate. Displace wellbore from 10.2 ppg LSND to 12.3 ppg LSND. Stopped circulation w/12.1 ppg LSND at surface,performed flow check,then removed MPD RCD&installed the trip nipple. Completed displacement w/12.3 ppg back to surface. Lubricate w/rotation out of the hole f/15,276'U 11,649'. ***Perform weekly function test of BOP equipment as per AOGCC&PTD requirements.*** 5/6/2015 5/7/2015 15,726.0 0.00 12.30 Pull 5 stands on elevators f/11,649'U 11,174'on elevators. Good displacement&no swabbing. Pump dry job. POOH on elevators f/11,174'U 604'. L/D BHA#6 f/604'to surface. Change upper rams from 2-7/8"x5"VBR to 7". Test 7"rams against 7"test joint according to AOGCC&PTD requirements. -250 PSI low&4500 PSI high test. -Hold each test for 5 min.&chart same. -Tests performed with 8.5 ppg seawater. R/D test equipment. R/U Tesco casing equipment. Run 7"26#L-80 Hydril 563 casing from surface to 1675'. Fill 7"casing w/10.1 ppg LSND. 5/7/2015 5/8/2015 15,726.0 0.00 10.10 Run 7"26#L-80 Hydril 563 casing from 1675'to 14,242', Rotated 7"casing down f/14,243'U 14,276 w/20-30 RPM. Fill 7"casing w/10.1 ppg LSND. 5/8/2015 5/9/2015 15,726.0 0.00 10.10 Rotated 7"casing down f/14,276'U 15,699 w/25-30 RPM. Fill 7"casing w/10.1 ppg LSND. R/D Tesco Casing Drive System. R/U Halliburton cement head. Establish circulation utilizing the step rate method to 6 BPM. Just before initiating cementing operations,experienced a 1000 PSI pressure increase/pack-off. Attempt to re-establish full circulation unsuccessful--assumed packed-off at the HRZ. Zero to 20%returns was the best achievable. Perform 7"casing Intermediate#2 first stage cement job. -Fill lines&pump 10 bbls of 8.5 ppg seawater. -Test lines to 4500 PSI. -Pump 60 bbls of 11.5 ppg Tuned Spacer at 1 to 3 BPM. -Mix&pump 78.4 bbls of 15.69 ppg Premium G cement, 365 sacks,1.17 ft^3/sack yield at 3 BPM. -Drop shut-off plug. �v� -Pump 20 bbls of 8.5 ppg seawater at 3 BPM. -Displace utilizing rig pumps&10.1 ppg LSND at 5 BPM. --Observe lift as cement turned the corner @ 5944 stokes. Halliburton calculated 216 PSI of lift pressure. ** 263'TVD of fill for calculated TCIC at 14ç12' ** 570'above Kuparuk C marker. -Slow to 3 BPM to bump plug at 6870 strokes. -CIP@22:11. -Pressure up to 2335 PSI&hold for 5 min. -Bleed off&check floats-holding. r -725 bbls lost of 750 bbls pumped. lea Pressure up to shift the Halliburton ES cementer open @ 12,339'. Establish circulation utilizing the step rate method from 2 BPM to 5 BPM. Page 5/9 Report Printed: 6/22/2015 Jperations Summary Report - State Well Name: ODSN-22 eam ELU r r Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 5/9/2015 5/10/2015 15,726.0 0.00 10.15 Circulate 10.1 ppg LSND at 5 BPM. Displace wellbore through ES cementer @ 12,339'from 10.1 ppg LSND to 10.1 ppg MOBM. Continue to circulate while preparing for second stage cement job. Perform 7"casing Intermediate#2 second stage cement job. -Fill lines&pump 10 bbls of 11.0 ppg Tuned Spacer III at 1 BPM,425 PSI. -Test lines to 3500 PSI-good test. -Pump 50 bbls of 11.0 ppg Tuned Spacer III at 3 BPM,650 PSI. -Shut down and mix cement. -Drop bottom plug. 4 ,V -Pump 52.7 bbls of 15.8 ppg Premium G cement, 255 sacks, 1.17 ft^3/sack yield at 3 BPM,475 �L7 PSI. -Drop top plug. 5 -Pump 20 bbls of 8.5 ppg seawater at 5 BPM,325 PSI. -Displace utilizing rig pumps&10.1 ppg LSND. --5 BPM,700 PSI start. --5 BPM,1100 PSI end. --Observed bottom plug rupture @ 4756 strokes. -Bumped plug @ 5350 strokes,452.6 bbls(95.9%efficiency). -Pressure up to 2500 PSI,the pressure dropped immediately to 2325 PSI&held for 5 minutes-- good test. -CIP @ 12:06. -Full returns throy_g hout entirejob. Re-pressured casing to 2600 psi and held at 2550 for 5 minutes—good test. Closed Annular. Lined up returns to trip tank and bleed 7"casing to verify ES Cementer closed—6.2 bbls returned and no flow. Open kill line and no pressure and no flow from annulus—open annular and verified no flow. Remove trip nipple,break Vetco Gray multi-bowl well head between the casing and tubing spools. Hoist BOP stack&tubing spool. Install Vetco Gray emergency slips with 122K tension. Cut 7"casing as per Vetco Gray specification. Install 10-1/8"x7"pack-off. Lower&re-install BOP stack&tubing spool. Test 10-1/2"x7"pack-off&void between Vetco Gray tubing&casing spools. Test to 4300 PSI for 10 min.&chart same-good test. Set test plug with 4"test joint. Change upper pipe rams from 7"to 2-7/8"x5"VBR. 5/10/2015 5/11/2015 15,726.0 0.00 10.10 Finish changing upper rams from 7"to 2-7/8"x5"VBR,C/O IBOP from 4-1/2"IF to XT-39 and install XT-39 saver sub. R/U test equipment. -Test upper&lower 2-7/8"x 5"pipe rams-good tests. -Test TIW floor safety valve-failed. --Mobilize new TIW floor safety valve to the rig floor. -Test floor safety valves,upper IBOP&lower IBOP-good tests. -Tests performed to 250 PSI low&4500 PSI high. -All tests performed w/8.5 ppg seawater. -All tests held for 5 min.&charted. -Attempted to test annular preventer-failed high pressure test. Remove test joint&test plug. Change out annular preventer element. Install test plug&4"test joint. -Test the annular preventer to 250 PSI low/2500 PSI high. --Tests held for 5 min.each&charted. --Tests performed w/8.5 ppg seawater. R/D test equipment&install Vetco Gray wear bushing. L/D 183 joints of 5"drill pipe from the derrick. ***Provided 48 hour notification of BOP test request to the AOGCC @ 11:56 on 10 May 2015 for expected test @ 11:50 on 12 May 2015.*** 5/11/2015 5/12/2015 15,726.0 0.00 10.10 L/D 67 stands(201 joints)of 5"drill pipe from the derrick in the mousehole. MU Muleshoe and Tih with 60 joints of 4"drill pipe. Slip and Cut 96'of drill line. Cont to Tih while PU additional 226 joints of 4"drill pipe to 9148'md. Rig Crew conducted BOP Drill. Page 6/9 Report Printed: 6/22/2015 • Operations Summary Report - State Well Name: ODSN-22 CAELUS F rc Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 5/12/2015 5/13/2015 15,726.0 0.00 10.20 Finish PU 89 joints of 4'drill pipe to 12030'md. Circulate 1.5x drill pipe volume. Toh and LD Mule Shoe. Remove Vetco Gray wear bushing&install Vetco Gray test plug w/4"test joint. Test BOPE per AOGCC PTD:. *Test upper and lower 2-7/8"x5"VBR w/4"test joint to 250/4500. *Test upper and lower IBOP valves to 250 psi low/4500 psi high. t7-43' *Test annular w/4" test joint to 250 psi low/2500 psi high. /(3 *Test all floor valves to 250 psi low/4500 psi high. *Test 14 choke manifold valves to 250 psi low/4500 psi high. *All tests charted and all tests held for 5 min. *All tests performed with sea water *Initial system psi:3000 psi;1950 psi after closure;200 psi=25 sec,full pressure 1 min.54 sec. ***AOGCC notified of BOP test at 1150 hrs on 10 May 2015.*** ***AOGCC Inspector Johnnie Hill waived witness @ 0712 hrs on 12 May 2015. ** Tested MPD Equipment 250 psi low&2000 psi high. MU BHA#7 and shallow pulse test. Tih while PU 4"drill pipe to 1165'md. 5/13/2015 5/14/2015 15,726.0 0.00 10.30 Finish Tih with clean-out bha while PU 306 jts 4"drill pipe f/1165't/10980'. Continue Tih with stands t/12033'. Wash&ream t/12324'. Drilled cement,top and bottom plugs t/12339'. Drill ES Cementer U12441'. Continue Tih to 15204';Wash&ream t/15503'and drill cement to 15524'. Attempt to pressure test casing to 4000 psi--experience leak in high pressure 4"mud line in pump room. Repair12 feet length of section of high pressure mud line in pump room. 5/14/2015 5/15/2015 15,726.0 0.00 10.30 Completed repair of 4"high pressure mud line in the pump room. Drilled the float track(Baffle Collar+2 Joints+Float Collar+2 Joints+Float Shoe). Cleaned out rat hole U15726'md.CBU and Performed Bat Sonic LogEvaluation to verify Stage 1 cement coverage to 14307'bit depth. Toh U12595'bit depth and resume Bat Sonic Log Evaluation to verify Stage 2 cement coverage U11461'as per L&MWD Engineer. (Note:Bat Sonic Sensor is located 56'above the bit). 5/15/2015 5/16/2015 15,726.0 0.00 10.30 Finish performing Bat Sonic Log Evaluation for Stage 2 cement coverage f/11461' U10979'bit depth as per M&LWD Engineer(Note:Bat Sonic Sensor is located 56'above the bit). Finish Toh f/11056'and LD Clean-out BHA#7. Re-Test BOPE to afford maximum window for drilling the lateral(sidetrack contingency time). . 5/16/2015 5/17/2015 15,726.0 0.00 10.30 Tested MPD Equipment 250 psi low&2000 psi high. Test BOPE per AOGCC PTD:. *Test upper and lower 2-7/8"x5"VBR w/4"test joint to 250/4500. *Test upper and lower IBOP valves to 250 psi low/4500 psi high. *Test annular w/4" test joint to 250 psi low/2500 psi high. *Test all floor valves to 250 psi low/4500 psi high. *Test 14 choke manifold valves to 250 psi low/4500 psi high. *All tests charted and all tests held for 5 min. *All tests performed with sea water *Initial system psi:3000 psi; 1950 psi after closure;200 psi=23 sec,full pressure 1 min.53 sec. ***AOGCC notified of BOP test at 1040 hrs on 13 May 2015.*** ***AOGCC Inspector Bob Noble waived witness @ 1815 hrs on 13 May 2015. ** Pull Upper Test Plug and Install Upper Wear Ring. PJSM&MU the 6-1/8"Geo-Steering BHA as per DD and L&MWD Engineer. MU the 6-1/8"Geo-Steering BHA#8 and Tih to the 7"casing shoe. Slip&Cut Drill Line. Page 7/9 Report Printed: 6/22/2015 • Operations Summary Report- State Well Name: ODSN-22 CC- CAE1JJS F c rQv Alaska Start Depth. Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 5/17/2015 5/18/2015 15,726.0 324.00 7.55 Finish cut&Slip drilling line,Service rig. -CBU 1.5 times,Max gas 5460 units and to 98 units Flow check well. -Install RCD. -Displace f/10.2 ppg LSND to 7.6 ppg MOBM,Holding 9.8 ppg EMW w/MPD. -Wash f/shoe to 15,726'. -Drill 20'new hole f/15,726'to 15,747'. -Perform 12.5 ppg EMW FIT-OK. -Drill f/15,746'to 15,953'holding 9.8 ppg EMW at shoe. -Pull back into shoe&CBU 1.5 times. -Shut in well while trapping 700 psi with the MPD(9.8 ppg EMW at the 7"casing shoe). -Close Annular Preventer. -Pressure bled to 625 psi—bump pressure back up to 709 psi. - Close bleeder—Monitor wellhead pressure below BOP. - Pressure dropped f/709 psi t/551 psi in 28 minutes—static at 551 psi for 6 minutes. -Reduce pressure by bleeding mud f/551 psi[/509 psi.in Pressure increased to 540 psi in 6 minutes—static at 540 psi for next 6 minute.Calculated Pore Pressure @ 9.3 ppg EMW. -DSL&NRS called Drlg Manager on WE Duty and discussed plan forward. Agreed to hold 9.5 ppg EMW at the Shoe while Geo-Steering Well. -Run back in hole to bottom @ 15,953'. -Geo-Steer&Drill f/15,953'to 16,050'. 5/18/2015 5/19/2015 16,050.0 989.00 7.60 Geo Steer&Drill 6-1/8"Lateral f/16,050'to 17,039'. 7.6 ppg w/EMW 10.0 ppg via MPD. 5/19/2015 5/20/2015 17,039.0 1,276.00 7.65 Geo Ster&Drill 6-1/8"lateral(/17,039'to 18,315'MD(6,155'TVD). 7.65 ppg w/10.0 ppg EMW via MPD. 5/20/2015 5/21/2015 18,315.0 1,393.00 7.80 Geo Steer&Drill 6-1/8"Lateral ff 18,315' to 19,708'MD (6,173'TVD). 7.8 ppg w/EMW 10.0 ppg via MPD. 5/21/2015 5/22/2015 19,708.0 1,156.00 7.80 Geo Steer&Drill 6-1/8"Lateral f/19,708' to 20,864'MD (6,178'TVD). -MPD holding 10.0 ppg EMW at shoe. -Raised MPD EMW from 10.0 ppg to 10.2 ppg EMW at shoe©20,575'(4:35 PM) -MW.7.8 ppg.Vis 62. 5/22/2015 5/23/2015 20,864.0 1,102.00 7.80 Geo Steer&Drill 6-1/8"Lateral ff 20,864' to 21,634'MD. -Reduced MPD EMW from 10.2 ppg to 10.0 ppg EMW at shoe @ 21,250'(6:10 AM). -Directional tool on MWD Failed at Bit Depth of 21,534'.(Last Survey @ 21,483'MD,6180.63' TVD,Inc.88.73°,Azi.253.30°) Geo Steer&Drill 6-1/8"Lateral ft 21,634' to 22,185'MD. -BOP Drill while Drilling,Responce time 1 min.55 seconds. 5/23/2015 5/24/2015 21,966.0 242.00 7.80 Geo Steer&Drill 6-1/8"Lateral to TD of 22,208'MD.• -MPD holding 10.0 ppg EMW at shoe. -Circ BU 1-1/2 times. -Perform Pore Pressure test to 9.7 ppg EWM. -BOP Drill while Drilling,Well shut in 25 sec's,Crew on station in 2 min.30 seconds. -Back ream at full drilling rate to 20,187'. -Circ.BU. -Back ream at 200 gpm @ 3150 psi,60 RPM to 18,073' 5/24/2015 5/25/2015 22,208.0 0.00 7.80 Finished Back Reaming out to 15,665'. -Circ.3 X's BU. r , -Change out&Test Top Drive IBOP to 250/4500 psi. TIH on Elevators to 22,208'. -BOP Drill while Tripping,Crew responce time 2 min.10 sec's. " ' Displace well f/7.8 ppg MOBM to 10.2 ppg MOBM. -MPD holding 10.0 ppg EMW at shoe while circulating.. Page 8/9 Report Printed: 6/22/2015 Operations Summary Report- State Well Name: ODSN-22 C CAELL S F- '1- ' Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 5/25/2015 5/26/2015 22,208.0 0.00 10.20 Finish 7.8 ppg to 10.2 ppg MOBM Displacement,Flow Check well-Static,Luricate out of hole f/ 22,208'to 15,699'pumping 1 bpm pulling 4 min/std,Flow check well-Static,Continue to Lubricate out of hole from shoe at 1/2 bpm. *24 hr BOPE test notice given to AOGCC at 0900 hrs on 5-25-15. 5/26/2015 5/27/2015 22,208.0 0.00 10.20 Lubricate out of hole to 4,881'pumping at 1 bpm pulling 3 min./std,TOOH on Elevators to 2,190', Lay down 54 joints 4"Drill pipe to BHA,Lay down BHA. Lou Grimaldi with AOGCC Field Rep.Waived BOPE witness at 03:00 hrs 5/27/15 5/27/2015 5/28/2015 22,208.0 0.00 10.20 Pick up 54 jts 4"HW DP,Flush,POOH&Std back in Derrick,Pull wear bushing&Install junk bushing, Flush Stack,Rig&Test BOPE 250/4500 psi(Annular to 250/2500 psi),Replace oil seal in lower Ram door,Finish BOP Test,Rig&Run 4-1/2"liner. 5/28/2015 5/29/2015 22,208.0 0.00 10.25 Run 4-1/2"Liner as per liner tally f/1,623'U 6,775'. M/U Baker 5"x7"ZXP Liner Hanger Packer. M/U bumper sub&magnet assembly to 6,809'. Stage up pumps to 2 BPM to pump a liner volume. Experienced 60%losses,so reduced flow rate to 1 BPM w/20%losses for remainder of liner volume,1250 strokes total. Run 4-1/2"12.6#C-110 liner on 4"drill pipe f/6,809'U 15,469'at 40'per min.running speed. 5/29/2015 5/30/2015 22,208.0 0.00 10.20 Run 4-1/2"12.64 C-110 liner on 4"drill pipe f/15,469'U 22,205'. Set Baker 5"x7"hanger and Baker ZXP packer. Pressure test 5"x7"ZXP packer to 4,000 PSI for 5 min.-good test. Displace wellbore f/10.2 ppg MOBM to 10.2 ppg treated brine. POOH w/liner running tool f/15,329'V 5,612'. 5/30/2015 5/31/2015 22,208.0 0.00 10.20 UD 4"drill pipe f(5,612'U 41'and UD Baker running tool assembly. R/U to run 4-1/2"upper completion. Run 4-1/2"12.6#C-110 Hydril 521 upper completion to 4,330'. 5/31/2015 6/1/2015 22,208.0 0.00 10.20 R,pn 4-1/2"upper completion f/4330'SL14,681L_ 6/1/2015 6/2/2015 22,208.0 0.00 10.20 Run 4-1/2"upper completion f/14,681'V 15484'. Perform space out,P/U landing joint&tubing hanger. Land 4-1/2"upper completion on hanger w/40K down weight. Test hanger seals to 10,000 PSI for 10 min. Drop 1-7/8"ball&rod. Pressure test tubing to 3,500 PSI for 30 min.& chart same. Test 4-1/2"x7"IA to 4,000 PSI for 30 min.&chart same. Shear DSK valve&verify communication. Install TWC,N/D BOP equipment&N/U Vetco Gray 10,000 PSI tree. Test tree to 10,000 PSI for 10 min. Test surface safety valve to 5,000 PSI for 10 min. Test hanger void to 5,000 PSI for 10.min. Remove TWC. Pump 100 bbls of 6.9 ppg diesel freeze protect&allow to u-tube. Set BPV&install tree cap. ***Provided notification to the AOGCC at 08:42 on 1 June 2015 of upcoming BOP test on ODSN -01 at 20:00 on 2 June 2015.*** Page 9/9 Report Printed: 6/22/2015 Well Planning -Caelus- Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-22 PSW2 50-703-20708-00-00 Sperry Drilling Definitive Survey Report 27 May, 2015 I I HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22 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-22 North Reference: True Wellbore: ODSN-22 PSW2 Survey Calculation Method: Minimum Curvature Design: ODSN-22 PSW2 Database: EDMPrd 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-22 Well Position +NI-S 0.00 usft Northing: 6,031,023.58 usft Latitude: 70°29'44.98 N +E/-W 0.00 usft Easting: 469,793.67 usft Longitude: 150°14'49.18 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 13.50 usft Wellbore ODSN-22 PSW2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) IGRF2010 5/15/2015 19.35 81.01 57,700 Design ODSN-22 PSW2 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 0.00 256.21 Survey Program Date 5/27/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 78.00 921.00 ODSN-22 SRG-SS(ODSN-22 PSW2) SRG-SS Surface readout gyro single shot 963.88 6,513.62 ODSN-22 MWD+IFR2+MS+sag(1)(ODS MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 6,603.36 11,687.60 ODSN-22 MWD+IFR2+MS+sag(2)(ODS MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11,740.61 15,661.37 ODSN-22 MWD+IFR2+MS+sag(3)(ODS MWD+IFR2+MS+sag Fixed:v2:lIFR dec&3-axis correction+sag 15,705.99 21,483.62 ODSN-22 MWD+IFR2+MS+sag(4)(ODS MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 22,208.00 22,208.00 ODSN-22 BLIND(ODSN-22 PSW2) Blind Blind drilling(no survey data) Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (1 (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4270 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,023.58 469,793.67 0.00 0.00 UNDEFINED 78.00 0.11 310.69 78.00 21.80 0.02 -0.03 6,031,023.60 469,793.64 0.31 0.02 SRG-SS(1) 140.00 0.54 294.33 140.00 83.80 0.18 -0.34 6,031,023.76 469,793.33 0.70 0.28 SRG-SS(1) 168.00 1.35 271.21 167.99 111.79 0.24 -0.79 6,031,023.83 489,792.88 3.14 0.71 SRG-SS(1) 262.00 4.21 260.75 261.87 205.68 -0.29 -5.30 6,031,023.31 469,788.37 3.08 5.22 SRG-SS(1) 355.00 5.22 255.24 354.56 298.36 -1.92 -12.76 6,031,021.72 469,780.90 1.19 12.85 SRG-SS(1) 448.00 7.41 253.13 446.99 390.79 -4.73 -22.59 6,031,018.94 469,771.06 2.37 23.07 SRG-SS(1) 542.00 10.82 252.08 539.79 483.59 -9.21 -36.79 6,031,014.52 469,758.84 3.63 37.93 SRG-SS(1) 637.00 12.76 251.44 632.78 576.58 -15.29 -55.22 6,031,008.52 469,738.39 2.05 57.28 SRG-SS(1) 732.00 17.90 253.75 724.37 668.17 -22.72 -79.20 6,031,001.18 469,714.38 5.45 82.34 SRG-SS(1) 5/27/2015 8:23:02AM Page 2 COMPASS 5000.1 Build 58 Halliburton Definitive Survey Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22 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-22 North Reference: True Wellbore: ODSN-22 PSW2 Survey Calculation Method: Minimum Curvature Design: ODSN-22 PSW2 Database: EDMPrd Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 827.00 22.36 254.20 813.54 757.34 -31.73 -110.62 6,030,992.30 469,682.93 4.70 115.00 SRG-SS(1) 921.00 25.15 256.60 899.57 843.37 -41.23 -147.26 6,030,982.95 469,646.25 3.14 152.85 SRG-SS(1) 963.88 26,61 258.84 938.15 881.95 -45.20 -165.55 6,030,979.06 469,627.95 4.10 171.55 MWD+IFR2+MS+sag(2) 1,059.60 28.37 257.43 1,023.08 966.86 -54.30 -208.78 6,030,970.13 469,584.69 1.96 215.71 MWD+IFR2+MS+sag(2) 1,153.15 33.91 257.03 1,103.10 1,046.90 -65.00 -255.94 6,030,959.63 469,537.49 5.93 264.06 MWD+IFR2+MS+sag(2) 1,249.31 34.86 256.69 1,182.46 1,126.26 -77.35 -308.83 6,030,947.49 469,484.56 1.01 318.36 MWD+IFR2+MS+sag(2) 1,344.33 37.58 255.69 1,259.11 1,202.91 -90.77 -363.34 6,030,934.30 469,430.00 2.93 374.50 MWD+IFR2+MS+sag(2) 1,439.51 42.20 255.93 1,332.12 1,275.92 -105.72 -422.50 6,030,919.59 469,370.78 4.86 435.52 MWD+IFR2+MS+sag(2) 1,534.35 44.82 257.11 1,400.90 1,344.70 -120.92 -485.99 6,030,904.65 469,307.23 2.89 500.81 MWD+IFR2+MS+sag(2) 1,629.08 46.58 256.89 1,467.06 1,410.86 -136.18 -552.05 6,030,889.66 469,241.12 1.87 568.60 MWD+IFR2+MS+sag(2) 1,724.06 51.15 256.05 1,529.52 1,473.32 -152.93 -621.58 6,030,873.20 469,171.54 4.86 640.11 MWD+IFR2+MS+sag(2) 1,819.42 55.36 256.54 1,586.56 1,530.36 -171.02 -695.80 6,030,855.41 469,097.25 4.43 716.51 MWD+IFR2+MS+sag(2) 1,914.11 59.94 258.42 1,637.22 1,581.02 -188.32 -773.87 6,030,838.43 469,019.11 5.12 796.45 MWD+IFR2+MS+sag(2) 2,008.42 61.31 258.81 1,683.48 1,627.28 -204.54 -854.44 6,030,822.54 468,938.49 1.50 878.56 MWD+IFR2+MS+sag(2) 2,103.68 65.27 258.17 1,726.29 1,670.09 -221.52 -937.80 6,030,805.89 468,855.07 4.20 963.57 MWD+IFR2+MS+sag(2) 2,199.54 65.96 258.26 1,765.86 1,709.66 -239.36 -1,023.27 6,030,788.41 468,769.53 0.72 1,050.83 MWD+IFR2+MS+sag(2) 2,294.16 68.61 257.01 1,802.40 1,746.20 -258.05 -1,108.51 6,030,770.06 468,684.22 3.05 1,138.07 MWD+IFR2+MS+sag(2) 2,388.47 69.84 257.68 1,835.85 1,779.65 -277.37 -1,194.55 6,030,751.10 468,598.12 1.46 1,226.23 MWD+IFR2+MS+sag(2) 2,483.63 70.55 257.94 1,868.09 1,811.89 -296.27 -1,282.06 6,030,732.55 468,510.54 0.79 1,315.73 MWD+IFR2+MS+sag(2) 2,578.43 69.59 257.69 1,900.41 1,844.21 -315.08 -1,369.17 6,030,714.10 468,423.36 1.04 1,404.81 MWD+IFR2+MS+sag(2) 2,674.76 71.40 256.88 1,932.57 1,876.37 -335.07 -1,457.74 6,030,694.47 468,334.72 2.04 1,495.59 MWD+IFR2+MS+sag(2) 2,769.87 69.84 256.41 1,964.13 1,907.93 -355.79 -1,545.04 6,030,674.11 468,247.35 1.71 1,585.31 MWD+IFR2+MS+sag(2) 2,865.05 70.99 255.73 1,996.03 1,939.83 -377.38 -1,632.07 6,030,652.87 468,160.24 1.38 1,674.98 MWD+IFR2+MS+sag(2) 2,959.26 69.96 255.95 2,027.52 1,971.32 -399.10 -1,718.16 6,030,631.50 468,074.07 1.12 1,763.77 MWD+IFR2+MS+sag(2) 3,054.78 69.26 255.74 2,060.80 2,004.60 -421.00 -1,804.98 6,030,609.96 467,987.17 0.76 1,853.30 MWD+IFR2+MS+sag(2) 3,149.28 70.88 254.49 2,093.01 2,036.81 -443.82 -1,890.83 6,030,587.49 467,901.24 2.12 1,942.12 MWD+IFR2+MS+sag(2) 3,244.83 68.33 256.15 2,126.31 2,070.11 -466.53 -1,977.46 6,030,565.14 467,814.53 3.13 2,031.66 MWD+IFR2+MS+sag(2) 3,339.46 69.85 255.36 2,160.08 2,103.88 -488.28 -2,063.13 6,030,543.74 467,728.77 1.79 2,120.05 MWD+IFR2+MS+sag(2) 3,433.99 72.19 255.19 2,190.82 2,134.62 -511.00 -2,149.58 6,030,521.37 467,642.24 2.48 2,209.42 MWD+IFR2+MS+sag(2) 3,529.58 70.57 255.99 2,221.34 2,165.14 -533.55 -2,237.31 6,030,499.18 467,554.43 1.87 2,300.00 MWD+IFR2+MS+sag(2) 3,624.63 70.10 257.25 2,253.33 2,197.13 -554.26 -2,324.39 6,030,478.83 467,467.28 1.34 2,389.50 MWD+IFR2+MS+sag(2) 3,720.09 73.22 258.06 2,283.37 2,227.17 -573.62 -2,412.89 6,030,459.82 467,378.70 3.37 2,480.07 MWD+IFR2+MS+sag(2) 3,815.37 71.90 257.66 2,311.92 2,255.72 -592.74 -2,501.76 6,030,441.07 467,289.77 1.44 2,570.93 MWD+IFR2+MS+sag(2) 3,910.55 71.35 257.16 2,341.93 2,285.73 612.43 -2,589.91 6,030,421.74 467,201.55 0.76 2,661.24 MWD+IFR2+MS+sag(2) 4,005.72 71.01 257.65 2,372.63 2,316.43 -632.07 -2,677.82 6,030,402.46 467,113.56 0.60 2,751.30 MWD+IFR2+MS+sag(2) 4,100.39 69.97 257.86 2,404.24 2,348.04 -651.00 -2,765.03 6,030,383.89 467,026.29 1.12 2,840.50 MWD+IFR2+MS+sag(2) 4,194.86 70.69 256.98 2,436.04 2,379.84 -670.37 -2,851.85 6,030,364.87 466,939.40 1.16 2,929.44 MWD+IFR2+MS+sag(2) 4,289.49 70.26 256.76 2,467.67 2,411.47 -690.63 -2,938.70 6,030,344.96 466,852.47 0.50 3,018.62 MWD+IFR2+MS+sag(2) 4,385.04 71.08 255.76 2,499.30 2,443.10 -712.05 -3,026.28 6,030,323.91 466,764.81 1.31 3,108.78 MWD+IFR2+MS+sag(2) 4,480.11 71.94 255.55 2,529.45 2,473.25 -734.39 -3,113.64 6,030,301.92 466,877.38 0.93 3,198.94 MWD+IFR2+MS+sag(2) 5/27/2015 8:23:02AM Page 3 COMPASS 5000.1 Build 58 Halliburton Definitive Survey Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22 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-22 North Reference: True Wellbore: ODSN-22 PSW2 Survey Calculation Method: Minimum Curvature Design: ODSN-22 PSW2 Database: EDMPrd Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 4,574.41 71.85 255.34 2,558.75 2.502.55 -756.91 -3,200.39 6,030,279.75 466 590.55 0.23 3,288.56 MWD+IFR2+MS+sag(2) 4,670.23 71.64 255.71 2,588.77 2,532.57 -779.66 -3,288.50 6,030,257.37 466,502.35 0.43 3,379.55 MWD+IFR2+MS+sag(2) 4,765.18 72.12 256.70 2,618.30 2,562.10 -801.18 -3,376.14 6,030,236.21 466,414.64 1.11 3,469.79 MWD+IFR2+MS+sag(2) 4,860.50 70.69 257.66 2,648.69 2,592.49 -821.22 -3,464.22 6,030,216.52 466,326.48 1.78 3,560.12 MWD+IFR2+MS+sag(2) 4,955.70 71.48 258.16 2,679.55 2,623.35 -840.09 -3,552.28 6,030,198.02 466,238.35 0.97 3,650.14 MWD+IFR2+MS+sag(2) 5,050.73 70.55 258.79 2,710.47 2,654.27 -858.04 -3,640.33 6,030,180.42 466,150.24 1.16 3,739.93 MWD+IFR2+MS+sag(2) 5,145.48 71.74 258.69 2,741.09 2,684.89 -875.55 -3,728.27 6,030,163.28 466,062.24 1.26 3,829.50 MWD+IFR2+MS+sag(2) 5,240.38 70.10 259.31 2,772.11 2,715.91 -892.66 -3,816.30 6,030,146.52 465,974.15 1.84 3,919.08 MWD+IFR2+MS+sag(2) 5,335.46 71.40 259.17 2,803.46 2,747.26 -909.42 -3,904.49 6,030,130.12 465,885.90 1.37 4,008.72 MWD+IFR2+MS+sag(2) 5,430.23 70.03 259.52 2,834.76 2,778.56 -925.96 -3,992.39 6,030,113.94 465,797.94 1.49 4,098.03 MWD+IFR2+MS+sag(2) 5,525.67 69.24 259.52 2,867.97 2,811.77 -942.24 -4,080.38 6,030,098.03 465,709.90 0.83 4,187.36 MWD+IFR2+MS+sag(2) 5,621.23 70.66 259.49 2,900.73 2,844.53 -958.59 -4,168.64 6,030,082.04 465,621.58 1.49 4,276.98 MWD+IFR2+MS+sag(2) 5,715.99 69.83 259.27 2,932.76 2,876.56 -975.02 -4,256.30 6,030,065.96 465,533.87 0.90 4,366.02 MWD+IFR2+MS+sag(2) 5,810.57 70.12 259.65 2,965.15 2,908.95 -991.28 -4,343.66 6,030,050.06 465,446.45 0.49 4,454.74 MWD+IFR2+MS+sag(2) 5,904.04 69.87 257.96 2,997.12 2,940.92 -1,008.33 -4,429.81 6,030,033.36 465,360.23 1.72 4,542.48 MWD+IFR2+MS+sag(2) 6,000.93 70.80 257.67 3,029.73 2,973.53 -1,027.59 -4,519.00 6,030,014.47 465,270.98 1.00 4,633.68 MWD+IFR2+MS+sag(2) 6,095.92 70.28 258.02 3,061.37 3,005.17 -1,046.44 -4,606.55 6,029,995.97 465,183.36 0.65 4,723.21 MWD+IFR2+MS+sag(2) 6,190.64 71.34 258.57 3,092.51 3,036.31 -1,064.59 -4,694.15 6,029,978.18 465,095.70 1.25 4,812.60 MWD+IFR2+MS+sag(2) 6,285.78 70.53 257.69 3,123.59 3,067.39 -1,083.09 -4,782.14 6,029,960.04 465,007.64 1.22 4,902.47 MWD+IFR2+MS+sag(2) 6,380.56 71.27 257.86 3,154.60 3,098.40 -1,102.05 -4,869.67 6,029,941.44 464,920.04 0.80 4,992.00 MWD+IFR2+MS+sag(2) 6,475.38 69.68 258.39 3,186.29 3,130.09 -1,120.44 -4,957.12 6,029,923.40 464,832.52 1.76 5,081.31 MWD+IFR2+MS+sag(2) 6,513.62 69.75 257.97 3,199.55 3,143.35 -1,127.79 -4,992.23 6,029,916.20 464,797.39 1.05 5,117.16 MWD+IFR2+MS+sag(2) 6,603.36 69.40 258.01 3,230.86 3,174.66 -1,145.29 -5,074.49 6,029,899.04 464,715.07 0.39 5,201.22 MWD+IFR2+MS+sag(3) 6,844.71 70.12 258.03 3,245.17 3,188.97 -1,153.34 -5,112.44 6,029,891.14 464,677.09 1.74 5,239.99 MWD+IFR2+MS+sag(3) 6,742.88 70.70 257.23 3,278.08 3,221.88 -1,173.15 -5,202.78 6,029,871.69 464,586.68 0.97 5,332.45 MWD+IFR2+MS+sag(3) 6,837.17 71.03 257.40 3,308.99 3,252.79 -1,192.72 -5,289.69 6,029,852.49 464,499.70 0.39 5,421.52 MWD+IFR2+MS+sag(3) 6,932.25 71.20 257.46 3,339.77 3,283.57 -1,212.29 -5,377.49 6,029,833.27 464,411.83 0.19 5,511.46 MWD+IFR2+MS+sag(3) 7,031.74 71.35 258.08 3,371.71 3,315.51 -1,232.25 -5,469.58 6,029,813.68 464,319.67 0.61 5,605.65 MWD+IFR2+MS+sag(3) 7,125.09 71.41 259.08 3,401.51 3,345.31 -1,249.77 -5,556.29 6,029,796.52 464,232.90 1.02 5,694.03 MWD+IFR2+MS+sag(3) 7,220.41 71.21 258.42 3,432.06 3,375.86 -1,267.38 -5,644.85 6,029,779.27 464,144.28 0.69 5,784.24 MWD+IFR2+MS+sag(3) 7,319.06 70.88 258.75 3,464.10 3,407.90 -1,285.85 -5,736.30 6,029,761.18 464,052.76 0.46 5,877.46 MWD+IFR2+MS+sag(3) 7,413.40 70.70 259.42 3,495.14 3,438.94 -1,302.72 -5,823.77 6,029,744.67 463,965.22 0.70 5,966.43 MWD+IFR2+MS+sag(3) 7,508.45 70.50 259.04 3,526.71 3,470.51 -1,319.47 -5,911.85 6,029,728.27 463,877.09 0.43 6,055.96 MWD+IFR2+MS+sag(3) 7,607.04 70.48 258.82 3,559.64 3,503.44 -1,337.31 -6,003.05 6,029,710.80 463,785.83 0.21 6,148.78 MWD+IFR2+MS+sag(3) 7,702.79 70.52 258.50 3,591.60 3,535.40 -1,355.06 -6,091.54 6,029,693.42 463,697.27 0.32 6,238.96 MWD+IFR2+MS+sag(3) 7,798.57 70.58 258.62 3,623.50 3,567.30 -1,372.98 -6,180.06 6,029,675.86 463,608.69 0.13 6,329.20 MWD+IFR2+MS+sag(3) 7,895.47 70.24 257.00 3,655.99 3,599.79 -1,392.25 -6,269.29 6,029,656.95 463,519.39 1.61 6,420.45 MWD+IFR2+MS+sag(3) 7,990.34 70.65 257.30 3,687.74 3,631.54 -1,412.13 -6,356.45 6,029,837.43 463,432.16 0.52 6,509.83 MWD+IFR2+MS+sag(3) 8,085.04 70.78 256.62 3,719.02 3,662.82 -1,432.30 -6,443.53 6,029,617.62 463,345.01 0.69 6,599.21 MWD+IFR2+MS+sag(3) 8,183.09 70.70 257.74 3,751.36 3,695.16 -1,452.84 -6,533.79 6,029,597.45 463,254.68 1.08 6,691.76 MWD+IFR2+MS+sag(3) 5/27/2015 8:23:02AM Page 4 COMPASS 5000.1 Build 58 Halliburton Definitive Survey Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22 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-22 North Reference: True Wellbore: ODSN-22 PSW2 Survey Calculation Method: Minimum Curvature Design: ODSN-22 PSW2 Database: EDMPrd Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,277.58 70.83 257.99 3,782.49 3,726.29 -1,471.59 -6,621.01 6,029,579.05 463,167.39 0.29 6,780.94 MWD+IFR2+MS+sag(3) 8,372,77 70.75 257.01 3,813.81 3,757.61 -1,491.05 -6,708.76 6,029,559.95 463,079.56 0.98 6,870.80 MWD+IFR2+MS+sag(3) 8,470.79 70.71 257.29 3,846.16 3,789.96 -1,511.63 -6,798.98 6,029,539.74 462,989.28 0.27 6,963.32 MWD+IFR2+MS+sag(3) 8,566.17 70.56 257.77 3,877.79 3,821.59 -1,531.06 -6,886.84 6,029,520.67 462,901.35 0.50 7,053.28 MWD+IFR2+MS+sag(3) 8,661.06 70.74 257.23 3,909.23 3,853.03 -1,550.43 -6,974.24 6,029,501.65 462,813.87 0.57 7,142.79 MWD+IFR2+MS+sag(3) 8,758.99 70.82 257.59 3,941.47 3,885.27 -1,570.59 -7,064.49 6,029,481,86 462,723.55 0.36 7,235.24 MWD+IFR2+MS+sag(3) 8,854.43 70.77 259.59 3,972.86 3,916.66 -1,588.42 -7,152.83 6,029,464.40 462,635.15 1.98 7,325.28 MWD+IFR2+MS+sag(3) 8,949.17 70.89 258.99 4,003.97 3,947.77 -1,605.05 -7,240.76 6,029,448.13 462,547.16 0.61 7,414.64 MWD+IFR2+MS+sag(3) 9,047.93 70.75 258.25 4,036.42 3,980.22 -1,623.45 -7,332.20 6,029,430.09 462,455.65 0.72 7,507.83 MWD+IFR2+MS+sag(3) 9,142.65 70.84 258.12 4,067.58 4,011.38 -1,641.77 -7,419.76 6,029,412.14 462,368.04 0.16 7,597.23 MWD+IFR2+MS+sag(3) 9,237.54 70.90 258.27 4,098.68 4,042.48 -1,660.11 -7,507.51 6,029,394.15 462,280.22 0.16 7,686.82 MWD+IFR2+MS+sag(3) 9,336.10 70.56 258.16 4,131.20 4,075.00 -1,679.11 -7,598.59 6,029,375.52 462,189.07 0.36 7,779.81 MWD+IFR2+MS+sag(3) 9,431.10 71.01 258.75 4,162.47 4,106.27 -1,697.06 -7,686.48 6,029,357.93 462,101.12 0.75 7,869.44 MWD+IFR2+MS+sag(3) 9,525.64 71.42 259.24 4,192.91 4,136.71 -1,714.15 -7,774.34 6,029,341.20 462,013.20 0.65 7,958.84 MWD+IFR2+MS+sag(3) 9,624.39 70.96 258.85 4,224.75 4,168.55 -1,731.91 -7,866.11 6,029,323.82 461,921.36 0.60 8,052.20 MWD+IFR2+MS+sag(3) 9,719.31 70.61 257.70 4,255.99 4,199.79 -1,750.13 -7,953.87 6,029,305.96 461,833.54 1.20 8,141.77 MWD+IFR2+MS+sag(3) 9,814.22 70.82 258.14 4,287.34 4,231.14 -1,768.87 -8,041.47 6,029,287.57 461,745.87 0.49 8,231.32 MWD+IFR2+MS+sag(3) 9,912.59 70.96 257.83 4,319.54 4,263.34 -1,788.22 -8,132.38 6,029,268.59 461,654.89 0.33 8,324.22 MWD+IFR2+MS+sag(3) 10,007.57 70.52 257.35 4,350.87 4,294.67 -1,807.49 -8,219.95 6,029,249.68 461,567.25 0.66 8,413.86 MWD+IFR2+MS+sag(3) 10,102.77 70.64 256.89 4,382.53 4,326.33 -1,827.51 -8,307.48 6,029,230.03 461,479.66 0.47 8,503.63 MWD+IFR2+MS+sag(3) 10,201.01 70.70 258.15 4,415.05 4,358.85 -1,847.54 -8,397.99 6,029,210.36 461,389.08 1.21 8,596.31 MWD+IFR2+MS+sag(3) 10,296.36 70.88 258.14 4,446.42 4,390.22 -1,866.04 -8,486.11 6,029,192.23 461,300.89 0.19 8,686.30 MWD+IFR2+MS+sag(3) 10,391.15 70.87 258.53 4,477.47 4,421.28 -1,884.14 -8,573.81 6,029,174.48 461,213.12 0.39 8,775.79 MWD+IFR2+MS+sag(3) 10,489.92 70.90 257.40 4,509.82 4,453.62 -1,903.60 -8,665.09 6,029,155.39 461,121.78 1.08 8,869.07 MWD+IFR2+MS+sag(3) 10,584.58 70.63 257.73 4,541.00 4,484.80 -1,922.85 -8,752.36 6,029,136.50 461,034.43 0.44 8,958.42 MWD+IFR2+MS+sag(3) 10,677.79 70.43 257.71 4,572.07 4,515.87 -1,941.54 -8,838.23 6,029,118.16 460,948.49 0.22 9,046.27 MWD+IFR2+MS+sag(3) 10,777.09 70.49 258.19 4,605.29 4,549.09 -1,961.07 -8,929.75 6,029,099.00 460,856.91 0.46 9,139.81 MWD+IFR2+MS+sag(3) 10,872.23 70.76 257.89 4,636.85 4,580.65 -1,979.67 -9,017.56 6,029,080.76 460,769.04 0.41 9,229.52 MWD+IFR2+MS+sag(3) 10,967.41 70.90 257.57 4,668.10 4,611.90 -1,998.78 -9,105.40 6,029,062.01 460,681.12 0.35 9,319.39 MWD+IFR2+MS+sag(3) 11,066.29 70.96 258.04 4,700.41 4,644.21 -2,018.52 -9,196.75 6,029,042.65 460,589.70 0.45 9,412.80 MWD+IFR2+MS+sag(3) 11,161.64 70.95 258.80 4,731.52 4,675.32 -2,036.61 -9,285.04 6,029,024.91 460,501.34 0.75 9,502.87 MWD+IFR2+MS+sag(3) 11,256.90 70.68 257.82 4,762.83 4,706.63 -2,054.84 -9,373.15 6,029,007.05 460,413.18 1.01 9,592.77 MWD+IFR2+MS+sag(3) 11,351.04 70.67 258.22 4,793.98 4,737.78 -2,073.28 -9,460.05 6,028,988.96 460,326.21 0.40 9,681.56 M1ND+IFR2+MS+sag(3) 11,446.68 70.56 258.50 4,825.73 4,769.53 -2,091.48 -9,548.41 6,028,971.12 460,237.78 0.30 9,771.72 M1ND+IFR2+MS+sag(3) 11,540.05 70.64 258.04 4,856.74 4,800.54 -2,109.39 -9,634.64 6,028,953.57 460,151.49 0.47 9,859.73 MWD+IFR2+MS+sag(3) 11,636.17 70.75 258.73 4,888.52 4,832.32 -2,127.65 -9,723.50 6,028,935.67 460,062.57 0.69 9,950.38 MWD+IFR2+MS+sag(3) 11,687.60 70.78 258.17 4,905.46 4,849.26 -2,137.37 -9,771.07 6,028,926.14 460,014.96 1.03 9,998.90 MWD+IFR2+MS+sag(3) 11,740.61 70.60 257.97 4,922.99 4,866.79 -2,147.72 -9,820.02 6,028,916.00 459,965.98 0.49 10,048.90 MWD+IFR2+MS+sag(4) 11,836.07 70.42 258.56 4,954.84 4,898.64 -2,166.02 -9,908.13 6,028,898.05 459,877.80 0.61 10,138.83 MWD+IFR2+MS+sag(4) 11,931.09 71.20 259.27 4,986.07 4,929.87 -2,183.27 -9,996.19 6,028,881.16 459,789.68 1.08 10,228.47 MWD+IFR2+MS+sag(4) 5/27/2015 8:23:02AM Page 5 COMPASS 5000.1 Build 58 Halliburton Definitive Survey Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22 Project: Oooguruk Development ND Reference: 42.7'+13.5'©5620usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-22 North Reference: True Wellbore: ODSN-22 PSW2 Survey Calculation Method: Minimum Curvature Design: ODSN-22 PSW2 Database: EDMPrd Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E)-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,025.87 71.07 259.45 5 016.72 4.960.52 -2 199.82 -10 084.34 6,028 864.97 459.701.47 0.23 10,318.03 MWD+IFR2+MS+sag(4) 12,120.18 70.28 259.21 5,047.93 4,991.73 -2,216.29 -10,171.80 6,028,848.86 459,613.96 0.87 10,406.89 MWD+IFR2+MS+sag(4) 12,215.96 70.28 258.65 5,080.25 5,024.05 -2,233.61 -10,260.28 6,028,831.91 459,525.41 0.55 10,496.95 MWD+IFR2+MS+sag(4) 12,310.94 70.67 258.31 5,111.99 5,055.79 -2,251.48 -10,348.00 6,028,814.39 459,437.63 0,53 10,586.40 MWD+IFR2+MS+sag(4) 12,405.25 70.81 259.00 5,143.10 5,086.90 -2,269.00 -10,435.29 6,028,797.23 459,350.28 0.71 10,675.35 MWD+IFR2+MS+sag(4) 12,500.19 71,01 258.54 5,174.15 5,117.95 -2,286.47 -10,523.29 6,028,780.12 459,262.22 0.50 10,764.98 MWD+IFR2+MS+sag(4) 12,595.84 70.85 258.62 5,205.40 5,149.20 -2,304.37 -10,611.90 6,028,762.58 459,173.54 0.19 10,855.30 MWD+IFR2+MS+sag(4) 12,690.60 70.74 258.15 5,236.57 5,180.37 -2,322.39 -10,699.55 6,028,744.92 459,085.83 0.48 10,944.72 MWD+IFR2+MS+sag(4) 12,786.36 70.94 258.00 5,268.00 5,211.80 -2,341.08 -10,788.06 6,028,726.59 458,997.26 0.26 11,035.13 MWD+IFR2+MS+sag(4) 12,881.21 70.68 257.66 5,299.18 5,242.98 -2,359.96 -10,875.62 6,028,708.06 458,909.62 0.44 11,124.67 MWD+IFR2+MS+sag(4) 12,975.17 70.67 257.66 5,330.27 5,274.07 -2,378.91 -10,962.24 6,028,689.47 458,822.94 0.01 11,213.31 MWD+IFR2+MS+sag(4) 13,071.36 70.27 257.86 5,362.43 5,306.23 -2,398.13 -11,050.84 6,028,670.61 458,734.27 0.46 11,303.93 MWD+IFR2+MS+sag(4) 13,166.57 70.88 257.03 5,394.09 5,337.89 -2,417.65 -11,138.48 6,028,651.45 458,646.56 1.04 11,393.70 MWD+IFR2+MS+sag(4) 13,261.50 70.55 256.84 5,425.45 5,369.25 -2,437.90 -11,225.76 6,028,631.55 458,559.21 0.40 11,483.30 MWD+IFR2+MS+sag(4) 13,355.96 71.05 256.47 5,456.51 5,400.31 -2,468.49 -11,312.56 6,028,611.32 458,472.33 0.65 11,572.50 MWD+IFR2+MS+sag(4) 13,451.55 70.60 256.57 5,487.91 5,431.71 -2,479.54 -11,400.36 6,028,590.63 458,384.46 0.48 11,662.78 MWD+IFR2+MS+sag(4) 13,546.16 70.94 255.95 5,519.07 5,462.87 -2,500.76 -11,487.13 6,028,569.77 458,297.61 0.72 11,752.11 MWD+IFR2+MS+sag(4) 13,642.31 70.22 256.10 5,551.04 5,494.84 -2,522.66 -11,575.13 6,028,548.23 458,209.53 0.76 11,842.79 MWD+IFR2+MS+sag(4) 13,736.38 69.94 255.45 5,583.09 5,526.89 -2,544.39 -11,660.85 6,028,526.85 458,123.73 0.71 11,931.23 MWD+IFR2+MS+sag(4) 13,831.54 71.25 256.40 5,614.71 5,558.51 -2,566.21 -11,747.91 6,028,505.38 458,036.59 1.67 12,020.98 MWD+IFR2+MS+sag(4) 13,926.74 70.60 256.19 5,645.82 5,589.62 -2,587.53 -11,835.32 6,028,484.42 457,949.10 0.71 12,110.95 MWD+IFR2+MS+sag(4) 14,021.89 70.42 256.45 5,677.56 5,621.36 -2,608.74 -11,922.48 6,028,463.56 457,861.87 0.32 12,200.65 MWD+IFR2+MS+sag(4) 14,116.91 70.49 258.18 5,709.35 5,653.15 -2,628.41 -12,009.83 6,028,444.26 457,774.45 1.72 12,290.18 MWD+IFR2+MS+sag(4) 14,211.74 70.67 259.70 5,740.89 5,684.69 -2,645.56 -12,097.60 8,028,427.46 457,686.61 1.52 12,379.51 MWD+IFR2+MS+sag(4) 14,306.55 70.65 260.51 5,772.28 5,716.08 -2,660.93 -12,185.73 6,028,412.45 457,598.43 0.81 12,468.76 MWD+IFR2+MS+sag(4) 14,401.88 70.67 261.40 5,803.79 5,747.59 -2,675.05 -12,274.37 6,028,398.70 457,509.74 0.88 12,558.21 MWD+IFR2+MS+sag(4) 14,496.60 71.84 260.94 5,834.29 5,778.09 -2,688.84 -12,363.19 6,028,385.26 457,420.88 1.32 12,647.76 MWD+IFR2+MS+sag(4) 14,591.97 71.84 259.87 5,864.02 5,807.82 -2,703,95 -12,452.54 6,028,370.52 457,331.47 1.07 12,738.13 MWD+IFR2+MS+sag(4) 14,687.13 71.79 259.42 5,893.72 5,837.52 -2,720.20 -12,541.48 6,028,354.63 457,242.48 0.45 12,828.38 MWD+IFR2+MS+sag(4) 14,781.94 71.77 258.55 5,923.36 5,867.16 -2,737.41 -12,629.87 6,028,337.79 457,154.03 0.87 12,918.33 MWD+IFR2+MS+sag(4) 14,876.99 70.73 257.55 5,953.91 5,897.71 -2,756.04 -12,717.93 6,028,319.51 457,065.91 1.48 13,008.28 MWD+IFR2+MS+sag(4) 14,972.13 73.46 257.23 5,983.16 5,926.96 -2,775.80 -12,806.27 6,028,300.11 456,977.50 2.89 13,098.79 MWD+IFR2+MS+sag(4) 15,066.90 76.21 256.18 6,007.95 5,951.75 -2,796.84 -12,895.27 6,028,279.44 456,888.41 3.09 13,190.24 MWD+IFR2+MS+sag(4) 15,162.11 80.63 255.54 6,027.06 5,970.86 -2,819.62 -12,985.70 6,028,257.02 456,797.91 4.69 13,283.49 MWD+IFR2+MS+sag(4) 15,256.66 85.18 255.63 6,038.73 5,982.53 -2,842.98 -13,076.54 6,028,234.04 456,706.97 4.81 13,377.29 MWD+IFR2+MS+sag(4) 15,351.66 84.75 255.47 6,047.07 5,990.87 -2,866.59 -13,168.18 6,028,210.80 456,615.25 0.48 13,471.91 MWD+IFR2+MS+sag(4) 15,446.63 85.31 254.95 6,055.30 5,999.10 -2,890.74 -13,259.66 6,028,187.03 456,523.68 0.80 13,566.51 MWD+IFR2+MS+sag(4) 15,541.57 85.00 255.00 6,063.32 6,007.12 -2,915.27 -13,351.03 6,028,162.88 456,432.23 0.33 13,661.09 MWD+IFR2+MS+sag(4) 15,636.18 84.88 254.53 6,071.66 6,015.46 -2,940.03 -13,441,96 6,028,138.48 458,341.21 0.51 13,755.30 MWD+IFR2+MS+sag(4) 15,681.37 85.06 254.27 6,073.87 6,017.67 -2,946.78 -13,466.12 6,028,131.83 456,317.01 1.25 13,780.38 MWD+IFR2+MS+sag(4) 5/27/2015 8:23:02AM Page 6 COMPASS 5000.1 Build 58 Halliburton Definitive Survey Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22 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-22 North Reference: True Wellbore: ODSN-22 PSW2 Survey Calculation Method: Minimum Curvature Design: ODSN-22 PSW2 Database: EDMPrd 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 15,705.99 85.09 252.93 6,077.70 5.021.50 -2,959.33 -13,508.77 6,028,119.46 456,274.32 2.99 13,824.79 MWD+IFR2+MS+sag(5) 15,802.52 85.77 252.13 6,085.39 6,029.19 -2,988.22 -13,600.55 6,028,090.95 456,182.43 1.09 13,920.81 MWD+IFR2+MS+sag(5) 15,898.51 84.84 252.77 6,093.25 6,037.05 -3,017.06 -13,691.77 6,028,062.47 456,091.11 1.17 14,016.27 MWD+IFR2+MS+sag(5) 15,995.33 84.28 252.75 6,102.43 6,046.23 -3,045.63 -13,783.82 6,028,034.28 455,998.95 0.58 14,112.48 MWD+IFR2+MS+sag(5) 16,091.59 84.59 252.57 6,111.76 6,055.56 -3,074.18 -13,875.27 6,028,006.11 455,907.39 0.37 14,208.10 MWD+IFR2+MS+sag(5) 16,188.88 85.58 251.40 6,120.10 6,063.90 -3,104.16 -13,967.45 6,027,976.51 455,815.10 1.57 14,304.77 MWD+IFR2+MS+sag(5) 16,285.05 86.57 251.81 6,126.68 6,070.48 -3,134.44 -14,058.49 6,027,946.60 455,723.95 1.11 14,400.40 MWD+IFR2+MS+sag(5) 16,380.32 88.67 253.07 6,130.64 6,074.44 -3,163.15 -14,149.24 6,027,918.26 455,633.10 2.57 14,495.38 MWD+IFR2+MS+sag(5) 16,477.51 88.67 252.14 6,132.89 6,076.69 -3,192.20 -14,241.95 6,027,889.59 455,540.27 0.96 14,592.35 MWD+IFR2+MS+sag(5) 16,573.05 90.09 252.64 6,133.93 6,077.73 -3,221.10 -14,333.01 6,027,861.06 455,449.11 1.58 14,687.67 MWD+IFR2+MS+sag(5) 16,669.98 89.85 251.99 6,133.98 6,077.78 -3,250.55 -14,425.36 6,027,831.99 455,356.65 0.71 14,784.37 MWD+IFR2+MS+sag(5) 16,767.23 89.91 251.62 6,134.18 6,077.98 3,280.91 -14,517.75 6,027,802.01 455,264.15 0.39 14,881.34 MWD+IFR2+MS+sag(5) 16,862.24 89.79 253.89 6,134.43 6,078.23 -3,309.08 -14,608.48 6,027,774.21 455,173.31 2.39 14,976.17 MWD+IFR2+MS+sag(5) 16,958.47 89.84 253.38 6,134.74 6,078.54 -3,336.19 -14,700.81 6,027,747.48 455,080.88 0.53 15,072.30 M1ND+IFR2+MS+sag(5) 17,054.92 89.97 251.76 6,134.90 6,078.70 -3,365.08 -14,792.83 6,027,718.97 454,988.75 1.69 15,168.55 MWD+IFR2+MS+sag(5) 17,151.16 88.48 251.49 6,136.20 6,080.00 -3,395.42 -14,884.15 6,027,689.01 454,897.32 1.57 15,264.47 MWD+IFR2+MS+sag(5) 17,248.03 88.48 252.14 6,138.77 6,082.57 -3,425.64 -14,976.15 6,027,659.16 454,805.21 0.67 15,361.02 MWD+IFR2+MS+sag(5) 17,343.77 88.67 253.24 6,141.15 6,084.95 -3,454.12 -15,067.52 6,027,631.06 454,713.73 1.17 15,456.55 MWD+IFR2+MS+sag(5) 17,440.70 89.97 255.28 6,142.30 6,086.10 -3,480.41 -15,160.80 6,027,605.15 454,620.35 2.50 15,553.41 MWD+IFR2+MS+sag(5) 17,536.79 90.03 254.48 6,142.30 6,086.10 -3,505.47 -15,253.57 6,027,580.47 454,527.49 0.83 15,649.47 MWD+IFR2+MS+sag(5) 17,632.47 89.60 254.69 6,142.61 6,086.41 -3,530.90 -15,345.80 6,027,555.41 454,435.16 0.50 15,745.11 MWD+IFR2+MS+sag(5) 17,728.34 88.55 254.60 6,144.16 6,087.96 -3,556.28 -15,438.24 6,027,530.41 454,342.64 1.10 15,840.93 MWD+IFR2+MS+sag(5) 17,825.20 89.41 256.10 6,145.89 6,089.69 -3,580.78 -15,531.93 6,027,506.30 454,248.85 1.78 15,937.76 MWD+IFR2+MS+sag(5) 17,922.18 89.53 255.74 6,146.78 6,090.58 -3,604.37 -15,625.99 6,027,483.09 454,154.71 0.39 16,034.74 MWD+IFR2+MS+sag(5) 18,017.60 89.23 255.68 6,147.81 6,091.61 -3,627.92 -15,718.46 6,027,459.92 454,062.16 0.32 16,130.15 MWD+IFR2+MS+sag(5) 18,114.83 89.47 254.87 6,148.92 6,092.72 -3,652.63 -15,812.48 6,027,435.59 453,968.04 0.87 16,227.36 MWD+IFR2+MS+sag(5) 18,211.16 88.36 255.16 6,150.74 6,094.54 -3,677.53 -15,905.52 6,027,411.07 453,874.91 1.19 16,323.65 MWD+IFR2+MS+sag(5) 18,308.11 88.67 255.18 6,153.25 6,097.05 -3,702.34 -15,999.21 6,027,386.65 453,781.13 0.32 16,420.55 MWD+IFR2+MS+sag(5) 18,404.37 88.61 254.42 6,155.54 6,099.34 -3,727.57 -16,092.08 6,027,361.79 453,688.17 0.79 16,516.75 MWD+IFR2+MS+sag(5) 18,500.39 88.92 253.80 6,157.61 6,101.41 -3,753.86 -16,184.40 6,027,335.89 453,595.75 0.72 16,612.69 MWD+IFR2+MS+sag(5) 18,596.78 89.10 253.15 6,159.27 6,103.07 -3,781.27 -16,276.80 6,027,308.86 453,503.25 0.70 16,708.95 MWD+IFR2+MS+sag(5) 18,693.01 89.17 253.22 6,160.73 6,104.53 -3,809.10 -16,368.90 6,027,281.40 453,411.04 0.10 16,805.04 MWD+IFR2+MS+sag(5) 18,789.41 89.10 253.14 6,162.18 6,105.98 -3,836.99 -16,461.17 6,027,253.88 453,318.67 0.11 16,901.29 MWD+IFR2+MS+sag(5) 18,885.82 89.84 252.80 6,163.07 6,106.87 -3,865.23 -16,553.35 6,027,226.03 453,226.39 0.84 16,997.54 MWD+IFR2+MS+sag(5) 18,979.21 89.91 252.40 6,163.28 6,107.08 -3,893.16 -16,642.46 6,027,198.47 453,137.17 0.43 17,090.75 MWD+IFR2+MS+sag(5) 19,075.36 89.04 252.70 6,164.16 6,107.96 -3,921.99 -16,734.18 6,027,170.01 453,045.34 0.96 17,186.70 MWD+IFR2+MS+sag(5) 19,171.55 88.86 252.26 6,165.92 6,109.72 -3,950.94 -16,825.90 6,027,141.43 452,953.52 0.49 17,282.67 MWD+IFR2+MS+sag(5) 19,268.31 88.92 252.14 6,167.80 6,111.60 -3,980.51 -16,918.01 6,027,112.24 452,861.30 0.14 17,379.17 MWD+IFR2+MS+sag(5) 19,364.38 89.10 252.35 6,169.46 6,113.26 -4,009.80 -17,009.49 6,027,083.32 452,769.71 0.29 17,475.00 MWD+IFR2+MS+sag(5) 19,460.98 89.35 253.46 6,170.76 6,114.56 -4,038.20 -17,101.81 6,027,055.31 452,677.28 1.18 17,571.43 MWD+IFR2+MS+sag(5) 5/27/2015 8:23:02AM Page 7 COMPASS 5000.1 Build 58 Halliburton Definitive Survey Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(d3 56.20usft(Nabors 19AC) Well: ODSN-22 North Reference: True Wellbore: ODSN-22 PSW2 Survey Calculation Method: Minimum Curvature Design: ODSN-22 PSW2 Database: EDMPrd 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 19.557.48 89.29 253.57 6,171.91 6,115.71 -4,065.58 -17,194.34 6,027,028.30 452.584.66 0.13 17,667.81 MWD+IFR2+MS+sag(5) 19,653.43 88.73 252.96 6,173.57 6,117.37 -4,093.20 -17,286.21 6,027,001.06 452,492.68 0.86 17,763.62 MWD+IFR2+MS+sag(5) 19,750.15 88.98 252.83 6,175.50 6,119.30 -4,121.64 -17,378.63 6,026,972.99 452,400.15 0.29 17,860.16 MWD+IFR2+MS+sag(5) 19,846.18 89.54 253.33 6,176.74 6,120.54 -4,149.59 -17,470.50 6,026,945.42 452,308.19 0.78 17,956.04 MWD+IFR2+MS+sag(5) 19,943.36 88.98 253.07 6,177.99 6,121.79 -4,177.68 -17,563.52 6,026,917.72 452,215.06 0.64 18,053.07 MWD+IFR2+MS+sag(5) 20,039.88 89.48 253.64 6,179.29 6,123.09 -4,205.32 -17,655.99 6,026,890.45 452,122.49 0.79 18,149.46 MWD+IFR2+MS+sag(5) 20,135.97 90.22 252.62 6,179.54 6,123.34 -4,233.20 -17,747.94 6,026,862.94 452,030.43 1.31 18,245.41 MWD+IFR2+MS+sag(5) 20,232.89 90.83 252.34 6,178.65 6,122.45 -4,262.38 -17,840.36 6,026,834.15 451,937.90 0.69 18,342.12 MWD+IFR2+MS+sag(5) 20,328.35 90.58 251.99 6,177.48 6,121.28 -4,291.62 -17,931.22 6,026,805.28 451,846.93 0.45 18,437.34 MWD+IFR2+MS+sag(5) 20,423.85 90.03 252.75 6,176.97 6,120.77 -4,320.54 -18,022.24 6,026,776.73 451,755.81 0.98 18,532.62 MWD+IFR2+MS+sag(5) 20,521.36 89.97 252.56 6,176.97 6,120.77 -4,349.61 -18,115.31 6,026,748.05 451,662.63 0.20 18,629.94 MWD+IFR2+MS+sag(5) 20,616.94 90.25 251.77 6,176.79 6,120.59 -4,378.88 -18,206.30 6,026,719.14 451,571.53 0.88 18,725.28 MWD+IFR2+MS+sag(5) 20,711.40 89.72 254.21 6,176.81 6,120.61 -4,406.51 -18,296.62 6,026,691.88 451,481.11 2.64 18,819.59 MWD+IFR2+MS+sag(5) 20,808.04 89.53 254.21 6,177.44 6,121.24 -4,432.81 -18,389.61 6,026,665.97 451,388.02 0.20 18,916.17 MWD+IFR2+MS+sag(5) 20,906.19 89.66 253.42 6,178.14 6,121.94 -4,460.17 -18,483.87 6,026,639.00 451,293.66 0.82 19,014.23 MWD+IFR2+MS+sag(5) 21,000.90 89.97 253.18 6,178.44 6,122.24 -4,487.38 -18,574.58 6,026,612.15 451,202.85 0.41 19,108.82 MWD+IFR2+MS+sag(5) 21,097.63 90.28 253.20 6,178.23 6,122.03 -4,515.36 -18,667.18 6,026,584.56 451,110.15 0.32 19,205.41 MWD+IFR2+MS+sag(5) 21,195.34 89.41 252.92 6,178.50 6,122.30 -4,543.83 -18,760.65 6,026,556.47 451,016.57 0.94 19,302.97 MWD+IFR2+MS+sag(5) 21,291.88 90.31 252.77 6,178.73 6,122.53 -4,572.30 -18,852.89 6,026,528.37 450,924.22 0.95 19,399.34 MWD+IFR2+MS+sag(5) 21,387.53 89.35 254.06 6,179.02 6,122.82 -4,599.60 -18,944.56 6,026,501.45 450,832.45 1.68 19,494.88 MWD+IFR2+MS+sag(5) 21,483.62 88.73 253.30 6,180.63 6,124.43 -4,626.60 -19,036.76 6,026,474.83 450,740.15 1.02 19,590.86 MWD+IFR2+MS+sag(5) 22,208.00 88.73 253.30 6,196.68 6,140.48 -4,834.71 -19,730.42 6,026,269.56 450,045.72 0.00 20,314.13 Blind(6) brian.wheeler@halliburt0.4 M..a •_ �,.. Checked By: on.com -,o,o,,, ,o,owoa Approved By: cary.taylor@halliburton.com o o aj16m:m Date: 5/27/2015 8:23:02AM Page 8 COMPASS 5000.1 Build 58 Caelus Energy Alaska CASING&CEMENTING REPORT Lease&Well No. ODSN-22i Date 13-Apr-15 County North Slope Burough State Alaska Supv. CASING RECORD-Surface TD 6558.00 Shoe Depth: 6548.00 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Float Shoe 11.75 60 L-80 BTC-M HES 2.85 6,548.00 6,545.15 (1-2)Casing 11.75 60 L-80 BTC 79.60 6,545.15 _ 6,465.55 Float Collar _ 11.75 60 L-80 _ BTC-M HES 1.30 6,465.55 6,464.25 (3-26)Casing 11.75 60 L-80 BTC-M 1,016.04 6,464.25 5,448.21 _(26-148)Casing 11.75 60 L-80 BTC 4,916.57 5,448.21 531.64 TAMPort Collar 11.75 60 L-80 BTC 1.80 531.64 529.84 (149-160)Casing 11.75 60 L-80 BTC 486.74 529.84 43.10 Pup Joint 11.75 60 L-80 _Hydril 521 3.19 43.10 39.91 Casing Hanger 11.75 60 L-80 _ BTC _ 1.10 39.91 38.81 Landingloint 11.75 60 L-80 BTC 38.84 38.81 -0.03 Totals 6,548.03 Csg Wt.On Hook: Type Float Collar: Halliburton SSII No.Hrs to Run: 29 Csg Wt.On Slips: Type of Shoe: HES Comp.Eccent. Casing Crew: TESCO Fluid Description: Liner hanger Info(Make/Model): _ Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 1-per Joint 6,548'-5,488.9',1-EOJ from 5488.9'-1,940.5',1-per joint from 572.7-488.2',1-125.7-84.6' CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 10.0 Volume pumped(BBLs) 100 Lead Slurry Type: Permafrost L Yield(Ft3/sack): 3.91(Downhole Yield) Density(ppg) 11.34 Volume (BBLs/sacks): 648.3/931 Mixing/Pumping Rate(bpm): 4.5 Tall Slurry Type: Surface Tail Yield(Ft3/sack): 1.18 ) Density(ppg) 15.8 Volume (BBLs/sacks): 121.8/580 Mixing/Pumping Rate(bpm): 4.5 tl Post Flush(Spacer) w rc Type:SeaWater Density(ppg) 9.61 Rate(bpm): 6.1 Volume: 20 il Displacement: Type: WBM Density(ppg) 9.3 Rate(bpm): 8 Volume(actual/calculated): 713.2/713.2 FCP(psi): 1275 Pump used for disp: Rig pumps Plug Bumped? Yes X No Bump press - Casing Rotated? _Yes X No Reciprocated? Yes X No %Returns during job tee Remark Cement returns to surface? X Yes_No Spacer returns? X Yes_No Vol to Surf: 60.8 bbl cmt/100 bbl spacer Cement In Place At: 11:15 Date: 4/13/2015 Estimated TOC: 0'(Surface) Method Used To Determine TOC: Returns to 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 w Type: Yield(Ft3/sack): a Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 6 Type: Density(ppg) Rate(bpm): Volume: Displacement: N Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Rig pumps 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: t Remarks:Lost a total of 89 bbls during the cement job ✓ Caelus Energy Alaska CASING&CEMENTING REPORT Lease&Well No. ODSN-221 Date 25-Apr-15 County North Slope Burough State Alaska Supv. CASING RECORD-Intermediate#1 TD 11720.00 Shoe Depth: 11717.00 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Float Shoe 9.625 40 L-80 Hydril 521 HES 2.72 11,717.00 11,714.28 Centralizer Pup 9.625 _ 40 L-80 Hydril 521 Ray Oil Tool 3.44 11,714.28 11,710.84 (1)Casing 9.625 40 L-80 Hydril 521 38.10 11,710.84 11,672.74 Centralizer Pup 9.625 40 L-80 Hydril 521 Ray Oil Tool 3.43 11,672.74 11,669.31 (2)Casing 9.625 40 L-80 Hydril 521 39.33 11,669.31 11,629.98 Float Collar 9.625 40 L-80 Hydril 521 HES 1.36 11,629.98 11,628.62 Centralizer Pup 9.625 40 L-80 Hydril 521 Ray Oil Tool 3.43 11,628.62 11,625.19 (3)Casing 9.625 40 L-80 Hydril 521 37.09 11,625.19 11,588.10 Landing Collar 9.625 _ 40 L-80 Hydril 521 Baker 1.39 11,588.10 11,586.71 Centralizer Pup 9.625 40 L-80 Hydril 521 Ray Oil Tool 3.45 11,586.71 11,583.26 (4-132) 9.625 40 L-80 Hydril 521 5,156.57 11,583.26 6,426.69 Seal Bore 10.070 40 L-80 Hydril 521 Baker 4.76 6,426.69 6,421.93 Liner Cross Over 9.980 40 L-80 Hydril 513 11.14 6,421.93 6,410.79 Liner Top Packer 10.470 40 L-80 Hydril 513 Baker 19.43 6,410.79 6,391.36 Totals 5,325.64 Csg Wt.On Hook: Type Float Collar: Halliburton SSII No.Hrs to Run: Csg Wt.On Slips: Type of Shoe: HES Comp.Eccent. Casing Crew: TESCO Fluid Description: Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 4-Ray Oil Tool Centralizer Pups on Shoe Track CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 11.0 Volume pumped(BBLs) 65 Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume(BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: HalCem IPT Yield(Ft3/sack): 1.17 Density(ppg) 15.69 Volume(BBLs/sacks): 41.75/200 Mixing/Pumping Rate(bpm): 2.9 y Post Flush(Spacer) m Type:SeaWater Density(ppg) 8.81 Rate(bpm): 3.8 Volume: 19.77 LL Displacement: Type: OBM Density(ppg) 10 Rate(bpm): 3.42 Volume(actual/calculated): 476.11/476.20 FCP(psi): 830.3 Pump used for disp: Rig pumps Plug Bumped? X Yes No Bump press 3500 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job tee Remark Cement returns to surface? _Yes X No Spacer returns? _Yes X No Vol to Surf: Cement In Place At: 4:53 Date: 4/25/2015 Estimated TOC: Undetermined Method Used To Determine TOC: TOC calculator gave a negative value and returns were not a 100%during cement job 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 w Type: Yield(Ft3/sack): a Density(ppg) Volume(BBLs/sacks): Mixing/Pumping Rate(bpm): m Post Flush(Spacer) 0 oType: Density(ppg) Rate(bpm): Volume: NDisplacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Rig pumps 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:Lost a total of 332 bbls of mud during cementing operations Caelus Energy Alaska CASING&CEMENTING REPORT Lease 8 Well No. ODSN-22i Date 8-May-15 County North Slope Burough State Alaska Supv. CASING RECORD-Intermediate#2 TD 15726.70 Shoe Depth: 15699.30 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Float Shoe 7.000 26 L-80 Hydril563 HES 2.74 15,699.30 15,696.56 (1-2)Casing 7.000 26 L-80 Hydril 563 79.29 15,696.56 15,617.27 Float Collar 7.000 26 L-80 Hydril 563 HES 2.65 15,617.27 15,614.62 (3-4)Casing 7.000 26 L-80 Hydri1563 80.84 15,614.62 15,533.78 Baffle Adapter 7.000 26 L-80 Hydril 563 HES 2.08 15,533.78 15,531.70 (5-83)Casing 7.000 26 L-80 Hydril 563 HES 3,189.50 15,531.70 12,342.20 Stage Tool 7.000 - 26 L-80 Hydril 563 HES 3.42 12,342.20 12,338.78 1/7 (84-386)Casing 7.000 26 L-80 Hydril 563 12,255.50 12,338.78 83.28 Pup Joint 7.000 26 L-80 Hydril 563 9.83 83.28 73.45 (387)Casing 7.000 - 26 L-80 Hydril 563 36.80 73.45 36.65 RKB 7.000 26 L-80 Hydril 563 36.65 36.65 0.00 Totals 15,699.30 Csg Wt.On Hook: Type Float Collar: Halliburton SSII No.Hrs to Run: 33 Csg Wt.On Slips: Type of Shoe: HES Comp.Eccent. Casing Crew: TESCO Fluid Description: Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 1 per Joint-15,699.3-14,320.6,1 per Joint 12,382.6-11,285.9 CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 11.5 Volume pumped(BBLs) 60 Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume(BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: HalCem IPT Yield(Ft3/sack): 1.17 15{.-- i Density(ppg) 15.69 Volume(BBLs/sacks) 78.4/365 Mixing/Pumping Rate(bpm) 2.6 y Post Flush(Spacer) 0 Type:SeaWater Density(ppg) 8.53 Rate(bpm): 3.0 Volume: 20 LL Displacement: Type: LSND Density(ppg) 10.1 Rate(bpm): 4.49 Volume(actual/calculated): 575.63/574.47 FCP(psi): 1,842 Pump used for disp: Rig pumps Plug Bumped? X Yes No Bump press 2,335 Casing Rotated? _Yes X No Reciprocated? _Yes X No %Returns during job No Cement returns to surface? _Yes X No Spacer returns? _Yes X No Vol to Surf: - Cement In Place At: 22:11 Date: 5/8/2015 Estimated TOC: 14,512 Method Used To Determine TOC: BATSonic Log Preflush(Spacer) I20342'' e-> Type: Tuned Spacer III Density(ppg) 11 Volume pumped(BBLs) 60 Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume(BBLs/sacks): Mixing/Pumping Rate(bpm): 2 V t7 Tail Slurry w Type: HalCem IPT Yield(Ft3/sack): 1.2 i Density(ppg) 15.8 Volume(BBLs/sacks): 52.68/255 Mixing/Pumping Rate(bpm): 2.79 m Post Flush(Spacer) 0 g Type:SeaWater Density(ppg) 8.5 Rate(bpm): 4.03 Volume: 20 ) Displacement: Type: MOBM Density(ppg) 10.1 Rate(bpm): 4.87 Volume(actual/calculated): 452.37/452.60 FCP(psi): 710 Pump used for disp: Rig pumps Plug Bumped? X Yes_No Bump press 2,342 Casing Rotated? procate _Yes X No Reciprocated/_ Yes X No %Returns during job 100 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: - _ _ Cement In Place At: 12:06 Date: 5/9/2015 Estimated TOC: 11,100 Method Used To Determine TOC: Cement volume pumped with full returns during cement job ii Remarks: RECEIVED JUN 1 1 2015 G CAELLJ S LETTER OF TRANSMITTAL 2.t5-054 Energy Alaska 15�� DATE: June 10, 2015 FROM: TO: Shannon Koh AOGCC Caelus Energy Alaska Attn: Meredith Guhl 3700 Centerpoint Dr., Suite 500 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter Maps ❑ CD-R ❑ Other— Dry samples n Agreement DETAIL QTY DESCRIPTION Well Name: ODSN-22 (50-703-20708-0000) 7 boxes of well cutting samples Details on next page Received by: � Date: (°/I2–( I S— leases•n 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.koh@caelusenergy.com " yam_ • �i■ry/i + _Y y £ r Hale•i.�' H1 2[2:6 6 AOGCC Well Name: ODSN-22 API: 50-703-20708-00-00 AFE: 150015 ODSN-22 Dry Sample BOX/SAMPLE(Dry) TOP DEPTH BOTTOM DEPTH SAMPLE COUNT WELL COMMENTS 1 of 7 6578-6600 8300-8350 36 ODSN-22 Intermediate 1 Section/MOBM 2 of 7 8350-8400 10100-10150 36 ODSN-22 Intermediate 1 Section/MOBM -Intermediate 1 Hole Section-MOBM Samples To 11720'MD. 3 of 10150-10200 11850-11900 36 ODSN-22 -Intermediate 2-Water Based from 11750'MD 4 of 7 11900-11950 13650-13700 36 ODSN-22 Intermediate 2 Hole Section/Water Based 5 of 7 13700-13750 15450-15500 36 ODSN-22 Intermediate 2 Hole Section/Water Based -Intermediate 2 Hole Section-Water Based to 15727'MD. 6 of 7 15500-15550 18700-18800 36 ODSN-22 -Production Section-MOBM from 15800'MD. -No Sample-17600'and 17700'MD-Computer down 7 of 7 18800-18900 22100-22208 TD+BU 35 ODSN-22 Production Section/MOBM 251 Total bottle muni PTO Z/5—o5+ Loepp, Victoria T (DOA) From: Alex Vaughan <Alex.Vaughan@caelusenergy.com> Sent: Saturday, May 23, 2015 5:54 PM To: Schwartz, Guy L(DOA) Cc: Loepp, Victoria T (DOA); Bettis, Patricia K (DOA); Regg, James B (DOA); Oooguruk DrillingTechAdmin Subject: Re: ODSN-22, PTD#215-054 Follow Up Flag: Follow up Flag Status: Flagged Guy, We are not planning to gather any additional survey data. My understanding of the regs for an intentionally deviated hole is that they must be directionally surveyed at intervals not more than 500' in straight or tangent sections. The last survey obtained was at: 21.483'MD We are currently at TD'ed at 22,200' MD. Alex Sent from my iPhone On May 23, 2015, at 7:45 AM, Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov>wrote: Alex, Are there any plans to obtain a survey after well is completed or some other. ie gyro Guy Sent from my iPhone On May 22, 2015, at 6:39 PM, "Alex Vaughan"<AIex.Vaughan@caelusenergy.com>wrote: Victoria, Regarding: Operator:Caelus Energy Well: ODSN-22 PTD#215-054 PTD approved TD: 22,804' MD/6,081'ND Caelus Energy has been given verbal approval via telephone with Victoria Ferguson to drill ahead without the ability to obtain directional survey data. The following summary is for informational and records purposes. Currently we are drilling ahead at 21,730' MD/6,189'TVD in the ODSN-22 lateral production section. The last directional survey was recorded at 21,483' MD. Shortly 1 afterword's we had a failure in the directional assembly preventing us from the ability to obtain additional survey data. Caelus Energy is comfortable drilling to a TD of 22,200' MD/6,192'ND (projection)without the ability to obtain directional surveys based on our knowledge of reservoir thickness, our current directional position, build tendency of the directional BHA,and planned target. I can provide additional information as requested. Alex Vaughan Senior Drilling Engineer Caelus Energy Alaska, LLC 3700 Centerpoint Dr. I Anchorage, AK 99503 Direct 907.343.2186 I Cell 907.748.5478 alex.vaughan@caelusenergy.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 2 abivvuk- C6 SAJ -zz z-1 So sty Regg, James B (DOA) From: Oooguruk DrillingSupervisor <03.DrillingSupervisor@caelusenergy.com> Sent: Tuesday, May 19, 2015 3:08 PM To: DOA AOGCC Prudhoe Bay Subject: FW: Letter to Jim Regg Closing Blinds during BOPE Test for ODSN-22 Well Attachments: Blind Closing Letter to AOGCC Jim Regg.docx From: Robert Tirpack Sent: Tuesday, May 19, 2015 1:54 PM To: Oooguruk DrillingSupervisor Subject: FW: Letter to Jim Regg Closing Blinds during BOPE Test for ODSN-22 Well Rod —please send this in to the AGOCC Thanks, Rob From: joseph polya jmailto:joe.polya©yahoo.com] Sent: Tuesday, May 19, 2015 11:52 AM To: Robert Tirpack; Oooguruk DrillingSupervisor; Rod Klepzig; rob.tirpack@caelusenergy.com Subject: Letter to Jim Regg Closing Blinds during BOPE Test for ODSN-22 Well Rob, Apologize for the delay always a struggle with wording for the AOGCC correspondence. From now on, I suggest whoever makes a decision to shut the BOPE should be the one who writes the letter to the AOGCC LOU Please respond to this email to verify receipt. Thanks, Joe Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 1 (JlrT/V't. ic_ 06-,A) f'N) 2tSO54 Mr. Reggs, Well bore Conditions and Scenario: On Friday, May 15, 2015 the blinds were closed on the ODSN-22 as the Nabors 19AC crew was preparing to conduct a BOPE Test. The BOP equipment had been tested just 3 days prior. After the BOPE test, a clean out assembly was Rih to drill out the two stage cementer, float track and clean out the 27 feet of rat hole in the Nuiqsut formation below the 7" casing shoe set at 15,699 feet. A Bat Sonic logging-while-drilling cement evaluation tool was installed in the clean out assembly. After cleaning out the rat hole a Bat Sonic Mad Pass was performed from the 7" casing shoe to 11,000' feet (500 feet above the Torok formation) to collect cement bond data for the two stages of cement. A dry job was then pumped and the clean out assembly was tripped out of the hole and laid down. Caelus Management had elected to retest the BOPE prior to tripping in the hole with the geo-steering assembly in an effort to afford the maximum allowable time for drilling the production lateral prior to the next BOPE Test. Description of Event Prior to Closing the Blind Rams:The stack was drained and the rig crew had tested the Managed Pressure Drilling Equipment prior to testing the BOPE. A test cap is installed into the rotary control device on top of the diverter which isolates the BOP Stack during the testing of the Managed Pressure Drilling (MPD) equipment. Nabors standard practice is to open the wellhead valve below the test plug to avoid pressuring up the casing in the event pressure were to leak by the MPD Test Cap or the BOP test plug during the test. A member of the rig crew monitors this open valve during the testing operations. While testing the MPD equipment, water based drilling fluid began to seep from the open wellhead valve from the 7" casing. The driller was immediately notified who in turn notified the Caelus representative and Tool Pusher. This situation was monitored closely while testing the MPD equipment with the following observations. The seepage would gradually increase to a stream about the diameter of a No. 2 lead pencil and then gradually reduce to no flow. This intermittent flow (burps) was observed while collecting about 24 gallons of water based drilling fluid while testing the MPD equipment. The MPD test cap was removed and the BOPE Test Plug was installed on a joint of 4" drill pipe to begin testing BOPE. Description of Events After Closing the Blind Rams: The Caelus Drilling Representative discussed this situation with the Caelus Drilling Superintendent and the decision was made to pull the test plug, close the blind rams and put a gauge on the wellhead casing valve to more closely monitor and evaluate the situation. A tee arrangement was installed onto the casing valve to allow for monitoring pressure and bleeding fluid. The pressure gauge built to 60 psi and the valve was opened to bleed pressure — air escaped first followed by intermittent air and fluid slugs while collecting 5 gallons of 10.2 ppg drilling fluid. The subsequent shut-in pressure was recorded at 49 psi. This cycle was repeated three more times with the subsequent shut-in pressure increasing. Two separate gas detectors were utilized to sample the air being bled from c the casing valve and there was zero hydrocarbons/gas which confirmed this was air. To this point there was a total of 44 gallons of drilling fluid collected from the casing valve. While this data was being collected the Caelus Drilling Representative verified the following information with the Mud Logger's records and Pit Watcher's Trip Sheet: 1. The hole fill for the Toh with the clean out assembly showed the hole took 4 barrels more than calculated. 2. The well was stable with no losses and no gains during - 14 hours of Bat Sonic Mad Pass Operations to acquire cement bond log information. 3. Even though only 25 bbls of returns were recorded of the 750 bbls of total fluid pumped during stage one cementing operations, there were no gains recorded when the float track was drilled and the rat hole was cleaned out. So the formation was not charged releasing fluid wellbore. 4. Finally, the Mad Passing operations required serveral instances where the MWD engineer had to circulate to verify the high side tool orientation and that the Bat Sonic was activated and in the recording data mode. These instances combined with the pumping of the dry job to Toh resulted in air several slugs being pumped down hole. The Caelus Drilling Representative called the AOGCC North Slope Inspector Mr. Bob Noble to inform him that the Blind Rams had been closed to further evaluate flow from the 7" casing valve in the process of testing BOPE. Mr. Noble informed the Caelus Drilling Representative to send an email of the event to AOGCC Anchorage Representative Jim Reggs. The Caelus Drilling Representative called the Caelus Drilling Manager and relayed the information. Based on this information and the data collected from the pressure/bleed cycles it was concluded that this intermittent flow was most likely the result of air slugs migrating upward in a highly deviated well. The decision was agreed to rig up the casing valve to take returns through the gas buster to the trip tank; open the casing valve and monitor the trip tank to verify no flow and then open the blinds. This would allow the rig crew to re-install the test plug and test the BOPE while continuing to monitor the wellbore through the casing valve. Description of Events After Opening the Blind Rams: The rig crew recorded 1.5 bbls in the trip tank upon opening the casing valve. The flow stopped and the blinds were opened. The well was static and the test plug was installed on a joint of 4" drill pipe allowing the rig crew to test the BOPE. While testing the BOPE an additional 31 gallons were recorded. Midway through the testing of the BOPE the Caelus Drilling Representative elected to close the casing valve and monitor the casing pressure during the test. The pressure built to 131 psi and stabilized. Once the BOP test was concluded the pressure was bled from the casin. and for the first time h drocarbons were dere- ted w' e gas detector at 24% LEL. This pressure was bled from 131 psi to 30 psi into a bleed trailer. The casing valve was again lined up through the gas buster to the trip tank and the pressure was bled to zero while recording zero fluid gain. The test plug was removed and the well was observed to have a static fluid level with gas bubbles breaking out. To this point the well fluid level was static and a total of 131 gallons (3.25 bbls) of 10.2 ppg drilling fluid had been discharged from the well. The wear ring was installed and the rig crew proceeding making up the geo-steering drilling assembly and Tih to 4800 feet. Gas cut mud was observed while circulating to perform the shallow pulse tests at various stages of this process; however, the fluid level in the well bore remained static while making connections and there was no evidence of flow at flow checks with the pipe stationary. The geo-steering assembly was tripped to the 7" casing shoe at 15,699' while the pipe was filled every 3000 feet. Again, no flow was observed from the well at any time while the pipe was stationary — the hole fill showed 3 bbls more than calculated for the entire trip; however, this was most likely attributed to the gas cut mud in the surface pits displaced from the well during the trip. The hole was circulated at full rate (210 gpm) and a max trip gas of 4875 units was associated with 4100 bottoms up strokes (347 barrels) and this reduced substantially to 98 units gas over the additional 1025 strokes to achieve 1.25x BU. The fluid level was observed for 5 minutes and although it was static it was very frothy with gas bubbles visibly breaking out of the drilling fluid. It was decided to pump another 1025 stokes to achieve 1.5xBU over which time the gas decreased to 45 units. Again the fluid level was once again static; however, this time the fluid was not frothy and there was no sign of gas bubbles breaking out in the drilling fluid. The trip nipple was then pulled and the rotary control device (RCD) was installed. The 10.2 ppg water based drilling fluid was displaced with the 7.6 ppg mineral oil based drilling fluid; 20 feet of new formation were drilled to 15,747 feet and a 12.5 ppg FIT was performed without issue. Lateral drilling operations were initiated. Lesson Learned: In hind sight, to prevent a reoccurrence of these air slugs for future operations Caelus will circulate the wellbore sufficiently to remove these air slugs prior to pumping a dry job and tripping out of the hole with the clean out assembly. Joe Polya Caelus Drill Site Leader joe.palya(c�caelusenergy.com 907-670-6606 office phone 907-414-6714 mobile phone V OF Tye �w\�A �j� � sv THE STATE Alaska Oil and Gas ���►`!—i�iM ofALASIc;A Conservation Commission _ _7 _ _= Wet_— 333 West Seventh Avenue OF � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main' 907.279.1433 ALAS Fax 907.276 7542 www.aogcc alaska.gov Alex Vaughan Senior Drilling Engineer Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-22 Caelus Natural Resources Alaska, LLC Permit No: 215-054 Surface Location: 2908' FSL, 1204' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 3180' FSL, 382' FEL, SEC. 18, T13N, R7E, UM Dear Mr. Vaughan: Enclosed is the approved application for permit to drill the above referenced development well. 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster Chair DATED this 2s day of March, 2015. RECEIVED STATE OF ALASKA ;KA OIL AND GAS CONSERVATION COME ON MAR 1 6 2015 PERMIT TO DRILL 20 AAC 25.005 ? �/+► GC la.Type of Work• lb.Proposed Well Class: Development-Oil ❑� ' Service- Winj El Single Zone Lvi � 1c.Specify if wellisproposed or: Drill ❑✓ • Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name: 5. Bond: Blanket ❑ Single Well ❑ 11.Well Name and Number: Caelus Natural Resources Alaska,LLC ' Bond No. 4/0:2-1-15- 10365520 ODSN-22 3 Address: 6.Proposed Depth. 12.Field/Pool(s): 3700 Centerpoi nt Drive,Anchorage,AK 99503 MD. 22,804' • TVD 6,288' • 4a. Location of Well(Governmental Section). 7.Property Designation(Lease Number). Oooguruk-Nuiqsut Oil Pool • Surface: 2908'FSL, 1204'FEL,Sec. 11,T13N, R7E,UM • ADL 355036,ADL 355037• Top of Productive Horizon: 8.Land Use Permit. 13.Approximate Spud Date: 5178'FSL,4231'FEL,Sec. 16,T13N, R7E, UM 417497 3/26/2015 Total Depth 9 Acres in Property 14.Distance to Nearest Property 3180'FSL,382'FEL,Sec. 18,T13N, R7E, UM • 11,484 I 3,180' 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- 469793 67 y- 6031023.58 Zone- • ASP-4 GL Elevation above MSL. . 13.5 feet to Same Pool' 1,798'(ODSN-48) 16.Deviated wells: N/A Kickoff depth . 193 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle- - 90 degrees Downhole: 3204 psi ' Surface. 2513 psi . 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) Driven 16" 109# H-40 Welded 115' Surface Surface 158' 158' N/A 14-1/2" 11-3/4" 60# L-80 BTC 6595' Surface Surface 6638' 3236' 860 sks lead,595 sks tail 11-3/4" 9-5/8" 40# L-80 Hyd 521 5362' 6488' 3187' 11850' 4954' X190 sks primary 9-1/2" 7" 26# L-80 Hyd 563 15761' Surface Surface 15803' 6094' Stage 1 -345 sks primary- Li...-rc Stage 2-248 sks primary T,-:.i... 6-1/8" 4-1/2" 12.6# C-110 Hyd 521 7150' 15654' 6081' 22804' 6288' N/A 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). Perforation Depth TVD(ft). See attached schematic See attached schematic 20 Attachments• Property Plat ❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis] Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25 050 requirements❑✓ 21. Verbal Approval' Commission Representative: Date 22 I hereby certify that the foregoing is true and correct Alex Vaughan,343-2186 Contact alex.vaughanacaeluseneray.com Email Printed Name Alex Vaughan Title Senior Drilling Engineer Signature ._..._/' Phone 343-2186 Date 3/16/2015 l Commission Use Only Permit to DrillAPI Number: Permit App vat See cover letter for other Number. ,2[5-- 0511 50- 70S --6 og-OO-00 Date: /2rJ/22_015 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: [tC Other: et- Ll5c'2c.) lase 66 8 t'S f-- Samples req'd Yes❑ No❑✓ Mud log req'd:Yes No✓❑" H2S measures Yes❑ No[✓]• Directional svy req'd:Yes171 No❑ r FU`c-i. re 3 -..-:-.2.-1-_ Spacing exception req'd. Yes❑ Nolij Inclination-only svy req'd:Yes❑ No APPROVED BY Approved by: - 411. % V-4./•----._ COMMISSIONER THE COMMISSION Date: 5,25-1-/S— , i 3._a3- PM j/,71/s i n' Submit Form and Form 10-401(Revised 10/2012) i i �I7�f��months from the date of,a (20 AAC 25.005(g)) Attachments in Duplicate �..�3%//J cAELus Energy Alaska Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive,Anchorage,AK 99503 Tel:(907)277-2700 Fax:(907)343-2190 March 16th, 2015 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSN-22 Surface Location: 2907' FSL, 1204' FEL, Sec. 11, T13N, R7E, Umiat X = 469,793.67 & Y = 6,031,023.58 ASP4 Caelus Natural Resources Alaska, LLC. (CNRA) 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. CNRA 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 -6,638, MD / 3,236' TVD 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 -11,850' MD / 4,954' 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 -15,804' MD / 6,094' TVD and set 7" Intermediate casing into the top of the Oooguruk-Nuiqsut formation. • Lateral Hole: o Drill 6-1/8" horizontally to -22,804' MD / 6,288' TVD and set a 4-1/2" liner with a Halliburton mechanical diversion frac system. • Fracture Stimulation Completion: •-� Sz, - S 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 ScSSV & GLM. Alaska Oil & Gas Conservation Commission March 16th, 2015 Page 2 of 3 CNRA will implement Managed Pressure Drilling technology (MPD) while drilling the Intermediate 2 section and the lateral hole section as outlined below. r Intermediate 2 shoe to TD o Use -10.0-10.4 ppg WBM 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 is Lateral shoe to TD o Use -7.6-8.4 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. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A summary of the drilling operations. e. A summary of drilling hazards per 20 AAC 25.005 (c) (4). f. A wellbore schematic is attached visually depicting the proposed well. g. One-half mile plot of ODSN-22 Torok intersection relative proximity to the ODSDW1-44 Torok disposal well. h. Proximity plots showing relative distance from the T46i injector to the ODSN- 22 Torok intervals. i. Proximity plot of closest offset Nuiqsut injector ODSN-23i to ODSN-22 j. ODSN-22 Diverter routing 3) A copy of the Planned Directional Well Path - including traveling cylinder and development layout plots. Alaska Oil & Gas Conservation Commission March 16`h, 2015 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) CNRA 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@caelusenergy.com 2) Geologic Data and Logs Greg Griffin, Operations Geologist (20 AAC 25.071) 907.343.2141 greg.griffin@caelusenergy.com The anticipated spud date for this well is March 27th, 2015. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186 Sincerely, Alex Vaughan Senior Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSN-22 Well File Permit to Drill Well Plan Sumi..ary ODSN-22 Oooguruk — Nuiqsut Single Lateral Production Well Surface TD @ 6,638' MD / 3,236' TVD Drilling Liner TD @ 11 ,850' MD / 4,954' TVD Intermediate TD @ 15,804' MD / 6,094' TVD Lateral TD @ 22,804' MD / 6,288' TVD Surface Location: 2907' FSL, 1204' FEL, Sec. 11, T13N, R7E, Umiat ASP 4 (NAD27) projection X=469793.67 Y=6,031,023.58 Target: Oooguruk-Nuiqsut 5178' FSL, 4231' FEL, Sec. 16, T13N, R7E, Umiat(ADL355037) X=456,199.28 Y=6,028,081.88 6094'TVDrkb Bottom Hole Location 3180' FSL, 382' FEL, Sec. 18, T13N, R7E, Umiat(ADL355037) X =449,482,61 Y=6,026,126.78 6288' TVDrkb AFE Number:TBA Est. Start Date: March 27th, 2015 Rig: Nabors 19AC Operating days: 82 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 Caelus Natural Resources Alaska LLC Last Revised: March 16th, 2015 ODSN-22 Permit To Drill Page 1 of 15 Well Control: Well Section Pressure Depth psi TVD Basis 14-1/2" Surface Section Maximum anticipated BHP 1447 3236 Based on seawater gradient of 0.4472 psi/ft Maximum surface pressure 1091 Surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 10-5/8" x 11-3/4" Intermediate 1 Casing Hole Section Maximum anticipated BHP 2216 4954 Based on seawater gradient of 0.4472 psi/ft Maximum surface pressure 1671 Surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 8-1/2" x 9-1/2" Intermediate 2 Casing Hole Section Maximum anticipated BHP 3106 6094 Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) Maximum surface pressure 2435 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 6-1/8" Production Hole Section ,R Maximum anticipated BHP 3204 r 6288 Based on 9.8 ppg Oooguruk-Nuiqsut pore AAA 3P pressure) Maximum surface pressure 2513 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Maximum casing pressure: 4000 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(schematicon file with AOGCC)— 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(schematic on file with AOGCC): 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 Caelus Natural Resources Alaska LLC Last Revised: March 16th,2015 ODSN-22 Permit To Drill Page 2 of 15 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 Surface— EOB 8.8-9.5 70-200 30 - 50 10 - 25 10— 15 unrestricted EOB —TD'MD 9.2-9.6 70-100 25—35 15—25 10— 15 <12 Intermediate 1 Hole Mud Properties: 10-5/8" x 11-3/4" hole MOBM HTHP@ Interval Density(ppg) Viscosity(secs) YP PV 200 OWR Intermediate 1 10.0-10.4 ppg 55 -80 12 - 25 20 - 35 <6 80 / 20 Intermediate 2 Hole Mud Properties: 8-1/2" x 9-1/2" hole LSND -, Interval Density(ppg) Viscosity(secs) YP PV MBT API (ml) Intermediate 2 10.2-10.5 ppg 50— 70 25-30 10 - 25 < 15 <6 (-12.5 ppg via MPD) Production Hole Mud Properties: 6-1/8" hole Enviromul Interval Density(ppg) Viscosity (secs) YP PV HTHP OWR ,l�' Lateral 7.6 -8.2 ppg 55 - 80 8-15 12 - 25 <6 94/ 10 ('',0‘) ° (-9.8 ppg via MPD) Caelus Natural Resources Alaska LLC Last Revised: March 16th, 2015 ODSN-22 Permit To Drill Page 3 of 15 Formation Markers: Estimated Name TVD MD Pore Pressure Top of Permafrost 853.2 868 Base of Permafrost 1668.2 1963 UGNU 1736.2 2111 WSAK 2278.2 3732 CRET TUFF 2857.2 5488 HUE 2 3206.2 6547 SCP (30'TVD below Hue 2 marker- see Hue 2 marker on logs) 3236.2 6638 Hue Res C tied 3414.2 7178 Hue Res B tied 3874.2 8574 Hue Res A tied 4148.2 9405 8.6 BROOK 2B 4170.2 9472 ICP1 (15'TVD above the Torok ) 4954.2 11850 TOROK TOP 4969.2 11896 TOROK BASE 5152.2 12451 TOROK SH1 MKR 5329.2 12988 115 TOP HRZ 5797.2 14408 129 BASE HRZ 5918.2 14775 130 KALUBIK MKR 5992.2 15012 KUP C 6022.2 15139 134_LCU 6022.2 15139 145 BCU 6075.2 15586 NUIQSUT 6086.2 15712 NUIQ 1 6090.2 15758 9.8 ICP2 —(4' TVD below Nuiqsut 1 -see Nuig1 marker on logs ) 6094.2 15804 Permit TD (7K) 6287.8 22804 Anticipated Fault Tops Est Throw Estimated Throw Direction Dark Brown Fault 45 down to up down to up but also very Yellow fault 20 chaotic Caelus Natural Resources Alaska LLC Last Revised: March 16th, 2015 ODSN-22 Permit To Drill Page 4 of 15 Logging Program: 14-1/2" Section: Drilling: Dir/GR v Open Hole: N/A Cased Hole: N/A 10-5/8"x 11-3/4" Section: Drilling: Mud Logging—50' samples Dir/GR/Res/At-bit GR/ PWD Open Hole: N/A Cased Hole: 8-1/2"Section: Drilling: Mud Logging— 50ft samples Dir/GR/ Res/PWD/At-bit GR Open Hole: N/A Cased Hole: Bat Sonic Bond log of 7" Casing 6-1/8" Section: Drilling: Mud logging— 100ft samples, 200ft isotube gas samples Dir/GR/ Res/AzDens/ Neut /PWD/At-bit Inc Open Hole: N/A Cased Hole: N/A Caelus Natural Resources Alaska LLC Last Revised: March 16th,2015 ODSN-22 Permit To Drill Page 5 of 15 Casing Program: Hole Casing/ Weight Grade Conn. Casing Csg/Tbg Top Hole Btm Size Tubing Length MDrkb MDrkb/TVDrkb 24" 16" 100.2# X-65 Welded 115 Surface 158 158 14-1/2" 11-3/4" 60# L-80 BTC 6595 Surface 6638 3236 11-3/4" 9-5/8" 40# L-80 Hydril 521 5362 6488.08 11850 4954 9-1/2" 7" 26# L-80 Hydril 563 15761 Surface 15804 6094 6-1/8" 4-1/2" 12.6# 0-110 Hydril 521 7200 15603.77 22804 6288 Tubing 4-1/2" 12.6# C-110 Hydril 521 15571 Surface 15614 6077 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" BTC 5830 ' 3170 1384M 1384M 9-5/8" 40# L-80 8.835' 8.75" Hydril 521 5750 ' 3090 641 M 916 M 7" 26# L-80 6.276" 6.151 Hydril 563 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 Caelus Natural Resources Alaska LLC Last Revised: March 16th,2015 ODSN-22 Permit To Drill Page 6 of 15 V Cement Calculations: ODSN-22 Surface Casing Volumes Outer Innes AI TWe.. .Top MD Bottom MD Length weight Grade Meted. Conductor Casing 0 158 rYiamaterDiameter 158 16 14.688 109 Conductor= 158 158 1,963.42 1805.42 14.5 75.00% Open Hole 1,963.42 6,638.08 4674.66 14.5 30% Surface Casing 0 6,638.08 6638.08 11.75 10.772 60 L80 Float Collar 6,554.08 Float Shoe 6,638.08 a se of Permafrost= 1,963.42 --- --- apedtycattora Cement bbl/ft Density Yield Water Req. Total Conductor%Surface 0.0755 ppg ft3/sk gal/sk sk bhl Open Hole 0.2042 Lead 11.34 3.91 19.24 859.72 598.71 Open Hole%Surface 0.0701 Tail 15.8 1.1853 5.238 595.20 125.65 Surface Casing 0.1127 Total Lead Volume Total Tail Volume Total Lead Length I 5421.45 ft Tad Cement Column Length 1,216.63 ft Below Permafrost 3458.03 ft Excess 30% % Excess 30% % Open Hole Volume 85.31 bbl Top ofTail Cement= 5421.45 Below Permafrost Volume 242.49 bbl Excess Volume 25.59 bbl 3,000'TVD= 5921.45 Excess Volume 72.75 bbl Shoe Track Length 84.00 ft Permafrost Zone 1805.42 ft Shoe Track Volume 9.47 bbl Excess 75.00% % Rat Hole Length 0.00 ft .. I♦ Float Collar= 6,554.08 Permafrost Zone Volume 126.60 bbl Rat Hole Volume 0.00 bbl Excess Volume 94.95 bbl Cement to Fill Lines(25 sacks) 5.28 bbl Conductor Annulus Volume 11.92 bbl Total Cement Volume 125.65 bbl `V Float Shoe= 6,638.08 Additional Volume 50.00 bbl Total Cement Volume 598.71 bbl Y Displacement Water Behind 20.00 bbl Rig Displacement 718.76 bbl Total Displacement 738,76 661 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. Caelus Natural Resources Alaska LLC Last Revised: March 16th,2015 ODSN-22 Permit To Drill Page 7 of 15 ODSN-22 Intermediate 1 Type Top MD Bottom MD Length Ater Inner Weight Grade Excess Diameter Diameter Surface Casing 0 6,638.08 6638.08 11.75 10.772 60 L80 Open Hole 6,638.08 11,850.48 5212.4 11.75 15.00% Drill Pipe 0.00 6,438.08 6438.08 5 4.276 19.5 Intermediate Casing 6,438.08 11,850.48 5412.4 9.625 8.835 40 L80 Landing Collar 11,730.48 Float Shoe 11,850.48 Capacity Factors Cement Top of Liner= 6,438.08 6bl/ft Density Yield Water Req. Total ' Surface XIntermediate 0.0227 ppg ft3/sk gal/sksk bbl Open Hole 0.1341 Primary 15.8 1.1726 5.089 I1 39.69 ® ,Surface Casing= 6,638.08 Open Hole X Intermediate 0.0441 Intermediate Casing 0.0758 Drill Pipe 0.0178 Drill Pipe X Surface 0.0884 Total Lead Volume Total Lead Length 500.00 ft Open Hole Volume 22.06 bbl Excess 15% Top of Cement= 11,350.48 Excess Volume 3.31 bbl Shoe Track 9.10 bbl Rat Hole Length 0.00 ft Landing Calla r= 11,730.48 Rat Hole Volume 0.00 bbl Additional Line Volume(25 sacks) 5.22 bbl L_� _ Float Shoe= 11,850.48 Tate!Cc-rent Voll'nor 39.69 bbl Displacement Water Behind 20.00 bbl Drill Pipe Volume 114.35 bbl Intermediate Volume 410.39 bbl Rig Displacement 504.74 bbl The planned TOC is 15' TVD above the Top of Torok formation. The Torok formation will be drilled through in the intermediate 2 hole section. The following information is provided due to proximal vertical distance between 9-5/8"shoe and top of Torok formation. At the intersection with the Torok disposal zone, this well is outside of the 1/2 mile radius from disposal well ODSDW1-44. This well is inside the % mile radius of the T46i Torok injection well. The ODSN-22 is approximately 772'away from the ODST-46i when it enters the Torok and approximately 1309'away when it exits the base Torok. (see attached plot) The ODST-46i has been shut-in and will remain shut-in until the ODSN-22 has drilled out Intermediate 2. The planned TOC is 500ft above 9-5/8"shoe depth. Caelus Natural Resources Alaska LLC Last Revised: March 16th, 2015 ODSN-22 Permit To Drill Page 8 of 15 ODSN-22 Intennediate 2-Stage 1 I Outer Miter Type ToPMD Bottom MD Length Diameter Diameter Grade Emma Surface Casing 0 6,638.08 6638.08 11.75 10.772 60 L80 Intermediate Casing 6,438.08 11,850.48 5412.4 9.625 8.835 40 L80 Intermediate 2 Casing 0.00 15,803.77 15803.77 7 6.276 26 L80 Open Hole-Stagel 11,850.48 15,803.77 3,953.29 9.5 30% Open Hole-Stage 2 11,850.48 15,803.77 3953.29 9.5 40% ES-Il Cementer 12,447.20 12,451.20 4 7.875 6.17 26 L80 Baffle Adapter 15,643.77 Float Collar 15,723.77 Float Shoe 15,803.77 CApxityPactors Cement bbl/ft Density Yield Water Req. Total Surface X Intermediate 0.0227 ppg R3/sk gal/sk sk bbl Top of Liner= 6,438.08 Surface X Intermediate 2 0.0651 Primary 15.8 1.1726 5.089 344.76 72.00 AM ,, Intermediate 1 0 - Surface Casing 6,638.08 _ 0.0282 Intermediate 2 X Open Hole 0.0401 Intermediate 2 0.0383 Open Hole 0.0877 Total PrimaryCement Volume Total Lead Length 1164.47 ft Open Hole Volume 46.66 bbl Excess 30% % Excess Volume _ 14.00 bbl _ Shoe Track 6.12 bbl Rat Hole Length 0.00 ft Rat Hole Volume 0.00 bbl AIL Intermediate 1= 11,850.48 Additional Line Volume(25 sacks) 5.22 bbl Torok Top= 11,895.90 1i Total Cement Volume 72.00 bbl Torok Base 12,451.20 I ES-Il Cementer= 12,451.20 Torok SH1 MKR 12,988.20 1 Displacement I Water Behind 20.00 bbl � Intermediate Volume Above Cementer 476.40 bbl Top HRZ= 14,408.10 i Intermediate Volume Below Cementer 122.15 bbl Base HRZ= 14,775.20 I Top of Cement= 14,639.30 Rig Displacement 578.56 b61 Kal ubik MKR= 15,012.20 I Total Displacement 592.51 LII Kuparuk= 15,139.30 I---- 4 I Balite Adapter= 15,643.77 Nuigsut= 15,711.90 I - __ r71=-11775-7.0 i Float Collar= 15,723.77 L 11111111111111 _ __, Float Shoe= 15,803.77 The planned TOC is 500ft above potential Kuparuk formation. Planned TOC is precautionary since Kuparuk is not mapped in ODSN-22 wellbore and was not encountered on the offset ODSN-48. Sikumi offset well located in close proximity to ODSN-48 and indicated no Kuparuk present. e' Caelus Natural Resources Alaska LLC Last Revised: March 16th,2015 ODSN-22 Permit To Drill Page 9 of 15 ODSN-22 Intermediate 2-Stage 2 Type Top MD Bottom MO length Outer Inner....fr.,....fr., Weight Grade Excess Olssueaer Surface Casing 0 6,638.08 6638.08 11.75 10.772 60 L80 Intermediate Casing 6,438.08 11,850.48 5412.4 9.625 8.835 40 L80 Intermediate 2 Casing 0.00 15,803.77 15803.77 7 6.276 26 L80 Open Hole-Stage 1 11,850.48 15,803.77 3,953.29 9.5 30% Open Hole-Stage 2 11,850.48 15,803.77 3953.29 9.5 40% ES-Il Cementer 12,447.20 12,451.20 4 7.875 6.17 26 L80 Baffle Adapter 15,643.77 Float Collar 15,723.77 Float Shoe 15,803.77 Capacity enters Cement bbl/ft Density Yield Water Req. Total Surface X Intermediate 0.0227 ppg ft3/sk gal/sk sk bbl Top of Liner= 6,438.08 Surface X Intermediate 2 0.0651 Primary 15.8 1.1733 5.093 247.66 51.75 PriiSurface Casing= 6,638.08 Intermediate,X 0.0282 Intermediate 2 X Open Hole 0.0401 Intermediate 2 0.0383 Open Hole 0.0877 Total Primary Cement Volume Total Lead Length 1055.30 ft Open Hole Length 600.72 ft Open Hole Volume 24.07 bbl Excess 40% % Excess Volume 9.63 bbl Cased Hole Length 454.58 ft Top of Cement= 11,395.90 Cased Hole Volume 12.83 bbl Intermediate 1= 11,850.48 Additional Line Volume(25 sacks) 5.22 bbl_ Torok Top= 11,895.90 'JI Total Cement Volume 51.75 bbl Torok Base= 12,451.20 ES-Il Cementer= 12,451.20 wok 5/11 MKR= 12,988.20 I Dhplacement I Water Behind 20.00 bbl Intermediate Volume Above Cementer 476.40 bbl Top HRZ0 14,408.10 i Rig Displacement 456.40 bbl Base HRZ= 14,775.20 I Top of Cement= 14,639.30 Total Displacement 476.40 bbl Kalubik MKR= 15,012.20 Kuparuk= 15,139.30 I I ►� Baffle Adapter= 15,643.77 Nuigs ut= 15,711.90 Nuiq 1= 15,757.80 ►= I Float Collar= 15,723.77 I ® I I I_ __I Float Shoe= 15,803.77 TOC is designed to cover 500'MD above Top of Torok Sand Package. The second stage cement job will fill the 9-5/8"x 7"annulus with cement thereby sealing off annular pressure communication between the 11-3/4"x 9-5/8r"x 7"annulus and formations below the 9-5/8"shoe. Disposal: Annular Injection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal well, ODSDW1-44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal well, ODSDW1-44. Caelus Natural Resources Alaska LLC Last Revised: March 16th,2015 ODSN-22 Permit To Drill Page 10 of 15 Caelus Natural Resources Well Plan Summary Drilling Operations Pre-Riq Work 1. 16" Conductors have been set and the Well Bay modules have been placed. Riq Activity: Drill and Complete 1. MIRU Nabors 19AC over pre-installed 16" conductor casing. kett' 2. Nipple up spacer spools, riser, &diverter. -��e 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. Note: A Port Collar will be run as a precaution and used if the primary job is deemed unacceptable. 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" Bit and dumb iron cleanout assembly and RIH. 8. Clean out cement stringers to top of float collar and test casing to 3500psi-chart and hold test for 30 minutes. 9. MU 10-5/8"x 11-3/4" RSS, including Weatherford Under-reamer and MWD/LWD and RIH. 10. Displace to Intermediate 1 10.0ppg MOBM drilling fluid. 11. Drill rathole + 20' of new hole and perform LOT to a minimum of 12.5 ppg. 12. Drill 10-5/8"x 11-3/4" Intermediate 1 to casing point. • Intermediate 1 hole section will be drilled to roughly 15'TVD above the Top of Torok. 13. Change one set of pipe rams to 9-5/8" and test BOPE as required. 14. Run 9-5/8"drilling liner on 5" DP. Set liner hanger, release from liner and cement. • Planned cement top is 500ft above 9'5/8" shoe depth. 15. 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 16. 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 17. 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 18. POOH w/5" DP. 19. ND BOPE, ND Drilling spool, NU Multi-bowl Wellhead, & NU BOPE and install Halliburton managed pressure drilling (MPD)equipment. Test BOPE 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 20. MU 8-1/2" bit and dumb iron assembly and RIH to top of 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 liner shoetrack and rathole. Displace Intermediate 1 drilling fluid to Intermediate 2 drilling fluid while drilling the shoetrack. 23. MU 8-1/2" x 9-1/2" RSS, MWD/LWD on 5" DP and RIH. RU MPD seal bearing package in the rotary control device. 24. Drill 20' MD of new formation. Pull the bit back into the casing and perform FIT to 13.5ppg EMW. POOH. 25. Drill 8-1/2" Intermediate 2 to Torok 1 Shale Marker holding 12.5 ppg EMW via MPD. 26. Slot LCM pill across Torok Sand Package. Caelus Natural Resources Alaska LLC Last Revised: March 16th, 2015 ODSN-22 Permit To Drill Page 11 of 15 27. Pull into 9-5/8" shoe and perrurm bore hole strengthening squeeze. 28. Drill 8-1/2" Intermediate 2 to casing point holding 12.5 ppg EMW via MPD. 29. Wash and ream in hole to Torok 1 Shale Marker. 30. 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. 31. Change one set of pipe rams to 7" and test BOPE as required. 32. Run 7" 26# L-80 Hydril 563 Intermediate 2 casing to TD. • Position stage cementer at Base of Torok Sand Package. /Z1 yoor A.A.() 33. Pump stage 1 cement job. • TOC of cement job designed to cover 500' MD above Top of Kuparuk. • Minimal Kuparuk formation is expected in ODSN-22 as was observed in both of the nearest offset wells, ODSN-43 and ODSN-48 34. Precede second stage of cement job with MOBM spacer intended to act as a freeze protection fluid for the 11-3/4" x 9-5/8" x 7" annulus 35. Pump stage 2 cement job. a. TOC is designed to cover 500' MD above Top of Torok Sand Package. The second stage cement job will fill the 9-5/8" x 7" annulus with cement thereby sealing off annular pressure communication between the 11-3/4" x 9-5/8" x 7" annulus and formations below the 9-5/8" shoe. 36. Bump the plug and bring the pressure up to 3500 psi-hold for 5 minute pressure test. Release pressure and ensure floats are holding. 37. LD 5" DP 38. RU MPD trip nipple & PU 4" DP as needed to TD the lateral hole section. 39. RIH to landing collar and w/4" DP & mill tooth cleanout bit. 40. Change pipe rams to 4" and test BOPE to 250/4500 psi-Notify AOGCC 48 hours in advance of test. 41. Pressure test casing to 4000 psi -chart and hold for 30 minute pressure test. Send chart to ODE. 42. Drill through Intermediate 2 shoe and POOH w/cleanout assembly. 43. MU 6-1/8" Motor, agitator, MWD/LWD drilling assembly on 4" DP and RIH. 44. RD MPD trip nipple and RU bearing assembly. 45. Displace to drill-in-fluid for lateral hole. 46. Drill rathole 20' of new hole and perform FIT to 12.5 ppg. 47. Drill 6-1/8" lateral lateral hole to TD. 48. Circulate and condition hole to run liner. 49. POOH to intermediate shoe and set heavy weight balance brine pill. 50. RD MPD bearing assembly and RU MPD trip nipple. Continue POOH to surface. 51. Change one set of pipe rams to 4-1/2" and test BOPE as required. 52. RIH w/4-1/2" production liner w/ Halliburton frac sleeves and swellpackers from 150' inside the intermediate shoe to TD. 53. Release from the liner and set the liner top packer. Displace the well over to completion brine and POOH. 54. Run 4-1/2"fracture stimulation string to top of 4-1/2" liner seal bore. 55. Reverse circulate corrosion inhibited brine or diesel to freeze protect the well to -2000' TVD. 56. Sting 4-1/2"fracture stimulation string into the 4-1/2" liner seal bore. 57. Pressure test 7-5/8" x 4-1/2" annulus to 3500 psi - chart and hold for 30 minute pressure. Send chart to ODE. Caelus Natural Resources Alaska LLC Last Revised: March 16th, 2015 ODSN-22 Permit To Drill Page 12 of 15 CNRA will submit a sundry prior to executing the following program Post Rig Operation: Fracture Stimulation Of/ jiteP 1. Fracture stimulate well �J 2,000,000 lbs of 20/40 Carboceramics Carbolite proppant puri ped in 600,000 gallons of Schlumberger's YF125ST. The fluid volume includes a pad stage yet to be determined. The stimulation will target the Nuiqsut reservoir in a 11 stage treatment using the Halliburton frac sleeve 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 '/2"fracture stimulation string. 4. RIH w/ ESP completion w/ Packer&Tubing Retrievable ScSSSV. 5. Space out and land tubing hanger. 6. RILDS and test both the upper and lower tubing hanger body seals to 5000psi. 7. Set BPV, ND BOPE, NU Production Tree 8. Replace BPV w/TWC & Test Production Tree void to 5000psi & recover TWC 9. Reverse circulate corrosion inhibited brine or diesel to freeze protect the well to —2000'TVD 10. Set packer and test annulus to 3500 psi for 30 min. Post Rig Operations: 1. Rig up slickline 2. Retrieve ball/rod assembly from the RHC-M plug body 3. Pull dummy valve from lower GLM, set '/" OV in same. 4. Retrieve RHCM plug body 5. Rig down slickline 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. Caelus Natural Resources Alaska LLC Last Revised: March 16th, 2015 ODSN-22 Permit To Drill Page 13 of 15 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 1/4 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. Caelus Natural Resources Alaska LLC Last Revised: March 16th,2015 ODSN-22 Permit To Drill Page 14 of 15 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Torok, hold a pre-reservoir meeting to outline heightened awareness for kick detection and lost circulation. o Following the Torok 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 • The Kuparuk formation is not predicted in the ODSN-22 wellpath, however heightened awareness for lost circulation or overpressure will be stressed prior to drilling the interval. • 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 I Maximum Mud Weight Exp Pore Min LOT/ FIT Interval Influx Volume Press 11-3/4" Surface/ Infinite 10.0-10.4 ppg 2216 12.5 ppg (LOT) 10-5/8"x 11-3/4" 9-5/8" Drilling Liner/ Infinite 10.2-10.5 ppg 3106 13.5 ppg (FIT) 8-1/2"x 9-1/2" (13.0 EMW w/MPD) 7" Intermediate/ Infinite 7.4-8.4 ppg 3204 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. Caelus Natural Resources Alaska LLC Last Revised: March 16th, 2015 ODSN-22 Permit To Drill Page 15 of 15 0 6;3-' 1O in 0 ' ? 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N LTo L _4- C~ ` C o V \ p a ai � �c c ,,'t f6 -.o u � S N a 3 0.10 A C 0 O c c V — © � O3aflmc • F m _c - O Ce a «v 3 w z 2 a z C 0 z c° 3 w ODSN-22 Nuiqsut Production Well Completion r�65,t r.,-16-2015 I No. Upper Completion MD(ft) TVD(ft) .1111 I Land Upper 1 Tubing Hanger 43 43 I Completion 2 4-'"12.6#/ftC-110 Hydri1521 Tubing I with 40,000 lbs 4-124"Halliburton'XXO'SVLN w/3.813""X"profile with singlel/4"x 0.049"s/s control line. Cannon Cross-coupling clamps on every joint w/15ft Pup BxP Top&Bottom 11 I Slack-Off 4 4-%"12.6#/ft C-110 Hydril 521 Tubing 1 5 4-A"x 1"GLM#3,KBG-2 Hydril 521 w/15ft Pup BxP Top&Bottom 3425 2175 1 6 4-A"12.6#/ftC-110 Hydril 521 Tubing 7 HES"X"Nipple 3.813"w/15ft Pup BxP Top&Bottom 3480 2193 I 16"Conductor 8 4-'/:"12.6#/ftC-110 Hydril 521 Tubing • -- ‘it 1O 9 4,A"x1"GLM#2,KBG-2 Hydril 521 w/15ft Pup BxP Top&Bottom 8959 4000 Ai .. ,Packer Fluid mix: 10 4-A"12.6#/ftC-110 Hydril 521 Tubing _ 1 Inhibited Kill 11 4A"xl"GLM#1,KBG-2Hydril 521w/15ft Pup BxP Top&Bottom 14417 5800 I weight Brine 12 4-A"12.6#/ftC-110Hydril 521 Tubing GLM#31 with 2000'TVD 13 HES"X"Nipple 3.813"w/15ft PupBxP Top&Bottom 14337 5774 OSOV 5 GL 14 4-A"12.6#/ftC-lb Hydril 521 Tubing Installeddiesel Cap 4-1/2"Halliburton'ROC'Gauge Carrier w/Encapsulated e-line to Surface w/15ft Pup I, 7,000 psiI Bottom Mae ' X 1 1 11-3/4"60#L-80 18 4-A"12.6#/ftC-110 Hydril 521 Tubing(2jts) 1 cBTC Surface Casing 41/2"APCV II Non-Elastomeric Sliding Sleeve,125ksi Frac Harden Body&Inner Sleeve 3.81.3" Aii., @ 6,638'MD/ 19 PCU(Profile W/41/2"12.60#Hyd 521 Box X Pin,Opens Up,10,030 Psi w/15ft Pup BxP Top& 14782 5920 1 3,236'TVD Bottom I cemented to surface 20 4-X"12.6#/ftC-110 Hydril 521 Tubing(2jts) • 1 21 HES XN 3.813"(3.725"NoGo)-w/15ft Pup BxP Top&Bottom 14877 5952 22 4-A"12.6#/ftC-110 Hydril 521 Tubing I 4-1/2"x4"Crossover P-110 Locator with a 5.66'long 41/2"handling pup on top,4"Spacer Pup w/ 1 TOC 23 Bullet Seal Assembly+Auto Entry Guide Shoe • 15577 6074 GLM#2 I Estimated Bottom of Shoe 15613 6077 DGLV @ 500 ft Installed O GL h' above 9-5/8" No. Lower Completion MD(ft) TVD(ft) 7,000 psi i Shoe 24 Baker 5"X 7"ZXP Liner Top Packer with 20ft 5.25"Tie Back extension and Flex Lock Hanger/20 1555E Max rated ' I ft4.25"Seal Bore Receptide Below Hanger 1 9-5/8"40#L-80 25 4-A"12.6#/ft Hydril 521 C-110 Liner 26 Resman Internally Vented Carrier 84 ROS-1157/RWS-1199 w/15ft Pup BxP Top&Bottom 15,818 6095 1 Hydril 521 27 4-A"12.6#/ft Hydril 521 C-110 Liner I Intermediate 1 Halliburton Swell Packer#12(4-A"Hydril 521)OD 5.85'-9meter long oil activated with Slide oi". 11 I Casing 28 Volant Centralizer Pin End and 6ft Pup4-1/2"12.6#/ft P.110 Hydril 521 Box x Pin w/Slide On 1 @ 11,794'MD/ Volant Centralizer on Top of Swell Packer 4,935'TVD 29 4-A"12.6#/ft Hydril 521 C-110 Liner I , 30 HLB 4-1/2"RapidStage Ball Actuated Sleeve(3.009 ball/2.95 Seat)w/15ft 4-1/2"P-110 Pup 4 16,227 6,131 GLM#'I 1/2"12.6#/ft P-110 Hydril 521 Box x Pin I ES Cementer 31 4-V,'12.6#/ft Hydril 521 C-110 Liner DGLV I• Halliburton Swell Packer#11(4-A"Hydril 521)0D 5.85'-9meter long oil activated with Slide o' Installed GL Base Torok 32 Volant Centralizer Pin End and 6ft Pup 41/2"12.6#/ftP-110 Hydril 521 Box Pin w/Slide On 7,000 psi® Volant Central,, on Top of Swell Packer Max rated t x I 33 4-'"12.6#/ft Hydril 521 C-110 Liner I 11's 7"Stage 2 TOC 34 HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.925 ball/2.867 Seat)w/15ft 4-1/2"P-110 Pup4- 16,843 6,147 17 aac 1/2"12.6#/ft P-110 Hydril 521 Box x Pin Estimated 35 4,A"12.6#/ft Hydril 521 C-110 Liner Sliding • @ 500 ft above Halliburton Swell Packer#10(4'"Hydril 521)005.85'-9 meter long oil activated with Slide or SleeveTorok Sand 36 Vol ant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 79 Closed UDU Package Volant Centralizer on Top of Swell Packer 37 4-A"12.6#/ft Hydri1521 C-110 Liner 38 HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.842 ball/2.786 Seat)w/15ft 4-1/2"P-110 Pup 4 17,460 6,159 RHC Plug® XN 1/2"12.6#/ft P-110 Hydril 521 Box x Pin Installed 7"Stage 1 TOC 39 4-A"12.6#/ft Hydril 521 C-110 Liner Estimated 40 Resman Internally Vented Carrier#3 ROS-1156/RWS-1198 w/15ft Pup BxP Top&Bottom 17,668 6,163 @ 500 ft above 41 4-A"12.6#/ft Hydril 521 C-110 Liner Halliburton Swell Packer#9(44"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on Kuparuk 42 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-130 Hydril 521 Box x Pin w/Slide On --- Volant Centralizer on Top of Swell Packer I 43 4-A"12.6#/ft Hydril 521 C-110 Liner ® • 24 HIS 4-1/2"RapidStage Ball Actuated Sleeve(2.761 ball/2.706 Seat)w/15ft 4-1/2"P110 Pup 4 !� 44 18,076 6,171 hp 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 44k, .;\ - 45 4-A"12.6#/ft Hydril 521 C-110 Liner 7"26# L-80 BTC-Mi!;':. &Hydril 563 i� 32 5Lo' ( ' Intermediate 2 , i1; 36 4z i Casing 49 � 154 Ed R RI , @ 15,804'MD/ 2a 0 5 _ JR = RI NI_ _ _ _ _ _ _ o 6,094'TVD O _ _ I_I _ _ _I _ ' _ I-I 2 34 � 44 D4 El N N ®_.__� 38 40 4-'/2" Hydril 521 /C-110 Liner with Halliburton Ball Actuated 6-1/8" Hole TD Sleeves, &Swell Packers " @ 22,804'MD/ 6,288'TVD ODSN-22 Nuiqsut Production Well Completion 3-16-2015 1 I Land Upper 1 Completion No. Lower Completion MD(ft) TVD(ft) with 40,000 lbs Halliburton Swell Packer#8(4-'A"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on 1 46 Volant Centralizer Pin End and 6ft Pu " Slack-Off P 4-1/2 12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 18,384 I Volant Centralizer on Top of Swell Packer ( 47 4-A"12.6#/ft Hydril 521 C-110 Liner 48 HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.681 ball/2.628 Seat)w/15ft 4-1/2"P-110 Pup 4- 18,693 6,181 I 1/2"12.6#/ft P-110 Hydril 521 Box x Pin lO16"Conductor 49 4-A"12.6#/ft Hydril 521 C-110 Liner ' 1 % Halliburton Swell Packer 7(4- "Hydril 521)0D 5.85'-9 meter long oil activated with Slide on ',Packer Fluid mix: 50 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On . 1:4:; I Inhibited Kill Volant Centralizer on Top of Swell Packer I weight Brine 51 4-A"12.6#/ft Hydril 521 C-110 Liner GLM#3HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.603 ball/2.552 Seat)w/15ft 4-1/2"P-110 Pup 4- SGV Os GL f with 2000'TVD 52 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 19,309 6,181 Installed 1 diesel can 53 4-A"12.6#/ft Hydril 521 C-110 Liner 7,000 psi,-;- I 54 Resman Internally Vented Carrier#2 ROS-1155/RWS-1197 w/15ft Pup BxP Top&Bottom 20,134 6,197 Max rated x 11-3/4"60#L-80 55 4-A"12.6#/ft Hydril 521 C-110 Liner BTC Surface Casing Halliburton Swell Packer#6(4-%"Hydril 521)OD5.85'-9meter long oil activated with Slide on ©6,638'M D/ 56 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 19,617 (I;.:;: Volant Centralizer on Top of Swell Packer I ° 3,236'TVD 57 4-X"12.6#/ft Hydril 521 C-110 Liner IIIIIII I cemented to surface58 HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.527 ball/2.477 Seat)w/15ft 4-1/2"P-110 Pup 4 19,926 6,192 , 1 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 59 4-X"12.6#/ft Hydril 521 C-110 Liner I Halliburton Swell P. or#5(4:: Hydril 521)OD5.85'-9meter long oil activated with Slide on I TOC i7. Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 20,234 GLM#2 i Estimated Volant Centralizer on Top of Swell Packer DGLV @ 500 ft 61 4-'X"12.6#/ft Hydril 521 C-110 Liner 1 HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.452 ball/2.404 Seat)w/15ft 4-1/2"P-110 Pup 4- 9 Installed GL _I above 9-5/8" 62 20,542 6,206 7,000 psi i Shoe 1/2"12.6#/ft P-110 Hydril 521 Box x Pin Max rated ) 63 4-r"12.6#/ft Hydril 521 C-110 Liner Halliburton Swell Packer#4(4-%"Hydril 521)0D 5.85'-9 meter long oil activated with Slide on 9-5/8"40#L-80 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On I Hydril 521 Volant Centralizer on Top of Swell Packer 65 4-A"12.6#/ft Hydril 521 C-110 Liner 1 . Intermediate 1 HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.379 ball/2.332 Seat)w/15ft 4-1/2"P-110 Pup 4- 66 21,159 6,220 1 Casing 1/2"12.6#/ft P-110 Hydril 521 Box x Pin IIIL 1 @ 11,794'MD/ 67 4-X"126#/ft Hydril 521 C-110 Liner 4,935'TVD 68 Resman Internally Vented Carrier#1 ROS-1154/RWS-1196 w/15ft Pup BxP Top&Bottom 21,983 6,252 I � 69 4-A"12.6#/ft Hydril 521 C-110 Liner GLM#1 I i Halliburton Swell Packer#3(4-A"Hydril 521)0D 5.85'-9 meter long oil activated with Slide on ". i 1 ES Cementer 70 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On Installed GL T Base Torok Volant Centralizer on Top of Swell Packer 71 4-A"12.6#/ft Hydril 521 C-110 Liner 7,000 psi® f I HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.307 ball/2.261 Seat)w/15ft 4-1/2"P-110 Pup 4- 72 21,775 6,243 Max rated 3 x[' 1/2"12.6#/ft P-110 Hydril 521 Box x Pin --- I 7"Stage 2 TOC 73 4-X"12.6#/ft Hydril 521 C-110 Liner L,..11.) Roc 1 Halliburton Swell Packer#2(4-A"Hydril 521)OD 5.85'-9 meter long oil activated with Slide on Estimated 74 Volant Centralizer Pin End and Eft Pup 41/2"12.6#/ftP-110 Hydril 521 Box x Pin w/Slide On 22,083 Sliding I @ 500 ft above Volant Centralizer on Top of Swell Packer Sleeve „..._,' A A A Torok Sand 75 4-14"12.6#/ft Hydril 521 C-110 Liner Closed I9 Package 76 HLB 4-1/2"RapidStage Ball Actuated Sleeve(2.236 ball/2.192 Seat)w/15ft 4-1/2"P-110 Pup 4- 22 392 6,270 1/2"12.6#/ft P-110 Hydril 521 Box x Pin 77 4-A"12.6#/ft Hydril 521 C-110 Liner RHC PIut 0 I XN Halliburton Swell Packer#1(4-Y.."Hydril 521)0D 5.85'-9 meter long oil activated with Slide on Installed 7"Stage 1 TOC 78 Volant Centralizer Pin End and 6ft Pup 4-1/2"12.6#/ft P-110 Hydril 521 Box x Pin w/Slide On 22,700 Volant Centralizer on Top of Swell Packer Estimated 79 4-X"12.6#/ft Hydril 521 C-110 Liner @ 500 ft above 80 Pre-perforated Pup w/4-'/:"12.6#/ft Hydril 521 w/15ft 4-1/2"P-110 Pup BxP Top&Bottom 22,750 6,285 Kuparuk 81 4-A"12.6#/ft Hydril 521 C-110 Liner 82 4X"Hydril 521 Eccentric Shoe with Double Float Sub 22,800 i,i;'r. Bottom of Assembly 22,805 6,288 ® 4 �� t9 7"26# L-80 BTC-M ..,...\,,, lc. 0 &Hydril 563 i% sz Intermediate 2 1 �O 3s az Casing v ® .� ba -15Z.1 6a ba @ 15,804'MD/ za -`O 0 _ _ _ _ _ _ _ _ _ 6,094'TVD --/-,-,...\., 4 as QQ I-I I- - -I - I- I - 38 40 El El_ 41/2" Hydril 521 /C-110 Liner with Halliburton Ball Actuated 6-1/8" Hole TD Sleeves, &Swell Packers @ 22,804' MD/ 6,288'TVD Well Planning -Caelus- Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-22i ODSN-22i ISW2 Plan: ODSN-22 ISW2 wp11 Standard Proposal Report 16 March, 2015 HALU BURTON Sperry Drilling Services 0 MNWMMOWN,-VW K _0 Ncr,-OaWNO)�hW�pooO `a a. 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MC,..,.00D -OCNOirrrrWWWWWmm WWW — _ O.-IDD�.-N rtn 0000NNtOtt0O00p - 0 W W0QW W W WUNN00 UO - —0 Y:8 Or�MWtON•OrrhrIhVOIt��1t��f�V _ r 1 c E 0 •NNoONN-NWWWNvtWnttWmot)tc0WQtQWW ro a .000 > O O ���N.O NN N QW W W W W W m m N N N vm., _ _ LL poop O O O o _ Quo CO LOO m O�'NMQtOWr Wm O -� —h vt DD \ - 0 l —� 1 O - . 1 I. t 1 -LC0 -N 3 1 \ t _o J 0 t s _ r J r t t - Q \ '10 I m 1 tea_ t, iZZ,-0I- -- 8 V J 6 O M W t _ co y Z r' N 1�) - 1 } td . u' -88,Vto in�tnr4 g' } t J `� mE,1-61m a 3 } - O c 1- WN-0. - o M 2 - 3>EA,' w NQrpop N. \ t , < —P tmullo 5 GN2 O Woo° N 1 t,- wC E , ..FWOG U• 0<0 co mW W - vEti aiv Z ft�,_,_N z ,e\_ ti - ovov.-.o N N t.. _ O i f U O 6288 —o y L t t C 0 0 0 m.- N 3wJWE F0.O�OON 11II11 I liii1 111111111111 , 11 , 1I 111111111 I I III IIII II II II 111111 III II Ca 3 MQ OW 0 g o 0 0 8 o 0 0 0 0 0 0 o O U o 0 0 0 0 0 0 0 0 0 0 0000 M r co tr 9m r e h a N NNW.- N q Vt r Oui,1vn a (uygsn OM)(+)4uoN/(-)4;nnS Halliburton HAPvvv,g, , r ,g Standard Proposal Report Database: EDMPrd Local Co-ordinate Reference: Well ODSN-22i Company: Well Planning-Caelus-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-22i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 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: 469,920.45 usft Longitude: 150°14'45.46 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.23° Well ODSN-22i Well Position +N/-S 0.00 usft Northing: 6,031,023.58 usft Latitude: 70°29'44.98 N +El-W 0.00 usft Easting: 469,793.67 usft Longitude: 150°14'49.18 W 11 Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 13.50 usft I Wellbore ODSN-22i ISW2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) IGRF2010 11/12/2014 19.59 81.00 57.694 Design ODSN-22 ISW2 wp11 Audit Notes: Version: Phase: PLAN Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) r) 42.70 0.00 0.00 256.21 3/16/2015 9:59.03AM Page 2 COMPASS 5000.1 Build 58 Halliburton Standard Proposal Report Database: EDMPrd Local Co-ordinate Reference: Well ODSN-22i Company: Well Planning-Caelus-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-22i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 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) (°1100usft) (°I100usft) (°) 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 0.00 0.00 0.00 0.00 192.70 0.00 0.00 192.70 136.50 0.00 0.00 0.00 0.00 0.00 0.00 292.70 2.50 256.50 292.67 236.47 -0.51 -2.12 2.50 2.50 0.00 256.50 509.37 9.00 256.50 508.13 451.93 -5.57 -23.22 3.00 3.00 0.00 0.00 2,273.65 70.75 256.50 1,797.54 1,741.34 -257.03 -1,070.61 3.50 3.50 0.00 0.00 3,873.65 70.75 256.50 2,325.04 2,268.84 -609.66 -2,539.42 0.00 0.00 0.00 0.00 3,923.20 70.76 258.07 2,341.38 2,285.18 -619.95 -2,585.05 3.00 0.01 3.18 90.05 14,880.47 70.76 258.07 5,952.88 5,896.68 -2,757.67 -12,706.76 0.00 0.00 0.00 0.00 15,377.55 85.00 253.55 6,057.05 6,000.85 -2,876.96 -13,176.46 3.00 2.87 -0.91 -17.79 15,677.55 85.00 253.55 6,083.20 6,027.00 -2,961.60 -13,463.08 0.00 0.00 0.00 0.00 16,227.55 85.00 253.55 6,131.14 6,074.94 -3,116.78 -13,988.55 0.00 0.00 0.00 0.00 16,357.55 88.90 253.54 6,138.05 6,081.85 -3,153.55 -14,113.02 3.00 3.00 -0.01 -0.15 18,557.55 88.90 253.54 6,180.29 6,124.09 -3,776.91 -16,222.44 0.00 0.00 0.00 0.00 18,594.22 90.00 253.54 6,180.64 6,124.44 -3,787.30 -16,257.60 3.00 3.00 0.00 0.00 19,394.22 90.00 253.54 6,180.64 6,124.44 -4,014.01 -17,024.81 0.00 0.00 0.00 0.00 19,437.55 88.70 253.54 6,181.13 6,124.93 -4,026.29 -17,066.36 3.00 -3.00 0.00 180.00 21,337.55 88.70 253.54 6,224.24 6,168.04 -4,564.60 -18,888.00 0.00 0.00 0.00 0.00 21,377.55 87.50 253.54 6,225.56 6,169.36 4,575.93 -18,926.34 3.00 -3.00 0.00 180.00 22,804.00 87.50 253.54 6,287.78 6,231.58 4,979.79 -20,293.00 0.00 0.00 0.00 0.00 3/16/2015 9:59:03AM Page 3 COMPASS 5000.1 Build 58 Halliburton HALLIRLIRTnN Standard Proposal Report Database: EDMPrd Local Co-ordinate Reference: Well ODSN-22i Company: Well Planning-Caelus-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-22i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -13.50 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,023.58 469,793.67 0.00 0.00 100.00 0.00 0.00 100.00 43.80 0.00 0.00 6,031,023.58 469,793.67 0.00 0.00 ., 192.70 0.00 0.00 192.70 136.50 0.00 0.00 6,031,023.58 469,793.67 0.00 0.00 Start Dir 2.51100':192.7'MD,192.7'TVD 200.00 0.18 256.50 200.00 143.80 0.00 -0.01 6,031,023.58 469,793.66 2.50 0.01 292.70 2.50 256.50 292.67 236.47 -0.51 -2.12 6,031,023.08 469,791.54 2.50 2.18 Start Dir 3°l100':292.7'MD,292.67'TVD 300.00 2.72 256.50 299.96 243.76 -0.59 -2.44 6,031,023.01 469,791.22 3.00 2.51 400.00 5.72 256.50 399.68 343.48 -2.30 -9.60 6,031,021.32 469,784.06 3.00 9.87 500.00 8.72 256.50 498.87 442.67 -5.24 -21.81 6,031,018.43 469,771.83 3.00 22.43 509.37 9.00 256.50 508.13 451.93 -5.57 -23.22 6,031,018.10 469,770.43 3.00 23.88 Start Dir 3.5°1100':509.37'MD,508.13'TVD 600.00 12.17 256.50 597.21 541.01 -9.46 -39.41 6,031,014.28 469,754.23 3.50 40.52 700.00 15.67 256.50 694.26 638.06 -15.08 -62.80 6,031,008.76 469,730.82 3.50 64.58 800.00 19.17 256.50 789.65 733.45 -22.06 -91.91 6,031,001.89 469,701.68 3.50 94.52 867.79 21.54 256.50 853.20 797.00 -27.57 -114.84 6,030,996.48 469,678.73 3.50 118.10 Top of Permafrost 900.00 22.67 256.50 883.05 826.85 -30.40 -126.62 6,030,993.70 469,666.93 3.50 130.22 1,000.00 26.17 256.50 974.08 917.88 -40.05 -166.82 6,030,984.21 469,626.70 3.50 171.56 1,100.00 29.67 256.50 1,062.43 1,006.23 -50.98 -212.35 6,030,973.47 469,581.14 3.50 218.38 1,200.00 33.17 256.50 1,147.75 1,091.55 -63.15 -263.03 6,030,961.51 469,530.41 3.50 270.50 1,300.00 36.67 256.50 1,229.73 1,173.53 -76.51 -318.69 6,030,948.37 469,474.70 3.50 327.74 1,400.00 40.17 256.50 1,308.06 1,251.86 -91.02 -379.11 6,030,934.12 469,414.23 3.50 389.88 1,500.00 43.67 256.50 1,382.46 1,326.26 -106.61 -444.06 6,030,918.79 469,349.22 3.50 456.68 1,600.00 47.17 256.50 1,452.63 1,396.43 -123.24 -513.32 6,030,902.44 469,279.91 3.50 527.89 1,700.00 50.67 256.50 1,518.33 1,462.13 -140.83 -586.60 6,030,885.15 469,206.56 3.50 603.26 1,800.00 54.17 256.50 1,579.31 1,523.11 -159.33 -663.65 6,030,866.97 469,129.44 3.50 682.50 1,900.00 57.67 256.50 1,635.33 1,579.13 -178.66 -744.18 6,030,847.96 469,048.84 3.50 765.32 1,963.42 59.89 256.50 1,668.20 1,612.00 -191.32 -796.92 6,030,835.52 468,996.06 3.50 819.55 Base of Permafrost 2,000.00 61.17 256.50 1,686.19 1,629.99 -198.76 -827.88 6,030,828.21 468,965.07 3.50 851.40 2,100.00 64.67 256.50 1,731.71 1,675.51 -219.54 -914.45 6,030,807.78 468,878.43 3.50 940.42 2,110.58 65.04 256.50 1,736.20 1,680.00 -221.77 -923.76 6,030,805.58 468,869.11 3.50 950.00 UGNU 2,200.00 68.17 256.50 1,771.70 1,715.50 -240.93 -1,003.55 6,030,786.75 468,789.24 3.50 1,032.06 2,273.65 70.75 256.50 1,797.54 1,741.34 -257.03 -1,070.61 6,030,770.93 468,722.13 3.50 1,101.02 End Dir :2273.65'MD,1797.54'TVD 2,300.00 70.75 256.50 1,806.22 1,750.02 -262.84 -1,094.80 6,030,765.22 468,697.92 0.00 1,125.89 2,400.00 70.75 256.50 1,839.19 1,782.99 -284.88 -1,186.60 6,030,743.56 468,606.04 0.00 1,220.30 2,500.00 70.75 256.50 1,872.16 1,815.96 -306.92 -1,278.40 6,030,721.89 468,514.16 0.00 1,314.71 2,600.00 70.75 256.50 1,905.13 1,848.93 -328.96 -1,370.20 6,030,700.23 468,422.28 0.00 1,409.12 2,700.00 70.75 256.50 1,938.10 1,881.90 -351.00 -1,462.00 6,030,678.56 468,330.40 0.00 1,503.53 2,800.00 70.75 256.50 1,971.07 1,914.87 -373.03 -1,553.80 6,030,656.90 468,238.52 0.00 1,597.93 2,900.00 70.75 256.50 2,004.04 1,947.84 -395.07 -1,645.60 6,030,635.24 468,146.64 0.00 1,692.34 3,000.00 70.75 256.50 2,037.01 1,980.81 -417.11 -1,737.40 6,030,613.57 468,054.76 0.00 1,786.75 3/16/2015 9:59.03AM Page 4 COMPASS 5000.1 Build 58 Halliburton ,.r s 1' '°' r Standard Proposal Report Database: EDMPrd Local Co-ordinate Reference: Well ODSN-22i Company: Well Planning-Caelus-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-22i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +Nl-S +E/-W Northing Easting DLS Vert Section (usft) (°) (0) (usft) usft (usft) (usft) (usft) (usft) 2,013.78 3,100.00 70.75 256.50 2,069.98 2,013.78 -439.15 -1,829.20 6,030,591.91 467,962.88 0.00 1,881.16 3,200.00 70.75 256.50 2,102.95 2,046.75 -461.19 -1,921.00 6,030,570.24 467,871.00 0.00 1,975.56 3,300.00 70.75 256.50 2,135.91 2,079.71 -483.23 -2,012.80 6,030,548.58 467,779.12 0.00 2,069.97 3,400.00 70.75 256.50 2,168.88 2,112.68 -505.27 -2,104.60 6,030,526.92 467,687.24 0.00 2,164.38 3,500.00 70.75 256.50 2,201.85 2,145.65 -527.31 -2,196.40 6,030,505.25 467,595.36 0.00 2,258.79 3,600.00 70.75 256.50 2,234.82 2,178.62 -549.35 -2,288.20 6,030,483.59 467,503.48 0.00 2,353.19 3,700.00 70.75 256.50 2,267.79 2,211.59 -571.39 -2,380.00 6,030,461.93 467,411.60 0.00 2,447.60 3,731.57 70.75 256.50 2,278.20 2,222.00 -578.35 -2,408.99 6,030,455.09 467,382.59 0.00 2,477.41 WSAK 3,800.00 70.75 256.50 2,300.76 2,244.56 -593.43 -2,471.81 6,030,440.26 467,319.72 0.00 2,542.01 3,873.65 70.75 256.50 2,325.04 2,268.84 -609.66 -2,539.42 6,030,424.31 467,252.05 0.00 2,611.54 Start Dir 3°1100':3873.65'MD,2325.04'TVD 3,900.00 70.75 257.34 2,333.73 2,277.53 -615.29 -2,563.65 6,030,418.77 467,227.80 3.00 2,636.42 3,923.20 70.76 258.07 2,341.38 2,285.18 -619.95 -2,585.05 6,030,414.20 467,206.38 3.00 2,658.31 End Dir :3923.2'MD,2341.38'TVD 4,000.00 70.76 258.07 2,366.69 2,310.49 -634.94 -2,655.99 6,030,399.50 467,135.38 0.00 2,730.78 4,100.00 70.76 258.07 2,399.65 2,343.45 -654.45 -2,748.37 6,030,380.37 467,042.94 0.00 2,825.14 4,200.00 70.76 258.07 2,432.61 2,376.41 -673.96 -2,840.74 6,030,361.24 466,950.49 0.00 2,919.51 4,300.00 70.76 258.07 2,465.57 2,409.37 -693.47 -2,933.11 6,030,342.11 466,858.05 0.00 3,013.87 4,400.00 70.76 258.07 2,498.53 2,442.33 -712.98 -3,025.49 6,030,322.98 466,765.61 0.00 3,108.23 4,500.00 70.76 258.07 2,531.49 2,475.29 -732.49 -3,117.86 6,030,303.84 466,673.16 0.00 3,202.59 4,600.00 70.76 258.07 2,564.45 2,508.25 -751.99 -3,210.24 6,030,284.71 466,580.72 0.00 3,296.96 4,700.00 70.76 258.07 2,597.41 2,541.21 -771.50 -3,302.61 6,030,265.58 466,488.28 0.00 3,391.32 4,800.00 70.76 258.07 2,630.37 2,574.17 -791.01 -3,394.99 6,030,246.45 466,395.83 0.00 3,485.68 4,900.00 70.76 258.07 2,663.33 2,607.13 -810.52 -3,487.36 6,030,227.32 466,303.39 0.00 3,580.04 5,000.00 70.76 258.07 2,696.29 2,640.09 -830.03 -3,579.74 6,030,208.18 466,210.94 0.00 3,674.40 5,100.00 70.76 258.07 2,729.25 2,673.05 -849.54 -3,672.11 6,030,189.05 466,118.50 0.00 3,768.77 5,200.00 70.76 258.07 2,762.21 2,706.01 -869.05 -3,764.48 6,030,169.92 466,026.06 0.00 3,863.13 5,300.00 70.76 258.07 2,795.17 2,738.97 -888.56 -3,856.86 6,030,150.79 465,933.61 0.00 3,957.49 5,400.00 70.76 258.07 2,828.13 2,771.93 -908.07 -3,949.23 6,030,131.65 465,841.17 0.00 4,051.85 5,488.20 70.76 258.07 2,857.20 2,801.00 -925.28 -4,030.71 6,030,114.78 465,759.63 0.00 4,135.08 CRET TUFF 5,500.00 70.76 258.07 2,861.09 2,804.89 -927.58 -4,041.61 6,030,112.52 465,748.73 0.00 4,146.22 5,600.00 70.76 258.07 2,894.05 2,837.85 -947.09 -4,133.98 6,030,093.39 465,656.28 0.00 4,240.58 5,700.00 70.76 258.07 2,927.01 2,870.81 -966.60 -4,226.36 6,030,074.26 465,563.84 0.00 4,334.94 5,800.00 70.76 258.07 2,959.97 2,903.77 -986.11 -4,318.73 6,030,055.13 465,471.39 0.00 4,429.30 , 5,900.00 70.76 258.07 2,992.93 2,936.73 -1,005.62 -4,411.10 6,030,035.99 465,378.95 0.00 4,523.66 6,000.00 70.76 258.07 3,025.89 2,969.69 -1,025.13 -4,503.48 6,030,016.86 465,286.51 0.00 4,618.03 6,100.00 70.76 258.07 3,058.85 3,002.65 -1,044.64 -4,595.85 6,029,997.73 465,194.06 0.00 4,712.39 6,200.00 70.76 258.07 3,091.81 3,035.61 -1,064.15 -4,688.23 6,029,978.60 465,101.62 0.00 4,806.75 6,300.00 70.76 258.07 3,124.77 3,068.57 -1,083.66 -4,780.60 6,029,959.47 465,009.18 0.00 4,901.11 6,400.00 70.76 258.07 3,157.73 3,101.53 -1,103.17 -4,872.98 6,029,940.33 464,916.73 0.00 4,995.48 6,500.00 70.76 258.07 3,190.69 3,134.49 -1,122.68 -4,965.35 6,029,921.20 464,824.29 0.00 5,089.84 6,547.06 70.76 258.07 3,206.20 3,150.00 -1,131.86 -5,008.83 6,029,912.20 464,780.78 0.00 5,134.25 HUE2 3/16/2015 9:59:03AM Page 5 COMPASS 5000.1 Build 58 Halliburton i r Standard Proposal Report Database: EDMPrd Local Co-ordinate Reference: Well ODSN-22i Company: Well Planning-Caelus-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-22i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,167.45 6,600.00 70.76 258.07 3,223.65 3,167.45 -1,142.19 -5,057.72 6,029,902.07 464,731.84 0.00 5,184.20 6,638.08 70.76 258.07 3,236.20 3,180.00 -1,149.62 -5,092.91 6,029,894.78 464,696.64 0.00 5,220.14 11 314" 6,700.00 70.76 258,07 3,256.61 3,200.41 -1,161.70 -5,150.10 6,029,882.94 464,639.40 0.00 5,278.56 6,800.00 70.76 258.07 3,289.57 3,233.37 -1,181.21 -5,242.47 6,029,863.80 464,546.96 0.00 5,372.92 6,900.00 70.76 258.07 3,322.53 3,266.33 -1,200.71 -5,334.85 6,029,844.67 464,454.51 0.00 5,467.29 7,000.00 70.76 258.07 3,355.49 3,299.29 -1,220.22 -5,427.22 6,029,825.54 464,362.07 0.00 5,561.65 7,100.00 70.76 258.07 3,388.45 3,332.25 -1,239.73 -5,519.60 6,029,806.41 464,269.63 0.00 5,656.01 7,178.13 70.76 258.07 3,414.20 3,358.00 -1,254.98 -5,591.77 6,029,791.46 464,197.40 0.00 5,729.74 Hue Res C tied 7,200.00 70.76 258.07 3,421.41 3,365.21 -1,259.24 -5,611.97 6,029,787.28 464,177.18 0.00 5,750.37 7,300.00 70.76 258.07 3,454.37 3,398.17 -1,278.75 -5,704.35 6,029,768.14 464,084.74 0.00 5,844.74 7,400.00 70.76 258.07 3,487.33 3,431.13 -1,298.26 -5,796.72 6,029,749.01 463,992.29 0.00 5,939.10 7,500.00 70.76 258.07 3,520.29 3,464.09 -1,317.77 -5,889.09 6,029,729.88 463,899.85 0.00 6,033.46 7,600.00 70.76 258.07 3,553.25 3,497.05 -1,337.28 -5,981.47 6,029,710.75 463,807.41 0.00 6,127.82 7,700.00 70.76 258.07 3,586.21 3,530.01 -1,356.79 -6,073.84 6,029,691.62 463,714.96 0.00 6,222.19 7,800.00 70.76 258.07 3,619.17 3,562.97 -1,376.30 -6,166.22 6,029,672.48 463,622.52 0.00 6,316.55 7,900.00 70.76 258.07 3,652.13 3,595.93 -1,395.81 -6,258.59 6,029,653.35 463,530.08 0.00 6,410.91 8,000.00 70.76 258.07 3,685.09 3,628.89 -1,415.32 -6,350.97 6,029,634.22 463,437.63 0.00 6,505.27 8,100.00 70.76 258.07 3,718.05 3,661.85 -1,434.83 -6,443.34 6,029,615.09 463,345.19 0.00 6,599.63 8,200.00 70.76 258.07 3,751.01 3,694.81 -1,454.34 -6,535.71 6,029,595.95 463,252.74 0.00 6,694.00 8,300.00 70.76 258.07 3,783.97 3,727.77 -1,473.85 -6,628.09 6,029,576.82 463,160.30 0.00 6,788.36 8,400.00 70.76 258.07 3,816.93 3,760.73 -1,493.36 -6,720.46 6,029,557.69 463,067.86 0.00 6,882.72 8,500.00 70.76 258.07 3,849.89 3,793.69 -1,512.87 -6,812.84 6,029,538.56 462,975.41 0.00 6,977.08 8,573.77 70.76 258.07 3,874.20 3,818.00 -1,527.26 -6,880.98 6,029,524.44 462,907.22 0.00 7.046.69 Hue Res B tied 8,600.00 70.76 258.07 3,882.85 3,826.65 -1,532.38 -6,905.21 6,029,519.43 462,882.97 0.00 7,071.45 8,700.00 70.76 258.07 3,915.81 3,859.61 -1,551.89 -6,997.59 6,029,500.29 462,790.53 0.00 7,165.81 8,800.00 70.76 258.07 3,948.77 3,892.57 -1,571.40 -7,089.96 6,029,481.16 462,698.08 0.00 7,260.17 8,900.00 70.76 258.07 3,981.73 3,925.53 -1,590.91 -7,182.33 6,029,462.03 462,605.64 0.00 7,354.53 9,000.00 70.76 258.07 4,014.69 3,958.49 -1,610.42 -7,274.71 6,029,442.90 462,513.20 0.00 7,448.89 9,100.00 70.76 258.07 4,047.65 3,991.45 -1,629.92 -7,367.08 6,029,423.77 462,420.75 0.00 7,543.26 9,200.00 70.76 258.07 4,080.60 4,024.41 -1,649.43 -7,459.46 6,029,404.63 462,328.31 0.00 7,637.62 9,300.00 70.76 258.07 4,113.56 4,057.37 -1,668.94 -7,551.83 6,029,385.50 462,235.86 0.00 7,731.98 9,400.00 70.76 258.07 4,146.52 4,090.32 -1,688.45 -7,644.21 6,029,366.37 462,143.42 0.00 7,826.34 9,405.08 70.76 258.07 4,148.20 4,092.00 -1,689.45 -7,648.90 6,029,365.40 462,138.72 0.00 7,831.14 Hue Res A tied 9,471.83 70.76 258.07 4,170.20 4,114.00 -1,702.47 -7,710.56 6,029,352.63 462,077.02 0.00 7,894.12 BROOK 2B 9,500.00 70.76 258.07 4,179.48 4,123.28 -1,707.96 -7,736.58 6,029,347.24 462,050.98 0.00 7,920.71 9,600.00 70.76 258.07 4,212.44 4,156.24 -1,727.47 -7,828.96 6,029,328.11 461,958.53 0.00 8,015.07 9,700.00 70.76 258.07 4,245.40 4,189.20 -1,746.98 -7,921.33 6,029,308.97 461,866.09 0.00 8,109.43 9,800.00 70.76 258.07 4,278.36 4,222.16 -1,766.49 -8,013.70 6,029,289.84 461,773.65 0.00 8,203.79 9,900.00 70.76 258.07 4,311.32 4,255.12 -1,786.00 -8,106.08 6,029,270.71 461,681.20 0.00 8,298.15 10,000.00 70.76 258.07 4,344.28 4,288.08 -1,805.51 -8,198.45 6,029,251.58 461,588.76 0.00 8,392.52 3/16/2015 9:59:03AM Page 6 COMPASS 5000.1 Build 58 Halliburton Standard Proposal Report Database: EDMPrd Local Co-ordinate Reference: Well ODSN-22i Company: Well Planning-Caelus-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-22i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 4,321.04 10,100.00 70.76 258.07 4,377.24 4,321.04 -1,825.02 -8,290.83 6,029,232.44 461,496.31 0.00 8,486.88 10,200.00 70.76 258.07 4,410.20 4,354.00 -1,844.53 -8,383.20 6,029,213.31 461,403.87 0.00 8,581.24 10,300.00 70.76 258.07 4,443.16 4,386.96 -1,864.04 -8,475.58 6,029,194.18 461,311.43 0.00 8,675.60 10,400.00 70.76 258.07 4,476.12 4,419.92 -1,883.55 -8,567.95 6,029,175.05 461,218.98 0.00 8,769.97 10,500.00 70.76 258.07 4,509.08 4,452.88 -1,903.06 -8,660.32 6,029,155.92 461,126.54 0.00 8,864.33 10,600.00 70.76 258.07 4,542.04 4,485.84 -1,922.57 -8,752.70 6,029,136.78 461,034.10 0.00 8,958.69 10,700.00 70.76 258.07 4,575.00 4,518.80 -1,942.08 -8,845.07 6,029,117.65 460,941.65 0.00 9,053.05 10,800.00 70.76 258.07 4,607.96 4,551.76 -1,961.59 -8,937.45 6,029,098.52 460,849.21 0.00 9,147.41 10,900.00 70.76 258.07 4,640.92 4,584.72 -1,981.10 -9,029.82 6,029,079.39 460,756.76 0.00 9,241.78 11,000.00 70.76 258.07 4,673.88 4,617.68 -2,000.61 -9,122.20 6,029,060.26 460,664.32 0.00 9,336.14 11,100.00 70.76 258.07 4,706.84 4,650.64 -2,020.12 -9,214.57 6,029,041.12 460,571.88 0.00 9,430.50 11,200.00 70.76 258.07 4,739.80 4,683.60 -2,039.63 -9,306.95 6,029,021.99 460,479.43 0.00 9,524.86 11,300.00 70.76 258.07 4,772.76 4,716.56 -2,059.14 -9,399.32 6,029,002.86 460,386.99 0.00 9,619.23 11,400.00 70.76 258.07 4,805.72 4,749.52 -2,078.64 -9,491.69 6,028,983.73 460,294.55 0.00 9,713.59 11,500.00 70.76 258.07 4,838.68 4,782.48 -2,098.15 -9,584.07 6,028,964.59 460,202.10 0.00 9,807.95 11,600.00 70.76 258.07 4,871.64 4,815.44 -2,117.66 -9,676.44 6,028,945.46 460,109.66 0.00 9,902.31 11,700.00 70.76 258.07 4,904.60 4,848.40 -2,137.17 -9,768.82 6,028,926.33 460,017.21 0.00 9,996.68 11,800.00 70.76 258.07 4,937.56 4,881.36 -2,156.68 -9,861.19 6,028,907.20 459,924.77 0.00 10,091.04 11,850.48 70.76 258.07 4,954.20 4,898.00 -2,166.53 -9,907.82 6,028,897.54 459,878.11 0.00 10,138.67 9 5/8" 11,895.99 70.76 258.07 4,969.20 4,913.00 -2,175.41 -9,949.86 6,028,888.83 459,836.04 0.00 10,181.61 TOROK_TOP 11,900.00 70.76 258,07 4,970.52 4,914.32 -2,176.19 -9,953.57 6,028,888.07 459,832.33 0.00 10,185.40 12,000.00 70.76 258.07 5,003.48 4,947.28 -2,195.70 -10,045.94 6,028,868.93 459,739.88 0.00 10,279.76 12,100.00 70.76 258.07 5,036.44 4,980.24 -2,215.21 -10,138.31 6,028,849.80 459,647.44 0.00 10,374.12 12,200.00 70.76 258.07 5,069.40 5,013.20 -2,234.72 -10,230.69 6,028,830.67 459,555.00 0.00 10,468.49 12,300.00 70.76 258.07 5,102.36 5,046.16 -2,254.23 -10,323.06 6,028,811.54 459,462.55 0.00 10,562.85 12,400.00 70.76 258.07 5,135.32 5,079.12 -2,273.74 -10,415.44 6,028,792.41 459,370.11 0.00 10,657.21 12,451.21 70.76 258.07 5,152.20 5,096.00 -2,283.73 -10,462.74 6,028,782.61 459,322.77 0.00 10,705.53 TOROK_BASE 12,500.00 70.76 258.07 5,168.28 5,112.08 -2,293.25 -10,507.81 6,028,773.27 459,277.66 0.00 10,751.57 12,600.00 70.76 258.07 5,201.24 5,145.04 -2,312.76 -10,600.19 6,028,754.14 459,185.22 0.00 10,845.94 Yellow fault 12,700.00 70.76 258.07 5,234.20 5,178.00 -2,332.27 -10,692.56 6,028,735.01 459,092.78 0.00 10,940.30 12,800.00 70.76 258,07 5,267.16 5,210.96 -2,351.78 -10,784.93 6,028,715.88 459,000.33 0.00 11,034.66 12,900.00 70.76 258.07 5,300.12 5,243.92 -2,371.29 -10,877.31 6,028,696.74 458,907.89 0.00 11,129.02 12,988.22 70.76 258.07 5,329.20 5,273.00 -2,388.50 -10,958.80 6,028,679.87 458,826.33 0.00 11,212.27 TOROK SH1 MKR 13,000.00 70.76 258.07 5,333.08 5,276.88 -2,390.80 -10,969.68 6,028,677.61 458,815.45 0.00 11,223.38 13,100.00 70.76 258.07 5,366.04 5,309.84 -2,410.31 -11,062.06 6,028,658.48 458,723.00 0.00 11,317.75 13,200.00 70.76 258.07 5,399.00 5,342.80 -2,429.82 -11,154.43 6,028,639.35 458,630.56 0.00 11,412.11 13,300.00 70.76 258.07 5,431.96 5,375.76 -2,449.33 -11,246.81 6,028,620.22 458,538.12 0.00 11,506.47 13,400.00 70.76 258.07 5,464.92 5,408.72 -2,468.84 -11,339.18 6,028,601.08 458,445.67 0.00 11,600.83 13,500.00 70.76 258.07 5,497.88 5,441.68 -2,488.35 -11,431.56 6,028,581.95 458,353.23 0.00 11,695.20 13,600.00 70.76 258.07 5,530.84 5,474.64 -2,507.85 -11,523.93 6,028,562.82 458,260.78 0.00 11,789.56 3/16/2015 9:59:03AM Page 7 COMPASS 5000.1 Build 58 Halliburton _-,r ' 1 s a tx c- <,a � , t'- e.,-,i,. ' Standard Proposal Report Database: EDMPrd Local Co-ordinate Reference: Well ODSN-22i Company: Well Planning-Caelus-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-22i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +El-W Northing Easting DLS Vert Section (usft) (°) (') (usft) usft (usft) (usft) (usft) (usft) 5,507.60 13,700.00 70.76 258.07 5,563.80 5,507.60 -2,527.36 -11,616.30 6,028,543.69 458,168.34 0.00 11,883.92 13,800.00 70.76 258.07 5,596.76 5,540.56 -2,546.87 -11,708.68 6,028,524.56 458,075.90 0.00 11,978.28 13,900.00 70.76 258.07 5,629.72 5,573.52 -2,566.38 -11,801.05 6,028,505.42 457,983.45 0.00 12,072.64 14,000.00 70.76 258.07 5,662.68 5,606.48 -2,585.89 -11,893.43 6,028,486.29 457,891.01 0.00 12,167.01 14,100.00 70.76 258.07 5,695.64 5,639.44 -2,605.40 -11,985.80 6,028,467,16 457,798.57 0.00 12,261.37 14,200.00 70.76 258.07 5,728.60 5,672.40 -2,624.91 -12,078.18 6,028,448.03 457,706.12 0.00 12,355.73 14,300.00 70.76 258.07 5,761.56 5,705.36 -2,644.42 -12,170.55 6,028,428.89 457,613.68 0.00 12,450.09 14,400.00 70.76 258.07 5,794.52 5,738.32 -2,663.93 -12,262.92 6,028,409.76 457,521.23 0.00 12,544.46 14,408.13 70.76 258.07 5,797.20 5,741.00 -2,665.52 -12,270.43 6,028,408.21 457,513.72 0.00 12,552.13 115_TOP_HRZ 14,500.00 70.76 258.07 5,827.48 5,771.28 -2,683.44 -12,355.30 6,028,390.63 457,428.79 0.00 12,638.82 14,600.00 70.76 258.07 5,860.44 5,804.24 -2,702.95 -12,447.67 6,028,371.50 457,336.35 0.00 12,733.18 14,700.00 70.76 258.07 5,893.40 5,837.20 -2,722.46 -12,540.05 6,028,352.37 457,243.90 0.00 12,827.54 14,775.24 70.76 258.07 5,918.20 5,862.00 -2,737.14 -12,609.55 6,028,337.97 457,174.35 0.00 12,898.54 129_BASE_HRZ 14,800.00 70.76 258.07 5,926.36 5,870.16 -2,741.97 -12,632.42 6,028,333.23 457,151.46 0.00 12,921.90 14,880.47 70.76 258.07 5,952.88 5,896.68 -2,757.67 -12,706.76 6,028,317.84 457,077.07 0.00 12,997.84 Start Dir 3°!100':14880.47'MD,5952.881VD 14,900.00 71.31 257.89 5,959.23 5,903.03 -2,761.52 -12,724.82 6,028,314.07 457,058.99 3.00 13,016.30 15,000.00 74.17 256.94 5,988.89 5,932.69 -2,782.33 -12,818.01 6,028,293.63 456,965.73 3.00 13,111.77 Dark Brown Fault 15,012.26 74.52 256.82 5,992.20 5,936.00 -2,785,01 -12,829.51 6,028,291.00 456,954.22 3.00 13,123.57 130_KALUBIK MKR 15,100.00 77.04 256.01 6,013.75 5,957.55 -2,804.99 -12,912.17 6,028,271.36 456,871.48 3.00 13,208.61 15,139.35 78.16 255.66 6,022.20 5,966.00 -2,814.39 -12,949.43 6,028,262.11 456,834.19 3.00 13,247.04 KUP C-134_LCU 15,200.00 79.90 255.11 6,033.74 5,977.54 -2,829.42 -13,007.05 6,028,247.32 456,776.52 3.00 13,306.58 15,300.00 82.77 254.23 6,048.79 5,992.59 -2,855.56 -13,102.38 6,028,221.57 456,681.09 3.00 13,405.39 15,377.55 85.00 253.55 6,057.05 6,000.85 -2,876.96 -13,176.45 6,028,200.47 456,606.94 3.00 13,482.43 End Dir :15377.55'MD,6057.05'TVD 15,400.00 85.00 253.55 6,059.01 6,002.81 -2,883.29 -13,197.90 6,028,194.23 456,585.47 0.00 13,504.77 15,500.00 85.00 253.55 6,067.73 6,011.53 -2,911.51 -13,293.44 6,028,166.40 456,489.82 0.00 13,604.28 15,585.76 85.00 253.55 6,075.20 6,019.00 -2,935.70 -13,375.38 6,028,142.54 456,407.79 0.00 13,689.63 145_BCU 15,600.00 85.00 253.55 6,076.44 6,020.24 -2,939.72 -13,388.98 6,028,138.58 456,394.18 0.00 13,703.79 15,677.55 85.00 253.55 6,083.20 6,027.00 -2,961.60 -13,463.08 6,028,117.00 456,320.00 0.00 13,780.97 15,700.00 85.00 253.55 6,085.16 6,028.96 -2,967.94 -13,484.52 6,028,110.75 456,298.53 0.00 13,803.31 15,711.97 85.00 253.55 6,086.20 6,030.00 -2,971.31 -13,495.96 6,028,107.42 456,287.08 0.00 13,815.22 NUIQSUT 15,757.87 85.00 253.55 6,090.20 6,034.00 -2,984.26 -13,539.81 6,028,094.65 456,243.18 0.00 13,860.89 NUIQ_1 15,800.00 85.00 253.55 6,093.87 6,037.67 -2,996.15 -13,580.06 6,028,082.93 456,202.89 0.00 13,902.82 15,803.77 85.00 253.55 6,094.20 6,038.00 -2,997.21 -13,583.66 6,028,081.88 456,199.28 0.00 13,906.57 7" 3/16/2015 9:59:03AM Page 8 COMPASS 5000.1 Build 58 Halliburton HALLIBURTON Standard Proposal Report Database: EDMPrd Local Co-ordinate Reference: Well ODSN-22i Company: Well Planning-Caelus-000guruk TVD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) Project: 000guruk Development MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-22i Survey Calculation Method: Minimum Curvature s Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,038.02 15,804.00 85.00 253.55 6,094.22 6,038.02 -2,997.28 -13,583.88 6,028,081.82 456,199.06 0.00 13,906.80 , Begin Geo-steering as per Geologist 15,900.00 85.00 253.55 6,102.59 6,046.39 -3,024.37 -13,675.60 6,028,055.11 456,107.24 0.00 14,002.33 16,000.00 85.00 253.55 6,111.30 6,055.10 -3,052.58 -13,771.14 6,028,027.28 456,011.60 0.00 14,101.84 16,100.00 85.00 253.55 6,120.02 6,063.82 -3,080.79 -13,866.68 6,027,999.46 455,915.95 0.00 14,201.35 16,200.00 85.00 253.55 6,128.73 6,072.53 -3,109.01 -13,962.22 6,027,971.64 455,820.31 0.00 14,300.86 16,227.55 85.00 253.55 6,131.14 6,074.94 -3,116.78 -13,988.55 6,027,963.97 455,793.95 0.00 14,328.28 16,300.00 87.17 253.54 6,136.08 6,079.88 -3,137.26 -14,057.86 6,027,943.78 455,724.57 3.00 14,400.48 16,357.55 88.90 253.54 6,138.05 6,081.85 -3,153.55 -14,113.02 6,027,927.71 455,669.34 3.00 14,457.93 16,400.00 88.90 253.54 6,138.87 6,082.67 -3,165.58 -14,153.72 6,027,915.85 455,628.60 0.00 14,500.33 16,500.00 88.90 253.54 6,140.79 6,084.59 -3,193.92 -14,249.60 6,027,887.91 455,532.61 0.00 14,600.20 16,600.00 88.90 253.54 6,142.71 6,086.51 -3,222.25 -14,345.49 6,027,859.97 455,436.63 0.00 14,700.07 16,700.00 88.90 253.54 6,144.63 6,088.43 -3,250.58 -14,441.37 6,027,832.02 455,340.64 0.00 14,799.94 16,800.00 88.90 253.54 6,146.55 6,090.35 -3,278.92 -14,537.25 6,027,804.08 455,244.65 0.00 14,899.82 16,900.00 88.90 253.54 6,148.46 6,092.26 -3,307.25 -14,633.14 6,027,776.14 455,148.66 0.00 14,999.69 17,000.00 88.90 253.54 6,150.38 6,094.18 -3,335.59 -14,729.02 6,027,748.20 455,052.68 0.00 15,099.56 17,100.00 88.90 253.54 6,152.30 6,096.10 -3,363.92 -14,824.90 6,027,720.26 454,956.69 0.00 15,199.43 17,200.00 88.90 253.54 6,154.22 6,098.02 -3,392.25 -14,920.78 6,027,692.32 454,860.70 0.00 15,299.31 17,300.00 88.90 253.54 6,156.14 6,099.94 -3,420.59 -15,016.67 6,027,664.38 454,764.71 0.00 15,399.18 17,400.00 88.90 253.54 6,158.06 6,101.86 -3,448.92 -15,112.55 6,027,636.43 454,668.73 0.00 15,499.05 17,500.00 88.90 253.54 6,159.98 6,103.78 -3,477.26 -15,208.43 6,027,608.49 454,572.74 0.00 15,598.92 17,600.00 88.90 253.54 6,161.90 6,105.70 -3,505.59 -15,304.31 6,027,580.55 454,476.75 0.00 15,698.80 17,700.00 88.90 253.54 6,163.82 6,107.62 -3,533.92 -15,400.20 6,027,552.61 454,380.76 0.00 15,798.67 17,800.00 88.90 253.54 6,165.74 6,109.54 -3,562.26 -15,496.08 6,027,524.67 454,284.78 0.00 15,898.54 17,900.00 88.90 253.54 6,167.66 6,111.46 -3,590.59 -15,591.96 6,027,496.73 454,188.79 0.00 15,998.42 18,000.00 88.90 253.54 6,169.58 6,113.38 -3,618.93 -15,687.84 6,027,468.79 454,092.80 0.00 16,098.29 18,100.00 88.90 253.54 6,171.50 6,115.30 -3,647.26 -15,783.73 6,027,440.84 453,996.81 0.00 16,198.16 18,200.00 88.90 253.54 6,173.42 6,117.22 -3,675.60 -15,879.61 6,027,412.90 453,900.83 0.00 16,298.03 18,300.00 88.90 253.54 6,175.34 6,119.14 -3,703.93 -15,975.49 6,027,384.96 453,804.84 0.00 16,397.91 18,400.00 88.90 253.54 6,177.26 6,121.06 -3,732.26 -16,071.38 6,027,357.02 453,708.85 0.00 16,497.78 18,500.00 88.90 253.54 6,179.18 6,122.98 -3,760.60 -16,167.26 6,027,329.08 453,612.86 0.00 16,597.65 18,557.55 88.90 253.54 6,180.29 6,124.09 -3,776.91 -16,222.44 6,027,313.00 453,557.62 0.00 16,655.13 18,594.22 90.00 253.54 6,180.64 6,124.44 -3,787.30 -16,257.60 6,027,302.75 453,522.42 3.00 16,691.76 18,600.00 90.00 253.54 6,180.64 6,124.44 -3,788.93 -16,263.15 6,027,301.13 453,516.87 0.00 16,697.53 18,700.00 90.00 253.54 6,180.64 6,124.44 -3,817.27 -16,359.05 6,027,273.19 453,420.86 0.00 16,797.42 18,800.00 90.00 253.54 6,180.64 6,124.44 -3,845.61 -16,454.95 6,027,245.24 453,324.86 0.00 16,897.31 18,900.00 90.00 253.54 6,180.64 6,124.44 -3,873.95 -16,550.85 6,027,217.30 453,228.85 0.00 16,997.20 19,000.00 90.00 253.54 6,180.64 6,124.44 -3,902.29 -16,646.75 6,027,189.35 453,132.85 0.00 17,097.09 19,100.00 90.00 253.54 6,180.64 6,124.44 -3,930.63 -16,742.65 6,027,161.40 453,036.84 0.00 17,196.98 19,200.00 90.00 253.54 6,180.64 6,124.44 -3,958.97 -16,838.55 6,027,133.46 452,940.84 0.00 17,296.88 19,300.00 90.00 253.54 6,180.64 6,124.44 -3,987.31 -16,934.45 6,027,105.51 452,844.83 0.00 17,396.77 19,394.22 90.00 253.54 6,180.64 6,124.44 -4,014.01 -17,024.81 6,027,079.18 452,754.38 0.00 17,490.88 19,400.00 89.83 253.54 6,180.65 6,124.45 -4,015.65 -17,030.35 6,027,077.56 452,748.83 3.00 17,496.66 19,437.55 88.70 253.54 6,181.13 6,124.93 -4,026.29 -17,066.36 6,027,067.07 452,712.78 3.00 17,534.17 19,500.00 88.70 253.54 6,182.55 6,126.35 -4,043.98 -17,126.23 6,027,049.62 452,652.84 0.00 17,596.53 3/16/2015 9:59:03AM Page 9 COMPASS 5000.1 Build 58 Halliburton HALLIBLJRTON Standard Proposal Report .u.,. . ,.., _,.r: „.�_ ,n_,.. „ „„_, ,,.� -.. .., Database: N EDMPrd Local Co-ordinate Reference: Well ODSN-22i .4 Company: Well Planning-Caelus-Oooguruk ND Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) s Site: Oooguruk Drill Site North Reference: True Well: ODSN-22i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (1 (°) (usft) usft (usft) (usft) (usft) (usft) 6,128.61 19,600.00 88.70 253.54 6,184.81 6,128.61 -4,072.31 -17,222.11 6,027,021.68 452,556.86 0.00 17,696.39 19,700.00 88.70 253.54 6,187.08 6,130.88 -4,100.65 -17,317.98 6,026,993.74 452,460.88 0.00 17,796.26 19,800.00 88.70 253.54 6,189.35 6,133.15 -4,128.98 -17,413.86 6,026,965.80 452,364.90 0.00 17,896.12 19,900.00 88.70 253.54 6,191.62 6,135.42 -4,157.31 -17,509.73 6,026,937.86 452,268.92 0.00 17,995.99 20,000.00 88.70 253.54 6,193.89 6,137.69 -4,185.64 -17,605.61 6,026,909.92 452,172.94 0.00 18,095.86 20,100.00 88.70 253.54 6,196.16 6,139.96 -4,213.97 -17,701.49 6,026,881.98 452,076.96 0.00 18,195.72 20,200.00 88.70 253.54 6,198.43 6,142.23 -4,242.31 -17,797.36 6,026,854.04 451,980.98 0.00 18,295.59 20,300.00 88.70 253.54 6,200.70 6,144.50 -4,270.64 -17,893.24 6,026,826.11 451,885.00 0.00 18,395.45 20,400.00 88.70 253.54 6,202.96 6,146.76 -4,298.97 -17,989.11 6,026,798.17 451,789.02 0.00 18,495.32 20,500.00 88.70 253.54 6,205.23 6,149.03 -4,327.30 -18,084.99 6,026,770.23 451,693.04 0.00 18,595.18 20,600.00 88.70 253.54 6,207.50 6,151.30 -4,355.63 -18,180.86 6,026,742.29 451,597.06 0.00 18,695.05 20,700.00 88.70 253.54 6,209.77 6,153.57 -4,383.97 -18,276.74 6,026,714.35 451,501.08 0.00 18,794.91 20,800.00 88.70 253.54 6,212.04 6,155.84 -4,412.30 -18,372.61 6,026,686.41 451,405.09 0.00 18,894.78 20,900.00 88.70 253.54 6,214.31 6,158.11 -4,440.63 -18,468.49 6,026,658.47 451,309.11 0.00 18,994.64 21,000.00 88.70 253.54 6,216.58 6,160.38 -4,468.96 -18,564.37 6,026,630.53 451,213.13 0.00 19,094.51 21,100.00 88.70 253.54 6,218.85 6,162.65 -4,497.29 -18,660.24 6,026,602.59 451,117.15 0.00 19,194.37 21,200.00 88.70 253.54 6,221.11 6,164.91 -4,525.63 -18,756.12 6,026,574.65 451,021.17 0.00 19,294.24 21,300.00 88.70 253.54 6,223.38 6,167.18 -4,553.96 -18,851.99 6,026,546.71 450,925.19 0.00 19,394.10 21,337.55 88.70 253.54 6,224.24 6,168.04 -4,564.60 -18,888.00 6,026,536.22 450,889.15 0.00 19,431.61 21,377.55 87.50 253.54 6,225.56 6,169.36 -4,575.93 -18,926.34 6,026,525.05 450,850.77 3.00 19,471.54 21,400.00 87.50 253.54 6,226.54 6,170.34 -4,582.28 -18,947.84 6,026,518.78 450,829.24 0.00 19,493.94 21,500.00 87.50 253.54 6,230.90 6,174.70 -4,610.59 -19,043.65 6,026,490.86 450,733.32 0.00 19,593.74 21,600.00 87.50 253.54 6,235.26 6,179.06 -4,638.91 -19,139.46 6,026,462.94 450,637.41 0.00 19,693.53 21,700.00 87.50 253.54 6,239.63 6,183.43 -4,667.22 -19,235.27 6,026,435.02 450,541.50 0.00 19,793.33 21,800.00 87.50 253.54 6,243.99 6,187.79 -4,695.53 -19,331.08 6,026,407.10 450,445.58 0.00 19,893.13 21,900.00 87.50 253.54 6,248.35 6,192.15 -4,723.84 -19,426.89 6,026,379.18 450,349.67 0.00 19,992.92 22,000.00 87.50 253.54 6,252.71 6,196.51 -4,752.16 -19,522.70 6,026,351.26 450,253.76 0.00 20,092.72 22,100.00 87.50 253.54 6,257.07 6,200.87 -4,780.47 -19,618.51 6,026,323.34 450,157.84 0.00 20,192.51 22,200.00 87.50 253.54 6,261.44 6,205.24 -4,808.78 -19,714.32 6,026,295.42 450,061.93 0.00 20,292.31 22,300.00 87.50 253.54 6,265.80 6,209.60 -4,837.09 -19,810.12 6,026,267.50 449,966.01 0.00 20,392.10 22,400.00 87.50 253.54 6,270.16 6,213.96 -4,865.41 -19,905.93 6,026,239.58 449,870.10 0.00 20,491.90 22,500.00 87.50 253.54 6,274.52 6,218.32 -4,893.72 -20,001.74 6,026,211.66 449,774.19 0.00 20,591.70 22,600.00 87.50 253.54 6,278.88 6,222.68 -4,922.03 -20,097.55 6,026,183.74 449,678.27 0.00 20,691.49 22,700.00 87.50 253.54 6,283.25 6,227.05 -4,950.34 -20,193.36 6,026,155.82 449,582.36 0.00 20,791.29 22,800.00 87.50 253.54 6,287.61 6,231.41 -4,978.65 -20,289.17 6,026,127.90 449,486.44 0.00 20,891.08 22,804.00 87.50 253.54 6,287.78 6,231.58 -4,979.79 -20,293.00 6,026,126.78 449,482.61 0.00 20,895.08 Total Depth:22804'MD,6287.78'ND,4 112" 3/16/2015 9:59:03AM Page 10 COMPASS 5000.1 Build 58 Halliburton Standard Proposal Report _ ,.. .. , .. ,� " 4,;.. 20 . Database: EDMPrd Local Co-ordinate Reference: Well ODSN-22i Company: Well Planning-Caelus-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-22i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 Targets ,,a 1*P '" wog w >' #1040,*Y,A^..sa* 4W4 ;b'k ;, t'”, 's Target Name ` -hit/miss target Dip Angle Dip Dir. '. TVD +NI-S +EI-W Northing Easting -Shape (") (1 `,., (usft) (usft) (usft) (usft) (usft) ISW2 v6 heel 0.00 0.00 6,083.20 -2,961.60 -13,463.08 6,028,117.00 456,320.00 -plan hits target center -Point Geo-Poly 0.00 0.00 6,094.22 -2,997.28 -13,583.89 6,028,081.82 456,199.06 -plan hits target center -Polygon Point 1 6,094.22 -265.76 79.64 6,027,815.77 456,277.61 Point 2 6,094.22 -293.36 -11.92 6,027,788.54 456,185.95 Point 3 6,094.22 -522.94 -776.63 6,027,562.09 455,420.39 Point 4 6,094.22 -812.11 -1,733.70 6,027,276.84 454,462.25 Point 5 6,094.22 -1,072.09 -2,589.13 6,027,020.37 453,605.85 Point 6 6,094.22 -1,307.40 -3,359.79 6,026,788.21 452,834.32 Point 7 6,094.22 -1,571.07 -4,220.08 6,026,528.07 451,973.05 Point 8 6,094.22 -1,865.20 -5,175.59 6,026,237.85 451,016.45 Point 9 6,094.22 -2,101.01 -5,939.32 6,026,005.17 450,251.84 Point 10 6,094.22 -2,337.41 -6,702.82 6,025,771.90 449,487.46 Point 11 6,094.22 -2,338.60 -6,706.63 6,025,770.72 449,483.65 Point 12 6,094.22 -1,682.99 -6,903.23 6,026,427.06 449,289.73 Point 13 6,094.22 -1,681.91 -6,899.39 6,026,428.12 449,293.58 Point 14 6,094.22 -1,465.31 -6,129.95 6,026,641.58 450,063.81 Point 15 6,094.22 -1,248.11 -5,360.65 6,026,855.63 450,833.91 Point 16 6,094.22 -975.61 -4,398.64 6,027,124.19 451,796.93 Point 17 6,094.22 -729.29 -3,533.15 6,027,366.97 452,663.33 Point 18 6,094.22 -507.89 -2,758.32 6,027,585.19 453,438.97 Point 19 6,094.22 -261.13 -1,898.93 6,027,828.43 454,299.27 Point 20 6,094.22 16.37 -938.36 6,028,102.00 455,260.87 Point 21 6,094.22 239.21 -171.52 6,028,321.70 456,028.53 Point 22 6,094.22 265.76 -79.64 6,028,347.88 456,120.51 Casing Points "` Measured Vertical R $" Casing Hole Depth Depth a ,#- : ; Diameter Diameter 1 q (usft) (usft) zI Name (') ("I usft usft 15,803.77 6,094.20 7" 7 9-1/2 11,850.48 4,954.20 9 5/8" 9-5/8 11-3/4 6,638.08 3,236.20 11 3/4" 11-3/4 14-1/2 22,804.00 6,287.78 4 1/2" 4-1/2 6-1/8 3/16/2015 9:59:03AM Page 11 COMPASS 5000.1 Build 58 Halliburton Standard Proposal Report Database: EDMPrd Local Co-ordinate Reference: Well ODSN-22i Company: Well Planning-Caelus-Oooguruk TVD Reference: 42.7'+13.5'©56.20usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ousft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-22i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-22i ISW2 Design: ODSN-22 ISW2 wp11 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1 (°) 9,471.83 4,170.20 BROOK 2B 12,451.21 5,152.20 TOROK BASE 14,408.13 5,797.20 115_TOP_HRZ 12,988.22 5,329.20 TOROK SH1 MKR 15,711.97 6,086.20 NUIQSUT 2,110.58 1,736.20 UGNU 11,895.99 4,969.20 TOROK TOP 15,585.76 6,075.20 145_BCU 6,547.06 3,206.20 HUE 2 15,757.87 6,090.20 NUIQ_1 5,488.20 2,857.20 CRETTUFF 8,573.77 3,874.20 Hue Res B tied 15,012.26 5,992.20 130_KALUBIK MKR 867.79 853.20 Top of Permafrost 15,139.35 6,022.20 KUP C 12,600.00 5,201.24 Yellow fault 9,405.08 4,148.20 Hue Res A tied 15,000.00 5,988.89 Dark Brown Fault 1,963.42 1,668.20 Base of Permafrost 15,139.35 6,022.20 134_LCU 14,775.24 5,918.20 129_BASE_HRZ 3,731.57 2,278.20 WSAK 7,178.13 3,414.20 Hue Res C tied Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-5 +E/-W (usft) (usft) (usft) (usft) Comment 192.70 192.70 0.00 0.00 Start Dir 2.5°/100':192.7'MD,192.71-VD 292.70 292.67 -0.51 -2.12 Start Dir 3°/100':292.7'MD,292.67'TVD 509.37 508.13 -5.57 -23.22 Start Dir 3.5°/100':509.37'MD,508.13'TVD 2,273.65 1,797.54 -257.03 -1,070.61 End Dir :2273.65'MD,1797.54'TVD 3,873.65 2,325.04 -609.66 -2,539.42 Start Dir 3°/100':3873.65'MD,2325.04'TVD 3,923.20 2,341.38 -619.95 -2,585.05 End Dir :3923.2'MD,2341.38'TVD 14,880.47 5,952.88 -2,757.67 -12,706.76 Start Dir 3°/100':14880.47'MD,5952.88'TVD 15,377.55 6,057.05 -2,876.96 -13,176.45 End Dir :15377.55'MD,6057.05'TVD 15,804.00 6,094.22 -2,997.28 -13,583.88 Begin Geo-steering 22,804.00 6,287.78 -4,979.79 -20,293.00 Total Depth:22804'MD,6287.78'TVD 3/16/2015 9:59:03AM Page 12 COMPASS 5000.1 Build 58 Well Planning -Caelus- Ooog u ru k Oooguruk Development Oooguruk Drill Site ODSN-22i ODSN-22i ISW2 ODSN-22 ISW2 wp11 Anticollision Summary Report 16 March, 2015 Q$� U U p_, y F F NQr'CD7�N���OWD�fpNOZ LL 0 O ..ti q N O /G Wp�mnma W1•14"STP0".Iolnrnu, A.. 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' O,A eu �a / ; 1 ark ...r.K '' �M w a i a4 �l It rl a` +G•s`G ,c.'i` f\N V ❑ BJH a a d�.i`I��o f e ;d141 cs riNg�ti, I' .: , I m a/ w = o Y p z //11 \:,,�= '\ s ''? 74, 74 O v o Z> > N 31 / A i, 7r-.'•i70 fu v 2NWN a ! !!!! msr> /'/ // �,,��, `---.0:w 6-. . y O 11 '�.�"' O// /I - Wiltel_ �`o ./ / I 1 I 44, '� `N`�-`�i , iii c ❑— i I 1 I �� ,���`,�_,►�1111� / , Z f- I I l I 0 61``,`.,, `'�� , E W_ 'y/ / I I - / / I1/�.�. _ LE?LL KR'RR'O N pTMm�I -% / I I I�/ / �,,'I \ '100. 400, '� rY ZOO."" . ,-O�,-N , l 1 1 / t`,I , I �2 CO_ V. / I 1 -/ \ • Wo Cg)y° E II'I 1 I // x09 �' 1'N 9.w. cn u-• 0888 -i o U oNN0,0cop 3 N Zo W 0Q°8z=0 § 3p; +o E V Halliburton Anticollision Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22i 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.O0usft North Reference: True Reference Well: ODSN-22i Survey Calculation Method: Minimum Curvature Well Error: 0.O0usft Output errors are at 2.00 sigma Reference Wellbore ODSN-22i ISW2 Database: EDMPrd Reference Design: ODSN-22 ISW2 wp11 Offset ND Reference: Offset Datum Reference ODSN-22 ISW2 wp11 Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Method: MD Interval 25.O0usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 200.00usft Error Surface: Elliptical Conic Survey Tool Program Date 3/16/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 42.70 1,075.00 ODSN-22 ISW2 wp11(ODSN-22i ISW2) SRG-SS Surface readout gyro single shot 1,075.00 6,638.00 ODSN-22 ISW2 wp11(ODSN-22i ISW2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 6,638.00 11,850.00 ODSN-22 ISW2 wp11(ODSN-22i ISW2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11,850.00 15,804.00 ODSN-22 ISW2 wp11(ODSN-22i ISW2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 15,804.00 22,804.00 ODSN-22 ISW2 wp11(ODSN-22i ISW2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 3/16/2015 10:56:58AM Page 2 of 6 COMPASS 5000.1 Build 58 Halliburton Anticollision Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22i Project: Oooguruk Development TVD Reference: 42.T+13.5 @ 56.20usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.T+13.5 @ 56.20usft(Nabors 19AC) Site Error: 0.00usft North Reference: True ;Reference Well: ODSN-22i Survey Calculation Method: Minimum Curvature ;Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-22i ISW2 Database: EDMPrd Reference Design: ODSN-22 ISW2 well 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-ODSDWI 274.00 275.00 35.51 5.34 30.17 Pass-Major Risk ODSK-13-ODSK-13-ODSK-13 272.77 275.00 74.49 6.09 68.40 Pass-Major Risk ODSK-13-ODSK-13A-ODSK-13A wp01 272.77 275.00 74.49 6.09 68.40 Pass-Major Risk ODSK-13-ODSK-13PB1-ODSK-13PB1 272.77 275.00 74.49 6.09 68.40 Pass-Major Risk ODSK-13-ODSK-13PB2-ODSK-13PB2 272.77 275.00 74.49 6.09 68.40 Pass-Major Risk ODSK-14-ODSK-14-ODSK-14 KupB 273.03 275.00 67.23 6.14 61.09 Pass-Major Risk ODSK-14-ODSK-14 PB1-ODSK-14 PB1 KupB 273.03 275.00 67.23 6.14 61.09 Pass-Major Risk ODSK-14-ODSK-14 PB2-ODSK-14 PB2 KupB 273.03 275.00 67.23 6.14 61.09 Pass-Major Risk ODSK-33-ODSK-33 KupA-ODSK-33 KupA 246.07 250.00 117.52 5.48 112.04 Pass-Major Risk ODSK-33-ODSK-33 PB1 KupA-ODSK-33 PB1 K 246.07 250.00 117.52 5,48 112.04 Pass-Major Risk ODSK-35Ai-ODSK-35 KupB-ODSK-35 KupB Su 247.57 250.00 104.72 5.47 99.26 Pass-Major Risk ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Sury 247.57 250.00 104.72 5.47 99.26 Pass-Major Risk ODSK-38i-ODSK-38i KupD-ODSK-38i KupD Su 271.16 275.00 74.62 6.04 68.58 Pass-Major Risk ODSK-41-ODSK-41 KupF-ODSK-41 KupF Sury 271.79 275.00 55.43 6.03 49.40 Pass-Major Risk ODSK-41-ODSK-41 PB1 KupF-ODSK-41 PB1 K 271.79 275.00 55.43 6.12 49.31 Pass-Major Risk ODSK-42i-ODSK-42Ai-ODSK-42Ai 273.24 275.00 50.68 6.18 44.51 Pass-Major Risk ODSK-42i-ODSK-42i KupG-ODSK-42i KupG 273.24 275.00 50.68 6.22 44.47 Pass-Major Risk ODSK-42i-ODSN-42B-ODSN-42B 273.24 275.00 50.68 6.02 44.66 Pass-Major Risk ODSK-42i-ODSN-42B PB1-ODSN-42B PB1 273.24 275.00 50.68 6.02 44.66 Pass-Major Risk ODSK-42i-ODSN-42B PB2-ODSN-42B PB2 273.24 275.00 50.68 6.02 44.66 Pass-Major Risk ODSN-1-ODSN-1 KE3-ODSN-1 KE3 246.40 250.00 180.60 5.47 175.13 Pass-Major Risk ODSN-1-ODSN-1 KE3 PBI-ODSN-1 KE3 PB1 246.40 250.00 180.60 5.47 175.13 Pass-Major Risk ODSN-10-ODSN-10 18EXT-ODSN-10 18EXT w 223.96 225.00 106.38 4.56 101.84 Pass-Major Risk ODSN-11 i-ODSN-11 i 15EXT-ODSN-11 i 15EXT 247.96 250.00 99.59 5.03 94.58 Pass-Major Risk ODSN-12-ODSN-12 16EXT-ODSN-12 16EXT w 320.43 325.00 93.17 6.55 86.67 Pass-Major Risk ODSN-15i-ODSN-15i-ODSN-15i IN12 273.24 275.00 59.66 6.22 53.44 Pass-Major Risk ODSN-16-ODSN-16-ODSN-16 PN13 Surveys 273.42 275.00 53.55 5.98 47.58 Pass-Major Risk ODSN-16-ODSN-16 ST-ODSN-16a wp01 273.42 275.00 53.55 5.98 47.58 Pass-Major Risk ODSN-16-ODSN-16L1-ODSN-16L1 PN13 273.42 275.00 53.55 5.98 47.58 Pass-Major Risk ODSN-17-ODSN-17-ODSN-17 PN13 Mid Surve 224.44 225.00 47.43 5.02 42.41 Pass-Major Risk ODSN-17-ODSN-17 L1-ODSN-17 L1 PN13 224.44 225.00 47.43 5.02 42.41 Pass-Major Risk ODSN-17-ODSN-17L1 A-ODSN-17L1 Awp01 224.44 225.00 47.43 5.02 42.41 Pass-Major Risk ODSN-18-ODSN-18-ODSN-18 PN11 249.18 250.00 39.73 5.44 34.30 Pass-Major Risk ODSN-18-ODSN-18 PB5-ODSN-18 PN11 PBS 249.18 250.00 39.73 5.44 34.30 Pass-Major Risk ODSN-18-ODSN-18 PB1-ODSN-18 PN11 PB1 249.18 250.00 39.73 5.44 34.30 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18 PN11 PB2 249.18 250.00 39.73 5.44 34.30 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18_PB2 249.18 250.00 39.73 5.02 34.71 Pass-Major Risk ODSN-18-ODSN-18 PB3-ODSN-18 PN11 PB3 249.18 250.00 39.73 5.44 34.30 Pass-Major Risk ODSN-18-ODSN-18 PB4-ODSN-18 PN11 PB4 249.18 250.00 39.73 5.44 34.30 Pass-Major Risk ODSN-18-ODSN-18A-ODSN-18A wp01 249.18 250.00 39.73 5.44 34.30 Pass-Major Risk ODSN-19i-ODSN-19i 34 ext-ODSN-19i 34 ext 249.52 250.00 20.03 5.61 14.42 Pass-Major Risk ODSN-19i-ODSN-19i 34 ext PB1-ODSN-19i 34e 249.52 250.00 20.03 5.61 14.42 Pass-Major Risk ODSN-19i-ODSN-19i 34 ext PB2-ODSN-19i 34 249.52 250.00 20.03 5.61 14.42 Pass-Major Risk ODSN-19i-ODSN-19i 34 ext PB3-ODSN-19i 34 249.52 250.00 20.03 5.61 14.42 Pass-Major Risk ODSN-2-ODSN-02 PN3 ext-ODSN-02 PN3 ext 174.99 175.00 174.32 3.85 170.47 Pass-Major Risk ODSN-2-ODSN-2 PN3 ext PB1-ODSN-2 PN3 e 174.99 175.00 174.32 3.85 170.47 Pass-Major Risk ODSN-20-ODSN-20 PSWO-ODSN-20 PSWO w 249,69 250.00 14.58 5.04 9.57 Pass-Major Risk ODSN-21-ODSN-21 ISW1-ODSN-21 ISW1 wp0 274.77 275.00 7.79 5.54 2.27 Pass-Major Risk ODSN-23i-ODSN-23i-ODSN-23i IN14 149.99 150.00 7.71 3.28 4.44 Pass-Major Risk ODSN-23i-ODSN-23i PB1-ODSN-23i IN14 PB1 125.00 125.00 7.28 1.77 5.51 Pass-Minor Risk 1/200 ODSN-23i-ODSN-23i PB2-ODSN-23i IN14 PB2 149.99 150.00 7.71 3.28 4.44 Pass-Major Risk ODSN-24-ODSN-24 KE5-ODSN-24 KE5 175.00 175,00 14.44 3.81 10.62 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB1-ODSN-24 PB1 175.00 175.00 14.44 3.81 10.62 Pass-Major Risk 3/16/2015 10:56:58AM Page 3 of 6 COMPASS 5000.1 Build 58 Halliburton Anticollision Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22i 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-22i Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-22i ISW2 Database: EDMPrd Reference Design: ODSN-22 ISW2 wp11 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-24-ODSN-24 KE5 PB2-ODSN-24 KE5 P 175.00 175.00 14.44 3.81 10.62 Pass-Major Risk ODSN-25-ODSN-25-ODSN-25 KE1 199.65 200.00 183.26 4.37 178.88 Pass-Major Risk ODSN-25-ODSN-25 PB1-ODSN-25 PB1 199.65 200.00 183.26 4.37 178.88 Pass-Major Risk ODSN-25-ODSN-25 PB2-ODSN-25 KE1 PB2 199.65 200.00 183.26 4.37 178.88 Pass-Major Risk ODSN-25-ODSN-25 PB3-ODSN-25 KE1 PB3 199.65 200.00 183.26 4.37 178.88 Pass-Major Risk ODSN-25-ODSN-25 PB4-ODSN-25 KE1 PB4 199.65 200.00 183.26 4.37 178.88 Pass-Major Risk ODSN-26i-ODSN-26i KE2-ODSN-26i KE2 222.83 225.00 176.54 4.98 171.56 Pass-Major Risk ODSN-26i-ODSN-26i KE2 P81-ODSN-26i KE2 222.83 225.00 176.54 4.98 171.56 Pass-Major Risk ODSN-26i-ODSN-26i KE2 PB2-ODSN-26 KE2 222.83 225.00 176.54 4.98 171.56 Pass-Major Risk ODSN-27i-ODSN-27i IN4-ODSN-27i IN4 269.68 275.00 169.40 6.07 163.33 Pass-Major Risk ODSN-28-ODSN-28 PN3-ODSN-28 PN3 199.68 200.00 163.38 4.28 159.11 Pass-Major Risk ODSN-29-ODSN-29 PN5-ODSN-29 PN5 246.54 250.00 156.17 5.43 150.73 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB1-ODSN-29 PN5 P 246.54 250.00 156.17 5.43 150.73 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB2-ODSN-29 PN5 P 246.54 250.00 156.17 5.43 150.73 Pass-Major Risk ODSN-29-ODSN-29A-ODSN-29A wp02 246.54 250.00 156.17 5.43 150.73 Pass-Major Risk ODSN-30-ODSN-30 PS4-ODSN-30 PS4 wp03 246.68 250.00 149.28 5.51 143.77 Pass-Major Risk ODSN-31-ODSN-31-ODSN-31 PN6 Surveys 247.03 250.00 131.66 5.68 125.98 Pass-Major Risk ODSN-31-ODSN-31 PB1-ODSN-31 PB1 PN6 Su 247.03 250.00 131.66 5.68 125.98 Pass-Major Risk ODSN-31-ODSN-31 ST-ODSN-31 ST wp02 247.03 250.00 131.66 5.59 126.07 Pass-Major Risk ODSN-32i-ODSN-32i IN7-ODSN-32i IN7 Survey 247.16 250.00 124.73 5.60 119.13 Pass-Major Risk ODSN-32i-ODSN-32iP81 IN7-ODSN-32iPB1 IN 247.16 250.00 124.73 5.60 119.13 Pass-Major Risk ODSN-34i-ODSN-34 IN9-ODSN-34i IN9 Survey 247.45 250.00 110.52 5.56 104.96 Pass-Major Risk ODSN-34i-ODSN-34i P82-ODSN-34iP82 IN9 247.45 250.00 110.52 5.56 104.96 Pass-Major Risk ODSN-34i-ODSN-34i PB3-ODSN-34iP63 IN9 247.45 250.00 110.52 5.56 104.96 Pass-Major Risk ODSN-34i-ODSN-34iP81-ODSN-34iP81 IN9 247.45 250.00 110.52 5.56 104.96 Pass-Major Risk ODSN-36-ODSN-36 L1-ODSN-36a wp08 247.69 250.00 98.61 5.43 93.18 Pass-Major Risk ODSN-36-ODSN-36 PB1-ODSN-36 P81 PN10 247.69 250.00 98.61 5.52 93.09 Pass-Major Risk ODSN-36-ODSN-36 PB2-ODSN-36 P82 PN10 247.69 250.00 98.61 5.52 93.09 Pass-Major Risk ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Sur 247.69 250.00 98.61 5.52 93.09 Pass-Major Risk ODSN-37-ODSN-37-ODSN-37 PN8 248.07 250.00 80.77 5.67 75.10 Pass-Major Risk ODSN-37-ODSN-37L1-ODSN-37L1 wp10a 248.07 250.00 80.77 5.58 75.19 Pass-Major Risk ODSN-3i-ODSN-3i IN4 ext-ODSN-3i IN4 ext 199.69 200.00 167.10 4.38 162.73 Pass-Major Risk ODSN-3i-ODSN-3i IN4 ext-ODSN-3i IN4 ext wp 199.69 200.00 167.10 4.38 162.73 Pass-Major Risk ODSN-4-ODSN-04 PN5 ext-ODSN-04 PN5 ext 340.68 350.00 161.61 7.72 153.90 Pass-Major Risk ODSN-4-ODSN-4 PN5 ext P81-ODSN-04 PN5 340.68 350.00 161.61 7.72 153.90 Pass-Major Risk ODSN-40-ODSK-40 ST-ODSK-40 ST wp1.0 271.56 275.00 62.65 5.89 56.76 Pass-Major Risk ODSN-40-ODSN-40 PN12-ODSN-40 PN12 Sur 271.56 275.00 62.65 6.08 56.56 Pass-Major Risk ODSN-40-ODSN-4OPB1 PN12-ODSN-40PB1 P 271.56 275.00 62.65 6.08 56.56 Pass-Major Risk ODSN-40-ODSN-40PB2 PN12-ODSN-40PB2 P 271.56 275.00 62.65 6.08 56.56 Pass-Major Risk ODSN-43-ODSN-43 Western ERD-ODSN-43 W 224.51 225.00 39.13 4.40 34.76 Pass-Major Risk ODSN-43-ODSN-43 Western ERD P81-ODSN- 224.51 225.00 39.13 4.74 34.42 Pass-Major Risk ODSN-43-ODSN-43 Western ERD PB2-ODSN- 224.51 225.00 39.13 4.40 34.76 Pass-Major Risk ODSN-48-ODSN-48 Western ERD-ODSN-48 S 174.99 175.00 36.12 3.80 32.31 Pass-Major Risk ODSN-5i-ODSN-5i PS2-ODSN-5i PS2 wp01 246.94 250.00 152.63 5.01 147.65 Pass-Major Risk ODSN-6-ODSN-6 IS3-ODSN-6 IS3 wp01 247.07 250.00 145.59 5.01 140.61 Pass-Major Risk ODSN-7i-ODSN-7i PS4-ODSN-7i PS4 wp01 223.55 225.00 127.25 4.54 122.73 Pass-Major Risk ODSN-8-ODSN-8 PS8-ODSN-8 PS8 wp09-8K 247.55 250.00 120.58 5.52 115.06 Pass-Major Risk ODSN-9i-ODSN-9i IS9-ODSN-9l wp13-8k horz 247.69 250.00 113.56 5.48 108.08 Pass-Major Risk ODST-39-ODSN-39i IN11-ODSN-39i IN11 272.63 275.00 69.09 6.12 62.97 Pass-Major Risk ODST-39-ODST-39 Torok D-ODST-39 Torok D 272.60 275.00 69.09 6.03 63.06 Pass-Major Risk ODST-39-ODST-39 Torok D P81-ODST-39 Tor 272.60 275.00 69.09 6.03 63.06 Pass-Major Risk ODST-45-ODSN-45i PB1 IN13-ODSN-45i PB1 249.41 250.00 34.89 5.75 29.14 Pass-Major Risk ODST-45-ODST-45A-ODST-45A Surveys 249.41 250.00 34.89 5.75 29.14 Pass-Major Risk 3/16/2015 10:56:58AM Page 4 of 6 COMPASS 5000.1 Build 58 Halliburton Anticollision Report Company: Well Planning-Caelus-Oooguruk Local Co-ordinate Reference: Well ODSN-22i 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-22i Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 2.00 sigma Reference Wellbore ODSN-22i ISW2 Database: EDMPrd Reference Design: ODSN-22 ISW2 wp11 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance DeviationWarning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODST-46i-ODST-46i-ODST-46i Torok C 125.00 125.00 32.70 1.74 30.96 Pass-Minor Risk 1/200 ODST-46i-ODST-46i PB1-ODST-46i Torok C PB 149.99 150.00 33.09 3.23 29.86 Pass-Major Risk ODST-46i-ODST-46i PB2-ODST-46i Torok C PB 125.00 125.00 32.70 1.74 30.96 Pass-Minor Risk 1/200 ODST-46i-ODST-46i Torok C PB3-ODST-46i PB 149.99 150.00 33.09 3.23 29.86 Pass-Major Risk ODST-47-ODST-47-ODST-47 299.42 300.00 33.79 6.63 27.16 Pass-Major Risk ODST-47-ODST-47A-ODST-47a wp13 299.42 300.00 33.79 6.58 27.20 Pass-Major Risk Oooguruk Offset Wells Kalubik#1-Kalubik#1-Kalubik#1 4,809.28 2,624.99 125.43 60.29 65.38 Pass-Minor Risk 1/200 Sikumi#1 Sikumi#1-Sikumi#1-Sikumi#1 Out of range Sikumi#1-Sikumi#1 PB1-Sikumi#1 PB1 Out of range 3/16/2015 10:56:58AM Page 5 of 6 COMPASS 5000.1 Build 58 -i' t - • t • i { , i 41Lj ,, *1-1 F 1 IT :All aiikrri-r-t —r :-1 i 1 t !r-rL.+-t—T'r-- } !---4, ,f...� { ..� I t _ - :1:. — _. • - Zn: qi■■ ■ i '44fiLf1-?, , H t---1-4:-1-1-4- ,-1-1- 1 : YI • • ■ . ii.ni i�iai... t f , 1 j E ... 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HPA.ii, ..8>It'Jt . .118NNk8'In:,`,,,NN,',4g3g; g3.#, 33g3a3g.5.32F,F, tgKtt,qg NT •000nnnn000nnnnnonn.,,,c.oncnonnonnn000n,,,oc+ oon0000 00(n :,,, X .40000n000.4,4-0000000088c2,000000000000,o,9.0,880.0. 00n0000no..00, !gl,,Iq..4,1:fq^4Arr,q44:i.;1:4,,r,zn'.e.. .22?-97.22.S14°14,q,4"4 ,1.7;,14444. '44 4 IsiNggNggr,;. ',.:‘,e,igtitiN33, .„gtE ,t, ,ta ,l‘rt,qt,#„te,,*, gEgEE 3 3 3 3 3, 3 8 880088o08088880888088o808o888888008088888 0000088888 8 $ T4$11+4+$41 4*VD+1+1 1.:1 Vil<1 VC[14+11-11 TV:VII I VNIF11+41 ifT+1+4+EP 13T+Itm+HC[1]* Mi Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, March 13, 2015 3:29 PM To: 'Alex Vaughan' Subject: RE: ODSN-22 Proposed Diverter Routing (PTD 211-078) expired Alex, As we discussed the targeted (SCH-100)90 deg is acceptable for ODSN-22 but the 45 deg must also be SCH- 100. Please get me the drawings as soon as you can for the new 45 deg pieces. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Schwartz, Guy L (DOA) Sent: Friday, March 13, 2015 2:29 PM To: 'Alex Vaughan' Subject: RE: ODSN-22 Proposed Diverter Routing (PTD 211-078) expired Alex, I see.. good reason to always put the PTD number in the subject line of email!! I didn't realize this was an old approved PTD. It actually expired after two years anyway so would need to resubmit. My feeling is that the 90 deg(thick walled SCH 100) is ok. I would also get a 45 deg SCH 100 . If you can get extra 45 degs (two=90 deg) that would even be better to spread out the turn radius. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Alex Vaughan [mailto:Alex.Vaughan@caelusenergv.com] Sent: Friday, March 13, 2015 12:26 PM To: Schwartz, Guy L (DOA) Subject: RE: ODSN-22 Proposed Diverter Routing 1 Guy, The original ODSN-22 PTD was approved by the AOGCC on 6/27//2011 with PTD#211-078 (attached). We will re-submit a PTD application as the current intended well path is significantly different than the originally submitted version. The "new" ODSN-22 surface casing point is 680' away from the ODSN-48 surface casing point. Caelus will not be requested an exception from using a diverter in the ODSN-22 PTD application. Please reference the ODSN-22 SCP diagram below. The diverter equipment planned for use on ODSN-22: • The 90° sweep is not a Targeted 'T'. The attached email correspondence between yourself and Dennis Hartwig from ODSN-03i describes the SCH 100—90°sweep we have available. • The 45° sweep is not a Targeted 'T'. It can be beefed up in a similar manner as the current 90° sweep should the AOGCC require this be done. N. r. \Ix ..-- .••• 40 lok ,. . c.,_ A 0 is ... , SN.-22 wp10 ..I..... I' 680" 1600° �° _ , ``N O• 1-48 0o ODST-461 4111, Ilk ODSN-23P� ODST-47 ODS 1 -23 OD ,-43 SCD Alex Vaughan Senior Drilling Engineer Caelus Energy Alaska, LLC 3700 Centerpoint Dr. I Anchorage,AK 99503 Direct 907.343.2186 I Cell 907.748.5478 alex.vaughan@caelusenergy.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, March 13, 2015 10:30 AM 2 To: Alex Vaughan Cc: Oooguruk DrillingTechAdmin Subject: RE: ODSN-22 Proposed Diverter Routing Alex, My bad... forgot to get back to you. Are the 45 and 90 deg bends targeted? What about requesting waiver ... is surface casing within 500 ft of existing SC shoes? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Alex Vaughan [mailto:Alex.Vaughan@caelusenergy.com] Sent: Friday, February 27, 2015 11:01 AM To: Schwartz, Guy L (DOA) Cc: Oooguruk DrillingTechAdmin Subject: ODSN-22 Proposed Diverter Routing Guy, Would you please review and comment on the proposed diverter routing for ODSN-22. This well is scheduled to Spud 4/4/2015. Alex Vaughan Senior Drilling Engineer Caelus Energy Alaska, LLC 3700 Centerpoint Dr. I Anchorage, AK 99503 Direct 907.343.2186 I Cell 907.748.5478 alex.vaughan@caelusenergy.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 3 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: boor 0\V3-2 2 PTD: a/5- ✓Development Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: 60:yU IQ< POOL: C00 l,.✓'JA Ij ltii 5 W 6,-j 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 also required for this well: Well Logging Requirements v Per Statute AS 31.05.030(dX2XB) 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 2/2015 0 N u) a . . of0. o C (o, Q ° . C g . U' U E" P ca C 6. O• 1 co 01 LL (n -O E 0 P P p o O m a)' t : rn c 00' o o a' a. Z — o' 'v IT) k ed c0� C '. N. �: ayY c0' -o U: o y a 'o: 0: =, c c v: a a 3 m. y, 06' c c 0' O c 3' 7, ' € �: N, 0 y: Zf , co c 3o y. vyc'c m, o oS c ymw: °� E _O N ay : V: at U:'; c-.3 .. In, E: � yoo � a r;: ax Z , E. E o O �', u, v:: of "' >, a• " , I : , o. a). . , a; w c y a �,� J o c c' �. : Z �, 'a O, w N: a N: . v cvo U w J O 0) ct t , f Ot ' ' w ' NU D a ' .- a)' — v) : . O . >' M. . _ Q O) O) yo II" O 0 C: o. O' . . W' L c, N: >: m W; y. = : 4 —_: i a 1 N O ? 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: Caelus Energy Alaska Field: Oooguruk Development Rig: Nabors 19AC Date: May 30, 2015 Surface Data Logging End of Well Report ODSN-22 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: Caelus Energy Rig: Nabors 19AC Well: ODSN-22 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20708-00-00 Sperry Job Number: AK-XX-0902261396 Job Start Date: 03 April 2015 Spud Date: 04 April 2015 Total Depth: 22208’ MD, 6196’ TVD North Reference: True Declination: 19.416° Dip Angle: 80.994° Total Field Strength: 57722 nT Date Of Magnetic Data: 15 March 2015 Wellhead Coordinates N: North 70° 29’ 44.98” Wellhead Coordinates W: West 150° 14’ 49.18“ Drill Floor Elevation: 56.2’ Ground Elevation: 13.5’ Permanent Datum: Mean Sea Level SDL Engineers: Kerry Garner, Martin Nnaji, David Durst, Ashley Wilderom SDL Sample Catchers: Jarrett Johns, Eric Andrews, Mario Luescher, Julia Ruth Company Geologist: Mindaugas Kuzminskas, Fletcher England, Paul Cozma, John Hill Company Representatives: Joe Polya, Rodney Klepzig, CA Demoski, Joe Petitjean SSDS Unit Number: 123 DAILY SUMMARY 04/03/2015 SDL continued on location from previous well. The rig crew moved the rig and the pit module from ODSN-03i to ODSN-22, then spotted and leveled the rig over ODSN-22. The crew rigged up berms, landings, beaver slide, skate, and the lines in the putz and hutz. The Internal Blowout Preventer and saver sub were changed out. Surface and diverter lines were rigged up. This required cutting the saddles on top of the well bay to move the diverter line. 04/04/2015 The diverter surface stack was rigged up. The rig took on spud mud into pits 1-5. The rig crew picked up 5" drill pipe using the mouse hole, then picked up 14 joints of 5" heavy weight drill pipe, 3rd party tools, jars, and bit. The drill line was slipped and cut and the top drive was serviced. The diverter was tested. After that, the Gyro tools were rigged up. Then, the top drive’s block height was calibrated for MWD. The standpipe was tested to 3500 pounds per square inch. The rig picked up the bottom hole assembly and ran in the hole, then tagged ice at 67' MD. The rig drilled ahead from 67' MD to 158' MD at 400 gallons per minute, 30 revolution per minute, 270 pounds per square inch, 1-2K Torque. Gas: No significant gas was detected. Fluids: There were 0 barrels lost down hole. 04/05/2015 Drilled ahead from 158' MD to 193' MD at 400 gallons per minute, 260 pounds per square inch, 40 revolutions per minute, 1.5K Torque, and 12-15K weight on bit. Gyro hands logged each connection. The rig then pulled out of the hole and made up bottom hole assembly number 1. The rig tripped back in the hole to 193' MD, then drilled ahead from 193' MD to 626' MD at 450 gallons per minute, 450 pounds per square inch, 40 revolutions per minute, 2.5K Torque, and 12-15K weight on bit. Drilling continued from 626' MD to 1357' MD at 515 gallons per minute, 750 pounds per square inch, 40 revolutions per minute, 4-5K Torque, and 15-20 weight on bit. Use of gyro stopped at 1006' MD. The top drive was serviced. Gas: The max gas was 62 units at 902’ MD and the average gas was 27 units. Fluids: There were 0 barrels lost down hole. 04/06/2015 Drilled ahead from 1357' MD to 2145' MD at 590 gallons per minute, 1130 pounds per square inch, 40 revolutions per minute, 8K Torque, 20K weight on bit. Drilling resumed from 2145' MD to 2620' MD at 590 gallons per minute, 1350 pounds per square inch, 40 revolutions per minute, 6K Torque, 18-21K weight on bit. The rig back reamed out of the hole from 2620' MD to 721' MD. The rig circulated 3 bottoms up while back reaming standing back 1 stand every bottoms up. Back reaming was performed at 650 gallons per minute, 150 pounds per square inch, 6-8K Torque. Gas: The max gas was 37 units at 1359’ MD and the average gas was 17 units. Fluids: There were 0 barrels lost down hole. 04/07/2015 Back reamed from 1170' MD to 160' MD. Laid down bottom hole assembly and serviced the top drive. The rig tripped in the hole on elevators from 250' MD to 1605' MD, worked through tight spot by adjusting pumps and orienting high side. Worked pipe from 1605' MD to 1626' MD, tripped in the hole from 1625' MD to 2532' MD and washed down from 2532' MD to 2600' MD. Drilled ahead from 2600' MD to 3606' MD at 650 gallons per minute, 100 revolutions per minute, 8-9K Torque, serviced the top drive and drilled ahead. Gas: The max gas was 32 units at 2688’ MD and the average gas was 11 units. Fluids: There were 0 barrels lost down hole. 04/08/2015 Drilled ahead from 3606' MD to 3777' MD, circulated bottoms up at 670-700 gallons per minute and changed out shaker screens for the increased rate to 850 gallons per minute. The rig drilled ahead from 3777' MD to 4986' MD at 850 gallon per minute, 2390 pounds per square inch, 8-9K torque, 120 revolutions per minute, 18-20 weight on bit. Serviced the top drive and currently drilling at 150 feet per hour. Gas: The max gas was 24 units at 4444’ MD and the average gas was 15 units. Fluids: There were 0 barrels lost down hole. 04/09/2015 Drilled ahead from 4336' MD to 6142' MD, serviced the top drive and continued drilling from 6142' MD to 6242' MD at 850 gallons per minute, 11K torque, 18-20K weight on bit. Gas: The max gas was 47 units at 5764’ MD and the average gas was 20 units. Fluids: There were 0 barrels lost down hole. 04/10/2015 Drilled ahead from 6237' MD to 6558' MD, back reamed from 6558' MD to 6237' MD and circulated three bottoms up. Performed a 700 barrel dilution and continued to back ream from 6237' MD to 2532' MD. Broke out the ghost reamer and continued back reaming from 2532' MD to 2057' MD. The rig circulated four bottoms up, racking back one stand per bottoms up from 2400' MD to 2100' MD. Tripped out of the hole from 2057' MD to 1758' MD and back reamed from 1758' MD to 253' MD. Gas: The max gas was 47 units at 6520’ MD and the average gas was 29 units. Fluids: There were 0 barrels lost down hole. 04/11/2015 Laid down bottom hole assembly from 253' MD to 0' MD. Laid down third party tools and picked up the casing running equipment. Rigged up Tesco casing equipment and calibrated torque equipment. Picked up the shoe joint and second joint laid down second joint and picked up a replacement. Re-rigged Tesco casing spiders and ran in the hole to 168' MD. Checked floats and ran in the hole from 168' MD to 1549' MD. Hit a tight spot - pumped and rotated down casing from 1549' MD t o 2031' MD. Continued in hole with casing from 2031' MD to 2765' MD filled every joint at each connection. Gas: No significant gas was detected. Fluids: There were 38 barrels lost down hole. 04/12/2015 Continued tripping in hole with 11.75" casing from 2765' MD to 6509' MD and continued filling every joint. Worked through tight spots at 4285'MD and 5276' MD, completed running casing from 6509' to 6548' MD. Picked up landing joint and hanger circulated one bottoms up after reaching 8 barrels a minute. Gas: The max gas was 80 units at 6558’ MD and the average gas was 9 units. Fluids: There were 269 barrels lost down hole. 04/13/2015 Rigged down Tesco equipment and rigged up the cementing equipment. Pumped spacer and cement as per cement pump schedule. Displaced cement with rig pumps using the spud mud. Pumped 7075 strokes without bumping the plug monitored the well for 30 minutes and flushed the stack. Gas: The max gas was 41 units while circulating and the average gas was 4 units. Fluids: There were 89 barrels lost down hole. 04/14/2015 Nipple up blow out preventers and tested the lower connection to 2700 psi. Picked up testing equipment and performed a full blow out preventers test. Laid down testing equipment and blew down lines. Picked up bottom hole assembly and installed the elevators. Ran in the bottom hole assembly from surface to 626' MD. Picked up 5" drill pipe and singled in from 626' MD to 5950' MD, while filling pipe ever 45 joints. Serviced the top drive and tripped in the hole from 5950' MD to 6330' MD. Gas: No significant gas was detected. Fluids: There were 0 barrels lost down hole. 04/15/2015 Circulated one bottoms up at 6330' MD, blew down top drive, cut / slipped drilling line. Tripped in the hole and tagged up at 6363' MD; pulled out of the hole to 6330' MD. Tested 11.75" casing to 3500 pounds per square inch for 30 minutes, displaced well to 10 pounds per gallon mineral oil based mud and reamed down from 6425' MD to 6520' MD. Drilled out shoe track with cemented and 20’ of new hole to 6578' MD with 405 gallons per minutes, 1002 pounds per square inch, and 40 rotations per minutes. Circulated two bottoms up at shoe and performed formation integrity test to 12.5 pounds per gallon equivalent mud weight. Pumped dry job and tripped out of the hole to 538' MD. Changed out jars and laid down bottom hole assembly. Gas: No significant gas was detected. Fluids: There were 13 barrels lost on surface. 04/16/2015 Picked up BHA to 112' MD and uploaded MWD tools. Picked up BHA, broke in reamer and shallow pulse tested the MWD tools. Picked up BHA to 648' MD and then filled pipe. Tripped in the hole and broke in Geo-Pilot. Tripped in the hole to 6578' MD installed Cuttings Bed Impeller every three stands. Drill ahead from 6578' MD to 6709' MD at 700 gallons per minutes, 2931 pounds per square inch. Took directional survey, dropped tags and opened reamer, and pulled against shoe to verify it opened. Drill ahead from 6709' MD to 6948' MD at 750 gallons per minutes, 2887 pounds per square inch, weight on bit 7K, and 100 rotations per minutes. Gas: The max gas was 46 units at 6963’ MD and the average gas was 30 units. Fluids: There were 0 barrels lost down hole. Geology: Samples were predominately grey to dark grey shale with platy cleavage and firm structure. 04/17/2015 Drilled ahead from 6948' to 7063' MD; serviced the top drive. Drilled ahead from 7063' MD to 8118' MD at 800 gallons per minute serviced and inspected the top drive. Proceed to drill ahead from 8118' to 8190' MD, with an average rate of penetration of 75’ per hour, 5K weight on bit, with a 141 rotation per minutes. Gas: The max gas was 84 units at 8024’ MD and the average gas was 61 units. Fluids: There were 0 barrels lost down hole. Geology: Samples were predominately grey to dark grey shale with platy cleavage and firm structure with trace amounts of claystone and siltstone found throughout the day. 04/18/2015 Drilled ahead from 8184' MD to 8694' MD at 800 gallons per minute, 3750 pounds per square inch, 140 revolutions per minute, 12K Torque. Serviced and inspected the top drive. Drilled ahead from 8694' MD to 9369' MD at 800 gallon per minutes, 3900 pounds per square inch, 140 rotations per minutes, 12K Torque. Serviced and inspected the top drive; cleaned suction screens on both pumps. Drilled ahead from 9369' MD to 9418' MD at 800 gallons per minutes, 3950 pounds per square inch, 140 rotations per minutes 12.5K Torque. Gas: The max gas was 144 units at 9381’ MD and the average gas was 87 units. Fluids: There were 0 barrels lost down hole. Geology: Samples were predominately grey to dark grey shale with platy cleavage and firm structure with trace amounts of tuff, claystone and siltstone found throughout the day. 04/19/2015 Drilled ahead from 9418' MD to 9847' MD at 800 gallons per minute, 4000 pounds per square inch, 14K Torque, 142 revolutions per minute. Serviced and inspected the top drive. Drilled ahead from 9847' MD to 10329' MD to 800 gallons per minute, 4180 pounds per square inch, 14K Torque, 141 revolutions per minute. Finished trouble shooting Geo-Pilot and drilled ahead from 10329' MD to 10581' MD at 800 gallons per minute, 4200 pounds per square inch, 15K Torque, and 140 revolutions per minute. Average rate of penetration was 70 feet per hour, 8k pounds weight on bit, 141 revolutions per minute, and standpipe pressure of 4300 pounds per square inch. Gas: The max gas was 199 units at 9720’ MD and the average gas was 93 units. Fluids: There were 0 barrels lost down hole. Geology: Samples were predominately grey to dark grey shale with tabular cleavage and firm structure with trace amounts of tuff and claystone found throughout the day. 04/20/2015 Drill ahead from 10560' MD to 10906' MD at 800 gallons per minute, 4250 pounds per square inch, 16K Torque, 140 revolutions per minute. Serviced top drive and replaced hydraulic line. Drilled ahead from 10906' MD to 11670' MD at 800 gallons per minute, 4430 pounds per square inch, 16K -17K Torque, 140 revolutions per minute. Serviced the top drive and greased blocks. Average rate of penetration was 70 feet per hour, 8K pounds weight on bit, 140 revolutions per minute, and standpipe pressure of 4400 pounds per square inch. Gas: The max gas was 109 units at 11575’ MD and the average gas was 75 units. Fluids: There were 0 barrels lost down hole. Geology: Samples were predominately grey to dark grey shale with tabular cleavage and firm structure with trace amounts of tuff and claystone found throughout. 04/21/2015 Drilled ahead from 11670' MD to 11720' MD at 800 gallons per minute begin pumping down the closing tag for reamer and function tested rams and annular. Picked up 30' and rotated at 10 revolutions per minute to verify that the reamer closed. Started quadrant reaming from 11720' MD to 11670' MD at 750 gallons per minute and transferred a 500 barrel of new mud for dilution during second bottoms up circulation. Circulated four bottoms up, racked back a stand and back-reamed from 11670' MD to 11575' MD. Serviced and inspected the top drive begins lubing out of the hole at 2 barrels per minute from 11575' MD to 6750' MD. Worked bottom hole assembly through the shoe with no rotation per minutes to 6385' MD. Started staging up pumps for a bottoms up circulation. Average rate of penetration was 48 feet per hour, 8K pounds weight on bit, 141 revolutions per minute, and standpipe pressure of 4400 pounds per square inch. Gas: The max gas was 87 units at 11671’ MD and the average gas was 83 units. Fluids: There were 15 barrels lost down hole during trip out of hole to the shoe. Geology: Samples were predominately grey to dark grey shale with tabular cleavage and firm structure with trace amounts of tuff and claystone found throughout. 04/22/2015 Circulate using step rate method to achieve 750 gallons per minute and circulate 1.5 bottoms up. Back reaming out of the hole from 6385' MD to 3706' MD at 750 gallons per minute, 3500 pounds per square inch, 140 revolutions per minute. Circulate 2 bottoms up and back ream out from 3706' MD to 648' MD. Lay down bottom hole assembly to surface. Clean and clear rig floor, trip in the hole with 18 joints of heavy weight drill pipe and flushed the stack. Trip out of the hole with 6 stands and rack back in derrick. Pick up test tools and test joint. Set test plug and change rams. Test blowout prevention equipment. Gas: The max gas was 53 units and the average gas was 15 units, all trip gas. Fluids: There were 15 barrels lost down hole during trip out of hole from the shoe to surface. 04/23/2015 Pull test plug laid down test joint clean and clear rig floor. Rig up Tesco to run 9 5/8" liner held pre-job and begin running liner. Run liner from surface to 2009' MD and circulate bottoms up using step rate method. Run liner from 2009' MD to 4002' MD. Circulate bottoms up using step rate method. Run liner from 4002' MD to 5290' MD. Rig down Tesco running tools and rig up Tesco power tongs. Pick up and made up liner hanger. Rig down Tesco power tongs sent tools down beaver slide. Continued in the hole with 9 5/8" liner hanger from 5290' MD to 5325' MD begin running 9 5/8" liner on 5" drill pipe from 5325' MD to 5448' MD. Break circulation, fill pipe and pump 20 barrels. Break circulation and check all parameters. Gas: The max gas was 13 units and the average gas was 9 units. Fluids: There were 20 barrels lost down hole during the liner run. 04/24/2015 Circulate using step rate method continued running 9 5/8" liner from 5488' MD to 6491' MD. Circulate liner volume using step rate method, service rig, and check load cell on dead man. Ran 9 5/8" liner on 5" drill pipe from 6491' MD to 7038' MD. Work through tight spot with 30 rpm and pumping 2 barrel per minute to 7441' MD. Run liner from 7441' MD to 11602' MD. Install cement head and lines; proceed to run liner from 11602' MD to 11720' MD. Circulate using step rate method in 1/2 barrel increments, packing off at 4.5 barrel per minute. Decrease pump rates until losses stabilize. Drop ball and pump down, seat at 1085 strokes. Verify set and pressure up to 4400 psi. Slacked off, bleed off and establish circulation using step rate method in 1/2 barrel increments. Gas: The max gas was 177 units and the average gas was 23 units. Fluids: There were 80 barrels lost down hole. 04/25/2015 Continue to stage up pumps to 4 barrels per minute, reduce pump rate to 2 barrels per minute while preparing for cement job. Cement 9 5/8" liner as per Halliburton Cement pump schedule. Blow down cement lines. Un-sting drill pipe from liner and lay down cement head. Circulate 1 bottom up. Stand back two stands drill pipe and cut and slip drilling line. Pump dry job and trip out of the hole from 6276' MD to surface. Lay down 21 joints heavy weight on trip out. Lay down bottom hole assembly. Hold pre-job safety meeting to nipple down. Drain stack and remove trip nipple, choke and kill lines. Nipple down blowout prevention equipment pick up multi bowl well head and lower to well bay. Gas: The max gas was 218 units and the average gas was 18 units. Fluids: There were 336 barrels lost down hole. 04/26/2015 Install multi-bowl well head and lower riser. Nipple up surface stack picked up blowout preventer test tools and set test plug. Change out lower blowout preventer rams and test blowout prevention equipment. Drain blowout preventer stack; lay down test tools and service rig. Pick up the bottom hole assembly to 504’ MD. Trip in the hole picking up single joints out of the pipe shed to 4207' MD. Trip in the hole to 11423' MD washed down from 11423' MD to 11585' MD, tag up on cement. Circulate 1 bottom up at 600 gallons per minute. Pressure test casing to 3500 psi for 30 min test was successful. Gas: The max gas was 113 units and the average gas was 16 units. Fluids: There were 0 barrels lost down hole. 04/27/2015 Pressure test casing to 3500 pounds per square inch for 30 minutes ,drill down cleaning out shoe track from 11585' MD to11720' MD. Displace well over to 10.2 pound per gallon LSND mud system. Drill ahead from 11720' MD to 11740' MD. Circulate one bottom up to 600 gallons per minutes. Perform formation integrity test. Monitor well to verify static. Pump dry job and trip out of the hole from 11740' MD to 504' MD. Laid down bottom hole assembly at surface. Bring bottom hole assembly number 6 up beaver slide and stage on floor. Pick up test tools, drain stack in preparation for blowout preventer equipment test. Gas: The max gas was 24 units at 11720’ MD and the average gas was 17 units. Fluids: There were 0 barrels lost down hole. 04/28/2015 Pull wear ring and set test plug. Test blow out prevention equipment. Lay down test tools and blow down lines. Service the top drive. Service top drive and clean rig floor. Pick up Bottom hole assembly to 78’ MD. Download MWD tools. Pick up bottom hole assembly to 137’ MD and rest reamer. Perform shallow pulse test to 600 gallons per minute. Pick up bottom hole assembly to 604’ MD. Break in Geo-Pilot at 600 gallons per minute. Trip into the hole to 10574’ MD, service the top drive and continued in hole. Gas: The max gas was 9 units and the average gas was 5 units. Fluids: There were 0 barrels lost down hole. 04/29/2015 Tripped into the hole from 10573' MD to 11522' MD while washing and reaming into the hole working through tight spots as necessary from 11522' MD to 11740' MD at 600 gallons per minute, 2700 pounds per square inch, 40-80 revolutions per minute, 14-18K Torque. Drilled ahead from 11740' MD to 11850' MD at 605 gallons per minute, 2700 pounds per square inch, 100 revolutions per minute, 20.5K Torque, 12K weight on bit. Established parameters and dropped 10 tags to open the reamer. Drilled ahead from 11850’ MD to 12091' MD at 756 gallons per minute; 3400 pounds per square inch; 60-160 revolutions per minute; 21-26K Torque; 17- 25K weight on bit. Obtained slow pump rates. Performed a kick while drilling drill and continued drilling ahead from 12091' MD to 12566' MD at 750 gallons per minute, 3650 pounds per square inch, 120 revolutions per minute, 21K Torque, 15-18K weight on bit. Obtained slow pump rates. Performed a kick while drilling drill with the opposite rig crew. Drilled ahead from 12566' MD to 12800' MD at 750 gallons per minute, 3720 pounds per square inch, 130 revolutions per minute, 21K Torque, 14-20K weight on bit. Gas: The max gas was 188 units at 12028’ MD and the average gas was 84 units. Fluids: There were 0 barrels lost down hole. Geology: Samples have been dominantly siltstone: dark to medium gray in color, tabular, crumbly to moderately hard, with trace amounts of sandstone, claystone, and pyrite. 04/30/2015 Drilled ahead from 12800' MD to 13137' MD at 757 gallons per minute; 3800 pounds per square inch, 140 revolutions per minute, 21-26K Torque, 17-20K weight on bit. Circulated bottoms up, lubricated out of the hole from 13137' MD to 12328' MD at 2 barrels per minute. Spotted 71 barrels of 50 pound per barrel LCM pill right outside the bit; covering the Torok. Tripped out from 12328' MD to 11428' MD and performed lost circulation material squeeze job. Serviced top drive and blocks, worked on the top drive. Cut and slipped drilling line. Tripped in the hole from 11428' MD to 13137' MD and installed rotating control device bearing. Staged up pumps until we achieved 2 barrels per minute, and then we went back to 1 barrel increments. Worked on mud pump number one; having blower motor issues. Gas: The max gas was 134 units at 12843’ MD and the average gas was 82 units. Fluids: There were 0 barrels lost down hole. Geology: Samples were grey to dark grey, tan, light brown, moderately hard to hard, tabular fracture, well sorted, with very fine to fine grained sandstone. 05/01/2015 Continued to circulate 5 bottoms up, increasing pump rate while maintaining a 12.5 pounds per gallon equivalent circulating density. Pulled rotating control device bearing and installed trip nipple, then drilled ahead from 13137’ MD to 13232’ MD at 750 gallons per minute, 3600 pounds per square inch, 120 revolutions per minute, 22K Torque, 18-22K weight on bit. Pulled the trip nipple and installed the rotating control device bearing. Drilled ahead from 13232’ MD to 13422’ MD at 700 gallons per minute, 3500 pounds per square inch, 120 revolutions per minute, 25-27K Torque, 18-22 weight on bit, performed a kick while drilling drill and drilled ahead from 13422’ MD to 13893’ MD at 650 gallons per minute, 3500 pounds per square inch, 135 revolutions per minute, 10-20 weight on bit. Obtained slow pump rates. Serviced top drive, then drilled ahead from 13893’ MD 13992’ MD at 650 gallons per minute, 3450 pounds per square inch, 140 revolutions per minute, 20-25K Torque, 20K weight on bit. Gas: The max gas was 237 units at 13648’ MD and the average gas was 84 units. Fluids: There were 0 barrels lost down hole. Geology: Samples were grey to dark grey, firm to moderately hard, blocky fracture, well sorted slightly calcareous siltstone with trace sandstone and shale 05/02/2015 Drilled ahead from 13992’ MD to 14376’ MD at 650 gallons per minute, 3500 pounds per square inch, 140 revolutions per minute, 26K Torque, 12-15 weight on bit. Drilled ahead from 14375’ MD to 14467’ MD at 650 gallons per minute, 3500 pounds per square inch, 150 revolutions per minute, 26K Torque, 12-15K weight on bit. Encountered a loss zone with partial pack offs. Serviced rig and monitored the well to ensure static. Drilled ahead from 14467’ MD to 14483’ MD at 650 gallons per minute, 3500 pounds per square inch, 150 revolutions per minute, 26K Torque, 12-15K weight on bit and still losing to the hole. Monitored the well while working the drill pipe periodically and then performed a kick while drilling drill. Continued to work the drill pipe and monitor the well while the RSC was building more 10.2 pounds per gallon LSND. Drilled ahead from 14483’ MD to 14721’ MD back reaming 60' of every stand at 650 gallons per minute, 3680 pounds per square inch, 150 revolutions per minute, 24K Torque, 10-20K weight on bit. Pumping a 15 barrel, 70 pound per barrel, loss circulations sweep every 500'. Gas: The max gas was 551 units at 14483’ MD and the average gas was 247 units. Fluids: There were 540 barrels lost down hole. Geology: Samples were dark grey, occasionally light grey, firm to moderately hard shale with inter-bedded organic laminations, trace glauconite, trace pyrite, and trace sandstone. 05/03/2015 Drilled ahead from 14721’ MD to 15038’ MD at 650 gallons per minute, 3660 pounds per square inch, 150 revolutions per minute, 20-22K Torque, 10-15K weight on bit and observed a 200 pounds per square inch pressure loss while drilling, worked pipe while determining what the problem was and the possible solutions. Pumped a carbide pill at 3 barrels per minute, 940 pounds per square inch and it came back at 680 strokes, 530' down. Found the washout below the tool joint on stand 149. Replaced the joint and tripped back in the hole to 15038’ MD, then staged up pumps to 650 gallons per minute, 150 revolutions per minute. Drilled ahead from 15038’ MD to 15228’ MD at 650 gallons per minute, 3770 pounds per square inch, 150 revolutions per minute, 23K Torque, 15-20 weight on bit. Obtained slow pump rates. Pumped a 26 barrel, 70 pound per barrel LCM sweep and drilled ahead from 15228’ MD to 15481’ MD at 650 gallons per minute, 3800 pounds per square inch, 150 revolutions per minute, 23-25K Torque, 8-15K weight on bit. Gas: The max gas was 490 units at 14838’ MD and the average gas was 254 units. Fluids: There were 0 barrels lost down hole. Geology: Samples were clear, light grey, dark grey, hard, medium to fine grained, sub spherical, sub rounded, moderately sorted sandstone. 05/04/2015 Drilled ahead from 15481’ MD to 15709’ MD at 650 gallons per minute, 3800 pounds per square inch, 150 revolutions per minute, 23K Torque, 28K weight on bit. Serviced top drive and replaced the encoder on the top drive. Drilled ahead from 15709’ MD to 15726’ MD at 650 gallons per minute, 3700 pounds per square inch, 150 revolutions per minute, 26K Torque, 13- 15 weight on bit. Obtained slow pump rates and pumped down reamer tags. Quadrant reamed from 15638’ MD to 15726’ MD at 650 gallons per minute, 4100 pounds per square inch, 150 revolutions per minute, 22K Torque. Pumped 25 barrels weighted sweep, then circulated 6 bottoms up. Lubricated out of the hole from 15726’ MD to 11649’ MD at 48 gallons per minute, 650 pounds per square inch, 40 revolutions per minute and 60 foot per minute. Gas: The max gas was 872 units at 15696’ MD and the average gas was 321 units. Fluids: There were 25 barrels lost down hole while lubing out of hole. Geology: Samples were 65% Sandstone: clear, white, translucent, medium to fine grained , sub-spherical to spherical, sub-rounded to rounded, moderately sorted, with trace pyrite and glauconite; 35% Siltstone: light grey, grey, dark grey, brown, tan, firm to moderately hard, non- calcareous. 05/05/2015 Tripped in the hole from 11649’ MD to 15726’ MD and staged up pumps to 650 gallons per minute, at 4150 pounds per square inch, 150 revolutions per minute, 24K Torque. Pumped 1 bottoms up then pumped a 25 barrel weighted, high viscosity sweep around for a total of 3.5 bottoms up, then displaced well from 10.2 pounds per gallon to 12.3 pounds per gallon. The 12.3 pounds per gallon was expected to come back at 16147 strokes, 12.3 pounds per gallon came back to surface at 18050 strokes (161 barrels past). Removed the rotating control device and installed the trip nipple. Lubricated out of the hole from 15726’ MD to 11649’ MD at 84 gallons per minute, 80-100 pounds per square inch, then function tested the blowout prevention equipment. Gas: The max gas was 2008 units and the average gas was 111 units. Fluids: There were 0 barrels lost down hole while lubing out of hole. 05/06/2015 Tripped out of the hole from 11649' MD to 11142' MD pumped a dry job and continued to trip out of the hole from 11142' MD to 604' MD. Laid down BHA from 604' MD to 0' MD; cleaned and cleared the rig floor. Changed top rams to 7" and serviced the top drive. Removed the wear ring, installed the test plug, and tested the 7" rams. Laid down testing equipment and rigged up Tesco casing equipment. Tested the torque with a Load Cell and ran in the hole with 7” Casing from 0' MD to 1675' MD. Gas: The max gas was 5 units and the average gas was 3 units. Fluids: There were 0 barrels lost down hole. 05/07/2015 Ran in with 7" Casing from 1675' MD to 14276' MD, filling with 10.1 pounds per gallon LSND. Hit a tight spot at 14237' MD; rotated through it at 20 revolutions per minute with 15K Torque. Gas: The max gas was 70 units and the average gas was 30 units. Fluids: There were 0 barrels lost down hole. 05/08/2015 Ran in with 7" Casing from 14276' MD to 15699' MD and emergency slips were set due to rotating to get casing down. Rigged down and laid down Tesco casing equipment. Rigged up the cement head and cement lines and staged up and displaced out 12.3 pounds per gallon LSND to 10.1 pounds per gallon LSND. Pressure tested the cement lines. Performed cement job with little returns. Bumped the plug at 3 barrels per minute at 6870 strokes, opened the ES cementer and pumped 2 barrels per minute at 3484 pounds per square inch. Pumps were staged up to 5 barrels per minute in 0.5 barrel increments with no losses. Gas: The max gas was 440 units and the average gas was 61 units. Fluids: There were 725 barrels lost down hole from the first stage cement job. 05/09/2015 Circulated two bottoms up and cleaned pits to displace the 10.1 pounds per gallon MOBM. W ell was displaced from 10.1 pounds per gallon LSND mud to 10.1 pounds per gallon MOBM. Circulated one bottoms up at 210 gallons per minute. Pumped the second stage portion of the cement job according to the cement plan and bumped the plug with 10.1 pounds per gallon LSND. Closed the ES Cementer and pressure tested the casing to 2500 pounds per square inch. Rigged down the cementing equipment, drained the stack and rigged down the casing running equipment. Nippled down the blow out preventer and set the emergency slips. Laid down the casing cut joint, tested the emergency pack off to 4300 pounds per square inch and picked up blow out preventer testing equipment. Gas: The max gas was 1090 units and the average gas was 45 units. Fluids: There were 0 barrels lost down hole. 05/10/2015 Finished changing out the rams and sent out the internal blowout preventer and saver sub. Picked up testing equipment and tested the BOP; annular failed the test. Changed out the annular preventer and rigged up and tested the new annular preventer. Laid down the testing equipment, blew down the lines, and installed the Wear Ring, Rotary Bushings and Mouse Hole. 61 of the 163 stands of the 5” drill pipe were laid down. Gas: The max gas was 0 units and the average gas was 0 units. Fluids: There were 0 barrels lost down hole. 05/11/2015 Laid down the 5" drill pipe using the mouse hole and brought up thread protectors to the rig floor. Serviced the top drive and finished laying down the 5" drill pipe. Removed the mouse hole and laid it down; kicked out the remainder of the 5" drill pipe in the pipe shed. Picked up 4" drill pipe singles to 1926' MD and cut and slipped drilling line. Serviced the top drive and picked up 4" drill pipe from 1926' to 9148' MD. Performed a kick while tripping drill and continued picking up 4” drill pipe. Gas: The max gas was 0 units and the average gas was 0 units. Fluids: There were 0 barrels lost down hole. 05/12/2015 Picked up 4" drill pipe from 9148' MD to 12030' MD and circulated 1.5 times drill volume; pressure tested to 2600 pounds per square inch. Pumped a dry job and tripped out of hole to surface. Removed wear ring and installed the test plug. Picked up testing equipment and tested blow out preventers. Rigged up and tested the Managed Pressure Drilling equipment, laid down testing equipment, and blew down lines. Picked up and ran in bottom hole assembly, shallow pulse tested, blew down top drive and continued picking up 4" drill pipe from 394' MD to 1165' MD. Gas: The max gas was 0 units and the average gas was 0 units. Fluids: There were 0 barrels lost down hole. 05/13/2015 Picked up 4" drill pipe and tripped in hole from 1165' MD to 12033' MD. Washed down and drilled out ES cementer to 12421' MD. Washed down and tripped into hole to 15305' MD. Washed down and pulled out of hole to 15493' MD and began pressuring up for casing test. Washed out and replaced high pressure mud line. Gas: The max gas was 0 units and the average gas was 0 units. Fluids: There were 0 barrels lost down hole. 05/14/2015 Replaced high pressure mud line and tested. Pressure tested casing to 4000 pounds per square inch for 30 minutes and reamed/washed down. Circulated one bottoms up. Tripped out of the hole and performed bat sonic logs. Gas: The max gas was 113 units and the average gas was 0 units. Fluids: There were 0 barrels lost down hole. 05/15/2015 Tripped out of the hole from 11461' MD to 10979' MD and logged a Cement Bond Log with XBAT tool. Pumped a 20 barrel dry job and continued to trip out of the hole to 394' MD. Laid down bottom hole assembly to surface and downloaded MWD. Pulled the wear ring, installed junk basket, and flushed the stack. Drained the stack and installed the test plug. Observed the well flowing slowly; filled the stack and installed and tested the MPD equipment. Pulled the plug and installed gauge on annulus with blinds shut. Monitored pressure and bled off, bled the well through the choke lines to verify no flow. Opened the blinds and monitored the well for 10 minutes with no flow. Gas: The max gas was 0 units and the average gas was 0 units. Fluids: There were 0 barrels lost down hole. 05/16/2015 Tested blow out preventer and bled off pressure on the annulus. Removed test plug and installed wear ring. Picked up bottom hole assembly from surface to 144' MD. Downloaded MWD tools and shallow pulse test at 180 gallons per minute. Tripped in the hole to 1548' MD and circulated 1300 strokes. Tripped in the hole from 1548' MD to 15665' MD and filling at every 30 stands. Transfer oil based mud from pit 2 to RSC to run the degasser. Cut and slip drilling line. Gas: The max gas was 2208 units and the average gas was 189 units. Fluids: There were 14 barrels gained during tripping in. 05/17/2015 Cut and slipped drilling line and circulated 1.5 bottoms up at 200 gallons per minute. Removed trip nipple and installed RCD head. Displaced the well over to a 7.5 pounds per gallon oil based mud. Drilled ahead from 15726' MD to 15746' MD and performed a formation integrity test to 12.5 pounds per gallon equivalent mud weight. Drilled ahead from 15717' MD to 15953' MD at 210 gallons per minute; circulated 4100 strokes until the same mud weight in and out was reached. Conducted a Pore Pressure Test; resulting in 9.3 pounds per gallon equivalent mud weight. Drilled ahead from 15953' MD to 16050' MD; holding 9.5 pounds per gallon with MPD at the shoe. Observed high gas levels and increased MPD pressure to 9.8 pounds per gallon and circulated until gas was below 3500 units. Gas: The max gas was 6615 units at 15768’MD and the average gas was 4591 units. Fluids: There were 0 barrels lost down hole. Geology: Geologic samples were sandstone: clear, translucent, tan, very fine to fine grained, sub-rounded to rounded, moderately sorted and silty. 05/18/2015 Drilled ahead from 16050' MD to 16339' MD at 220 gallons per minute and 3500 pounds per square inch; serviced top drive and drilled ahead from 16399' MD to 17039' MD at 220 gallons per minute and 3600 pounds per square inch. Serviced and inspected top drive. Gas: The max gas was 6498 units at 16208’MD and the average gas was 1375 units. Fluids: There were 0 barrels lost down hole. Geology: Geologic samples were sandstone: clear, translucent, tan, very fine to fine grained, sub-rounded to rounded, well sorted and silty. 05/19/2015 Drilled ahead from 17039' to 17495' MD and serviced the top drive. Drilled ahead from 17495' to 18315' MD and serviced the top drive. Gas: The max gas was 2908 units at 1756’MD and the average gas was 985 units. Fluids: There were 0 barrels lost down hole. Geology: Geologic samples were sandstone: clear, translucent, tan, very fine to fine grained, sub-rounded to rounded, well sorted. 05/20/2015 Drilled ahead from 18315' MD to 18940' MD and serviced top drive. Drilled ahead from 18940' to 19034' MD at 220 gallons per minute, 3710 pounds per square inch, 16.5k torque, 70 revolutions per minute. Drilled ahead from 19034' MD to 19708' MD at 230 gallons per minute, 4075 pounds per square inch, 15.5k torque, 80 revolutions per minute and serviced top drive. Gas: The max gas was 3933 units at 19465’MD and the average gas was 651 units. Fluids: There were 40 barrels lost down hole. Geology: Geologic samples were sandstone: clear, translucent, tan, very fine to fine grained, sub-rounded to rounded, well sorted. 05/21/2015 Drilled ahead from 19708' MD to 20190' MD at 230 gallons per minute, 4180 pounds per square inch, 16.4k torque, 80 revolutions per minute; serviced top drive. Drill ahead from 20190' MD to 20864' MD at 230 gallons per minute, 4200 pounds per square inch, 15.9k torque, 80 revolutions per minute; serviced top drive. Gas: The max gas was 2651 units at 20636’MD and the average gas was 1333 units. Fluids: There were 25 barrels lost down hole. Geology: Geologic samples were sandstone: clear, translucent, tan, very fine to fine grained, sub-rounded to rounded, well sorted, with trace siderite and pyrite. 05/22/2015 Drilled ahead from 19708' MD to 20190' MD at 230 gallons per minute, 4180 pounds per square inch, 16.4k torque, 80 revolutions per minute and serviced top drive. Drill ahead from 20190' MD to 20864' MD at 230 gallons per minute, 4200 pounds per square inch, 15.9k torque, 80 revolutions per minute and serviced top drive. Gas: The max gas was 3254 units at 21690’ MD and the average gas was 1117 units. Fluids: There were 0 barrels lost down hole. Geology: Geologic samples were sandstone: clear, translucent, tan, very fine to fine grained, sub-rounded to rounded, well sorted, with trace siderite and pyrite. 05/23/2015 Drilled ahead from 21966' MD to 22019' MD at 230 gallons per minute, 4350 pounds per square inch, 16k torque, and 80 revolutions per minute; changed out the RCD bearing and drilled ahead to 22208' MD. Circulated 1.5 bottoms up from 22208' MD to 22019' MD and performed a pore pressure test; resulting in a 9.75 EMW. Circulated one bottoms up from 22019' MD to 21926' MD and back reamed out of the hole to 20187' MD. Circulated 6500 strokes at 200 gallons per minute; back reamed out of the hole to 18073' MD at 200 gallons per minute, 3150 pounds per square inch, 60 revolutions per minute; and serviced the top drive. Gas: The max gas was 1842 units at 22084’ MD and the average gas was 793 units. Fluids: There were 59 barrels lost down hole. Geology: Geologic samples were sandstone: clear, translucent, tan, very fine to fine grained, sub-rounded to rounded, well sorted, with trace siderite and pyrite. 05/24/2015 Back-reamed from 18073' MD to 15665' MD at 200 gallons per minute and circulated 3 bottoms up; serviced the top drive and changed out the Inner Blow out Preventer and saver sub. Tripped in the hole from 15665' to 22208' MD and serviced the blocks. Displaced well over to a 10.2 pound per gallon oil based, kill weight mud. Gas: The max gas was 9194 units and the average gas was 782 units. Fluids: There were 59 barrels lost down hole. Geology: No geological samples were collected. 05/25/2015 Finished displacing the well with a 10.2 pound per gallon oil based mud and checked the well for flow. Well was static, so rig crew and MPD pulled the RCD bearing and installed the trip nipple. Lubed out of the hole from 22208' MD to 15699' MD; while pumping at a rate of 1 barrel per minute, checked the well for 15 minutes, results were static. Dropped 2 3/8" drift and lubed out of the hole from 15699' to 14027' MD, while pumping at a 2 barrel per minute at 3 minute stands. Observed losses while tripping; attempted to pull on the elevators and encountered swabbing. Lubed out of the hole to 13064' MD pumping 1/2 barrel per minute at 5 minute stands. Gas: The max gas was 2615 units and the average gas was 185 units. Fluids: There were 59 barrels lost down hole. 05/26/2015 Lube out of the hole from 13064' MD to 4881' MD at 1 barrel per minute and 3 minutes per stand. Trip out of the hole from 4881' MD to 2190' MD. Lay down 4" drill pipe from 2190' MD to 431' MD. Lay down bottom hole assembly and unload nuclear sources. Gas: The max gas was 616 units and the average gas was 23 units. Fluids: There were 10 barrels lost down hole. 05/27/2015 Finish laying down bottom hole assembly and clear rig floor. Pick up 54 joints heavy weight drill pipe, then flush and rack back. Pull wear ring, pick up junk basket, function test rams and flush stack. Set test plug and test blowout prevention equipment. Lay down test tools and make up Baker sub magnet assembly. Clean and clear rig floor. Rig up GBR tubing tools. Hold pre-job safety meeting on running 4.5" tubing. Run 4.5" 12.6# C-110 Hyd-521 from surface to 1623’ MD. Gas: The max gas was 186 units and the average gas was 8 units. Fluids: There were 0 barrels lost down hole. 05/28/2015 Ran 4.5" Liner from 1623’ MD to 6712’ MD. Picked up and ran in the liner hanger. Rigged down power tongs. Changed over to 4" drill pipe handling equipment. Picked up bumper sub magnet assembly. Circulated 2 bottoms up at 6809’ MD at 2 barrels per minute, 640 pounds per square inch. Started seeing losses at 2 barrels per minute, reduced rate to 1 barrel per minute and losses stopped. Ran liner in on 4" drill pipe from 6809’ MD to 15469’ MD at 40 feet per minute, pumping 30 strokes every 10 stands. Gas: The max gas was 1193 units and the average gas was 63 units. Fluids: There were 18 barrels lost down hole. 05/29/2015 Landed 4” liner at 22205’ MD and proceeded to rig down. Gas: The max gas was 3121units and the average gas was 394 units 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 22000 23000 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 Me a s u r e d D e p t h Rig Days WELL NAME: ODSN-22 OPERATOR: Caelus Energy Alaska MUD CO: Baroid RIG: Nabors 19AC SPERRY JOB: AK-XX-0902261396 Days vs. Depth 02 Apr 2015 Sperry SDL remains on location from previous well 03 Apr 2015 Sperry SDL services online LOCATION: Oooguruk AREA: North Slope Borough STATE: Alaska SPUD: 4-Apr-2015 TD: 23-May-2015 Landed 11.75" Casing 6548' MD, 3211' TVD 12 Apr 2015 Commenced 14.5" Surface Hole Section On Bot: 23:44 04 Apr 2015 POOH to change Mud Motor bend 06 April 2015 TD Surface Hole Section 6558' MD, 3214' TVD Off Bot: 06:45 10 Apr 2015 Commenced 10.625" Intermediate 1 Hole Section On Bot: 14:02 16 Apr 2015 TD Intermediate 1 Hole Section 11720' MD, 4916' TVD Off Bot: 01:15 21 Apr 2015 Commenced 8.5" Intermediate 2 Hole Section On Bot: 02:23 29 Apr 2015 TD Intermediate 2 Hole Section 15726' MD, 6079' TVD Off Bot: 06:29 04 May 2015 Landed 7" Casing 15699' MD, 6079' TVD 08 May 2015 Landed 9.625" Liner 11717' MD, 4915' TVD 24 April 2015 Commenced 6.125" Production Hole Section On Bot: 10:34 17 May 2015 TD Production Hole Section 22208' MD, 6196' TVD Off Bot: 05:18 23 May 2015 Landed 4.5" Liner 22205' MD, 6196' TVD 29 May 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Little to no issues with gas equipment / CVE / Hydrogen Generator. ODSN-22 Oooguruk Caelus Energy Alaska North Slope Borough AK-XX-0902261396 Alaska Nabors 19AC Surface Ashley Wilderom 13-Apr-2015 What went as, or better than, planned: Difficulties experienced: -IRIS and Workstation screen froze seperately during operations - restarted computers to resolve issues. Recommendations: Keep CVE covered during drilling with a high flow out - mud splashes on top and covers hoses. Innovations and/or cost savings: N/A Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: -Workstation froze up a few times during drilling, but did not interrupt any data being recorded. Recommendations: -Send in computers to be checked out. Innovations and/or cost savings: N/A -No issues during drilling. -All paperwork was filled out and submitted on time. -No CVE / Gas Gear equipment failures. ODSN-22 Oooguruk Caelus Energy Alaska North Slope Borough AK-XX-0902261396 Alaska Nabors 19AC Intermediate 1 Ashley Wilderom 8-May-2015 What went as, or better than, planned: Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: Transparent hose between the degasser and the drop-down jar at the pits was observed to contain lots of moisture at a short period of time which could hinder gas flow. Recommendations: Check and drain moisture in hose into the drop down at regular intervals. And completely empty drop- down jar during connection when the rig stops pumping. Innovations and/or cost savings: Used a carbide pill to detect the depth where a washout occurred on a drill pipe, as a result we saved the rig from utilizing other processes to detect this which could have cost the rig time and money. Nabors 19AC Intermediate 2 Martin Nnaji 8-May-2015 What went as, or better than, planned: All went as planned. Computers, gas gears, CVE and Hrdrogen generator worked good all through. ODSN-22 Oooguruk Caelus Energy Alaska North Slope Borough AK-XX-0902261396 Alaska Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 -Improvements to InSite plots made by several team members - made it easier to see trends in gas to identify gas coming from other parts of the wellbore. Note: plots were lost during the replacement of workstation computer. ODSN-22 Oooguruk Caelus Energy Alaska North Slope Borough AK-XX-0902261396 Alaska Nabors 19AC Production Section Ashley Wilderom 29-May-2015 What went as, or better than, planned: Difficulties experienced: -IRIS failed - lost data on depth logs. -Workstation failed - full replacement was needed. -Company suggested a multiple point gas calibration - 10/20/99% for high gas readings. Recommendations: Equipment peaked out at 10000 units on several occassions during drilling the section. Multiple calibration points were suggested by several members of Caelus, HXR, and Sperry. Innovations and/or cost savings: N/A Surface Data Logging After Action Review WELL NAME:ODSN-22 LOCATION:Oooguruk OPERATOR:Caelus Energy Alaska AREA:North Slope Borough MUD CO:Baroid STATE:Alaska RIG:Nabors 19AC SPUD:4-Apr-2015 SPERRY JOB:AK-XX-0902261396 TD:23-May-2015 Marker MD INC AZ TVD TVDSS 14.5" Surface Borehole Top Permafrost 870.0 23.64 255.30 853.13 796.93 Base Permafrost 1,977.0 60.85 258.68 1,668.28 1,612.08 Ugnu D 2,090.0 64.70 258.26 1,720.50 1,664.30 Top West Sak 3,720.0 73.22 258.06 2,283.46 2,227.26 Cretaceous Tuffs 5,386.0 70.67 259.36 2,819.88 2,763.68 Hue 2 Shale 6,460.0 69.94 258.30 3,180.98 3,124.78 11 3/4" SCP 6,548.0 69.62 257.99 3,211.48 3,155.28 10.625" Intermediate 1 Borehole Hue Res C 7,099.0 71.39 258.80 3,393.20 3,337.00 Hue Res B 8,573.0 70.57 257.73 3,880.06 3,823.86 Hue Res A 9,529.0 71.40 259.23 4,193.98 4,137.78 Brookian 2B 9,663.0 70.82 258.38 4,237.39 4,181.19 9 5/8" ICP1 11,717.0 70.68 258.06 4,915.21 4,859.01 8.5" Intermediate 2 Borehole Top Torok Sand 11,835.0 70.42 257.55 4,954.52 4,898.32 45' DTE Fault from Torok SS::Below Base Torok SS 12,328.0 70.70 257.91 5,117.69 5,061.49 Base Torok Sand Torok 1 Shale 13,006.0 70.54 257.72 5,340.53 5,284.33 Top HRZ 14,242.0 70.66 259.96 5,750.92 5,694.72 Base HRZ (Top Kalubik Shale)14,643.0 71.81 259.63 5,879.95 5,823.75 Dark Brown Fault ±45' DTE Kalubik Marker 14,865.0 70.86 257.68 5,949.99 5,893.79 LCU (Top Miluveach Shale)15,018.0 74.79 256.72 5,995.73 5,939.53 BCU (Top Kingak Shale)15,270.0 85.12 255.61 6,039.88 5,983.68 Top Nuiqsut 15,647.0 84.96 254.42 6,072.64 6,016.44 Top Nuiqsut::Nuiq_1 D1 15,673.0 85.06 254.27 6,074.89 6,018.69 7" ICP2 15,699.5 85.06 254.27 6,077.17 6,020.97 6.125" Production Borehole Possible small fault 16,291.0 86.70 251.73 6,126.95 6,070.75 TD 6-1/8" Lateral 22,208.0 88.7 253.3 6,196.0 6,140.48 Formation Tops Removed by Fault Not Apparent on Logs ODSN-22 Caelus Energy Alaska Baroid Nabors 19AC AK-XX-0902261396 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 ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 4-Apr 158 8.80 112 26 37 9/12/14 6.4 89/63/51/35/11/9 2/0 3.4 1.0/95.3 0.01 0.40 9.9 1.0 0.35/0.70 2,100 240 Drilling Ahead 5-Apr 1195 9.00 90 15 40 13/17/19 7.2 70/55/45/34/15/13 2/0 3.5 1.0/94.3 0.50 1.10 9.9 7.5 0.45/0.75 22,000 320 Drilling Ahead 6-Apr 2620 9.25 95 21 36 15/20/23 8.0 78/57/46/36/18/16 2/0 5.3 1.0/92.5 1.00 0.95 9.8 7.5 0.40/0.75 22,500 440 Back Reaming 7-Apr 3500 9.25 78 17 33 15/18/21 6.0 67/50/40/30/18/16 2/0 5.5 1.5/91.8 1.00 0.70 10.0 12.0 0.35/0.60 22,500 400 Drilling Ahead 8-Apr 4907 9.30 85 17 43 21/26/30 6.4 77/60/52/43/24/22 2/0 5.8 2.0/91.0 1.00 0.65 9.6 10.0 0.10/0.60 22,000 280 Drilling Ahead 9-Apr 6130 9.45 60 16 35 18/26/31 6.0 67/51/44/36/20/18 2/0 6.8 2.0/90.0 1.00 0.65 9.7 10.0 0.20/0.50 22,000 280 Drilling Ahead 10-Apr 6558 9.50 60 15 27 17/27/37 7.0 57/42/35/29/16/15 2/0 9.0 2.0/88.0 1.00 0.70 9.5 10.0 0.10/0.75 19,000 240 Drilling Ahead / TD Surface Section 11-Apr 6558 9.30 48 14 25 15/28/35 7.6 53/39/33/22/15/13 2/0 6.0 2.0/91.0 1.00 0.60 9.2 10.0 0.10/0.70 19,000 240 TIH w/ Surface Casing 12-Apr 6558 9.50 43 13 20 12/20/27 7.6 46/33/29/22/11/9 2/0 7.5 2.0/89.5 1.00 0.65 9.0 12.5 0.10/0.60 19,500 240 TIH - Surface / Rig Down TESCO 13-Apr 6558 9.65 50 15 19 13/19/27 7.6 49/34/29/20/13/11 2/0 8.5 2.0/88.5 1.00 0.80 9.3 12.5 0.20/0.75 19,500 240 Nipple down surface stack 14-Apr 6558 9.60 47 15 19 13/20/28 8.0 49/34/29/20/13/11 2/0 8.4 2.0/88.6 1.00 0.60 9.0 12.5 0.10/0.70 19,500 240 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 15-Apr 6578 10.00 108 30 19 12/31/44 2.8 79/49/37/24/10/9 0/2 10.7 86.4/13.6 -7.25 882 4.32 242,893 2.53/113.06 3.748 Picking up BHA 16-Apr 6776 10.00 98 28 20 11/29/44 2.6 76/48/37/24/10/9 0/2 10.7 86.4/13.6 -6.73 863 7.24 250,555 29.02/110.99 3.725 Drilling Ahead 17-Apr 7928 10.00 98 35 20 12/42/58 2.4 90/55/42/28/11/10 0/2 11.0 85.7/14.3 -6.60 944 7.24 269,903 33.41/107.77 3.666 Drilling Ahead 18-Apr 9223 10.00 98 34 20 14/53/67 2.8 88/54/41/27/11/10 0/2 11.0 75.5/12.0 -5.96 914 10.15 280,730 38.07/101.06 3.595 Drilling Ahead 19-Apr 10334 10.00 92 35 21 15/58/67 2.2 91/56/41/26/11/11 0/2 11.0 75.5/12.0 -5.18 880 10.15 280,730 38.07/101.06 3.595 Drilling Ahead 20-Apr 11435 10.00 91 36 19 16/61/71 2.6 91/55/42/27/12/11 0/2 11.6 86.8/13.2 -4.92 825 10.15 282,622 47.66/93.76 3.479 Drilling Ahead 21-Apr 11720 10.00 101 35 19 13/52/68 2.2 89/54/40/25/10/9 0/2 11.0 75.5/12.0 -4.92 1123 10.63 282,816 38.23/100.74 3.592 Drilling Ahead / TD Intermediate Section 1 22-Apr 11720 10.00 120 35 18 12/49/71 2.6 88/53/39/24/10/9 0/2 11.5 75.0/12.0 -4.53 1482 10.63 282,816 47.80/92.64 3.473 Testing BOPE 23-Apr 11720 10.00 126 37 17 12/48/72 2.4 91/54/40/25/9/8 0/2 11.0 75.5/12.0 -4.66 1346 10.15 280,730 38.07/101.06 3.595 Running 9 5/8" Liner 24-Apr 11720 10.05 130 37 19 12/51/72 2.6 93/56/41/26/9/8 0/2 11.5 75.0/12.0 -4.66 928 10.15 280,730 44.23/98.48 3527 Circulating/Landed 9 5/8" Liner 25-Apr 11720 10.10 147 35 18 12/50/72 2.8 88/53/37/24/9/8 0/2 11.5 75.0/12.0 -4.14 840 10.15 280,730 40.82/103.99 3579 Nipple up multi-bowl 26-Apr 11720 10.20 21 35 20 12/53/74 2.8 90/55/39/25/9/8 0/2 12.0 74.5/12.0 -4.4 824 10.15 280,730 43.65/106.91 3,565 Casing Test 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 ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 27-Apr 11740 10.20 62 18 27 9/11/14 2.4 63.0/45.0/37.0/26.0 2/0 6.7 4.0/88.0 0.05 0.80 10.1 1.0 0.20/1.25 25,500 720 Drill 20' of new hole 28-Apr 11740 10.20 54 15 27 8/10/11 3.4 5.7/42.0/34.0/24.0 2/0 6.7 4.0/88.0 0.01 0.80 10.3 1.0 0.3/1.30 25,500 800 Trip in hole 29-Apr 12688 10.20 57 18 36 10/15/21 3.4 67.0/49.0/40.0/30.0 2/0 7.3 5.0/86.5 0.10 0.75 9.9 0.5 0.30/1.20 24,000 740 Drilling Ahead 30-Apr 13137 10.20 60 17 35 10/17/21 3.0 69/52/43/32/11/9 2/2 7.3 5.0/86.5 0.10 0.75 9.8 5.0 0.30/1.30 24,000 720 Circulating 1-May 13950 10.20 61 19 39 14/26/35 3.5 77/58/49/38/12/11 2/2 7.8 6.0/85.0 0.10 0.65 10.0 12.5 0.30/1.10 23,500 280 Drilling Ahead 2-May 14653 10.20 60 14 38 13/21/25 4.0 66/52/44/34/13/12 2/2 7.3 4.0/87.5 0.10 0.70 10.2 10.0 0.35/1.30 24,000 320 Drilling Ahead 3-May 15417 10.25 56 17 38 13/16/20 4.0 72/55/46/36/14/12 2/2 7.5 4.5/86.5 0.10 0.65 9.8 12.5 0.35/0.25 30,000 200 Drilling Ahead 4-May 15726 10.20 45 13 29 10/13/14 3.4 55/42/33/23/10/9 2/2 7.3 5.0/86.0 0.01 -10.5 10.0 0.40/1.90 34,000 144 LOOH to Shoe 5-May 15726 12.30 54 20 27 7/9/10 2.0 67/47/37/26/9/8 2/2 13.2 4.0/78.0 0.01 5.00 10.1 -1.80/4.10 100,000 560 LOOH to Surface 6-May 15726 10.15 48 12 20 6/8/10 4.4 44/32/26/20/7/5 2/2 7.1 4.0/87.5 0.10 0.75 10.2 7.5 0.35/1.25 28,500 280 RIH w/ 7" Casing 7-May 15726 10.15 48 12 20 6/7/9 4.4 44/32/25/20/7/5 2/2 7.0 4.0/87.5 0.10 0.70 10.0 7.5 0.30/1.20 30,500 280 RIH w/ 7" Casing 8-May 15726 10.10 50 13 19 6/9/11 4.6 45/32/24/18/7/6 2/2 7.0 3.0/88.5 0.10 0.55 9.8 7.5 0.30/1.30 30,000 280 Circulating 9-May 15726 10.15 50 13 19 7/9/10 4.6 45/32/25/18/8/7 2/2 7.5 3.0/88.0 0.10 0.65 9.8 7.5 0.25/1.10 29,500 280 Changing Rams Remarks Water Based Mud TD:23-May-2015 Remarks Water Based Mud Oil Based Mud WELL NAME:LOCATION:Oooguruk OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:4-Apr-2015 SPERRY JOB: W a t e r a n d O i l B a s e d M u d ODSN-22 Caelus Energy Alaska Baroid Nabors 19AC AK-XX-0902261396 10-May 15726 10.10 50 13 19 6/8/10 4.6 45/32/25/19/7/6 2/2 7.0 3.0/88.5 0.10 0.60 9.6 7.5 0.15/1.10 29,500 280 Lay down 5" DP 11-May 15726 10.10 51 12 20 7/9/10 4.6 44/32/24/18/8/7 2/2 7.5 3.0/88.0 0.10 0.65 9.6 7.5 0.15/1.10 30,000 280 Picking up 4" DP Singles 12-May 15726 10.20 52 13 18 7/9/10 4.8 44/31/26/20/7/6 2/2 7.5 3.0/88.0 0.10 0.60 9.6 7.5 0.15/1.10 29,500 280 Picking up 4" DP Singles 13-May 15726 10.30 51 12 18 6/9/11 5.6 42/30/24/17/7/6 2/0 7.7 4.0/86.5 0.01 2.50 11.6 7.5 0.80/1.90 36,000 800 Changing High Pressure Mud Line 14-May 15726 10.25 46 12 14 5/7/9 5.8 38/26/21/14/6/5 2/3 7.6 3.0/87.5 0.01 2.80 11.8 7.5 0.90/2.40 38,000 840 Bat Sonic Log, TOOH 15-May 15726 10.25 40 12 12 5/7/9 6.4 36/24/21/14/6/5 2/3 8.0 3.0/87.0 0.01 3.20 11.9 7.5 1.40/2.60 40,500 1,200 Monitoring well / BOP Test 16-May 15726 10.25 15 15 11 6/10/12 6.4 41/26/20/13/6/5 2/3 8.0 3.0/87.0 0.01 3.60 11.9 7.5 1.23/2.80 40,000 1,200 Slip and Cut Drilling Line 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-May 15953 7.55 67 12 16 19/28/37 4.6 40/28/23/18/12/11 0/2 1.7 88.7/11.3 -6.86 1648 2.87 154968 15.15/1.28 2.68 Drilling Ahead - Production Section 18-May 16820 7.55 60 12 15 21/34/42 4.6 39/27/23/18/12/11 0/2 1.7 86.6/11.0 -6.22 2000 2.87 160,285 14.88/1.26 2.68 Drilling Ahead 19-May 18315 7.65 58 13 13 20/34/41 4.4 39/26/22/17/11/10 0/2 2.5 85.8/11.0 -6.86 2000 1.9 161,225 22.56/0.09 2.604 Drilling Ahead 20-May 19708 7.80 54 10 12 9/20/33 4.6 32/22/17/13/9/8 0/2 3.4 84.9/11.0 -5.05 1995 2.58 157,919 30.24/1.53 2.649 Drilling Ahead 21-May 20689 7.80 61 13 13 9/24/38 4.4 39/26/20/14/9/8 0/2 3.4 85.4/10.5 -6.47 1872 1.9 156,594 29.61/2.85 2.69 Drilling Ahead 22-May 21762 7.80 58 13 14 8/29/44 4.4 40/27/21/15/9/8 0/2 3.6 85.3/10.5 -6.73 1954 1.41 157,091 32.07/0.79 2.624 Drilling Ahead 23-May 22208 7.80 62 14 12 8/0/47 4.6 40/26/20/14/8/7 0/2 3.5 85.4/10.5 -6.47 2000 1.9 148,134 29.99/2.89 2.69 TD Production Section / Pore Pressure Test 24-May 22208 7.80 64 12 11 12/34/48 4.6 35/23/18/14/8/7 0/2 3.5 89.1/10.9 -6.22 2000 1.41 148,641 29.58/3.28 2.703 TOOH / TIH / Displace Well 25-May 22208 10.20 86 25 17 11/42/53 2.6 67/42/31/20/10/9 0/2 11.5 86.2/13.8 -6.99 870 5.29 266,494 31.82/118.32 3.715 Lube out of hole 26-May 22208 10.20 91 25 18 10/39/53 3.4 68/43/33/21/10/9 0/2 12.0 74.0/12.5 -6.22 823 5.78 262,362 41.95/109.08 3.587 Laying Down BHA 27-May 22208 10.20 146 27 18 11/39/56 3.8 72/45/32/21/10/9 0/2 12.0 74.0/12.5 6.22 1106 6.26 267,786 41.82/108.77 3.587 Running 4.5" Liner 28-May 22208 10.25 107 27 21 12/38/54 3.8 75/48/35/22/11/10 0/2 12.2 74.0/12.5 6.02 960 15.49 273,735 44.73/107.47 3.557 Running 4.5" Liner Casing Record 4-Apr-2015 SPERRY JOB:TD:23-May-2015 Water Based Mud 9.625" Casing @ 11717' MD, 4915'TVD 7" Casing @ 15699' MD, 6079'TVD Oil Based Mud WELL NAME:LOCATION:Oooguruk OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD: 11.75" Casing @ 6548' MD, 3211'TVD 16" Conductor @ 158' MD, 158'TVD W a t e r a n d O i l B a s e d M u 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/MXL-IV 14.500 158 2620 2462 22.97 0.994 45.0 23 40 958 505 1-2-CT-C23-E-1-WT-BHA Surface Hole Section 2 200 2 Baker/VM-1 14.500 2620 6558 3938 43.39 0.994 56.5 15 113 2930 850 1-1-CT-A-E-1-ER-TD Surface Hole Section 3 300 3 Baker Hughes / GT-C1 10.625 6558 6578 22 0.23 0.942 96.4 25 60 2815 700 0-1-CT-C1-E-I-NO-BHA Intermediate 1 Clean out 4 400 4 PDC HDBS/FXG65S 10.625 6578 11720 5142 111.37 1.350 73.0 15 140 4525 804 0-0-NO-A-X-IER-TD Intermediate 1 5 500 5 Baker Hughes/ GT-C1 8.500 11720 11740 20 0.35 0.920 57.0 17 60 2450 600 2-3-WT-AR-E-2-ER-BHA Intermediate 2 Clean Out 6 600 6 HDBS /SFE46D 8.500 11740 15726 3986 56.76 1.107 70.0 22 180 3834 750 1-1-BT-S-X-I-ER-TD Intermediate 2 7 700 7 Baker Hughes/RC216 6.125 15726 15726 0 13.74 0.920 -25 100 840 240 2-1-WT-A-E-I-ER-BHA Production Clean Out 8 800 8 HDBS / MM64 6.125 15726 22208 6482 82.36 0.389 79.0 20 100 4392 230 3-4-BT-A-X-I-ER-TD Production Section WELL NAME:ODSN-22 LOCATION:Oooguruk OPERATOR:Caelus Energy Alaska AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902261396 TD:23-May-2015 Baroid STATE:Alaska RIG:Nabors 19AC SPUD:4-Apr-2015 B i t R e c o r d . . * 24 hr Recap: (current) % Chlorides cP ml/30min - Ss Logging Engineers: Background Mud Loss (24hrs): 0 bbls 00 (max) 0 0 10,000 Units 0 (lb/100ft2)Mud Type Weight Min 0 - N/A Comments mg/l PhAPI FL N/A Avg N/AECD (ppg) Cor Solids 100% Gas In Air 0 = YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Nabors 19AC Report For:12:00 AM Oooguruk R. Klepzig, J. Petitjean N/AMWD Summary 0 Gallons/stroke @ N/A Density (ppg) Morning Report Report # 1 Customer: Well: Area: Location: Rig: Caelus Energy Alaska berms, landings, beaver slide, skate, and the lines in the putz and hutz. Changed out IBOP and saver sub. Nippled up the surface 0 Connection Depth Type C-4i LstSiltst 0 and diverter line. Had to cut the saddles on top of the well bay to move the diverter line. Currently nippling up the surface bag to Moved the rig and the pit module from ODSN-03i to ODSN-22. Spotted and leveled the rig over ODSN-22. Rigged up 1750 ftlbs torque. Max Gas = 0 units, Avg Gas = 0 units Average Gvl 0 0 00 0 0 Gas Summary Chromatograph (ppm) Minimum - RPM -- Depth in / out WOB Condition Sh Footage Time: Tools N/A Current Pump & Flow Data: 0 N/A Max 96% 0.0 North Slope 0.0 AK-AM-0902261396 Nipple Up Surface Stack ODSN-22 Current 0.0 ROP Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max N/A Max @ ft Hours N/A - Size Mud Data Depth - in N/A - out (sec/qt) Grade (ppb Eq) - 0 - SPP (psi) 4.23 - Flow In (spm) MBT - C-5n 0 C-5i 0' 0' 0' Yesterday's Depth: Current Depth: 3-Apr-2015 24 Hour Progress: Date: (max) Trip N/A 0 0 0 Casing Summary Lithology (%) N/A Tuff 0 Cly ClystCht David Durst Maximum Report By:Martin Nnaji / David Durst 0 Size Silt C-1 (current) Set At 0 0 Units* 0 Unit Phone:907-670-6636 0 0 CementCoal C-3C-2 Bit Type C-4n . . * 24 hr Recap: Bit Type C-4n Unit Phone:907-670-6636 0 0 CementCoal C-3C-2 0 0 Units* 0 Size Silt C-1 (current) Set At David Durst Maximum Report By:Martin Nnaji / David Durst 0 Cly ClystCht Casing Summary Lithology (%) N/A Tuff 0 (max) Trip N/A 0 0 0 0' 158' 158' Yesterday's Depth: Current Depth: 4-Apr-2015 24 Hour Progress: Date: C-5n 0 C-5i 0 3.4 SPP (psi) 4.23 1.0 Flow In (spm) MBT 26 out (sec/qt) Grade (ppb Eq) 0.994 112 - Hours N/A 8.80 Size Mud Data Depth - in 158'Spud Mud Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max 163' Max @ ft North Slope 73.0 AK-AM-0902261396 Drilling Ahead ODSN-22 Current 0.0 ROP Time: Tools N/A Current Pump & Flow Data: 0 N/A Max 96% 104.4 Condition Sh - Footage 36557 RPM 9.9 - 37 Depth in / out --- WOB Gas Summary Chromatograph (ppm) Minimum Gvl 0 0 00 0 00 Rigged up Gyro tools. Calibrated the top drive's block height for MWD. Held a pre job safety meeting for spudding. Tested the Nipple up the diverter surface stack. Took on Spud mud into pits 1-5. Picked up 5" drill pipe using the mouse hole. standpipe to 3500 PSI. Picked up BHA and ran in the hole. Tagged ice at 67' MD. Drilled ahead from 67' MD to 158' MD @ 400 Max Gas = 0 units, Avg Gas = 0 units Average Depth Type C-4i LstSiltst - 0 Connection GPM, 30 RPM, 270 PSI, 1-2K Torque. Currently drilling ahead at 158' MD. Picked up 14 joints of 5" HWDP, 3rd party tools, Jars, and bit. Cut and slipped drilling line. Serviced top drive. Tested the diverter 1 Density (ppg) Morning Report Report # 2 Customer: Well: Area: Location: Rig: Caelus Energy Alaska Nabors 19AC Report For:12:00 AM Oooguruk R. Klepzig, J. Petitjean N/AMWD Summary 0 Gallons/stroke @ YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Cor Solids 100% Gas In Air 0 = mg/l pHAPI FL N/A Avg N/AECD (ppg) Min 0 2100 N/A Comments 0 (lb/100ft2)Mud Type 14.5 Weight 0 10,000 Units Logging Engineers: Background Mud Loss (24hrs): 0 bbls 00 (max) 0 % Chlorides cP ml/30min 8.80 Hughes MXL-1V Tricone Ss (current) . . * 24 hr Recap: (current) % Chlorides cP ml/30min 9.00 Hughes MXL-1V Tricone Ss Logging Engineers: Background Mud Loss (24hrs): 0 bbls 00 (max) 0 0 10,000 Units 0 (lb/100ft2)Mud Type 14.5 Weight Min 0 22000 N/A Comments mg/l pHAPI FL N/A Avg N/AECD (ppg) Cor Solids 100% Gas In Air 0 = YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Nabors 19AC Report For:12:00 AM Oooguruk R. Klepzig, J. Petitjean -MWD Summary 121 Gallons/stroke @ 1 Density (ppg) Morning Report Report # 3 Customer: Well: Area: Location: Rig: Caelus Energy Alaska connection. Pulled out of the hole and made up BHA number 1. Tripped back in the hole to 193' MD. Drilled ahead from 193' MD to - N/A Connection Depth Type C-4i LstSiltst 0 626' MD at 450 GPM, 450 PSI, 40 RPM, 2.5K Torque, 12-15K WOB. Drilled ahead from 626' MD to 1357' MD at 515 GPM, 750 PSI, Drilled ahead from 158' MD to 193' MD at 400 GPM, 260 PSI, 40 RPM, 1.5K Torque, 12-15K WOB. Gyro logged each 40 RPM, 4-5K Torque, 15-20 WOB. Quit using Gyro at 1006' MD. Serviced top drive. Currently drilling ahead at 1357' MD. Max Gas = 62 units, Avg Gas = 27 units Average Gvl 62 0 00 0 0 Gas Summary Chromatograph (ppm) Minimum 7.2 RPM 9.9 - 40 Depth in / out --- WOB Condition Sh - Footage 107.0 Time: Tools Directional, Gamma, Vibration Current Pump & Flow Data: 515 N/A Max 96% 292.7 North Slope 125.8 AK-AM-0902261396 Drilling Ahead ODSN-22 Current 157.0 ROP Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max 347' Max @ ft Hours 158' 9.00 Size Mud Data Depth - in 1195'Spud Mud out (sec/qt) H-40 Grade (ppb Eq) 0.994 90 - 1123 3.5 SPP (psi) 4.24 7.5 Flow In (spm) MBT 15 C-5n 0 C-5i 158' 1357' 1199' Yesterday's Depth: Current Depth: 5-Apr-2015 24 Hour Progress: Date: (max) Trip N/A 27 0 33 Casing Summary Lithology (%) N/A Tuff 0 Cly ClystCht Conductor David Durst Maximum Report By:Martin Nnaji / David Durst 8480 Size 158' Silt C-1 (current) 16.00'' Set At 2005 0 Units* 0 Unit Phone:907-670-6636 0 18 CementCoal C-3C-2 Bit Type C-4n . . * 24 hr Recap: (current)(max) 0 % Chlorides cP ml/30min 9.30 Hughes MXL-1V Tricone Ss Logging Engineers: Background Mud Loss (24hrs): 0 bbls 000 10,000 Units 0 (lb/100ft2)Mud Type 14.5 Weight Min 0 22500 26 Comments mg/l pHAPI FL N/A Avg N/AECD (ppg) Cor Solids 100% Gas In Air 0 = YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Nabors 19AC Report For:12:00 AM Oooguruk R. Klepzig, J. Petitjean 2620' MWD Summary 145 Gallons/stroke @ 1 Density (ppg) Morning Report Report # 4 Customer: Well: Area: Location: Rig: Caelus Energy Alaska 2145' MD to 2620' MD at 590 GPM, 1350 PSI, 40 RPM, 6K Torque, 18-21K WOB. Back reamed out of the hole from 2620' MD to - 112 Connection Depth Type C-4i LstSiltst 0 721' MD. Circulated 3 bottoms up while back reaming standing back 1 stand every bottoms up. Back reamed at 650 GPM, 150 PSI, Drilled ahead from 1357' MD to 2145' MD at 590 GPM, 1130 PSI, 40 RPM, 8K Torque, 20K WOB. Drilled ahead from 6-8K Torque. Currently back reaming at 721' MD. Max Gas = 37 units, Avg Gas = 17 units Average Gvl 37 0 00 0 0 Gas Summary Chromatograph (ppm) Minimum 8.0 RPM 9.8 - 36 Depth in / out --- WOB Condition Sh - Footage 107.0 Time: Tools Directional, Gamma, Vibration Current Pump & Flow Data: 615 N/A Max 96% 305.2 North Slope 131.6 AK-AM-0902261396 Back Reaming ODSN-22 Current 0.0 ROP Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max 2101' Max @ ft Hours 1357' 9.25 Size Mud Data Depth - in 2620'Spud Mud out (sec/qt) H-40 Grade (ppb Eq) 0.994 95 - 1134 5.3 SPP (psi) 4.24 7.5 Flow In (spm) MBT 21 C-5n 0 C-5i 1357' 2620' 1263' Yesterday's Depth: Current Depth: 6-Apr-2015 24 Hour Progress: Date: (max) Trip 1359' 17 3 22 Casing Summary Lithology (%) 1907' Tuff 0 Cly ClystCht Conductor David Durst Maximum Report By:Martin Nnaji / David Durst 5158 Size 158' Silt C-1 (current) 16.00'' Set At 2249 0 Units* 0 Unit Phone:907-670-6636 0 274 CementCoal C-3C-2 Bit Type C-4n . . * 24 hr Recap: Drilled ahead from 21346' 21700' MD. Changed out swab and liners on the mud pump #1. Drilled ahead to 21730' and 1117 Casing Summary circulated 2320 strokes, then drilled ahead to 21870' MD. Fluid Gain / Loss (24 Hrs): -16 bbls L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- 15726' - ---- 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 7 Baker Hughes / RC216 6.125 0.920 - 6 HDBS / SFE46D 8.5 1.107 - 11740' 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Drilled ahead from 20864' to 21346' MD at 230 gpm, 4200 psi, 18.6k torque, 100 rpm; serviced the top drive. Comments - C-4n Density (ppg) out (sec/qt) Viscosity 02910 387Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 4403 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Morning Report Report # 5 Customer: Well: Area: Location: Rig: ODSN-22 22-May-2015 Total Charges: Rig Activity: Cor Solids 10.68 Avg Min YPPV 10.41 Lime 10.83 Max Date: Time: - Drilling Ahead ECD (ppg) Flow In (gpm) Flow In (spm) SPP (psi) Current Pump & Flow Data: ENVIROMUL - Ratio Mud Data Depth 89.0 / 11.021762' cP Oil / Water 14 1-2-CT-C23-E-1-WT-BH ml/30min 6.73- (lb/100ft2) ConditionFootage 3.6 Mud (lb/bbl) 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 =10,000 Units7379Connection - C-4i Trip (max) 4006 123 1923 Average N/A 100% Gas In Air 1215 84368 340982 C-2 129 37 - C-5n Lst - Chromatograph (ppm) - 29167 Depth in / out Mud Type in Cement C-1 C-5i -100 - 0.994 1358 2462'14.5 158' 22.97 HoursTFA Weight - Ss Cht Silt - Size Current 85.0 ROP (ft/hr) Max @ ftAvg 101.0 MWD Summary Depth PWD / ABI / 4" Triple Combo 21585'68.0 % 3.55 @ 96% to20800' Tools 21973' 20861' 21985' 1124'24 Hour Progress: 66 Yesterday's Depth: Current Depth: RPM 394 101921 API FL L-80 232 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 21690' 31 390 21 Bit # 1 7.90 (current) Units* Lithology (%) Bit Type Depth 7.80 Gas Summary 3256 21934'Minimum 49 Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Siltst 6548' MD / 3221' TVD Clyst 60.0 7462 Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Maximum 11740' - 5150 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 - 11720' 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 . . * 24 hr Recap: Bit Type C-4n Unit Phone:(907)670-6636 0 329 CementCoal C-3C-2 1612 0 Units* 0 Size 158' Silt C-1 (current) 16.00'' Set At Conductor Ashley Wilderom Maximum Report By:Martin Nnaji / Ashley Wilderom 2858 Cly ClystCht Casing Summary Lithology (%) 4447' Tuff 0 (max) Trip 4444' 15 3 9 3650' 4998' 1348' Yesterday's Depth: Current Depth: 8-Apr-2015 24 Hour Progress: Date: C-5n 0 C-5i 2385 5.8 SPP (psi) 4.23 10.0 Flow In (spm) MBT 17 out (sec/qt) H-40 Grade (ppb Eq) 0.994 85 - Hours 3581' 9.30 Size Mud Data Depth - in 4907'Spud Mud Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max 4912' Max @ ft North Slope 56.0 AK-AM-0902261396 - - Drilling Ahead ODSN-22 Current 61.0 ROP Time: Tools Directional / Gamma / Vibration Current Pump & Flow Data: 857 N/A Max 96% 148.0 Condition Sh - Footage 107.0 6.4 RPM 9.6 - 43 Depth in / out --- WOB Gas Summary Chromatograph (ppm) Minimum Gvl 24 0 00 0 00 Serviced the top drive and currently drilling at 150 ft/hr. Drilled ahead from 3606' to 3777' MD. Circulated bottoms up at 670-700 GPM and changed out shaker screens Average Depth Type C-4i LstSiltst - N/A Connection for the increase to 850 GPM. Drilled ahead from 3777' to 4986' MD at 850 GPM, 2390 PSI, 8-9K Torque, 120 RPM, 18-20 WOB. 1 Density (ppg) Morning Report Report # 6 Customer: Well: Area: Location: Rig: Caelus Energy Alaska Nabors 19AC Report For:12:00 AM Oooguruk R. Klepzig, J. Petitjean 4930' MWD Summary 203 Gallons/stroke @ YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Cor Solids 100% Gas In Air 0 = mg/l pHAPI FL N/A Avg N/AECD (ppg) Min - 0 280 19 Comments 0 (lb/100ft2)Mud Type 14.5 Weight 10,000 Units Logging Engineers: Background Mud Loss (24hrs): 0 bbls 00 0 % Chlorides cP ml/30min 9.40 Hughes MXL-1V Tricone Ss (current)(max) 0 . . * 24 hr Recap: - - -2 Baker Hughes VM-1 14.5 0.994 - 2620' (current)(max) 24 % Chlorides cP ml/30min 9.50 Baker Hughes MXL-1V Ss Logging Engineers: Background Mud Loss (24hrs): 0 bbls 00 0 10,000 Units 4 (lb/100ft2)Mud Type 14.5 Weight - Min - 0 22000 37 Comments mg/l pHAPI FL N/A Avg N/A ECD (ppg) Cor Solids 100% Gas In Air 0 = YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Nabors 19AC Report For:12:00 AM Oooguruk R. Klepzig, J. Petitjean 6200' MWD Summary 201 Gallons/stroke @ 1 Density (ppg) Morning Report Report # 7 Customer: Well: Area: Location: Rig: Caelus Energy Alaska 850 GPM, 11K Torque, 18-20K WOB. Currently drilling to estimated surface TD of 6638' MD. - N/A Connection Depth Type C-4i LstSiltst 0 Drilled ahead from 4336' to 6142' MD. Serviced the top drive and continued drilling from 6142' to 6242' MD at Average Gvl 47 0 00 0 -- 0 Gas Summary Chromatograph (ppm) Minimum 6.0 RPM 9.7 2620' 35 Depth in / out 158' -2462' WOB Condition Sh - Footage 107.0 - - Time: Tools Directional / Gamma / Vibration Current Pump & Flow Data: 850 N/A Max 96% 127.0 North Slope 51.0 AK-AM-0902261396 - - Drilling Ahead ODSN-22 Current 91.0 ROP Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max 5955' Max @ ft Hours 4930' 9.45 Size Mud Data Depth - in 6130'Spud Mud out (sec/qt) H-40 Grade (ppb Eq) 0.994 60 - 2801 6.8 SPP (psi) 4.23 10.0 Flow In (spm) MBT 16 C-5n - 0 C-5i 4998' 6242' 1244' Yesterday's Depth: Current Depth: 9-Apr-2015 24 Hour Progress: Date: (max) Trip 5764' 20 5 17 Casing Summary Lithology (%) 5890' Tuff 4 Cly - Clyst - Cht - Conductor Ashley Wilderom Maximum Report By:Martin Nnaji / Ashley Wilderom 5312 Size 158' Silt C-1 (current) 16.00'' Set At 2073 32 Units* 0 Unit Phone:(907)670-6636 0 337 CementCoal - C-3C-2 - Bit Type --- C-4n . . * 24 hr Recap: Bit Type --- C-4n Unit Phone:(907)670-6636 23 596 CementCoal - C-3C-2 - 3623 72 Units* 6 Size 158' Silt C-1 (current) 16.00'' Set At Conductor Ashley Wilderom Maximum Report By:Kerry Garner / Ashley Wilderom 5599 Cly - Clyst - Cht - Casing Summary Lithology (%) 6391' Tuff 29 (max) Trip 6520' 29 5 19 6242' 6558' 316' Yesterday's Depth: Current Depth: 10-Apr-2015 24 Hour Progress: Date: C-5n - 0 C-5i 1306 9.0 SPP (psi) 4.23 10.0 Flow In (spm) MBT 15 out (sec/qt) H-40 Grade (ppb Eq) 0.994 60 - Hours 6200' 9.50 Size Mud Data Depth - in 6558'Spud Mud Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max 6523' Max @ ft North Slope 13.0 AK-AM-0902261396 - - TD Surface / BROOH ODSN-22 Current 0.0 ROP Time: Tools Directional / Gamma / Vibration Current Pump & Flow Data: 850 N/A Max 96% 92.0 Condition Sh - Footage 107.0 6558' 3938' 7.0 RPM 9.5 2620' 27 Depth in / out 158' -2462' WOB Gas Summary Chromatograph (ppm) Minimum Gvl 47 0 023 0 -- 05 continued back reaming from 2532' to 2057' MD. Circulated four bottoms up, racking back one stand per bottoms up from Drilled ahead from 6237' to 6558' MD. Back reamed from 6558' to 6237' MD and circulated three bottoms up. 2400' MD to 2100' MD. Tripped out of the hole from 2057' to 1758' MD and back reamed from 1758' to 253' MD. Average Depth Type C-4i LstSiltst - 136 Connection Performed a 700 barrel dilution and continued to back ream from 6237' to 2532' MD. Broke out the ghost reamer and 1 Density (ppg) Morning Report Report # 8 Customer: Well: Area: Location: Rig: Caelus Energy Alaska Nabors 19AC Report For:12:00 AM Oooguruk R. Klepzig & J. Petitjean 6515' MWD Summary 201 Gallons/stroke @ YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Cor Solids 100% Gas In Air 0 = mg/l pHAPI FL N/A Avg N/A ECD (ppg) Min - 53 19000 38 Comments 13 (lb/100ft2)Mud Type 14.5 Weight - 10,000 Units Logging Engineers: Background Mud Loss (24hrs): 0 bbls 810 15 % Chlorides cP ml/30min 9.60 Baker Hughes MXL-1V Ss (current)(max) 37 ---2 Baker Hughes VM-1 14.5 0.994 - 2620' . . * 24 hr Recap: - - -2 Baker Hughes VM-1 14.5 0.994 - 2620' (current)(max) 0 % Chlorides cP ml/30min 9.50 Baker Hughes MXL-1V Ss Logging Engineers: Background Mud Loss (24 hrs): 38 bbls / Trip In with Casing 00 0 10,000 Units 0 (lb/100ft2)Mud Type 14.5 Weight - Min - 0 19000 N/A Comments mg/l pHAPI FL N/A Avg N/A ECD (ppg) Cor Solids 100% Gas In Air 0 = YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Nabors 19AC Report For:12:00 AM Oooguruk R. Klepzig & J. Petitjean 6558' MWD Summary - Gallons/stroke @ 1 Density (ppg) Morning Report Report # 9 Customer: Well: Area: Location: Rig: Caelus Energy Alaska to 2765' MD - filling on every joint. Rigged up Tesco casing equipment and calibrated torque equipment. Picked up shoe joint and second joint. Laid down second - 7 Connection Depth Type C-4i LstSiltst 0 joint and picked up a replacement. Re-rigged Tesco casing spiders and ran in the hole to 168' MD. Checked floats and ran in the Laid down BHA from 253' to 0' MD. Laid down third party tools and picked up the casing running equipment. hole from 168' to 1549' MD. Hit a tight spot - pumped and rotated down casing from 1549' to 2031' MD. Ran casing from 2031' Average Gvl 7 0 00 0 -- 0 Gas Summary Chromatograph (ppm) Minimum 7.6 RPM 9.2 2620' 25 Depth in / out 158' -2462' WOB Condition Sh - Footage 107.0 - 6558' 3938' Time: Tools Directional / Gamma / Vibration Current Pump & Flow Data: - N/A Max 96% - North Slope - AK-AM-0902261396 - - TIH w/ 11.75" Casing ODSN-22 Current - ROP Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max - Max @ ft Hours 6515' 9.30 Size Mud Data Depth - in 6558'Spud Mud out (sec/qt) H-40 60.0 Grade L-80 (ppb Eq) 0.994 48 - - 6.0 SPP (psi) 4.23 10.0 Flow In (spm) MBT 14 C-5n - 0 C-5i 6558' 6558' 0' Yesterday's Depth: Current Depth: 11-Apr-2015 24 Hour Progress: Date: (max) Trip - 2 0 2 Casing Summary Lithology (%) - Tuff 0 Surface Cly - Clyst - Cht - 6548' Conductor Ashley Wilderom Maximum Report By:Kerry Garner / Ashley Wilderom 758 11.75'' Size 158' Silt C-1 (current) 16.00'' Set At 315 0 Units* 0 Unit Phone:(907)670-6636 0 0 CementCoal - C-3C-2 - Bit Type --- C-4n . . * 24 hr Recap: - - -2 Baker Hughes VM-1 14.5 0.994 - 2620' (current)(max) 6 % Chlorides cP ml/30min 9.50 Baker Hughes MXL-1V Ss Logging Engineers: Background Mud Loss (24 hrs): -269 bbls 00 0 10,000 Units 0 (lb/100ft2)Mud Type 14.5 Weight - Min - 15 19500 N/A Comments mg/l pHAPI FL N/A Avg N/A ECD (ppg) Cor Solids 100% Gas In Air 0 = YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Nabors 19AC Report For:12:00 AM Oooguruk R. Klepzig & J. Petitjean 6558' MWD Summary - Gallons/stroke @ 1 Density (ppg) Morning Report Report # 10 Customer: Well: Area: Location: Rig: Caelus Energy Alaska 5276' MD. Finished running casing from 6509' to 6548' MD. Picked up landing joint and hanger. Circulated one bottoms up - N/A Connection Depth Type C-4i LstSiltst 0 after reaching 8 barrels a minute. Ran in with 11.75" casing from 2765' to 6509' MD filling every joint. Worked through tight spots at 4285' and Average Gvl 80 0 07 0 -- 0 Gas Summary Chromatograph (ppm) Minimum 7.6 RPM 9.0 2620' 20 Depth in / out 158' -2462' WOB Condition Sh - Footage 107.0 - 6558' 3938' Time: Tools Directional / Gamma / Vibration Current Pump & Flow Data: - N/A Max 96% - North Slope - AK-AM-0902261396 - - TIH w/ 11.75" Casing ODSN-22 Current - ROP Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max - Max @ ft Hours 6515' 9.50 Size Mud Data Depth - in 6558'Spud Mud out (sec/qt) H-40 60.0 Grade L-80 (ppb Eq) 0.994 43 - - 7.5 SPP (psi) 4.23 12.5 Flow In (spm) MBT 13 C-5n - 0 C-5i 6558' 6558' 0' Yesterday's Depth: Current Depth: 12-Apr-2015 24 Hour Progress: Date: (max) Trip - 9 2 2 Casing Summary Lithology (%) - Tuff 8 Surface Cly - Clyst - Cht - 6548' Conductor Ashley Wilderom Maximum Report By:Kerry Garner / Ashley Wilderom 9389 11.75'' Size 158' Silt C-1 (current) 16.00'' Set At 1010 40 Units* 0 Unit Phone:(907)670-6636 8 261 CementCoal - C-3C-2 - Bit Type --- C-4n . . * 24 hr Recap: Bit Type --- C-4n Unit Phone:(907)670-6636 0 0 CementCoal - C-3C-2 - 482 19 Units* 0 Size 158' Silt C-1 (current) 16.00'' Set At Conductor Ashley Wilderom Maximum Report By:Kerry Garner / Ashley Wilderom 4511 11.75''Surface Cly - Clyst - Cht - 6548' Casing Summary Lithology (%) - Tuff 7 (max) Trip - 4 0 1 6558' 6558' 0' Yesterday's Depth: Current Depth: 13-Apr-2015 24 Hour Progress: Date: C-5n - 0 C-5i - 8.5 SPP (psi) 4.23 12.5 Flow In (spm) MBT 15 out (sec/qt) H-40 60.0 Grade L-80 (ppb Eq) 0.994 50 - Hours N/A 9.65 Size Mud Data Depth - in 6558'Spud Mud Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max - Max @ ft North Slope - Alaska - AK-AM-0902261396 - - Nipple down surface stack ODSN-22 Current - ROP Time: Tools Directional / Gamma / Vibration Current Pump & Flow Data: - N/A Max 96% - Condition Sh 16.0 Footage 107.0 - 6558' 3938' 7.6 RPM 9.3 2620' 19 Depth in / out 158' 392462' WOB Gas Summary Chromatograph (ppm) Minimum Gvl 41 0 06 0 -- 00 plug. Monitored the well for 30 minutes and flushed the stack. Rigged down Tesco equipment and rigged up the cementing equipment. Pumped spacer and all cement Average Depth Type C-4i LstSiltst - N/A Connection per cement pump schedule. Displaced cement with rig pumps using the spud mud. Pumped 7075 strokes without bumping the 1 Density (ppg) Morning Report Report # 11 Customer: Well: Area: Location: Rig: Caelus Energy Alaska Nabors 19AC Report For:12:00 AM Oooguruk Island R. Klepzig & J. Petitjean N/AMWD Summary - Gallons/stroke @ YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Cor Solids 100% Gas In Air 0 = mg/l pHAPI FL N/A Avg N/A ECD (ppg) Min - 12 19500 N/A Comments 0 (lb/100ft2)Mud Type 14.5 Weight - 10,000 Units Logging Engineers: Background Mud Loss (24 hrs): -89 bbls / Cement Job 00 0 % Chlorides cP ml/30min 9.65 Baker Hughes MXL-1V Ss (current)(max) 0 19.0 119 -2 Baker Hughes VM-1 14.5 0.994 - 2620' . . * 24 hr Recap: - - -- 0-1-CT-C1-E-I-NO-BHA3Baker Hughes GT-C1 10.625 0.942 - 6558' 19.0 119 -2 Baker Hughes VM-1 14.5 0.994 - 2620' (current)(max) 0 % Chlorides cP ml/30min 9.60 Baker Hughes MXL-1V Ss Logging Engineers: Background Mud Loss (24 hrs): 0 bbls 00 0 10,000 Units 0 (lb/100ft2)Mud Type 14.5 Weight - Min - 0 19500 N/A Comments mg/l pHAPI FL N/A Avg N/A ECD (ppg) Cor Solids 100% Gas In Air 0 = YP Depth Viscosity Avg ROP (ft/hr) PV Flow In (gpm) Nabors 19AC Report For:12:00 AM Oooguruk Island R. Klepzig & J. Petitjean N/AMWD Summary - Gallons/stroke @ 1 Density (ppg) Morning Report Report # 12 Customer: Well: Area: Location: Rig: Caelus Energy Alaska BOP test. Laid down testing equipment and blew down lines. Picked up BHA and installed the elevators. Ran in BHA from surface - N/A Connection Depth Type C-4i LstSiltst 0 to 626' MD. Picked up 5" drill pipe and singled in from 626' to 5950' MD, while filling pipe ever 45 joints. Serviced the top drive and Nippled up BOP and tested the lower connection to 2700 psi. Picked up testing equipment and performed a full tripped in the hole from 5950' to 6330' MD. Average Gvl 0 0 00 0 -- 0 Gas Summary Chromatograph (ppm) Minimum 8.0 RPM 9.0 2620' 19 Depth in / out 158' 392462' WOB Condition Sh 16.0 Footage 107.0 - 6558' 3938' Time: Tools Directional / Gamma / Vibration Current Pump & Flow Data: - N/A Max 96% - North Slope - Alaska - AK-AM-0902261396 - - TIH for cleanout run ODSN-22 Current - ROP Bit #TFA Job No.: Daily Charges: Rig Activity: Total Charges: 24 hr Max - Max @ ft Hours N/A 9.60 Size Mud Data Depth - in 6558'Spud Mud out (sec/qt) H-40 60.0 Grade L-80 (ppb Eq) 0.994 47 - - 8.4 SPP (psi) 4.23 12.5 Flow In (spm) MBT 15 C-5n - 0 C-5i 6558' 6558' 0' Yesterday's Depth: Current Depth: 14-Apr-2015 24 Hour Progress: Date: (max) Trip - 0 0 0 Casing Summary Lithology (%) - Tuff 0 Surface Cly - Clyst - Cht - 6548' Conductor Ashley Wilderom Maximum Report By:Kerry Garner / Ashley Wilderom 0 11.75'' Size 158' Silt C-1 (current) 16.00'' Set At 0 0 Units* 0 Unit Phone:(907)670-6636 0 0 CementCoal - C-3C-2 - Bit Type --- C-4n . . * 24 hr Recap: 6558' 3938' 19.0 119 - Report By:Unit Phone:(907)670-6636Ashley Wilderom - - - - 0-1-CT-C1-E-I-NO-BHA 2 Baker Hughes VM-1 14.5 0.994 - 3 Baker Hughes GT-C1 10.625 0.942 - 6558' Circulated one bottoms up at 6330' MD, blew down top drive, cut / slipped drilling line. Tripped in the hole and tagged Density (ppg) out (sec/qt) Viscosity - ROP ROP (ft/hr) R. Klepzig & C.A. Demoski 24 hr Max Morning Report Report # 13 Customer: Well: Area: Location: Rig: ODSN-22 15-Apr-2015 12:00 AM AK-AM-0902261396Caelus Energy Alaska Oooguruk Island North Slope - Alaska Job No.: Daily Charges: Total Charges: Rig Activity: - - Cor Solids - Avg Min YP MaxECD (ppg) Tools - 3.55 @ Current Pump & Flow Data: Nabors 19AC Report For: 6578'10.7 -MWD Summary 96% %Mud Type ENVIROMUL - Ratio Mud Data Depth 86.4 / 13.6 Size 158'-Conductor 10.00 2620' WOB Baker Hughes MXL-1V TFA Condition 1 14.5 158' -- 2620' to 538' MD. Changed out jars and laid down BHA. Circulated two bottoms up to shoe. Performed formation integrity test to 12.5 ppg EMW. Pumped dry job and tripped out of the hole MOBM while reaming down from 6425' MD to 6520' MD. Drilled out shoe track, cement and 20' of new hole to 6578' MD. 6548' 100% Gas In Air=10,000 UnitsN/AConnection - Comments - 11Background Trip (max) 0Average 16 Mud (lb/bbl)ml/30min 7.25- 16.0 (lb/100ft2) 10.00 Type 19 C-3 Bit # 0 Lst - - - 00 C-4i C-4n Chromatograph (ppm) 0 4 0 Cement C-1 C-5i - ShSiltst - - - Picking up BHA PV cP 60.0 Weight Flow In (gpm) Flow In (spm) Oil / Water Casing Summary Lithology (%) 0.994 30108 2462' Footage (current) Units* Clyst - - Ss Cht Silt - API FL Depth N/A Avg to N/A Current -- 24 Hour Progress: - SPP (psi) Max @ ft - Date: Time: 0 6558' 6578' 20' Lime TuffGvl C-5n Yesterday's Depth: Current Depth: - Alkal Coal - Gallons/stroke L-80 Mud Loss (24 Hours): -13 bbls up at 6363' MD; pulled out of the hole to 6330' MD. Tested 11.75" casing to 3500 PSI for 30 minutes. Displaced well to 10 ppg 11 - 0 5 0 -Minimum Depth 11.75'' Maximum in 0 0 1185 0 0 0 0 1616 0 - 0 C-2 - Gas Summary 16 0 Set AtSize 107.0 H-40 Grade Depth in / outBit Type RPM 39 Hours 16.00'' Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Cly . . * 24 hr Recap: Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Cly Set AtSize 107.0 H-40 Grade 16.00'' - 624 C-2 - Gas Summary 46 0 0 0 0 4623 0 0 3299 6709'Minimum Depth 11.75'' Maximum in 5 6963' 0 0 0 Mud Loss (24 Hours): 0 bbls pulse tested the MWD tools. Picked up BHA to 648' MD and filled pipe. Tripped in the hole and broke in Geo-Pilot. 30 745 Alkal Coal - Gallons/stroke L-80 6558' 6966' 408' Lime TuffGvl Yesterday's Depth: Current Depth: RPM 39 24 Hour Progress: 210 SPP (psi) Max @ ft Date: Time: - API FL Depth 6936' Avg to6558' Current 16.0 - (current) Units* Clyst - - Ss Cht Silt - Casing Summary Lithology (%) 0.994 2898 2462' Footage Depth in / outBit Type Hours - - Drilling Ahead PV cP 60.0 Weight Flow In (gpm) Flow In (spm) Oil / Water 0 Cement C-1 C-5i - ShSiltst 100 0 Chromatograph (ppm) 26 0 C-5n 0 Bit # 0 Lst - - - 10.00 Type 20 C-3 C-4i Mud (lb/bbl)ml/30min 6.73- 16.0 (lb/100ft2) Average N/ATrip (max) 16 Tripped in the hole to 6578' MD installed Cuttings Bed Impeller every three stands. Drill ahead from 6578' to 6709' 6548' 100% Gas In Air=10,000 Units39Connection - Drill ahead from 6700' MD to 6966' MD at 750 GPM. MD at 700 GPM. Took directional survey, dropped tags and opened reamer, and pulled against shoe to verify it opened. 1 14.5 158' -- 2620' Size 158'-Conductor 10.00 2620' WOB Baker Hughes MXL-1V TFA Condition MWD Summary 96% %Mud Type ENVIROMUL - Ratio Mud Data Depth 86.40 / 13.60 3.55 @ Current Pump & Flow Data: Nabors 19AC Report For: 6966'10.7 - - Cor Solids - Avg Min YP MaxECD (ppg) Tools Full Service / PWD / 7600 Geo-Pilot Caelus Energy Alaska Oooguruk Island North Slope - Alaska Job No.: Daily Charges: Total Charges: Rig Activity: 74.0 Morning Report Report # 14 Customer: Well: Area: Location: Rig: ODSN-22 16-Apr-2015 12:00 AM AK-AM-0902261396 3210 ROP R. Klepzig & C.A. Demoski 24 hr Max ROP (ft/hr) 27Background 00 C-4n Density (ppg) out (sec/qt) Viscosity Baker Hughes GT-C1 10.625 0.942 - 6558' Picked up BHA to 112' MD, uploaded MWD tools. Picked up BHA, broke in reamer and shallow Comments - --- 0-1-CT-C1-E-I-NO-BHA 2 Baker Hughes VM-1 14.5 0.994 - 3 6558' 3938' 19.0 119 - Report By:Unit Phone:(907)670-6636Ashley Wilderom - . . * 24 hr Recap: 6558' 3938' 19.0 119 - Report By:Unit Phone:(907)670-6636Ashley Wilderom - - - - 0-1-CT-C1-E-I-NO-BHA 2 Baker Hughes VM-1 14.5 0.994 - 3 Baker Hughes GT-C1 10.625 0.942 - 6558' Drilled ahead from 6948' to 7063' MD; serviced the top drive. Drilled ahead from 7063' to 8118' MD at 800 GPM. Comments - Density (ppg) out (sec/qt) Viscosity 023 C-4n 54Background Rig: ODSN-22 17-Apr-2015 12:00 AM AK-AM-0902261396 3637 ROP R. Klepzig & C.A. Demoski 24 hr Max Total Charges: Rig Activity: 72.0 Morning Report Report # 15 Customer: Well: Area: Location: YP MaxECD (ppg) Tools Full Service / PWD / 7600 Geo-Pilot Caelus Energy Alaska Oooguruk Island North Slope - Alaska Job No.: Daily Charges: 10.36 10.76 Cor Solids 10.65 Avg Min Depth 85.7 / 14.3 3.55 @ Current Pump & Flow Data: Nabors 19AC Report For: 7928'11.0 TFA Condition MWD Summary 96% %Mud Type ENVIROMUL - Ratio Mud Data -- 2620' Size 158'-Conductor 2620' WOB Baker Hughes MXL-1V 6548' 100% Gas In Air=10,000 Units74Connection - Trip (max) 170Average N/A Mud (lb/bbl)ml/30min 6.60- 16.0 (lb/100ft2) C-3 C-4i 0 Lst - - - Chromatograph (ppm) 183 67 C-5n 0 0 Cement C-1 C-5i - ShSiltst 100 0 - - Drilling Ahead PV cP 60.0 Weight Flow In (gpm) Flow In (spm) Oil / Water 98 2462' Footage Depth in / outBit Type Hours 10.00 20 14.5 158' - - Ss Cht Silt - 80.0 (current) Units* Clyst Casing Summary Lithology (%) 0.994 35 Depth 8160' Avg to6936' Current 51.8 ROP (ft/hr) 39 24 Hour Progress: 224 SPP (psi) Max @ ft Date: Time: 8160' API FL L-80 6966' 8190' 1224' Lime TuffGvl Yesterday's Depth: Current Depth: RPM 795 Alkal Coal - Gallons/stroke Mud Loss (24 Hours): 0 bbls Serviced and inspected the top drive. Drilled ahead from 8118' to 8190' MD. 61 8024' 0 22 0 Depth 11.75'' Maximum in 22 Bit # 1 10.00 0 5965 11 12 0 70 7596 9 C-2 - Gas Summary 84 7125'Minimum Set AtSize 107.0 H-40 Grade 16.00'' Type Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Cly - 1803 . . * 24 hr Recap: 6558' 3938' 19.0 119 - Report By:Unit Phone:(907)670-6636Ashley Wilderom - - - - 0-1-CT-C1-E-I-NO-BHA 2 Baker Hughes VM-1 14.5 0.994 - 3 Baker Hughes GT-C1 10.625 0.942 - 6558' Drilled ahead from 8184' to 8694' MD at 800 gpm, 3750 psi, 140 rpm, 12.2k torque. Serviced and inspected the Comments - Density (ppg) out (sec/qt) Viscosity 066 C-4n 82Background AK-AM-0902261396 6962 ROP R. Klepzig & C.A. Demoski 24 hr Max Morning Report Report # 16 Customer: Well: Area: Location: Rig: ODSN-22 18-Apr-2015 12:00 AM Caelus Energy Alaska Oooguruk Island North Slope - Alaska Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids 10.60 Avg Min YP MaxECD (ppg) Tools Full Service / PWD / 7600 Geo-Pilot 3.55 @ Current Pump & Flow Data: Nabors 19AC Report For: 9223'11.0 10.35 10.70MWD Summary 96% %Mud Type ENVIROMUL - Ratio Mud Data Depth 75.5/12.0 -- 2620' Size 158'-Conductor 2620' WOB Baker Hughes MXL-1V 12.5k torque. drive; cleaned suction screens on both pumps. Drilled ahead from 9369' to 9418' MD at 800 gpm, 3950 psi, 140 rpm, 6548' 100% Gas In Air=10,000 Units96Connection - Trip (max) 463Average N/A ml/30min 5.96- 16.0 (lb/100ft2) 39 Condition C-3 C-4i 0 Lst - - - Chromatograph (ppm) 781 434 C-5n 20 20 Cement C-1 C-5i - ShSiltst 100 0 14.5 158' - - Drilling Ahead PV cP Flow In (gpm) Flow In (spm) Oil / Water Footage Depth in / outBit Type Hours 10.00 20 TFA 0.994 34 - - Ss Cht Silt - 98 2462' (current) Units* Clyst Casing Summary Lithology (%) 60.0 Weight 9406' Avg to8160' Current 52.0 ROP (ft/hr) Max @ ft Date: Time: 8522' Depth 95.072.0 L-80 8190' 9436' 1246' Lime 24 Hour Progress: 226 SPP (psi) Mud (lb/bbl) Gvl Yesterday's Depth: Current Depth: RPM 60 8965 API FL 801 Alkal Coal - Gallons/stroke Tuff Mud Loss (24 Hours): 0 bbls top drive. Drilled ahead from 8694' to 9369' MD at 800 gpm, 3900 psi, 140 rpm, 12.2k torque. Serviced and inspected the top 87 9381' 0 125 24 Depth 11.75'' Maximum in 20 Bit # 1 10.05 28 51 8 242 14664 112 C-2 - Gas Summary 144 8153'Minimum Set AtSize 107.0 H-40 Grade 16.00'' Type Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Cly - 2152 . . * 24 hr Recap: Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Cly - 1155 Set AtSize 107.0 H-40 Grade 16.00'' Type C-2 - Gas Summary 199 10370'Minimum 40 77 7 343 18671 63 Depth 11.75'' Maximum in 16 Bit # 1 10.05 9720' 0 181 36 Mud Loss (24 Hours): 0 bbls top drive. Drilled ahead from 9847' to 10329' MD to 800 gpm, 4180psi, 14.9k Torque, 141 rpm. Finished Trouble shooting Geo-Pilot 93 800 Alkal Coal - Gallons/stroke TuffGvl Yesterday's Depth: Current Depth: RPM 39 8867 API FL L-80 9436' 10581' 1145' Lime 24 Hour Progress: 225 SPP (psi) Mud (lb/bbl) Date: Time: 10245' Depth 80.076.0 to9406' Current 47.0 ROP (ft/hr) Max @ ft (current) Units* Clyst Casing Summary Lithology (%) 60.0 Weight 0.994 35 - - Ss Cht Silt - 92 2462' Footage Depth in / outBit Type Hours 10.00 21 TFA 14.5 158' - - Drilling Ahead PV cP Flow In (gpm) Flow In (spm) Oil / Water 23 Cement C-1 C-5i - ShSiltst 100 7 Chromatograph (ppm) 1137 593 C-5n 35 Lst - - - Condition C-3 C-4i Average N/ATrip (max) 626 and drilled ahead from 10329' to 10581' MD at 800 gpm, 4200 psi, 15k Torque, and 140 rpm. 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units157Connection - 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 Ratio Mud Data Depth 86.3 / 13.7 -- ml/30min 5.18- (lb/100ft2) 10334'11.0 10.38 10.73MWD Summary %Mud Type ENVIROMUL - Tools Full Service / PWD / 7600 Geo-Pilot 3.55 @ Current Pump & Flow Data: Nabors 19AC Report For: 96% 10551' Avg Daily Charges: Total Charges: Rig Activity: Cor Solids 10.63 Avg Min YP MaxECD (ppg) Morning Report Report # 17 Customer: Well: Area: Location: Rig: ODSN-22 19-Apr-2015 12:00 AM AK-AM-0902261396 4255 ROP R. Klepzig & C.A. Demoski 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Job No.: 84Background 998 C-4n 19 Density (ppg) out (sec/qt) Viscosity Baker Hughes GT-C1 10.625 0.942 - 6558' Drilled ahead from 9418' to 9847' MD at 800 gpm, 4000 psi, 14.5k Torque, 142 rpm. Serviced and inspected the Comments - --- 0-1-CT-C1-E-I-NO-BHA 2 Baker Hughes VM-1 14.5 0.994 - 3 6558' 3938' 19.0 119 - Report By:Unit Phone:(907)670-6636Ashley Wilderom - . . * 24 hr Recap: 6558' 3938' 19.0 119 - Report By:Unit Phone:(907)670-6636Ashley Wilderom - - - - 0-1-CT-C1-E-I-NO-BHA 2 Baker Hughes VM-1 14.5 0.994 - 3 Baker Hughes GT-C1 10.625 0.942 - 6558' Drill ahead from 10560' to 10906' MD at 800 gpm, 4250 psi, 16.6k Torque, 140 rpm. Serviced top drive and replaced Comments - Density (ppg) out (sec/qt) Viscosity 028 C-4n 0 72Background 4521 ROP R. Klepzig & C.A. Demoski 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Job No.: Morning Report Report # 18 Customer: Well: Area: Location: Rig: ODSN-22 20-Apr-2015 12:00 AM AK-AM-0902261396 Daily Charges: Total Charges: Rig Activity: Cor Solids 10.70 Avg Min YP MaxECD (ppg)Full Service / PWD / 7600 Geo-Pilot 3.55 @ Current Pump & Flow Data: Nabors 19AC Report For: 96% 11610' Avg 11435'11.6 10.47 10.84MWD Summary %Mud Type ENVIROMUL - Ratio Mud Data Depth 36.0 -- ml/30min 4.92- (lb/100ft2) 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 drive and greased blocks. 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units89Connection - Trip (max) 312Average N/A Condition C-3 C-4i Lst - - - Chromatograph (ppm) 468 179 C-5n 0 21 Cement C-1 C-5i - ShSiltst 100 0 14.5 158' - - Drilling Ahead PV cP Flow In (gpm) Flow In (spm) Oil / Water Footage Depth in / outBit Type Hours 10.00 19 TFA 0.994 36 - - Ss Cht Silt - 91 2462' (current) Units* Clyst Casing Summary Lithology (%) 60.0 Weight to10551' Current 45.0 ROP (ft/hr) Max @ ft Tools Date: Time: 11443' Depth 85.053.0 L-80 10581' 11670' 1089' Lime 24 Hour Progress: 223 SPP (psi) Mud (lb/bbl) Gvl Yesterday's Depth: Current Depth: RPM 55 7128 API FL 799 Alkal Coal - Gallons/stroke Tuff Mud Loss (24 Hours): 0 bbls hydraulic line. Drill ahead from 10906' to 11670' MD at 800 gpm, 4430 psi, 16.3k to 17.1k Torque, 140 rpm. Serviced the top 75 11575' 0 38 5 Depth 11.75'' Maximum in 14 Bit # 1 10.00 12 18 7 121 9157 93 C-2 - Gas Summary 109 11093'Minimum Set AtSize 107.0 H-40 Grade 16.00'' Type Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Cly - 1200 . . * 24 hr Recap: 139 - - 4 HDBS FXG65S 10.625 1.353 70.76 6578' 11720' 5142' 12.0 Casing Summary 9.625"-Intermediate 1 -- Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Cly - 2661 Set AtSize 107.0 H-40 Grade 16.00'' Type - Gas Summary 87 11704'Minimum 9 149 8330 173 C-2Depth 11.75'' Maximum in 28 Bit # 1 10.00 11671' 5 41 0 Mud Loss (24 Hours): -15 bbls / TOOH annular. Picked up 30' and rotated at 10 rpm to verify that the reamer closed. Started quadrant reaming from 11720' to 11670' MD 83 808 Alkal Coal - Gallons/stroke TuffG vl Yesterday's Depth: Current Depth: RPM 85 7166 API FL L-80 11670' 11720' 50' Lime 24 Hour Progress: 211 SPP (psi) Mud (lb/bbl) Date: Time: 11693' Depth 61.00.0 to11610' Current 48.0 ROP (ft/hr) Max @ ft Tools (current) Units* Clyst Lithology (%) 60.0 Weight - - Ss Cht Silt - Bit Type Hours 10.00 19 TFA 0.994 35101 2462'14.5 158' - - TD Intermediate 1 / TOOH PV cP Flow In (gpm) Flow In (spm) Oil / Water 26 Cement C-1 C-5i - ShSiltst 100 0 Chromatograph (ppm) 460 184 C-5n 519 Lst - - - C-3 C-4i 16Average 50Trip (max) 343 at 750 gpm. Began 500 barrel new mud dilution on second bottoms up. Circulated four bottoms up, racked back a stand and 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units81Connection - 6750' MD. Worked BHA through the shoe with no rpm to 6385' MD. Started staging up pumps for a bottoms up circulation. backreamed from 11670' to 11575' MD. Serviced and inspected the top drive. Lubed out of the hole at 2 bpm from 11575' to 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39-1-2-CT-C23-E-1-WT-BH ml/30min 4.92- (lb/100ft2) ConditionFootage Depth in / out Mud Type ENVIROMUL - Ratio Mud Data Depth 86.3 / 13.7 11720' Avg 11720'11.0 4.97 10.82MWD Summary % 3.55 @ Current Pump & Flow Data: Nabors 19AC Report For: 96% Total Charges: Rig Activity: Cor Solids 10.61 Avg Min YP MaxECD (ppg)Full Service / PWD / 7600 Geo-Pilot Morning Report Report # 19 Customer: Well: Area: Location: Rig: ODSN-22 21-Apr-2015 12:00 AM AK-AM-0902261396 4021 ROP R. Klepzig & C.A. Demoski 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Job No.: Daily Charges: 17Background 1552 C-4n 0 Density (ppg) out (sec/qt) Viscosity Baker Hughes GT-C1 10.625 0.942 - 6558' Drilled ahead from 11670' to 11720' MD. Pumped down closing tab on reamer and function tested rams and Comments - 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA 2 Baker Hughes VM-1 14.5 0.994 - 3 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907)670-6636Ashley Wilderom 6578' . . * 24 hr Recap: 139 - - 4 HDBS FXG65S 10.625 1.353 70.76 6578' 11720' 5142' 12.0 Casing Summary 9.625"-Intermediate 1 -- Set AtSize Logging Engineers:Kerry Garner / David Durst (max)(current) Surface Cly - 0 Depth Maximum 107.0 H-40 Grade 16.00'' Type 11.75'' Clyst 60.0 153 60 Gas Summary 49 N/AMinimum 0 in 0 Bit # 1 10.05 (current) Units* Lithology (%) Bit Type N/A 0 15 0 Mud Loss (24hrs): -15 bbls 6385' MD to 3706' MD at 750 gpm, 3500 psi, 140 rpm. Circulate 2 bottoms up and back ream out from 3706' MD to 648' MD. Lay 15 0 Alkal Coal - Gallons/stroke Tuff - Gvl Yesterday's Depth: Current Depth: RPM 0 177 API FL L-80 11720' 11720' 0' Lime 24 Hour Progress: 0 SPP (psi) 11.00 Current Pump & Flow Data: Max Mud (lb/bbl) Date: Time: N/A 10.35 % 3.55 @ 0.0 to11720' Tools 11720' Current 0.0 ROP (ft/hr) Max @ ftAvg 0.0 Weight - - Ss Cht Silt - Chromatograph (ppm) 0.994 35120 2462'14.5 158' Flow In (gpm) Flow In (spm) Oil / Water MWD Summary Hours 10.00 18 TFA Depth Cement C-1 C-5i - ShSiltst - C-5n 08 0 0 Lst - - - 4552 C-2 C-4i 510 0 Average 53Trip (max) 19 down BHA to surface. Clean and clear rig floor. Trip in the hole with 18 joints of heavy weight drill pipe and flush. Trip out of the hole 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Max Gas = 49 units, Avg Gas = 15 units with 6 stands and rack back in derrick. Pick up test tools and test joint. Set test plug and change rams. Test BOPE. 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3922.97 1-2-CT-C23-E-1-WT-BH ml/30min 4.53- (lb/100ft2) ConditionFootage Depth in / out 11.5 Mud Type ENVIROMUL - Ratio Mud Data Depth 86.2/13.811720' PV cP 96% Total Charges: Rig Activity: Cor Solids 10.66 Avg Min YP Testing BOPE ECD (ppg)Full Service / PWD / 7600 Geo-Pilot Morning Report Report # 20 Customer: Well: Area: Location: Rig: ODSN-22 22-Apr-2015 ROP J. Polya, C.A. Demoski 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 0Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 060 Density (ppg) out (sec/qt) Viscosity 6558' Circulate using step rate method to achieve 750 gpm and circulate 1.5 bottoms up. Back reaming out of the hole from Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' . . * 24 hr Recap: 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Pull test plug and lay down test joint. Clean and clear rig floor. Rig up Tesco to run 9 5/8" liner. Hold pre-job and begin Comments - C-4n Density (ppg) out (sec/qt) Viscosity 000 8Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 623 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 ROP J. Polya, C.A. Demoski 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: ECD (ppg)- Morning Report Report # 21 Customer: Well: Area: Location: Rig: ODSN-22 23-Apr-2015 96% Total Charges: Rig Activity: Cor Solids - Avg Min YP Running 9 5/8" Liner ENVIROMUL - Ratio Mud Data Depth 86.3/13.711720' PV cP 1-2-CT-C23-E-1-WT-BH ml/30min 4.66- (lb/100ft2) ConditionFootage 11.0 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 Max Gas = 13 units, Avg Gas = 9 units 9 5/8" liner hanger from 5290' MD to 5325' MD. Run 9 5/8" liner on 5" drill pipe from 5325' MD to 5448' MD. Break circulation, fill pipe power tongs. Pick up and make up liner hanger. Rig down Tesco power tongs and send tools down beaverslide. Run in the hole with Circulate bottoms up using step rate method. Run liner from 4002' MD to 5290' MD. Rig down Tesco running tools and rig up Tesco 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Trip (max) 0Average C-4i 00 0 Lst - - - 17 C-2 C-5n 00 0 0 Cement C-1 C-5i - ShSiltst - Oil / Water MWD Summary Hours 10.00 17 TFA Depth Depth in / out Mud Type 0.994 37126 2462'14.5 158' 22.97 Weight - - Ss Cht Silt - Chromatograph (ppm) Current 0.0 ROP (ft/hr) Max @ ftAvg 0.00.0 to - Tools - Flow In (gpm) Flow In (spm) Mud (lb/bbl) Date: Time: N/A - % 3.55 @ 11720' 11720' 0' Lime 24 Hour Progress: 24 SPP (psi) - Current Pump & Flow Data: Max Yesterday's Depth: Current Depth: RPM 0 25 API FL L-80 86 Alkal Coal - Gallons/stroke Tuff - Gvl Mud Loss (24hrs): -20 bbls running liner. Run liner from surface to 2009' MD. Circulate bottoms up using step rate method. Run liner from 2009' MD to 4002' MD. 9 and pump 20 bbls. Break circulation and check all parameters. N/A 0 0 0 in 0 Bit # 1 10.10 (current) Units* Lithology (%) Bit Type 0 0 Gas Summary 13 N/AMinimum 0 Depth Maximum 107.0 H-40 Grade 16.00'' Type 11.75'' Clyst 60.0 Logging Engineers:Kerry Garner / David Durst (max)(current) Surface Cly - 0 5142' 12.0 Casing Summary 9.625"-Intermediate 1 -- Set AtSize 139 - - 4 HDBS FXG65S 10.625 1.353 70.76 6578' 11720' . . * 24 hr Recap: 139 - - 4 HDBS FXG65S 10.625 1.353 70.76 6578' 11720' 5142' 12.0 Casing Summary 9.625"-Intermediate 1 -- Set AtSize Logging Engineers:Kerry Garner / David Durst (max)(current) Surface Cly - 19 Maximum 107.0 H-40 Grade 16.00'' Type 11.75'' Clyst 60.0 571 202 Gas Summary 177 N/AMinimum 06 Bit # 1 10.00 (current) Units* Lithology (%) Bit Type Depth N/A 0 35 0 Mud Loss (24hrs): -80 bbls rig, check load cell on deadman. Run 9 5/8" liner on 5" drill pipe from 6491' MD to 7038' MD. Work through tight spot with 30 rpm and 23 step rate in 1/2 bbl increments. 85 Alkal Coal - Gallons/stroke Tuff - Gvl Yesterday's Depth: Current Depth: RPM 0 1858 API FL L-80 11720' 11720' 0' Lime 24 Hour Progress: 24 SPP (psi) - Current Pump & Flow Data: Max Date: Time: N/A - % 3.55 @ 0.0 to - Tools - Flow In (gpm) Flow In (spm) Current 0.0 ROP (ft/hr) Max @ ftAvg 0.0 Weight - - Ss Cht Silt - Chromatograph (ppm) 0.994 37130 2462'14.5 158' 22.97 MWD Summary Hours 10.05 19 TFA Depth Depth in / out Mud Type in Cement C-1 C-5i - ShSiltst - C-5n 017 0 0 Lst - - - 18411 C-2 C-4i 324 0 Average 16Trip (max) 56 pumping 2 bpm to 7441' MD. Run liner from 7441' MD to 11602' MD. Install cement head and lines. Run liner from 11602' MD to 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Max Gas = 177 units, Avg Gas = 23 units ball and pump down, seat at 1085 strokes. Verify set and pressure up to 4400 psi. Slack off and bleed off. Establish circulation using 11720' MD. Circulate using step rate in 1/2 bbl increment, packing off at 4.5 bpm. Decrease pump rates until losses stabilize. Drop 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 1-2-CT-C23-E-1-WT-BH ml/30min 4.66- (lb/100ft2) ConditionFootage 11.5 Mud (lb/bbl) ENVIROMUL - Ratio Mud Data Depth 86.2/13.811720' PV cP Oil / Water 96% Total Charges: Rig Activity: Cor Solids - Avg Min YP Circulating ECD (ppg)- Morning Report Report # 22 Customer: Well: Area: Location: Rig: ODSN-22 24-Apr-2015 ROP J. Polya, C.A. Demoski 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 121Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 1440 060 Density (ppg) out (sec/qt) Viscosity 6558' Circulate using step rate. Run 9 5/8" liner from 5488' MD to 6491' MD. Circulate liner volume using step rate. Service Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' . . * 24 hr Recap: 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Continue to stage up pumps to 4 bpm, reduce pump rate to 2 bpm while preparing for cement job. Cement 9 5/8" Comments - C-4n Density (ppg) out (sec/qt) Viscosity 070 0Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 J. Polya, C.A. Demoski 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Morning Report Report # 23 Customer: Well: Area: Location: Rig: ODSN-22 25-Apr-2015 ROP Total Charges: Rig Activity: Cor Solids - Avg Min YP Nipple Up Multi-Bowl ECD (ppg) ENVIROMUL - Ratio Mud Data Depth 86.2/13.811720' PV cP Oil / Water 1-2-CT-C23-E-1-WT-BH ml/30min 4.14- (lb/100ft2) ConditionFootage 11.5 Mud (lb/bbl) 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 Max Gas = 218 units, Avg Gas = 18 units choke and kill lines. Nipple down BOPE. Pick up multi bowl and lower to well bay. surface. Lay down 21 joints heavy weight on trip out. Lay down BHA. Hold pre-job to nipple down. Drain stack and remove trip nipple, bottoms up. Stand back two stands drill pipe and cut and slip drilling line. Pump dry job and trip out of the hole from 6276' MD to 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Trip (max) 99Average N/A C-4i 336 0 - 18411 C-2 0 0 ShSiltst - C-5n 017 Depth in / out Mud Type in Cement C-1 C-5i - Lst - - 0.994 35147 2462'14.5 158' 22.97 Hours 18 TFA Weight - - Ss Cht Silt - Chromatograph (ppm) Current 0.0 ROP (ft/hr) Max @ ftAvg 0.00.0 to - Tools - Flow In (gpm) Flow In (spm) MWD Summary Depth Date: Time: N/A - % 3.55 @ 96% 11720' 11720' 0' Lime 24 Hour Progress: 0 SPP (psi) - Current Pump & Flow Data: Max Yesterday's Depth: Current Depth: RPM 0 3183 API FL L-80 0 Alkal Coal - Gallons/stroke Tuff - Gvl Mud Loss (24hrs): -336 bbls liner as per HES pump schedule. Blow down cement lines. Un -sting drill pipe from liner and lay down cement head. Circulate 18 N/A 0 35 0 Bit # 1 10.15 (current) Units* Lithology (%) Bit Type Depth 10.10 202 Gas Summary 218 N/AMinimum 00 Maximum 107.0 H-40 Grade 16.00'' Type 11.75'' Clyst 60.0 571 Logging Engineers:Kerry Garner / David Durst (max)(current) Surface Cly - 0 5142' 12.0 Casing Summary 9.625"-Intermediate 1 -- Set AtSize 139 - - 4 HDBS FXG65S 10.625 1.353 70.76 6578' 11720' . . * 24 hr Recap: 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 6578' -- - 5 Baker Hughes GT-C1 8.5 0.920 - 11720' - - 0 -- Casing Summary 9.625"11717' MD / 4915' MD Intermediate 1 40.0 Clyst 60.0 350 Logging Engineers:Kerry Garner / David Durst (max)(current) Surface Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set AtSize 113 N/AMinimum 00 Maximum Bit # 1 10.10 (current) Units* Lithology (%) Bit Type Depth 10.20 Gas Summary N/A 0 16 0 Mud Loss (24hrs): 0 bbls rams and test BOPE. Drain stack, lay down test tools and service rig. Pick up BHA to 504 MD. Trip in the hole picking up singles out 16 0 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 Yesterday's Depth: Current Depth: RPM 0 1905 API FL L-80 11720' 11720' 0' Lime 24 Hour Progress: 0 SPP (psi) - Current Pump & Flow Data: Max N/A - % 3.55 @ 96% 0.0 to - Tools - Flow In (gpm) Flow In (spm) MWD Summary Depth Current 0.0 ROP (ft/hr) Max @ ftAvg 0.0 20 TFA Weight - Ss Cht Silt -- - 0.994 35210 2462'14.5 158' 22.97 Hours 09 Depth in / out Mud Type in Cement C-1 C-5i - ShSiltst - C-5n Lst - Chromatograph (ppm) 0 0 - 14169 C-2 1025 0 98 Average N/ATrip (max) 67 100% Gas In Air=10,000 UnitsN/AConnection - C-4i 16.0 39 Max Gas = 113 units, Avg Gas = 16 units at 600 gpm. Pressure test casing to 3500 psi for 30 min. of the pipe shed to 4207' MD. Trip in the hole to 11423' MD. Wash down from 11423' MD to 11585' MD, tag up. Circulate bottoms up 6548' MD / 3221' TVD Mud (lb/bbl) 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V cP Oil / Water 1-2-CT-C23-E-1-WT-BH ml/30min 4.40- (lb/100ft2) ConditionFootage 12.0 Casing Test ECD (ppg) ENVIROMUL - Ratio Mud Data Depth 86.1/13.911720' Rig Activity: Cor Solids - Avg Min YPPV Date: Time: - Morning Report Report # 24 Customer: Well: Area: Location: Rig: ODSN-22 26-Apr-2015 ROP J. Polya, C.A. Demoski 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: Total Charges: 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 0Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 0121 Density (ppg) out (sec/qt) Viscosity 6558' Install multi-head and lower riser. Nipple up surface stack. Pick up test tools and set test plug. Change out lower Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' . . * 24 hr Recap: 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 6578' -- - 5 Baker Hughes GT-C1 8.5 0.920 - 11720' - - 723 -- Casing Summary 9.625"11717' MD / 4915' MD Intermediate 1 40.0 Clyst 60.0 79 Logging Engineers:Kerry Garner / David Durst (max)(current) Surface 107.0 H-40 Grade 16.00'' Type 11.75'' Set AtSize 24 11734'Minimum 014 Maximum Bit # 1 10.20 (current) Units* Lithology (%) Bit Type Depth 10.20 Gas Summary 11720' 0 10 0 Mud Loss (24hrs): 0 bbls Displace well over to 10.2 ppg LSND mud system. Drill ahead from 11720' MD to 11740' MD. Circulate one bottoms up at 600 gpm. 17 - Gallons/stroke Tuff - Gvl L-80 Yesterday's Depth: Current Depth: RPM 15 1140 API FL L-80 11720' 11740' 20' Chlorides 24 Hour Progress: 0 SPP (psi) - Current Pump & Flow Data: Max % 3.55 @ 96% to pH - Tools - Flow In (gpm) Flow In (spm) MWD Summary Depth - 11727'0.0 Current 78.2 ROP (ft/hr) Max @ ftAvg 121.1 - Ss Cht Silt - Cly Sh 14.5 158' 22.97 Hours 27 TFA in Cement C-1 C-5i -- - 0.994 1862 00 Depth in / out 2462' Weight Coal 0 Siltst - C-5n Lst - Chromatograph (ppm) 732 - 2272 C-2 Average 12 (max) 44 C-4i Trip 32 019 Perform formation integrity test. Monitor well to verify static. Pump dry job and trip out of the hole from 11740' MD to 504' MD. Lay 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Max Gas = 24 units, Avg Gas = 17 units down BHA to surface. Bring BHA #6 up beaverslide and stage on floor. Pick up test tools, drain stack in preparation for BOPE test. 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 1-2-CT-C23-E-1-WT-BH ml/30min 2550010.10 (lb/100ft2) ConditionFootage 6.7 mg/l LSND 2.4 (ppb Eq) Mud Data Depth 1.011740' cP MBT Mud Type Date: Time: Picking Up BOP Test Tools ECD (ppg) 0 Corr Solids - Avg Min YPPV - Morning Report Report # 25 Customer: Well: Area: Location: Rig: ODSN-22 27-Apr-2015 Total Charges: Rig Activity: ROP J. Polya, C.A. Demoski 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 6Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 050 Density (ppg) out (sec/qt) Viscosity 6558' Pressure test casing to 3500' MD psi for 30 min. Drill down cleaning out shoe track from 11585' MD to 11720' MD. Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' . . * 24 hr Recap: 11740' 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 12.06 11720' 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Pull wear ring and set test plug. Test BOPE. Lay down test tools and blow down lines. Service top drive. Service top Comments - C-4n Density (ppg) out (sec/qt) Viscosity 040 6Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: 28-Apr-2015 Total Charges: Rig Activity: ROP J. Polya, C.A. Demoski 24 hr Max YPPV - Morning Report Report # 26 Customer: Well: Area: Location: Rig: ODSN-22 Date: Time: Trip in hole ECD (ppg) 0 - Avg LSND 3.4 (ppb Eq) Mud Data Depth 1.011740' cP MBT Mud Type ml/30min 2550010.30 (lb/100ft2) ConditionFootage 6.7 mg/l 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 Max Gas = 9 units, Avg Gas = 5 units pulse test to 600 gpm. Pick up BHA to 604’ MD. Break in Geo-Pilot at 600 gpm. Trip in the hole to 10574’ MD. Service top drive. 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - C-4i Trip 4 55 (max) 12Average 9 - 241 C-2 00 0 Siltst - C-5n Lst - Chromatograph (ppm) 00 Depth in / out 2462' Weight Coal in Cement C-1 C-5i -- - 0.994 1554 14.5 158' 22.97 Hours 27 TFA - Ss Cht Silt - Cly Sh Current 0.0 ROP (ft/hr) Max @ ftAvg 0.0 Flow In (gpm) Flow In (spm) MWD Summary Depth PWD, RES, Gamma, ABG, ABI, Directional -0.0 96% to pH 11740' Tools - Corr Solids Min 11740' 11740' 0' Chlorides 24 Hour Progress: 0 SPP (psi) - Current Pump & Flow Data: Max Yesterday's Depth: Current Depth: RPM 0 50 API FL L-80 - Gallons/stroke Tuff - Gvl L-80 % 3.55 @ 1-2-CT-C23-E-1-WT-BH Mud Loss (24hrs): 0 bbls drive and clean rig floor. Pick up BHA to 78’ MD. Download MWD tools. Pick up BHA to 137’ MD and rest reamer. Perform shallow 5 N/A 0 0 0 Bit # 1 10.20 (current) Units* Lithology (%) Bit Type Depth 10.20 Gas Summary 9 N/AMinimum 00 Maximum 107.0 H-40 Grade 16.00'' Type 11.75'' Set AtSize 40.0 Clyst 60.0 8 Logging Engineers:Kerry Garner / David Durst (max)(current) Surface - - 0 -- Casing Summary 9.625"11717' MD / 4915' MD Intermediate 1 6578' -- - 6 HDBS SFE46D 8.5 1.107 - 11740' 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 . . * 24 hr Recap: 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 - 6 HDBS SFE46D 8.5 1.107 - 11740' - 100 493 -- Casing Summary 9.625"11717' MD / 4915' MD Intermediate 1 Logging Engineers:Kerry Garner / David Durst (max)(current) Surface11.75'' Set AtSize 40.0 Clyst 60.0 188 11740'Minimum 05 Maximum Units* Lithology (%) Bit Type Depth 10.20 Gas Summary 107.0 H-40 Grade 16.00'' 12028' 0 230 55 Mud Loss (24hrs): 0 bbls necessary from 11522' MD to 11740' MD at 600 GPM, 2700 PSI, 40-80 RPM, 14-18K Torque. Drilled ahead from 11740' MD to 84 120 RPM, 21K Torque, 15-18K WOB. Obtained slow pump rates. Performed a kick while drilling drill with the opposite rig crew. at 12800' MD. Drilled ahead from 12566' MD to 12800' MD at 750 GPM, 3720 PSI, 130 RPM, 21K Torque, 14-20K WOB. Currently drilling ahead Tuff - Gvl L-80 % 3.55 @ 1-2-CT-C23-E-1-WT-BH -- Yesterday's Depth: Current Depth: RPM 9 7120 API FL L-80 11740' 12800' 1060' Chlorides 24 Hour Progress: 214 SPP (psi) 12.10 Current Pump & Flow Data: Max 96% to pH 11740' Tools - Corr Solids Min Gallons/stroke MWD Summary Depth PWD, RES, Gamma, ABG, ABI, Directional 12033'110.0 86.9 ROP (ft/hr) Max @ ftAvg 163.8 - Ss Cht Silt - Cly Sh (current) 158' 22.97 Hours 36 TFABit # 1 10.20 Type in Cement C-1 C-5i -- - 0.994 1857 4689 Depth in / out 2462' Weight Coal 0 Siltst - C-5n Lst - 022 - 18387 C-2 Chromatograph (ppm) - 1145 Average N/A (max) 554 Trip 613 54353 11850' MD at 605 GPM, 2700 PSI, 100 RPM, 20.5K Torque, 12K WOB. Established parameters and dropped 10 tags to open the 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Max Gas = 188 units, Avg Gas = 84 units Obtained slow pump rates. Performed a kick while drilling drill. Drilled ahead from 12091' MD to 12566' MD at 750 GPM, 3650 PSI, reamer. Drilled ahead from 11850’ MD to 12091' MD at 756 GPM, 3400 PSI, 60-160 RPM, 21-26K Torque, 17-25K WOB. Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 ml/30min 240009.90 (lb/100ft2) ConditionFootage 7.3 mg/l LSND 3.4 (ppb Eq) Mud Data Depth 0.512688' cP MBT Mud Type Drilling Ahead ECD (ppg) 760 11.67 Avg Flow In (gpm) Flow In (spm) YPPV 11.14 Morning Report Report # 27 Customer: Well: Area: Location: Rig: ODSN-22 29-Apr-2015 Total Charges: Rig Activity: ROP J. Polya, C.A. Demoski 24 hr Max Date: Time: Current Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i 90Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 3800 425444 Density (ppg) out (sec/qt) Viscosity Tripped into the hole from 10573' MD to 11522' MD. Washed and reamed in the hole working through tight spots as Comments - C-4n 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 11720' 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142' 11740' 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 . . * 24 hr Recap: 4 HDBS FXG65S 10.625 1.353 70.76 - Size 40.0 15.0 140 0-0--NO-A-X-I-ER-TD 6 HDBS SFE46D 8.5 1.107 - 11740' - 483 -- Casing Summary 9.625"11717' MD / 4915' MD Intermediate 1 Set At Logging Engineers:Kerry Garner / David Durst (max)(current) Surface11.75'' Clyst 60.0 134 12966'Minimum 516 Maximum Units* Lithology (%) Bit Type Depth 10.20 Gas Summary 107.0 H-40 Grade 16.00'' 12843' 0 301 80 Mud Loss (24hrs): 0 bbls bottoms up. Lubricated out of the hole from 13137' MD to 12328' MD at 2 BPM. Spotted 71 Bbls of 50 lb/bbl LCM pill right outside 82 motor problems. Currently circulating and establishing parameters to keep ECD below 12.5 ppg. 3.55 @ 1-2-CT-C23-E-1-WT-BH -- - L-80 Tuff - Gvl L-80 % Current Pump & Flow Data: Max Yesterday's Depth: Current Depth: RPM 30 5780 Min Gallons/stroke 12826' 13137' 311' Chlorides 24 Hour Progress: 177 SPP (psi) 12.58 ROP (ft/hr) 96% to pH 11740' Tools - Corr Solids (current) 158' 22.97 Hours MWD Summary Depth PWD, RES, Gamma, ABG, ABI, Directional API FL Cly Sh Max @ ftAvg 176.0 12952'0.0 97.0 Bit # 1 10.20 Type - Size 158' MD / 163' TVD Ss Cht in Cement C-1 C-5i -- - 0.994 1760 Depth in / out 2462' Weight Coal TFA - Silt - 0 Siltst - C-5n Lst - 2140 10148 C-2 Chromatograph (ppm) 8879 - 854 Average (max) 517 Trip 557 53361 157 outside the bit covering the Torok. Tripped out from 12328' MD to 11428' MD. Performed LCM squeeze job. Serviced top drive and 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units184Connection - Max Gas = 134 units, Avg Gas = 82 units bearing. Staged up pumps in 1/2 Bbl increments until 2 BPM, then in 1 Bbl increments. Worked on mud pump number 1, blower blocks. Worked on the top drive. Cut and slipped drilling line. Tripped in the hole from 11428' MD to 13137' MD. Installed RCD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' ml/30min 240009.80 (lb/100ft2) ConditionFootage 7.3 mg/l 35LSND 1.0 (ppb Eq) Mud Data Depth 0.513137' cP MBT Mud Type Circulating ECD (ppg) 630 12.11 Avg Flow In (gpm) Flow In (spm) YPPV 11.54 Morning Report Report # 28 Customer: Well: Area: Location: Rig: ODSN-22 30-Apr-2015 Total Charges: Rig Activity: ROP J. Polya, C.A. Demoski 24 hr Max Date: Time: Current Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i 22Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 3109 665359 Density (ppg) out (sec/qt) Viscosity Drilled ahead from 12800' MD to 13137' MD at 757 GPM, 3800 PSI, 140 RPM, 21-26 Torque, 17-20 WOB. Circulated Comments - C-4n 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142' 11740' 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 . . * 24 hr Recap: 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142' Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Continued to circulate 5 bottoms up increasing pump rate while maintaining a 12.5 ppg ECD. Pulled RCD bearing and Comments - C-4n Density (ppg) out (sec/qt) Viscosity 524850 144Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 3454 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: Rig Activity: ROP J. Polya, C.A. Demoski 24 hr Max Date: Time: Current YPPV 11.54 Morning Report Report # 29 Customer: Well: Area: Location: Rig: ODSN-22 Drilling Ahead ECD (ppg) 650 12.60 Avg Flow In (gpm) Flow In (spm) Total Charges: LSND 3.6 (ppb Eq) Mud Data Depth 12.513950' cP MBT Mud Type ml/30min 2350010.00 (lb/100ft2) ConditionFootage 7.8 mg/l 39 -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' Max Gas = 237 units, Avg Gas = 84 units PSI, 135 RPM, 10-20 WOB. Obtained slow pump rates. Serviced top drive, then drilled ahead from 13893’ MD 13992’ MD at 650 GPM, 25-27K Torque, 18-22 WOB. Performed a kick while drilling drill and drilled ahead from 13422’ MD to 13893’ MD at 650 GPM, 3500 Pulled the trip nipple and installed the RCD bearing. Drilled ahead from 13232’ MD to 13422’ MD at 700 GPM, 3500 PSI, 120 RPM, 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units154Connection - Trip 857 49341 N/A (max) 534 1522 Average 21206 C-2 Chromatograph (ppm) 114115 4096 9 Siltst - C-5n Lst - Depth in / out 2462' Weight Coal TFA - Silt -- in Cement C-1 C-5i -- - 0.994 1961 Bit # 1 10.20 Type - Size 158' MD / 163' TVD Ss Cht Max @ ftAvg 172.1 13710'60.0 75.0 (current) 158' 22.97 Hours MWD Summary Depth PWD, RES, Gamma, ABG, ABI, Directional API FL ROP (ft/hr) 96% to pH 11740' Tools - Corr Solids 855' Chlorides 24 Hour Progress: 183 SPP (psi) 12.88 1-May-2015 67 6857 Min Gallons/stroke Cly Sh Gvl L-80 % Current Pump & Flow Data: Max Yesterday's Depth: Current Depth: RPM 13137' 13992' 3.55 @ 1-2-CT-C23-E-1-WT-BH -- - L-80 Tuff - Mud Loss (24hrs): 0 bbls installed trip nipple, then drilled ahead from 13137’ MD to 13232’ MD at 750 GPM, 3600 PSI, 120 RPM, 22K Torque, 18-22K WOB. 82 3450 PSI, 140 RPM, 20-25K Torque, 20K WOB. Currently drilling ahead at 13992’ MD. 13648' 13 433 110 Units* Lithology (%) Bit Type Depth 10.20 Gas Summary 107.0 H-40 Grade 16.00'' 237 13376'Minimum 916 Maximum Logging Engineers:Kerry Garner / David Durst (max)(current) Surface11.75'' Clyst 60.0 100 1178 -- Casing Summary 9.625"11717' MD / 4915' MD Intermediate 1 Set AtSize 40.0 15.0 140 0-0--NO-A-X-I-ER-TD 6 HDBS SFE46D 8.5 1.107 - 4 HDBS FXG65S 10.625 1.353 70.76 -11740' 11740' . . * 24 hr Recap: 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Drilled ahead from 13992’ MD to 14376’ MD at 650 GPM, 3500 PSI, 140 RPM, 26K Torque, 12-15 WOB. Drilled ahead Comments - C-4n Density (ppg) out (sec/qt) Viscosity 958987 287Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 3614 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: Rig Activity: J. Polya, C.A. Demoski 24 hr Max Date: Time: Current Drilling Ahead 12.29 Morning Report Report # 30 Customer: Well: Area: Location: Rig: ODSN-22 ROP 12.70 Avg Flow In (gpm) Flow In (spm) YPPV Total Charges: LSND 4.0 (ppb Eq) Mud Data Depth 10.0 cP MBT Mud Type ml/30min 24,00010.20 (lb/100ft2)in API FL ConditionFootage 7.3 mg/l 38 -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' Max Gas = 551 units, Avg Gas = 247 units performed a kick while drilling drill. Continued to work the drill pipe and monitor the well while the RSC was building more 10.2 ppg 150 RPM, 26K Torque, 12-15K WOB and still losing to the hole. Monitored the well while working the drill pipe periodically and then pack offs. Serviced rig and monitored the well to ensure static. Drilled ahead from 14467’ MD to 14483’ MD at 650 GPM, 3500 PSI, 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units506Connection - Trip 1211 91754 N/A 1509Average (max) Chromatograph (ppm) 1221312698 1932 0 Siltst 100 C-5n Lst - Depth in / out 2462' Weight Coal TFA - Silt -- Cement C-1 C-5i -- - Gvl Units* Lithology (%) 0.994 1460 Bit # 1 10.20 Type - Size 158' MD / 163' TVD Ss Cht Max @ ftAvg 224.9 14471'79.0 75.0 (current) 158' 22.97 Hours MWD Summary Depth PWD, RES, Gamma, ABG, ABI, Directional ROP (ft/hr) 96% to pH 11740' Tools - Corr Solids 744' Chlorides 24 Hour Progress: 183 SPP (psi) 12.96 2-May-2015 @ ECD (ppg) 650 22 24357 Min Gallons/stroke Cly Sh L-80 % Current Pump & Flow Data: Max Yesterday's Depth: Current Depth: RPM 13992' 14736' 3.554 1-2-CT-C23-E-1-WT-BH -- - L-80 Tuff - 15.0 140 Mud Loss (24hrs): -540 bbls from 14375’ MD to 14467’ MD at 650 GPM, 3500 PSI, 150 RPM, 26K Torque, 12-15K WOB. Encountered a loss zone with partial 247 LSND. Drilled ahead from 14483’ MD to 14721’ MD back reaming 60' of every stand at 650 GPM, 3680 PSI, 150 RPM, 24K Torque, 10-20K WOB. Pumping a 15 bbl 70 lb/bbl LCM sweep every 500'. Currently drilling ahead at 14721’ MD. 14483' 0 525 118 Bit Type Depth 10.20 Gas Summary 107.0 H-40 Grade 16.00'' Size 40.0 Minimum 08 Maximum 52498 11.75'' Clyst 60.0 551 14409' C-2 Casing Summary 9.625"11717' MD / 4915' MD Intermediate 1 Set At Logging Engineers:Martin Nnaji / David Durst (max)(current) Surface 4 HDBS FXG65S 10.625 1.353 70.76 - 358 ---11740' 11740' 6 HDBS SFE46D 8.5 1.107 - . . * 24 hr Recap: -11740' 11740' 6 HDBS SFE46D 8.5 1.107 - 4 HDBS FXG65S 10.625 1.353 70.76 85 1415 -- 9.625"11717' MD / 4915' MD Intermediate 1 Set At Logging Engineers:Martin Nnaji / David Durst (max)(current) Surface11.75'' Clyst 60.0 490 15258' C-2 Casing Summary Minimum 2422 Maximum 47393 Bit Type Depth 10.25 Gas Summary 107.0 H-40 Grade 16.00'' Size 40.0 14838' 47 546 121 Mud Loss (24hrs): 0 bbls a 200 PSI pressure loss while drilling, worked pipe while determining what the problem was and the possible solutions. Pumped a 254 and blocks. Pumped a 26 bbl, 70 lb/bbl LCM sweep. Drilled ahead from 15228’ MD to 15481’ MD at 650 GPM, 3800 PSI, 150 RPM, 23-25K Torque, 8-15K WOB. Currently drilling ahead at 15481’ MD. 15481' 3.554 1-2-CT-C23-E-1-WT-BH -- - L-80 Tuff - Cly Sh L-80 % Max RPM 15.0 140 13.70 3-May-2015 @ ECD (ppg) 650 Min Gallons/stroke Current Pump & Flow Data: pH 11740' Tools - Corr Solids 745' Chlorides 24 Hour Progress: 183 SPP (psi) (current) 158' 22.97 Hours MWD Summary Depth PWD, RES, Gamma, ABG, ABI, Directionalto 158' MD / 163' TVD Ss Cht Max @ ftAvg 151.5 14758'81.0 72.5 0.994 1756 Bit # 1 10.20 Type - Size Cement C-1 C-5i -15 - Gvl Units* Lithology (%) Depth in / out 2462' Weight Coal TFA - Silt -- 62 Siltst - C-5n Lst - 125130122 Chromatograph (ppm) 1351352347 Average (max) 136523827 Trip 1198 100770 N/A carbide bomb at 3 BPM, 940 PSI. Carbide bomb came back at 680 strokes, 530' down. Found the washout below the tool joint on 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units7553Connection - Max Gas = 490 units, Avg Gas = 254 units 15038’ MD to 15228’ MD at 650 GPM, 3770 PSI, 150 RPM, 23K Torque, 15-20 WOB. Obtained slow pump rates. Serviced top drive stand 149. Replaced the joint and tripped back in the hole to 15038’ MD. Staged up pumps to 650 GPM, 150 RPM. Drilled ahead from -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' ConditionFootage 7.5 mg/l 3815417' cP MBT Mud Type ml/30min 30,0009.8 (lb/100ft2)in API FLYPPV Total Charges: LSND 4.0 (ppb Eq) Mud Data Depth 12.5 ROP 12.71 Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% Morning Report Report # 31 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 14736' 24 hr Max Date: Time: Current Drilling Ahead 12.51 Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: Rig Activity: J. Polya, C.A. Demoski 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i 225Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 3836 12798112 Density (ppg) out (sec/qt) Viscosity Drilled ahead from 14721’ MD to 15038’ MD at 650 GPM, 3660 PSI, 150 RPM, 20-22K Torque, 10-15K WOB. Observed Comments - C-4n 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 . . * 24 hr Recap: 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Drilled ahead from 15481’ MD to 15709’ MD at 650 GPM, 3800PSI, 150 RPM, 23K Torque, 28K WOB. Serviced top drive Comments - C-4n Density (ppg) out (sec/qt) Viscosity 14196121 12Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: Rig Activity: J. Polya, C.A. Demoski 24 hr Max Date: Time: Current Servicing Top Drive 12.52 Morning Report Report # 32 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15481' ROP 12.70 Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% YPPV Total Charges: LSND 3.4 (ppb Eq) Mud Data Depth 10.015726' cP MBT Mud Type ml/30min 34,00010.5 (lb/100ft2)in API FL ConditionFootage 7.3 mg/l 29 -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' Max Gas = 850 units, Avg Gas = 321 units hole from 15726’ MD to 11649’ MD at 48 GPM, 650 PSI, 40 RPM, 60 FPM. Serviced top drive. Currently servicing top drive getting ready GPM, 4100 PSI, 150 RPM, 22K Torque. Pumped around a 25 bbl weighted sweep, then circulated 6 bottoms up. Lubricated out of the 13-15 WOB. Obtained slow pump rates and pumped down reamer tags. Quadrant reamed from 15638’ MD to 15726’ MD at 650 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units850Connection - Trip 1385 97742 48 154432321Average (max) Chromatograph (ppm) 1881523397 159137138 79 Siltst - C-5n Lst - Depth in / out 2462' Weight Coal TFA - Silt -- Cement C-1 C-5i -- - Gvl Units* Lithology (%) 0.994 1345 Bit # 1 10.25 Type - Size 158' MD / 163' TVD Ss Cht Max @ ftAvg 142.4 15617'0.0 85.5 (current) 158' 22.97 Hours MWD Summary Depth PWD, RES, Gamma, ABG, ABI, Directionalto pH 11740' Tools 15726' Corr Solids 245' Chlorides 24 Hour Progress: 0 SPP (psi) 12.89 4-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: Cly Sh L-80 % Max RPM 15.0 140 15726' 3.554 1-2-CT-C23-E-1-WT-BH 150 - - L-80 Tuff - Mud Loss (24hrs): -25 bbls (LOOH) and replaced the encoder on the top drive. Drilled ahead from 15709’ MD to 15726’ MD at 650 GPM, 3700 PSI, 150 RPM, 26K Torque, 321 to trip in the hole. 15696' 61 618 160 Bit Type Depth 10.20 Gas Summary 107.0 H-40 Grade 16.00'' Size 40.0 2927 Maximum 77411 Clyst 60.0 872 15645' C-2 Casing Summary Minimum 9.625"11717' MD / 4915' MD Intermediate 1 Set At Logging Engineers:Martin Nnaji / David Durst (max)(current) Surface11.75'' 4 HDBS FXG65S 10.625 1.353 70.76 - 1899 3986' 25.015726' 11740' 11740' 6 HDBS SFE46D 8.5 1.107 56.76 . . * 24 hr Recap: 15726' 11740' 11740' 6 HDBS SFE46D 8.5 1.107 56.76 4 HDBS FXG65S 10.625 1.353 70.76 - 291 3986' 25.0 9.625"11717' MD / 4915' MD Intermediate 1 Set At Logging Engineers:Martin Nnaji / David Durst (max)(current) Surface11.75'' Clyst 60.0 2008 N/A C-2 Casing Summary Minimum 3 Maximum 198315 Bit Type Depth 12.30 Gas Summary 107.0 H-40 Grade 16.00'' Size 40.0 N/A 0 1030 208 Mud Loss (24hrs): 0 bbls Torque. Pumped 1 bottoms up then pumped a 25 bbl weighted, high viscosity sweep around for a total of 3.5 bottoms up, 111 to check for swabbing, getting ready to pull on elevators. 15726' 3.554 1-2-CT-C23-E-1-WT-BH 150 - - L-80 Tuff - Cly Sh L-80 % Max RPM 15.0 140 12.96 5-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: pH 11740' Tools 15726' Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) (current) 158' 22.97 Hours MWD Summary Depth PWD, RES, Gamma, ABG, ABI, Directionalto 158' MD / 163' TVD Ss Cht Max @ ftAvg 0.0 -0.0 0.0 0.994 2054 Bit # 1 12.30 Type - Size Cement C-1 C-5i -- - Gvl Units* Lithology (%) Depth in / out 2462' Weight Coal TFA - Silt -- 0 Siltst - C-5n Lst - 71270 Chromatograph (ppm) 2382959059 Average (max) 5689963 Trip 3240 36291 23 then displaced well from 10.2 ppg to 12.3 ppg. The 12.3 ppg was expected to come back at 16147 strokes, 12.3 ppg came 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Max Gas = 2008 units (Circ B/U from TD, 05:13), Avg Gas = 111 units from 15726’ MD to 11649’ MD at 84 GPM, 80-100 PSI, then function tested the BOPs. Currently pulling 1 stand on elevators back to surface at 18050 strokes (161 bbls past). Removed the RCD and installed the trip nipple. Lubricated out of the hole -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' ConditionFootage 13.2 mg/l 2715726' cP MBT Mud Type ml/30min 100,00010.1 (lb/100ft2)in API FLYPPV Total Charges: LSND 2.0 (ppb Eq) Mud Data Depth - ROP 12.70 Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% Morning Report Report # 33 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' 24 hr Max Date: Time: Current Lubricating Out of Hole 12.17 Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: Rig Activity: J. Polya, C.A. Demoski 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i 9Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 5315545 Density (ppg) out (sec/qt) Viscosity Tripped in the hole from 11649’ MD to 15726’ MD. Staged up pumps to 650 GPM, at 4150 PSI, 150 RPM, 24K Comments - C-4n 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 . . * 24 hr Recap: 15726' 11740' 11740' 6 HDBS SFE46D 8.5 1.107 56.76 4 HDBS FXG65S 10.625 1.353 70.76 - 0 3986' 25.0 9.625"11717' MD / 4915' MD Intermediate 1 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75'' Clyst 60.0 0 N/A C-2 Casing Summary Minimum 0 Maximum 0 Bit Type Depth 10.15 Gas Summary 107.0 H-40 Grade 16.00'' Size 40.0 N/A 0 0 0 11142' to 604' MD. Laid down BHA from 604' to 0' MD; cleaned and cleared the rig floor. Changed top rams to 7" and 3 15726' 3.554 1-2-CT-C23-E-1-WT-BH 150 - - L-80 Tuff - Cly Sh L-80 % Max RPM 15.0 140 - 6-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) (current) 158' 22.97 Hours MWD Summary Depth N/Ato 158' MD / 163' TVD Ss Cht Max @ ftAvg 0.0 -0.0 0.0 0.994 1248 Bit # 1 12.30 Type - Size Cement C-1 C-5i -- - Gvl Units* Lithology (%) Depth in / out 2462' Weight Coal TFA - Silt -- 0 Siltst - C-5n Lst - 000 0 Chromatograph (ppm) 000 Average (max) 15245 Trip 0 68 25 serviced the top drive. Removed the wear ring, installed the test plug, and tested the 7" rams. Laid down testing 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Fluid - Gain / Loss (24 hrs): 0 bbls 1675' MD. equipment and rigged up Tesco casing equipment. Tested the torque with the load cell. Ran the 7" casing from 0' to -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' ConditionFootage 7.1 mg/l 2015726' cP MBT Mud Type ml/30min 28,50010.2 (lb/100ft2)in API FLYPPV Total Charges: LSND 4.4 (ppb Eq) Mud Data Depth 7.5 ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% Morning Report Report # 34 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' 24 hr Max Date: Time: Current RIH w/ 7" Casing - Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Rig Activity: - J. Polya, C.A. Demoski 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i 6Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 090 Density (ppg) out (sec/qt) Viscosity Tripped out of the hole from 11649' to 11142' MD. Pumped a dry job and continued to trip out of the hole from Comments - C-4n 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Report By: Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 . . * 24 hr Recap: 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Ran with 7" Casing from 1675' to 14276' MD, filling with 10.1 ppg LSND. Hit a tight spot at 14237' MD; Comments - C-4n Density (ppg) out (sec/qt) Viscosity 5260 11Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Rig Activity: - J. Polya, C.A. Demoski 24 hr Max Date: Time: Current RIH w/ 7" Casing - Morning Report Report # 35 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% YPPV Total Charges: LSND 4.4 (ppb Eq) Mud Data Depth 7.515726' cP MBT Mud Type ml/30min 30,50010.0 (lb/100ft2)in API FL ConditionFootage 7.0 mg/l 20 -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' Fluid - Gain / Loss (24 hrs): 0 bbls 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Trip 114 759 70 1463809Average (max) Chromatograph (ppm) 1112274 000 0 0 Siltst - C-5n Lst - Depth in / out 2462' Weight Coal TFA - Silt -- Cement C-1 C-5i -- - Gvl Units* Lithology (%) 0.994 1248 Bit # 1 12.30 Type - Size 158' MD / 163' TVD Ss Cht Max @ ftAvg 0.0 -0.0 0.0 (current) 158' 22.97 Hours MWD Summary Depth N/Ato pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) - 7-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: Cly Sh L-80 % Max RPM 15.0 140 15726' 3.554 1-2-CT-C23-E-1-WT-BH 150 - - L-80 Tuff - rotated throught it at 20 rpm with 15K Torque. 30 N/A 0 45 10 Bit Type Depth 10.15 Gas Summary 107.0 H-40 Grade 16.00'' Size 40.0 0 Maximum 7868 Clyst 60.0 70 N/A C-2 Casing Summary Minimum 9.625"11717' MD / 4915' MD Intermediate 1 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75'' 4 HDBS FXG65S 10.625 1.353 70.76 - 0 3986' 25.015726' 11740' 11740' 6 HDBS SFE46D 8.5 1.107 56.76 . . * 24 hr Recap: 9.625"11717' MD / 4915' TVD Intermediate 1 40.0 L-80 - 15726' 11740' 11740' 6 HDBS SFE46D 8.5 1.107 56.76 4 HDBS FXG65S 10.625 1.353 70.76 - 254 3986' 25.0 7.00"15699' MD / 6079' TVD Intermediate 2 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75'' Clyst 60.0 440 N/A C-2 Casing Summary Minimum 2 Maximum 45349 Bit Type Depth 10.10 Gas Summary 107.0 H-40 Grade 16.00'' Size 26.0 N/A 0 180 41 Rigged down and laid down Tesco casing equipment. Rigged up the cement head and cement lines. Staged up 61 15726' 3.554 1-2-CT-C23-E-1-WT-BH 150 - - L-80 Tuff - Cly Sh L80 % Max RPM 15.0 140 - 8-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) (current) 158' 22.97 Hours MWD Summary Depth N/Ato 158' MD / 163' TVD Ss Cht Max @ ftAvg 0.0 -0.0 0.0 0.994 1350 Bit # 1 10.10 Type - Size Cement C-1 C-5i -- - Gvl Units* Lithology (%) Depth in / out 2462' Weight Coal TFA - Silt -- 0 Siltst - C-5n Lst - 722140 Chromatograph (ppm) 43551849 Average (max) 2516340 Trip 602 13104 270 and displaced out 12.3 ppg LSND to 10.1 ppg LSND. Pressure tested the cement lines. Performed cement job with 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Fluid - Gain / Loss (24 hrs): -725 bbls / Cement Job increments. little returns. Bumped plug at 3 BPM and 3484 psi at 6870 strokes at 11:11PM. Staged up pumps to 5 BPM in 0.5 bbl -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' ConditionFootage 7.0 mg/l 1915726' cP MBT Mud Type ml/30min 30,0009.8 (lb/100ft2)in API FLYPPV Total Charges: LSND 4.6 (ppb Eq) Mud Data Depth 7.5 ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% Morning Report Report # 36 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' 24 hr Max Date: Time: Current Circulating - Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Rig Activity: - J. Polya, C.A. Demoski 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i 33Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 164412 Density (ppg) out (sec/qt) Viscosity Ran in with 7" Casing from 14276' to 15699' MD. Set emergency slips due to rotating to get casing down. Comments - C-4n 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 . . * 24 hr Recap: 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Circulated two bottoms up and cleaned pits to displace the 10.1 ppg MOBM. Displaced the well from a Comments - C-4n Density (ppg) out (sec/qt) Viscosity 0324 N/ABackground Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Rig Activity: - J. Polya, C.A. Demoski 24 hr Max Date: Time: Current Changing rams - Morning Report Report # 37 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% YPPV Total Charges: LSND 4.6 (ppb Eq) Mud Data Depth 7.515726' cP MBT Mud Type ml/30min 29,5009.8 (lb/100ft2)in API FL ConditionFootage 7.5 mg/l 19 -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' Fluid - Gain / Loss (24 hrs): 0 bbls casing running equipment. Nippled down the BOP and set the emergency slips. Laid down the casing cut joint. Tested pressure tested the casing to 2500 psi. Rigged down the cementing equipment and drained the stack. Rigged down the cement job according to the cement plan and bumped the plug with 10.1 ppg LSND. Closed the ES Cementer and 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Trip 1920 13109 N/A 2684698Average (max) Chromatograph (ppm) 1201705263 000 0 0 Siltst - C-5n Lst - Depth in / out 2462' Weight Coal TFA - Silt -- Cement C-1 C-5i -- - Gvl Units* Lithology (%) 0.994 1350 Bit # 1 10.15 Type - Size 158' MD / 163' TVD Ss Cht Max @ ftAvg 0.0 -0.0 0.0 (current) 158' 22.97 Hours MWD Summary Depth N/Ato pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) - 9-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: Cly Sh L-80 % Max RPM 15.0 140 15726' 3.554 1-2-CT-C23-E-1-WT-BH 150 - - L-80 Tuff - 10.1 ppg LSND to a 10.1 ppg MOBM. Circulated one bottoms up at 210 gpm. Pumped the second stage portion of the 45 the emergency pack off to 4300 psi. Picked up testing equipment. N/A 0 575 117 Bit Type Depth 10.15 Gas Summary 107.0 H-40 Grade 16.00'' Size 26.0 0 Maximum 110001 Clyst 60.0 1090 N/A C-2 Casing Summary Minimum 7.00"15699' MD / 6079' TVD Intermediate 2 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75'' 4 HDBS FXG65S 10.625 1.353 70.76 - 0 3986' 25.015726' 11740' 11740' 6 HDBS SFE46D 8.5 1.107 56.76 9.625"11717' MD / 4915' TVD Intermediate 1 40.0 L-80 - . . * 24 hr Recap: 9.625"11717' MD / 4915' TVD Intermediate 1 40.0 L-80 - 15726' 11740' 11740' 6 HDBS SFE46D 8.5 1.107 56.76 4 HDBS FXG65S 10.625 1.353 70.76 - 0 3986' 25.0 7.00"15699' MD / 6079' TVD Intermediate 2 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75'' Clyst 60.0 0 N/A C-2 Casing Summary Minimum 0 Maximum 0 Bit Type Depth 10.10 Gas Summary 107.0 H-40 Grade 16.00'' Size 26.0 N/A 0 0 0 tested the BOP; annular failed the test. Changed out the annular preventer and rigged up and tested the new annular 0 15726' 3.554 1-2-CT-C23-E-1-WT-BH 150 - - L-80 Tuff - Cly Sh L-80 % Max RPM 15.0 140 - 10-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) (current) 158' 22.97 Hours MWD Summary Depth N/Ato 158' MD / 163' TVD Ss Cht Max @ ftAvg 0.0 -0.0 0.0 0.994 1350 Bit # 1 10.10 Type - Size Cement C-1 C-5i -- - Gvl Units* Lithology (%) Depth in / out 2462' Weight Coal TFA - Silt -- 0 Siltst - C-5n Lst - 0000 Chromatograph (ppm) 000 Average (max) 00 Trip 0 00 N/A preventer. Laid down the testing equipment and blew down the lines. Installed the wear ring, rotary bushings and mouse 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Fluid - Gain / Loss (24 hrs): 0 bbls hole. Laid down 61 / 163 stands. -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' ConditionFootage 7.0 mg/l 1915726' cP MBT Mud Type ml/30min 29,5009.6 (lb/100ft2)in API FLYPPV Total Charges: LSND 4.6 (ppb Eq) Mud Data Depth 7.5 ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% Morning Report Report # 38 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' 24 hr Max Date: Time: Current Laying down 5" DP - Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Rig Activity: - J. Polya, C.A. Demoski 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i N/ABackground Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 000 Density (ppg) out (sec/qt) Viscosity Finished changing out the rams and sent out the IBOP and saver sub. Picked up testing equipment and Comments - C-4n 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 . . * 24 hr Recap: 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Laid down 5" drill pipe using the mouse hole. Brought up thread protectors to the rig floor. Serviced the Comments - C-4n Density (ppg) out (sec/qt) Viscosity 000 N/ABackground Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Rig Activity: - J. Polya, C.A. Demoski 24 hr Max Date: Time: Current Picking up single 4" DP - Morning Report Report # 39 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% YPPV Total Charges: LSND 4.6 (ppb Eq) Mud Data Depth 7.515726' cP MBT Mud Type ml/30min 30,0009.6 (lb/100ft2)in API FL ConditionFootage 7.5 mg/l 20 -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' Fluid - Gain / Loss (24 hrs): 0 bbls top drive and picked up 4" drill pipe from 1926' to 9148' MD. Performed a kick while tripping drill. of the 5" drill pipe in the shed. Picked up 4" drill pipe singles to 1926' MD and cut and slipped drilling line. Serviced the 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Trip 0 00 N/A 00Average (max) Chromatograph (ppm) 000 000 0 0 Siltst - C-5n Lst - Depth in / out 2462' Weight Coal TFA - Silt -- Cement C-1 C-5i -- - Gvl Units* Lithology (%) 0.994 1251 Bit # 1 10.10 Type - Size 158' MD / 163' TVD Ss Cht Max @ ftAvg 0.0 -0.0 0.0 (current) 158' 22.97 Hours MWD Summary Depth N/Ato pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) - 11-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: Cly Sh L-80 % Max RPM 15.0 140 15726' 3.554 1-2-CT-C23-E-1-WT-BH 150 - - L-80 Tuff - top drive and finished laying down the 5" drill pipe. Removed the mouse hole and laid it down. Kicked out the remainder 0 N/A 0 0 0 Bit Type Depth 10.10 Gas Summary 107.0 H-40 Grade 16.00'' Size 26.0 0 Maximum 0 Clyst 60.0 0 N/A C-2 Casing Summary Minimum 7.00"15699' MD / 6079' TVD Intermediate 2 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75'' 4 HDBS FXG65S 10.625 1.353 70.76 - 0 3986' 25.015726' 11740' 11740' 6 HDBS SFE46D 8.5 1.107 56.76 9.625"11717' MD / 4915' TVD Intermediate 1 40.0 L-80 - . . * 24 hr Recap: 150 -6 HDBS SFE46D 8.5 1.107 56.76 11740' 15726' 3986' 25.0 9.625"11717' MD / 4915' TVD Intermediate 1 40.0 L-80 - -15726' 11740' 7 Baker Hughes RC216 6.125 1.169 - 4 HDBS FXG65S 10.625 1.353 70.76 - 0 -- 7.00"15699' MD / 6079' TVD Intermediate 2 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75'' Clyst 60.0 0 N/A C-2 Casing Summary Minimum 0 Maximum 0 Bit Type Depth 10.20 Gas Summary 107.0 H-40 Grade 16.00'' Size 26.0 N/A 0 0 0 Pumped a dry job and tripped out of hole to surface. Removed wear ring and installed the test plug. Picked up testing 0 15726' 3.554 1-2-CT-C23-E-1-WT-BH - - - L-80 Tuff - Cly Sh L-80 % Max RPM 15.0 140 - 12-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) (current) 158' 22.97 Hours MWD Summary Depth N/Ato 158' MD / 163' TVD Ss Cht Max @ ftAvg 0.0 -0.0 0.0 0.994 1352 Bit # 1 10.20 Type - Size Cement C-1 C-5i -- - Gvl Units* Lithology (%) Depth in / out 2462' Weight Coal TFA - Silt -- 0 Siltst - C-5n Lst - 000 0 Chromatograph (ppm) 000 Average (max) 00 Trip 0 00 N/A equipment and tested BOPs. Rigged up and tested the MPD equipment, laid down testing equipment, and blew down 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Fluid - Gain / Loss (24 hrs): 0 bbls 1165' MD. lines. Picked up and ran in BHA, shallow pulse tested, and blew down top drive. Picked up 4" drill pipe from 394' to -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' ConditionFootage 7.5 mg/l 1815726' cP MBT Mud Type ml/30min 29,5009.6 (lb/100ft2)in API FLYPPV Total Charges: LSND 4.8 (ppb Eq) Mud Data Depth 7.5 ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% Morning Report Report # 40 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' 24 hr Max Date: Time: Current TIH 4" DP - Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Rig Activity: - J. Polya, C.A. Demoski 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i N/ABackground Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 000 Density (ppg) out (sec/qt) Viscosity Picked up 4" drill pipe from 9148' to 12030' MD. Ciculated 1.5 times drill volume; pressure tested to 2600 psi. Comments - C-4n 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Report By: Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 . . * 24 hr Recap: -6 HDBS SFE46D 8.5 1.107 56.76 11740' 15726' 3986'25.0 9.625"11717' MD / 4915' TVD Intermediate 1 40.0 L-80 150 - -15726' 11740' 7 Baker Hughes RC216 6.125 1.169 - 158' MD / 163' TVD 4 HDBS FXG65S 10.625 1.353 70.76 - 0 -- 15699' MD / 6079' TVD Intermediate 2 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75''60.0 0 N/A C-2 Casing Summary Minimum 7.00" 0 Maximum 0 Bit Type Depth 10.30 Gas Summary 107.0 H-40 Grade 16.00'' Size 26.0 N/A 0 0 0 ES cementer to 12421' MD. Washed down and tripped into hole to 15305' MD. Washed down and pulled out of hole 0 15726' 3.530 1-2-CT-C23-E-1-WT-BH -- - L-80 Tuff - Sh L-80 % Max RPM 15.0 140 Clyst - 13-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) (current) 158' 22.97 Hours MWD Summary Depth N/Ato Cht Max @ ftAvg 0.0 -0.0 0.0 0.994 Cly 51 Bit # 1 10.30 Type - Size Depth in / out Ss Cement C-1 C-5i --- Gvl Units* Lithology (%) 2462' Weight Coal TFA - Silt -- Chromatograph (ppm) 0 Siltst - C-5n Lst - 0000 000 Average (max) 00 Trip 0 00 N/A to 15493' MD and began pressuring up for casing test. Washed out high pressure mud line. 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Fluid - Gain / Loss (24 hrs): 0 bbls -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' ConditionFootage 7.7 mg/l 181215726' cP MBT Mud Type ml/30min 36,00011.6 (lb/100ft2)in API FLYPPV Total Charges: LSND 5.6 (ppb Eq) Mud Data Depth 7.5 ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% Morning Report Report # 41 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' 24 hr Max Date: Time: Current Changing out mud line - Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: Rig Activity: J. Polya, C.A. Demoski 20'24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i N/ABackground Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 000 Density (ppg) out (sec/qt) Viscosity Picked up 4" drill pipe and tripped in hole from 1165' MD to 12033' MD. Washed down and drilled out Comments - C-4n 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3938'19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD 20'17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 . . * 24 hr Recap: 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Replaced high pressure mud line and tested. Pressure tested casing to 4000 psi for 30 minutes and reamed/ Comments - C-4n Density (ppg) out (sec/qt) Viscosity 000 N/ABackground Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Rig Activity: - J. Polya, C.A. Demoski 24 hr Max Date: Time: Current Bat Sonic Log - Morning Report Report # 42 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% YPPV Total Charges: LSND 5.8 (ppb Eq) Mud Data Depth 7.515726' cP MBT Mud Type ml/30min 38,00011.8 (lb/100ft2)in API FL ConditionFootage 7.6 mg/l 1412 -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' Fluid - Gain / Loss (24 hrs): 0 bbls 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Trip 0 00 N/A 00 (max) 000 Average 000 0 0 Siltst - C-5n Lst - 2462' Weight Coal TFA - Silt -- Chromatograph (ppm) Cement C-1 C-5i -- - Gvl Units* Lithology (%) 46 Bit # 1 10.25 Type - Size Depth in / out Ss Cht Max @ ftAvg 0.0 -0.0 0.0 0.994 Cly (current) 158' 22.97 Hours MWD Summary Depth N/Ato pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) - 14-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: Sh L-80 % Max RPM 15.0 140 Clyst 15726' 3.530 1-2-CT-C23-E-1-WT-BH - - - L-80 Tuff - washed down. Circulated one bottoms up. Tripped out of the hole and performed bat sonic logs. 0 N/A 0 0 0 Bit Type Depth 10.25 Gas Summary 107.0 H-40 Grade 16.00'' Size 26.0 0 Maximum 0 60.0 0 N/A C-2 Casing Summary Minimum 7.00"15699' MD / 6079' TVD Intermediate 2 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75'' 4 HDBS FXG65S 10.625 1.353 70.76 - 0 -- 11740' 7 Baker Hughes RC216 6.125 1.169 - 9.625"11717' MD / 4915' TVD Intermediate 1 40.0 L-80 150 - -15726' 158' MD / 163' TVD -6 HDBS SFE46D 8.5 1.107 56.76 11740' 15726' 3986' 25.0 . . * 24 hr Recap: 6 HDBS SFE46D 8.5 1.107 56.76 11740' 40.0 L-80 150 - -15726' -15726' 3986' 25.0 7 Baker Hughes RC216 6.125 1.169 - 9.625"11717' MD / 4915' TVD Intermediate 1 158' MD / 163' TVD 4 HDBS FXG65S 10.625 1.353 70.76 - 0 -- 15699' MD / 6079' TVD Intermediate 2 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75''60.0 0 N/A C-2 Casing Summary Minimum 7.00" 0 Maximum 0 Bit Type Depth 10.25 Gas Summary 107.0 H-40 Grade 16.00'' Size 26.0 N/A 0 0 0 20 bbl dry job and continued to trip out of the hole to 394' MD. Laid down BHA to surface and downloaded MWD. 0 blinds and monitored the well for 10 minutes with no flow. 05/14/2015 Morning Report correction: Max gas = 113 units (after reaching TD and circulating). 15726' 3.530 1-2-CT-C23-E-1-WT-BH - - - L-80 Tuff - Sh L-80 % Max RPM 15.0 140 Clyst - 15-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) (current) 158' 22.97 Hours MWD Summary Depth N/Ato Cht Max @ ftAvg 0.0 -0.0 0.0 0.994 Cly 40 Bit # 1 10.25 Type - Size Depth in / out Ss Cement C-1 C-5i -- - Gvl Units* Lithology (%) 2462' Weight Coal TFA - Silt -- Chromatograph (ppm) 0 Siltst - C-5n Lst - 000 0 000 Average (max) 00 Trip 0 00 N/A Pulled the wear ring, installed junk basket, flushed the stack. Drained the stack and installed the test plug. Observed 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Fluid - Gain / Loss (24 hrs): 0 bbls on annulus with blinds shut. Monitored pressure and bled off. Bled well through choke lines to verify no flow. Opened the the well flowing slowly. Filled the stack and installed and tested the MPD equipment. Pulled the plug and installed gauge -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' ConditionFootage 8.0 mg/l 121215726' cP MBT Mud Type ml/30min 40,50011.9 (lb/100ft2)in API FLYPPV Total Charges: LSND 6.4 (ppb Eq) Mud Data Depth 7.5 ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% Morning Report Report # 43 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' 24 hr Max Date: Time: Current Monitoring Well / BOP Test - Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Rig Activity: - J. Polya, M. Thornton 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i N/ABackground Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 000 Density (ppg) out (sec/qt) Viscosity Tripped out of the hole from 11461' to 10979' MD, while logging Cement Bond Log with XBAT. Pumped a Comments - C-4n 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Report By: Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 11740' . . * 24 hr Recap: 20' 17.0 60 2-3-WT-AR-E-2-ER-BHA5Baker Hughes GT-C1 8.5 0.920 0.35 11740' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD2620' 6578' 11720' 5142'0-0--NO-A-X-I-ER-TD Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Tested BOP and bled off pressure on the annulus. Removed test plug and installed wear ring. Picked up Comments - C-4n Density (ppg) out (sec/qt) Viscosity 1792846286 112Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 C-4i Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Rig Activity: - J. Polya, M. Thornton 24 hr Max Date: Time: Current Cut and Slip drilling lines - Morning Report Report # 44 Customer: Well: Area: Location: Rig: ODSN-22 Yesterday's Depth: Current Depth: 15726' ROP - Avg Flow In (gpm) Flow In (spm) ROP (ft/hr) 96% YPPV Total Charges: LSND 6.4 (ppb Eq) Mud Data Depth 7.515726' cP MBT Mud Type ml/30min 40,00011.9 (lb/100ft2)in API FL ConditionFootage 8.0 mg/l 1115 -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 3914.5 11720' 6558' +10 bbls TIH * +4 bbls was observed during BHA assembly Fluid - Gain / Loss (24 hrs): +14 bbls* pit 2 to RSC to run the degasser. Cut and slip drilling line. and circulated 1300 strokes. Tripped in the hole from 1548' to 15665' MD filling every 30 stands. Transfer MOBM from 6548' MD / 3221' TVD 100% Gas In Air=10,000 UnitsN/AConnection - Trip 588 11677839 2203 476919327 (max) 0287301 Average 000 0 0 Siltst - C-5n Lst - 2462' Weight Coal TFA - Silt -- Chromatograph (ppm) Cement C-1 C-5i -- - Gvl Units* Lithology (%) 43 Bit # 1 10.25 Type - Size Depth in / out Ss Cht Max @ ftAvg 0.0 -0.0 0.0 0.994 Cly (current) 158' 22.97 Hours MWD Summary Depth N/Ato pH - Tools - Corr Solids 0' Chlorides 24 Hour Progress: 0 SPP (psi) - 16-May-2015 @ ECD (ppg) 0 Min Gallons/stroke Current Pump & Flow Data: Sh L-80 % Max RPM 15.0 140 Clyst 15726' 3.530 1-2-CT-C23-E-1-WT-BH - - - L-80 Tuff - PVT sensor during TIH allowed for some discrepencies in actual gains due to the mud being aired up. BHA from surface to 144' MD. Downloaded MWD tools and shallow pulse test at 180 gpm. Tripped in the hole to 1548' MD 189 N/A 0 12 0 Bit Type Depth 10.25 Gas Summary 107.0 H-40 Grade 16.00'' Size 26.0 0 Maximum 228252 60.0 2208 N/A C-2 Casing Summary Minimum 7.00"15699' MD / 6079' TVD Intermediate 2 Set At Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface11.75'' 4 HDBS FXG65S 10.625 1.353 70.76 - 0 --7 Baker Hughes RC216 6.125 1.169 - 9.625"11717' MD / 4915' TVD Intermediate 1 158' MD / 163' TVD 40.0 L-80 150 - -15726' -15726' 3986' 25.06HDBS SFE46D 8.5 1.107 56.76 11740' . . * 24 hr Recap: Displaced well over to a 7.5 ppg MOBM system. Drilled ahead from 15726' to 15746' MD and perform FIT test to 12.5 ppg EMW. 4591 Casing Summary MPD at the shoe. Observed high gas levels and increased MPD pressure to 9.8 ppg and circulated until gas was below 3500 units. Conducted a pore pressure test resulting in a 9.3 ppg EMW. Drilled ahead from 15953' to 16050' MD holding 9.5 ppg with Drilled ahead from 15717' to 15953' MD at 210 gpm. Circulated 4100 strokes until the same mud weight in and out was reached. Fluid Gain / Loss (24 Hrs): 0 bbls L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- 15726' - ---- 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 7 Baker Hughes / RC216 6.125 0.920 - 6 HDBS / SFE46D 8.5 1.107 - 11740' 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By: Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Cut and slipped drilling line. Circulated 1.5 bottoms up at 200 gpm. Removed trip nipple and install RCD head. Comments - C-4n Density (ppg) out (sec/qt) Viscosity 2819828 1580Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 3685 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 ROP J. Polya, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Morning Report Report # 45 Customer: Well: Area: Location: Rig: ODSN-22 17-May-2015 Total Charges: Rig Activity: Cor Solids 10.02 Avg Min YPPV Date: Time: - Drilling Ahead Production ECD (ppg) ENVIROMUL - Ratio Mud Data Depth 88.7 / 11.315953' cP Oil / Water 1-2-CT-C23-E-1-WT-BH ml/30min 6.86- (lb/100ft2) ConditionFootage 1.7 Mud (lb/bbl) 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units6615Connection - C-4i Trip (max) 7481 5593 Average N/A 921476 3338 - 854596 C-2 130 20 Siltst - C-5n Lst - Chromatograph (ppm) 58405 Depth in / out Mud Type in Cement C-1 C-5i -100 - 0.994 1267 2462'14.5 158' 22.97 Hours 16 TFA Weight - Ss Cht Silt - Current 13.4 ROP (ft/hr) Max @ ftAvg 97.2 15699' Tools 16050' Flow In (gpm) Flow In (spm) MWD Summary Depth PWD / ABI / 4" Triple Combo 15773' 9.42 % 3.55 @ 96% 90.0 to 15726' 16050' 324' Lime 24 Hour Progress: 63 SPP (psi) 11.73 Current Pump & Flow Data: Max Yesterday's Depth: Current Depth: RPM 889 364900 API FL L-80 222 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 15858' 18 958 133 Bit # 1 7.55 (current) Units* Lithology (%) Bit Type Depth 7.55 Gas Summary 9295 15777'Minimum 61623 Maximum Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set AtSize Sh 40.0 Clyst 60.0 23632 Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface 11740' - 71729 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 - 11720' 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 . . * 24 hr Recap: 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 - 11720' 11740' - 102395 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 Clyst 60.0 20286 Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface Maximum Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Depth 7.55 Gas Summary 6498 16493'Minimum 217 Bit # 1 7.55 (current) Units* Lithology (%) Bit Type 16208' 130 1119 175 220 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 Yesterday's Depth: Current Depth: RPM 1900 144765 API FL L-80 16050' 17063' 1013' Lime 24 Hour Progress: 62 SPP (psi) 10.38 Current Pump & Flow Data: Max % 3.55 @ 96% to16050' Tools 16958' Flow In (gpm) Flow In (spm) MWD Summary Depth PWD / ABI / 4" Triple Combo 16813'70.0 Current 78.0 ROP (ft/hr) Max @ ftAvg 89.0 TFA Weight - Ss Cht Silt - Size 100 - 0.994 1260 2462'14.5 158' 22.97 Hours 208458 Depth in / out Mud Type in Cement C-1 C-5i - Siltst - C-5n Lst - Chromatograph (ppm) 625 152 - 632118 C-2 2142154 4838140 5405 Average N/A C-4i Trip (max) 6162 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units9729Connection - 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 1-2-CT-C23-E-1-WT-BH ml/30min 6.22- (lb/100ft2) ConditionFootage 1.7 Mud (lb/bbl) ENVIROMUL - Ratio Mud Data Depth 88.7/11.316820' cP Oil / Water 15 Date: Time: - Drilling Ahead ECD (ppg) Cor Solids 10.06 Avg Min YPPV 9.65 Morning Report Report # 46 Customer: Well: Area: Location: Rig: ODSN-22 18-May-2015 Total Charges: Rig Activity: ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 560Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 3660 122591102 Density (ppg) out (sec/qt) Viscosity 6558' Drilled ahead from 16050' MD to 16339' MD at 220 gpm and 3500 psi. Serviced top drive and drilled ahead from Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By: Unit Phone:(907) 670-6636Ashley Wilderom 6578' 6 HDBS / SFE46D 8.5 1.107 - 11740' 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 7 Baker Hughes / RC216 6.125 0.920 - 15726' - ---- L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- Fluid Gain / Loss (24 Hrs): 0 bbls 16399' MD to 17039' MD at 220 gpm and 3600 psi. Serviced and inspected top drive. 1375 Casing Summary . . * 24 hr Recap: 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 - 11720' 11740' - 14988 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 Clyst 60.0 12708 Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface Maximum Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Depth 7.65 Gas Summary 2908 18177'Minimum 60 Bit # 1 7.70 (current) Units* Lithology (%) Bit Type 17560' 44 567 103 211 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 Yesterday's Depth: Current Depth: RPM 543 100584 API FL L-80 17063' 18340' 1277' Lime 24 Hour Progress: 62 SPP (psi) 10.49 Current Pump & Flow Data: Max % 3.55 @ 96% to17063' Tools 18300' Flow In (gpm) Flow In (spm) MWD Summary Depth PW D / ABI / 4" Triple Combo 18313'86.0 Current 87.0 ROP (ft/hr) Max @ ftAvg 91.6 TFA Weight - Ss Cht Silt - Size 100 - 0.994 1358 2462'14.5 158' 22.97 Hours 14259 Depth in / out Mud Type in Cement C-1 C-5i - Siltst - C-5n Lst - Chromatograph (ppm) 181 55 - 301854 C-2 1151245 1258165 3122 Average N/A C-4i Trip (max) 3957 6548' MD / 3221' TVD 100% Gas In Air=10,000 Units5871Connection - 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 1-2-CT-C23-E-1-WT-BH ml/30min 6.86- (lb/100ft2) ConditionFootage 2.5 Mud (lb/bbl) ENVIROMUL - Ratio Mud Data Depth 88.6 / 11.418069' cP Oil / Water 13 Date: Time: - Drilling Ahead ECD (ppg) Cor Solids 10.26 Avg Min YPPV 10.01 Morning Report Report # 47 Customer: Well: Area: Location: Rig: ODSN-22 19-May-2015 Total Charges: Rig Activity: ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 306Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 3668 6031788 Density (ppg) out (sec/qt) Viscosity 6558' Drilled ahead from 17039' to 17495' MD and serviced the top drive. Drilled ahead from 17495' to 18315' MD and Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 6 HDBS / SFE46D 8.5 1.107 - 11740' 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 7 Baker Hughes / RC216 6.125 0.920 - 15726' - ---- L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- Fluid Gain / Loss (24 Hrs): 0 bbls serviced the top drive. 985 Casing Summary . . * 24 hr Recap: gpm, 3710 psi, 16.5k Torque, 70 rpm. Drilled ahead from 19034' to 19708' MD at 230 gpm, 4075 psi, 15.5k Torque, 80 rpm and 651 Casing Summary serviced top drive. Fluid Gain / Loss (24 Hrs): -40 bbls L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- 15726' - ---- 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 7 Baker Hughes / RC216 6.125 0.920 - 6 HDBS / SFE46D 8.5 1.107 - 11740' 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By: Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Drilled ahead from 18315' to 18940' MD and serviced top drive. Drilled ahead from 18940' to 19034' MD at 220 Comments - C-4n Density (ppg) out (sec/qt) Viscosity 031289 348Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 4131 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Morning Report Report # 48 Customer: Well: Area: Location: Rig: ODSN-22 20-May-2015 Total Charges: Rig Activity: Cor Solids 10.40 Avg Min YPPV 10.12 Date: Time: - Drilling Ahead ECD (ppg) ENVIROMUL - Ratio Mud Data Depth 88.5/11.519458' cP Oil / Water 12 1-2-CT-C23-E-1-WT-BH ml/30min 5.05- (lb/100ft2) ConditionFootage 3.4 Mud (lb/bbl) 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 =10,000 Units9003Connection - C-4i Trip (max) 3518 1742 Average N/A 100% Gas In Air 1141211 1306159 388138 C-2 201 66 - C-5n Lst - Chromatograph (ppm) - 7154 Depth in / out Mud Type in Cement C-1 C-5i -100 - 0.994 1054 2462'14.5 158' 22.97 HoursTFA Weight - Ss Cht Silt - Size Current 94.0 ROP (ft/hr) Max @ ftAvg 100.0 Flow In (gpm) Flow In (spm) MWD Summary Depth PWD / ABI / 4" Triple Combo 18806'66.0 % 3.55 @ 96% to18300' Tools 19680' 18340' 19718' 1378' Lime 24 Hour Progress: 64 SPP (psi) 10.51 Current Pump & Flow Data: Max Yesterday's Depth: Current Depth: RPM 596 62048 API FL L-80 230 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 19465' 49 353 11 Bit # 1 7.80 (current) Units* Lithology (%) Bit Type Depth 7.80 Gas Summary 3933 18274'Minimum 69 Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Siltst 6548' MD / 3221' TVD Clyst 60.0 7408 Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface Maximum 11740' - 14161 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 - 11720' 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 . . * 24 hr Recap: 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 - 11720' 11740' - 6669 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 Clyst 60.0 5959 Logging Engineers:Martin Nnaji / Ashley Wilderom (max)(current) Surface Maximum Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Siltst 6548' MD / 3221' TVD Depth 7.80 Gas Summary 2651 20795'Minimum 59 Bit # 1 7.90 (current) Units* Lithology (%) Bit Type 20636' 0 328 25 230 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 Yesterday's Depth: Current Depth: RPM 441 128838 API FL L-80 to19680' Tools 20800' 19718' 20861' 1143'24 Hour Progress: 66 MWD Summary Depth PWD / ABI / 4" Triple Combo 20720'80.0 % 3.55 @ 96% Current 85.0 ROP (ft/hr) Max @ ftAvg 96.0 TFA Weight - Ss Cht Silt - Size 100 - 0.994 1361 2462'14.5 158' 22.97 Hours 0125 Depth in / out Mud Type in Cement C-1 C-5i -- C-5n Lst - Chromatograph (ppm) - 153 14 268261 C-2 1100 89588 1504 Average N/A 100% Gas In AirTrip (max) 3974 115 =10,000 Units6928Connection - C-4i 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 1-2-CT-C23-E-1-WT-BH ml/30min 6.47- (lb/100ft2) ConditionFootage 3.4 Mud (lb/bbl) ENVIROMUL - Ratio Mud Data Depth 89.1 / 10.920689' cP Oil / Water 13 Date: Time: - Drilling Ahead ECD (ppg) Flow In (gpm) Flow In (spm) SPP (psi) Current Pump & Flow Data: Cor Solids 10.51 Avg Min YPPV 10.21 Lime 10.85 Max Morning Report Report # 49 Customer: Well: Area: Location: Rig: ODSN-22 21-May-2015 Total Charges: Rig Activity: ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 608Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 4243 02670 Density (ppg) out (sec/qt) Viscosity 6558' Drilled ahead from 19708' to 20190' MD at 230 gpm, 4180 psi, 16.4k torque, 80 rpm and serviced top drive. Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By: Unit Phone:(907) 670-6636Ashley Wilderom 6578' 6 HDBS / SFE46D 8.5 1.107 - 11740' 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 7 Baker Hughes / RC216 6.125 0.920 - 15726' - ---- L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- Fluid Gain / Loss (24 Hrs): -25 bbls Drill ahead from 20190' to 20864' MD at 230 gpm, 4200 psi, 15.9k torque, 80 rpm and serviced top drive. 1333 Casing Summary . . * 24 hr Recap: 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 - 11720' 11740' - 5150 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 Clyst 60.0 7462 Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Maximum Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Siltst 6548' MD / 3221' TVD Depth 7.80 Gas Summary 3256 21934'Minimum 49 Bit # 1 7.90 (current) Units* Lithology (%) Bit Type 21690' 31 390 21 232 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 Yesterday's Depth: Current Depth: RPM 394 101921 API FL L-80 to20800' Tools 21973' 20861' 21985' 1124'24 Hour Progress: 66 MWD Summary Depth PWD / ABI / 4" Triple Combo 21585'68.0 % 3.55 @ 96% Current 85.0 ROP (ft/hr) Max @ ftAvg 101.0 TFA Weight - Ss Cht Silt - Size 100 - 0.994 1358 2462'14.5 158' 22.97 Hours 29167 Depth in / out Mud Type in Cement C-1 C-5i -- C-5n Lst - Chromatograph (ppm) - 129 37 340982 C-2 1215 84368 1923 Average N/A 100% Gas In AirTrip (max) 4006 123 =10,000 Units7379Connection - C-4i 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 1-2-CT-C23-E-1-WT-BH ml/30min 6.73- (lb/100ft2) ConditionFootage 3.6 Mud (lb/bbl) ENVIROMUL - Ratio Mud Data Depth 89.0 / 11.021762' cP Oil / Water 14 Date: Time: - Drilling Ahead ECD (ppg) Flow In (gpm) Flow In (spm) SPP (psi) Current Pump & Flow Data: Cor Solids 10.68 Avg Min YPPV 10.41 Lime 10.83 Max Morning Report Report # 50 Customer: Well: Area: Location: Rig: ODSN-22 22-May-2015 Total Charges: Rig Activity: ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 387Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 4403 02910 Density (ppg) out (sec/qt) Viscosity 6558' Drilled ahead from 20864' to 21346' MD at 230 gpm, 4200 psi, 18.6k torque, 100 rpm; serviced the top drive. Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By: Unit Phone:(907) 670-6636Ashley Wilderom 6578' 6 HDBS / SFE46D 8.5 1.107 - 11740' 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 7 Baker Hughes / RC216 6.125 0.920 - 15726' - ---- L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- Fluid Gain / Loss (24 Hrs): -16 bbls Drilled ahead from 21346' 21700' MD. Changed out swab and liners on the mud pump #1. Drilled ahead to 21730' and 1117 Casing Summary circulated 2320 strokes, then drilled ahead to 21870' MD. . . * 24 hr Recap: 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 - 11720' 11740' - 17186 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 Clyst 60.0 4734 Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Maximum Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Siltst 6548' MD / 3221' TVD Depth 7.80 Gas Summary 1842 22032'Minimum 88 Bit # 1 7.90 (current) Units* Lithology (%) Bit Type 22084' 14 262 35 198 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 Yesterday's Depth: Current Depth: RPM 751 75458 API FL L-80 to21973' Tools 22208' 21985' 22208' 223'24 Hour Progress: 56 MWD Summary Depth PWD / ABI / 4" Triple Combo 22200'- % 3.55 @ 96% Current 73.0 ROP (ft/hr) Max @ ftAvg 95.0 TFA Weight - Ss Cht Silt - Size 100 - 0.994 1462 2462'14.5 158' 22.97 Hours 0112 Depth in / out Mud Type in Cement C-1 C-5i -- C-5n Lst - Chromatograph (ppm) - 197 0 191619 C-2 990 2024191 1238 Average 2457 100% Gas In AirTrip (max) 3101 96 =10,000 Units9727Connection - C-4i 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 1-2-CT-C23-E-1-WT-BH ml/30min 6.47- (lb/100ft2) ConditionFootage 3.5 Mud (lb/bbl) ENVIROMUL - Ratio Mud Data Depth 89.1 / 10.922208' cP Oil / Water 12 Date: Time: - TD Production / BROOH ECD (ppg) Flow In (gpm) Flow In (spm) SPP (psi) Current Pump & Flow Data: Cor Solids 10.54 Avg Min YPPV 10.14 Lime 10.78 Max Morning Report Report # 51 Customer: Well: Area: Location: Rig: ODSN-22 23-May-2015 Total Charges: Rig Activity: ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 243Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 2789 02500 Density (ppg) out (sec/qt) Viscosity 6558' Drilled ahead from 21966' to 22019' MD at 230 gpm, 4350 psi, 16k torque, and 80 rpm. Changed out the RCD Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By: Unit Phone:(907) 670-6636Ashley Wilderom 6578' 6 HDBS / SFE46D 8.5 1.107 - 11740' 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 7 Baker Hughes / RC216 6.125 0.920 - 15726' - ---- L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- Fluid Gain / Loss (24 Hrs): -59 bbls bearing and drilled ahead to 22208' MD. Circulated 1.5 bottoms up from 22208' to 22019' MD and performed a pore pressure 793 Casing Summary top drive. Circulated 6500 strokes at 200 gpm; backreamed out of the hole to 18073' MD at 200 gpm, 3150 psi, 60 rpm; and serviced the test that resulted in 9.75 EMW. Circulated one bottoms up from 22019' to 21926' MD and backreamed out of the hole to 20187' MD. . . * 24 hr Recap: 15726' 0'-- 2-1-WT-A-E-I-ER-BHA7Baker Hughes / RC216 6.125 0.920 - 15726' changed out the IBOP and saver sub. Tripped in the hole from 15665' to 22208' MD and serviced the blocks. Began to displace 782 Casing Summary the well over to a 10.2 ppg MOBM KW mud. * Trip Out: -18 bbls / Trip In: +11 bbls Fluid Gain / Loss (24 Hrs): -7 bbls L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- 15726' 22208' 6482' - -- 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 8 HDBS / MM64 6.125 0.389 82.36 6 HDBS / SFE46D 8.5 1.107 56.70 11740' 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Back-reamed from 18073' to 15665' MD at 200 gpm and circulated 3 bottoms up. Serviced the top drive and Comments - C-4n Density (ppg) out (sec/qt) Viscosity 0830 107Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 712 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - Morning Report Report # 52 Customer: Well: Area: Location: Rig: ODSN-22 24-May-2015 Total Charges: Rig Activity: Cor Solids 9.97 Avg Min YPPV 9.87 Lime 10.61 Max Date: Time: - Displacement to 10.2 ppg ECD (ppg) Flow In (gpm) Flow In (spm) SPP (psi) Current Pump & Flow Data: ENVIROMUL - Ratio Mud Data Depth 89.1 / 10.922208' cP Oil / Water 11 1-2-CT-C23-E-1-WT-BH ml/30min 6.22- (lb/100ft2) ConditionFootage 3.5 Mud (lb/bbl) 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 =10,000 UnitsN/AConnection - C-4i Trip (max) 1784 40 16360 Average 9194 100% Gas In Air 422 00 872481 C-2 0 0 - C-5n Lst - Chromatograph (ppm) - 6841468 Depth in / out Mud Type in Cement C-1 C-5i --- 0.994 1264 2462'14.5 158' 22.97 HoursTFA Weight - Ss Cht Silt - Size Current - ROP (ft/hr) Max @ ftAvg - MWD Summary Depth PWD / ABI / 4" Triple Combo -- % 3.55 @ 96% to - Tools - 22208' 22208' 0'24 Hour Progress: 12 Yesterday's Depth: Current Depth: RPM 0 74032 API FL L-80 42 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 N/A 0 3818 633 Bit # 1 7.90 (current) Units* Lithology (%) Bit Type Depth 7.80 Gas Summary 9194 N/AMinimum 0 Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Siltst 6548' MD / 3221' TVD Clyst 60.0 46928 Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Maximum 11740' - 0 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 0.40 11720' 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 . . * 24 hr Recap: 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 0.40 11720' 11740' - 860 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 Clyst 60.0 6205 Logging Engineers:Kerry Garner / Ashley Wilderom (max)(current) Surface Maximum Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Siltst 6548' MD / 3221' TVD Depth 10.20 Gas Summary 2615 N/AMinimum 28 Bit # 1 10.20 (current) Units* Lithology (%) Bit Type N/A 0 186 0 0 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 Yesterday's Depth: Current Depth: RPM 117 17491 API FL L-80 to - Tools - 22208' 22208' 0'24 Hour Progress: 0 MWD Summary Depth PWD / ABI / 4" Triple Combo -- % 3.55 @ 96% Current - ROP (ft/hr) Max @ ftAvg - TFA Weight - Ss Cht Silt - Size -- 0.994 2586 2462'14.5 158' 22.97 Hours 0102 Depth in / out Mud Type in Cement C-1 C-5i -- C-5n Lst - Chromatograph (ppm) - 134 0 254757 C-2 318 09 1343 Average 2615 100% Gas In AirTrip (max) 876 48 =10,000 UnitsN/AConnection - C-4i 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 1-2-CT-C23-E-1-WT-BH ml/30min 6.99- (lb/100ft2) ConditionFootage 11.5 Mud (lb/bbl) ENVIROMUL - Ratio Mud Data Depth 86.2 / 13.822208' cP Oil / Water 17 Date: Time: - Lube out of hole ECD (ppg) Flow In (gpm) Flow In (spm) SPP (psi) Current Pump & Flow Data: Cor Solids - Avg Min YPPV - Lime - Max Morning Report Report # 53 Customer: Well: Area: Location: Rig: ODSN-22 25-May-2015 Total Charges: Rig Activity: ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: - 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 27Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 9 01020 Density (ppg) out (sec/qt) Viscosity 6558' Finished displacing the well with a 10.2 ppg MOBM and checked the well for flow. Well was static, so rig crew / MPD Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636Ashley Wilderom 6578' 6 HDBS / SFE46D 8.5 1.107 56.70 11740' 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 8 HDBS / MM64 6.125 0.389 82.36 15726' 22208' 6482' --- L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- per minute. Checked the well for 15 minutes, results were static. Dropped 2 3/8" drift and lubed out of the hole from 15699' to Losses include: -20 bbls Displacement / -37 bbls LOOH Fluid Gain / Loss (24 Hrs): -57 bbls 15726' pulled the RCD bearing and installed the trip nipple. Lubed out of the hole from 22208' to 15699' MD, while pumping 1 barrel 185 Casing Summary the elevators, encountered swabbing. Lubed out of the hole to 13064' MD pumping 1/2 barrel per minute / 5 minute stands. 14027' MD, while pumping at a 2 barrel per minute / 3 minute stands. Observed losses while tripping. Attempted to pull on 15726' 0'-- 2-1-WT-A-E-I-ER-BHA7Baker Hughes / RC216 6.125 0.920 - . . * 24 hr Recap: 15726' 0'-- 2-1-WT-A-E-I-ER-BHA7Baker Hughes / RC216 6.125 0.920 0.00 15726' to 2190' MD. Lay down 4" drill pipe from 2190' MD to 431' MD. Lay down BHA and unload nuclear sources. 23 Casing Summary Mud Loss (24hrs): -10 bbls Max Gas = 616 units, Avg Gas = 23 units L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- 15726' 22208' 6482' --- 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 8 HDBS / MM64 6.125 0.389 82.36 6 HDBS / SFE46D 8.5 1.107 56.70 11740' 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Lube out of the hole from 13064' MD to 4881' MD at 1 bpm, 3 minutes per stand. Trip out of the hole from 4881' MD Comments - C-4n Density (ppg) out (sec/qt) Viscosity 2171 7Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: Morning Report Report # 54 Customer: Well: Area: Location: Rig: ODSN-22 26-May-2015 Total Charges: Rig Activity: Cor Solids - Avg Min YPPV - Lime - Max Date: Time: Laying Down BHA ECD (ppg) Flow In (gpm) Flow In (spm) SPP (psi) Current Pump & Flow Data: ENVIROMUL - Ratio Mud Data Depth 85.5/14.522208' cP Oil / Water 18 1-2-CT-C23-E-1-WT-BH ml/30min 6.22- (lb/100ft2) ConditionFootage 12.0 Mud (lb/bbl) 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 =10,000 UnitsN/AConnection - C-4i Trip (max) 89 4 665 Average 616 100% Gas In Air 47 03 70098 C-2 0 0 - C-5n Lst - Chromatograph (ppm) - 043 Depth in / out Mud Type in Cement C-1 C-5i -- - 0.994 2591 2462'14.5 158' 22.97 HoursTFA Weight - Ss Cht Silt - Size Current - ROP (ft/hr) Max @ ftAvg - MWD Summary Depth PWD / ABI / 4" Triple Combo -- % 3.55 @ 96% to - Tools - 22208' 22208' 0'24 Hour Progress: 0 Yesterday's Depth: Current Depth: RPM 0 1945 API FL L-80 0 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 N/A 0 96 0 Bit # 1 10.20 (current) Units* Lithology (%) Bit Type Depth 10.20 Gas Summary 616 N/AMinimum 0 Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Siltst 6548' MD / 3221' TVD Clyst 60.0 2655 Logging Engineers:Kerry Garner / David Durst (max)(current) Surface Maximum 11740' - 32 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 0.40 11720' 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 . . * 24 hr Recap: 15726' 0'-- 2-1-WT-A-E-I-ER-BHA7Baker Hughes / RC216 6.125 0.920 0.00 15726' basket, function rams and flush stack. Set test plug and test BOP's. Lay down test tools and make up Baker sub magnet assembly. 8 Casing Summary to 1623’ MD. Clean and clear rig floor. Rig up GBR tubing tools. Hold pre-job on running 4.5" tubing. Run 4.5" 12.6# C-110 Hyd-521 from surface Mud Loss (24hrs): 0 bbls Max Gas = 186 units, Avg Gas = 8 units L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- 15726' 22208' 6482' 20.0 100 3-4-BT-A-X-I-ER-TD 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 8 HDBS / MM64 6.125 0.389 82.36 6 HDBS / SFE46D 8.5 1.107 56.70 11740' 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' Finish laying down BHA and clear rig floor. Pick up 54 joints HWDP and flush, rack back. Pull wear ring, pick up junk Comments - C-4n Density (ppg) out (sec/qt) Viscosity 030 3Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 ROP R. Klepzig, M. Thornton 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: Morning Report Report # 55 Customer: Well: Area: Location: Rig: ODSN-22 27-May-2015 Total Charges: Rig Activity: Cor Solids - Avg Min YPPV - Lime - Max Date: Time: Running 4.5" Liner ECD (ppg) Flow In (gpm) Flow In (spm) SPP (psi) Current Pump & Flow Data: ENVIROMUL - Ratio Mud Data Depth 85.5/14.522208' cP Oil / Water 18 1-2-CT-C23-E-1-WT-BHA ml/30min 6.22- (lb/100ft2) ConditionFootage 12.0 Mud (lb/bbl) 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 =10,000 UnitsN/AConnection - C-4i Trip (max) 9 0 120 Average 616 100% Gas In Air 5 00 15647 C-2 0 0 - C-5n Lst - Chromatograph (ppm) - 011 Depth in / out Mud Type in Cement C-1 C-5i -- - 0.994 27146 2462'14.5 158' 22.97 HoursTFA Weight - Ss Cht Silt - Size Current - ROP (ft/hr) Max @ ftAvg - MWD Summary Depth - -- % 3.55 @ 96% to - Tools - 22208' 22208' 0'24 Hour Progress: 0 Yesterday's Depth: Current Depth: RPM 0 213 API FL L-80 0 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 N/A 0 27 0 Bit # 1 10.20 (current) Units* Lithology (%) Bit Type Depth 10.20 Gas Summary 186 N/AMinimum 0 Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Siltst 6548' MD / 3221' TVD Clyst 60.0 465 Logging Engineers:Kerry Garner / David Durst (max)(current) Surface Maximum 11740' - 0 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 0.40 11720' 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 . . * 24 hr Recap: 11720' 5142' 15.0 140 0-0--NO-A-X-I-ER-TD4HDBS FXG65S 10.625 1.353 70.76 6578' 60 2-3-WT-AR-E-2-ER-BHA - 5 Baker Hughes GT-C1 8.5 0.920 0.40 11720' 11740' - 0 20' 17.0 9.625"11717' MD / 4915' TVD Intermediate 1 Sh 40.0 Clyst 60.0 12579 Logging Engineers:Kerry Garner / David Durst (max)(current) Surface Maximum Cly 107.0 H-40 Grade 16.00'' Type 11.75'' Set At Siltst 6548' MD / 3221' TVD Depth 10.25 Gas Summary 1193 N/AMinimum 0 Bit # 1 10.20 (current) Units* Lithology (%) Bit Type N/A 0 561 69 0 Alkal Coal - Gallons/stroke Tuff - Gvl L-80 Yesterday's Depth: Current Depth: RPM 0 5748 API FL L-80 to - Tools - 22208' 22208' 0'24 Hour Progress: 0 MWD Summary Depth - -- % 3.55 @ 96% Current - ROP (ft/hr) Max @ ftAvg - TFA Weight - Ss Cht Silt - Size - - 0.994 27107 2462'14.5 158' 22.97 Hours 68283 Depth in / out Mud Type in Cement C-1 C-5i -- C-5n Lst - Chromatograph (ppm) - 0 0 104115 C-2 250 00 3670 Average 1193 100% Gas In AirTrip (max) 638 26 =10,000 UnitsN/AConnection - C-4i 2620' Size 158' MD / 163' TVD -Conductor 2620' WOB Baker Hughes MXL-1V 16.0 39 1-2-CT-C23-E-1-WT-BHA ml/30min 6.02- (lb/100ft2) ConditionFootage 12.2 Mud (lb/bbl) ENVIROMUL - Ratio Mud Data Depth 85.5/14.5 cP Oil / Water 21 Date: Time: Running 4.5" Liner ECD (ppg) Flow In (gpm) Flow In (spm) SPP (psi) Current Pump & Flow Data: Cor Solids - Avg Min YPPV - Lime - Max Morning Report Report # 56 Customer: Well: Area: Location: Rig: ODSN-22 28-May-2015 Total Charges: Rig Activity: ROP R. Klepzig, C. A. Demoski 24 hr Max Caelus Energy Alaska Oooguruk Island North Slope - Alaska Nabors 19AC Report For: 20' 24.0 60 0-1-CT-C1-E-I-NO-BHA C-3 96Background Job No.: Daily Charges: 12:00 AM AK-AM-0902261396 0 106010 Density (ppg) out (sec/qt) Viscosity 6558' Ran 4.5" Liner from 1623’ MD to 6712’ MD. Picked up and ran in the liner hanger. Rigged down power tongs. Comments - C-4n 2 Baker Hughes VM-1 14.5 0.994 43.39 3 Baker Hughes GT-C1 10.625 0.942 0.23 6558' 3938' 19.0 119 1-1-CT-A-E-1-ER-TD Report By:Unit Phone:(907) 670-6636David Durst 6578' 6 HDBS / SFE46D 8.5 1.107 56.70 11740' 15726' 3986' 20.0 143 1-1-BT-S-X-I-ER-TD 8 HDBS / MM64 6.125 0.389 82.36 15726' 22208' 6482' 20.0 100 3-4-BT-A-X-I-ER-TD L-8026.0Intermediate 215699' MD / 6079' TVD7.00"- at 2 BPM, 640 PSI. Started seeing losses at 2 BPM, reduced rate to 1 BPM and losses stopped. Ran liner in on 4" drill pipe from Mud Loss (24hrs): -18 bbls Max Gas = 1193 units, Avg Gas = 63 units 15726' Changed over to 4" drill pipe handling equipment. Picked up bumper sub magnet assembly. Circulated 2 bottoms up at 6809’ MD 63 Casing Summary 6809’ MD to 15469’ MD at 40 FPM, pumping 30 strokes every 10 stands. Currently running in the hole on drill pipe at 15469’ MD. 15726' 0'-- 2-1-WT-A-E-I-ER-BHA7Baker Hughes / RC216 6.125 0.920 0.00 ! " # $ %&' ! ' (& ) &' *+ &' ' ,- ' - ' & .)' !"#$ %!&%' ( )* #+, - ' - '. / &' !"#$ %!&%' ( )* #+, - " . &' 0 !' / !' %& 0' ! !'1#+ ).23 - ,#+ ), 1- , 4( 5 1 3 1 /3 33 ( )' ( )' 1 ' " .' 213 2"3 4& / )(' ( (( ( (( '6($#6( $ %7 '+6 +$ ' #$ %(.)1' ( (( (8 +! +7 #%(8# ! + #7 - & 567 8) . 5*7 ! 9 567 )"!& 9:; (#( %<#%< (#% #+ $% 7# (# % 6 (( . '+ ' 9 )" ' # ( , 01,5 + & &' .8 !5*+7 5 7 2"3 5 7 & 567 213 5 7 * .' 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