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Coated) Hydril-563 Production TubingHAL 5-½” Oil Swell Packer4-½” x-cplg cable clamps, for ESP Power Cable, (1) 3/8" Chem Inj LineSP08-N7Dual Lateral Producer with ESP LiftNikaitchuq Field –Spy Island5-½” Silver Bullet Ecc. Nose Guide ShoeAs Completed12/24/2020 Interm. Casing 9-5/8", 40# 8,030' MD, 4,068' TVD84º Inc.Slotted Liner,5-½” 15.5 ppf15,860' MD, 3,999' TVD101º Inc. 7,830' MD, 4,042' TVD - Baker SLXP Liner Hanger/PackerSurf. Casing13-3/8", 68 # 2,677' MD, 2,472' TVD33º Inc.7,237' MD 32# Shroud Gen2 Assembly with cable and chemical injection line feed-thru, 3.5" Perforated Gas Dispersion Tube7,231' MD, 3,954' TVD, 81º Inc – Bottom of Motor Centralizer Centrilift, ESP, 59 stg, 538 PMSXD Flex 47 + 20 stg 538 PMSXD GINSPHH pump, 5.13 GSB3DB seals, 150 HP MTR 562XP motor. 7,169' MD, 3,941' TVD - Discharge Gauge Sub7,630' MD, 4,017' TVD – L1 - Baker SLXP Liner Hanger/Packer5-½” Silver Bullet Ecc. Nose Guide Shoe with Bent JointHAL 5-½” Oil Swell Packer7,791-7,808' MD, Planned Casing Exit WindowSlotted Liner,5-½” 15.5 ppf15,828' MD, 4,012' TVD92º Inc.Item (Lower Lateral) MD (ft)5 1/2" Oil Swell Pck #1 82925 1/2" Oil Swell Pck #2 103155 1/2" Oil Swell Pck #3 112325 1/2" Oil Swell Pck #4 126695 1/2" Oil Swell Pck #5 13887Item (Upper Lateral) MD (ft)5 1/2" Oil Swell Pck #1 7,845 5 1/2" Oil Swell Pck #2 8,539 5 1/2" Oil Swell Pck #3 9,829 5 1/2" Oil Swell Pck #4 12,011 5 1/2" Oil Swell Pck #5 13,492 5 1/2" Oil Swell Pck #6 15,168 35' MD, 35' TVD Swivel Joint Hydril-563 By Samantha Carlisle at 11:21 am, Oct 22, 2020 320-451 MGR22OCT20 BOPE test to 3500 psi. 24 hour notice to AOGCC to witness. 10-404 SFD 10/22/2020 DSR-10/22/2020 10/23/2020 dts 10/23/2020 RBDMS HEW 11/9/2020 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.perfelici@eni.com October 21st, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SP08-N7 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP08-N7. SP08-N7 is a dual lateral producer well with ESP lift. The well was completed on Spy Island on November 14th, 2013 with a through-tubing conveyed electric submersible pump (TTC- ESP). In July 2014, a workover was performed to run a new TTC-ESP to optimize production. Production was restored until September2018, when the well was shut-in due to a suspected tubing leak. A workover was performed in October 2018 and a new ESP was run in hole. The well has been continually operated until August 8th 2020, when the ESP suffered an electrical failure. The estimated date for beginning this work is December 25th, 2020. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Alessio Medea at 907- 865-3347. Sincerely, Stefano Pierfelici Well Operations Project Manager SP08-N7 Workover – Proposal Summary and Wellbore Schematic PTD#: 213-134 Current Status Well SP08-N7 is currently shut down due to an ESP electrical failure occurred on August 8th, 2020. Scope of Work Scope of this workover is to pull the current ESP tubing completion and recomplete with a new conventional ESP system and coated tubing. Repair has to be completed with no HSE accidents or incidents, to comply with state AOGCC and company requirements. General Well Info Reservoir Pressure/TVD: Wellhead pressure during shut-in is around 1200 psi Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/Pipe/Blind/Pipe Well type: Producer Estimated start date: December 25th, 2020 Drilling Rig: Doyon 15 Drilling Engineer: Alessio Medea Alessio.medea@eni.com Work: 907-865-3347 Well Operations Project Manager: Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 Procedure Summary 1. MURU Doyon 15; 2. Kill the well; 3. Set BPV; 4. N/D X-tree; 5. Set Blanking Plug; 6. N/U BOP and test to 250/3500 psi; 24 hour notice to AOGCC to witness; 7. Pull out of hole Blanking Plug and BPV; 8. POOH tubing and lay down ESP assembly; 9. Perform a contingent clean-out run; 10. PU a test packer, set at 7500 ft MD to test 9 5/8” casing to 1500 psi; 11. MU new ESP assembly and RIH new coated tubing to setting depth; 12. Land hanger and test it; 13. Install BPV; 14. N/D BOP; 15. N/U tubing adapter and X-tree; 16. Pull BPV; 17. Install Two Way Check Valve and test X-tree; 18. Circulate Freeze protect through X-tree down IA; 19. RDMO. Below the current schematic of the well: Vetco Gray, MB-247/5000 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Plug Perforations LJ Fracture Stimulate U Pull Tubing L Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ESP Chance Out ❑� 2. Operator Eni US Operating Co. Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic ❑ Exploratory ❑ Service ❑ 213-134 3. Address: 3800 Centerpoint Dr Ste 300, Anchorage, AK 6. API Number: 99503 50-62923501-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 0391283, 0388583,0388581, 0388571 SP08-N7 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Nikaitchu / Schrader Bluff Oil Pool 11. Present Well Condition Summary: Total Depth measured 15870 feet Plugs measured N/A feet true vertical 3997 feet Junk measured N/A feet Effective Depth measured 15860 feet Packer measured N/A feet true vertical 3999 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 2677 13-3/8" 2677 2472 5210 2480 Intermediate 8030 9-5/8" 8030 4068 6890 4790 Production Liner 7830 5-1/2" 15860 3999 slotted slotted Perforation depth Measured depth 8,030-15,860 feet True Vertical depth 4,068-3,999 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 11.6 ppf L80 7221 MD 3952' TVD Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl I Casing Pressure I Tubing Pressure Prior, to well operation: 1105 27 1699 1250 1260 Subsequent to operation: 1330 105 11589 1285 1297 14. Attachments (required per 20 AAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development Service ❑ Straligraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Ld Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct t0 the best of my knowledge.Sundry Number or N/A if C.O. Exempt: S g6& —J9 Authorized Name: Stefano Pierfelici Contact Name: Amjad Chaudhry Authorized Title: Well Operations Projeckmanager Contact Email: amiad.chaudirmuleni.com ( 907-865-3379 Authorized Signature: � � Date: ot o vIIl ♦ Contact Phone: Z-Ze, t if Form 10-404 Revised 4/2017 RBDMS Fe 0 8 1019 Submit Original Only \ \0 m LO \ ) � f_§ CDL @ 1 It (D 00 3 K \2 £\Em2&§ �/ m7 6�oa o[ rL CD \m(j\§ _ {/2®§$>�2 c�� .) �w U �cCD n �\§{ ��a®c §_-k/2� E o 0 \\\\/\\ _\» §2& cli ® / /»\ C� 2 00 mG GE\ 2 IL E o I) CLL�kCL 2 2 E Csl j\ �o + CL CD 0c - OL m ■U )\ o k )02 $5 }333333 f) \ _ / /§ j\/ C') \ \ {\}}\\} >:3 `° \\ }/\-2 0 \J � ° GGa66 / �� a \ \0 m LO \ ) � f_§ CDL @ 1 It (D 00 3 K \2 £\Em2&§ �/ m7 6�oa o[ Ea- \m(j\§ _ {/2®§$>�2 .) �w I �cCD �\§{ §_-k/2� o \}}}7} \\\\/\\ _\» )§ /»\ Fmk 73 GE\ )$) I) \cu �o + �AA3aG $\ x )\ a 7 }333333 f) \ _ / /§ j\/ \ \ {\}}\\} `° \\ }/\-2 0 \J � ° GGa66 / s \CO $moo § Sa % 3LIJ0- co 2 . CL \7*�7§ \\ 24 \ » a) LO L) r 2 D D\ -®\~�� E 4 40- ® ,AAA \ \0 m LO \ ) � f_§ CDL @ 1 It (D 00 3 K £\Em2&§ m7 6�oa \�> \m(j\§ o -Jr {/2®§$>�2 �w I �cCD \ \0 m LO \ ) � f_§ CDL @ 1 It (D 00 3 £\Em2&§ \m(j\§ 2,=,g;; I \}}}7} \\\\/\\ )$) I) �AA3aG }333333 \ \0 m LO \ ) � f_§ CDL @ 1 It (D 00 3 \| £\Em2&§ 2,=,g;; \\\\/\\ }333333 {\}}\\} \| Well Header Well Name:P Wellbore Name: e: -1,17 O -N 7 Daily Report ani Well Code: 27537 Job: WORKOVER WCER Level: Date: 10124/2018 Report#: 1 Page:I oft Well Header PenniOConcession N° OperawrSmiddle, Initial "has Code AIASKA ENIPETROLEUM ENIPetmleum Co. Inc DEVELOPMENT WELL O POZZO DI COLTVAZIONE Rotary Table Elevation (R) Ground Level 00 Fire- Flange lh) WE -Base Flange IRITubing "pool ("I 5393 32.805.12 1]19 36.74 Rigs Rte Name Contractor Rig Type Rig Num Rig Sort Date Rig Release Data Daily Information Weather Temperature (°F) wind Days LTI (days) Days M (days) PDB Overcast 28.4 SW @20 MPH 33100 33100 81.0 Safety Incidents - Near Miss pate Category Type Subtype Severity Cause Lost time? Comment Safety Drills I Days Until Next Chttk Type Is Occur Last Data Next Dale (tlays) Rig Inspection n 1 101242018 1025/2018 1 Safety Meeting 1 10/24121118 102512018 1 Casings seat Co.. Type Go (in) IG (in) Grace Tup1hKB) Bottom III TVD Bot (RKS) Run Data CONDUCTO20 18.25 X65 0.0 160.0 160.0 9292013 CASING 13 LB 1242 480 443 ABT7.0 2p710 iM62013 CASING 95M 8.84 L - a0 0.5 8.030.4/ 4,0680 1-6162013 LINER 512 483 L-00 7,8296 15,080.0 3,999.9 10272013 Last Cementing Cementing Sbrt Date: 10/182()13 Shing: CASING. 8.030.OftKB Comment: Stg # Tap IaKB) Top Meas Meth a. (ftl(B) Com 1 5,0000 Temperature Log 8,0 .0 down ng pumps and Schlumberger pumped 10 bbl. H2 to Int lines and tested lines to 900 PSI low -S3 high stall, good. Switched back ng pumping 100 teals. of 10.5 ppg Mud Push II rate of 5 bpm @ 170 par. Shutdown 8 drop bottom plug. SLB ink & pump Lead slurry 261.4 bbla. 12.5 ppg Class LleCRETE. (1.56 Yield mix water at 5.467 joras gal/sK) Pump rate 04 bpm @ ICP 140 PSI, FCP 40 PSI. SLB pump 10 bible H2O and wash up, Displaco with 592 bola 9 25 ppg treated mud with rig pump at 5 bpm w/ 460 psi, slaw to 3 bpm at 570 bbl away, FCP 710 PSI, Bump Plug P"I up to 1.210 PSI held 5 Min. Bleed off goats holding. Cement in place @ 11.12 hre. Job Information Job Phase Planned Skirt Dale "tart Dale Entl Date PW Duration (days) WORKOVER 10Yt4201818:00 10.24201818:00 0.00 Daily Summary Operations Ids Forecast Set liner and matting boards. Finish preparing to were dg, move ng over SP -00. Sled ng up. an Summary Finish cleaning plus. LRS finish bull heading kill fluids. Move components and prepare W move rig Oceraoon -.t07 00 Rig Move Operations Time Log Start EntlCum Dur Trine Time Dw(hn (ten Pha3e Our. I Act Plan Opec Green 1800 :00 d no 600 OMP M 2 P Final came, palls. Maya generator p5, mud pump WD and mud pump Q. Clean court yam and prepare W lay liner. LRS finlsb pumpag 1100 ods 9.3 ppg brine dawn A annulus to NII well pr w musty pumped 172 able down tubing. Blow down steam and water on sub. Skid dg floor. Commu kation between tubing and A annulus. Total of 9.3 ppg boxes pumped into well =1273 bids. Gas Readings Avg Background Gas (%) Max Background Gas (%) Avg Connection Gas (%) Mex Connection Gas (Y.1 Avg Drill Gas (%) Max Drill Gas (%) Avg Trip Gas (%) Max Trip Gas (%) Cumulative Mud Volumes Active Volume(bbff Hold Volume Intel) Additwobl) Cum Additions(bluff Losses hieff Cum Losses(bbl) Daily Contacts Position Contact Now Company Title Email OMs. Nablus Eni representative a.. Simons- Enl Detling Supv xi idniting@empehoomm, coin 907-685-0715 Eni representative Mks Double Eni Drilling Supv_ slddnim tIenipebokum.com 907-6850715 Em wasemlative Wada Thomas Eni Rg Clerk AKRrgCImksDoyml 5@empetmleum. core 907()05-0722 Eni representative Palm. Em HSE Eni representative Mack Hubner Eni HSE Tool Push Jush. Heys Doyun DrAng Tool Pusher ml5@doyondn9ing corn Tool Push Ted Kreger Doyvn Ddlling Tour Pusher ng15@doyondMling.com 907-6850718 Tool Push Handful Ri.bams- Carrier Drilling HSE hnchardson@doymdnllhg.cam 685-0796 Tool Push Gave Sen. Doyon Calling HSE dean@doyendnlling.com 685-0796 Personnel Log (P( B) Company Sam. Type Work H (hr) Stand4ry H (hr) Count We Amher Commissioning 12.50 0 Brining Doyon Field Superintendent 12.50 0 Drilling Centg Rig Watch 12.50 0 DnIIIng ASRC Cite 1250 1 Drilling ASRC BOA 1250 1 SID Support ASRC Crane Advisor 12.50 1 SIDSupport Beacon Medic 12.50 1 SIDSuppart Namlem OifleOd Services pusher 12.50 1 SIDSUPWit ACS Enviromental 12.50 2 SID Support ASRC Conway Man 12.50 2 Drilling Seacon HSE12,50 2 SID Support Dwan Tool pushers 12.50 2 Doling Do, HSE 12.50 2 Ddlrng Well Name: SP08-N7 OR Wellbore Name: SP08-N7 Well Code: 27537 Job: WORKOVER WCER Level: Daily Report Date: 1 012 412 01 8 Report #: 1 Page: 2 of 2 Personnel Log (POB) Company Serv. Type Work H (hr) Stand-by H tun Count Noh LBOe Red Services Pumping 12.50 2 SID Support MI Swans Mud Plant 12.50 2 Drilling Halliturian Mud loggers 12.50 2 On ling V.I. Grey Wellhead 12.50 2 DdOng GBR Casing S.M. 12.50 2 Drilling ASPIC Logistic 12.50 3 SIDSuppod Ml Swam WIF 12.50 4 SID Support Purcell Security 12.50 4 SID Support Baker Hughes Baker Hughes Cenbilin 1250 6 Drilling Jam55 Truck treat l Crime operator 12.50 10 Wing ESS Caleb, 1250 10 SID Suppod D,mu Ry Personnel 1250 19 Dtllling_Total D,IINg PemoUmu54 Daily Bulk Supply Item Descthalon: Equipment Fuel Unk Label: Gel Unit Size:I Note: Data armed Receive0 Reported Cum Consumed Gum Received Cum ReWrned Cum On Loc Note 1012412018 1019.0 1,O1B.0 1.019.0 1,0190 00 0.0 Supply Icahn Description: Mud Rant eollem Unit Ubel: Gal Unit Size: Note: Date Consumetl Recelvetl Returned um nsumed Cum Recelvetl Cum Returned Cum On Lac No[e 10124/2018 198.0 198.0 188.0 1980 00 00 Su ply lkm Description: Ry Fuel UnNLabN: gel us Umtsize: 1 Note: Dale Consumetl Recelvetl Returned Cu. Consumed Cu. Recelvetl CUM Returned Cu. Oa Loc Note 10242018 1688.0 10,23].0 1,888.0 10.237,0 00 8,549.0 Sup y Item Desert non: Rig Waler UMt Label: bbl Unit Size: 1 Note: Doh Consumetl Received ReWrnetl Cu. Consumed Cu. Recelvetl U. Returned Cum On Loc Note 10242018 50.0 166.0 50.0 lo30 00 1160 Supply Item Deatdptlen: WIF aoilem UMt Label: Gal Unit Size: Note: Oare Consumetl Remived Remrnetl Cum Consumed Cum Received Lum Returned Cum On Loc Note 10242018 42.0 42.0 42.0 42.0 00 00 supply Item Oescripdon: WIF Injected Diesel Unit Label: Gal Unit Size: rush: Data Consumetl Recelvetl ReWrnetl Cum Consumetl Cum Recelvetl Cum Returned Cum On Loc Note 102M2018 420.0 4200 420.0 4200. 0.0 0.0 Last Authority Visit Date Tot map Nbr real I.N.C. number Comment STOP cams 1111,11niffed Company allots Cum Doyon Drilling 6 PJSM'S Doyen Drilling Inc. 6 Sale Cams Doyon Drilling Inc. 2 HRWS Doyon Drilling Inc. 2 COW Ml Swans 4 RIR's Ml Swaco 4 HARCUSA General Notes Comment: Well Name:7 OR Wellbore Name: e: SP SP08-N-N7 Well Code: 27537 eI'I Job: WORKOVER 11 X91 II II WCER Level: Daily Report Date: 10/2512018 Report #: 2 Page: 1 of 2 Well Header Penniti0oncession N° Operator Subsidiary Initial Lane. Code ALASKA ENIPETROLEUM ENI Petmieum Co. Inc. DEVELOPMENT WELL O POMO OI COLTIVAZIONE Rotary Table Greaten (R) Gmund Level HtFist Flange (R) RKB -Base Flange (m RKB -Tubing Spool (K) 53.93 32,805.12 17.19 W.74 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Data Daily Information Weather Temperature ('F) Wind Days UP (days) Days RA (do,.) POB Overcast 24.8 SW@17 MPH 33200 33200 00.0 Safety Incidents - Near Miss Data Category Type Subtype Severity Cause I L051 time? Comment Safety Drills Days Undl Next Check Type #Occur Last Date Next Date (days) Rig inspection 2 10252018 ID2fi12018 1 Safety Meeting 2 1025!2010 101282010 1 Casings seat Conifer I Do (in) ID (in) Ginnie Top(RKB) Beft.HKB) I TVD BOL(0K8) I Be. Data ONDUCTOR 20 18.25 %65 0.0 160.0 160.0 0 CASING 133/8 1242 L -ell 44.3 2,67]0 $471.9 10/6/2013 CASING 95/8 854 L-80 0.5 0,030.0 4,0880 lWlMD13 LINER 512 4.83 L-80 7,829.6 15,Bfi80 3,899.9 102712013 Last Cementing Cementing Sht Date: 10/182013 String: CASING, 8,03008KB Comment: Top Meas Meth RM (we) COI. Temperature Lag 0,030.0 Sbuo down rig pumps and SCMumberger pumped 10 bass. H2O to MI lines and tested lines LO 900 PSI low S 3,600 PSI high stall, good. SwOched back ng Pumping 100 clubs. of 105 ppg Mud Push If rah of 5 bpm @ 170 psi. Sh rt-dwn 8 112ti��NILU ,,up bottom plug. SLB mk 8 Pump Lead slurry 261A bis. 125 ppg Class UIeCRETE. [1.56 Yield, her water at 5,467 gatlakJ Pump mte of 4 bpm @ ICP 1 W PSI, FCP 40 PSI. SLB pump 10 bas H2O and wash up. Displace with 592 hobs 9.25 ppg Posted mud with rig pump at 5 bpm w1460 or saw h 3 bpm al 570 bbl away. FCP 710 PSI, Bump Plug PSI up to 1,210 PSI held5 Min. Bleed off floah hoMing. Cement In place @ 11:12 hrs. Job Information Job Phase Planned Sort Date Start Date End Data P50 Duration (days) WORKOVER 1024201016:00 1 10124/20181890 ON Daily Summary Operations 24h Forecast Complete ng up and ng acceptance. MU SUPE. Perform BOP haling (wowed by AOGCC). Rig up apoobmg unit add sheaves. Rig up tubing handling equipment. Pull tubing hanger and start Wiling tubing and ESP assembly. 2M Summary Set liner and mark. Move sub and pits module to SP -08. Set up mud pump #S pump VFD unit and Kemal Sled banning and rigging up interconnects on or, Question at 07.00 Completing MIRU Operations Time Log Stat Endcum Our Time Time our Sri (M1n Phase 0, Act. Plan Oper. Credit. 0000 06:00 600 600 W.O. A 2 P Set heBuldh and male. Empty dg water tank. Bow down steam b pita Disconnect pits electrical. Rig down berm sedum eMmtrces 0 dg. moo 1200 6.00 12.00 WO A 2 P ova pits sway sub. Pull sub oh well and finish seleng mats. Crab sub down well row. Spat sub over SP40 and start to shim. M. plot down Me wall new 1200. 18 W 6.00 1800 W.O. A 2 P Lower sub stompers and skirt rig floor to drilling portiion. Spot pits and pump module, Rig up intemonrm. between park and sub. Lay drab for auv modules on west site of ng. Make up under rig floor and choke manifold imemmneds. Stan building banning around ng. 1000 moo 6.00 24.00 W O. A 2 P tan building harming around dg. Spot mud pump AS Spat ganedator #5. Ptug in top drive and mud pump #3. Spot mud pump VFD mut Set up maltitg boaMs aM betming far Koomay unit. Gas Readings Avg Background Gas I%) Max Background Gas I%) Avg Connection Gas Pt) We Cornerstone Gas(%) Avg Drill Gas 1%) Max Drill Gas (%i Avg Trip Gas (Y.) Max I "Gas (%1 Cumulative Mud Volumes Mold, Volume/bbl) Hole Volume(bb0 infamous (hot) Com AddMons(ab) Losses(boo Cum Laurie. (bei Daily Contacts Position Contact Name Company Tide Email OBMe Mobile End representable a.. Sinmmon En! Dolling Supv, uddolling@emp Andeum.com 907-685-0715 Em repreaentathe Militia Grubb Em Drying Supv. siddMling@eniWtmhumcom 907-685-0715 End represantatdve Wada Thomas Ear Rig Clerk AKRigOebroaDfi nl 5@enipetmbeden cam 907-605-0722 But reprefintate. Pat Ahem End HSE Ent mpresentaPo. Me* Hoofer End HSE Tool Push lust. Heys Doyen DNbing Tool Pusher "gl5@tloymMtlllingcpm Tool Push Ted Kreger Doyon DBtidng Tour Pusher r1u15@doyanddlldngcom 907-6850716 Tool Push Hamid Richardson Doyon Drill, HSE hnchaMson@doyonddlling.com 885-0791 Tool Push Scop Simmons Doyon Drilling HSE Personnel Log (P( B) Company Sam. Type Work H(bl I Stan- yH(hn I Count I Note Archer mmdseards, 12.50 0 D of, Doyon Field Superintendent 12.50 0 Diming Carl Rig Watch 12.50 0 Drilling ful Cad, 12.50 1 Coding ASRC SOA 12.50 1 SID Supped ASRC Crane Advdam 12.50 1 SID Support Search Medic 1250 1 SID Support Well Name: SP08-N7 OR Wellbore Name: SP08-N7 Well Code: 27537 Job: WORKOVER WCER Level: Daily Report Date: 10/2512018 Report #: 2 Page: 2 of 2 Personnel Log (POB) Company Sion. Type Work H (hr) StantlLy H (hr) Court Note Northern OdteiM Services Finder 12.50 1 SID Sopron ACS Enommental 12.50 2 SID Support ASRC Compnry Man 1250 2 Drilling Beacon HSE 1250 2 SID Suppori Dayan Tod pushers 12.50 2 Droing Doyon WE 12.SD 2 Dolling Lima Retl Services Pumping 12.50 2 SID Sup,n MI Sam. Mutl Plant 12.5D 2 OMling Halliburton MW loggers 12.50 2 Count; Vence Gray Walinsnd 12.50 2 Drilling GBR Casing Service 12.50 2 Drilling ASRC Logistic 12.50 3 SID Support Ml Sweco WIF 12.50 4 SID Support Purcell Security 12.50 4 SID Support Baker Hughes Baker Hughes Centrild 12.50 6 Dnlling Jacobs Truck shno/Came operator 12.50 9 Dtlring ESS Catering 1250 10 SID Support Doyon Rig Personnel 1250 19 Dritling Total Dolling Personnel 52 Daily Bulk Supplyltsm Description: Equipment Fuel Unit Label: Gal Und Sizer/ Note: Ort. Consumed Receivetl Serum Cum Consumed Cum Receivetl (tum Returned 0. Lot Note t 01292018 1086.0 10860 2,105.0 2,1050 00 1C. 00 Supply Ilam Description: Mud Plant Solkes Unit Laird: Gal Unit Size: Note: Data ConsumetlReceived Returned Co.Cum Cansuetl Cum ReceivCu.,etl CuReturned Cum On Loc Note 108512016 198.0 1980 396.0 396.0 0.0 0 0 Supply Item Description: Rig Fail Unit Labe: gal us Unit Size: 1 Note: Data Consumetl Receivetl Returned Cum Consumetl Cum Received Cum Returned tum On Loc Note 10252018 1467.0 00 3,1550 10,23].0 0.0 7.0820 Supply Ilam Description: Rig Waler Unit Labe: atil Unit Size:1 Note: Data Cansumetl Receivetl Returrred Cum Consumed Cum Received Cum Rdurnetl Lum On Let Note 10252018 0.0 0.0 50.0 165.0 00 116.0 Supply Rum Description: WIF "a Unit Label: Gal Unit Size: Note: DataConsumed Received Returnetl Cum Consumed Cum Received Lum Assumed Cum On Lm Note 10252018 42.0 42.0 84.0 84.0 DO 0.0 Supply Rem Description: WIF Injected Diesel Unit Label: Gel Unit Size: Note: Data Cansumetl Received Remrnetl Cum Consumed tum Reear ed Cum Returnetl Cum On Lac Note 10292018 420.0 420.D 840.0 8400 00 0.0 Last Authority Visit Date Td I., Nbr Total I.N.C. number Comment STOP Cards Submitted Lcai p Rets Co. Doyon Crime 4 PJSM'S Doyon Coding Inc. 8 Safe Cams Doyon polling Inc. 4 MWS Doyon Drilling Inc. 4 COW MI Sees. 4 RIRY Ml Swaco 4 HARGJSA General Notes Comment: Well Name:7 OR Wellbore Name: e: SP SPOS-N-N7 Well Code: 27537 Job: WORKOVER e IP51 11 i WCER Level: Daily Report Date: 10/26/2018 Report #: 3 Page: 1 of 2 Well Header PermithConcession N° Operator Subsideary Initial Lance Code ALASKA ENIPETROLEUM ENI Petroleum Co. Inc. DEVELOPMENT WELL O POZZO 01 001-TIW21ONE Rotary Table Elevation(fp Least (it) First flango got RKB-ease Flange(1t) RKB-Tubing Spoul(ft) lumber! 5393 32,805.12 1].19 36.74 Rigs Me Name Contractor Rig Type Rig Num Rig Start Debt Rig Release Date Daily Information Weather Temperature l°F) Wena Days LTl (tlays) Days Ell ldaY%I Po6 Cloudy 24 8 N 09 MPH 333.00 333.00 77.0 Safety Incidents - Near Miss Dale Category Tyve Subtype Severity Cause Losttime9 Comment Safety Drills Days Until Nem Check Type #Occur Last DateNext Dale (day.) Rig Inspection 3 102612018 1012]12018 1 Safety Meeting 3 1012612018 102712018 1 Casings seat Cas. Type 00 (in) ID ling Grade Top HtKB) Bottom(RKEd I TVD BOt(ftKB) Run Data CONDUCTOR 20 18.25 85 0.0 1 1600 92912013 CASING 13318 1242 L -Bit 44.3 2,fiR0 24719 tOR2013 CASING 9518 8.84 L -8D 0.5 8,0300 4,0880 IWIW013 LINER 512 4.83 L-00 7,829.6 15,a80.0 3,9999 10.272013 Last Cementing Cemendrg $fin efh: 101182013 Sb m: CASING, 8,030.01KB Comment Slit Top Meas all Bhn (focal mCo000 0 Temperature Log 0,030.0 PSI Shut -n-,;Fp-..pa and Schlumberger pumped 10 hot. H2O to fill lines and tested lines h 900 PSI low 8 3' No high stall, good Switched back M pumping 100 this. of 105 ppg Mud Push II rate of 5 bon Q 110 psi, Shut-0exn 8 r drop bottom plug. SLB and 8 pump Lead slurry 261.4 bbes. 125 ppg. Class LNCRETE. 11.56 Yield, mix water at 5467 gallsk I Pump rah of 4 bpm @ ICP 140 PSL FCP 40 PSI. SLB pump 10 bbls H2O and wash up, Displace with 592 I bbls 9.25 ppg Treated mud with rig pump at 5 bpm 031480 psi, slaw to 3 bpm at 570 bbl away, FCP 710 PSI, Bump Plug PSI up to 1.210 PSI heed 5 Min. Bleed off floats holding, Cement in pairs @ 11:12 bra. Job Information Job Phase Planned Start Doh Sort Date End Data Pyo Duration (days) WORKOVER 1024201816:00 1/24201818:00 0.00 Daily Summary Operations Zan Forecast Finish performing BOP telling (waived by AOGCC). Rig up apoohn, unit and sheaves. Rig up tubing handling equipment Pull tubing hanger and start Wiling tubing and ESP assembly 24h Summary Complete dg up and ng acceptance. Nipple down tree and nipple up BOP and lunation test. AOGCC Bop Not witness waived by Austin McLeod Test gas alarms. Stan testing BOPS. Operated at 07.00 Testing BOPE Time Log Sart End Cu. Dur Time Time Dur dr) (fin Phase I OPr. I Act Plan DR., Deapr. 0000 08:30 8.50 8.50 W. . A 2 P Bleed pressure from tubing on SP -08.14 psi to 0 psi 1 gas only). Set MI shack, finish terming rig. Clean up marriage from SP -21. Set slop tank and Hoak up kommsy hoses. Rave pipe shed skid supports. Prepare rig and take on wale to teal lines and III pump #3. Test lines and connections as 35M psi. SIM OPS'. Conduct weeny derrick inspection. Take on 694 bines of 9.3 ppg brine from mud plant thm suit cases. 08:30 100 150 1000 W.O. C 5 P Sei HMlib Wan Kid Logging Unit, add perform acceptance test (posh Verify well as dead. Make up wire line valve and lubricator and install BIW. Lay down lubricator and wire line valve. Nipple down tied. 10:00 0000 1400 24.00 WO C 12 P Clean Larger murk void, M and cep con"I line. Install test died. Nipple up ever and shale, primary antl secondary choke and all lines, deer, tlreh hoses and flow, line. Make up hoses to stack and ran Mer to name, unit. Function test all rams and valves on stack. Install 4 W but joint. Grease all valves. Test gas alars: B mPS sensom as its (sensor response with .NarroPod of 0 ppm lest gas) 43.40 ppm ® 31 sec., shale shakers 39 86 ppm W 35 sec., cellars 43.01 ppm Q 21 sec., ng floor 40.17 ppm @ 42 sen, ouvide generator room 41 ppm @ 29 secall tests in compliance. test LEL modes M die (sensor response with 50 %concenthnn of LEL Net gas) 51%@ 35 sec shale sta nds's St%@ 13 sec. cellar 49 %®22 . rig floor 51%@ 25 sec, wteee generator mom 61%@ 16 sec, all test in compliance. Finish rigging up lest equipment. Pressure test ROPE 2502500 psi high on annular. 25013500 psi on all order rams and valves. 80P test waved witness by AOGCC rep Ausfin MCLertl. Operation from 00:00 to 06:00 Stan EndCum Dur Time Time our (nn (h) Phase Op, Act Plan Order. Descr, 00:00 140 10 W 38.00 Wo, C 12 P Continue ROPE Test Pull W test pint and make up S fest join Test annular 2502500 pen. Test manually operated and motel, operated chokes. Test 1.2 5 Neu 15 choke manifold valves, primary and secondary kill damcos, manual and HCRs. Primary and secondary choke manuals and Hl upper and lower IBOP, upper and laxer variable rams with S test join(. 25013500 psi. Ratio= Worry lest Initial acn 3000 psi, after closure= 2200 psi, 200 psi gain 9 seconds, MII pressum=80 sesames. 10 nitrogen bodies average 3100 psi. Blow down choke manned Test upper pipe rams with 4 W and 5° test jokes. Will choke manibhl valves 3 and 425013500 net Test annular with 4 %' test joint 25012500 psi. test upper pipe wall %" X 7") antl lower rams (3 h° X 6") with 4W lest joint, dad valve add FOSV 25013500 psi. Poll test joint with lest dad. Blow down fast equipment. SIM OPS: Troubleshoot Pressure drop while testing upper pipe rams(4 %" X 7°)with 4'/.' lesljoinl. Continue to tlnfl antl slap 4 %- completion tubing. Gas Readings Avg Background Gas (°A) Max Background Gas (%) Avg Cwnedion Gas (%) Max Connection Gu (%) Avg Drill Gas I%) Man Drill Gas I%) Avg Trip Gas (%) Max Trip Gas I., Cumulative Mud Volumes Active Volume (bhp Help Volume (half Addlflons (bbl) Cu. Addition. (bM) Lossas Ibbg Cum Lceses (big) Daily Contacts Pwlflon Contact Name Company Title Email Ofika Mebik En representee a Bmw 5lmoncon n Dritimg Sropv. sitltlnl ing�enipelrolaum.com 90]685-0715 Enl representeWe Mike Gmbb EM Drilling Supv sidtlnllin9@epdimubdeum.wm 907685-0715 En represeMalNe Wade Thomas Eni Rig Clerk AKRgClerksOoyonl 541tenipetrateum. mum 907685D722 Well Name: SP08-N7 OR Wellbore Name: SP08-11,17 Well Code: 27537 Job: WORKOVER WCER Level: Daily Report Date: 10126/2018 Report #: 3 Page: 2 of 2 Daily Contacts Position Contact Name Company Title Emill Office Mobile Enl representatives Pat Mem Ent HSE Ens representative Mark Hubler Eni HSE Tool Push Jua(in Here Doyon Dr01bm Tool Pusher riglS@doyontlnllmg.com Tool Push Ted Kroger Carron Drilling Tour Pusher 0g15tiltloyoMtllling.com 90E050716 Tool Push Harald recreation Dopa Dallas HSE hdchaMmn@doypnddilsng.Lom 685-0796 Tool Push Scott Simpson. Doyon Drilling HSE Personnel Eog (P( B) Company Saaa. Type Work H NN Stand -lay H (hr) Count Note Archer Commissioning 12.50 0 Drilling Doyon Field Superintendent 12.50 0 Onlling Citing Rig Watch 12.50 0 Drilling ASRC Clerk 1250 1 Drilling ASRC SOA 12.5) 1 SID Support ASRC Crane Advisor 12.50 1 SID Support Be... Medic 12.50 1 SID Support Northam Would Services Pusher 12.50 1 SID Support ACS Enviremental 12.50 2 SIDSupporl ASRC Company Man 12.50 2 Drilling Bexrn HSE 1250 2 SID Support Doyon Tool pushers 12.50 2 Dulling Doyon HSE 12.50 2 Dulling Utile Red Bervlms Pumping 12.50 2 SID Support MI Banco Mud Plain 12.50 2 Drying Halliburton Mud loggers 12.50 2 0n111ng Vetm Gray WelmBad 12.50 2 Drilling GBR Calling Service 1250 2 Dntling ASRC Logistic 12.50 3 SID Support Baker Hughes Baker Hughes Cenhllla 12.50 3 Calling Ml Swaco WIF 12.5) 4 SID Support Purcell Secunly12.50 4 SID Support Jambs Track driver/Crena operator 12.50 9 pilling ESS Catering 12.50 10 SIDGupporl Doyon Rig Personnel 12.50 19 Drilling Total Drilling Personnel 50 Daily Bulk Supply Item Description: Equipment Fuel Unit label: Gal Unit Size: 1 New: Deb Donsumetl Receivetl Returned Co. Conquered Cum Recessed! Cum Returned Sum On Loc C' Note 10262018 990.0 990.0 3,095.0 3.095.0 0.0 Supply loy n Uescdpdon: Mud Plans Bcilers Unit Label: Gal Unit Size: Note: Date Consumed Recepad Returned Cum Consumetl Cum Receivetl Cum Returnetl Cum On Lac Note 10262018 198.0 190.0 5940 594.0 00 00 Supply Bem Description: Rig Fuel Unit Label: gal us Unit Size: I Note: Dela Consumed Roo Wild Returned Cum ConsumedCo. Receivetl Cum Returned Cum On Loc Note .2018 1,500.0 00 4,655.0 10.231.0 0.0 5,582.0 Supply Item Description: Rig Winer Untt Label: bbl Unit Size: I Note: Deal Comumed Received Returnetl Cum Consumed Cum Received Co. Returned Cum De Loc Note 1&Z6/2018 0.0 00 50.0 166.0 0.0 116.0 Supply lbm Descdptlon: WIFBWam Unit Label: Gal Unit Size: Note: Dare Consumetl Receivetl Returned Cum Consumetl Cum Received Cum Returned Cum On Loc Note ID262018 42.0 42.0 126.0 126.0 00 00 SuMlyltem Deecdption: WIFIn)ecald Dlesd Unit label: Gal Unit Size: Note: Dab Consumed Receivetl Returnetl Cum Consumed Cum Receivetl Lum Rammed Cum On Lon Note 102&2018 4200 420.0 1,260.0 1,260.0 D.0 00 Last Authonty visit who Tot insp. Nor Total LN.C. number Comment STOP Cards Submitted company #Rpb Co. Doyon Detling 4 PJSMS Doyon Orllling Inc. 4 Safe Lards Doyon Drilling Inc. 4 HRWS Doyon Drilling Inc. 4 COW Ml Swaco 4 RlR's Ml Seneca 4 HAROIJSA General Notes Comment: Well Name:S-N7 OR Wellbore Name: e: SPOS-N-N7 Well Code: 27537 Job: WORKOVER eni WCER Level: Daily Report Date: 10/2712018 Report #: 4 Page: 1 of 2 Well Header Permrcimcesmon N'Opeumr Subridlary Inifial Users Code ALASKA ENIPETROLELEM ENI Petroleum Co. Inc DEVELOPMENT WELL O POZZO DI COLTNAZIONE Rotary Table Elawardi RE Ground L8 We First Flange(k) RKe - Base Flange in) RKB- Tubing Spent (fid 5393 32,805.12 1].19 35.T4 Rigs Rig Name Contractor Rig Type Big Num Rig awn OM Rig Release Date Daily Information Weather Temperature ('F) Wind Days LIFE (days) Days RE plays) POB Clear 21.2 S 4 MPH 334.00 334.00 80.0 Safety Incidents - Near Miss to Category Type Subtype Severity Cause Lost tlme7 Comment Safety Drills Days Unfit Neat Check Type .Occur Last Date Next Date (day:) Aulnonty Vsit 1 102'2018 lI' 010 ] Rig Inspection 4 10/1'2018 102812018 1 Safety Mason, 4 10272018 10282018 I Casings seat Co. Tills oo (in) ID gn) Grade Top thus) Bokpm (M(B) TVD Bot (kKB) Run Date CONDUCTOR 20 18.25 X85 00 160.0 1600 9R 013 CASING 13318 12.42 L -BO 443 2.8]L0 2.4]1.9 1NS2013 CASING 95/6 8.84 L-80 0.5 8,030.0 4,088.0 EM612013 LINER 512 483 L -8(E 7,829.6 15,affit 3.9999 10272013 Last Cementing CameMfng Smit Dale: 10118IM13 String: CASING, 8.030 011108 Comment 3Ig N top (kKe) Top Meas Mem Bun thus) Com t 5,00 0 Temperature Log ..030.0 Shut down M pumps and chlumberger pumped 10 bbls. H to in an tested lines to 900 PSI low 8 3,fi00 PSI high stall, good. Switched back rig pumping 100 bels. of 10.5 poll Mud Push II Me of 5 bpm C 170 pal. Shot am 8 drop bottom plug. SLB mix 8 pump Lead slurry 2614 bbls. 12.5 ping, Class Li1eCRETE, [1.55 Yield, mix water at 5.467 flapeul Pump rate of 4 bpm @ ICP 140 PSI, FCP 40 PSI. SLB pump 10 obis H2O and wash up. Display who 592 tools 925 poll (mated mud with rig pump at 5 bpm wI 460 psi, slow to 3 upon at 570 bbl away. FCP 710 PSI, Bump Plug PSI up to 1,210 PSI held 5 Min. Bleed oh floats Facing. Cement In place @ 11]2 his Job Information Job Phase Plannetl Smrt Dale Smrt Date End Date P50 Damon.(days) WORKOVER 10124201816:00 10124201818:00 0.00 Daily Summary Operations Zan Forecast Finish laying down tubing and ESP assembly. Change out spools and clear floor. Prepare and ten in hole with ESP assembly on 4%'tubing. 24h Summary Finish testing HOPE, wdtyss waived by AOGCC. Pull tubing hanger and lay down 415- tubing 12,523. Operation at 07.00 UD ESP ASSY Time Log Start End Cum Dur Time Time Dur(nd (hr) Phase Dan. Act Plan 011.0escr. 00:0 02:00 2.00 200 W.O. C 1 P Tmubleshaol pressum dray while teffing upper pipe mms(4 W X 7') mh 4 W and met. Iso1Me additional chokmall line valves and choke expands. 020 07:30 5.50 7,50 W.0 G 12 P Pull 4 W lest lout and make up T test joint. Ted annular 2502500 fee Test manually operated and remotely operated chokes. Test 1,2 5 Mm 15 choke manifold valves, primary antl secondary WE do.., manual and HCR.. Primary and secondary choke manuals mW HCfla, upper and lower IBOP, upper and fewer variable rams wipe 5' test joint 25013500 psi. Perform koany Mt. Initial ace, 3000 psi, akar datura= 220 psi, 200 psi gain 9 apposes, full pressure=80 seconds, 10 stri ps Extends average 310 An. 0730 0830 100 8,50 W O. C 25 P Blow down choke manned. Open upper pipe ram doom and mWdld a T X' upper rams nit reinstall. Hang elephant bunk for ESP cads. Construe to tldn and atop 4'R completion tubing. 08:30 1230 4.0 1250 W.O. 12 P Re -flood lines and stack, deed air. Test upper pipe rams with 4'W aid 5 -best jouts, last dsoke, man Id valves 3 add4 2501350 psi. Test annular with 4 W bout u1250250 psi test upper pipe mms(4 W X 7') and lower rams (3'.- X 6") with 4 X' lest joint, dad valve and FOSV 2501350 psi. 12:30 14:0 1 1.50 1400 IWO, C 112 P Pull test joint with teal dad. Blow down and equipment. 1400 2.50 1650 W. . L 4 P up and pull 4''A tubing hanger, stage up to 180 it when hanger came e. Pick up weight 115k u hanger to flow. Pump 10 bob with no returns. Terminate cap rine and ESP cable toy down hanger. 18'30 500 21.50 W O. L 0 P Lay down 4 %' 12.5 ppf Kid 563 to efig FI]204' T520. toy down upper gas fit ma M. Continue to lay down tubing F320' T14230, P W 102k. pump 93 ppg man M 10 Enron with no d%m.. 2130 4�� t0 2250 W- L 9 P Pump 71 tools 9.3 ppg brine dawn tubing, stage pumps up 3 bpm a akar 22 obis pumped caught pleasure to 1250 psi, no returns 22:30 1.50 24.00 W.O. L 4 P Continue to pulland ey down tubing F/4230' T12,523' Continue to pump 10 bels per hour into annulus. Scaring observed In tubing. Pumping 10 bph dawn annulus with no returns 170 bah of 9.3 ppg cone pumped Into hole East 24 Fours. Gas Readings Avg Background Gas (%)Max each Empire Gas (%I Avg Cameroon. Gas (%) Max Connection Gas (%) Avg Drill Gas (%) Max o nl Gas (%) Avg Trip Gas (%) Max THp Gas t%) Cumulative Mud Volumes Active Volume (blip Hole Volume @bp AddMons (bbl) cum Additions (bbl) Losses (obi) Cu. Losses (bb) Daily Contacts Poshion Contact Name Company TM. Email Office Mobile Eni depresentaMe Bruce Simon. Eni Drilling Supv. sitlddiling@empetroleum can 907-685 0 715 Eni monasticism hake Grubb Eni DfIlllog Supv. sdddflllin9@empetrplsm,pom 907-6850715 Eni mpresentaare Wade Thomas Eni Rig Clank AKRigClerolDoyon l 5@eniporoleum. can 907885-0722 Eni mpresansW. David Leonard End HSE End mprasanMive Mark ".ban End HSE Tool Push Justin Hays opyon Dniky Tod Pusher rg15@doyondollingcom Tool Push Tied Kroger Doyon Min Torn Pusher rgl5@tlospermling.com 9076850716 Pike f Well Name: SP08-1147 OR Wellbore Name: SP08-N7 Well Code: 27537 Job: WORKOVER WCER Level: Daily Report Date: 10/27/2018 Report #: 4 Page: 2 of 2 Daily Contacts Position Contact Name Company Tide Email Office Mobile Tool Push Hamad HumaNaon Doron Drilling HSE ..sonl,repnormingeom fi85-0796 Tool Push Scoh Simmons 1 Doron DNling HSE looms Personnel Log (POB) Company Sam. Type work H (hr) Staral H (hr) Count Note Archer Commissioning 12.50 0 Drink, Doyon Field Superintendent 12.60 0 Drilling ASRC Clad: 12.50 1 Drilling ASRC SOA 12.50 1 SIO Support ASRC Crane Advisor 12.50 1 SID Support Beacon Medic 12.50 1 SID Support MI Swam Mud Plant 12.50 1 Dmling Northern Oftfuld Selmer Fueler 12.50 1 SID Support ACS Environmental 12.50 2 SID Seem" ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 D riling Doyon WE 12.50 2 Drilling Chile Red Selvlms Pumping 12.50 2 SID Support HBlbbuton Mud diggers 12.50 2 Drilling Vel. Only WelAead 12.50 2 DtlBing ASRC Logistic 12.50 3 SID Support Came Rig Walsh 12.50 3 Dun, Purcell Security 12.50 4 SIOSuppod GSR Casing go". 12.50 4 DnIft Baker Hughes Baker Hughes Carom 12.50 5 DNlkng MI So. WIF 12.50 5 SID Support Jacobs Truck driver I Cone operator12.50 10 DriAing ESS Catering 12.50 10 SID Support Doyon Rq Personnel 12.50 22 Dnlling_Total Drilling Personnel 60 Daily Bulk Supply Item Description: Equipment Fuel Unit Label: Gal Umt Size: t Note: Date Consumetl Received ReNrnetl Co. Consumed Cum Receivetl Co. Returned Cum On Loc Note 10/2]2018 12144 1,2140 4,309.0 4,309.0 0.0 0.0 Supply Item Description: Mud Plant Boilers UnNLabel: Gel Unit Size: Note: Date Consumed Receivetl Returned Cum Consumetl Lum Received Cum Returned Cum On Lou No[e 1027/2010 1980 196.0 ]920 ]820 00 00 Supply Item Description: Rig Fuel Unit Labe: gal us Unit Size: 1 Note: Date Consumed Received Returned Cu. cc sunned Cum Receivetl Cum Returned Cum On L. Note 10/27/2018 1.229.0 5,490.0 5,8840 1S,]27.0 0.0 9,843.0 Supply Item Descripgon: Rig Water UNt Label: bbl Unit Size:1 Note: Date Consumed ReceNadl Returned Cum Consumetl Cum Receivetl Cum Returned Cum On Loc Note 102712018 165.0 3550 215.0 521.0 0.0 306.0 Supply been Descriptor: WIF Bogus Unit Label: Gel Unit Size: Note: Dae Consumetl Received Returned Cu. Consumed Cum Receivetl Gum Returned Cum p1 Loc Note 102712018 420 420 160.0 1680 00 00 Supply boom Description: WIF lmected Diesel Unit Label: Gal Unit Size: Note: Data Co.sumetl RI It Returned Cum Consumed Cu. Received Cum Returned Cum On L. Note 102]2010 4200 420.0 1,600.0 1,680.0 00 Ca Last Authority Visit Data Tot map. Nor Total I.N.G. number comment 102]/2018 I I I BOP Test, seem Mcleod of AOGCC Waived Witness. Next test due 1113118 STOP Cards Submitted Company 41 Ridge Co. Doyon Drilling 6 PJSM'S Down Drilling lino. 4 Sate Card. Doyon Drilling Inc, 6 HRWS Gooch Drilling Inc, 6 COW MI Swa. 4 RIR'6 Ml Swaco 4 HARCIJSA General Notes Comment Well Name:S-N7 OR Wellbore Name: e: SP08-N-N7 Well Code: 27537 � 1Job: WORKOVER e Ili WCER Level: Daily Report Date: 10/28/2018 Report #: 5 Page: 1 of 2 Well Header PermiVConcession N° operator Subsidiary tat"" Leff0 Godo ALASKA ENIPETROLEUM ENI Pnrolaum Co. Inc. pEVELOPMENT WELL O POZZO DI CO,TIV".NE Rotary Table Elevation (it) Ground Level in) First Flange(ft)RKis - Base Flange IS) RKB-Tubing Spoof (it) 53.93 32 805.12 17.19 274 Rigs Rig Name Contractor Mg Type R19 Num Rig Start Dale Rig Release Date Daily Information Weather Temperature(°F) Wind Days LTI(do,) Days R1 (day.) POB Olpudy 14 a SW @ 13 MPH 335 00 335.00 05.0 Safety Incidents - Near Miss Gate Category Type Subtype Severity Caose I Lost Hmni Comment Safety Drills Days until Next Check Type #Occur Last Date Next Date (days) Authority Visa 110272018 tv32018 6 Fire Ong 1 1020/2010 11;11/2018 14 Rg Inspection 5 1028.2010 102912018 1 Safety Meeting 5 10282010 102912010 1 TT Kick White Tripping Drill 2 tO2&2018 11/412018 7 Casings seat Cas.Type Do (I.) to (in) Grade I Top IftKB) I Bottom filit TVD BpL(ftKBI Run Data CONDUCTOR 20 18.25 X65 0.0 180.0 1806 92912013 CASING 1338 12.42 L -BD 44.3 Z—T ff 2.471.8 t0l&2ot3 CASING 9518 8.84 L80 0.5 8.090.0 4,068.0 101162013 LINER 512 4.83 LA0 7,8296 15,890.0 3,999.9 10272013 Last Cementing Cemanong51hrl Dao: lWlB 013 Sbing: CASING, 8 WOUMB Comment: Sfg p Top IftKel Top Meas Meth BM (ftK6) Cam t 0 Temperature Log 0.030.0 Shut tl.-a ng pumps and Scblum ai pumped 10 bbls. H2O te till lines and leaded lines b 800 P I low 8 3.800 P I high stall, good Switched beck rig pumping 100 bola. of 105 ppg Mud Push II rate of 5 than @ 170 all, Shul-down 8 drop bottom plug. SLB mix 8 pump Lead starry 281.4 Was, 12.5 ppg- Class LdeCRETE, 11.56 YbM, raw water at 5.487 gal/sk ] Pump rated 4 bpm @ICP 140 PSI, FCP 40 PSI. SLB pump 10 bbls HM and wash up. Displace with592 bills 9 25 ppg treated mud with rg pump at 5 bpm w/ 460 psi, slow to 3 bpm at 570 bbl away, FCP 710 PSI, Bump Plug PSI up to 1,210 P51 had 5 Min. Bleed off 6oaft honing. Cement In place @ 11:12 has. Job Information Job PhasePl' n" Start Ogle Start Data End Data P50 Guyana. (days) WORKOVER 1012420181600 1D124QO1818:00 0.00 Daily Summary Operations 24h Forecast Finish aleariwl spf and teat cable. Tie In cap tube and lest. Continue W con in hole with ESP assembly on 4 W along, Min Summary Finish deaomplefron, prepare add make up new ESP assembly and run in We W 102'. operation at 07.00 RIH w1ESP HL 1.260' Time Log Star[ End Cam our Time Time Durlbn Ibrl Phase Our. Act. Plan Oper. Descr. GOOD 02:M 209 200 W.O. L 14 P Congress to lay down 4 W tubing and ESP completion F2.523'TROD ', PU-nk 02:M 02:30 0.50 250 W.O. L 19 P Ciialate 20 bola down tubing at 3 bpm, 800 psi. 0230 04:30 2.90 4,50 W . L 4 P Continue to ley dawn 4' tubing and ESP assembly FROD T80'. Pipe started pulling wet H ]o'(dw hakes nand o1 Wbinp). Scale full on last tubing joint above tubing stop (16') 04:30 0730 3.90 750 W . L 4 P SMp last tubing joint off of over motor. Annual M pull motor, PN GLM and make up in pup on star Laytlrivan with ,as In wish elevators. Lay down pump assembly add T stood 07:30 12'oO 4.50 1200 W . L 20 P Unload pipe shed an short side. Pull edeas ESP cable and cap tube over sheaves. Clear floor of old clamps and epuignent. Clean and clear fear 1200 1600 4. 1-60 K 20 P Mobi1¢e ESP components in pipe shed. Test wire an new spools in spooling all. tage clamps add tails. Rig up GBR torque Win tongs and computer. Run cables and cap Nb over sheaves to rig flow. Continue to In hake at 10 bids per hour 9 3 ppg bane (no rsmms ). 16:06 2290 650 22.511 W.(k K 9 P Pick up 7 5;8 pump shroud Pick up pump and seal aasemble and service. install 2 stainless steel bands. 2 proaddlizers, 4 pump clamps, 2 single clamps. 1 camas collar damp Wok spina. Run In We to 102' , SI It. Continue to fill help with 10 I able of 9.3 ppg bane per hour. 22:30 1.0 2400 Wb K 5P Start able spike aam ENI elect Ian wartace 100C) 1 AND ebb brine tamped into well the lent 24 hours. Gas Readings Avg Background Gas (%) We Background Gas (%l Avg Connection Gas (%) Man Connection Gas (%) Avg ONII Gas (%) Maz Drill Ws III Avg Trip Gas I%) Max Trip Gas ill Cumulative Mud Volumes Active Volume (heal Hole Volume (bop Additions (bell Cum Additions (blip Losses (Doi) I Gum Losses (661) Daily Contacts Person. contact Name Company Title Emelt Office Mil End representative San. Simonson Ent Drifing Supv. scidnlMg®enipMrobum.wm 907,685-0715 End representative Mike Grubb Ear Drilling Sups, siddrilling®empetrokumcom 907-685-0715 Eni raprecentagve Wad. Thomas Em Rig Clerk AKRg(DIBIN0oyoniSiMnipetrolean, 907-685-0722 EatmpesentaWe David Leonard EM HSE Ent represent. Me* Hoover End HSE Thal Push Justin Hays Doyon Drilling Tool Pusher rigl5Qgdpyondriumgcam Triol Push Ted Kruger Doyon Drilling Tour Pusher rg156doyond illing.win 9078850716 Trill Push HaroM Richardson Doyon Ddling HSE hochardsonodoyondafling.wm 685-07% Tod Pon SwH am..s Doyon Drilling HSE Well Name: SP08-N7 OR Wellbore Name: SP08-N7 Well Code: 27537 Job: WORKOVER WCER Level: Daily Report Date: 10/28/2018 Report q: 5 Page: 2 of 2 Personnel Log (POB) Company sure Type Work H (lr) Standby H pa) Centel Note Ander Commissioner, 12.50 0 Dulling Doyon Field Superintendent 1250 0 Drilling Can, Rig Watch 12.50 0 Dulling ASK Clerk 12.60 1 Ddlling ASK SOA 1250 1 SID Support ASK Crane Ativii or 12.50 1 SIDSupport Beacon Medic 12.50 1 SID Support MI swam Mut Plant 12.50 1 Dolling Northam Oliteid Services Fueler 12.50 1 SID Support ACS Enviromentil 12.50 2 SID Supped ASK Company Man 12.50 2 Diflim, Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 Dulling Doyon HSE 12.50 2 Drilling Me Red Services Pumpiry 12.50 2 SID Support Halliburton Med bggere 12.50 2 Deur, Velm Gray Wallowed 12.50 2 Drilling ASK Logistic 12.50 3 SIDSUppod Purnell Security 1250 4 SID Support GSR Guam Service 12.50 4 Drilling Baker Hughes Bakst Hughes Caudill 1250 5 Drilling Ml Swam WIF 12.50 5 SID Support Jamba Truck driver I Crane operator12.50 10 Drilling ESS Catering 12.50 10 SIDSupport Doyen Rig Personnel 12.50 22 Collins Total Dulling Personnel 57 Daily Bulk Suppyll�n Description: Equipment Fuel Unit Label: Gel Und Size: 1 Note: W[a Consumetl Received Returned Cum Wnsunmd Cum Received Cum Rastres. Cum On Loc Note 102012010 L164.0 1.164.0 5,4]3.0 5.4]3.0 0.0 00 Supply lldn Description: Mul Ram Boons Wattled: Gal Lot St.. : Note: Dela Consumed Received Returned Cum Consumed Co. Received Cum Returned Cum on Loc Note 10282010 190.0 198 0 990.0 990.0 0.0 0.0 Supply Item Description: So FUN Unit Label: gal us Unit Size: I Note: Dale Consumetl Receivetl Returned Cum Consumetl LUm Resolved Lum Returned Co. On Lx Note 10202010 1 340 D 0 0 ],224.0 15.72] 0 0 0 8.503.0 Supply llem Deamp6on: Rig Water Ums Label: bbl Unit Size:1 Note: Date Consumed Received Returned Cum Consumetl Cum Received Lum Returned Cum On Loc Note 102&2018 32.0 00 2410 5210 00 274.0 Supply teem Dasentsfam WIFBoeen Unit Label: Gal Unit Size: Noce: Oah Consumetl Received Returned Cu. Consumed Cum Receyed Cum Returned Cum On Loc Nate 102812018 azo 42.0 210.0 210.0 00 0 0 Supply Rem Drp crlptlon: WIF opeletl Diesel Unit Label: Gal Unit Size: Nate: Consumetl Receyed Returned Cum Consumed ceivetl Cum Returned Cum On Lm Note M0 1028I001a 420.0 d200 2,100.0 People 00.0 0.0 0.0 Last Authority Visit Wee Toe map. suer Treat I.N.C. number Comment 102]2018 I I BOP Test, Austin Mcleod of AGGCC W...d Witness. Nevilest due 1113118 STOP Cards Submitted Company a Reis Cam Dawn DNling 7 PJSM'S Dayan Drilling Inc. ] HRWS Wynn Dulling Inc. 15 Sal Card. Wynn Dulling Inc. 7 COW Ml Swaca 4 Rleh Ml eased 4 HARCIJSA General Notes Comment: Daily Report Date: 10129/2018 Report #: 6 Page: 1 of 2 Well Header Well Name: SP08-N7 OR Y111Ffi� Wellbore Name: SP08-N7 Su I lary Well Code: 27537 rot ' Job: WORKOVER en i WCER Level: Daily Report Date: 10129/2018 Report #: 6 Page: 1 of 2 Well Header PennitlConcession all Operator Su I lary Initial Lahee Code AIASKA ENIPETROLELIM ENI Petroleum Co. Inc. DEVELOPMENT WELL O PORO DI COLTIVA K)NE Rotary Table Elevation lf) ...no Level Do First Ftange(h) fol -Base plunge (.1 RNB-Tubing Spoil(R) 5393 321805.12 17.19 3674 Rigs Rg Name Contractor Rig Type tale Num Rig scan Usta Rig Release Date Daily Information weather Tempeoval rF) WindDays LTI(days) Days pt (days) POB ClOutly 3.2 8W (ffi tOMPH 336.00 335.00 850 Safety Incidents - Near Miss ease category TVA Subtype severity Cause Lost time? Comment Safety Drills Days Until Next Check Typo pOccur Last Date Next Oona (days) Authority Visit 1 1027120181122018 5 Fire Drill 1 1012&2018 11/1112018 13 Kick While Topping Dnp 1 102912018 111512010 7 tag Inspection 6102912010 101302018 1 Safety Meeting 6 10292018 101302018 1 TT Kkk While Topping Unit 2 10/2&2018 11/42018 6 Casings seat Cas.Type 00 (in) ID (in) Gains Top (kKB) Bottom(ftKB)TVDBOt.(bKBi Run Date CONDUCTOR 2D 18.25 X65 0.0 mu 1800 1600 82812013 CASING 13318 12.42 L -BD 44.3 2.471.9 t0�B2013 CASING 9518 8.84 L-80 aft 8,030.0 4,060.0 1W16r2013 LINER 512 4.83 L40 7,829.6 15,a60.0 3,999.9 1=72013 Last Cementing Cementing Sbn Date: 1W182013 String: CASING, B4Ooffef B Comment Sfgp Top IkKB) I Top Meas Mem B6n IRKB) 4 Com 1 5,0000 Temperature Log 8.030.0 Shut down rg pumps and Schlumberger pumped 10 bels. H2O la fill lines and tested If... M 900 PSI low 8 3,600 PSI high stalk good Switched back ng W mptng 100 bbls. of 105 ppg Mud Push II rate of 5 bpm @ 170 p51. Shut down 8 drop bottom plug. SLB mix 8 pump Lead slurry 261A bible, 12.5 ppg. Clesa UWCRETE, [1.55 Yield, mix wafer at 5A67 1 gaimul Pump rate offl bpm @ ICP 140 PSI, PCP 40 PSL SLB pump 10 bible H2O and wash up. Displace wlth 592 bels 9.25 ppg treated mud wish rig pump al5 bpm «1460 psi, slow to 3 bpm of 570 bbl away, FCP 710 PSI, Bump Plug PSI up to 1,210 PSI hake 5 Min. Bleed off Dome holtling. Cement in place ®11:12Ire. Job Information JobPhase %anted -Sl Start Date End Da h PSO Duration (days) WORKOVER 1024201816:00 1W24201018:00 0.00 Daily Summary operations 244 Forecast Finish terminating Max through tubing hanger . Iain out tubing hangar. Install BW ant nipple down SOPE. Nipple up potludloe tree and passport test baa. Stan ngging down far rig move to SP -05. 2M Summary Make up MILE spice and run In hole wind ESP on 11.6 ppf 521 Hyd filling hole 10 bb15 per hour and pumping tubing volume every 3000'. Run in hole Tnt 88and make up tubing hanger and make splice pene or. Pumped a total of 378 ebb 9.3 ppg bone in the last 24 hours. Optimal at 07.00 No BOPE Time Log Blatt End Cum Dur Time Time our (hr) Mn Phase OF, Act Plan Opo. Ciao. 00:00 03:30 3.50 350 W.O. K 5 P Continue make spllceaM RSL Splice witnessed by ENI elecWcien. 03:30 10:00 6 W 4000 W.O. K 4 P Continue to run in hole add 4 W Hyd. 521 tubing and ESP completion F1102' T2,000' IDUO 11:00 LOU 11.00 W.O K 9 P -1700 -0 Pump tubing volume Of 45 bels at 3 bpm. 875 Met MIN .W 17.00 K 4 ontnue to ronin hole with 4 X Fit 521 tubing and ESP mmplef on F2,(I00 TABON Fill how"Iff labels 9 3 ppg M every hour Testing ESP line ant cap lube every 1000'. 17:00 18:00 1.00 18.00 W. . K 9 P Pump tiding volume of 95 Ibis at 3 bpm, 1.080 pet. 18.00 20:00 2.00 20.00 WO, K 4 P Continue to test ESP line every 10D0', Cordifinue to run in hole war 4 W Hyd. 521 tubing and ESP complefil F/6,000' -1 T2,180', SO=90 k. Fill hOle wph tabbls 9.3 ppg finne every hour. Testing ESP line and wp tube ivory 1000'. No returns. 20:00 210 So 21.30 W.O. K P Makeup XO pup Flo %" hyd 521 to 4 % ler, IBT X 562 md. Pickup lififinfloglond and make up hanger PUl K 21:30 woo 2.% 24.M W.O. K 5 P Install penfihiOr an hanger and tamlinMe cables. VON test control Ane passage In hanger to 5000 psi. Pumped a total of 3718Ibis 9.3 ppg brine in Me bat 24 Mum. Gas Readings Avg Background Gas I%) Max Background Gas (%) Avg Connection Gas PAI Max Connection Gas I41 Avg ortil Gas (%1 Max 01.11 Gas 1°AI Avg Trip Gas (%I Max Trip Gas I%) Cumulative Mud Volumes Active Volume (bbl) Hole Volume (bbl) Mandate @6S Cum Additions Intl) Losses (bbd Cum Losses (bbl) Daily Contacts Position Contact Name Company Title Email miss Mobile Ertl representable Broca Simenson Yn= Drilling S,w siddd1Im,@.mpelhleuducmn lkll.S0715 Eni repreaentaove Mika Grubb But Griping Send, sidddlhoO®enipeboleum.com 907-685-0715 Ent representative Amjkd Chesil EN DdOng Engineer Ent representative Wada Thomas Ent Rig Clank AKMgCbrksOoyonl 5lilempetroleum. 907-685-0722 End representative David Leonard Em HSE Ertl representative Mark HUWer Em HSE Toot Push Juniin Hays Doyon Wing Tod Pusher rg15filldoyoMnllingcom Tool Push Ted Magor Doyon Drilling Toot Pusher rg15®d,dri nllbg cam 907-6850716 Tool Push Harold RRhaNnon Doyon Drilling HSE Mchardson®dayondnlllfif,com 685-W96 TOO 1 Push Send Simmms p0hohn DMling HSE F- I Well Name: SP08-1,17 OR Wellbore Name: SP08-1,17 Well Code: 27537 Job: WORKOVER WCER Level: Daily Report Date: 10/29/2018 Report #: 6 Page: 2 of 2 Personnel Log (POE) Lompeny Serv. Type Work H hr) Stand-by H (hr) Count Note Archer Commissioning 12.50 0 Drilling Doyon Field Superintendent 12.50 0 Drilling Caeg Rag Watch 12.50 0 Drilling ASRC Gerk 12.50 1 Willing ASRC SOA 1250 1 SID Support ASRC Crane Adviser 12.50 1 SIDSupport Beacon Medic 12.50 1 SIDSuppon MI Swaco Mud Plant 12.50 1 Dnling Northam Oigeild Services Further 12.50 1 SIO Support HellibuHon Mud Wggem 12.50 1 Drilling ACS Euvlromental 12.50 2 SIO Support ASRC Company Man 12.50 2 Drilling Beacon HSE 12.50 2 SID Support Doyon Tool pushers 12.50 2 DrlOing Doyon HSE 12.50 2 pilling Lure Red Services Pumping 12.50 2 SID Supporl Via. Gay Wellhead 12.50 2 Dnlfmg ASRC Logim. 12.50 3 SIO Support Purcell Security 12.50 4 SIO Support GBR Casing Service 12.50 4 Drilling Baker Hughes Baker FYvghes Centrillp 12.50 5 Drilling Ml Swaco WIF 12.50 5 SID Support Jacobs Truck driver l Cane operatcr12.50 10 Name ESS Caterirg 12.50 11 SIDSupport Doyon Rrg personnel 12.50 22 Driling Total Dulling Personnel 56 Daily Bulk Supply Item DeaeNption: Equipment Fuel Unit Labet: Gal Unit Size: 1 Note: Data Consumed Receivetl Returnetl Cum Careu shed Cum par dived Cum Returnetl Cum On Loc Note 10@9/2018 12010 12010 8,8]4.0 5,8]4.0 0.0 00 Supply Hem Description: Mud PWM Boilers Unit Label: Gal Unit Size: Note: Data Consumed Recurved Relumed Cum Consumed Cum Received Co. Recorded Com On Loc Note 10242018 198.0 1980 1,188.0 I 1,188.0 00 0.0 I Supply Ihm Description: Rig Fuel Unit Label: gal us Unit Size. I Nate: Oats Consumed Received Returned Cum Consumed Cum Receivetl Cum Returned Cum OR Lm Note 10292018 1.790.0 0.0 9,0160 15]270 0.0 6.7130 Supply Ilam Description: Rig Water Unit Label: bbl Unit Size:1 Note: OrtaConsumed Receivetl Returned Cum Consumed CUM Recerved Co. Returned Cum On Loc Note 10]292018 960 0.0 343.0 5210 0.0 1780 Supply llnn Description: WIF Sale. Wall Gal Unit Size: Note: Dale Consumetl Receivetl Returned Cum Consumed Cum Received Cum ReWrned Cum On Loc No[e 1.2018 42.0 42.0 2520 2520 00 0.0 Supply IWn Description: WIF Injected Ousel Unit Label: Gal Unit Size: Note: Date Consumetl Recow it Returned L.......... d Cum Received Cum Returned Cum On Loc NOH 101292018 420.0 420.0 2,520 2,5200 0.0 0.0 Last Authority Visit Data Tot limp NW Total I.N.C. number Comment 10272018 BOP Tesl. Austin Mcleod of AOGCC Waived Witness. Nest test due 1113118 STOP Cards Submitted Company tlRpm Com Doyon Digifing 5 PJSM'S Doyon Drilling Inc. 5 COW Doyon Drilling Inc. 15 Sate Card. Doyon Oiling ins. 4 HMS MiSwaco 4 RIR's Mlswac0 4 lWRCUSA General Notes Commem: • • M O oo INn ^ .-MO0a 0 o mM o m ONN � c0D N w N m rP7 r-m N n m m w m U \ — i CN U F a VMD U) Ca o M m 00j n , 'p N 10 N fo w 0 CO N M 0 0 IO 0 • julp �{ N +- N N co M N 0 N N M N Y M • • t.In w .7 CV Z. 'y 0 e4 c �. w ' wt' C') 0 a 0 O w N N. h N N W 10 < CD) o 0 N 0w) N 10 h N N N N 0 CO CO 10 CO CO CD 0 CO m N N U) AtVO0 C O N M N co N V n O N N r Y Y M V Y w a4 O = ,' U) W U) W w W O W m m m N. N W n N. CO m w Is h !� w CO n W 0) la. Zy N r N r .1- CU w Q w C7 m O 2 011 II W O N w c :622 o Vle m N O N - NNw N pW CO SOD) 0 1U) 0 CO N. N 0 •- M O M m O N M M Y M /A M p 10 N N V O9 1n CAD N N N N m m e t` co " M N Qv Z O z 3 a 5 O_ Cl) OLLC m -56' a O.E r T tor-N IN. r n CD 0 n N N m m0 40 m 0 o CC m CO m t` tN. N n N n o 0^ o m y F £ E 0 • 1- o 0 r4 11 Z O >- m o © w W C O 7 N N N N r r v- '- 0 L ' N N N N N N 0 M M M 0 N N r M N N N N N w co, F' O O y O cc w t.,•-., 2 U LL V J N w o C9 a m Z U e N N 0 w CO N M a V 0 w 0 N N O co co O m O N N. O CO 4D M c ~ Q 0 0 " Q Q w w W w m w w w N co w I N M N M < < M M N N N M M �t a} y a m 3 Q NNN N N NNNNN N N N N N N N N N y O Q N Y cn s, Jx Eco 2 ` W Q 0 H N .2 co O n N N n O O Q r Y 0 CD O O m W w CO M m M V) n n Z Z0 U N r O W W O m m M mN - A N N ,- N N N N N N N N N m J 2 ° tV o 2 O c rs (� 0 M N W N O 0 N. M m N m N CO N N CO CO 0 CO N V O 1n m CD 0 N COON CO N a CO M N �,,, M N N C9 N M N N N N N N N N N N N M C 5 3 m N ; � C m CO m CO CO CO CO COsi. CO CO a a C e r r N N N N N al N N r r r M r r r V '? N N go., r N m r N N o 0 C w C) C) d o I Fo 2 Y L. N N N N N N N N N N N CO N N N N 10 ) N N N N N N N tO N N N N n E w y Y 2 1! Z t N N C 12 CD m CD m CD CO CD CD m CO m m m m m m m m m m m m m m m m m m m r.,. 2 t. 8 'S N O N d d el. d 6 6 d W CD d> 1 d d r d m N to .1 0 •1 $ O 0S O O t VO to .k. p p 8 O S O O S O 04 0 0 0 Q O O S O p qp qp cps p G O Q O 0 C 0 0 o d d d O z 4 a s d a d di c �CJ7 $ d 2 co o 0 4 0 CaD o $ 1x 00 C') 9 tCo o 0 4 c 2 N N N M ; ; lD 4 CO m N C' 10 < � N n U) Cn N 1C) 7 10 d o A Cw M v M M m F. C9 M M M M CD M CD CO CD CO CO M 11 £ Q N N N N N N N N N N N N N N N N N N Ni N N N N Ni O N N N N N N w N N N N N N N N N N N N N N N N N N N N N N N 1 eO OOO O O O O m CD m dom PQ m O CO m 0CD CD cOd d d d d 6 6 d a d06ddd61 dddNNNNNN t0 to N N N N CO N N 47 CCN N N N d d 28 L w O w 40 co 7 w •E a• w O w w C tu E o 0 0 co0 o o co a o 2 1` 'o N. N M M 5)2 •- a a a a CO a s to a a o )= w w 2 1. 2 w 2 N �D �n w" si d rn w z .y. f uj LL 7r LL y LL z z 1zi z twit z z 3 al 5 5 E a ' 0 8 0 0 o d N .} 1p r d w 0 m d N tb m N N m ,C .� z w` w a C. C. C. D. O. D. a. a s 0. a a z 0 0 0 0 0 0 0 0 0 0 0 0 CO CO CCD CO D. O. D.V CCD tan tan tan CD CD tai, CD CD CD CI) CO a.CD Q - a 2-(3 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, April 14, 2014 9:49 AM To: 'james.wright@enipetroleum.com' Cc: Guhl, Meredith D (DOA) Subject: Nikatichuq SP08-N7: Total Depth James, While reviewing the Well Completion Report submitted for SP08-N7, I noticed that the total depth of the well stated on the report form is 15,870' measured depth. However, in the Daily Report for November 7, 2013,the 8-3/4" production hole is reported as being drilled to a total measured depth of 15,977'. The End Depth reported on that and subsequent Daily Reports is given as 4,869.79 meters, which equals 15,977' measured depth, or 3,977.3'true vertical depth. I have hand-corrected the Well Completion Report submitted by Eni to AOGCC. Could you please correct this error in Eni's databases ? Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 AOGCC: 907-279-1433 1 .M STATE OF ALASKA ALA.,,.A OIL AND GAS CONSERVATION COMMI ,iON RECEIVED WELL COMPLETION OR RECOMPLETION REPORT AND LQ 0 4. 2A13 1a.Well Status: Oil❑� • Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.11` � Development ❑� EI' J: r C GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: J4 ,.'‘`�4 l 7r Service ❑ Stratigr i e`1; 2.Operator Name: 5.Date Comp.,Susp.,or 0.3.1;12.Permit to Drill Number: Lt c ii3-Pli ENI US Operating Co.Inc. Aband.: 11/14/2013 • 213-134 • 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 10/3/2013 • 50-629-23501-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4476.9 FSL 1233.5 FEL S19 T14N R9E UM 11/7/2013 • SP08-N7. Top of Productive Horizon: 8.KB(ft above MSL): 53.6 15.Field/Pool(s): 2478 FSL 4926 FEL 17 T14N R9EUM GL(ft above MSL): 13.08 Nikaitchuq/Schrader Bluff Oil Pool Total Depth: 9.Plug Back Depth(MD+TVD): 2318 FSL 494 FEL 12 T14N R8EUM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Tof Deepth(�V,19�j�+•SVD): 306.Property Designation: Surface: x- 511676.16 y-6053658.8 Zone- 4 �-1'6 �OTMG1449-TVD ;//5/✓,/ ADL 391283,0388583,0388581,0388571 •TPI: x- 513246.08 y- 6056941.66 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 507326.16 y- 6062053.38 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes U No LJ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 13.1 (ft MSL) 1,860'MD/1,769'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/Den/Periscope N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 178.89 X-65 36.85 160 36.85 160 Driven N/A N/A 13.375 68 L-80 36.85 2677 36.85 2472 16 10.7 ppg:447 bbls N/A 12.5 ppg:64 bbls li 9.625 40 L-80 35.53 8030 35.53 4068 12.25 12.5 ppg LiteCRETE:261 bbls N/A 5.5 15.5 L-80 7830 15860 4042 3999 8.75 Slotted Liner N/A 24.Open to production or injection? Yes No❑ If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Slotted liner 4.5 7220 N/A 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ".'1 3 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 11/22/2013 ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio:scf/bbl 11/21/2013 24h Test Period 1010.0 0.0 5.0 128/64 0 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: •Water-Bbl: Oil Gravity-API(corr): Press. 125 psi 0 psi 24-Hour Rate ....0. 1010 0.00 5 18 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No E • Sidewall Cores Acquired? Yes ❑ No❑✓ • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RBEM:1-, MAR 2 0 2 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE aL, �/l/y Submit original l only G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes I No . If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1860 1769 Top Ugnu 2430 2263 Top Lower Ugnu 5236 3572 Top Schrader Bluff 6882 3893 Top N Sand 7222 3954 Top OA Sand 8320 4099 Formation at total depth: OA sand 15870 3997 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Giuseppe Maugeri Printed Name: James Wright Title: Drilling and Completion Engineering Manager Signatur .,,,=, Phone Contact: (907)865-3328 Date: 12/2/2013 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 lb: 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: ess U CD • QC W L V 1-1• in c 5 a) m nc) > m o = am +D-' ~ NTh. O J i) M C C p1:3 +O. N ''' > U -- o T- W/ co cl J:J:!CO LO • ty9 v) 5 I IL lOt I I 110 1 C I' __ .-i N M Cf N0m o 6 � NO I I iUltItU I YYYYY0 ae re a a a a a in "' z N N N N N 3 3_ Tv— .T U Ii I I I 0 0 0 0 0 E- co N L E N N N N N X X 0E U c5 a) I I. N N N N N N LQ \ � I I < .O E O 1 d — Q ca J I 3 kJ �' o x _c = E1 I ' I I `� g m z 0E v)CO OY m o � 3 ' 1 I I U co > „ . „ \ (v m 2 o mo , 2 : .� _ � a a � 2) IM 11) III I i C W e U a c Q oCI c N `- — C O N o < v0- 1 t > of o .— N = � I I os I— I— 0 N .0 z C c co � t 1 p co I .` .� ' 00 Q O U 0 �,. -- N O t0 = 1- O U � F- O I- N N CIL 0 . C CO W O O O � co-Cfl � M O E � Q Zr Q •c ? 2co a a) 6 � v) M MI cB CO .N o 0 /d �_ co Q r H h M ~ Q ~ p U - + M CO Q � (-On Q N N r. 73 o N CO a x U Q bp oCD ., v rn = O c ti C 0) CNJ / o rn � o c• oo sU _ 4 (. N - d. (0 CO ' / � a / / 2 > J C d - 1- 2 401* '. `' CO N C71al .-1 N CO illili . \ ` Cl M N d Ol l0 / CO N CO O *1 ‘--I 0 Il W cm- N M u'1 13 .--I c-I c-I 2 cc 1 1NV z N 1.- da.- T'. . t .--1 Nm N to >' i ilip ,,lisp : ___-- — Yk Xk Xk 7t �' COEN = CV 2 d d d d 0 -6 o � a cCL v a v a v v 0 0 Q C C J J Cc) 'Cr) in In vii In v) Ln t- I Uco > o :I..; C) eco - 0 0 0 0 0 0 f - M m (/) t•' as m co co N N N N N N Z N ENI-SLB CASING&CEMENTING REPORT Lease&Well No. SP08-N7 Intermediate Date 18-Oct-13 County GPB State Alaska Supv. T.Simson CASING RECORD- Intermediate casing TD 8045/4069.1 'TVD Shoe Depth: 8029.54/4067.6 TVD PBTD: MD/ TVD Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 10.625 N/A N/A HY563 Davis Linch 2.54 8,029.54 8,027.00 2 9-5/8 40 _ L-80 HY563 Tenaris 81.54 8,027.00 7,945.46 Float collar 10.625 N/A N/A HY563 Davis Linch 2.87 7,945.46 7,942.59 192 9-5/8 40 L-80 HY563 Tenaris 7,910.70 7,942.59 31.89 1 9-5/8 40 L-80 HY563 landing jt 31.89 31.89 0.00 0.00 0.00 Totals 8,029.54 Csg Wt.On Hook: Type Float Collar: Float No.Hrs to Run: Csg Wt.On Slips: Type of Shoe: Float Casing Crew: Wfd Fluid Description: 9.2 ppg LNSD mud Liner hanger Info(Make/Model): Liner top Packer?: Yes No Liner hanger test pressure: Centralizer Placement: centralizers on every joint in shoe track,every other joint to 500'above N Sand CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10.5 Volume pumped(BBLs) 100 Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: Crete Type 1 Blended Yield(Ft3/sack): 1.56 aDensity(ppg) 12.5 ppg Volume (BBLs/sacks): 260/9 Mixing/Pumping Rate(bpm): 4.5 I- Post Flush(Spacer) V) Type: Density(ppg) Rate(bpm): Volume: cc LL Displacement: Type: Mud Density(ppg) 9.5 ppg Rate(bpm): 7 Volume(actual/calculated): FCP(psi): 420 Pump used for disp: Rig pumps Plug Bumped? x Yes No Bump press 1200 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 At: 10:55 Date: Estimated TOC: 5000'MD Method Used To Determine TOC: Calculated TOC Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: Yield(Ft3/sack): w a Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): u) Post Flush(Spacer) a z Type: Density(ppg) Rate(bpm): Volume: 0 w Displacement: rn 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: • • • • Eni Petroleum Company CASING&CEMENTING REPORT Lease&Well No. SP08-N7 Date 6-Oct-13 County GPB State Alaska Supv. Chant CASING RECORD-Surface casing TD 2692/2484'TVD Shoe Depth: 2676.51'MD/2471'ND PBTD: MD/ ND Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make. Length Bottom Top Shoe/jt 14 3/8 BTC Weatherford 2.53 2,676.51 2,673.98 2 13 3/8 68 L-80 BTC Tenaris 78.62 _ 2,673.98 2,595.36 F.Collar/jt 14 3/8 BTC Weatherford 1.48 2,595.36 2,593.88 65 jts 13 3/8 68 L-80 BTC Tenaris 2,556.69 2,593.88 37.19 L Hanger 13 3/8 BTC 0.45 _ 37.19 36.74 landing jt 13 3/8 68 L-80 BTC Tenaris 36.74 36.74 0.00 Totals 2,676.51 Csg Wt.On Hook: Type Float Collar: Float No.Hrs to Run: 9 Csg Wt.On Slips: Type of Shoe: Casing Crew: Wfd Fluid Description: 9.5 ppg WBM / Spud Mud Liner hanger Info(Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure: Centralizer Placement: Centralizers 5'&8'above shoe;Centralizer 10'above FC;from 3rd joint through tail slurry(500'tail slurry),2 on 13 3/8"csg collars inside conductor @TD. CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10.5 Volume pumped(BBLs) 100 Lead Slurry Type: Dispersed Type1 Blend Yield(Ft3/sack): 2.77 Density(ppg) 10.7 Volume (BBLs/sacks): 446 bbls/904 sacks Mixing/Pumping Rate(bpm): 5 Tail Slurry Type: Crete Type 1 Blended Yield(Ft3/sack): 1.6 Density(ppg) 12.5 ppg Volume (BBLs/sacks): 64 bbls/230 sacks Mixing/Pumping Rate(bpm): 4.0 bpm co Post Flush(Spacer) Type: Density(ppg) Rate(bpm): Volume: LL Displacement: ' Type: Mud Density(ppg) 9.5 ppg Rate(bpm): 5 bpm Volume(actual/calculated): 389/384 FCP(psi): 420 Pump used for disp: Rig pumps Plug Bumped? x Yes No Bump press 1040 Casing Rotated? Yes X No Reciprocated? Yes x No %Returns during job 100 Cement returns to surface? X Yes _No Spacer returns? X Yes _No Vol to Surf: 160 bbl cmt/100 bbl spacer Cement In Place At: 14:04 PM Date: 10/6/2012 Estimated TOC: Surface Method Used To Determine TOC: 10.5 ppg Cement sample taken&weighed @ surface Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry w Type: Yield(Ft3/sack): a Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): t- o Post Flush(Spacer) zType: Density(ppg) Rate(bpm): Volume: i Displacement: co 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: Eni E&P Division `Well Name:SP08-N7 OR Ififiliii ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • Date:9/30/2013 - Report#: 1 APIIUWI:50 629-23501-00-00 2 rr rr page 1 of 1 Wellbore name: SP08-N7 Well Header PermitIConcession N` Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3,99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 -2.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 0.00 96.0 -2.2 Light Snow WC 16" ENE @ 15 MPH Daily summary operation 24h Summary Move rig off 0135 location and prep SPO8 location. Operation at 07.00 Spotting drill module over well SP08-N7. 24h Forecast Move rig over SPO8 location,berm and secure,and R/U for spud. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 06.00 12:00 6.00 6.00-MOB A 2 P PJSA Prep for rig move,R/D pump#3,suitcases,pipe shed,blow down water and steam.Skid rig floor. 12:00 18:00 6.00 12.00 MOB A 2 P 'PJSA Move rock washer suitcases and move rock washer down pad.R/D and move manifold suitcases and prep location. 18.00 00:00 6.00 18.00 MOB A 2 P PJSA Move pit and sub modules off well SI35-W4 and stage for move.Spread herculite and set matts on SPO8 location. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907.685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Tom Klein ENI Mails Coordinator 907-685-0718 Eni representative Mach Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 9/29/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgfIcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') • a- or 1Eni E&P Division �.} I Well Name:SP08-N7 OR ENI Petroleum Co.Inc. Daily Repo L Well Code:27537 Field Name: Nikaitchuq • API/UW1:50-629-23501-00-00 2�, Date:10/1/2013 - Report#: 2 If II page 1 of 1 Wellbore name: SP08-N7 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 10000 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 -1.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 103.0 -1.7 Light Snow WC 20` ENE @ 10 MPH Daily summary operation 24h Summary Set up location and spot rig modules.Install diverter lines,and N/U Vetco speed head and test to 500 psi. Operation at 07.00 Freeze protected SI35-W4 w/130 bbls diesel down the IA.N/U Diverter system.Install backside suit cases. 24h Forecast Continue proper R/U and N/U diverter system and test.Bring on spud mud and have PJSA.P/U&M/U BHA and spud well. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 0000 0600 6.00 6.00 MOB A 2 P PJSA Set matt for ng move and spot ng over well SP08-N7.Install diverterlines on well bay vA crane. 06:00 12:00 6.00 12.00 MOB A 2 P PJSA Cont to R/U diverter line.Set rig floor stompers and skid rig over well.Install manifold side suit cases. 12:00 18.00 6.00 18.00 MOB A 2 P PJSA Spot pit complex and begin R/U of same.Set herculite and matt boards for rock washer/#3 pump complex. 18.00 00.00 6.00 24.00 MOB A 2 P PJSA Spot pump#3 and rock washer.N/U Vetco speed head to conductor and test to 500 psi. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 9/29/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') • �� Eni E&P Division (Well Name: SP08-N7 OR ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • 2^n Date:10/2/2013 - Report#: 3 II API/UW:50 629-23501-00-00 — II 'I page 1 of 1 wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3,99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 -0.31 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 106.0 0.6 Overcast,WC 33` W @ 1 MPH Daily summary operation 24h Summary Cont.to R/U.N/U Vetco well head equipment and 20"diverter system and test.Load pipe shed w/BHA and prep for P/U.Fill pits wl 740 bbls of 8.7 ppg spud mud.Note CIO shear valve on SI35 and tested. Operation at 07.00 P/U drill collars.Stand back. 24h Forecast Complete wire line work on 0I35 and reinstall diverter line.Test diverter system,M/U BHA#1 and fill hole and check for leaks.Perform PJSA and spud well as per SLB.Drill ahead to casing point. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1054.5 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 MOB A 2 -P 'PJSA Berm around ng.Spot mud and Sperry shacks and R/U.Work on suit cases.N/U speed head and riser and test seals to 500 psi f/10 min. 06:00 12:00 6.00 12.00 MOB A 2 'P PJSA N/U 20"Annular Preventer and riser nipple.Test seals to 500 psi f/10 min.0/0 Choke valve#13.Load HWDP in pipe shed and strap. 12:00 18:00 6.00 18.00 MOB A 2 'P PJSA Fabricate diverter line to knife valve.Install flow,hole fill,fill line. Load and prep BHA in pipe shed.Load pits wl 740 bbls of 8.7 ppg 130 vis spud mud. 18:00 00:00 6.00 24.00 MOB A 2 P 'PJSA Check accumulator bottles and charge system.M/U 13 3/8"casing hanger on landing jt and perform dummy run. Fabricate suit case bridge for crane work.Service and inspect top-drive and draw works.Note;0/0 shear valve on SI35 and tested. Daily Contacts Position Contact Name Company Title _ E-mail Office i Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Sup. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Dave Evans Doyon Dnlling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 9/29/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') c Eni E&P DivisionWell Name: SPO8-N7 OR ENI Petroleum Co.Inc. _Daily Report Well Code:27537 Field Name:Nikaitchuq •2^n Date:101312013 - Report#: 4 APIIUWI:so 629-23501-00-00 If II II page 1 of 1 wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(10) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SPOB-N7 DRILLING 10/3/2013 4,767.38 1,209.66 4,788.41 134.16 35.7 0.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POE Temperature(°C) Weather Wind 238.05 237.75 189.28 4.11 46.1 107.0 -2.8 Overcast,WC 18` N @ 9 MPH Daily summary operation 24h Summary Complete R/U,Perform Diverter test,P/U BHA#land drill to 160'.C/O BHA and drill to 486',pump out hole and add rest of BHA#2 and drlg to 781'. Operation at 07.00 Drilling ahead @ 1180'. 24h Forecast Ddg ahead as per SLB to Est casing point of 2627'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1066.5 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 MOB A 12 P PJSA R/U suit cases and build bridge for wire line work access.Perform Diverter test;bag-38 sec,knife valve-12 sec. Witness waived by Lou Grimaldi. 01:30 04:00 2.50 4.00 MOB 'A 2 P PJSA P/U HWDP,Flex collars and jars and rack in derrick.Sim ops,install diverter line section after wire line work on SI35. 04:00 05:30 1.50 5.50 DRILL E 4 P PJSA P/U BHA#1,Bit,Motor,XO,1 stand HWDP and RIH and tag Btm @ 51.5'. 05:30 06:30 1.00 6.50 DRILL E 12 P PJSA Flood conductor and pressure test surface mud equipment to 3000 psi. 06:30 08:00 1.50 8.00 DRILL E 3 P PJSA Cleanout conductor to 160'@ 600 gpm,350 psi,40 rpm,2k tq,80k puw/sow. 08:00 09.30 - 1.50 9.50 DRILL E 4 P PJSA P/U BHA#2 as per SLB,Orient motor to Gyropulse and MWD. J 09:30 10.30 1.00 10.50 DRILL E 12 P PJSA Take MWD/Gyro surveys and correlate. 10:30 12.00 1.50 12.00 DRILL E 3 P PJSA DrIg f/160'-208'@ 500 gpm.430 psi,40 rpm.2-3k tqo,2-3k tqf,2-10k wob,94k puw/sow/rotw,Max Gas 2..48 ADT/A/Jars. ' 12:00 17.00 5.00 17.00 DRILL E 3 P PJSA Dug f/208'-486'(485'TVD)@ 650 gpm.720 psi.40 rpm,3k tqo,1k tqf,2-10k wob,90k puwlsow/rotw,8.2 ECD. 1.77 ADT,1.07 AST,.7 ART,2.25 Bit/Jars. 17:00 18:00 1.00 18.00 DRILL "E 4 P PJSA Circulate hole clean @ 650 gpm,710 psi.Pump out of hole f/486-115'. 18:00 20:30 2.50 20.50 DRILL E 4 P PJSA M/U remaining BHA#2 w/Stb,3 NM Flex,Saver sub,HWDP w/jars and RIH to 486'. 2030 00.00 3.50 24.00 DRILL 'E 3 P PJSA Dug f/486'-781'(779'TVD)@ 650 gpm.870 psi,40 rpm,3-5k tqo.2k tqf,5-20k wob,120k puw/sow/rotw,Max Gas 3.9.27 ECD,1,86 ADT,1.37 AST,.49 ART.4.11 Bit/Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative 'Mike Ross 'ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Dave Evans Doyon Dulling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 9/29/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division I Well Name:SP08-N7 OR 11* ENI Petroleum Co.Inc. Daily Report l Well Code:27537 Field Name:Nikaitchuq • Date:10/4/2013 - Report#: 5 API/UW:50-629-23501-00-00 2 rt page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 1.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wed 806.50 745.55 568.45 14.02 40.5 107.0 -2.8 Overcast,WC 18' E @ 10 MPH Daily summary operation 24h Summary Drlg f/781'-2646'(2444'TVD) Operation at 07.00 BROOH @ 2462'. 24h Forecast Drill to Geologists TD @ 2692'MD.Perform KW cleanup cycle and BROOH as per schedule.LD BHA and clear rig floor. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 3 P PJSA Ddg f/781'-1341'(1307'TVD)@ 700 gpm,1230 psi,40 rpm.10-25k wob,4-5k tqn.2-3k tqf.132k puw,125k sow, 130k rotes,Max Gas 22.9.50 ECD.3.91 ADT,3.09 AST..82 ART,8.02 Bit/Jars. 06:00 12.00 6.00 12.00 DRILL E 3 P PJSA DrIg f/1341'-1900'(1805'TVD)@ 700 gpm,1250 psi,40 rpm,10-25k wob,5-6k tqn,4-5k tqf.147k puw,130k sow, 138k rotes,Max gas 212,10.01 ECD,4.31 ADT,1.62 AST,2.69 ART,12.33 Bit/Jars. 12:00 18:00 6.00 18.00 DRILL E 3 P PJSA Dr-1g f/1900'-2272'(2127'TVD)@ 650 gpm,1070 psi,40 rpm,10-25k wob,6-7k tqn,3-5k tqf,152k puw,132k sow, 141k rotw,Max Gas 186,9.77 ECD,2.85 ADT,2.19 AST,.66 ART,15.18 Bit/Jars. 18:00 00.00 6.00 24.00 DRILL E 3 P PJSA Ddg f/2272'-2646'(2444'TVD)@ 708 gpm.1400 psi,40 rpm,10-25k wob,8k tqn,6k tqf,170k puw,132k sow, 149k rotw,Max Gas 149,9.96 ECD,2.95 ADT,2.41 AST,.54 ART,18.13 Bit/Jars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Dulling Supv 'SIDDrilling@enipetroleurn.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv, SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 9/29/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') ft* Eni E&P Division .. Well Name: SP08-N7 OR ENI Petroleum Co.Mc. Daily Report Well Code:27537 Field Name:Nikaitchuq • 2^ii Date:1015/2013 - Report#: 6 APIIUWI:50-629-23501-00-00 II II page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 2.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 820.52 757.26 14.02 0.35 40.1 106.0 -5.0 Clear,WC 8' E @ 17 MPH . Daily summary operation 24h Summary TD surface @ 2692',Perform K&M cleanup cycle and BROOH and LD BHA.R/U and RIH w/13 3/8",68#,L-80,BTC casing to 633'. Operation at 07.00 RIH w/13 3/8"casing @ 2000'. 24h Forecast RIH w/13 3/8"casing and land on Vetco hanger and landing jt.@ 2677'.Break circulation and condition mud.Hold PJSA and perform cement job as per plan.Displace w/mud and ng pump and bump plug and pressure up 500 psi over and hold for 5 min.Bleed pressure and check floats.Clean up after cement job and Johnny Wack stack.N/D Divener system and R/U Vetco well head assy.and BOPE. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 00:30 0.50 0.50 DRILL E 3 P PJSA Ddg f/2646'-2692'(2484'TVD)Geologist's TD @ 708 gpm,1570 psi,40 rpm.10-25k wob,7-8k tqn,5-6k tqf,171k puw,132k sow,149k rotes,Max Gas 77, 9.97 ECD,.35 ADT,.21 AST,.14 ART,18.48 Bit/Jars. 00.30 01:30 1.00 1.50 DRILL E 19 P PJSA MWD perform surveys and place Gyro Data Tool in battery out run mode. 01:30 03:30 2.00 3.50 DRILL E 4 P PJSA Perform K&M cleanup cycle while racking back 2-stands f/2692'-2556'@ 850 gpm,1690 psi,60 rpm,5-6k tq,160k puw,135k sow. 03:30 12:00 8.50 12.00 DRILL E 4 P PJSA BROOH f/2556'-691'@ 850 gpm,1482 psi,60 rpm,3-5k tq,124k pow,120k sow,121k rotw. 12:00 14:30 2.50 14.50 DRILL E 4 P PJSA BROOH f/691'-348'@ 800 gpm,905 psi,60 rpm,1-3k tq,100k puw/sow/rotw. 14:30 17:30 3.00 17.50'DRILL E 4 P PJSA Rack back HWDP and flex stand.LD BHA#2. 17:30 18:30 1.00 18.50 DRILL E 20 P PJSA Clear and clean ng floor. 1830 20:00 1.50 20.00 DRILL G 20 P PJSA R/U volant casing running tools and equipment. 20:00 -00.00 4.00 24.00 DRILL G 4 -P PJSA M/U 13 3/8"shoe track and fill w/mud.Test floats.RIH w/13 3/8",68#,L-80,BTC casing to 633'.95k sow w/Volans as per tally. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Mike Ross ENI Senior Drilling Supv SIDDnIling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 r Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Pete Maninusen Doyon Dolling Tour Pusher rig15@doyondnlling.com 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 9/29/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm°) Eq.Mud Weight(gIL) P LeakOff(kgf/cm') Eni E&P Division `Well Name: SP08-N7 OR 01* ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • APIIU1ArI:50-629-23501-00-00 2^n II Date:10/6/2013 - Report#: 7 II II page 1 of 1 Wellbore name: SPO8-N7 Well Header Permit/Concession N` Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 _ Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.36 1209.68 4,788.41 134.16 35.7 3.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 820.52 757.26 0.00 107.0 -3.3 Clear,WC 17' W @ 8 MPH Daily summary operation 24h Summary Run and land 13 3/8"casing @ 2677'on Vetco hanger.Circ.&condition mud.Perform cement job and displace w/mud and bump plug and floats held.N/D Diverter system and N/U Vetco multi-bowl assy,test and install riser. Operation at 07.00 L/D HWDP from derrick and prep to P/U 5"DP and rack in derrick. 24h Forecast Complete R/U of wellhead assy and BOPE.Load pipe shed w/5"DP and process.P/U&M/U 5"DP and rack in derrick.Test BOPE w/5"test jt as per AOGCC regs.Witness waived by Bob Noble.M/U BHA#3 and RIH and perform shallow hole test.RIH to TOFC and perform casing test.Ddg shoe track and 20'of new hole.Displace well to LSND mud. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL G 4 P PJSA M/U&RIH w/13 3/8'casing f/633'-2640',255k puw,180k sow. 06:00 06:30 0.50 6.50 DRILL G 4 P PJSA P/U&M/U Vetco hanger and landing jt and land casing @ 2677'. 06:30 09:00 2.50 9.00 DRILL H 7 P PJSA Circulate and condition mud. 1 0900 14:30 5.50 14.50 DRILL H 9 P PJSA Pressure test cement lines to 350/3500 psi for 5 min.Rig pump 100 bbls 10.1 ppg MudPushll and install Btm Plug. +"Lk- Mix&pump 447 bbls of 10.7 Lead cement @ 5 bpm,450 psi followed by 64 bbls 12.5 ppg DeepCrete tail cement @ 4 bpm,475 psi.Install top plug and pump 10 bbls water.Displace cement w/375 bbls.9.2 ppg spud mud @ 5 bpm,230/350 psi.Pressure to 850 psi for 5 min.Floats held.CIP @ 1400 hrs.160 bbls cement to surface.• 14.30 18:00 3.50 18.00 DRILL H 20 P PJSA R/D cement/casing equipment.L/D Landing jt,flush and clean diverter system.Clear and clean rig floor. 18.00 21:00 - 3.00 21.00'DRILL C 20 P PJSA N/D diverter and knife valve assembly.Remove surface riser and speed head. 21 00 00:00 3.00 24.00 DRILL C 20 P PJSA Prep,onent and N/U Vetco multi-bowl assy.Test hanger neck seals to 2000 psi for 10 min.N/U lower high pressure riser.N/D Diverter line cellar pup. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative 'Mike Ross ENI -Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDdlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 13.50 815.95 10/6/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 1'"" ' Eni E&P Division I Well Name:SP08-N7 OR ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name: Nikaitchuq • API/UWI:50-629-23501-00-00 2 n Date:10/7/2013 - Report#: 8 " 'I ii page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SPO8-N7 DRILLING 10/3/2013 4.767.38 1.209.68 4,788.41 134.16 35.7 4.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 820.52 757.26 0.00 112.0 -3.3 Overcast,WC 12` E @ 21 MPH Daily summary operation 24h Summary N/U BOPE.P/U&M/U 5"DP and rack in dernck.Test BOPE as per regs.Witness Waived by AOGCC Rep Bob Noble. Operation at 07.00 P/U BHA#3. 24h Forecast M/U BHA#3 and RIH and perform shallow hole test.RIH to TOFC and perform casing test.Drill shoe track and 20'of new hole.Displace well to 9.2 LSND mud.Perform FIT/LOT and report.Drill ahead as per SLB. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03.30 3.50 3.50 DRILL C 20 P PJSA N/U BOPE,RKB to top of muttibowl-31.25'. 03:30 05.30 2.00 5.50 DRILL E 25 P 'PJSA C/O saver sub and service pipe handler. 05:30 06:30 1.00 6.50 DRILL E 20 P PJSA Transfer 2 stands of BHA in derrick and UD 3 stands of HWDP. 06:30 08:00 ' 1.50 8.00 DRILL E 25 P PJSA Service rig,and load BHA in pipe shed. 08:00 15:30 7.50 15.50 DRILL E 20 P PJSA P/U&M/U 5"DP and rack in derrick. 15:30 16:00 ' 0.50 16.00 DRILL C 20 P PJSA Set test plug,R/U BOP test equipment. 16:00 21:30 5.50 21.50 DRILL C 12 P PJSA Test BOPE as per AOGCC regs.w/5"test jt.Witness waived by AOGCC Rep Bob Noble. 21:30 2230 1.00 22.50 DRILL C 20 P PJSA Set wear bushing. 22:30 23:00 ' 0.50 23.00 DRILL C 20 P PJSA Blow down and R/D from testing. 23:00 2330 0.50 23.50 DRILL E 25 P PJSA Service IBOP'S. 23:30 00:00 0.50 24.00 DRILL E 20 P PJSA P/U BHA tools to rig floor. Daily Contacts I Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI 'Senior Drilling Supv 'SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Eni representative 011ie Atwell ENI HSE 907-685-0721 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 En:representative Steve Abbott ENI Rig Clerk i Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 13.50 815.95 10/6/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) I P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division 'Well Name: SP08-N7 OR ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • 2 r,lif* Date:10/8/2013 - Report#: 9 APIIUWI:50-629-23501-00-00 II II II page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 5.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 820.52 757.26 0.00 109.0 -1.1 Overcast,WC 17' NE @ 22 MPH Daily summary operation 24h Summary P/U&M/U BHA#3.Attempt to use Scorpion Torque machine without success.WO weather while processing 4.5"DP,and P/U&M/U and rack in derrick. Operation at 07.00 P/U 4.5"DP 24h Forecast Cont.racking back 4.5"DP in derrick. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00.00 01:30 1.50 1.50 DRILL E 20 P PJSA P/U BHA#3 components and Scorpion Torque unit equipment. -01-730 02:00 0.50 2.00'DRILL E 20 P PJSA Prep Black Box Subs w/NOV rep. 02.00 ' 04:00 2.00 4.00 DRILL E 20 P PJSA P/U and M/U 9"BHA#3 and R/U Scorpion equipment to torque. 04:00 12:00 8.00 12.00 DRILL E 22 TW01 PJSA Attempt of M/U BHA w/Scorpion Torque machine.Would not torque properly.WO Weather. 12:00 '18:00 6.00 18.00'DRILL E 20 TWO1 'PJSA Load and process 9 5/8"casing.Work on MP2 maintenance.Replace hydraulic lines on moving system,leak on top- drive and safety gate on rock washer. 18:00 20:30 2.50 20.50 DRILL E 20 TWO1 PJSA Load and process 9 5/6"casing. 20:30 21:30 1.00 21.50'DRILL E 20 TWO1 PJSA Transfer Jar stand and HWDP from driller's side of derrick to ODS.M/U XO and 5"pup jt to BHA and rack in derrick. 21:30 00:00 2.50 24.00'DRILL E 20 TW01 'PJSA Load 4.5"DP in pipe shed and process.P/U mouse hole and P/U&M/U 4.5"DP and rack back. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI -Senior Drilling Supv SIDDdlling@enipetroleum.corn 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling@enipetroleum com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dnlling Tour Pusher ng15@doyondrilling.corn 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 13.50 815.95 10/6/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 IP* Eni E&P Division I Well Name:SPO8-N7 OR ENI Petroleum Co.Inc. Daily Report.,}` Well Code:27537 Field Name:Nikaitchuq • 2 n Date:10/9/2013 - Report#: 10 API/UWI:50-629-23501-00-00 page 1 of 1 Wellbore name: SPO8-N7 Well Header Permit/Concession N° Operator ENI Share(%) I Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 6.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 826.62 762.34 6.10 0.13 46.9 106.0 -1.1 Overcast,WC 17' SE @ 20 MPH Daily summary operation 24h Summary M/U BHA#3 and RIH to 1012'and perform shallow hole test.RIH to FC and perform casing test to 2500 psi for 30 charted min.Drill shoe track and 20'of new hole and displace well to 9.2 ppg LSND mud. Operation at 07.00 Drill ahead in 12 1/4"intermediate hole @ 2,712'MD. 24h Forecast Perform FIT to 13.0 ppg EMW.Cut and slip drill line. Set dolling parameters and drill ahead as per SLB. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 DRILL E 20 TW01 PJSA Cont.to load 4.5"DP,process and M/U and rack in derrick. 07:00 11:00 4.00 11.00 DRILL E 20 TW01 PJSA R/U HT 100 manual tongs for 9"BHA. 11:00 15:00 4.00' 15.00 DRILL E '4 TW01 PJSA M/U BHA#3 as per SLB and RIH to 362'. 15:00 '18:00 3.00' 18.00'DRILL E '4 P PJSA RIH vd BHA#3 to 1012'and perform MWD shallow hole test @ 650 gpm,580 psi,40 rpm.RIH to 2425',wash and ream to 2518'@ 350 gpm,280 psi,40 rpm.5-8k tq,160k puw.135k sow,140k rotw. 18:00 18:30 0.50' 18.50'DRILL E '7 P PJSA Circulate&condition mud @ 600 gpm,700 psi,80 rpm,5-12k tq,balanced @ 9.2 ppg. 18:30 19:30 1.00 19.50'DRILL E '12 P PJSA R/U and test 13 3/8"casing to 2500 psi for 30 charted min.4 bbls pressure up-3 bbls bleed back.R/D. 19:30 22:00 2.50 22.00 DRILL E 3 P PJSA Wash&ream f/2518'@ 650 gpm.780 psi.80 rpm,5-15k tq to TO Float Collar @ 2594'.Drill out shoe track to 2677' plus rat hole to 2692'. 22:00 22:30 0.50' 22.50 DRILL E '3 P PJSA Drill 20'of new hole to 2712'@ 650 gpm,780 psi,80 rpm,5-15k tq.160k puw,135k sow,140k rotw,Max Gas 2, 9.77 ECD. .13 ADT/Bit,18.63 Jars. 22:30 00.00 1.50 24.00 DRILL E 7 P PJSA Displace well to 9.2 ppg LSND mud,50 bbls hi-vis spacer followed w/350 bbls mud @ 8.5 bpm.250 psi,40 rpm,5- 10k 19 while reciprocating. Daily Contacts Position Contact Name Company Title I E-mail Office Mobile Eni representative 'Jack Keener 'ENI 'Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 '715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDdlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 13.50 815.95 10/6/2013 Last Leakoff Test Depth(mKB) TVD(mKB) •Fluid Type 'Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 l Eni E&P Division I Well Name:SP08-N7 OR ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name: Nikaitchuq � APIIUWI:50-629-23501-00-00 2^ Date:10/10/2013 - Report#: 11 II II ii page 1 of 1 Wellbore name: SP08-N7 Well Header PermiVConcession N° Operator ENI Share(14) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) - SPO8-N7 DRILLING 10/3/2013 4.767.38 1,209,68 4,788.41 134.16 35.7 7.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 844.30 777.02 17.68 4.19 4.2 104.5 -2.8 Overcast,WC 17` SE @ 8 MPH Daily summary operation 24h Summary Perform FIT test to 13.0 EMW,Cut drlg line and service rig.Set drilling parameters and ddg/2712'-2719'(Low penetration rate do to hard streak).POOH and C/O bit and RIH to 2719'.Ddg f/2719'- 2770'. Operation at 07.00 Drilling ahead @ 3,089'MD. ___ _ 24h Forecast Drill ahead in 12 1/4"intermediate hole as per SLB. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0,50 DRILL E 7 P PJSA Complete displacing well to 9.2 ppg LSND mud w/53 bbls @ 8.5 bpm,250 psi,40 rpm,5-10k tq. - 00:30 01:30 1.00 1,50 DRILL 6 12 P PJSA R/U and perform FIT test to 13.0 EMW.R/D from test. i.-" r I 01:30 03:30 2.00 3.50 DRILL 6 25 P PJSA Cut 8 slip 94'of drill line,service draw works,crown,traveling equipment and adjust brakes, 0330 09:30 6.00 9.50 DRILL 'E 3 P PJSA Ddg 8 2712'-2719'(2507'TVD)@ 856 gpm.1034 psi,198 rpm,30k wob,3-5k tqn,3-5k tqf,158k puw,131k sow. 144k rotw,Max Gas 1,9.56 ECD,3.68 ADT,3.81 Bit,22.31 Jars. 09:30 12:30 3.00 12.50 DRILL 'E 4 P PJSA POOH f/2719'-1389'.125k puw,115k sow.1389'-169',90k puw/sow. 12:30 14:00 1.50 14.00 DRILL E 4 TD99 PJSA UD BHA to 81'.MWD plug into ARC and test batteries. 14:00 16:30 2.50 16.50 DRILL E 4 TD99 PJSA @ 81',decision was made to L/D ARC.R/U double line tong equipment for 9"tools.Break out and L/D ARC. 16:30 18:00 1.50 18,00 DRILL 'E 20 TD99 PJSA MWD CIO batteries on ARC. 18:00 19:30 1.50 19.50 DRILL E 20 TD99 PJSA Mk/BHA#4 as per SLB.L/D 12 1/4"PDC and M/U Smith button bit. 19.30 22:30 3.00 22.50 DRILL E 4 TD99 PJSA RIH to 1000'and perform shallow hole test @ 700 gym,740 psi.Cont.to RIH to 2611'and wash and ream to 2719', @ 700 gpm,740 psi,80 rpm.5k tq.150k puw,120k sow,135k rotw. 22.30 00'.00 1.50 24.00 DRILL E 3 P PJSA Ddg 1/2719'-2770'(2549'TVD)@ 800 qpm.1040 psi,140 rpm,10-30k wob,5-10k tqn,56 tqf.150k puw,120k sow 135k rotw,Max Gas 5,9.77 ECD,.51 ADT/Bit,22.82 Jars, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipelroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 13.50 815.95 10/6/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) -P LeakOff(kgf/cm') 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 149* Eni E&P Division I Well Name:SP08-N7 OR EN!Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • APIIUWI:50-629-23501-00-00 2^ Date:10/11/2013 - Report#: 12 II II page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator EM Share(14) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information • Contractor Rig Name Rig Type o DOYON RIG 15 LAND RIG r Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 8.69 . Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,426.46 1.053.83 582.17 14.65 39.7 103.0 -1.7 Overcast,WC 20' SE @ 10 MPH Daily summary operation } 24h Summary Drill 12.25"Intermediate F/2,770'to 4,680'MD(3,456'TVD)900 GPM,1,520 PSI,150 RPM,WOB 20-30K,TON 8-9K,TQF 7-8K,HST 165K,SLK 128K,ROT 149K,ECD 9.62 ppg W/MW 9.2 ppg.Max Gas 13 units.ADT 14.65,Bit Hrs 15.16,Jar Hrs 37.47.Monitor well,static. Operation at 07.00 Drilling ahead 12.25"@ 4,820'MD. 24h Forecast Drill ahead in 12.25"intermediate hole as per SLB F/4,680'to—7,992'MD. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr( Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill 12.25"Intermediate F/2,770'to 3,290'MD(3,290'TVD)759 GPM,990 PSI,110 RPM,WOB 30K,TQN 6K,TQF 5-6K. HST 160K,SLK 135K,ROT 149K,ECD 9.65 ppg WI MW 9.2 ppg.Max Gas 20 units.ADT 4.49,Bit Hrs 5.0,Jar Hrs 27.32. Monitor well,static. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill 12.25"Intermediate F/3,290'to 3,738'MD(3,195'TVD)913 GPM,1,360 PSI,140 RPM,WOB 20-30K,TON 5K,TQF 4-5K,HST 160K,SLK 141K,ROT 150K,ECD 9.86 ppg W/MW 9.2 ppg.Max Gas 4 units.ADT 3.51,Bit Hrs 8.51,Jar Hrs 30.82.Monitor well,static. SPR @ 3,729'MD(3.200'TVD)W/9.2 ppg MW MP#1 30-80,40-110 MP#2 30-80,40-110 MP#3 30-80,40-110 12.00 18-.00 6.00 18.00 DRILL E 3 P Drill 12.25"Intermediate F/3,738'to 4,371'MD(3.399'TVD)900 GPM,1,500 PSI,150 RPM,WOB 20-30K.TON 8-9K, TQF 6-9K,HST 165K,SLK 125K,ROT 145K.ECD 9.77 ppg W/MW 9.2 ppg.Max Gas 13 units.ADT 3.29,Bit Hrs 11.80, Jar Hrs 34.11.Monitor well,static. 18100 00:00 6.00 24.00 DRILL E 3 P Drill 12.25"Intermediate F/4,371'to 4,680'MD(3,456'TVD)900 GPM,1,520 PSI,150 RPM,WOB 20-30K,TON 8-9K, TOE 7-8K,HST 165K,SLK 128K,ROT 149K,ECD 9.62 ppg W/MW 9.2 ppg.Max Gas 12 units.ADT 3.36,Bit Hrs 15.16, Jar Hrs 37.47.Monitor well,static. SPR @ 4,662'MD(3.452'TVD)W/9.2 ppg MW MP#1 30-110,40-140 MP#2 30-110,40-140 MP#3 30-110,40-140 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI i Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 13.50 815.95 10/6/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 0 D Eni E&P Division I Well Name:SPOB-N7 OR ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • 2�,r, Date:10/12/2013 - Report#: 13 APIIUWI 50 629-23501-00-00 II II II page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..,Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 9.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,720.60 1,112.57 294.13 16.85 17.5 105.0 -3.9 Clear,WC 18° NE @ 6 MPH Daily summary operation 24h Summary Doll 12.25"Intermediate F/4.680'to 5,645'MD(3,648'TVD)900 GPM,1,540 PSI,120-160 RPM,WOB 10-35K,TON 9-11K,TOF 7-9K,HST 165K,SLK 125K,ROT 150K,ECD N/A.Max Gas 13 units. ADT 16.83,Bit Hrs 31.99,Jar Hrs 54.30.Monitor well,static.Encountered ARC failure @ 5,620'MD.After discussion W/town it was determined to drill ahead to-6,500'MD to get beyond the Lower Ugnu before POOH W/9"BHA. Operation at 07.00 Drilling ahead 12.25"@ 5,673'MD. 24h Forecast Drill ahead in 12.25"intermediate hole as per SLB F1 5,645'to-7,992'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill 12.25"Intermediate F/4,680'to 4,918'MD(3,503'ND)776 GPM,1,230 PSI,110 RPM,WOB 20-30K,TON 8K,TQF 6K,HST 165K,SLK 138K,ROT 149K,ECD 9.65 ppg W/MW 9.2 ppg.Max Gas 3 units.ADT 4.97,Bit Hrs 20.13,Jar Hrs 42.44.Monitor well,static. 06.00 12:00 6.00 12.00 DRILL E 3 P Drill 12.25"Intermediate F/4,918'to 5,316'MD(3.589'ND)897 GPM,1,550 PSI,127 RPM,WOB 20-30K,TQN 8K,TQF 7K.HST 168K,SLK 150K,ROT 150K,ECD 9.89 ppg W/MW 9.2 ppg.Max Gas 10 units.ADT 3.82,Bit Hrs 23.95,Jar Hrs 46.26.Monitor well,static. SPR @ 5,316'MD(3.589'TVD)W/9.2 ppg MW MP#1 30-170,40-180 MP#2 30-170,40-180 MP#3 30-170,40-180 12.00 18.00 6.00 18.00 DRILL E 3 P Drill 12.25"Intermediate F/5,316'to 5,596'MD(3,640'ND)900 GPM,1,580 PSI,120-160 RPM,WOB 10-25K.TQN 8K. TQF 6-8K,HST 165K.SLK 125K,ROT 150K,ECD 9.75 ppg W/MW 9.2 ppg.Max Gas 13 units.ADT 4.27,Bit Hrs 28.22 Jar Hrs 50.53.Monitor well,static. SPR @ 5,596'MD(3,640'TVD)W/9.2 ppg MW MP#1 30-170,40-180 MP#2 30-170,40-180 MP#3 30-170,40-180 18.00 00.00 6.00 24.00 DRILL E 3 P Drill 12.25"Intermediate F/5,596'to 5,645'MD(3.648'TVD)900 GPM,1,540 PSI,120-160 RPM.WOB 10-35K,TON 9- 11K,TOF 7-9K,HST 165K,SLK 125K,ROT 150K,ECD N/A.Max Gas 4 units.ADT 3.77,Bit Hrs 31.99,Jar Hrs 54.30. Monitor well.static.Encountered ARC failure @ 5,620'MD.After discussion W/town it was determined to drill ahead to -6,500'MD to get beyond the Lower Ugnu before POOH W/9"BHA. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Jack Keener -ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 13.50 815.95 10/6/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 Eni E&P Division I Well Name: SP08-N7 OR PIA ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • APIIUWI:50-629-23501-00-00 2^ Date:10/13/2013 - Report#: 14 II Ii page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL • Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.36 1,209.68 4,788.41 134.16 35.7 10.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,754.12 1,118.97 33.53 8.64 3.9 105.0 -1.1 Overcast,WC 26' SE @ 3 MPH Daily summary operation 24h Summary Doll 12.25"Intermediate F/5.645'to 5,755'MD(3,668'TVD)780 GPM,1,200 PSI,120-150 RPM,WOB 15-20K,TON 8K,TQF 7K,HST 175K,SLK 127K,ROT 150K,ECD N/A.Max Gas 5 units.ADT 8.64,Bit Hrs 40.63,Jar Hrs 62.94.Monitor well,static.CBU 3X while POOH F/5,755'to 5.596'MD @ 900 GPM,120 RPM,TRQ 7-9K,HST 175K,SLK 126K.ROT 150K.Decision was made to pump out of hole due to level 3 shocks.Pump out of hole F/5,596'to 4,440'MD,500 GPM,640 PSI,HST 170K,SLK 130K.Over pull was observed,begin BROOH as per K&M Rep F/4,440'to 2,611'MD,900 GPM,1,330 PSI,150 RPM.TRQ 4-8K,ROT WT 141K.CBU 3X 900 GPM,1,310 PSI.80 RPM,TRQ 4K,HST 151K,SLK 130K,ROT WT 141K.Monitor well for 10 Min.,static.Blow down Top Drive. POOH on Elevators F/2,611'to 2,144'MD HST 145K,SLK 130K. Operation at 07.00 L/D BHA#4 as per Schlimberger DD. 24h Forecast POOH on Elevators,L/D BHA#4 and P/U M/U BHA#5.RIH to 5,755'MD and continue drilling 12.25"Intermediate to-7,992'MD. i Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End Cum • Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drill 12.25"Intermediate F/5,645'5,684'MD(3,656'TVD)900 GPM,1,500 PSI,120-140 RPM,WOB 20-30K,TQN 9K, TQF 8K,HST 175K,SLK 128K,ROT 150K,ECD N/A.Max Gas 4 units.ADT 4.53,B4 Hrs 36.52,Jar Hrs 58.83.Monitor well,static. 06:00 12.00 6.00 12.00 DRILL E 3 P Drill 12.25"Intermediate FI 5,684'to 5,755'MD(3,668'TVD)780 GPM,1,200 PSI,120-150 RPM,WOB 15-20K,TON 8K. TQF 7K,HST 175K,SLK 127K,ROT 150K,ECD N/A.Max Gas 5 units.ADT 4.11,Bit Hrs 40.63,Jar Hrs 62.94.Monitor well,static. SPR @ 5,754'MD(3.670'TVD)WI 9.2 ppg MW. MP#1 30-160,40-170 MP#2 30-160,40-170 MP#3 30-160,40-170 1200 13:30 ' 1.50 13.50 DRILL E 7 P PJSA CBU 3X while POOH F/5.755'to 5,596'MD @ 900 GPM,120 RPM,TRQ 7-9K.HST 175K,SLK 126K,ROT 150K. 13.30 15:30 2.00 15.50 DRILL E 4 XDO1 PJSA Decision was made to pump out of hole due to level 3 shocks.Pump out of hole F/5,596'to 4,440'MD,500 GPM. 640 PSI,HST 170K,SLK 130K. 15:30 21:30 6.00 21.50 DRILL E 6 XDO1 PJSA Over pull was observed,begin BROOH as per K&M Rep F/4.440'to 2,611'MD,900 GPM,1,330 PSI,150 RPM, TRQ 4-8K,ROT WT 141K. 21:30 23:00 1.50 23.00 DRILL E 7 XDO1 PJSA CBU 3X 900 GPM,1,310 PSI,80 RPM,TRO 4K.HST 151K,SLK 130K,ROT WT 141K.Monitor well for 10 Min., static.Blow down Top Drive. 23:00 0000 1.00 24.00 DRILL E 4 XDO1 PJSA POOH on Elevators F/2,611'to 2.144'MD HST 145K,SLK 130K. Daily Contacts • Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Eni representative Nelson Carballo ENI Dilling Superintenda Eni representative Matt Smith ENI Matls Coordinator Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L-80 13.50 815.95 10/6/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g(L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 1 011)1* Eni E&P Division (well Name: SPO8-N7 OR EN!Petroleum Co.Inc. Daily Report Well Code:27537 Field Name: Nikaitchuq • 2^n Date:10/14/2013 - Report#: 15 APIIUWI:50-629-23501-00-00 'III II page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 11.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,933.04 1,156.20 178.92 3.19 56.1 109.0 -2.2 Overcast,WC 14° SW @ 25 MPH Daily summary operation 24h Summary Cont.CBU 3X due to clay pack off in Stack W/842 GPM,1,136 PSI.Blow down TDS-8.Cont.POOH on Elevators F/2,144'to 361'MD.Monitor well @ BHA,static.R/U HT-100 Tongs to L/D BHA#4. Rack back Jar stand,stand of HWDP and Collars.UD BHA#4 as per Schlumberger DD and MWD onsite.Clean and clear rig floor.Calculated hole fill observed on trip out.Function BOPE to wash out clay from cavities.P/U M/U Johnny Whacker with one stand of D.P.to wash out the Stack and Well Head.SIMOPS Stage new BHA#5 components on rig floor.P/U M/U BHA#5 W/rerun 12.25"PDC Bit. R/D HT-100 Tongs.R/U HT-65 Tongs.HST 101K,SLK 101K.RIH BHA#5 W/5"D.P.F/361'to 1,011'MD,shallow hole test tools as per Sclumberger DD&MWD.Cont.RIH F/1,011'to 1,475'MD.P/U M/U NOV Black Box Sub.Cont.to RIH F/1,475'to 2,670'MD.Gather parameters as per K&M Rep onsite,ROT WT 141K,TRQ 3-5K,30 RPM,Cont.RIH F/2,670'to 5,598'MD HST 175K,SLK 126K, Filling pipe every 20 stands.Perform check shot survey as per Schlumberger DD.Wash and ream F/5,598'to 5,755'MD,900 GPM,1,580 PSI,40 RPM,TRQ 4-9K,ROT 150K,ECD 9.61 ppg W/9.25 ppg MW.Drill 12.25"Intermediate F/5,755'to 6,342' MD(3,792'TVD)750 GPM,1,210 PSI.100-120 RPM,WOB 4-12K,TON 9-10K,TQF 6-9K,HST 179K,SLK 130K,ROT 151K,ECD 9.84 ppg WI 9.25 ppg MW.Max Gas 42 units.ADT 3.19,Bit Hrs 7,Jar Hrs 66.13.Monitor well,static. Operation at 07.00 Drilling ahead 12.25"@ 6,810'MD. 24h Forecast Drill ahead in 12.25"intermediate hole as per SLB F/6,342'to-7,992'MD. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 0500 5.00 5.00 DRILL E 4 XDO1 PJSA Cont.CBU 3X due to clay pack off in Stack W/842 GPM,1,136 PSI.Blow down TDS-8.Cont.POOH on Elevators F/ 2.144'to 361'MD.Monitor well 5 BHA,static. 05:00 07.30 2.50 7.50 DRILL E 20 XDO1 PJSA R/U HT-100 Tongs to L/D BHA#4.Rack back Jar stand,stand of HWDP and Collars.UD BHA#4 as per Schlumberger DD and MWD onsite.Clean and clear rig floor.Calculated hole fill observed on trip out. 07:30 08.00 0.50 8,00 DRILL E 20 XDO1 PJSA Function BOPE to wash out clay from cavities.P/U M/U Johnny Whacker with one stand of D.P.to wash out the Stack and Well Head.SIMOPS Stage new BHA#5 components on rig floor. 08:00 12:00 4.00 12.00 DRILL E '20 XDO1 PJSA P/U M/U BHA#5 W/rerun 12.25"PDC Bit.R/D HT-100 Tongs.R/U HT-65 Tongs. 12:00 12:30 0.50 12.50 DRILL E 20 XDO1 PJSA Cont.P/U M/U BHA#5 asper Schlumberger DD&MWD onsite.HST 101K,SLK 101 K. 12.30 17:00 4.50 17.00 DRILL E 4 XDO1 PJSA RIH BHA#5 WI 5"D.P.F/361'to 1,011'MD,shallow hole test tools as per Schlumberger DD&MWD.Cont.RIH F/ 1.011'to 1,475'MD.P/U M/U NOV Black Box Sub.Cont.to RIH F/1,475'to 2.670'MD.Gather parameters as per K&M Rep onsite.ROT WT 141K,TRQ 3-5K.30 RPM.Cont.RIH F/2,670'to 5.598'MD HST 175K,SLK 126K,Filling pipe every 20 stands.Perform check shot survey as per Schlumberger DD. 17.00 18:00 1,00 18.00 DRILL E 4 XDO1 PJSA Wash and ream F/5,598'to 5,755'MD,900 GPM,1,580 PSI,40 RPM,TRQ 4-9K,ROT 150K,ECD 9.61 ppg W/ 9.25 ppg MW. SPR @ 5,688'MD(3,657'TVD)W/9.25 ppg MW. MP#1 30-140,40-160 MP#2 30-130,40-150 MP#3 30-140,40-160 18.00 00:00 6.00 24.00 DRILL E 3 P Drill 12.25"Intermediate F/5,755'10 6,342' MD(3,792'ND)750 GPM,1,210 PSI,100-120 RPM,WOB 4-12K,TON 9- _,.....- 10K, i10K,TQF 6-9K,HST 179K,SLK 130K,ROT 151K,ECD 9.84 ppg W/9.25 ppg MW.Max Gas 42 units.ADT 3.19,Bit Hrs 7, Jar Hrs 66.13.Monitor well,static. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl 5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig155doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig155doyondrilling.com 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Eni representative Nelson Carballo ENI Dilling Superintenda Eni representative Matt Smith ENI Malls Coordinator Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 13.50 815.95 10/6/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 If* Eni E&P Division I Well Name:SPOS-N7 OR ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name: Nikaitchuq • API/UWI:50-629-23501-00-00 enn Date:10/15/2013 - Report#: 16 I' II II page 1 of 1 Wellbore name: SPO8-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 .DRILLING 10/3/2013 4,767.38 1209.68 4.788.41 134.16 35.7 12.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr( Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2.452.12 1,240.35 519.07 7.77 66.8 110.0 -3.3 Overcast,WC 26° Calm Daily summary operation 24h Summary Drill 12.25"Intermediate F/6,342'to 8,045'MD(4,068'TVD)800 GPM,1,560 PSI,120-160 RPM,WOB 8-15K,TON 12K,TOP 7K,HST 182K,SLK 135K,ROT 159K,ECD 9.98 ppg W/9.3 ppg MW.Max Gas 1,290 units.ADT 7.77,Bit Hrs 14.77,Jar Hrs 73.90.Monitor well,static.TD 12.25"Intermediate @ 14:31.Shoot survey as per Schlumberger DD.CBU,900 GPM,1,900 PSI,120 RPM,TRQ 8-9K, ROT 156K,ECD 9.95 ppg W/9.3 ppg MW.Max Gas 260 units.BROOH as per K&M BROOH schedule @ 10 Min.per stand F/8,045'to 5,038'MD,900 GPM 1,610 PSI,120 RPM,TRQ 6-7K,ROT 148K, ECD 9.79 ppg W/9.35 ppg MW.Max Gas 5 units.No losses to formation. Operation at 07.00 BROOH 12.25"Intermediate as per K&M BROOH schedule @ 3,731'MD. 24h Forecast BROOH 12.25"Intermediate as per K&M BROOH schedule FI 5,038'to BHA#5.UD BHA#5 as per Schlumberger DD&MD.CIO and test 9 5/8"Rams.CIO Wear Ring to short body as per Vetco.R/U Tesco Csg.Tool as per Rep onsite.P/U M/U 9 5/8"Csg.Shoe.Test Float and float 9 5/8"Csg as per tally and K&M running speed. Lithology Shows MAASP(kgf/cmt) Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dar(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 DRILL E 3 P Drip 1225"Intermediate F/6,342'to 7,088' MD(3.930'TVD)900 GPM,1,730 PSI,160 RPM,WOB 9K,TON 8-11K,TOF 8K,HST 178K,SLK 135K,ROT 155K,ECD 9.91 ppg W/9.25 ppg MW.Max Gas 52 units.ADT 3.44,Bit Hrs 10.44,Jar Hrs 69.57.Monitor well,static. - 06.00 1200 6.00 12.00 DRILL E 3 P Drill 12.25"Intermediate F/7,088'to 7,744'MD(4,025'TVD)750 GPM,1,430 PSI,150 RPM,WOB 10K,TON 8-12K,TOP 9K,HST 185K,SLK 131K,ROT 155K,ECD 9.94 ppg W/9.25 ppg MW.Max Gas 1,290 units.ADT 3.18,Bit Hrs 13.62,Jar Hrs 72.75.Monitor well,static. SPR @ 7,741'MD(4,025'NO)W/9.25 ppg MW. MP#1 30-260,40-280 MP#2 30-260,40-280 MP#3 30-260,40-280 12.00 14.30 2.10 14.50 DRILL E 3 P Drill 12.25"Intermediate F/7,744'to 8,045'MD(4,068'ND)800 GPM,1,560 PSI,120-160 RPM,WOB 8-15K,TQN 12K, TOE 7K,HST 182K,SLK 135K,ROT 159K,ECD 9.98 ppg W/9.3 ppg MW.Max Gas 657 units.ADT 1.15,Bit Hrs 14.77, Jar Hrs 73.90.Monitor well,static.TD 12.25"Intermediate @ 14:31.Shoot survey as per Schlumberger DD. SPR @ 8,044'MD(4,068'ND)W/9.3 ppg MW. MP#1 30-220,40-250 MP#2 30-220,40-250 MP#3 30-220,40-250 14:30 15:30 1.00 15.50 DRILL E 7 P PJSA CBU,900 GPM,1,900 PSI,120 RPM,TRO 8-9K,ROT 158K,ECD 9.95 ppg W/9.3 ppg MW.Max Gas 260 units. 15:30 18:00 2.50 18.00 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule @ 10 Min.per stand F/8,045'to 6,980'MD,900 GPM 1,820 PSI,120 RPM. TRO 9-10K,ROT 152K,ECD 9.96 ppg W/9.35 ppg MW.Max Gas 5 units. 18:00 00:00 6.00 24.00 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule @ 10 Min.per stand F/6,980'to 5,038'MD,900 GPM 1,610 PSI,120 RPM. TRQ 6-7K,ROT 148K,ECD 9.79 ppg W/9.35 ppg MW.Max Gas 5 units.No losses to formation. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Tool Push •Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Eni representative Steve Abbott ENI Rig Clerk Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L-80 13.50 815.95 10/6/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P Lea kOff(kgf/cm°) 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 Eni E&P Division �. Iwel1 me:SPO8-N7OR VII* ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • Date:10/16/2013 - Report#: 17 API/UWI:50 629-23501-00-00 t i io page 1 of 1 Wellbore name: SP08-N7 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11,20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3'2013 4,767.38 1,209.68 4.788.41 134.16 35.7 13.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 2,452.12 1,240.35 0.00 110.0 -1.7 Overcast WC 18' E @ 14 MPH Daily summary operation 24h Summary BROOH as per K&M BROOH schedule F/5,038'to 2,611'MD,900 GPM 1,290 PSI,120 RPM,TRQ 2-5K,HST 149K,SLK 138K,ROT 145K.Back ream @ 10 Min.per stand to 4,400'MD,increase to 5 Min.per stand to 2,611'MD.No losses to formation.Circulate @ Shoe 2,611'MD,900 GPM,1,220 PSI,120 RPM,TQF 2-3K,HST 149K,SLK 145K.Pumped a total of 17.766 Strks till Shakers were clean.POOH on Elevators F/2,611'to 2,141'MD,HST 141K.Pump dry job&blow down TS-8.Cont.POOH F/2,141'to 360'MD.No losses to formation.Lay down BHA#5 8"components as per Schlumberger DD&MWD.Clear rig floor.R/D rig tongs.R/U HT-100 tongs.Lay down BHA#5 9"components as per Schlumberger DD&MWD.R/D L/D HT-100 tongs from ng floor.C/O upper rams to 9 5/8"Csg.SIMOPS clear and clean rig floor.Drain Stack,pull Wear Ring&set test plug as per Vetco Grey Rep onsite.Install 9 5/8"test joint.R/U test Equip.&test 9 5/8"Rams to 250 PSI low and 3,500 PSI high.Pull test plug,drain Stack&set Wear Ring as per Vetco Grey Rep onsite.Length 48.0",13.438"OD,12,31"ID.PJSM W/all essential personnel onsite.R/U M/U Tesco running tools as per Tesco Rep onsite.R/U rig tongs to run 9 518"Csg.P/U M/U 9 5/8"Csg.Shoe track and RIH to 168'MD.Test floats,good test.HST 178K,SLK 178K. Operation at 07.00 Float 9 5/8"Csg @ 2,057'MD.Changing out damaged jnt 24h Forecast RIH Floating Intermediate 9 5/8"Csg.F/168'to 8,030'MD.R/D Tesco Tool as per Rep onsite.R/U M/U Cement head to 9 5/8"Csg.Fill 9 5/8"Csg as per well plan.Circ.and condition mud as per MI Swaco plan forward prior to cement job.Perform cement job. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 08:30 8.50 8.50 DRILL E 6 P PJSA BROOH as per K8M BROOH schedule F/5,038'to 2,611'MD,900 GPM 1,290 PSI,120 RPM,TRQ 2-5K,HST 149K,SLK 138K,ROT 145K.Back ream @ 10 Min.per stand to 4,400'MD,increase to 5 Min.per stand to 2,611'MD.No losses to formation. 08:30 10:00 1.50 10.00 DRILL E 7 P PJSA Circulate @ Shoe 2,611'MD,900 GPM,1,220 PSI,120 RPM.TOP 2-3K,HST 149K.SLK 145K.Pumped a total of 17,766 Strks till Shakers were clean. 10:00 12:00 2.00 12.00 DRILL E 4 P PJSA POOH on Elevators F/2,611'to 2,141'MD.HST 141K.Pump dry job&blow down TS-8.Cont.POOH F/2.141'to 1.677'MD,No losses to formation. 12:00 12:30 0.50 12.50 DRILL E 4 P PJSA POOH on Elevators F/1,677'to 360'MD,HST 100K,SLK 100K.No losses to formation. 12.30 14:30 2.00 14.50 DRILL E 4 P PJSA Lay down BHA#5 8"components as per Schlumberger DD&MWD. 14:30 16:30 2.00 16.50 DRILL E 20 P PJSA Clear rig floor.R/D rig tongs.R/U HT-100 tongs.Lay down BHA#5 9"components as per Schlumberger DD&MWD. R/D L/D HT-100 tongs from rig floor.12.25"PDC Bit Grade 0-0-CT-A-X-I-NO-TD 16:30 17.30 1.00 17.50 DRILL C 20 P PJSA C/O upper rams to 9 5/8"Csg.SIMOPS clear and clean ng floor. 17:30 18:30 1.00 18.50 DRILL C 20 P PJSA Drain Stack,pull Wear Ring&set test plug as per Vetco Grey Rep onsite.Install 9 5/8"test joint. 18:30 19:30 1.00 19.50 DRILL C 12 P PJSA R/U test Equip.&test 9 5/8"Rams to 250 PSI low and 3,500 PSI high. 19:30 20:00 0.50 20.00 DRILL C 20 P PJSA Pull test plug,drain Stack&set Wear Ring as per Vetco Grey Rep onsite.Length 48.0",13.438"OD,12.31"ID. 20:00 23:00 3.00 23.00 DRILL G 20 P PJSM W/all essential personnel onsite.R/U M/U Tesco running tools as per Tesco Rep onsite.R/U rig tongs to run 9 5/8" Csg. 23:00 00.00 1.00 24.00 DRILL G 4 P PJSA P/U M/U 9 5/8"Csg.Shoe track and RIH to 168'MD.Test floats,good test,HST 178K,SLK 178K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Steve Abbott ENI Rig Clerk Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 0.14 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 Eni E&P Division I Well Name:SPO8-N7 OR ENI Petroleum Co.Inc. Daily Report Wen Code:27537_ Field Name:Nikaitchuq $11* • API/UWI:50-629-23501-00-00 2^n Date:10/17/2013 - Report#: 18 (I 'I II page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16_44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7 DRILLING 10/3/2013 4..767.38 1,209.68 4.788.41 134.16 35.7 14.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2.452.12 1,240.35 0.00 110.0 1.7 Clear WC 29' ENE @ 8 MPH Daily summary operation 24h Summary PJSM WI all essential personnel.Float in hole 9 5/8"Csg.as per tally F/168'to 2,181'MD.Crushed 9 5/8"Csg.Joint 53 due to over torque.Egged Joint 54 due to trying to break out joint.Cut joint 54 and laid it down.Pulled and laid down joint 53.Float 9 5/8"Csg.as per K&M running schedule F/2,181'to 3,987'MD.Before entering open hole @ 2,673'MD get parameters for K&M,SLK 79K,ROT 86K, TRQ 4K.Total joints in hole 97 joints.HST 92K,SLK 75K.Calculated displacement observed.Float in hole 9 5/8"Cog.as per K&M schedule Fl 3,987'to 6.652'MD,down weight 55K.Rotate in hole F/ 6,652'to 8,030'MD,40 RPM,TRQ 8K,ROT W'80K.Total of 195 9 5/8"Tenaris dope less RIH.Calculated displacement observed.Tesco running tool and clear floor of Csg.Equip.P/U M/U Cement Head&R/U to fill 9 5/8"Csg.as per well plan.Fill 9 5/8"Csg.as per well plan.Pump 4 bpm to 1/2 way&bleed,3/4 away&bleed.Top off three times and bleed air.Venfy Csg.is topped off.Load Cement Head W/Wiper Plugs W/Schlumberger cementer Rep onsite.Break Circ.W/break over PSI @ 320 PSI.Cont.Circ.@ 2 bpm,270 PSI to treat for cement job to bring YP<18. Operation at 07.00 Circ.and condition for 9 5/8"Csg.cement job. 24h Forecast Cont.to Circ.and condition to<18 YP for cement job.Perform cement job pumping 100 bbl Mud Push II and 260 bbl 12.5 ppg LiteCrete.Have rig pump 593 bbl to bump plug.R/D Cement Head.Displace mud out of 9 5/8"Csg.stump.P/U BOPE stack and set emergency slips as per Vetco Grey.Perform 20 bbl injectivity test in 13 3/8"X 9 5/8"annulus. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL G 4 P PJSM WI all essential personnel.Float in hole 9 5/8"Csg.as per tally F/168'to 2.181'MD. 03:30 09.00 5.50 9.00 DRILL G 20 U PJSA Crushed 9 518"Csg.Joint 53 due to over torque.Egged Joint 54 due to trying to break out joint.Cut joint 54 and laid it down.Pulled and laid down joint 53. • 09:00 12.00 3.00 12.00 DRILL G 4 P PJSA Float 9 5/8"Csg.as per K&M running schedule F/2,181'to 3,987'MD.Before entering open hole @ 2,673'MD get parameters for K&M,SLK 79K.ROT 86K,TRQ 4K Total joints in hole 97 joints.HST 92K.SLK 75K.Calculated displacement observed. 12.00 16.30 4.50 16.50 DRILL 0 4 P PJSA Float in hole 9 5/8"Csg.as per K&M schedule F/3,987'to 6,652'MD,down weight 55K.Rotate in hole F/6,652'to 8.030'MD.40 RPM,TRO 8K,ROT WT 80K.Total of 195 9 5/8"Tenaris dope less RIH.Calculated displacement observed. 1630 17:30 1.00 17.50 DRILL G 20 P PJSA R/D Tesco running tool and clear floor of Csg.Equip. 17.30 18:00 0.50 18.00 DRILL H 20 P PJSA P/U M/U Cement Head&R/U to fill 9 5/8"Csg.as per well plan. 18.00 21:30 3.50 21.50 DRILL G 7 P PJSA Fill 9 5/8"Csg.as per well plan.Pump 4 bpm to 1/2 way&bleed,3/4 away&bleed.Top off three times and bleed air. 21.30 22:00 0.50 22.00 DRILL H 20 P PJSA Verify Csg.is topped off.Load Cement Head W/Wiper Plugs W/Schlumberger cementer Rep onsite. 22:00 00:00 2.00 24.00 DRILL H 7 P PJSA Break Circ.W/break over PSI @ 320 PSI.Cont.Circ.@ 2 bpm,270 PSI to treat for cement job to bring YP<18. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Sup/ SIDDnlling@enipetroleum.com '907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 0.14 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 Eni E&P Division 'Wen Name:SP08-N7 OR $111* ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • APIIUWI:50-629-23501-00-00 • 2in o Date:10/18/2013 - Report#: 19 (( I� page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlltr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 15.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours)hr) Avg ROP(m/hr) POB Temperature('C) Weather Wind 2,452.12 1,240.35 0.00 107.0 -2.8 Overcast WC 20° ENE @ 7 MPH Daily summary operation 24h Summary Stage up bumps F/2 bpm to 6 bpm,290 PSI,condition LSND for cement job to a 14 YP.PJSM W/all essential personnel.Test cement line to 900 PSI low and 3,600 PSI high stall.Pump 100 bbl Mud Push II 10.5 ppg @ 5 bpm,170 PSI.Drop bottom plug as per Schlumberger Rep onsite.Pump 261.4 bbl 12.5 ppg LiteCRETE @ 4 bpm,ICP 140 PSI,FCP 40 PSI.Drop top plug as per Schlumberger Rep onsite and kick out W/10 bbl water.Displace W/ng pumps @ 8 bpm,ICP 80 PSI.Slow pumps down @ 570 bbl away to 3 bpm.Plug bumped @ 592 bbl away,FCP 710 PSI.Increase Press.to 1,210 PSI and hold for 5 Min.Bleed off Press.and check floats.(Good)CIP @ 11:12 Hrs.Blow down lines.Close Annular Preventor and inject 20 bbl down 13 3/8"X 9 5/8"annulus @ 2 bpm,710 PSI. Bleed off Press.R/D lines and Cement Head.Clean and clear rig floor.R/U Bails.Get 1 stand F/Derrick and displace mud from 9 5.8"landing joint.Blow down lines,drain and rinse stack.N/D BOPE. Split BOPE as per Vetco Grey Rep onsite.Prep Multi Bowl for emergency sips.Pull 100K over and set emergency slips as per Vetco Grey Rep onsite.Cut 9 5/8"Csg with air cutter.Pull landing joint and L/D.Dress 9 5/8"Csg stump&install Pack Off.Test to 2,200 PSI witnessed by CO Rep.Pull Wear Ring.N/U BOPE.C/O upper rams to 3.5"X 6".SIMOPS Freeze Protect 13 3/8"X 9 5/8"Csg.W/Little Red Services at 2 bpm 1,000 PSI. Operation at 07.00 R/U to Test BOP's 24h Forecast Cont.N/U BOPE.P/U 4.5"D.P.from Pipe Shed.Set test plug and test BOPE.R/U HOWCO Wireline and tractor.Perform CBL.R/D Wireline.P/U M/U BHA#6. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deser. 00:00 07.30 7.50 7.50 DRILL H 7 P PJSA Stage up bumps F/2 bpm to 6 bpm,290 PSI,condition LSND for cement job to a 14 YP. • 0730 '11 30 4.00 11.50 DRILL H 9 P PJSM W/all essential personnel.Test cement line to 900 PSI low and 3,600 PSI high stall.Pump 100 bbl Mud Push II 10.5 / r, ppg @ 5 bpm,170 PSI.Drop bottom plug as per Schlumberger Rep onsite.Pump 261.4 bbl 12.5 ppg LiteCRETE @ 4 `T bpm,ICP 140 PSI,FCP 40 PSI.Drop top plug as per Schlumberger Rep onsite and kick out W/10 bbl water.Displace WI rig pumps @ 8 bpm,ICP 80 PSI.Slow pumps down @ 570 bbl away to 3 bpm.Plug bumped @ 592 bbl away,FCP 710 PSI.Increase Press.to 1,210 PSI and hold for 5 Min.Bleed off Press.and check floats.(Good)CIP @ 11:12 Hrs.Blow G down lines. 11:30 12:00 0.50 12.00 DRILL H 9 -P PJSA Close Annular Preventor and inject 20 bbl down 13 3/8"X 9 5/8"annulus @ 2 bpm,710 PSI.Bleed off Press. 12:00 12:30 0.50 12.50 DRILL H 20 P PJSA R/D lines and Cement Head.Clean and clear rig floor. 12:30 13:00 0.50 13.00 DRILL E 20 •P PJSA R/U Bails.Get 1 stand F/Derrick and displace mud from 9 5.8"landing joint.Blow down lines,drain and rinse stack. 13:00 14:30 1.50 14.50 DRILL C 20 P PJSA N/D BOPE.Split BOPE as per Vetco Grey Rep onsite.Prep Multi Bowl for emergency sips. 14:30 19:00 4.50 19.00 DRILL C 20 P PJSA Pull 100K over and set emergency slips as per Vetco Grey Rep onsite.Cut 9 5/8"Csg with air cutter.Pull landing joint and L/D.Dress 9 5/8"Csg stump&install Pack Off.Pull Wear Ring. 19:00 00:00 5.00 24.00 DRILL C 20 'P PJSA N/U BODE.C/O upper rams to 3.5"X 6".SIMOPS Freeze Protect 13 3/8"X 9 5/8"Csg.W/Little Red Services at 2 bpm 1,000 PSI. Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile En:representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator En:representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 En:representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 0.14 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) 'TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 • filf* Eni E&P DivisionWell Name:SP08-N7 OR EN!Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • 2^ii Date:10/19/2013 - Report#: 20 APIIUWI.50-629-23501-00-00 II 'I page 1 of 1 Wellbore name: SP08-N7 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4.767.38 1.209.68 4.788.41 134.16 35.7 16.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 2,452.12 1,240.35 0.00 107.0 -1.7 Light Fog WC 22` E @ 7 MPH Daily summary operation 24h Summary PJSA Clear and clean rig floor.Install guards on Dravwwrks and drill console.Install Bell Guide on TS-8.CIO elevators to 4.5"and CIO Super Choke. SIMOPS Freeze protect 13 3/8"X 9 5/8"Annulus W/160 bbl Diesel @ 2 bpm,100 PSI.P/U M/U60 joints 4.5"D.P.F/Pipe Shed via Mouse Hole and rack back in Derrick.Drift 2.375".R/U to test BOPE.M/U TT-525,NC-50 and NC-46 floor valve and dart.M/U landing joint to test plug and set as per Vetco Grey rep onsite.Test BOPE,Witnessed waived by AOGCC Rep Jeff Turkington.R/D test Equip.Pull test plug and set Wear Ring as per Vetco Grey Rep onsite.W/all essential personnel.R/U Wireline Equip.and build tool string W/HOWCO and Well Tech Services.Power up tools and lest.(Test Good)RIH W/Tractor and CBL Tools to 900' WLM.E-Line unit experienced intermittent communication with down hole tools and POOH.Trouble shot communication issue.C/O CBL Tool.Test Tool,good.SIMOPS Took on 630 bbl 9.25 ppg Faze Pro @ 19:00.W/Wireline CBL Tools to 7,950'WLM.Begin logging out of hole @ 35 FPM. Operation at 07.00 R/D HOWCO&Well Tech Services. 24h Forecast Perform CBL logging W/Well Tech and HOWCO.R/D Wireline and tools.Perform 9 5/8"Csg.test to 3,000 PSI for 30 Min.P/U M/U BHA#6 and RIH. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1103.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 20 P PJSA Clear and clean rig floor.Install guards on Dravw.orks and drill console.Install Bell Guide on TS-8.C/O elevators to 4.5"and C/O Super Choke.SIMOPS Freeze protect 13 3/8"X 9 5/8"Annulus W/160 bbl Deisel @ 2 bpm,100 PSI. 01:30 04:00 2.50 4.00 DRILL E 20 P PJSA P/U M/U 60 joints 4.5"D.P.F/Pipe Shed via Mouse Hole and rack back in Derrick.Drift 2.375". 04:00 06:00 - 2.00 6.00 DRILL C 12 P PJSA R/U to test BOPE.M/U TT-525,NC-50 and NC-46 floor valve and dart.M/U landing joint to test plug and set as per Vetco Grey rep onsite. 06:00 12:00 6.00 12.00 DRILL C 12 P PJSA Test BOPE:Test to 250 PSI low 5 Min.and 2,500 PSI 5 Min.high,Annular preventer W/4.5"&5.5"test joint.Test to 250 PSI 5 Min.low and 3,500 PSI 5 Min.high.W/5.5"test joint:Top Pipe Rams(3.5"X 6"VBR'S),Blind Rams,Lower Pipe Rams(4.5"X 7"VBR'S),HCR Kill,HCR Choke,Main Kill,Main Choke,Upper IBOP,Lower IBOP,3 1/8"Kill on Mud Line, 4.5"IF TIW,4.5"IF Dart Valve,TT-525 TIW,TT-525 Dart Valve,NC46 Dart Valve,Choke Manifold Valves 1 thru 18. Witnessed waived by AOGCC Rep Jeff Turkington. 12.00 13.00 1.00 13.00 DRILL C 12 P PJSA Test Upper Pipe Rams(3.5"X 7"VBR's)&Lower Pipe Rams(4.5"X 7"VBR's)W/4.5"test joint&NC-46 TIW to 250 PSI low 5 Min.&3,500 PSI high 5 Min.Test A&B Manual Choke&Super Choke to 1,500 PSI.Perform Koomey draw down test.Start Press.2,950 PSI,Press.after function 1,500 PSI,200 PSI increase @ 42 Sec.Total recharge time 194 Sec.5 Nitrogen bottles average 2,450 PSI. 13:00 14:00 1.00 14.00 DRILL C 20 P PJSA R/D test Equip.Pull test plug and set Wear Ring as per Vetco Grey Rep onsite. 14:00 16:00 2.00 16.00 DRILL R 1 P PJSM W/all essential personnel.R/U Wireline Equip.and build tool string W/HOWCO and Well Tech Services. 16:00 16:30 0.50 16.50 DRILL R 12 P PJSA Power up tools and test.(Test Good) 16:30 17:30 1.00 17.50 DRILL R 4 P PJSA RIH W/Tractor and CBL Tools to 900'WLM. 17:30 18:30 1.00' 18.50 DRILL R 4 P E-Line unit experienced intermittent communication with down hole tools and POOH.Trouble shot communication issue. C/O CBL Tool.Test Tool,good.SIMOPS Took on 630 bbl 9.25 ppg Faze Pro @ 19:00. 18:30 00:00 5.50 24.00 DRILL R 4 P RIH W/Wireline CBL Tools to 7,950'WLM.Begin logging out of hole @ 35 FPM. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 '715-6434 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 0.14 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/LI P LeakOff(kgf/cm') 815.95 753.45 WBM 1102.4 34.3 155:.1 1173 -I Eni E&P Division 'Well Name:SP08-N7 OR rif* ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • Date:10/20/2013 - Report#: 21 APIIUWI:50-629-23501-SO-OS en11 page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4.788.41 134.16 35.7 17.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,458.52 1,240.92 6.40 0.22 29.1 103.0 -3.9 Clear WC 15' WSW @ 10 MPH Daily summary operation 24h Summary Perform CBL via HOWCO CAST tool on wireline and Well Tech tractor tool F/7,850'to 3.358'WLM.R/D HOWCO wireline as per Well Tech and HOWCO Rep onsite.L/D all tools and Equip.R/U test Equip.for 9 5/8"Csg.Test 9 5/8"Csg.to 3,000 PSI for 30 Min.charted W/CO Rep onsite.R/D test Equip.Clear and clean rig floor.Blow down Kill Line.Bring BHA#6 subs to rig floor via Beaver Slide. C/O Saver Sub on TS-8.PJSM W/all essential personnel.P/U M/U 8 3/4"BHA#6 as per Schlumberger DD&MWD Rep onsite.Bit,Exceed,Periscope.STAB,ADN Vision.C/O to back up ADN Vision due to defective density sensor.Have SID security call out stay clear due to nuclear sources being loaded.Load Radioactive sources in ADN Vision as per Schlumberger MWD Rep onsite.SID security give all clear.Cont.P/U M/U 8 3/4"BHA#6 as per Schlumberger DD&MWD.STAB,3 NMFC,Saver Sub,X/O,1 stand 5"HWDP,Jars,Saver Sub and 2 Jnts 5"HWDP.HST 98K,SLK 98K.TIH F/394' to 1,433'MD.Shallow hole test tools.400 GPM,540 PSI.Cont.RIH to 7,509'MD,HST 185K,SLK 125K.Filling pipe every 20 stands.Perform strip in drill.Strip in 1 stand,POOH remove Dart&TIW valve.Have lesson learned with crew.RIH W/4.5"D.P.F/7,509'to 7,794'MD.Wash&Ream F/7.794'and tag plugs @ 7,941'MD.400 GPM.1,050 PSI.HST 185K,SLK 125K.CBU @ 7,941'MD 400 GPM,1.050 PSI.W/all essential personnel.Pump 50 bbl High Vie Spacer @ 5 bpm,430 PSI,Pump 40 bbl LVT Spacer @ 5 bpm,740 PSI.Displace well W/575 bbl 9.25 ppg new FazePro @ 12 bpm, 2.000 PSI,POOH to 7.889'MD racking back 1 stand.Cut and slip drilling line.Check Rollers,inspect and adjust Brakes.SIMOPS Clean surface Equip.from displacement.RIH to 7,941'MD and drill out plugs and float,drill out cement&tag Shoe @ 8,030'MD.Drill cement and tag bottom @ 8,045'MD.Cont.to drill ahead 20'to 8,066'(4,071'ND)MD.500 GPM,2,130 PSI.60 RPM.TRO 8-12K.SLK 125K,ROT 150K,ECD 10.09 W/9.2 ppg MW.ADT 0.22 Operation at 07.00 Drill 8 3/4"Production hole @ 8.145'MD. 24h Forecast Circ.and conditon FazePro until!9.2 ppg mud weight is seen in and out.R/U and Perform LOT or FIT.Drill ahead 8 3/4"Production hole to-15,873'MD. Lithology Shows MAASP(kgflcm2) Mud Weight(g/L) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02.00 2.00 2.00 DRILL R 11 P PJSA Perform CBL via HOWCO CAST tool on wireline and Well Tech tractor tool F/7,850'to 3.358'WLM. 02.00 03.00 1.00 3.00 DRILL R 20 P PJSA R/D HOWCO wireline as per Well Tech and HOWCO Rep onsite.LID all tools and Equip. 03.00 04-.00 1.00 4.00 DRILL E 12 P PJSA R/U test Equip.for 9 5/8"Csg.Test 9 5/8"Csg.to 3,000 PSI for 30 Min.charted W/CO Rep onsite.R/D test Equip. 04.00 07:00 3.00 7.00 DRILL E 20 P PJSA Clear and clean rig floor.Blow down Kill Line.Bring BHA#6 subs to rig floor via Beaver Slide.C/O Saver Sub on TS- 8. 07:00 09:30 2.50 9.50 DRILL E 20 P PJSM W/all essential personnel.P/U M/U 8 3/4"BHA#6 as per Schlumberger DD 8 MWD Rep onsite.Bit,Exceed, Periscope,STAB,ADN Vision.C/O to back up ADN Vision due to defective density sensor. 09:30 10:00 0.50 10.00 DRILL E 20 P PJSA Have SID security call out stay clear due to nuclear sources being loaded.Load Radioactive sources in ADN Vision as per Schlumberger MWD Rep onsite.SID security give all clear. 10:00 12:00 2.00 12.00 DRILL E 20 P PJSA Cont.P/U M/U 8 3/4"BHA#6 as per Schlumberger DD&MWD.STAB,3 NMFC.Saver Sub,X/O,1 stand 5"HWDP, Jars,Saver Sub and 2 Jnts 5"HWDP.HST 98K,SLK 98K. 12:00 15:30 3.50 15.50 DRILL E 4 P PJSA TIH F/394'to 1,433'MD.Shallow hole test tools.400 GPM,540 PSI.Cont.RIH to 7,509'MD,HST 185K,SLK 125K. Filling pipe every 20 stands. 15:30 16:00 0.50 16.00 DRILL E 12 P PJSA Perform strip in drill.Strip in 1 stand,POOH remove Dart 8 TIW valve.Have lesson learned with crew. 16:00 16.30 0.50 16.50 DRILL E 4 P PJSA RIH W/4.5"D.P.F/7,509'to 7,794'MD,HST 185K,SLK 124K. 16:30 17:00 0.50 17.00 DRILL E 4 P PJSA Wash&Ream F/7,794'and tag plugs @ 7,941'MD.400 GPM,1,050 PSI,HST 185K,SLK 125K. 17:00 1730 0.50 17.50 DRILL E 7 P PJSA CBU @ 7,941'MD 400 GPM,1,050 PSI. 17:30 19.30 2.00 19.50 DRILL E 9 P PJSM W/all essential personnel.Pump 50 bbl High Vis Spacer @ 5 bpm,430 PSI,Pump 40 bbl LVT Spacer @ 5 bpm, 740 PSI.Displace well W/575 bbl 9.25 ppg new FazePro @ 12 bpm.2,000 PSI.60 RPM,TRO 8K,ROT WT 149K.POOH to 7,889'MD racking back 1 stand. 19-.30 21'.30 2.00 21.50 DRILL E 20 P PJSA Cut and slip drilling line.Check Rollers,inspect and adjust Brakes.SIMOPS Clean surface Equip.from displacement. 21:30 00:00 2.50 24.00 DRILL E 3 P PJSA RIH to 7,941'MD and drill out plugs and float.drill out cement&tag Shoe @ 8.030'MD.Drill cement and tag bottom @ 8,045'MD.Cont.to drill ahead 20'to 8.066'(4,071'ND)MD.500 GPM,2,130 PSI.60 RPM,TRO 8-12K.SLK 125K. ROT 150K,ECD 10.09 W/9.2 ppg MW.ADT 0.22,Bit Hrs 0.22,JAR Hrs 0.22. SPR @7,889'MD(4,050'ND)W/9.25 ppg MW MP#1 20-150,30-180 MP#2 20-150,30-180 MP#3 20-150,30-180 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl 5@enipetroleum.corn 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 0.14 2,447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgticm2) 815.95 753.45 WBM 1102.4 34.3 1557.8 117.3 I* Eni E&P Division 'Well Name:SP08-N7 OR ENI Petroleum Co.Inc. Daily ReporttWell Code:27537 Field Name: Nikaitchuq • API/UWI:50-629-23501-00-00 2^r, Date:10121/2013 - Report#: 22 II 'I II page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7 DRILLING 10/3/2013 4.767.38 1,209.68 4,788.41 134.16 35.7 18.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 2,888.28 1.253.36 429.77 14.88 28.9 103.0 -10.6 Clear WC 2' SW @ 8 MPH Daily summary operation 24h Summary Circ.&condition mud for balance mud weight in and out,500 GPM,2,080 PSI,60 RPM,7.5K TRQ.Obtain 9.2 ppg MW in and out,POOH F/8,066'to 7,896'MD.R/U test Equip.Perform FIT to 13.0 ppg EMW,806 PSI SIDPP,lost 13 PSI over 10 Min.charted and witnessed by CO Rep onsite.R/D test Equip.Blow down Kill Line.Stand back 1 stand of 5"D.P.C/O elevators to 4.5",RIH 2 stands of 4.5" D.P.F/7,896'to 7,986'MD.C/O elevators to 5",wash to 8,066'MD.Drill ahead 8 3/4"production hole F/8,066'to 9,476'MD(4,108'ND)550 GPM,2,460 PSI,160 RPM,TQN 11K.TQF 8K,WOB 4- 12K,HST 195K,SLK 105K,ROT 154K.ECD 10.31 ppg W/9.2 ppg MW.Max Gas 4.108 units.ADT 14.88,Bit Hrs 15.10,JAR Hrs 15.10.Monitor well,static. Operation at 07.00 Drill 8 3/4"Production hole @ 9,872'MD. 24h Forecast Drill ahead 8 3/4"Production hole F/9,476'to-15,873'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 • Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 7 P PJSA Circ.&condition mud for balance mud weight in and out,500 GPM,2,080 PSI,60 RPM,7.5K TRQ.Obtain 9.2 ppg MW in and out.POOH Fl 8.066'to 7,896'MD. 00:30 01:30 1.00 1.50 DRILL E 11 P PJSA R/U test Equip.Perform FIT to 13.0 ppg EMW,806 PSI SIDPP,lost 13 PSI over 10 Min,charted and witnessed by CO Rep onsite.R/D test Equip.Blow down Kill Line. 01:30 02:00 0.50 2.00 DRILL E 20 P PJSA Stand back 1 stand of 5"D.P.C/O elevators to 4.5".RIH 2 stands of 4.5"D.P.F/7,896'to 7,986'MD.C/O elevators to 5",wash to 8,066'MD 500 GPM.2.080 PSI,60 RPM,7.5K TRQ. 02.00 06.00 4.00 6.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/8,066'to 8,356'MD(4,102'ND)548 GPM.2,530 PSI,80-140 RPM,TQN 11K, TOF 7K,WOB 8-10K,HST 200K,SLK 115K,ROT 150K.ECD 10.6 ppg W/9.2 ppg MW.Max Gas 28 units.ADT 1.8,Bit Hrs 2.02,JAR Hrs 2.02.Monitor well,static. 06.00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/8,356'to 8,690'MD(4,108'ND)548 GPM,2,430 PSI,160 RPM,TON 10-14K, TOF 8K,WOB 6-12K,HST 195K,SLK 115K,ROT 152K.ECD 10.33 ppg W/9.15 ppg MW,Max Gas 1.465 units,ADT 4.58,Bit Hrs 6.6,JAR Hrs 6.6.Monitor well,static. SPR @8635'MD(4.117'TVD)9.15 ppg MW MP#1 20-220,30-280 MP#3 20-220,30-280 12:00 18.00 6.00 18.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/8.690' to 8,795'MD(4,110'TVD)550 GPM,2,380 PSI,160 RPM,TQN 11K, TQF 8K,WOB 4-15K,HST 195K,SLK 115K,ROT 150K.ECD 10.31 ppg W/9.15 ppg MW.Max Gas 235 units.ADT 5.69. Bit Hrs 12.29,JAR Hrs 12.29.Monitor well,static. 18:00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/8,795'to 9,476'MD(4,108'TVD)550 GPM,2,460 PSI,160 RPM.TON 11K, TQF 8K,WOB 4-12K,HST 195K,SLK 105K,ROT 154K,ECD 10.31 ppg W/9.2 ppg MW.Max Gas 4,108 units.ADT 2.81, Bit Hrs 15.10,JAR Hrs 15.10.Monitor well,static. SPR @ 9,476'MD(4.108'TVD)9.25 ppg MW MP#1 20-200,30-260 MP#2 20-200,30-260 MP#3 20-200,30-260 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.cow 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.cow 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 0.14 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB( Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.447.54 1,239.91 FAZE Pro 1102.4 56.6 1559.4 193.3 Eni E&P Division I Well Name: SP08-N7 OR 1"I* ENI Petroleum Co.Inc. Daily Report 'Well Code:27537 Field Name:Nikaitchuq • Date:10/22/2013 - Report#: 23 APIIUWI:50-629-23501-00-00 e i� page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 19.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,429.00 1,243.87 540.72 15.92 34.0 108.0 -7.2 Freezing Fog WC 9' W @ 8 MPH Daily summary operation 24h Summary Drill ahead 8 3/4"production hole F/10,835'to 11,250 MD(4,080'TVD)500 GPM,2,280 PSI,120 RPM,TQN 11K,TQF 8K,WOB 4-10K,HST 205K,SLK 99K,ROT 160K.ECD 10.37 ppg W/9.2 ppg MW.Max Gas 5,727 units.ADT 15.92,Bit Hrs 31.05,JAR Hrs 31.05.Monitor well.static. Operation at 07.00 Drill 8 3/4"Production hole @ 11,668'MD. 24h Forecast Drill ahead 8 3/4"Production hole F/11,250'to-15,873'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log _ Start End Cum • Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 7 6.00'DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/9,476'to 9,943'MD(4,096'TVD)550 GPM,2,480 PSI,160 RPM,TQN 12K, TOF 9K,WOB 6-12K,HST 200K,SLK 104K,ROT 152K.ECD 10.37 ppg W/9.15 ppg MW.Max Gas 2,922 units.ADT 4.29,Bit Hrs 19.39,JAR Hrs 19.39.Monitor well,static. 06.00 1200 6.00 12.00 7 DRILL E 73 P 'PJSA Drill ahead 8 3/4"production hole F/9,943'to 10.223'MD(4.088'TVD)550 GPM,2,490 PSI,160 RPM,TON 12K, TQF 9K,WOB 6-15K,HST 200K,SLK 105K,ROT 150K.ECD 10.49 ppg W/9.2 ppg MW.Max Gas 2.602 units.ADT 4.29. Bit Hrs 23 68,JAR Hrs 23.68.Monitor well,static. SPR @ 10,223'MD(4,088'TVD)9.25 ppg MW MP#1 20-180,30-240 MP#2 20-180,30-240 MP#3 20-180,30-240 12.00 18.00 6.00- 18.00'DRILL E 73 P 'PJSA Drill ahead 8 3/4"production hole F/10,223'to 10,835'MD(4,077'TVD)550 GPM,2.680 PSI,120-160 RPM,TON 12K,TQF 8K,WOB 2-12K,HST 200K,SLK 98K,ROT 155K.ECD 10.59 ppg W/9.2 ppg MW.Max Gas 4.733 units.ADT 4.16.Bit Hrs 27.87,JAR Hrs 27.87.Monitor well,static. 1800 0000 6.007 24.00 1DRILL I E . . 3 P 'PJSA Drill ahead 8 3/4"production hole F/10,835'to 11,250 MD(4,080'TVD)500 GPM,2,280 PSI.120 RPM.TON 11K, i TOF 8K,WOB 4-10K,HST 205K,SLK 99K,ROT 160K.ECD 10.37 ppg W/9.2 ppg MW.Max Gas 5,727 units.ADT 3.18, Bit Hrs 31.05.JAR Hrs 31.05.Monitor well,static. SPR @ 11,156'MD(4,077'TVD)9.2 ppg MW MP#1 20-200,30-260 MP#2 20-200,30-260 MP#3 20-200.30-260 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 0.14 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.447.54 1,239.91 FAZE Pro 1102.4 56.6 1559.4 193.3 Eni E&P Division I Well Name: SP08-N7 OR EN!Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • 2^01191* Date:10/23/2013 - Report#: 24 APIIUWI:50-629-23501-00-00 '111 IInpage 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator EM Share(%( Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 20.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,226.05 1,230.37 797.05 14.09 56.6 110.0 -5.6 Light Snow WC 10` WNW @ 13 MPH Daily summary operation 24h Summary Drill ahead 8 3/4"production hole Fl 11,937'to 13,865'MD(4,033'ND)550 GPM,3,000 PSI,120-160 RPM,TQN 12-13K,TQF 9-10K,WOB 4-12K,HST 212K,SLK 85K,ROT 154K.ECD 11.01 ppg W/ 9.3 ppg MW.Max Gas 4.200 units.ADT 14.09,Bit Hrs 45.14,JAR Hrs 45.14.Monitor well,static. Operation at 07.00 Drill 8 3/4"Production hole @ 14,164'MD. 24h Forecast • Drill ahead 8 3/4"Production hole F/13,865'to-15,873'MD. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/11,250'to 11,937'MD(4,071'ND)525 GPM,2,530 PSI,160 RPM.TQN 11K, TQF 8K,WOB 6-10K,HST 205K,SLK 95K,ROT 155K.ECD 10.98 ppg W/9.3 ppg MW.Max Gas 4,200 units.ADT 3.75, Bit Hrs 34.8,JAR Hrs 34.8.Monitor well,static. 06:00 12.00 6.00 12.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/11,937'to 12,557'MD(4,050'ND)550 GPM,2,780 PSI,160 RPM.TQN 11.5K, TOE 8-9K,WOB 6-15K,HST 210K.SLK 85K,ROT 152K.ECD 11.05 ppg W/9.3 ppg MW.Max Gas 1,838 units.ADT 3,94, Bit Hrs 38.74,JAR Hrs 38.74.Monitor well,static. SPR @ 12,090'MD(4,068'ND)9.3 ppg MW MP#1 20-190,30-260 MP#2 20-200,30-260 MP#3 20-190,30-260 1200 18.00 6.00 18.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/12,557'to 13,212'MD(4,044'ND)550 GPM,2,930 PSI,120-160 RPM,TON 12-13K,TQF 9-10K,WOB 4-12K,HST 210K,SLK 85K.ROT 153K.ECD 11.16 ppg W/9.3 ppg MW.Max Gas 1,548 units. ADT 3.63,Bit Hrs 42.37,JAR Hrs 41.37.Monitor well,static. 18.00 00:00 6.00 24.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/13,212'to 13,865'MD(4,033'ND)550 GPM,3,000 PSI,120-160 RPM,TON 12-13K,TQF 9-10K,WOO 4-12K,HST 212K,SLK 85K,ROT 154K.ECD 11.01 ppg W/9.3 ppg MW.Max Gas 1,749 units. ADT 2.77,Bit Hrs 45.14,JAR Hrs 45.14.Monitor well,static. SPR @ 13,865'MD(4,033'ND)9.3 ppg MW MP#1 20-300,30-390 MP#2 20-300,30-390 MP#3 20-300,30-390 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker EM Expediter 907-980-7545 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L-80 0.14 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.447.54 1,239.91 FAZE Pro 1102.4 56.6 1559.4 193.3 Eni E&P Division I Well Name:SP08-N7 OR 1"1* EN!Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • Date:10/24/2013 - Report#: 25 API/UM:50-629-23501-00-00 ei page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 21.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,786.27 1,227.16 560.22 13.01 43.1 112.0 -17.2 Freezing Fog WC- ENE @ 7 MPH 12" Daily summary operation 24h Summary Drill ahead 8 3/4"production hole F/13,865'to 14.165'MD(4,045'ND),Service TS-8,Blocks&Drawworks. Drill ahead 8 3/4"production hole F/14,465'to 15,703'MD(4,028'TVD) 550 GPM,3,100 PSI,160 RPM,TON 14K,TOP 11K,WOB 4-16K,HST 245K,SLK 85K,ROT 159K.ECD 11.32 ppg W/9.3 ppg MW.Max Gas 5,298 units.ADT 13.01,Bit Hrs 58.15,JAR Hrs 58.15.Monitor well,static. Operation at 07.00 BROOH as per K&M BROOH schedule @ 'MD. 24h Forecast Drill ahead 8 3/4"Production hole F/15.703'to-15,873'MD.BROOH as per K&M BROOH schedule. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 0400 400 4.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/13,865'to 14,165'MD(4,045'TVD)550 GPM,3,025 PSI,120-160 RPM,TON 13K,TQF 9K,WOB 6-15K,HST 230K,SLK 85K,ROT 155K.ECD 11.36 ppg W/9.3 ppg MW.Max Gas 2,573 units.ADT 2.06,Bit Hrs 47.20,JAR Hrs 47.20.Monitor well,static. 04:00 04:30 0.50 4.50 DRILL E 20 P PJSA Service TS-8,Blocks&Drawworks. 04:30 0600 1.50 6.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole FI 14,165'to 14,237'MD(4,049'TVD)505 GPM,2,570 PSI,180 RPM,TON 13K. TQF 9K,WOB 6-15K,HST 230K,SLK 85K,ROT 155K.ECD 11.15 ppg W/9.3 ppg MW.Max Gas 1,100 units.ADT 1.07. Bit Hrs 48.27,JAR Hrs 48.27.Monitor well,static. 0600 1200 6.00 12.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/14,237' to 14,679'MD(4,049'TVD)550 GPM,3,050 PSI,160 RPM.TON 13- 14K,TQF 11K,WOB 6-15K.HST 225K,SLK 85K,ROT 155K.ECD 11.5 ppg W/9.3 ppg MW.Max Gas 5,165 units.ADT 3.01,Bit Hrs 51.28,JAR Hrs 51.28.Monitor well,static. SPR @ 14,679'MD(4,049'ND)9.3 ppg MW MP#1 20-350,30-420 MP#2 20-350,30-420 MP#3 20-340,30-420 12.00 1800 6.00 18.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/14,679'to 15,262'MD(4,056'TVD)550 GPM,3,020 PSI,160 RPM,TON 15K, TQF 12K,WOB 4-15K.HST 229K,SLK 85K,ROT 155K.ECD 11.32 ppg WI 9.3 ppg MW.Max Gas 5,298 units.ADT 3.63, Bit Hrs 54.91.JAR Hrs 54.91.Monitor well,static. 18.00 00.00 6.00 24.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/15,262'to 15,703'MD(4,028'TVD)550 GPM,3,100 PSI,160 RPM,TON 14K. TQF 11K,WOB 4-16K.HST 245K,SLK 85K,ROT 159K.ECD 11.32 ppg WI 9.3 ppg MW.Max Gas 783 units.ADT 3.24, Bit Hrs 58.15.JAR Hrs 58.15.Monitor well,static. SPR @ 15,635'MD(4,035'ND)9.3 ppg MW MP#1 20-380.30-460 MP#2 20-380,30-460 MP#3 20-380,30-470 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher L rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 0.14 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L( P LeakOff(kgf/cm') 2.447.54 1.239.91 FAZE Pro 1102.4 56.6 1559.4 193.3 Eni E&P Division !Well Name:SPO8-N7 OR rit* ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • API/UWI:50-629-23501-00-00 enll Date:10/25/2013 - Report#: 26 I� II page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..,Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) 'DFS(days) SP08-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4.788.41 134.16 35.7 22.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 4.837.18 1.218.60 50.90 2.14 23.8 112.0 -5.6 Overcast WC 10° SE @ 13 MPH Daily summary operation 24h Summary Drill ahead 8 3/4"production hole F/15,703'to 15,870'MD(3,997'TVD)505 GPM,2,770 PSI,160 RPM,TON 12-16K,TQF 10-11K,WOB 10-17K,HST 225K,SLK 85K,ROT 150K.ECD 11.50 ppg W/ 9.35 ppg MW.Max Gas 1,529 units.ADT 2.14,Bit Hrs 60.29,JAR Hrs 60.29.Monitor well,static.CBU 18 as per KW BROOH schedule,450 GPM,2,270 PSI,130 RPM,TRQ 12K.BROOH as per K8M BROOH schedule oras hole dictates F/15,870'to 7,983'MD,500 GPM,2,060 PSI,150 RPM,TRF 10-12K,HST 170K,SLK 130K,ROT 148K.Max Gas 16 units.ECD 10.14 ppg W/9.35 ppg MW.At 8,160'MD observe packing off while pulling BHA thru Shoe @ 8,030'MD.Work string thru Shoe to 7,983'MD clearing obstruction.Circulate and condition hole @ 500 GPM,2,050 PSI,reciprocate F/ 7,983'to 7,888'MD 120 RPM,TRQ 8K.Total lost to formation 50 bbl.. Operation at 07.00 POOH on Elevators 24h Forecast Circulate hole clean.POOH on Elevators to BHA.L/D BHA as per Schlumberger DD 8 MWD.Clean and clear ng floor.PJSM W/all essential personnel.R/U GBR Volant tool and Csg.Equip.RIH W/5.5" slotted liner as per tally. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr( Phase Opr. Act. Plan Oper.Descr. 00.00 0300 3.00 3.00 DRILL E 3 P PJSA Drill ahead 8 3/4"production hole F/15,703'to 15,870'MD(3,997'TVD)505 GPM,2,770 PSI,160 RPM,TON 12- 16K,TOE 10-11K,WOB 10-17K,HST 225K,SLK 85K,ROT 150K.ECD 11,50 ppg W/9.35 ppg MW.Max Gas 1,529 units. ADT 2.14,Bit Hrs 60.29,JAR Hrs 60.29.Monitor well,static. SPR @ 15,870'MD(3,997'TVD)9.35 ppg MW MP#1 20-360,30-440 MP#2 20-360,30-440 MP#3 20-360,30-440 03:00 04:30 1.50 4.50 DRILL E 7 P PJSA CBU 18 as per K8M BROOH schedule.450 GPM,2,270 PSI,130 RPM,TRO 12K, 0430 1200 7.50 12.00 DRILL E 6 P PJSA BROOH as per KW BROOH schedule or as hole dictates F/15,870'to 13,588'MD,500 GPM,2,450 PSI,150 RPM, TRF 11K,HST 215K,SLK 83K.ROT 150K.Drop 2.9"daft on 117'wire.SLM out.Actual displacement 19 bbl.Calculated displacement 42 bbl.Lost 23 bbl to formation. 12:00 18:00 6.00 18.00 DRILL E 6 P PJSA BROOH as per K8M BROOH schedule or as hole dictates F/13,588'10 10,320'MD,500 GPM,2,340 PSI,150 RPM, TRF 8-10K,HST 190K,SLK 115K,ROT 148K.Max Gas 4 units,ECD 10.66 ppg W/9.35 ppg MW. 18-.00 23-.00 5.00 23.00 DRILL E 6 P PJSA BROOH as per K&M BROOH schedule or as hole dictates F/10,320'to 7,983'MD,500 GPM,2,060 PSI,150 RPM, TRF 10-12K,HST 170K,SLK 130K,ROT 148K.Max Gas 16 units.ECD 10.14 ppg W/9.35 ppg MW.At 8,160'MD observe packing off while pulling BHA thru Shoe @ 8,030'MD.Work string thru Shoe to 7.983'MD clearing obstruction. 23.00 00.00 1.00 24.00 DRILL E 7 P Circulate and condition hole @ 500 GPM.2,050 PSI,reciprocate FI 7,983'to 7,888'MD 120 RPM,TRQ 8K.Total lost 27 bbl for tour. Daily Contacts Position Contact Name Company Title i E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Em representative Jack Kvasnikoff ENI HOE 907-685-0721 907-398-8770 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher ng15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L-80 0.14 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgticm') 2.447.54 1,239.91 FAZE Pro 1102.4 56.6 1559.4 193.3 111* Eni E&P Division Ewen Name:$R08-N7 OR ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • 2^n Date:10/26/2013 - Report#: 27 APIIUWI:50-629-23501-00-00 �f II ii page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DES(days) SP08-N7 DRILLING 10/3!2013 4.767.38 1,209.68 4,788.41 134.16 35.7 23.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,837.18 1,218.60 0.00 113.0 -5.6 Overcast WC 10" SE @ 13 MPH Daily summary operation 24h Summary Cont.Circ.BU @ 500 GPM,2,020 PSI,120 RPM,TRQ 10K,HST 180K,SLK 130K,ROT 145K.5 bph dynamic loss.Monitor well,static.C/O Elevators to 4.5",L/D X/O,blow down TS-8.POOH as per K&M BROOH schedule on elevators F/7,986'to 7,034'MD.Pump 25 bbl 11.6 ppg Dry Job.Blow down TS-8.Retrieve drift in stand 80 of 4.5"D.P.POOH on elevators as per K&M schedule F/7,034'to 6,244'MD.Service Dravwnorks.C/O hose on Iron Roughneck.POOH on elevators as per K&M schedule F/6,244'to 394'MD,HST 98K.SLK 98K,Calculated displacement 69 bbl,Actual displacement 91 bbl,lost 22 bbl to formation.PJSM WI all essential personnel.L/D BHA#6 as per Schlumberger DD 8 MWD.Stand back JARS&NMFC.UD Saversub,NM STAB,unload radioactive sources.ADN, Telescope,STAB,Periscope,Exceed and Bit Bit Grade 0-1-CT-Sh-X-In-No-TD Clean and clear rig floor of all non essential tools.Bring tubing handling tools to floor via Beaver Slide.R/U Volant tubing handling Equip.Run 5.5"Liner as per tally F/0'to 5,160'MD.HST 132K.SLK 123K,Total lost 31 bbl to formation. Operation at 07.00 RIH W/5 1/2"Liner @ 7.500'MD 24h Forecast RIH W/Volant 5.5"Liner F/5,160'MD to 7,999'MD.P/U M/U SLZXP Packer as per Baker Rep onsite.Get running parameters for K&M.Cont.RIH W/5"D.P.F/8,041'to 15.860'MD.Chad and set hanger as per Baker Rep onsite.Test hanger to 1.500 PSI for 10 Min.Release from hanger and POOH W/5"D.P.UD running Assy.Test BOPE. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1120.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00'00 01:30 1.50 1.50 DRILL E 7 P PJSA Cont.Circ.BU @ 500 GPM.2.020 PSI,120 RPM,TRQ 10K,HST 180K,SLK 130K,ROT 145K.5 bph dynamic loss. 01:30 02:00 0.50 2.00 DRILL E 20 P Monitor well.static.C/O Elevators to 4.5",UD X/O,blow down TS-8, 02:00 04.00 2.00 4.00 DRILL E 4 P PJSA POOH as per K&M BROOH schedule on elevators F/7,986'to 7.034'MD.Pump 25 bbl 11.6 ppg Dry Job.Blow down TS-8.Retrieve drift in stand 80 of 4.5"D.P. 04:00 04.30 0.50 4.50 DRILL E 4 P PJSA POOH on elevators as per K&M schedule Fl 7,034'to 6,244'MD. 04:30 05:00 0.50 5.00 DRILL E 20 P PJSA Service Draww.orks,CIO hose on Iron Roughneck. 05:00 0900 4.00 9.00 DRILL E 4 P PJSA POOH on elevators as per K&M schedule F/6,244'to 394'MD,HST 98K,SLK 98K,Calculated displacement 69 bbl. Actual displacement 91 bbl,lost 22 bbl to formation. 09:00 11 00 2.00 11.00 DRILL E 4 P PJSM WI all essential personnel.L/D BHA#6 as per Schlumberger DD&MWD.Stand back JARS&NMFC.UD Saversub, NM STAB,unload radioactive sources,ADN,Telescope,STAB,Periscope.Exceed and Bit.Bit Grade 0-1-CT-Sh-X-In-No- TD 11:00 12:00 1.00 12.00 DRILL E 20 P PJSA Clean and clear rig floor of all non essential tools.Bring tubing handling tools to floor via Beaver Slide. 12:00 13:00 1.00 13.00 DRILL G 20 P PJSM W/all essential personnel.R/U Volant tubing handling Equip. 13:00 18:00 5.00 18.00 DRILL G 4 P PJSA Run 5.5"Liner as per tally to 2,148'MD.HST 117K,SLK 110K. 18:00 00:00 6.00 24.00 DRILL G 4 P PJSA Run 5.5"Liner as per tally F/2,148'to 5,160'MD.HST 132K,SLK 123K,calculated displacement 35 bbl,actual displacement 26 bbl.Lost 9 bbl to formation. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Troy England ENI HSE Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.825 L-80 2,386.47 4.834.13 10/27/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgt/cm') 2.447.54 1,239.91 FAZE Pro 1102.4 56.6 1559.4 193.3 f* Eni E&P Division Well Name: SP08-N7 OR EN!Petroleum Co.Inc. Daily Report Well Code:27537 Field Name: Nikaitchuq Date:10/27/2013 - Report#: 28 APIIUWI:50-629-23501-00-00 2" " page 1 of 1 Wellbore name: SPO8-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SPO8-N7 DRILLING 10/3/2013 4,767.38 1,209.68 4,788.41 134.16 35.7 24.44 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,837.18 1.218.60 0.00 109.0 -6.7 Clear WC 11° NW @ 7 MPH Daily summary operation 24h Summary RIH as per tally 5.5"Liner on Volant running tool F/5,160'to 7,999'MD,HST 150K,SLK 120K,Calculated displacement 54 bbl,actual displacement 39 bbl.Lost 15 bb)to formation. R/D Volant tool,Bail Ext.,5.5"Elevators,R/U 5"Elevators.P/U M/U SLZXP Packer as per Baker Rep onsite,mix Pal Mix and let set F/30 Min.RIH 1 stand 5"D.P.,obtain parameters @ 8,130'MD,126 GPM,60 PSI,30 RPM,TRQ 5-OK,ROT 136K,HST 152K,SLK 125K RIH 5.5"Liner 8 SLZXP Packer on 5"D.P.F/8,137'to 15,852'MD,HST 110K,SLK 220K.PJSM W/all essential personnel.RIH 5.5"Liner on 5"D.P. F/15,852'to tag bottom @ 15,873'MD set 10K to confirm,SLK 110K Pull up and orient Liner top @ 7,830'MD,5.5"Liner Shoe @ 15,860'MD.HST 220K.Drop setting ball and pump down @ 3 bpm, 190 PSI.Ball seat @ 89 bbl.Set SLZXP Packer as per Baker rep onsite.Press.up to 1,500 PSI,hold 5 Min,increase to 3,000 PSI observe shear @ 2,300 PSI.hold for 5 Min.,increase to 3,500 PSI, observe shear @ 3,250 PSI,hold for 5 Min.SLK off 30K,Press.up to 4,000 PSI hold for 1 Min.SLK off 60K on weight indicator,40K down.Bleed off Press.P/U to 120K on weight indicator.Test Liner top Packer to 1,500 PSI for 10 Min.(Good)Put up 40'to clear Liner top Packer to 7,782'MD,HST 180K Blow down test Equip.Monitor well for 10 Min.static.POOH 5"D.P.W/Liner running Assy.F/7,782' and UD Liner Hanger running tool as per Baker Rep onsite.HST 180K.Calculated displacement 62 bbl,actual displacement 76 bbl.Total lost 29 bbl to formation for the day. Operation at 07.00 Test BOPE waived by AOGCC Robert Noble. 24h Forecast Test BOPE waived by AOGCC Robert Noble.P/U M/U Whip Stock and RIH to set @ TOW 7,791'MD BOW 7,808'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL G -4 P •PJSA RIH as per tally 5.5"Liner on Volant running tool F/5,160'to 7,999'MD,HST 150K,SLK 120K,Calculated displacement 54 bbl,actual displacement 39 bbl.Lost 15 bbl to formation. 05:00 05:30 0.50 5.50 DRILL G X20 P PJSA R/D Volant tool,Bail Ext,5.5"Elevators,R/U 5"Elevators. 05:30 06:30 1.00 6.50 DRILL G X20 P PJSA P/U M/U SLZXP Packer as per Baker Rep onsite,mix Pal Mix and let set F/30 Min. 06:30 07:00 0.50 7.00 DRILL G 4 P PJSA RIH 1 stand 5"D.P..obtain parameters @ 8,130'MD,126 GPM,60 PSI,30 RPM,TRQ 5-6K,ROT 136K.HST 152K,SLK 125K. 07:00 12:00 5.00 12.00 DRILL G 4 P PJSA RIH 5.5"Liner&SLZXP Packer on 5"D.P.F/8,137'to 15,852'MD,HST 110K,SLK 220K • 12:00 13:30 1.50 13.50 DRILL G 20 P PJSM W/all essential personnel.RIH 5.5"Liner on 5"D.P.F/15,852'to tag bottom @ 15,873'MD set 10K to confirm,SLK 110K.Pull up and orient Liner top @ 7,830'MD,5.5"Liner Shoe @ 15,860'MD.HST 220K.Drop setting ball and pump down @ 3 bpm,190 PSI.Ball seat @ 89 bbl.Set SLZXP Packer as per Baker rep onsite.Press.up to 1,500 PSI,hold 5 Min,increase to 3,000 PSI observe shear @ 2,300 PSI.hold for 5 Min.,increase to 3,500 PSI,observe shear @ 3,250 PSI, hold for 5 Min.SLK off 30K,Press.up to 4,000 PSI hold for 1 Min.SLK off 80K on weight indicator,40K down.Bleed off Press.P/U to 120K on weight indicator.Test Liner top Packer to 1,500 PSI for 10 Min.(Good)Pull up 40'to clear Liner top Packer to 7,782'MD,HST 180K. 13:30 14:00 0.50 14.00 DRILL G 20 P Blow down test Equip.Monitor well for 10 Min.static. 14:00 18:00 4.00 18.00 DRILL G "4 P "PJSA POOH 5"D.P.W/Liner running Assy.Fl 7,782'and UD Liner Hanger running tool as per Baker Rep onsite.HST 180K.Calculated displacement 62 bbl.actual displacement 76 bbl.Lost 14 bbl to formation. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Tom Klein ENI Matls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Troy England ENI HSE Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.corn 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher vg15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.825 L-80 2.386.47 4.834.13 10/27/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgt/cm') 2,447.54 1,239.91 FAZE Pro 1102.4 56.6 1559.4 193.3 • ffi* Eni E&P Division 'Well Name:SP08-N7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27891 Field Name:Nikaitchuq • Date:10/27/2013 - Report#: 1 API/UW:50-629-23501-60-00 eni[I page 1 of 1 Wellbore name: SP08-N7L1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 5P08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 0.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POE Temperature(°C) Weather Wind 0.00 109.0 -6.7 Clear WC 11' NW @ 7 MPH Daily summary operation 24h Summary Clear and clean rig floor.Pull Wear Bushing and set test plug as per Vetco Grey Rep onsite.PJSM R/U test Equip.to test BOPE.Test BOPE W/5.5"test joint.Annular Preventer tested 250 PSI low and 2.500 PSI high.Test Pipe Rams and Choke Manifold valves 250 PSI low and 3,500 PSI high for 5 Min.charted.Test waived by Robert Noble of AOGCC 10-25-13 @ 15:11. Operation at 07.00 P/U M/U Whipstock Milling BHA. 24h Forecast Cont.test BOPE W/5"&4.5"test joints.R/D test Equip.Set Wear Bushing.P/U M/U Whipstock Milling BHA.RIH and set Whipstock,proceed to mill window. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 18.00 19:00 1.00 1.00 DRILL E 20 P PJSA Clear and clean rig floor. 19:00 '19:30 0.50 1.50 DRILL E 20 P PJSA Pull Wear Bushing and set test plug as per Vetco Grey Rep onsite 19.30 20:00 0.55 2.00 DRILL C 12 P PJSM R/U test Equip.to test BOPE. 20'00 00:00 4.00 6.00 DRILL C 12 P PJSA Test BOPE W/5.5"test joint.Annular Preventer tested 250 PSI low and 2,505 PSI high.Test Pipe Rams and Choke Manifold valves 250 PSI low and 3,500 PSI high for 5 Min.charted.Test waived by Robert Noble of AOGCC 10-25-13 @ 15:11. Daily Contacts Position Contact Name Company Title E-mail • Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com '907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Troy England ENI HSE Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm°) • 1111* Eni E&P DivisionWell Name:SP08-N7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27891 Field Name: Nikaitchuq � API/UWI:50-629-23501-60-00 2 nI n Date:10/28/2013 - Report#: 2 I' II� page 1 of 1 Wellbore name: SPO8-N7L1 Well Header Permit/Concession IT Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) - RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 1.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(`C) Weather Wind 0.00 103.0 -2.8 Light Snow WC 17' NNW @ 12 MPH Daily summary operation 24h Summary Test BOPE 250 PSI low and 2,500 PSI high for 5 Min.Annular Preventer.Test 4.5"&5.5"test Jnt.250 PSI low and 3,500 PSI high for 5 Min.BOPE test.Function test Koomey.R/D test Equip.Clear and clean rig floor.Blow down lines and choke.Pull test plug and set Wear Bushing as per Vetco Grey Rep onsite.9"ID.Bring Baker Subs to rig floor via Beaver Slide.Well Commander,X/O,Mills,Bumper Sub and Anchor Assy.PJSM W/all essential personnel.P/U M/U Whip Stock BHA as per Baker Rep onsite.Orient MWD to Whip Stock as per Schlumberger MWD&DD.Remove 2 Anchor setting shear screws and shipping bolt.(3 Shear screws left in Anchor 19,900 lb shear)P/U Bumper Jars and Well Commander,RIH 2 stands 5"HWDP.HST 98K,SLK 98K.RIH W/5"D.P.F/335'to 1,268'MD HST 110K,SLK 110K.Shallow test MWD tools @ 450 GPM,560 PSI.RIH W/5"D.P.F/1,268'to 7,709'MD.HST 175K,SLK 140K.Break Circ.,stage up pumps to 450 GPM,1,110 PSI.Wash down orienting Whip Stock to 35 degree left of high side.SLK 140K.Tag Liner top @ 7,829'MD SLK 50K and set bottom Trip Anchor as per Baker Rep onsite.P/U to 120K on weight indicator,SLK off 50K shear Mills AL free from slide.P/U to 7,670'MD Mill depth,HST 165K.Mill window @ 450 GPM,1,070 PSI,110 RPM,TRO 8-11K,WOB 2-6K,TOW 7,791'to 7,818'MD.HST 175K,ROT 155K �J Operation at 07.00 Pumping Super Sweep spacer. 24h Forecast Cont.Milling operations to 7,840'MD.Work Mills thru window checking for drag.Open Well Commander and pump Super Sweep spacer.POOH L/D Milling Assy. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 4.4 / Time Log StartEnd Cum )h Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL C 12 P PJSA Test BOPE to 250 PSI low and 3,500 PSI high for 5 Min.W/5.5"test joint.Lower Pipe Rams W/4.5"test jnt..250 PSI low and 2,500 PSI high for 5 Min.13 3/8"Annular Preventer,250 PSI low and 3,500 PSI high for 5 Min.Top Pipe Rams(3.5"X 6"VRB),Lower Pipe Rams(4.5"X 7"VRB),Manual Choke Valve,NC 46 Dart Valve,NC 46 Floor Valve, • Blind Rams,Test Choke A,B&Super Choke to 1,500 PSI.Koomey test:Sytem Press.2,900 PSI,Manual 1,500 PSI, Annular 750 PSI.All valves function 1,500 PSI.200 PSI 34 Sec.full Press.168 Sec.Nitrogen 5 bottles average 2,500 PSI. 1 1 4 • 03:00 04:00 1.00 4.00 DRILL C 20 P PJSA R/D test Equip.Clear and clean rig floor.Blow down lines and choke.Pull test plug and set Wear Bushing as per Vetco Grey Rep onsite.9"ID 04:00 05:00 1.00 5.00 DRILL E 20 P PJSA Bring Baker Subs to rig floor via Beaver Slide.Well Commander,X/O,Mills,Bumper Sub and Anchor Assy. 05:00 08:30 3.50 8.50 DRILL E 20 P PJSM W/all essential personnel.P/U M/U Whip Stock BHA as per Baker Rep onsite.Orient MWD to Whip Stock as per Schlumberger MWD&DD.Remove 2 Anchor setting shear screws and shipping bolt.(3 Shear screws left in Anchor 19,900 Ib shear)P/U Bumper Jars and Well Commander,RIH 2 stands 5"HWDP.HST 98K.SLK 98K 08:30 09:30 1.00 9.50 DRILL E 20 P PJSA RIH W/5"D.P.F/335'to 1,268'MD HST 110K,SLK 110K • 09:30 10:00 0.50 10.00-DRILL E 19 P Shallow test MWD tools @ 450 GPM,560 PSI. 10:00 12:00 2.00 12.00 DRILL E 4 'P PJSA RIH W/5"D.P.F/1,268'to 3,600'MD HST 150 PSI,SLK 140K.Fill D.P.every 25 stands. 12:00 14:00 2.00 14.00 DRILL E 4 P PJSA Cont.RIH W/5"D.P.F/3.600'to 7,709'MD.HST 175K,SLK 140K. 14:00 15:00 1.00 15.00 DRILL E 14 P Break Circ.,stage up pumps to 450 GPM,1,110 PSI.Wash down orienting Whip Stock to 35 degree left of high side.SLK 140K.Tag Liner top @ 7,829'MD SLK 50K and set bottom Trip Anchor as per Baker Rep onsite.P/U to 120K on weight indicator,SLK off 50K shear Mills free from slide.P/U to 7,670'MD Mill depth.HST 165K. SPR @ 7,791'(4,035'TVD)W/9.3 ppg MW MP#1 20-100,30-110 MP#2 20-100,30-110 15:00 00:00 9,00 24.00 DRILL E 14 P PJSA Mill window @ 450 GPM,1,070 PSI,110 RPM,TRO 8-11K,WOB 2-6K,TOW 7,791'to 7,818'MD.HST 175K,ROT 155K Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Troy England ENI HSE Tool Push Steve Dambacher Doyon Drilling Tool Pusher rigt5@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2,447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') Eni E&P Division Well Name:SP08-N7 LI if* EN!Petroleum Co.Inc. Daily Report Well Code:27891 Field Name:Nikaitchuq • Date:10/29/2013 - Report#: 3 APIIUWI:50-629-23501-60-00 2 rr rr iipage 1 of 1 Wellbore name: SP08-N7L1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 2.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 104.0 -6.1 Light Snow WC 13` W @ 7 MPH Daily summary operation 24h Summary Mill Window as per Baker Rep onsite to 7,818'MD.Mill rat hole to 7,838'MD @ 450 GPM,1,060 PSI,110 RPM,TRQ 10K,WOB 5-6K.Work Mills thru window 2X WI pumps and rotation,no drag observed.Work Mills thru window 4X no pumps and rotation,no drag observed.HST 185K.SLK 140K.Drop 2.125"OD ball @ 100 GPM,150 PSI,ball seat @ 53 bbl away.Well Commander sub shear open @ 1,300 PSI,confirm open 450 GPM 680 PSI.Drop 2.063"OD Seal Off Ball,wait 5 Min.,pump 40 bbl Super Sweep Spacer and chase W/100 bbl OBM @ 275 GPM,295 PSI.Drop closing ball and pump down @ 125 GPM 120 PSI,ball seat @ 61.5 bbl away,closed Well Commander @ 1,700 PSI.Circ.spacer out @ 450 GPM,1,060 PSI.20%increase in metal @ Shakers.Repeat process a second time W/20%increase seen at Shakers.Circ.additional BU @ 500 GPM,1,300 PSI,80 RPM.Stand back 1 stand of 5"D.P.Cut and slip drilling line.service TS-8,Blocks and Drawworks.POOH F/7,746'to 7.297'MD,pump 20 bbl 11.1 ppg dry job.POOH on Elevators F/7,297'to Mill BHA.L/D Mill Assy.As per Baker Rep onsite.Function and flush BOPE.PJSM W/all essential personnel.P/U M/U 8 3/4"Motor BHA#8 as per Schlumberger DDS MWD Rep onsite.RIH BHA#8 on 5"D.P.F/345'to 438'MD.Shallow hole test MWD @ 350 GPM.720 PSI.Cont.RIH F/438'to 7.227'MD.Filling D.P.every 20 stands.HST 175K,SLK 135K. Operation at 07.00 Drill 8 3/4"L1 W/Motor BHA. 24h Forecast Cont.to RIH F/7.227 to 7,838'MD.CBU 1X and perform 13.0 ppg FIT or LOT.Drill ahead 8 3/4"hole to 8,038'MD and POOH.UD BHA#8 and P/U M/U BHA#9 W/Exceed motor.RIH and drill ahead. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03.00 3.00 3.00 DRILL E 14 P Mill Window as per Baker Rep onsite to 7,818'MD.Mill rat hole to 7,838'MD @ 450 GPM.1,060 PSI.110 RPM,TRQ 10K, WOB 5-6K.Work Mills thru window 2X W/pumps and rotation,no drag observed.Work Mills thru window 4X no pumps and rotation,no drag observed.HST 185K,SLK 140K 03.00 08.30 5.50 8.50 DRILL E 9 P PJSA Drop 2.125"OD ball @ 100 GPM,150 PSI.ball seat @ 53 bbl away.Well Commander sub shear open @ 1,300 PSI. confirm open 450 GPM 680 PSI.Drop 2.063"OD Seal Off Ball,wait 5 Min.,pump 40 bbl Super Sweep Spacer and chase W/100 bbl OBM @ 275 GPM,295 PSI.Drop closing ball and pump down @ 125 GPM 120 PSI.ball seat @ 61.5 bbl away. closed Well Commander @ 1,700 PSI.Circ.spacer out @ 450 GPM.1,060 PSI.20%increase in metal @ Shakers.Repeat process a second time W/20 A increase seen at Shakers.Circ.additional BU @ 500 GPM,1,300 PSI,80 RPM,Stand back 1 stand of 5"D.P. 08:30 10:00 1,50 10.00 DRILL E 20 P PJSM Cut and slip drilling line,service TS-8,Blocks and Drawworks. 10:00 10:30 0.50 10.50 DRILL E 4 P PJSA POOH F/7,746'to 7,297'MD,pump 20 bbl 11.1 ppg dry job. 10:30 12:00 1.50 12.00 DRILL E 4 P PJSA POOH on Elevators F/7,297'to 5.805'MD HST 165K,SLK 136K 12:00 15:00 3.00 15.00 DRILL E 4 P PJSA POOH on Elevators F/5,805'to Milling BHA. 15:00 16:00 1.00 16.00 DRILL E 20 P L/D Milling tools as per Baker Rep onsite.Clean and clear rig floor. 16:00 17:00 1.00 17.00 DRILL E 20 P Function and flush BOPE. 17:00 19:00 2.00 19.00 DRILL E 20 P PJSM W/all essential personnel.P/U M/U 8 3/4"Motor BHA#8 as per Schlumberger DD&MWD Rep onsite. 19:00 00:00 5.00 24.00 DRILL E 4 P PJSA RIH BHA#8 on 5"D.P.F/345'to 438'MD.Shallow hole test MWD @ 350 GPM,720 PSI.Cont.RIH F/438'to 7,227' MD.Filling D.P.every 20 stands.HST 175K,SLK 135K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI DnIling Supv. 907-685-0715 Eni representative Tom Klein ENI Malls Coordinator 907-685-0718 Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Troy England ENI HSE Tool Push Steve Dambacher Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') • Eni E&P Division I Well Name: SP08-N7 L1 1111* ENI Petroleum Co.Inc. Daily Report Well Code:27891 Field Name:Nikaitchuq •II Date:1013012013 - Report#: 4 APIIUWI:50-629-23501-60-00 2" " page 1 of 1 Wellbore name: SPO8-N7L1 - Well Header Permit/Concession N° Operator ENI Share(%) •Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL 1 Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information ' Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 3.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,449.98 1.237.37 60.96 3.25 18.8 105.0 -8.9 Overcast,WC 4° NE @,12 MPH Daily summary operation 24h Summary RIH BHA#8 on 5"D.P.F/7,227'to 7,719'MD,orient motor wash to 7,838'MD,350 GPM,1,100 PSI.Stand back 1 stand.CBU lX @ 450 GPM,1,610 PSI.30 RPM,TRQ 8K @ 7.791'MD.R/U test Equip.Perform LOT @ 7,809'MD(4,038'TVD)to 486 PSI EMW 11.61 ppg.R/D test Equip.Blow down lines.Slide and rotate drill F/7,838'to 8,038'MD(4,070'TVD).Max Gas 32 units.Monitor well, static.Circ.BU @ 550 GPM,2,220 PSI,40 RPM,TRO 8K.POOH F/8,038'to 7,719'MD Observed 5-10K drag pulling BHA thru window.CBU 2X @ 550 GPM,2,180 PSI,40 RPM,TRQ 8K,ROT 149K. POOH F/7.719'to 7,252'MD HST 180K,SLK 140K,Pump 27 bbl Dry Job.Blow down lines.POOH F/7.252'to 345'MD.Monitor well for 10 Min.,static.L/D Motor BHA#8.Calculated displacement 74 bbl,actual displacement 85 bbl.Lost 11 bbl to formation on trip out.Clear and clean rig floor.P/U tools to floor for BHA#9.Service TS-8 and Blocks.PJSM W/all essential Personnel.P/U M/U 8.75"Bit, Xceed Motor,Periscope,TeleScope,and ADN Vision 675.to 100'MD.PJSM Load nuclear sources as per Schlumberger MWD.Contact security for an all call on loading sources.P/U M/U BHA#9 to 107'MD.Decision was made to L/D BHA#9 F/107'MD.STAB,unload nuclear sources,cont,to L/D BHA to 51'MD for reprogramming MWD tools in Pipe Shed.P/U M/U BHA F/51'to 107'and load sources by Schlumberger Rep onsite.Give all clear by security.Cont.P/U M/U BHA#9 F/107'to 396'MD.HST 100K,SLK 100K RIH W/4,5"D.P.Fl 396'to 678'MD. Operation at 07.00 RIH BHA#9 @ 7.681'MD. 24h Forecast Shallow test MWD tools at surface.Cont.RIH BHA#9 on 4.5"D.P.F/678'to 8,038'MD.Drill ahead 8.75"production hole to-15,880'MD. Lithology Shows MAASP(kgflcm2) Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 DRILL E 4 P PJSA RIH BHA#8 on 5"D.P.F/7.227'to 7,719'MD,orient motor wash to 7,838'MD,350 GPM,1,100 PSI.Stand back 1 stand. 01'00 02:00 1.00 2.00 DRILL E 7 P PJSA CBU 1X @ 450 GPM,1,610 PSI,30 RPM,TRQ 8K @ 7,791'MD. 02.00 04:00 2.00 4.00 DRILL E 11 P PJSA R/U test Equip.Perform LOT @ 7,809'MD(4.038'TVD)to 486 PSI EMW 11.61 ppg.R/D test Equip.Blow down lines. 04.00 08:30 4.50 8.50 DRILL E 3 P PJSA Slide and rotate drill F/7,838'to 8,038'MD(4,070'TVD)550 GPM,2,300 PSI.40 RPM,TON 9K.TQF 8K,WOB 10K,HST 188K,SLK 132K.ROT 155K.Max Gas 32 units.ADT 3.25,TST 1.72,TRT 1.53.Bit Hrs 3,25,Jar Hrs 63.6. Monitor well,static. SPR @ 8,038'MD(4,070'TVD)W/9.25 ppg MW MP#1 20-220,30-280 • MP#3 20-220,30-280 • 08:30 09:30 1.00 9.50 DRILL E 7 P Circ.BU @ 550 GPM,2,220 PSI,40 RPM,TRQ 8K. 09:30 10:00 0.50 10.00 DRILL E 4 P PJSA POOH F/8,038'to 7,719'MD Observed 5-10K drag pulling BHA thru window. 10:00 11:00 1.00 11.00 DRILL E 7 P PJSA CBU 2X @ 550 GPM,2,180 PSI,40 RPM,TRQ 8K,ROT 149K, 11:00 12:00 1,00 12.00 DRILL E 4 P PJSA POOH F/7,719'to 7,252'MD HST 180K,SLK 140K,Pump 27 bbl Dry Job.Blow down lines. 12:00 16:00 4.00 16.00 DRILL E 4 P PJSA POOH F/7,252'to 345'MD.Monitor well for 10 Min.,static.UD Motor BHA#8.Calculated displacement 74 bbl, actual displacement 85 bbl.Lost 11 bbl to formation on trip out. 16:00 17:00 1.00 17.00 DRILL E 20 P Clear and clean rig floor.P/U tools to floor for BHA#9. 17:00 17.30 0.50 17.50 DRILL E 20 P Service TS-8 and Blocks. 17:30 1930 1.50 19.00 DRILL E 20 P PJSM W/all essential Personnel.P/U M/U 8.75"Bit.Xceed Motor,Periscope,TeleScope,and ADN Vision 675.10 100'MD as per Schlumberger DD and MWD onsite. 19:00 20.00 1.00 20,00 DRILL E 20 P PJSM Load nuclear sources as per Schlumberger MWD.Contact security for an all call on loading sources. - 20:00 20:30 0.50 20.50 DRILL E 20 P PJSA Cont.P/U M/U BHA#9 to 107'MD. 20:30 21:30 1.00 21.50 DRILL E 20 P Decision was made to LID BHA#9 F/107'MD,STAB,unload nuclear sources,cont.to L/D BHA to 51'MD for reprogramming MWD tools in Pipe Shed. 21:30 22:30 1.00 22.50 DRILL E 20 P PJSA P/U M/U BHA F/51'to 107'and load sources by Schlumberger Rep onsite,Give all clear by security. 22:30 2330 1.00 23.50 DRILL E 20 P PJSA Cont.P/U M/U BHA#9 F/107'to 396'MD.HST 100K,SLK 100K 23:30 0000 0.50 24.00 DRILL E 4 P PJSA RIH W/4.5"D.P.F/396'to 678'MD. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com .907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon 15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Wade Thomas ENI Rig Clerk 907-685-0722 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Troy England ENI HSE Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dnlling Tour Pusher rig15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm2) Eq.Mud Weight(gIL) P LeakOff(kgflcm2) 2.380.18 1.230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 raj* Eni E&P Division I Well Name:SP08-N7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27891 Field Name: Nikaitchuq Date:10/31/2013 - Report#: 5 API/UWI:50-629-23501-60-00 2" " page 1 of 1 Wellbore name: SP08-N7L1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 4.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2.855.37 1,242.87 405.38 11.12 36.5 105.0 -10.0 Light Snow,WC 5' 5 @ 7 MPH Daily summary operation 24h Summary RIH W/BHA#9 on 4.5"D.P.F/678'to 1.340'MD.Shallow test MWD as per Schlumberger MWD Rep @ 350 GPM,540 PSI.Cont.RIH W/BHA#9 on 4.5"D.P.F/1,340'to 7,795'MD Filling D.P.every 25 stands.Wash F/7,795'to 8,038'MD @ 350 GPM,1,150 PSI.Taking survey's as per Schlumberger MWD&DD,5-10K drag W/BHA#9 thru window,oscillating string as needed to break over.Drill 8.75"Production hole F/8,038'to 9.368'MD(4,078'TVD)550 GPM,2,400 PSI,130-160 RPM,TQN 12.5K,TQF 10K,WOE 6-10K,HST 188K,SLK 110K,ROT 152K.ECD 10.33 ppg W/9.3 ppg MW. Max Gas 2,455 units.ADT 11.12,Bit Hrs 11.15,Jar Hrs 74.75.Monitor well,static. Operation at 07.00 Drill 8 3/4"L1 Production hole to 9,605'MD. 24h Forecast Drill 8 3/4"L1 Production hole F/9,368'to-15,880'MD as per well plan. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 4 P PJSA RIH WI BHA#9 on 4.5"D.P.F/678'to 1,340'MD.Shallow test MWD as per Schlumberger MWD Rep @ 350 GPM. 540 PSI. 00:30 04:00 3.50 4.00 DRILL E 4 P PJSA RIH W/BHA#9 on 4.5"D.P.F/1,340'to 7,795'MD Filling D.P.every 25 stands.HST 175K,SLK 130K 04:00 06:00 2.00 6.00 DRILL E 4 P PJSA Wash F/7,795'to 8,038'MD @ 350 GPM,1,150 PSI.Taking survey's as per Schlumberger MWD&DD.5-10K drag W/BHA#9 thru window,oscillating string as needed to break over. 06:00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"Production hole F/8,038'to 8,277'MD(4,079'TVD)550 GPM,2,400 PSI,120 RPM,TON 6-13K,TQF 8K. WOB 6-10K,HST 190K,SLK 115K,ROT 150K.ECD 10.27 ppg W/9.3 ppg MW.Max Gas 41 units.ADT 3.3,Bit Hrs 3.3, Jar Hrs 66.9.Monitor well,static. SPR @ 7,795'MD(4.038'TVD)W/9.3 ppg MW MP#1 20-160,30-220 MP#3 20-160,30-220 12:00 18:00 6.00 18.00 DRILL E 3 P Drill 8.75"Production hole F/8,277'to 8,730'MD(4,095'TVD)550 GPM,2,460 PSI,110-160 RPM,TON 12K,TOF 10K, WOB 2-12K,HST 190K,SLK 112K,ROT 150K.ECD 10.38 ppg WI 9.3 ppg MW.Max Gas 2,520 units.ADT 4.09,Bit Hrs 7.42,Jar Hrs 70.99.Monitor well,static. 18:00 00:00 6.00 24,00 DRILL E 3 P Drill 8.75"Production hole F/8,730'to 9,368'MD(4,078'TVD)550 GPM,2,400 PSI,130-160 RPM,TON 12.5K,TOF 10K, WOB 6-10K,HST 188K,SLK 110K,ROT 152K.ECD 10.33 ppg W/9.3 ppg MW.Max Gas 2,455 units.ADT 3.73,Bit Hrs 11.15,Jar Hrs 74.75.Monitor well,static. SPR @ 9,196'MD(4.080'TVD)W/9.3 ppg MW MP#1 20-160,30-220 MP#3 20-160,30-220 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend EM Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Steve Abbott ENI Rig Clerk Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2,447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2.380.18 1,230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 • f. ,ID Eni E&P Division Q ..} Ewen Name SPO8-N7 u ENI Petroleum CO.Inc. Daily Report Well Code:27891 Field Name:Nikaitchuq • eDate:11/112013 - Report#: 6 APIIUWI:50-629-23501-60-00 2" " page 1 of 1 Wellbore name: SP08-N7L1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL — Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) • 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 5.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m)Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,945.59 1242.39 90.22 2.17 41.6 106.0 -16.1 Clear,WC-7' SSE @ 8 MPH Daily summary operation 24h Summary Drill 8.75"Production hole F/9,368'to 9,664'MD(4,075'TVD)450-550 GPM,1,730-2,410 PSI,100-160 RPM,TON 12K,TQF 11K,WOB 4-10K,HST 190K,SLK 105K,ROT 152K.ECD 10.34 ppg W/9.3 ppg MW.Max Gas 2,815 units.ADT 2.17,Bit Hrs 13.32,Jar Hrs 76.92.Mondor well,static.Decision was made to BROOH due to erratic steering of Xceed,Monitor well 10 Min.,static.BROOH as per K&M BROOH schedule F/9,664'9,292'MD @ 450 GPM,1,170 PSI,150 RPM,TRO 12K,HST 195K,SLK 110K,ROT 152K.Circ.BU for the first 2 stands each and additional BU for the next 2 stands. BROOH as per K&M BROOH schedule F/9,292'to 7,946'MD @ 450 GPM,1,110 PSI,60-150 RPM,TRQ 8-10K.At 7,946'MD pull BHA#9 thru window oscillating,HST 180K,SLK 110K,ROT 148K to 7,759'MD.POOH on elevators F/7,759'to 7,320'MD HST 180K.Observed calculated hole fill.Pump 30 bbl Dry Job,blow down TS-8.Cont to POOH F/7,320'to 396'MD.No losses to formation.PJSM L/D BHA#9 and unload nuclear sources.Send Xceed to town to get worked on via Hover Craft.The 8 3/4"Bit showed broken gauge teeth all the way around.Would not have made it to TD.Clean and clear rig floor.Load rig floor W/BHA#10 components.PJSM W/all essential personnel.P/U M/U BHA#10 8 3/4"BHA as per Schlumberger DD&MWD Rep onsite to 395'MD.Load nuclear sources as per Schlumberger MWD.Contact Security and secure well bay from personnel until nuclear sources clear BOPE.C/O handling Equip F/5"to 4.5".RIH W/4.5"D.P.Fl 395'to 1,340'MD.Fill D.P.and perform shallow hole test of MWD tools as per Schlumberger MWD rep onsite. Operation at 07.00 RIH @ 7,316'MD. 24h Forecast RIH F/1,340'MD to 9,664'MD.Drill 8 3/4"Production hole to-15,880'MD as per directional plan in well plan. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1114.4 I Time Log Start End Cum Time Time Dar(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL E 3 P 'Drill 8.75"Production hole F/9,368'to 9,664'MD(4,075'ND)450-550 GPM,1,730-2,410 PSI,100-160 RPM,TON 12K, TQF 11K,WOB 4-10K,HST 190K,SLK 105K,ROT 152K.ECD 10.34 ppg Wl 9.3 ppg MW.Max Gas 2,815 units.ADT 2.17,Bit Hrs 13.32,Jar Hrs 76.92.Monitor well,static. • SPR CO 9,664'MD(4,075'ND)W/9.3 ppg MW MP#1 20-120,30-200 MP#3 20-110,30-190 05:00 06.00 1.00 6.00 DRILL E 7 XDO1 'Decision was made to BROOH due to erratic steering of Xceed,Monitor well 10 Min.,static.BROOH as per K&M BROOH schedule F/9,664'9,292'MD @ 450 GPM,1,170 PSI,150 RPM,TRO 12K,HST 195K,SLK 110K,ROT 152K.Circ.BU for the first 2 stands each and additional BU for the next 2 stands. 06:00 12.00 - 6.00 12.00 DRILL E 6 XD01 PJSA BROOH as per K&M BROOH schedule F/9,292'to 7,946'MD @ 450 GPM,1,110 PSI,60-150 RPM,TRO 8-10K.At 7,946'MD pull BHA#9 thru window oscillating,HST 180K,SLK 110K,ROT 148K to 7,759'MD. 12.00 16.00 4.00 16.00 DRILL E 4 XDO1 'PJSM POOH on elevatorsF/7,759'to 7,320'MD HST 180K.Observed calculated hole fill.Pump 30 bbl Dry Job.blow down TS-8.Cont to POOH F/7,320'to 396'MD.No losses to formation. 16.00 18.30 2.50 18.50 DRILL E 4 XD01 PJSM LID BHA#9 and unload nuclear sources.Send Xceed to town to get worked on via Hover Craft.The 8 3/4"Bit showed broken gauge teeth all the way around.Would not have made it to TD. 18:30 1930 1.00 19.50 DRILL E 20 XDO1 Clean and clear ng floor.Load rig floor W/BHA#10 components. 19.30 23.00 3.50 23.00 DRILL 'E 20 XD01 PJSM W/all essential personnel.P/U M/U BHA#10 8 3/4"BHA as per Schlumberger DD&MWD Rep onsite to 395'MD. Load nuclear sources as per Schlumberger MWD.Contact Security and secure well bay from personnel until nuclear sources clear BOPE. 23.00 23.30 0.50 23.50 DRILL E 4 XD01 PJSA C/O handling Equip F/5"to 4.5".RIH W/4.5"D.P.F/395'to 1,340'MD. 23:30 00.00 0.50 24.00 DRILL E 12 XDO1 PJSA Fill D.P.and perform shallow hole test of MWD tools as per Schlumberger MWD rep onsite. Daily Contacts Position Contact Name Company Title E-mall Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.380.18 1,230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 Eni E&P Division 'Well Name: SP08-N7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27891 Field Name: Nikaitchuq • • API/UWI:50-629-23501-60-00 2^n Date:11/2/2013 - Report#: 7 II II I� page 1 of 1 Wellbore name: SPO8-N7L1 Well Header Permit/Concession N° Operator ENI Share(10) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DC/YON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 6.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 3,172.36 1,248.03 226.77 6.93 32.7 105.0 -13.3 Clear,WC-5' SSW @ 12 MPH Daily summary operation 24h Summary RIH WI BHA#10 on 4.5"D.P.F/1,340'to 7.695'MD.Slip and cut drilling line.Service traveling Equip,TS-8,Drawworks.Crown and inspect brakes and adjust as required.RIH W/4.5"D.P.F/7,695'to 7,987'MD.M/U X/O,C/O Elevators to 5".RIH W/5"D.P.F/7,987'to 9,664'MD.Worked thru numerous tight spots between 7,987'to 8,270'MD.Washed down last 90'to 9,664'MD.Obtain slow pump rates and set drilling parameters as per Schlumberger MWD and DD Rep onsite.No losses to formation.Drill 8.75"L1 Production hole F/9,664'to 10,408'MD(4,095'TVD)600 GPM,2.580 PSI,60-140 RPM,WOB 4-12K,TQN 10K,TOE 11-12K,HST 200K,SLK 110K.ROT 150K.ECD 10.63 ppg W/9.3 ppg MW.Max Gas 2,200 units.ADT 6.93,Bit Hrs 6.93,Jar Hrs 83.85.Monitor well,static. Operation at 07.00 BROOH as per K&M BROOH schedule due to Xceed failure @ 10,409'MD. 24h Forecast Drill 8 3/4"L1 Production hole F/10,408'to—15,880'MD as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1108.4 Time Log Start End Cum • Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00 DRILL E 4 XD01 PJSM RIH W/BHA#10 on 4.5"D.P.F/1,340'to 7,695'MD.HST 175K.SLK 128K. 04:00 06.00 2.00' 6.00 DRILL E '20 -XD01 PJSM Slip and cut drilling line.Service traveling Equip,TS-8,Drawworks,Crown and inspect brakes and adjust as required. 06:00 09.30 3.50' 9.50 DRILL E 4 -XD01 PJSA RIH W/4.5"D.P.F/7.695'to 7,987'MD.M/U X/O,CIO Elevators to 5".RIH W/5"D.P.F/7,987'to 9,664'MD. Worked thru numerous tight spots between 7,987'to 8,270'MD.Washed down last 90'to 9,664'MD.Obtain slow pump rates and set drilling parameters as per Schlumberger MWD and DD Rep onsite.No losses to formation. SPR @ 9,661'MD(4,076'TVD)W/9.3 ppg MW MP#1 20-120,30-180 MP#2 20-120,30-180 MP#3 20-120,30-180 09:30 12.00 2.50 12.00 DRILL E 3 'P Drill 8.75"L1 Production hole F/9,664'to 9,727 MD(4,076'TVD)550 GPM.2,300 PSI.120 RPM,WOB 10-12K.TON 10- 12K,TOP 10K,HST 185K,SLK 125K,ROT 151K ECD 10.51 ppg W/9.3 ppg MW.Max Gas 500 units.ADT.67.Bit Hrs.67,Jar Hrs 77.59.Monitor well,static. 12:00 18:00 6.00' 18.00 DRILL E .3 'P Drill 8.75"L1 Production hole F/9,727'to 10,086'MD(4,090'TVD)590 GPM,2,580 PSI,70-140 RPM,WOB 4-10K,TON 11K,TOF 9-10K,HST 200K,SLK 112K,ROT 152K.ECD 10.51 ppg W/9.3 ppg MW.Max Gas 2,000 units.ADT 3.94.Bit Hrs 4.61,Jar Hrs 81.53.Monitor well,static. 18:00 00:00 6.00' 24.00 DRILL E 3 'P PJSA Drill 8.75"L1 Production hole F/10,086'to 10408'MD(4,095'TVD)600 GPM,2,580 PSI,60-140 RPM.WOB 4-12K, TON 10K,TOE 11-12K,HST 200K,SLK 110K,ROT 150K.ECD 10.63 ppg W/9.3 ppg MW.Max Gas 1,700 units.ADT 2.32,Bit Hrs 6.93,Jar Hrs 83.85.Monitor well,static. SPR @ 10,410'MD(4,095'TVD)W/9.25 ppg MW MP#1 20-180,30-210 MP#2 20-180,30-210 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2.380.18 1,230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 I D En!E&P Division I Well Name: SP08-N7 L1 ENI Petroleum Co.Inc. Daily ReportWell Code:27891 Field Name:Nikaitchuq • APIIUWI:50-629-23501-60-00 2^ii Date:11/3/2013 - Report#: 8 II II page 1 of 1 Wellbore name: SP08-N7L1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) • SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 7.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 3,215.03 1,247.33 42.67 0.76 56.1 104.0 -7.8 Cloudy,WC 6' WSW @ 10 MPH Daily summary operation 24h Summary Drill 8.75"Li Production hole F/10,408'to 10,548'MD(4,093'TVD)600 GPM,2,690 PSI,70-120 RPM,WOB 12-16K,TQN 12K,TQF 11K,HST 202K,SLK 1051,ROT 154K.ECD 10.7 ppg W/9.4 ppg MW.Max Gas 517 units.ADT.76,Bit Hrs 7.96,Jar Hrs 84.86.Monitor well,static.Decision was made to POOH due to Xceed failure.Zero directional tool for BROOH.Day light saving observed,fat back @ 02:00.CBU as per K&M BROOH schedule.Rack back 1 stand per BU for 4 stands F/10,548'to 10,227'MD 500 GPM,1,950 PSI,120 RPM,TOE 10-11K,HST 195K,SLK 115K,ROT 158K.BROOH as per K&M BROOH schedule Fl 10,227'to 8,012'MD.450 GPM,1,490 PSI,120 RPM,TQF 9-10K,HST 153K,SLK 110K,ROT 147K.Work thru numerous tight spots that were observed on the trip out W/K&M Rep onsite.No losses to formation.Pump out Fl 8,012'to 7,983'MD.Observed slight packing off thru area,work BHA across Whipstock as per K&M Rep onsite W/8-12K over pull.HST 190K. Swap handling tools to 4.5"and cont.to POOH on elevators working BHA across Whipstock to 7,759'MD.At 7,759'MD monitor well for 10 Min,static.POOH on elevators to 7,633'MD observed swabbing and decision was made to CBU.Circ.and condition hole @ 550 GPM,60 RPM,TRO 6K reciprocate F/7,700'to 7,605'MD.POOH on elevators F/7,700'to 7,126'MD HST 185K,now swabbing seen in well.Pump 30 bbl Dry Job,Cont.to POOH to 6,808'MD.Observed 25-35K over puN.Circ.hole until clean as per K&M Rep onsite 600 GPM,1,720 PSI,60 RPM,TRO 7K.Reciprocate F/6,844'to 6,750'MD.POOH on elevators F16,844'to 5,514'MD HST 175K.Pump 30 bbl Dry Job.Cont.POOH F/5,514'to 395'MD.Monitor well,static.W/all essential personnel.Rack back 5" HWDP,UD Jars.UD BHA#10,unload nuclear sources informing Security of operations. Operation at 07.00 P/U M/U BHA#11. 24h Forecast I Cont.to lay down BHA#10.P/U M/U BHA#11 as per Schlumberger DD and MWD.RIH to 10,548'MD and Cont.drifing to—15,580'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) i 1108.4 I Time Log ' Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. a 0000 01:30 1.50 1.50 DRILL E 3 P PJSA Drill 8.75"Lt Production hole F/10,408'to 10,548'MD(4,093'TVD)600 GPM,2,690 PSI,70-120 RPM,WOB 12- e 16K,TON 12K,TQF 11K,HST 202K,SLK 105K,ROT 154K.ECD 10.7 ppg W/9.4 ppg MW.Max Gas 517 units.ADT.76. , Bit Hrs 7.96,Jar Hrs 84.86.Monitor well,static.Decision was made to POOH due to Xceed failure. SPR @ 10,542'MD(4,093'TVD)W/9.3 ppg MW MP#1 20-180,30-220 a MP#2 20-180,30-220 MP#3 20-180,30-220 01:30 02:00 0.50 2.00 DRILL E 5 XD01 PJSA Zero directional tool for BROOH.Day light saving observed,fall back @ 02:00 02:00 05:00 3.00 5.00 DRILL E 6 XD01 PJSM CBU as per K&M BROOH schedule.Rack back 1 stand per BU for 4 stands F/10,548'to 10,227'MD 500 GPM, 1,950 PSI,120 RPM,TQF 10-11K,HST 195K,SLK 115K,ROT 158K. 05:00 12:00 7.00 12.00 DRILL E 6 XD01 PJSA BROOH as per K&M BROOH schedule F/10,227'to 8,359'MD.450 GPM,1,490 PSI,120 RPM,TQF 9-10K,HST 153K,SLK 110K,ROT 147K.Work thru numerous light spots that were observed on the trip out W/K&M Rep onsite.No losses to formation. 12:00 13:30 1.50 13.50 DRILL E 6 XD01 PJSM BROOH as per K&M BROOH schedule F/8,359'to 8,012'MD 450 GPM,1,460 PSI,60-120 RPM,TRF 5-7K,pump r out F/8,012'to 7,983'MD.Observed slight packing off thru area,work BHA across Whipstock as per K&M Rep onsite W/8 -12K over pull.HST 190K.Swap handling tools to 4.5"and cont.to POOH on elevators working BHA across Whipstock to 7.759'MD. 13:30 14:00 0.50 14.00 DRILL E 4 XDO1 PJSA At 7,759'MD monitor well for 10 Min,static.POOH on elevators to 7,633'MD observed swabbing and decision was made to CBU.HST 185K 14:00 15:00 1.00 15.00 DRILL E i XDO1 PJSA Circ.and condition hole @ 550 GPM,60 RPM,TRQ 6K reciprocate F/7,700'to 7,605'MD. 15:00 16:00 1.00 16.00 DRILL E 4 XD01 PJSA POOH on elevators F/7,700'to 7,126'MD HST 185K,now swabbing seen in well.Pump 30 bbl Dry Job,Cont.to POOH to 6,808'MD.Observed 25-35K over pull. 16:00 18:00 2.00 18.00 DRILL E 7 XD01 PJSA Circ.hole until clean as per K&M Rep onsite 600 GPM,1,720 PSI,60 RPM,TRO 7K.Reciprocate F/6,844'to 6,750' MD 18:00 22:00 4.00 22.00 DRILL E 4 XD01 PJSA POOH on elevators F/6,844'to 5,514'MD HST 175K.Pump 30 bbl Dry Job.Cont.POOH F/5,514'to 395'MD. Monitor well,static. 22:00 00:00 2.00 24.00 DRILL E 4 'XD01 'PJSM W/all essential personnel.Rack back 5"HWDP,UD Jars.UD BHA#10,unload nuclear sources informing Security of operations.HST 80K,SLK 80K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv 'SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator • Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dnlling Tool Pusher rig15@doyondrilling com 907-685-0716 Tool Push Pete Martinusen Doyon Dolling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,380.18 1,230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 Eni E&P Division Well Name:SP08-N7 L1 • ENI Petroleum Co.Inc. Daily Report Well Code:27891 Field Name:Nikaitchuq • APIIUWI:50-629-23501-60-00 2^n Date:11/4/2013 - Report#: 9 II �I I� page 1 of 1 Wellbore name: SPO8-N7L1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name •Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2.480.77 56.78 43.7 8.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,258.31 1,245.18 43.28 0.62 69.8 117.0 -6.1 Overcasr,WC 6' WSW @ 15 MPH Daily summary operation 24h Summary PJSM W/all essential personnel.L/D BHA#10 as per Schlumberger Rep onsite F/99'to 0'.No losses.Clean and clear rig floor of BHA#10 components.P/U BHA#11 components.SIMOPS program BHA tools WI Schlumberger MWD.Service Traveling Equip.,TS-8 and Drawworks.SIMOPS Cont.program BHA#11 tools.PJSM W/all essential personnel.P/U M/U BHA#11 as per Schlumberger DD &MWD.Load nuclear sources and contact security.C/O handling Equip.F/5"to 4.5"and RIH F/395'to 1,341'MD.Fill D.P.and shallow hole test MWD.(Failed)POOH F/1,340'to 395'MD.C/O handling Equip.F/4.5"to 5".PJSM W/all essential personnel.Unload nuclear source from BHA#11 W/Schlumberger MWD&DD Rep onsite.Set a XO to ADN Vision and pumped on it and found a washed out plug on inline STAB on top of the Periscope.C/O defective ILS F/BHA#11.P/U M/U BHA#12 F/45'MD.Finish C/O ILS,M/U Telescope and ADN.Shallow test MWD @ 350 GPM.480 PSI. (Good)L/D D.P.Pups and XO used for handling BHA.Blow down lines.Load nuclear source and finish M/U BHA#12 to 394'MD.RIH W/BHA#12 on 4.5"D.P.F/394'to 1,340'MD.Shallow hole test MWD.(Good)@ 400 GPM,750 PSI.Cont.RIH F/1,340'to 7,034'MD.HST 165K,SLK 130K.RIH F/7,034'to 7,791'MD HST 175K,SLK 135K.Work BHA Across Whipstock W/8-10K drag @ 8.000' MD.Loss of SLK weight,wash down F 8,000'to 8,079'MD.SLK 125-130K W/pumps on.Cont.RIH taking surveys check shots as per Schlumberger MWD to 10,506'MD.Wash and ream F/10,506'to 10,548'MD 400 GPM,1,720 PSI,120 RPM,TRQ 10K.Drill 8.75"Ll Production hole F/10,548'to 10,690'MD(4,087'TVD)500 GPM,2,400 PSI,130 RPM.WOB 2-8K,TQN 12K,TQF 8K,HST 200K. SLK 110K,ROT 152K.ECD 10.4 ppg W/9.25 ppg MW.Max Gas 500 units.ADT 0.62,Bit Hrs 8.58,Jar Hrs 8.58.Monitor well,static. Operation at 07.00 Drill 8 3/4"L1 Production hole to 10.970'MD. 24h Forecast Drill 8 3/4"L1 Production hole F/10,690'to-15,880'MD as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1108.4 Time Log Start End Cum i Time Time Due(hr) Dur(hr)• Phase Opr. Act. Plan Oper.Descr. 00.00 01 30 1.50 1.50'DRILL E 20 XD01 PJSM W/all essential personnel.L/D BHA#10 as per Schlumberger Rep onsite F/99'to 0'.No losses. 01 30 02.30 1.00 2.50'DRILL E 20 XD01 PJSA Clean and clear rig floor of BHA#10 components.P/U BHA#11 components.SIMOPS program BHA tools W/ Schlumberger MWD. 02.30 03.00 0.50 3.00'DRILL ‘E 20 XD01 PJSA Service Traveling Equip.,TS-8 and Drawworks.SIMOPS Cont.program BHA#11 tools. 03.00 06.30 3.50 6.50'DRILL -E 20 XD01 PJSM W/all essential personnel.P/U M/U BHA#11 as per Schlumberger DD&MWD.Load nuclear sources and contact security. 06:30 07.00 0.50 7.00'DRILL E 20 XD01 PJSA CIO handling Equip.FI 5"to 4.5"and RIH F/395'to 1,341'MD. 0700 07'30 0.50 7.50 DRILL E 12 XD01 PJSA Fill D.P.and shallow hole test MWD.(Failed) 07:30 08:30 1.00 8.50'DRILL E 4 XD01 PJSA POOH F/1,340'to 395'MD.CIO handling Equip.F/4.5"to 5". 08.30 1200 3.50 12.00'DRILL E 20 XD01 PJSM W/all essential personnel.Unload nuclear source from BHA#11 W/Schlumberger MWD&DD Rep onsite.Set a XO to ADN Vision and pumped on it and found a washed out plug on inline STAB on top of the Periscope.CIO defective ILS F/ BHA#11. 12:00 13.30 1.50 13.50'DRILL E 20 XD01 PJSM P/U M/U BHA#12 F/45'MD.Finish C/O ILS,M/U Telescope and ADN.Shallow test MWD @ 350 GPM,480 PSI. (Good)L/D D.P.Pups and XO used for handling BHA.Blow down lines.Load nuclear source and finish M/U BHA#12 to 394'MD. 13.30 18.00 4.50 18.00-DRILL E 4 -XDO1 PJSA RIH W/BHA#12 on 4.5"D.P.F/394'to 1,340'MD.Shallow hole test MWD.(Good)@ 400 GPM,750 PSI.Cont.RIH F/1,340'to 7,034'MD.HST 165K,SLK 130K. 18:00 21.30 3.50 21.50'DRILL E 4 -XD01 PJSA RIH F/7,034'to 7,791'MD HST 175K,SLK 135K.Work BHA Across Whipstock W/8-10K drag @ 8,000'MD.Loss of SLK weight.wash down F 8,000'to 8,079'MD.SLK 125-130K W/pumps on.Cont.RIH taking surveys check shots as per Schlumberger MWD to 10,506'MD. • 21:30 22:00 0.50 22.00 DRILL 'E 4 XD01 PJSA Wash and ream F/10,506'to 10,548'MD 400 GPM,1,720 PSI,120 RPM,TRQ 10K. 22:00 00:00 2.00 24.00"DRILL E 3 •P PJSA Drill 8.75"L1 Production hole F/10,548'to 10,690'MD(4,087'TVD)500 GPM,2,400 PSI,130 RPM,WOB 2-8K, TQN 12K,TQF 8K,HST 200K,SLK 110K,ROT 152K.ECD 10.4 ppg W/9.25 ppg MW.Max Gas 500 units.ADT 062,Bit Hrs 8.58,Jar Hrs 8.58.Monitor well,static. SPR @ 10,548'MD(4,092'TVD)W/9.25 ppg MW MP#1 20-210,30-240 MP#2 20-210,30-240 • Daily Contacts Position Contact Name Company Title I E-mail Office Mobile Eni representative Mike Ross ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Troy England ENI HSE Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Pete Maninusen Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2.380.18 1.230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 Ig* Eni E&P Division 'Well Name:SP08-N7 L1 ENI Petroleum Co.Inc. Daily Repo�.}L Well Code:27891 Field Name:Nikaitchuq • APIIUWI:50-629-23501-60-00 2^ Date:11/5/2013 - Report#: 10 I( IIpage 1 of 1 Wellbore name: SPO8-N7L1 • Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00,HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 9.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3.879.19 1.237.37 620.88 12.98 47.8 123.0 -12.2 Partly Cloudy.WC- SSW @ 10 MPH 4` Daily summary operation 24h Summary Drill 8.75"L1 Production hole F/10,690'to 12,727'MD(4,064'TVD)555 GPM,2,910 PSI.80-170 RPM,WOB 2-12K.TON 12-13K,TQF 10K.HST 220K.SLK 83K,ROT 152K.ECD 11.0 ppg W/9.3 ppg MW.Max Gas 3,636 units.ADT 12.98,Bit Hrs 21.56,Jar Hrs 13.6.Monitor well,static. Operation at 07.00 Drill 8 3/4"LI Production hole to 13.104'MD. 24h Forecast Drill 8 3/4"L1 Production hole F/12,727'to-15,880'MD as per well plan. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"L1 Production hole F/10,690'to 11,157'MD(4,065'TVD)500 GPM,2,420 PSI,130 RPM,WOB 8-10K. TON 12K,TOF 8-11K,HST 205K,SLK 95K,ROT 153K.ECD 10.66 ppg W/9.3 ppg MW.Max Gas 3.200 units.ADT 3.57, Bit Hrs 12.15,Jar Hrs 4.19.Monitor well,static. 06.00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"L1 Production hole F/11,157'to 11,623'MD(4,055'TVD)550 GPM,2,910 PSI,80-130 RPM.WOB 6-10K, TON 6-10K,TQF 8-11K,HST 210K,SLK 90K,ROT 153K.ECD 11.09 ppg W/9.3 ppg MW.Max Gas 3,636 units.ADT 2.92,Bit Hrs 15.07,Jar Hrs 7.11.Monitor well,static. SPR @ 11,523'MD(4,059'TVD)W/9.3 ppg MW MP#1 20-250,30-310 MP#2 20-260,30-310 MP#3 20-250,30-310 12.00 18.00 6.00 18.00 DRILL E 3 P PJSA Drill 8.75"L1 Production hole F/11,623'to 12,183'MD(4,052'TVD)555 GPM,2.920 PSI,80-170 RPM.WOB 2-8K. TON 13K,TOF 9-10K,HST 212K,SLK 83K,ROT 152K.ECD 11.15 ppg W/9.3 ppg MW.Max Gas 1.500 units.ADT 3.65. Bit Hrs 18.72,Jar Hrs 10.76.Monitor well,static. 18.00 00.00 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"L1 Production hole F/12,183'to 12,727'MD(4,064'TVD)555 GPM,2,910 PSI.80-170 RPM.WOB 2-12K. TON 12-13K,TQF 10K.HST 220K,SLK 83K,ROT 152K.ECD 11.0 ppg W/9.3 ppg MW.Max Gas 1.300 units.ADT 2.84. Bit Hrs 21.56.Jar Hrs 13.6.Monitor well,static. SPR @ 12,463'MD(4,058'TVD)W/9.3 ppg MW MP#1 20-280,30-320 MP#2 20-280,30-320 MP#3 20-280,30-340 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Pete Martinusen Doyon Dulling Tour Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2,380.18 1,230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 V Eni E&P Division [ell Name: SPO8-N7 Li rifi* ENI Petroleum Co.Inc. Daily ReportWell Code:27891 Field Name:Nikaitchuq • 2 n Date:11/6/2013 - Report#: 11 APIIUWI:50-629-23501-60-00 'I �'II page 1 of 1 Wellbore name: SP08-N7L1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100,00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DES(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 10.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather W nd 4.526.28 1.231.45 647.09 13.76 47,0 120.0 -11.7 Partly Cloudy.WC- NE @ 28 MPH 10" Daily summary operation 24h Summary Drill 8.75"L1 Production hole F/13,304'to 13,770'MD(4,041'TVD).Main Drawworks chain failure.Remove and replace.Drill 8.75"L1 Production hole F/13,770'to 14,850'MD(4,042'TVD)545 GPM, 3,030 PSI,140-160 RPM,WOB 2-11K,TQN 14K,TQF 9K,HST 240K,SLK 83K,ROT 155K.ECD 11.23 ppg W/9.3 ppg MW.Max Gas 3.168 units.ADT 13.76,Bit Hrs 35.32,Jar Hrs 27.36.Monitor well. static. Operation at 07.00 Drill 8 3/4"L1 Production hole to 15.260'MD. 24h Forecast Drill 8 3/4"L1 Production hole F/14,850'to-15,880'MD as per well plan.At TD BROOH as per K&M BROOH schedule. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"L1 Production hole F/12,727'to 13,304'MD(4,054'TVD)550 GPM,2,990 PSI,100-170 RPM,WOB 4- 10K,TQN 11-14K,TQF 9-12K,HST 215K,SLK 83K,ROT 152K.ECD 10.88 ppg W/9.3 ppg MW.Max Gas 1.321 units. ADT 5.28,Bit Hrs 26.84,Jar Hrs 18.88.Monitor well,static. 06.00 1030 4.50 10.50 DRILL E 3 P PJSA Drill 8.75"L1 Production hole F/13,304'to 13,770'MD(4,041'ND)550 GPM,3,000 PSI,120-160 RPM,WOB 6- 10K,TQN 12.13K,TQF 9-10K,HST 220K,SLK 83K,ROT 155K.ECD 11.18 ppg W/9.3 ppg MW.Max Gas 1.157 units. ADT 2.26,Bit Hrs 29.10,Jar Hrs 21.14.Monitor well,static. SPR @ 13,396'MD(4,048'ND)W/9.2 ppg MW MP#1 20-300,30-380 MP#2 20-300,30-380 MP#3 20-300,30-380 10:30 12:00 1.50 12.00 DRILL E 20 XR99 Main Drawworks chain failure.Remove and replace. 12:00 12:30 0.50 12.50 DRILL E 20 XR99 Cont.replace chain on Drawworks. 12:30 13:00 0.50 13.00 DRILL E 20 P Service Rig,TS-8,Drawworks and Blocks. 13:00 18:00 5.00 18.00 DRILL E 3 P PJSA Drill 8.75"L1 Production hole F/13,770'14,423'MD(4,045'ND)550 GPM.3,000 PSI,140-160 RPM,WOB 2-10K. TQN 15K,TQF 9K,HST 230K,SLK 83K,ROT 152K.ECD 11,3 ppg W/9.3 ppg MW.Max Gas 2,964 units.ADT 2.77,Bit Firs 31.87,Jar Hrs 23.91.Monitor well,static. 18.00 0000 6.00 24.00 DRILL E 3 P PJSA Drill 8.75"L1 Production hole F/14,423'to 14,850'MD(4,042'ND)545 GPM,3,030 PSI,140-160 RPM,WOB 2- 11K,TON 14K,TQF 9K,HST 240K,SLK 83K,ROT 155K.ECD 11.23 ppg W/9.3 ppg MW.Max Gas 3,168 units.ADT 3.45,Bit Hrs 35.32,Jar Hrs 27.36.Monitor well,static. SPR @ 14,329'MD(4,040'ND)W/9.25 ppg MW MP#1 20-300,30-390 MP#2 20-300,30-380 MP#3 20-300,30-380 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dnlling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dnlling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondnlling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2,447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2.380.18 1.230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 Eni E&P Division .. !Wen Name: SP08-N7 L1 ENI Petroleum Co.Inc. Daily Report Well Code:27891_ Field Name:Nikaitchuq • Date:11/712013 - Report#: 12 APIIUWI:50-629-23501-60-00 2" " page 1 of 1 Wellbore name: SP08-N7L1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4.640.22 2480.77 56.78 43.7 11.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4.869.79 1,221.07 343.51 5.19 66.2 119.0 -11.1 Partly Cloudy.WC- E @ 28 MPH 13" Daily summary operation 24h Summary Drill 8.75"L1 Production hole F/14.850'to 15,977'MD(4,012'TVD)500 GPM,2,950 PSI.160 RPM,WOB 6-10K,TQN 14-15K,TOF 11-12K.HST 220K.SLK 83K,ROT 146K.ECD 11.36 ppg W/9.3 ppg MW.Max Gas 2,785 units.ADT 5.19,Bit Hrs 40.51,Jar Hrs 32.55.Encountered well bore losses and breathing @ 15,171'MD. Monitor well,static.PJSM At 15,977'MD perform exhale test initial pumps off flow rate 13%,recording fluid strap every 15 Min.First 15 Min 6.5 bbl returned.Second 15 Min.1/2 bbl returned.Third 15 Min.1/4 bbl returned.Down trend established for well bore breathing.Monitor well 45 Min.total.BROOH as per K&M BROOH schedule F/15,977'to 14,310'MD @ 450 GPM,2,160 PSI,120 RPM,TRQ 10K,ECD 10.7 ppg W/9.3 ppg MW.Max Gas 105.HST 220K,SLK 83K,ROT 151K.Total lost 163 bbl for today.Well breathing W/dynamic losses 10-15 bph. Operation at 07.00 BROOH as per K&M @ 12,654'MD 24h Forecast BROOH as per K&M BROOH schedule F/14,310'to BHA#12.L/D BHA#12. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr( Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 3 P PJSA Drill 8.75"L1 Production hole Fl 14,850'to 15,449'MD(4,015'TVD)500 GPM,3,080 PSI,160 RPM,WOE 6-10K, TON 13-14K,TQF 9-13K,HST 225K,SLK 83K,ROT 148K.ECD 11.16 ppg W/9.3 ppg MW.Max Gas 2,785 units.ADT 2.79,Bit Hrs 38.11.Jar Hrs 30.15.Encountered well bore losses and breathing @ 15,171'MD.Monitor well,static. SPR @ 15,449'MD(4,015'ND)W/9.3 ppg MW MP#1 20-330,30-420 MP#2 20-330,30-420 MP#3 20-330,30-420 06.00 12:00 6.00 12.00 DRILL E 3 P PJSA Drill 8.75"L1 Production hole F/15,449'to 15,977'MD(4,012'ND)500 GPM,2,950 PSI,160 RPM,WOB 6-10K, TON 14-15K,TOF 11-12K,HST 220K,SLK 83K,ROT 146K.ECD 11.36 ppg W/9.3 ppg MW.Max Gas 1,988 units.ADT 2.4,Bit Hrs 40.51,Jar Hrs 32.55.Well breathing W/Dynamic losses around 10 bph.Lost 69 bbl to formation for tour. Monitor well,static. 12:00 13:00 1.00 13.00 DRILL E 11 P PJSM At 15,977'MD perform exhale test initial pumps off flow rate 13%,recording fluid strap every 15 Min.First 15 Min 6.5 bbl returned.Second 15 Min.1/2 bbl returned.Third 15 Min.114 bbl returned.Down trend established for well bore breathing.Monitor well 45 Min.total. 13:00 1800 5.00 18.00 DRILL E '6 P BROOH as per K&M BROOH schedule F/15,977'to 15,500'MD @ 450 GPM,2,330 PSI,120 RPM,TRQ 12K,ECD 10.9 ppg W/9.3 ppg MW.Max Gas 2.005,HST 230K,SLK 83K,ROT 150K. 18:00 00:00 6.00 24.00 DRILL E 6 P BROOH as per K&M BROOH schedule F/15,500'to 14,310'MD @ 450 GPM,2,160 PSI,120 RPM,TRQ 10K.ECD 10.7 ppg W/9.3 ppg MW.Max Gas 105,HST 220K,SLK 83K,ROT 151K.Calculated displacement 12 bbl,actual 106 bbl,total lost 94 bbl for tour.Well breathing W/dynamic losses 10-15 bph. SPR @ 15,977'MD(4,009'ND)WI 9.3 ppg MW MP#1 20-320,30-440 MP#2 20-340,30-440 MP#3 20-340,30-440 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv 'SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Dulling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dolling Tool Pusher rig15@doyondnlling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB( Bottom(mKB) Run Date CASING 2447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.380.18 1,230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 1 D Eni E&P Division (Well Name: SP08-N7 L1 _ ENI Petroleum Co.Inc. Daily Report Well Code:27891 Field Name:Nikaitchuq • API/UWI:50-629-23501-60-00 2^n Date:11/8/2013 - Report#: 13 II "II page 1 of 1 Wellbore name: SPOB-N7L1 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2.480.77 56.78 43.7 12.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP)mlhr) POB Temperature(°C) Weather Wind 4,869.79 1,221.07 0.00 123.0 -11.1 Partly Cloudy.WC 0° S @ 9 MPH Daily summary operation 24h Summary BROOH as per K&M BROOH schedule FI 14,310'to 7,985'MD @ 450 GPM,1,868 PSI,120 RPM,TRQ 9-10K.ECD 10.49 ppg W/9.3 ppg MW.Max Gas 71,HST 189K,SLK 115K,ROT 150K.Log stand 110 @ 300 fph.Grease traveling Equip.POOH on elevators F/7,985'to 7,790'thru window,HST 180k,SLK 125K.CBU 3X @ 7,895'MD 450 GPM,1.720 PSI,60 RPM,TRQ 8K,ROT 147K.Total lost for trip 65 bbl to formation.POOH on elevators F/7,985'to 7,509'MD.Pump 20 bbl 11,3 ppg @ 6 bpm,500 PSI.Cont.POOH on elevators F/7,509'to 392'MD HST 100K.SLK 100K.Monitor well 10 Min,static.No losses. Operation at 07.00 P/U M/U Whipstock BHA 24h Forecast LID BHA#12 as per Schlumberger DD&MWD.Clean and clear ng floor.P/U M/U Whipstock fishing tools as per Baker,Schlumberger DD Rep onsite.RIH to retrieve Whipstock. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 6 P BROOH as per K&M BROOH schedule F/14,310'to 11,907'MD @ 450 GPM,2.050 PSI,120 RPM,TRQ 11K,ECD 10.49 ppg W/9.3 ppg MW.Max Gas 30,HST 195K,SLK 110K,ROT 151K. 06:00 12:00 6.00 12.00 DRILL E 6 P BROOH as per K&M BROOH schedule F/11,907'to 9,853'MD @ 450 GPM,1,868 PSI,120 RPM,TRO 9-10K,ECD 10.49 ppg W/9.3 ppg MW.Max Gas 71,HST 189K,SLK 115K,ROT 150K.Log stand 110 @ 300 fph.Grease traveling Equip. Calculated displacement 34,actual displacement 63 bbl.Lost 29 bbl to formation during trip. 12:00 16:30 4.50 16.50 DRILL E 6 P BROOH as per K&M BROOH schedule F/9,853'to 7,985'MD @ 450 GPM,1,790 PSI,60-130 RPM,TRQ 8-12K,ECD 9.92 ppg W/9.3 ppg MW,ROT 148K.Lost 25 bbl to formation during trip. 16:30 17:00 0.50- 17.00 DRILL E 4 P PJSA POOH on elevators F/7.985'to 7.790'thru window,HST 180k,SLK 125K. 17:00 20:00 3.00 20.00 DRILL E 7 P PJSA CBU 3X @ 7,895'MD 450 GPM,1,720 PSI,60 RPM,TRO 8K,ROT 147K. 20:00 00.00 4.00 24.00 DRILL E 4 P PJSA POOH on elevators F/7.985'to 7,509'MD.Pump 20 bbl 11.3 ppg @ 6 bpm.500 PSI.Cont.POOH on elevators F/ 7,509'to 392'MD HST 100K,SLK 100K.Monitor well 10 Min,static.No losses. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dolling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher dg15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2,447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD)mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2.380.18 1,230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 I , Eni E&P Division (Well Name:SP08-N7 L1 EN!Petroleum Co.Inc. Daily Report WellCode:27B91 Field Name:Nikaitchuq • APIIUWI:50-629-23501-60-00 en11 Date:11/9/2013 - Report#: 14 I' II page 1 of 1 Wellbore name: SPO8-N7L1 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 13.25 Daily Information End Depth(mKB) End Depth(TVD)(...Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4.669.79 1,221.07 0.00 110.0 1.7 Cloudy,WC 21' SSW @35 MPH Daily summary operation 24h Summary L/D BHA#12 as per Sclumberger DD&MWD.L/D Nuclear Sources,HWDP,Saver Sub,Jars,XO'S,Float Sub,NM Flex Collars,NM STAB,MWD.Xceed&Bit)No change on pipe tally from SLM out of hole.Lost 4 bbl static.Bit grade 0-0-CT-N-X-In-No-TD.Clean and clear rig floor of BHA#12 components.Monitor well,1 bph losses.Service rig and Equip.0/0 TT525 Saver Sub,clean and clear rig floor.P/U M/U Whipstock retrievable BHA with Baker and Sclumberger DD&MWD onsite.Orientate MWD to retrieval hook.RIH W/Whipstock retrievable Assy.on 5"D.P.FI 87'to 1,020'MD,HST 125K, SLK 130K.Shallow hole test MWD tools,400 GPM,460 PSI(Good Test).Cont.RIH F/1,020'to 7,646'MD,HST 174K,SLK 141K.Filling every 20 stands.Cut and slip drilling line.Adjust brakes and rollers.0/0 brake linkage bolt.RIH F/7,646'to 7,740'MD Orient tool and latch onto Whipstock©7,794'MD.Hst 174K,SLK 141K.P/U to 280K to release Whipstock.300 GPM,560 PSI,POOH 7,760' MD Hst 190K Circ.bottoms up @ 9 bpm,800 PSI,lost 5 bbl to formation.Drop Rabbit Length 17.5",OD 2.90"POOH F/7,760'to 7,111'MD Pump 30 bbl 11.2 ppg Dry Job @ 6 bpm,480 PSI.POOH W/ Whipstock on 5"D.P.F/7,111'to 1,267'MD.Lost 24 bbl to formation today. Operation at 07.00 R/U GBR Liner Equip. 24h Forecast Cont POOH W/Whipstock F/1,267'to Whipstock.L/D Whipstock as per Baker Rep onsite.PJSM R/U GBR Liner Equip.P/U M/U 5.5"Liner as per tally.RIH as per tally and P/U M/U Hanger as per Baker Rep onsite.RIH 5.5"Liner on 5"D.P. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(Er) Phase Opr. Act. Plan Oper.Descr. 00:00 0330 3.50 3.50 DRILL E 20 P 'PJSA L/D BHA#12 as per Sclumberger DD&MWD.L/D Nuclear Sources.HWDP,Saver Sub,Jars,XO'S,Float Sub,NM Flex Collars.NM STAB,MWD,Xceed&Bit)No change on pipe tally from SLM out of hole.Lost 4 bbl static.Bit grade 0-0- CT-N-X-In-No-TD 03:30 04:30 1.00 4.50 DRILL E 20 P Clean and clear rig floor of BHA#12 components.Monitor well,1 bph losses. 04:30 05:00 0.50 5.00 DRILL E 20 P Service rig and Equip. 05:00 07:30 2.50 7.50 DRILL E 20 P PJSA C/O TT525 Saver Sub,clean and clear rig floor. 07:30 09:30 2.00 9.50 DRILL E 20 P PJSA P/U M/U Whipstock retrievable BHA with Baker and Sclumberger DD&MWD onsite.Orientate MWD to retrieval hook. 09:30 12:00 2.50 12.00 DRILL E 4 P PJSA RIH W/Whipstock retrievable Assy.on 5"D.P.F/87'to 1,020'MD,HST 125K,SLK 130K.Shallow hole test MWD tools,400 GPM,460 PSI(Good Test).Cont.RIH F/1,020'to 2,327'MD HST 125K,SLK 130K Filling every 20 stands. 12:00 15:00 3.00 15.00 DRILL E 4 P PJSA RIH W/Whipstock retrievable Assy.on 5"D.P.F/1,020'to 7,646'MD,HST 174K,SLK 141K.Filling every 20 stands. 15:00 16:30 1.50 16.50 DRILL E 20 P PJSA Cut and slip drilling line.Adjust brakes and rollers.CIO brake linkage bolt. 16:30 17:00 0.50 17.00 DRILL E 13 P PJSA RIH F/7,646'to 7,740'MD Orient tool and latch onto Whipstock @ 7,794'MD.Hst 174K,SLK 141K.P/U to 280K to release Whipstock.300 GPM.560 PSI,POOH 7,760'MD Hst 190K 17:00 18:00 1.00 18.00 DRILL E 7 P PJSA Circ.bottoms up @ 9 bpm,800 PSI,lost 5 bbl to formation. 18:00 00:00 6.00 24.00 DRILL E 4 P PJSA Drop Rabbit Length 17.5",OD 2.90"POOH F/7,760'to 7,111'MD Pump 30 bbl 11.2 ppg Dry Job @ 6 bpm,480 PSI. POOH W/Whipstock on 5"D.P.F/7,111'to 1,267'MD.Lost 5 bbl to formation. Daily Contacts • Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com -907-685-0715 715-6434 Eni representative Oliver Amend ENI Dolling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2.447.54 10/16/2013 Last Leakoff Test • Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') •Eq.Mud Weight(gIL) P LeakOff(kgf/cm2) 2.380.18 1,230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 111* Eni E&P Division I Well Name:SP08-N7 L1 EN!Petroleum Co.Inc. Daily Report Well Code:27891 Field Name: Nikaitchuq • Date:11/10/2013 - Report#: 15 APIIUWI:50 629-23501-60-00 2 rr r'o page 1 of 1 Wellbore name: SP08-N7L1 Well Header PermitlConcession N° Operator ENI Share(14) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 14.25 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mihr) POB Temperature(°C) Weather Wind 4,869.79 1,221.07 0.00 ___ 107.0 -7.2 Overcast,WC 2' SSW @ 23 MPH Daily summary operation 24h Summary POOH W/Whipstock on 5"D.P.Fl 1,067'to 200'MD.HST 90K.PJSM on laying down Whipstock W/all essential personnel.L/D MWD and Whipstock as per Schlumberger MWD and Baker Rep onsite. Monitor well 1 bph static loss.Found large flat metal shaving about 8"X 4"X 1/32".Clear and clean rig floor,Press.wash all BHA tools.L/D Whipstock and BHA down Beaver Slide.PJSM W/all essential personnel.P/U M/U GBR Volant 5.5"handling Equip.P/U M/U Bent Jnt.and RIH W/5.5"15.58 Liner as per tally to 1,439'MD and tagged Liner Hanger @ 7,856'MD.POOH to 7.762'MD HST 147K,SLK 119K.Rotate string 180 degree and worked TRQ down 3 times.RIH F/7,762'to 8,166'MD thru window.HST 149K,SLK 117K.R/D GBR Volant and 5.5"handling tools.Clear rig floor of Csg.Equip. PJSM W/all essential personnel.P/U M/U SLZXP Packer as per Baker Rep onsite.Mix and pour Pal Mix into Hanger and let setup for 30 Min.RIH to 8,208'MD,M/U 4.5"IF X TTR525 XO.M/U 5"Stand D.P.,pump 5 bbl @ 2 bpm,50 PSI.Acquire ROT parameters as per K&M Rep onsite.ROT WT 135K,TRQ 7K @ 40 RPM.RIH 5.5"Liner and SLZXP Packer on 5"D.P.Fl 8,208'to 9,612'MD.SLK 117K. SIMOPS take on 220 bbl of 9.2 ppg KCL/NaCI Brine.Total lost 27 bbl to formation today.. Operation at 07.00 RIH 5.5"Liner and SLZXP Packer on 5"D.P.@ 14,701'MD. 24h Forecast RIH 5,5"Liner and SLZXP Packer on 5"D.P.F/9,612'to 15,828'MD.TOL @ 7,630'MD.Set Packer as per Baker Rep onsite.Test Packer to 1,500 PSI for 10 Min.on chart.Release from Packer and displace OBM to 9.2 ppg KCL/NaCl Brine as per MI Swaco plan forward.POOH and rack back 5"D.P.Test BOPE. Lithology Shows MAASP(kgficm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00'30 0.50 0.50 DRILL E 4 P PJSA POOH W/Whipstock on 5"D.P.F/1,067'to 200'MD.HST 90K. 00:30 03:30 3.00 3.50 DRILL E 20 P PJSM on laying down Whipstock W/all essential personnel.UD MWD and Whipstock as per Schlumberger MWD and Baker Rep onsite.Monitor well 1 bph static loss.Found large flat metal shaving about 8"X 4"X 1/32". 03:30 05:00 ' 1.50 5.00 DRILL E 20 'P Clear and clean rig floor,Press.wash all BHA tools.L/D Whipstock and BHA down Beaver Slide, 05:00 06:30 1.50 6.50 DRILL G 20 P PJSM W/all essential personnel.P/U M/U GBR Volant 5.5"handling Equip. 06.30 12.00 ' 5.50 12.00 DRILL G 4 P PJSA P/U M/U Bent Jnt,and RIH W/5.5"15.58 Liner as per tally to 1,439'MD HST 100K,SLK 98K.Lost a total of 15 bbl for the tour. 12.00 20.00 8.00 20.00 DRILL G 4 P PJSA P/U M/U Bent Jnt.and RIH W/5.5"15.5#Liner as per tally F/1,439' MD and tagged Liner Hanger @ 7,856'MD. POOH to 7.762'MD HST 147K,SLK 119K.Rotate string 180 degree and worked TRQ down 3 times.RIH F/7,762'to 8.166'MD thru window.HST 149K,SLK 117K. 20.00 20.30 0.50 20,50 DRILL G 20 'P PJSA R/D GBR Volant and 5.5"handling tools.Clear rig floor of Csg.Equip. 20.30 22:00 1.50 22.00 DRILL G 20 P PJSM W/all essential personnel.P/U M/U SLZXP Packer as per Baker Rep onsite.Mix and pour Pal Mix into Hanger and let set up for 30 Min.RIH to 8,208'MD,M/U 4.5"IF X TTR525 XO. 22:00 00:00 2.00 24.00 DRILL G 4 'P PJSA M/U 5"Stand D.P.,pump 5 bbl @ 2 bpm,50 PSI.Acquire ROT parameters as per K&M Rep onsite.ROT WT 135K, TRQ 7K @ 40 RPM.RIH 5.5"Liner and SLZXP Packer on 5"D.P.F/8,208'to 9,612'MD.SLK 117K.SIMOPS take on 220 bbl of 9.2 ppg KCL/NaCI Brine.Total lost 12 bbl this tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Malls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 2.447.54 10/16/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgficm') 2.360.18 1,230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 { Eni E&P Division I Well Name:SP08-N7 L1 ' Ill* ENI Petroleum Co.Inc. Daily Report Well Code:27891 Field Name:Nikaitchuq Date:1111112013 - Report#: 16• API/UWI:50-629-23501-60-00 e i o page 1 of 1 Wellbore name: SP08-N7L1 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr,(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7L1 DRILLING 10/27/2013 4,840.22 2,480.77 56.78 43.7 15.25 Daily Information • • End Depth(mKB) End Depth(TVD)(...Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 4,869.79 1,221.07 0.00 106.0 -12.2 Cloudy,WC-9° SW @ 20 MPH Daily summary operation 24h Summary RIH 5.5"Liner 8 SLZXP Packer on 5"D.P.F/9,612'to 14,697'MD,Tagged up rotate F/14,697'to 14,745'MD 40 RPM,ROT 158K,TRQ 14K.RIH FI 14,745'to 15,720'MD,Tagged up rotate F/15,720' to 15,835'MD 40 RPM,ROT 158K,TRQ 13K W/K&M Rep onsite.Circ.5"D.P.volume @ 2 bpm to ensure air is out of string.Press.test mud lines to 4,200 PSI.Break off single Jnt and drop 1 5/8"Frac Ball.POOH to set depth 15,828'MD,pull string in tension HST 178K.Pump ball down @ 2 bpm,150 PSI for 1,106 Strokes to seat ball.Stage Press.up to 4,000 PSI and hold for 15 Min.W/Baker Rep onsite.Bleed off Press.and test SLZXP Packer to 1,500 PSI for 15 Min.and charted.(Good)Liner top set at 7,630'MD.Un sting F/SLZXP Packer and L/D 2 Jnts 5"D.P.PJSM W/all essential personnel for displacement.Displace Faze Pro to 9.2 ppg KCL/NaCl Brine.Pump 40 bbl LVT&90 bbl Hi Vis Citric Acid treated Brine through MP 1,2 83 at 10 SPM each W/180 PSI.Encountered Phase 3 conditions working at low risk projects.Secure tugger lines in Derrick&inspect rig floor&roof due to Phase 3 weather conditions.PJSM W/all essential personnel for displacement Cont.to displace Face Pro to 9.2 ppg Brine W/560 bbl @ 6 bpm,180 PSI,40 RPM,TRO 7K,ROT WT 153K @ 7,629'MD.Blow down TS-8.Clean surface Equip.in Pits.Clean rig floor 8 drip pan.SIMOPS inspect Drawmorks chains.Circ.drill string volume @ 3bpm,60 PSI due to Phase 3 weather condition.Reduced to Phase 2 weather conditions.Blow down TS-8.R/U to lay down 5"D.P.POOH laying down 5" D.P.F/7,612'MD to Baker running tools.HST 79K,SLK 79K.L/D Packer running tools as per Baker Rep onsite.Lost a total of 31 bbl to formation today. Operation at 07.00 L/D 4.5"D.P.F/Derrick. FINAL DAILY DRILLING REPORT. 24h Forecast L/D 4.5"D.P.F/Derrick until 6:00 AM.Test BOPE witnessed by Jeff Turkington.P/U M/U 4.5"Tubing Csg.Equip.P/U M/U ESP Motor and RIH W/4.5"Tubing. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:30 5.50 5.50 DRILL G 4 P PJSA RIH 5.5"Liner 8 SLZXP Packer on 5"D.P.F/9,612'to 14,697'MD,Tagged up rotate F/14,697'to 14,745'MD 40 RPM,ROT 158K,TRQ 14K.RIH F/14,745'to 15,720'MD,Tagged up rotate F/15,720'to 15.835'MD 40 RPM,ROT 158K, TRQ 13K W/K&M Rep onsite. 05:30 07:00 1.50 7.00 DRILL G 7 P PJSA Circ.5"D.P.volume @ 2 bpm to ensure air is out of string.Press.test mud lines to 4,200 PSI. 07:00 10:00 3.00 10.00 DRILL G 19 P PJSA Break off single Jnt and drop 1 5/8"Frac Ball.POOH to set depth 15,828'MD,pull string in tension HST 178K.Pump ball down @ 2 bpm,150 PSI for 1,106 Strokes to seat ball.Stage Press.up to 4,000 PSI and hold for 15 Min.WI Baker Rep onsite.Bleed off Press.and test SLZXP Packer to 1,500 PSI for 15 Min.and charted.(Good)Liner top set at 7,630' MD.Un sting Fl SLZXP Packer and L/D 2 Jnts 5"D.P. 10:00 12:00 2.00 12.00 DRILL G 9 P PJSM W/all essential personnel for displacement.Displace Faze Pro to 9.2 ppg KCL/NaCI Brine.Pump 40 bbl LVI'&90 bbl Hi Vis Citric Acid treated Brine through MP 1,2 83 at 10 SPM each W/180 PSI.Encountered Phase 3 conditions working at low risk projects. 12:00 12:30 0.50 12.50 DRILL G 20 P PJSA Secure tugger lines in Derrick&inspect rig floor&roof due to Phase 3 weather conditions. 12:30 15:00 2.50 15.00 DRILL G 9 P PJSM W/all essential personnel for displacement.Cont.to displace Face Pro to 9.2 ppg Brine W/560 bbl @ 6 bpm,180 PSI,40 RPM,TRQ 7K.ROT WT 153K @ 7,629'MD.Blow down TS-8.Phase 3 conditions working at low risk projects. 15:00 18:00 3.00 18.00 DRILL G 20 P PJSA Clean surface Equip.in Pits.Clean ng floor 8 drip pan.SIMOPS inspect Drawworks chains.Phase 3 conditions working at low risk projects. 18:00 19:00 1.00 19.00 DRILL G 7 P PJSA Circ.drill string volume @ 3bpm,60 PSI due to Phase 3 weather condition. 19:00 00:00 5.00 24.00 DRILL G 4 P PJSA Reduced to Phase 2 weather conditions.Blow down TS-8.R/U to lay down 5"D.P.POOH laying down 5"D.P.Fl 7,612'MD to Baker running tools.HST 79K,SLK 79K.L/D Packer running tools as per Baker Rep onsite.Lost a total of 31 bbl to formation today. • Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDrilling@enipetroleum.com 907-685-0715 715-6434 • Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.950 L-80 2,325.75 4.824.37 11/11/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 2.380.18 1,230.86 OBM Faze Pro 1114.4 34.2 1392.0 171.3 r rill* Eni E&P Division } (Well Name: SP08-N7 OR ENI Petroleum Co.Inc. Daily Repo.. Well Code:27537 Field Name: Nikaitchuq • APIIUWI:50-629-23501-00-00 2^r,'I Date:11/1212013 - Report#: 1 " II page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 COMPLETION 40.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 112.0 -12.2 Mostly Cloudy.WC- E @ 17 MPH 8' Daily summary operation 24h Summary Rig on Completion AFE @ 0001 hrs.L/D all 4.5"and 5"DP.R/U and test BOPE w/4.5"test jt to 250/3500 psi as per state AOGCC rep Jeff Turkington.P/U and start to M/U completion,7"shroud,motor and seal assy.R/U Howco wire line and set pump and pack off. Operation at 07.00 Running 4.5"completion. 24h Forecast RIH with 4.5"completion string as per program. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:30 4.50 4.50 COMP K 20 P PJSA C/O elevators to 4.5"and LD 35 stands of DP 04:30 05:30 1.00 5.50 COMP K 20 P PJSA Pull wear bushing and install test plug as per Vetco. 05:30 06:30 1.00 6.50 COMP K 12 P PJSA R/U BOPE test equipment,fill stack and perform body test on stack and choke. 06:30 07:30 1.00 7.50 COMP K 25 P Service blocks,draw works,top-dnve and iron roughneck. 07:30 13:30 6.00 13.50 COMP K 12 P PJSA test BOPE as per slate regs @ 250/3500 psi with 4.5"test jt.Witnessed by AOGCC Rep Jeff Turkington.Perform draw down and checked all gas,pit and flow monitors. 13:30 14:00 0.50 14.00 COMP K 20 P PJSA Pull test plug,B/D choke,kill and top-dove.Grease IBOP's. 14:00 18:30 4.50 18.50 COMP K 20 P PJSA UD 135 jts of 4.5"DP.C/O handling equipment to 5"and L/D 12 jts of 5". 18:30 20:00 1.50 20.00 COMP K 20 P PJSA Clear and clean rig floor,Load completion equipment to ng floor.Prep pipe shed for P/U pump assy. 20:00 22:00 2.00 22.00 COMP K 4 P PJSA with all parties involved.P/U and M/U 7"shroud,M/U shroud hanger,XO and jt#1.M/U Tandem seal sections and TTC crossover screen intake and lower in shroud. 2200 00:00 2.00 24.00 COMP K 20 P PJSA with all parties involved.R/U Howco wire line equipment and set pump and L/D wire line tool string.POOH to verify proper pump seat.RIH P/U wire line tools and set pack off.Total fluid loss for day 26 bbls. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Bernie Leas ENI Rig Clerk aktigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dulling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.825 L-80 2,386.47 4.834.13 10/27/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2.447.54 1,239.91 FAZE Pro 1102.4 56.6 1559.4 193.3 t • Ill* Eni E&P Division I Well Name:SP08-N7 OR ENI Petroleum Co.Inc. Daily Report Well Code:27537 Field Name:Nikaitchuq • APIIUWI:50-629-23501-00-00 2^ Date:11/13/2013 - Report#: 2 rill(In page 1 of 1 Wellbore name: SP08-N7 Well Header Permit/Concession N° Operator ENI Share(/4) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m( Ground Level(m) Water Depth(m) 'RKB-Base Flange(m) RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information • • Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) SP08-N7 COMPLETION 41.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr( Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 103.0 -6.1 Snow WC 7` WNW©19 MPH Daily summary operation 24h Summary Test Tubing pack off to 1000 psi for 15 charted min.Set Tbg stop and M/U lower completion wl ESP and cap tube assemblies.RIH w/4.5"12.6#L-80 HYD 563 ESP completion to 4083'. Operation at 07.00 Running 4.5"ESP completion as per tally @ 5,735'MD 24h Forecast RIH w14.5"ESP completion to setting depth of 7220'. • Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr( Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 COMP K 12 P PJSA Fill tubing with water and fluid level falling.so pack off not seated.RIH w/wire line and resealed pack off.RIH and set test tool and R/U and test system to 1000 psi for 15 charted min. 01:00 02:30 1.50 2.50 COMP K 20 P PJSA Pull test plug and set tubing stop.R/D Howco wire line equipment. 02:30 0630 4.00 6.50 COMP K 4 P PJSA M/U motor assy and service.Terminate capillary and Tec wire connections and gauge.Lower assy into shroud.M/U TTC XO and pump assy to motor.Terminate MLE to motor.M/U motor shroud hanger to shroud and RIH w/completion on joint#1. 06.30 07:30 1.00 7.50 COMP K 20 P PJSA with GBR on R/U of Volant CRT.R/U bail extensions and elevators.Service swivel packing and top-dove. • 07:30 11:00 3.50 11.00 COMP K 20 P PJSA P/U&M/U XO pup to jt#2.Terminate TEC wire to DGU.Hang sheaves and pull cat line&ESP cable to rig floor.P/U bow centralizers and stage on rig floor. 11:00 13:00 2.00 13.00 COMP K 20 P PJSA Baker Centrilitl splice MLE to ESP cable.Cable tested good. 13.00 18.00 5.00 18.00 COMP K '4 P PJSA with all parties for completion run.M/U 3/8"Cap line to 1/4"Cap tube.RIH w/4.5"12.68 L-80 HYD 563 ESP completion as per tally checking cable every 1000'to 1497'. 18:00 00.00 6.00 24.00 COMP K 4 P PJSA Cont.running 4.5"ESP completion f/1497'-4083'. Daily Contacts Position Contact Name Company Title ' E-mail Office Mobile Eni representative Jack Keener ENI Senior Drilling Supv SIDDnlling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Dave Evans Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Dolling Tool Pusher rig15@doyondrilling.com 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.825 L-80 2,386.47 4.834.13 10/27/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2.447.54 1,239.91 FAZE Pro 1102.4 56.6 1559.4 193.3 • °"'. Eni E&P Division } Well Name:SP08-N7 OR 161* EN/Petroleum Co.Inc. Daily Report Well Code:27537 Field Name: Nikaitchuq •2^ Date:11/14/2013 - Report#: 3 APIIUWI:50 629-23501-00-00 II 'I page 1 of 1 Wellbore name: SPO8-N7 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 213-134 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) •RKB-Tubing Spool(m) 16.44 3.99 11.20 Rig Information Contractor Rig Name Rig Type DOYON RIG 15 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) SP08-N7 COMPLETION 42.69 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 0.00 101.0 -10.0 Snow WC-3' W @25 MPH Daily summary operation f 24h Summary Run 4.5"12.66 L-80 Hyd 563 ESP completion to 7220'landed on Vetco tubing hanger.N/U tree and test all components to 5000 psi.Freeze protect IA w/100 bls of diesel.Secure well and release rig @ 2400 hrs. Operation at 07.00 Moving off of well SP08-N7. 24h Forecast R/D ng and move off well SP08-N7 Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 COMP K 4 P 'PJSA RIH w/4.5"12.60 L-80 HYD 563 ESP completion to 7177'. 07:00 07:30 0.50 7.50 COMP K 20 P PJSA M/U XO pup,R/D Volant tool,P/U YC elevators and Vetco hanger. 07:30 12:00 4.50 12.00 COMP K 4 P PJSA M/U tubing hanger to landing jt.Test Penetrator splice and capillary line.RIH and land @ 7220'w/177 jts.@ 1100 hrs.Clean and clear rig floor.156 total clamps,3 centralizers and 1 splice clamp used. 12:00 13:00 1.00 13.00 COMP K 12 P PJSA RILDS,LID landing jt.Test upper and lower hanger seals to 5000 psi f/10 min.Lower ESP and cap tube to spooling unit and secure.Clean and clear rig floor. 13:00 15:30 2.50 15.50 COMP K 20 P PJSA L/D mouse hole,N/D BOPE and Hi-pressure riser. 15:30 18:30 3.00 18.50 COMP K 12 P PJSA Clean and dress well head,N/U tree and test void to 5000 psi f/10 min.Pull BPV and instal TWC and test tree to 5000 psi f/10 min.Baker perform final conductivity tests.Pull TWC.R/D Rock Washer suit case lines,undo berming and work on interconnects. 18:30 21:00 2.50 21.00 COMP K 9 P PJSA R/U LRS to IA and PT lines to 2500 psi.Bull head 100 bbls of diesel down IA.IP-400psi,FP-600 psi. 21:00 23:00 2.00 23.00 COMP K 20 P PJSA Shut in well and secure. 225 psi tubing 500 IA 200 OA 23.00 00:00 1.00 24.00 COMP K 20 P PJSA Prep for rig move.Blow down water,take down diverter line from well bay.Rig Released @ 2400 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI 'Senior Drilling Supv -SIDDrilling@enipetroleum.com 907-685-0715 715-6434 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative 011ie Atwell ENI HSE 907-685-0721 Eni representative Jack Kvasnikoff ENI HSE 907-685-0721 907-398-8770 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Steve Dambacher Doyon Drilling Tool Pusher ng15@doyondrilling.com 907-685-0716 Tool Push Chad Johnson Doyon Drilling Tool Pusher ng15@doyondrilling.corn 907-685-0716 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 51/2 4.825 L-80 2,386.47 4.834.13 10/27/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.447.54 1,239.91 FAZE Pro 1102.4 56.6 1559.4 193.3 a A1� '812,7:2 {p Y� ��pp pmmOt1 O .5 9'1V lVN1M.IV tBop42�CpA�V.00 $28$31pp pM{R{'IR2�pQ^1� 48;§P§ 81pTy(+If$t^T') 8y81O200 N 1 NNNN- §IEiM C P28 AA1f..A10 310 .'110 w00$pW --P2 p2228[{ S J FIM�A( 410r7I0A1ON YAf A1O0NHN Hi10[ A10SN yA1�I rm YAINNN§ ilffl yNi iii i N10hh0 1ANbNb 101)101010 011 N.0N N.N.N Ear731§ AAAA A 00000 00000 00000 AA0AA 00000 00000 000P: r,- 1'12"111 {{((+pp.'�. tlm�� p ppb m f�ep-I pp1 {y tap �fOp�yp♦p ^ (y p� a lN•)1�')M1W OYYem '4"ri VT 0101Wi NOm 10 11PP IVO �q1 ll $$$$i SS agg,$$ 82288 $OO OROOO 8$888$ fff$8888 2222 c7 aaaaV aaaaa aaaVa aVVaa aaaaa aaaaa aVaaa away = Sm1 W �cmM tilgN '6“§$ Fill� N $mm mffito pO" � lg N NN .2 01010100O10 10(�1001010 ..101010 ...In. ....10 10.0.0.011 (..10.)0 10)0Q..0 C bW 0A10R ti22G NRONi ANA OA.N�Ola'I R$:04 N V8 17 Me V N $$$2 Z�ggy g e, mmmm RA 22nAA 22 4Vi 66666 2 .n2�g „ 88888 $y1p88f88 888888 88p8♦88� 888888 888888 038$3$ 3282 j _40-Oe 21002$ 0110000 .-NR*N OOO.tO $Z.:2.-In 0NN1m RAV$ ia 'Z0.,00 00.x'- 00000 . 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F 0 LL 's ° > DMO(7a 10j .% cminNm°1 mr�rnoc aa2" M< mm 8t2'8 ^M N OoomoO8 D y toiLeini y $nm O4m--� .a N ^ rnlw4m,0o F, Z ? 2 \ 4, r.-- HALLI B U RTO N �' DATA LOGGED __. _ )Z/%l/2013 Sp& r 4�'i t"Td MKBENDER RECEWED To: Alaska Oil and Gas Conversation Commission f C 2Q1 333 W 7th Ave Suite 100 Anchorage, AK 99501 Attn: Howard Oakland AOGCC From: Sperry Drilling -Alaska Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage, AK 99518 907-273-3559 Office 907-273-3535 Fax Robert.Haverfield( Halliburton.com Re: Eni Well —SP08-N7 & SP08-N7L1 AFE # 6206 Rig — Doyon 15 Spy Island —Nikaitchuq, Alaska Shipment Includes: 1 End of Well Reports 1 Final Data Listing on CD-ROM 1 Sets of Final Logs—for each well contains: • 2" Color Log — Formation Evaluation TVD • 2" Color Log — Formation Evaluation MD • 2" Color Log — Drilling Engineering MD • 2" Color Log — Gas Ratio MD Received By: Print Name ) , 1/4 } Sign Name Date r II' Please sign acknowledgement of receipt g e pt - email, fax, or mail back. Thank you. -11 1/Pib X13 -/3'71 HALLIBURTON Cen II EnO Petirolletuirn C_1riEling PACKING LIST Spy Island Drillsite Nikaitchuq SPO8-N7&5P08-N7L1 Shipping Date: 9-Nov-2013 Spy Island,Alaska Ship From: Ship To: ENI Petroleum AOGCC C/O Sperry Drilling Alaska 333 West 7th Avenue; Suite 100 6900 Arctic Blvd. Anchorage,AK 99501 Anchorage,AK 99515 Attn: Howard Oakland 907-739-1235 itim Description 111111111111 Interval Packaging Box Desc on SP08-N7 Pit 02,,{.3^ 131 Washed and Dried Samples-50' 2,700'to 5,750' Paper envelopes 1 of 10 Washed and Dried Samples-50' 5,800'to 8,300' Paper envelopes 2 of 10 Washed and Dried Samples-50' 8,350'to 10,850' Paper envelopes 3 of 10 Washed and Dried Samples-50' 10,900'to 13,000' Paper envelopes 4 of 10 • Washed and Dried Samples-50' 13,050'to 15,870'TD Paper envelopes 5 of 10 SP08-N7L1 ?TI) 275— {t9 Washed and Dried Samples-50' 7,850'to 9,900' Paper envelopes 6 of 10 Washed and Dried Samples-50' 9,950'to 11,600' Paper envelopes 7 of 10 Washed and Dried Samples-50' 11,650'to 13,600' Paper envelopes 8 of 10 Washed and Dried Samples-50' 13,650'to 15,550' Paper envelopes 9 of 10 Washed and Dried Samples-50' 15,600'to 15,977'TD Paper envelopes 10 of 10 One(1)Bundle Contains all Ten(10)Boxes Notes: Total Packages this Shipment: 1 Please notify sender upon receipt of delivery; Andrew Buchanan 907-865-3388 Received by Expediter: Date: L IVIS' Apo ��I3 0w\"\\�j/j's THE STATE Alaska Oil and Gas °ALASKAConservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue �wh' ALAS Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Davide Simeone Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, SP08-N7 ENI US Operating Co. Inc. Permit No: 213-134 Surface Location: 4478' FSL, 1234' FEL, S19, T14N, R9E, UM Bottomhole Location: 2317' FSL, 501' FEL, S12, T14N, R8E, UM Dear Mr. Simeone: Enclosed is the approved application for permit to drill the above referenced service 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this/ l`day of September, 2013. RECEIVED STATE OF ALASKA ALt-xoKA OIL AND GAS CONSERVATION COMM,__.ON SEP 0 9 2013 PERMIT TO DRILL �®�� 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil U Service- Winj U Single Zone ❑ 1c.Specify if well is proposed for: Drill E Lateral ❑ Stratigraphic Test E 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 Q Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 SP08-N7 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 15738 TVD: 3969 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Nikaitchuq/Schrader Bluff Surface: 4478 FSL,1234 FEL,S19 T14N R9E UM ADL 0391283,0388583,0388581,0388571 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2571 FSL,5084 FEL,S17 T14N R9E UM ADL 417493 10/6/ 013 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2317 FSL,501 FEL,S12 T14N R8E UM 10940 10600'to unit bundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 54.1 feet 15.Distance to Nearest Well Open Surface: x-511676 y- 6053659 Zone-4 GL Elevation above MSL: 13.1 feet to Same Pool: 2200'to SP18-N5 16.Deviated wells: Kickoff depth: 400 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92.81 degrees Downhole: 1750 psig Surface: 1314 psig 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade _ Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 160 36 36 160 160 Pre-Installed i 16" 13-3/8" 68 L-80 BTC 2588 35 35 2623 2454 1286 TOTAL sx LEAD: 1050 sx 10.7 ppg ASL 12.25" 9-5/8" 40 L-80 Hydril 563 8056 33 33 8089 4019 786 TOTAL sx 786 sx 12.5 ppg DeepCrete 8-3/4" 5-1/2" 15.5 L-80 Hydril 521 7849 7889 4007 15738 3969 Liner in open hole 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): 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑., Seabed Report ❑ Drilling Fluid Program 2 20 AAC 25.050 requirements❑Q 21. Verbal Approval: Commission Representative: Date 9/6/2013 22. I hereby certify that the foregoing is true and correct. Lara Occhionero 907 947 4100 Contact Email Printed Name Davide Simeone Title Well Operation Project Manager 1/ I Signature II6,vtafr..- Phone (907)865-3320 Date 9/6/2013 Commission Use Only Permit to Drill \ Permit Approval q/q/� ISee cover letter for other Number: a 13-'3y - 2 3 sot-00-a) Date: / / 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: Other: * gsoo '-a SO S Samples req'd: Yes❑ No1I " Mud log req'd:Yes No[� / H2S measures: Yes❑ No 12' Directional svy req'd:Yes["No❑ Spacing exception req'd: Yes❑ No" Inclination-only svy req'd:Yes❑ No I.J i ,diS/ APPROVED BY 9b 7(/ Approved �/ ^ Da e:Submit Form and �Afm 10-401(Rrviced moon 9) Thiser� ti lej' ftNnAlripte of as Wtitekl 00 c t^' li^rI V Z•/t(3 �,[`vR �! ' G RECEIVED STATE OF ALASKA AUG 2 9 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ��G�� 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil LI" Service- Winj U Single Zone Q lc.Specify if well is proposed for: Drill Q Redrill ❑ Stratigraphic Test Li Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 • SP08-N7 k 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: ' 15738 TVD: 3969 J Nikaitchuq/Schrader Bluff i I 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): , Surface: 4478 FSL, 1234 FEL,S19 T14N R9E UM • ADL 0391283,0388583,0388581,0388571- Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2571 FSL,5084 FEL,S17 T14N R9E UM . ADL 417493 9/26/2013 Total Depth: 9.Acres in Property: 4 i 14.Distance to Nearest Property: 2317 FSL,501 FEL,S12 T14N R8E UM • 189- /O�j>{O,j� 10600'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL; 54.1 15.Distance to Nearest Well Open Surface:x- 511676 y- 6053659 Zone- 4 _ GL Elevation above MSL: 13.1 to Same Pool: 2200'to SP18-N5 1 16.Deviated wells: Kickoff depth: yb° -0-feet 'la 17.Maximum Anticip,afed Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92.81 degrees • Downhole: 1750/p'sig Surface: 1314 psig • 18.Casing Program: Specifications Top -'Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 16036 160 160 Pre-Installed 1286 TOTAL sx 16" 13-3/8" 68 L-80 BTC 2588 3'5 35 2623 2454 LEAD:1050 sx 10.7 ppg ASL TAIL:236 sx 12.5 ppg DeepCrete 786 TOTAL sx 12.25" 9-5/8" 40 L-80 Hydril 563 80549...../' 33 33 8089 4019 786 sx 12.5 ppg DeepCrete : 8-3/4" 5-1/2" 15.5 L-80 Hydril 521 . •9 7889 4007 15738 3969 Liner in open hole 19. PRESENT WELL CONDITION SUMMAR (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plug>=sured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface .-N-1,..Intermediate 'x'11 Production Liner 'Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q ' BOP Sketch 0, Drilling Program 0 ' Time v.Depth Plot ❑ Shallow Hazard Analysis 2 Diverter Sketch❑., , Seabed Report ❑ Drilling Fluid Program 0 ' 20 AAC 25.050 requirements 1 21. Verbal Approval: Commission Repres ntative: Date 8/27/2013 22. I hereby certify that the foregoing is tr e and correct. Contact Lara Occhionero 907-947-4100 Printed Name Davide Simeone Title Well Operation Project Manager SignatureOL V b Q Phone (907)865-3320 Date 8/27/2013 Commission Use Only Permit to Drill P Number: Permit Approval See cover letter for other Number: ,2/3())31-1 / 50- G 2� - .23s-01 -00 - OD Date: requirements. Conditions of approval: If box is checked,wet may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: Samples req'd: Yes❑ No[ Mud log req'd: Yes ❑ No 0/ H2S measures: Yes❑ No10 Directional svy req'd: Yes Ia"No ❑ s?c..: E(c-el)) f L i&{ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER OR J '3 ''e Form 10-401(Revised 7/2009) This s f rh from the date of approval(20 AAC 25.005(g)) Su it in Dupli` tate ct1 RECEIVED AUG 2 9 2013 fili441".' AOGCC • En ii PetirII ; um ern 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Davide Simeone Phone(907)865-3320 Email: Davide.Simeone@enipetroleum.com August 29,2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer SP08-N7 Dear Commissioners, Eni US Operating Co. Inc. hereby applies for a Permit to Drill for the Offshore Producer well SP08-N7. This well will be drilled and completed using the rig Doyon 15. The Reservoir team at EniPetroleum would like to utilize the end of the production wellbore of SP08-N7 to further delineate the Schrader Bluff Reservoirs. The planned well path will not breach the Schrader Bluff Top ( i.e. we will not exit the TOP of N-Sand sequence,we always remaining within the Schrader Bluff Oil Pool). The lateral section upon exiting the defined primary fault block from 8039-15738 MD will be not cased/completed. Attached are the plan view and the cross section. The planned spud date could be as early as 9/26/2013. Please find attached for the review of the Commission forms 10-401, the information required by 20 ACC 25.005. If you have any questions or require further information,please contact Lara Occhionero 907-947- 4100. Sincerely, ikV I ( Davide Sime e Well Operati 'roject Manager Enil D Application for Permit to Drill SP08-N7 Saved:27-Aug-13 Application for Permit to Drill Document Producer Well SP08-N7 Table of Contents 1. Well Name 3 Requirements of 20 MC 25.005(f) 3 2. Location Summary 3 Requirements of 20 MC 25.005(c)(2) 3 Please see Attachment 7:Surface Platt 3 Requirements of 20 MC 25.050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 MC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 MC 25.005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 • Requirements of 20 MC 25.005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 MC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 MC 25.005(c)(7) 5 8. Drilling Fluid Program 6 Requirements of 20 MC 25.005(c)(8) 6 Surface Hole Mud Program(extended bentonite) 6 Intermediate Hole Mud Program 6 (LSND) 6 Lateral Mud Program 6 (MI FazePro Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 MC 25.005(c)(9) 6 10. Seismic Analysis 7 AOGCC PERMIT Document.doc Page 1 of 9 Printed:27-Aug-13 en a Petirolleum Application for Permit to Drill SP08-N7 Saved:27-Aug-13 Requirements of 20 MC 25.005(c)(10) 7 11. Seabed Condition Analysis 7 Requirements of 20 MC 25.005(c)(11) 7 12. Evidence of Bonding 7 Requirements of 20 MC 25.005(c)(12) 7 13. Proposed Drilling Program 7 Requirements of 20 MC 25.005(c)(13) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 MC 25.005(c)(14) 9 15. Attachments 9 Attachment 1 Drilling Procedure 9 Attachment 2 Directional Plan 9 Attachment 3 Drilling Hazards Summary 9 Attachment 4 BOP and Diverter Configuration 9 Attachment 5 Cement Loads and CemCADE Summary 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 Attachment 8 Casing Design Program 9 AOGCC PERMIT Document.doc Page 2 of 9 Printed:27-Aug-13 Eni Petirolleum enn Application for Permit to Drill SP08-N7 Saved:29-Aug-13 1. Well Name Requirements of 20 MC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: SP08-N7 2. Location Summary Requirements of 20 MC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified/n the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 4478 FSL, 1234 FEL, S19 T14N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 54.1'AMSL Northing: 6,053,659' Easting:511,676' Pad Elevation 13.1'AMSL Location at Top of Productive Interval 2571 FSL, 5084 FEL, S17 T14N R9E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 8,089' Northing: 6,057,034' Easting: 513,088' Total Vertical Depth, RKB: 4,019' Total Vertical Depth, SS:_ 3,965' Location at Total Depth 2317 FSL, 501 FEL, S12 T14N R8E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 15,738' Northing: 6,062,051' Easting: 507,319' Total Vertical Depth, RKB: 3,969' Total Vertical Depth, SS: 3,915' Please see Attachment 7: Surface Platt and (D)other information required by 20 MC 25.050(b); Requirements of 20 MC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner • The Applicant is the only affected owner. AOGCC PERMIT Document.doc Paoe 3 of 9 Enil Petirolleum ens Application for Permit to Drill SP08-N7 Saved: 29-Aug-13 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 MC 25.036, or 20 MC 25.037,as applicable; Please see Attachment 4: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 MC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards, including (A)the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum ressure gradient, a P methane gradient (0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3,968'TVDss)(0.45 - 0.11 psi/ft) = 1314 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 MC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 MC 25.0300; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc fl...... A..1 II Enii Petirolleuim Application for Permit to Drill SP08-N7 Saved:27-Aug-13 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (1nt (lb/ft) Grade Connection (ft) (ft) (R) Cement Program 20 Driven 178.89 X-65 Welded 120 36/ 36 160'/ 160' Pre-Installed 4K fir IP� 1382 TOTAL sx 13-3/8 16 68 L-80 BTC 2588' 35/ 35 2623'/ 2454' LEAD: 1146 sx 10.7 ppg ASL TAIL: 236 sx 12.5 ppg DeepCrete • x_938 TOTAL sx 4) 9-5/8 12-1/4 40 L-80 Hydril 563 8056' 33/ 33 8089'/ 4019' 938 sx 12.5 ppg DeepCrete , 8-3/4"OA 5-1/2 Sand 15.5 L-80 Hydril 521 7798' 7940'/ 4010 15738'/ 3969' Liner in Open Hole-no cement Lateral 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 4: BOP and Diverter Configuration. AOGCC PERMIT Document.doc Page 5 of 9 Printed:27-Aug-13 • CN Petirolleuim eno Application for Permit to Drill SP08-N7 Saved:27-Aug-13 8. Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 sf) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) (MI FazePro Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 8.7-9.4 Density(ppg) 8.8 - 9.5 Plastic Viscostiy 15 - 25 Funnel Viscosity (CP) (seconds) 45 - 60 Yield Point Plastic Viscostiy (lb/100 sf) 15 20 12 - 18 (CP) HTHP Fluid loss Yield Point (ml/30 min @ <5.0 (lb/100 sf) 18-24 200psi&100°F API Filtrate Oil/Water (cc/30 min)) Ratio - 6 Ratio 60/ 40 Chlorides(mg/1) <500 Electrical >600 pH 9.0 - 10.0 Stability MST <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 MC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 MC 25.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. AOGCC PERMIT Document.doc Page 6 of 9 Printed:27-Aug-13 • Enil Petirolleum ens Application for Permit to Drill SP08-N7 Saved:27-Aug-13 10. Seismic Analysis Requirements of 20 MC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 MC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform, mobile bottom-founded structure,jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(b),• Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 MC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 MC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Please refer also to Attachment 1— Drilling Procedure 1) Move in/ rig up Doyon 15. IJ`�• ./ I,. (S 2) RU Diverter and test as per AOGCC requirements. '� 3) Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4) Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. • 5) Install and test wellhead to 5000 PSI. .6) Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. .7) Pressure test casing to 2500 psi per AOGCC regulations. Record results.(C46.1/3° - 8) PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. 9) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. Min LOT= 11 ppg. 10) Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 11) Install 9-5/8"casing rams in the BOP and test to 3500 PSI. 12) RU casing drive system. AOGCC PERMIT Document.doc Page 7 of 9 Printed:27-Aug-13 • Enil Petirolleum Application for Permit to Drill SP08-N7 Saved:27-Aug-13 13) Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 14) Install 9-5/8" Emergency Slips. 15) Install 9-5/8"packoff and test to 5000 psi. 16) Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 17) Pressure test casing to 3000 psi per AOGCC regulations. Record results. 18) PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 19) Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. Min FIT= 12.2pg. 20) Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming. 21) RU to run 5-1/2"slotted liner 22) PU and run 5-1/2"slotted liner to TD. 23) Land liner, set liner hanger with 200' Liner lap inside the 9-5/8" intermediate casing. POOH laying down DP as required. E51' 24) RU tubing running equipment and run 4-1/2"tubing. Land tubing. Set BPV 25) Nipple down BOP, nipple up tree and test void to 5000 psi for 10 min. rov • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). PPS • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 26) Pull BPV and set TWCV. 27) Fill tree with diesel and function valves. Test and chart tree to 500 psi for 5 min. Test and chart tree to 5000 psi for 15 min. 28) Pull TWCV. 29) Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 30) Set BPV and secure tree and wellhead. 31) RDMO AOGCC PERMIT Document.doc Page 8 of 9 Printed:27-Aug-13 eno• ChM Petirolleum Application for Permit to Drill SP08-N7 Saved:27-Aug-13 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 MC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point or Spy Island Class I disposal well. Alternative disposal method will include hauling the fluids to the Prudhoe Bay Grind and Inject Facility. 15. Attachments Attachment 1 Drilling Procedure Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 BOP and Diverter Configuration Attachment 5 Cement Loads and CemCADE Summary Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt Attachment 8 Casing Design Program • • AOGCC PERMIT Document.doc Page 9 of 9 Printed:27-Aug-13 witit era us amain WELL SP08-N7 Drilling Procedure SP08-N7 Spy Island Conductor slot #8 Reservoir location #N7 Producer (Schrader Bluff) Nikaitchuq Project M • en!' us oper fl9 � WELL SP22-FN1 Spy Island Nikaitchuq Field ani pctroleil SPO8_N7 North Slope - Alaska DIR/LWD FORMDEPTH HOLE CASING MUD INFO MWD MD TVD SIZE SPECS INFO Cement to Surface 20' Hole Angle �.'0 X-65 0: 20"Conductor Shoe 16'5' 160 Driven Welded NIA o GR/Res v 6urface Csg Dir/PWD i13-3/3' 0 68= 11';(ppg) '\r'etlbore Stabihb, Mud Motor B/Permafrost 2,000' 1,907 g _ • L-80,BTC 8.8-9.5 Lost Circulation u Hole Cleaning "' Casing Sections. KOP:' Casing Wear DLS: Surface T/Ta'Cement 2.119' 1,983' 0.3.5`/100' . 4. Hole Angle 30.42 Deg 13-3/8"Csg 2,623' 2,454' i 16" 50'F WBFI • • j GR/RES 1nil) • Inter.Casing Wellbore Stab'.,tY • • 9-5,l8' Lost Circulation Xceed 900 .•• • • . 40= MW(ppg) Hole Cleaning • L-80,Hydril 563 8.8-9.5 Torque&Drag • Casing Sections Tangent Angle: : Casing Wear r =DIY/01 Deg BHA Expense Intermediate TOC 5,653' 3,725' r Pldc-up Top Of Send ti Top 6,65' 3.594 .. Hole Angle 70_ 7,559 3.752' 86.50 Deg 9-5/8"Csg 5,034' 4,019' • IP 12.25 85'F WBIfl GR i RES I I I ADN1�� !PeriSCOPE {bl 1E1 Wellbore Stab,',ty I I Lost Circulation I I I Monti,'c I Monti,'r inry Hole Cleaning m 5-1,'2' Torque&Drag 15.5= MW(ppg) Casing Sectors Xceed 675 I I LSO.Hydril 521 8.7-9.4 Casing Wear I I BHA Expense I 1 I I Liner shoe TD 15.733 3.955 Hole Angle 92.81 Deg 3-3,,4' 85°F MO811 CO11 _ dd Q 0 C (0 .--0.m 0C.,0,117- A D00A20 N20f-m OAM V 107 1'NSA10 2‘,1221.12. 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U v i i it .� i o i ii i I Ili y > I 1 1 j, i10 1 N i l Fi W1 1 1 1 I I N11 F/ II w 1 1 1 1 1 1 N l l is i 1 1 1 1 1 1 li 1 1 F,1 1 1 1 1 1 1 ii 1 1 Iii t 1 1 1 1 1 ■11 iii co co er N M R 0)009:L=OleoS Gni jr-4811106* Schlumberger AP en El WELL SP08-N7 (P5) FIELD Nikaitchuq 5 RUG URE Spy Island Maps.Par-am/Awn Surfs.Laca5en NAD276lefaa 510le Pleir.Zen.04.US F.M 66sc.Ymws Want BGGM 2013 Dq'. 51045' DM. Sap9m6M24.2013 1H N 703326.126 NM., 605]656.605515 548 Cam'0.090' Slel SPO6 ND Ref Rotary Taa1N54.16a6999 MSU Mp O. 19.69, F5: 57531.5, Lon: W149 54 15 235 Ea4aq 511576.165515 Scale Fac[099900015 Pan' SPOSN7 TS/ 51W DMa:au9n227.2013 -4500 -3000 -1500 0 1500 3000 9000 9000 N and Cry Tgt14 4A, SP08-N7(P5) Cry 2/100 End Cry � ~ S Tgt 12 7500 End.Civ t....crv.21100 7500 Tgt 13 A . Cry 2/10 . End Cry End Cry ' Tgt 10 Tgt 11 ; Cry 2/100 Cry 2/100• End Cry :Tgt I End Cry : CIV 21100 Tgt 9 6000 Cry WOO 6000 End Cry Tgt 7 i. End CIN ' Cry 2/100 Elsd cry Tgt 5 Cry 2/100 Tg18 A Cry 21100 AEnd Cry End CryTgt 3 Z 4500 Tgt 4..... .. . ....Cry 21100 - 4500 Cry 2/100 OO End Cry End Cry Ln Tgt2 Cry 21100 Cry21100 it End Cry d 0) Tgt 1 RI Cry 21100 - End Cry U Heel 1n 3000 94/5-C=g 3000 cn v v v 1500 1500 ......../<) Cry 3.5/100 RTE 0 End Cry 0 Cry 1.5/100 Cry 2.5/100 —41 Cry 5 Cry 3.ry 3.5/10Q 13-3/8••Csg -1500 -1500 -4500 -3000 -1500 0 1500 3000 «< W Scale= 1:1500(ft) E >>> suiluireer SP08-N7(P5)Anti-Collision Summary Report en Analysis Date-24hr Time: August 27.2013-1520 Analysis Method: Normal Plane Client En Petroleum Reference Trajectory: SPO8-N7(P5)(Del Plan) Field: Nikaitehuq Depth Interval: Every 10.00 Measured Depth(ft) Structure: Spy Island Rule Set: 06M MliCollision Standard S002 v5.1/5.2 Slot 9708 Min Pts: All local minima indeafed. Wel: SP08-N7 Borehole: SPO8-N7 Offset Trajectories Summary Offset selection Crlerlq Wellhead 6stence scan: Not performed! Selection filen. Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Del Surveys when no Def-Survey is set in a borehole-Al Non-Def Plans when no Del-Plan.s set in a borehole Offset Tr*Jerdory Separalon Allow Sets Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(lD I EOU(Il Den (t) Fact Rule MD(ft) I TVD(S) Wert I Minor I Major SF05-RaP131(Def Survey) Fel Minor 3207 25,90 30.85 6.17 N/A MAS•7.89(.1) 0.48 0.48 CtCt<•15m415.00 Enter Hart 1 7 25,90 28.1 5,07) 18.59 MAS•7,89(m) 340,48 340.48 MinPts 31.02 25,901 28.1(4 511 1760 MAS•7.89(m) 360.45 360,45 MINPT-0-EOU 3654 25.90 3285 10,:.'MEE IMS•7.89(m) 479.04 478.97 Ming-OSF 47,79 25.90 43.59 21.89 15.67 MAS•7.89(m) 546.41 546.23 CtCt<015m>15,00 Exit Plert 373649 74.92 3686,21 3661. ®'= 05F 1.50 5958.39 3780.84 MnPt-O-SF 3618.26 73.11 3569.17 3545.11EOSF 1.50 6145.31 3813.47 1110/1-0-57 538.08 71.97 3489.74 3466,11 74..< OSF 1.50 676.74 3843.58 Mn740-SF 345112 66.01 3408.751 3387.11 79.74 0571.50 6783.34 511.34 Mn171-0-AOP r 1 4 55.841 3408.7513367.15 79.91 OSF 1.50 679157 391268 MnPla 774.59 233.55 618.56 541.03 4.99 OSF 1.50 1445.08 402316 OSF6.00 Orion Pen 260.21 26418 83.76 -397 1.48 OSF 1.50 15621.30 3974.43 OSF<1.50 Enter Minor 208.09 266.5 30.18 58.25 1.17 OSF 1.50 15738.22 396870 OSF05.00 05701.50 Exit Minor 1505275 26.80 15034.56 15025.95 874,58 OSF 1.50 863.08 59.48 MinP1-0SF 14495.5 2590 14478.54 14470. 57.99 MAS•7.89(m) 881.79 877.76 MnP1-0-SF 14094.35 25.90 14077.28 14068.45` 876.00 MAS•7.89(m) 85.41 891.04 Mn%-0S7 1382672 25.90 13808.92 1379881 874.72 MAS•7.89(m) 90285 898.29 Min-0-S7 13283.51 25.90 13287.33 13257.61B7(77 685.7.89(m) 920,5 915.03 MirA-0S7 12836.60 2690 12620.95 12810.7 MAS•7.89(.1) 936.80 931.30 Min-0-SF 12394.93 25.90 12379.5 12369.03 MAS•7.89 in.) 955.91 949.83 MM+t-0-SF 1212698 2690 12114.19 12103.08 878.64 MAS.7.89(.1) 968.14 961.67 Min-0SF 1180102 2690 1179168 1178212 MAS•7.89(m) 983.66 976.66 66in-CSF • 15881.33 51.43 7584872 15829.90 472.24 OSF 1.50 340893 3063.74 Mne1-0-SF S705F47 Mel&my) Fail Minor 3207 25.90 30.85 6.17 WA MAS•7.60(m) 0.48 0.48 MC1..1577415.00 Enter Not I 5.971 25.90 28.151 5.071 18.59 MAS•7.89(m) 346.48 34048 MinPts • 31.02 25.901 28.10) 5.11 17.60 MAS.7.89(m) 360.45 36045 MINPT-0-E0U 36.54 25.90 325 10.631 14.371 MAS•7.89(m) 479.04 478.97 MnP1-0S7 47.79 25.90 43.59 21.89 15.87 MAS•7.39(m) 546.41 548.23 CICt<•15m>15.00 Ext Alert 3736.49 74.92 586.21 3661. OSF 1.50 5958.39 3780.84 MinPt-0-SF 518.26 73.11 569.17 3545.1 057 1.50 6145.31 3813.47 MnRA-57 538.08 71.97 3469,74 345,11 74.0 OSF 1.50 6325.74 3843.98 11007-0-57 345112 66.01 3408. 3387.11 79,74 057 1.50 6783.34 3911.34 MnPt-0-ADP 1 345300' 5.811 3408. 3387.15 79.94 OSP 1.50 6793.57 391268 MinPts 774,59 233.56 618,56 541.03 4.99 OSF 1,50 14435.08 4023.26 05705.00 Enter Nen 260.21 264.18 83.76 -3.97 1.48 OSF 1.50 15621.30 3974.43 OSF<7.50 Enter Mina 208.09 26936 30.18 -58,28 1,17 OSF 1.50 15738.22 3968.70 09705.60 09701.50 Ext Mina 1850.38 34.79 18926.5 18915.591 840.790 OSF 1.50 75.47 763,62 MinP7-0-57 18001.68 3277 17979.50 17968.91 849.37 OSF 1.50 788.75 75.55 MinPt-O-SF 17799.25 3248 17777.26 17766.7N" 84759 OSF 7,50 793.04 79077 MinPt-0SF 17088.08 31.09 1705.03 17054.99 51.26 0371.50 810.5 87.79 MinPF0-SF 16325.80 2929 16305.95 16296.52 865.21 05F 1.50 826.64 823.78 Mer71-0S7 15933.32 28.48 15914.01 15901.5 860.28 OSF 1.50 837.5 834.28 MnP1-0-57 15694.48 28.02 15675.47 1566646 870.63 OSF 1.50 844.03 840.83 Min1-0S7 15404.72 27.50 15386.03 15377.21 871.25 OSF 7.50 5215 848.78 Min-0S7 1505275 26.80 15034.58 15025.5 874.59 0571.50 863.08 859.48 MnPI.0-SF 14495.96 25.90 14478.54 14470.06 881.99 MAS•7.60(m) 881.79 877.76 MinPt-0-57 14094.35 25.90 14077.28 14068.451 876.00 MAS•7.5(m) 85.41 891.04 MnP40-SF 13825.72 25.90 13808.92 13799.81 874.12 6565•7.89(m) 902.85 898.29 MinP7-0-SF 13283.51 25.90 13267.33 13257.61 874.07 MAS•7.89(m) 920.05 915.03 MnPt-0-SF 1283560 25.90 12820.5 1281070 875.23 MAS•7.89(m) 936.80 931.30 Ming-0-57 12394.93 25.90 12379.5 12360.03 879.62 PAPS.7.89(m) 955.91 949.83 MInPt-O-SF 12128.98 25.90 12114.19 12103.08 878,64 11445•7.89(m) 968.14 961.67 Min16-0.57 11808.02 25.90 11793.68 1178212 884.00 MAS•7.89(m) 983.66 97666 MinPI-0-SF 18987.49 46.05 18966.46 18941.44, 63200 OSF 1.50 3547.62 3150.53 Ming-0-SF 19046.02 46.19 19014.91 18999.84 631.99 OSF 7.50 3560.19 315207 16001-0-SF 20303.26 57.45 20264.63 20245,81 539.31 OSF 1.50 3615.06 3190.29 MinPl-O-SF 907-SE4(72)(Def Phn) Waning Alert 7.96 6.61 6.74 1.5 N/A MAS•202(m) 10.00 70.00 CtCt<•75m015.00 Enter Nerd I 7.581 6.61 4.80 0.971 4.08 MAO.2.02(m) 329.98 329.98 MinPts 7.67 6.611_ 4.73 1.06 3.75 MAS•202(m) 349.94 349.94 MINPT-0-EDU• 8.09 6.61 4.95 1.4819 MAS•202(m) 369.87 360.86 MinPt-O-SF 47.09 6.61 4279 40.48 14.90 1445.202(m) 583.48 583.18 CIC1<015m>15.00 Ext Nat 666.99 10.81 859.36 656.158 OSF 1.50 1150.73 1136.25 Min-0-SF 262635 92.59 2564.30 2531.77 42.99 05F 1.50 8773.93 4036.56 TD 1".......7 5.90 35.21 343.57 9.44 0571.50 5583.49 371267 MnPFCtct 409.51 66.021 35.171 343. 9.42 OSF 7.50 5586.25 3713.18 Mins 411.90 66.59 367.18 345.31 9. OSF 1.50 5597.64 3715.28 Min-O-SF 140237 106.17 1331.27 1296.21 19. OSF 1.50 7526.99 3984.65 MMPI-0-SF SX06N3(P2((Del Plan) Werr,.g Nen 7.99 6.63 6.76 1.5 N/A MAS•202(m) 0.00 0.00 CtCt4.15m<15.00 Ether Alert 7.94 6.63 5.47 1.301-07 MAS•202(m) 300.00 300.00 Min-O-SF 7.92 6. =LE 1.29 5.43 MAS•202(m) 309.99 309.99 MINPT-D-EOU 1 7.9211 6.63 5.4 MEE 5.47 M45.202(m) 319.98 319.98 Minns 10.20 6.63 7.50 3.:MIKE MAS.202(m) 549.76 549.57 MnPI-0-SF 1317 6.63 10.06 6.- MAS.202(m) 629.70 629.17 Min%-C-SF 48.87 9.80 41.93 39.97 8.33 OSF 1.50 1030.28 1021.55 CICI<.15m>15.00 Ed Nat 186.00 2237 170.68 163.63 13.11 057 1.50 1777.48 1705.41 McPt-0-SF 221.50 26.61 203.35 194. 13.01 OSF 1.50 1945.61 154.50 MinPt-0-SF 6348.71 144.97 6251.71 6203.73 66.1 OSF 1.50 704266 3942.75 MInPt-0S7 6305.92 129.74 6219.101 6176.18 73.45 OSF 1.50 7168.15 355.82 MinP1.0-40P 6306.27 728.971 6216961 6176.30 73.88 OSF 1.50 7175.21 3958.51 MINPT-O-EOU FA127.17 6219.53 6177.47 74.93 OSF 1.50 719268 3968.72 MnPt-CICt 281.91 4880.78 4787.13 27.06 OSF 1.50 13759.39 1020.89 M.0/t-73C1 5097.18 350.91 4862.91 4746.27 21.85 OSF 1.50 15738.22 3968.70 TD Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SP08-N7\SP08-N7\SP08-N7(P5) 8/27/2013 3:21 PM Page 1 of 12 0Irset Trajectory Separation Allow Sep. -- Controlling Reiterate*Traieetn.y Risk Level Alert Shuts Ct-C7(R)1 MAS lfq I EOU(M Dev.(R) Fact Ruh MD(R) I TVD(M Alert I Minor I Major 4007,01 11230 3931.81 3894.71 53.98 007 1.50 2270.10 2143.55 44in13-0.07 352619 81.57 3471.45 3444,62 65,69 OSF 1.50 2473.68 2324.18 Ming-O-SF 3476.40 73.20 3427.2 3403.19 7227 OSF 1.50 2520.37 2368.% Ming-0-ADP 3476.30 73.04 3427. 3403.21 72.38 OSF 1.50 2525.22 2369.40 MINPT-O•EOU MOE 7269 3127.38 340,50 7278 069 1.50 2527.78 2371.64 Mn171.00 INEEM 41.791 2394.311 2380.711 89.001 OSF 1.50 2638.27 246749 MnPls SP10FN5(Dot Survey) Warring AIM 15.93 12.99 1471 2.94 WA MAS•3.96(m) 0,18 018 CIG<•15m<15.00 Enter Alert MEM 72% 1477 WA MAS••3%(m) 41.0 41.00 Minh MIEE 1299 10,81 0.41 8.91 MA5.3.95(n8 330.02 330,02 Minh 13.42 12991 10,81 0.43 8.79 MAS•3.%(m) 339.98 339.97 MINPT-0-EOU 13.52 1299 10.89 0.531 8,751 MAS•3.96(m) 349.92 349.92 Ming-O-SF 48.85 1293 45.36 35.86 21.02 MAS•3.%(m) 574.18 573.92 41450.15.'15.0 Est Alert 4053,40 73.94 4003.75 3979, 83.4 069 1.50 6374.73 3851.46 448171-0-SF 3823.0 64.10 3779.911 3758. 50.95 069 1.50 6967.83 3936.57 MnR-0-ADP 382290 63.991 3779.MI 3758.91 91,11 069 1.50 6995.22 3937.44 MINPT-0-000 UK= 63.87 3779.92 3758.99 91.28 069 1.50 700280 3936.30 M81R-4141 259857 355.88 2360.99 224269 1058 007 1,50 15738.22 396670 TD 81086 61.42 9064.58 8044.43 201,15 OSF 1.50 4438,66 3506.78 Ming-0.SF 19803.11 30.96 1958214 1957.2150. OSF 1.50 74841 746,79 44in13•0-SF 1901.06 30.22 19010.60 1900.86 976.40 OSF 1.50 757.80 756,05 Min13-0SF 18117.21 2887 18097.64 18098.34 97453 007 1.50 774.09 77211M1/P1-0SF 1629842 26,37 16280.51 16272135!%2. 0SF 1.50 817.02 814.34 MinPS-0-SF 15841.56 25.75 15824.07 15815.81 959,35 057 1.50 827.61 824.74 Min13-0-SF 15023.26 24.59 15006.53 14998.66, 954.41 0.07 1.50 849.11 846.80 Ming-O-SF 14918.14 24.41 14901,51 14893.73\ 956.09 0.07 1.50 851.88 84851 441/71-0-SF 14298,78 21.64 1428269 14275,14 946.53 OSF 1.50 870.72 86894 MnR-0-SF 1312201 2223 1310686 13099.78 007 1.50 90833 904.60 MnR-O-69 12053.96 20,82 12019.75 12013,14 90.81 051 1.50 950,26 944.36 Ming-0-SF 2053284 58.04 204/182 20474.8 007 1.50 401689 3365,79 Ming-0-SF 5111-F66(P5)(Dar map) Warning Pier 24.01 19.45 2278 4.56 WA MAS•5.93(m) 0.00 00 CI00.15m015.0 Erten Ne MINIM 19.45 21.42 4,561 1668 ANS.5.93(m) 300.00 33100 MnPSe 24.02 19.451 21.39 4.57 16.30 MAS•5,%(m) 30,97 30,97 MINPT-0-EOU 2861 19.45 23.59 7.1•IMEInjE MAS•5,%(m) 49.39 43836 Ming-0.SF 31.62 19.45 28,26 12.1 inzE MAS•5,93(m) 518,53 518.41 Ming-0.SF 47.41 19,45 43.27 27.96 15,85 MAS•5.93(m) 625.26 624,78 CICI0.15m>75.0 Est Alert 449.66 19.45 441.93 43021 MEM MAS•5.93(m) 1213.29 1195.01 Ming-0.SF 4017.34 103,29 3948.15 3914..,11111.ZE 057 1.50 5981,93 3785,37 M1ng-0.SF 3568.09 76. MEMI MEMIIIE 70,79 007 1.50 686840 392227 Mir4s 76.33 351680 3491.68 71.02 097 1.50 6865,40 3924.38 M1/13-CtC1 1193.45 34642 96217 847.02 5.18 OSF 1,50 15738.22 3968,70TD 12155,35 27.30 12136,82 12128... OSF 1,50 951,03 945.74 MinR•0-SF 15639.52 49.28 15808.33 15790..4 NEM 007 1.50 3656.39 3213.72 MnR-0-SF 1635273 50.77 16318.56 16301,':= M OSF 1.50 3672.91 322289 M1/R•0SF 1729871 53,70 17260,58 17243,01 1mm 097 1.50 3706.22 3241.01 M1/R-OSF 17814.67 55.32 17777.47 17759. jam" 'C' 007 1.50 3725,78 3251.43 Mn13-0.$F 5506.64(P2)(Der Ren) Wamrq Alen 24.03 19.47 21,81 4,56 N/A MAS•5.%(m) 0,00 0.00 GCI0•15m075,0 Enter Alen 1 24.04 19.471 21.311 4.56' 15.28 MAS•5.93 5.) 40,31 40029 Minh 43.07 19.47 37.61 23.60 9.87 MAS•5,93(m) 954.19 948.17 148113-0SF 48.34 19.47 42.44 28.88 10.07 MAS•5,93(m) 1014,97 100684 CICt<.15m>15,0 Est Alen 437.57 28,49 418,17 409.08 24, 007 1.50 25505.39 235203 Mn13A-SF 1715,96 54,81 1679.09 1661.1 47, 007 1.50 279742 260229 MnR•0-SF 5219.92 140.0 5136.25 5089,91 56. OSP 1.50 6835.65 3918.15 1643-0-57 5106.63 110.13 5032 49%.50 70.17 069 1.50 7218.91 3960.68 Ming-O-ADP 5105.% 10.30) 5032 4996,66 70.70 007 1,50 7233.15 39620 MINPT-0.EOU 107.73 5033.24 4997,66 71.73 057 1,50 7261.66 3964.58 MnPI-CtCt 3879,3 288.28 7685,85 3590.0 47.21 0571.50 13940.34 4023.90 MMR-GCI 3895.95 325.6493678 3570.34 18.0 OSF 1.50 15026.39 4001.25 MINPT-0-E0U 3916.46 351,23 3681.98 3565.23 1877 0571,50 15738.22 3968.70 TD 3328.39 8287 327282 3245.'I jam.'. 0571.50 2406.83 2264,98 MnPI-0.SF 3279.62 81.67 3224.84 3197.•Imo-''.'-. 0.07 1.50 2627.05 2279.51 MnPI.0.51 3115.77 77.62 3063.40 3038.1• 0.07 1.50 267817 2328,17 1196.1-0.57 2804.75 68.72 2758,81 2736.. OSF 1.50 258/25 2425,16 Mn13-0.SF 240520 6241 236126 2342•MEM 007 1,50 2715.75 2533.66 MInR•0-SF 2347,27 60.83 230639 2286, ZIS 007 1,50 2736.98 2551.62 MnPt-0.SF 2335,19 6858 2234.47 2274,.. •1' 007 1,50 274213 2 .96 MnR-0.SF 2323.60 93.10 2783.20 2203,1=1M 097 1.50 2747.44 2560.44 88175-0.SF 279078 59.12 2251,04 2231,. 0.07 1.50 276840 2571.33 MnP5-0SF r..'9' 57.1•MI=ENILVEY111.11M OSF 1.50 2901.23 2605.46 MMR% 57125E3(72)(Der Pan) Warning Ake 32.04 25.87 30.81 6,16 WA MAS.7,89(m) 10.0 10.00 CICI0.15m<15,00 Enter AIM 1 3204 25,87 30.04 6.14 40.02 MAS•7.89(m) 20203 200.0 MinPts 3215 25.871 29.93 527 31.11 MAS.7.89(m) 240,0 2480 MINPT-0.EOU 40,27 25,57 37,18 14.v®' MM•7.89(m) 428,66 428.65 MnR-0-SF 48.67 25.87 45.26 2279 21,77 MAS.7,89(m) 487,19 487.12 C10<.1581>15.0 Est MM 687,81 25.87 679.59 661.947 MAS•7,89(m) 1143,31 1129.24 44nR-0-SF 1" "''0) 56,15 58298 564.93 17,14 007 1.50 4403,64 3499.67 MnR•CICt 620.22 55.381 582971 564 17.08 007 1.50 4403.80 3499970 MnR, 634,34 57,88 5%.43 576.4 15701 OSP 1.93 4405,68 3500.06 44n7-0-SF 3400.40 90.89 3337.48 3306.52 54.89 069 1.50 8649.60 4036.33 TD SPO4-SE5(72)(Der Ran) Warning AIM 3996 32.21 38.74 7.75 WA MAS•9.82(m) 100 10.00 CtCtc-151n.115.00 Enter NM 1 38,591 3221 35.29 6.381 17.95 MAS•9,82(m) 480.43 480.37 MnPts 38.61 32.211 3626 640 17.53 MAS.9.82(m) 490.38 490.30 MINPT-O-EOU 42.96 32.21 3803 10. 1111.1XE MAS•9.82(m) 588.82 568.49 MInR-O-SF i 4806 32.21 43.02 15.66 160 MAS•9.82(m) 627.38 626.86 CIG<•1511>15.00 Est Alert 2852.55 75.00 2802.21 2777.54 577 007 1.50 5204.25 3643.07 MInR-0SF 1823.81 88.77 1764.30 1735.03 31,15 0571.93 8732.42 4036.29 TD 239.08 7260 190,35 166.48 4,99 007 1.50 6873.95 397296 057,5,00 Enter Alert EMU 73.69 62.44 38.20 2.29 OSP 1.50 7103.04 3949.72 MOR-CIC] 11516 83.83 31.33 2.07 057 1.50 7143.66 3%3.38 MINPT-0.EOU 116.69 85.64- 59. 31.051, 205 0.SF 1.50 7151.97 3951.21 MnR-0-807 120.49 88.89 6890 31.591 2041 007 1.50 7168.76 3955.88 Ming-0-SF 324.18 98.32 258.31 225.86 4.98 0.07 1.50 7719,50 3996.42 007.15.00 Est AIM 57133-116(P2)(Dar PM) Warring Alrt 48.02 32.81 46.80 15.22 WA MAS•10.0(m) 0.00 0,0 CIG<.15n1015.0 Enter Al. 1 48.051 32.81 45. !MEE 43.82 MM•10.0(m) 250.0 250.00 MinPts 48.10 32.81 MEM, 15.29 38.53 MAS.10.0(m) 290.0 290.0 MINPT-0.EOU 48.15 32.81 45.67 15. EljE MAS.10.0(m) 30,0 30,0 Min13-0-SF 49.15 3281 1661 1635 3632 MAS•100(m) 461.01 460.96 G0<.15m.11500 Est AIM 80,96 3281 74,01 481 MAS•10.0(m) 10080nS 64 10 .75 MR-0F r1r"... 1 3281 314...J 25.95 MAS•10.031n) 263293 246290 Min% Drilling Office 2.6,1166.0 Nikaitchuq\Spy Island\SP08-N7\SPO8-N7\SP08-N7(P5) 8/27/2013 3:21 PM Page 2 of 12 Off set Trajectory Separation Allow Sap. Controlling Reference Trajectory Risk Level Alert SUNS Ct-Ct(81)1 TMAS(ft) EOU 1111_Dev.(R) Fact Md. MD(R) I TVD(R) Alert I Minor I Major 33072 3281, 31239 297.92 19.01 MAS•10.00(m) 2731.93 2547.36 MINPT-0-EOU 384.91 45.40 354.31 339.51 MI1M 051 1.50 2938.25 2717.43 Ming-0SF 4147.25 124.83 4063.70 4022.•. OSF 1.50 6544.39 3877.69 93n7-0-OF 1." 4 283.74 2482.81 238856 14.17 OSF 1.50 13825.64 4021.91 MnR-act 2673.25 286.7 11EMIE 2386.51 14.03 OSF 1.50 13925.59 4023.64 01571-0-EOU 2694.09 325.29 2478.90 2369.69 12.46 OSF 1.50 15075.46 4001.28 TO 66. 46.t 111111:E NM=MCM OSF 1.50 3207.33 2923.47 Minns 5114.486(P2)(Def%n) Wanting Alert 1 6259( 32.81 60.17 29.781 51.48 MAS-10.03(m) 39021 399.20 MinPls 62.59 33611 6017 29.79 50.97 MAS•1000(m) 409.14 409.12 MINPT-O-EOU 90.91 32.81 82.32 5811 IMIff.fi MAS=10.00(m) 1093.29 1081.79 MinRA-SF 116.00 3281 105.75 83..E 1111.1L MAS•10.00(01) 1359.94 1330.32 58n11-0SF 181.01 32.81 164.08 148.21 ME= MAS-70.00(m) 1918.81 1830.81 MinR-0SF 18392 3281 166.73 151.1.EINEM MAS-10.00(m) 194336 185296 MinPt-0-SF 427.96 6212 396.22 3E5. MODE OSF 1.50 431821 3481.18 Min4't-OSF 115.96 1107.59 1069.27 15.45 OSF 1.50 6628.49 4036.74 MER-CICt 1199.62 38184 958.73 838.78 5.00 0911.50 1514802 3996.72 05755.00 Enter Alert 120215 384.67 945.37 817.48 4.70 OSF 1.50 15734.80 396887 OSF•500 Eat Alen 3113FN4(Del Survey) Pan 1---"7 3281 53.96 2234 WA MAS=10.00(m) 41.00 41.00 MnPts 55.26 32811 53.89 2245 378.38 MAS-10.00(m) 70.09 70.09 MINPT-0-EOU 85.14 3281 78.77 5233 16.32 MAS=10.00(m) 563.27 563.04 M1nR-OSF 87.13 3281 80.65 54.334 16.32 MAS•10.00(m) 572.71 57245 Ming-0SF 4183.52 70.32 4138.28 4113.20 90.59 OSF 1.50 6770.96 3909.70 . Minn-05F 4051.81 64.28 4008611 3987.55 96.15 OSF 1.50 7122.22 3951.20 MinR-0-ADP 11. 64.181 400861 3987.58 56.27 0911.50 7128.77 3561.67 MERs IEME 21210 3806.51 3536.14 26.62 OSF 1.50 12095.20 4061.79 - MER-C10 286.51 3494.09 3398.91 19.36 OSF 1.50 13915.14 4023.48 MER-CICt 330.82 348266 3372.11 16.84 OSF 1.50 14979.52 4003.02 446R-CSCt 3567.20 36226 3425.37 3304.94 15.22 0911.50 15738.22 3968.70 TD 13869.76 73.86 13540.16 13815.', 0911.50 4757.57 3563.12 9861-0-SF 15558.98 79.99 15506.29 15478-- 05F1.50 4929.42 3593.83 9331.0-SF 12391.07 3281 12375.43 12358. MEM:"--, MAS•10.00(m) 928.70 923.44 hi R-OSF 11611.21 3289 11596.31 11578. Mina MAS-10.00 0) 961.57 9555.32 58n11-0SF 1146181 3281 11454.06 11436...1=1:1E'- MAO=10.00(m) 967.58 961.13 98661-0SF 20463.54 63.30 20440.99 20420.2=ME 091 1.50 4254.37 3464.86 MI,61-0SF S62-SE6(P2)(est Pin) Pass 1 55.9,E 3281 53. 23.141 7101 MAS•10.00(m) 200.00 203.00 MERs 56.20 32811 53.67 23.39 41.88 MAS•10.00(m) 289.99 289.99 MINPT.0-EOU 68.38 • 32.81 64.40 35. MIKE MAO-10.00(m) 558.25 558,03 MER-OSF 2669.11 82.83 2613.56 2586. NUM OSF 1.50 5311.11 3662.53 MER-0SF 2830.76 78.71 577.'.MEM1I 50.75 OSF 1.50 5606.08 3753.46 Ming-0ADP 2630.60 78. ME 255216 50.92 OSF 1.50 5828.41 3757.50 MINPT.0-EOU 78.18 - ..10 255237 51.10 ()SF 1.50 5850.81 3761.56 MnPI-CICt 88.90 69.16 789.46 766.74 1637 OSF 1.50 9003.62 4038.16 TD 551.77 10286 48287 448.91 8.111 0511.50 8787.98 406.66 MEPI-0SF 529.22 94.50 464.61433.72` 8.46 OSF 1.50 885215 4037.11 M4nPF0-ADP 527.61 93.791 464.7 433.83 8.51 ()SF 1.50 8858.32 4037.14 MINPT-0-EOU 91.57 466.35 435.16 8.71 0911.50 886151 4037.22 MER-CICt SP01-5E7(1,2)(De Ran) Pm 1 63.971 3281 60... 8.64 MAS•10.00(m) 400.76 400.75 MitRs 63.99 3181=Ma 31.18 34.27 MAS=10.00(m) 420.88 420.86 MINPT-O-EOU 74.48 3281 70.41 41.67 25.791 MAS•10.00(m) 629.37 628.84 M64'I-O-SF 2290.25 8026 2236.42 2209.99 43. OSF 1.50 5209.08 3643.94 58,61-0-SF 2260.21 78.591 2227.491 2201.62 44.05 OSF 1.50 5575.06 3711.12 MIME 78.22 2227.57 2201.82 4426 OSF 1.50 562308 3719.96 MER-CICt t 68.26 746.01J 716.92 13.82 0911.50 8905.89 40'37.48 MER-CICI 1 805.71 90.011 745. 715.70 13.56 OSF 1.50 8915.94 4037.55 MINPT-O-EOU 806.62 91.19 745. 715.431 1340 OSF 1.50 89228 4037.59 Ming-0-ADP 862.44 105.8 791.86 757.00 12381 OSF 1.50 8986.82 4038.03 Ming-0-SF 979.01 113.18 903.25 866.86 13.08 OSF 1.50 9005.17 4038.17 TD 2764.94 130.22 2677.80 2634.72 32 091 1.50 7021.18 3940.37 Ming-0-SF 2691.32 12421 2568.16 2527.06 32. 0511.50 7129.76 3961.97 MnR-O-SF 111111 3 1 113.81 908.811 871.36 13.1 OSF 1.50 90355.46 4038.17 MnPts 5515482(P2)(Def P4a) • Pm 71.18 32.81 8894 38.35 NIA MAO=10.00(m) 0.00 0.00 Surface A 32.81 j MEE 51.21 MAS-10.00(m) 300.00 300.00 MWIs 71.80 32.81 69.14 31.t mug MAS•10.00(m) 399.10 39908 Ming-0-SF 131.12 3281 123.25 9631 MEM MAO=10.00(m) 1085.06 1073.95 Mont-0-6F 193.10 3281 183.24 160.:NEM MAS-10.00(m) 1373.89 134299 MinP1-0SF 345.22 32.81 327.96 31241 1111111111RO MAS-10.00(m) 194210 1851.41 91n75-0-SF 718.14 15229 708.28 69&5.: OSF 1.50 6959.92 3933.35 94481-0-SF 7138.44 1521' I �': -- 70.79 OSF1.50 6998.71 8937.84 Minna Mrja= 152.18 7034.66 6984.26 70.79 OSF 1.50 7001.70 3938.17 MER-CICI 268.81 6071.58 5975.62 3264 OSF 1.50 13846.57 402227 MnR-C10 6265.07 290.79 5974.28 32.42 OSF 1.50 13908.55 4023.31 MINPT-0-EOU 6207.87 351.96 5972.91 5855.91 26.53 OSF 1.50 15686.73 3971.13 TD , 4608.26 128.40 452233 4479..rEWE OSF 1.50 2180.86 2063.14 Ming-0-6F 4346.89 9811 4281.15 4248. 67.1. OSF 1.50 2370.70 2233.12 MinR-0-SF 4316.70 88.85 4257.10 4227.. 7374 OSF 1.50 2407.03 2265.34 MER-0-ADP 4315.89 87.671 4258. 422802 74.56 OSF 1.50 2410.36 2268.29 MINPT.0-EOU MEM 86.15 4257.56 4229.20 76.06 OSF 1.50 2418.14 2273.40 MER-CICt NE= 32.611 2929.791 2918.631 142.731 MAO.10m(m) 2566.60 2405.49 Minna SP16-FN3 IDE Survey) Pass 4 32.81 M4,NEM WA IMS-10.00(m) 0.18 0.18 MinP1s 96.19 3281 9249 63.:MEM MAS=10.00(m) 460.23 460.18 MER-0-SF 105.46 3291 101.53 72,MOM MAS=10.00(m) 513.67 513.56 MER-O-SF 4459.64 73.81 4410.11 438.:4 Main OSF 1.50 6534.71 3876.24 98081-0-SF 4253.98 70.02 4206.98 4183.- M' OSF 1.50 6740.94 3605.68 MER-0-SF 4143.59 63.83 4100..'.=ZEE 99.33 OSF 1.50 7114.02 3950.36 MinR-0-ADP 4143.60 63. MEE 4079.97 9908 OSF 1.50 7119.79 3950.96 MINPT-0-EOU Man 63.33 4100.86 4080.11 99.60 OSF 1.50 7131.34 852.14 M9R-CICt '- 107.66 3884.23 3848.66 56.60 OSF 1.50 9132.50 4039.05 MinR-CICI 3958.78 115.7 3881. 3843.00 51.71 OSF 1.50 9372.77 4038.09 58581-0.605 3960.24 117.52 3881. 3842.74 50.96 OSF 1.50 9421.20 4037.43 Ming-0-ADP 4685.73 365.17 4441.96 4320.56 19.30 OSF 1.50 1573822 868.70 TD . 19688.14 32.81 19666.29 19655.33, 943.19 MAS=10.00(m) 743.29 741.73 MER-0-SF 18868.52 3281 18847.8 1888.71 98.90 MAS=10.00(m) 758.62 75626 MER-0SF 17923.30 3201 17903.08 17890.4 MAS•10.00(m) 775.47 773.47 MER-O-SF 14807.01 3281 14789.57 14774.20 899.97 MAS 630.00(m) 84874 845.44 Ming-0SF 13964.18 3281 13947.54 13931. 89282 MAS=10.03(m) 875.14 871.26 9869-0-5F 13351.10 3281 13335.09 13318.291 888.83 MAS 4 10.00(m) 896.05 893.62 Ming-0-SF 13126.71 3281 13110.93 13093.90 887.59 MAS•10.00(m) 904.06 899.47 (8011-0SF 1266892 3281 12853.69 12636.11 888.84 MAS•10.00(m) 921.42 916.36 MER-0-SF • Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SP08-N7\SP08-N7\SP08-N7(P5) 8/27/2013 3:21 PM Page 3 of 12 Offset Trajectory Separation Allow Sp. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(R)I MAS(ft)I EOU(ft) Den.(ft) Fact Rule MD(R) I TVD(R) Alert I Minor I Myor 12217.67 3281 1720295 12184.86 889.71 MAS.10.00(m) 939.77 934.18 Ming-0SF 11995.46 3281 11961.03 11962.13152. MAS.10.03(m) 949.18 943.31 145n1-04F 11788.50 3281 11754.31 11735.701 891. MAS•10.00(m) 960.33 951.11 84771-0SF 1133810 3281 1133239 11303.30 600.24 MAS•10.00(m) 98296 976.00 Ming-0-SF 32.811 2059.24 2035,91 250.43 MAS•10.00(m) 1480.17 1438.99 MirPts 5117-SE2(731(Dol Pmn) Pas 1-----R 3181 85.,=x.. 111.44 MAS.10.00(m) 203.00 21729.00 MinPts 87.17 32.81 54,36 91.96 8845.10.00(m) 230.00 230.00 MINPT•0.EOU 144.33 3281 139.82 111.'c MEM MAS.10.00(m) 63239 632.34 8401-0SF 476.31 3281 46820 443.'.I MAS•10.00(m) 101206 1004.0 MnPI-O-SF 89.40 100818 978.70 18.10 OSF 1.50 3631.03 3199.41 Ming-CIC{ 1068.22 89.':imEm 978.27 17.99 OSF 1.50 3633.71 320096 MINPT-3E0U 1068.41 90.21 1007.• 11111ZE 17.95 OSF 1.50 3635.06 3201.72 Ming-0-ADP 1085.42 93,63 102267 991.'MIKIM OSF 1.50 3657.42 3214.30 MinIt-O-SF 4336.37 64. llllll M:51/E 10257 OSF1.50 7166.70 395567 MiWls ing=K 64.29 4293.09 427201 10286 OSF 1.50 7178.26 3956.80 MnR-CICI ' 392291 99.10 3856.52 3923.82 59.96 OSF 1.50 8817.54 4036.87 TD • SP1 9N5(Del Survey) Pass NEM 3281 9303 62001 168.09 MAS.10.0(m) 170.23 170.23 MMI. 94.97 32811 6284 8216 103.72 MAS.10.00(m) 230.20 230.20MINPT-0-005 3281 101.81 74,911 2260 MAS•10.00(m) 844.62 841.47 Minns 107.75 32.811 101.79 74,94 72.50 MAS.70.00(m) 853.14 84975 MINPT-0-E0U 15281 3281 14232 120.01' MAS.1000(m) 150802 1465,0 MinP1-0SF 204.52 3281 189.70 171.71 11,6 MAS•10,00(m) 199254 1896.05 Mink.OSF 263.35 3291 24658 230.54 16,87 MAS•10.00(m) 2513.28 2368.95 MIR-0SF 216.44 32.81 248.67 23263 16.84 MAO.10.00(m) 2547.38 2388.76 f.6ng-0SF 276.77 3281 258.29 243.96' 15,76 MAS•10.00(m) 2688.82 2510.77 18871•0SF 710.02 38.30 684.16 671. 28.50 OSF 1.50 3758.01 3268.22 l,6n1't-O-SF 235345 79.06 230841 2274,38 45.19 05F 1.50 7119.17 7%0.89 6071.0SF Fq77.791 2277.24 2251.64 45,47 OSF 1.50 7496.23 398271 MMI. 79.14 2275.90 2249.65 44.68 OSF 1.50 7580.80 3967.95 MIR-Mt 232833 80,IIS:. 2249.29 44.18 05F 1.50 7610.72 3989,78 MINPT-0-EOU 2331.73 82.76 2276...I 4275 05F 1.50 7707.49 3996.69 MIR-0-ADP 2334.24 6.' 2248.27 41.18 OSF 1.50 783028 4003.18 MINPT-0-EOU 2335,35 87.33 7176.:. x.` 40.57 05F 1,50 788021 4006.23 MIR-0.ADP 2316.22 88.14 2277.1•111111aM 4019 OSF 1.50 7910.17 4006.06 MIR-0-ADP 2393.82 116. n-' 2277,06 31.03 057 1.50 8898.83 4037.43 MINPT-0.EOU 294.58 117.66 2315.:.MEKE 30.77 057 1.50 8928.75 4037.64 MirPl•0-ADP M=EC 220.08 2238.19 216,15 18.32 OSF 1.50 71870.75 4053.80 MMI-CIC{ NE= 233.39 2228.69 2149,23 15.37 OSF 1.50 12227.90 4050.30 MIR-CtCt 2386.57242•IlliQK 2144.31 14.83 OSF 1.50 12464206 4040.89 MINPT•0-EOU r---4 256.09 2215.80 213076 14.03 OSF 1.50 12840.81 4028.60 MIR-CICt 2388.29 262',•MlaIM 2125,31 13.67 OSF 1.50 13020.77 4026.92 MINPT-0-EOU 2388.64 263.36 2272 MEilM 1366 OSF 1.50 13030.77 4026.82 MinPl•0.ADP Man 306.60 2210.20 2108.33 11.6 OSF 1.50 14202.60 4028.40 MIR-CtCt 2371.78 388.01 211278 1983,77 9.19 057 1,50 15638,33 3973.60 TO •• 520022 44,33 5170.37 51%.•.MEE 0951.50 364261 3200.99 6071•0SF 9777.84 56.% 9740.15 9721,.== OSF 1.50 4074.25 3407.49 MMR-O-SF 0P10.1 6781(Dal Survey) Pew 3281 93. 62.001 168.09 MAS•10.93(m) 17023 170.23 Minns 94.97 32811 92 6216 103.72 8865.10.00(m) 230.20 230.20 5INPT.0.EOU • IIS 3281 101,81 74.941 7260 MAS.30.00(m) 844.62 841.41 MinPls 107.75 32811 101, 74.94 2250 MAS.10.03(m) 853.14 849.75 MINPT-0.EOU 15281 3281 14232 120.01=Ku MAS•10.00(m) 1509.02 1465.04 Ming-OSF 204.52 3281 189.70 171.71 IIIIIIIIIIIIjiLE.. MAS•10.60(m) 199254 1896.05 MinP1-0-SF 2638 32.81 246.58 270. ginam MAS.10.00(m) 2513.28 2358.56 9571.0SF 26.44 3281 248.67 232 v.MOM MAS.10.00(m) 2547.38 2388.76 MIR.0.5F 276.77 3287 258.29 243.'•IIIMIX6 MAS.10.00 On) 2688.82 2510.77 Ming-0-SF 71002 38.30 684.16 671. .11ME.'. 05F 1.50 3758,01 3268.22 MIR-0-SF 2353.45 79.06 2300.41 2274, OSF 1.50 7119.17 3950.89 MirR-0SF 77.' 45.47 OSF 1.50 7496.23 398271 MMIs 1= 79.14 2275.90 2249.85 44.68 OSF 1.50 7580.80 3987.95 MIR-C1C1 2729.33 60...M ]:. 2249.29 44.18 0571.50 7610.72 3969.78 M1NPT-0.EOU 2331.73 8276 2276.i.NEM 42.75 OSF 1.50 7707.49 3995.69 Ming-0-ADP 2334.24 85.' 2248.27 41.18 OSF 1.50 7830.28 4003.18 MINPT-0-EOU 2335.35 87.30 2276.:.M=.* 40.57 OSF 1.50 788021 4006.23 Mi1R-0.ADP 2336.22 88.14 2277.1•IIIA 40.19 OSF 1.50 7910.17 4008.06 1,6.71-0-407 2393.82 116. MICEr.s. 2277.06 31.00 OSF 1.50 8898.83 4037.43 MINPT-0•EOU 2394.56 117.08 2315."MEEE, 30.77 OSF 1.50 8928.75 4037.64 MIR-O-ADP 179.24 2269.57 2210.15 20.10 057 1.50 10748.39 4044.05 Men-0ICI 2389.98 180.x.M=ILE 2209.28 19.96 OSF 1.50 10787.37 4045.11 MINPT-0-500 I .q 20269 2256.08 2188.84 17.78 OSF 1.50 11406.86 4056.40 M#R•CICI 2392.42 249.35 2225,86 2143.08 14.44 OSF 1.50 11516.57 4055.94 TO 5445.66 44.27 5416.02 5401.'ER= OSF 1.50 3657.25 3214.21 34071-0-SF 5607.24 70.99 5809.58 5586..MEM OSF 1.50 4682.15 3549.6 84071-0.SF 5119.FN2(Del Survey) Paw 1 111.12' 32.81 109.89 78.311 WA MAS•10.00(m) 41.00 41.00 MinPt. 111.34 32.81 103.68 78.53 253.00 MAS•10.00(m) 160.45 160.45 MINPT-0-EOU 111.43 3281 109.67 7862 205.68 MAS.10.00(m) 160.45 190.45 MINPT.0-EOU 151.60 32.91 147.15 118.79 46.4 MAS.10.00(m) 647.00 646.36 88073-0-SF 4371.70 68.18 4325.89 4300.52 97. OSF 1.50 6922.52 3928.91 MinP1-0-SF 4194.94 62.701 415274 413224 10207 OSF 1.50 7283.78 3964.77 MnPt. 62.62 4152.83 4132.31 102.20 OSF 1.50 7269.69 3965.29 MIR-CtC1 MEM 75.57 4099.70 4074.86 8354 OSF 1.50 8086.63 4018.83 Men-CtCt 4160.6 76.451 4099. 4074.40 8249 OSF 1.50 9113.91 4020.50 MINPT-0-EOU 4151.13 76.76 4099. 4074.361 8215 OSF 1.50 812272 4021.0 • MIR-0-ADP 5913.89 366.38 5669.31 5547.51 24.27 0951.50 15738.22 3968.70 TD 17477.75 3281 17457.13 17444.' IIS MAS•10.00(m) 784.41 78226 6i071-0-SF • 16275.76 32.61 16256.31 16242-•=Te MAS•10.00(m) 812.85 810.25 64771-0-SF 14099.34 3281 14082.05 14066. �-- y MAS•10.03(m) 871.13 867.35 MIR-0•SF 13782.58 3287 13765.61 13749.• :/ MAS•10.00(m) 880.87 876.85 84n73-0-SF 13668.28 3281 13601,44 13635.:IIM M MAS.10.00(m) 885.02 880.90 68.07-0-SF 1326240 3281 13246.09 13229.:IIIIIIIIf MAS•10.03(m) 900.36 8%.86 Ming-OSF 1290217 3261 12886.29 12869.: Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(m 1 MAS 00 EOU(f) Dev.(ft) Fact Rule MD(ft) I TVD(ft) Alert I Minor I Major 20752.85 88.71 2164138 20664.14- 354.81 OSF 1.50 5301.64 3660.80 MinFl-0.5F 5426444(Del SMwy) Pass MIMI 32.81 117.91 88.34 N/A MAS•10.03(m) 0.11 0.11 MinRe 119.28 32.81 117, 88.47 328.85 MAS=10.03(m) 150.11 150.11 MINPT-O-EOU 145.97 3281 13670 113.17239711 MAS•10.00(m) 763.47 761.65 MinPl-OSF 231.66 3281 220.64 19686 MAS•10.00(m) 151825 1473.35 1N/P1-0.SF 282.55 3281 267.31 249.74 20.07 MAS•10.00(m) 2000.92 190526 14611OSF 4250.83 81.15 4196.40 4169.68 OSF 1.50 679208 391249 MnR-0-SF 4217.22 90.50 4163.22 4136,7254 OSF 1.50 6853.72 3920.42 Ming-0.SF 4015.35 77.69 396323 3937.66 78.50 OSF 1.50 7450.78 3979.64 66in-0SF • 4004.05 77.46 395208 3926,59 78.54 557 1,50 7505,36 3983,30 14in-0SF 1- 1 260.34 3533.30 3446.85 21.44 OSF 1.50 12981.00 4027.29 34679-CtCI 370803 26275 3531. 3445.28 21.24 OSF 1.50 13044.07 4026.70 MINPT-0-EOU 370902 263.90 35327 3445.121 21.16 OSF 1.50 13074.11 4026.42 MinRA-ADP ME 338.67 350258 3390.68 16.66 OSF 1.50 14995,14 4002.43 Ming-CICt 355,81 3458.89 3340.62 15.62 ()SF 1.50 15493.97 3980.68 Mr1R-C1C1 3898.74 394.39 3435.48 3304,35 14.10 OSF 1,50 75859.04 3972.58 70) 32.811 1649.971 1633,40 108.151 MAS•10.00(m) 3093.00 2838.42 MinRe 5126N4P611(Del SMsey) Paw 1 119.11 32.81 117. 88.341 N/A MAS•10.00(m) 0.11 0.11 MirPla 119.28 32.81 117.7 88.47 328.85 MAS•10.00(m) 150,11 150.11 MINPT-O-EOU 145.97 3281 13870 113.1 MEM MAS•1100(m) 763.47 761.65 66461-0SF 231.66 32.81 22164 198,:=NmELE MAS•10.00(m) 1518.25 1473.35 MnR-0.SF 28255 32.81 267,31 249.7 11111111SM MAS•10.00(m) 200292 190526 Min05F 1481.58 49.97 1447.94 7431.61 MOE OSF 1.50 3453.43 3091.95 141461-0-SF 5221-N1(P2)(DM Pin) Paw 127.08 32.87 125.86 94.27 WA MMS•10.00(m) 090 000 Surface 127.05 32.81 NEM 94.2 MIME MAS•10.00(m) 30000 20000 95909 1-� 3281 124.<miznE. 103.18 MAS•10.00(m) 309.84 309.84 AMP* 173.22 32.81 163.85 140.41 MEM MAS.10.00(m) 1081.38 7070.45 1140171-0-SF 436.89 33.27 414.31 403,.o,MES OSF 1.50 1948.23 7856.82 Min-0-SF 8887.39 157.23 858124 8530.1:MEM OSF 1.50 6597.73 3885.55 MrPt-0-3F 8416.57 15264 6314.48 8263,'.MEM, OSF 1.50 6784.96 3911.55 9i 11-0-SF 8280.99 150.07 6180.61 8130.91 MIMED OSF 1.50 690661 392698 18461-0SF 8257.01 149.64 8156.92 8107,3 OSF 1.50 6933.10 3930.18 14.90-0-SF 9232.84 749.2 8133.04 81183,0.Magi OSF 1.50 696223 3933.62 14n71-0-9F 8210.76 148.81 8111.23 8061.•-MIKE OSF 1.50 6991.57 3937.02 68in-0-SF 8124.37 147.72 802.56 7976.- MEM OSF 1.50 7171.18 3956.11 MinR-0SF 8117,23 142.88 ecal.,Wbrie. 85.80 OSF 1.50 7204.07 3959.28 Ming-0-40P 8114.93 140.'M=KE 7974.68 87.40 OSF 1.50 7219.27 3960.71 MINPT-O-EOU MOM 138.2 6321.70 7975,93 88.84 OSF 1.50 7231.95 3961,89 MnR-C1Ct wzia 290.53 7266.82 7170.30 38,65 OSF 1.50 13859.27 402249 MnR43C1 746673 322.4,MEME. 7144,31 34,84 OSF 7,50 1478230 4010.49 MINPT-O-EOU 7487,85 323,76 721..:MUM 34.70 OSF 1.50 1482225 4008.98 Ming-0-ADP 7590.50 356,2 734268 7224.2 3200 OSF 1.50 15738.22 3988.70 TD 5339.89 129,15 5253,46 521074( 62.481 OSF 1.50 2144.91 231,74 6649-0S7 506249 82.11 5037.411 4980.1 93.69 OSF 150 2341.56 2207.22 14671-0-ADP 5061,80 81161 5007.24 4980.54 94,66 OSF 1.50 234478 221007 MINPT-0-EOU 79.78 5007.78 4981.54 96.43 OSF 1.50 2350,31 221501 9..39-13C1 1 36.-:IIICilla MUM MEM. OSF 1.50 2508.92 2156,12 9TnRs 5P22-5741783(066 Survey) Pee 32.81 133.04152.141180.67 MAS.10,03(m) 202.04 20204 tarots 13507 32.811 132321 102.2 131.50 MAS•10.00(m) 26028 260.28 14167/0608 194.61 3281 190,02 761.80 57.45 MAS•10.00(6,) 671.20 670.38 66466P143-SF 447698 6674 443083 4401324 99.10 OSP 1.50 6627.14 3917.04 MiPt-0-SF 4288.59 63.221 424604 4225.37 10348 057 1.50 713827 3952.99 MnPle jam:, 6314 424813 4215.44 103.61 OSP 1.50 7144.78 3953.49 0in-C1C1 MEME 87.14 473.72 4105.01 72.97 OSP 1.50 8529.77 4037.29 66,R-C1C1 419153 88.271 413136 4104.27 7203 OSF 1.50 8562.31 4037.10 MINPT-0-E00 419278 88,56 413142! 4104.231 71.81 05F 1.50 8570.57 4037.06 912772-0-AOP 7303.59 363.25 7061,10 6940,35 30.24 0571.50 15738.22 3968.70 TO 16993.63 3281 1397242 16960,:0.jam- MAS•10.00(m) 797.97 795.62 6649-0SF 14381.89 32.81 14363.23 14349.x.MEE MAS•10.00(m) 871.19 867,40 66n71-0-SF 13957.61 32.81 1393939 13924.:r NE= MAS•10.00(m) 886.48 88233 MnR-0SF 13888.27 32.81 13870.10 13855,•:NEM MAS•10.00(m) 839.43 885.21 MnR-0-SF 13203.39 3281 1328117 13270.;MIM MAS•1900(m) 91285 90803 14n71-0-SF 13142.77 32.81 13125.77 13109': :2-r, MAS•10.00(m) 919.58 914.57 Ming-0-SF 12971.72 3281 1290608 12889,91 :fir MAS•10.00(m) 929.44 924.15 Ming-0-0F 11949.04 3281 11934.33 11916. MEM p MAS•10.00(m) 977.29 970.51 14i071-0-SF 11897.45 3281 11832.78 11864,.-IIMIC MAS=1900(m) 98016 973.28 Ming-0-SF 1182.37 32.81 11814.75 11796.s�-�•- MAS.1000(m) 984,41 977.39 Ming-0-SF • 11764.48 3281 11749.97 11731,. 1111111= MAS.10.03(m) 988.19 981.04 14nR-04F 1184879 3281 11634.42 11615.-: :®r MAS.1090(m) 993.59 986.25 Ming-0SF • 11598.85 3281 11574.54 11556.. M--�''.7 MAS•10.00(s) 996.18 968.75 AMR-0-SF 11445.02 3281 1143091 1141121 ELM MAS•10.00(m) 1003.32 995.63 44677-0SF 11327.04 3281 11313.08 11294.2 MaEC MAS•10.00(m) 1009.16 001.25 MnR-0-SF 1122561 3281 11211.78 11192.:.111111ME MAO.10.03(m) 1013.87 005.78 Mn71-0-SF 1109877 32.81 11065,09 11065,-.M1M, MAS•10,00(s) 1019.88 011.57 14n76-0.95 1104608 32.81 11034.46 11015. mum MAS.10.00(m) 10712 013.88 111171-0-SF 10971.18 3281 10968.36 10939,. MOE MAS•10,00(m) 1025.92 017.36 141471-0.SF 10838.64 3281 1082520 10805..0 Miail MAS•10.00(m) 103239 024.06 14149-0-SF 3181�i- ',MUM IIIIIIEMI MAS•1000(m) 1580.37 529.20 MnPls SP22-FN7(Der Savoy) Pass 1 134.94 32.81 133.01 102181 180.67 MAS•10.00(m) 202in 04 202.04 Ms 135.07 32.811 1328 102.26 1022 131.50 MAS.1000(0) 260.2 26028 MINPT-0-EOU 194.61 3281 190,02 161.80 57.45) MAS•10.00(in) 671.20 67038 MnRS -OF 4475.98 6874 4410.83 440824 997 OSF 1.50 6827.14 3917.04 Mn77-0-SF 42859 63.24 424604 4225.37 103.49 OSF 1.50 7139.77 3952.99 Mina M=IE 63.14 4246.13 4225.44 103.61 OSF 1.50 7144.78 3953.49 M.R-C1C! MEW 87.14 413172 4105.01 7297 OSF 1.50 852.77 4037.29 MnR-C1C1 4192.53 841.27r413'''1. 4104.27 7203 057 1,50 8562 -E 31 4037.10 MINPT-060U 419178 88.55 4131 4104.21 71.81 OSF 1.50 8570.57 4037.06 MnR-0-A0)P 703.59 363.25 7061.10 6340.35 30.24 OSF 1.50 15738.22 3968.70 TD • 20653.50 4285 23624.61. tup-10,65 739.88 OSF 1.50 704.28 703.16 Ming-0-A0)P 17007.76 3281 16986.36 16974.95`.02) MAS•10.00(m) 79898 796.61 48671-0SF 14381.89 3281 14363.23 14349,08 813,56 MAS.10.00(m) 871.19 867.40 Min-0SF 13957.61 32.81 13939.36 13924.80 808.25 MAS•10.00(m) 886.48 882.33 14071-0-5F 13888.27 32.81 13870.10 1365546' 807.95 MAS.10.00(6,) 889.43 885.21 14.71-0-56 13303.39 3281 13286.17 13270, BiB.90 MAS•10.00(6,) 91285 908,03 Mn71-0-SF 1314277 32.81 13125.77 131 09. 820,64 MAS=10.40(10) 919.58 914.57 14071-0-SF 12971,72 3281 1290608 12509,91 825.73 MAS•1000(m) 929.44 924.15 Ming-0SF 11949.04 3281 11934.33 1191623 MAS•10.00(s) 977.29 970.51 1467-0-SF 11397.45 3281 11882.75 11864, MAS•1900(m) 980.16 973.28 M1n71-0-SF 1182.37 3281 11814.78 11796.56 BW.6/ MAS=10.00(m) 984.41 977.39 MinP10SF 1 Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SP08-N7\SP08-N7\SP08-N7(P5) 8/27/2013 3:21 PM Page 5 of 12 Offset Trajectory Spratlat Allow Sp. Controlling Reference Trajectory Risk Level Alert Status Ct•Ct IMI MAS(M I EOU(M Dm IM Fact _ Rule MD(R) I TW 1R) Alert I Minot I Major 11754.48 3281 11749.97 11731.67 870. MAS•10.00(m) 988.19 981.04 Min111-03F 11648.79 32.81 11634.42 11615. 1 1570.11 MAS•10.00(m) 993.50 986.25 MinRA-SF 1158885 3281 11574.54 11556.04, 889.90 MAS•10.00(m) 99118 988.75 MinRASF 1144802 32.81 11430.91 1141221 87229 MAS•10.00(m) 1003.32 995.63 Mi FT-O-SF 11327.04 32.81 11313.08 11294.24 87224 MAS•10.00(m) 1009.16 1001.25 86nR-0SF 11715.61 3281 11211.78 11192.81 177.98 MAS•10.00(m) 1013.87 1005.78 MMR-O45F 11098.77 32.81 11086.09 11065,96 874.52 MAS•10.00(m) 1019.88 1011.57 Ming-0.4F 11048.08 3281 11034.46 11015.27 674.57 MAS•10.00(m) 102229 1013.88 Ming-0SF 10971.88 3281 10958.36 10939.07 875.03 MAS•10.00(m) 1025.92 1017.36 6611--041 10838.64 3281 10825.20 1080.5.8 MAS•10.00(m) 103189 102406 MiiPFO-SF 21994.88 100.03 21927.86 21894.8 OSF 1.50 5467.40 3691.28 Ming-O-OF SP22-FNIPB4(Dal Savoy) Pm ( 134.991 3281 133..•M.r :1'.� 180.67 MAS•10m(m) 202.04 202.04 MMR* 135.07 3281=OEM 102.26 131.50 MAS•10.00(m) 260.28 260.28 MINPT-0.25043 194.61 3281 190.02 161.81 57.451 MAS•10.00(m) 671.20 670.38 MMR-0.SF 4476.98 68.74 4430.83 4408.24 99.1 OSF 1.50 6827.14 3917.04 1.1045-0-SF 4288.59 63221 4246.091 4225.37 103.48 05F 1.50 7139.77 395299 M6R: M=E 6314 424613 4225.44 103.61 OSF 1.50 7144.78 395149 MMR-C1C1 =ME 87.14 413372 4105.08 7297 OSF 1.50 8529.17 4037.29 MM111-CtC1 ' 4192.53 86 4137. 4104.27 7203 0011.50 8562.31 4037.10 MINPT-0-EOU 419278 88.55 4133. 4104.231 71.81 OSF 1.50 8570.57 4037.06 MMR•0-ADP 7303.59 363.25 7067.10 6940.35 3124 OSF 1.50 15738.22 3964.70 TO 171107.78 32.81 1698536 13974. (jam MAS=10.00(m) 798.96 79661 MinR•O-SF 14381.89 3261 14363.23 14340.:=ME MAS•10.00(m) 871.19 867.40 546975041 1397.61 3281 13939,36 13924.:.ME= MAS•10.00(m) 886,48 882.33 Ming-06F 1388827 3281 13870.10 13856.-:�� 2 MAS•10.03(m) 839.43 885.21 MMR-0-5F 13303.39 32.81 13288.17 13270.<mum MAS•10.00(m) 912.85 908.03 MMR-O-SF 13142.77 3281 13125.77 13109. Mig= MAS•10.00(m) 919.58 914.57 MM1R-0SF 12922.72 32.81 12908.08 12889.91 IIMEM MAS•10.03(m) 929.44 924.15 M41R-OSF 11949.04 3281 11934.33 11916.a.=ILK: MAS•10.00(m) 977.29 970.51 M6g-0SF 11897.45 3281 1188278 11864..•O---•^, MAS•10.00(m) 960.16 973.28 Ming-0SF 11829.37 32.81 11814.78 11796.:(((( 4. MAS•1000(m) 984.11 977.39 1,6ng-0SF 11764.48 32.81 11749.97 11731.• Mill= MAS•10.00(m) 96619 981.04 MMR-08F 1164679 3281 11634.42 11615.•>MOE MAS•1000(m) 993.59 98625 54i978-0-SF 1158685 32.81 11574.54 11556.. •'••.• MAS•10.00(m) 99618 966675 MIN1-0.5F 11045.02 3281 11433.91 1141221 IMIEM MAS•10.00(m) 1003.32 995.63 Ming-04F 11327.04 3281 11313.06 11294.2 1111128M MAS•10.00(m) 1008.16 1001.25 1.5615041 11225.61 3281 11211.78 11192:.MEE MAS•10.00(m) 1013.87 1005.78 Ming-0-OF 1109677 3281 11085.09 11066.':MaKI, MAS•1000(m) 1019.88 1011.57 MMR00.SF 11048.06 3281 11034.46 11015. INNIMIFIA MAS•10.00(m) 1071.29 1013.88 MMPI-0-SF 10371.88 3281 10958.36 10939.• MOE MAS•10.00(m) 1025.92 1017.36 MMR-0.$F 10838.64 3281 10825.20 10805.:=111111=8 MAS•1000(m) 103289 1024.06 661-041 1 85., 20382. - 33354 NW= OSF1.50 5425.25 3683.50 Minna SP22-FN1P82(041 Survey) Par I I 134.991 3281 133..4 ME= 180.67 MAS•10.00(m) 20204 202.04 Ming* 135.07 3281 MEE= 10226 131.50 MAS•1000(m) 260.28 260.28 MINPT-0•EOU 194.81 3281 190.02 161.80 MAS.7000(m) 671.20 670.38 MMR-OSF 447696 68.74 443183 4408.2 99.1 OSF 1.50 6327.14 3917.04 Ming-0.OF 4288.59 63.221 4248.091 4225.37 103.48 OSF 1.50 7139.77 3952.99 MinPta (j(Z'lZ :. 63.14 4248.13 4225.44 103.61 OSF 1.50 7144.78 3953.49 MMR-Clot 87.14 4133.72 4105.01 72.97 051 1.50 8529.17 4037.29 546R•CICt 4192.53 88271 4133.314104.27 7203 OSF 1.50 8562.31 4037.10 M1NP7-0-EOU 4192.78 88.55 4133.4 4104.231 71.81 OSF 1,50 8570.57 4037.06 Ming-0-ADP 7303,59 363.25 7061.10 6940.35 30.24 OSF 1.50 15738.22 396970 TD 14278.54 3281 14260.44 14245.7-((((((0 MAS•10.00(m) 874.13 870.28 46M1R-0-0F 13535.37 3281 1817.96 13002.•MWECO MAS•10.00(m) 902.57 398.02 Ming-0•SF 1314277 3281 13125.77 13109.•: 820.. MAS•10.03(m) 919.58 914.57 61978-0-SF 1297272 3281 12906.08 12889.91(((((( MAS•10.00(m) 929.44 924.15 54801•0-SF 11949.04 3281 11934.33 11916.. 2 MAS•10.00(m) 977.29 970.51 MiN0-0•SF 11897.45 32.81 1188278 11564..•'�.---^, MAS•1000(m) 960.16 977.28 MMR-0SF 11829.37 32.81 11814.78 11796.:M•, MAS•70.00(m) 984.41 97739 M1ng-0SF 11764.48 32.81 11749.97 11731.6=LEM MAS•10.00(m) 988.19 981,04 8A6P1•0•SF • 11648.79 3281 11634.42 11615.•:)jifif J MAS•10.00(m) 993.59 96625 Ming-0SF 1158885 3281 11574.54 11556.. 11111=E MAS•10.00(m) 996.18 988.75 Ming-0SF 11445.02 3281 11430.91 11412.21(MIME MAS•10.00(m) 1003.32 995,63 Min101-0SF • 11327.04 32.81 11313.06 11294.2(((((()3 MAS•1000(m) 1009.16 1001.25 64801-0SF 11225.61 32.81 11211.78 11192.:.(j((M' MAS•1000(m) 1013.87 100578 MNI.O-SF 11098.77 32.81 11085,09 11065.':MIXEE MAS•10.00)m) 1019.88 1011.57 8Ang-0.SF 11048,03 3281 11034.48 11015.2 1111.EM MAS•10.00(m) 1072,29 1013.88 6611-0-SF 10971.88 3251 10758,36 10936.• immEMAS•10.00(m) 1025.92 1017.36 MinP1-0.5F 1088.643281 10825.20 10805.•11111M1g1 14AS 4 1600(m) 103289 1024.06 69801-0SF 1-, 3281 NESDEM==ja MAS•10.00(m) 1580.37 1529.20 Min.* SP22.FNIPB1(OM Swvey) Paw I 134.991 32.81 133 102181 180.67 MAS•10.00(m) 202.04 202 %MR* 18.07 32811 13284 04 10226 131.50 MAS•10.00(m) 260.28 260.28 M1NPT-0-EOU 194.61 3281 190.02 161. 57. MAS=10.00(m) 671.20 670.38 64nP1-0-SF 447596 68.74 4430.63 4408. 99.1 OSF 1.50 6827.14 3917.04 648P1-0-SF 4288.59 63.271 424609 4225.3 103.48 OSF 150 7139.77 395299 MMRa 63.14 4246.13 4225.44 103.61 OSF 150 7144.78 3953.49 M R-0ICI WOE 87.14 4133.72 4105.01 7297 OSF 1.50 8529.17 4037.29 MMR-C1C1 419253 88. 4133. 4104.27 72.03 OSF 1.50 8562.31 4037.10 MINPT-0.E0U 4192.78 88.55 4133. 4104.231 71.81 059 1.50 8570.57 4037.06 MMR-0-AOP 7303.59 363.25 7061.10 6940.35 30.24 051 1.50 1578.22 396870 TO i 12581.50 3281 12565.71 12548..-NUM MAS 4 10.00(m) 943.01 937.33 MR-0SF 12925.89 32.81 12011.09 11993..:MEM MAS.10.00(m) 972.12 965.52 Ming-0-SF 11957.8 32.81 1194263 11924.•(j((((am MAS•10.00(m) 976.32 939.57 MinR•O-SF ' 11897.41 3281 11882.74 11864.:. 54A0•10.00(m) 980.09 973.22 M6R-0-SF 11829.37 3281 11814.78 11796.:�-'<-r, MAS•10.00(m) 984.41 977.39 M'nR-0.SF 11764.48 3281 11749.97 11731.. .111:0 MAS•10.00(m) 988.19 981.04 MnR-O-SF 11648.79 3281 81634.42 11615.':=26111 MAS•10.00(m) 993.59 986.25 M:R-0-SF 11588.85 3281 11574.54 11556.. ( MAS•10.00(m) 996.18 988,75 MinR-0-SF • 11445.02 3281 11430.91 11412.21 MIME MAS 4 10.00(m) 1003,32 995.63 MIn101-0-SF 11327.04 32.81 11313.08 11294.2 IWOIEC MAS•10.00 08) 1009.16 001.25 54611-0-SF 11225.61 3287 11211.78 11192:.MEE MAS•10.00(m) 1013.87 005.78 6611•0•01 11098.77 3281 11085.09 1108.': MAS•10.00(m) 1019.88 011.57 MR-0-SF 11048.08 32.81 11034.46 11015. IIIEDM MAS•10.00(m) 102229 013.88 85971-0.SF ' 10971.88 3281 10958,36 10939.0(((((((31 MAS•10.00(m) 1025.92 017.36 54801-0-SF 10838.64 3281 10825.20 10805.: mixED MAS•10.00(m) 103289 024.06 MInR•0-SF 1 71 3181 IllEaM num MAS•10.00(m) 1580.37 529.20 MMR• 5P23443P81 foal Survey) Peso MIME 3981 140.38 110.031 115.04 MAO•10.00(m) 230.08 28.06 MRs 143.88 32911 139.26 111.07 41.97 MAS 4 10.00(m) 388.29 386.29 MINP7-0-E01.1 171.09 3281 154.27 18. MCC 4445 4 10.00(m) 90545 900.82 M1nR•0.5F 6866.99 110.77 679281 6756.,11111WID 00F 1.50 6276.43 383851 S6n1R-0-SF 6367.11 103.83 6297.56 6253.:�' -r•', OSF 1.50 6541.19 3877.21 54801•0•SF Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SP08-N7\SP08-N7\SP08-N7(P5) 8/27/2013 3:21 PM Page 6 of 12 Onset Trajectory Separation Mow Sep, Controlling Reference Tralsetory Risk Level AIM Status Cf-C1(R)I MAS(R)I EOU(M Das.IR)_Fact Rule MD(R) 1 TVD OR Alwt I MInor I M40r 5780.47 8295 572484 5697.51 105.76 OSF 1.50 7379.82 3974.41 610115-0-ADP 5780.3982871 572481 5697.52 105.87 OSF 1.50 7383.84 3974.72 MINPT-0-EOU 57803 8272 5724.86 5697.60 106.07 OSF1.50 7391,87 3975,34 M81PI-C7C1 5190.49 260.62 5016.41 4929.87 29,98 OSF 1.50 11846.39 4054.02 70 3459,07 46.98 3427.43 341209 11278 OSF 1,50 2459,04 2311.28 MnR-0SF 339670 46.11 3365,64 3350. OSF 1.50 2480.76 2330.40 Ming-0-SF • 3206.13 43.51 3176.76 3162 713.26 0571.50 2541.53 238169 Min15-0-SF 3742.56 4265 3113,77 3099.91 11133 OSF 1.50 256888 2398,77 74677-0SF r3111.12 4206 308272 3069.061 OSF 7.50 266608 2406,78 66ng-0SF 1 33.22 2356.481 2316.71 110.67 OSF 1.50 2723.83 256.51 MORS 5723.0(Del Survey) Pass lllllllll C 3291 140,38 170.031 115.04 MAS=16200(m) 230.08 230.08 Minns 143,88 32.811 139,26 111.07 41.97 MAS•70.00(m) 388.29 38629 MINP7-0-E0U 171,09 3281 15427 13628 10. MAS=10.00(m) 905,6 900.82 68int-0-SF 6866,99 11877 679281 6756. 9181 OSF 1.50 6276.43 3835.51 66int-0SF 6367.11 701.83 629756 6263. 92 OSF 1,50 6541.19 3877.21 MORA-SF 5780.47 8295 5724.8415697.51 105.76 OSF 1.50 7379.82 3974.41 MinR-0-ADP 5780.39 92871 572181 5697,52 105,87 OSF 1.50 7383.84 3974.72 MINP7-0-EOU mu••-- 82.72 5724.85 5697.60 106,07 OSF 1.50 7391,87 3975,34 Mint-CICI MOH 234,71 5007.41 4929.50 33,14 0571.50 12198.47 1050.84. MMR-C1Ct M., 279.95 4929.37 4836.38 27.50 0571.50 1342235 1023.34 MOR-C1C1 5117,70 283.r 11111ME 4834,68 27.21 OSF 1,50 13502.33 402267 MINPT-0-EOU 5124,99 293.•II= 4831,60 26.29 OSF 1.50 13777,59 4021.09 MINP7-0-EOU llllll�lj 370.39 4913.92 4810.78 24.82 OSF 1.50 14229.82 4028,59 91Ft-0101 5121.52 311.,MEM 4809,93 24.73 OSF 1,50 1426261 4029,6 MINPT-0-EOU 512217 31238 4913.: ":•--y- 2467 OSF 1.50 14284.6 4028,20 MOR-0-ADP MIMS 337.59 4889,98 4777.78 22.79 OSF 1.50 14947.52 4004.23 16R-CtCt MIME. 356.93 4868,93 4750.28 21.52 057 1.50 15447,68 3962.94 74672-C1Ct 5109.10 362•11 4746.80 21.21 OSF 7.50 15587.61 3976.08 MINPT-0-E0U 5111.87 47674 4792.38 4633.13 16.05 OSF 1.50 1567854 3971.63 71) 369.07 6.98 3427.43 3412•=NOM OSF 1.50 2455,04 2311,28 9.9.0-SF 339670 46.11 3365,64 3350.:•MEM OSF 1.50 248076 2330.40 MnR-0SF 3236,73 43,51 317676 3162e,MEM OSF 1.50 2541,53 238365 Ming-0-SF 314256 4269 311177 3099.91 1111111aM OSF 1.50 2558.88 239677 MOR-0SF 3111,12 42.06 309272 3069.,MEE!( 057 1.50 256808 240678 MnR-0-SF 1"9' 33 i-MEM IIMEMit MIEM OSF 1.50 272183 2540.51 MinPts SP24861(P2)pa Pan) Pep • MEIIEE 3281 149.13 118311 194.56 MAS•70,00(m) 200.00 20000 MnPts 151,22 32.811 149,06 118,41 161,14 MAS•10.00(m) 230.00 230.00 MINPT-0-200 26.50 32.81 240.34 21269`•F' MAS•10.00(m) 704,62 703,50 MnR-O-SF 721.6 7875.92 1775.78 2362 OSF 1.50 3137,60 2872.07 MnR-CICI ' 1897.42 122•-MUM 7775,37 23,50 0571.60 3142.25 2875.54 MINP7-O-EOU 1897,61 12227 1819, ME1U 23.6 OSF 1.50 3143,79 2876.69 MOR-0-93P 1931.41 127.76 1846.91 1803,1111111M OSF1.50 3193.22 2913,19 MOR-0SF 621.64 70,20 4774.52 4751,•`�• ,7:, OSF 1.50 6774.27 3910.14 91n91-0-SF 480.57 69.86 4753.66 4730.•lam- OSF 1.50 6790.81 3912.32 91,9-0SF 454298 61.10 4501.::M=41E 113,49 OSF 1.50 737290 3973.68 MnR-0-ADP 454294 61.. MEM 4481.90 113,80 OSF 1.50 7378.42 3974.31 MINPT-0-EOU 4542 9199 4501.92 4481.95 113.70 097 1.50 7383.95 3974,73 MnR-CICt MBt.S 10014 441747 4384.42 67.82 OSF 1.50 8933.39 637.67 M6R-CtCt 4485.00 101. 4416. 4363.26 66.75 05F 1,50 8971,70 4037,94 MINPT-0-EOU 4485.60 10248 4416. 4383.121 66.28 057 1,50 8968,99 4038.06 MinR-0-AOP 4518.38 108.75 4445.55 4409.63 6288 057 1,50 9093,78 403678 7D 1691,76 111,78 4616.92 4579.98 63,511 OSF 150 870020 405.33 88in7-0-SF 4546.50 109.86 447293 4436.64 62.65105F 1,50 9374,45 4039.65 119115-0-SF MEM 108.791 446.251 4410.31 6286 056 1.50 9093,16 4038.78 Minns 5125412(De(Survey) Peas 1 174.2.4 3281 173,06 141.421 44959337 MAS•10,00(m) 10.00 1000 MinPta 174.68 3281 172.75 141.85 25290 MAS•10,00(m) 200,00 20000 MINPT-0-EOU 212.19 3281 205.28 179_MEM MAS•10.00(m) 817,83 815.14 MinR-OSF 28393 3297 275,52 251.1.)E MAS•10.00(m) 1157.66 1142.78 Ming-O-SF 391,70 3281 380.15 358.-• firj:i MAS•10.00(m) 1474,43 1433.87 Ming-O-SF 56678 32.81 551,93 533,• =MU MAS•10,00(m) 1947.00 1955.73 Min9-0-SF 7367,02 11219 7291.91 7254, OSF 1.50 661008 3887,5 MOR-0-SF 1. 24221 6179,88 6099.47 39.43 OSP 1.50 12086,57 4051.87 MOR-CICI 6342.36 244. 6178. 6097,50 5,00 OSF 1.50 12756,56 4051.24 MINPT-0-EOU 6343.66 246.40 6179. 6097.771 38,77 OSF 1.50 12197.79 4050.85 Mi 391-0-ADP 634822 251.07 618051 6097.1_41 38.07 OSF 1.50 12327.03 406,64 M677-0-ADP 1-1 32262 5254.75 6177,54 5,31 OSF 1.50 14214,31 4028,51 44071-C1Ct 6501.00 325,4 6283,:: 6175,52 5.05 057 1,50 14292.27 4028,06 MINP7A-EOU 650239 327.17 628.'•MESE 2990 057 1.50 74336.63 4026.86 MOR-0-ADP ll� 36,09 6261,8 6146,19 28,06 OSF 1,50 74884.92 4006,61 Mon-0ICI 639254 428.24 610672 5964.5 2244 007 1.50 15719.54 398,66 TD 538153 608 5342.62 5322 057 1.50 7546.8 1856.63 M671-0-SF 1 5236,19 59.06 5796,49 5177,13 ,21 OSF1.50 1999.10 7901.87 M4R-0-SF 518,55 58,54 5749,19 5130.01 15.20 0571.50 2015,48 1916.41 MoR-0-SF 468,64 54.30 4624,8 4606.34` OSF 1.50 21528 2038,79 MOR-0-SF 2956,33 41,09 2928,58 2915.24 110.76 OSF 1.50 2460.57 231263 91n91-0SF llllllE 32.811 1940.64 1928.94 97.85 8645 4 10.00(m) 2627,6 2453.03 MORS 5326FN4(72)(Def PW) Pass 18219 3281 180,96 149,36 N/A MAS•10.00(m) 0.00 0.00 5urlaes I 182191 32.81 179.931149.381 13253 MAS=10.00(8,) 300,00 300.00 Minns 182.23 32811 179.581 149.8 126.61 MAS•70.00(91) 319.55 319.55 511672-0-605 29598 32.81 28.16 263.1 MEM, MAS=10.00(m) 918,03 913.06 MOR-O-SF 546,26 3281 537.99 513.•-MIE, MAS=10,00(m) 1190.73 1173,89 88n71-0-SF 1290218 86.71 12544.04 12615,4 MEM. 057 1.50 572210 366.30 91471-0-SF 469098 99.43 4624.5 4591. KI( OSF 1.50 625,11 3829.32 MOR-0-SF 3976.27 79.11 3923.21 3897.1 MM OSF 1.50 6967,8 392220 9.91-0-SF 3917.84 78.65 3869.06 3839,•MEC 057 7,50 7084,09 3947.23 1M71-0-SF 3915,69768 3862.93 3837,MEM OSF 1.50 7124,86 351,47 MinP1-0-SF 1 5. 78.'• 75.74 056 1.93 7738.38 3952 n 85 Mins Il '"1 136.32 3680.59 3635.48 41.80 OSF 1,50 9441,25 4037.16 M615-CICI 3773.96 142.161 578. 36315 8 0 40,00 0571.50 9549, 4075,67 114113P7 -EOU 3784.39 155,28 3680.54 36291 36,78 OSF 7,50 9744,59 4037.41 MinR-0-ADP 38042 344.44 3620.6 3505.98 16.81 OSF 1.50 1575.22 398.70 TD 1212609 5,14 12104.33 120921 53263 007 1.50 9188 913,8 MinR-0SF 1E. 65.731 19430231 19406, 451,17 OSF 1.50 4343.79 3487.12 Minns SF27-MI(Del Survey) Pass I 19(1251 7287 18.021 157.441 N/A 4445=10.00(m) 41,00 41,00 Minns 191.14 32811 18.71 156.33 158.04 MAS•10.00(m) 300.21 300.21 5I677-0-600 390.75 3281 375.8 357.• =FM MAS•1000(m) 1943.74 185285 Ming-0-SF 8287.66 9220 8225.8 8195,:MEM OSF 1.50 6663.17 383.52 MnR-0-SF 815.44 90.55 8075.74 8045...111111111= OSF 1.50 6701.26 3900.25 9677-04F 1 785.75 84.82 7773.86 7745.-,=KZ OSF 1.50 697232 3927.68 74677-0-SF Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SP0&N7\SP08-N7\SP0&N7(P5) 8/27/2013 3:21 PM Page 7 of 12 Offset Trajectory 9a aliD84, Allow Sap Controlling Reference Trajectory Risk Leval Alert 1� tos Ctyt 1111 MAS Ory EOU(ft) Day.(R) Fact Rule MO(It) I NO(M Alert I Mlnor I MO. 7380.0 130.42 729274 7249.59 85.51 OSF 1.50 942231 4037,41 M1I.-CICt 7380.45 131.x••MIE:In 7248.62 84.60 OSF 1.50 9482.17 4426.87 MINPT-0-EOL( 7381.01 13252 7292='MEM 84.16 OSF 1.50 948209 4426.60 MinPt-0.ADP Man 172.85 7196.11 7138,82 63.81 OSF 1.50 10628.57 4043.04 Mn.-C1C1 7311,84 173.:MEM 7138.26 63.54 OSF 1.50 10648.56 4043.14 MINPT-0-EOU 731213 173.95 7195..4 1MEIMEE 63.40 OSF 1.50 10668.55 4043.19 M8.-0-ADP 1/9=Z 221.37 7336.05 726252 50.93 OSF 1.50 11930.80 4053.26 M.Pt•C1C1 7484.52 223. 7261,27 50.50 057 1.50 11990.72 405281 MINPT-O-EOU 7485.49 224,38 7335. Wan 50.26 OSF 1.50 12010.84 405255 Mn.-0-ADP 7504.64 245. jpH 7252.27 4006 05F 1.50 12571.71 4036.38 MINPT-0-EOU 750653 247.63 7341.11 111Z11E 45.84 OSF 1.50 12631.62 4033.87 1401.-0-ADP 7717.44 381.78 7462.59 7335,66 3040 OSF 1.50 15738.22 3968.70 TD 967151 61.22 9631,37 9811..MI= OSF 1.50 1147.77 1133.45 MinP.-0SF 7386.71 54.42 7360.10 7332.:lMMEI"t OSF 1.50 1386.49 1354.41 M9.-0SF 8983.58 51.54 6848.90 6832.1 wig OSF 1.50 156.25 1519.21 M,R-0SF 6852.83 51.37 6818.30 6801, •MIMI OSF 1.50 1582.23 1530.87 Mm.-0SF 5840.62 46.30 580.42 5794. •Il{!{!f ( OSF 160 1968,00 1874.31 MinPt-0-SF 5440.69 41.36 541276 5399.a MME OSF 1.50 2074.22 1968.68 MinPt-0SF 5168.20 37.85 5142.61 5130. MillIELM OSF 1.50 2129.80 2018.25 Mn.-0-5F MEIZM 32.81 11.1aIM IIIMIIIE MAS=10.0(m) 2567.83 240.56 Minna 5228-FT17(P2)(04 FIRE P... 198.15 32.81 196.92 166.34 N/A MAS.10.00On) 0.00 0.03 5u5a0. MII1=1E 32.81 195.56 165.341 144.22 MAS=10.00(m) 30000 300.00 Min95. 19819 32.811 195.54 165.35 141.11 MAS.10.00(m) 30.75 30.75 MINPT-0-EOU 320.51 32.81 313.93 287.• ''�•.-'�1-• MAS.10.00(m) 928.71 921.50 Minn-0-5F 1393.02 90.76 1303218 13002,IMINEE 05F 1.50 5395.13 3677.95 139156.0-SF 4064.62 98.23 4888.81 4856.•MUD OSF 1.50 6430.6 3860.30 M569-O-SF 4723.25 77.33 4171.37 4145...NEM OSF1.50 6963.49 3933.77 MnPbQSF MIME 77 M=1E Eiraia 8080 OSF 1.50 7279.83 366.18 MnPts 4115.40 63 77.46 40 ,40 4037.' �- t• OSF 1.50 726.62 3966.6 Mol.-0-5F 1 90.54 405.89 3976.04 6810 OSF 1.50 8194.58 4025.42 Mn.-C1C1 4066.87 91.:I 3975,50 67.47 OSF 1.50 8231.6 4027.71 MINPT-O-E0U 4067.04 91.58 4005.•4 11111 . 67.32 OSF 1.50 8241.39 4028.28 Mn.-0-AOP 4067.48 9203 400.,,lllll „12 67,0 OSF 1.50 8260.25 4029.43 Ming-QADP 5158.83 347.87 4926.59 48106 2233 057 1.50 15738,22 3968.70 10 12686.94 47.81 1264.74 128.19.131/4408.3 OSF 1.50 899.69 86.21 MinP1-0-5F 17118.38 47.27 1218854 12171.11 356.97 OSF 1.50 918.113 913.27 1310P5-0.$F 10793.48 32.81 10775.89 1076.67 MAS.10.0(m) 96,28 978.23 Mn.-O-SF 10592.43 3281 10575.19 10559.67 MAS=10.0(m 6 ) 99237 9 .08 Min.-0•S9 1 32.81 1848411 1824.63 16.41 MAS=1000(m) 1719.61 1653.84 MOPts 62242(Def Survey) Pea MEM! 3281 244. 173.201 40.63 MAS=10,0(m) 150.0 150.08 MinPS. 20.11 32811 204.111173.30 264.38 MAS.10.0(m) 200.6 2006 MINPT-0-EOU 225.43 3281 221.89 192,llinZja 80.5=10.0(m) 48294 482.87 505.-0SF 235.76 32.81 232.13 201.,IIIIMUE MAS.10.0(5n) 537.42 537.26 Mn.-04F 297.91 32.81 293.44 26.11 Ifs MAS=1000(m) 720.75 719.46 69.-0SF 4778.39 65.36 473216 4711.• =Mal 05F1.50 70846 3945.17 MOR-0-SF 4714.07 64.52 4670.70 4649...1=110 OSF 1.50 710.73 3949,92 MnR•0-SF 4549.63 60.78 4508. �'..."`• 11426 007 1.50 7375.72 397410 Ming-0-ADP Ifs 60,7. 446.6 114,34 OSF 1.50 7360.34 3974.45 MOPIs 1132 67.85 448995 4467.69 101.85 057 1.50 785210 404.51 M71.-69 4535.62 68. 4489. 4467,54 101.51 OSF 1,50 7859.82 4004.99 MINPT-0-E0U 4535.79 68.30 440, 4467.491 101.17 OSF 1.50 7867.56 405.46 Ming-0-A0F 63012 147.43 6270.50 6221.6511 6.231 OSF 1,50 10299.89 4041.38 Mn.-0-SF 706.06 155.74 661.91 6930.32 68.67 OSF 1.50 10505.01 104242 10 4700.32 32.81 4688.61 4667.51 441. MAS=10.0 9..) 1330.58 130.53 Mn.-0SF 210.60 426.62 4216.95 31.68 OSP 1.50 2636.37 246.6 50sP5-CICI 4430,33 218.4:in=g1 4211,6 30.52 OSF 1.50 266.91 2491.21 MINPT-0-EOU 443238 221.16 42134.m.Ifs 3019 OSF 1.50 2675.6 2499.54 MnP1.0.DP 4770.19 264.26 45936 45070 AL OSF 1.50 2871.39 263.31 M9575-0.SF 8333.60 148.42 8234,32 8185.1:Il{!fW2& OSF 1.50 9383,42 4037,95 M1ng-0-SF 8105.37148.41 8206.10 816,-:Ifs OSF 1.50 9538.37 4035.83 Min.-0-5F 155.7•(,M , 007 1.50 10505.01 404242 66ng. SP30491PB1(Oa/Survey) Pas 1 213.191 3281 210.46 180.381 140.47 MAS 410,0(40 319.62 319.62 Mins 213.42 32.811 21029 180.61 111.82 MAS=10,0(m) 368.32 368.31 MINPT-0-E01J 253.22 3281 231.75 220.41 1245 MAS=40.0(m) 959,56 953.37 Ming-OSF 9834.83 102.57 9766.12 9732.26 145,21 OSF 1.50 6571,74 3881.75 Mo571•0SF 9148.70 92.48 9086.72 905621 749,97 OSF 1.50 676.57 3913.34 44nn78-0SF 9134,51 92.33 907263 904218 149.97 OSF 1.50 6804.36 3914.0 Mn.-0SF 8907.92 6,17 8850.81 8822757 158.71 OSF 1.50 7050.10 3943.57 MinPt-S-ASP 8907.91 05.161 8850.811 882275 15872 OSF 1.50 7050.53 3943.61 MINPT-0-EOU 1 6.06 8850.85 622.83 156 4. 92 OSF 1,50 7054.63 3906 Mn.-CtOt rr -8rl 170.95 526.17 8229.52 74.13 OSF 1.50 10380,52 4043.20 Min.-Clot 8401.12 1727:•'-`-Z•• 8226,36 73,35 OSF 1.50 10709.6 4043,46 MINPT-QEOU 8401.96 173.78 826. 5 7293 OSF 1,50 10737,21 4043.83 Min.-0-ADP 8407.79 178.66 8288.:(jjjjIE:XE 70.97 OSF 1.50 10875.64 4047,72 Mn.-0-ADP 0420,30 16.• (�'-..'r; 8220.34 6347 OSF1.50 11484.39 4056.16 MINPT-0-EOU 8421.52 201.44 826.•127M 63.01 OSF 1.50 11504.36 4056,99 6n.-0-ADP 8454.43 22210 836..41 57,35 OSF 1.50 12084.37 405206 M9575-0-ADP , 8893.0 316.45 861,71 646.55 3861 OSF 1.50 14466.27 402212 TD 7626,50 64.70 7583,02 7561.:,MEM 05F1.50 1502.6 1459,30 61,71-0-5F 712333 6.60 708259 762 OSF 1.50 1741,16 1673,0 MnPt-0-SF • 67540 56.53 6716.03 6697. •(E. OSF 1.50 1938,6 1848,36 60n.-0-SF 670,52 56.28 66626 6644.2-IIIKEDUOSF 1.50 19526 1860.42 16n135-0-5F6413.6 54.71 6376.86 6358.- (� OSF 1.50 4416.46 1977.28 60491-0SF 6305.15 5206 5270.0 6253,,IIIOSF 1.50 2047.47 194.85 Mn.-0•SF 622263 51.58 6187,89 8171.,NEM 087 1.50 2073.84 196.34 Min.•0-5F MICR 36. MEM NEM M1f./E OSF 1.50 2492.53 2340.75 Mn.s SP30-W1(DN Survey) Pa. • 1 213.191 3281 210.46 180.381 140.47 MAS.10.00(m) 319.52 319.62 MnPts 21142 32811 210.29 180.81 111.82 MAS.10.0(m) 368.32 36.31 MINPT-0-E0L( I 253.22 32.81 231.75 220.41 12.45 MAS 4 10.00(m) 959.56 953.37 Mn.-0-5F I 13393.91 126.01 1330.57 13267.90 1806 057 1.50 5973.19 3783.47 Mn.-0SF 12255.0 120.6 12174.01 12134.01 153.16 OSF 1.50 6170.46 3817.76 136n.-0SF 9834.83 102.57 976.12 9732.26 145.21 OSF 1.50 6571.74 3881.75 Min.-0-5F 914.70 9248 906.72 9056.22 149.97 OSF 1.50 676,57 3913.34 MmPt-0-SF 9134,51 92.33 907261 9042.18 149.97 OSF 1.50 6804.36 3914.09 MrPt-QSF •• 8907.92 8417 8850.811 67175 158,71 OSF 1.50 7050.10 3943.57 Min.-0-ADP 8907.91 6.161 8850.81 67275 15872 OSF 1.50 7050,53 3943,61 MINPT-0-EOU 6 66 6 .06 80. 2287 158.92 OSF 1.50 71)54.67 3944.06 . MnCICI l�'••c7 170.95 826.17 8729.52 74.13 OSF 1.50 10660.52 4043.20 MhR-CICI 8401.12 172.761 616, 8728.36 7335 OSF 1.50 1070.6 4043.46 MINPT-0•E06 8401.95 173.78 926. 82281 7293 OSF 1.50 10737.21 4043.83 MnP1-0-ADP 8407,79 178.6 8288. 8729.1 70.97 OSF 1.50 10875.64 4047.72 MinFI-0-ADP Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SP08-N7\SP08-N7\SP08-N7(P5) 8/27/2013 3:21 PM Page 8 of 12 Offset Trajectory Separation Allow Sap Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft) EOU Ift) Dear.(ft) Fact Rule MD(ft) I TVD(ft) Alert I Minor I Major 8420.30 199.97 8286.66 8220.34 63.47 OSF 150 11464.39 4056.16 MINPT-0-EOU 8421.52 201.44 8286.90 8220. 63.01 OSF 150 11504.8 4056.99 Ming-0-690 8454.43 22210 8306.03 8232 57.8 OSF 1.50 12064.37 405206 58001-0-ADP 8693.14 360.79 845229 63328 36.24 OSF 150 15738.22 3968.70 TD 11719.71 83.02 11664.04 11636.69) 214.28 OSF 1.50 7009.90 1001.96 MAR-0-5F 10939.21 81.30 10884.68 10857.91 204.30 OSF 1,50 1066.25 1066.00 54i491-0SF 1080257 80.26 10748.74 1072231 204.39 OSF 1.50 1078.36 1067.56 S6ng-0.SF 1039263 79.30 10339.43 10313.3 OSF 1.50 1112.77 1100.31 MInP1-04F 762650 64.70 7563.02 7561,8 OSF 150 150205 1459.30 Ming-04F 7123.33 60,60 7082.59 7062.74'= OSF 1.50 1741.16 1673.06 54,146-0.5F 6754.05 5653 6716.03 6697.53 18253 OSF 1.50 198.66 164136 Mn46-04F 6700.52 56.28 666266 6644,24 181.90 OSF 1.50 195255 1860.64 540491-0SF 6413.68 54.71 6376.86 6358,97 179,21 OSF 1.50 2016.46 1917.28 MinR-0SF 630615 52.06 6270.09 6253.3 OSF 1.50 2047.47 1944.85 Ming-0SF 621263 51.58 6187.89 6171.05 184.75 OSF 1.50 2073.84 1968.34 0646-04F l 36.753 1555.251 154.3.8 66.38 OSF 1.50 249253 2340.75 MinPls 5331-F102(P2)(DM Plan) Pan 230.23 3281 129.00 197.42 WA MAS•10.00(m) 0.00 0.00 S.e500 ( 230.1 3281 227...MEM 167,72 MAS•10.00(m) 300.00 303.00 Minns 230.24 3281 MOM 197.43 164.28 MAS•10.00(m) 30672 309.72 MINPT-O-EOU 36250 3281 35.8 329691 6698 MAS•10.00(111) 929.63 924.34 54001-0SF 603.75 3281 595.77 570.94 89.10 MAS•10.00(m) 1188.51 1171.80 0646-0SF 13454.63 97.36 1338940 13357. 69.42 OSF 1.50 5560.40 370934 064643-SF 546612 89.93 5407.84 5378.1 OSF 1.50 6604.34 3886.52 0646-04F 4291.34 7603 4238.96 4213.31 83.61 OSF 1.50 7277.18 3965.95 MinR-0SF 4266.25 73.67 4216. 4192.58 88.12 OSF 1.50 7378.71 3974.33 MinPI.0-413P 4266.03 73.411 4216. 419262 88.43 OSF 1.50 7383.48 3974.70 MINPT-0-E0U ME= 72.89 4216.88 4192.94 89.06 OSF 1.50 7392.99 3975.42 06nR-CICI MOE. 81.31 4199.54 4172.79 79.50 OSF 1.50 7816.01 400231 Mint-C1G 4254.79 83.'MEM MESM' 77.32 OSF 1.50 7854.20 4004.64 Mint, 661139 345.10 638299 6268.15 2882 950 1.50 15738.22 86870 TD 1226042 61.76 1221692 12198. SEEM 050 1.50 921.70 916.63 54049F6.0SF 11006.64 33.58 1098390 10973.0 507.:. OSF 1.50 983.66 97665 54001-0SF 1-- 32811 7927.701 1506.< 191.7 MAS•10.00(m) 169632 1630.36 58r.s 6132-W2(0e4 Sveey) Par 28.71 3281 236':Mg= WA MAS•10.00(n1) 41.00 41.00 MnPts 238.56 3281 27576 448.58 MA.S-10.00(111) 170.07 170.07 MINPT-O-E0U 238.94 3281)jam; 206.13 27230 MAS•10.00(m) 240.48 240.48 54I601-0.606 285.14 3281 278.65 252E7j MAS•10m(m) 853.15 850.06 Min1M-0.SF 36071 3281 372.36 347.91 MOH MAS•10.00(m) 1198.34 118102 3961-0SF 506.78 3281 495.45 473..>MEE MAS•10.00(m) 1540.24 1493.13 51948-0SF 660,51 3281 66341 636,.lam MAS•10.00(11) 1948.09 1856.70 03179-0-SF 13000,04 11139 1292612 12880.>-)jam 060 1.50 626982 3834.41 53001-0SF 12527.41 115.56 12450.04 12411,:..MIME OSF 1.50 683.87 3848,12 58146.0SF 1196239 110.14 11888.64 11852.•:=i1M OSF 1.50 6459.70 3864.82 MMI-0-SF 11823.48 10892 11750.54 11714,:lam OSF 1.50 6488.51 386925 MnR-0-SF 11529.11 10591 11458.17 11423,1'=am 000 150 6547.16 3878.10 MkA-0SF 10566.8 94.13 1050327 10472••MEM OSF 1.50 6797.05 3913.14 54001-0SF 8135.68 73.34 8086.46 8062.-MajZ, OSF 1.50 760108 3989.19 Mint-0SF • 9661.46 128,39 9575. MZMXI 113.74 OSF 1.50 9449.41 4037.04 Mi46-0-A90 9668.83 18.31 Ij 953152 107,96 OSF 150 9648.96 4034.32 MINP1'-0-E0U 9666.98136.60 9578.5•MUM 108.87 OSF 1.50 9688.90 4033.77 54i146-0-009 1- i 18004 9525.78 9466.10 60.80 050 1.50 10921.40 4049.07 Mon-CICI 964645 181.161 9525. 9465.28 80.30 OSF 1.50 10951.39 4049.95 MINPT-0-E06 9647.06 181.91 9525. 9466,11 79.97 OSF 1,50 10971.38 4050.54 54.1 6-0-000 1�9.. 207.93 9538.98 9470.00 70.14 OSF 1.50 11674.84 4055.27 MnR-CICI 9679,17 212.59 9537.30 9466,65 68.69 0501.50 11794.64 4054.48 MINPT.0-E0U 9680.09 213.45 9537.47 9466, 68.34 OSF 1.50 11824.83 4054.21 Mnt-0-40P 9714.78 28.14 95555.60 9476, 61.44 OSF 1.50 1248950 1039.83 54007-0.690 l 292.02 961261 9515,59 50.54 050 150 1391427 4023.51 061171-CIC1 9724.61 36972 9481.80 9363.89 40.54 OSF 1.50 1578.22 3968.70 TO 11637.36 76,81 1158583 11560.56 23021 OSF 1.50 1050.19 1040.64 615101-0-SF 10978.01 74.93 10927.73 10963.06 OSF 1.50 1108.77 1096.51 54I491-0-6F 1043056 71.68 108245 10358.88 221,28 OSF 1.50 1166,88 1151.47 011791-0SF 9760,18 66.90 9724.25 970228 22217 OSF 1.50 1243.50 1223.17 54.491-0-SF 9682.22 66.33 9637,67 9615.89 Z21.b OSF 1.50 1254.52 123342 54ing-0-5F 96035 65.94 9569.06 9537.11 221.73 OSF 1.50 1264.86 1243.00 06491-0.5F 9257.73 63.13 9215.31 9794.64 713.43 OSF 150 1313,82 128816 06491-0-SF 8810.28 59.90 8710.02 8750,34 724.19 OSF 1.50 138544 135146 06491-0-SF 8071.82 52.43 8036.54 8019.39 235,30 OSF 1.50 1745.52 167695 161W1-0-SF 778927 49.8 779603 778,3 OSF 1.50 188632 163206 06496-0-SF 7718.88 4893 7685.93 7660.95' 241.47 OSF 1.50 1924.51 188.68 54001-0-SF 7685.06 4871 735226 768,3 050 1,50 1944.07 1853.14 MM-0-SF 1• 7 32811 2023.451 2008903 118.59 MAS•10.00(m) 241226 2239.97 Minns 5033.603(Del 5Mvey) Pass 32.81 245, 213. WA 4445•70.00 511) 40.82 1682 Mints ..�'• 32.81 244.71 213. 545.26 MAS•10.00(m) 170.00 170.00 MinPls 246.50 32811 244.5 21169 35124 MAS•10.00(m) 219.94 219.94 MINPT-0-E0U 273.09 3281 2815 240, MEM MAS•10.00(m) 703.47 70236 MiFl-0.SF 370.30 3281 362.82 337.'NEM, MAS•10.00 511) 1099.73 1084.11 MnR-0-SF 57797 32.81 566,61 545.1>Man MAS•1600(18) 1609.05 1554.93 58,1M-0SF 614.88 32.81 601.79 582. =M- MAS•10.00(m) 1693.91 1630.89 06491-0.SF 68252 32.81 668.24 649.71 lei MAS•70,00(m) 1853.13 177264 MM1-0SF 722.77 3281 707.47 669.'.)jam MAS•10.00(m) 194.5.06 1854.02 4461-0SF 777.03 3281 711.66 664,MallE MAS•10.00(m) 1951.27 1859,51 MMI-0-SF 14761.96 141.28 14667.45 1462(1.•:=OE 05F1.50 6236.64 3818.90 54000.0SF 14518.16 139,45 14424.87 14378. - 7El OSF 1.50 6273.88 3835.08 0646-0-5F 1418,22 136.8 1404503 13999, •IN= OSF 1.50 6329,53 3844.19 51160-0-SF 182916 133,92 1378,58 13686.2 11111,12E OSF 1.50 6377.28 3851,87 54601-0-5F 13505,87 131.19 13418.08 13374...111.1aUE OSF 1.50 6426.13 3859.59 54001-0-SF 13366,34 129.48 13268.69 13225::11111111= OSF 150 6450.93 3863.46 54681-0SF 13198.53 728.79 13112.74 73070. IMEEE OSF 1.50 6477.50 3867.56 54001-0.5F 13018.06 128.31 1298.53 12891. Ij OSF 1.60 6500.32 87242 M00t-0-SF 1284219 124.47 1275889 12717, 'MEE 050 1.50 654232 3877.38 M00t-OSF 11561.25 105.85 11490.35 11455..�.'-�,-, OSF 1.60 6890.16 3924.97 MPPI-0.3F • 10813,89 153.1.ELME 10660.79 106.63 OSF 1.50 9946.18 4036.40 MINPT-0.E0U 10815.42 154.93 10711.81 lam-". C- 105.37 OSF 1.50 9996.23 4037.20 Ming-0•AOP .�. .T, 204.97 10605.87 10597.87 79.43 OSF 1.50 11363.06 40556.59 MnR-CICI i .ia=lEi 221.81 10053.59 10579,98 73,37 OSF 150 11824,73 4054.21 MnR-GCI 10806.23 234.x•) 10572.20 69.55 OSF 1,50 12154.68 4051,25 MINPT-0.EOU 10808.63 236.87 10651 4 MIEMBE 68.71 OSF 1,50 1228.28 4050.17 Ming-0-690 11 289.90 1064229 10545.98 56.25 OSF 1.50 1364248 4021.49 MnPI-GC1 1081845 301•>ME= 10539,79 54.26 OSF 150 13926.76 4023.66 MINPT-0-EOU 1084220 30276 10640..c II= 53.89 OSF 1.50 13981.16 4024.60 M1ng-0-ADP 1035224 313,.:ELMS/ 10539.19 52.16 OSF 1.60 1425202 4028.56 MINPT-0-EOU 111358.03 319.58 10644.. jam, 5112 OSF 1.50 14426.78 4023.57 S8ng-0-ADP Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SP08-N7\SP08-N7\SP08-N7(P5) 8/27/2013 3:21 PM Page 9 of 12 Offset Trajectory Separation Abw Sp. Controlling ReterenC.Trigectory Risk levet Alert Status CtCt(try I MAS(ft) EOU ffti D.s.DT) Fact. Rule MD(8) ( TVD UH Alert I Minor ( Major 10879,89 350.73 10646.71 1052115 4696 OSF 1,50 15237.03 39913 MINPT-0-EOU 10881,22 35233 1064.00 10528.88' 46.45 OSF 1.50 15279.25 3991.20 13nP1-0-ADP 363.79 111645.86 10519.92 44.99 OSF 1,50 15579.14 3976.50 88881-0101 1068172 369.81 10636.65 10513,91 44.26 OSF 1.50 15738.22 3968,70 TD 12710,32 96.82 1264544 12613.•=EL OSF 1.50 1026.36 1017.79 Ming-0-SF 12430.11 96.31 12366.25 12334.81 IIIIIMM OSF 1.50 1047.39 103716 60ng-0-SF 72294.24 94.22 12231.10 12200.•r.IMUK. OSF 1.50 1057.79 1047,92 1•10161•0-OF 11993,70 42.71 11931.57 11900.'<M OSF 7.50 1080.06 1059.19 Ming-0SF 1163288 90.83 11572.01 11542.4 ME261 OSF 1,50 1111.48 7099.09 Ming-0-SF 11278.21 8840 11218.81 11189.61 OSF 1.50 119197 1136.47 456 1-0-SF 10924,66 8611 106E693 10838,':EMEDM OSF 1.50 1190.15 11718 M4911-0-SF 10717.50 84.60 10660.78 10632'• OSF 1,50 1217.57 1199.01 46g-0SF 10697.08 84.40 1063649 10608.:=man OSF 1.50 1220.74 1201.97 Ming-0SF 10637.50 83.68 10551.8 10523.81 MM.. OSF 1,50 123200 121248 10ng-0SF 1051228 83,10 10456.56 10429,1:MEM OSF 1,50 1244.95 1224.53 Ming-0SF 1025257 81.21 1079610 10171..man OSF 1,50 1284.50 1261,16 4nR-0SF 98655,8 76.96 9813,72 9788,4 MI= OSF 1.50 181.04 132221 8i881-0SF 9769.97 76.23 9718,82 9693.7 111.121I OSF 7.50 1366.65 133641 9i881-0-OF 9703,43 75.73 94.261 9627.•MIME OSF 1,50 1379.00 1347.62 410001-0SF 889,79 66,34 8866.23 8833, OSF 1.50 160699 1731.66 118881-0-SF MID:= 32.81 Mr=ELMEMAS=1044(m) 233.95 2253.75 Mins S%34.FN1(P2)(064 Plan) Pas. 254,27 32.81 25304 221.46 714. MAS=/0.00(44) 04.0 0.00 Steac. 254.271 32.81 257.=.'s 18532 MAS•10.00(m) 300,00 30000 66,77s 254.28 3281 1111110/5-y 221.47 181,94 MAS•1100(m) 30969 30989 MINPT-0•EOU 391.78 3281 38544 358.• =KU MAS•10.00(m) 929.59 924.30 MinPSO-SF 631.47 3281 623.65 598... MAS•1600(m) 119198 1176.94 Min-0SF 1398257 104.01 1391290 1878,c==js OSF 1.50 575.06 3735.57 14411.1-0-SF 570679 88.29 5649.60 5620.-•Q OSF 1.50 6668,87 3895,74 • 84887-0-SF 4481.80 76.8 443055 4406.--=CM OSF 1.50 7326.14 3970.12 MnR-0-SF 4438.27 70.08 4381,1• 96.44 OSF 1.50 7464.59 398059 8i777-0.807 448,12 69.::�•' 1 4368.23 96.72 OSF 1.50 7468.70 3980.87 MINPT-0-EOU 69,48 4391.34 4368.54 97.29 OSF 7,50 747686 3981.43 MnR-CICt rf '�"•7! 73.49 438149 43623 91.85 OSF 1.50 766250 892.94 66,71-0101 j 4436,37 75. 4366.07 4361,8 89,97 OSF 1.50 7690.07 3994.62 MINPT-0-EOU 4437,33 76.19 43861 4361,14 88,56 OSF 1,50 7711.16 895.91 Min-0•ADP 5168,76 15610 5064.3 501265 49,91 OSF 1.50 978,04 4033,40 84881•0-SF 7858,78 344.01 7629.11 7514,76 34,36 OSF 1,50 1578,72 3968.70 TD 16088,20 6326 1603236 16004.94, 5328 OSF 1.50 801.67 799.26 Ming-0SF 12588.85 73.21 1253,72 12515.64 281,44 OSF 1,50 91699 914.00 Ming-0SF 11367.19 3281 11345.88 17334,38• 561,68 MAS•10.00(44) 984.92 977.89 Min01-0•SF 10244,56 3281 102265 10271.75 67146 MAS.104.0(44) 1034,60 1025,70 4In71-0-SF �' ' 32811 1896.34 1877,51_ 177,50 MAS•10.00(m) 1715.44 1660.11 MinPl, 5135W4(P7)(0.1 Plan) Pass 26227 3281 261.04 25,46 WA MAS.10.00(.) 0.00 0.00 Surface 262271 3281 260,27 25,461 338,81 MAS•10.00(m) 20000 200.00 Mins 26239 3281) 50.16 25.58 260.90 MAS•10.00(44) 27400 270.00 MINPT-0-EOU 26252 3281 50.18 23.77 MAS•10.00(96 59.99 299.99 Ming-0-SF 437,19 3281 42262 404,8 3266 MAS.10.00(m) 1231.54 121205 Min71-0-SF 84268 8,16 818,17 806, 8,13 OSF 1.50 1944,09 1853,16 Min144-0-SF 13416,73 137.94 13324,44 13278.7E . OSF 1,50 6710.95 3901,55 Min-0SF 13197.04 18,32 1310650 13067,7 066 1,50 6766,66 390913 8in-0SF 12678,74 13382 12589,20 12544.90 066 1.50 695,67 3929,79 58nP1-0SF 1219259 9259 1213054 121000 OSF 1.50 7153.63 854.8 Min-0-SF 9644.37 89,83 9784,16 9754,7 066 1,50 7840,21 4003,79 7#nR-0-SF 9881,42 90.16 9820,99 9791,- 166,20 OSF 1.50 7853,19 4004,58 M6Pt-0-SF 10273.87 93.79 10211,02 10180.04 766,04 OSF 1,50 799462 401297 Ming-0-SF • 10886.27 97,48 10620,95 10688.79 166,10 OSF 1.50 8137,19 4021.92 MnR•0-SF C' 195,67 1179994 1178,05 91,92 OSF 1,50 11193,64 4056,79 46.911-CMCt 1198.27 21293 1177134 84.46 0SF 1,50 11530,47 405688 MINPT-0-EOU 11977.57 32944 11757,62 11648.14 54.70 OSF 1,50 1578.22 3968.70 TD 74616,27 17297 7450462 14443,-�l OSF 1.50 966.61 960,19 MnR-0-SF 14568.45 172.41 14453.19 14396,• X1 OSF 1,50 969.36 96285 MIR-0-SF 13750,93 16290 1364203 13588,•4 IMIEgiE OSF1.50 1014,11 100602 Min.0-SF 1347246 159.25 13366,97 1813.21 EfflEffla OSF 1.50 108.30 1024,45 Ming-0SF 13441.90 158.90 1338,64 1353,01 Mil1Fig OSF 1.50 1035.49 1026,56 MnR-0-SF 12978.02 15281 12875,62 72825,21 MEN OSF 1.50 1072.19 1061,68 MIR-0-SF 12293.28 142.94 12197,66 12150..M`'. OSF1,50 1137,16 1123,43 88nR-0-SF 12258,16 142.54 1216281 12115,,7. OSF 1.50 1140,91 115,98 AMMO-SF 11661.34 133,47 1157203 11527.:MINOM OSF 1,50 1209.21 1191.20 1.91911-0SF 11607,39 13286 115164 11474. •MIMI OSF 1.50 1215.21 1196.81 Min-04F 11560.75 1328 114725 1145.-.MDL OSF 1,50 1221,00 120222 M4n111-0-SF 1158,56 127.20 11124,43 11082-�".' 066 1.50 1273.55 1251.04 8,1111-0SF i 10880.30 122.73 10796.16 10757.:=j1gla 05F 1.50 1334.77 1307,36 Mi F1.0-SF 998,97 116.12 9861.22 98221-MEM OSF 1.50 1804,76 773,68 8I71-0-SF 9217,17 67.72 9171.69 9149, OSF 1.50 2031,96 1931,06 MnR-0-SF , 4.'c MIEME ME:REEIMUE OSF 1.50 2294.13 2764.98 MinPls SP360/45(Dar Sway) Fac. 3287 260.1•® N/A MAS•10.00(m) 41.00 41,00 MInRs 270,373281 E"jjy."•p 237,56 3958.95 MAS•10,00(m) 60.43 60.43 MINPT-0-EOU 926' 3281 260. MEME 323.69 MAO.10.00(44) 230,40 230,40 118067. 271,33 3261 MEM 23652 56.04 MAO•10.00)44) 250.8 250,8 MINPT-0-EOU 401.96 3281 39290 369.7 MIME MAS.10.00(44) 924.84 919.69 Min-0-SF 720,56 3281 7095 687,'MM, MAS•10.00(m) 155214 1503.83 Min111.0-SF 785.59 3281 772.25 752:�L• MAO•10,00(m) 1642.23 1584,66 M4i1•0-SF 98.46 3281 918.38 900..-INE3EE 845.10.00 On) 1838.51 1759,66 M881-0-SF 1024,04 3281 1007,56 991,aMIIME MAO•10,00(m) 1942.77 1851,99 8.881-04F 1759618 50.66 17455,41 17445.5.=ID.. OSF 1.50 6253.25 831,67 19M1-0-SF 1753279 50,12 174328 17382. MIME OSF 1.50 6259,19 383266 66,71-0SF 17274.59 47.92 17175.95 17126.6 =KU OSF 1.50 628.52 83700 8in-0SF 1696023 45.26 1686106 16814. MIKE OSF 1,50 6321.79 3842.93 Ming-0SF 16714,79 43.49 16678,81 19571,•=j12E OSF 1.50 6352,10 3847.84 8in71-0SF 16366,07 39.91 1626247 16216,1.MIKE OSF 1.50 6399.01 3855.32 M7l-O-SF 14159.89 08,8 14087,31 14051,51 05F 1.50 6810.82 3914.93 M4R-0-SF .1=1 i 4217 1285757 1281051 137.61 OSF 1.50 998.64 4036,28 MnR-C1C1 12966,45 50.'4 MI= 12804.51 15,59 OSF 1.50 10188.5 4040.27 MINPT-O-EOU 12959,22 5527 12856.: 12803.'- ' 125,99 OSF 1.50 10309.79 4041.43 Ming-0-ADP' BE= 77,15 12845.22 12786.49 110,37 OSF 1.50 10921.00 4049.05 MnR-CICt 1111E= 95.52 12835.80 12770.95 99.97 OSF 1.50 1145.29 4056.32 M6m71-C1C1 I- E 23.8 12906.89 12734.76 87.8 OSF 1.50 12188.83 4050,95 44911-0101 241,55 127915 12713,09 80.77 066 1.50 12687,25 4031,53 1186P1-CICt .11=E 276.63 12755.54 1266365 70.41 066 1.50 13627.81 4021,61 M1.R-CIC1 129324 319.44 12719.18 1513,03 60.91 OSF 1.50 14762,59 411,24 M'nP1-C1C1 345.62 12704.22 12589.34 56.29 OSF 1,50 75445.65 883.04 M'61Pl-CtCt 158.09 356.85 1270086 7258224 54.54 OSF 1,50 7578.22 3968,70 TD 15631.43 110.86 15557,5 15520.57r213, OSF 1,50 914.18 909.32 Ming-0SF Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SP08-N7\SP08-N7\SP08-N7(P5) 8/27/2013 3:21 PM Page 10 of 12 Offset Trajectory Separation Allow Sep, Controlling Reference Trajectory Risk Level Alert Status CtCt(ft)1 MAS(R)1 EOU IM Dev.(1t) Fact Rule MD(It) 1 TVD(RI Alert 1 Miner 1 Major 1510333 106.99 15034.6E 14999.- OSF 1.50 975.98 959.25 MinR-O-SF 14413.39 103.8 14344.34 14310.31 211.74 OSF 1.50 1018.47 1010.21 MinRA-SF 14075.81 100.51 14008797 13475.30y�21214 OSF 1.50 1042.15 103294 MnRS -0F 1381240 98.26 13746.56 13714.14 212.196 OSF 1.50 1064.66 1054.49 M1nR-O-SF 13413.81 96.34 13349.92 13318.47~3.23 OSF 1.50 105.56 1083.98 Ming-0-SF 13027.06 91.99 1296/41 129%.07 OSF 150 1130.90 1117.50 Ming-0SF 11489.65 71.62 11441.58 11418.04 243.98 OSF 1.50 1384.86 135294 MinR-0-SF IL 32.811 2998381 2983.34 180.07 MAS•10.00(m) 2201.62 208240 Minns 5%6%5.1(Del Survey) Pre I 275321 3291 259.1•® NIA MAS•10.00(m) 41.00 41.00 Minna 270.37 32.81 M-'-'AJ4 237.56 3958.95 MAO s 10.00(m) 60.43 6943 MINPT-560U NOME 32.81 269. 323.69 MAS•1500(m) 230.40 230.40 Minna 271.33 3281 muzIE 238.52 286.04 MAS.10.00(m) 250.38 250.38 MINPT.O-EOU 401.96 32.81 39290 369.15 51.18 MAS:10.00)m) 924.84 919.69 MMR-OSF 737956 3281 708.26 687.75,_s..96 MAS•1000(m) 155214 1503.83 M4401-05F 785.59 3281 77225 75278 64.72 MAO•1900)m) 164223 1584.66 Ming-0-SF 93146 3281 918.38 900, 67,31 MAS•10.0(m) 183351 1759.66 MinR-0-SF 1024.04 3281 1007.56 991.23 67.07 5685.10.00(m) 194277 1851.99 MinR-0-SF 1310279 86.64 13044.71 13016.16 OSF 1.50 7311.76 396592 M1n9-0-SF 12959.17 75.70 12908.38 12863.45 280.17 OSF 1.50 7351.44 397218 l.6ng-0-SF 12887.85 106.51 12817.19 1279234 184,94 OSF 1.50 8824.74 403692 Ming-O-SF • 76 147.59 12964.05 12915.19 133.64 OSF 1.50 10241.90 4041.06 MnR-C1Ct 13063.43 149.5112963,47 12913,92 131.92 OSF 1.50 1031283 4041.45 MINPT-0-E2U 13066.28 153.14 12983.86 12913.11 128,80 OSF 1.50 1044299 404210 Mi8R-0-ADP 13071.36 158.631 12965.28 12912.73 124.37 OSF 1.50 10632.90 4043.06 MINPT-O-EOU 1307287 160.67 12965.43 1291231' 12279 OSF 1.50 1070256 4043.41 MinR-0-ADP 213.58 12926.14 12856.27 9220 OSF 1.50 12369.95 4044.84 MOR-Cl01 269.11 12847,45 12758.08 7287 OSF 1.50 13996.43 4024.69 Ming-C4Ct 1302946 275. 12845. 12754.17 71.25 OSF 1.50 14156.29 4027.63 MINPT-O-EOU 1303483 281.43 12846. 12753.40' 69.71 OSF 1.50 14334.18 402995 MIrnR-0-ADP 1303889 295.8 12848.01 12753.06 5666 OSF 1.50 14455.46 402252 MINPT-0-EOU 14 303.17 1281282 1274209 64.75 OSF 1.50 1493271 4004.80 Ming-CICt 13025.86 332.86 12803.77 12693,21 5891 OSF 1.50 15738.22 346870 TD • 9928.16 52.39 969290 9875.:1== OSF I50 2085.08 1978.36 56449-0-SF 9743.91 34.15 9720.82 9709. 440.• OSF 1.50 2101.31 199283 56n49-0-SF 32.811 2998381 2983.• 186... 44795•1m50pn) 2201,62 208240 64171s 5037.0.871(DM S•svey) Pass 1-4 3281 28218 252351 161.78 MAS•10.00(m) 31864 34864 MinPts 285.19 32811 282.15 25238 156.42 MAS•10.00(m) 367.93 367.92 MINPT-O-EOU 30256 3281 296.23 269.'1111.1:ME MAS•10.00(m) 753.48 751.77 Ming-O-SF 740.85 32.131 730.31 708.• �'E MAS•10,00(m) 1946.89 1855.64 • Minn-0-SF 1306.61 3281 1341.95 1331•Z-' MAS•10.00(m) 3021.16 2783.04 Ming-0SF 3966.12 3281 3948.63 3933.32 240.21 MAS•10.00(m) 4115.29 342201 TD N4u1eMq 4034 S1nmy) Pse Qa 3281 8051.1•1111111:EN 322143.08 MAS•10.00(m) 5290 5290 MnPts 8053.08 3281( 8027,25 137233.13 MAS•10,00(m) 6284 6284 MINPT-O-EOU 1 ."'"A 3291 645250 MAS•1003(m) 576.58 57530 MmPta 608836 3281 806277 9033,':x.•-..''' MAO•10,00)m) 76240 760.59 MnR-O-SF 1-4 112''ME=1M=E MEM 05F1.50 6921.12 3928.74 Minns 6purt 1 P61(DM Suwy) Ince MEE 3281 5145.53 5115.221 8911.90 MAS•10.00(m) 169.07 169.07 MnPts 5148.12 31811 514545 5115.31 6919.76 5665•10.00(m) 209.07 209.07 MINPT-0-E0U 5344.12 3281 5335.60 5311.311118: MAS•10790(8,) 1160.76 1145.71 MinPI-0-SF 866.30 95.28 8561.24 8530.02 138.10 OSF 1.50 9026.30 4038.32 TD 599222 78.35 8939.45 8913.871 175.75) OSF 1.50 847239 4037.51 664014)-SF ayun 1(Del survey) Pass MEE 3281 5145.53 5115.22) 8911.90 MAS•10.00(m) 169.07 169.07 MinPts 5148.12 32811 5145.45 5115.31 6818.76 MAS•10.00(m) 20907 209.07 MINPT-0-E05 • 5344.12 3281 5335.60 5311.32' 807. MAS•10.00(m) 1160.76 1145.71 56in71-0SF 5714.56 3281 5699.30 5681.76 428. MAS•10.00(m) 2000.05 190271 Ming-0SF . 5840.92 3281 5825.73 5808.11 410. MAS•10.00(m) 2135.56 2023.39 Minit-0-5F 8704.60 63.91 8661.41 8640. 210. OSF 1.50 7179.91 3%6.96 56t49-0SF ® 63.611 8591.09 8630.47 210.81 OSF 1.50 7190.87 3958.02 MinPts 97.27 8475.51 8443.63 133.91 OSF 1.50 9001.86 4038.15 M1R-CIC1 854091 97.311 8475.51 8443. 13385 OSF 1.50 9044.97 4038.15 MiGs 8588.91 98.74 852254 8490.1 132 OSF 1.50 901257 4038.22 M649-0-SF 8590.01 96.75 8523.64 8491.2 132 05F 1.50 901273 403822 98406-0-SF 9061.19 96.33 9615.10 978286 153.23 OSF 1.50 9092.00 403877 TD TAnaaq ST I(OA Survey) Pass I 5148.01 32.81 5145.53 5115.22) 8911.90 MAS•10.00(m) 159.07 16907 MnRs 5148.12 32.811 5145.45 5115.31 6818.76 MAS•10.00(03) 20107 209.07 MINPT-O-E05 5344.12 32.81 5335.60 5311.32 807.83 MAS•1050(m) 1150.75 1145.71 M4nPt-0-SF 599603 3281 5975.92 5963 329.52 MAS•10.00(m) 1804.76 1729.68 Minn-0-SF 6115.72 3281 6095.36 6082.91 331.56 MAS•10.00(m) 1851.77 1771.44 Ming-0-SF 12664.40 110.19 12590.35 12554.21 175.17 OSF 1.50 637282 3851.16 Ming-04F 9003.65 66.88 8958.47 8936,77 217.34 OSF 1.50 7125.54 3451.54 56ng-0-SF 8875.07 62231 8832991 881284 22011 OSF 1.50 7252.63 3963.77 MOPS 1111112ME 62.21 8833.00 881263 220.22 OSF 1.50 7253.73 3963.87 Ming-C1C1 IL 95.99 8681.12 8649.66 138.97 OSF 1.50 9050.08 4038.48 MnR-C1CI 8746.11 97.1 8680. 8648.98 137.33 OSF 1.50 9084.66 4038.72 MINPT-0-EOU 8750.56 102. 8681. 8647.90 129.87 OSF 1.50 9261.55 40 958 MINPT-0-EOU 8750.79 103.01 8681. 864779) 129.43 OSF 1.50 9271.48 4039.43 Ming-0.427 10554.57 31860 10341.63 10236.97 19.94 OSP 1.50 15738.22 368.70 TD 10878.60 6671 10633.49 10811.•MIllallal OSF 1.50 1767.84 1696.83 64401-04F 10291.85 6259 10249.29 10228.-:l OSF 1.50 1784.81 1711.91 MnR-0-SF 10227.45 6251 10155.11 10164.•-11.11= OSF 1.50 1786.41 1713.36 Ming-0-SF 9928.13 60.75 9887.00 9157..�- •r-- OSF 1.50 1795.24 1721.21 MinR-O-SF 8992.22 78.35 8939.45 89178 fit. OSF1.50 8472.39 4037.51 MinR-0-SF Nike/minx'3(Del Survey) Pass l, 3 32.81 7803.111 7772241 312041.38 MAS•10.00(m) 52.90 5290 Minns 5348.44 6278 5306% 52860+61) 134.35, OSF 1.50 5991.45 3786.70 MnR-O-SF 5315.991 62771 5303.141_ 5283.27 131791 OSF 1.50 5998.07 3787.87 Minns 7918.92 54,07 788229 7864.85 227.04 OSF 1.50 6159.14 3815.83 TO r a 1 1 54.071 7892311 7874.761 227.31) OSF 1,50 5159.13 3815.83 Minns NibMchup 3781 IDM Survey) Pass 1 p5 32.81 7803.111 7772.24 312041.38 MAS•10.00(m) 52.90 5290 MnPts 6348.44 6278 5305.55 5285.45 134.36) OSF 1.50 5991.45 3786,70 M1ng-0-5F II-''8 52731 5303.141 528327 134.41 OSF 1.50 599807 3787,87 MnPts 7359.78 53.40 7333.58 73(6.37 214.03 OSF 1.50 6143.92 3813.23 TD • 53. 1111a_.•MEM OSF 1.50 6143.92 3813.23 . MinPla • NNalchup 378212960 Survey) Pass Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SP08-N7\SP08-N7\SP08-N7(P5) 8/27/2013 3:21 PM Page 11 of 12 Offset Trajectory v1Sepration Allow Sep, Controlling Reference Tra)ectoy Risk level Alert Status -CRCt(S9 MAS(ft)I EOU(R) Dw•IR11 Fact. RuN MD(R) I TVD(R) Alen Minor I Major 7805. 3281 7803.11 777224 312041.38 MAS•10.00(m) 5290 52.90 Min%s 5348.44 5278 5305.55 5285.66 134.351 057 1.50 5991.45 3786.70 Min%-0-5F 1 5345.991 62.731 5303.14 5283.27 134.41 OSF 1.50 5998.07 3787.87 86n77s 7108.35 5152 707108 7054.83 205.94 057 1.50 6143.59 381118 TD MU& 51.,,=UDE I OSF 1.50 6143.59 3813.18 Min%s Making 31,133(Del Survey) Pass 11m011 32.81 760111 777223312041.38 MAS•10,00(m) 5290 52.90 Min%s 5348.44 8278 5305.55 5268 134.351 OSF 1.50 5991.45 3786.70 Min%-04F ( 5345.991 62731 530114 5283. 13447 OSF 1.50 5996.07 3767.87 610915 791892 54.07 788229 786485 227.04 OSF 1.50 6159.14 3815.83 TD 154.071 7892201 7874.761 227.311 OSF 1.50 6159.13 3815.83 MinPts N4Wcteq 1(Dal Sway) Pass 7937.16 32.81 7934.10 7904.36 6477.2 MAS•10.00(m) 451.81 451.77 M6%-0-SF I 545273) 66.77 5407.14 5385.96 128.65 OSF 1.50 6336.92 3845.39 Ming-CIO 5452.74 66.791 5407.131 5385.95 128.61 OSF 1.50 6338.74 38455.68 MnPls 5613.74 6882 5466.78 5444.92, 126.03 OSF 1.50 6485.68 3868.82 61079-0-SF 559265 70.02 5544.93 552263 125.33 OSF 1.50 6564.83 3880.73 Min%-04F 5654.57 70.74 5606.41 5583.84, 125,20 OSF 1.50 6611.89 3887.58 Min%-0-SF 5733.73 71.47 5685.12 5662.251 125.33 OSF 1.50 666251 3894.84 Ming-0-SF 5804.86 7221 5756.81 573265 128.25 OSF 1.50 6703.22 3900.52 MinPS-0S7 5874.59 7289 5875.13 5801. 05F 8.50 6739.63 3905.50 4Mn%-0SF 8659.56 74.88 8609.05 9584.68 177.60 OSF 1.50 7727.35 3961.46 TO Mkrchq 4P81(DM Survey) Pass 1-11 3281 8051.1. 8027. • 322143.08 MAS•10.00(m) 52.90 5290 MinPts 8053.06 3z91 NI= 8021,25 137233.13 MAS•10.00(m) 62.84 62.84 MINPT-0-EOU 1 ".4 3281 11111 ®.. 645250 MAS•10.00(m) 576.58 576.30 Min%s 8066.36 32.81 806277 8033.-IIAII MAS•10.00(m) 76240 760.59 Ming-O-SF 5693.79 6273 566036 5631...Imo: OSF 1.50 5991.61 3786.73 Mn%-0-SF 65 82 . yam 143.05 OSF 7.50 5993.21 3787.01 Mins 5731.69 62.25 5689.20 5669.43 144,90 05F 1.50 6018.85 3791.53 TO Nicatehac 2(DA SLvsy) Pass EalL 3251 MIM:I N/A MAS,10.00(m) 14.15 14.15 Mints 13579.71 69.17 17532.57 13510. ==I 090 1.50 5925.86 3775.04 Min%-0-SF • 13512.25 72.45 13486289 13439.,ME' OFF 1.50 5987.02 3785.92 Mn%-0-SF i 13484.81 7240 13435.48 13412.41 EWA& OSF 1.50 6024.88 379259 61n91-0-SF 1348174 72.09 13434,x.MIME 293.39 OSF 1.50 6034.84 3794.34 Min%-0-ADP 13483.69 72. REM 13411.66 293.62 OSF 1.50 6036.43 3794.62 MINPT-0-EOU 1 13483.57) 72.24 13434.38 13411.33 5270 OSP 1.50 6049.08 3796.83 Mn%-C1C1 13483.63 72•rMEE, 13411.23 292.00 OSF 1.50 605.3.02 3747.52 MINPT-O-EOU 1348168 72.46 13434.s IIIME MEM 057 1.50 6054.46 3797.77 MinPts 13546.15 7251 13496.82 13473..•IQ- OSF 1.50 6124.20 3809.85 Min%-0-SF 13606.04 7293 73556.49 13533.11 M--=-, 057 1.50 6153.67 3814.90 Mn%-0-SF 13828.33 75.06 13777.60 13753. Wan OSP 1.50 6252.63 3831.57 65n79-0SF 13909.83 75.28 13659.05 13834.-4 MEM OSF 1.50 6278.43 3835.84 5446-0-SF 14027.64 76.05 13976.38 1351.:,MIEZE4 OSF 1.50 6308.42 3840.76 Mn%-0-SF 14290.06 76.74 14238.31 14213-..11 OSF 1.50 6359.90 3849.09 3M91-0-SF 1435211 77.13 14300.10 14274.•;1111.EaM OSF 1.50 6371.61 3850.96 74n71-0-SF 14789.50 77.44 14737.28 1471205 293.09 OSF 1.50 6433.42 3860.73 TO Drilling Office 2.6.1166.0 Nikaitchuq\Spy Island\SP08-N7\SPOS-N7\SP08-N7(P5) 8/27/2013 3:21 PM Page 12 of 12 Schlumberger TRAVELING CYLINDER PLOT NoGo Region EOU's based N Client: Eni Petroleum on: Oriented EOU .4f W, Well: SP08-N7 Dimension � Field: Nikaitchuq '410 Structure: Spy Island NoGo Region Anti- Date: August 27, 2013 Collision rule used: Minor Risk - Separation Factor North 350 0 10 340 of �r 20 0 - 700'md 330' .��` ir �/ 30 320'/' lit& �`, % 40 Aglx 310 �� '�+lii� � �� % � 50 �b ,i" -05-FN7PB1 AMT300 �_-'�AlIWArAmw �,• � �j � ` 60 olio, , Orgro�.-.••:, .�;�� , E��'aifi,f/tA! Ill 290jiff41 ,�, 1*. ; 70 — ► ,tail ta► r� �► illb - - * k 260 �\�� ora lieftf4.. . "°° '' `\. t ;Iii,iilisToosti,ci ,` �iw \ ..,AV,4,411111111110 L :' s . , N I, , 1 �•, X .105-FN7PB1 270 1, b-'11."'\\\ mi/��\��I�� ► lare \ - 90 ►, l ; �\\ll \�� '"!"�f 11�',,��,�', r, �� limink air �260,Ig1 `I1 -!F I/ . /, %% \410$44,4 ®$. , 100 Okla ►.. \ �1.�s�l•Vtosailli . t, I� r% �� 110 asaki 250 l� 1101:>„_440,46, 1 " it �� 11 �./�� \fit__, � / ' s4 ! 120 „e 'i., 220 140 210 150 { 200 160 190 180 170 • Well Ticks Type: MD on SP08-N7(P5) Calculation Method: Normal Plane f Ring Interval: 5.00 ft Azimuth Interval: 10.00 deg Scale: -11 INCH= 10.00 ft f 1 1 Schlumberger TRAVELING CYLINDER PLOT NoGo Region EOU's based; N Client: Eni Petroleum Ion: Oriented EOU .4 *, Well: SP08-N7 Dimension Field: Nikaitchuq ''1if Structure: Spy Island NoGo Region Anti- Date: August 27, 2013 Collision rule used: Minor Risk - Se•aration Factor North 350 0 10 340 �: 20 0 - 700'md 330 1 �j,�l► 30 All '� , -sE6(P2) 320 � \\�7 .,1_,411111:01.410141i 140 1M31046,V41311\), `�., `r ./'♦ t3.(PNIS VIII 5r Vill,P4''4 kiii . \. r Aar o".41,40 kJ.,-.1 11jA 300 � �Aore-e�� • �•`�� \ ,�' ifr1�7jl. OW •i. i 60 ilik►•� 1.�► �� /moi 290 jproek1 Iw0,��h,✓4116.4 e2:0Ni Aim* �� •- , ok,i � 1 70 . 1.471-.,.....4.4" „6../4„,,,,,......',VI TIP 280 "�— �. ��I�`�\��'�1 `:� l 7��7/�Ia _,� s iA1�� !ice \ 4 .�► \, 7# i '40101� , �♦ ��At Asir 4 80 • ► `N ��Ic��t► i; /�i'` Vallits 1",1c , ��1J=r,,._ mil,270 Sa� ...„<„,4 ..„.,. k.,„ '11W ��x,1 , ,'• ... rir.� 90 >�\ po ,-;z ! ' �,v i t v 1 N.�11/ �:i 1� . �� ,, 4 O I i �•'•#..: 1..',,,--.;,' /' i , �' 1' �, /, ,, / ��=��-,:��'/,,, A 100 260ll*;�, i�� :/i �pill��,i"; �� - / ,<. ,, ��_�H1+��i ��y�l i/�� ,,gy'IV 'Nor' p MO s- 110 250 ,,./4,. .1k,Afi.E': / °j%` O • ,,,-'4,„.41‘,-;-!•42.5-4,,,A3,..,, IV** a 240'=-irdx•:�_ 120 230 a 130 220 140 21014 150 ok, 20160 190 180 170 Well Ticks Type: MD on SP08-N7(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=30.00 ft Schlumberger TRAVELING C YLINDFR PLO T NoGo Region EOU's base' N Client: Eni Petroleum on: Oriented EOU I ► Well: SP08-N7 Dimension ' Field: Nikaitchuq_ �'► Structure: Spy Island NoGo Region Anti- Date: August 27, 2013 Collision rule used: Minor Risk- Se•aration Factor North 350 0 10 � 34001r- :.• �c rillprit• �7(P2) 700 - 2700 and330 �� . jahlr 30 320Ak� titilisofat, ao 310 �1j �\ NVAS�tStirt44*d.4450 1 ill 40.4 * Val I 300 ,15`\, 4. bity 60 e 290 k, T # 440.4timiir V 70 toll itkairelli 41*** 280 80 40 NA '1 �//► .i,�- I �rata S` 41°4111411S1Pbk 270 . �_'www,___:„.6.‘-_,��- �s�,oitiviAiiiniTi_ ■►_ 90 gArliallill nwroce. ,....... ..... ..., 260 ► S�oer Il i yy-N'!! �- �1►`J.' �'1% `14- 4"rati ♦ ,�� 100 101 •►•�,`olgX11:l�,+,.-0-�`� \-0.1 i- I iiti ` `�w��=�„,, r�� 250+` ovVP i ,.1 #o'-', I.'- ►�'• ;.• =1�1Nl*P��.$ �� ‘.11wohk...ogrim I�+�\ 110 1 1' k4 lit + ��r ��..,* 4/t ki i� o"14 ga44 �� r t X03 N5(P2) 240 ;: ,y t:„Fire,*it,'"4"aego 9, S* If \7141r47 1i.:11, -:---I1/� i 1 0 230 ":tetZvi".��,``: As- \ \ it 130 4`..��401466_V•',11 is g SXO6-N4(P2) NiNiibt°►t.• x,91, \.f 220;r,; �/� 1so1 14 � �J idir 4111? 210 II� 1• 150 200 -111114, 160 19• 180 170 Well Ticks Type: _MD on SP08-N7(P5) Calculation Method: Normal Plane Ring Interval: _ 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft I 1 Schlumberger TRAVELING C YLINDER PLO T NoGo Region EOU's based N Client: Eni Petroleum on: Oriented EOU 41 * Well: SP08-N7 Dimension Field: Nikaitchuq 1C Structure: Spy Island NoGo Region Anti- Date: August 27, 2013 Collision rule used: Minor Risk- Separation Factor North 350 10 340 111111111,*0 2600 - 8100'md 330 30 All 140 320 40 Mu 120 asks.11,4 310 50 30060290 it*,,ioloort # WIrill r 70 280 alth iffAA111111111 X11 ao 270 11111111k14gal9. ir2so �rgn 250 /_•�, ,�r'••'... %f ♦a 110 240 lorAlj. ►� airv".* 4iW20 N, IRO , - VSPO4SES(P2) 230PA7 .,tr l 130 r . 1 t 'NIP 220 ; b ` % 140 210 \ -SE5(P ,. 200 .,� 160 190 +on 170 Well Ticks Type: MD on SP08-N7(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT _ __ NoGo Region EOU's based :7‘1 Client: Eni Petroleum on: Oriented EOU Well: SP08-N7 Dimension A4A Field: Nikaitchuq Structure: Spy Island O Date: August 27, 2013 NoGo Region Anti- Collision rule used: Minor Risk - Setaration Factor North 1 350 0 10 8000 - TD Sao '320 20 330 _300 WO -280 320 44440 41E1 ireti, S4150 300 ♦ ,, �' `.® 60 .r►`s �� ♦ ate, :, f 290 4P407�.** 4NN*\4* ,♦ ♦.'',f,®S� 111111 70 280 '.intildr144414441 '`\.,� , Scliskirittf4 • ,`1410O.all ° ► 20 4111111111 270 90 260 ,'�� i �� ♦�►�� ,.1l t1111111110111M4,41 s'AMI111111111 �♦Oran 100 7P A* ‘.14P‘ . 1 ♦ til l t V4r111111 ` ,`�' 250 .�.►, I •ice, �: „o 4, X144E 1► �i®�►�/� ♦ ti ,*IV•�/•�,®�1,��, a o°wwssai 240 ��i/ ,, ,� 120 230 ,�+' �®��•WIMP, 130 OI * I,*440,4011110 Ji . ,, I Ir 14°220 ��,�/��'� � 2,0 '�� 150 20� 160 190 ...- 170 Well Ticks Type: MD on SP08-N7(P5) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft REV DATE BY CK APP r DESCRIPTION _.. `;REV CAM BY CK APF DESCRIWIION At.. j ;- 7I :,v .. .'J'N 1, ' VICINITY :\TAI' ; , rs NT 1 + . _ , _ ,' ? I 1`.,... , ' 1 THIS .. . SURVEY �i� oia T14N iT14N I I _._. .._._ ._ T13N I T15% �^ I{iFgP1`'AtDK �DCdI ri� r a I I fIowu �,- i \G� OA 'v I, I. • ......,./;.:[;NCC{ 0I TON'X, I \� ' P. I ! a'AGIM AMx �1 ►AF'U ;'g � DS-3G i 4.1 w„ RI QAC•. J I. ' ,�'. DS/13u r t i / `� I :I to ‘ i ;t5, f ?Aihe S E--;' l i a ,, ! 11 ,,, '" I i 1 I ; { I♦ ',I • l ii. �- I'`} '¢ar'rxo ,.'• AAPL I I' i y 8 3 , I I ; )DS-3H . III i! I• ci° `' ' -'a r' • . i.,,.. ``.': i 1 ' .i I, f I rN PAD 6ih + I e q# I CP I .' ' . - vit. ' ..:Ali r , f �'' � 1+, F 1�rt DRAWING NOTES: I. GRID) COORDINATES SOWN ARE A.AltA STATE PLANE, ;SONE- 4, NADS3. U.S.iAti'CLS SHOWN ARE -RUE HOR'ZOMTAL DISTANCES. 2 GEODETIC COORDINATES SHOWN ARE NADB3. 3. BASIS OF LOCATION DERIVED FROM GPS STATIC OBS. PROCESSED INTO OPUS S0.UT1ONS. 4 CONDUCTORS ARE LOCATED WITHIN PROTRACTED SEC"ION 'S, TOWNSHIP 14 NORTH, RANGE a EAST. LMIA1 MERIDIAN. 5 ELEVATIONS SHOWN ARE B. .M.S.L. DA-UM 5 AI.I SLCTIONS SHOWN AND/OR RcTERENCEC IN -HIS DRAWING ARE 'PRO"RAC TED SECTION'S'. . '! RL.LR=DICE LJ!NSBURY DOCUMENT E-057 ;OR COORDINATE VALUES IN NA027. SURVEYOR'S CERTIFICATE _ 4C4t"h \A" $ i f I HEREBY CERTIFY THAT i AM PROPERLY REGISTERED AND .� LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF % ' ---,, r I ' '' ' ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY f b FRANC'S GOA^,I�;G i IREV DAZE _ E__CK ftiPP i cLscRIf 1R, REv+ OATS: @3' Cdt.�-A^P --- DESCRIPTION'I t J T. ,. I � w ----] 1 1 CJ„y1 1 w tr, LA l iJ N tO u •fir a, ' I �J G (AS ' fIQ! CJ Cr In L: L r '•'”. 1 p l ✓ 01 I. c: '1 t4 y N p JJ I cry ,p On Di.lit : A. SCALL , _JEC, SA+I9BAG Z�.,. ,...„....„\\N / �r l A;E� 5)-1000)t? J/ 1 i 1 Ii/7--:_ ----- \ w v.1 :jest 071P7 ii �oi0e q'C ffi V 1 GJ\� QC, �r� c \ ro rYI ru MIA L. A \ 1r `a fir �� 1 SPY ISLAND DRILL SITE ' ; ti (SID) 1 1' \ 1 , 1 5vigt1L01r" / 1 • tipNf)6PG ZCE .=GEN: SCALE _._�. . ^c c -UL 2JC C - W c. CONDUCTCC AS-BUIL 1•-ii C Su;vry IL 1... _ 200' all' �,��ca/�o` SPY ISLAND DRILL SITE sf` '� '' WELL CONDUCTORS A y �(��I�. AS—BUILT LOCATIONS Pro]11] (�r .,,„0.1, CFC FIi F.EA..35 :';I us Oper II(r`►lc 01''I:C14':J2O10 °RAVING NO: Eni-3543—d9 PART: REV: REV 4 v~F D 1t. HY r.K APP rSCRIP17CA_.. . i ..r�_. CK A ___ oFs�r�Y�o . 1 l , , r .' \_1. CC -i. 1. :,,:01,' ., 1 ' Protracted Secti0n 19, T. 14 N., R. 9 L, Um at Meridian Aiaska State Plane, NAD83 GRID NAD83 Geographic Section Line Offset Pad + Xetude (N) Longitude (WL F;oy_L F.E.t i Flev -_-_-_--� - - - (US ft.) (US rt.) 1 6053423.20 1651769.82 70033127.209'7 149` 4'74.765" 797 1171 j 12.4 2 6053471.65 1651761.87 70033127,194' 149'54'25.000" 798 1179 12,4 3 _ 6053420.07 1651754,10 i 70033127,1.79" 149054125.229" 800 1186 32.4 4 6053418.56 1651746.17 70033127.164" 149054125.463" 801 1194 1 17.4 5 6053417.03 1651735.44 70°33'27.149" 149'54'25,692" 803 _ 1202 1 12,4 6 6053415.54 1651730.54 70033727.134" 149°54'25.925" j 804 1210 12.4 I 6053412.44 1651714.77 70033127.104" 149054'26.391" 80/ 1.226 12,4 8 6053410.91 1651706.96 70033127.089" 149054126.622" 809 1234 tI 12.4 9 6053409.39 1651699.11 70033127.074" 149°54'26.853 810 1241 I 12.4 10 6053407.94 1651691.31 /0033727.060" 149"54'27.084" 817. 1249 12.4 • 11 6053406.32 1651683.39 70°33'27.044" 149054127,318" 813 1257 12.4 12 6053404.80 1651675.51 70033127.029" 149°54'27.551" 815 1265 12.4 13 6053400.38 1651652.80 70033126.986" 149'54'28.221" 819 1288 12.4 14 6053398,83 1651644.95 70033126.971" 149054'28.453" 821 1296 12.4 I 15 6053397,31 1651637.12 70°33'26.956" 149°54'28.685" 822 1304 12.4 I 16 6053395,82 1651629.26 70°33'26.942" 149054128.917'' 824 1311 12.4 17 6053394,32 1651621.47 70°33'26.927" 149054729.147" 825 1319 12.4 18 6053392.78 1651613.58 /0'33126.912" 149054429.380" 827 1327 12.4 19 6053389.63 1651597.90 70'33'26.881" 149°54'29.843" 830 1343 12.4 20 1 6053388.17 1651590.00 70'33126.867" 149054'30.076" 831 _ 1351 12.4 21 6053386.60 1651582.24 70°33'26.852" 149054130.306" 833 1358 12.4 22 6053385.19 1651574.35 70033126.838" 149'54'30.538" 834 1366 12.4 23 6053383.64 1651566.41 70033126.823" 149054130.773" 836 1374 12.4 24 6053382.12 1653.558.61 70033726.808" 149°54131.003" 837 1382 12.4 25 6053377.65 1651535.94 70033126.764" 149054131.673" 842 1405 12.4 26 6053376.14 1651528.13 70°33'26.750" 149°54'31.904" 843 1413 12.4 27 6053374.53 1651520.23 70°33126.73411 149054732.137" 845 1421 12,4 28 6053373.11 1651512.46 70033126.720" 14905432.3661' 846 1428 12.4 29 I 6053371.56 16515C4.49 70033'26.7051- 149054132.602" 848 1436 17..4 30 6053370.06 1651496.66 70033'26.690" 149054432,833" 849 2444 12.4 31 6053367.05 1651480.97 70°33'26.661" 149'54'33.296' } 852 1460 12.4 32 6053365.47 1651473.16 70033126.646" 149054733.527' 854 1468 12.4 33 6053363.93 1651465.22 70°33'26.631" 149054133.762" 855 1476 12.4 34 6053362.44 1651457.37 70°33'26.616" 149754'33.993" 857 1483 12.4 _ 35 6053360.91 1651449.52 70033'26.801" 149°54'34.225" 858 1491 13 4 36 6053359.33 1651441.62 70°33'26.586" 149054'34.459" 860 1499 12.4 I_ 37 6053356.19 1651425.30 70033726,555" 149054134.9411' 863 1516 12.4 ' 38 6053354.74 1651417.32 70°33'26.541" 149054135.177" 864 1524 12.4 +°►fils 0O 1.440eSPY ISLAND DRILL SITE 1 t WELL CONDUCTORS X11 . AS-BUILT LOCATIONS @nil ,,, ,. ,ILI:E hi3543C9 US oiler inrog DAt;c,�ot/2oto DRAWING ND. ED's-3 43-d9 PART: REV: 3 REO L. v 7 I 1 I I o '-',0 -C 0 ' 1 I o g . w -0 > vav, vlvv, aaevcavv',vavva;aq vavavvv C y0j A V to O/ N N N N N N N N N N N N N NN N N N N I N N N N N N N N N N Q Z 00 0. W 4 .-1 .•1 ey I N N N N .1 N e-1 N e-1 N I N N N e-1 .i 1 e-1 e-1 .-1 - e.4 e-I N N N 1-1-1 ot C I • I I W C W J ' N N 00 Oat 10 C� N M a I a Ill i0 CO 01 O e•1 .�-I N aim LA t0 r-i co to N CO O .4-4 to m-I N co o w W to e-1 e-I ei ,-I'N N N N N I N N N N N M M In M M;M In M in M a;a a s o .1- LL O e.4 N ey 1 N e-1 N N .-1 N I 4 N ei ei N..-1 .-i e-1 e-I ei I e-1 e-1 N .- .-1 e-1 I N .-1 ei O j C I J --. oC pp I 1 Z 01 01 0 010 0 0 0 00 00 e-1 e-1 e-1 N N N N N co in n M M M M M .cr00 00 00 CO a LL. 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N ° 40NinmN0oi40 a. —' in n n to t0'10 t0 tO V1 in in: 5 �. m m m m m m m m m m a • N Y M M M M M M M M M M Q H to M to V1 M In to V1 to M M 0 0 0 0 0 0 0 0 0 0 Q Q t0 t0 t0 t0 t0 t0 t0 t0 to l tO H u U • U O Z p O ' 0 m .-I > M O V O m O y 0 'O O z 01 O .-i N,to a N t0 n 00 a .i N a 0 N M M M M M M m MIM O w tl N Y al V °UoUa I o tAQ y ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 � Em E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight (PPG) Metric units EMW = P x 10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Big E&P Division REVISION STAP-P-1-M-6140 0 I 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. ENI S.p.A. S P E 0 IDENTIFICATION CODE PAG 208 OF 338 Eng E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of 'Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. SPEO IDENTIFICATION CODE PAG 209 or 338 ENI S.p.A. EMI E&P Division REVISION STAP-P-1-M-6140 0 1 - WA LEAK-OFF TEST REPORT Report N' Date: WELL NAME: WELL CODE CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud TW e: FWGELS Rig twe: J.UPs Hole Dameter(in): 121/4 Weight(KgA): 1.3 R.K.B.ele vat on(m): 26 Last Cog.Shoe(m) 797 Marsh Vscosity(sec/Qt): 44 Water Depth(m): 24 Cog.diameter(in): 13'3r8 P.V.(cps): 19 Pumps: 12.P.160 Grade: J65 3.P.(1b11006a). 6 Users(in). 6.5" Weight Ob/t): 61 GelsOb/100 tO: 2,5 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(cc/30 min) 10.5 Litholog y Shale Expected EMW 1.68 Kg!cm2J10 m Time Volume Pressure Time Volume Pressure Time Volume Pressure (min) (bb) (Psi) (min) Lbfl (Psi) (min) (bbl) (Psi) 1 025 60 9 2 490 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 1D0 300 10.6 2 463 125 400 11 2 456 6 150 500 11.6 2 460 7 1.75 570 12 2 4466 8 200 600 13 2 440 8 2.00 550 14 2 437 8.6 2D0 _ 505 _ 15 2 435 Note. Pumped with a constant low rate of(bbl). Wlume pumped(bbl): Vtlume renimed(bbl). (pot) 1000 900 • 800 - - - stop pump r 700 ` e 600 / _ S shut in curve 500 - - S U 400 X' . _ r 8 minutes l e 300 200 - 100 - - 0 - — 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbf) 4 111. Time mins RESULTS: (Press.,,„+Press.t.o.)o10/Depth=[(1.3 x 797/10)+(430 x0.07)]x10/797=1.68(Kg/cm2/10 m) Note. I CompanyRepreserdatim Figure 15-1 - Leak-Off Test Report Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out 8-1/2t� Open Hole / 5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out, backreaming SPEO IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of'Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Metric units EMW = P x 10 +MW ND where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight(kg/I). ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 i 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. SPEO IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve • begins to bend awayfrom the straight line is called Leak Off Point (Refer 9 9 to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of 'Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. • 10 SPEO IDENTIFICATION CODE PAG 209 OF 338 � ENI S.p.A. Bail E&P Division REVISION • STAP-P-1-M-6140 0 1 • 041 LEAK-OFF TEST REPORT Report N" Date: WELL NPME. WELL CO DE: CONTRACTOR: RIG NAME: RIG CODE. Open hole depth(m): 825 MudT}pe. FWGELS Rigtwe: J.LIPs Hole 0ameter(in): 12114 Weight(K9A): 1.3 R.1(.8.ele Ab on(m): 26 Last Csg.Shoe(m): 797 Marsh Mscosity(sec/Dt). 44 Water Depth(m): 24 Csg diameter(in). 13"3/x P.V.(cps): 19 Pumps: 12•P.160 Grade: .155 Y.P.(1bf100le): Liners(in) 6.5" Weight(Ib/t): 61 Gelstb/100 e): 2/8 Flow Rate(bpi): 0.25 Max.burst pres(psi): 3103 W.L(cc50 min). 10.5 Litholog y Shale Expected EMW 1.68 Kg/cm2f10 rrl Time Vol tme Pressure Time Volume Pressure Time Vdume Pressure (min) (bb) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 1100 300 10.5 2 463 5 125 400 11 2 465 6 150 500 11.5 2 460 7 1.75 570 12 2 445 8 250 600 13 2 440 J 8 250 550 14 2 437 8.5 2100 505 15 2 435 Nd e: Pumped with a constant low rate of(bbl): Wlume pumped(bbl): Volume returned(bbl). (psi) 1000 900 - ( 800 stop pump r 700 r - k e 600 - S shut in curve 500 S - / ~�+�~_.'-* •- LI 400 r 8 minutes e 300 200 100 . ...,./. 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(PIA) 1 II. Time mins RESULTS: (Press.,,„A+Pres.u,.)x110/Depth=[(1.3 x797 110)+(430 x 0.07)]x10 1797=1.68(Kg/cm2f10 m) Note: Company Representative L I Figure 15-1 - Leak-Off Test Report 0G �o� w N =J D � 48 Z a N U cr < w 10_ ,..0 =0 :0 z M b.0 oz g JN mCCa5 —� n'`b w o J O K z a z \. .O? _O'' _O� O'` za r p�tx ii — [v M y v) UD N p Q aa w9 D O o 0 I w R L.,_'-- O Lr0 N Z _IN Vaa& C7=N 2 �V coNu_ •-` \ n a. �i!.-I.1 -_ ♦ wOZ -tQ — 4 Z p ona aJ — x�z ,. a i1 ,( oo �a M p 0 p U a co c/ .<,... r<,, _,c / u_ _ z g C K Ag W gm $ i c % of p s or •,.5E w- • S s s _ .,-e Z Iiii iiii_A, 16 II ■ i -- U1HØi1i'kl-iE} -- yIf . �j e ' sP 13 o V >� i ! e z ■ �� j j2 I le 0a kl Ij D I 1 n '' C 0 ! 1011 t--11-1<-11-14--).--k- 9/0/11=111--- Lgx \ i w .o/ss SI j a LeI CC N c 4f ,,, ,,,=. co c ,„:„ ,. 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L1 --/ O) :ti. 1 i i 1 I H h I FN .o t0 ,g S 903a a�1 ' 1 A.,pp3_-9 1 iu - 8 sal._ -_+_- f .9-032 •3i le v y \/j _ p L--- � ,i►" " dtl .£ k,,- ea)s 1 —- u Pp :►` �y1 71'AN `\ ,1 \ Q—L3:fm93]/AVA10YJe 3�___4 / WI.Mil MON 'ft \ I Z s_., b ir„ !flit— i 4.1 I „/ *" • ••r,, 8.4. ! 4 h a NIL ai - ILL I Schlumberger C emCAD E* well cementing recommendation for 13 3/8 Surface Casing Operator : Eni Petroleum Well : SP08-N7 Country : USA Field State : Alaska Prepared for : Lara Occhionero Location : Spy Island Proposal No. : v1 Service Point : Prudhoe Bay Date Prepared : 8/27/2013 Business Phone : (907)659 2434 FAX No. Prepared by : Stephen Lauper Phone : (907)273-1765 E-Mail Address : slauper©slb.com Q $1,) tt`L VRTE Disclaimer Notice: Schlumberger submits this document with the oerefit of As judgment,experience,and good oilfield practices This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others.limitations.computer models.measurements.assumptions and inferences that are not infallible Calculations are estimates based on provided information.All proposals.recommendations.or predictions are opinions only. NO WARRANTY IS GP/EN CONCERNING ACCURACY OR COMPLETENESS OE DATA.INFORMATION PRESENTED.EFFECT VFW SS OF MATERIAL.PRODUCTS OR SUPPI IFS,RFCOMMFNCATIONS MADE,OR RESULTS Of THE SERVICES RENDERED. freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no imellecrual properly rights are granted hereby. Mark of Schlumberger Page 1 SVOB-N7.cfw;08-28-2013; LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2623.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000)psi l > 0 1 2 - - I I — ;I.. - �. 1 1 o r,_ S4' 3 1, _ SV-2 I , 5 6: Permafrost 1 r, 1 G— lJgnu To ilJ34 O Well Ltthology Formation Press Page 2 SPOB-M.cfw;W28-7013; LoadCase 13 3/Bin Surface Casing:Version wcs cem972_05 Client : Eni Petroleum Well : SPOB-N7 Schlimilrgcr String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/Bin Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.250 Landing Collar MD : 2543.0 ft Casing/liner Shoe MD : 2623.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2623.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 150.8 % Mean OH Equivalent Diameter: 19.294 in Total OH Volume : 890.7 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) , (in) (%) (in) 2000.0 16.000 190.0 20.063 2595.0 16.000 35.0 16.822 2623.0 16.000 35.0 16.822 Max. Deviation Angle : 30 deg Max. DLS : 3.533 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 749.5 11.70 8.40 SV-4 Siltstone 1144.4 11.50 8.40 SV-3 Sandstone 1434.4 11.50 8.40 SV-2 Siltstone 2000.0 11.50 8.40 B/Permafrost Shale 2083.4 12.00 8.40 SV-1 Sandstone 2468.6 12.50 8.40 Ugnu Top(UG4) Shale 2595.0 12.50 8.40 TD Shale 2623.0 12.50 8.40 Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2000.0 1902.7 32 0.6 2595.0 2430.0 50 1.2 2623.0 2454.2 50 1.2 Page 3 SPOB-N7 cfw:0B-28-2013: LoadCase 13 3/Bin Surface Casing:Version wcs-cern472_05 Client : Eni Petroleum Well : SP08-N7 Schlmohrger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Page 4 SPm-M.c(w;08-28-2013; LoadCase 13 3/8in Surface Casing;Version wcs-cern472_05 Client : Eni Petroleum Well : SP08-N7 Schiumdcrgur String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 2: fluid sequence Job Objectives: Cement Surface Casing with Returns Seen at Surface Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n : 0.262 Ty :0.48 Ibf/100ft2 Displacement Volume 380.8 bbl Total Volume 979.4 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Surface Lead 435.6 2118.4 0.0 10.70 k:1.23E-1 lbf.s^n/ft2 n:0.268 Ty:1.22 Ibf/100ft2 12.5ppg DeepCRETE 63.0 504.6 2118.4 12.50 k:1.68E-1 Ibf.s^n/ft2 n:0.301 Ty:0.44 Ibf/100ft2 Surface Tail Mud 380.8 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks: Frac 8 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2002 psi at 2543.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 59 ton Check Valve Diff Press 184 psi ft (x 1000) psi 0 -Hydrostatic 2 -Frac -Pore G r. � J. r 7 r 2. Fluid Sequence Static Well Security I Page 5 SP08-N7 cfw:08-28-2013: LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SPOB-N7 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Load case : 13 3/8in Surface Casing Simulated ECDs at Casing Shoe during Placement o Depth= 2623 ft cr) - Frac I i_1+^j 1 J N ion= Hvdrostatii Al N— IMMIM Dynamic , N- ■�� .. Ill SI _ __ Ls.) , 11111111111111 N - ' 11111111111 -. _to ' ii iniifinfi..in o- F_.■!�lQ .C. = - aim ! ! ■ ■_ r U.U_!l a o ! ii! :.. !!!!!!!!!!!! !!!!!!�/!!_ ■5U5 • ■ nail: E . ai- IS MIN - Ili IN i II- 111 . - ill s CD f" r 1 r r r I I I I I 1 0 25 50 75 100 125 150 175 200 225 250 275 Time(min) F Page 7 SP08-N7.cfw;O8-28.2013; loadCase 13 3/8in Surface Casing,Version wcs-cem4/2_85 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated ECDs at Previous shoe during Placement o_ Depth= 160 ft CNi - Frac Fbre c . Hydrostatic 71 r_ Dynamic CV I v— CO To • rll c)- -11) —1.1dco U Q I co c cocci O r 0 30 60 90 120 150 180 210 240 270 Time(min) Page 8 SPO8-N7.cfw;0828-2013: oadCase 13 3/8in Surface Casing;Version wcs-cern471_05 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated Surface Pressures during Placement — Calc.PumpPress CemHP �A• — M O \ O— —M .0— -- N rn to O p- _N dr✓7� O O— O V7 p 4..4'4%)N. r r r r r r r r 0 30 60 90 120 150 180 210 240 270 Time (min) Page 9 SPo8-N7 cfw;08-28-2013: loadCase 13 3/Bin Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated Slurry Temperatures during Placement 73 Fir stSackSack Temp' I.4_ i I__ ' _ 1 I_N I 000_ AR HCT _,_ ■/I1 w/ 111 ///111111 � _in o ///� u= H/ /� Lo 111111111111111111111111111111uI • Iczi N11111111111111211 ONO H _o N — _ IIImIIIIII :i _ _ in O O i O ''<•°- O X o 1 N N( fl I lf)L (Ni.— ,........, N.,,..,...,...., P i 1—1'. in _N o_ t _1111111111111 ' -. �� -- N NOME . //11/ ■ _ o -II 11011•111 in / l l t ,Th l i -in N 0 - o i- r r r r r r r r r r M 0 25 50 75 100 125 150 175 200 225 250 275 Time(min) Page 10 SP08-N7 01w,08.28-2013: LoadCase 13 3,/8in Surface Casing,Version wcs cem47Z_05 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Simulated Slurry Temperatures up to 24hours after Placement Un -o co — Last Sack Temp., — First Sack Temp. in O API BHCT —p 00' O O ti- _I- O O u_ j jg O_ iiimilimiliiwommilifiimiliminieMiinginimimiiimaimmilimilimi 1111 =O �i�1 iii i —�-- II I- E. 1111111111 . _--� _ o a.u) IIIIIIIIIIIIIIIIIINMIIIINIIIIIIIIKIMIMIII 111111111111111 cp `n- MIIIINZCSC •C ril rLn Lr)' NI !g:1111111EIIIIW;::''N/IIIIIIM -U) NM ii Man iiw:_ - MIN .---� :U � 10� I 0 200 400 600 800 1000 1200 1400 1600 1800 Time (min) Page 11 SP08-N7 cfw;08-28-2013: loadlase 13 3/81n Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SPOB-N7 Schmlerger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/Bin Surface Casing Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl; 2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue:time<30 min c) If issue with mixing system—switch to back-up mixing system d) If issue with tri-plex pump—Cont.job with secondary tri-plex pump on unit. 3) Top Plug is not Bumped at calculated Volume a) Pump'/shoe track volume MAX b) If Bump not seen, shut in and hold pressure 4) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue: time<10 min c) Note displacement volume pumped by mud pumps:verify with Co. Rep/WSL d) Subtract pumped volume from total volume=volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit:volume verified by Co. Rep/WSL Page 12 SPOB-N7.cfw;1313-28-2013; LoadCase 13 3Bin Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SP08-N7 S�hmberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Page 13 SP08-N7.cfw;08-28-2013; LoadCase 13 3/8in Surface Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : SP08-N7 SiImierger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Surface Lead DESIGN li Fluid No:4 Density : 10.70 lb/gal Rheo.Model : HERSCHEL_B. k : 1.23E-1 Ibf.s^n/ft2 At temp. :70 degF n :0.268 Ty : 1.22Ibf/100ft2 Gel Strength :(lbf/100ft2) DESIGN BLEND SLURRY Name :ASL B439(53) Mix Fluid : 11.496 gal/sk Job volume :435.6 bbl Dry Density : 110.16 Ib/ft3 Yield :2.44 ft3/sk ./ Quantity : 1000.58 sk Sack Weight : 100 lb Solid Fraction :37.1 % BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 11.446 gal/sk Additives Code Conc. Function D185 0.050 gal/sk blend Dispers.LT Thickening Time Schedule 9.2-1 (Bc) at (hr:mn) Compressive Strength Schedule () (psi) at (hr:mn) Page 15 SP08-N7.cfw;08-28-2013: LoadCase 13 3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2603.0 ft Casing Shoe :2623.0 ft NB of Cent. Used :24 NB of Floating Cent. :16 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 1903.0 15 1/3 NW-ST-13 3/8-8-ST A3B W131 0.0 743.0 2623.0 9 1/2 NW-ST-13 3/8-8-ST A3B W131 27.8 2003.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-ST-13 3/8-8-ST W131 13 3/8 18.386 14.685 No Hannover 16.000 1225.21 2996.70 A3B ft 0 20 =0 60 80 100 Eet..e_- I I I -V -I At:.e-1 ++ ++ - ++ +� + -f- 111111111111111111111111111 I 11.11 Pipe Standoff Page 16 SP08-N7.cfw;08-28-2013: LoadCase 13 3/8in Surface Casing:Version wcs-cern472_05 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 13 3/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 6: WELLCLEAN II Simulator ft Bio ok 0 fin 100 I I 100 - Std Betw. Cent. —Mud Contamination —Cement Coverage —Uncontaminated Slurry L G G -.20110111 fl..../••••••••• -"ROW' G — G G' C r, r, Cement Coverage Uncontaminated Slurry Page 17 SPOt-N7.cfw;08-28-2013: LoadCase 13 3/8in Surface Casing;Version wcs-cenn472_05 Client : Eni Petroleum Well : SP08-N7 Sciimierger String : 133/8 Surface Casing District : Prudhoe Bay Country : USA Loadcase : 13 3/8in Surface Casing Section 7: operator summary MIXING PREPARATION MUDPUSH II Volume: 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.046 bbl D182 552.278 lb 6.000 lb/bbl of base fluid D047 20.000 gal 0.200 gal/bbl of spacer D031 9536.741 lb 95.37 Ib/bbl of spacer 12.5ppg DeepCRETE Surface Tail Volume:63.0 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend: 22786 lb Design Mix Water 29.4 bbl 10.0 bbl LAS Design 12.5-0.82-53 22604.963 lb Fresh water 29.445 bbl 10.001 bbl D046 45.210 lb 0.200%BWOB D065 56.512 lb 0.250%BWOB D167 56.512 lb 0.250%BWOB D153 22.605 lb 0.100%BWOB Surface Lead Volume:486.1 bbl Density : 10.70 lb/gal Yield :2.44 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix Water 305.6 bbl 10.0 bbl LAS Design 0.050 gal/sk blend Page 18 SPOB-N7.cfw;08-20-2013; LoadCase 13 3/Bin Surface Casing:Version wcs-cen472_05 Schlumberger CemCAD E*well cementing recommendation for 9 5/8 Intermediate Casing Operator : Eni Petroleum Well : SP08-N7 Country : USA Field State : Alaska Prepared for : Lara Occhionero Location : Spy Island Proposal No. : v2 Service Point : Prudhoe Bay Date Prepared : 8/28/2013 Business Phone : (907)659 2434 FAX No. Prepared by : Stephen Lauper Phone : (907)273-1765 E-Mail Address : slauper@slb.com O 04, ZVATE Disclaimer Notice: Schlumberger submits this document with the oenefit of its Judgment,experience,and good oilf field practices. This information is provided in accordance with generally accepted industry practice,retying on facts or information provided by others.limitations,computer models,measurements.assumptions and inferences that are not infallible. Calculation are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTNENESS OF MATERIAL,PRODUCTS OR SUPPI IES,RECOMMENMTIONS MADE.OR PESIA.TS OF THE SERVICES RENDERED Freedom from infringement of any intellectual property rights of Schlumberger or others is ncr to be interred and no imellectual property rights are granted hereby. Mark of Schlumberger Page 1 SPOB-N7.clw;0&28-2013; LoadCase 9 578in Intermediate Casing;Version wcs-cem472_05 • Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 8089.0 ft BHST : 90 degF Bit Size : 12 1/4 in ft (x 1000) psi < A & > 0 1 2 3 F•__ I I Siltstone—_- - • • • 'Sandstone. • • • r-, V . s. }l ,— — ___ — • i _ . ___ II c. ,...:_'Sandstone.::: ::::Sandstone'::: 1 c Well Lithology Formation Press Page 2 SPC8-N7.cfw;0&28-2013; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem47Z_05 Client : Eni Petroleum Well : SPOB-N7 Sallnierger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2623.0 13 3/8 68.0 12.415 Landing Collar MD : 8009.0 ft Casing/liner Shoe MD : 8089.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 8089.0 9 5/8 40.0 40.0 8.835 L-80 3090 5750 BTC Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 949.3 bbl (including excess) Max. Deviation Angle : 87 deg Max. DLS : 3.563 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 749.5 11.50 8.40 SV-4 Siltstone 1144.4 11.50 8.40 SV-3 Sandstone 1434.4 11.50 8.40 SV-2 Siltstone 2000.0 11.50 8.40 B/Permafrost Shale 2083.4 12.00 8.40 SV-1 Sandstone 2468.6 12.50 8.40 Ugnu Top(UG4) Shale 3168.4 12.50 8.40 UG-2 Coal Bed Shale Marke 5017.4 12.50 8.40 Lower Ugnu Shale 6256.2 12.50 8.40 Schrader Bluff Top Shale 6377.3 12.50 8.40 N Sequence Top Sandstone 6599.5 12.50 8.40 N Top Sandstone 6946.8 12.50 8.40 N Bottom Sandstone 7456.3 12.50 8.40 N Sequence Base Sandstone 8140.0 12.50 8.40 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1900.0 1814.2 32 0.7 2595.0 2430.0 50 1.2 8140.0 4021.5 90 1.7 Page 3 SP08-N7 cfw;08-28-2013: LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 5653'(1,000'above the"N" Sand Top) Original fluid Mud 9.50 lb/gal k: 5.97E-3 Ibf.s^n/ft2 n : 0.616 Ty : 8.86 Ibf/100ft2 Displacement Volume 607.3 bbl Total Volume 917.2 bbl TOC 5653.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 1195.1 4457.9 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 12.5ppg DeepCRETE 209.9 2436.0 5653.0 12.50 k:4.89E-3 lbf.s^n/ft2 n:0.960 Ty:15.95 Ibf/100ft2 Mud 607.3 0.0 9.50 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Static Security Checks: Frac 382 psi at 2623.0 ft Pore 140 psi at 2623.0 ft Collapse 2871 psi at 8009.0 ft Burst 5750 psi at 0.0 ft Csg.Pump out 67 ton Check Valve Diff Press 56 psi ft (x 1000)psi _ 0 3 —Hydrostatic —Frac —Pore G_ Fluid Sequence Static VNell Security Page 4 SP08-N7.ctw:0&18-2013: LoadCase 9 5/Bin Intermediate Casing:Version wcs•cem472_05 Client : Eni Petroleum Well : SP08-N7 Schlin rgnr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 3: pumping schedule - Spacer/Cement Max Rate is 7-BPM - (No significant amount of time to be spent outside of+/-0.2ppg Density Range) - Max Shut down time is 30-minutes; if time is being approached,contact Town Engineer - Max displacement Rate is 8-BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Mud to be thinned back prior to cementing - Maintain returns during cement job if possible - Attempt to follow highlighted flow rates as close as possible and within ranges specified o Please note variance from noted Rates in Job Report Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead w/Rig Pumps Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Line-up Cement Unit 12.5ppg DeepCRETE 6.0 209.9 35.0 209.9 80 Mix/Pump Cement Slurry(3-7 BPM) Pause 0.0 0.0 2.0 0.0 80 Shut Down Pumping Pause 0.0 0.0 3.0 0.0 80 Drop Top Plug Mud 8.0 400.3 50.0 400.3 80 Kick Out Plug w/Cement Unit Mud 3.0 207.0 69.0 607.3 80 Slow Rate If need to handle Returns Pause 0.0 0.0 5.0 0.0 80 Line up Rig Pumps Shut-In 0.0 0.0 3.0 0.0 80 Bleed Off/Check Floats Total 03:10 917.2 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 305 psi at 2623.0 ft Pore 140 psi at 2623.0 ft Collapse 2687 psi at 390.6 ft Burst 5469 psi at 0.0 ft Temperature Results BHCT 85 degF Simulated Max HCT 90 degF Simulated BHCT 76 degF Max HCT Depth 8089.0 ft CT at TOC 77 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time (hr:mn) 00:03 hr:mn Geo.Temp. Top of Cement (degF) 77 degF 1 83 degF Bottom Hole (degF) 76 degF 90 degF Page 5 SP08-N7.cfw:O8-28-2013; LoadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SP08-N7 Scilinberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated ECDs at Casing Shoe during Placement o DD pth= 8089 ft r) . Frac 1. I. :_._.__ 4. `n imil IrostatiG Dynamic , L 1._ . i- .111111111111•11 ILICIIM . �......>....�� 111 __■ �, s ...: m _=.11 ill 5�=' IN ■ - — inalalan _ - Ural ___ `- i .. _ r-t 1•--i�E _ al c, a _�•_" :=C"' 0 Ng 4 _ �___ __ :_ _ ___ _ : i�i�y I-rr �r� 11111111111111111111 �rr�_ rn - _ r.r mom a o C o_ __, i 1. _ _ mos c•— If—.17:0 7— 44" oo" 0 c6 r r r r r r r r r r 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 6 SPO8 N7.ciw;0828-2013: LoadCase95/8inIntermediate Casirtg;Version wcs-cem472_85 Client Eni Petroleum Well SPO8-N7 Sdillibrilli String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated ECDs at Previous shoe during Placement o Depth= 2623 ft Ci — Frac { Pore f 1 1 I I i t 1 t 11 t f trt '1 I i 1 i i f j j in c‘i mom Hvdrostati namic 1 o , - - _— __ Coo CD rn _ Qo ----- ------- } I } I Ilk u7 ' i 0_ _ of co -1*_ 0 co , , 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 7 SP08-N7 cfw;08-28-2013; loadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Surface Pressures during Placement — Calc.Ri ess. T-"-i 1---t -1----j _j_-_� Calc.Cen i — -- • -- 11 _ - .- 'g -1:0 -_ - __. __ I7 - 71- 1. .l . , :: : I: : ei ^N __innim.. -.. :. _ , o _ . _Eli_ , ai. - ...,^. min "EEl.._ I BrONMIN . .._ _ ... laia.ai s■�. MINN MI MI _ OM �...E al .3MI a�" .�1•11111 s ... Ii M.m 1 + T_ _a__a . 111110111 MI _-I_ L MI. 1 _ 1_ NI, _ _ _ CV nal II 6--_ I a._ c), t r r 0 25 50 75 100 125 150 175 Time(min) Page 8 SP08-N7ctw:08-202013; LoadCase95/8inIntermediate Casing;Versionwcs-cem412_05 Client : Eni Petroleum Well : SPOB-N7 Schlumberger String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Simulated Slurry Temperatures during Placement ti ro c° Last Sack Temp. j c er cnUro in AR BHCT I —) .--1 —N Nt- Ci 4 _ _— _ �______ __ o _ i .._ o — ..., in co- __ CD i �CO _o • __ �_ �_ _N 0 Lf) O p 1 . O N 1 jorp#0111 :Ti f a 0 N LO ( _ 00El LN lV CO O_ (\j O O O (D r r 1 r r r t M 0 25 50 75 100 125 150 175 Time (min) Page 9 SP08-N7 ctw.08-202013. toadCase 9 5/8in Intermediate Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : SP08-N7 Schi irgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Contingencies Any issue that occurs during cement mixing, pumping, and displacement must be approached in a step by step method. Anytime a stoppage in the job occurs it must be noted how much time can be allotted to fix any issue and calculate time remaining based off of Field Blend Testing. 1) If Losses prior to cementing a) Utilize CemNET(1-2 lb/bbl; 2 lb MAX) b) Attempt to establish Max Rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue:time<30 min c) If issue with mixing system—switch to back-up mixing system d) If issue with tri-plex pump—Cont.job with secondary tri-plex pump on unit. 3) Top Plug is not Bumped at calculated Volume a) Pump % shoe track volume MAX b) If Bump not seen, shut in and hold pressure 4) Mud Pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue: time<10 min c) Note displacement volume pumped by mud pumps:verify with Co. Rep/WSL d) Subtract pumped volume from total volume=volume pumped by Cement Unit e) Rig up hoses to get mud to Cement Unit i) Begin displacement with Cement Unit:volume verified by Co. Rep/WSL Page 10 SPOB-N7.dm,;08 28-2013; LoadCase 9 5/8in Intermediate Casing;Version wcs-cern472_05 Client : Eni Petroleum Well : SP08-N7 Schlim rgcr String : 9 5/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.50 lb/gal Rheo. Model : HERSCHEL_B. k : 5.97E-3 Ibf.s^n/ft2 At temp. :80 degF n : 0.616 Ty : 8.861bf/100ft2 Gel Strength : 32.02 lbf/100ft2 MUD Mud Type :WBM Job volume :607.3 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil : 0.0% Water : 96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k : 5.23E-2 Ibf.s^n/ft2 At temp. :80 degF n :0.324 Ty : 12.92 lbf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl 12.5ppg DeepCRETE DESIGN Fluid No: 3 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :4.89E-3 Ibf.s^n/ft2 At temp. :74 degF n :0.960 Ty : 15.95 lbf/100ft2 Gel Strength :(Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.5-0.82-53 Mix Fluid : 5.471 gal/sk Job volume :209.9 bbl Dry Density : 121.24 lb/ft3 Yield : 1.56 ft3/sk Quantity :753.11 sk Sack Weight : 100 lb Solid Fraction 53.3% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.471 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Thickening Time Schedule () 100 Bc at 06:58 hr:mn Compressive Strength Schedule () (psi) at (hr:mn) Page 11 SP08-N7 cfw:08-28-2013: LoadCase 9 5/13in Intermediate Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :8069.0 ft Casing Shoe :8089.0 ft NB of Cent. Used :67 NB of Floating Cent. :67 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 5409.0 0 0/0 0.0 5424.8 8089.0 67 1/1 1502395-9 5/8-6-POSITIVE W051 43.4 8089.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) 1502395-9 5/8-6- W051 9 5/8 12.000 12.000 Yes Houma N.A. N.A. N.A. POSITIVE (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft /0 _ 0 '0 60 80 100 -IA!..c't j o Q r•-, I •- ►� 1 _ ; ` I - i C Pipe Standoff Page 12 SP08Nl ctw;08-28-2013; LoadCase 9 5/8in Intermediate Casing;Version wcs-cema12_05 Client : Eni Petroleum Well : SP08-N7 Schlumberger String : 95/8 Intermediate Casing District : Prudhoe Bay Country : USA Loadcase : 9 5/8in Intermediate Casing Section 6: WELLCLEAN II Simulator opo o;G ft 0 fin 100 I I 100 —Std Sew.Cent. r ldud Contamination r; —Cement Coves ----Uncontaminated Slurry O_ O cn O- Cement Coverage Uncontaminated Slurry Section 7: operator summary MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.50 lb/gal Code Quantity Design Fresh water 90.625 bbl D047 20.000 gal 0.200 gal/bbl of spacer D182 543.750 lb 6.000 lb/bbl of base fluid D031 11722.021 lb 117.22 lb/bbl of spacer 12.5ppg DeepCRETE Volume :209.9 bbl Density : 12.50 lb/gal Yield : 1.56 ft3/sk Dry Phase Liquid Phase Blend : (Ib) Design Mix Water 98.1 bbl 10.0 bbl LAS Design 12.5-0.82-53 75310.563 lb Fresh water 98.097 bbl 10.001 bbl D046 150.621 lb 0.200%BWOB D065 188.276 lb 0.250%BWOB D167 188.276 lb 0.250%BWOB D153 75.311 lb 0.100%BWOB Page 13 SPmm-N7.clw;08-28-2013; LoadCase 9 5Bin intermediate Casing;Version vas-scold/2_05 String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Surface Casing 13 3/8",68.000 ppf,L-80 BTC,L-80 32.0-2856.0 12.259 2.38 L 2.12 3.70 2.67 132,707 Total=132,707 L Conn Leak Burst Design(13 3/8"Surface Casing) Collapse Design(13 3/8"Surface Casing) Axial Design(13 3/8"Surface Casing) 850 - 850 850 U U U t 1700 - - .c 1700 t 1700 a a a a) a) a) 0 0 0 mm m 2 m 2550 - = 2550 - j 2550 • U rn w . N a) N 3400 3400 - 3400 - Design Load Line - Design Load Line - Design Load Line - Pi.e Ratin• - Pipe Ratin• - Pi.e Ratin• 2550 3400 4250 5100 0 750 1500 2250 400000 800000 1200000 1600000 Burst Rating (psi) Collapse Rating (psi) Axial Force(lbf) Minimum Safety Factors(13 3/8"Surface Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Burst Load Data(13 3/8"Surface Casing) 32 13 3/8",68.000 ppf,L-80 BTC,L-80 2.47 B5 L +100.00 Cl 5.26 A4 3.18 85 42 2.47 85 L +100.00 Cl 5.27 A4 3.18 85 Drilling Load: Pressure Test 160 2.46 B5 L 31.96 Cl 5.34 A4 3.18 B5 Test Pressure: 2000.00 psi 160 2.46 B5 L 31.95 Cl 5.34 A4 3.18 B5 Mud Weight: 9.20 ppg 300 2.46 B5 L 17.21 Cl 5.43 A4 3.17 B5 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 300 2.46 B5 L 17.21 Cl 4.30 A4 3.12 B5 700 2.44 B5 L 7.43 Cl 3.70 A4 2.94 B5 Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface 900 2.43 B5 L 5.81 Cl 3.76 A4 2.91 B5 Surface Pressure(1/3'BHP): 577.83 psi 1100 2.43 B5 L 4.80 Cl 3.83 A4 2.88 B5 Shoe Depth,MD: 2856.0 usft 1200 2.42 B5 L 4.42 Cl 3.87 A4 2.86 B5 Fracture Pressure at Shoe: 1598.50 psi 1300 2.42 85 L 4.11 C1 3.91 A4 2.85 B5 Fracture Margin of Error: 0.00 ppg 1500 2.41 B5 L 3.61 Cl 4.01 A4 3.04 B5 1900 2.40 B5 L 2.92 Cl 4.22 A4 3.00 B5 External Pressure: Fluid Gradients(w/Pore Pressure) 2087 2.39135 L 2.69 Cl 4.33 A4 2.74 B5 TOC,MD: 32.0 usft 2087 2.39 B5 L 2.69 Cl 4.33 A4 2.73 B5 Prior Shoe,MD: 160.0 usft 2200 2.39 B5 L 2.57 Cl 4.41 A4 2.72 85 Mud Weight Above TOC: 9.20 ppg 2300 2.39 B5 L 2.48 Cl 4.47 A4 2.71 85 Fluid Gradient Below TOC: 8.60 ppg 2400 2.39 B5 L 2.40 Cl 4.54 A4 2.70 B5 Pore Pressure In Open Hole: No 2532 2.38 B5 L 2.30 Cl 4.64 A4 2.69 B5 2600 2.38 B5 L 2.26 Cl 4.70 A4 2.68 B5 2700 2.38 B5 L 2.20 Cl 4.78 A4 2.68 B5 2800 2.38 B5 L 2.15 Cl 4.86 A4 2.67 85 2855 2.38 65 L 2.12 Cl 4.91 A4 2.95 B5 2856 2.38 B5 L 2.12 Cl 25.62 A5 2.96 B5 Collapse Load Data(13 3/8"Surface Casing) L Connection Leak Drilling Load: Full/Partial Evacuation B5 Pressure Test Mud Weight: 9.40 ppg Cl Full/Partial Evacuation A4 Overpull Force Mud Level,MD: 2856.0 usft A5 Green Cement Pressure Test(Axial) Assigned External Pressure: Fluid Gradients(w/Pore Pressure) External Pressure: Fluid Gradients(w/Pore Pressure) TOC,MD: 32.0 usft Prior Shoe,MD: 160.0 usft Fluid Gradient Above TOC: 9.20 ppg Fluid Gradient Below TOC: 8.33 ppg Pore Pressure In Open Hole Below TOC: No Axial Load Data(13 3/8"Surface Casing) Running in Hole-Avg.Speed: 0.7 ft/s Overpull Force: 150000 lbf Green Cement Pressure Test: 1000.00 psi Service Loads: Yes v String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Surface Casing 9 5/8",71.800 ppf,T-95 N/A 0.0-8140.0 7.969 5.96 7.09 6.45 5.71 286,366 Total=286,366 Burst Design(9 5/8"Surface Casing) Collapse Design(9 5/8"Surface Casing) Axial Design(9 5/8"Surface Casing) 850- 850 850 <n - U) U) - - t 1700- .c 1700 .c 1700 n - a a 0 0 i -c3 -D N - a) a) j 2550- = 2550 = 2550 to (0 N a) - a) a) 2 - 2 2 3400- 3400 3400 _ - Design Load Line I-sign Load Line - Design Load Line - - Pipe Rating • .e Ratin. - Pi.e Ratin. [ [ 111111 [ 1r ii [ 3500 7000 10500 0 4500 9000 13500 550000 1100000 1650000 Burst Rating (psi) Collapse Rating (psi) Axial Force(lbf) Minimum Safety Factors(9 5/8"Surface Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Burst Load Data(9 5/8"Surface Casing) 0 9 5/8",71.800 ppf,T-95 N/A 6.49 B5 + 100.00 Cl 7.99 Al 7.25 85 12 6.51 B5 + 100.00 Cl 7.99 Al 7.29 B5 Drilling Load: Pressure Test 30 6.51 B5 + 100.00 Cl 8.00 Al 7.30 B5 Test Pressure: 1990.00 psi 300 6.48 B5 94.08 Cl 8.03 Al 7.40 B5 Mud Weight: 9.20 ppg 300 6.48 B5 94.07 Cl 6.78 Al 6.71 Al Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 700 6.44 B5 40.49 Cl 6.45 Al 6.30 Al 1000 6.41 B5 28.57 Cl 6.47 Al 6.27 Al Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface 1200 6.39 B5 24.01 Cl 6.49 Al 6.25 Al Surface Pressure(1/3'BHP): 579.33 psi 1400 6.38 B5 20.80 Cl 6.50 Al 6.23 Al Shoe Depth,MD: 15738.0 usft 1800 6.34 B5 16.51 Cl 6.55 Al 6.20 Al Fracture Pressure at Shoe: 1855.54 psi 2500 6.27 85 12.17 Cl 6.68 Al 6.19 Al Fracture Margin of Error: 0.00 ppg 2595 6.26 B5 11.75 Cl 6.70 Al 6.19 Al 2595 6.19 B5 11.75 Cl 6.70 Al 6.19 Al External Pressure: Fluid Gradients(w/Pore Pressure) 2667 6.18 B5 11.46 Cl 6.71 Al 6.19 Al TOC,MD: 30.0 usft 2700 6.18 B5 11.33 Cl 6.72 Al 6.19 Al Prior Shoe,MD: 2594.8 usft 2900 6.15 B5 10.63 Cl 6.77 Al 6.20 Al Mud Weight Above TOC: 9.20 ppg 3000 6.14 85 10.32 Cl 6.80 Al 6.21 Al Fluid Gradient Below TOC: 8.60 ppg 3100 6.13 B5 10.04 Cl 6.82 Al 6.21 Al Pore Pressure In Open Hole: Yes 3200 6.12 B5 9.78 Cl 6.85 Al 6.22 Al 3300 6.11 85 9.55 Cl 6.87 Al 6.23 Al 3400 6.10 85 9.33 Cl 6.90 Al 6.24 Al 3500 6.09 85 9.14 Cl 6.93 Al 6.23 B5 3600 6.08 85 8.97 Cl 6.95 Al 6.19 B5 Collapse Load Data(95/8"Surface Casing) 3700 6.07 85 8.81 Cl 6.98 Al 6.15 B5 3800 6.07 85 8.67 Cl 7.01 Al 6.12 B5 Drilling Load: Full/Partial Evacuation 3900 6.06 B5 8.55 Cl 7.03 Al 6.09 85 Mud Weight: 9.20 ppg 4000 6.05 B5 8.44 Cl 7.06 Al 6.07 B5 Mud Level,MD: 8140.0 usft 4100 6.05 B5 8.35 Cl 7.09 Al 6.04 B5 Assigned External Pressure:Fluid Gradients(w/Pore Pressure) 4200 6.04 B5 8.27 Cl 7.12 Al 6.02 B5 4300 6.04 85 8.20 Cl 7.14 Al 6.01 B5 External Pressure:Fluid Gradients(w/Pore Pressure) 4432 6.04 B5 8.14 Cl 7.18 Al 5.99 85 TOC,MD: 30.0 usft 4432 6.04 B5 8.14 Cl 7.18 Al 6.37 Al Prior Shoe,MD: 2594.8 usft 5500 6.01 B5 7.71 Cl 8.05 Al 5.87 85 Fluid Gradient Above TOC: 9.20 ppg 6100 5.99 85 7.49 Cl 9.11 Al 5.81 B5 Fluid Gradient Below TOC: 9.20 ppg 6400 5.99 B5 7.39 Cl 9.84 Al 5.78 B5 Pore Pressure In Open Hole Below TOC: No 6700 5.98 B5 7.31 Cl 10.29 Al 5.75 B5 7000 5.98 B5 7.24 Cl 10.81 Al 5.73 B5 7277 5.97 85 7.19 Cl 11.48 Al 5.71 B5 7300 5.97 85 7.18 Cl 11.48 B11 5.71 B5 7302 5.97 85 7.18 Cl 11.54 Al 5.72 B5 7600 5.97 B5 7.15 Cl 12.53 Al 6.94 85 Axial Load Data(9 5/8"Surface Casing) 8139 5.96 B5 7.09 Cl 15.20 Al 6.92 B5 8140 5.96 B5 7.09 Cl 15.20 Al 6.92 B5 Running in Hole-Avg.Speed: 0.0 ft/s B5 Pressure Test Overpull Force: 0 lbf B11 Fracture©Shoe w/1/3 BHP at Surface Cl Full/Partial Evacuation Pre-Cement Static Load: Al Running in Hole-Avg.Speed Pickup Force: 0 Ibf Green Cement Pressure Test 1000.00 osi Yes 1 ENI PETROLEUM NIKAITCHUQ C885015-1 TUBING . 6.00 HEAD ADAPTER, 11� jjj"' I Iti ° Producer or Injector MB-247,ASSY,OFFSET, � �1 BM 4-1/2,SR137 VGRS Illik I :..4_� -• • 0._ .._ �[,- prA •if 20.81 20.81 4� _% s$ 0 i ��/" f'kj38.70 so: lam :9 I �h. 38.70ter„CAI /or ,,,44 ' (�`' 11.37 IllM' np, 11 i 25.64 27.16 • illi 1 qtly -Si. �'1' tt 1-', e. i f C885005-1 MB HEAD,ASSY, MB-247,UPPER, ;‘CAIF 13-5/8-5000 MOD STD BTM,13-5/8-5000 VG HUB TOP, :tow n Ingo C/W 12)2-1/16-5000 LOWER SSO W/1.900 ISO VR,IDI 4-1/16-5000 UPPER SSO W/4 HBPV 15 DEG OFF FROM ;M TWO HOLES CENTERLINE 'i`rt O ® i 11.37 1 (oa r 0 _4 12.31 C 20.63 25.64 - 1991101.111-il.l = 3 '° � 5 1 SU � II. 11.51 . n!� 20" X 13-s" X 9-s" X 4-z" j o o - -. - Normal Operations ISI C885003-1 MB,ASSY,MB-247,LOWER,Q D BTM W/ 17.0-4TPI ACME,13-5/8-5000 MOD FLG W/134 VGRS TOP,TWO 2-1/16-5000 SSO W/1.900 SHARP fIN VEE ISO VRT,ANNULUS OUTLETS 15 DEG.OFF FROM 10.92Ell I I CENTERLINE 13.44 .- 22.55 `+ hi ®_® .� 04.06 ` '` 22.13 17.13' '_ 1111111 30.69 .t - 21.301 X4.06 � 01' _--- 1 MN 10.251111 4 C885026-1 TUBING HGR,MB-247,OFFSET,ASSY,11 X 4-4,4.500 12.6#IBTM C885030-1 TUBING HANGER PART,MB-247,FALSE BOWL, BTM X 4.909-6TPI MCA LIFT W/4 HBPV,Ill HORZ OUTLET,A/F Ill PENT AND 131 ASSY,13-3/8 X 11 ARR FOR Ill HORIZONTAL 4.06 DIA OUTLET 3/8 CONT CMR LINES WITH ISOLATION SEALS 7.02 ft 13.' 14.95 . i 975"' 12.06 a�12.55 ? � 7 I 17.95 , I i 12.' � + T t --- ` H281504-23 PACKOFF ASSEMBLY,MB-247,12-13/161325,5MMI 1 ` "�� 5.19 X 9-5/8,WITH DOUBLE ELASTOMER SEALS H165239-1 CASING HGR ASSY,MB-243,18.19 X 13-3/8,FLUTED } MANDREL,13-3/8168 LBS)BUTTRESS BOX BTM,14.0-2TPI LH SA I I PIN TOP,W/W-H MULTI-BOWL HEAD LOCKDOWN ADAPTER RING 13.56 I I 3.44 I ` 8.76 20.00-+1 �. 1i 7 1111=14.38 18, f 22L87 � 1 .44 i i • 10.63 + T lfi C1020009-2 LANDING RING,ASSY,20 X 18.19,16.88 C885087-1 CASING HGR,MB-247,FLUTED MANDREL ASSY,12-13/16 X ID,75K 4130 FOR-50 DEG F,ARRANGE FOR 20 X 9-5/8,9-5/8 MOD BUTT.BOX BTM,10.375-2 TPI LEFT HAND STUB ACME 0.875 CONDUCTOR,C/W CENTERING SET SCREWS EXTERNAL LIFT S08146-1 16 GE imagination at work vetcog ray a GE Oil&Gas business ENI PETROLEUM NIKAITCHU Q :\ilf=6.->..0.. Producer or Injector Os is Eni C885015-1 TUBING HEAD ADAPTER,MB-247,ASSY,6.00 am. ��1 OFFSET,4-1/2,SR137 VGRS,VG CLAMP HUB BTM, A" � Jr_ 4-1/16-5000 D-6 STDD TOP,W/PENETRATOR PROFILE, W/1/2LPTESTPORT 11 �R�►'\ _ 1 "k1i11111= k ii) ® _ • if1 20s1 =aim.- 1 i f ( I2O sl1a ' � . 38.70 11..4* ---' 38.70 �' ° r' 7fliteit", "'1 I' " 11, 11,37 � , �, � •�.'• I4 �i�aT=_25.64 27.16 9I'Iu,ii � o N`:I a. ' ' ?�' 1 C885005-1 MB HEAD,ASSY, MB-247,UPPER, I' 13-5/8-5000 MOD STD BTM,13-5/8-5000 VG HUB TOP, C/W(212-1/16-5000 LOWER SSO W/1.900 ISO VR,Ill I I I I , I 4-1/16-5000 UPPER SSO W/4 HBPV 15 DEG OFF FROM I I 1 I TWO HOLES CENTERLINE I I r_ 747.117177 `" 11.37 I 3 5 1 - 12.31 20.63 20" X 13-8" X 9-8" X 4-2" an 25.64 'I 5.01 , =' Emergency Operations 11.51 .1111.11041?��r 0 O O . �� MIN i_l 10.92 NA C885003-1 MB,ASSY,MB-247,LOWER,Q D BTM W/ ��. 22.55maw. 17.0-4TPI ACME,13-5/8-5000 MOD FLG W/13404.06 1,14 22.13 ' VGRS TOP,TWO 2-1/16-5000 550 W/1.900 SHARP -VEE ISO VRT,ANNULUS OUTLETS 15 DEG.OFF FROMMill 30.69 `_CENTERLINE `' I 1 1 11.7 r 13.44 , . IL.-1- ski 17.13 �b4.06 � � C885026-1 TUBING HGR,MB-247,OFFSET,ASSY,11 X 4-i,4.50012.6#IBTM 21.30 1�r'ik BTM X 4.909-6TPI MCA LIFT W/4 HBPV,Ill HORZ OUTLET,AlF Ill PENT AND(31 �,.! 3/8 CONT CNTR LINES MIIIIIIIIIBM10.25 11 H-12.78--1 0885030-1 TUBING HANGER PART,MB-247,FALSE BOWL, -� `i!_+1 ASSY,13-3/8 X 11 ARR FOR Ill HORIZONTAL 4.06 DIA OUTLET O 7.+2 t- WITH ISOLATION SEALS 1347 1,52 k-18.19-- l 13.66 6.53 __ H281504-24 PACKOFF ASSEMBLY,MB-247,WITH EMERGENCY f 6.97 == BTM RING + , - 1.52 H275609-38 CASING HGR,QUICK DISCONNECT,18.19 X 13-3/8,SLIP TYPE,75K LA NACE F/-50 DEG SERVICE H115220-4- 12.78- iT 3.75 .---20.00--� 3.44 _k-12.75 7.44 4.38 18. 7.00 '��'- T 16.:, _i_____ Ulla 1-Mr. C1020009-2 LANDING RING,ASSY,20 X 18.19,16.88 ID,75K H275609-46 CASING HGR,MB-243,12-13/16 X 9-5/8,SLIP TYPE,75K LA 4130 FOR-50 DEG F,ARRANGE FOR 20 X 0.875 CONDUCTOR, NACE,W/INTEGRAL BLAST SLEEVE C/W CENTERING SET SCREWS 508146-2 0GE imagination at work V@tCOgray a GE Oil&Gas business • 2010 FIs operrarornns WELL ,-52'1241 .S1°&8 7iz +3 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 6 SURFACE SECTION 7 Surface Drilling 8 Surface Casing 11 Surface Cementing 14 Pick Up Intermediate Drilling Assembly 16 INTERMEDIATE SECTION 17 Intermediate Drilling 19 Intermediate Casing 20 Intermediate Cementing 23 Pick Up Production Drilling Assembly 25 PRODUCTION SECTION 26 Production Drilling 28 Production Liner 29 ATTACHMENTS 32 Recommended Drilling Practices 33 Health, Safety & Environment 34 Safety Meeting Topics 35 Well Shut In Procedure While Running Production Tubing 37 Conductor Broach—Contingency Cementing Plan 38 TAM PORT COLLAR Utilization Decision Tree 39 SP22-FN1 Drilling Wellplan Page 3 of 39 08/27/13 ros 2rn11 us operrarins WELL SP22-FN1 WELL PLAN SUMMARY Rig: Doyon 15 Type of Well: Producer Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 5-1/2"Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program& Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. SP22-FN1 Drilling Wellplan Page 4 of 39 08/27/13 2rnn n us operr hng WELL SPos -n!7 OBJECTIVES: 1. Drill the well at or under AFE cost and time. Perform work in a safe and professional manner meeting all ENI Petroleum Health, Safety, and Environmental requirements. 2.Land Intermediate casing point within 100' radius of the planned directional target. 3.. Land the Intermediate hole section with the targeted inclination of 85° -87°within the OA sand. Maximum dogleg severity in the landing shall be no greater than 3.5°/100' DLS. 4. Target Greater than 90% within the OA sand Reservoir. 5.. 8-3/4" hole LWD Failure Requirements: GR/Res/Dir/PWD— Require GR/Res/Dir to achieve TD. SP22-FN1 Drilling Wellplan Page 5 of 39 08/27/13 • eno• us operrahng WELL SP22-FN1 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (PPO Type (psi) (psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. ➢ Each conductor is to be marked with a common pad elevation survey mark by the surveyors ➢ Surveyors to also mark each conductor with a degree of angle to set each horizontal wing valve 2. Move in and rig up. Record move distance and rig floor distance to pad and sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N drive. • Ensure all concerned parties(Directional Drillers,MWD Operators, and Geologists)are using the same rig floor elevation. 3. Post drilling permit in the rig office and company office. 4. Nipple up the Vetco Gray landing ring,Vetco starter head,the diverter spool,and the annular preventer. Function test the system. ➢ Notify AOGCC prior to spudding well and 24 hours prior to performing diverter function test ➢ Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. ➢ Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area ➢ Place drip berm under the end of diverter line 5. Verify that two 3"threaded nipples have been welded on the conductor on opposite sides. Include ball valves and Cam-Lock male fittings on each nipple. Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: ➢ Assist in washing out surface casing hanger on cement jobs ➢ Take returns to Vac trucks while cementing ➢ Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Refer to the detailed MI-Swaco Mud Program(attached). SP22-FN1 Drilling Wellplan Page 6 of 39 08/27/13 ifs* • eno us op rarnns WELL SP2 - SOd - 1J7 SURFACE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (5) True Measured Formation Tops Vertical Comments Depth. ft Depth, ft SV-4 SO4 -46 SV-3 1195 ::_: SV-2 1488 1381 N Permafrost 2054 1801 SV-1 213- 1940 Ugnu Top (U-G4) 2521 2273 13-318" C s= .-zfrG6 3. 2454 q-rz-�3 SCP UG-2 Coal Bed Marker === 2833 Lower Ugnu f0-1 3524 Schrader Bluff Top 6310 3S15 N Sequence Top 6431 3815 N Top 6653 3880 ReCalc Intermediate Cement w Actual N Bottom 700 3934 N Sequence Base 7510 3986 9-5 8" Cs. 4019 ' ICP OA Sand Top :c4; 4022 OA-2 Top 8303 4028 5 1/2" Liner 15738 396- ✓ Total Depth SP22-FN1 Drilling Wellplan Page 7 of 39 08 27 13 is* rn� us operating WELL SP22-FN1 Surface Close Approach Wells NOTE: It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. Surface Mud Program: NOTE: Maintain Weight up Schedule as listed below to casing point API Fluid Density 6 RPM Chlorides Interval Depth Loss PH (ppg) Reading (ml/30min) 110'— 1800' $.8 -9.2 20—24 <8 <2000 9.0—9.5 Surface: 1800'—C.P. 9.2 9.5 20—24 <6 <2000 9.0—9.5 Surface Logging/Formation Evaluation Program: Surface: MWD Directional LWD GR/Resistivity Surface Drill Pipe Pipe WT Grade Conn. Tool Tool Body Make Up Joint Body DP Tensile (ppf) type Joint Joint ID(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (kips) (in) (ft lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Efforts should be made to minimize high doglegs in surface hole. ESP equipment will be damaged running through high doglegs. Inform the Drilling Engineer of any doglegs over 6 degrees per hundred. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections • Ensure lecithin is added to the mud system. SP22-FN1 Drilling Wellplan Page 8 of 39 08/27/13 • IfOs e o us operrafing WELL Sea- N 7 Surface Hole Procedure: 1. Pick up and drift all DP,HWDP,and DC's for surface section to confirm free of debris. 2. PU BHA(Include GWD if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA 3. Directionally drill surface hole: ➢ Drilling Parameters: • 650-800 GPM • Lower flow rates of 450-600 GPM will help avoid anti-collision boundaries by minimizing hole washout and optimize dog leg capability in the build section • RPM:40-80 RPM ➢ Avoid anti-collision boundaries ➢ Take MWD surveys as frequently as needed. Carefully review the anticipated close crossings with existing wellbores. Make sure that directional drillers are aware of all drilling close crossing issues,hardlines and no-go lines. If a no-go or hardline has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. ➢ Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas-cut mud before continuing to drill. • Due to expected gas hydrates,keep mud as cool as possible(cold lake water). • Control drill at 100 to 120 fph through any troublesome zone so the hole does not load-up with gas cut mud. • Check and report trip gas. • Have 2 ppb Lecithin on location prior to drilling below the permafrost to minimize the effects of hydrates on the mud if hydrates are encountered. ➢ Consider adding 0.5%Drilzone for screen blinding in shallow intervals right below the conductor. 5. Surface casing point: ➢ Landed in good shale found in this area between 2000' SSTVD and 2150' SSTVD ➢ Below the sand at the base of the Sagavanirktok Formation(SV-1). ➢ Inside the upper Ugnu(UG-4). > Drill the footage necessary to leave the appropriate amount of rathole below the casing shoe. 6. Backream out of the hole at surface casing point: > Circulate until shakers are clean(+/-3 to 5 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 800 GPM or higher • 80 RPM or higher ➢ Backream to the HWDP • 800 GPM or higher • 80 RPM or higher • Pull 5-10 feet per minute • Decrease backreaming speed as torque and pump pressure dictate. SP22-FN1 Drilling Wellplan Page 9 of 39 08/27/13 us op rrafing WELL SP22-FN1 • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • Expect+/-100%increase in cuttings from 1800'-600'. • Lesson Learned from:While backreaming out of the hole in the transition from horizontal to vertical, have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate ➢ Once the HWDP is reached,circulate until hole is clean(shakers clean) 7. Pull and lay down BHA. 8. Perform a dummy hanger run before running casing. SP22-FN1 Drilling Wellplan Page 10 of 39 08/27/13 PI* ern o us operrafing WELL step_A17 Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (PO Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface Casing Connection Make Up Torque (ft.lbs) OD WT Opt. (in) (PPOGrade Conn.Type Make Up Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running Notes a. Surface casing will be landed on hanger and emergency casing slips will be the contingency plan. b. Rig up and utilize a Fill Up tool for the casing job. c. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. d. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. Run 4"lines from side outlets on conductor to a Vac Truck to help reduce pack off problems and minimize chance of spill. It is preferable to pull casing out until circulation can be re-established rather than risk not getting cement to surface. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. e. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. f. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. 1. Inspect and drift all surface casing to 12.259". 2. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. 3. While RIH with the the Casing: D obtain SO Weights every 10 joints D obtain PU Weights every 10 joints SP22-FN1 Drilling Wellplan Page 11 of 39 08/27/13 1041 • en CI �s operrafing WELL SP22-FN1 4. Run the surface casing as follows: Surface Casing Running Order 1 Float shoe Bakerlock 2 2 joints 13-3/8"68#L-80 BTC casing Bakerlock 3 Float Collar Bakerlock 4 13-3/8"68#L-80 BTC casing ** TAM BTC port collar+/-500 ft Only run if losses are expected 6 13-3/8"68#L-80 BTC casing to hanger 7 Vetco Gray 13-3/8"mandrel hanger 13-3/8"landing joint Slick landing joint if not 8 running the TAM port collar **If TAM port collar is run: • A landing joint,which has a connection that can be broken below the rotary table,will need to be run to allow for running the drill pipe inside the 13-3/8"without needing a false rotary table. Also,the drill pipe running tool needs to be on location and stood back in the derrick ready to run in case the TAM port collar needs to be opened to circulate cement to surface. • If decision to run is at the last minute,ensure the additional footage of the port collar plus handling pup will allow for sufficient rathole below the surface casing shoe. Surface Centralizers +/- 18 13-3/8"Tandem Rise Weatherford SP22-FN1 Drilling Wellplan Page 12 of 39 08/27/13 11* WELL SP22-FN1 Surface Centralizer Placement C 10' Float 13-3/8" x 16" Tandem Rise Centralizers Collar • 2 at 5'&8' above Float shoe on stop collars,using stop buttons or stop collars. • No centralization on collar of 1"joint. • 1 at 10'above Float Collar,using stop buttons or stop collars. • From 3rd joint through tail slurry(500'tail slurry),1 centralizer per joint run on collars. Do not allow centralizer to float between collars. • 2 on 13-3/8"casing collars,inside conductor @ TD so csg can be reciprocated. } 8' � C 5' SP22-FN1 Drilling Wellplan Page 13 of 39 08/27/13 fff* ( rnn o operatuns WELL SP22-FN1 Surface Cementing Program Section Casing Size Type of Fluid / Cmt Volume Properties Mudpush II 100 bbls Density10.1 ppg Lead Slurry Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) 433 bbls Yield 2.33 ft3/sk Tail Slurry Density 12.5 ppg (DeepCRETE) 63 bbls Yield 1.50 ft 3/sk Top of Tail @ 2,514'MD Surface Cementing Casing Cementing Notes a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. b. Use split landing joint if TAM port collar is utilized and needs to be opened by running tool on drill pipe. 1. After reaching bottom, rig up and circulate with casingon bottom at 5 bpm, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if necessary. D To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to YP < 20 lb/100ft2 prior to cementing the casing but after the casing is on bottom. Have adequate supply of cold lake water on hand to ensure the desired rheologies can be achieved. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. Cement volumes are based on 35%excess below the Permafrost and 190%excess in the Permafrost. D If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool D If necessary,rack TAM running tool in derrick and ready to run D Hook up or install a water inlet below the landing ring(to the 3"threaded nipples)and the mandrel hanger to add water to clabbered mud returns when necessary. > Run 4"lines x-over from 3"side outlets to a vacuum truck. ■ Include a tee to allow for cement sampling 4. Report the number of bbls of cement returned to surface: ➢ Task one person to be in charge of monitoring for cement returns and volume of cement returns ➢ Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement at 8.5 bpm maximum. 8. Drop circulation rate to 3 BPM for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. ➢ Do not over displace the cement(no more than''Y2 the shoe joint volume). SP22-FN1 Drilling Wellplan Page 14 of 39 08/27/13 • us opera rung WELL SP22-FN1 ➢ Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. ■ The pack off problem has occurred on some offset wells when the hanger by-pass area was restricted. ➢ In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ If there is any doubt about the proper orientation,call the Drilling Superintendent. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. ➢ Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8" 5M BOP stack and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC SP22-FN1 Drilling Wellplan Page 15 of 39 08/27/13 • enn us operating WELL SP22-FN1 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. Pick up: ➢ 12-1/4"bit • Rotary Steerable • PWD • GR/RES ➢ Flow rate of 900 GPM ➢ 120—140 RPM 2. RIH to top of float equipment and pressure test surface casing to 2500 psi for 30 min and record on chart. ➢ Plot Casing Pressure Test on LOT form on N drive. Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. ➢ Note: All BHA trips thru the TAM port collar(if applicable)should be done slowly with slow rotation to avoid accidentally opening port collar. If set-down weight is noted,stop immediately,PU,resume slow rotation and try slacking off through port collar area. 3. Drill out the float collar&shoe. ➢ See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 4. Drill 20'-50' of new hole using spud mud. 5. Displace hole to new LSND mud system. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(less than 11.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Plot on LOT form on N drive. • SP22-FN1 Drilling Wellplan Page 16 of 39 08/27/13 e n o• us oyer has WELL SP22-FN1 INTERMEDIATE SECTION Surface Formation Markers: (all depths Doyon 15: Schlumberger Plan (5'1 True Measured Formation Tops Vertical Comments Depth. ft Depth. ft S'V 4 SO4 -46 SV-3 119S 1121 S'"-2 14SS 13S1 Bi Permafrost 2054 1501 S'--1 213- 1940 L gnu Top (LG.t) :5:1 == _- 13-3 8" Csg , 23 2454 SCP UG-2 Coal Bed Marker 3222 )833 Lower L-gnu 50-1 3'5:4 Schrader Bluff Top 6310 3515 N Sequence Top 6431 3515 N Top 6653 3880 ReCalc Intermediate Cement w Actual N Bottom 7000 3934 N Sequence Base 7510 3956 9-5 8" Csa 8089 4019 • ICP OA Sand Top 5193 4022 OA-2 Top 5303 4025.1 5 1 2" Liner 15738 = " Total Depth SP22-FN1 Drilling Wellplan Page 17 of 39 08/27/13 if* e us operating WELL SP22-FN1 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the"N" sand Density 6 RPM API FL Drill Solids Interval PV pHoMBT (ppg) Reading (ml/30min) (/o) Intermediate: 9.2—9.4 12-18 12-18 <6.0 9-10 <6.0 <18 Intermediate Logging/Formation Evaluation Program: Intermediate: MWD—Directional/PWD(Pressure While Drilling) LWD—GR/Res Intermediate Drill Pipe Tool Tool Make Up Joint Body DP Tensile Pipe WT Grade Conn. Joint Joint Body Torque Torsion Torsional capacity Capacity (ppJ) Type OD ID(in) al Yield Yield w/conn. (in) ID(in) (Albs) (ft Ibs) (ft.lbs) (gal/ft) (kips) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 5"HWDP 49.5 Intermediate Section Notes: a. If the well is to be an ESP producer,a pump tangent must be placed in the intermediate hole section as per the planned directional profile. The pump tangent must be within 300' TVD from the top of the uppermost OA sand and at least 200'MD in length. b. Efforts should be made to minimize high doglegs above the pump tangent(if applicable). The ESP equipment will be damaged running through high dog legs(>6 degrees per hundred). c. Shallow test MWD tools. d. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. e. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. f. Keep shut down times to a minimum during connections. g. Swab/Surge: Make"easy on,easy off'slips a standard practice h. Control the ROP if necessary to maintain good hole cleaning i. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. SP22-FN1 Drilling Wellplan Page 18 of 39 08/27/13 2n us operahns J WELL SP22-FN1 Intermediate Drilling 1. Directionally Drill 12-1/4"hole ➢ Use the following Parameters: • Flow rate of 900 GPM • 120-140 RPM 2. Casing Point: Land Intermediate casing 50' into the 0A2 sand reservoir 3. LOW ROP: Consult with Town as ROP drops to< 1-2 ft/hr for one(1)full hour. This usually occurs in the Lower Ugnu at high tangent angles(+80 degrees). Goal is to avoid excessive BHA and DP wear. Decision should be made to trip BHA out of the hole before excessive wear begins. 4. Backream at Intermediate Casing point: ➢ Circulate until shakers are clean(+/-5 to 7 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 900 GPM • 120-140 RPM ➢ Backream into the surface casing shoe. • 900 GPM • 120 RPM • Slow backreaming speed when pulling into the surface casing shoe/rathole. Hold parameters steady at 900 GPM and 120 RPM. Large chunks of coal can be deposited in the 16"rathole near the shoe. • Lesson Learned from OP09-S 1:While backreaming out of the hole in the transition from horizontal to vertical,have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. Check drilling nipple for overflow at BOP's. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the surface casing shoe. Do not attempt to pull out on elevators once backreaming has started. ➢ Circulate until shakers are clean(+/-3 to 7 bottoms up per K&M model)in the surface casing shoe • 900 GPM • 120 RPM 5. Pull and lay down BHA. SP22-FN1 Drilling Wellplan Page 19 of 39 08/27/13 co* • en II us operat'ns WELL SP22-FN1 Intermediate Casing Program: (all depths feet RKB) OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (ppb Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) **Special 9-5/8 40 L-80 H561 10.625 8.835 Drift 3090 5750 916 3 8.75 Intermediate Connection Make Up Torque (ft.lbs) Min. Target Max. OD (� Grade Conn. Type TMque�Up ft- Make Up Make Up Yield Torque lbs(in) Torque Torque 9-5/8 40 L-80 H56d31 10,800 13,000 N/A 75,000 **Special Drift casing to 8.75 Intermediate Casing Interval Notes: a. Ensure proper sized rams are installed and tested prior to running intermediate casing. b. Rig up and utilize a casing fill up tool for the casing job. Shoe Track: 1. Have a spare float shoe and collar made up with centralizers and on location ready to go D Shoe joint misalignment has caused cross threading with Hydril 563 connection and requires make up by hand for first 10-15 joints • Make-up Shoe track(and first 10-15 joints)by hand using chain tongs until enough weight is in the slips to prevent cross threading • The shoe track joints should be Bakerlocked. • Inspect the float valves as the shoe track is picked up. • Run the shoe track into the well to test and confirm the floats are holding negative differential pressure. Connection Make Up: 1. Refer to the TenarisHydril"Running Manual General Guidelines"attachment for make up,pipe dope,etc....(Also available on Tenaris website) 2. Make up the first joint to the specified target torque and relax the tongs. > Draw a longitudinal line across the pin and box and reapply the published target torque. ➢ If the drawn line does not move more than'h"after the second torque application,continue running the rest of the string normally using the published target torque. > If the drawn line moves more than'h"after the second torque application,this indicates that a portion of the torque was absorbed by other variables in the make-up system.If this occurs,follow these steps: • Increase the target torque by 15%and reapply the torque. • Draw a second line and apply the original,specified target torque. • If the second drawn line does not move more than''/",continue running the rest of the string normally using the 15%higher target torque. • If the second drawn line moves more than 1/2",recheck the alignment,dope application and tong function, then continue to repeat this procedure from above until the drawn line does not move more than 1/2". SP22-FN1 Drilling Wellplan Page 20 of 39 08/27/13 • 119* 2n us operating WELL SP22-FN1 ■ It is best practice to repeat this procedure in the event the tongs are changed out during the running of the pipe. 3. Ensure that the joint about to be made up is hanging along the same axis as the joint in the slips. Due to the fact that sometimes the rig is a few inches off center the slips and bell nipple may have to be adjusted. Casing Running Order 1 Float shoe—Davis-Lynch Model 501-DV-PVTS Baker Lock down jet float shoe(double valve)**** 2 2 joints 9-5/8"casing Baker-Lock Float Collar—Davis-Lynch Model Type 700 DVSB- 3 LAPN double-valve float collar w/anti-rotation Baker-Lock baffle**** 4 9-5/8"Casing 5 9-5/8"Casing 6 Vetco Gray 9-5/8"mandrel hanger 7 9-5/8"landing joint Slick landing joint for reciprocation purposes Centralizers +/-38 9-5/8"x 11-3/4"Rigid Hydroforms(Floating) Volant 1. Inspect and drift intermediate casing(drift 8.75"). 2. Centralizers(See Diagram Below) 3. Pull wear bushing. Install 9-5/8"rams and test. Pick up and run casing. 4. Monitor running speeds to minimize surge and swab pressures while running in or picking up off slips. ➢ K&M Engineer will provide a trip speed schedule for each intermediate casing run based on individual well mud properties,hole angle,and depth. ➢ Circulate casing capacity at surface casing shoe,then break circulation every+/-2,000' MD and check flow through floats. Circulate bottoms up each time. ➢ Monitor trip tank while running in hole. Reduce speed if decrease or loss of flow is noted. 5. While running in open hole with Casing: ➢ obtain SO Weights every 10 joints 6. Once on bottom with the casing: ➢ obtain PU and SO Weight 7. Run the casing string on bottom. Establish circulation rate and pressure while pumping at least 1-2 bottoms up to condition hole. Reciprocate casing while circulating and cementing. 8. If needed,circulate and thin mud to properties slightly as outlined in CemCADE and Mud plan summary after running casing to bottom and prior to pumping cement. SP22-FN1 Drilling Wellplan Page 21 of 39 08/27/13 fo* • • en us opere ns WELL SP22-FN1 Intermediate Centralizer Placement _ 1 l 10' moat 9-5/8" x 11-3/4" Hydroform Centralizers Collar Run 1 Hydroform: • On Stop collar 5'above Float shoe. • No centralizer on next joint l • On Stop collar 10'above Float Collar. • From 4th joint to+/-1000' above the shoe- 1 centralizer floated between collars • 1 centralizer floated between collars from N sand oil bearing zone to+/-500' above N sand oil bearing zone - 111 C1 O SP22-FN1 Drilling Wellplan Page 22 of 39 08/27/13 rfAis en �s operraing WELL SP22-FN1 Intermediate Cementing Program Section Casing Size Type of Fluid/ Cmt Volume Properties Intermediate 9-5/8" Mudpush II 70 bbls Density 10.5 ppg DeepCrete 218 bbls Density 12.5 ppg Top of Cement @5377 MD Yield 1.50 ft3/sk Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. If need be,confer with Drilling Superintendent. b. Do not over displace the cement(no more than''Y2 the shoe joint volume). c. For injectors,a cement bond log is required. Prefer to run sonic LWD in production hole BHA and log intermediate casing on trip in hole to drill out intermediate shoe. 1. Perform Rig pump efficiency check and confirm+96%efficiency before pumping and displacing cement. 2. Ensure Schlumberger re-calculates cement volume based on"N"sand actual depth! D Cement volume is based on 50%excess and at least 1000'of annular fill above top of the N sand(highest known hydrocarbon bearing zone). Refer to attached cement detail sheet for volumes. 3. Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program. 4. Displace cement with rig pumps and LSND water-based drilling mud. D Ensure that the cement unit and rig pumps are manifolded so there will be redundancy in case of any pump failure during displacement. D. Pump cement at 5 bpm and displace with 8.0 bpm if possible without losing returns. Slow rate to 3 bpm during last+/-30 bbls prior to bumping plug. 5. When the plug bumps,pressure the casing to 500 psi over the final displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 6. Land casing on mandrel hanger D Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. D Do not exceed 80%of intermediate casing collapse D Record test on IADC report and in WellView • eni us operating WELL SP22-FN1 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. ➢ Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. ➢ Pressure limitations are as follows: 80%of surface burst or 80%of intermediate collapse,whichever is less. ■ 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) ➢ Freeze protect the surface by intermediate annulus with diesel at 1-1/2 to 3 BPM. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 11. Install wear bushing. 12. Clean mud pits in preparation to receive OBM • Pits must be clean and free of all Barite SP22-FN1 Drilling Wellplan Page 24 of 39 08/27/13 /otos us operrarornng WELL SP22-FN1 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly as per the attached BHA diagram. ➢ 8-3/4"PDC ➢ Rotary Steerable ➢ Flow rate: 550 GPM ➢ 120— 140 RPM 2. RIH to the float equipment. > Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). ➢ Plot Casing Pressure Test on the Pressure LOT form in N drive Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid ➢ Do not contaminate new OBM in rig pits ➢ Displace old water based fluid to trucks or exterior tanks for disposal 4. Drill out the float collar&shoe. > See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50' of new hole using the Oil Based Reservoir Drill-In fluid. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. > If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). > If LOT is unacceptable to drill ahead(less than 12.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. ➢ Plot on LOT form in N drive SP22-FN1 Drilling Wellplan Page 25 of 39 08/27/13 �_ ( f O us operating WELL SP22-FN1 PRODUCTION SECTION Surface Formation Markers: (all depths Dovon 15: Schlumberger Plan (5) True -Measured Formation Tops Vertical Comments Depth, ft Depth, ft S1--4 50- -46 SV-3 1198 1121 SV--2 1185 13S1 B Permafrost 2054 1 801 SV--1 2137 1940 Ugnu Top (UG4) 2521 22-3 13-3.8" Csg 2662 2454 SCP 1L-G-2 Coal Bed Marker 3222 2833 Lower t-gnu f0-1 3524 Schrader Bluff Top 6310 3815 N Sequence Top 6431 3815 N Top 6653 3SSO ReCalc Intermediate Cement w- Actual N Bottom -00o 3934 N Sequence Base 7510 39S6 9-5 8" Csg 8089 4019 ICP OA Sand Top 8193 4022 OA-2 Top 8303 4028.1 5 1:2" Liner :..7.--; 3967 Total Depth SP22-FN1 Drilling Wellplan Page 26 of 39 08/27/13 10* en II uss operafi nns WELL SP22-FN1 Production Mud Program: FazePro Density HTHP FL Electrical Interval YP Oil:water Stability (I)Pg) (mU30min) mlVolts Production 9.2 14-20 <5.0 65:35 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD(Pressure While Drilling) LWD GR/Res/ADN/PeriSCOPE Production Drill Pipe Tool Joint Body DP Tool Pipe Tensile WT Grade Conn. Joint Joint Body To Make Torsion Torsional capacity Capacity (ppb type OD ID(in) al Yield Yield w/conn. (in) ID(in) (ft.lbs) (t lbs) (ft.lbs) (gal/ft) (fps) 5"DP 19.5 S-135 TT525 6.50 3.875 4.276 49,600 82,700 74,100 .731 712 Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. d. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. e. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Openhole Sidetrackine Practices: f. Lowside in a fast drilling interval where the wellbore is heading up and where the ABI's show a good build rate. g. Orient within 15 degrees either side of lowside and trough with high rotary RPM's while reciprocating from the kickoff point back to the first stabilizer. Trough for approximately 30 minutes. h. Time drill at 4 to 6 feet per hour with high flow rates and rotary RPM's for the first 5 feet. Gradually increase the penetration rate as the openhole sidetrack is achieved. i. If any openhole sidetracks are drilled,confer with Drilling Supt.and consider tripping without circulating or without rotating past the sidetrack point. SP22-FNI Drilling Wellplan Page 27 of 39 08/27/13 en o us operaing WELL SP22-FN1 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. ➢ Geosteering will be required to remain in the target boundary 100%of the time ➢ Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. ➢ Maintain proper Calcium Carbonate concentration per MI mud plan. • Ensure Centrifuges are operating effectively to remove fine drill solids 2. Backream at TD: ➢ At TD circulate 50%of calculated TAD cleanup cycle pulling 1 stand per bottoms up. Once the first 50% cleanup cycle is completed circulate the remaining 50%of the calculated cleanup cycle pulling 2 stands per bottoms up. Decrease backreaming speed as torque and pumpPressure dictate. • 550 GPM • 120-140 RPM ➢ Backream into the intermediate casing shoe. • 550 GPM • 120-140 RPM • Slow backreaming speed when pulling BHA into the Intermediate casing shoe/rathole. Hold parameters steady at 550 GPM and 120 RPM. • Decrease backreaming speed as torque and pump pressure dictate • NOTE: once backreaming in the open hole has been started,do not stop backreaming. Do not attempt to pull out on elevators once backreaming has started. 3. Drop rabbit down drill string once bit is above the intermediate shoe:the SLM of landing string portion of the tapered DP • Drift OD dependent on Completion • COMPLETION DP RABBIT SIZE: 2-3/8"OD • All drifting tools will be accounted for and held in one place at all times. 4. Continue backreamina until depth at which it is possible to pull out on elevators at>9.1 swab EMW at 2.5 min/stand • 550 GPM • 120-140 RPM • Determine depth at which swab can be kept>9.1 EMW at 2.5 min/stand as per K&M TAD Model. p p 5. Circulate until shakers are clean as per K&M. • 550 GPM • 120-140 RPM 6. Slug DP and trip out of hole on elevators. SP22-FN1 Drilling Wellplan Page 28 of 39 08/27/13 It* en II us operrafnng WELL SP22-FN1 ➢ Utilize K&M's swab model to control trip speed and avoid swabbing the open hole below 9.1 ppg EMW. 7. Lay down BHA ➢ When out of hole,down load the recorded tool data and send to the Geologist in town Production Liner Completion DP RABBIT SIZE Will BE: 2-3/8" OD Production Liner OD Conn. Cplg OD Collapse Burst Tensile Yield (in) WT(ppb Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) 5-1/2 15.5 L-80 5 dnl 5.713 4.950 4.825 4990 7000 242 Production Liner Connection Make Up Torque (ft-lbs) Mm. Target Max. OD WT Make Up Yield (in) (ppb Grade Conn. Type Torque, ft- Make Up Make Up Torque • lbs Torque* Torque 5-1/2 15.5 L-80 Hydril 521 4600 8100 N/A 24,000 * See attached TenarisHydril Guidelines for make-up torque recommendations Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 5-1/2"x 7" top -Mid joint -Crimped on -Hydroform,Volant(Crimp on) Liner Running Procedure Notes: • Ensure proper crossover from DP to slotted liner is on the rig floor in case of a well control situation. • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. • Ensure accurate torque and drag data is gathered. Record pick up and slack off weights every stand and free rotating torque every five stands. Data gathered will assist in future liner running operations throughout the project. • Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WellView. • Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. • Review all setting operations and shear pressures with Baker Oil Tools service hand. • Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools.Rabbit DP on last trip out of prior to running liner. • If any openhole sidetracks have been drilled,monitor sidetrack depths during run in and ensure shoe enters the correct hole. SP22-FN1 Drilling Wellplan Page 29 of 39 08/27/13 It* 2nd us operating WELL SP22-FN1 • DO NOT run E-CD subs on drill pipe while running liner string. • Torque ratings for string components: String Components Yield Torque(ft-lb) 5" 19.5#TT525 Drill Pipe 74,100 HRD Running Tool 40,000 7" 29#Hydril 563 39,000 5-1/2" 15.5#Hydril 521 24,000 • Shear pressures for liner hanger assembly: Item Description Shear Value Shear Range HRD Running Tool,7" Nominal- 3192 psi 15%+ 3671 psi 6795 mch rel,3 pins 15%- 2713 psi Pusher Tool Activation Nominal- 1986 psi 15%+ 2284 psi 15%- 1688 psi Pusher Tool Neutrlz. Nominal- 3588 psi 15%+ 4126 psi 15%- 3050 psi Ball Seat SOLID *****Make-up torque for liner hanger sub-assembly,including running tool connections,should be torqued to 14,000 ft-lbs prior to deliver to rig. Procedure: 1. Hold Pre job safety meeting to ensure all parties understand operation 2. PU the Liner Assembly and Running/Inner String as outlined above. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. Fill Liner Tieback Sleeve with"pal mix" and ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. Record ROTATE,PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIH with Liner Assembly as hole conditions allow,but do not exceed running speed of one stand per minute. Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Record PU, SO, and Rotating torque in open hole every 500' to ensure friction factors are sufficient to run the liner to bottom successfully. If friction trend indicates liner will not go to bottom then call Drilling Supt. immediately. 9. Rotating liner 20-60 RPM will be necessary to run to bottom. 10. Continue RIH with Liner Assembly to proper setting depth. Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"casing shoe. 11. Trip slightly deeper than desired liner top location with liner top. Last motion of the liner should be up to ensure it is set in tension. Ensure Liner Hanger assembly does not exit 9-5/8"casing shoe. 12. Prior to setting the hanger&packer,double check all pipe tallies and record amount of drill pipe on location. SP22-FN1 Drilling Wellplan Page 30 of 39 08/27/13 2n us operrahns WELL SP22-FN1 13. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. 14. Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 15. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 16. Packer can now be pressure tested. Bleed DP pressure to zero,close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 17. Bleed off pressure and pickup to verify that the HRD running tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, 6,795 ft-lbs of left hand torque can mechanically release the tool. 18. Once running tool is free and packer is tested,Displace mud from liner top to surface with 9.0ppg KC1 brine per MI recommended program. 19. POOH and LD and inspect the liner running tools. SP22-FN1 Drilling Wellplan Page 31 of 39 08/27/13 • eno• us operating WELL SP22-FN1 ATTACHMENTS 1. Recommended Drilling Practices 2. Health, Safety,and Environment 3. Safety Meeting Topics 4. Well Shut In Procedure While Running Tubing 5. Conductor Broaching Contingency Plan 6. Port Collar Decision Tree SP22-FN1 Drilling Wellplan Page 32 of 39 08/27/13 2n0 us operr zeins WELL SP22-FN1 Recommended Drilling Practices Hole Cleaning With a deviated well path and potential for losses,hole cleaning will require special practices. Pipe rotation is critical for effective hole cleaning. The maximum string RPM,as determined by the BHA,is specified for each hole section in the detailed procedures. The shakers should be monitored as an indicator of adequate circulating time. If circulation is of long duration,then pipe movement to prevent casing wear is critical and a stand should be laid down occasionally to prevent excess hole erosion over the length of pipe reciprocation. In addition the following practices should be employed at all times: a) Use all available solids control equipment to keep mud as clean as possible. b) Emphasize proper hole cleaning after slides by rotating at maximum allowable RPM c) As the hole angle increases,hole cleaning practices must be altered. Maximum pipe rotating speeds along with maximum achievable flow rates will increase hole cleaning efficiencies. Circulating times prior to trips should be increased accordingly to account for longer times required to remove cuttings from higher angle wells. d) Use good connection practices while drilling. After reaching the bottom of a stand,allow a small amount of circulating time to allow cuttings to get above the BHA prior to picking up off bottom. Be sure to pick up slowly to prevent packing off the cuttings bed around the top of the drill collars. Slower Trip/Connection Speeds High POOH and RIH speeds can aggravate fragile shales/formations due to the pressure variations between surge/swab. PWD data shows that excessive tripping and reaming speeds can exert pressure spikes in excess of 2 ppg equivalent. Effective ROP Strive to find the maximum effective rate of penetration.That is,the maximum rate at which a clean hole can be produced. While on bottom ROPs in excess of 400 fph may be possible,but such ROPs may load a high angle hole with cuttings that are not being removed fast enough. Using torque and drag trends,ECD and the shakers,establish a base line clean hole ROP,and then try to improve it by altering the hole cleaning practices. Slower Initial Pump Rates PWD data has shown that the most significant period for increased ECD occurs when the pumps are brought on at drilling rate while washing a connection to bottom. The study also concluded the least damaging procedure is if pump rates are held at 40%or less of drilling rate while reaming connections. SP22-FN1 Drilling Wellplan Page 33 of 39 08/27/13 Iff* 2nd us operaung WELL SP22-FN1 Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H7S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures,full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. SP22-FN1 Drilling Wellplan Page 34 of 39 08/27/13 PI* n0 us operating WELL SP22-FN1 Safety Meeting Topics Move In,Rig Up ➢ Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. > A'Diverting Shallow Gas'drill should be held with rig crews prior to spud,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ An'Accumulator'drill should be held with rig crews prior to spud. Document drill and record on morning report. ➢ Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. ➢ Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. ➢ Perform and document all drills. ➢ Designate crew member to control access at the pad entrance in case of diverter operation. Surface ➢ A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. > Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. > Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production > Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss production hole risks and open hole drilling procedures. > Potential formation pressures and mud weight,Well control procedures. > Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. SP22-FN1 Drilling Wellplan Page 35 of 39 08/27/13 ffiAtt 111 2rnln us operefing WELL SP22-FN1 D. Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Completion ➢ Operation of the control line spooler. D Pinch points associated with tongs and slips. ➢ Proper tripping practices and hole fill calculations with tubing and control line. ➢ Well control practices while running production tubing with control line. D Pressure testing and minimizing personnel exposure to pressurized lines. ii SP22-FN1 Drilling Wellplan Page 36 of 39 08/27/13 en o us operrarong WELL SP22-FN1 Well Shut In Procedure While Running Production Tubing If well is suspected to be flowing: 1. Install TIW valve and pull back to the first banding point below the BOP stack. 2. Shut off air to control line spool and bleed off line pressure while checking well for flow. 3. If well is confirmed to be flowing,cut control line with bolt cutters directly above a banding point. 4. Slack off until full joint of pipe with no control line attached is spaced out across BOP stack. 5. Close annular and monitor pressure. If well is coming in rapidly and time is not permitted to complete above operations: 1. Install TIW and close annular around pipe and control line. 2. Shut off air to control line spool and bleed off line pressure while picking up a joint of drill pipe and making it up to TIW and top drive. 3. Close IBOP on top drive and open TIW valve. 4. Cut control line and strip the joint of drill pipe across stack for ram closure if needed. 5. If annular does not seal off around tubing and control line and the joint of drill pipe cannot be safely picked up, close blind/shear rams on production tubing. Notes: 1 • Specify location of bolt cutters required to cut control line. • Need to have access to a joint of drill pipe and the appropriately sized elevators at all times. SP22-FN1 Drilling Wellplan Page 37 of 39 08/27/13 en0 us operrahng WELL SP22-FN1 Conductor Broach— Contingency Cementing Plan In the event of a broach to surface of drilling fluids during the drilling of the surface interval,the following contingency plan is recommended to remediate the situation. Conductor Hole Diameter Conductor Casing Size 20" Conductor Setting Depth +/- 120'MD DP/Conductor Annular Volume 5"DP x 18.25"ID: (36 bbls) Conductor Pipe Volume 39 bbls 16"Open Hole Capacity 0.2487 bbls/ft 1. Upon establishing that a broach of the conductor casing has occurred,POOH and stand back BHA. 2. RIH with open-ended drill pipe to 20' below the base of the conductor pipe. 3. Establish circulation with mud at normal drilling rate. Begin circulating and establish rate of flow through broach with drilling fluid. 4. Circulate up to 120 bbls of water or until water returns are seen from the broach. 5. R1H to 200'below the base of the conductor. If mud viscosity is<300sec/qt.,spot a 150'pill of 150K cp polymer (Biozan)to 50' below the conductor. POOH to 20' inside the conductor. 6. Mix and displace+/-80 bbls of Artic Set 1 cement at 15.8 ppg. Cement may U-tube with no ability to obtain squeeze. Do not over displace DP. Monitor and gauge all returns. 7. POOH and WOC for 8 hours. 8. PU 16"bit and BHA and RIH to clean out cement to 40' below conductor. Establish normal circulating rate and evaluate broaching. If no broaching is seen,continue with planned operations. If additional broaching occurs, repeat steps 6,7 and 8. SP22-FN1 Drilling Wellplan Page 38 of 39 08/27/13 • eno• us operating WELL SP22-FN1 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job No Cement -ment to to Surface ' Surface Drilling Foreman and Nipple Up and Engineer determine the x Test BOP's Top of Cement Top of / - - Cement Cement Continue wit' above Port below Port Completion / Collar Collar - (1000'TVD) (10o0'TVG., V 7 — X Indicators of Cement Top Perform Top Job as per ► pen Port Collar 1. Observation of Tracers in Spacer ahead of lead cement requirements of If Top Job is ineffective or using drillpipe p AOGCC unacceptable to AOGCC 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up andirculate Cement Test BOP's Ito Surface and 'lose Port Collar Continue with Nipple Up and Completion Test BOP's Continue with Completion SP22-FN1 Drilling Wellplan Page 39 of 39 08/27/13 TRANSMITTAL LETTER CHECKLIST WELL NAME: & i k c i"(1,w 0�-N 7- : PTD. c1.1 3 1M /Development _Service _Exploratory _Stratigraphic Test Non-Conventional FIELD: l,�111a.l-tel, POOL: l�t�J� Cc.,1 c.� /b.J J 3Q--i © ) ---i l' Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo m also required for this well: gg g / Requirements Per Statute AS 31.05.030(dX2XB) and Regulation 20 AAC 25.071, V composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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M CO N N O 0) p r CO CN 0 U C CO CNI re co ,O CI C 0) D V co a) w -Cr--) a �, ° 'E d M 0 2 .I N N N m O C W OIE a c a -J 0 Qa 0 a s a w a ( a Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: November 18, 2013 Surface Data Logging End of Well Report SP08-N7 SP08-N7L1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Show Reports 7. Mud Record 8. Bit Record 9. Morning Reports 10. 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: ENI Petroleum Rig: Doyon 15 Well: SP08-N7 & SP08-N7L1 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23501-00-00 (SP08-N7) 50-629-23501-60-00 (SP08-N7L1) Sperry Job Number: AK-AM-0900797980 Job Start Date: 02 October 2013 Spud Date: 03 October 2013 Total Depth: 15,870’ MD, 3997’ TVD (SP08-N7) 15,977’ MD, 4009’ TVD (SP08-N7L1) North Reference: True North Declination: 19.643° Dip Angle: 81.049° Total Field Strength: 57632 nT Date Of Magnetic Data: 27 Oct 2013 Wellhead Coordinates N: North 70° 33’ 28.12597” Wellhead Coordinates W: West 149° 54’ 15.23805“ Drill Floor Elevation 53.93’ Ground Elevation: 13.10’ Permanent Datum: Mean Sea Level SDL Engineers: A. Paul Kalenuik, Leigh Ann Rasher, Kori Jo Plowman, Martin Nnaji, Jeremy Tiegs SDL Sample Catchers: Jade Miller, Hilary Garney, Jason Ostrem, Jeff Manook Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 DAILY SUMMARY 10/02/2013 SDL continues on location from previous well. Spot and set mudlogging shacks. Wait on the unit to warm up before rigging up. Pipe shed was loaded with drill pipe and heavy weight drill pipe. Began rigging up and ran gas line to the unit. Rig up network connection with MWD and WITS to Canrig. 10/03/2013 Pick up BHA #1 and fill conductor with spud mud. Pressure test surface equipment and clean out conductor to 160’ MD. Lay down clean out BHA and picked up BHA #2 and drilled ahead to779’ MD as of midnight. Gas: The max gas was 11 units at 720’ MD. The average gas was 5 units. Geology: Spot sample was 80% sandstone, 10% clay, and 10% shale 10/04/2013 Continue drilling 16” surface section from 779’ MD to 2659’ MD. Gas: The max gas was 180 units at 2318’ MD. The average gas was 73 units. 10/05/2013 Rig up casing equipment for surface casing. Make up 13 3/8” shoe track and test FC equipment. Run casing from 122’ MD to 633’ MD. 10/06/2013 Run casing from 633’ MD to 2640’ MD. Pick up and mak e up landing joint, break circulation and land hanger shoe at 2677’ MD. Cement surface casing and lay down landing joint. Calibrate gas gear and test it for accuracy. It is operating within normal parameters. 10/07/2013 Loaded shed with BHA #3 and made up 5” drill pipe stands via the mouse hole. Then racked 180 joints drill pipe onto the derrick. Tested BOP’s and then set the wear bushing. Then rigged down testing equipment and pulled up the BHA tools to the rig floor. 10/08/2013 Pull up BHA #3 per Directional Driller and MWD using Scorpion torque unit. Then loaded 9 5/8” casing in pipe shed and repaired top drive leak. Pulled up 4.5” drill pipe via the mouse hole and racked in the derrick. 10/09/2013 Pick up BHA #3. Run in hole to 1012' MD and perform MWD shallow hole test at 650’ MD. Continue to run in hole and tag float at 2594' MD. Drill out 13 3/8" shoe at 2674' MD. Drill 20' rat hole to 2712' MD. Gas: The max gas was 26 units. The average gas was 3 units. Geology: 90% sandstone and 10% clay. 10/10/2013 Cut and slip drill line. Run in hole and begin to wash and ream from 2611' MD to 2719' MD. Drill ahead through 12.25” intermediate section to 2770' MD. Gas: The max gas was 33 units at a depth of 2770’ MD. The average gas was 14 units. Geology: 70% sandstone and 30% siltstone. 10/11/2013 Drill ahead through 12.25" intermediate section from 2770' MD to 4683’ MD. Gas: The max gas was 41 units at a depth of 4683’ MD. The average gas was 7 units. Geology: 100% sandstone 10/12/2013 Drill ahead through 12.25” intermediate section from 4683’ MD to 5649’ MD. Gas: The max gas was 14 units at a depth of 5228’ MD. The average gas was 3 units. Geology: 90% siltstone and 10% sandstone 10/13/2013 Drill ahead through 12.25” intermediate section from 5649’ MD to 5755’ MD. Afterwards we monitored the well and conditions were static. We then back reamed out of hole to 2611’ MD. Then we pulled out of hole to 2144’ MD. Gas: The max gas was 24 units at a depth of 5740’ MD. The average gas was 4 units. Geology: 60% siltstone and 30% sandstone 10% clay 10/14/2013 Pull out of the hole to 361’ MD. We then monitored the well and the condition was static. They then laid down the BHA and picked up a 12.25” PDC bit and RIH to 1011’. MWD did a shallow test that went good. The hole was washed and reamed from 5598’ to 5755’ at the drill rate. They then drilled to 6342’ MD. Gas: The max gas was 28 units at a depth of 6342’ MD. The average gas was 16 units. Geology: 65% sandstone 25% siltstone 10% clay 10/15/2013 Drilled 12.25” hole from 6342’ MD to TD at 8045’ MD. There were no drilling losses. Begin back reaming out of hole. Gas: The max gas was 1290 units at a depth of 7228’ MD. The average gas was 120 units. Geology: 60% sandstone 40% siltstone 10/16/2013 Continue to back ream out of hole. Pull out of hole and lay down BHA #5. Begin to run 9 5/8” casing to 168’ MD. 10/17/2013 Float 9 5/8” casing to 2181’ MD. Run in hole to 6652’ MD. Start rotating casing to 8030’ MD. Circulate and condition hole. 10/18/2013 Condition hole while Cementers work on pump. Cement 9 5/8” casing. Drop bottom plug and test lines. Drop top plug. Rig down cement equipment. Nipple down BOPE. Set 9 5/8” emergency slips. Install packoff and test. Nipple up BOPE. Freeze protect OA sands. 10/19/2013 Service rig and top drive. Pick up 60 joints of 4.5” drill pipe. Test BOPE’s. Rig down test equipment and pull test plug. Set wear ring. Rig up wireline and function test. Run in hole with tractor and CBL. There were intermittent communication issues. Pull out of hole with wireline and CBL tool. Run in hole with wireline to 7950’ MD and begin logging out of the hole. 10/20/2013 Rig down wireline. Test 9 5/8” casing. Pick up BHA #6. Run in the hole, wash down and tag the plug at 7941’ MD. Displace to 9.25 lb/gal FazePro mud. Clean surface equipment, cut and slip drill line. Drill shoe track, shoe, and 21’ rat hole to 8065’ MD. Pull out of hole to 7899’ MD to circulate for FIT. 10/21/2013 Condition hole, rig up to perform FIT, then rig down equipment. Drill 8.75” production hole from 8065’ MD to 9568’ MD. Gas: The max gas was 4108 units at 8825’ MD. The average gas was 1108 units. Geology: Samples consist mainly of Sandstone 10/22/2013 Continue to drill from 9596’ MD to 11302’ MD. Mud weight increased from 9.15 ppg to 9.3 ppg by 0.5 ppg increments due to high gas. Gas: The max gas observed was 5727 units at 10889’ MD. The average gas was 1753 units. Geology: Samples consisted mainly of sandstone with some local silts. 10/23/2013 Continue to drill from 11302’ MD to 13958’ MD. Gas: The max gas observed was 4200 units at 11271’ MD. The average gas was 961 units. Geology: Samples consisted mainly of sandstone with some local silts. 10/24/2013 Continue to drill from 13958’ MD to 15728’ MD. Serviced top drive, block, and drawworks. Gas: The max gas observed was 5300 units at 14820’ MD. The average gas was 1682 units. Geology: Samples consisted mainly of sandstone with some local silts. 10/25/2013 Continue to drill from 15728’ MD to production section TD of 15870’ MD. Begin to back ream out of the hole per K&M representative. Gas: The max gas observed was 1640 units at 15828’ MD. The average gas was 828 units. Geology: Samples consisted mainly of sandstone with some local silts. 10/26/2013 Continue to back ream out of the hole per K&M representative. Circulate bottoms up and monitor the well, static. Continue to pull out of the hole. Lay down BHA #6 and rig up to run in hole with 5.5” liner. Gas: The max gas observed was 12 units while tripping out of the hole. 10/27/2013 Continue to run in the hole with 5.5” liner. Make up liner assembly and continue to run in the hole with 5” drill pipe. Set liner and pull out of the hole. Test BOP’s. 10/28/2013 Continue to test BOP’s. Make up and pick up whip stock BHA. RIH with whip stock BHA and begin milling window at 7791’ MD. Gas: The max gas observed was 19 units and the average gas was 10 units. Geology: Spot sample collected at 7801’ MD consisted of 100% sandstone. 10/29/2013 Continue to mill window. Top of the window is at 7791’ MD and bottom of the window is at 7808’ MD. Continue milling operations to 7838’ MD. Drop ball and pump sweep. Pull out of the hole and lay down whip stock BHA. Make up and pick up BHA #8. Begin to run in the hole. Gas: The max gas observed was 19 units and the average gas was 14 units. 10/30/2013 Continue to run in the hole. Perform leak off test at 7791’ MD to 11.61 ppg. Drill ahead from 7838’ MD to 8038’ MD. Circulate bottoms-up and pull out of the hole. Lay down BHA #8 and pick up BHA #9. Perform rig maintenance. Begin to run in the hole. Gas: The max gas observed was 32 units and the average gas was 21 units. Geology: Samples consisted of 50% sandstone and 50% siltstone. 10/31/2013 Continue to run in the hole. Drill ahead from 8038’ MD to 9363’ MD. Gas: The max gas observed was 2555 units at 8652’ MD and the average gas was 811 units. Geology: Samples consisted of mostly siltstone with some sandstone from 8038’ MD to 8500’ MD. There was abundant sandstone from 8500’ MD to 9363’ MD. 11/01/2013 Continue to drill ahead from 9363’ MD to 9664’ MD. Begin to pull out of the hole due to tool failure. Lay down BHA #9. Pick up BHA #10 and run in the hole. Gas: The max gas observed was 2815 units at 9304’ MD and the average gas was 1114 units. Geology: Samples consisted of 100% sandstone. 11/02/2013 Continue to run in hole with BHA #10. Drill ahead from 9664’ MD to 10454’ MD. Gas: The max gas observed was 2176 units at 9890’ MD and the average gas was 941 units. Geology: Samples consisted of 100% sandstone with 30%-50% siltstone. 11/03/2013 Drill ahead from 10454’ MD to 10548’ MD. Begin to pull out of hole due to MWD tool failure. Gas: The max gas observed was 540 units at 10521’ MD and the average gas was 312 units. Geology: Samples consisted of 50%-70% sandstone with 30%-50% siltstone. 11/04/2013 Continue to pull out of hole and lay down BHA #10. Pick up BHA #11 and being to run in hole. Shallow hole test tools and fail. Pull out of the hole and lay down BHA #11. Pick up BHA #12 and run in the hole. Drill ahead from 10548’ MD to 10696’ MD. Gas: The max gas observed was 2092 units at 10691’ MD and the average gas was 777 units. Geology: Samples consisted of 80% sandstone with 20% siltstone. 11/05/2013 Continue to drill ahead from 10696' MD to 12837' MD. Gas: The max gas observed was 3636 units at 11500’ MD and the average gas was 1093 units. Geology: Samples have consisted of 100% sandstone. 11/06/2013 Continue to drill ahead from 12837' MD to 14955' MD. Gas: The max gas observed was 3186 units at 14558’ MD and the average gas was 781 units. Geology: Samples consisted of 100% sandstone. 11/07/2013 Continue to drill ahead from 14955' MD to TD of 15977' MD. Began to back ream out of hole per K&M representative. Gas: The max gas observed was 2018 units at 15891’ MD and the average gas was 667 units. Geology: Samples consisted of 90% sandstone and 10% siltstone. 11/08/2013 Continue to back ream out of hole to window. Pull out of hole and begin to lay down BHA. Gas: The max gas observed was 71 units. 11/09/2013 Lay down BHA #12. Run in hole to retrieve whipstock and pull out of hole. 11/10/2013 Lay down whipstock and rig up to run in hole with 5.5” liner. Run in hole and tag TOL @ 7856’ MD. Work liner through window and continue to run in hole. 11/11/2013 Continue to run in hole with 5.5” liner to 15828’ MD. Displace well to brine and begin to lay down drill pipe. 11/12/2013 Continue to lay down drill pipe. Pull wear ring and install test plug and test BOP’s. Finish laying down drill pipe. Prepare for completions equipment and pump assembly. Rig up for wireline. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 0 5 10 15 20 25 30 35 40 45 Me a s u r e d D e p t h Rig Days Prognosed Actual Days vs. Depth 02 Oct 2013 Sperry SDL continues on location from previous well WELL NAME: SP08-N7 & SP08-N7L1 OPERATOR: ENI Petroleum MUD CO: MI Swaco RIG: Doyon 15 SPERRY JOB: AK-AM-0900797980 LOCATION: North Slope AREA: Spy Island STATE: Alaska SPUD: 3 Oct 2013 TD: 7 Nov 2013 Commenced 16" Surface Hole Section On Bot: 07:30 02 Oct 2013 Commenced 12.25" Intermediate Hole Section On Bot: 22:05 09 Oct 2013 TD Surface Hole Section 2692' MD, 2692' TVD Off Bot: 00:20 04 Oct 2013 POOH for Bit Change Off Bot : 09:25 10 Oct 2013 On Bot: 22:20 10 Oct 2013 POOH for Bit change Off Bot: 13:25 13 Oct 2013 On Bot: 17:00 14 Oct 2013 Landed 13 3/8" Casing 2677' MD, 2471' TVD 06 Oct 2013 TD Intermediate Hole Section 8030' MD, 4067' TVD Off Bot: 14:00 15 Oct 2013 Landed 9 5/8" Casing 8030' MD, 4069' TVD 17 Oct 2013 Commenced 8.75" Production Hole Section On Bot: 02:30 21 Oct 2013 TD Production Hole Section 15870' MD, 3997' TVD Off Bot: 04:30 25 Oct 2013 Commenced 8.75" L1 Production Hole Section On Bot: 04:00 30 Oct 2013 POOH for Tool Failure Off Bot: 05:50 01 Nov 2013 On Bot: 10:40 02 Nov 2013 POOH for Bit Change Off Bot: 09:10 30 Oct 2013 On Bot: 06:30 31 Oct 2013 TD Production Hole Section 15977' MD, 4008' TVD Off Bot: 14:10 07 Nov 2013 POOH for Tool Failure Off Bot: 01:30 03 Nov 2013 On Bot: 22:00 04 Nov 2013 WELL NAME:LOCATION:North Slope OPERATOR:AREA:Spy Island SPERRY JOB:STATE:Alaska RIG:Doyon 15 HOLE SECTION Surface EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 ENI Petroleum AK-AM-0900797980 Paul Kalenuik 4-Oct-2013 SP08-N7 What went as, or better than, planned: No major difficulties were experienced. The Canrig computer did freeze towards the beinning of the section and was fixed by closing out the RigWatch program and restarting it. The bit depth got thrown off a few times during connections. Recommendations: Innovations and/or cost savings: Surface section was completed without major problems. Gas chromatograph worked fine and within parameters. Difficulties experienced: Check your bit depth during each connection to make sure it stays on track. N/A Surface Data Logging After Action Review WELL NAME:LOCATION:North Slope OPERATOR:AREA:Spy Island SPERRY JOB:STATE:Alaska RIG:Doyon 15 HOLE SECTION:Intermediate EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 What went as, or better than, planned: Some difficulties were experienced. The Gas Chromatograph would just stop running on two different occasions. This caused a sixty foot gap on our logs. Recommendations: Innovations and/or cost savings: Intermediate section was completed without any major issues. Difficulties experienced: Check your bit depth during each connection to make sure it stays on track. Replaced the H2 Generator with backup unit and the 8900 Chromatograph. The Geni filter was replaced. N/A ENI Petroleum AK-AM-0900797980 Paul Kalenuik 16-Oct-2013 SP08-N7 Surface Data Logging After Action Review WELL NAME:LOCATION:North Slope OPERATOR:AREA:Spy Island SPERRY JOB:STATE:Alaska RIG:Doyon 15 HOLE SECTION Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 What went as, or better than, planned: At the beginning of the production run, TVD was not tracking correctly. This was fixed by going into the Survey Descriptor and making adjustments. Recommendations: Innovations and/or cost savings: Production section was completed with no major issues. We experienced no failures from CanRig and our depth tracked fairly well. Difficulties experienced: Go through and check Descriptors before starting a new section or run. N/A ENI Petroleum AK-AM-0900797980 Kori Jo Plowman 29-Oct-2013 SP08-N7 Surface Data Logging After Action Review WELL NAME:LOCATION:North Slope OPERATOR:AREA:Spy Island SPERRY JOB:STATE:Alaska RIG:Doyon 15 HOLE SECTION Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 ENI Petroleum AK-AM-0900797980 Leigh Ann Rasher 10-Nov-2013 SP08-N7 L1 What went as, or better than, planned: The GC (8900) had issues connecting to IRIS after run changes. Also, the GC was not calibrated correctly prior to the L1 section. The C3 and C4 norm were calibrated to read 10x their ppm. Lag was approx 40-50-bbls off prior to the L1 section. Pump configurations were off slightly. Hydrogen generator was leaking pressure. Recommendations: Innovations and/or cost savings: L1 production section was completed with no major issues. The THA(8800) was switched out to the newer THA (9000) and worked without any issues. Difficulties experienced: The GC will be changed out to SDL ready GC recieved from town a few weeks ago to resolve connectivity issues. Need to make sure to check GC gas concentrations when calibrating the equipment to make sure they are correct. Also all configurations should be checked after each run (pumps, lag, etc.). If a lag adjustment is made it should be communicated to other loggers to avoid issues. Make sure hydrogen generator poly flow connectioin is on tight enough to avoid any leaks which may cause drops in pressure. N/A Surface Data Logging After Action Review WELL NAME:SP08-N7 & SP08-N7L1 LOCATION:Spy Island OPERATOR:ENI Petroleum AREA:North Slope MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:3-Oct-2013 SPERRY JOB:AK-AM-0900797980 TD:7-Nov-2013 Marker MD INC AZ TVD TVDSS 16"Surface Borehole 20" Conductor Shoe 160.0 0.6 234.1 160.0 -106.1 SV-4 768.0 8.0 138.9 767.4 -713.5 SV-3 1,137.0 21.9 139.1 1,122.4 -1,068.5 SV-2 1,422.0 29.0 140.3 1,379.0 -1,325.1 Permafrost Base 1,860.0 27.4 140.0 1,769.0 -1,715.1 SV-1 2,055.0 29.7 130.3 1,938.7 -1,884.8 Ugnu Top (UG4)2,429.0 31.3 103.1 2,262.2 -2,208.3 13 3/8" Casing Shoe 2,677.0 33.5 85.9 2,471.7 -2,417.7 TD 16" Borehole 2,692.0 33.6 84.9 2,484.3 -2,430.3 12 1/4" Intermediate Borehole UG-2 Coal Bed Marker 3,140.0 45.3 70.0 2,835.3 -2,781.4 Lower Ugnu 5,232.0 77.7 27.3 3,571.9 -3,518.0 Schrader Bluff 6,836.0 79.7 338.6 3,890.5 -3,836.6 N Sequence Top 6,976.0 78.9 334.0 3,911.8 -3,857.9 N Sand Top 7,229.0 80.8 329.1 3,955.4 -3,901.5 N2 7,276.0 81.7 327.3 3,962.2 -3,908.3 N3 7,364.0 82.8 324.6 3,974.0 -3,920.1 N Sand Bottom 7,486.0 83.1 322.1 3,988.9 -3,935.0 N Sequence Base 7,675.0 80.4 311.9 4,016.6 -3,962.7 9 5/8" Casing Shoe 8,030.0 84.4 309.7 4,067.9 -4,014.0 TD 12 1/4" Borehole 8,045.0 84.8 309.9 4,068.9 -4,015.0 8 3/4" Lateral OA Sand Top 8,320.0 84.3 310.5 4,098.8 -4,044.9 OA-2 Top 8,363.0 85.5 310.8 4,102.7 -4,048.8 OA-3 Top 8,416.0 86.4 311.5 4,106.5 -4,052.6 OA-3 Top 10,074.0 93.2 307.3 4,096.2 -4,042.3 OA-2 Top 10,192.0 92.4 306.2 4,090.3 -4,036.4 OA-2 Top 11,203.0 88.5 315.7 4,078.8 -4,024.9 OA-3 Top 11,263.0 86.6 315.0 4,081.3 -4,027.4 Fault 3 12,508.0 94.0 309.4 4,050.4 -3,996.5 OA Top 12,601.0 93.4 308.6 4,044.3 -3,990.4 OA Top 12,767.0 87.8 308.3 4,042.3 -3,988.4 OA-2 Top 14,033.0 87.7 308.5 4,040.5 -3,986.6 OA-3 Top 14,109.0 87.3 308.6 4,043.7 -3,989.8 OA-4 Top 15,154.0 87.4 312.0 4,054.1 -4,000.2 Fault 4 15,186.0 87.0 312.2 4,055.5 -4,001.6 OA Bottom 15,732.0 98.5 311.6 4,020.9 -3,967.0 OA-4 Top 15,762.0 99.4 311.9 4,016.6 -3,962.7 TD 8 3/4" Borehole 15,870.0 100.5 313.7 3,997.0 -3,943.1 Formation Tops WELL NAME:SP08-N7 & SP08-N7L1 LOCATION:Spy Island OPERATOR:ENI Petroleum AREA:North Slope MUD CO:MI Swaco STATE:Alaska RIG:Doyon 15 SPUD:3-Oct-2013 SPERRY JOB:AK-AM-0900797980 TD:7-Nov-2013 Marker MD INC AZ TVD TVDSS 8 3/4 " Lateral L1 TOW 7,791.0 80.3 307.6 4,035.5 -3,981.6 BOW 7,808.0 80.6 307.8 4,038.3 -3,984.4 OA-1 Top 8,520.0 87.4 308.5 4,092.5 -4,038.6 OA-2 Top 9,779.0 87.8 308.6 4,076.3 -4022.4 OA-3 Top 9,830.0 87.7 310.5 4,078.3 -4024.4 OA-4 Top 10,236.0 89.3 312.8 4,089.4 -4035.5 OA-4 Top 10,570.0 92.5 314.2 4,091.6 -4037.6 Fault 3 10,857.0 94.2 313.5 4,071.7 -4017.7 OA-1 Top 10,952.0 93.2 313.2 4,065.1 -4011.2 OA-1 Top 11,114.0 88.9 312.2 4,062.7 -4008.7 OA-1 Top 11,615.0 92.1 311.4 4,050.4 -3996.5 OA-1 Top 11,711.0 89.7 311.1 4,048.6 -3994.6 Fault 4 11,994.0 90.4 311.9 4,051.6 -3997.7 OA-3 Top 13,425.0 92.0 312.7 4,045.1 -3991.2 OA-2 Top 13,495.0 92.5 312.7 4,042.4 -3988.4 Fault 5 15,118.0 91.8 312.7 4,038.4 -3984.4 OA Bottom 15,268.0 94.7 312.3 4,027.2 -3973.3 OA-4 Top 15,325.0 93.3 312.0 4,023.1 -3969.2 Fault 6 15,648.0 90.8 310.3 4,018.5 -3964.5 OA-2 Top 15,722.0 91.5 310.9 4,017.0 -3963.1 OA-1 Top 15,908.0 92.6 310.9 4,010.9 -3957.0 TD 8 3/4" Borehole 15,977.0 92.7 310.8 4,009.1 -3955.2 Formation Tops Show Report Report # 1 Show Report Report # 1 Well Name: Depth (MD) to ft Location: (TVD) to ft SP08-N7 Spy Island 9970 4099 8756 4109 Location: (TVD) to ft Operator: Report Prepared By: Formation: Spy Island ENI Petroluem Kori Jo Plowman 4099 4109 OA-Sand Report Prepared By: Formation: Report Delivered To: Date: 30-Oct-2013 Kori Jo Plowman Andrew Buchanan OA-Sand Interpretation: Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 77000 8825 4108 1 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 77000 8825 4108 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =1906 389648 391554 267 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = 1906 389648 735 1308 547 17 530 1470 12 391554 267 1458 NPH C4 - =C1/C5 = C5 - = 547 17 530 325 27 94 4190 298 1 93 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 9058 3405 75000 2 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 =1246 354661 351255 1234 12 285 721 3406 10 C2 -=C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 =3314 1246 1234 12 721 995 15 487 370 17 502 353 Oil C4 C1/C5 = C5 - = Production 3314 370 17 353 106 0 106 1 NPH Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 75000 2649 9522 3 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 75000 2649 9522 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =269 292716 17604 275112 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 =C1/C4 = 269 691 576 292716 17604 275112 1084 62 1022 550 478 72 NPH C3 =C1/C4 = C4 - =C1/C5 = C5 -= 691 2237 72 398 123 19 142 550 478 470 72 NPH C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 123 19 142 4 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 68000 2088 9961 4 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 =537 252 225945 934 38 896 237919 11974 10 Oil C2 -=C1/C3 = C3 - =C1/C4 = C4 -=C1/C5 = 537 616 2627 31 421 425 58 367 934 38 896 452 NPH C4 -=C1/C5 = C5 - = Production 2627 0.00 425 58 367 143 57 86 1 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 2 Show Report Report # 2 Well Name: Depth (MD) to ft Location: (TVD) to ft 11278 4081 10344 4085 SP08-N7 Spy Island Location: (TVD) to ft Operator: Report Prepared By: Formation: 4081 4085 OA-Sand Spy Island ENI Petroluem Kori Jo Plowman Report Prepared By: Formation: Report Delivered To: Date: OA-Sand 30-Oct-2013 Kori Jo Plowman Andrew Buchanan Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Interpretation: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 1 70000 10440 4481 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 70000 10440 4481 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =402069 257 378910 23159 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = 402069 257 1476 562 74 488 1552 76 378910 776 1207 23159 NPH C4 - =C1/C5 = C5 - =33 111 144 3414 314 562 74 488 395 81 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 2 70000 10889 5727 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 17565 289 1014 1554 445593 428028 1482 72 10 C2 -=C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 = 80 422 335 105 502 230 1014 1861 1554 1482 72 4459 Oil C4 C1/C5 = C5 - = Production 135 39 96 335 105 230 4459 1 NPH Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 3 4362 11014 69000 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 4362 11014 69000 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =401296 34112 367184 327 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 =C1/C4 =462 390 72 1208 86 1122 401296 34112 367184 941 1360 327 NPH C3 =C1/C4 = C4 - =C1/C5 = C5 -= 462 390 345 72 117 75 270 103 14 1360 3565 NPH C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 117 103 14 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 4 4199 11269 69000 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 388206 11187 1244 43 1201 377019 790 314 10 Oil C2 -=C1/C3 = C3 - =C1/C4 = C4 -=C1/C5 =421 96 325 1244 43 1201 540 63 477 790 1160 3887 NPH C4 -=C1/C5 = C5 - = Production 136 39 97 421 96 325 0.00 3887 1 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 3 Show Report Report # 3 Well Name: Depth (MD) to ft Location: (TVD) to ft 13985 4038 11651 4082 SP08-N7 Spy Island Location: (TVD) to ft Operator: Report Prepared By: Formation: 4038 4082 OA-Sand Spy Island ENI Petroluem Kori Jo Plowman Report Prepared By: Formation: Report Delivered To: Date: OA-Sand 30-Oct-2013 Kori Jo Plowman Andrew Buchanan Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Interpretation: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 1 68000 11737 1998 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 68000 11737 1998 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =221685 177 193142 28543 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = 221685 177 1089 566 119 447 1192 103 193142 432 594 28543 NPH C4 - =C1/C5 = C5 - =67 86 153 2246 325 566 119 447 486 161 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 2 69000 12371 1838 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 34946 160 421 1128 195657 160711 1003 125 10 C2 -=C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 = 165 382 532 231 547 301 421 534 1128 1003 125 2060 Oil C4 C1/C5 = C5 - = Production 175 97 78 532 231 301 2060 1 NPH Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 3 1748 13347 65000 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 1748 13347 65000 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =192227 13607 178620 116 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 =C1/C4 =1741 1632 109 1628 84 1544 192227 13607 178620 109 127 116 NPH C3 =C1/C4 = C4 - =C1/C5 = C5 -= 1741 1632 1551 109 242 149 1402 191 51 127 935 NPH C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 242 191 51 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 4 1889 13910 68000 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 = 210868 23896 1154 180 974 186972 725 192 10 Oil C2 -=C1/C3 = C3 - =C1/C4 = C4 -=C1/C5 =486 275 211 1154 180 974 505 247 258 725 886 2077 NPH C4 -=C1/C5 = C5 - = Production 168 78 90 486 275 211 0.00 2077 1 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 4 Show Report Report # 4 Well Name: Depth (MD) to ft Location: (TVD) to ft SP08-N7 Spy Island 15103 4051 14450 4048 Location: (TVD) to ft Operator: Report Prepared By: Formation: Spy Island ENI Petroluem Kori Jo Plowman 4051 4048 OA-Sand Report Prepared By: Formation: Report Delivered To: Date: 30-Oct-2013 Kori Jo Plowman Andrew Buchanan OA-Sand Interpretation: Interpretation: No producible oil within these zones based upon gas and chromatograph data collected. Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 68000 14542 5165 1 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 68000 14542 5165 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =49082 375051 424133 216 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 - =C1/C4 = 49082 375051 567 850 768 106 662 1866 129 424133 216 1737 NPH C4 - =C1/C5 = C5 - = 768 106 662 573 132 182 3152 441 63 119 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 14727 4363 68000 2 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 =1688 396074 365916 1584 104 231 594 30158 10 C2 -=C1/C3 = C3 - =C1/C4 = C4 - =C1/C5 =2671 1688 1584 104 594 877 114 616 558 141 730 417 Oil C4 C1/C5 = C5 - = Production 2671 558 141 417 184 47 137 1 NPH Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 68000 5298 14820 3 Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 . Flowline Background Show C2 C3 C4 C5 ppm ppm ppm 68000 5298 14820 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 =222 429075 28441 400634 1000 C1 -=C1/C2 = C2 - =C1/C3 = C3 =C1/C4 = 222 708 435 429075 28441 400634 1958 155 1803 1167 922 245 NPH C3 =C1/C4 = C4 - =C1/C5 = C5 -= 708 4006 303 566 100 100 200 1167 922 869 245 NPH C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 100 100 200 4 100 Depth ft Gas Units Mud Chlorides (mg/L) = . Flowline Background Show 70000 2472 15085 4 Gas Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10 Hydrocarbon Ratios C1 - =C1/C2 = C2 -=C1/C3 =218 156 254594 1694 59 1635 264855 10261 10 Oil C2 -=C1/C3 = C3 - =C1/C4 = C4 -=C1/C5 = 218 287 1552 124 1169 1078 191 887 1694 59 1635 1293 NPH C4 -=C1/C5 = C5 - = Production 1552 0.00 1078 191 887 234 70 164 1 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Gas Units Mud Chlorides (mg/L) = Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Gas Units Mud Chlorides (mg/L) = Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 1 2 3 4 140 2 100 1 33 96 18 No producible oil within these zones based upon gas and chromatograph data collected. 66 21539123 6650086522555 179 138 151 0 306377 14546 26159304 188 23 88 561 40 500 216 486 5 418 107 12 138 138 37 179 47 241400 3960 229184 282236 2407 587 33 477 8487145 125 16 125 482 24 145 35 280071 67000 2241 1932 553 67000 1874 1661 5502 536 9015 270791 258575 468 17 2443 0 60 15 174 294357 77 0 1692 3345 2944 3820 2976 589 Interpretation: Show Report Report # 5 9304 4077 8652 4094 OA-Sand 1-Nov-2013 67000 548 SP08-N7L1 Spy Island ENI Petroluem Leigh Ann Rasher Andrew Buchanan 3918 6342 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Gas Units Mud Chlorides (mg/L) = Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Gas Units Mud Chlorides (mg/L) = Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 1 2 3 4 37 2 35 1 94 106 18 No producible oil within these zones based upon gas and chromatograph data collected. 88 209210691 6100098902176 87 87 94 0 338139 14546 318610812 144 23 121 506 40 466 145 352 5 347 22 12 153 241 37 165 204 238679 3960 234719 242165 2407 516 95 457 2509209 187 16 171 481 24 244 35 235823 67000 1379 1128 492 61000 1343 2698 1007 435 10068 207895 205488 418 17 1863 0 94 15 130 323593 22 0 2489 2674 9246 2497 10669 694 Interpretation: Show Report Report # 6 10812 4074 9890 4080 OA-Sand 5-Nov-2013 67000 676 SP08-N7L1 Spy Island ENI Petroluem Leigh Ann Rasher Andrew Buchanan 2335 6342 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Gas Units Mud Chlorides (mg/L) = Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Gas Units Mud Chlorides (mg/L) = Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 1 2 3 4 185 34 151 13 57 84 28 No producible oil within these zones based upon gas and chromatograph data collected. 56 128212439 61500113193450 193 146 322 47 147943 6404 132312650 389 77 312 607 44 563 246 505 65 440 154 34 153 227 74 187 153 143386 6666 136720 354567 17486 747 70 452 5920140 156 20 136 491 39 180 40 337442 65000 2481 2410 715 61500 2263 936 2263 547 11500 363780 346294 484 63 3636 111 211 30 216 141539 110 44 655 454 937 648 1243 251 Interpretation: Show Report Report # 7 12650 4061 11319 4061 OA-Sand 6-Nov-2013 65000 311 SP08-N7L1 Spy Island ENI Petroluem Leigh Ann Rasher Andrew Buchanan 6184 17125 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Gas Units Mud Chlorides (mg/L) = Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Hydrocarbon Ratios Depth ft Gas Units Mud Chlorides (mg/L) = C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Gas Units Mud Chlorides (mg/L) = Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 1 2 3 4 157 50 107 53 45 169 48 No producible oil within these zones based upon gas and chromatograph data collected. 121 318614558 64000139551503 280 245 400 35 297356 12637 278514836 308 103 205 585 58 527 203 776 62 714 196 42 183 344 100 225 244 330097 20886 309211 169060 10903 319 98 481 3406121 198 43 155 542 61 226 105 153249 64500 989 1267 481 64000 1706 1262 1279 707 14236 323046 312143 649 58 3070 93 307 40 163 284719 146 50 1747 1389 2661 1007 2118 540 Interpretation: Show Report Report # 8 14836 4041 13955 4037 OA-Sand 6-Nov-2013 62000 433 SP08-N7L1 Spy Island ENI Petroluem Leigh Ann Rasher Andrew Buchanan 2580 15811 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH SP08-N7 & SP08-N7L1 ENI Petroleum MI Swaco Doyon 15 AK-AM-0900797980 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++ 2-Oct 160 8.80 136 28 34 22/42/51 6.5 90/62/52/39/18/17 3/-3.0 1/96 ---9.6 21.0 .10/.25 1300 40 Rig up 3-Oct 514 8.90 110 23 37 25/49/58 -89/63/52/39/20/18 3/-5.0 2/93 0.25 0.15 10.1 22.0 .10/.26 2000 40 drilling 16" surface 4-Oct 2432 9.30 86 23 37 26/55/66 5.8 87/62/50/37/19/18 2/-7.0 1/92 0.25 0.15 9.5 22.5 .08/.25 1900 80 drilling 16" surface 5-Oct 2692 9.30 84 26 33 22/48/59 5.6 85/59/48/35/19/17 2/-4.0 1/95 0.25 0.15 9.5 22.5 .05/2.1 1300 60 running 13 3/8" casing 6-Oct 2692 9.20 40 13 7 3/4/5 6.2 33/20/16/10/4/3 ----------7.1 ----1300 --N/U BOP's 7-Oct 2692 9.20 40 13 7 3/4/5 6.2 33/20/16/10/4/3 ----------7.1 ----1300 --P/U & M/U BHA #3 8-Oct 2692 9.20 40 13 7 3/4/5 6.3 33/20/16/10/4/3 ----------7.1 ----1300 --P/U 4.5" DP 9-Oct 2692 9.20 43 9 12 3/4/5 --30/21/16/11/4/4 ----------9.4 ----1300 --Displacing to LSND 10-Oct 2719 9.20 49 9 28 11/13/15 6.3 46/37/32/26/13/11 1/-3.5 2/94.5 0.00 0.17 9.9 0.0 .05/.85 700 40 Drill 12.25" Hole 11-Oct 4649 9.20 47 10 26 11/18/23 5.2 46/36/31/25/12/11 1/-4.3 3/92.75 0.05 0.20 9.8 10.0 .10/.75 1100 40 Drill 12.25" Int. 12-Oct 5622 9.20 46 10 27 11/18/22 5.6 47/37/31/25/12/11 1/-5.0 3/92 0.05 0.20 9.8 12.5 .10/.85 1100 60 Drill 12.25" Int 13-Oct 5755 9.20 47 10 28 12/19/23 4.8 48/38/33/26/13/11 1/-5.0 3/92 0.02 0.15 9.7 12.5 .08/.85 1200 60 POOH:12.25" Int 14-Oct 6342 9.30 52 10 27 11/18/22 4.6 47/37/31/25/12/11 1/-5.3 3/91.75 0.02 0.15 9.9 12.5 .10/.80 1100 60 Drill 12.25" Int 15-Oct 8045 9.30 88 11 24 13/24/30 4.6 46/35/31/25/13/12 1/-6.3 3/90.75 0.05 0.10 9.6 15.5 .05/.70 1100 40 Drill 12.25" hole 16-Oct 8045 9.20 45 10 22 10/17/24 5.0 42/32/28/22/11/10 1/-6.3 3/90.75 0.05 0.10 9.6 15.0 .05/.65 1100 40 Float 9 5/8" casing 17-Oct 8045 9.20 48 11 24 11/19/26 5.2 46/35/30/24/12/10 1/-6.5 2.5/91 0.00 0.10 9.6 15.0 .05/.60 1100 40 Circulate and Condition 18-Oct 8045 9.20 46 10 14 7/10/14 5.2 34/24/22/17/8/7 1/-6.5 2.5/91 0.00 0.06 9.2 15.0 .02/.60 1100 60 Freeze protect OA 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 19-Oct 8045 9.25 50 10 18 10/14/20 -38/28/24/19/10/9 1/----------Wireline: CBL 20-Oct 8045 9.20 46 13 18 7/7/8 -44/31/25/19/8/7 -6.51 64/36 2.95 3.84 410 29.36 -3.73/59.75 -Circulate hole/FIT 21-Oct 9163 9.20 43 12 17 7/7/8 4.0 41/29/24/18/8/7 -/2 7.20 67/33 2.75 3.58 715 28.46 -24.58/46.47 -Drill 8.75" Prod 22-Oct 10986 9.20 42 13 14 7/7/7 4.0 40/27/22/16/7/6 -/2 7.72 69/31 2.60 3.38 707 27.48 -35.61/37.24 -Drill 8.75" Prod 23-Oct 13542 9.30 45 15 17 7/8/8 3.8 47/32/26/19/8/7 -/1 8.22 70/30 2.30 2.99 630 29.36 -30.61/51.35 2.7 Drill 8.75" Prod 24-Oct 15523 9.30 46 14 20 7/8/8 3.8 48/34/28/20/8/7 -/2 8.24 70/30 2.30 2.99 687 29.68 -36.85/41.96 2.7 Drill 8.75" Prod 25-Oct 15870 9.30 44 13 16 6/7/7 -42/29/23/17/7/6 -/-8.43 70/30 1.95 2.54 600 28.42 -25.28/55.37 2.7 Circ & Cond 26-Oct 15870 9.35 42 13 16 6/7/7 -42/29/23/17/7/6 -/-8.51 70/30 2.20 2.86 605 28.80 -22.26/61.27 2.7 Run 5.5" Liner 27-Oct 15870 9.40 43 14 15 6/7/7 -43/29/23/17/7/6 -/-8.97 70/30 2.00 2.60 604 28.85 -14.32/72.46 2.8 Test BOPs 28-Oct 7808 9.30 45 14 16 6/7/7 -44/30/24/17/7/6 -/-7.74 69/31 2.2 2.86 710 31.13 -18.06/56.41 2.7 Milling Window Leg 1 29-Oct 7838 9.30 46 14 16 6/7/7 4.2 44/30/24/18/7/6 1/-8.06 69/31 2.20 2.86 685 28.05 -20.33/57.10 2.7 RIH 30-Oct 8038 9.30 46 14 18 7/7/7 4.0 46/32/26/18/7/6 -/1 8.24 70/30 2.2 2.86 700 28.27 -9.4/70.55 2.8 RIH w/BHA #9 31-Oct 9017 9.30 45 14 13 6/6/7 4.2 41/27/22/16/7/6 -/1 8.36 71/29 2.2 2.86 650 28.82 -5.93/75.54 2.8 Drill 8.75" L1 Prod 1-Nov 9664 9.30 43 13 16 6/7/7 4.6 42/29/23/16/7/6 -/1 8.98 72/28 2.00 2.6 620 28.37 -22.48/63.73 2.7 RIH w/BHA #10 2-Nov 10313 9.25 45 14 17 7/7/7 4.7 45/31/25/18/7/6 -/1 8.51 71/29 2.20 2.86 630 27.18 -20.37/61.38 2.7 Drill 8.75" L1 Prod 3-Nov 10548 9.25 45 14 16 6/7/7 4.6 44/30/24/17/7/6 -/1 8.22 71/29 2.30 2.99 630 29.04 -26.22/52.25 2.7 L/D BHA #10 4-Nov 10548 9.25 45 15 16 7/7/7 4.8 46/31/25/18/7/6 -/1 8.56 71/29 2.20 2.86 625 28.98 -49.09/30.98 2.7 Drill 8.75" L1 Prod 5-Nov 12462 9.25 47 15 17 7/7/8 4.9 47/32/26/19/8/7 -/1 8.8 71/29 2.00 2.60 615 27.05 -14.65/70.41 2.8 Drill 8.75" L1 Prod 6-Nov 14649 9.30 47 14 19 7/7/8 5.1 47/33/27/19/8/7 -/1 8.75 71/29 1.90 2.47 608.0 27.37 -12.96/71.76 2.8 Drill 8.75" L1 Prod 7-Nov 15977 9.25 48 15 19 7/7/8 -49/34/28/21/8/7 -/-8.51 71/29 2.25 2.93 610 27.18 -12.18/70.2 2.8 BROOH 9.75" Lateral 8-Nov 15977 9.3 48 15 18 7/7/8 -48/33/27/20/8/7 -/-8.43 69/31 1.90 2.47 640 26.84 -12.26/69.41 2.8 POH BHA #12 9-Nov 15977 9.3 51 14 19 7/7/8 -47/33/27/20/8/7 -/-8.53 70/30 1.90 2.47 620 27.13 -12.25/70.33 2.8 POH Whipstock 10-Nov 15977 9.30 51 14 19 7/7/8 -47/33/27/20/8/7 -/-8.5 70/30 1.90 2.47 615 27.1 -12.25/70.33 2.800 RIH 5.5" Liner L1 Casing Record Remarks 20" Conductor @ 160' MD, 160' TVD 13.375" Casing @ 2677' MD, 2471' TVD 9.625" Casing @ 8030' MD, 4068' TVD WELL NAME:LOCATION:Spy Island OPERATOR:AREA:North Slope MUD CO:STATE:Alaska RIG:SPUD:3-Oct-2013 SPERRY JOB:TD:7-Nov-2013 W a t e r a n d O i l B a s e d M u d R e c o r d 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 2 200 1 Hughes MX-1 Milltooth 16.00 160 2692 2532 18.50 1.117 137.00 25 40 1500 700 1-1-WT-A-E-In-No-TD Surface TD 3 300 2 Hycalog SKHI716D-E10C PDC 12.25 2692 2720 28 3.80 0.969 7.3 15 160 1150 900 0-0-WT-A-X-In-No-PR ROP problems 4 400 3 Smith GF15B Insert 12.25 2720 5755 3035 40.80 0.969 74.4 25 130 1500 900 2-6-BT-G-E-2-WT-BHA Lack of DLS 5 500 4 Hycalog SKHI716D-E10C PDC 12.25 5755 8045 2290 11.00 0.969 208.9 10 160 1650 900 0-0-CT-A-X-I-N0-TD Intermediate TD 6 600 5 MDSi616 BPX Smith PDC 8.75 8045 15870 7825 60.30 0.902 129.8 10 160 3100 550 0-1-CT-Sh-X-In-No-TD Production TD 8 700 6RR Smith XR+ Milltooth 8.75 7838 8038 200 3.30 0.745 61.5 12 40 2220 550 0-0-WT-A-E-In-No-BHA BHA Change 9 800 7 Hycalog MDSi616M-E1D PDC 8.75 8038 9664 1626 13.30 0.902 122.1 10 120 2400 550 0-6-BT-G-X-1-CT-DTF Xceed Tool Failure 10 900 8 Hycalog MDSi616M-E1D PDC 8.75 9664 10548 884 8.00 0.902 111.1 10 150 2700 550 0-0-CT-N-X-IN-WT-DTF Xceed Tool Failure 11 1000 8RR Hycalog MDSi616M-E1D PDC 8.75 10548 10548 0 0.00 0.902 N/A N/A N/A N/A N/A 0-0-CT-N-X-IN-WT-DTF Xceed Tool Failure 12 1000 8RR2 Hycalog MDSi616M-E1D PDC 8.75 10548 15977 5429 32.60 0.902 166.8 10 150 2800 550 0-0-CT-N-X-IN-No-TD Production TD Alaska RIG:Doyon 15 SPUD:3-Oct-2013 WELL NAME:SP08-N7 & SP08-N7L1 LOCATION:Spy Island OPERATOR:ENI Petroleum AREA:North Slope MUD CO: SPERRY JOB:AK-AM-0900797980 TD:7-Nov-2013 MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap: (max)(current) 0 0 Cly 908 Set AtSize Grade 20" 685-0772Unit Phone: 0 P.Kalenuik Maximum Report By:Logging Engineers:P. Kalenuik/ M. Nnaji 189 0 Units* Casing Summary Lithology (%) 0 MBT 0' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 21.0136 C-5n 720' C-2 11 in 2Minimum Depth Time: BHA in shed. Load mud in pits. 5 160' 160' 0' Max @ ft Current Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) B. Perry/R. Wimmer ShClyst TuffGvlCoal cP 28 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0900797980 $2,810.00 $5,620.00 RIG UP PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 000 Gel Mud 6.5160'34 Depth in / out Mud Type Lst Type Average 1Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 160' WOB 100% Gas In Air=10,000 UnitsConnection 0 160'MD ConditionBit # 1 16"Hughes MX-1 8.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE ROP ROP (ft/hr) 4.23 @ Mud Data Depth 2-Oct-2013 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 1300.00 Rig up operations for pre spud acceptance. N/U speed head riser and test seals to 500 PSI for 10 minutes. Load Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:P/U BHA #1. Fill conductor with spud mud. Pressure test surface equipment. Clean out Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2000.00 0 3-Oct-2013 12:00 AM Current Pump & Flow Data: 856 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report #2 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: ConditionBit # 1 5.0 16"Hughes MX-1 8.90 Size Spot sample : 80% sandstone, 10% clay, 10% shale @ 915' MD 160'MD 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 160' WOB 9.43 Avg Min Comments RPM ECD (ppg) ml/30min 1Background (max)Trip Average Mud Type Lst Type Gel Mud 6.2514'37 Depth in / out YP (lb/100ft2) 10.10 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0900797980 drilling ahead PV Footage M.Ross/R. Wimmer ShClyst TuffGvlCoal cP 26 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 160' 779' 619' Max @ ft Current 24.3 Date: Time: conductor T/160'. P/U BHA #2 SHT MWD, shoot gyro srvy, confirm srvy. M/U Remaining tools for BHA #2. Drill F/486' T/781' . 5 in 2Minimum Depth C-5n 720' 339.0 C-2 11 SPP (psi) Gallons/stroke TFABit Type Depth 22.0110 MBT 0' pH 1.117 0 0 0 Siltst 691 Units* Casing Summary Lithology (%) 0189 0 670-0772Unit Phone: 0 P.Kalenuik Maximum Report By:Logging Engineers:P. Kalenuik/ M. Nnaji Set AtSize Grade 20" (max)(current) 0 0 Cly 908 . . * 24 hr Recap:Con't drilling 16" surface F/781' T/2646' @ 650-700 GPM. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1900.00 0 4-Oct-2013 12:00 AM Current Pump & Flow Data: 1186 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: ConditionBit # 1 7.0 16"Hughes MX-1 9.30 Size 160'MD 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 160' WOB 9.76 Avg Min Comments RPM ECD (ppg) ml/30min 4Background (max)Trip Average Mud Type Lst Type Gel Mud 5.82432'37 Depth in / out YP (lb/100ft2) 9.50 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0900797980 drilling ahead PV Footage M.Ross/R. Wimmer ShClyst TuffGvlCoal cP 25 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 712.0 Flow In (gpm) Flow In (spm) 779' 2646' 1867' Max @ ft Current 829'81.4 Date: Time: 73 in 2Minimum Depth C-5n 2318' 0.0 C-2 180 SPP (psi) Gallons/stroke TFABit Type Depth 22.586 MBT 0' pH 1.117 0 0 0 Siltst 687 Units* Casing Summary Lithology (%) 08764 26 670-0772Unit Phone: 0 P.Kalenuik Maximum Report By:Logging Engineers:P. Kalenuik/ M. Nnaji Set AtSize Grade 20" (max)(current) 4 0 Cly 32212 . . Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1300.00 5-Oct-2013 12:00 AM Current Pump & Flow Data: Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition Bit # 1 4.0 16" Hughes MX-1 9.30 Size 160'MD Tools API FL 160' WOB 9.76 Avg Min Comments RPM ECD (ppg) ml/30min Mud Type Lst Type Gel Mud 5.6 2692'33 Depth in / out YP (lb/100ft 2) 9.50 Cement Cht Silt 24 hr Max Weight Hours Ss (ppb Eq) AK-AM-0900797980 $3,810.00 $15,050.00 casing PV Footage M.Ross/R. Wimmer Sh Clyst Tuff Gvl Coal cP 26 (current) Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2646' 2692' 46' Max @ ft Current Date: Time: in 0.0 SPP (psi) Gallons/stroke TFA Bit Type Depth 22.5 84 MBT 0' pH 1.117 Siltst 13 3/8" Casing Summary Lithology (%) Set At Size Grade 20" Cly * 24 hr Recap: R/U Csq equipt. M/U 13 3/8" Shoe track & test FC equip. (GOOD) T/122'. Run 13 3/8" Csg F/122' T/633'. 0 100% Gas In Air =10,000 Units Connection 0 Chromatograph (ppm) Background (max) Trip Average 000 00 C-4i C-4n 0 C-3 C-1 C-5i Gas Summary 0 0 0 (current) Minimum Depth C-5n C-2 0 0 0 Units* 0 Unit Phone: 0 P.Kalenuik Maximum Report By: Logging Engineers: P. Kalenuik/ M. Nahji (max) (current) 4 0 . . BTC Cly Set At Size 178.9 X-65 Grade 20" 13 3/8" Casing Summary Lithology (%) L-80 MBT 0' pH 1.117 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 40 0.0 in Time: 2692' 2692' 0' Max @ ft Current Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) (current) M.Ross/R. Wimmer Sh Clyst Tuff Gvl Coal cP 13 2532' Footage Ss (ppb Eq) AK-AM-0900797980 $2,810.00 $17,860.00 cementing PV 24 hr Max 68.0 Weight Hours Cement Cht Silt YP (lb/100ft 2) 7.10 12.0 Gel Mud 6.2 2692'7 Depth in / out Mud Type Lst Type 9.76 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL 3.2 160' 2692' WOB EVEMAR 2676'MD 160'MD Condition 1-1-WT-A-E-In-No-TD Bit # 2 16" Hughes MX-1 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE ROP ROP (ft/hr) 4.23 @ Mud Data Depth 6-Oct-2013 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l 1300.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % * 24 hr Recap: (max) (current) 0 0 Unit Phone: 0 P.Kalenuik Maximum Report By: Logging Engineers: P. Kalenuik/ M. Nahji Units* 0 0 0 0 C-5n C-2 Minimum Depth R/D Cement/Csq equip. L/D Landing jt. Test Well head to hanger neck seal T/2000 PSI F/10min. (Good Test). N/D Diverter line Gas Summary 0 0 0 (current) C-1 C-5i 0 C-3 00 C-4i C-4n 000 Average Background (max) Trip Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 0 cellar pup. Calibrate gas gear and test for accuracy. Operating within normal parameters. 0 Run 13 3/8" Csg F/633' T/2640'MD. P/U & M/U Landing Jt. Break Circ & land hanger shoe depth 2677'. . . * 24 hr Recap: (max)(current) BTC 0 0 Cly Set AtSize 178.9 X-65 Grade 20" Unit Phone: 0 P.Kalenuik Maximum Report By:Logging Engineers:P. Kalenuik/ j. Tiegs 13 3/8" Units* Casing Summary Lithology (%) 0 L-80 MBT 0' pH 1.117 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 40 C-5n 0.0 C-2 in Minimum Depth Time: R/U BOP test equip. Test BOP's (Good). Set wear bushing. R/D Testing equip. P/U BHA tools to rig floor. 2692' 2692' 0' Max @ ft Current Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) M.Ross/R. Wimmer ShClyst TuffGvlCoal cP 13 2532' Footage Ss (ppb Eq) C-1 C-5i AK-AM-0900797980 $3,410.00 $21,270.00 P/U BHA#3 PV 24 hr Max 68.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 7.10 000 12.0 Gel Mud 6.22692'7 Depth in / out Mud Type Lst Type Average Background (max)Trip 9.76 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 3.2160' 2692' WOB EVEMAR 100% Gas In Air=10,000 UnitsConnection 0 2676'MD 160'MD Condition 1-1-WT-A-E-In-No-TD Bit # 2 16"Hughes MX-1 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE ROP ROP (ft/hr) 4.23 @ Mud Data Depth 7-Oct-2013 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 1300.00 Load shed with BHA #3. P/U & M/U 5" DP stds via mouse hole & rack back on derrick 180 jts. Set Test plug. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:P/U BHA #3 per SLB DD & MWD using Scorpion torque unit. Load 9-5/8" csg in pipe shed, repair top drive leak. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1300.00 0 8-Oct-2013 12:00 AM Current Pump & Flow Data: Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # 2 16"Hughes MX-1 9.20 Size 3 2676'MD 160'MD 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 3.2160' 2692' WOB EVEMAR 9.76 Avg Min Comments RPM ECD (ppg) ml/30min Background (max)Trip Average Mud Type Lst Type 12.0 Hycalog PDC Gel Mud - 2692' 2692'7 Depth in / out YP (lb/100ft2) 7.10 000 00 CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0900797980 $3,410.00 $24,680.00 P/U 4.5"DP PV 2532' 12.25 1.117 Footage M.Ross/R. Wimmer ShClyst TuffGvlCoal cP 13 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2692' 2692' 0' Max @ ft Current Date: Time: P/U 4.5" DP via mousehole & rack in derrick. in Minimum Depth C-5n 0.0 C-2 SPP (psi) Gallons/stroke TFABit Type Depth 40 L-80 MBT 0' pH 1.117 0 0 0 Siltst 13 3/8" Units* Casing Summary Lithology (%) 0 Unit Phone: 0 P.Kalenuik Maximum Report By:Logging Engineers:P. Kalenuik/ j. Tiegs Set AtSize 178.9 X-65 Grade 20" (max)(current) BTC 0 0 Cly . . Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1300.00 9-Oct-2013 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 0.00 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # 2 16" Hughes MX-1 9.20 Size 3 2676'MD 160'MD Tools API FL 3.2 160' 2692' WOB EVEMAR 9.77 Avg Min Comments RPM ECD (ppg) ml/30min Mud Type Lst 90 Type 12.0 Hycalog PDC LSND - 2692' 2692'12 Depth in / out YP (lb/100ft 2) 9.40 Cement Cht Silt 24 hr Max 68.0 Weight Hours 10 Ss (ppb Eq) AK-AM-0900797980 $3,410.00 $28,090.00 Drilling Intermidate PV 2532' 12.25 1.117 Footage M.Ross/R. Wimmer Sh Clyst Tuff Gvl Coal cP 9 (current) Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2692' 2712' 20' Max @ ft Current Date: Time: in 0.0 SPP (psi) Gallons/stroke TFA Bit Type Depth 43 L-80 MBT 0' pH 1.117 Siltst 13 3/8" 0 0 Casing Summary Lithology (%) Set At Size 178.9 X-65 Grade 20" BTC Cly * 24 hr Recap: P/U BHA #3. RIH to 1012' MD & perform MWD shallow hole test @ 650. RIH to 2518' MD. 0 100% Gas In Air =10,000 Units Connection 0 Chromatograph (ppm) 0Background (max) Trip Average 90 000 00 C-4i C-4n 0 C-3 10 C-1 C-5i Gas Summary 0 0 0 (current) RIH, tag float at 2594' MD. Drill out 13 3/8" shoe at 2674'. Drill 20' rathole to 2712' MD / 2500' TVD. 3 0Minimum Depth C-5n C-2 26 0 0 0 Units* 0340 0 Unit Phone: 0 P.Kalenuik Maximum Report By: Logging Engineers: P. Kalenuik/ j. Tiegs (max) (current) 3 0 3192 . . BTC Cly Set At Size 178.9 X-65 Grade 20" 30 13 3/8" 746 Casing Summary Lithology (%) L-80 MBT 0' pH 1.117 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 0.0 49 0.0 in Time: 2712' 2770' 58' Max @ ft Current 2813'55.0 Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 339.0 Flow In (gpm) Flow In (spm) (current) J. Kenner/R. Wimmer Sh Clyst Tuff Gvl Coal cP 9 2532' 12.25 1.117 Footage Ss (ppb Eq) AK-AM-0900797980 $3,410.00 $31,500.00 Drilling Ahead PV 24 hr Max 68.0 Weight Hours Cement Cht Silt YP (lb/100ft 2) 9.90 12.0 Hycalog PDC LSND 6.3 2692' 2719'28 Depth in / out Mud Type Lst 70 Type 9.77 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL 3.2 160' 2692' WOB EVEMAR 3 2676'MD 160'MD Condition 1-1-WT-A-E-In-No-TD Bit # 2 3.5 16" Hughes MX-1 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE ROP ROP (ft/hr) 0.00 @ Mud Data Depth 10-Oct-2013 12:00 AM Current Pump & Flow Data: 933 Max Chlorides mg/l 700.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % * 24 hr Recap: (max) (current) 0 0 3612 907-685-0772 Unit Phone: 0 P.Kalenuik Maximum Report By: Logging Engineers: P. Kalenuik/ J. Tiegs 30 1610 40 Units* 0 0 0 0 C-5n 2770' C-2 33 0Minimum Depth 14 Gas Summary 0 0 0 (current) C-1 C-5i 0 C-3 00 C-4i C-4n 000 70 Average 2Background (max) Trip Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 0 0 Cut & slip drill line. RIH. Wash & ream f/2611' to 2719'. Drill to 2770' MD / 2549' TVD at report time. ECD . . * 24 hr Recap: 4 SKHI7 16D-E1OC 12.25 1.117 Drill 12.25" hole f/2770' MD to 3738' MD / 3195' TVD. Monitor well.Static.ECD at 9.86 lb/gal. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1100.00 0 11-Oct-2013 12:00 AM Current Pump & Flow Data: 1501 Max 0-0-WT-A-X-In-No-PR ROP ROP (ft/hr) 0.00 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # 2 4.3 16"Hughes MX-1 9.20 Size 3 ECD at 9.62 lb/gal. Max Gas: 12 & 13 units. No losses noted. 2676'MD 160'MD 100% Gas In Air=10,000 UnitsConnection 0 Tools API FL Chromatograph (ppm) 28 3.2160' 2692' WOB EVEMAR 0.00 Avg Min Comments RPM ECD (ppg) ml/30min 5Background (max)Trip Average Mud Type Lst 100 Type 159 12.0 Hycalog PDC LSND 5.2 2692' 4649'26 2717' Depth in / out YP (lb/100ft2) 9.80 000 00 CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0900797980 $3,410.00 $34,910.00 Drilling Ahead PV 2532' 12.25 1.117 Footage 4.10 25' 18.80 J. Kenner/O. Amend ShClyst TuffGvlCoal cP 10 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 673.0 Flow In (gpm) Flow In (spm) 2770' 4683' 1913' Max @ ft Current 4576'83.0 Date: Time: AM Max Gas: 4 & 20 units.No AM losses. Drill f/3738' MD to 4680' MD / 3456' TVD at report time. Monitor well.Static. 7 in 0Minimum Depth C-5n 4683' 140.0 C-2 41 SPP (psi) Gallons/stroke TFABit Type Depth 10.047 L-80 MBT 0' pH 1.117 0 0 0 Siltst 13 3/8" 905 Units* Casing Summary Lithology (%) 0724 0 907-685-0772Unit Phone: 46 P.Kalenuik Maximum Report By:Logging Engineers:P. Kalenuik/ J. Tiegs Set AtSize 178.9 X-65 Grade 20" (max)(current) BTC 0 0 Cly 5279 . . BTC Cly Set At Size 178.9 X-65 Grade 20" 90 13 3/8" 885 Casing Summary Lithology (%) L-80 MBT 0' pH 1.117 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 12.5 46 15.0 in Time: 4683' 5649' 966' Max @ ft Current 4664'38.0 Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 594.0 Flow In (gpm) Flow In (spm) (current) J. Kenner/O. Amend Sh Clyst Tuff Gvl Coal cP 10 2532' 12.25 1.117 Footage 4.10 25' 18.80 Ss (ppb Eq) AK-AM-0900797980 $3,410.00 $38,320.00 Drilling Ahead PV 24 hr Max 68.0 Weight Hours Cement Cht Silt YP (lb/100ft 2) 9.80 159 12.0 Hycalog PDC LSND 5.6 2692' 5622'27 2717' Depth in / out Mud Type Lst 10 Type 0.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL 28 3.2 160' 2692' WOB EVEMAR 3 2676'MD 160'MD Condition 1-1-WT-A-E-In-No-TD Bit # 2 5.0 16" Hughes MX-1 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 11 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE 0-0-WT-A-X-In-No-PR ROP ROP (ft/hr) 0.00 @ Mud Data Depth 12-Oct-2013 12:00 AM Current Pump & Flow Data: 1497 Max % Chlorides mg/l 1100.00 Density (ppg) out (sec/qt) Viscosity Cor Solids 4 SKHI7 16D-E1OC 12.25 1.117 * 24 hr Recap: (max) (current) 9 0 1289 907-685-0772 Unit Phone: 46 P.Kalenuik Maximum Report By: Logging Engineers: P. Kalenuik/ J. Tiegs 90 374 0 Units* 0 0 4 0 C-5n 5228' C-2 14 10% Sandstone : trnsl-trnsp-wh-lt-med gy-blk, hd, med-f gr, ang-sb rnd, ply sort, abd cht, r pyr, tr glauc. 0Minimum Depth Monitor well. Static. ECD at 9.89 lb/gal. AM Max Gas: 3 & 10 units. No AM losses. Drill f/5316' MD to 5645' MD / 3648' TVD 3 Latest Sample : 90% Siltstone : blk-brn, v crs-crs gr, hd, ang, mo srt, r pyr. Gas Summary 0 0 0 (current) C-1 C-5i 0 C-3 00 C-4i C-4n 000 10 Average 1Background (max) Trip Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 0 at report time. Monitor well. Static. 0 Drill 12.25" hole f/4680' MD to 5316' MD / 3589' TVD at 776 to 897 gpm, 1230 to 1550 psi & 110 to 127 rpm. . . BTC Cly Set At Size 178.9 X-65 Grade 20" 60 13 3/8" 833 Casing Summary Lithology (%) L-80 MBT 0' pH 1.117 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 12.5 47 0.0 in Time: 5649' 5755' 106' Max @ ft Current 5744'31.0 Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 203.0 Flow In (gpm) Flow In (spm) (current) J. Kenner/O. Amend Sh Clyst Tuff Gvl Coal cP 10 2532' 12.25 1.117 Footage 4.10 25' 18.80 10 Ss (ppb Eq) AK-AM-0900797980 $3,410.00 $41,730.00 POOH PV 24 hr Max 68.0 Weight Hours Cement Cht Silt YP (lb/100ft 2) 9.70 159 12.0 Hycalog PDC LSND 4.8 2692' 5755'28 2717' Depth in / out Mud Type Lst 30 Type 0.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL 28 3.2 160' 2692' WOB EVEMAR 3 2676'MD 160'MD Condition 1-1-WT-A-E-In-No-TD Bit # 2 5.0 16" Hughes MX-1 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE 0-0-WT-A-X-In-No-PR ROP ROP (ft/hr) 0.00 @ Mud Data Depth 13-Oct-2013 12:00 AM Current Pump & Flow Data: 1121 Max % Chlorides mg/l 1200.00 5755' Density (ppg) out (sec/qt) Viscosity Cor Solids 3038' 22 129 4 SKHI7 16D-E1OC 12.25 1.117 42.00 2717' * 24 hr Recap: (max) (current) 13 0 3016 907-685-0772 Unit Phone: 46 P.Kalenuik Maximum Report By: Logging Engineers: P. Kalenuik/ J. Tiegs 60 400 0 Units* 0 0 4 0 C-5n 5740' C-2 24 30% Sandstone : trnsl-trnsp-wh-lt-med gy-blk, hd, med-f gr, ang-sb rnd, ply sort, abd cht, tr pyr, tr glauc. 1Minimum Depth Overpull observed. BROOH at 900 gpm to 2611'. At 2611' 1st BU: 75% increase in 1" to 2" clay chunks. Circ total 3 BU. Monitor well. 4 Latest Sample : 60% Siltstone : blk-brn, v crs-crs gr, hd, ang, mo srt, tr pyr. 10% Clay Gas Summary 0 0 0 (current) 10 C-1 C-5i 4 C-3 00 C-4i C-4n 000 30 Average 1Background (max) Trip Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 5 10 min. Static. POH w/elevators to 2144' at report time. 0 Drill 12.25" hole f/5645' MD to 5755' MD / 3668' TVD. Monitor well. Static. PumpOH to 4440' due to level 3 shocks. . . 3038' 22 129 4 SKHI7 16D-E1OC 12.25 1.117 42.00 2717' 5755' Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1100.00 14-Oct-2013 12:00 AM Current Pump & Flow Data: 1450 Max 0-0-WT-A-X-In-No-PR ROP ROP (ft/hr) 0.00 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # 2 5.3 16" Hughes MX-1 9.30 Size 3 2676'MD 160'MD Tools API FL 28 3.2 160' 2692' WOB EVEMAR 0.00 Avg Min Comments RPM ECD (ppg) ml/30min Mud Type Lst 65 Type 159 12.0 Hycalog PDC LSND 4.6 2692' 6066'27 2717' Depth in / out YP (lb/100ft 2) 9.90 Cement Cht Silt 24 hr Max 68.0 Weight Hours 10 Ss (ppb Eq) AK-AM-0900797980 $3,410.00 $45,140.00 Drilling Ahead PV 2532' 12.25 1.117 Footage 4.10 25' 18.80 J. Kenner/O. Amend Sh Clyst Tuff Gvl Coal cP 10 (current) Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 374.0 Flow In (gpm) Flow In (spm) 5755' 6342' 587' Max @ ft Current 6345'100.0 Date: Time: in 240.0 SPP (psi) Gallons/stroke TFA Bit Type Depth 12.5 52 L-80 MBT 0' pH 1.117 Siltst 13 3/8" 883 Casing Summary Lithology (%) 25 Set At Size 178.9 X-65 Grade 20" BTC Cly * 24 hr Recap: POH to 361'. Monitor well. Static. L/D BHA. No AM Losses. P/U 12.25" PDC bit. RIH to 1011'. 0 100% Gas In Air =10,000 Units Connection 56 Chromatograph (ppm) 4Background (max) Trip Average 65 000 00 C-4i C-4n 0 C-3 10 C-1 C-5i Gas Summary 0 0 3 (current) Shallow test MWD. OK. RIH. Wash & ream f/5598' to 5755' at drill rate. Drill to 6342' MD / 3792' TVD. 16 Latest Sample : 65% Sandstone : trnsl-trnsp-wh-lt-med gy-blk, sft, med-v f gr, sb ang-sb rnd, ply srt, tr cht, tr pyr, v slty. 10% Clay 25% Siltstone : blk-brn, v crs-crs gr, hd, ang, mo srt, tr pyr. sort, abd cht, tr pyr, tr glauc. 0Minimum Depth C-5n 6342' C-2 28 0 25 0 Units* 0 25 1959 0 907-685-0772 Unit #110 Phone: 0 P.Kalenuik Maximum Report By: Logging Engineers: P. Kalenuik/ J. Tiegs (max) (current) 0 0 7246 . . BTC Cly Set At Size 178.9 X-65 Grade 20" 25 13 3/8" 895 Casing Summary Lithology (%) L-80 MBT 0' pH 1.117 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 15.5 51 0.0 in Time: 6342' 8044' 1702' Max @ ft Current 6345'76.0 Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 491.0 Flow In (gpm) Flow In (spm) (current) J. Kenner/O. Amend Sh Clyst Tuff Gvl Coal cP 11 2532' 12.25 1.117 Footage 4.10 25' 18.80 10 Ss (ppb Eq) AK-AM-0900797980 $3,410.00 $48,550.00 Drilling Ahead PV 24 hr Max 68.0 Weight Hours Cement Cht Silt YP (lb/100ft 2) 9.60 159 12.0 Hycalog PDC LSND 4.6 2692' 8045'24 2717' Depth in / out Mud Type Lst 65 Type 9.74 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL 28 3.2 160' 2692' WOB EVEMAR 3 2676'MD 160'MD Condition 1-1-WT-A-E-In-No-TD Bit # 2 6.3 16" Hughes MX-1 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 14 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE 0-0-WT-A-X-In-No-PR ROP ROP (ft/hr) 0.00 @ Mud Data Depth 15-Oct-2013 12:00 AM Current Pump & Flow Data: 1540 Max % Chlorides mg/l 1100.00 5755' Density (ppg) out (sec/qt) Viscosity Cor Solids 3038' 22 129 4 SKHI7 16D-E1OC 12.25 1.117 42.00 2717' * 24 hr Recap: (max) (current) 304 0 161618 907-685-0772 Unit #110 Phone: 8 P.Kalenuik Maximum Report By: Logging Engineers: P. Kalenuik/ J. Tiegs 25 14778 0 Units* 6 0 173 0 C-5n 7228' C-2 1290 40% Siltstone : blk-brn, v f gr, hd, ang-sb rnd, mo srt. 0Minimum Depth 120 Latest Sample : 60% Sandstone : trnsl-trnsp-wh-lt-med gy-blk, sft, CRS-f gr, sb ang-sb rnd, ply srt, r glauc, tr pyr. Gas Summary 0 173 7 (current) 10 C-1 C-5i 28 C-3 00 C-4i C-4n 060 65 Average 0Background (max) Trip Chromatograph (ppm) 100% Gas In Air =10,000 Units Connection 391 32 Drill 12.25" hole f/6342' MD to TD at 8045' MD / 4070' TVD. No Drilling losses. . . 3038' 22 129 4 SKHI7 16D-E1OC 12.25 1.117 42.00 2717' 5755' Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1100.00 16-Oct-2013 12:00 AM Current Pump & Flow Data: Max 0-0-WT-A-X-In-No-PR ROP ROP (ft/hr) 0.00 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # 2 6.3 16" Hughes MX-1 9.20 Size 3 2676'MD 160'MD Tools API FL 28 3.2 160' 2692' WOB EVEMAR 9.42 Avg Min Comments RPM ECD (ppg) ml/30min Mud Type Lst 65 Type 159 12.0 Hycalog PDC LSND 5.0 2692' 8045'22 2717' Depth in / out YP (lb/100ft 2) 9.60 Cement Cht Silt 24 hr Max 68.0 Weight Hours 10 Ss (ppb Eq) AK-AM-0900797980 $3,410.00 $51,960.00 Float 9-5/8" Csg PV 2532' 12.25 1.117 Footage 4.10 25' 18.80 J. Kenner/O. Amend Sh Clyst Tuff Gvl Coal cP 10 (current) Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 8044' 8044' 0' Max @ ft Current Date: Time: in 0.0 SPP (psi) Gallons/stroke TFA Bit Type Depth 15.0 45 L-80 MBT 0' pH 1.117 Siltst 13 3/8" Casing Summary Lithology (%) 25 Set At Size 178.9 X-65 Grade 20" BTC Cly * 24 hr Recap: Cont BROOH f/5038' to 2611' at 900 gpm,1290 psi & 120 rpm. CBU x 5 at drill rate. POH. L/D BHA #5. Runni 100% Gas In Air =10,000 Units Connection Chromatograph (ppm) Background (max) Trip Average 65 C-4i C-4n C-3 10 C-1 C-5i Gas Summary (current) Run 9-5/8" csg to 168'. Check float. OK.. Latest Sample : 60% Sandstone : trnsl-trnsp-wh-lt-med gy-blk, sft, CRS-f gr, sb ang-sb rnd, ply srt, r glauc, tr pyr. 40% Siltstone : blk-brn, v f gr, hd, ang-sb rnd, mo srt. Minimum Depth C-5n C-2 Units* 25 907-685-0772 Unit #110 Phone: P.Kalenuik Maximum Report By: Logging Engineers: P. Kalenuik/ J. Tiegs (max) (current) . . BTC Cly Set At Size 178.9 X-65 Grade 8030'MD 20" 9 5/8" 40 13 3/8" 80 Casing Summary Lithology (%) L-80 MBT 0' pH 1.117 Siltst SPP (psi) Gallons/stroke TFA Bit Type Depth 15.0 48 0.0 in Time: 8044' 8044' 0' Max @ ft Current 0'0.0 Date: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) (current) J. Kenner/O. Amend Sh Clyst Tuff Gvl Coal cP 11 2532' 12.25 1.117 Footage 4.10 25' 18.80 Ss (ppb Eq) AK-AM-0900797980 $3,410.00 $55,370.00 Circ & Condition PV 24 hr Max 68.0 Weight Hours Cement Cht Silt YP (lb/100ft 2) 9.60 159 12.0 Hycalog PDC LSND 5.2 2692' 8045'24 2717' Depth in / out Mud Type Lst 60 Type 9.74 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL 28 3.2 160' 2692' WOB EVEMAR 3 2676'MD 160'MD Condition 1-1-WT-A-E-In-No-TD Bit # 2 6.5 16" Hughes MX-1 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE 0-0-WT-A-X-In-No-PR ROP ROP (ft/hr) 0.00 @ Mud Data Depth 17-Oct-2013 12:00 AM Current Pump & Flow Data: 257 Max % Chlorides mg/l 1100.00 5755' Density (ppg) out (sec/qt) Viscosity Cor Solids 3038' 22 129 4 SKHI7 16D-E1OC 12.25 1.117 42.00 2717' * 24 hr Recap: (max) (current) 0 0 0 907-685-0772 Unit #110 Phone: 0 P.Kalenuik Maximum Report By: Logging Engineers: P. Kalenuik/ J. Tiegs 40 0 0 Units* 0 0 0 0 C-5n 0' C-2 0 40% Siltstone : blk-brn, v f gr, hd, ang-sb rnd, mo srt. 0 0'Minimum Depth Circ & condition hole; 2 bpm & 270 psi. 0 Latest Sample : 60% Sandstone : trnsl-trnsp-wh-lt-med gy-blk, sft, CRS-f gr, sb ang-sb rnd, ply srt, r glauc, tr pyr. Gas Summary 0 0 0 (current) C-1 C-5i 0 C-3 00 C-4i C-4n 000 60 Average 00Background (max) Trip Chromatograph (ppm) 100% Gas In Air =10,000 Units 0Connection 0 0 Float 9-5/8" casing f/186' to 2181'. L/D jts #53 & #54. RIH to 6652'. Start rotating casing f/6652' to 8029' MD. . . 3038' 22 129 4 SKHI7 16D-E1OC 12.25 1.117 42.00 2717' 5755' Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1100.00 18-Oct-2013 12:00 AM Current Pump & Flow Data: 0 Max 0-0-WT-A-X-In-No-PR ROP ROP (ft/hr) 0.00 @ Mud Data Depth Morning Report Report # 17 Customer: Well: Area: Location: Rig: SP08-N7 ENI PETROLEUM SPY ISLAND NORTH SLOPE Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: DOYON15 Report For: Condition 1-1-WT-A-E-In-No-TD Bit # 2 6.5 16" Hughes MX-1 9.20 Size 3 2676'MD 160'MD Tools API FL 28 3.2 160' 2692' WOB EVEMAR 0.00 Avg Min Comments RPM ECD (ppg) ml/30min Mud Type Lst 60 Type 159 12.0 Hycalog PDC LSND 5.2 2692' 8045'14 2717' Depth in / out YP (lb/100ft 2) 9.20 Cement Cht Silt 24 hr Max 68.0 Weight Hours Ss (ppb Eq) AK-AM-0900797980 $4,410.00 $59,780.00 Freeze Protect OA PV 2532' 12.25 1.117 Footage 4.10 25' 18.80 J. Kenner/O. Amend Sh Clyst Tuff Gvl Coal cP 10 (current) Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 8044' 8044' 0' Max @ ft Current 0'0.0 Date: Time: in 0.0 SPP (psi) Gallons/stroke TFA Bit Type Depth 15.0 46 L-80 MBT 0' pH 1.117 Siltst 13 3/8" 0 Casing Summary Lithology (%) 40 Set At Size 178.9 X-65 Grade 8030'MD 20" 9 5/8" BTC Cly * 24 hr Recap: Cond hole at 2 to 6 bpm while SLB cementers work on pump. Cmt Job; 9-5/8" csg. Drop bottom plug.Test lines. 0 Freeze protect OA at 2 bpm & 1000 psi at report time. 100% Gas In Air =10,000 Units 0Connection 0 Chromatograph (ppm) 0Background (max) Trip Average 0 60 000 00 C-4i C-4n 0 C-3 C-1 C-5i Gas Summary 0 0 0 (current) Drop top plug, no losses noted. R/D cmt equip. N/D BOPE. Set 9-5/8" emergency slips. Install packoff & test. OK. N/U BOPE. 4 Latest Sample : 60% Sandstone : trnsl-trnsp-wh-lt-med gy-blk, sft, CRS-f gr, sb ang-sb rnd, ply srt, r glauc, tr pyr. 40% Siltstone : blk-brn, v f gr, hd, ang-sb rnd, mo srt. 0Minimum Depth C-5n C-2 87 0 0 0 Units* 0 40 1008 0 907-685-0772 Unit #110 Phone: 0 K. Plowman Maximum Report By: Logging Engineers: K. Plowman/ J. Tiegs (max) (current) 0 0 11041 . . 20" 9 5/8" Cly 160'MD 2676'MD 8030'MD EVEMAR BTC Depth in / out Bit Type RPM 8045' 160 129.0 ENI PETROLEUM SP08-N7 SPY ISLAND NORTH SLOPE DOYON15 AK-AM-0900797980 $3,410.00 $63,190.00 J. Kenner/O. Amend SKHI7 16D-E1OC SKHI7 16D-E1OC 178.9 68.0 X-65 L-80 Set At Size Grade 8044' 8044' 19-Oct-2013 13 3/8" in 0 Alkal Coal Gallons/stroke 0' Lime Tuff Gvl Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) Max @ ft 0' Date: Time: API FL Depth 0' Avg to 0' Current 0.0 0.0 (current) Clyst Ss Cht Silt Casing Summary Lithology (%) 1.117 10 50 3038' 12.25 0.969 Footage Wireline: CBL PV cP Weight Flow In (gpm) Flow In (spm) Oil / Water Hours Cement Sh Siltst Lst (lb/100ft 2) 9.25 Type 18 Mud (lb/bbl) ml/30min 2290' 10 22.0 Comments Bit # 4 12.25 2717' 5 5755'11.00 42.00 Size 5755' WOB TFA Condition MWD Summary 96% %Mud Type FAZEPRO 5.6 Ratio Mud Data Depth 4.23 @ Current Pump & Flow Data: Report For: 8045' Cor Solids Avg Min YP Max ECD (ppg) Tools Job No.: Daily Charges: Total Charges: Rig Activity: 0.0 Morning Report Report # 18 Customer: Well: Area: Location: Rig: 12:00 AM 0 ROP ROP (ft/hr) 24 hr Max Density (ppg) out (sec/qt) Viscosity * 24 hr Recap: Report By: Logging Engineers: K. Plowman / J. Tiegs (max) (current) 907-685-0772 Unit # 110 Phone: 0 K. Plowman 0 C-2 Gas Summary 0 0 0 0 0 0 0 0 Minimum Depth Maximum 0 0 0 R/U wireline and function test. RIH w/tractor and CBL. Intermittent communication issues. POOH w/wireline and C/O CBL tool. 0 C-5n (current) Units* 0 C-1 C-5i Chromatograph (ppm) 0 0 00 C-4i C-4n 0 C-3 Average Trip (max) 0 Background RIH to 7950' and begin logging out of hole. 100% Gas In Air =10,000 Units Connection Service rig and top drive. P/U 60 jts 4.5" DP. Test BOPE's. Rig down test equipment. Pull test plug. Set wear ring. . . Cly 160'MD L-80 Bit Type RPM 20" 9 5/8" NORTH SLOPE DOYON15 AK-AM-0900797980 $3,410.00 $66,600.00 J. Kenner/O. Amend X-65 L-80 Casing Summary 4 12.25 5 160.0 2676'MD 8030'MD EVEMAR Set At Size Grade 8044' 8065' 20-Oct-2013 MDSi616 BPX 13 3/8" in SKHI7 16D-E1OC 489 Alkal Coal Gallons/stroke API FL Cement 21' Lime Tuff Gvl 24 Hour Progress: 117 SPP (psi) Max @ ft 8047' Date: Time: Depth 0' Avg to 0' Current 84.8 0.0 MWD Summary Bit # (current) Clyst Ss Cht Silt 2290' 8.75 0.902 Footage Size 40.0 178.9 68.0 BTC Depth in / out Flow In (gpm) Flow In (spm) Oil / Water Hours 5755' 8045' 11.00 13 46 Sh Siltst 9.20 Type 18 Lst Hydril 563 Lithology (%) Mud (lb/bbl) ml/30min 3.84 2.95 10.0 (lb/100ft 2)cP 8045' WOB TFA Condition 0-0-CT-A-X-I-NO-TD Comments Weight 0.969 96% %Mud Type FAZEPRO - Ratio Mud Data Depth 1.8 4.23 @ Current Pump & Flow Data: Report For: 8045'6.5 Cor Solids 10.12 Avg Min YP Max ECD (ppg) Tools PV Job No.: Daily Charges: Total Charges: Rig Activity: 253.3 ENI PETROLEUM SP08-N7 SPY ISLAND Morning Report Report # 19 Customer: Well: Area: Location: Rig: 12:00 AM FIT Yesterday's Depth: Current Depth: 2056 ROP ROP (ft/hr) 24 hr Max Density (ppg) out (sec/qt) Viscosity * 24 hr Recap: Report By: Logging Engineers: K. Plowman / J. Tiegs 907-685-0772 Unit # 110 Phone: 0 K. Plowman 0 C-2 Gas Summary 0 0 0 0 0 0 0 Minimum Depth Maximum 0 0 0 to 9.25 lb/gal FazePro mud. Clean surface equipment, cut and slip drill line. Drill shoe track, shoe, and 21' rat hole to 8065' MD. Latest Sample: No new samples 0 C-5n 0 (current) Units* Chromatograph (ppm) 00 C-4i C-4n 0 C-5i 0 0 0 C-1 Average 3 (max) 0 (max) (current) Background Trip C-3 =10,000 Units Connection POOH to 7899' MD to circulate for FIT. 100% Gas In Air Rig down wireline. Test 9 5/8" casing. Pick up BHA #6. Run in hole, wash down and tag plug at 7941'. Displace . . Set At Size 8.75 20" 9 5/8" NORTH SLOPE DOYON15 Casing Summary 4 12.25 AK-AM-0900797980 $3,410.00 $70,010.00 J. Kenner/O. Amend X-65 L-80 Grade Max @ ft 9242' 2290' 5 160.0 2676'MD 8030'MD EVEMAR 8065' 9568' 21-Oct-2013 MDSi616 BPX 1503' Lime Tuff Gvl Depth 0' 13 3/8" in SKHI7 16D-E1OC Bit # (current) 486 Alkal Coal Gallons/stroke API FL Cement L-80 24 Hour Progress: 0 SPP (psi) Date: Time: Mud to 0' Current 74.8 0.0 MWD Summary Clyst Ss Cht Silt Cly 0.902 Footage Size 40.0 178.9 68.0 BTC Depth in / out 160'MD Bit Type Flow In (gpm) Flow In (spm) Oil / Water Hours 5755' 8045' 11.00 12 43 Sh Siltst 9.20 Type 17 Lst 95 Hydril 563 5 Lithology (%) (lb/bbl) ml/30min 3.58 2.75 10.0 (lb/100ft 2)cP RPM 8045' WOB TFA Condition 0-0-CT-A-X-I-NO-TD Comments Weight 0.969 96% %Mud Type FAZEPRO - Ratio Mud Data Depth 67/33 4.23 @ Current Pump & Flow Data: Report For: 9163'7.2 Cor Solids 10.34 Avg Min YP Max ECD (ppg) Tools PV Job No.: Daily Charges: Total Charges: Rig Activity: 501.9 ENI PETROLEUM SP08-N7 SPY ISLAND Avg Morning Report Report # 20 Customer: Well: Area: Location: Rig: 12:00 AM Drill 8.75' Prod Yesterday's Depth: Current Depth: 2288 ROP ROP (ft/hr) 24 hr Max Density (ppg) out (sec/qt) Viscosity * 24 hr Recap: Report By: Logging Engineers: K. Plowman / J. Tiegs 907-685-0772 Unit # 110 Phone: 27 K. Plowman 13 C-2 Gas Summary 114 00Minimum 536 391554 0 82213 4108 Depth Maximum (current) 8825' 0 1187 67 0 8066' MD to 9476' MD / 4108' TVD at midnight. Monitor well. No losses noted while drilling. 1108 30% even dull yel-wh fluor, strmg dull yel-wh ct fluor, dull yel res fluor. Latest Sample: 95% Sandstone : trnsl-trnsp-wh-lt gy-brn-grn, f-vf gr, sb ang-sb rnd, w srt, abd glauc, tr mic, SHOW: no odor, tr lt brn stn, 0 Units* Chromatograph (ppm) C-5n 6416 C-4i C-4n 21 C-5i 39 735 2190 95 5 C-1 3 Average 3 (max) 0 (max) (current) 98 Background Trip C-3 =10,000 Units Connection 5% Siltstone 100% Gas In Air Cond hole. R/U to perform FIT. R/D equip. Drill 8.75" production hole w/tapered drill string 5" & 4.5" DP from . . Size 8.75 20" 9 5/8" NORTH SLOPE DOYON15 Casing Summary 4 12.25 AK-AM-0900797980 $3,410.00 $73,420.00 J. Kenner/O. Amend X-65 L-80 Grade Max @ ft 10411' 2290' 5 160.0 2676'MD 13 3/8" in 8030'MD EVEMAR 9569' 11302' 22-Oct-2013 1733' Lime Tuff Gvl Depth 0' Bit # (current) 502 Alkal Coal Gallons/stroke API FL Cement L-80 2.60 24 Hour Progress: 120 SPP (psi) Date: Time: Mud (lb/bbl) ml/30min 3.38 to 0' Current 78.2 10.0 MWD Summary Avg Clyst Ss Cht Silt Cly 178.9 68.0 BTC Depth in / out 160'MD Bit Type SKHI7 16D-E1OC MDSi616 BPX Set At 11.00 13 42 0.902 Footage Size Flow In (gpm) Flow In (spm) Oil / Water Hours 5755' 8045' Lithology (%) 9.20 Type 14 Sh Siltst Lst 95 Hydril 563 5 40.0 10.0 (lb/100ft 2)cP RPM 8045' WOB TFA Condition 0-0-CT-A-X-I-NO-TD Comments Weight 0.969 96% %Mud Type FAZEPRO - Ratio Mud Data Depth 69/31 4.23 @ Current Pump & Flow Data: Report For: 10986'7.7 Cor Solids 10.56 Avg Min YP Max ECD (ppg) Tools PV Job No.: Daily Charges: Total Charges: Rig Activity: 538.7 ENI PETROLEUM SP08-N7 SPY ISLAND Morning Report Report # 21 Customer: Well: Area: Location: Rig: 12:00 AM Drill 8.75' Prod Yesterday's Depth: Current Depth: 2261 ROP ROP (ft/hr) 24 hr Max Density (ppg) out (sec/qt) Viscosity * 24 hr Recap: Report By: Logging Engineers: K. Plowman / J. Tiegs 907-685-0772 Unit # 110 Phone: 42 K. Plowman 46 C-2 Gas Summary 141 00Minimum Depth Maximum 93 10018' 887 445593 0 (current) 10889' 0 1536 5727 0 ECD's=10.59-10.37ppg. Max Gas=5727 units. Due to high gas unit increased mud weight F/9.15ppg T/9.3ppg by 0.5ppg increment 1753 lt brn stn, 10% even brt yel-wh fluor, brt yel-wh ct fluor, amb ct. Latest Sample: 95% Sandstone : trnsl-trnsp-wh-lt gy-brn-crm, m-vf gr, sb ang-sb rnd, mod srt, abd glauc, tr mic, tr pyr, SHOW: no odor, 0 C-5n 21 803 C-4i C-4n 54 C-5i 67 777 2512 6 Chromatograph (ppm) 95 5 C-1 Units* Average (max) 244 (max) 121 134276 Trip (current) Background C-3 =10,000 Units Connection 5% Siltstone regarding gas units. No loss for today. 100% Gas In Air Drilling F/9569' T/11302' @ midnight. Con't drilling F/10223' T/11250' @ GPM=550-500 PSI=2300 . . Density (ppg) out (sec/qt) Viscosity 2967 ROP ROP (ft/hr) 24 hr Max Morning Report Report # 22 Customer: Well: Area: Location: Rig: 12:00 AM Drill 8.75' Prod Yesterday's Depth: Current Depth: Job No.: Daily Charges: Total Charges: Rig Activity: 493.0 ENI PETROLEUM SP08-N7 SPY ISLAND YP Max ECD (ppg) Tools PV Cor Solids 11.25 Avg Min Depth 70/30 4.23 @ Current Pump & Flow Data: Report For: 13542'8.2 Comments Weight 0.969 96% %Mud Type FAZEPRO - Ratio Mud Data 8045' WOB TFA Condition 0-0-CT-A-X-I-NO-TD 10.0 (lb/100ft 2)cP RPM Lst 90 Hydril 563 10 40.0 Lithology (%) 9.30 Type 17 Sh Siltst Flow In (gpm) Flow In (spm) Oil / Water Hours 5755' 8045' 11.00 15 45 0.902 Footage Size 178.9 68.0 BTC Depth in / out 160'MD Bit Type SKHI7 16D-E1OC MDSi616 BPX Set At Avg Clyst Ss Cht Silt Cly (lb/bbl) ml/30min 2.99 to 0' Current 119.0 0.0 MWD Summary 2.30 24 Hour Progress: 105 SPP (psi) Date: Time: 535 Alkal Coal Gallons/stroke API FL L-80 Mud (current) Depth 0' Bit # 11302' 13958' 23-Oct-2013 2656' Lime Tuff Gvl Cement L-80 Grade Max @ ft 11907' 2290' 5 160.0 2676'MD 13 3/8" in NORTH SLOPE DOYON15 Casing Summary 4 12.25 AK-AM-0900797980 $3,410.00 $76,830.00 M. Ross/O. Amend X-65 Size 8.75 20" 9 5/8" 8030'MD EVEMAR * 24 hr Recap: Continue to drill ahead in production section from 11302' MD to 13958' MD. The max gas observed was 4200 units 100% Gas In Air =10,000 Units Connection Trip (current) Background 289 (max) 137 90326 Average (max) 90 10 C-1 Units* 10 Chromatograph (ppm) 631 2125 C-3 C-4i C-4n 74 C-5i 90 C-5n Latest Sample: SST: trnsl-trnsp-wh-lt gy-brn-crm, f-vf gr, sb ang-sb rnd, w srt, abd glauc, r sh frag, sli slty, SHOW: no odor, lt brn stn, 0 33 1118 0 @ 11271' MD 961 50% even brt yel-wh fluor, dull yel ct fluor, lt amb ct. (current) 11271' 0 1540 4200 1137 392632 0 Gas Summary 134 00Minimum Depth Maximum 907-685-0772 Unit # 110 Phone: 42 K. Plowman 36 94 12955' Report By: Logging Engineers: K. Plowman / J. Tiegs C-2 . . 20" 9 5/8" 8030'MD EVEMAR NORTH SLOPE DOYON15 Casing Summary 4 12.25 AK-AM-0900797980 $3,410.00 $80,240.00 M. Ross/O. Amend X-65 15083' 2290' 5 160.0 2676'MD 13 3/8" in Size 8.75 Cement Bit # 13958' 15728' 24-Oct-2013 1770' Lime Tuff Gvl (current) 486 Alkal Coal Gallons/stroke API FL L-80 Mud 2.30 24 Hour Progress: 111 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.99 to 0' 0' L-80 Grade Set At Avg Clyst Ss Cht Silt 35 Size 178.9 68.0 BTC Depth in / out 160'MD Bit Type SKHI7 16D-E1OC MDSi616 BPX 8045' 11.00 14 46 0.902 Footage Flow In (gpm) Flow In (spm) Oil / Water Hours 5755' Lithology (%) 9.30 Type 20 Sh Siltst Lst 65 Hydril 563 40.0 10.0 (lb/100ft 2)cP RPM 8045' WOB TFA Condition 0-0-CT-A-X-I-NO-TD Comments Weight 0.969 96% %Mud Type FAZEPRO - Ratio Mud Data Current Pump & Flow Data: Report For: 15523'8.2 Current 78.8 0.0 Avg Min Depth 70/30 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools PV Cor Solids 11.40 Job No.: Daily Charges: Total Charges: Rig Activity: 514.0 ENI PETROLEUM SP08-N7 SPY ISLAND Max @ ft Morning Report Report # 23 Customer: Well: Area: Location: Rig: 12:00 AM Drill 8.75' Prod Yesterday's Depth: Current Depth: 2943 ROP ROP (ft/hr) 24 hr Max Density (ppg) out (sec/qt) Viscosity * 24 hr Recap: Report By: Logging Engineers: K. Plowman / J. Tiegs C-2 Maximum 907-685-0772 Unit # 110 Phone: 60 K. Plowman 121 140 15542' Gas Summary 207 00Minimum Depth 1764 429075 0 (current) 14820' 0 2401 5300 0 max gas observed was 5300 units @ 14820' MD. 1682 lt brn stn, 40% brt wh-yel fluor, dull yel ct fluor, lt amb ct. Latest Sample: SST: trnsl-trnsp-wh-gy-brn-grn-crm, m-vf gr, sb ang-sb rnd, mod srt, tr mic, tr pyr, r shl frag, v slty, SHOW: no odor, 0 53 1622 35 C-5n C-4i C-4n 105 C-5i 134 979 3501 C-3 13 Chromatograph (ppm) 65 C-1 Units* Average (max) 502 (max) 47 190380 Trip (current) Background =10,000 Units Connection 100% Gas In Air Continued to drill production hole from 13958' MD to 15728' MD. Serviced top drive, block, and Drawworks. The . . * 24 hr Recap:Continue to drill production hole from 15728' MD to TD of 15870' MD. Begin to BROOH per K&M rep. Max gas 2026 ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig:12:00 AM BROOH Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7 SPY ISLAND Max @ ft Morning Report Report # 24 Customer: Well: Area: Location: Current Pump & Flow Data: PV 11.27 11.70 Cor Solids 11.56 Job No.: Daily Charges: Total Charges: Rig Activity: 305.7 4.23 @ MWD Summary Depth YP MaxECD (ppg)Tools Xceed 675, Periscope 675, TeleScope 675, adnVision 675 Report For: 15870'8.4 Current 207.0 96% %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft2)cP 70/309.30 Avg Min Depth 100% Gas In Air 9.30 8045' WOBTFA Condition 0-0-CT-A-X-I-NO-TD Comments (current) Background (max) 55 98415 Trip 96 (max) 280 =10,000 Units-Connection 10.0 40.0 Type 68 RPM Average Weight 0.969 Hydril 563 C-1 Lithology (%) 46 15828' 16 ShSiltst C-5i 551 1944 C-5n Flow In (gpm) Flow In (spm) Oil / Water Hours 5755' C-4i C-4nC-3 1344 0.902 Footage 15870' Chromatograph (ppm) Lst 160'MD Bit Type SKHI7 16D-E1OC MDSi616 BPX 8045' 11.00 Avg ClystSsChtSilt 20 Size to15728' 15870' L-80 GradeSet At 178.9 68.0BTC 119 SPP (psi) Date: Time: Cly (lb/bbl)ml/30min 2.54 Depth in / out API FL L-80 Mud 1.95 293 30852 498 Alkal Coal Gallons/stroke 61 observed was 1640 units @ 15828' MD. Samples have consisted of 80% sst & 20% sltst. 828 34 1396 1716 (current) 1640 80 Units* 15728' 15870' 25-Oct-2013 142' Lime TuffGvl 24 Hour Progress: Cement Gas Summary 119 19137Minimum Depth 907-685-0772Unit # 110 Phone: 42 Leigh Ann Rasher 3261 88 15806' 935 15844' 2290' 5 160.0 2676'MD13 3/8" in Size 8.75 Bit # NORTH SLOPE DOYON15 Casing Summary 4 12.25 AK-AM-0900797980 $4,410.00 $84,650.00 M. Ross/O. Amend X-65 Report By: 20" 9 5/8" Logging Engineers:Leigh Ann Rasher / Kori Jo Plowman 8030'MD EVEMAR C-2 Maximum 185201 . . * 24 hr Recap: Report By: 20" 9 5/8" Logging Engineers:Leigh Ann Rasher / Kori Jo Plowman 8030'MD EVEMAR C-2 Maximum 0 NORTH SLOPE DOYON15 Casing Summary 4 12.25 AK-AM-0900797980 $3,410.00 $88,060.00 M. Ross/O. Amend X-65 2290' 5 160.0 2676'MD13 3/8" in Size 8.75 Bit # 907-685-0772Unit # 110 Phone: 0 Leigh Ann Rasher 0 0 0 Cement Gas Summary 0 00Minimum Depth 15870' 15870' 26-Oct-2013 0' Lime TuffGvl 24 Hour Progress: (current) Units* 0 0 00 0 0 00 Alkal Coal Gallons/stroke API FL 0-1-CT-Sh-X-In-No-TD L-80 Mud 2.20 10 SPP (psi) Date: Time: Cly (lb/bbl)ml/30min 2.86 Depth in / out to15870' 15870' L-80 GradeSet At 7825' 178.9 68.0BTC Avg ClystSsChtSilt Size 160'MD Bit Type SKHI7 16D-E1OC MDSi616 BPX 8045'60.30 11.00 1342 0.902 Footage 15870' Chromatograph (ppm) Lst C-5n Flow In (gpm) Flow In (spm) Oil / Water Hours 5755' C-4i C-4nC-3 16 ShSiltst C-5i 0 0 Lithology (%) RPM 160 Average Weight 0.969 Hydril 563 C-1 0 =10,000 Units-Connection 10.0 40.0 Type 0 Trip 12 (max) 0 (current) Background (max) Condition 0-0-CT-A-X-I-NO-TD Comments Avg Min Depth 100% Gas In Air 9.35 8045' WOBTFA %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft2)cP 70/309.35 Report For: 15870'8.5 Current 96%4.23 @ MWD Summary Depth YP MaxECD (ppg)Tools PV Cor Solids Job No.: Daily Charges: Total Charges: Rig Activity: ENI PETROLEUM SP08-N7 SPY ISLAND Max @ ft Morning Report Report # 25 Customer: Well: Area: Location: Current Pump & Flow Data: Rig:12:00 AM RIH w/ 5.5" liner Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ROP ROP (ft/hr) 24 hr Max Density (ppg) Cont. BROOH per K&M rep. Circ B/U & monitor well. Cont POOH. L/D BHA #6. R/U to RIH w/ 5.5" liner. . . * 24 hr Recap:Cont RIH w/ 5.5" liner. M/U liner hanger assy. Cont RIH w/ 5" DP. Set liner & POOH. Test BOPs. ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig:12:00 AM Test BOPs Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7 SPY ISLAND Max @ ft Morning Report Report # 26 Customer: Well: Area: Location: Current Pump & Flow Data: PV Cor Solids Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ MWD Summary Depth YP MaxECD (ppg)Tools Report For: 15870'9.0 Current 96% %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft2)cP 70/309.40 Avg Min Depth 100% Gas In Air 9.40 8045' WOBTFA Condition 0-0-CT-A-X-I-NO-TD Comments (current) Background (max) 0 Trip (max) 0 =10,000 Units-Connection 10.0 40.0 Type 0 RPM 160 Average Weight 0.969 Hydril 563 C-1 Lithology (%)ShSiltst C-5i 0 0 C-5n Flow In (gpm) Flow In (spm) Oil / Water Hours 5755' C-4i C-4nC-3 151443 0.902 Footage 15870' Chromatograph (ppm) Lst 160'MD Bit Type SKHI7 16D-E1OC MDSi616 BPX 8045'60.30 11.00 Avg ClystSsChtSilt Size to15870' 15870' L-80 GradeSet At 7825' 178.9 68.0BTC SPP (psi) Date: Time: Cly (lb/bbl)ml/30min 2.60 Depth in / out API FL 0-1-CT-Sh-X-In-No-TD L-80 Mud 2.00 10 0 00 Alkal Coal Gallons/stroke 0 0 0 00 (current) Units* 15870' 15870' 27-Oct-2013 0' Lime TuffGvl 24 Hour Progress: Cement Gas Summary 0 00Minimum Depth 907-685-0772Unit # 110 Phone: 0 Leigh Ann Rasher 0 0 0 2290' 5 160.0 2676'MD13 3/8" in Size 8.75 Bit # NORTH SLOPE DOYON15 Casing Summary 4 12.25 AK-AM-0900797980 $3,410.00 $91,470.00 M. Ross/O. Amend X-65 Report By: 20" 9 5/8" Logging Engineers:Leigh Ann Rasher / Kori Jo Plowman 8030'MD EVEMAR C-2 Maximum 0 . . 20" 9 5/8" 8030'MD EVEMAR NORTH SLOPE DOYON15 Casing Summary 6RR 8.75 AK-AM-0900797980 $3,410.00 $94,880.00 M. Ross/O. Amend X-65 2676'MD 13 3/8" in Size Bit # Cement 7791' 7821' 28-Oct-2013 30' Lime Tuff Gvl 24 Hour Progress: (current) 444 Alkal Coal Gallons/stroke API FL L-80 Mud 2.20 106 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.86 Depth in / out to 7791' 7821' L-80 Grade Set At 178.9 68.0 BTC Avg Clyst Ss Cht Silt Size 160'MD Bit Type Smith XR+ Milltooth 14 45 Footage Lst Flow In (gpm) Flow In (spm) Oil / Water Hours 15870' 16 Siltst Lithology (%) Sh RPM Weight 0.902 Hydril 563 40.0 Type Condition Comments Avg Min Depth 9.30 WOB TFA %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 2.2 9.30 Report For: 7808'7.7 Current 3.8 96% 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools SP Motor 1.50, TeleScope 675 PV Cor Solids Job No.: Daily Charges: Total Charges: Rig Activity: ENI PETROLEUM SP08-N7 L1 SPY ISLAND Max @ ft Morning Report Report # 27 Customer: Well: Area: Location: Current Pump & Flow Data: Rig: 12:00 AM Milling window Yesterday's Depth: Current Depth: out (sec/qt) Viscosity 1073 ROP ROP (ft/hr) 24 hr Max Density (ppg) * 24 hr Recap: Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 0 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 0 0 0 Gas Summary 0 00Minimum Depth (current) Units* 00 Max Gas = 19 u Avg Gas = 10 u 0 0 00 Chromatograph (ppm) C-5n C-4i C-4n C-3 C-5i 0 0 0 0 Average C-1 0 =10,000 Units -Connection 0 Trip 19 (max) 0 (current) Background (max) Spot sample collected @ 7801' MD consisted of 100% sst. 100% Gas In Air Cont test BOPs. M/U & P/U whipstock BHA. RIH & begin milling window at 7791' MD. . . ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig: 12:00 AM RIH Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7 L1 SPY ISLAND Max @ ft Morning Report Report # 28 Customer: Well: Area: Location: Current Pump & Flow Data: PV Cor Solids Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools SP Motor 1.50, TeleScope 675 Report For: 7838'8.1 Current 96% %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 69/31 9.30 Avg Min Depth WOB TFA Condition Comments 40.0 Type RPM Weight 0.902 Hydril 563 Lithology (%) Sh Siltst Flow In (gpm) Flow In (spm) Oil / Water Hours 7838' 16 14 46 Footage Lst 160'MD Bit Type Smith XR+ Milltooth Avg Clyst Ss Cht Silt Size to 7821' 7838' L-80 Grade Set At 178.9 68.0 BTC SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.86 Depth in / out API FL L-80 Mud 2.20 Alkal Coal Gallons/stroke (current) 7821' 7838' 29-Oct-2013 17' Lime Tuff Gvl 24 Hour Progress: Cement 2676'MD 13 3/8" in Size Bit # NORTH SLOPE DOYON15 Casing Summary 6RR 8.75 AK-AM-0900797980 $3,410.00 $98,290.00 M. Ross/O. Amend X-65 20" 9 5/8" 8030'MD EVEMAR * 24 hr Recap: Cont milling window. TOW @ 7791' MD, BOW @ 7808' MD. Mill to 7838' MD. Drop ball & pump sweep. POOH. L/D 100% Gas In Air (current) Background (max) 0 Trip 19 (max) 0 =10,000 Units -Connection 0Average C-1 C-5i 0 0 0 0 C-5n C-4i C-4n C-3 Chromatograph (ppm) 0 00 Max Gas = 19 u Avg Gas = 14 u 0 milling BHA & P/U BHA #8. RIH. 00 (current) Units* Gas Summary 0 00Minimum Depth 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 0 0 0 Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 0 . . 20" 9 5/8" 8030'MD EVEMAR NORTH SLOPE DOYON15 Casing Summary 6RR 8.75 AK-AM-0900797980 $3,410.00 $101,700.00 M. Ross/O. Amend X-65 7917' 200' 7 40.0 2676'MD 13 3/8" in Size 8.75 Bit # Cement 7838' 8038' 30-Oct-2013 200' Lime Tuff Gvl 24 Hour Progress: (current) 50 Alkal Coal Gallons/stroke API FL L-80 Mud 2.20 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.86 Depth in / out to 7838' 8038' L-80 Grade Set At 178.9 68.0 BTC Avg Clyst Ss Cht Silt 50 Size 160'MD Bit Type Smith XR+ Milltooth Smith MDSi616 BPX PDC 8038' 3.30 14 46 0.902 Footage Lst Flow In (gpm) Flow In (spm) Oil / Water Hours 7838' 18 Siltst Lithology (%) Sh RPM Weight 0.902 Hydril 563 12.0 40.0 Type Condition 0-0-WT-A-E-In-No-BHA Comments Avg Min Depth 9.30 8038' WOB TFA %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 70/30 9.30 Report For: 8038'8.2 Current 70.4 96% 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 PV 10.12 10.12 Cor Solids 10.12 Job No.: Daily Charges: Total Charges: Rig Activity: 162.8 ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 29 Customer: Well: Area: Location: Current Pump & Flow Data: Rig: 12:00 AM RIH w/ BHA 9 Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ROP ROP (ft/hr) 24 hr Max Density (ppg) * 24 hr Recap: Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 3024 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 1272 0 7846' 0 Gas Summary 0 00Minimum Depth (current) 32 50 Units* 00 BHA #8 & P/U BHA #9. Rig maintainence. Begin to RIH. Samples have consisted of 40%-60% sst & 40%-60% sltst. 21 Max Gas = 32 u Avg Gas = 13 u 0 0 00 50 Chromatograph (ppm) C-5n C-4i C-4n C-3 C-5i 0 0 0 0 13 7859' Average C-1 0 =10,000 Units -Connection 0 Trip 8 (max) 1920 (current) Background (max) 13 100% Gas In Air Cont RIH. Perform LOT @ 7791' MD to 11.61 ppg EMW. Drill ahead f/ 7838' MD to 8038' MD. CBU & POOH. L/D . . 2122 ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig: 12:00 AM Drill 8.75" L1 Section Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 30 Customer: Well: Area: Location: Current Pump & Flow Data: PV 9.85 10.53 Cor Solids 10.31 Job No.: Daily Charges: Total Charges: Rig Activity: 331.8 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 Report For: 9017'8.4 Current 177.7 253.9 96% %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 71/29 9.30 Avg Min Depth 9.30 8038' WOB TFA Condition 0-0-WT-A-E-In-No-BHA Comments 12.0 40.0 Type RPM Weight 0.902 Hydril 563 Lithology (%) Sh Siltst Flow In (gpm) Flow In (spm) Oil / Water Hours 7838' 13 14 45 0.902 Footage Lst 160'MD Bit Type Smith XR+ Milltooth Smith MDSi616 BPX PDC 8038' 3.30 Avg Clyst Ss Cht Silt Size to 8038' 9363' L-80 Grade Set At 178.9 68.0 BTC 116 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.86 Depth in / out API FL L-80 Mud 2.20 518 Alkal Coal Gallons/stroke (current) 100 8038' 9363' 31-Oct-2013 1325' Lime Tuff Gvl 24 Hour Progress: Cement 9323' 200' 7 40.0 2676'MD 13 3/8" in Size 8.75 Bit # NORTH SLOPE DOYON15 Casing Summary 6RR 8.75 AK-AM-0900797980 $3,410.00 $105,110.00 M. Ross/O. Amend X-65 20" 9 5/8" 8030'MD EVEMAR * 24 hr Recap: Cont RIH w/ BHA#9. Drill ahead f/ 8038' MD to 9363' MD. Samples have consisted of mostly slst w/ some sst f/ 8038' 100% Gas In Air (current) Background (max) 66 70819 Trip - (max) 156 =10,000 Units -Connection 46 Average C-1 13 8652' C-5i 482 1257 0 739 C-5n C-4i C-4n C-3 Chromatograph (ppm) 0 0506 Max Gas = 2555 u Avg Gas = 811 u 30 MD to 8500' MD. Abundant sst f/ 8500' MD to 9363' MD w/ high gas intervals. 811 00 (current) 2555 100 Units* Gas Summary 72 00Minimum Depth 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 1041 33 8038' 541 Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 282236 . . 20" 9 5/8" 8030'MD EVEMAR NORTH SLOPE DOYON15 Casing Summary 7 8.75 AK-AM-0900797980 $3,410.00 $108,520.00 M. Ross/O. Amend X-65 9508' 1626' 7RR 120.0 2676'MD 13 3/8" in Size 8.75 Bit # Cement 9363' 9664' 1-Nov-2013 301' Lime Tuff Gvl 24 Hour Progress: (current) 100 Alkal Coal Gallons/stroke API FL L-80 Mud 2.00 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.60 Depth in / out to 9363' 9664' L-80 Grade Set At 178.9 68.0 BTC Avg Clyst Ss Cht Silt Size 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 9664' 13.30 13 43 0.902 Footage Lst Flow In (gpm) Flow In (spm) Oil / Water Hours 8038' 16 Siltst Lithology (%) Sh RPM Weight 0.902 Hydril 563 10.0 40.0 Type Condition 0-6-BT-G-X-1-CT-DTF Comments Avg Min Depth 9664' WOB TFA %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 72/28 9.30 Report For: 9664'9.0 Current 199.5 96% 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 PV 10.15 10.50 Cor Solids 10.31 Job No.: Daily Charges: Total Charges: Rig Activity: 317.2 ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 31 Customer: Well: Area: Location: Current Pump & Flow Data: Rig: 12:00 AM RIH BHA #10 Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ROP ROP (ft/hr) 24 hr Max Density (ppg) * 24 hr Recap: Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 306377 907-685-0772 Unit # 110 Phone: 42 Leigh Ann Rasher 19181 98 9560' 42 Gas Summary 153 55 50 Minimum Depth (current) 2815 100 Units* 25 66 Samples have consisted of 100% sst. 1114 Max Gas = 2815 u Avg Gas = 1114 u 40 72 16 56 Chromatograph (ppm) C-5n C-4i C-4n C-3 C-5i 561 216 54 173 112 9304' Average C-1 65 =10,000 Units -Connection 45 Trip 79 (max) 12367 (current) Background (max) 78 100% Gas In Air Cont drill ahead f/ 9363' MD to 9664' MD. Begin to POOH due to tool failure. L/D BHA #9. P/U BHA #10 & RIH. . . 2677 ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig: 12:00 AM Drill 8.75" L1 Section Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 32 Customer: Well: Area: Location: Current Pump & Flow Data: PV 10.34 10.91 Cor Solids 10.64 Job No.: Daily Charges: Total Charges: Rig Activity: 364.5 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 Report For: 10313'8.5 Current 217.3 68.1 96% %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 71/29 9.25 Avg Min Depth 9664' WOB TFA Condition 0-6-BT-G-X-1-CT-DTF Comments 10.0 40.0 Type RPM Weight 0.902 Hydril 563 Lithology (%) Sh Siltst Flow In (gpm) Flow In (spm) Oil / Water Hours 8038' 17 14 45 0.902 Footage Lst 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 9664' 13.30 Avg Clyst Ss Cht Silt 50 Size to 9664' 10454' L-80 Grade Set At 178.9 68.0 BTC 141 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.86 Depth in / out API FL L-80 Mud 2.20 596 Alkal Coal Gallons/stroke (current) 50 9664' 10454' 2-Nov-2013 790' Lime Tuff Gvl 24 Hour Progress: Cement 9687' 1626' 7RR 120.0 2676'MD 13 3/8" in Size 8.75 Bit # NORTH SLOPE DOYON15 Casing Summary 7 8.75 AK-AM-0900797980 $3,410.00 $111,930.00 M. Ross/O. Amend X-65 20" 9 5/8" 8030'MD EVEMAR * 24 hr Recap: Cont RIH w BHA #10. Drill ahead f/ 9664' MD - 10454' MD. Samples have consisted mainly of 100% sst w/ 30%-50% 100% Gas In Air (current) Background (max) 44 95720 Trip - (max) 238 =10,000 Units -Connection 74 Average C-1 24 9304' C-5i 481 187 0 130 C-5n C-4i C-4n C-3 Chromatograph (ppm) 50 5 25 91 Max Gas = 2176 u Avg Gas = 941 u 54 sltst f/ 10150' MD - 10350' MD. 941 00 (current) 2176 50 Units* Gas Summary 113 00Minimum Depth 907-685-0772 Unit # 110 Phone: 29 Leigh Ann Rasher 2214 66 9560' 93 Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 242165 . . 20" 9 5/8" 8030'MD EVEMAR NORTH SLOPE DOYON15 Casing Summary 7 8.75 AK-AM-0900797980 $3,410.00 $115,340.00 M. Ross/O. Amend X-65 10507' 1626' 7RR 120.0 2676'MD 13 3/8" in Size 8.75 Bit # Cement 10454' 10548' 3-Nov-2013 94' Lime Tuff Gvl 24 Hour Progress: (current) 70 Alkal Coal Gallons/stroke API FL L-80 Mud 2.20 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.86 Depth in / out to 10454' 10548' L-80 Grade Set At 178.9 68.0 BTC Avg Clyst Ss Cht Silt 30 Size 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 9664' 13.30 14 45 0.902 Footage Lst Flow In (gpm) Flow In (spm) Oil / Water Hours 8038' 17 Siltst Lithology (%) Sh RPM Weight 0.902 Hydril 563 10.0 40.0 Type Condition 0-6-BT-G-X-1-CT-DTF Comments Avg Min Depth 9664' WOB TFA %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 71/29 9.25 Report For: 10313'8.5 Current 104.7 96% 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 PV 10.65 10.77 Cor Solids 10.71 Job No.: Daily Charges: Total Charges: Rig Activity: 204.9 ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 33 Customer: Well: Area: Location: Current Pump & Flow Data: Rig: 12:00 AM L/D BHA #10 Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ROP ROP (ft/hr) 24 hr Max Density (ppg) * 24 hr Recap: Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 66154 907-685-0772 Unit # 110 Phone: 1 Leigh Ann Rasher 969 34 10548' 35 Gas Summary 36 00Minimum Depth (current) 540 70 Units* 00 w/ 30%-50% sltst. 312 Max Gas = 540 u Avg Gas = 312 u 33 3 16 45 30 Chromatograph (ppm) C-5n C-4i C-4n C-3 C-5i 126 41 0 46 10 10521' Average C-1 74 =10,000 Units -Connection 34 Trip 127 (max) 30953 (current) Background (max) 44 100% Gas In Air Drill ahead f/ 10454' MD - 10548' MD. POOH due to tool failure. Samples have consisted mainly of 50-70% sst . . 2322 ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig: 12:00 AM Drill 8.75" L1 Section Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 34 Customer: Well: Area: Location: Current Pump & Flow Data: PV 10.15 10.62 Cor Solids 10.39 Job No.: Daily Charges: Total Charges: Rig Activity: 341.7 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 Report For: 10548'8.6 Current 238.4 276.4 96% %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 71/29 9.25 Avg Min Depth 10548' WOB TFA Condition 0-0-CT-N-X-IN-WT-DTF Comments 10.0 40.0 Type RPM Weight 0.902 Hydril 563 Lithology (%) Sh Siltst Flow In (gpm) Flow In (spm) Oil / Water Hours 9664' 16 115 45 0.902 Footage Lst 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 10548' 8.00 Avg Clyst Ss Cht Silt 20 Size to 10548' 10696' L-80 Grade Set At 178.9 68.0 BTC 112 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.86 Depth in / out API FL L-80 Mud 2.20 495 Alkal Coal Gallons/stroke (current) 80 10548' 10696' 4-Nov-2013 148' Lime Tuff Gvl 24 Hour Progress: Cement 10602' 884' 7RR 150.0 2676'MD 13 3/8" in Size 8.75 Bit # NORTH SLOPE DOYON15 Casing Summary 7RR 8.75 AK-AM-0900797980 $3,410.00 $118,750.00 M. Ross/O. Amend X-65 20" 9 5/8" 8030'MD EVEMAR * 24 hr Recap: Cont. POOH. L/D BHA #10 & P/U BHA #11. RIH & Shallow hole test tools, fail. POOH & P/U BHA #12 & RIH. Drill 100% Gas In Air (current) Background (max) 34 85168 Trip - (max) 153 =10,000 Units -Connection 21 Average C-1 14 10691' C-5i 352 87 0 47 C-5n C-4i C-4n C-3 Chromatograph (ppm) 20 0 022 Max Gas = 2092 u Avg Gas = 777 u 2 ahead f/ 10548' MD - 10696' MD. Samples have consisted of 80% sst & 20% sltst. 777 00 (current) 2092 80 Units* Gas Summary 46 00Minimum Depth 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 2465 22 10551' 35 Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 238679 . . 20" 9 5/8" 8030'MD EVEMAR NORTH SLOPE DOYON15 Casing Summary 7RR 8.75 AK-AM-0900797980 $3,410.00 $122,160.00 M. Ross/O. Amend X-65 10785' 884' 8 150.0 2676'MD 13 3/8" in Size 8.75 Bit # Cement 10696' 12837' 5-Nov-2013 2141' Lime Tuff Gvl 24 Hour Progress: (current) 100 553 Alkal Coal Gallons/stroke API FL L-80 Mud 2.20 130 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.86 Depth in / out to 10696' 12837' L-80 Grade Set At 178.9 68.0 BTC Avg Clyst Ss Cht Silt 0 Size 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 10548' 8.00 115 45 0.902 Footage Lst Flow In (gpm) Flow In (spm) Oil / Water Hours 9664' 16 Siltst Lithology (%) Sh RPM Weight 0.902 Hydril 563 10.0 40.0 Type Condition 0-0-CT-N-X-IN-WT-DTF Comments Avg Min Depth 10548' WOB TFA %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 71/29 9.25 Report For: 10548'8.6 Current 240.2 353.4 96% 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 PV 10.81 11.17 Cor Solids 10.15 Job No.: Daily Charges: Total Charges: Rig Activity: 456.7 ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 35 Customer: Well: Area: Location: Current Pump & Flow Data: Rig: 12:00 AM Drill 8.75" L1 Section Yesterday's Depth: Current Depth: out (sec/qt) Viscosity 2949 ROP ROP (ft/hr) 24 hr Max Density (ppg) * 24 hr Recap: Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 363780 907-685-0772 Unit # 110 Phone: 23 Leigh Ann Rasher 1608 61 11407' 176 Gas Summary 108 02Minimum Depth (current) 3636 100 Units* 00 11100' MD. 1093 Max Gas = 3636 u Avg Gas = 1093 u 93 0 42 161 0 Chromatograph (ppm) C-5n C-4i C-4n C-3 C-5i 547 187 0 119 18 11500' Average C-1 454 =10,000 Units -Connection 134 Trip - (max) 103382 (current) Background (max) 62 100% Gas In Air Cont drill ahead f/ 10696' MD to 12837' MD. Samples have consisted of mainly sst w/ abundant sltst f/ 10950' MD to . . 3037 ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig: 12:00 AM Drill 8.75" L1 Section Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 36 Customer: Well: Area: Location: Current Pump & Flow Data: PV 10.76 11.47 Cor Solids 11.14 Job No.: Daily Charges: Total Charges: Rig Activity: 708.9 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 Report For: 14649'8.8 Current 264.7 154.1 96% %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 71/29 9.30 Avg Min Depth 10548' WOB TFA Condition 0-0-CT-N-X-IN-WT-DTF Comments 10.0 40.0 Type RPM Weight 0.902 Hydril 563 Lithology (%) Sh Siltst Flow In (gpm) Flow In (spm) Oil / Water Hours 9664' 19 14 47 0.902 Footage Lst 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 10548' 8.00 Avg Clyst Ss Cht Silt 0 Size to 12837' 14955' L-80 Grade Set At 178.9 68.0 BTC 128 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.47 Depth in / out API FL L-80 Mud 1.90 541 Alkal Coal Gallons/stroke (current) 100 12837' 14955' 6-Nov-2013 2118' Lime Tuff Gvl 24 Hour Progress: Cement 13026' 884' 8 150.0 2676'MD 13 3/8" in Size 8.75 Bit # NORTH SLOPE DOYON15 Casing Summary 7RR 8.75 AK-AM-0900797980 $3,410.00 $125,570.00 J. Keener/O. Amend X-65 20" 9 5/8" 8030'MD EVEMAR * 24 hr Recap: Cont drill ahead f/ 12837' MD to 14955' MD. Samples have consisted of mainly sst. 100% Gas In Air (current) Background (max) 121 72802 Trip - (max) 213 =10,000 Units -Connection 75 Average C-1 12 14558' C-5i 776 280 0 216 C-5n C-4i C-4n C-3 Chromatograph (ppm) 0 0 33 94 Max Gas = 3186 u Avg Gas = 781 u 68 781 00 (current) 3186 100 Units* Gas Summary 184 00Minimum Depth 907-685-0772 Unit # 110 Phone: 65 Leigh Ann Rasher 115 131 14096' 87 Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 330097 . . 20" 9 5/8" 8030'MD EVEMAR NORTH SLOPE DOYON15 Casing Summary 7RR 8.75 AK-AM-0900797980 $3,410.00 $128,980.00 J. Keener/O. Amend X-65 15078' 884' 8 150.0 2676'MD 13 3/8" in Size 8.75 Bit # Cement 14955' 15977' 7-Nov-2013 1022' Lime Tuff Gvl 24 Hour Progress: (current) 90 448 Alkal Coal Gallons/stroke API FL L-80 Mud 2.25 106 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.93 Depth in / out to 14955' 15977' L-80 Grade Set At 178.9 68.0 BTC Avg Clyst Ss Cht Silt 10 Size 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 10548' 8.00 15 48 0.902 Footage Lst Flow In (gpm) Flow In (spm) Oil / Water Hours 9664' 19 Siltst Lithology (%) Sh RPM Weight 0.902 Hydril 563 10.0 40.0 Type Condition 0-0-CT-N-X-IN-WT-DTF Comments Avg Min Depth 10548' WOB TFA %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 71/29 9.25 Report For: 15977'8.5 Current 248.8 96% 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 PV 10.71 11.48 Cor Solids 11.20 Job No.: Daily Charges: Total Charges: Rig Activity: 405.9 ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 37 Customer: Well: Area: Location: Current Pump & Flow Data: Rig: 12:00 AM BROOH Yesterday's Depth: Current Depth: out (sec/qt) Viscosity 2128 ROP ROP (ft/hr) 24 hr Max Density (ppg) * 24 hr Recap: Report By: Logging Engineers: Leigh Ann Rasher / Kori Jo Plowman C-2 Maximum 219252 907-685-0772 Unit # 110 Phone: 57 Leigh Ann Rasher 1097 114 15900' 110 Gas Summary 154 43Minimum Depth (current) 2018 90 Units* 07 sst. 667 Max Gas = 2018 u Avg Gas = 667 u 77 3 36 110 10 Chromatograph (ppm) C-5n C-4i C-4n C-3 C-5i 645 233 0 187 10 15891' Average C-1 251 =10,000 Units -Connection 86 Trip 312 (max) 66035 (current) Background (max) 125 100% Gas In Air Cont drill ahead f/ 14955' MD to TD of 15977' MD. Began to BROOH per K&M rep. Samples have consisted of mainly . . ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig: 12:00 AM L/D BHA Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 38 Customer: Well: Area: Location: Current Pump & Flow Data: PV Cor Solids Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Xceed 675, PeriScope 675, TeleScope 675, adnVision 675 Report For: 15977'8.5 Current 96% %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 71/29 9.30 Avg Min Depth 10548' WOB TFA Condition 0-0-CT-N-X-IN-WT-DTF Comments 10.0 40.0 Type RPM Weight 0.902 Hydril 563 Lithology (%) Sh Siltst Flow In (gpm) Flow In (spm) Oil / Water Hours 9664' 19 15 48 0.902 Footage Lst 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 10548' 8.00 Avg Clyst Ss Cht Silt Size to 15977' 15977' L-80 Grade Set At 178.9 68.0 BTC SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.93 Depth in / out API FL L-80 Mud 2.25 Alkal Coal Gallons/stroke (current) 15977' 15977' 8-Nov-2013 0' Lime Tuff Gvl 24 Hour Progress: Cement 884' 8 150.0 2676'MD 13 3/8" in Size 8.75 Bit # NORTH SLOPE DOYON15 Casing Summary 7RR 8.75 AK-AM-0900797980 $4,568.10 $133,548.10 J. Keener/O. Amend X-65 20" 9 5/8" 8030'MD EVEMAR * 24 hr Recap: Cont to BROOH to window. POOH. Begin to L/D BHA 100% Gas In Air (current) Background (max) 0 Trip 71 (max) 0 =10,000 Units -Connection 0Average C-1 C-5i 0 0 0 0 C-5n C-4i C-4n C-3 Chromatograph (ppm) 0 00 Max Gas = 71u 0 00 (current) Units* Gas Summary 0 00Minimum Depth 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 0 0 0 Report By: Logging Engineers: Leigh Ann Rasher / Jade Miller C-2 Maximum 0 . . 20" 9 5/8" 8030'MD EVEMAR NORTH SLOPE DOYON15 Casing Summary 7RR 8.75 AK-AM-0900797980 $2,810.00 $136,358.10 J. Keener/O. Amend X-65 884' 8 150.0 2676'MD 13 3/8" in Size 8.75 Bit # Cement 15977' 15977' 9-Nov-2013 0' Lime Tuff Gvl 24 Hour Progress: (current) Alkal Coal Gallons/stroke API FL L-80 Mud 1.90 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.47 Depth in / out to L-80 Grade Set At 178.9 68.0 BTC Avg Clyst Ss Cht Silt Size 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 10548' 8.00 15 48 0.902 Footage Lst Flow In (gpm) Flow In (spm) Oil / Water Hours 9664' 18 Siltst Lithology (%) Sh RPM Weight 0.902 Hydril 563 10.0 40.0 Type Condition 0-0-CT-N-X-IN-WT-DTF Comments Avg Min Depth 10548' WOB TFA %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 69/31 9.30 Report For: 15977'8.4 Current 96% 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools PV Cor Solids Job No.: Daily Charges: Total Charges: Rig Activity: ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 39 Customer: Well: Area: Location: Current Pump & Flow Data: Rig: 12:00 AM POOH w/ whipstock Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ROP ROP (ft/hr) 24 hr Max Density (ppg) * 24 hr Recap: Report By: Logging Engineers: Leigh Ann Rasher / Jade Miller C-2 Maximum 0 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 0 0 0 Gas Summary 0 00Minimum Depth (current) Units* 00 0 0 00 Chromatograph (ppm) C-5n C-4i C-4n C-3 C-5i 0 0 0 0 Average C-1 0 =10,000 Units -Connection 0 Trip (max) 0 (current) Background (max) 100% Gas In Air L/D BHA #12. RIH to retrieve whipstock. POOH. . . ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig: 12:00 AM RIH w/ 5.5" liner Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 40 Customer: Well: Area: Location: Current Pump & Flow Data: PV Cor Solids Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Report For: 15977'8.5 Current 96% %Mud Type FAZEPRO - Ratio Mud Data (lb/100ft 2)cP 70/30 9.30 Avg Min Depth 10548' WOB TFA Condition 0-0-CT-N-X-IN-WT-DTF Comments 10.0 40.0 Type RPM 150.0 Weight 0.902 Hydril 563 Lithology (%) Sh Siltst Flow In (gpm) Flow In (spm) Oil / Water Hours 9664' 19 14 51 0.902 Footage 105977' Lst 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 10548' 32.60 8.00 Avg Clyst Ss Cht Silt Size to L-80 Grade Set At 5429' 178.9 68.0 BTC SPP (psi) Date: Time: Cly (lb/bbl) ml/30min 2.47 Depth in / out API FL 0-0-CT-N-X-In-No-TD L-80 Mud 1.90 10.0 Alkal Coal Gallons/stroke (current) 15977' 15977' 10-Nov-2013 0' Lime Tuff Gvl 24 Hour Progress: Cement 884' 8RR2 150.0 2676'MD 13 3/8" in Size 8.75 Bit # NORTH SLOPE DOYON15 Casing Summary 8RR 8.75 AK-AM-0900797980 $2,810.00 $139,168.10 J. Keener/O. Amend X-65 20" 9 5/8" 8030'MD EVEMAR * 24 hr Recap: L/D whipstock. R/U to RIH w/ 5.5" liner. RIH & tag TOL @ 7856' MD. Work liner through window. Cont RIH. 100% Gas In Air (current) Background (max) 0 Trip (max) 0 =10,000 Units -Connection 0Average C-1 C-5i 0 0 0 0 C-5n C-4i C-4n C-3 Chromatograph (ppm) 0 000 00 (current) Units* Gas Summary 0 00Minimum Depth 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 0 0 0 Report By: Logging Engineers: Leigh Ann Rasher / Jade Miller C-2 Maximum 0 . . 20" 9 5/8" 8030'MD EVEMAR NORTH SLOPE DOYON15 Casing Summary 8RR 8.75 AK-AM-0900797980 $2,810.00 $141,978.10 J. Keener/O. Amend X-65 884' 8RR2 150.0 2676'MD 13 3/8" in Size 8.75 Bit # Cement 15977' 15977' 11-Nov-2013 0' Lime Tuff Gvl 24 Hour Progress: (current) Alkal Coal Gallons/stroke API FL 0-0-CT-N-X-In-No-TD L-80 Mud 10.0 SPP (psi) Date: Time: Cly (lb/bbl) ml/30min Depth in / out to L-80 Grade Set At 5429' 178.9 68.0 BTC Avg Clyst Ss Cht Silt Size 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 10548' 32.60 8.00 27 0.902 Footage 105977' Lst Flow In (gpm) Flow In (spm) Oil / Water Hours 9664' Siltst Lithology (%) Sh RPM 150.0 Weight 0.902 Hydril 563 10.0 40.0 Type Condition 0-0-CT-N-X-IN-WT-DTF Comments Avg Min Depth 10548' WOB TFA %Mud Type Brine Ratio Mud Data (lb/100ft 2)cP 9.20 Report For: 15977' Current 96% 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools PV Cor Solids Job No.: Daily Charges: Total Charges: Rig Activity: ENI PETROLEUM SP08-N7L1 SPY ISLAND Max @ ft Morning Report Report # 41 Customer: Well: Area: Location: Current Pump & Flow Data: Rig: 12:00 AM L/D DP Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ROP ROP (ft/hr) 24 hr Max Density (ppg) * 24 hr Recap: Report By: Logging Engineers: Leigh Ann Rasher / Jade Miller C-2 Maximum 0 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 0 0 0 Gas Summary 0 00Minimum Depth (current) Units* 00 0 0 00 Chromatograph (ppm) C-5n C-4i C-4n C-3 C-5i 0 0 0 0 Average C-1 0 =10,000 Units -Connection 0 Trip (max) 0 (current) Background (max) 100% Gas In Air Cont RIH w/ 5.5" liner to 15828' MD. Displace to brine. L/D 5" DP. . . ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig: 12:00 AM Set packoff Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7 SPY ISLAND Max @ ft Morning Report Report # 42 Customer: Well: Area: Location: Current Pump & Flow Data: PV Cor Solids Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Report For: 15977' Current 96% %Mud Type Brine Ratio Mud Data (lb/100ft 2)cP 9.20 Avg Min Depth 10548' WOB TFA Condition 0-0-CT-N-X-IN-WT-DTF Comments 10.0 40.0 Type RPM 150.0 Weight 0.902 Hydril 563 Lithology (%) Sh Siltst Flow In (gpm) Flow In (spm) Oil / Water Hours 9664' 27 0.902 Footage 105977' Lst 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 10548' 32.60 8.00 Avg Clyst Ss Cht Silt Size to L-80 Grade Set At 5429' 178.9 68.0 BTC SPP (psi) Date: Time: Cly (lb/bbl) ml/30min Depth in / out API FL 0-0-CT-N-X-In-No-TD L-80 Mud 10.0 Alkal Coal Gallons/stroke (current) 15977' 15977' 12-Nov-2013 0' Lime Tuff Gvl 24 Hour Progress: Cement 884' 8RR2 150.0 2676'MD 13 3/8" in Size 8.75 Bit # NORTH SLOPE DOYON15 Casing Summary 8RR 8.75 AK-AM-0900797980 $2,810.00 $144,788.10 J. Keener/R. Wimmer X-65 20" 9 5/8" 8030'MD EVEMAR * 24 hr Recap: Cont L/D DP. Pull wear ring & install test plug. Test BOPs. Finish L/D DP. Prepare for comp equip & pump assembly. 100% Gas In Air (current) Background (max) 0 Trip (max) 0 =10,000 Units -Connection 0Average C-1 C-5i 0 0 0 0 C-5n C-4i C-4n C-3 Chromatograph (ppm) 0 000 R/U wireline. 00 (current) Units* Gas Summary 0 00Minimum Depth 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 0 0 0 Report By: Logging Engineers: Leigh Ann Rasher / Jade Miller C-2 Maximum 0 . . ROP ROP (ft/hr) 24 hr Max Density (ppg) Rig: 12:00 AM RIH 4.5" comp tbg Yesterday's Depth: Current Depth: out (sec/qt) Viscosity ENI PETROLEUM SP08-N7 SPY ISLAND Max @ ft Morning Report Report # 43 Customer: Well: Area: Location: Current Pump & Flow Data: PV Cor Solids Job No.: Daily Charges: Total Charges: Rig Activity: 4.23 @ MWD Summary Depth YP Max ECD (ppg) Tools Report For: 15977' Current 96% %Mud Type Brine Ratio Mud Data (lb/100ft 2)cP 9.20 Avg Min Depth 10548' WOB TFA Condition 0-0-CT-N-X-IN-WT-DTF Comments 10.0 40.0 Type RPM 150.0 Weight 0.902 Hydril 563 Lithology (%) Sh Siltst Flow In (gpm) Flow In (spm) Oil / Water Hours 9664' 27 0.902 Footage 105977' Lst 160'MD Bit Type Hycalog SKH616M-E1D PDC Hycalog SKH616M-E1D PDC 10548' 32.60 8.00 Avg Clyst Ss Cht Silt Size to L-80 Grade Set At 5429' 178.9 68.0 BTC SPP (psi) Date: Time: Cly (lb/bbl) ml/30min Depth in / out API FL 0-0-CT-N-X-In-No-TD L-80 Mud 10.0 Alkal Coal Gallons/stroke (current) 15977' 15977' 13-Nov-2013 0' Lime Tuff Gvl 24 Hour Progress: Cement 884' 8RR2 150.0 2676'MD 13 3/8" in Size 8.75 Bit # NORTH SLOPE DOYON15 Casing Summary 8RR 8.75 AK-AM-0900797980 $2,810.00 $147,598.10 J. Keener/R. Wimmer X-65 20" 9 5/8" 8030'MD EVEMAR * 24 hr Recap: Test packoff & tool. M/U pump asmbly & RIH w/ lower comp. Cont RIH w/ 4.5" comp tubing. 100% Gas In Air (current) Background (max) 0 Trip (max) 0 =10,000 Units -Connection 0Average C-1 C-5i 0 0 0 0 C-5n C-4i C-4n C-3 Chromatograph (ppm) 0 000 00 (current) Units* Gas Summary 0 00Minimum Depth 907-685-0772 Unit # 110 Phone: 0 Leigh Ann Rasher 0 0 0 Report By: Logging Engineers: Leigh Ann Rasher / Jade Miller C-2 Maximum 0 WELL INFORMATION Customer :ENI PETROLEUM Well Name :SP08-N7 Job Number :AK-XX-0900797980 Rig Name :DOYON 15 Field Name :NIKAITCHUQ Country :USA Survey Report DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 140.00 0.00 0.00 N 0.00 E 0.00 0.00 40.83 0.00 140.00 40.83 0.00 N 0.00 E 0.00 0.00 73.34 0.38 256.80 73.34 0.02 S 0.10 W -0.02 1.17 117.51 0.57 244.66 117.51 0.15 S 0.45 W -0.15 0.48 161.25 0.64 233.85 161.25 0.39 S 0.84 W -0.39 0.31 254.18 0.78 187.00 254.17 1.32 S 1.34 W -1.32 0.62 283.28 0.86 176.32 283.27 1.74 S 1.35 W -1.74 0.59 313.50 1.11 165.10 313.48 2.25 S 1.26 W -2.25 1.04 347.03 1.51 152.07 347.00 2.95 S 0.97 W -2.95 1.48 377.21 1.85 144.19 377.17 3.70 S 0.49 W -3.70 1.36 409.39 1.93 142.39 409.33 4.55 S 0.14 E -4.55 0.31 440.20 2.11 140.16 440.12 5.39 S 0.82 E -5.39 0.64 455.28 2.21 138.13 455.19 5.82 S 1.19 E -5.82 0.83 548.94 3.04 135.50 548.75 8.94 S 4.14 E -8.94 0.90 579.98 3.02 135.70 579.75 10.11 S 5.29 E -10.11 0.07 639.66 4.19 137.50 639.31 12.85 S 7.86 E -12.85 1.97 697.00 5.60 140.48 696.44 16.55 S 11.05 E -16.55 2.50 789.98 8.76 138.57 788.68 25.36 S 18.63 E -25.36 3.41 883.32 13.08 136.88 880.31 38.40 S 30.55 E -38.40 4.64 976.59 16.08 136.90 970.56 55.54 S 46.60 E -55.54 3.22 1069.74 19.83 138.02 1,059.16 76.71 S 65.99 E -76.71 4.04 1163.02 22.63 139.40 1,146.10 102.11 S 88.25 E -102.11 3.05 1256.30 24.43 140.05 1,231.63 130.52 S 112.32 E -130.52 1.95 1349.28 28.63 139.92 1,314.80 162.32 S 139.02 E -162.32 4.52 1442.49 29.07 140.41 1,396.44 196.86 S 167.83 E -196.86 0.54 1535.72 27.69 139.90 1,478.46 230.88 S 196.22 E -230.88 1.50 1629.11 26.63 140.77 1,561.55 263.69 S 223.43 E -263.69 1.21 1722.34 26.17 141.18 1,645.06 295.90 S 249.53 E -295.90 0.53 1815.56 24.94 140.79 1,729.16 327.14 S 274.85 E -327.14 1.33 1908.91 30.16 139.24 1,811.89 360.18 S 302.62 E -360.18 5.64 2002.13 30.62 133.11 1,892.33 394.15 S 335.25 E -394.15 3.36 2095.48 29.07 127.95 1,973.31 424.35 S 370.49 E -424.35 3.21 INSITE V7.4.20 Page 1Job No:AK-XX-0900797980 Well Name:SP08-N7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2188.72 29.54 119.86 2,054.65 449.73 S 408.31 E -449.73 4.27 2282.00 30.39 113.05 2,135.48 470.43 S 449.97 E -470.43 3.76 2375.18 30.79 106.46 2,215.72 486.42 S 494.54 E -486.42 3.62 2468.56 31.77 100.62 2,295.54 497.72 S 541.64 E -497.72 3.41 2561.73 31.77 94.07 2,374.77 503.99 S 590.23 E -503.99 3.70 2609.64 33.11 90.23 2,415.21 504.93 S 615.90 E -504.93 5.13 2703.48 33.63 84.15 2,493.60 502.39 S 667.39 E -502.39 3.61 2750.38 33.82 84.72 2,532.61 499.86 S 693.31 E -499.86 0.79 2809.60 34.20 84.19 2,581.70 496.66 S 726.28 E -496.66 0.81 2843.73 34.79 83.32 2,609.83 494.56 S 745.49 E -494.56 2.25 2937.12 38.43 79.03 2,684.79 485.93 S 800.47 E -485.93 4.76 3031.26 42.22 73.92 2,756.57 471.59 S 859.62 E -471.59 5.34 3123.89 45.08 70.56 2,823.60 452.05 S 920.48 E -452.05 3.97 3218.12 46.51 67.46 2,889.30 427.84 S 983.52 E -427.84 2.80 3310.73 48.33 63.97 2,951.97 399.78 S 1,045.64 E -399.78 3.40 3404.09 51.24 58.54 3,012.27 365.45 S 1,108.06 E -365.45 5.42 3497.43 53.91 54.23 3,069.01 324.40 S 1,169.74 E -324.40 4.65 3590.83 56.03 51.87 3,122.62 278.41 S 1,230.83 E -278.41 3.07 3684.19 59.61 51.48 3,172.34 229.42 S 1,292.81 E -229.42 3.85 3777.55 62.90 51.43 3,217.23 178.42 S 1,356.82 E -178.42 3.52 3870.90 66.21 52.77 3,257.33 126.66 S 1,423.33 E -126.66 3.78 3964.32 68.18 51.32 3,293.54 73.69 S 1,491.23 E -73.69 2.55 4057.64 71.12 49.72 3,325.99 18.06 S 1,558.74 E -18.06 3.54 4151.00 75.46 48.63 3,352.83 40.39 N 1,626.38 E 40.39 4.78 4244.34 78.60 48.07 3,373.78 100.83 N 1,694.34 E 100.83 3.41 4337.67 78.98 44.94 3,391.92 163.84 N 1,760.74 E 163.84 3.31 4431.03 78.78 44.16 3,409.93 229.12 N 1,825.00 E 229.12 0.85 4524.43 79.49 42.10 3,427.54 296.06 N 1,887.71 E 296.06 2.30 4617.73 79.11 40.14 3,444.86 365.12 N 1,948.00 E 365.12 2.10 4711.02 77.68 38.14 3,463.63 435.99 N 2,005.68 E 435.99 2.60 4804.38 79.45 36.27 3,482.14 508.87 N 2,061.00 E 508.87 2.73 4897.65 78.91 34.86 3,499.65 583.39 N 2,114.28 E 583.39 1.59 4991.01 77.26 33.57 3,518.93 658.92 N 2,165.65 E 658.92 2.23 5084.27 77.34 31.65 3,539.43 735.55 N 2,214.67 E 735.55 2.01 5177.78 77.49 29.36 3,559.81 814.18 N 2,261.00 E 814.18 2.40 5271.20 77.86 25.78 3,579.75 895.07 N 2,303.23 E 895.07 3.76 5364.68 78.92 23.15 3,598.57 978.41 N 2,341.14 E 978.41 2.98 5458.11 79.46 19.59 3,616.10 1,063.86 N 2,374.58 E 1063.86 3.79 5551.45 79.92 17.43 3,632.81 1,150.93 N 2,403.73 E 1150.93 2.33 5644.82 79.39 16.19 3,649.57 1,238.86 N 2,430.29 E 1238.86 1.42 5737.51 78.58 14.01 3,667.29 1,326.69 N 2,453.99 E 1326.69 2.47 5830.85 79.25 9.88 3,685.24 1,416.29 N 2,472.94 E 1416.29 4.40 5924.14 79.03 6.46 3,702.82 1,506.96 N 2,485.96 E 1506.96 3.61 6017.32 77.49 2.43 3,721.79 1,597.89 N 2,493.04 E 1597.89 4.55 6110.61 77.75 356.75 3,741.80 1,688.97 N 2,492.39 E 1688.97 5.95 INSITE V7.4.20 Page 2Job No:AK-XX-0900797980 Well Name:SP08-N7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6203.95 77.40 350.79 3,761.90 1,779.54 N 2,482.50 E 1779.54 6.25 6297.22 76.62 346.09 3,782.88 1,868.55 N 2,464.30 E 1868.56 4.98 6390.37 77.60 343.31 3,803.66 1,956.13 N 2,440.34 E 1956.13 3.09 6483.65 78.08 341.22 3,823.31 2,042.98 N 2,412.56 E 2042.98 2.25 6576.93 80.45 340.62 3,840.69 2,129.58 N 2,382.60 E 2129.58 2.62 6669.91 80.08 340.44 3,856.41 2,215.98 N 2,352.06 E 2215.98 0.44 6763.12 80.24 339.68 3,872.34 2,302.31 N 2,320.74 E 2302.31 0.82 6856.35 79.55 338.35 3,888.70 2,388.01 N 2,287.87 E 2388.01 1.59 6949.74 78.62 334.66 3,906.39 2,472.09 N 2,251.32 E 2472.09 4.01 7042.97 79.66 332.36 3,923.96 2,554.03 N 2,210.48 E 2554.03 2.67 7136.19 80.64 330.29 3,939.90 2,634.60 N 2,166.41 E 2634.60 2.43 7229.54 80.79 329.06 3,954.97 2,714.12 N 2,119.90 E 2714.12 1.31 7322.76 82.66 325.57 3,968.39 2,791.75 N 2,070.09 E 2791.75 4.21 7416.11 83.06 323.39 3,979.99 2,867.13 N 2,016.28 E 2867.13 2.36 7509.35 83.05 321.64 3,991.27 2,940.57 N 1,959.95 E 2940.57 1.86 7602.63 80.94 316.87 4,004.26 3,010.54 N 1,899.69 E 3010.54 5.55 7696.60 80.30 310.38 4,019.59 3,074.47 N 1,832.62 E 3074.47 6.85 7789.19 80.29 307.59 4,035.20 3,131.88 N 1,761.69 E 3131.88 2.97 7882.37 81.99 308.44 4,049.56 3,188.58 N 1,689.15 E 3188.58 2.03 7975.59 83.09 309.13 4,061.66 3,246.48 N 1,617.11 E 3246.48 1.39 8000.95 83.52 309.14 4,064.62 3,262.37 N 1,597.57 E 3262.38 1.70 8078.71 85.79 310.53 4,071.86 3,311.97 N 1,538.12 E 3311.97 3.42 8103.49 84.33 310.75 4,073.99 3,328.05 N 1,519.39 E 3328.05 5.96 8196.81 82.82 310.31 4,084.44 3,388.31 N 1,448.91 E 3388.31 1.68 8290.11 83.53 310.34 4,095.52 3,448.25 N 1,378.28 E 3448.26 0.76 8383.43 85.99 310.92 4,104.05 3,508.76 N 1,307.76 E 3508.76 2.71 8476.79 87.13 312.46 4,109.65 3,570.74 N 1,238.18 E 3570.74 2.05 8570.15 91.42 315.78 4,110.83 3,635.71 N 1,171.19 E 3635.71 5.81 8663.48 90.74 314.16 4,109.07 3,701.65 N 1,105.17 E 3701.65 1.88 8756.85 89.32 315.63 4,109.02 3,767.55 N 1,039.03 E 3767.55 2.19 8850.23 87.82 312.69 4,111.35 3,832.58 N 972.07 E 3832.58 3.53 8943.60 88.01 310.78 4,114.75 3,894.69 N 902.44 E 3894.69 2.05 9036.93 89.23 311.88 4,117.00 3,956.30 N 832.38 E 3956.30 1.76 9130.28 90.30 310.02 4,117.38 4,017.48 N 761.88 E 4017.48 2.30 9223.64 90.42 308.24 4,116.79 4,076.40 N 689.47 E 4076.40 1.91 9317.03 92.49 307.75 4,114.42 4,133.86 N 615.90 E 4133.86 2.28 9410.41 90.34 307.75 4,112.12 4,191.01 N 542.09 E 4191.01 2.30 9503.88 91.11 307.83 4,110.93 4,248.28 N 468.23 E 4248.28 0.83 9597.27 91.83 308.14 4,108.54 4,305.74 N 394.65 E 4305.74 0.84 9690.62 89.79 306.67 4,107.22 4,362.43 N 320.51 E 4362.43 2.69 9784.02 93.41 307.40 4,104.61 4,418.66 N 245.99 E 4418.66 3.95 9877.50 91.20 306.35 4,100.85 4,474.70 N 171.28 E 4474.70 2.62 9970.90 90.67 304.10 4,099.33 4,528.56 N 94.99 E 4528.56 2.47 10064.25 93.17 307.39 4,096.20 4,583.05 N 19.29 E 4583.05 4.42 10157.46 93.07 306.85 4,091.13 4,639.22 N 54.93 W 4639.22 0.59 INSITE V7.4.20 Page 3Job No:AK-XX-0900797980 Well Name:SP08-N7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10250.90 91.36 305.08 4,087.51 4,694.05 N 130.49 W 4694.05 2.63 10344.24 90.51 304.53 4,085.99 4,747.32 N 207.12 W 4747.32 1.08 10437.59 89.82 305.85 4,085.72 4,801.11 N 283.41 W 4801.11 1.60 10530.98 90.80 306.97 4,085.22 4,856.54 N 358.57 W 4856.54 1.59 10624.37 91.91 309.87 4,083.01 4,914.55 N 431.71 W 4914.55 3.32 10717.75 91.69 311.38 4,080.07 4,975.32 N 502.54 W 4975.32 1.63 10811.17 88.90 308.65 4,079.59 5,035.38 N 574.08 W 5035.38 4.18 10904.59 90.27 313.19 4,080.27 5,096.55 N 644.65 W 5096.55 5.08 10997.95 90.99 317.44 4,079.24 5,162.91 N 710.28 W 5162.91 4.62 11091.29 90.96 316.45 4,077.66 5,231.10 N 773.99 W 5231.10 1.06 11184.69 89.12 315.89 4,077.59 5,298.48 N 838.67 W 5298.48 2.06 11278.05 86.14 314.81 4,081.45 5,364.83 N 904.21 W 5364.83 3.39 11371.41 87.81 314.79 4,086.38 5,430.52 N 970.37 W 5430.52 1.79 11464.76 90.78 315.59 4,087.53 5,496.73 N 1,036.14 W 5496.73 3.29 11558.18 91.94 314.83 4,085.31 5,563.01 N 1,101.94 W 5563.01 1.48 11651.50 91.93 314.77 4,082.16 5,628.73 N 1,168.12 W 5628.73 0.07 11744.86 92.38 313.83 4,078.65 5,693.89 N 1,234.89 W 5693.89 1.12 11838.20 92.48 312.87 4,074.69 5,757.90 N 1,302.70 W 5757.90 1.03 11931.53 91.62 312.99 4,071.35 5,821.43 N 1,370.99 W 5821.43 0.93 12024.89 90.98 312.22 4,069.23 5,884.61 N 1,439.69 W 5884.61 1.07 12118.29 91.15 312.73 4,067.50 5,947.67 N 1,508.56 W 5947.67 0.58 12211.59 92.12 312.32 4,064.83 6,010.71 N 1,577.30 W 6010.71 1.13 12304.88 92.76 311.58 4,060.86 6,073.01 N 1,646.61 W 6073.01 1.05 12398.24 92.66 309.77 4,056.45 6,133.79 N 1,717.34 W 6133.79 1.94 12491.51 94.03 309.59 4,051.01 6,193.24 N 1,789.00 W 6193.24 1.48 12584.87 93.93 308.58 4,044.53 6,251.96 N 1,861.29 W 6251.96 1.08 12678.23 90.87 308.90 4,040.62 6,310.32 N 1,934.04 W 6310.32 3.30 12771.64 87.65 308.22 4,041.82 6,368.54 N 2,007.06 W 6368.54 3.52 12865.06 89.58 310.15 4,044.08 6,427.54 N 2,079.44 W 6427.54 2.92 12958.54 90.82 311.33 4,043.76 6,488.54 N 2,150.27 W 6488.54 1.83 13051.97 89.74 311.55 4,043.30 6,550.38 N 2,220.31 W 6550.38 1.18 13145.31 89.93 311.47 4,043.57 6,612.24 N 2,290.20 W 6612.24 0.22 13238.68 90.35 311.38 4,043.34 6,674.02 N 2,360.21 W 6674.02 0.46 13332.14 90.31 310.86 4,042.80 6,735.48 N 2,430.62 W 6735.48 0.56 13425.48 90.27 309.88 4,042.33 6,795.93 N 2,501.73 W 6795.93 1.05 13518.77 91.00 309.78 4,041.29 6,855.68 N 2,573.37 W 6855.68 0.79 13611.95 91.58 309.85 4,039.20 6,915.33 N 2,644.92 W 6915.33 0.63 13705.24 91.51 309.74 4,036.68 6,975.02 N 2,716.58 W 6975.02 0.14 13798.58 90.29 309.11 4,035.22 7,034.29 N 2,788.67 W 7034.29 1.47 13891.85 88.93 308.61 4,035.85 7,092.80 N 2,861.29 W 7092.80 1.55 13985.00 88.27 308.60 4,038.13 7,150.91 N 2,934.06 W 7150.91 0.71 14078.28 87.19 308.39 4,041.82 7,208.92 N 3,007.01 W 7208.92 1.18 14171.56 87.63 308.94 4,046.04 7,267.14 N 3,079.77 W 7267.14 0.75 14264.54 89.33 309.66 4,048.50 7,326.01 N 3,151.69 W 7326.01 1.99 14357.75 90.07 310.89 4,048.99 7,386.26 N 3,222.80 W 7386.26 1.54 INSITE V7.4.20 Page 4Job No:AK-XX-0900797980 Well Name:SP08-N7 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14450.98 90.03 310.93 4,048.91 7,447.32 N 3,293.26 W 7447.32 0.06 14544.37 90.02 311.80 4,048.87 7,509.03 N 3,363.35 W 7509.03 0.93 14637.60 89.15 311.51 4,049.54 7,571.00 N 3,433.01 W 7571.00 0.98 14730.82 90.89 313.75 4,049.51 7,634.12 N 3,501.59 W 7634.12 3.04 14824.17 90.81 314.39 4,048.13 7,699.04 N 3,568.65 W 7699.04 0.69 14917.39 90.42 313.41 4,047.13 7,763.68 N 3,635.81 W 7763.68 1.13 15010.74 88.12 311.77 4,048.32 7,826.84 N 3,704.53 W 7826.84 3.03 15103.98 88.08 311.73 4,051.41 7,888.89 N 3,774.05 W 7888.89 0.06 15197.26 86.85 312.30 4,055.53 7,951.27 N 3,843.29 W 7951.27 1.45 15290.44 91.72 312.63 4,056.70 8,014.15 N 3,912.00 W 8014.15 5.24 15383.82 93.03 314.08 4,052.83 8,078.20 N 3,979.83 W 8078.20 2.09 15477.14 94.21 312.82 4,046.93 8,142.25 N 4,047.44 W 8142.25 1.85 15570.22 95.08 311.67 4,039.40 8,204.62 N 4,116.12 W 8204.62 1.55 15663.42 96.63 310.99 4,029.89 8,265.85 N 4,185.74 W 8265.85 1.81 15756.59 99.20 311.76 4,017.06 8,326.84 N 4,254.98 W 8326.84 2.88 15804.57 100.54 312.74 4,008.83 8,358.62 N 4,289.97 W 8358.62 3.44 15870.00 100.54 312.74 3,996.87 8,402.27 N 4,337.22 W 8402.27 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (True) - A total correction of 19.69 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 15,870.00 feet is 9,455.67 feet along 332.70 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V7.4.20 Page 5Job No:AK-XX-0900797980 Well Name:SP08-N7 Survey Report WELL INFORMATION Customer :ENI PETROLEUM Well Name :SP08-N7L1 Job Number :AK-XX-0900797980 Rig Name :DOYON 15 Field Name :NIKAITCHUQ Country :USA Survey Report DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 140.00 0.00 0.00 N 0.00 E 0.00 0.00 40.83 0.00 140.00 40.83 0.00 N 0.00 E 0.00 0.00 73.34 0.38 256.80 73.34 0.02 S 0.10 W -0.02 1.17 117.51 0.57 244.66 117.51 0.15 S 0.45 W -0.15 0.48 161.25 0.64 233.85 161.25 0.39 S 0.84 W -0.39 0.31 254.18 0.78 187.00 254.17 1.32 S 1.34 W -1.32 0.62 283.28 0.86 176.32 283.27 1.74 S 1.35 W -1.74 0.59 313.50 1.11 165.10 313.48 2.25 S 1.26 W -2.25 1.04 347.03 1.51 152.07 347.00 2.95 S 0.97 W -2.95 1.48 377.21 1.85 144.19 377.17 3.70 S 0.49 W -3.70 1.36 409.39 1.93 142.39 409.33 4.55 S 0.14 E -4.55 0.31 440.20 2.11 140.16 440.12 5.39 S 0.82 E -5.39 0.64 455.28 2.21 138.13 455.19 5.82 S 1.19 E -5.82 0.83 548.94 3.04 135.50 548.75 8.94 S 4.14 E -8.94 0.90 579.98 3.02 135.70 579.75 10.11 S 5.29 E -10.11 0.07 639.66 4.19 137.50 639.31 12.85 S 7.86 E -12.85 1.97 697.00 5.60 140.48 696.44 16.55 S 11.05 E -16.55 2.50 789.98 8.76 138.57 788.68 25.36 S 18.63 E -25.36 3.41 883.32 13.08 136.88 880.31 38.40 S 30.55 E -38.40 4.64 976.59 16.08 136.90 970.56 55.54 S 46.60 E -55.54 3.22 1069.74 19.83 138.02 1,059.16 76.71 S 65.99 E -76.71 4.04 1163.02 22.63 139.40 1,146.10 102.11 S 88.25 E -102.11 3.05 1256.30 24.43 140.05 1,231.63 130.52 S 112.32 E -130.52 1.95 1349.28 28.63 139.92 1,314.80 162.32 S 139.02 E -162.32 4.52 1442.49 29.07 140.41 1,396.44 196.86 S 167.83 E -196.86 0.54 1535.72 27.69 139.90 1,478.46 230.88 S 196.22 E -230.88 1.50 1629.11 26.63 140.77 1,561.55 263.69 S 223.43 E -263.69 1.21 1722.34 26.17 141.18 1,645.06 295.90 S 249.53 E -295.90 0.53 1815.56 24.94 140.79 1,729.16 327.14 S 274.85 E -327.14 1.33 1908.91 30.16 139.24 1,811.89 360.18 S 302.62 E -360.18 5.64 2002.13 30.62 133.11 1,892.33 394.15 S 335.25 E -394.15 3.36 2095.48 29.07 127.95 1,973.31 424.35 S 370.49 E -424.35 3.21 INSITE V7.4.20 Page 1Job No:AK-XX-0900797980 Well Name:SP08-N7L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2188.72 29.54 119.86 2,054.65 449.73 S 408.31 E -449.73 4.27 2282.00 30.39 113.05 2,135.48 470.43 S 449.97 E -470.43 3.76 2375.18 30.79 106.46 2,215.72 486.42 S 494.54 E -486.42 3.62 2468.56 31.77 100.62 2,295.54 497.72 S 541.64 E -497.72 3.41 2561.73 31.77 94.07 2,374.77 503.99 S 590.23 E -503.99 3.70 2609.64 33.11 90.23 2,415.21 504.93 S 615.90 E -504.93 5.13 2703.48 33.63 84.15 2,493.60 502.39 S 667.39 E -502.39 3.61 2750.38 33.82 84.72 2,532.61 499.86 S 693.31 E -499.86 0.79 2809.60 34.20 84.19 2,581.70 496.66 S 726.28 E -496.66 0.81 2843.73 34.79 83.32 2,609.83 494.56 S 745.49 E -494.56 2.25 2937.12 38.43 79.03 2,684.79 485.93 S 800.47 E -485.93 4.76 3031.26 42.22 73.92 2,756.57 471.59 S 859.62 E -471.59 5.34 3123.89 45.08 70.56 2,823.60 452.05 S 920.48 E -452.05 3.97 3218.12 46.51 67.46 2,889.30 427.84 S 983.52 E -427.84 2.80 3310.73 48.33 63.97 2,951.97 399.78 S 1,045.64 E -399.78 3.40 3404.09 51.24 58.54 3,012.27 365.45 S 1,108.06 E -365.45 5.42 3497.43 53.91 54.23 3,069.01 324.40 S 1,169.74 E -324.40 4.65 3590.83 56.03 51.87 3,122.62 278.41 S 1,230.83 E -278.41 3.07 3684.19 59.61 51.48 3,172.34 229.42 S 1,292.81 E -229.42 3.85 3777.55 62.90 51.43 3,217.23 178.42 S 1,356.82 E -178.42 3.52 3870.90 66.21 52.77 3,257.33 126.66 S 1,423.33 E -126.66 3.78 3964.32 68.18 51.32 3,293.54 73.69 S 1,491.23 E -73.69 2.55 4057.64 71.12 49.72 3,325.99 18.06 S 1,558.74 E -18.06 3.54 4151.00 75.46 48.63 3,352.83 40.39 N 1,626.38 E 40.39 4.78 4244.34 78.60 48.07 3,373.78 100.83 N 1,694.34 E 100.83 3.41 4337.67 78.98 44.94 3,391.92 163.84 N 1,760.74 E 163.84 3.31 4431.03 78.78 44.16 3,409.93 229.12 N 1,825.00 E 229.12 0.85 4524.43 79.49 42.10 3,427.54 296.06 N 1,887.71 E 296.06 2.30 4617.73 79.11 40.14 3,444.86 365.12 N 1,948.00 E 365.12 2.10 4711.02 77.68 38.14 3,463.63 435.99 N 2,005.68 E 435.99 2.60 4804.38 79.45 36.27 3,482.14 508.87 N 2,061.00 E 508.87 2.73 4897.65 78.91 34.86 3,499.65 583.39 N 2,114.28 E 583.39 1.59 4991.01 77.26 33.57 3,518.93 658.92 N 2,165.65 E 658.92 2.23 5084.27 77.34 31.65 3,539.43 735.55 N 2,214.67 E 735.55 2.01 5177.78 77.49 29.36 3,559.81 814.18 N 2,261.00 E 814.18 2.40 5271.20 77.86 25.78 3,579.75 895.07 N 2,303.23 E 895.07 3.76 5364.68 78.92 23.15 3,598.57 978.41 N 2,341.14 E 978.41 2.98 5458.11 79.46 19.59 3,616.10 1,063.86 N 2,374.58 E 1063.86 3.79 5551.45 79.92 17.43 3,632.81 1,150.93 N 2,403.73 E 1150.93 2.33 5644.82 79.39 16.19 3,649.57 1,238.86 N 2,430.29 E 1238.86 1.42 5737.51 78.58 14.01 3,667.29 1,326.69 N 2,453.99 E 1326.69 2.47 5830.85 79.25 9.88 3,685.24 1,416.29 N 2,472.94 E 1416.29 4.40 5924.14 79.03 6.46 3,702.82 1,506.96 N 2,485.96 E 1506.96 3.61 6017.32 77.49 2.43 3,721.79 1,597.89 N 2,493.04 E 1597.89 4.55 6110.61 77.75 356.75 3,741.80 1,688.97 N 2,492.39 E 1688.97 5.95 INSITE V7.4.20 Page 2Job No:AK-XX-0900797980 Well Name:SP08-N7L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6203.95 77.40 350.79 3,761.90 1,779.54 N 2,482.50 E 1779.54 6.25 6297.22 76.62 346.09 3,782.88 1,868.55 N 2,464.30 E 1868.56 4.98 6390.37 77.60 343.31 3,803.66 1,956.13 N 2,440.34 E 1956.13 3.09 6483.65 78.08 341.22 3,823.31 2,042.98 N 2,412.56 E 2042.98 2.25 6576.93 80.45 340.62 3,840.69 2,129.58 N 2,382.60 E 2129.58 2.62 6669.91 80.08 340.44 3,856.41 2,215.98 N 2,352.06 E 2215.98 0.44 6763.12 80.24 339.68 3,872.34 2,302.31 N 2,320.74 E 2302.31 0.82 6856.35 79.55 338.35 3,888.70 2,388.01 N 2,287.87 E 2388.01 1.59 6949.74 78.62 334.66 3,906.39 2,472.09 N 2,251.32 E 2472.09 4.01 7042.97 79.66 332.36 3,923.96 2,554.03 N 2,210.48 E 2554.03 2.67 7136.19 80.64 330.29 3,939.90 2,634.60 N 2,166.41 E 2634.60 2.43 7229.54 80.79 329.06 3,954.97 2,714.12 N 2,119.90 E 2714.12 1.31 7322.76 82.66 325.57 3,968.39 2,791.75 N 2,070.09 E 2791.75 4.21 7416.11 83.06 323.39 3,979.99 2,867.13 N 2,016.28 E 2867.13 2.36 7509.35 83.05 321.64 3,991.27 2,940.57 N 1,959.95 E 2940.57 1.86 7602.63 80.94 316.87 4,004.26 3,010.54 N 1,899.69 E 3010.54 5.55 7696.60 80.30 310.38 4,019.59 3,074.47 N 1,832.62 E 3074.47 6.85 7789.19 80.29 307.59 4,035.20 3,131.88 N 1,761.69 E 3131.88 2.97 7791.00 80.32 307.61 4,035.51 3,132.97 N 1,760.27 E 3132.97 1.98 7808.00 82.04 306.37 4,038.12 3,143.08 N 1,746.86 E 3143.08 12.42 7899.43 84.54 303.00 4,048.80 3,194.73 N 1,672.20 E 3194.73 4.57 7972.80 86.20 299.48 4,054.73 3,232.65 N 1,609.69 E 3232.65 5.29 8062.67 85.00 300.03 4,061.62 3,277.12 N 1,531.90 E 3277.12 1.47 8104.24 85.18 297.39 4,065.18 3,297.01 N 1,495.57 E 3297.01 6.34 8197.56 85.39 294.73 4,072.85 3,337.87 N 1,412.03 E 3337.87 2.85 8290.86 86.37 299.75 4,079.56 3,380.45 N 1,329.32 E 3380.45 5.47 8384.18 87.26 306.42 4,084.75 3,431.28 N 1,251.30 E 3431.28 7.20 8477.54 86.66 309.05 4,089.70 3,488.33 N 1,177.58 E 3488.33 2.89 8570.90 88.58 307.39 4,093.58 3,546.04 N 1,104.30 E 3546.04 2.72 8664.23 89.63 306.83 4,095.04 3,602.34 N 1,029.88 E 3602.34 1.28 8757.60 91.58 303.77 4,094.05 3,656.28 N 953.69 E 3656.29 3.89 8850.98 91.48 302.34 4,091.56 3,707.20 N 875.46 E 3707.20 1.53 8944.35 91.49 302.09 4,089.14 3,756.96 N 796.49 E 3756.96 0.27 9037.68 92.42 302.64 4,085.95 3,806.89 N 717.70 E 3806.89 1.16 9131.03 92.46 302.41 4,081.98 3,857.03 N 639.07 E 3857.03 0.25 9224.39 90.99 302.55 4,079.17 3,907.14 N 560.35 E 3907.14 1.58 9317.78 91.26 303.46 4,077.34 3,958.00 N 482.04 E 3958.00 1.02 9411.16 90.08 304.82 4,076.24 4,010.40 N 404.77 E 4010.41 1.93 9504.63 90.30 304.58 4,075.93 4,063.62 N 327.92 E 4063.62 0.35 9598.04 91.18 304.25 4,074.73 4,116.40 N 250.87 E 4116.40 1.01 9690.67 89.44 306.27 4,074.23 4,169.87 N 175.24 E 4169.87 2.88 9784.07 87.74 308.77 4,076.52 4,226.73 N 101.19 E 4226.73 3.24 9877.55 87.73 312.22 4,080.22 4,287.38 N 30.17 E 4287.38 3.69 9970.95 87.39 313.26 4,084.20 4,350.71 N 38.37 W 4350.71 1.17 10064.30 89.09 313.03 4,087.06 4,414.51 N 106.44 W 4414.51 1.84 INSITE V7.4.20 Page 3Job No:AK-XX-0900797980 Well Name:SP08-N7L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10157.51 89.27 312.73 4,088.40 4,477.93 N 174.74 W 4477.93 0.38 10250.95 89.25 312.80 4,089.60 4,541.37 N 243.33 W 4541.37 0.08 10344.29 88.57 312.62 4,091.38 4,604.67 N 311.90 W 4604.67 0.75 10437.64 89.60 312.10 4,092.87 4,667.56 N 380.87 W 4667.56 1.24 10478.04 91.39 312.47 4,092.52 4,694.74 N 410.76 W 4694.74 4.52 10531.73 92.10 313.97 4,090.89 4,731.49 N 449.86 W 4731.49 3.09 10625.12 92.88 313.92 4,086.83 4,796.24 N 517.04 W 4796.24 0.84 10718.50 93.69 313.50 4,081.48 4,860.66 N 584.43 W 4860.66 0.98 10811.92 94.27 313.61 4,074.99 4,924.87 N 651.97 W 4924.87 0.63 10905.34 94.16 313.41 4,068.13 4,989.02 N 719.54 W 4989.02 0.24 10998.70 92.28 312.93 4,062.88 5,052.79 N 787.52 W 5052.79 2.08 11092.04 88.58 312.43 4,062.18 5,116.05 N 856.12 W 5116.05 4.00 11185.44 89.90 311.61 4,063.42 5,178.56 N 925.50 W 5178.56 1.66 11278.80 91.41 313.71 4,062.36 5,241.82 N 994.15 W 5241.82 2.77 11372.16 91.04 313.31 4,060.36 5,306.08 N 1,061.84 W 5306.08 0.58 11465.51 92.50 311.58 4,057.48 5,369.04 N 1,130.69 W 5369.05 2.42 11558.93 93.05 311.05 4,052.95 5,430.65 N 1,200.77 W 5430.65 0.82 11652.25 91.55 311.57 4,049.21 5,492.20 N 1,270.81 W 5492.20 1.70 11745.61 88.58 310.79 4,049.10 5,553.66 N 1,341.07 W 5553.66 3.29 11838.95 89.19 311.04 4,050.92 5,614.78 N 1,411.59 W 5614.78 0.71 11932.28 91.12 311.46 4,050.67 5,676.32 N 1,481.76 W 5676.32 2.12 12025.64 90.10 312.62 4,049.67 5,738.83 N 1,551.09 W 5738.83 1.65 12119.04 89.94 313.75 4,049.64 5,802.75 N 1,619.19 W 5802.75 1.22 12212.34 88.57 313.41 4,050.85 5,867.06 N 1,686.77 W 5867.06 1.51 12305.63 88.68 312.62 4,053.09 5,930.68 N 1,754.96 W 5930.68 0.85 12398.99 88.82 313.22 4,055.13 5,994.24 N 1,823.31 W 5994.24 0.66 12492.26 87.80 313.02 4,057.88 6,057.97 N 1,891.36 W 6057.97 1.11 12585.62 89.02 313.05 4,060.47 6,121.65 N 1,959.58 W 6121.65 1.31 12678.88 90.30 313.72 4,061.02 6,185.71 N 2,027.35 W 6185.71 1.55 12772.39 90.63 314.48 4,060.26 6,250.78 N 2,094.50 W 6250.78 0.89 12865.81 90.65 313.21 4,059.22 6,315.49 N 2,161.87 W 6315.49 1.36 12959.29 91.07 313.26 4,057.82 6,379.52 N 2,229.97 W 6379.52 0.45 13052.72 90.92 313.75 4,056.19 6,443.82 N 2,297.72 W 6443.82 0.55 13146.06 90.67 312.09 4,054.90 6,507.38 N 2,366.07 W 6507.38 1.80 13239.43 92.25 313.48 4,052.52 6,570.77 N 2,434.57 W 6570.78 2.25 13332.89 92.47 313.28 4,048.67 6,634.91 N 2,502.44 W 6634.91 0.32 13426.23 91.97 312.72 4,045.06 6,698.52 N 2,570.65 W 6698.52 0.80 13519.52 92.69 312.75 4,041.26 6,761.78 N 2,639.11 W 6761.78 0.77 13612.70 89.65 312.07 4,039.36 6,824.60 N 2,707.89 W 6824.60 3.34 13705.99 89.85 312.14 4,039.77 6,887.15 N 2,777.10 W 6887.15 0.23 13799.33 90.06 311.19 4,039.84 6,949.20 N 2,846.83 W 6949.20 1.04 13892.60 91.24 310.57 4,038.78 7,010.23 N 2,917.34 W 7010.24 1.43 13985.75 90.54 309.73 4,037.34 7,070.29 N 2,988.53 W 7070.29 1.17 14079.03 89.00 309.09 4,037.71 7,129.51 N 3,060.60 W 7129.51 1.79 14172.31 88.82 309.52 4,039.49 7,188.58 N 3,132.77 W 7188.58 0.50 INSITE V7.4.20 Page 4Job No:AK-XX-0900797980 Well Name:SP08-N7L1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14265.29 88.97 309.66 4,041.28 7,247.83 N 3,204.41 W 7247.83 0.22 14358.50 88.88 310.74 4,043.03 7,307.98 N 3,275.59 W 7307.98 1.16 14451.73 90.18 312.60 4,043.79 7,369.96 N 3,345.22 W 7369.96 2.43 14545.12 89.67 312.48 4,043.91 7,433.10 N 3,414.03 W 7433.10 0.56 14638.35 90.91 313.10 4,043.44 7,496.43 N 3,482.44 W 7496.43 1.49 14731.57 90.73 312.94 4,042.11 7,560.02 N 3,550.59 W 7560.02 0.26 14824.92 89.92 312.94 4,041.58 7,623.61 N 3,618.93 W 7623.61 0.87 14918.14 90.03 312.16 4,041.62 7,686.65 N 3,687.60 W 7686.65 0.85 15011.49 91.16 312.72 4,040.65 7,749.64 N 3,756.49 W 7749.64 1.35 15104.73 91.21 312.79 4,038.72 7,812.92 N 3,824.94 W 7812.92 0.09 15198.01 95.37 312.21 4,033.37 7,875.82 N 3,893.58 W 7875.82 4.50 15291.19 94.43 312.30 4,025.41 7,938.25 N 3,962.30 W 7938.25 1.01 15384.57 91.37 311.41 4,020.69 8,000.47 N 4,031.75 W 8000.47 3.41 15477.75 89.99 310.66 4,019.58 8,061.64 N 4,102.03 W 8061.64 1.69 15570.97 90.39 310.62 4,019.27 8,122.35 N 4,172.77 W 8122.35 0.43 15664.17 90.87 310.23 4,018.25 8,182.78 N 4,243.71 W 8182.79 0.66 15757.34 91.88 311.28 4,016.01 8,243.59 N 4,314.27 W 8243.59 1.56 15850.64 91.73 312.09 4,013.07 8,305.61 N 4,383.91 W 8305.61 0.88 15912.84 92.71 310.85 4,010.66 8,346.76 N 4,430.48 W 8346.77 2.54 15977.00 92.71 310.85 4,007.63 8,388.68 N 4,478.96 W 8388.68 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (True) - A total correction of 19.69 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 15,977.00 feet is 9,509.52 feet along 331.90 degrees (True) INSITE V7.4.20 Page 5Job No:AK-XX-0900797980 Well Name:SP08-N7L1 Survey Report WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V7.4.20 Page 6Job No:AK-XX-0900797980 Well Name:SP08-N7L1 Survey Report