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Home My WebLink About211-052David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251113 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# OP08-04 50029234247000 210041 06/12/2013 SCHLUMBERGER USIT OP14-S03 50029234470000 211052 09/26/2013 SCHLUMBERGER CBL/USIT SI29-S02 50629234640000 213006 02/29/2012 SCHLUMBERGER SONIC VISION - TOC SP24-SE1 50629235100000 214011 03/19/2014 HALLIBURTON CAST-M/CBL-M/ACE Please include current contact information if different from above. T41096 T41097 T41098 T41099 212-006 OP14-S03 50029234470000 211052 09/26/2013 SCHLUMBERGER CBL/USIT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.13 13:15:44 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 21,340 (main) 21,371 (L1) Casing Collapse Conductor NA Surface 2,260psi Intermediate 3,090psi Liner (main) slotted Liner (L1) slotted Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 3,672 745 NA NA Ryan Rupert Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 3,672 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355024, ADL0373301, ADL0390616, ADL0391283 211-052 & 213-132 NIKAITCHUQ OP14-S03& L1 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23447-00-00 and 60-00 NIKAITCHUQ Hilcorp Alaska, LLC Length Size Proposed Pools: 3,672 21,363 3,672 SCHRADER BLUFF OIL Same 154 154 12.6#, L-880 TVD Burst 7,395 slotted MD NA slotted 10,440 5,020psi 5,750psi 2,163 3,847 3,672 2,324 10,440 See Schematic 3,6725-1/2" 154 20" 13-3/8" 9-5/8" 2,324 5-1/2"11,127 See Schematic 907-777-8503 ryan.rupert@hilcorp.com Operations Manager November 20, 2025 4/1/2002 Perforation Depth MD (ft): NA NA and NA NA and NA 21,363 21,325 11,381 21,325 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:52 am, Nov 10, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.11.07 15:53:53 - 09'00' Sara Hannegan (2519) 325-685 A.Dewhurst 10NOV25 10-404 MGR12NOV2025 *BOPE pressure test to 2000 psi. 24 hour notice to AOGCC. DSR-11/13/25JLC 11/13/2025 11/13/25 ESP Swap RWO Well: OP14 Well Name:OP14 API Number:50-029-23447-00-00 Current Status:ESP producer Permit to Drill Number:211-052 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Keith Lopez (907) 903-5432 (c) Regulatory Tech Darci Horner (907) 777-8406 (w) Maximum Expected BHP:1100 psi @ 3,558 TVD (6.0ppg) 2025 Max offset static Max. Potential Surface Pressure: 745 psi Using 0.1 psi/ft Brief Well Summary OP14 is a dual lateral OA sand producer. It is currently showing performance issues, and likely needs an ESP swap. It passed an MIT of the 9-5/8 casing in 2022. The goal of this project is install a new ESP and return the well to full production Pertinent wellbore information: - Deviation: Goes >70 degrees at 3600 MD - DLS: o Max DLS above top liner = 5.7 degrees / 100 at 1175 MD o DLS spike into 3-6 degrees / 100 from top liner up to 8,000 MD o Current ESP set from 7395 7475, but that was only due to cable length onsite at the time o Previous ESPs were successfully set from 7700 7850 MD -Last casing test: MIT PASSED to 1600psi against a 9-5/8 test packer set at 9950 MD on 5/5/22. - Pertinent History: o June-2011: Drill and complete as single OA lateral. Installed TT-ESP (0.2 year run life) o Sept-2011: ESP yo-yo RWO. Installed TT-ESP o 2012: ESP yo-yo RWO. Installed TT-ESP o 2013: Elective ESP pull for add-lateral drilling 9-5/8 casing scraper down to 10,137 MD Set isolation packer at 10,210 MD. Passed PT to 500psi Run new TT-ESP after 2nd lateral added o 2014: ESP yo-yo RWO. Installed conventional ESP with 7 shroud o 2022: RWO Pulled failed ESP, and ran casing scraper and magnets to ToL at 9970 MD (68# metal recovered) Ran VACS tool and magnets to 1500 inside top lateral to 14,482 MD (all the pipe we had). Recovered 29# more metal on magnets and minimal debris inside snorkel pipe Ran 9-5/8 test packer to 9950 MD, and PASSED MIT above to 1600psi Ran conventional ESP ESP Swap RWO Well: OP14 RWO Procedure 1. MIRU Nordic #4 2. Circulate / kill well: a. Work over fluid will be injection water (8.33ppg or heavier) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume = 114bbls d. IA to top liner = 612bbls 3. Set BPV/TWC, ND tree, NU BOP stack (see attached) a. Notify AOGCC 24 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC (lubricate out if pressure below is suspected) 5. Unseat hanger 6. POOH laying down 4-1/2 ESP completion 7. Pickup cleanout run (if necessary) 8. Cleanout casing and liner as deep as practical 9. Pickup and RIH with 3-1/2 tubing ESP completion a. Bottom ESP to be set at ±7,900 MD 10. Land ESP completion 11. Set BPV/TWC, ND BOP 12. NU tree and test, pull BPV/TWC 13. RDMO RWO crew and equipment Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. BOP schematic Completion Tubing: 4-½ 12.6# L80 TH563 TK-15XT internal coatedWell Head: Vault MB-247 13-5/8" 5K5-½ HAL Oil Swell Packer4-½ x-cplg cable clamps, for ESP Power Cable(1) 3/8" Chem Inj LineOP14-S3Dual Lateral Producerwith ESP Lift5-½ Silver Bullet Ecc Nose Guide Shoe 9-5/8" 40# L80 TH56310,440' MD 3,847' TVD 87º21,325' MD 3,671' TVD5-½ 17# L80 TH521 Slotted10,198' MD Baker SLXP LTP13-3/8" 68# L80 BTC2,324' MD 2,163' TVD36º7,475' MD 3,534' TVD 82ºBaker Conventional ESP, Bottom of Motor Centralizer7,395' MD 3,522' TVD Discharge Gauge Sub9,982' MDBaker SLXP LTP10,102-10,118' MD Window21,363' MD 3,672' TVD5-½ 15.5# L80 TH521 SlottedAs Completed5/9/20225-½ HAL Water Swell Packer21,371' MD 90° 8-¾ TD (L1: 2013)21,340' MD 89° 8-¾ TD (2011) Proposed Completion Tubing: 3-½ 9.3# 13Cr5-½ HAL Oil Swell PackerProposed ESP Power Cable and (1) 3/8" Chem Inj LineOP14-S3Dual Lateral Producerwith ESP Lift5-½ Silver Bullet Ecc Nose Guide Shoe 9-5/8" 40# L80 TH56310,440' MD 3,847' TVD 87º21,325' MD 3,671' TVD5-½ 17# L80 TH521 Slotted10,198' MD Baker SLXP LTP13-3/8" 68# L80 BTC2,324' MD 2,163' TVD36º~7,900' MD 3,934' TVD 82ºProposed ESP, Bottom of Motor Centralizer~7,820' MD 3,583' TVD Discharge Gauge Sub9,982' MDBaker SLXP LTP10,102-10,118' MD Window21,363' MD 3,672' TVD5-½ 15.5# L80 TH521 SlottedProposed11/7/20255-½ HAL Water Swell Packer21,371' MD 90° 8-¾ TD (L1: 2013)21,340' MD 89° 8-¾ TD (2011)OP14-S3 Proposed Schematic 11-7-2025.vsdx Last edited by: DH 11/7/2025 Nordic Rig 4 ARRS 5M Nordic Calista 02.24.2025 All Components 5,000 psi BLIND/SHEAR RAMS VBR RAMS CHOKE HCR MANUAL CHOKE KILL HCR INSIDE KILL3" 5,000 PSI WP KILL LINE Annular 2 7/8 x 5 VBR New Plugback Esets 7/3/2024 Well Name API Number PTD Number ESet Number Date 1D-141A PB1 50-029-22967-73-00 208-016 T39107 7-16-2008 1D-141APB2 50-029-22967-74-00 208-016 T39108 7-16-2008 1D-141APB3 50-029-22967-75-00 208-016 T39109 7-16-2008 2K-08APB2 50-103-20111-71-00 211-049 T39110 6-13-2011 2K-08APB3 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O u.6 a6D O N d m Z LL 0z1) m Z Z 3 .1 A AA, t d E o 0 0 o d `� .} ab r' m a O N CU ao V c z w`• 3 a a a a a a a a a a a a 0 a 0 0 — a a a a a a a a a aa.a) CO aa. a c a 0 0 0 0 0 0 0 0 0 0 0 0 co c0 cn co co N aA co co y N u) co y y y y N Q RELIVED STATE OF ALASKA DEC 0 3 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U ESP Change Out Performed: Alter Casing E Pull Tubing Q Stimulate-Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program E Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well E 2.Operator Eni US Operating Co.Inc 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development Q Exploratory ❑ 211-0520 3.Address: 3800 Centerpoint Drive,Ste.300,Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-23447-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: 0373301,0355024,0391283,390616 OP14-S3 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Nikaitchuq/Schrader Bluff Oil Pool 11.Present Well Condition Summary: Total Depth measured 21,340 feet Plugs measured feet true vertical 3,671 feet Junk measured feet Effective Depth measured feet Packer measured feet true vertical feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 154 154 Surface 2,324 13 2,324 2,163 5,210 2,480 Intermediate 10,440 10 10,440 3,847 6,890 4,790 Production Liner 11,127 6 21,325 03,671 slotted slotted 15 Perforation depth Measured depth 10,440-21,325 feet S�^��D mlvY >r True Vertical depth 3,847-3,847 feet Tubing(size,grade,measured and true vertical depth) 4.5" 12.6 ppf L80 7,863 3,583'TVD Packers and SSSV(type,measured and true vertical depth) 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 Casing Pressure Tubing Pressure Prior to well operation: 1404 118 79 0 183 Subsequent to operation: 1498 119 118 0 196 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑✓ Service ❑ Stratigraphic E Daily Report of Well Operations X 16.Well Status after work: Oil U Gas U WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ GINJ E 3USP ❑ SPLUG E 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt: 314-588 Contact Giuseppe Maugeri Email giuseppe.maugeri@enipetroleum.com Printed Name Marc Kuck Title Drilling&Completion Engineering Manager Signature XPhone (907)865-3328 Date 12/2/2014 Z.2,-/S ,. Z-/S,. RBE MS DEC 11 211 _- s/moi N p d Q CO LC Q.M C) L ,� V nC = Q t0.~C U -0 iit A\ N M o o _ '(� r o M ^t+ LO O \ W ti Q� •-/ L W 0 0 0 Z -N E cna Qo E � � N cn I � 0 1 _ a N4 w I N M L W 0 N cf)N w 4) I I U N W C J ._ Qco COCO m I. 5 il :.> ., Mu) v) M - O _ ,T) „,,,) Z , : ,I I \ Z u7 CD" N M' v. = � N I CD co M l � — L X � m � �7), - I : I ii . .- . X U (n Ln a �- .N U _ f6 o �' JNA I . �; � o Q I I. _ II o O = = _ I „. 1 J U 2 ( Q H 2 rn 2 CO a) O p c . 1 "« ' Q c co Y 0) E X .2 w Y oz1 \.'z I t c H _1 N U' a) and N ca " I = ti = U -0 W e c N t LL I U c 'a c N L o c U — CD 0 I ;'. I o p Q V) Co Q N d N to to ONO ❑ + _ " ww. L-. m 1` co N I r W - co C c-U ❑ (/) i C O ❑ > a) 2 6 0 \ ❑ M 3 O ~ O N ~ F- Co M F-iD C o- ... J Lf) ._. L() Ln I-1-1 00 ❑ N J Q 0 6 U N M Q M CO (0 2 O K j4 O d 2 H c e x d w �co 0 _ ❑ O ❑ ❑ O CMO r J i Ni N QU O2 LE. co c4i O O I co1-1 > r / O) O X (11-) M N ( > O _ 0o - oRI o •\ o N- co CNI 0 , �j a) cat 4 N N 4 o � § ti R U v- m O CO M M_ CO �' O 8 (D C a0 M N O O - / .— a) D O O 00 f� CO N O fC L a�co �,E lii\LI. v , , 3 E (1) 0 0 0 (I) a� a.),C ,C Y Y Y Y Y Y O Q L N U U U U U U U U 0_ L CD 03 CD CO CO CD CO RS 0_ 0_ 0- 0_ 0_ 0_ 0_ 0_ YO ! ‘W % J �._._.. O N COc0 CN CO N- N- •, -4101"-- N COC e--to _ CI X d CO CO LO v CO CO N- o o -o (6 .. N C J L Y O 6i co- to M N 0 N co m cr C)I M M O4t 4k 4t 0 Y CD d •- N 1- In CO N- CO 0) r CoN RS 2 m m a� a� a� aD a� a� m a� a� . as E N 4 . Y . Y . . . . . - M N N N 0 0 COVCVIS COVCO z N 0_ 0_ 0_ 0_ 0_ 0_ 0_ 0_ 0_ Orooil Eni E&P Division Well Name:0P14-S3 OR EN!Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • APIIUWI:50-029-23447-00-00 2^ Date:11118/2014 - Report#: 1 II II page 1 of 1 Wellbore name: OP14-S3 Well Header PermitlConcession N° Operator ENI Share)%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 4.87 6.58 Rig Information Contractor •Rig Name Rig Type NABORS ALASKA NABORS 245 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) OP14-S3 WORKOVER 1293.00 Daily Information End Depth(mKB) End Depth(TVD((... Depth Progress(m( Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 57.0 -5.6 Overcast WC 6° ENE @ 22 MPH Daily summary operation 24h Summary Prepare rig to move over well OP14-S3 RWO Operation at 07.00 Moving Rig. 24h Forecast Move to OP14-S3 RWO Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 14:00 2.00- 2.00 W.O. A 5 P Disconnect innerconnects and lines,prepare for rig move. 14:00 18:00 4.00 6.00 W.O. A 1 P Empty pits,blow down water and steam,lift lampson curtains. 18:00 00:00 6.00 12.00 W.O. A 1 P Jack up utility module,move utility mod away f/sub,jack up sub module Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv - 907-685-0715 Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Billy Petty ENI HSE Tool Push Gary Hoffman Nabors Alaska Drilling Tool Pusher Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 51/2 4.892 L-80 3,109.88 6.499.86 6/6/2011 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') 3,182.11 1,172.65 FazePro 1126.4 51.7 1567.0 183.7 Eni E&P Division Well Name:OP14-S3 OR lif* ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ •2^ Date:11/19/2014 - Report#: 2 APIIUVJI:50-029-23447 -00 I) II page 1 of 1 wellbore name: OP14-S3 Well Header Permit/Concession N" Operator ENI Share)%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 4.87 6.58 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) OP14-S3 WORKOVER 1294.00 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 63.0 -7.2 Blowing Snow WC- E @ 40 MPH Gust 1' to 52 MPH Daily summary operation 24h Summary Move ng over well OP14-S3. R/U to kill well.Bleed off psi 11182 psi on IA t/48psi&100 psi on tbg till psi Operation at 07.00 Start tree removal. 24h Forecast Pump kill fluid down tubing and shear upper GLM valve,displace tubing with 8.8 ppg brine. Line up on IA and pump kill fluid down IA and kill well. Monitor for pressure buildup. Bleed off.set BPV and N/D tree and N/U BOP's. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 11:00 11.00 11.00 W.O. A 1 P Move ng from OP18-08 to OPt4-S3 well. Set drig module,marry up utility module. Set berming,hook up inner connects. P/U rig mats.Spot cutting tank,set stairways, 11 00 13:00 2.00 13.00 W.O. M 8 P Stage chicksan lines to ng upon well.Take on kill fluid to mud pits. 13:00 14:00 1.00 14.00 W.O. M 8 P R/U lines to tubing and IA on well head. 14:00 16:00 2.00 16.00 W.O. M 8 P Cont RU f/pumping down IA&tubing&PT lines 16:00 21:00 5.00 21.00 W.O. M 9 P Pump 34 bbl 9.0 ppg brine down tubing shear GLM w/1010 psi,pump 438 bbl 9.0 ppg brine down IA @5bpm 200 psi shut in&monitor psi w/182 psi on IA&100 psi on tbg 21:00 00.00 3.00 24.00 W.O. M 8 P Bleed off psi on IA f/182 to 48 psi,&tbg f/100 toll psi Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Em representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bruce Simonson ENI Dnlling Supv. 907-685-0715 Eni representative Billy Petty ENI HSE Tool Push Gary Hoffman Nabors Alaska Drilling Tool Pusher Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 51/2 4.892 L-80 3,109.88 6.499.86 6/6/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm2) 3,182.11 1.172.65 FazePro 1126.4 51.7 1567.0 183.7 VII* Eni E&P Division Well Name:OP74-S]OR ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • APIIUWI:50-029-23447-00-00 2^ Date:11/20/2014 - Report#: 3 II II page 1 of 1 Wellbore name: OP14-S3 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 4.87 6.58 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) OP14-S3 WORKOVER 1295.00 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 65.0 -7.2 Blowing Snow WC- ENE @ 45 MPH W/ 3" Gust to 58 MPH Daily summary operation 24h Summary Bleed down tubing and IA to zero. N/D tree and N/U BOP's. Weather shut down due to phase 3 conditions. Resumed work at 1400 hrs. Phase 2 condition.Cont NU BOP Test BOP 250/3500.Test witness waived by AOGCC Rep.John Crisp Operation at 07.00 Rigging up to pull hanger. 24hForecast Finish N/U and test BOP's. Witness waived by John Crisp with AOGCC. R/U GBR and Baker equipment. Start production string pull. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 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 W.O. M 8 P Bleed down tubing and IA pressures from(tbg)11/(IA)48 psi to zero. R/D lines. 03:00 03:30 0.50 3.50 W.O. M 1 P Install BPV with Vetco rep. 03:30 05:00 1.50 5.00 W.O. C 5 P N/D production tree. 05:00 0900 4.00 9.00 W.O. C 5 P M/U test dart.N/U riser,BOP stack. Install bell nipple,Bowline,choke and kill lines. Start R/U Katch can. 09:00 1400 5.00 14.00 W.O. C 22 TWO1 Shut down due to Phase 3 conditions,Poor visibility,blowing snow,wind E @ 43 MPH Gust to 55 MPH 14:00 15:00 1.00 15.00 W.O. M 1 P Phase condition brought back down to a phase 2. Work resumed. Continue with Katch can R/U. 15:00 0000 9.00 24.00 W.O. C 12 P PU landing joint,fill stack and CM w/H20,test BOP equipment 250 low and 3500 high Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Dolling Supv 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Billy Petty ENI HSE Tool Push Gary Hoffman Nabors Alaska Drilling Tool Pusher Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 51/2 4.892 L-80 3.109.88 6,499.86 6/6/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgticm') 3.182.11 1,172.65 FazePro 1126.4 51.7 1567.0 183.7 __. +� Eni E&P Division Name:OP14-S3 OR ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUO 2 n S - Date:11/21/2014 - Report#: 4 APIIUWI:50-029-23447-00-00 I' II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 4.87 6.58 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) OP14-S3 WORKOVER 1.296.00 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 64.0 -7.8 Mostly Clear WC 1' E @ 33 MPH WI Gust to 50 MPH Daily summary operation 24h Summary Finish BOP test,Pull tubing hanger to floor and LID same. R/U to pull completion tubing.Hang elephant trunk,string up sheaves,berm cable path.LD tubing f/7783'1/6979' Operation at 07.00 POOH Laying down tubing 24h Forecast POOH with completion tubing.spooling ESP cable and cap tube with spooler. 'Lithology Shows -- - MAASP(kgflcm') Mud Weight(g/L) 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 W.O. C 12 P Finish testing BOP's,perform accumulator test. Blow down lines, 03:00 04.30 1.50 4.50 W.O. L 20 P M/U T-bar,pull BPV,R/D T-bar,Vetco rep onsite. 04:30 06:30 2.00 6.50 W.O. L 1 P M/U 4.5"landing jt into hanger,pull hanger free wrath 185k pull,pull to rig floor,disconnect ESP cable and cap tube. LID hanger assembly 06:30 12:00 5.50 12.00 W.O. L '22 TWO1 Shut down due to high winds(35-45 mph) to risky to put a man in the derrick to hang elephant trunk and work cable shieves. 12:00 14:00 2.00 14.00 W.O. L 1 P R/U shieves and elephant trunk from derrick. 14:00 19:00 5.00 19.00 W.O. L 1 P Cant RU elephant trunk.string up sheaves.brm cable path 19:00 00:00 5.00' 24.00 W.O. L 4 P LD tubing(/7783'V6979' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Billy Petty ENI HSE Tool Push Gary Hoffman Nabors Alaska Drilling Tool Pusher Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 51/2 4.892 L-80 3,109.88 6,499.86 6/6/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.182.11 1,172.65 FazePro 1126.4 51.7 1567.0 183.7 En!E&P Division Well Name:0P14-S3 OR 119* ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • APIIUWI:50-029-23447-00-00 2 Date:11/22/2014 - Report#: 5 �fh II page 1 of 1 wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 4.87 6.58 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) OP14-S3 WORKOVER 1297.00 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 65.0 -13.9 Overcast WC-17' E @ 31 MPH Daily summary operation 24h Summary POOH with production tubing to 1025'. R/U slickline. Make 2 slickline runs tagged sand unable to get to slip stop,RD slickline,Cont POOh w/completion f/1025'0/108',flush sand&oil f/last joint of tubing,RU slickline,pull slip stop Operation at 07.00 Clean up rig floor and prepare to PIU new ESP assembly and RIH 24h Forecast Pull packoff and pump.RD slickline,Continue POOH,L/D BHA.Clear clean rig floor, R/U and start running new completion. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 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 W.O. L 4 P Continue POOH with 4.5"production tubing from 6979'to 5616'. L/D GLM#1. Spooling ESP cable and cap tube. 01:30 03.00 1.50 i 3.00 W.O. L 9 P Fill tubing w/3 bbls,pressure up to 2200 psi and shear GLM valve#2,bullhead 82 bbls at 5 bpm,1250 psi to clean tubing. 03:00 12:00 9.00 12.00 W.O. L 4 P Continue POOH with 4.5"production tubing from 5616'to 1025'. 12:00 14.00 2.00' 14.00 W.O. L 15 P R/U Halliburton slickline and pull tbg stop.packoff and pump. 14:00 '15:30 1.50 15.50 W.O. L 1 P RD Halliburton slickline 15:30 '20:30 5.00 20.50 W.O. L 4 P Cont POOH w/completion f/1025'1/108',flush last joint of tubing 20:30 0000 3.50 24.00 W.O. L 1 P RU slickline&pull tubing stop Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Billy Petty ENI HSE Tool Push Gary Hoffman Nabors Alaska Drilling Tool Pusher Tool Push Tony Morales Nabors Alaska Dulling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 51/2 4.892 L-80 3,109.88 6,499.86 6/6/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,182.11 1,172.65 FazePro 1126.4 51.7 1567.0 183.7 • Eni E&P Division Name:OP14-S3 OR rill* ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • Date:11/23/2014 - Report#: 6 API/UWI:50-029-23447-00-00 2 r' 'r n page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 4.87 6.58 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) OP14-S3 WORKOVER 1298.00 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 65.0 -8.3 Mostly Cloudy WC- WSW @ 9 MPH 36' Daily summary operation 24h Summary Finish POOH with completion. Change out tools,spools,etc for new install. Had to send in to Deadhorse the shroud to have threads cut for gas separator. Continue P/U ESP while waiting for shroud to return.Stand back motor pump assembly,LD shroud already assembled,pu gas separator,MU first shroud joint,attempt to MU second joint of shroud,unable to make up because of incompatible thread Operation at 07.00 Waiting on Baker Shroud. 24h Forecast Breakout and LD gas separator,send shroud components back to Deadhorse for thread compatibility changes.Receive shroud components,MU same.install motor pump assembly in shroud,MU electrical connections.Continue running new ESP completion. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 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 W.O. -L 20 P L/D packoff and pump assembly w/slickline. R/D slickline. 01:30 04:00 - 2.50 4.00 W.O. L 20 P Finish laying down seals,motor assemblies. - -- 04:00 06:30 2.50 6.50 W.O. L 1 P Clean and clear rig floor of all misc.parts from pulling completion. 06:30 09:00 2.50 9.00 W.O. K 1 P Change spools in spooler,prep new completion tools,perform rig service. 09:00 14:00 5.00 14.00 W.O. K 1 P Start to make up new completion ESP. Noticed shroud jt was not cut for gas seperator make up. Sent to Deadhorse to have the threads cut.Continue M/U ESP assembly. 14:00 17:00 3.00 17.00 W.O. K 1 P Cont PU MU shroud assembly&motor seal assemblies 17:00 00:00 ' 7.00 24.00 W.O. -K 5 P Pull and stand back pump&motor asembly,breakout and LD shroud,PU gas separator,PU first shroud joint&MU to gas separator,PU second joint of shroud assembly&attempt to make it up,unable to MU due to thread incompatibility Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Billy Petty ENI HSE Tool Push Gary Hoffman Nabors Alaska Drilling Tool Pusher Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 51/2 4.892 L-80 3,109.88 6.499.86 6/6/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 3,182.11 1,172.65 FazePro 1126.4 51.7 1567.0 183.7 ft* Eni E&P Division ..} I Well Name:0P14-S3 OR ENI Petroleum Co.Inc. Daily Repo l Well Code:25485 Field Name:NIKAITCHUO • API/UWI:50-029-23447-00-00 2^ Date:11/24/2014 - Report#: 7 I) II page 1 of 1 Wellbore name: OP14-S3 • Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 4.87 6.58 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) OP14-S3 WORKOVER 1299.00 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 64.0 -16.7 Light Snow WC-13' W @ 9 MPH Daily summary operation 24h Summary MU first shroud joint,attempt to MU second joint of shroud,unable to make up because of incompatible thread. Send back to Deadhorse machine shop to have thread cut.Tools arrived @ 16:30 hours. PU MU 7"shroud,install motor&seal assembly in shroud,Lock down assembly in shroud,make MLE&cap tube connections as per BCL,attempt to PU 1st tubing joint unable to MU,LD same,breakout LD top pup joint due to incompatable thread. Operation at 07.00 Start RIH W/ESP Completions 24h Forecast PU new pup joint&MU to centalizer,PU 1st tubing joint,make splice f/MLE Vpower cable&cap tube connections,Continue running new ESP completion. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 14:00 14.00 14.00 W.O. K 24 TWO2 Waiting on Baker Centrilift to return with shroud assembly from Deadhorse machine shop. 14:00 1630 2.50. 16.50 W.O. K 24 TWO2 Cont wait on tools 1630 18:00 1.50 18.00 W.O. K 1 P PU MU shroud,lower motor&seal assembly into shroud. 18:00 00:00 6.00 24.00 W.O. K 1 P Lock down motor assembly in shroud.MU control lines&penetrator,test seals,attempt to PU 1st tubing joint would not MU to pup on top of centralizer(incompatable thread),LD joint 1,BO pup joint Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative 'Ben Perry ENI Senior Drilling Supv 907-685-0715 l Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Billy Petty ENI HSE Tool Push Gary Hoffman Nabors Alaska Drilling Tool Pusher Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 51/2 4.892 L-80 3,109.88 6.499.86 6/6/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.182.11 1,172.65 FazePro 1126.4 51.7 1567.0 183.7 • r91* Eni E&P Division (Well Name:OP14-S3 OR EN!Petroleum Co.Inc. Daily Re r o� Well Code:25485 Field Name:NIKAITCHUO • Date:11125/2014 - Report#: 8 APIIUWI:50-029-23447-00-00 e i ii page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 4.87 6.58 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) OP14-S3 WORKOVER 1300.00 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 61.0 -20.6 Overcast WC-22° ENE @ 9 MPH Daily summary operation 24h Summary Breakout LD pup joint on top of motor pump assembly due to incompatible thread,replace w/new,PU 1st joint of tubing,MU MLE&cap tube splice,run 4.5"completion 113311'testing cable every 1000'. cont add 5bph brine to hole,cont run 4.5"completion to 6170' Operation at 07.00 Preparing to make final splice. 24h Forecast Continue running new ESP completion.PU MU hanger,make final penetrator splice,land hanger,test seals,test conductivity,test tree,ND BOP Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 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 W.O. K 5 P BO,pup joint on top of motor pump assembly,replace w/new,PU MU 1st tubing joint 01:00 04:00 3.00 4.00 W.O. K 5 P MU MLE&cap tube splice 04:00 14:00 10.00 14.00 W.O. K 4 P Run 4.5"completion 113311',test cable every 1000' 14:00 00:00 10.00 24,00 W.O. K 4 P Cont.run 4.5"completion to 6170',test cable every 1000' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Billy Petty ENI HSE Tool Push Gary Hoffman Nabors Alaska Dolling Tool Pusher Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 51/2 4.892 L-80 3,109.88 6,499.86 6/6/2011 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') 3.182.11 1,172.65 FazePro 1126.4 51.7 1567.0 183.7 Eni E&P Division Well Name:OP14-S3 OR ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name: NIKAITCHUO 2�,fili* Date:11/26/2014 - Report#: 9 API/UWI:50-029-23447-00-00 II II page 1 of 1 Wellbore name: OP14-S3 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 4.87 6.58 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(in) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP14-S3 WORKOVER 1301.00 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 47.0 -17.8 Partly Cloudy WC E @ 17 MPH 19' Daily summary operation 24h Summary PU T-bar&attempt to pull BPV,psi under BPV,bleed off&monitor f/buildup PU MU hanger&landing joint Make final splice&terminate cap tubeLand hanger.RILDS,test upper&lower seals 55k f/10 min each RD LD third parry tools&equipment BD lines,ND choke&kill lines,ND katchkan&bell nipple Remove rams f/stack Cont.remove rams f/stack ND stack,set on stump&secure,LD riser,NU tre PU T-bar&attempt to pull BPV,psi under BPV,bleed off&monitor f/buildup Operation at 07.00 Prep For Rig Move 24h Forecast Prep For Rig Move Lithology Shows MAASP(kgflcml Mud Weight(gIL) Time Log Start End Cum Time Time Dur(Br) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03.30 3.50 3.50 W.O. K 4 P Cont run 4.5"completion f/6170'V7821' 03:30 04:30 1.00 4.50 W.O. K 5 P PU MU hanger&landing joint 04:30 06.00 1.50 6.00 W.O. K 5 P Make final splice&terminate cap tube 06:00 07:30 1.50 7.50 W.O. K 20 P Land hanger.RILDS.test upper&lower seals 55k f/10 min each 07.30 10:00 2.50 10.00 W.O. K 20 P RD LD third party tools&equipment 10.00 12:00 2.00 12.00 W.O. K 20 P BD lines,ND choke&kill lines,ND katchkan&bell nipple 12:00 14:00 2.00 14.00 W.O. K 20 P Remove rams f/stack 14:00 18:00 4.00 18.00 W.O. '-K '20 P Cont.remove rams f/stack 18:00 22:00 4.00 22.00 W.O. K 20 P ND stack.set on stump&secure,LD riser.NU tree 22:00 00:00 2.00 24.00 W.O. K 20 P PU T-bar&attempt to pull BPV,psi under BPV,bleed off&monitor f/buildup Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Billy Petty ENI HSE Tool Push Gary Hoffman Nabors Alaska Drilling Tool Pusher Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 51/2 4.892 L-80 3,109.88 6,499.86 6/6/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3.182.11 1,172.65 FazePro 1126.4 51.7 1567.0 183.7 Eni E&P Division Well Name:OP14-S3 OR 1119* ENI Petroleum Co.Inc. Daily ReportWell Code:25485 Field Name:NIKAITCHUQ • APIIUWI:50-029-23447-00-00 2 II II�, Date:11/27/2014 - Report#: 10 page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 0.00 4.87 6.58 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 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) OP14-S3 WORKOVER 1302.00 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 47.0 -20.6 Partly Cloudy WC- E @ 11 MPH 22' Daily summary operation 24h Summary Pull BPV.Install TWC.Test Tree T15.000 PSI F/10 Min.Pull TWC RD Test Equip.Secure Well Ba Flush Mud Pumps,Charge Pumps and Top Drive W/H2O,RD BD Same Bleed Down Koomey,Plug Hyd Lines and Remove Fittings From BOPE,Remove Elevators and Bails,Blow Down Charge Pumps and Lines Raise Curtains and Dixie Cup,Cont Cleaning Pits and Sumps,Blow Down H2O on Sub,Tear Down Mud Pumps Check Fluids&Start Lampsons,Remove Steam Traps,Drain Glycol FN/3 Gen.,Break Bolts On Stack,Separate Interconnects,Secure Stairs&Landings BD Steam,LD Well House Ladder Extensions,Roll Up Lampson Curtains.Set Mats, Operation at 07.00 Moving Rig 24h Forecast Moving Rig Lithology Shows MAASP(kgf/cm2) Mud Weight(gIL) 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'W.O. A 1 P Pull BPV.Install TWC.Test Tree T/5.000 PSI F/10 Min.Pull TWC • 02:00 03:00 1.00 3.00 W.O. A 1 P RD Test Equip,Secure Well Bay 03:00 05:30 2.50 5.50 W.O. A 1 P Flush Mud Pumps,Charge Pumps and Top Drive W/H2O,RD BD Same 05:30 08:00 2.50 8.00 W.O. A 1 P Bleed Down Koomey,Plug Hyd Lines and Remove Fittings From BOPE,Remove Elevators and Bails,Blow Down Charge Pumps and Lines 08:00 14:00 6.00 14.00 W.O. A 1 P Raise Curtains and Dixie Cup,Cont.Cleaning Pits and Sumps,Blow Down H2O on Sub,Tear Down Mud Pumps 14:00 17:00 3.00 17.00'W.O. A 1 P Check Fluids&Start Lampsons,Remove Steam Traps,Drain Glycol P/03 Gen., 17:00 18:00 1.00 18.00 W.O. A 1 P 'Break Bolts On Stack,Separate Interconnects,Secure Stairs&Landings 18:00 21:30 3.50 21.50 W.O. A 1 P BD Steam,LD Well House Ladder Extensions, 21:30 00:00 2.50 24.00 W.O. A 1 P 'Roll Up Lampson Curtains,Set Mats, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson .ENI Drilling Supv. 907-685-0715 Eni representative Billy Petty ENI HSE Tool Push Kelly Cozby Nabors Alaska Dulling Tool Pusher Tool Push Gary Hoffman Nabors Alaska Drilling Tool Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 51/2 4.892 L-80 3,109.88 6499.86 6/6/2011 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm2) Eq.Mud Weight(gIL) P LeakOff(kgflcm2) 3.182.11 1,172.65 FazePro 1126.4 51.7 1567.0 183.7 0 1 —' c cG CC 0 9 o g° z co Z co Z I-- 1 m i o o ° ° o o Q a 0 p O o 0) o N Z o 0 W0 W W a r 0 J �0 a0 0 E C O) 0 O 4 N co c c co 0)2 C o E E o >• N C0 0 co 0 c co N N 0 co Cl) a) co Q° O >> > u) =� co O E W,a) Q'a) �' �' a.W X W 0) LL O) J O J O U'co O) p co °co co a ao co Z Z U p p >°> >° ce 7 J p Co >>co p ao >>ao Q ao p cn 0 2 2 ~ F- 0WX _� F � � -� ∎� ∎Q Y. co 1 c o 0 o c N > r r r r r r r r r v- W .co o O O o O O O O 0 0 0 0 0 J 0 0 O N N N N N N N N N N N N N Q Q1 CO CO CO CO 00 CO CO 00 ✓ Q J N N N N N N N N N N N N N CD CO (O CD CD CD CD CO co CO CO co co C E 0 7 2 C C C C C C C C C C C C C a) ? f0 C = = a s �. a) a a Cl) a) a a) a) a) s E I— O Y OV O O O O O O O 0 0 0 0 0 0 o Ce ° c :a 0 co co CO CO CO 0 0) 0 0 0 O 0 CL O Z 0 O M_ _M M_ M_ M_ _N _ a' Q. r+CD CO /� ` 0 • O N N N N N N N M N M N N N j E as c W W V) Z A/ a Sc (O CO (O c0 �A 0 COO to (OD co 0 co O co .- LL O 1 N N. N- N- N- N- r co W Q U Z J > W O a) a) Z � z°I ce Q J a• . 1 O 0 0 a M C ZI v v v N g N0) O ` a N O1 16 M E a 0 0 N Cn N LO N N N N N N U Z. 0 E M J M 0 a N Ti N CZO a N O o N CO a 6- c o Z t Cl) .2 �� =• w W / ~ p Q c = W Z Z a ZI co T T T T T ce cc Q Z E > .> .> .> .> > > d U p d) H N y 4) E J 0 N 0 0 0 N O O Z j 0 W W W W' W c C lL 11 y d O O O O O O O) O) O o 0) E r J 0 0 0 0 0 CO r C �p 7 o 7 7 7 O 0 C V Z V V V V V y 7 7 7 7 O a 0 M j, y C C C C c CC 2 2 2 2 2 2 0 11 I I a) E N Q � O H• a N- coo 0 o I- I � m 5 .3 E v c ✓ Q z at.+ 0 W Z V) 0 D a)) N 0 0 Q C E .. a E E E E E i t 1. l a. N 0 A co 6 V co ? 42 01LL co J Z w N a O C) 6 d in W LL d ch E ¢ W 0 \ \ U U o y J Na, \ y Q O F- a m °) a o 0 0 rn ° a 0 0 o co ) 0 — d 0 FT J o F- J J J W C J J J J J W co 0 O 0 ' { Z N � oco U '''. : in C 1 z 1 a Gi cA U .y ? e N 0 0 r1 C) E O 2 O Z Z Z Y. ~w <C3 vJ V W Ceo c W M ,. °' U J W o Z az a Q 7 0 O J a o _ m >. E Y. M C ii O Eo 0 IL N Z. M E U = 0 M Q I M— O CO 1 ' r O C a N 0 m O I I• a) o Q E C a) Q 6 II z E 0 ;0 iA Z j co M Z O a0 CO O 2 } 3 ms a N 0 m u.Z �' d o J' re O Z N U P C C w N O O N y H d W a+ F, 0 y .T a E G E O a� a a Q 0 Qa 0 O . 1 77)IT TrL2k\Tr r= SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS / 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Marc D. Kuck Sr. Completion Engineer i _ O ca- Eni US Operating Co. Inc. O� l 3800 Centerpoint Drive, Ste 300 Anchorage, Alaska 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP 14-S3 Sundry Number: 312-080 Dear Mr. Kuck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2�day of February, 2012. Encl. fi a* Elm• RECEIVED eili': f FEB 2 7 2012 1 L11 :h : c0mm0n Alaska O & G Cs. issi ge 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc D.Kuck Phone(907)865-3322 Email: Marc.Kuck @enipetroleum.com February 27,2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 1 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP14-S3 ESP Replacement Dear Commissioners, ENI US Operating Co.Inc.hereby applies for a Workover Sundry for well OP14-S3. OP 14-S3 was originally completed by Eni Petroleum at Oliktok Point on June 6, 2011 with a Through- Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7895' MD. The well was started up for production on June 16, 2011. The well was operated for approximately 75 days when the ESP failed on September 5, 2011 and was replaced on September 17, 2011. The ESP failed again due to . down-hole problems on February 21,2012 and requires another rig workover. The estimated date for beginning this work is March 5,2012. 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 me at 907-865-3322. Sincerely, „,.._ /4sie, Marc D.Kuck Sr.Completion Engineer 'V �_ QED fly , .1 STATE OF ALASKA �Ir'7` ALASKA OIL AND GAS CONSERVATION COMMISSION FEB w' 2012 APPLICATION FOR SUNDRY APPROVA S 20 AAC 25.280 Alaska nil "��ns.Commission 1.Type of Request: Abandon III Plug for RednIl ❑ Perforate New Pool CI Repair Well Chaive,Appaged Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing ---- "i ime extension Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: 6f fOAoi El • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co.Inc. Development 151 • Exploratory ❑ 211-052 • 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23447-00-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ OP14-S3 • 9.Property Designation(Lease Number): 10.Field/Pool(s): 355024, 373301, 391283, 390616 Nikaitchuq Schrader Bluff Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): • Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 21,340 3671 21325 3671 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 Surface 2324 13-3/8" 2324 2163 5,020 2,270 Intermediate 10440 9-5/8" 10440 3847 6,870 4,760 Production 11127 5-1/2" 21325 3671 slotted slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10440-21325 3847-3671 4-1/2" L-80 7909 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Development El • Service ❑ 14.Estimated Date for 5-Mar-12 15.Well Status after proposed work: Commencing Operations: Oil Kg• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marc D.Kuck Printed Name Marc D.Kuck Title Sr.Completion Engineer Signature Phone 907 865-3322 Date /' r6 2/z ?//Z_ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31?..'D' Plug Integrity ❑ BOP Test Mechanical l Integrity Test ❑ Location Clearance ❑ Other: 3 5j06 `S:• r30e �1 Subsequent Form Required: /0 — y try I APPROVED BY Approved by: ,/ COMMISSIONER THE COMMISSION Date:�j�-9 h alza/rz 0RIGINATMS MAR 0 2 201 Form 10-403 Revised 1/210 i *n,itu,Duate 'f.I y AO 2/17k 01 OP14-S3 Workover - Additional Data Sheet 2/27/2012 Workover Objectives: • Objective of this workover is to pull the failed TTC-ESP tubing completion and run in with a . new TTC-ESP system. • Complete the planned work with no HSE accidents or incidents. Well History: OP14-S3 was originally completed by Eni Petroleum at Oliktok Point on June 6, 2011 with a Through-Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7895' MD. The well was started up for production on June 16, 2011. The well was operated for approximately 75 days when the ESP failed on September 5, 2011 and was replaced on September 17, 2011. The ESP failed again due to down-hole problems on February 21, 2012. Pressure Data: This well is expected to have a static pressure of approximately 1300 psi. 8.8 ppg hot seawater with 2% KCI is planned as kill wt fluid for this workover. Operational Plan Summary: 1. MIRU Nabors 245E. 2. Shear GLM valve and circulate hot 8.8 ppg hot 3% KCI seawater kill fluid through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi. 4. Pull tubing to lower GLM. Rig up wireline and pull tubing stop check valve. V- 5. Circulate out remaining production fluid. 6. Continue POOH and LD ESP assembly. 7. MU new ESP assembly and RIH to setting depth. 8. Land hanger, RILDS and test hanger. 9. Install BPV and nipple down BOP. 10. NU tubing adapter and tree. 11. Pull BPV, install test plug and test tree. 12. Circulate Freeze protect through tree down IA. 13. Shut in well. 14. RDMO. • co Y (-g 2 a) (O U U a) I-1J O C a) _c ' a•_ E > o w m � C0 13 N r` I I N 0 L L CL T- O o 8 OL U-1 (� O) a) p O N al 4 Q 3 cn m Y °c' O u) � � O 0 0 _ I OY X O i N U 0 d - - o) o N d N N pp 0 = co L = 4 Y 0 m e . I t �t 0 -I U U c m 2 0 .c c Y '• N N Q > X °° a0 E I ( J . 0 D a_ O 4 0 LLJ r� N 0 M ' O E co , (h X M C ; F- = C N U) L 0 1-0 LU OD— 0.) C CO n E - M M d 00 I c O M C N 0 0 d) •. UM (o . 2M � E: 0) H N 0 a) -- U) O c *k C -p ? O � v M O rn a) 2Oao U O I- U) (0 CO U Nr (1) C 0 aj 0 N- d � 7 _�.!O N- N M N 3 - O I Q (a ` Ct) 0 N- C -►' Q N .- U 0 00 L co X ` /` C O E rn N g Q \ r 7 C O �\ C N O co N N N " \ lk \/ +• 0 N L() CO N CD N- N- C CO CO N- N N- co O CO a) N LO 10 O ti CO O O IP, E SOOco- Ln MN N 0 =Mr lib Z CL L .: C co U .sC N CO C V _O m CO 0 (15 — m a) m a) a) a) m a) m a) a 6 A co — = Y Y Y Y Y Y Y Y Y d N U U U U U U U U U Y 3 c3 ft cu CZ cu CU c6 ca ca O (N (/) d 0_ 0_ 0_ 0_ d 0_ d d Y Y CSI 2 5 signE giF i SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Marc D. Kuck Sr. Completion Engineer ENI US Operating, Co. Inc. S 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP14-S3 Sundry Number: 311-276 Dear Mr. Kuck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. 5. cerel, o��' :n o missioner DATED this It/day of September, 2011. Encl. 1117*• Ell• troIeum 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 RECEIVED' Marc D.Kuck Phone(907)865-3322 S E P 0 9 2011 Email: Marc.Kuck @enipetroleum.com Alaska Oil&Gas Cans. Commission September 9,2011 Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP14-S3 ESP Replacement Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP14-S3. The well was last completed on June 6`h,2011 with an ESP completion. The ESP failed due to downhole electrical issues on September 5, 2011. This sundry is for replacement of the ESP system to place the well back in operating condition.The estimated date for beginning this work is September 13,2011 ., 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 me at 907-865-3322. Sincerely, Marc D.Kuck Sr. Completion Engineer (JP'n �� RECEIVED a,l it �� • STATE OF ALASKA SEP 9 9 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Alaska Oil&Gas Cons. Commission 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redd!'❑ Perforate New Pool❑ Repair Well❑ Changekilgram ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing 0 - /,Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other: 1 P B%rG(mrs/ 0- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co.Inc. Development 0 - Exploratory ❑ 211-052 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23447-00-00 ' 7. If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ OP14-S3 • 9.Property Designation(Lease Number): 10.Field/Pool(s): 355024, 373301, 391283, 390616 Nikaitchuq Schrader Bluff Oil Pool- 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 21,340 3671 21325 3671 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 16020" 160 160 Surface 2324 13-3/8" 2324 2163 5,020 2,270 Intermediate 10440 9-5/8" 10440 3847 6,870 4,760 Production 11127 5-1/2" 21325 3671 slotted slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10440-21325 3847-3671 4-1/2" L-80 7895 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development 0 - Service ❑ 14.Estimated Date for 13-Sep-11 15.Well Status after proposed work: Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marc D.Kuck Printed Name Marc D.Kuck Title Sr.Completion Engineer ,„0"..,L........... Phone 907 865-3322 Date COMMISSION USE ONLY ��/ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3) 1 ' O[ / b Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: 35C ps. /30P /7.,y F *Z��/oSt Ann'-`-Lu t �%e_S if (k"a 4 ) Subsequent Form Required: /0 a y 0 il fily APPROVED BY Approved by: - SSIONER THE COMMISSION Date: 9•,Z-/( `.� RI I Form 10-403 Revised 1/ D S ' 2 � 4 GINAL ?d- S, t u p licate � t, i OP14-S3 Workover - Additional Data Sheet 9/9/1 1 Workover Objectives: • Objective of this workover is to pull the failed TTC-ESP tubing completion and run in with a new TTC-ESP system. • Complete the planned work with no HSE accidents or incidents. Well History: OP14-S3 was originally completed by Eni Petroleum at Oliktok Point on June 6, 2011 with a Through-Tubing Conveyed Electric Submersible Pump (TTC-ESP) set at a depth of 7895' MD. The well was started up for production on June 16, 2011. The well was operated for approximately 75 days when the ESP failed on September 5, 2011 due to an electrical fault with causes currently unknown. Pressure Data: This well is expected to have a static pressure of approximately 1300 psi. 8.8 ppg hot seawater with 3% KCI is planned as kill wt fluid for this workover. Operational Plan Summary: 1. MIRU Nabors 245E. 2. Shear GLM valve and circulate hot 8.8 ppg hot 3% KCI seawater kill fluid through tree. 3. Set BPV. ND tree and NU BOP and test to 3500 psi.• 4. Pull tubing to GLM. Rig up wireline and pull tubing stop check valve. • 5. Circulate out remaining production fluid. . 6. Continue POOH and LD ESP assembly. . 7. MU new ESP assembly and RIH to setting depth. • 8. Land hanger, RILDS and test hanger. 9. Install BPV and nipple down BOP. 10. NU tubing adapter and tree. - 11. Pull BPV, install test plug and test tree. • 12. Circulate Freeze protect through tree down IA taking returns up tubing. . 13. Shut in well. 14. RDMO. • — D rn0 a) U n o a) to W 0 C O co 0 i w co t 0 6 E m -o E c Q 1— O ` J if) o N °� ) L I � to � � CO_ i co O v� 'ti_ U) "L' � N 0 l� � � M00 _. r E NJ ° 0 (C) o i0_R a 0 (/) V CD .N (c)O L- lI M rii N =E 61. ÷E. L a 3 a) a) C cm cn as x CO I o- Y p ` - U ^N a) as • p " J C _ co o E — a. N 75 I x oLn J Qcn m o Q co I Y °° E m I C 0 , 0 Le) . C.1 C X C C _N J 0_ o 0 0 I ' X N v C� a) W — u) co rn o co co ci H E in > D •- C U) C > L() © 0 •- Q-0 H co- ' 0 c o M >O cEu a\o Q Q) rn a� 1>- . o 5 co 2 0 I I. °' C .— O o0 CU O O M U a) co t9 0 _ co C cc o 0 0 . o) ,_ M N Q N U Qco <h ` Lo ti W Q 0 0 0) _ a O 00 - 0D 00 N C E 0 // cp • x � o U• Q M > cv N 3 �+`\ \\\' V' \- ++ 0 N LO c0 N Cp N- ti f` C C.O 00 N- N N- C) O ' CO d N LO L.0 co O ti O O ° E 5 c).- O f:00 Lc C7 N ,- r.. \/ C4 > I:" U-LI— U I o � o a cu co ,— N c`') 4r in Co N- co O U N M a E *k *k *k *k *k It *k *k *t � a. M 0 co — 2 N a) a) a) a) a) a) a) a) 0-5 o A 2 M d - Y - - - - - Y Y 2 cL (n 0 0 0 0 0 0 0 0 0 0 Y 3 ca CD C 3 C13 CO CTS Ca RS Ca o CO CO a_ a_ 0- a- 0- o_ a. a_ Y Cj Z O Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Christine Schartzer Well No OP14-S3 Date Dispatched: 9-Jun-11 Installation/Rig Nabors 245E Dispatched By: Brian Muzny Data No Of Prints No of CDs OP14-S3 Logs: 1 /C7 C 77 2 in MD 1 2 in TVD 1 5 in MD 1 5 in TVD 1 Received By: v i............1./....k, Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 aZSt I' Anchorage,Alaska 99503 JA,.....■ muzny1( Slb.com Brian Muzny Fax:907-561-8317 LWD Log Delivery V2.1,03-06-06 01 ' ) 2-- STATE OF ALASKA ALASKA L _AND GAS CONSERVATION COMMISSIC WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 • Gas❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development El • Exploratory GINJ❑ WINJ❑ WDSPL❑ WAG❑ Other❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: ENI US Operating Co Inc Aband.: 6/10/2011 • 211-052 • 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive Suite 300,Anchorage 99503 5/6/2011 50-029-23447-00-00 . 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3167.5 FSL 1632.7 FEL S5 T13N R9E UM 5/31/2011 OP14-S3 • Top of Productive Horizon: ‘f-,9110 ..-3,,<Ii-44)-N 8.KB(ft above MSL): 53.2 15.Field/Pool(s): 267 FSL 2581 FEL 29^T14N R9EUM L,(33 Ground(ft MSL): 12 Nikaitchuq jam'�� Total Depth: w 5W 9.9.Plug Back Depth(MD+TVD): , w"0/((. �1 898 FSL 1255 FEL 24 T14N R8EUM • 21325 MD/3671TVD ,' "7 �a 4b.Location of Well(State Base Plane-oordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation:f Surface: x- 516647.47 • y-6036520.67 • Zone- 4 • 21340 MD/3671 TVD • 355024,373301,390616,391283 TPI: x- 515658.73 y-6044177.18 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 506577.48 y-6050074.3 Zone- 4 none ADL 417493 18.Directional Survey: Yes 0 No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) 1858 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES/NEU/Den 22. 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 SURFACE 154 SURFACE 154 30 Cement to Surface 13-3/8" 68 L-80 SURFACE 2326 SURFACE 2164 16 430 bbls 10.7#ASL,BO bbls 12.5#Crete 9-5/8" 40 L-80 SURFACE 10440 SURFACE 3847 12.25 338 bbls 12.5#Deeperete 5.5" 17 L-80 10203 21325 3826 3671 8.75 slotted liner 23.Open to production or injection? Yes is No❑ If Yes,list each 24. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD) Slotted Liner with ESP completion 4.5 7893 NA I -iCo p 25. ACID,FRACTURE,CEMENT SQUEEZE,ETC. I4; DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED rt•'r a-t.- 26. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: NA NA Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - 27. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 111 Sidewall Cores Acquired? Yes ❑ No 0 • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,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. I I NI '/; 4. .?I I j RSDMS JUN 2 7 Aii ;a 01& G8g Caw C im nission q Rncnarefne X1'.7 c ' Form 10-407 Revised 2/2007 CONTINUED ON REVERSE y .,� t•I I I&16,4- 06,/3v/lo// 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FvrtMATION TESTS NAME MD TVD Well tested? ❑ Yes o 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 1858 1770 OA sand top 10230 3829 Formation at total depth: OA sand 21340 3671 30. List of Attachments: Summary of Daily ops, Directional survey,wellbore schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 907-865-3321 Printed Name: Maurizio Grandi Title: Well Operation Project Manager Signature: c`I p, — / Phone: Date: ,6/2 2 INSTRUCTIONS 6 IITIA to 2500 PSI. 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 Item 1a: 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 prod 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 in Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: 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 29: 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. 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E r I E > > •2 o o aS N N AB U U N W p ai ( ti "EL 0- 0 m c o_ C L 5 > M L � cn cn � NM 00 U) � z I C) J �,Lam I R a ccn p L W I I'E 4 a L o� W 1 c c _ p In N a� ca O Qr = co 00 co 1 ' VJ n o)CO X I I— L (0 N J L X N p , N U Q c � � `° Y (15 p co d 4 p W - N (n o] rn o L 3 0 a, r p c N ° E co Lv' � o c `- m oWO) 2 H °-U X 000 ice = I o 0) c N O p (60O 0 LO o c p x w E = Q � J 'N �# � D N 0 Q (� O c E (p N 00 o o v 2 o m m U - (� cu p a v rn� m coo o_ Eapc N Q C� QU Y L_ 2 N 0 Q \ C \� J Li (6 4 O M \ 407 s #' Ilk MIMI! ii 1 i rn,t c U c `E co cy p A (4 L d co ,— co O ('Si m Y Z O rift* Eni E&P Division 'Well Name:OP14-S's EN!Petroleum Co.,, . Daily Report Well Code:25485 Field Name:NIKAITCHUO • Date:5/4/2011 - Report#: 1 API/UW:50-029-23447-00-00 2" " page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) !Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP14-S3 DRILLING 5/6/2011 21,239.01 3.660.6 21,260.00 194.08 109.5 -1.00 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 0.0 84.0 -5.4 Cloudy,WC-14.4° 115"ESE @ 3.7 ,mph Daily summary operation 24h Summary Move rig from OP10-09 splice modules-grade pad-lay out herculite and rig mats.\Move rig over OP14-S3. Operation at 07.00 Move utility to rig and jack down-level off some-Working on interconnect between rig&utility module and hook-up service lines./Install berm around ng. 24h Forecast Finish spotting rig over OP14-S3 and install berm around same./Connect interconnect and service lines between modules.\N/U drilling adapter&riser.\Load pipe shed with 5"Drill pipe.\Strap&P/U 5" drill pipe-rack back in derrick to drill intermediate section.\Build spud mud. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log - Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 15.00 3.00 3.00 DRILL A 2 P Take down&clear berm around rig/Pull roof cover off well house#1. 15:00 21 30 6.50 9.50 DRILL A 2 P Jack-up rig&utility modules up and split.\Remove mats&old herculite.\Level off pad.\Lay out new herculite and mats. 21:30 00:00 2.50 12.00 DRILL A 2 P Move rig module over Well OP14-S3&jack down. Daily Contacts Position Contact Name Company Title E-rnail Office Mobile Dolling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum Ddg.Spvr. 907-685-1277 907-632-3058 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1277 Last Casing seat Ca s.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) / J' vot Eni E&P Division I Well Name:OP14-S3 ENI Petroleum Co. nc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • ell 1 Q Date:5/5/2011 - Report#: 2 API/UWI:50-029-23447-00-00 page 1 of 1 Welibore name: OP14-S3 Well Header 21 052 Permit/Concession N° !Operator ENI PETROLEUM 'ENI Share(%) 100.001 HOIRZONTAL Configuration type Rotary Table Elevation(ft) !Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase 'Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..I Depth Dr.(MD)(ft) 'Drilling Hours(hr) 'Avg ROP(ftlhr) I DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 0.00 Daily Information End Depth(RKB) End Depth(TVD)0..1 Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) I POB 'Temperature(°F) 'Weather I Wind 0.0 83.0 1.6 Cloudy,WC-13.5° 61°ENE @ 9.1 mph Daily summary operation 24h Summary Move rig and utility module over OP14-S3-level and berm same.\Hook-up interconnect&service lines./Load 5"DP in pipe shed&strap.\N/U starting head(500 psi test f/10 mins.)&drill riser-continue loading 5"DP.\R/U MI Swaco CCB units&lines.\Build spud mud.\P/U 5"drill pipe singles&rack back in derrick-Total 31 stands. Operation at 07.00 ✓ P/U 5"doll pipe&building spud mud. 24h Forecast Finish P/U 5"drill pipe&5"HWDP-rack back in derrick to drill intermediate section./Build spud mud./Prep to P/U BHA./Hold Pre-spud meeting./P/U BHA#1&clean out conductor./POOH&P/U Schlumberger/Gyro Data tools and drill ahead to surface TD. Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(Iblgal) 8.75 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 A 2 P Level up rig module and move utility module into place and level same./Install berm around modules. 03:30 10:00 6.50 10.00 DRILL A 5 P Install interconnects between modules,hook-up flow,choke and service lines-start systems up./Lower curtains on Lampson units.\Load pipe shed with 5"drill pipe.\Put mud pumps back together. 10:00 17:00 7.00 17.00 DRILL D 20 P Install valves/fittings on conductor pipe./Vetco Gray installed starting head(pressure test 11500 psi.for 10 mins./N/U drilling riser,flow&fill-up lines-install Ketch-Kan./Measurements:37.24'to load shoulder and 41.03 ground level./R/U MI Swaco CCB units&lines. 17:00 20:00 3.00 20.00 DRILL E 5 P Finished loading&strapping 315 joints of 5"drill pipe into pipe shed.\Break out saver sub&re-torque to 31K/Build spud mud.\Install MI Swaco CCB lines. 20:00 '00:00 4.00 24.00 DRILL E 4 P P/U 5"drill pipe singles(2.562"OD rabbit)&rack back in derrick with mouse hole-total 31 stands.\CCB lines&electrical. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. 'Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum 04g.Spvr. 907-685-1277 907-632-3058 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Drig Spvr. 907-685-1277 Last Casing seat Cas.Type I OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date Last Leakoff Test Depth(RKB) ITVD(f1KB) Fluid Type I Fluid Density(lb/gal) I P Surf Applied(psi) I Eq.Mud Weight(112/gal) I Leak Off Pressure(psi) PT* Eni E&P Division I Well Name:OP14-S3 ENI Petroleum Co.Inc. Daily Report L Well Code:25485 Field Name: NIKAITCHUQ • APIIUWI:50-029-23447-00-00 2^ Date:5/6/2011 - Report#: 3 II II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(81) Water Depth(ft) RKB-Base Flange(ft) IRKS-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DES(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3.660.6 21,260.00 194.08 109.5 1.00 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ftlhr) I POB Temperature(°F) Weather Wind 306.0 306.0 226.00 4.00 56.5 85.0 14.4 Clear,WC 9.9° 317°NW @ 2.3 mph Daily summary operation _ 24kSSummary Finish P/U 5"drill pipe&5"HWDP-rack back in derrick to drill intermediate section./Build spud mud./Prep to P/U BHA./Hold Pm-spud meeting.)P/U BHA#1&clean out conductor.)POOH&P/U / Schlumberger/Gyro Data tools and drill ahead to 306' �/ Operation at 07•0 Drilling ahead as per wellplan 24h Forecast Drill 16'section Slide/Rotary f/306'-V2321'proposed TD-Circulate bottoms-up 3-5x(K&M model)-POOH back reaming to HWDP Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 8.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 °11:00 11.00 11.00 l DRILL E 1 P P/U 10,046'of 5"DP through mouse hole and stand back in derrick. P/U 14 joints of HWDP and Jars. 11:00 14:30 3.50 14.50 DRILL E 5 P P/U Clean out BHA#1:16"bit+PDM motor @1.83+NM Stab+XO+5"HWDP 14:30 15:30 1.00 15.50 DRILL E 20 P Hold pre-spud meeting with all personnel and reviewed plan forward.Fill stack with mud and check for leaks. 15.30 '17:00 1.50 17.00 DRILL E 3 P Spud well OP14-S3:Drill rotary,clean out surface conductor f/80,1/1601(Q=400 gpm,SPP=300 psi,40 rpm @ 1.5k torque, WOB=5-8k lbs,Up wt=Dn wt=Rot wt=60k lbs,Mud wt=8.8 ppg) 17:00 19:30 2.50 19.50 DRILL E 5 P P/U BHA#2:16"bit+PDM motor @1.83+NM Stab+XO+GyroPulse+PowerPulse+ARC 825+NM Stab+XO+5" HWDP 19.30 °22:00 2.50 22.00 DRILL E 3 P Drill rotary f/160'-t/306'(0=450 gpm,SPP=450 psi,40 rpm @ 1.9k torque.WOB=8-11 k Ibs.Up wt=65,Dn wt=Rot wt=62k lbs.Mud wt=8.8 ppg) 22.00 '00:00 2.00 24.00 DRILL E 5 P POOH 2 stands HWDP-P/U NM DC+x2 NM Flex DC+Float Sub+JAR+XO+5"HWDP Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum 'Sr.Ddg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 .907-715-6434 Drilling Supt. Gary Goedich Eni Petroleum Ddg Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling !Tour Pusher 907-670-8539 Dnlling Supt. Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1277 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) -Leak Off Pressure(psi) 119* Eni E&P Division `Well Name:0P14-S3 ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • APIIUWI:50-029-23447-00-00 5/7/2011 - Repo #: 4 2^ page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information __ Wellbore ' Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP14-S3 DRILLING 5/6/2011 21.239.0 3.660.6 21,260.00 194.08 109.5 2.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 1,947.0 1,848.7 1.641.00 15.00 109.4 85.0 14.7 Cloudy,Lt Snow,WC 287`WNW @ 3.5 9.7' mph Daily summary operation 24h Summary Drill 16'section Slide/Rotary 1/306'-61947' Operation at 07.00 ✓ Drilling ahead as per wellplan 24h Forecast Drill 16'section Slide/Rotary f/1947'-V2338'proposed TD-Circulate bottoms-up 3-5x(K&M model)-POOH back reaming to HWDP-POOH and L/D BHA-R/U Csg equipment-Make Csg hanger dummy run-R/U and Run 13 3/8"Csg Lithology Shows MAASP Pressure(psi) !Mud Weight(Iblgal) 9.10 Time Log - Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. _ Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E 3 P Drill Slide/Rotary f/306'-1/1126'(0=550 gpm,SPP=930 psi,40 rpm @ 3.5k torque,WOB=20-25k lbs,Up wt=98k lbs.Dn wt=95k lbs,Rot wt=90k lbs,Mud wt=8.9 ppg) 12:00 00:00 12.00' 24.00 DRILL E 3 'P Drill Slide/Rotary f/1126'-61947'(Q=600 gpm,SPP=1000 psi,40 rpm @ 4k torque,WOB=15-20k lbs,Up wt=118k lbs,Dn w1=100k lbs.Rot wt=104k lbs,Mud wt=9+ppg,ECD=9.58) ADT=15.07 (ART=5.52 AST=9.55) JAR=16.3 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.DrIg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goerlich Eni Petroleum Drlg Spur. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum DrIg Spur. 907-685-1277 Last Casing seat - Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Lea.koff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) vot Eni E&P Division (Well Name:OP14-Ss EN/Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ �j(�p APIIUWI:50-029-23447-00-00 e 11 o• Date:5/812011 - Report It: 5 page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° [Operator ENI PETROLEUM IENI Share(%) 100.001 OIRIZ NTA Configuration type Rotary Table Elevation(ft) [Ground Level(ft) 1 Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Name Rig Type NABORS ALASKA NABORS 245 E 1 LAND RIG Job Information Wellbore Job Phase Spud Date [Target Depth(ftKB) !Target Depth(TVD..l Depth Dr.(MD)(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) IDFS(days) OP14-S3 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 3.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,338.0 2,174.4 391.00 3.22 121.4 85.0 10.8 Cloudy,Lt Snow,WC 133°SE @ 2 mph 7.5° Daily summary operation 24h Summary Drill 16'section Slide/Rotary f/1947'-112338'(2231'ND)-Circulate bottoms-up x4(K&M model)-POOH back reaming to HWDP-POOH and UD BHA-RIU Csg equipment-Make Csg hanger dummy run-R/U and Run 13 3/8"Csg Operation at 07.00 l' Circ&cond mud for cement job. 24h Forecast Run 13 3/8°Csg-R/D fill up tool-R/U Schlumberger cement head and lines-Cement Job-R/D Schlumberger and GBR equipment-UD landing Jnt-Flush out riser and lines-N/D drilling riser !, Lithology 'Shows I MAASP Pressure(psi) I Mud Weight(lb/gal) 9.10 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 'E 3 P 'Drill Slide/Rotary 1/1947-1/2338'TD.(0=700 gpm,SPP=1250 psi,42 rpm @ 4-5k torque,WOB=20-30k Ibs,Up wt=118k Ibs, Dn wt=100k Ibs,Rot wt=107k Ibs) ADT=3.22[Tot 20.291 (ART=1.23[Tot 8.75] AST=1.99[Tot 11.59]) JAR=19.52 05:00 07:30 2.50 7.50 DRILL E 7 P Circulate&reciprocate pipe(0=800 gpm,SPP=1550 psi,80 rpm al 3.7k TO)till shakers clean(x4 B/U) 07:30 13:00 5.50- 13.00 DRILL 'E 6 P BROOH 1/2338'1/1642'(Q=800 gpm,SPP=1450 psi,80 rpm @ 1.5-5k torque)no pack off but cycling torque-Reduced Q to 400 gpm and reciprocate till section clean BROOH(/1642'11499'top HWDP(0=800 gpm,SPP=1450-800 psi,80 rpm la 1.5k torque)-Circulate till shakers clean 13:00 17:00 4.00 17.00 DRILL 'E 4 P POOH and Std back HWDP-POOH and UD BHA 17:00 -18:00 1.00- 18.00 DRILL E 1 P -Clean rig floor and remove unneeded equipment 18:00 19:30 1.50' 19.50 DRILL 'G 2 P 'R/U GBR equipment to run Csg 13 3/8"-P/U Landing Jnt-Performed Csg hanger dummy run-L/D Landing jnt 1 19:30 20:00 0.50 20.00 DRILL 'G 20 P 'Held PJSM with all personnel involved 20:00 '00:00 4.00- 24.00 DRILL "G 4 P 'P/U and RIH Csg 13 3/8"68#L80 BTC lin 1573'-Checked float valves OK-Installed centralizer as per well plan Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener(lenipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goerlich Eni Petroleum Drig Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1277 Last Casing seat Cos.Type I OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) IND(ftKB) 'Fluid Type 'Fluid Density(lb/gal) I P Surf Applied(psi) I Eq.Mud Weight(Ibigal) Leak Off Pressure(psi) Ili 1 Eni E&P Division (Well Name:0P14-Ss EN!Petroleum Co.Inc. Daily Report l Well Code:25485 Field Name:NIKAITCHUO • APIIUWI:50-029-23447-00-00 tenDate:5/9/2011 - Report#: 6 • page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23_ 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Dale Target Depth(ftKB) 'Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 4.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(fWhr) POB Temperature(°F) Weather Wind 2.338.0 2,174.4 0.00 85.0 8.6 Cloudy,Lt Snow,WC 255`N @ 2.5 mph 4.1" Daily summary operation 24h Summary Run 13 3/8"Csg-R/D fill up tool-R/U Schlumberger cement head and lines-Cement Job-R/D Schlumberger and GBR equipment-UD landing Jnt-Flush out riser and lines-N/D drilling riser Operation at 07.00 Testing BOPE 24h Forecast Test BOPE as per AOGCC requirements-P/U BHA#3 and RIH above float collar-Test 13 3/8"Csg-Drill out float equipment and 20-50'new hole w/spud mud-Displace to LSND mud-Perform LOT/FIT Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.20 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 G 4 P P/U and RIH Csg 13 3/8"68#L80 BTC(/1573' 1/2284'(M/U torque 6.56 h Ibs)-M/U Landing Jnt and Hanger-Landed at 2,326'MD(Shoe depth)Up wt=172k Ibs,Dn wt=155k lbs 03:00 04:30 1.50 4.50 DRILL G 7 P Circulate to condition mud(0=260 gpm SPP=250 psi)and reciprocate casing up/down-No losses. 04:30 05:30 1.00 5.50 DRILL H 1 P R/D GBR Frank's fill up tool-R/U SLB cement head 8 lines-Load plugs as per SLB + 05.30 08.30 3.00- 8.50 DRILL -H 7 P Circulate w/cement head to condition mud(0=6 bpm SPP=180-130 psi)and reciprocate casing up/down-Clear rig floor- Mix up MudPush 0830 09.00 0.50 9.00 DRILL H 1 P Held PJSM with all personnel involved 09.00 12.30 3.50 12.50 DRILL H 9 P Cement job,w/Schlumberger pump unit,pumped in sequence.5 bbls H2O and test lines @ 3000 psi-100 bbls Mudpush II 50-14 1,7 (10.1 ppg)@ 5 bpm-Drop Bottom Plug-430 bbls Lead slurry(10.7 ppg)@ 6 bpm[Class Artic Sea Lite 1009 sacks,2.45 Yield,mix H2O at 11.513 gaVsk]-80 bbls Tail slurry(12.5 ppg)@ 6 bpm[DeepCRETE 299 sacks,1.54 Yield,mix H2O at GP/` 5.237 gal/5k)-Drop Top Plug-10 bbls H2O Displacement slurry pumped w/rig pump 325 bbls mud(9.2 ppg)@ 8 bpm P=250->450 psi Slow flow rate last 10 bbls @ 250 psi-Bump Plug @ 3250 stk w/900 psi held 10'-Check float OK-Reciprocate Csg up/down until cement tilled annulus-Lead slurry returns of 200 bbls 10.7 ppg cement to surface-No losses during job- Cement in Place @ 12.00 hrs 12.30 14:00 1.50 14.00 DRILL H 5 P R/D Schlumberger cement head and GBR 13 3/8"Csg tools and handling equipment-L/D landing joint-Clear rig floor- M/U flushing tool on 5"DP stand-Flush drill riser w/citric pill-R/D tool and drain dolling riser 14:00 16:30 2.50 16.50 DRILL C 5 P N/D Dolling riser and Starting head-Pull 8 L/D mouse hole 16:30 20:00 3.50 20.00 DRILL C 5 P N/U Vetco Gray Multi-bowl and well head valves w/Vetco Gray Rep-Test 5000 psi 10' 20:00 00:00 4.00 24.00 DRILL C 5 P N/U 13 5/8"riser and BOP stack-install choke 8 kill lines,bell nipple,flow lines,Katch Kan Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Drig.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goedich Eni Petroleum Dig Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1277 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 1111# Eni E&P Division (well Name:0P14-5s ENl Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ Date:5/10/2011 - Report#: 7 APIIUWI:50-029-23447-00-00 a n" page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° (Operator (ENI Share)%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..JDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3,660.6 21,260.00 194.08 109.5 5.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,338.0 2,174.4 0.00 85.0 9.3 Pt Cloudy,Lt Snow, 221°SW @ 2.5 mph WC 4.5° Daily summary operation 24h Summary Test BOPE as per AOGCC requirements-P/U BHA#3 and RIH above float collar-Test 13 3/8"Csg Operation at 07.00 Circulate and displace mud to new LSND mud 24h Forecast Drill out float equipment and 20-50'new hole w/spud mud-Displace to LSND mud-Perform LOT/FIT-Drill 12 1/4"intermediate hole section Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.20 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 25 TR01 Repair iron rough neck(replace upper and lower wrenches) ��11 CV 1 �� 07:00 14:00 7.00' 14.00 DRILL E 12 P P/U 5"Test Jnt-Installed plug-Fluid pack BOP stack and choke manifold-Test BOPE @ 250-3500 psi Waived witness by AOGCC rep.Bob Noble �+ 14:00 15:00 1.00 15.00 DRILL C 5 P Pull test plug-Install Wear Bushing-Install wear ring w/Vetco Gray rep.-L/D test joint-Blow down choke manifold and lines 0 15:00 21:00 6.00 21.00 DRILL E 4 P P/U and M/U 12 W BHA#3 for intermediate hole section:12 W Bit OD605XX(s/n 7024093)+Xceed 900+ARC 825+ NM Stab+Telescope+NM Stab+NMDC+x2 NM Flex DC+Float Sub+8"Jar+XO+2x 5'HWDP+x24 5"DP+ 12.25"Ghost Reamer(1055")-RIH till 2107'-Wash down f/2107'82227'(0 650 gpm,SPP 730 psi,MW 9.1 ppg)soft Tag ©2227' 21:00 21:30 0.50 21.50 DRILL E 7 P Circulate B/U(0 650 gpm,SPP 730 psi,MW 9.1 ppg) 21:30 22:30 1.00 22.50 DRILL G 19 P Stand back 1 Std-M/U Circulating Head and cement line-Pressure test Csg 13 3/8"2500 psi 30'OK-Bleed off-R/D Circulating Head and lines 22.30 00'00 1.50 24.00 DRILL E 3 P Tag soft cement f/2227'82236'and continue to doll Plug and float equipment f/2236'82237'(0 650 gpm.SPP 700 psi,40 rpm.3.2->4.4k Torque,WOB 2-4k Ibs)-Ongoing Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.DrIg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goerlich Eni Petroleum Ddg Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Dolling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Drig Spur. 907-685-1277 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division I Well Name:0P14-Ss ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name: NIKAITCHUQ • APIIUWI:50-029-23447-00-00 2 1191*^ Date:5/11/2011 - Report#: 8 II II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100,00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 _21.59 -Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(f1KB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) 0P14-S3 DRILLING 516/2011 21,239.0 3660.6 21,260.00 194.08 109.5 6.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather I Wind 3,063.0 2,701.4 725.00 10.24 70.8 86.0 -2.6 Clear,WC-15.3 99'E @ 6 mph Daily summary operation 24h Summary Drill out float equipment and 22 new hole w/spud mud-Displace to LSND mud-Perform LOT/FIT-Drill 12 1/4"intermediate hole section(/2360'/13063'as per well plan plan. Operation at 07.00 Drilling ahead rotary steerable as per well plan. 24h Forecast Drill ahead rotary steerable(/3063'MD as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Due(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 -03.30 - 3.50 3.50 DRILL E 3 P Drill plug and float equipment(/2236'1/2324'btm of shoe and drill out rat hole 1/2338'.Q=250-650 gpm.SPP=700 psi. TQ=2.8-6.5K,48-60 rpm,WOB=2-8K. 03:30 04:00 0.50 4.00 DRILL E 3 P Drill new hole(22 feet)1/2360'.0=660 gpm,SPM=153,SPP=700 psi.TQ-ON=4.8K.60 rpm,WOB=10K. 04:00 05:30 1.50 5.50 DRILL E 7 P CBU and reciprocate std pipe @ 0=650 gpm,SPP=630 psi,TQ=3.6K. Prepare rig mud system to displace to LSND mud. 05:30- 0630 ' 1.00 6.50 DRILL E 7 P Circulate and displace water base mud to 9.2 ppg LSND mud. Q=600 gpm,SPP=530 psi,60 rpm,TQ=3K,reciprocating std pipe. 06.30 07:00 0.50 7.00 DRILL E 11 P Rack std back V2297'.M/U head pin&chart recorder for LOT. �0 �� 07:00 08:00 1.00 8.00 DRILL E 7 P Circulate and conditions mud until 9.2 ppg mud wt in/out. 08.00 09:00 1.00 9.00 DRILL E 11 P Perform LOT with 9.2 ppg LSND mud-LOT @ 12.5 EMW. R/D B/D testing equipment. 1 . 09:00 10:00 1.00 10.00 DRILL E 7 P Circulate and condition mud.Took SPR @ 22961AD 2191'1VD#1 35-65psi,45-88psi,#2 35-63psi,45-85psi. 10.00 12:00 2.00 12.00 DRILL E 3 P Drill Rotary Steerable 1/2360'112573',0=800 gpm,SPP=1050 On 1000 Off.189 SPM,80-120 rpm @ 3.6K TQ on,2.8K TO off,Up w1=110K.Dwn wf=98K,Rot wt=100K,WOB=2-6K.ROP=175-250 fph,mud wt=9.2 ppg. ADT 1.63 12:00 18:00 ' 6.00 18.00 DRILL E 3 P Drill Rotary Steerable 1/2573'112860,Q=905 gpm,SPP=1300 On 1275 Off.215 SPM.60-120 rpm, @ 5K TO on,2.5K TQ off.Up w1=118K,Dwn wt=102K,Rot wt=110K.WOB=3-10K,mud wt=9.2 ppg.ECD=9.68. 18.00 00:00 6.00 24.00 DRILL E 3 P Drill Rotary Steerable 1/2860'/13063,0=905 gpm,SPP=1300 On 1340 Off,215 SPM.60-120 rpm, @ 5K TQ on,3K TQ off, Up wt=118K,Dwn wt=102K,Rot wt=110K,WOB=3-10K.mud wt=9.3 ppg.ECD=9.68.SPR @ 2967'MD(2596TVD)#1 35- 100psi,45-115psi,#3 35-95psi,45-118psi.ADT 8.61 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. 'Jack Keener Eni Petroleum Sr.Drig.Spur. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goedich Eni Petroleum Dig Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Mike Nelson Eni Petroleum HOE 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Dolling Tour Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamaina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 -0.4 2,324.0 5/9/2011 'LastLeakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 01 Eni E&P Division I Well Name:0P14-as ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name: NIKAITCHUQ • APIIUWI:50-029-23447-00-00 2^ Date:5/12/2011 - Report#: 9 o II II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) OP14-S3 DRILLING 5/6/2011 21,239.0 3.660.6 21,260.00 194.08 109.5 7.00 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) I P" Temperature(°F) Weather I Wind 5,072.0 3,193.4 2.009.00 18.61 108.0 86.0 2.7 Pt Cloudy,WC-9.6 77°ENE @ 6.9 mph Daily summary operation 24h Summary Drill ahead rotary steerable(/3063'MD to 5072'MD(3183'TVD)as per well plan. Operation at 07.00 Drilling ahead rotary steerable as per well plan. 24h Forecast Drill ahead rotary steerable(/5072'MD as per well plan. Lithology I Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.30 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 Rotary Steerable(/30631/3630.Q=905 gpm.SPP=1375 On 1330 Off,212 SPM,60-120 rpm, @ 5K TO on.3K TO off, WOB=2-10K,mud wt=9.2 ppg. Back reaming 30'up/dwn flow check every connection. Slow to 60 rpm when encountering hard spots. 06.00 12:00 6.00 12.00 DRILL E 3 P Drill Rotary Steerable f/3630'1/4130,0=900 gpm,SPP=1530 On 1490 Off,212 SPM.60-120 rpm, @ 5.4K TQ on,4K TO off,WOB=2-10K,mud wt=9.3 ppg,ECD=9.80,SPR @ 4116'MD(3373'TVD)#1 35-145psi,45-180psi,#2 35-143psi,45- 178psi.ADT 9.04.Same drilling practices. 12:00 '18:00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable 8/4130'1/4770'(3150 TVD),Q=902 gpm,SPP=1650 On 1640 Off,214 SPM,120 rpm. @ 6.5K TQ on,5K TO off,WOB=10K,mud wt=9.3 ppg,ECD=10.02.Add H2O 10 bbl/hr. 18:00 00:00 6.00- 24.00 DRILL E 3 P Drill Rotary Steerable(/4470'55072(3183 TVD),0=902 gpm,SPP=1710 On 1700 Off,214 SPM,120 rpm, @ 5.1K TQ on, 4.3K TO off,WOB=15K,mud wt=9.3 ppg,ECD=10.02,SPR @ 4976'MD(3170'TVD)#1 35-215psi,45-250psi,#2 35- i 215psi,45-255psi.ADT 9.57. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spur. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Dolling Supt. Gary Goerlich Eni Petroleum Ddg Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,360.0 2.192.05 LSND 9.20 370.0 12.45 1.417.6 Eni E&P Division 'Well Name:OPt4-Ss ri* EN!Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • Date:5/13/2011 - Report#: 10 APIIUWI:50-029-23447-00-00 2" " - page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator I ENI Share)%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.991 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) OP14-S3 DRILLING 5/6/2011 21,239.0 3,660.6 21,260.00 194.08 109.5 8.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6,053.0 3,348.0 981.00 19.97 49.1 88.0 17.8 Clear,WC 3.7' 67°ENE @ 14.2 mph Daily summary operation 24h Summary Drill ahead rotary steerable 1/5072'1/6053'MD(3348'TVD)as per well plan.Hard spots encountered @ 1/5072'1/5356'and 1/5990'1/6021'.slow drilling. Operation at 07.00 Pulling of of hole on elevators 24h Forecast POOH due to EXCEED 900 tool failure. CBU and back ream through concretion. Pump a slug plug and POOH on elevators. Replace EXCEED tool and bit. RIH and continue drilling ahead as per well plan. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(Iblgal) 9.20 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 Rotary Steerable f/5072'5/5390',0=900 gpm,SPP=1730 On 1700 Off,212 SPM,60-80 rpm, @ 5K TQ on,4K TO off, WOB=6-1OK,mud wt=9.3 ppg,Up wt=118K,Dwn wt=95K,Rot wt=108. Drilling 60-80 rpm 10K max WOB 1/5072 1/5356' hardspot.6-10K WOB,60 rpm,hard/slow drilling. 06:00 12'00 6.00 12.00 DRILL E 3 P Drill Rotary Steerable 1/5390'6/5615,0=900 gpm,SPP=1790 On 1740 Off,212 SPM,80 rpm, @ 7K TO on,6.5K TO off, WOB=4-10K,Up wt=121K,Dwn wl=90K,Rot wt=108,mud wt=9.3 ppg. Same drilling practices,occational hard/slow spots. SPR @ 5606'MD(3270'TVD)#1 25-150psi,35-175psi,#2 25-148psi,35-173psi. ADT 10.08. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable 1/5615'1/5996'(3334'TVD),0=898 gpm,SPP=1750,212 SPM,120 rpm, @ 7-8K TO WOB=2-8K, mud wt=9.3 ppg,ECD=10.01 Up wt=138K,Dwn w1=86K,Rot wt=108. 18:00 '00:00 6.00 24.00 DRILL E 3 P Drill Rotary Steerable 1/5996'1/6053'(3348'TVD),Q=900 gpm,SPP=1800,212 SPM,80 rpm. @ 8K TQ,WOB=7K,Up w1=142K,Dwn wt=85K,Rot w1=110,mud wt=9.32+ppg,ECD=9.78. Hard F/5990'1/6021'WOB to 20K,60rpm. SPR @ 6030'MD(3340'TVD)#1 25-100psi,35-110psi.#2 25-100psi.35-110psi. ADT 9.89,JARS 68.3. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Drilling Supt. Frank Cormier Eni Petroleum Sr.DrIg.Spur, 907-685-1227 337-277-1809 Drilling Supt. Gary Goedich Eni Petroleum DrIg Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamanna Eni Petroleum DrIg Spvr. angelo.lamarina@enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(11KB) Run Date CASING 13 3/8 12.415 L60 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type 'Fluid Density(1b/gall IP Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 • Viols Eni E&P Division Well Name:OP14-S., EN/Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ APIIUWI:50-029-23447-00-00 e 1 n Date:5/1412011 - Report#: 11 page 1 of 1 Wellbore name: OP14-S3 - Well Header Permit/Concession 7 0/Concession N° 'Operator pI PETROLEUM I ENI Share(%) 100.00!!Well Configuration type Rotary Table Elevation(ft) [Ground Level(ft) 'Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 1220 0.00 15.99 21.59 Rig Information Contractor Rig Name IRig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase 'Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..l Depth Dr.(MD)(ft) !Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) OP14-S3 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 9.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6,066.0 3,350.6 13.00 0.08 162.5 89.0 21.4 Cloudy,WC 7.7° 67°ENE 15.7 mph Daily summary operation 24h Summary Troubleshoot SLB down hole directional tools problem shooting toolface from Exceed tools. CBU reciprocating std and back ream through concretion. Pump a slug plug and POOH on elevators. UD BHA#3.P/U BHA#4.4 RIH to 3259'. Operation at 07.00 Drilling ahead rotary steerable as per well plan. 24h Forecast Drill ahead rotary steerable f/6066'MD as per well plan. Lithology 'Shows I MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.30 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 TD01 Drill Rotary Steerable 1/6053't/6066'.Problem getting tool face from Exceed tool.Troubleshoot problem as per SLB reps. 01:30 03:00 1.50 3.00 DRILL E 7 TD01 CBU g4)6056'and back ream 1/5930'to clean hole through concretion while reciprocating pipe.0=915 gpm,SPP=1800 psi, 120 rpm @ 6.5K torque. 03:00 06:00 3.00 6.00 DRILL E 4 TD01 Flow check,pump slug and POOH on elevators(/5930'1/4090'130-144K Up wt. No gain/loss. Pulled last 5 stds,improper hole 511(a 4090. '06:00 06:30 ' 0.50 6.50 DRILL E 7 TD01 Circulate hole clean @ 4090'while rotating and reciprocating pipe. Had increase in cuttings at bottom up with no gas, / shakers cleared up. y 06:30 10:00 3.50 10.00 DRILL E 6 TD01 BROOH f/4090'1/2225'inside shoe. 0=900 gpm,SPP=1500 psi,120 rpm @ 2.5-5K torque. No packoff,no drag. 10:00 11:00 1.00 11.00 DRILL E 7 TD01 Circulate hole clean while rotating and reciprocating pipe. 0=900 gpm,SPP=1300 psi,70 rpm. Had increase in cuttings at bottoms up,shakers cleared up after 2 1/2 bottoms up.Flow check:Ok. 11:00 14:30 3.50 14.50 DRILL E 4 TD01 POOH on elevators(/2225'to surface.STD Back HWDP,Jars,Collars and cull 4x bad joints. 14:30 15:30 1.00 15.50 DRILL E 5 TD01 UD BHA#3.Bit Dull:4-4-CT-A-X-I-LT-DTF. 15:30 16:30 1.00 16.50 DRILL E 25 P Service Rig:repair weld on lower STD pipe bracket,troubleshoot electrical problem with generator sync switch. 16:30 19:00 2.50 19.00 DRILL E 5 TD01 P/U and M/U 12''/°"BHA#4 for drilling ahead intermediate hole section:12''/°"PDC Bit MSF619M-A7C(s/n E143367)+ Xceed 900+ARC 825+NM Stab+Telescope+NM Stab+NMDC+x2 NM Flex DC+Float Sub+8"Jar+XO+2x 5" HWDP+24x 5"DP+12.25'Ghost Reamer(1058'). 19:00 21:00 2.00 21.00 DRILL E 4 TD01 RIH w/5"DPs till 2303'.Shallow Test @ 1000':760 gpm-800 psi. 21:00 22:30 1.50 22.50 DRILL E 20 P Cut and slip 100'drilling line. 22:30 23:30 1.00 23.50 DRILL E 25 TD01 C/O Saver Sub,grease gripper,calibrate block height,set and test com. 23:30 00:00 0.50 24.00 DRILL E 4 TD01 RIH BHA#4 5 2303'0/3259'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Dig.Spvr. 907-685-1227 337-277-1809 Drilling Supt. Gary Goerlich Eni Petroleum Drlg Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Drig Spvr. angelo.lamarina@enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(ftKB) I TVD(ftKB) I Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 ff� Eni E&P Division I Well Name:OP14-S3 EN!Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • API/UWI:50-029-23447-00-00 5/15/2011 - Repo #: 12 page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.201 0.00 15.99 21.59 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3.660.6 21,260.00 194.08 109.5 10.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather !Wind 6,990.0 3,469.5 924.00 17.26 53.5 88.0 27.0 Cloudy,WC 12.2° 49°NE @ 23.9 mph Daily summary operation 24h Summary Drill ahead rotary steerable 1/6066'1/6990'MD(3466'ND)as per well plan.Hard spot encountered @ 1/6174'1/6210',slow drilling. Operation at 07.00 Drilling ahead rotary steerable as per well plan. 24h Forecast Drill ahead rotary steerable 86990'MD as per well plan. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.35 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 E 4 TD01 RIH on elevators(/3330'1/5937'MD,fill pipe every 2000'.Proper displacement.Took 10-20K drag,Wash down(/5937' 1/6066'-bottom. 02:00 03:00 1.00 3.00 DRILL E 7 TD01 CBU shear mud 6030'. Perform ECD base line parameters as per K&M.Cycle survey up and down,link/orient down hole tools as per SLB reps. 03:00 04:30 1.50 4.50 DRILL E 3 P Drill Rotary Steerable 1/6066'1/6174',0=900 gpm,SPP=1793 on,1750 off,212 SPM,60-80 rpm, @ 6-7 K TO on,5-6K TQ off. Encountered hard spot @ 6174'. 04:30 14:00 9.50 14.00 DRILL E 3 P Drill Rotary Steerable slow/hard @ 2-10 fph 86174'1/6210%Q=900 gpm,SPP=1793 on,1750 off,212 SPM,60 rpm, @ 7- 10K TO on,6K TO off,WOB=4-15K,Up wt=140K,Dwn w1=90K,Rot wt=110,mud w1=9.2 ppg,ECD=9.63.ADT 7.81. 14:00 00:00 10.00 24.00 DRILL E 3 P Drill Rotary Steerable(/6210'1/6990'(3466'TVD),Q=902 gpm,SPP=1960,212 SPM,120 rpm, @ 9-10K TQ,WOB=10- 14K,mud wt=9.3 ppg,ECD=10.13,Up w1=140K,Dwn w1=90K,Rot wt=110.SPR @ 6607'MD(3424'ND)#1 25-100psi,35 -125psi,#2 25-120psi,35-130psi.ADT 9.45,JARS 85.7. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Drig.Spvr. 907-685-1227 337-277-1809 Drilling Supt. Gary Goedich Eni Petroleum Ddg Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamanna @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.201 370.0 12.45 1,417.6 fill* Eni E&P Division (Well Name:OP14-S3 EN!Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • API/UWI:50-029-23447-00-00 2^,t Date:5/16/2011 - Report#: 13 II II II page 1 of 1 Wellbore name: OP14-S3 Well Header P"mI ENI Share(�)052Concession N° I EONI 1PaEtoTrROLEUM 100.00 HORIZONTAL type Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) OP14-S3 DRILLING 5/6/2011 21,239.0 3660.6 21,260.00 194.08 109.5 11.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wnd 6,565.0 3,679.9 1,575.00 17.36 90.7 90.0 26.8 Cloudy,WC 15.4 27'NNE @ 136 mph Daily summary operation 24h Summary Drill ahead rotary steerable 56990'1/8565'MD(3681'TVD)as per well plan. Operation at 07.00 Back Reaming out of hole to change BHA. 24h Forecast Drill ahead rotary steerable(/8565'MD as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.40 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 Rotary Steerable f/6990 117540',0=900 gpm,SPP=2010 On,1980 Off,SPM=214.120 rpm, @ 8-9.8K TQ,WOB=8- 12K,ROP=100-150 fph.mud wt=9.4 ppg,ECD=10.29,Up w1=135K,Dwn wt=88K.Rot wt=112. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill Rotary Steerable 1/7540'1/7800',0=900 gpm,SPP=2180 On,2100 Off,SPM=214,120 rpm, @ 9-10K TO on,8-9 TO Off,WOB=10-15K.Up wt=138K,Dwn wt=87K,Rot wt=112.SPR @ 7750'MD#1 25-225psi,35-260psi.#2 25-227psi,35- 265psi.ADT 8.32. 12.00 18:00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable(/7800'1/6220',hard spot f/7950'to 7960',0=900 gpm,SPP=2200,SPM=214,60-120 rpm, @ 10- 11 K TO,WOB=10-17K,mud w1=9.5 ppg.ECD=10.25,Up wt=152K,Dwn w1=85K,Rot wt=112. 18.00 00:00 6.00 24.00 DRILL E 3 P Drill Rotary Steerable 1/8220'1/8565'(3681'TVD),0=750 gpm,SPP=1740,SPM=214,60 rpm, @ 10-11K TQ,WOB=17K, mud w1=9.4 ppg,ECD=10.08,Up wt=158K,Own wt=80K,Rot w1=112.SPR @ 8235'MD(3641'ND)#1 25-165psi,35- 190psi,#2 25-180psi.35-210psi.ADT 9.04. Daily Contacts Position Contact Name Company Title Email Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.DrIg.Spvr. 907-685-1227 337-277-1809 Drilling Supt. Gary Goedich Eni Petroleum Ddg Spvr. 907-685-1277 Eni representative Tom Norvig Em Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spur. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 If941 Eni E&P Division 'Well Name: 0P14-S3 ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • APIIUWI:50-029-23447-00-00 2^ Date:5/17/2011 - Report#: 14 II II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° !Operator ENI Share(%( Well Configuration type 211-052 IENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15,99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information •Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP14-S3 DRILLING 5/6/2011 21,239.0 3.660.6 21,260.00 194.08 109.5 12.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8,574.0 3,680.7 9.00 0.46 19.6 90.0 25.9 Patty Cloudy,WC 50°NE @ 7.7 mph 17.7" Daily summary operation 24h Summary Drill ahead rotary steerable 1/8565'1/8574'MD as per well plan.Circulate and BROOH to change BHA. Operation at 07.00 Preparation for M/U BHA#5. Rig service. 24h Forecast M/U and RIH new BHA and Dnll ahead 1/8574'MD as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 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 Drill Rotary Steerable f/8565 V8574'.Q=750 gpm,SPP=1650 On,1500 Off,SPM=175,120 rpm, @ 12K TQ On,10.5K TQ Off,WOB=3-10K,mud wt=9.4 ppg,ECD=10.19,Up wt=158K,Don wt=80K,Rot wt=112. ADT.46. 00:30 01:30 1.00 1.50 DRILL E 11 U Circulate and rotate @ 80 rpm.Unable to achieve sufficient DLS to complete directional objectives.Decided to POOH. 01:30 02:30 1.00 2.50 DRILL E 7 U Circulate hole clean as per K&M recommendation @ 900 gpm,120 rpm,2330 psi,10K TQ.Reciprocate while rotating. 02:30 15:00 12.50 15.00 DRILL E 6 U BROOH(/8573'112323 @ 900 gpm,214 spm,2300 psi,120 rpm. 15:00 i 15:30 0.50 15.50 DRILL E 7 U CBU and continue until hole clean @ 900 gpm 1300 psi.Flow check:Ok. 15:30 i 18:00 2.50 18.00 DRILL E 4 U Slug pipe and POOH on elevators.Cull out 8x bad joints DP. 18:00 i 20:00 2.00 20.00 DRILL E 5 U Flush BHA w/30 bbls of Fresh Water and L/D BHA.Bit dull:2-3-BT-S-X-I-CT-BHA. 20:00 20:30 0.50 20.50 DRILL E 1 U Clean rig floor from trip out and prepare rig floor for trip in. 2030 21:00 0.50 21.00 DRILL E 25 U Rig service.crowns.blocks,Top Drive,drawwnrks.Clean suction screens on mud pumps. 21:00 00.00 3.00 24.00 DRILL E 20 U Download Data from Xceed Tool and Wait for data interpretation.P/U and R/B replacement joint of DP's 0 5". Daily Contacts Position Contact Name Company I Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1227 337-277-1809 Drilling Supt. Gary Goerlich Eni Petroleum Ng Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamanna @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 1/19* Eni E&P Division .. 'Well Name:0P14-S3 EN/Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • APIIl1WI:50-029-23447-00-00 2^ Date:5/18/2011 - Report#: 15 l i page 1 of 1 Welibore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.001 HORIZONTAL Rotary Table Elevation(ft) - Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E _LAND RIG Job Information Welibore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) OP14-S3 DRILLING 5/6/2011 21,239.0 3.660.6 21,260.00 194.08 109.51 13.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 8,992.0 3,712.4 418.00 3.21 130.2 89.0 32.7 Cloudy,Rain,WC 157`SSE @ 1.8 32.7' mph Daily summary operation 24h Summary M/U and RIH new BHA and Drill ahead 1/8574'58992'MD(3711'ND). Operation at 07.00 Drilling ahead rotary steerable as per well plan. 24h Forecast Drill ahead rotary steerable 58992'MD as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 09:30 9.50 9.50 DRILL E 25 U Perform general rig maintenance while data from Exceed tool being interpreted and sleeve stabilizers being changed on Exceed tool in Deadhorse. Tool arrived on location @ 0900 hours ready for service. 09:30 10:30 1.00 10.50 DRILL E 1 U Program/upload Exceed too.PJSM. 10:30 12:00 1.50 12.00 DRILL E 4 U P/U and M/U 12 Z"BHA#5 for drilling ahead intermediate hole section:12 WI PDC Bit Hycalog MSX619S-A2C(s/n E141127)+Xceed 900+ARC 825+NM Stab+Telescope+NM Stab+NMDC+x2 NM Flex DC+Float Sub+8"Jar+ XO+2x5"HWDP. 12:00 13:00 1.00 13.00 DRILL E 25 TR01 Troubleshoot pipe skate.Found bad relay switches.Repair same. 13:00 15:00 2.00 15.00 DRILL E 4 U RIH BHA#5 on DPs 0 5"down to 2323'.Perform shallow test MWD @ 1000'and fill pipe every 20 stds. 15:00 18:30 3.50 18.50 DRILL E 4 U Continue RIH BHA#5 f/2323'S 8574'.Up wt=170K,Dwn wt=60K,no hard spots or bridges encountered. 18:30 19:00 0.50 19.00 DRILL E 19 U Tag bottom @ 8574',take 2x survey,downlink I/Xceed. 19:00 00:00 5.00 24.00 DRILL E 3 P Drill Rotary Steerable 1/8574'1/8992'(3711'ND),0=809 gpm,SPP=2020,120 rpm, @ 10-12K TO,WOB=15K,mud wt=9.4 ppg.ECD=10.07,Up wt=160K,Dwn wb=80K,Rot wt=112.SPR @ 8703'MD(3694'TVD)#1 25-180psi.35-200psi, #2 25-180psi,35-195psi.ADT 3.21. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Drilling Supt. "Frank Cormier Eni Petroleum Sr.DrIg.Spvr. 907-685-1227 337-277-1809 Drilling Supt. Gary Goerlich Eni Petroleum DrIg Spvr. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamarina @enipetroleum.corn 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall 1 P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 ft* Eni E&P Division [Well Name:0P14-S3 ENI Petroleum Co.lnc. Daily Report Well Code:25485 Field Name: NIKAITCHUQ � � APIIUWI:50-029-23447-00-00 211 11 Date:5/19/2011 - Report#: 16 • II II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) 'Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) --- 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...IDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) OP14-S3 DRILLING 5/6/2011 l 21,239.0 3,660.6 21,260.00 194.08 109.5 14.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10455.0 3,847.4 1.463.00 14.11 103.7 90.0 28.9 Cloudy,Heavy Fog. 19"NNE @ 11.2 WC 19.2- mph Daily summary operation 24h Summary Drill ahead rotary steerable 1/8992'V 10455'MD(3848.86'TVD)INTERMEDIATE CASING POINT-CBU x5 while back reaming 1std. Operation at 07.00 BROOH. 24h Forecast Continue CBU-BROOH to 13 3/8"Casing shoe-CBU until shakers clean-POOH&L/D BHA#5-R/U Tesco and run csg 9 5/8". Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.60 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 3 'P Drill Rotary Steerable(/8992'5/9450',0=850 gpm,SPM=200,SPP=2350 On,2335 Off,120 rpm, @ 12K TO,WOB=15K. mud wt=9.4 ppg,ECD=10.26,Up wt=163K,Dwn w1=73K,Rot wt=115.Back reaming 30'up/dwn. Flow check every connection. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill Rotary Steerable 1/9450'1/9910'(3785'TVD),Q=850 gpm,SPM=200,SPP=2460 On,2420 Off,120 rpm, @ 10-12K TO,WOB=14K,mud wt=9.4 ppg.ECD=10.6,Up w1=160K.Dwn wt=75K,Rot wt=115.SPR @ 9750'MD(3762'ND)#1 25- 240psi,35-280psi,#2 25-250psi,35-288psi.ADT 9 hrs. 12:00 19:00 7.00 19.00 DRILL E 3 'P Drill Rotary Steerable(/9910'1110455'((3848.86'ND)INTERMEDIATE CASING POINT.Q=900 gpm,SPM=215, 7 - SPP=2810,120 rpm, (d1 12-13K TO,Wl5 =10.15K,mud wt=9.5 ppg,ECD=16i'07,wt=162K,Dwn wt=80K,Rot wt=112. , Take bottom survey and downlink Xceed to neutral.ADT 5.11 hrs-Jars 121 hrs. Note:(/12:00 V12:30 dg blackout(engines overheat). 19.00 00:00 5.00 24.00 DRILL E 7 'P 5x CBU and condition mud @ 900 gym,120 rpm&SPP=2840 psi.Rack 1 std back each bottom up to 10043'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Drig.Spar. 907-685-1227 337-277-1809 Drilling Supt. Gary Goedich Eni Petroleum Dig Spar. 907-685-1277 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ng Spar. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 Eni E&P Division I Well Name:0P14-S's ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUO • APIIUWI:50-029-23447-00-00 2^n Date:5/20/2011 - Report#: 17 I� II ii page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° !Operator ENI Share)%) Well Configuration type 211-052 IENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) I DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 15.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) I POB Temperature(°F) Weather Wind 10,455.0 3,847.4 0.00 90.0 36.7 Clear,WC 32° 142'SE @ 5.6 mph Daily summary operation 24h Summary Circulate until clean-reciprocate and rotate string-CBU total 7X-rack back 1 stand every bottoms-up(/10,455'-119,757./POOH back reaming 1/9,757-U2,323'(13 3/8"csg.shoe)/CBU 4X until shakers clean-reciprocate and rotate string./POOH&UD BHA#5.1 Pull wear bushing and install test plug.\Change upper rams to 9 5/8"csg. Operation at 07.00 P/U and run 9 5/8"40#/L-801 Hydril 563 as per tally. 24h Forecast Finish changing upper rams to 9 5/8"csg.and test to 250/3500 psi.(chart record)\Pull test plug and install Vetco Gray special short wear bushing.\R/U Tesco casing equipment to top drive&function test.\P/U 9 5/8"40#L-80 Hydril 563 as per tally(check float equipment)and record parameters for K&M./R/D Tesco casing equipment from top drive./P/U cement head-fill&bleed 9 5/8"csg./Circulate &condition mud for cement job.\Prep Schlumberger for cement job. Lithology Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.40 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 E 7 P Circulate hole clean-reciprocating string with total 7X bottoms-up-racking 1 stand @ each CBU-f/10,455'-1/9.757'MD as per K&M recommendation./Pump rate 900 gpm @ 2600 psi.\120 rpm @ 12-14K torque.\Rot wt.=116K. 03.30 18:00 14.50 18.00 DRILL E 4 P POOH Back Reaming(/9,757'-1/2323'(13 3/8"csg.shoe)/Pumping rate 900 gpm @ 1250 psi./120 rpm @ 9-11K torque when started and decreased to 2.5-3.6K torque @ 2323'\Mud wt.=9.4 ppg.\Rot wt.=105K. 18:00 19:00 1.00 19.00 DRILL E 7 P Circulate clean(4X bosoms-up)@ 2323'\Pump rate of 900 gpm @ 1200 psi.\120 rpm @ 1.6K torque.\Rot wl=101K.\ Rotate&reciprocate pipe./Mud wt.=9.4 ppg. 19:00 20:30 1.50 20.50 DRILL E 4 P Monitor well-static\Pump dry job&blow down\POH 1/2323'-6283' 20:30 22:30 2.00 22.50 DRILL E 4 P Held PJSM with Schlumberger.\L/D BHA#5-all components from 5"HWDP to bit.\Clear floor and unload pipe shed./ Load Schlumberger tools on truck. 22:30 23:00 0.50 23.00 DRILL E 5 P Pull wear bushing&set test plug with Vetco Gray. 23:00 00.00 1.00 24.00 DRILL E 5 P Change top rams to 9 5/8"csg.\P/U 9 5/8"csg test joint. Ui Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Ddg.Spar. 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum Drig.Spar. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Drig Spar. angelo.lamanna @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Ca s.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 -0.4 2,324.0 5/9/2011 - Last Leakoff Test Depth(ftKB) ITVD(ftKB) Fluid Type Fluid Density(1b/gall I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 Eni E&P Division 'Well Name:OP14-6.3 ENI Petroleum Co.Inc. Daily Re pO Well Code:25485 Field Name:NIKAITCHUQ • API/UWl:50-029-23447-00-00 2�, Date:5/21/2011 - Report#: 18 If II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 IENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore_ Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3.660.6 21,260.00 194.08 109.5 16.00 - Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10,455.0 3,847.4 0.00 89.0 30.6 Cloudy,Fog,WC 34"@ 11.2 mph __ _21.4` __ _ Daily summary operation 24h Summary Finished changing upper rams to 9 5/8"csg.)Test 9 5/8"csg.rams to AOGCC requirement 250 low/3500 high psi.(chart record))Pull test plug and Vetco Gray install special short wear bushing.)Held PJSM-R/U Tesco casing/drilling system to run 9 5/8"csg.and function tested.)Down time due to pipe skate(proximity switch)replaced&function tested.)Held PJSM-P/U 9 5/8"csg.shoe track-fill& test float equipment,good.)Continue floating 9 5/8"csg.in hole as per tally and well plan-monitor displacement and K&M recording parameters-started rotating @ 4630'w/30 rpm @ 2K torque and increased to 60 rpm @ 4.5K torque.)Rot wt:52K. 'Operation at 07.00 Filling and bleeding 9 5/8"csg.with 9.4 ppg mud. 24h Forecast P/U 9 5/8"csg.40#/L-80/Hydril 563 as per tally to shoe depth 10.440'while rotating 60 rpm @ 5.5K torque-Rot wt.=50K./R/D Tesco casing equipment from top drive.)P/U cement head-fill&bleed 9 5/8"csg.\Circulate&condition mud for cement job.)Schlumberger mix&pump 12.5 ppg Deep Crete cement.\Displace with rig mud pumps and bump plugs-float check.)Perform 20 bbls injectivity test.) Pick BOP stack and cut 9 5/8"csg.-install slips&pack-off-set multi bowl assembly-Vetco Gray test same.)Freeze protect 13 3/8"x 9 5/8"csg.with diesel. 'Lithology Shows . . - . . MAASP Pressure(psi) Mud Weight(1b/gall 9.40 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 G 5 P 'Finished changing upper BOP rams to 9 5/8"csg. 00:30 01:30 1.00 1.50 DRILL G 12 P Test 9 5/8"csg.ram to 250 psi.Low/3500 psi.High-to AOGCC requirements(chart record). j$c j fc.1, 01:30 02:00 0.50' 2.00 DRILL G 5 P Pull test plug&Vetco Gray install special short wear ring(4'long x 12 3/8"ID). 02:00 05:30 3.50 5.50 DRILL G 20 P Held PJSM-R/U Tesco casing/drilling system on top drive to run 9 5/8"csg.\Function test equipment same. 05:30 06:00 0.50' 6.00 DRILL G 20 P Held PJSM to run 9 5/8"csg.(40#/L-80/Hydril 563)with Tesco-discussed procedures in well plan,well control.and tally. • 06:00 07:00 1.00 7.00 DRILL G 4 XR99 Down time due to pipe skate buggy would not move back-found proximity switch damaged-replaced&function tested. 07:00 12:00 5.00 12.00 DRILL G 4 P P/U.15/Long.(40#!.L-80/Hydril 563).._-fdl shoe track and check float equipment-good.)RIH V2254'-running speed @ 1 -1 1/2 mins./jt.\Make-up 14K\Dn wt.=54K/Mud weight=9.4 ppg. 12:00 16:00 4.00 16.00 DRILL G 4 P Continue P/U 9 5/8"csg.(40#/L-80/Hydril 563)as per tally and sliding/floating in hole as per well plan.1/2254'-1/4630'- running speed @ 2 mins/jt.\Make-up 14K/No down weight.)Mud weight=9.4 ppg. 16:00 00:00 8.00 24.00 DRILL G 4 P P/U 9 5/8"csg.(40#/L-80/Hydril 563)-Started rotating string in hole(/4630'-1/9144'running speed @ 2 mins./jt.\30 rpm @ 2K torque-increasing to 60 rpm with 4.5K @ 9017'\Make-up 14K\Rot wt:52K./Mud weight=9.4 ppg. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.DrIg.Spur. 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum Ddg.Spur. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Dulling Supt. Angelo Lamarina Eni Petroleum Ddg Spur. angelo.lamarina@enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 -0.4 2,324.0 5/9/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type I Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 Iffi* Eni E&P Division I Well Name:OP14-Ss ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ e Date:512212011 - Report#: 19 APUUWI:50-029-23447-00-00 e" " page 1 of 1 Wellbore name: OP14-S3 Well Header 21 052 Permit/Concession N° IOperator ENI PETROLEUM I ENI Share(%) 100.001 HORIZONTALation type Rotary Table Elevation(ft) 'Ground Level(ft) 'Water Depth(ft) I RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase 'Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...IDepth Dr.(MD)(ft) Drilling Hours(hr) !Avg ROP(ft/hr) I DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3,660.6 21,260.00 194.08 109.5 17.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10,455.0 3,847.4 0.00 89.0 30.4 Cloudy,Fog,WC 86°E @ 4.6 mph 25.5` Daily summary operation 24h Summary P/U 9 5/8"csg.409/L-80/Hydril 563 as per tally to shoe depth 10,440'while rotating 60 rpm @ 4.5K torque-Rot wt.=52K./R/D Tesco casing equipment from top drive.\P/U cement head-fill&bleed 9 5/8"csg.\Circulate&condition mud for cement job.\Schlumberger mix&pump 338 bbls.of 12.5 ppg Deep Crete cement.\Displace with rig mud pumps and bump plugs with connect volume-cement in place @ 1956 hrs.-float check.\Perform 20 bbls injectivity test.\Prep to P/U BOP stack @ Vetco Grey Multi-bowl R/D Katck-Kan&install hydraulic lift cylinders. Operation at 07.00 Install 9 5/8"pack-off assembly and N/U BOP stack. 24h Forecast P/U BOP stack @ Vetco Gray Multi-bowl&install Vetco Gray emergency slips-cut 9 5/8"csg.and remove landing joint-install 9 5/8"csg.pack-off assembly-set BOP stack down and test connection& pack-off.)Freeze protect 13 3/8"x 9 5/8"csg with diesel.\Change upper rams to Variable 4 1/2"x7"from 9 5/8".Load pipe shed with 4 1/2"drill pipe-prep to P/U.\Clean active&raw mud pits-for OBM. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.40 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 G 4 P P/U 9 5/8"csg.(409/L-80/Hydril 563)-Continue rotating string in hole 1/9144'-1110,440'\60 rpm with 4.5K @ 9017'\Rot wt=52K./Make-up 14K/Mud weight=9.4 ppg. 03:00 03:30 0.50 3.50 DRILL G 5 P R/D Tesco casing/drilling tool from top drive and equipment and remove from rig floor. 03:30 04:00 0.50 4.00 DRILL G 5 P Install cement head&R/U hoses on same to fill&bleed operation on 9 5/8"csg.with 9.4 ppg.mud. 04:00 10:30 6.50 10.50 DRILL G 7 P Fill&bleed 9 5/8"csg.with 9.4 ppg mud.\Pumped 398 bbls.-shut down f/15 mins.-filled with 198 bbls.-shut f/15 mins.- filled with 181 bbls. 10:30 15:30 5.00 15.50 DRILL H 7 P Switch lines to Schlumberger cement head-Break circulation @ 1/2 bpm @ 185 psi and stage rate up very 15 mins.to 8 bpm @ 500 psi.-circulate&condition mud for cement job to well plan&MI Swaco engineer spec. 15:30 16:00 0.50 16.00 DRILL H 20 P Held PJSM with Schlumberger for cement job and review procedure and permits required for fluid transfers. 16:00 16:30 0.50 16.50 DRILL H 20 P Remove cement head&load with two plugs(witness by ENI&Schlumberger reps)-P/U 350 ton spider elevators&re- instated cement head. 16:30 20:30 4.00 20.50 DRILL H 7 P Schlumberger pump 5 bbls.Mud Push II and test lines to 3700 psi:OK.\SLB pump 65 bbls.Mudpush II in 10.5 ppg- Pump rate of 5.0 bpm @ 440 psi.\Shut-down drop bottom plug.)SLB mix and pump DeepCrete stony 338 bbls.@ 12.5 ppg\1;40 aka/Yield=1.54 tl Lsk,mix water at 5.243 gal/sk.]-Pump rate of 5.8 bpm @ 1040 psi.\Shut down&drop top 15/ It yy plug-SLB pump 10 bbls.H2O and wash up.\Displarn with 772 hhie ray q d__pg mud with rig pump at 7.8 bpm vd1130 psi; at 738 bbls.away slow pump to 3.0 bpm with 830/psi.FCP\Bump plug to 500/psi;over FCP to 1330/psi.)Hold for 2 minutes and bleed off-check float equipment-Good.)Cement in place @ 1956 hrs.with full return through out the cement job. 20:30 21:00 0.50 21.00 DRILL H 7 P Closed annulus&Qerformed 20 bbls.injectivity test 9.4 ppg r�r g.Q down 13 3/8"x 9.5/8"csg.with 1.4 bpm @ 640 psi.&2 bpm©750 psi 21:00 22:30 1.50 22.50 DRILL H 5 P R/D Schlumberger cement head.)C/O 350 spiders to 5"elevator.\Displace 9 5/8"csg.with 1 std,2 pups&closed TIW valve-stand back 5"dp and L/D pup/valves.\C/O back to 350 spiders. 22:30 00:00 1.50 24.00 DRILL H 5 P R/D Ketch-Kan and prep hydraulic cylinders to P/U BOP stack to install Vetco Gray emergency slips&pack-off assembly. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum Drig.Spvr. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 1 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) 'Fluid Type 'Fluid Density(lb/gal) 'P Surf Applied(psi) I".Mud Weight(1b/gall I Leak Off Pressure(psi) 2,360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 Eni E&P Division [Well Name:OP14-S yr,* EN!Petroleum Co.l, . Daily Report Well Code:25485 Field Name:NIKAITCHUO • APIIUWI:50-029-23447-00-00 2 II^ Date:5/23/2011 - Report#: 20• II II n page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° [Operator ENI Share)%) Well Configuration type 211-052 I ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(H) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) [Target Depth(TVD..J Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3660.61 21,260.00 194.08 109.5 18.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) [Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10,455.0 3,847.4 0.00 89.0 29.8 Clear 126°SE @ 0 mph Daily summary operation 24h Summary Finished R/D BOP stack&lines./P/U BOP stack and Multi-bowl&Vetco Gray installed emergency slips-cut 9 5/8"csg.and remove landing joint-install 9 5/8"csg.pack-off assembly-set BOP stack down and test pack-off./Freeze protect 13 3/8"x 9 5/8"csg with 143 bbls.diesel pumping 2 bpm @ 1450 psi;while N/U lines to BOP stack./Change upper rams to vocable 4 1/2"x7"from 9 5/8"csg./Load pipe shed with 4 1/2"drill pipe./Service rig./RIH with 5"DP L/D pipe with bad hard band(85 Ifs total)/POOH installing WEI CD sub.\Clean active&raw mud pits-Put 540 bbls.of weighted 9.4 ppg OBM in raw mud pits. Operation at 07.00 RIH-P/U 5"DP with new hard band. 24h Forecast POOH installing WEI CD sub(SLM 87 stands)./P/U 5"DP with new hard band to replace pipe UD and to TD well.\POOH installing WEI CD sub\Test BOP to AOGCC requirements.\P/U 4 1/2"DP to compensate for BHA./P/U BHA#6./RIH-P/U 4 1/2"singles to 10,326'\Circulate bottoms-up.\Test 9 5/8"csg.to 3000 psi f/30 mins.(chart record).\Displace well to OBM.\Drill float equipment&20'+ new hole.\Pull into shoe&circulate bottoms-up for LOT/FIT. Lithology [Shows MAASP Pressure(psi) [Mud Weight(lb/gal) t 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL C 5 P Finished R/U lift cylinder for picking BOPE-Remove flow line,tum buckles,choke&kill lines.\Clean active&raw mud pits. 02:30 06:00 3.50 6.00 DRILL C 5 P Held PJSM-Pick BOP stack Vetco Gray Multi-bowl&install secondary restraint/Vetco Gray prep&installed 9 5/8"csg. emergency slips with 100K transfer-cut casing./L/D landing joint with 5.59'cut-off.\Pull wear bushing./Install 9 5/8"csg. pack-off.\Set BOP stack with Multi-bowl and test pack-off to 2500 psi.f/10 mins./Clean active&raw mud pits. 06:00 10.30 4.50 10.50 DRILL C 5 P Little Red freeze protected 9 5/8"x 13 3/8"annulus with diesel 143 bbls.pump rate of 2 bpm @ 1450 psi.-SICP 950 psi. completed 0800 hrs.\N/U BOP equipment-install choke&kill lines.flow line,fill-up&bleeder lines.tum buckets.and Katch-Kan.\Clean active&raw mud pits. 10:30 12:00 1.50 12.00 DRILL C 5 P Change out upper rams from 9 5/8'to 4 1/2"x 7"variables./Clean active pits. 12:00 12:30 0.50' 12.50 DRILL E 25 P Service rig-Crown,top drive,draw-works&blocks./Clean active pits. 12:30 22:00 9.50 22.00 DRILL E 4 P RIH'w/5"DP 1/7335'-L/D 85 joints with bad hard band-77 2/3 stands in hole./Finished cleaning active./Unload weighted 540 bbls.OBM into raw mud pits. 22:00 00:00 2.00 24.00 DRILL E 4 P POOH 1/7335'-1/5740'installing WEI CD sub as per well plan-SLM pipe in derrick with sub included. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Dulling Supt. Frank Cormier 'Eni Petroleum -Sr.Ddg.Spur. 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum Ddg.Spvr. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina@enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 0.0 10.440.0 5/22/2011 Last Leakoff Test Depth(ftKB) [TVD(f1KB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.360.0 2,192.05 LSND 9.20 370.0 12.45 1,417.6 Eni E&P Division Well Name:0P14-S3 EN!Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • Date:5/24/2011 - Report#: 21 APIIUWI:50-029-23447-00-00 2l " page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(14) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.991 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3.660.6 21,260.00 194.08 109.5 19.00 - Daily Information End Depth(ftKB) End Depth(TVD)(f..f Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) I POB Temperature(°F) Weather Wind 10,455.0 3,847.41 0.00 88.0 29.8 Clear 355°N @ 6.4 mph Daily summary operation 24h Summary POOH installing WEI CD sub(SLM 87 stands)./P/U 5"DP with new hard band to replace pipe L/D and to TD well.\POOH installing WEI CD sub-total 116 stds.5"DP\P/U 4 1/2"TT46 DP 61616'\ Circulate with 450 pgm @ 175 psi./POOH 4 1/2"TT46 DP rack back 17 stds.in derrick(SLM).\Pull wear bushing&install test plug&4 1/2"test joint- fill With H20./Test BOP to AOGCC requirements- witness waived by Chuck Scheve. Operation at 07.00 P/U BHA#6. 24h Forecast Complete BOP test with 4 1/2"&5"to AOGCC requirements.\P/U BHA#6 w/Schlumberger./RIH-P/U 4 1/2"singles to 10.326+/-\Circulate bottoms-up./Test 9 5/8"csg.to 3000 psi f/30 mins.(chart record)./Displace well to OBM.\Cut drilling line.)Drill float equipment&20'+new hole 10.475%1 Pull into shoe&circulate bosoms-up for LOT/FIT./Preform LOT/FIT as per well plan./Drill ahead to TD as per well. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:30 6.50 6.50 DRILL E 4 P POOH f/5740'-t/5517'with 5'DP installing WEI CD sub.\RIH 65805'P/U 9 joints./POOH(/5805'-6surface continue installing WEI CD sub as per well plan-SLM pipe in derrick with WEI sub. 06:30 10:30 4.00 10.50 DRILL E 4 P RIH P/U 5"DP 63445'(105 jts.). 10:30 14:00 3.50 14.00 DRILL E 4 P POOH with 5"DP installing WEI CD sub(115 valves)-Total 116 stds.5"drill pipe in derrick. 14:00 15:00 1.00 15.00 DRILL E 1 P Clear floor of sub racks&thread protector./Change handling equipment to 4 1/2"&R/U skate. 15:00 17:00 2.00 17.00 DRILL E 4 P P/U 4 1/2"DP 61616'-16.6#TT46(49 jts.)and two joints 16.6#NC46-Total 17 stds.in derrick and SLM.(TT46 31.6K torque&NC46 24.7K torque).)Called&left message @ 1655 hrs.informing AOGCC will be ready for BOP test @ 2100 hrs. 17.00 17:30 0.50 17.50'DRILL E 7 P Circulate through 4 1/2"DP pumping 450 gpm @ 175 psi.)Chuck Scheve returned call 1700 hrs and waived witness for BOP test. 17:30 18:30 1.00 18.50 DRILL E 4 P POOH 41/2"DP 16.6#TT46-f/1616'. 18:30 19:30 1.00 19.50 DRILL E 25 P Service Rig-change out saver sub&inspect&grease gripper. 19:30 21 00 1.50 21.00 DRILL E 5 P Pull wear bushing and install test plug&4 1/2"test joint.\Fill BOP stack&choke manifold with H2O and purge out air. 21:00 00:00 3.00 24.00 DRILL E 12 P Test BOP to AOGCC requirements on 4 1/2"tubular.\Annular w/4 1/2"@ 250 psi./2500 psi.\Pipe&blind rams,mud cross valves,choke manifold,floor and top drive valves:250 psi./3500 psi.\Hydraulic and Manual choke valves tested to 1500 psi./Chart record(5 minutes each)./BOP test witness was waived by AOGCC rep.Chuck Scheive @ 1700 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum Ddg.Spvr. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Dr-1g Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.360.01 2,192.05 LSND 9.20 370.0 12.45 1,417.6 f� Eni E&P Division I Well Name:OPt4-S3 EN!Petroleum Co.Inc. Daily Report Well Code:25485 Field Name: NIKAITCHUO • Date:5/25/2011 - Report#: 22 APIIUWI:50-029-23447-00-00 2 rr 'r II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° 'Operator ENI Share(%) I Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3.660.6 21,260.00 194.08 109.5 20.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10,455.0 3,847.4 0.00 88.0 28.9 Clear 355°N @ 3.5 mph Daily summary operation 24h Summary Complete BOP test with 4 1/2"&5"to AOGCC requirements.)P/U BHA#6 as per well plan.\RIH-P/U 4 1/2"singles 1/385'-1/9517/RIH w/4 1/2"DP from derrick 1/9517'-010,348'-tag w/8K.\Circulate bottoms-up-reciprocating&rotating./R/U to test 9 5/8"csg.and purge lines close rams. Operation at 07.00 Cut drilling-Clean shakers area and#7 active pit after displacement to FazePro OBM. 24h Forecast Test 9 5/8"csg.to 3000 psi f/30 mins.(chart record)&R/D)Displace well to FazePro 9.4 ppg OBM.\Cut drilling line./Drill float equipment&20'+new hole @ 10.475')Pull into shoe&circulate bottoms- up.)Perform LOT/FIT as per well plan./Drill ahead to TD @ 21,239'as per well. Lithology I Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 6 00:00 03:30 3.50 3.50 DRILL E 12 P Finished testing BOP to AOGCC requirements on 4 1/2"&5"tubular.\Pipe&blind rams,mud cross valves,choke manifold,floor 250 psi./3500 psi.)Koomey draw down test(Recovery times:01825-t/2025 psi.(200 psi.)in 41 seconds with final @ 3000 psi in 160 seconds-6 Nitrogen bottles @ 2650 psi average).Chart record(5 minutes each).\Test gas sensors./BOP test witness was waived by AOGCC rep.Chuck Scheve @ 1700 hrs on 5/24/2011.Valve#16 on choke j manifold F/P. 03.30 05:00 1.50 5.00 DRILL E 5 P R/D test equipment-pull test plug&install wear bushing(Vetco Gray)./Blow down choke manifold. 05.00 08.30 3.50 8.50 DRILL E 4 P Held PJSM-P/U BHA#6 per well plan&Schlumberger DD/MWD(Notified production&security-load radioactive sources)&3 joints 014 1/2"DP(16.6#NC46)1/385'. 08:30 12:00 3.50 12.00 DRILL E 4 P P/U 4 1/2"DP(16.600 NC46)f/385'-1/2065'.\Perform Schlumberger shallow hole test @ 1241'\NC46 24.7K torque./Drift 2 li 7/8"OD. 12:00 21:30 9.50 21.50 DRILL E 4 P Continue P/U 4 1/2"16.6#NC46 DP f/2065'-09517'/2 7/8"OD drift&fill pipe every 45 joints-break circulate. 21:30 22:30 1.00 22.50 DRILL E 4 P RIH 4 1/2"16.6#NC46 DP out of derrick 1/9517'-1/10,348'Tag w/8K.\Fill pipe and wash down f/10,278'. 22:30 23:30 1.00 23.50 DRILL E 7 P Circulate bottoms-up for 9 5/8"csg.test./Pump rate 500 gpm @ 2015 psi.-reciprocate&rotate string.40 rpm @ 11K torque.)Up wt.=165K-Dn wt.=60-Rot wt.=100K. 23:30 00:00 0.50 24.00 DRILL E 1 'P R/U to test 9 5/8"csg.-purge lines&close rams. • Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Dig.Spvr. 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum DrIg.Spur. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 ■ Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10.440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 virbil Eni E&P Division Well Name:OP14-Ss ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ e n i Date:5/26/2011 - Report#: 23 APIIUWI:50-029-23447-00-00 page 1 of 1 Wellbore name: OP14-S3 Well Header 211-052 Coneession N° I ENI PETROLEUM I ENI Share(%) 100.001 HORIZONTAL ation type Rotary Table Elevation(ft) !Ground Level(ft) 1 Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor !Rig Name (Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) OP14-S3 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 21.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..I Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) I POB Temperature(°F) !Weather 'Wind 11,329.0 3,862.7 874.00 5.90 148.1 91.0 28.6 Overcast,Fog 47°NE @ 3.1 mph Daily summary operation 24h Summary Test 9 5/8"csg.to 3000 psi f/30 mins.(chart record)&RID\Displace well to Faze Pro 9.4 ppg OBM.\Cut drilling line-Test WEI manifold-Calibrate blocks for SLB&CanRig.\Drill float equipment&20' new hole @ 10,475'1 Pull into shoe&circulate bottoms-up.\Perform FIT to 13.1 ppg\Drill rotary steerable(/10,475'-1111,164'1 Circulate bottoms-up 2X\POOH back reaming(/11,164'-1110,278'-RIH with remaining 4 1/2"DP from derrick 1111,164.\Drill rotary steerable(/11,164'-1111,329' Operation at 07.00 Drilling ahead rotary steerable @ 13,???'per well plan. 24h Forecast Drill ahead as per well plan to proposed TD @ 21,239' Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. J 00:00 01:30 1.50 1.50 DRILL E 12 P Test 9 5/8"csg.U3000 psi.for 30 mins.(chart record).\Pumped 9.9 bbls.&bleed back 9.4 bbls.\R/D&blow down kill& !/ cement fines. 01:30 03:00 1.50 3.00 DRILL E 7 P Displace well from LSND to FazePro 9.4 ppg OBM.\Pump 29 bbls.spacer pill and increased rate to 475 gpm @ 2576 psi.\ Reciprocate&rotate 60 rpm @ 6-8K torque.\Up wt=165K-Dn wt.=70K-Rot wt.=110K.\Record PWD baseline with K&M for model. 03:00 04:30 1.50 4.50 DRILL E 25 P Cut drilling line.\Clean under shakers and#7 active pit.\Service rig. 04:30 06:30 2.00 6.50 DRILL E 12 P Test WEI manifold system U4500 psi.(chart record).\Calibrate block height with Schlumberger&CanRig. 06:30 08:00 1.50 8.00 DRILL E 3 P Drill out float equipment&clean out to original TD,f/10,452'-V10,455'-Pump rate 510 gpm @ 2880 psi.\60 rpm @ 6-8 torque.\WOB=6-10K\Up W.=165K-Dn wt.=70K-Rot wt=110K\MW=9.4 ppg\ECD=10.6 ppg\ADT=1.25 hrs.\Jars =122.8 hrs. 08:00 08:30 0.50 8.50 DRILL E 3 P Drill rotary steerable 20'new hole f/10,455'-1/10,475'(3843'TVD)-Pump rate 510 gpm @ 2880 psi.\60 rpm @ 6-8 torque.\ WOB=6-11 K\Up wt.=165K-Dn wt=70K-Rot wt=108K\MW=9.4 ppg\ECD 10.81 ppg.\ADT=0.2 hrs.\Jam=123.0 hrs. 08:30 09:30 1.00 9.50 DRILL E 7 P POOH into shoe-Circulate bottoms-up-Reciprocate&rotate-Pump rate 525 gpm @ 3168 psi.\60 rpm @ 6.9K torque\ Rot wt.=110K. ' 09:30 10:30 1.00 10.50 DRILL E 19 P Perform FIT with 9.4 ppg FazePro OBM-surface pressure of 735 psi.-EMW=13.1 ppg. _ 10:30 12:00 1.50' 12.00 DRILL E 3 P Drill rotary steerable(/10,475'-U10,555'(3855'TVD)-Pump rate 520 gpm @ 3080 psi.\60 rpm @ 8-11 torque.\WOB=6- 11K\Up wt.=155K-Dn wt=68K-Rot wt.=105K\MW=9.4 ppg\ECD 10.88 ppg.\ADT=1.14 hrs.\Jars=124.14 hrs. 12:00 18:00 6.00 18.00 DRILL E 3 P 'Drill Rotary Steerable(/10,555'-1111,164'(3867'TVD).\Pump rate 550 gpm @ 3480 psi.\120 rpm @ 9-11K torque.\WOB= 10-15K.\Up wt=165K-Dn wt.=54K-Rot wt.=102K.19.4 ppg mud wt.\ECD 11.17 ppg.\ADT=3.84 hrs.\Jars=127.98 hrs.\Connection with WEI-CD subs. 18:00 19:30 1.50 19.50 DRILL E 7 P Circulate 2X bottoms-up pump rate 550 gpm @ 3480 psi.-Reciprocate&rotate 60 rpm @ 8K torque\Rot wt.=102K. 19:30 21:00 1.50 21.00 DRILL E 4 P POOH back reaming with 5"DP f/11,164'-1110,278'pumping 550 gpm @ 3400 psi.\120rpm @ 9K torque.\Rot wt.=102K.\ To put remaining 9 stands of 4 1/2"DP(NC46 16.60)in hole 21:00 22:30 1.50 22.50 DRILL E 4 P Change elevators to 4 1/2"DP\RIH f/10,278'-1111,160'-Rotated&washed f/10,440'-1110,460'(No Dn weight)-Pull back 1110,430'and slack off wlo rotary-no problem.\Up wt.=160K-On wt.=55K. 22:30 00:00 1.50 24.00 DRILL E 3 P Drill Rotary Steerable 511,164'-V11,329'(3862'TVD).\Pump rate 550 gpm @ 3480 psi.\120 rpm @ 9-11K torque.\WOB= 10-15K.\Up wt=162K-Dn wt.=50K-Rot wt=99K.19.4 ppg mud wt.\ECD 11.20 ppg.\ADT=0.72 hrs.\Jars=128.7 hrs.\ Connection with WEI-CD subs. Total ADT=5.90 hrs. Total Jar=128.7 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Drlg.Spvr. 907-685-1227 337-277-1809 Drilling Supt. David Smith Eni Petroleum Drlg.Spvr. 907-685-1277 907-632-3058 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-685-1286 907-229-6100 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 1 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(f1KB) Run Date CASING 95/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) I TVD(ftKB) I Fluid Type 'Fluid Density(Iblgal) IP Surf Applied(psi) IEq.Mud Weight(lblgal) 'Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 I VW* Eni E&P Division I Well Name:OP14-Ss ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name: NIKAITCHUO • APIIUWI:50-029-23447-00-00 2^ Date:5/27/2011 - Report#: 24 II II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° 'Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(ND..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239,01 3.660.6 21,260.00 194.08 109.5 22.00 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 13.592.0 3,849.3 2.263.00 12.86 176.0 91.0 34.0 Clear,WC 26.8° 1'N @ 8.7 mph Daily summary operation 24h Summary Drill rotary steerable 1/11,164'-013.592'as per well plan.\Back ream 30'before connection 8 use WEI-CD subs./Record rotate weight dry every 3rd stand. Operation at 07.00 Drilling ahead rotary steerable @ 14,000'per well plan. 24h Forecast Drill ahead as per well plan to proposed TD @ 21,239' Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 1 9.40 Time Log Start End Cum • Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 12:00 12.00I. 12.00 DRILL E 3 P Drill Rotary Steerable f/11,329'-8/12,215'(3828'ND).\Pump rate 550 gpm @ 3420 psi.\120 rpm @ 8-10K torque.\WOB= 10K.\Up wt.=160K-Rot wt.=100K-No Dn wl.\9.4 ppg mud wt.\ECD 11.31 ppg.\ADT=5.62 hrs.\Jars=135.69 hrs.\ Back ream 30'before connection F.use WEI-CD subs./Record rotate weight every 3rd.stand. 12:00 18:00 6.00- 18.00 DRILL E 3 P Drill Rotary Steerable(/12,215'-1/13,001'(3823'ND).\Pump rate 550 gpm @ 3480 psi.\120 rpm @ 9.9-11.7K torque.\ WOB=15K.\Up wt=160K-Rot wl.=104K-No Dn wt.\9.4 ppg mud wt.\ECD 11.40 ppg.\ADT=4.59 hrs.\Jars=140.28 hrs.\Back ream 30'before connection&use WEI-CD subs.\Record rotate weight every 3rd.stand. 18:00 00:00 6.00,r 24.00'DRILL E 3 P Drill Rotary Steerable f/13,001'-t/13,592'(3849'ND).\Pump rate 550 gpm @ 3550 psi.\120 rpm @ 9.3-11.9K torque.\ WOB=15-20K.\Up WA=170K-Rot wt.=108K-No Dn wt.\9.4 ppg mud wt.\ECD 11.40 ppg.\ADT=2.62 hrs.\Jars= 141.76 hrs.\Back ream 30'before connection 8 use WEI-CD subs./Record rotate weight every 3rd.stand. Total ADT=18.76 hrs. Total Jar=141.76 hrs. - Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum DrIg.Spar. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Dolling Supt. Angelo Lamanna Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Dulling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8- 8.835 L80 0.0y 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) lTVD(ftKB) Fluid Type 'Fluid Density(Iblgal) !P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 1119* Eni E&P Division .,} 'Well Name:OP14-S� EN!Petroleum Co.Inc. Daily Report 'well Code:25485 Field Name:NIKAITCHUO • Date:5/2812011 - Report#: 25 APIIUWI:50-029-23447-00-00 en page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date !Target Depth(ftKB) !Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.01 3,660.6 21,260.00 194.08 109.5 23.00 Daily Information End Depth(ftKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) I POB Temperature(°F) Weather Wind 16,000.0 3,812.8 2,408.00 13.261 181.6 89.0 33.6 Clear,WC 28.2° 36'N @ 5.9 mph Daily summary operation 24h Summary Drill rotary steerable t/13,592'-1/16,000'as per well plan&production zone geology./Back ream 30'before connection&use WEI-CD subs./Record every 3rd stand-Rotate weights without pump 120- 124K for this depth intervals.\Load pipe shed with 4 1/2"production tbg.(strap&drift). Operation at 07.00 Drilling ahead rotary steerable @ 16,350'per well plan. 24h Forecast Drill ahead as per well plan to proposed TD @ 21,239'\Continue loading pipe shed with 4 1/2"production tbg.and 5 1/2"liner-prep to run. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 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 Rotary Steerable 1/13,592'-1/14,208'(3827'TVD).\Pump rate 550 gpm @ 3682 psi./120 rpm @ 10-12K torque./ WOB=7-10K.\Up wt.=180K-Rot wt.=110K-No Dn wt.\9.4 ppg mud wt.\ECD 11.72 ppg.\ADT=3.69 hrs.\Jars=145.45 hrs.\Back ream 30'before connection&use WEI-CD subs./Rotate weight without pumps 120K-(every 3rd stand). 06:00 12:00 6.00 12.00 DRILL E 3 P Drill Rotary Steerable 1/14,208'-1/14,754'(3803'TVD).\Pump rate 550 gpm @ 3710 psi./120 rpm @ 8-12K torque./WOB= 8-12K.\Up wt.=180K-Rot wt.=110K-No Dn wt.\9.4 ppg mud wt./ECD 11.75 ppg./ADT=3.68 hrs./Jars=149.13 hrs.\ Back ream 30'before connection&use WEI-CD subs./Rotate weight without pumps 124K. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable f/14,754'-(/15,363'(3801'TVD).\Pump rate 554 gpm @ 3820 psi./120 rpm @ 9.8-13.4K torque./ WOB=8-14K./Up wt.=172K-Rot wt.=108K-No Dn w1.19.4 ppg mud wt./ECD 11.89 ppg./ADT=2.87 hrs.\Jars=152.0 hrs.\Back ream 30'before connection&use WEI-CD subs.)Record rotate weight without pump 122K. 18:00 00:00 6.00 24.00 DRILL E 3 P D6l1 Rotary Steerable 1/15,363'-0/16,000'(3812'TVD)./Pump rate 554 gpm @ 3840 psi./120 rpm @ 10.4-13.8K torque./ WOB=8-20K./Up wt.=172K-Rot wt.=110K-No Dn wt./9.4 ppg mud wt.\ECD 11.61 ppg./ADT=3.02 hrs.\Jars=155.02 hrs.\Back ream 30'before connection&use WEI-CD subs.\Record rotate weight without pump 120K. Total ADT=32.02 hrs. Total Jar=155.02 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spur. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Dulling Supt. David Smith Eni Petroleum Ddg.Spur. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Em Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamanna @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher .1 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 Eni E&P Division Well Name:OPl4 ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • 2 ft*^ Date:5/29/2011 - Report#: 26 APUUwI:50-029-23447-00-00 II II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(it) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 24.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ftlhr) IPOB Temperature(°F) Weather 'Wind 18,117.0 3,727.2 2.117.00 13.55 156.2 90.0 29.5 Clear,WC 25.5' 273°W @ 3.7 mph Daily summary operation 24h Summary Drill rotary steerable f116,000'-518,117'as per well plan&production zone geology./Back ream 30'before connection&use WEI-CD subs./Record every 3rd stand-Rotate weights without pump 120- 122K for this depth intervals.)Load pipe shed with 5 1/2"production liner(strap&drift). Operation at 07.00 Drilling ahead rotary steerable @ 18,601'per well plan. 24h Forecast Drill ahead as per well plan to proposed TD @ 21.239'/Loading pipe shed with 5 1/2"liner-strap&drift. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 06:00 6.00 6.00 DRILL E 3 P Drill Rotary Steerable(/16,000'-1/16,544'(3805'TVD)./Pump rate 550 gpm @ 3920 psi.\120 rpm @ 11-13.6K torque.\ WOB=9-18K./Up we.=177K-Rot wt.=112K-No Dn wt.\9.4 ppg mud wt.\ECD 11.82 ppg.\ADT=3.49 hrs.\Jars=158.51 hrs.\Back ream 30'before connection&use WEI-CD subs.\Rotate weight without pumps 120K-(every 3rd stand). 06:00 12:00 6.00 12.00 DRILL E 3 P Drill Rotary Steerable f116,544'-1/16,937'(3774'TVD).\Pump rate 550 gpm @ 3980 psi./120 rpm @ 11-14.7K torque.\ WOB=8-16K./Up w1.=175K-Rot w1=110K-No Dn w1.\9.4 ppg mud wt./ECD 11.95 ppg\ADT=3.57 hrs.\Jars=162.08 hrs.\Back ream 30'before connection&use WEI-CD subs./Rotate weight without pumps 120K. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable 1/16,937'-517,430'(3765'TVD).\Pump rate 550 gpm @ 3995 psi.\120 rpm @ 11.3-15.2K torque./ WOB=12-20K.\Up wt.=188K-Rot wt.=110K-No Dn wt.\9.4 ppg mud wt.\ECD 11.98 ppg.\ADT=3.50 hrs.\Jars= 165.58 hrs.\Back ream 30'before connection&use WEI-CD subs./Record rotate weight without pump 120K. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill Rotary Steerable(/17,430'-1/18,117'(3728'TVD).\Pump rate 550 gpm @ 4100 psi./120 rpm @ 11.8-15.8K torque- Reduce to 60-80 rpm on hard spots.\WOB=14-20K./Up wt.=188K-Rot wt=110K-No Dn wt.\9.4 ppg mud wt.\ECD 12.0 ppg.\ADT=2.99 hrs.\Jars=168.57 hrs.\Back ream 30'before connection&use WEI-CD subs./Record rotate weight without pump 122K. Total ADT=45.57 hrs. Total Jar=168.57 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ng.Spvr. 'Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum DrIg.Spvr. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Dolling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 Vitit Eni E&P Division (Well Name:OP14-So 1 EN!Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ e Date:5/3012011 - Report#: 27 APIIUWI:50-029-23447-00-00 page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° [Operator I ENI Share(%) 100.00[Well ZONTALation type 211-052 ENI PETROLEUM Rotary Table Elevation(ft) !Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA NABORS 245 E [LAND RIG Job Information Wellbore I Job Phase 'Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...I Depth Dr.(MD)(ft) I Drilling Hours(hr) !Avg ROP(ftlhr) I DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 25.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(fthr) POB Temperature(°F) Weather Wind 20,084.0 3,669.2 1,967.00 14.74 133.4 89.0 31.5 Partly Cloudy,WC 46°NE @ 3.9 mph 27.3° Daily summary operation 24h Summary Drill rotary steerable(/18,117'-1/20,084'as per well plan.\Back ream 30'before connection&use WEI-CD subs.\Dry rotate weights 119-122K&13.7-20K torque.\Load pipe shed with 5 1/2"production finer(strap&drift). Operation at 07.00 Drilling ahead rotary steerable @ 20,312'. 24h Forecast Drill ahead as per well plan to proposed TD\Finish prep work on 5 1/2"liner. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.40 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 Rotary Steerable f118,117'-1/18,704'(3700'TVD).\Pump rate 550 gpm @ 4130 psi.\120 rpm @ 11-19K torque.\ WOB=7-17K.\Up wt.=179K-Rot wt.=110K-No Dn wt.\9.4 ppg mud wt.\ECD 12.0 ppg.\ADT=3.93 hrs.\Jars=172.5 hrs.\Back ream 30'before connection&use WEI-CD subs,\Every 3rd stand record rotate weight without pumps 122K @ 14K torque.\Slight fluid lose @ 0230 hrs.18,455'until 0600 hrs.with 25 bbls. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill Rotary Steerable f/18,704'-1/18,961'(3720'TVD).\Pump rate 550 gpm @ 4120 psi./120 rpm @ 17-18K torque.\ WOB=8-18K.\Up wt.=182K-Rot wt.=108K-No Dn wt.\9.4 ppg mud wt.\ECD 11.85 ppg.\ADT=3.99 hrs.\Jars=176.49 hrs.\Back ream 30'before connection&use WEI-CD subs.\Rotate weight without pumps 122K @ 20K torque.\Continue slight loses while drilling with average 3.5 bbls/hr. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable t/18,961-1/19,400'(3696'TVD).\Pump rate 550 gpm @ 4150 psi.\120 rpm @ 13.7-16.5K torque- Reduce to 60 rpm on hard spots.\WOB=8-12K.\Up wt.=190K-Rot wt.=108K-No Dn wt.\9.4 ppg mud wt.\ECD 11.85 ppg.\ADT=4.14 hrs.\Jars=180.63 hrs.\Back ream 30'before connection&use WEI-CD subs.\Rotate weight without pump 119K @ 13.7K torque.\3.5 bbls/hr average lose rate. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill Rotary Steerable 1/19,400'-1120,084'(3671'TVD).■Pump rate 550 gpm @ 4190 psi.\120 rpm @ 15.1-17.7K torque- 4 Reduce to 60 rpm on hard spots.\WOB=8-12K.\Up wt.=190K-Rot wt.=108K-No Dn wt.\9.4 ppg mud wt.\ECD 11.98 ppg.\ADT=2.68 hrs.\Jars=183.31 hrs.\Back ream 30'before connection&use WEI-CD subs./Rotate weight without pump 120K @ 17.7K torque.\3.5 bbls/hr average lose rate-Total lose of 86 bbls. Total ADT=60.31 hrs. Total Jar=183.31 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. 'Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum DrIg.Spvr. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907.685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) I WD(ftKB) 'Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 iiii* Eni E&P Division I Well Name:0P14-Ss ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUO • Date:5/31/2011 - Report#: 28 APIANN:50-029-23447-00-00 en page 1 of 1 Wellbore name: OP14-S3 Well Header 211-052 Permit/Concession N° 'ENI PETROLEUM 'ENI Share(%) 100.001 HOIRIZONTAL Configuration type Rotary Table Elevation(ft) 'Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) IRKS-Tubing Spool(ft) 53.23 12.201 0.00 15.99 21.59 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..1 Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) 'DFS(days) OP14-S3 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 26.00 Daily Information End Depth(ftKB) End Depth(ND)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) PO8 Temperature(°F) Weather Wind 21,340.0 3,671.8 1,256.00 10.25 122.5 92.0 28.8 Partly Cloudy,WC 34°NE @ 13.5 mph 18.1° Daily summary operation 24h Summary Drill rotary steerable 1/20,084'-1/20,575'.1 Trouble shoot Schlumberger MWD tool-would not stay in sync.\Drill rotary steerable 1/20,575'-521,340'@TD.\Circulate bottoms-up with 533 gpm @ 4130 psi.\ 140 rpm @ 19K torque. Operation at 07.00 Circulating bottoms-up while reciprocating&rotating pipe-rack back one stand every CBU-bit @ 21,067'. 24h Forecast Circulated bottoms-up(K&M model requires 12x)-reciprocate&rotate string,rack back one stand every CBU.\POOH back reaming to 9 5/8"csg shoe @ 10,440'\Circulate bottoms-up 5-7x+or until clean.\POOH with BHA#6 and LID. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 08:00 8.00 8.00 DRILL E 3 P Drill Rotary Steerable f/20,084'-1/20,575'(3688'ND).\Pump rate 547 gpm @ 4168 psi.\120 rpm @ 15.1-17.7K torque.\ WOB=8-12K.\Up wt.=210K-Rot wt.=110K-No Dn wt.\9.4 ppg mud wt.\ECD 12.08 ppg.\ADT=3.29 hrs.\Jars=186.6 hrs.\Back ream 30'before connection&use WEI-CD subs.\Rotate weight without pump 122K @ 17K torque. 08:00 10:00 2.00 10.00 DRILL E 7 XDO1 Schlumberger could not receive good signal from MWD tool-keep going out of sync-trouble shoot-Schlumberger checked equipment,change pump rate,switch pumps combination,dean suction screen,by pass WEI CD manifold.Finally tool went to sync and received good signal for data. 10:00 12:00 2.00 12.00 DRILL E 3 P Drill Rotary Steerable 1/20,575'-1/20,756'(3682'ND).\Pump rate 544 gpm @ 4180 psi.\120 rpm @ 15.6-17.3K torque.\ WOB=8-12K.\Up wt.=200K-Rot wt=110K-No Dn wt.\9.4 ppg mud wt.\ECD 12.08 ppg.\ADT=1.26 hrs.\Jars=187.86 V hrs.\Back ream 30'before connection&use WEI-CD subs.\Rotate weight without pump 122K @ 16K torque. 12:00 18:00 6.00 18.00 DRILL E 3 P Drill Rotary Steerable 1/20,756'-1121,161'(3669'ND).\Pump rate 540 gpm @ 4100 psi.\120 rpm @ 14.8-21K torque- Reduce to 60 rpm on hard spots.\WOB=8-12K.\Up wt=193K-Rot wt=110K-No Dn wt.\9.4 ppg mud wt.\ECD 11.91 ppg.\ADT=3.51 hrs.\Jars=191.37 hrs.\Back ream 30'before connection&use WEI-CD subs.\Rotate weight without pump 120K @ 18K torque. 18:00 23:00 5.00 23.00 DRILL E 3 P Drill Rotary Steerable f/21,161'•0/21,340'(3672'ND).\Pump rate 526 gpm @ 4150 psi.\120 rpm @ 8-20K torque.\WOB= 8-12K.\Up wt.=195K-Rot wt=110K-No Dn wt.\9.4 ppg mud wt.\ECD 11.98 ppg.\ADT=2.19 hrs.\Jars=193.56 hrs.\ Back ream 30'before connection&use WEI-CD subs.\Rotate weight without pump 120K @ 16.5K torque. Total ADT=70.56 hrs. Total Jar=193.56 hrs. 23:00 00:00 1.00 24.00 DRILL E 7 P Circulate bottoms-up,reciprocating&rotating pipe-pump rate 533 gpm @ 4130 psi.\140 rpm @ 19K torque.\Rot wt= 106K.K&M model require 12x CBU. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.DrIg.Spvr. Jack.Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum Drlg.Spvr. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Tool Push Wayne Stout Nabors Alaska Drilling Tour Pusher 907-670-8539 Last Casing seat Cas.Type OD(In) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) 'ND(ftKB) 'Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 Eni E&P Division Vtdh1 Name:0P14-uv fil* ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name: NIKAITCHUO • APIIUWI:50-029-23447-00-00 2^ Date:611/2011 - Report#: 29 If II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 _ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DES(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3.660.6 21,260.00 194.08 109.5 27.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,340.0 3,671.8 0.00 92.0 25.2 Partly Cloudy.WC 37°NNE @ 18.4 11.3` mph Daily summary operation 24h Summary Circulate bottoms-up(12X)with 551 gpm @ 4150 psi,/140 rpm @ 16.8K torque./Rack back a stand each CBU 8/21,340'-8/20.182'1 POOH back reaming 8/20,182'-8/19,001'.-speed&rates dictated by hole condition. Operation at 07.00 POOH-Back reaming @ 17,916'. 24h Forecast POOH back reaming to 9 5/8"csg shoe @ 10,440'1 Circulate bosoms-up 5-7xu or until clean./POOH with BHA#6 and L/D.\R/U&run 5 1/2"liner on 4 1/2"drill pipe as per well plan. Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 1 9.40 Time Log - _ Start End Cum Time _ Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00-.00 12:00 12.00 12.00 DRILL E -7 P Circulate bottoms-up 8X./Reciprocating&rotating pipe-pump rate 537 gpm @ 4160 psi./140 rpm @ 17.3K torque./Rot wt.=105K.\ECD 11.92 ppg.\ Rack back one stand every bottoms-up t/21,340'-1/20,595'.\Using WEI CD sub for connection. 12.00 '18:00 6.00 18.00 DRILL •E '7 P Circulate bottoms-up 4X./Reciprocating&rotating pipe-pump rate 540 gpm @ 4150 psi.\140 rpm @ 16.8K torque./Rot wt.=105K.1 ECD 11.8 ppg\Rack back one stand every bottoms-up(/20,595'-8120,182'\Using WEI CD sub for connection. 18.00 00:00 6.00' 24.00 DRILL •E .4 P POOH Back reaming(/20,182'-8/19,001'\Pump rate 551 gpm @ 4100 psi.\140 rpm @ 16.2K torque.\Rot w1=110K.\ECD 11.54 ppg.\Used WEI-CD subs for continuous circulation\Total fluid lose= 91 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 .907-715-6434 Drilling Supt. David Smith Eni Petroleum Ddg.Spur. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2.613.4 Eni E&P Division Well Name:OP14 EN/Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUO • API/UWI:50-029-23447-00-00 2�,01' Date:6/2/2011 - Report#: 30 If II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator IENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-S3 DRILLING 5'6/2011 21,239.0 3.660.6 21,260.00 194.08 109.5 28.00 Daily Information End Depth(ftKB) End Depth(TVD)(I..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,340.0 3,671.8 0.00 92.0 25.5 Clear,WC 10.4` 57"ENE @ 23.8 mph Daily summary operation 24h Summary POOH back reaming f/19,001'-1118,890'.1 Service Rig.1 Continue POOH back reaming 1/18,890.-1/11,329'-speed&rates dictated by hole condition Operation at 07.00 POOH-Back reaming @ 11,036'.1 Prep to change saver sub on top drive from 4 1/2"IF to NC 46. 24h Forecast POOH back reaming to 4 1/2"DP change saver subs to NC 46.1 Continue POOH back reaming to 9 5/8"csg shoe @ 10,440'\Circulate bottoms-up 5-7x+or until clean.\POOH with BHA#6 and L/D.\R/U &run 5 1/2"liner. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL 'E 4 P •POOH Back reaming f/19,001'-1/18,890'\Pump rate 551 gpm @ 4100 psi.\140 rpm @ 16.7K torque.\Rot wt.=110K.\ECD 11.54 ppg.\Used WEI-CD subs. 00:30 01:00 0.50 1.00 DRILL E 25 P Service rig-TD&draw-works. 01.00 12:00 11.00 12.00 DRILL E 4 P POOH Back reaming 1/18,890'-1/14,871'\Pump rate 550 gpm @ 3540 psi.\140 rpm @ 12.7K torque./Rot wt.=108K./ECD 11.04 ppg.\Used WEI-CD subs. • 12:00 00:00 12.00 24.00 DRILL E 4 P 'POOH Back reaming(/14,871'-1111,329'\Reamed section(/13,790'-8/13,600 several times due to hole condition.\ Pump I rate 576 gpm @ 3300 psi.\140 rpm @ 9.3K torque./Rot wt.=102K.\ECD 10.73 ppg.\Used WEI-CD subs./Total fluid lose =62 bbls. Daily Contacts ✓ Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spot. 'Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. David Smith Eni Petroleum Ddg.Spvr. 907-685-1277 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spur. angelo.lamadna @enipetroleum.com 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 • 01111* Eni E&P Division (Well Name:OP74-d. ENI Petroleum Co.Inc. Daily Report` Well Code:25485 Field Name: NIKAITCHUO • API/t1Wl:50-029-23447-00-00 2 Date:6/3/2011 - Report#: 31 page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD..JDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-S3 DRILLING 5,/6/2011 21,239.0 3,660.6 21,260.00 194.08 109.5 29.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POE Temperature(°F) Weather Wind 21,340.0 3671.8 0.00 91.0 28.9 Clear,WC 17.4" 63°ENE @ 16.2 mph Daily summary operation 24h Summary POOH back reaming 1/11,329'-510,907'-Circulate B/U and C/O Saver Sub to NC46-Continue POOH back reaming 510,907'-U 10,372'speed&rates dictated by hole condition.-CBU x 7-POOH on elevator f/10,372'to 2,382'. Operation at 07.00 L/D BHA#6. 24h Forecast POOH BHA#6 and L/D.R/U GBR&run 0 5 1/2"170 L-80 Hydrill 521liner. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 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 E 4 P POOH Back reaming 1/11,329'-510,907'\Reamed several times due to hole condition./ Pump rate 550 gpm @ 3000 psi./ 140 rpm @ 8.5K torque.\Rot wt.=105K./ECD 10.73 ppg. 03:30 05:00 1.50 5.00 DRILL E 7 P Circulate 1.5x B/U.Pump rate 550 gpm @ 2900 psi.\140 rpm @ 8.5K torque./Rot wt.=105K. 05:00 05:30 0.50 5.50 DRILL E 5 P Change Out Saver Sub from 4 1/2 IF to NC46. 05:30 08:30 3.00 8.50 DRILL E 4 P POOH Back reaming 1/10,907'-1/10,372'.Pump rate 550 gpm @ 2850 psi.\140 rpm @ 7.7K torque.\Rot wt.=100K. 08:30 13:30 5.00 13.50 DRILL E 7 P Circulate 7x bottoms-up reciprocating&rotating pipe with pump rate 550 gpm @ 2700 psi.\140 rpm @ 7.4K torque.\Rot wt.=100K.\Mud wt=9.4 ppg./ECD 10.39. 13.30 00:00 10.50 24.00 DRILL E 4 P Pump slug&drop 2 3/8"rabbit.Continue POOH on elevators f/10,372'1/2,382'as per K&M indications.Total fluid lose= 40 bbls. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum 'Sr.Ddg.Spur. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goerlich Eni Petroleum DrIg Spvr. 907-685-1277 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Em representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina@enipetroleum.com 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2.613.4 Eni E&P Division I Well Name:0P14-Su rifRill ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUO • 2^ Date:6/4/2011 - Report#: 32 API/UWI:50-029-23447-00-00• II 'I page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° (Operator ENI Share)%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD.../Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP14-S3 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 30.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) !Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 21,340.0 3,671.8_ 0.001 93.0 31.5 Clear.WC 22.1° 81'E @ 11.3 mph Daily summary operation 24h Summary POOH and L/D BHA#6-RIH 5"DP and L/D 43x WEI-CD subs-Held PJSM and RIH with 5 1/2"17#L-80 Hydril 521 slotted liner. Operation at 07.00 RIH with 5 1/2"17#Hydril 521 slotted liner at 4,740'. 24h Forecast RIH 0 5 1/2"17#L-80 Hydrill 521 slotted liner-Set ZXP packer/hanger and test.POOH and L/D drill pipe. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.40 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 Continue POOH on elevators f/2,382'U 1,890'as per K&M indications:No swab,proper Hole fill. 01:00 03:30 2.50 3.50 DRILL E 4 P Confine POOH laying down 0 4 1/2"DP f/1,890'U 290'(top BHA#6).C/O elevator&slip to 5"handling equipment. 03:30 06:30 3.00 6.50 DRILL E 5 P Held PJSM with Schlumberger DD/MWD[(radio active source)contact security and production].Pooh and L/D BHA#6.Bit Dull.1-1-WT-A-X-I-CT-TD. 06:30 0730 1.00 7.50 DRILL E 1 P Clear rig floor of BHA handling equipment.P/U thread protectors and WEI-CD baskets. 07:30 11:30 4.00 11.50 DRILL E 5 P RIH with 4,100'of 5"DP removing x43 WEI-CD subs.Clear rig floor of sub baskets. 11:30 13:30 2.00 13.50 DRILL E 25 P Cut and slip drilling line. 13:30 1430 1.00 14.50 DRILL E 25 P Service Top Drive:grease TD,change oil,fitter on lube. 14:30 17:30 3.00 17.50 DRILL E 4 P POOH 5"DP 1/4,100'V surface. 17:30 20:00 2.50 20.00 DRILL G 1 P Held PJSM.P/U GBR tongs and equipment to floor.R/U GBR equipment and torque tum for 5 1/2"liner. 20.00 00:00 4.00 24.00 DRILL G 4 P P/U 5 1/2"17#L-80 Hydrill 521 slotted liner.M/U shoe and RIH/12,553'.M/U torque turns average 6500 ft/lbs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.DrIg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goedich Eni Petroleum Ddg Spvr. 907-685-1277 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(RKB) I TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9,40 735.0 13.08 2.613,4 Eni E&P Division [Well Name:OP14-S 1191* EN!Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • Date:6/5/2011 - Report#: 33 APIIUWI:50-029-23447-00-00 er'ii page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-S3 DRILLING 5/6/2011 21,239.0 3660.6 21.260.00 194.08 109.5 31.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,340.0 3671.8 0.00 90.0 28.6 Cloudy,WC 19° 71°ENE @ 10.8 mph Daily summary operation 24h Summary RIH 5-1/2"17#L-80 Hydrill 521 down to 18.374'. Operation at 07.00 RIH w/5 1/2"17#L-80 Hydril 521 liner @ 20,940'. 24h Forecast RIH 0 5 1/2"17#L-80 Hydrill 521 slotted liner-Set ZXP packer/hanger and test.POOH and LID drill pipe. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.50 Time Log Start End Cum Time Time Dur(hr) Our(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 13.30 13.50 13.50 DRILL G 4 P Continue P/U 8 RIH 5 1/2"170 L-80 Hydrill 521 slotted liner f/2,553't/11,093'.M/U torque turns average 6200 ft/lbs.Up wt. =115K-Dwn wt.=75K.No tight spot/drag. Total:258 joints slotted liner 5-1/2"+13x blank 5-1/2"+9x Oil swell packers. 13:30 14:30 1.00 14.50 DRILL G 5 P Change out elevators.P/U ZXP liner hanger/packer and M/U-mix fill tie-back sleeve with pal-mix.wait 30 minutes to set up.M/U first stand 4-1/2"DP,RIH-break circulate 8 pump 5 bbls to ensure free flow paths:Ok. 14:30 21.30 7.00 21.50 DRILL G 4 P RIH 5-1/2"liner on 4-1/2"drill pipe f/11,093'1117,225'.Fill up pipe and record data every 10 stds.Rot Wt.=112K @ 43 rpm and TQ=9.1K. 2130 22:00 0.50 22.00 DRILL G 5 P Change out saver sub and elevators to 5". 22:00 00:00 2.00 24.00 DRILL G 4 P Continue RIH 5-1/2"liner on 5"drill pipe f/17,225'1118,374'.Fill up pipe and record data every 10 stds.Rot Wt.=113K @ 45 rpm and TO.=9K. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. i Jack Keener Eni Petroleum 'Sr.Ddg.Spvr. 'Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goedich Eni Petroleum Ddg Spvr. 907-685-1277 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative 'Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tour Pusher 907-670-8539 Dulling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamadna @enipetroleum.com 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L80 0.0 10,440.0 5/22/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 10440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 11191* Eni E&P Division . [Well Name:0P14-S ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name: NIKAITCHUO • APIIUWI:50-029-23447-00-00 2^ Date:6/6/2011 - Report#: 34 II II page 1 of 1 Wellbore name: OP14-S3 Well Header PermitlConcession N° !Operator ENI Share(%) Well Configuration type 211-052 IENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD..f Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP14-53 DRILLING 5/6/2011 21,239.0 3,660.61 21,260.00 194.08 109.5 32.00 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21.340.0 3,671.8 0.00 88.0 29.5 Cloudy,Lt Snow,WC 82`E @ 19.8 mph 16.2` Daily summary operation 24h Summary RIH 0 5 1/2"179 L-80 Hydrill 521slotted liner-Set ZXP packer/hanger and pressure test to 1500 psi-TOL @ 10,203'-shoe @ 21,325'.Displace well with KCI brine-POOH and L/D drill pipe. Operation at 07.00 L/D Drill Pipe&WEI-CD subs. 24h Forecast L/D Drill Pipe-L/D WEI-CD subs-Prepare for completion. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.40 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 G 4 P Continue RIH 5-1/2"liner on 5"drill pipe f/18,374't/21,325'.Fill up pipe and record data every 10 stds.Rot Wt.=113K @ 45 rpm and TQ.=94-10K.No tight spots consistant. 0900 05:30 1.50 5.50 DRILL G 19 P Held PJSM.Drop 1.6"ball&pump down with 4 bpm @ 400 psi-slowed to 2 bpm @ 200 psi 85 bbls before landing.-ball landed on 111 strokes.Set ZXP packer/hanger pressurizing up to 2300 psi as per Baker Rep.-increase pressure and neutrilize tool w/3200 psi and 4000 psi.Bleed-off pressure and slack-off 80K lbs.Ok. TOL @ 10.203'-Shoe @ 21325'. 05:30 06:00 0.50 6.00 DRILL G 12 P Pressure Test backside to Baker ZXP packer top to 1500 psi per 10'(charted):Ok. 06:00 06:30 0.50 6.50 DRILL G 19 P Pulled up to 225K:tool not released.Slacked off to 70K,pulled up to 235K,slacked off to 70K,pressured up to 3500 psi, pulled off @ 125K and bleed off pressure.P/U 6'slacked off dog sub and sheared @ 60K,repeat with rotation.Rack back stand. 06:30 09.30 3.00 9.50 DRILL E 9 P Pump 120 bbls cleaning pill and 50 bbls of Hi-Vis spacer pill and displace well to 9.0 ppg KCI/NaCI Brine f/10,100'to surface-450 gpm @ 1300 psi reciprocating stand. 09:30 11'00 1.50 11.00 DRILL E 1 P Cleaning pits,possum belly&under shaker system of OBM/Brine thick fluid.Prepare rig floor for L/D pipes. 11:00 17.00 6.00 17.00 DRILL E 4 P POOH&UD 126 jts x 5"drill pipe to 6087'.Cull and flag bad hardband joints.At 12:00 hrs service pipe skate and at 9599' circulate DP volume to balance mud. 17:00 23:00 6.00 23.00 DRILL E 4 P Continue POOH&L/D 192 jts x 4-1/2"drill pipe f/6087 t/surface. 23:00 23.30 0.50 23,50 DRILL E 5 P Service Baker liner setting tool and L/D same. 23:30 00.00 0.50 24.00 DRILL E 1 P Prepare rig floor to RIH DP for L/D same. Daily Contacts - Position Contact Name Company Title E-mail Office Mobile • Drilling Supt. Jack Keener Eni Petroleum Sr.Dug.Spur. Jack:Keener@enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goerlich Eni Petroleum Ddg Spur. 907-685-1277 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Dulling Tour Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 51/2 4.842 L-80 10,203.0 21,325.0 6/6/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 Eni E&P Division .} I Well Name:OP14-So PIA EN!Petroleum Co.Inc. Daily Report Well Code:25485 Field Name: NIKAITCHUO • APIIUWI:50-029-23447-00-00 2�, Date:6/7/2011 - Report#: 35 I( I' page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) (Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P14-53 DRILLING 5/6/2011 21,239.0_ 3.660.6 21,260.00 194.08 109.5 33.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,340.0 3,671.8 0.00 88.0 26.8 Cloudy,WC 10.9' 63°ENE @ 28.4 mph Daily summary operation 24h Summary RIH wl4 1/2"DP and POOH L/D\RIH w/5"DP and POOH L/D DP and WEI-CD subs\Circulated DP clean\L/D 5"DP from 7,039'to 256'1 No losses. Operation at 07.00 Testing BOPE. 24h Forecast Test BOPE 1 Prep for OP14-S3 well completion. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.05 Time Log Start End Cum Time Time Dur(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 02:30 2.50 2.50 DRILL E 4 P TIN w/32 stds 4 1/2"DP and mule shoe/proper displacement/circ pipe volume to clean inside of DP of OBM. 02.30 06:00 3.50 6.00 DRILL E 4 P L/D 96 jts of 4 1/2"DP\B/O mule shoe. 06:00 07:00 1.00 7.00 DRILL E 4 P Stage WEI sub baskets and thread protectors to drill floor. MU mule shoe. 07:00 12:00 5.00 12.00 DRILL E 4 P RIH to 5,269'w455 stds 5"DP from derrick\remove WEI-CD subs f/top of every std per WEI reps. 12:00 14:00 2.00 14.00 DRILL E 4 P TIH f/5,260'to 7,089'\Up Wt 140K Dn Wt 85K\remove WEI-CD subs as per WEI reps. 14'00 15:00 1.00 15.00 DRILL E 7 P Circulate and condition to flush DP\returns of contaminated OBM\circulated 4200 stks until returns cleared up\ciro @ 60 SPM 217 GPM 140 PSI. 1500 19:00 4.00 19.00 DRILL E 4 P L/D DP 8 7,089'to 3,671'\Up Wt 100K\no losses. 19:00 20:30 1.50 20.50 DRILL E 25 U Service rig\repair iron roughneck,stiff arm for spinners broke\broke hydraulic fitting no spill. 20:30 00:00 3.50 24.00 DRILL E 4 P L/D DP 83.671'to 256'\Up Wt 50k1 no losses. Daily Contacts Position Contact Name Company _ Title _ E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Dig.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goerlich Eni Petroleum DrIg Spur. 907-685-1277 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 / Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 V/ Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Dolling Tour Pusher 907-670-8539 Drilling Supt. Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamarina @enipetroleum.com 907-685-1277 907-903-7269 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 51/2 4.842 L-80 10,203.0 21,325,0 6/6/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.401 735.0 13.08 2,613.4 Eni E&P Division I Well Name:0P14-S EN!Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUQ • APIIUWI:50-029-23447-00-00 2 VIA^ Date:6/8/2011 - Report#: 1 II II page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° Operator I ENI Share)%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) OP14-S3 COMPLETION 34.00 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,340.0 0.0 85.0 27.7 Cloudy.WC 13.8' 69°ENE @ 21.1 mph Daily summary operation 24h Summary Complete L/D 5"DPs-Test BOPE-R/U Baker Centrilift and GBR equipment-P/U ESP pump components and set with Halliburton slick line Operation at 07.00 RIH ESP completion on 4 1/2"12.6#L-80 IBTM tubing. 24h Forecast RIH ESP Completion on 4 1/2"tbg-M/U Tubing Hanger and land in seat-Test hanger body seals-Install BPV Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.05 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 Complete L/D 5"drill pipe. 00:30 01:00 0.50 1.00 DRILL E 5 P Pull wear bushing per Vetco Gray rep. 01:00 02:00 1.00 2.00 DRILL K 5 P Clear drill floor of tools,wear ring,4 1/2"handling equipment,and XOs. 02:00 03:00 1.00 3.00 COMP K 12 P P/U 4 1/2"test joint assembly/Install test plug as per Vetco Gray rep/Fluid pack choke manifold and BOP stack vnth water/RU test equipment. 03:00 08:00 5.00 8.00 COMP K 12 P Test BOPE 250 low 3,500 high on annular.5 min chart recorded/Build up on Koomey 1,850 psi reecovered in 43 secs on air 1,950/Total 148 seconds to 3,000 psi./Average on bottles 2,700 psi. 08:00 '10:00 2.00 10.00 COMP K 5 P Pull test plug/L/D test joint/Blow down choke manifold line/Clean drill floor of testing equipment/wash drill floor. 10:00 12:00 2.00 12.00 COMP K 1 P R/U tools for TTC-ESP completion/PU Baker control line sheaves/GBR tongs/Spot Howco unit. 12:00 15:00 3.00 15.00 COMP K 1 P Bring ESP equipment to rig floor/RU Baker Centrilift equipment. 15:00 16.00 1.00 16.00 COMP K 1 P P/U 8 M/U TTC XOver/Drilled Tubing intake+x1 Jnt tubing 0 4%"12.6#L-80 IBTM+DGU 16:00 17:00 1.00 17.00 COMP K 1 P Held PJSM.R/U Halliburton slick line sheaves and M/U tools 1700 1900 2.00 19.00 COMP K 5 P Wireline operations: Run#1:M/U ESP Pump Assembly and set into TTC-XO housing.POOH running tool. Run#2:M/U Tubing Packoff Assembly and set into the top end of the pump assembly.POOH running tool. Run#3:M/U Pressure Test Tool and set into top of tubing packoff. Pressure Test Pump Ass.1000 psi 15 min OK Run#4:RIH pulling tool and pulled out Pressure Test tool. Run#5:M/U Tubing stop and set into receptacle in top of packoff assembly. 19.00 19:30 0.50 19.50 COMP K 2 P R/D Wireline equipment. 19:30 00:00 4.50 24.00 COMP K 5 P P/U and service Motor Assembly and sensor,Upper and Lower Seal Assembly.Check rotation,fill with oil&M/U per Centrilift reps. Terminate motor lead,0 Y.."TEC line.0 Z"cap tube line and MLE cable preparation. Install 0%"cap tube to check valve @ centralizer and TEC line to WellLift gauge.RIH installing Christolizer and Cannon clamps.Attached MLE to motor pothead temrinal and test.RIH to discharge pressure sub installing clamps.Conned 0'''A" TEC lines to same.Pull ESP Cable over sheave Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goerlich Eni Petroleum DrIg Spvr. 907-685-1277 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Dolling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci En:Petroleum Ddg Spvr. 907-685-1277 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 51/2 4.842 L-80 10.203.0 21,325.0 6/6/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 Eni E&P Division Well Name:OP14-S fil* ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUO • APIIUWI:50-029-23447-00-00 enDate:619/2011 - Report#: 2 If '� page 1 of 1 -Wellbore name: 0P14-S3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.23 12.20 0 00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(11KB) Target Depth(TVD..,Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP14-S3 COMPLETION 35.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,340.0 0.0 83.0 28.2 Cloudy,WC 15.1" 63°ENE @ 22.6 mph Daily summary operation 24h Summary RIH completion on 0 4 1/:"tbg/Install and test Tbg Hanger/Pull landing joint/Install BPV/Prepare to L/D BOPE. Operation at 07.00 Nippling down BOP stack. 24h Forecast N/D BOP stack/N/U Tubing adapter and X-Tree/Pull BPV and install test plug/Test tree to 5000 psi for 10 min/Freeze Protect well/Set BPV/Prepare to move rig to OP09-S1 well. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 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 COMP K 1 P Perform high wire splice and motor lead splice/hang control line sheave and string control line. 0300 04:30 1.50 4.50 COMP K 4 P RIH w/4 1/2"12.66 L-80 IBTM tubing f/143'to 505'w/1,800 M/U torque as per well program w/TTC-ESP completion and control lines/Install Cannon clamps over collars every connection 04:30 05:30 1.00 5.50 COMP K 25 U Eni spooling unit kinked the ESP armor/Replace ESP armor section as per Centrilift 05:30 17:30 12.00 17.50 COMP K 4 P RIH w/4 1/2"12.69 L-80 IBTM tubing w/TTC-ESP completion and control fines f/505'to 7774'/Proper displacement/Test ESP cable every 1,000'as per Centrilift rep. 1730 19:00 1.50 19.00 COMP K 5 P R/U GBR compensator and run w/VIT(2 joints).P/U 8 M/U Tbg Hanger with pups and landing joint-align hanger/penetrator to well head-space out cables and cut lines. 19:00 21:30 2.50 21.50 COMP K 5 P Vetco Gray dressed hanger with 0 7."Cap line-Centrlift splice penetrator pigtail to ESP cable with PDF black gator splice @ rig floor and installed in hanger.Performed electrical test and check readings on WellLift gauge OK 21:30 22:30 1.00 22.50 COMP C 5 P RIH and land tbg hanger-@ 7896'Up wt=98 k/Dwwl=75 k-screw-in lock down-test seals to 5000 psi x 10 min:Ok. POOH and L/D Landing joint.Install BPV (Used 166 cannon clamps/3 Cristolizer Clamps/1 Gator Splice/14 Equipment Clamps. 22:30 00:00 1.50 24.00 COMP C 5 P Blw Own mud lines and choke lines/ND kill and choke lines/Remove turnbuckles/Clean Ketch Kan. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum 'Sr.Ddg.Spvr. Jack.Keener @enipetroleum.com 907-685-1277 907-715-6434 Drilling Supt. Gary Goedich Eni Petroleum DrIg Spvr. 907-685-1277 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Drilling Supt. Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1277 Last Casing seat - Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 51/2 4.842 L-80 10,203.0 21,325.0 6/6/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 7350 13.08 2,613.4 Eni E&P Division 'Well Name:0P14-S OP*. ENI Petroleum Co.Inc. Daily Report Well Code:25485 Field Name:NIKAITCHUO • API/UWI:50-029-23447-00-00 2^ Date:6/10/2011 - Report#: 3 I1 ') page 1 of 1 Wellbore name: OP14-S3 Well Header Permit/Concession N° I Operator ENI Share(%) Well Configuration type 211-052 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.23 12.20 0.00 15.99 21.59 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) OP14-S3 COMPLETION 36.00 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 21,340.0 0.0 79.0 28.8 Cloudy,WC 17.8` 58°NE @ 15.2 mph Daily summary operation 24h Summary N/D BOPE-N/U X-Tree and 5000 psi P.T.-Freeze protect IA f/surface 5/2200'w/Diesel-Prepare to move rig. Operation at 07.00 Moving ng to OP09-S1 well. 24h Forecast Move rig to OP09-S1 well. Lithology (Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.00 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 5 P N/D BOP stack-Remove Katch-can,fill-up lines,flow line.bell nipple.riser and set stack on stump-Pull&L/D mouse hole 04:30 06:30 2.00 6.50 COMP K 5 P P/U and N/U X-Tree and valves with Vetco Gray Reps-Install TWC test plug 06:30 07:30 1.00 7.50 COMP K 5 P R/D&L/D ESP control lines&equipment from derrick. 07:30 10:30 3.00' 10.50 COMP K 12 P Centrilift perform final electrical continuity check-Test X-Tree to 5000 psi x 10 min:Ok(charted)-Pull TWC test plug. 10:30 12:00 1.50 12.00 COMP K 1 P R/U valves&lines f/tree 5/choke manifold-R/U LRS to freeze protect well-Held PJSM-Fill lines and pressure test freeze protect lines to 1500 psi. 12:00 14:30 2.50 14.50 COMP K 9 P Pump 120 bbl freeze protect(Diesel 7.08 ppg)through IA retum from Tbg(0=1 bbl/min,P=0->600 psi,1:1 returns)-8/0 and R/D lines 14:30 00:00 9.50 24.00 COMP B 1 P Clean rig pits-Raise cellar box-Blow down lines on rig floor-Unplug interconnect-Remove cuttings tank-Raise Lampson curtains-Lay mats-Rig release @ 00.00 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. -Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1277 337-277-1809 Drilling Supt. Gary Goerlich Eni Petroleum Drlg Spvr. 907-685-1277 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-685-1286 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1227 Eni representative Dan Lee Eni Petroleum Materals Coordinator 907-685-1226 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-8539 Dnlling Supt. Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1277 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 51/2 4.842 L-80 10,203.0 21,325.0 6/6/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 10,440.0 3,846.72 FazePro 9.40 735.0 13.08 2,613.4 oF 1. SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Nelson Carballo Oliktok Pt. Drilling and Completion Superintendent ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP14-S3 ENI US Operating Co. Inc. Permit No: 211-052 Surface Location: 3168' FSL, 1633' FEL, SEC. 05, T13N, R9E, UM Bottomhole Location: 931' FSL, 1234' FEL, SEC. 24, T14N, R8E, UM Dear Mr. Carballo: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. dilly 0 el orma Comm ssioner I DATED this /2- ay of April, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED; STATE OF ALASKA i.:\pp 0 'd ?MM ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Masks &£os Cons.Commission 20 MC 25.005 / 61.6•�� A ulus 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil el • Service- Winj ❑ Single Zone li 1 c.Specify if well is proposed for: Drill 0 • Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 • OP14-S3 . 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 21240 • TVD: 3660 • � Ni itchuq '414 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): d,./ raudeir- Surface: 3168 FSL,1633 FEL,S5 T13N R9E UM • ADL 355024 373301,39061e,391283• Jai a j/ / Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: tl 214 FSL,2592 FEL,S29 T14N R9E UM ADL 417493 4/21/2011 Total Depth: 9.Acres in Property: A, 14.Distance to Nearest Property: 931 FSL,1234 FEL,S24 T14N R8E UM .1219' 37go 9•/a 5492'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 52.2 15.Distance to Nearest Well Open Surface:x- 516647 • y- 6036521 • Zone- 4 GL Elevation above MSL: . 12.2 to Same Pool: 1030'SW to OP08-04 16.Deviated wells: Kickoff depth: 400 feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 96.77 degrees Downhole: 1711 psig • Surface: 1296 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 1305 TOTAL sx 16" 13-3/8" 68 L-80 BTC 2281 35 35 2321 • 2172 • LEAD:1036 sx 10.7 ppg ASL TAIL:269 sx 12.5 ppg DeepCrete 12.25" 9-5/8" 40 L-80 Hydril 563 10299 33 33 10339 • 3839 • 1106 TOTAL sx 1106 sx 12.5 ppg DeepCrete 8-3/4" 5.5" 17 L-80 Hydril 521 11101 10139 3603 21240 • 3660 ' Slottled 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 0 BOP Sketch El Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program IS 20 AAC 25.050 requirements S 21. Verbal Approval: Commission Representative: Date 4/7/2011 22. I hereby certify that the foregoing is true and correct. Contact Joseph Longo @ 907-865-3323 Printed Name Nelson Carballo / V Title Oliktok Point Drilling and Completion Superintendent %�Signature Phone (907)865-3325 Date 4/7/2011 Commission Use Only Permit to Drill /I A5� API Number: [�[-� �^ Permit Ap rov I See cover letter for other Number: t 50-OZ?-2.-3 T T/'w' ate: 1.4 ‘9\‘‘ requirements. Conditions of approval: Q If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 21 Other: 4 36.00 lOSo BoP 1,51-, Samples req'd: Yes❑ No[• Mud log req'd: Yes ❑ No l 'i .. Z.s" o p, . "kik u..L..t. is 4 17t.LI.)�H2S measures: Yes❑ No Rf Directional svy req'd: Yes Q No ❑ - D i r 1,/,...4...0._...0 Z° 44L Z S: d 3 3•.(4)I ) - SV,5- place-bt- j- c4-ii,�u�P , za z s : Co) �J �/ / APPROVED BY THE COMMISSION DATE: 4 4/Z .� ,COMMISSIONER 7 . L Hz • `/ �, �,G.: '� yam , Form 10-401(Revised 7/2009) This permit is valid for 24 m p (20 AAC 25.005(g)) ubmit in D plic to SZ • Eni Petirolleurn _ern ECE,Vt D. APR 0 2 ?al, 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi s 685 COn$,c0 • Phone(907)865-3320 htnenorag6 Email: Maurizio.Grandi @enipetroleum.com April 6,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer OP14-S3 Dear Commissioners, • Em US Operating Co. Inc.hereby applies for a Permit to Drill for the onshore production well OP14-S3. This well will be drilled and completed using Nabors rig 245E. The planned spud date could be as early as i2... j %ae4% ✓ 4/21/2011. The intent of this ap plication is to re.lace the onshore Iroduction well OP09-S03 APD# �. W I� 211041,API#50-029-23446-00-00 approved on March 21,2011. Although the intent of this application for permit to drill is to replace OP09-S03 the primary change is only to the surface location resulting in minor depth changes to the original well path. Eni US Operating Co. Inc.acknowledges the AOGCC's efforts and will strive to provide adequate time for future applications. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Joseph Longo at 907-865-3323. Sincerely, Nelso Car al o Oliktok Point Drilling and Completion Superintendent ins • lrole Application for Permit to Drill 0P14-S3 Saved:7-Apr-11 Application for Permit to Drill Document Producer Well OP14-S3 Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(0 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(LSND) 6 Lateral Mud Program(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 Requirements of 20 AAC25.005(c)(10) 7 AOGCC PERMIT Document.doc Page 1 of 9 Printed:7-Apr-11 =�°' Eni eum n Application for Permit to Drill OP14-S3 Saved:7-Apr-11 11. Seabed Condition Analysis 7 Requirements of 20 MC 25.005(c)(11) 7 12. Evidence of Bonding 7 Requirements of 20 AAC 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 8 Requirements of 20 MC 25.005(c)(14) 8 15.Attachments 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 AOGCC PERMIT Document.doc Page 2 of 9 Printed:7-Apr-11 , , tooh. Eni Petroleum :elm Application for Permit to Drill OP14-S3 Saved:7-Apr-11 1. Well Name Requirements of 20 AAC 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: OP14-S3 / 2. Location Summary Requirements of 20 AAC 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 in 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 3168 FSL, 1633 FEL, S5 T13N R9E UM , ASP Zone 4 NAD 27 Coordinates RKB Elevation 52.2'AMSL Northing 6,036,520.67' Easting: 516,64747' Pad Elevation 12.2'AMSL • Location at Top of Productive Interval 214 FSL, 2592 FEL, S29 T14N R9E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 10339' Northing: 6,044,123.15' Easting:515,648.42' Total Vertical Depth, RKB:, 3839' Total Vertical Depth, SS: 3787' Location at Total Depth 931 FSL, 1234 FEL, S24 T14N R8E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 21240' • Northing:6,050,105.30' Easting: 506,598.70' Total Vertical Depth, RKB: 3660' Total Vertical Depth, SS: 3608' Please see Attachment 7:Surface Platt and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(6) 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 1: Directional Plan and AOGCC PERMIT Document.doc Page 3 of 9 Printed:7-Apr-11 Pt Eng -- - tr I u ,.:_ent Application for Permit to Drill 0P14-S3 Saved:7-Apr-11 (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. 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(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC 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 pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP = (3,772'lVDss)(0.45 -0.11 psi/ft) = 1296 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 AAC 25.030(1) Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4 of 9 Printed:7-Apr-11 ph Eni -- -- ° ro eum ,,eni Application for Permit to Drill OP14-S3 Saved:7-Apr-11 6. Casing and Cementing Program Requirements of 20 AAC 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 MC 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/Tl/D MD/TVD OD(in) (in) (Ib/R) Grade Connection (ft) (ft) (ft) Cement Program 20 Driven 178.89 X-65 Welded 120 36/ 36 1607 160' Pre-Installed 1305 TOTAL sx 13-3/8 16 68 L-80 BTC 2281' 35/ 35 2321'/ 2172' LEAD: 1036 sx 10.7 ppg ASL TAIL:269 sx 12.5 ppg DeepCrete 1106 TOTAL sx 9-5/8 12-1/4 40 L-80 Hydril 563 10299' 33/ 33 10339'/ 3839' 1106 sx 12.5 ppg DeepCrete TOC: 678 MD/3434'ND 8-3/4"OA 5-1/2 Sand 17 L-80 Hydril 521 11101' 10139'/ 3603' 212407 3660' Slotted Liner-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 3: BOP Configuration. / ENI requests that AOGCC waive diverter requirements per 20 AAC 25.035. (h). (2). ✓ AOGCC PERMIT Document.doc Page 5 of 9 Printed:7-Apr-11 lik, , - Eni -- 1- troleum pitu Application for Permit to Drill 0P14-S3 Saved:7-Apr-11 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 10 MC 15.033; 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 ofPennafrost 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 (CP) 12 18 HTHP Fluid loss Yield Point 18-24 (ml/30 min Cad <5.0 (lb/100 s19 200psi&100°F API Filtrate 4 - 6 Oil/Water 60/40 (cc/30 min)) Ratio Chlorides(mg/1) <500 Electrical >600 pH 9.0- 10.0 Stability MBT <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: AOGCC PERMIT Document.doc Page 6 of 9 Printed:7-Apr-11 Eni Application for Permit to Drill OP14-S3 Saved:7-Apr-11 (9)for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(!) Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 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 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 2.5.005(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 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 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 AAC 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: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in/ rig up Nabors 245E. • 2. Spud and directionally drill 16"hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 3. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 4. Install and test wellhead to 5000 PSI. 5. Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 6. Pressure test casing to 2500 psi per AOGCC regulations. Record results. 7. PU 12-1/4"bit and directional drilling assembly with MWD, LVVD and PWD. 8. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording ' results. 9. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface - casing shoe. 10. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. AOGCC PERMIT Document.doc Page 7 of 9 Printed:7-Apr-11 1Plik jeni Eni rle Application for Permit to Drill OP14-S3 Saved:7-Apr-11 11. RU casing drive system. 12. Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 13. Install 9-5/8"Emergency Slips. 14. Install 9-5/8"packoff and test to 5000 psi. 15. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 16. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 17. 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. 18. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. 19. Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 20. PU and run 5-1/2"slotted liner to TD. 21. Land liner, set liner hanger with 200'Liner lap inside the 9-5/8"intermediate casing. POOH laying down DP as required. 22. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 23. Nipple down BOP, nipple up tree and test. Pull BPV. • ENI requests that the AOGCC waive surface safety valve requirements per 20 AAC 25.265. (c). — (1) v� • 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. 24. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 25. Move rig off. 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 Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. AOGCC PERMIT Document.doc Page 8 of 9 Printed:7-Apr-11 • Enli - troleu _ent Application for Permit to Drill OP14-S3 Saved:7-Apr-11 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface P/aft AOGCC PERMIT Document.doc Page 9 of 9 Printed:7-Apr-11 v _ p p 1pp o C F 4.ti�VOp(1�Np 2ari.ga00 MvpNr t,“4m<Opi ar ON)W N .00ntmO Ir000pnb 42 ,1; W L i i N i 10 E s s b s 22'222 �O�O 10 f0�O �O 10 10 2 ro Z-6437,,7;3 t0 f0(D f0 10 �O�O�O N m ClM NNNN 000 O qq q 00 ..... M 10 q 10 10 F 10 i 0 Y)10 ..... Y)U 10 10 N ..... U g U h F .... 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'•,.; 11. 2 .4- i i i i 4 i i ii iiiiii - ;:t• t ,4 0 o o 0 a t ; 0 0 0 0 -. .:' 0 0 0 (N 10 iri 0 o (0 en (4)000 I.:0-10 I..=eleoS CIAl (4)00Z 1.:(u0L.=eleoS CIAl limiks en Schlumberger WELL I FIELD 1 STRUCTURE OP14-S3 (P5b) Nikaitchuq Oliktok Point a Magnatk Parameters Surface Location NRD27 Alaska State Plane Zone 04,US Feet I Miscellaneous Modal. BGGM 2010 DIP. 61.007' Date May 17,2011 Lat. N 703039.488 N mhing 6036520 67 SUS Grid Cony 0.12842137' Slot OP14 WORM Rotary Table(52.211 above MSL) Ma9 Doc. 21.113' FS'. 57839.7nT Lon W 149 51 49.585 E stn9 516647 47 SUS Sale Fact 0.99990031 Plan. OP14-S3(P5b) Soy Date:March 31.2011 -10000 -8000 -6000 -4000 -2000 0 OP14-S3(P5b) 14000 TD 14000 End Cry S3 Tgt 20 End Cr, Cry 2/100 Cry S3 Tgt 121 S3 fan Cry j/100 dry 2/100 End Cry End Cry S3 Tgt 16 33 Tgt 19 Cry 2/100 End dry Cry 2/100 s3 Tgt u 12000 gnu.Otx/. Crv�)160 12000 S3 Tgt 17 : Cry - End Cry C d Cry S3 Tgt 12 $3 Tgt 16 Cry 2/100 Cry 2/180 End Cry 53 Tgt 13 End Cry Cry 2/100 S3 Tgt 10 End Cry Cry 2/100 533gt11 nd Cry Ctv 2/100 - :S3 Tgt 8 10000 Fod.C.n.... -.._ cry 2/100 10000 S3 Tgt 9 End Cry• S3 Tgt6 Cry 2/100 Cry 2/100 • End try End Cry S3Tgt4 S3 Tgt 7 Cr/2/100 A Cry 2/100 Cry 83 d Cry Tgt 2 A Erd C S8 Tgt 6 Cm 2/100 Z C v 2/100 End Cry End Cry E. 8000 68.904• .cre.2.6/30 u 8000 Cry 2.6/100 po N End Cry End Cry O S3Tgt 1 N Cry 2.5/100 C 9-5/8" 53 Heel II 2 N 6000 crnssnoo 6000 U) V FLT PO43 V V FLT 01-04 DTNE 4000 4000 2000 2000 End Cry RTE 13-3/8" 0 Cry 3,5/100 0 Bld 0.6/100 Bld 2.76/100 KOP Bld 1.5/100 -10000 -8000 -6000 -4000 -2000 0 c<< W Scale=1(in):2000(ft) E >>> Schiumberger OP14-S3 (P5b) Anti-Collision Summary Report Analysis Date-24hr Time: March 31,2011-09:07 Analysis Method: Normal Plane Client: ENI Reference Trajectory: OP14-S3(P5b)(Def Plan) Field: Nikaitchuq Depth Interval: Every 5.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: D&M Anti Collision Standard Slot: OP14 Min Pts: All local minima indicated. Well: OP14-S3 Borehole: OP14-S3 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 41010.5 ft Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole LOffset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 0113-03(P4)(Def Plan) Warning Alert 7 99 6.77 4.67 N/A 0.00 0.00 Surface 7.99 5.40 4.67 4.95 245.00 245.00 OSF<5 00 Enter Alert I 7.991 4.96 405 3.74 300.00 300.00 MinPt-CtCt 8.81 4.02 2.24 2.13 409.92 409.92 MinPt-O-EOU 9.29 414 2.17 2.05 424.89 424.89 MinPt-O-ADP 9.70 4.32 2.2 2.041 434.87 434.87 MinP1-OSF 70.37 55.26 48.32 4.98 879.86 876.71 OSF>5.00 Exit Alert 1117.00 1079.60 1061.4 30.65 3967.88 3037.34 MinPt-O-SF 4865.93 4723.5'7'11 4652.8 34.41 9023.31 3738.34 MinPt-O-SF 4510.61 4450. 38 21 9591.10 3792.20 MinPt-0-ADP 4631.721 4510.4 4450.26 3849 9610.33 3793.65 MinPt-0-EOU L4630.e 4511.50 4452.40 39.17 9654.34 3796.86 MinPt-CtCt 4426.21 4281.00 4208.8. 30.68 11673.66 3882.03 MinPt-0-SF 4424.59 4279.14 4206.9.ICI 11683.51 3882.38 MinPt-O-SF MIME 3731.89 3623.03 18.14 13963.86 3836.05 MinPt-CtCt 3910.044 3653.55 3525.8• 16113.94 3809.69 MinPt-0-SF r 3886.7 3623.98 3493.10 14.84 16680.65 3809.97 MinPt-CtCt 11-�3885.1 3600.91 3459.26 13.71 17709.67 3822.72 MinPt-CtCt 3887.1 3597. 3453 68 13.48 18148.88 3805.48 MinPt-O-EOU 3890.05 3598. 3453.281 13.39 18296.49 3793.22 MinPt-0-ADP 4132.97 3793.94 3624.92 12.22 21239.92 3660.30 TD Ol15-S4(P4)(Def Plan) r.:. ,- _ Wemkp AWt. 8.04 6.82 472 N/A 0.00 0.00 Surface 8.04 5.45 4.72 4.96 245.00 245.00 OSF<5.00 Enter Alert I 8,041 4.82 3.82 3.41 325.00 325.00 MinPt-ClCt 8.12 4.67j 3.55 3.10 365.00 365.00 MinPt-O-EOU 8.16 4.68 3.55 3.07 375.00 375.00 MinPt-O-ADP 8.21 4.71 3.56 3.061 385.00 385.00 MinPt-O-SF 13.41 7.24 4.73 2.45 635.81 835.34 MinPt-0-ADP 14.86 7.88 5.00 2.371 675.82 675.35 MinPt-O-SF 17.73 548 5.97 2.35 746.27 745.22 MinPt-O-SF 79.50 62.60 54.77 4.99 1559.98 1510.42 OSF;5.00 Exit Alen 436.95 409.61 396.4.IC, 3481.11 2906.31 MinPt-O-SF 450.68 422.50 408.91 Immo 3515.32 2919.47 MinPt-O-SF 676.03 631.82 610..-ills 4053.63 3049.40 MinPt-O-SF 2686.61 2525.42 2445. 8697.14 3699.31 MinPt-O-SF 2678.67 2518.8•.MEZE 16.86 8853.78 3718.66 MinPt-O-ADP 2678.4•WanEl1 243949 16.88 8869.55 3720.55 MinPt-O-EOU I - , 2519.13 2440.11 16.94 8909.00 3725.22 MinPt-CtCt 1971.78 1820.20 1744.90 r5y 11300.73 3868.66 MinPt-0SF MUE11 890.64 784.00 5.18 13720.23 3825.86 MinPt-CtCt 1108.47. ,h� 777.01 5.03 13847.35 3831.80 MinPt-0-EOU 1110.34 887.40 776.42 5.00 13878.32 3832.77 OSF<5.00 Enter Alert 1112.30 887.9,'® 4.98 13901.64 3833.76 MinPt-0-ADP 1169.57 927.37 806.76 mum 14510.62 3850.05 MinPt-O-SF 1198.62 950.81 827 39 MEM 14763.92 3852.93 MinPt-0-SF 1225.78 973.47 847.80® 15149.63 3836.81 MinPt-O-SF 1271.87 1012.03 882.60® 15749.52 3823.29 MinPt-O-SF 1278.0•NE= 888.67■ 16106.29 3810.09 MinPts 1247.63 979.7; 846.35 :111 16801.70 3811.94 MinPts 1213.40 937.82 600.52® 17314.74 3818.87 MinPt-O-SF 863.43 699.71 3 64 19440.40 3751.46 MinPt-CtCt I MILIE Mign 11.:=I®I 21239.92 3660.30 MinPts 0P16.03 working(Non-Def Survey) ` '' '818„.�"4-s.iN. ., )*"" ,' Warning Alan E® N/A 0.00 0.00 MinPts 12.27 1116 6.50 394.11 394.11 MinPt-CtCt =MI Man 10.65 5.81 479.25 479.25 MinPts 15.58 11.88® 5.80 484.26 484.25 MinPt-O-ADP 15.69 11.92 M1112, 5.68 519.34 519.32 MinPt-0-ADP 16.91 12.47 10.86 4.88 809.53 609.35 OSF<5.00 Enter Alert 17.18 12. 10.8 4.67 619.54 61033 MinPt-O-ADP 51.92 29.70 19.21 2.421 997.81 991.36 MinPt-OSF 122.60 96.95 84.74 4.97 135018 1322.00 05F;5.00 Exit Alert 10177.13 10107.29 10072.87 147 801 4992.41 3181.46 MinPt-O-SF 11712.52 11634.63 11596.1 152.291 5309.47 3226.07 MinPt-OSF 9531.60 9382.51 9308. 64.351 9062.31 3742.67 MinPt-OSF 8444.38 8311.78 8245.9 64.14 9558.46 3789.69 MinPt-0-5F Wan 8036.26 7922.65 36.37 14173.25 3843.26 MinPt-CtCt 8265.31 MMIE 7921.05 36.11 14238.16 3845.49 MinPt-O-EOU Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP14-S3\0P14-S3\0P14-S3(P5b) 3/31/2011 9:09 AM Page 1 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Statue Ct-Ct(ft)I EOU(ft) Dev.(ft)...� Fact. MD(ft) I TVD(ft) Alert I Minor I Major 8266.08 8035.62 7920.8 36.02 14263.11 3846.35 MinPt-O-ADP 8333.855 8076.80 7948.77 32.54 16180.68 3806.82 MinPt-O-ADP 8333.8 8076.8 7948.78 32.55 16186.54 3806.63 MinPt-O-EOU I8333.81 8076.81 7948.81 32.55 16192.40 3806.44 MinPl-CtCt 8327 66 8063.07 793126 31 59 16738.04 3810.90 MinPt-CtCI 8360.78 8103.84 7975.86 MEM 15778.35 3823.03 MinPt-O-SF 8332.75 8078.1 A.MIMEC 32.85 15984.41 3816.58 MinPt-O-ADP 8333.'e MU= 7950.10 32.69 18048.62 3813.17 MinPt-O-EOU 8334.43 8077.76 794 99 32.59 16078.56 3811.57 MinPt-O-ADP 8328.25 8062.16 7929.61' 31.41 16802.64 3811.95 MinPt-O-ADP 8328.0 N 7929.63 31.43 16807.89 3812.03 MinPt-O-EOU 8062.27 7929.96 31.47 16821.05 3812.24 MinPt-CtCt IIMMIII 8059.70 7926.49 31.25 16972.82 3814.31 MinPt-CtCt 8327.71 wan. 7924.97 31.09 17027.81 3815.04 MinPt-O-EOU 8328.34 8059.0. .. 31.03 17047.80 3815.31 MinPt-O-ADP 8757.74 8413.98 8242.59 25.55 19973.25 3740.58 TD 8377.6 MIMI 8011.82 ME=. 14771.79 3853.02 MinPts OP12.01(Def Survey) 1 31.971 30.751 28.65 120867.85 2.62 2.62 MinPts 31.55 28.17 27.09 14.05 317.52 317.52 MinPt-CtCI 32.06 27.15 25.31 8.36 427.34 427.34 MinPt-O-EOU 32.28 27. 25.271 8.04 442.31 442.31 MinPt-O-ADP 40.54 31.37 27.40 4.95 672.09 671.64 OSF<5.00 Enter Alert 42.99 32.1 27. 4.36 722.08 721.26 MinPt-O-ADP 62.85 36.64 24.15 2.47 996.96 990.54 MinPt-O-ADP 75.23 42.43 26.64 2.34 1101.74 109094 Min Pt-O-SF 178.75 141.96 124.17 4.99 1705.96 1640.44 OSF>5.00 Exit Alert =gm 207.21 194.35 9.06 3598.89 2949.18 MinPt-CtCt 236.8'MIME 188.04 7.40 3669.34 2971.49 MinPt-O-EOU 239.65 204.5 187.49 7.00 3694.97 2978.97 MinPt-O-ADP 267.58 223.79 202.39 96 3812.44 3008.91 MinPt-O-SF 4095.77 3951.12 3879.29® 9029.57 3739.04 MinPt-O-SF 3977.30 3843.49MM 29.94 9428.60 3778.92 MinPt-O-ADP 3976 71 3777.21 30.04 9442.61 3780.14 MinPt-O-EOU 3843.87 3778.19 30.26 9470.63 3782.54 MinPt-CtCt M r�.00 2819_6[=ME IMIKE 15435.73 3825.50 MinPts 0119-08(P6)(Def Plan) , _ Warning Alert 48.04 46.81 44.71 N/A 0.00 0.00 Surface I 48.04 4422 42.93 18.07 400.00 400.00 MinPt-CtCt 48.11 4408 42.68 16.73 445.26 445.26 MinPt-O-EOU 48.17 4409 42.67 16.48 460.35 460.34 MinPt-O-ADP 50.40 45.7 44. 14.31 606.67 606.50 MinPt-O-ADP 54.91 48.03 45.2 9.48 712.72 711.98 MinPt-O-ADP 75.65 59.50 52.03 4.99 965.02 959.65 OSF<5.00 Enter Alert 79.66 62.10 53.94 MIMIC 1000.32 993.78 MinPt-O-SF 94.02 74.14 64.81 4.97 1111.21 1099.94 OSF>5.00 Exit Alert 10367.09 10247.20 1018775 6976.51 3460.58 MinPt-O-SF 8237.55 8086.90 8012.07®I 9208.36 3758.10 MinPt-O-SF 6923.0' 6677.12 6554.63 28.26 14708.58 3852.30 MInPI-CICt 6920.85 6668.81 6543.29 MEE 15190.74 3833.85 MinPt-O-SF 6923.9 6675.26 6551.40 27.95 14920.43 3851.29 MinPts E r'y, 6213.26 6063.34 21.72 18220.61 3798.89 MinPt-CtCt I 6514.7a 1.133146u0! 6061.95 21.63 18270.38 3794.94 MinPt-O-EOU I1 1 6515.59 6212.71 6061.7' 21.58 18297.56 3793.15 MinPt-O-ADP 674151 6377.69 6196.22 18.57 20661.07 3712.65 TD 1 6797.12U 6927.44 6393 09' 25.29 16797.00 3811.86 MinPts S132-W2(P2)(Del Finn) Warning Alert r II 17862.091 17857.94 17829.281 6195.44 400.53 400.53 MinPts 4917.76 4714.85 4615.49 2433 18084.57 3811.41 MinPt-O-SF 17869.48 17868.26 17836.67 N/A 0.00 0.00 Surface 1084.43 862.63 754.65 4.99 19695.06 3747.87 OSF<5.00 Enter Alert I 195.181 68.221 524 1.541 21239.92 3660.30 MinPts OI1l-01P81(Def Survey) ... . . Warning Alert 39.81 38.11 36.48 81.03 138.95 138.95 MinPts 40 63 37.54 36.61 21.09 378.95 37895 MinPt-O-EOU 40.86 37.52 36.46 18.70 408.90 408.90 MinPt-O-EOU 40.98 37.54 36.431 1791 423.83 423.83 MinPt-O-ADP 76.46 60.15 5260 4.99 940.78 936.13 OSF<5.00 Enter Alert 136.19 97.98 79.4'MIME 1283.81 1261.36 MinPt-O-SF 196.46 155.97 136.33 4.97 1479.47 1438.36 OSF>5.00 Exit Alert 187.55 159.40 145.81 own 4073.94 3052.26 MinPt-O-SF 126.43 100.22 87.61 4.97 4274.89 3080.50 05F<5.00 Enter Alert II 125.14 93.60 78.30 4.06 4304.66 3084.72 MinPt-CtCt 131.'0"57 87.41 66.12 3.05 4368.97 3093.76 MinPt-O-EOU 135.40 88.3,',11 65.291 2.92 4390.42 3096.78 MinPI.O-ADP 147.18 94.44 68.56 2.821 4433.28 3102.81 MinPt-O-SF 334.55 266.47 232.92 4.97 4818.79 3157.04 OSF>5.00 Exit Alert 1370.34 1267.07 1215.93 13.39 6864.65 3444.84 TD 0111-01(Def Survey) . Warning Alert 38.11 6 t0 81.03 138.95 138.95 MinPts 40.6 IIIMIO 36.61 21.09 378.95 378.95 MinPt-O-EOU 40.86® 36.46 18.70 408.90 408.90 MinPt-O-EOU 40.98 37.54 MEE 17.91 423.83 423.83 MinPt-O-ADP 76.46 60.15 52.60 4.99 940.78 936.13 OSF<5.00 Enter Alen 136.19 97,98 79.4'0'' 1283.81 1261.36 MinPt-O-SF 196.48 155.97 136.33 4.97 1479.47 1438.36 OSF>5.00 Exit Alert 187.55 159.40 145.81 MUM 4073.94 3052.26 MinPt-O-SF 126.43 10022 87.61 4.97 4274.69 308050 OSF<5.00 Enter Alert Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P14-S3\0P14-S3\0P14-S3(P5b) 3/31/2011 9:09 AM Page 2 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 125.18 93.60 78.30 4.06 4304.66 3084.72 MinPt-CICI 131.0 . 87.41 66.12 3.05 4368.97 3093.76 MinPt-O-EOU 135.40 88.3 65.29( 2.92 4390.42 3096.78 MinPt.O-ADP 147.18 94,44 68.57! 2.821 4433.28 3102.81 MinPt-O-SF 334.55 266.47 232.92 4.97 4818.79 3157.04 OSF>5.00 Exit Alert 1082.36 989.11=2EM MIMI 6293.27 3364.46 MinPts 2390.23 2261.27 2197.6 Mal 8971.56 3732.48 MinPt-O-SF 2309.28 2198,mom 20.19 9471.89 3782.64 MinPt-O-ADP 2307.6 •."1 2136.37 20.40 9508.66 3785.70 MinPt-O-EOU 2194 93 2140.51 21.17 9619.85 3794.36 MinPt-CtCt L®' 5.69 2132.84 21.68 10021.66 3819.98 MinPt-CtCt 2293,32166 2132.49 21.61 10041.65 3821.20 MinPt-O-EOU 2293,64 2185.57! 99 21.56 10056.65 3822.12 MinPt-O-ADP 2323.80 2210.54 2154 72 20.801 10354.99 3840.33 MinPt-O-SF Ir 2324.141 2218.57 216660 22.34 10700.65 3856.20 MinPt-CtCt 2325.9 2217.36 2163.87 21.73 10751.35 3857.75 MinPt-O-EOU 2328.40 2217.8 2163 4 21.36 10784.28 3858.61 MinPt-O-ADP 2357.36 2235 44 2175 29 19.58 11292.68 3868.38 MinPt-O-SF 2361.59 223513 2172.72 18.90 11569.06 3878.28 MinPt-O-EOU 2293.90 2149.53 2078.16 16.06'1 12731.71 3820.18 MinPt-CtCt 2294.37 2147.91! 2075.48! 15.84 12812.82 3816.65 MInPts OP10-09(Def Survey) 9Y i ,W 'O 1. 1 47.93 46.751 44.651 241583.62 4.07 4.07 MinPts 48."°11 4629 45.05 54.52 199.07 199.07 MinPt-O-EOU 116.86 92.49 80.91 5.00 966.56 961.14 OSF<5.00 Enter Alert 125.76 98.70 85.78 1007.28 1000.49 MinPt-O-SF 142.78 113.17 98.97 4.99 1077.98 1068.30 OSF>5.00 Exit Alert 54892 515.31 498.491 1 3143.33 2746.68 MinPt-O-SF 483.18 459.65' 6.3 448.37, 21.38 3635.42 2961.06 MinPt-O-ADP 482.0 459.4 448.63 22.26 3661.81 2969.22 MinPt-O-EOU I481.1 460.11 450.07 23.90 3708.49 2982.78 MinPt-CtCt 717.03 671.12 648.6•®l 4362.05 3092.79 MinPt-O-SF 3648.32 3502.41 3429.••MOE 8859.85 3719.39 MinPt-O-SF 3575.40 3437. 6 3368.83 26.08 9228.80 3760.16 MinPt-O-ADP i 3574.78 3368.96 26.17 9245.69 3761.85 MinPt-O-EOU I� 3437.94 3370.33 26.42 9287.95 3765.98 MinPt-CtCt 3222.24 3084.26 3015.76'.® 11288.45 3868.24 MinPt-O-SF IIIIERIESIL2159.63 2047.55 10.63 14329.64 3847.99 MinPt-CtCt 2386.3„=4MLI 2045.15 10.52 14432.46 3849.16 MinPt-O-EOU 2391.1'MEIREE 2042.66 10.32 14627.38 3851.38 MinPt-O-EOU 2392.54 2158.7% 'E"• 10.27 14672.34 3851.89 MinPt-O-ADP 2405.'' 2046.84 10.09 15101.41 3840.52 MinPt-O-EOU 2406.55 2188.1. 20461 15151.26 3836.69 MinPt-O-ADP 2407.62 2168.96 2047.1 r w 15210.82 3832.56 MinPt-O-5F 2409.63 2168.83 2048.9. 10.04 15331.34 3827.11 MinPt-O-SF 2411.72 2170.1 MU 10.02 15439.91 3825.47 MinPt-O-ADP 2432.29 2183.10 2058." 9.80 15756.42 3823.24 MinPt-O-SF 2441.23 2191.,: .: '.y® 16105.44 3810.13 MinPts 2403.0,INGEEE mmiE,88® 16802.98 3811.96 MinPts MangE 1995.96 1849.14 7.80 18415.00 3787.57 MinPt-CtCt 2291.6' 1993.9. 1845.63 7.72 18534.96 3782.32 MinPt-O-EOU 2282,49 1994.151 18 4418 44 8 7.71 18559.92 3781.22 MinPt-O-ADP 23049. 1999.5: 1847.40 7.57 18823.26 3769.74 MinPt-O-EOU 2306.50 1999.91 7.54 18872.58 3768.06 MinPt-O-ADP 2547.13 2179.13 1995.63 6.94 21239.92 3660.30 TD OP26-DSPO2(Def Survey) , - .. _ 11,1Iffft, IIIIIME, 300.4:MIMI N A. 3.99 3.99 MinPts 1.. 120.10 101.48 93.15-' 1488.18 1446.16 MinPt-O-SF 110.38 94.46 87.48 7 76 1581.83 1529.94 MinPt-O-ADP 109.61 MOM 87.64 8 06 1600.64 1546.72 MinPt-O-EOU 94.99 8982 8 95 1642.69 1584.20 MinPt-CtCt 177.23 155.92 146.2 �•'it 2122.25 2005.32 MinPt.OSF 180.27 142.53 124.53 4.96 3831.43 3013.08 OSF<5.00 Enter Alert 156.02 118.73 100.971 4.341 3934.97 3032.40 MinPt-O-SF 117.2 99.°,,91 4.39 3959.69 3036.16 MinPt-O-ADP 153.42 117.211 99.99 4.40 3963.76 3036.75 MinPt-O-EOU II 15310117.54 100.64 4.48 3975.89 3038.47 MinPl-CtCt 155.66 122.90 107.41 4.97 4016.31 3044.15 OSF>5.00 Exit Alert 3281.27 3238.17 3217.511_®I 6684.71 3419.53 MinPt-O-SF OPO4-07(Def Survey) x }' i Warning Alert III 1. 100.60IIIIIIIIIIIIIII�. 1 75 08 278.84 278.84 MinPts 103.27 mulim 99.77 67.23 313.84 313.84 MinPt-O-EOU 103.42 100.5 •.• l 62.35 338.84 338.84 MinPt-O-ADP 208.57 191.37 183.38 1036,04 1028.16 MinPt-O-SF 922.45 895.34 882.29�� 2564.04 2364.10 MinPt-O-SF 437.38 348.93 305.20 4.99 7112.52 3479.71 OSF<5.00 Enter Alert 264.45 142.87 82.28 2.18 8469.44 3669.57 MinPt-CtCt 264.47 142.64 82.26 2.18 8476.08 3670.46 MinPts i 264.50 142.68 82.26 2.181 8480.35 3671.03 MinPt.OSF 548.11 437.44 382.59 4.99 9264.32 376168 OSF>5.00 Exit Alert 3015.09 2906.99 2853.43 28.14 11052.88 3863.66 TD OPO4-07P61(Def Survey) Warning Alert mew 100.60[ 99.851 75.08 278.84 278.84 MinPts 103.27=ma 99.77 67 23 31334 313.84 MinPt-O-EOU 103.42 100 55�l 62.35 338.84 338.84 MinPt-O-ADP ' 208.57 191.37 183.3:MERICI 1036.04 1028.16 MinPt-O-SF 922.45 895.36 882.31 IMalp 2564.04 2364.10 MinPt.OSF 437.38 348.94 305.22 4.99 7112.52 3479.71 OSF<5.00 Enter Alert [ 264.451 142.69 82.30 2.18 8469.44 3669.57 MinPt-CtCt Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP14-S3\OP14-S3\OP14-S3(P5b) 3/31/2011 9:09 AM Page 3 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)i EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 264.47L_(±2_681 82.28 2.18 8476.08 3670.46 MinPts 264.50 142.70 82.29 2.181 8480.35 3671.03 MinPt-O-SF 548.11 437.45 38262 4.99 9264.32 3763.68 OSF>5.00 Exit Alert 1716.29 1614.11 1563.52 16.95 10246.93 3833.73 TD OP08-04PB1(Def Survey) 63 95 62.73 60.62) N/A 0.00 0.00 _ MinPts 62.08 60.93 65.70 183.90 183.90 MinPt-O-EOU 163.15 142.01 132.06'. r 998.93 992.44 MinPt-O-SF 1 673 09 632.64 612 92 17.03 4030.22 3046.11 MinPt-CtCt 6731 632.51 612.81 16.99 4043.51 3047.98 MinPt-O-EOU 673.18 632 6 612.80 16.98 4047.95 3048.60 MinPt-O-ADP 675.47 633.5 613.13 16.49 4216.58 3072.32 MinPt-O-EOU 227.47 181.15 158.48 5.00 7337.18 3511.31 OSF<5.00 Enter Alert 209. 155.40 128.61 3.90 7584.05 3546.04 MinPt-CtCt 219.61 141.541 103.00 2.84 7746.35 3568.87 MinPt-O-EOU 227.70 143.1`nll 101.321 2.71 7785.50 3574.38 MinPt-O-ADP 244.72 151.66 105.61 2.651 7840.97 3582.18 MinPt-O-SF 624.34 498.39 435.90 4.99 8659.16 3694.47 OSF>5.00 Exit Alert 815.60 695.87 636.51 6.86 9151.08 3752.19 TD OP08-04(Def Survey) Warning Alert 1 63.9 62.73 60.621 N/A 0.00 0.00 MinPts 64.266 62.08 60.93 65.70 183.90 183.90 MinPt-O-EOU 163.15 142.01 132.06 3E, 988.93 892.44 MinPt-O-SF 673. 632.65 612.92 612.92 17.03 4030.22 3046.11 MinPt-CtCt 673.1 632.591 612.81 16.99 4043.51 3047.98 MinPt-O-EOU 673.18 632.6 612.801 16.98 4047.95 3048.60 MinPt-O-ADP 675.41 633.5 613.13 16.49 4216.58 3072.32 MinPt-O-EOU 227.47 181.15 158.48 5.00 7337.18 3511.31 OSF<5.00 Enter Alert 1 209. 155.40 128.61 3.90 7584.05 3546.04 MinPt-CtCt 219.610 141.541 103.00 2.84 7746.35 3568.87 MinPt-O-EOU 227.70 143.1 101.3 2.71 7785.50 3574.38 MinPt-O-ADP 244.72 151.66 105.62 2.651 7840.97 3582.18 MinPt-O-SF 621.28 495.90 433.71 4.99 8641.52 369220 OSF>5.00 Exit Alert 983.05 871.14 815.6 10356.99 3840.45 MinPt-O-SF 1 990.211 882.71 829.46 9.29 1073700 3857.34 MinPt-CtCt 993. 879.84 823.47 860 1083692 3859.81 MinPt-O-EOU 993.99 879.`4',11 823.26 8.78 10847.00 3859.94 MinPt-O-ADP 1020.53 898.78 835.40 8 3 11293.11 3868.40 MinPt-O-SF 1050.92 918.99 853.51 8.0 11687.26 3882.52 MinPt-O-SF 1065.72 932.50 866.38. 8.0 12000.20 3873.35 MinPt-O-SF OP09-S1(P3b)(Def Plan) 1,6 11/arnIng Alen 55.97 54.74 5264 N/A 0.00 0.00 Surface I 55.971 52.16 5066 21.15 400.00 400.00 MinP1-CtCt 56.03 52.081 50.71 20.07 419.87 41967 MinPt-O-EOU 56.11 52.08 50.69 19 62 429.80 429.60 MinPt-O-ADP 168.41 142.89 130.7 6.88 1097.86 1087.24 MinPt-O-SF 1 547.50 437.16 382.49 500 8286.85 3644.69 OSF<5.00 Enter Alert 1 546.46 435.60 380.66 4.96 8353.08 3653.80 MinPt-CtCt 546.•6'-,7' 435.45 380.35 4.95 8382.09 3657.76 MinPt-O-EOU 546.91 435.511 380.31 4.94 8398.67 3660.02 MinPt-O-ADP 565.73 449.14 391.34 4.891 8640.73 3692.10 MinPt-O-SF 617.48 493.16 431.50 5 00 8882.84 3722.13 OSF>5.00 Exit Alert 2794.01 2652.10 2581 64 11245.28 3867.14 MinPt-O-SF 2857.61 2709.4 2635.841-- 11687.78 3882.54 MinPts mil 2708.90 2635.38 19.42 11797.81 3883.99 MinPt-CtCt 2857.4 2634.08 19.26 11908.18 3880.37 MinPt-O-EOU 2858.02 2708.3.MEMET 19.21 11948.75 3877.72 MinPt-O-ADP 2862.60 2709."Mang11 18.87 12155.99 3855.54 MinPt-O-ADP 2391.28 2148.11 2027.01 '.-y 16182.40 3806.76 MinPt-O-SF 2388.78 2145.83 2024.o'=Ka 16224.78 3805.56 MinPt-O-SF 2386.04 2143.34 2022..>�"•If 16293.31 3804.60 MinPt-O-SF 2384.99 2142.5 MIME 9.87 1635691 380472 MinPt-O-ADP 2384.9 MEEE 2021.81 9.87 1635724 3804.78 MinPt-O-EOU MEMCIa 2142.56 2021.87 9.88 16369.90 3804.93 MinPt-CtCt 2386.21 MEMO 2007.6r 948 16798.39 3811.88 MinPts 2398.9 !ME16W 2004.61 17311.70 3818.83 MinPts 2506.29 2148.73'x• r;nl- 21087.53 3676.41 MinPts SP33-W3(P2)(Def Plan) 1 g -- Warning Alert 1 17863.471 17859.371 17830.661 621043 400.52 400.52 MinPts 17870.32 17869.10 17837.52 N/A 060 600 Surface 927.82 73845 645.98 4.99 19758.91 3746.97 OSF<5.00 Enter Alert 743.10 580.32 500.41 I E 1.r 19926.19 3742.72 MinPt-O-SF 627.63 501.15 43841 499 20083.99 3736.44 OSF>5.00 Exit Alert MMI 483.36 423.87 5.06 20155.08 373228 MinPt-CtCt 60408 482.24 421.81 469 20171.43 3731.54 OSF<5.00 Enter Alert 606.881 481.791 419.74 488 2019612 3730.69 MinPt-O-EOU 621.62 485.09 417.32 4.58 2023324 3728.73 MinPt-O-ADP 755.34 567.86 474.62 4.041 20415.81 3721.83 MinPt-O-SF 1207.91 956.78 831.71 4.82 21239.92 3660.30 TD S129-S2(P2)(Def Plan) ": . s Zt; :=3 Warring Alatt. 17867.2 17862.64 17834 5292.93 450.99 450.99 ., MinPts 178672 17862.6 1783444 5281.25 452.88 452.86 MinPt-O-EOU 17866.20 17864.98 17833.39 N/A 0.00 0.00 Surface 17866. 17863.6 17833.3 13452.29 198.80 198.80 MinPts 17866. 17863 36 17833.67 9396.66 258.80 258.80 MinPt-O-EOU 1 1284.8 1010.02 876.331 4.781 2123742 3660.56 0SF<5.00 Exit Alert 4773.70 4508.43 4378.12 18.30 21239.92 3660.30 TD 1592.99 1372.51 MIRE 7.43 12346.14 3839.04 MinPt-O-ADP Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP14-S3\0P14-S3\OP14-S3(P5b) 3/31/2011 9:09 AM Page 4 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 1098.46 880.23 774.62 5.171 16198.61 3806.25 MinPt-O-SF 1094.54 877.391 772.43 5.18 16318.79 3804.55 MinPt-O-ADP 1094.2 877.34 772.49 5.18 16338.50 3804.63 MinPt-O-EOU 1094.13 877.50 772.85 5.19 16370.03 3804.94 MinPt-CtCt 1095.38 875 611 769.40 5.121 16796.88 3811.86 MinPts 1107.83 884 81 777. 5 11 17312.70 3818.84 Min Pt-O-SF 1135.89 902.69 789.84 5.00 18319.75 3791.88 OSF<5.00 Enter Alert 120620 939.30 809.59 ME= 20708 37 3710.83 MinPt-O-SF SP3O-W1(P2)(Def Plan) „_: yypnUlgpy4d., wommansecilimo 6217.32 400.49 400.49 MinPts 17867.04 17865.82 17834.23 N/A 0.00 0.00 Surface 1301.28 1035.09 90546 4.99 20983.23 3687.43 OSF<5.00 Enter Alert I 1235 331 963 751 831 48 4.641 21239.92 3680.30 MinPts OP18-08(P10)(Def Plan) Pass 32.03 30.80 28.70 N/A 0.00 0.00 Surface MSG 29.39 28.68 21.80 250.00 250.00 MinPt-C1Ct 32.11 IMEZEI 28.45 19.05 285.00 285.00 MinPt-O-EOU 32.16 29.27=IBM 18.56 295.00 295.00 MinPt-O-ADP 32.23 29.29 NEM 18.11 305.00 305.00 MinPt-O-ADP 57.86 49.33 45.67® 702.43 701.77 MinPt-O-SF 7072.64 692407 6850.28® 9341.42 3771.05 MinPt-O-SF 6753.35 6590.-1-1 6509.49 41.70 12029.99 3870.30 MinPt-O-ADP 7668.52 7396.09 7260.37 MEM 15819.81 3822.40 MinPt-O-SF 7684.65 7391.9811116=E1 26.34 17332.69 3819.06 MinPt-O-ADP 7702.75 7312.17 7117 3771 19.77 21239.92 3660.30 TD 7678.09 7405.30 7269.4 28 2 15787.32 3822.92 MinPt-O-SF 7673.34' 7413.611 7284.2 29 6 14772.90 3853.03 MinPts OP23-W W02(Def Survey) �-:�-- 'YMEER 76.54 I®.1 65.71 267.98 267.98 MinPtn ce 76.25 75.50 51.95 329.00 329.00 MinPt-CtCt 79.04 111.1110 75.33 46.96 364.00 364.00 MinPt-0-EOU ® 75.85 74.89 40.32 419.18 419.18 MinPt-CtCt 69.66 60.14 55.99 8.25 826.02 823.90 MinPt-CtCt 70.74 NM= 53.38 6.46 889.49 886.13 MinPt-O-EOU 71.31 IMEAM 53.13 6.20 904.04 900.34 MinPt-0-EOU 72.57 59.04 MIME 5.80 928.18 923.87 MinPI-0-ADP 79.10 63.30 56.02 11EM 999.88 993.36 MinP1-0SF 564.73 542.62 532.11 t5,/ 2893.35 2596.66 MinPt-O-SF 711.40 680.98 666.31® 3688.45 2977.10 MinPt-O-SF 755.84 723.63 708.0 ® 3877.17 3022.32 MinPt-O-SF 5834.69 5778.55 5750.98 105.78 9187.93 3756.02 TD Oliktok Point I-2PB1(Def Survey) Pass 120.48 119.36 117.15 N/A 0.00 0.00 Surface 120.48 119.36=MEE N/A 40.00 40.00 MinPts 106.41 91.36 84.40 7.56 948.97 944.08 MinPt-CtCt 107.49=ill 79.85 6.02 1072.57 1063.14 MinPt-0-EOU 108.02 88.78 1097.76 1087.15 MinPts 919.71 895.24 883.4r mg= 3080.15 2711.17 MinPt-O-SF 1094.71 1065,53 1051 43 3277.47 2816.35 MinPt-O-SF 1129.27 1099,20 1084 65 MEM 3311.42 2832.70 MinPt-O-SF 3641.50 3580.40 3550.34 60.56 4605.88 3127.09 TD Oliktok Point 1-2(Def Survey) 1r Pe 120.48 119.36 117.15 N/A 0.00 0.00 Surface .111111= 119.36!x,' N/A 40.00 40.00 MinPts 91.36 8440 7.56 948.97 944.08 MinPt-CtCt 107.49 M211 79.85 6.02 1072.57 1063.14 MinPt-0-EOU 108.02 88.78 1097.76 1087.15 MinPts 919.71 895.24 883.4, 5t 3080.15 2711.17 MinPt-O-SF 1094.71 1065.53 1051.4 MIMI 3277.47 2816.35 MinPt-O-SF 1129.27 1099.20 1084.6 ® 3311.42 2832.70 MinPt-O-SF 6679.09 6558.55 6498.78 man 7141.64 3483.81 MinPt-O-SF 5849.19 5699,04 5624.46® 9024.43 3738.47 MinPt-0SF 5675.28 5542.50 5476 61 43.06 9656.63 3797.02 MinPt-0-ADP 5675.06=Mg 5476.64 43.11 9660.69 3797.31 MinPt-0-EOU 5674.84 554265 5477.05 43.24 9670.85 3798.03 MinPt-CtCt 5659.03 5522.54 5454.78 41.75 10238.37 3833.21 MinPt-CtCt 9 4167.68'i 4040.8,IMMICE 16063 42 3812.38 MinPts Oliktok Point I-2PB2(Def Survey) Pass 120.48 119.49 117.15 N;A 0.00 0.00 Surface =IE3n 119.36 MIME N/A 40.00 40.00 MinPts 91.37 84.41 756 948.97 944.08 MinPt-CtCt 107.49®.'.' r 79.86 6.02 1072.57 1063.14 MinPt-0-EOU 108.02 88.78 muzi 1097.76 1087.15 MinPts 919.71 895,24 883.50 MEE 3080.15 2711.17 MinPt-0-SF 1097.85 1068.58 1054 45® 3280.59 2817.87 MinPt-0-SF 1129.27 1099.20 1084.66 mg= 3311.42 2832.70 MinPt-0-SF 5849.19 5699.04 5624.':mom 9024.43 3738.47 MinPt-O-SF 5675.28 5542.51 Male 43.06 9656.63 3797.02 MinPt-0-ADP 5675.06�„ 5476.64 43.11 9660.69 3797.31 MinPt-0-EOU Win. 5542.65 5477.05 43.24 9670.85 3798.03 MinPt-CtCt 5659.031 5522.54 5454.79 41.75 10238.37 3833.21 MinPt-CtCt 4896.221 4707.79'1 4614.0 I9 13301.09 3809.25 MinPts OP22-W W01(P2)(Def Plan) Pass I 71.04 66.60 64.99 21.70 596.92 596.78 MinPt-CtOt 71.431 66.221 64.23 17.60 647.05 646.73 MinP50-EOU Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P14-S3\0P14-S3\0P14-S3(P5b) 3/31/2011 9:09 AM Page 5 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 71.74 66.28 64.17 16.66 662.01 661.61 MinPt-O-ADP 101.79 89.65 84.191 9.211 893.17 889.73 MinPt-O-SF 111.23 97.99 91.99 9.16 925.23 920.99 MInPI-O-SF 4085.64 4020.69 3988 701 63.861 6035.63 3328.22 MinPt-O-SF 6523.88 6445.21 6406.37 83.96 8252.17 3639.89 TD OP17.02P51(Del Survey) Pass �® 20.69 404024 26 0.00 0.00 MinPts 24.53 21.21 25.91 193.94 193.94 MinPt-O-EOU 24.72® 21.39 21.55 213.93 213.93 MinPt-O-EOU 25.19 22.495 16.21 248.90 248.90 MinPt-O-ADP 36.12 29.89 27.39 MN= 523.15 523.13 MinPt-O-SF 57.41 48.97 45.36 0 710.34 709.63 MinPt-O-SF 124.10 101.27 90.47® 1097.23 1086.65 MinP1-OSF 9624.11 9482.74 9412.5 '.® 7877.94 3587.38 MinPt-O-SF 7099.09 6950.15 6876.17 M. 9078.08 3744.39 MinPt-O-SF 6832.07 6699.0 6633.02 51.73 9567.35 3790.38 MinPt-O-ADP 6831.28hI 6698.88 6633.18 51.98 9581.59 3791.48 MinPt-O-EOU 6699.35 6634.14 52.37 9603.75 3793.16 MinPt-CtCt 5776.47 5530.66 5408.2 itgiEE 15184.47 3834.27 MinPt-O-SF 1111EM 5103.57 4959.98 18.77 17962.93 3820.07 MinPt-CtCt 5392.4.MUM 4958.44 18.67 18029.24 3815.99 MinPt-O-EOU 5403.4.MIME 4953.66 18.06 18437.41 3786.59 MinPt-O-EOU 5406.01 5103.7. � 17.94 18517.27 3783.09 MinPt-O-ADP 5410. .®" . 495050 17.69 18692.10 3775.43 MinPt-O-EOU 5411.44 5103.6. 4950.17 17.63 18732.07 3773.68 MinPt-O-ADP 554523 5198.9 Milt 16.06 20218.22 3729.40 MinPt-O-ADP 5665.40 5292.23 5106.14 15.22 21239.92 3660.30 TD OP17-02(Def Survey) 02/ .'t, ,;.;7 „N r - Pass - 1 24.02 23 01 20 691 N/A 0.00 0 00 MlnPfs 24721 22.54 2139 24.74 213.93 213.93 MinPt-O-000 36.49 30.31 27.83® 528.11 528.09 MinPt-O-SF 43.89 37.01 34.18® 607.26 607.09 MinPt-O-SF 58.84 50.31 46.65111111111111111111 720.12 719.32 MinPt-O-SF 124.10 101.31 90.53 1097.23 1088.65 MinPt-O-SF 9400.87 9262.20 9193.36® 7785.59 3574.39 MinPt-O-SF 7152.12 7001.90 6927.28, 8994.55 3735.10 MinPt-O-SF 6832.07 6698.1 6633.0 51.74 9567.35 3790.38 MinPt-O-ADP 6831.2• 6698.% 663818 51.98 9581.59 3791.48 MinPt-O-EOU MOM 6699.35 6634.15 52.37 9603.75 3793.16 MinPt-CtCt 5736.02 5494.,'=ma 23.84 14825.12 3853.15 MinPt-O-ADP 5726.55 5481.14 5358.9- 15189.43 3833.93 MinPt-O-SF MEM 5041.75 4895.02 18.18 1822387 3798.60 MinPt-CtCt 5337.0.II111111 E 4893.41 18.08 18284.14 3794.00 MinPt-O-EOU 5337.77 5041.0' 4893.241 1865 18307,31 3792.57 MinPt-O-ADP 5518.58 5175.1 I 5003.9 16.11 20118.58 3733.95 MinPt-O-ADP Il 5516 65 5165.97 4991.13 15.77 20395.42 3722.60 MinPt-CtCt 5517.82 5164.80 4988.77 15.67 20485.39 3719.23 MinPt-O-EOU 55221 5163.68 4984.97 15.45 20690.14 3711.56 MinPt-O-EOU 5523.21 5163.86 4984.68 15.41 20728.23 3709.91 MinPt-O-ADP 5593.89 5221.09 5035.19 15.04 21239.92 3660.30 TD MIME 5493.46 5373.38 23.87 14766.53 3852.96 MinPt-CtCt 0106-05(P9)(Del Plan) >k t# . 4f:;' PM* ,*7,4,--5'4'.' 87.97 86.74 84.64 N/A 0.00 0.00 Surface Mfffin 84.94 84.04 48.05 300.00 300.00 MinPt-CtCt 88.06 111111=1 83.27 36.47 414.82 414.82 MinPt-O-EOU 88.11 84.46 MM1 35.89 424.70 424.70 MinPt-O-ADP 137.14 125.70 120.60® 815.81 813.86 MinPt-O-SF 489.98 456.94 451.0'111.111072. 1203.12 1186.52 MinPt-O-SF 4601.47 4573.72 4560.38 1922.30 1831.56 MinPt-O-SF 3918.64 3787.31 3722.13330.06] 8515.71 3675.75 MinPt-O-SF 3917,4 MIIIM IIMM:111 30.07 8534,74 3678.27 MinPts MEM 3786.19 372106 30.07 8536.20 3678.46 MinPt-CtCt 5369.71 5233.06 5165.22 39.57 9438.45 3779.78 TD 0120-07(P10)(Def Plan) ^" ' Pass 56.06 53.43 52.72 38.80 250.00 250.00 MinPt-CtCt 56.79 MEM 51.22 19.18 455.06 455.06 MinPt-O-EOU 57.28 52.76® 17.00 485.00 484.99 MinPt-O-ADP 65.04 70.94 67.85 M1FEEI 599.21 599.06 MinP1-0SF 78.22 70.91 67.86® 687.35 686.80 MinP1-0SF 83.92 76.07 72.76® 716.43 715.66 MinPt-O-SF 171.03 154.28 146.51 997.15 990.72 MinP1-0-SF 9866.20 9813.19 9787.18 189.63 3824.07 3011.49 MinPt-0-SF 9032.74 8887.83 8815.87 MilE1 9400.74 3776.46 MinPt-O-5F 8552.83 8392.11 ELM 53.54 12053.85 3867.61 MinPt-0-ADP 9532.29 9301.56 9186.68 41.49 1391158 3834.22 MinPt-0-SF 9820.15 9585.93 9469.31 MOM 14262.47 3846.33 MinPt-0-8F 9652.39 9314.58 9146.17 28.65 21239.92 3860.30 TD 10046.34 9805.611 9685.74 41.9011 14767.87 3852,98 MinPts O P05-06(Def Survey) Pass 195.73 1 93.84 92.40 142.93 153.94 153.94 MinPts 95.79 93.79 92.47 121.86 173.94 173.94 MinPt-O-EOU 162.13 152.75 148.6 795.78 794.12 MinPt-O-SF 172.28 162.35 157.99 M1M 821.89 819.84 MinP1-OSF I 5228.851 5110.3 5051.62 44.49 8478.49 3670.78 MinPts 5228.85 5110.3 5051.621 44.49 8479.68 3670.94 MinP1-0-ADP 5279.27 5158.23 5098.20 43.96 8635.17 3691.39 MinPt-OSF 5330.26 5207.79 5147.04 43.87 8711.95 3701.18 MinPt-O-SF 6885.53 6751.44 6684.89 51 72 9399.34 3776.34 TD Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP14-S3\OP14-S3\OP14-S3(P5b) 3/31/2011 9:09 AM Page 6 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 6531.69 6501.58 6487 061 224.871 1944.59 1851.14 MinPt-O-SF OP05-06PB1(Def Survey) Pass k ,1; _ 95.73 93.84 92.40 142.93 153.94 153.94 MinPts 95 79 93.79 92.47 121.86 173.94 173.94 MinPt-O-EOU 182.13 152.75 148.6 MIDIZ 795.78 794.12 Min Pt-O-SF 172.28 162.35 157.99 " 821.89 819.84 Min Pt-O-SF 5850.88 5798.11 5772.22 112.97 4397.49 3097.77 TD OP05-06PB2(Def Survey) - •.t 95.73 93.84 92.40 142.93 153.94 153.94 MinPts 95 79 93.79 92.47 121.86 173.94 173.94 MinPt-O-EOU 162.13 152.75 148.6 MEM 795.78 794.12 MinPt-O-SF 172.28 162.35'1 157.99 821.89 819.84 Min Pt-O-SF 1 5228.851 5110.371 5051.63 44.50 8478.49 3670.78 MinPts 5228.85 5110.3 5051.6 44 49 8479.68 3670.94 MinPt-O-ADP 5279.27 5158.24 5098.21 43.971 8635.17 3691.39 MinPt-O-SF 5330.26 5207.80 5147.061 43.871 8711.95 3701.18 MinPt-O-SF 6032.52 5903.71 5839.80 47.19 9125.92 3749.54 TD 6531.69 6501.59 6487.0711 224 8811 1944.59 1851.14 MinPt-O-SF OP03-P05PB1(Def Survey) s, ` ® 110 58 111111111EM 1495.61 64.00 64.00 MinPts 1 109 76 108.66 110.47 244.00 244.00 MinPts 112.13]] 109.61 108.80 85.82 299.00 299.00 MinPt-O-EOU 112.16 10961 108.83 83.96 304.00 304.00 MinPt-O-EOU 223.68 208.89 202.10 MEM 1000.56 994.01 MinPt-O-SF 3079.94 3023.0 2995.03 55.00 4883.99 3166.21 MinPt-O-EOU 3081.02 302909 2994.61 54.08 4948.44 3175.28 MinPt-0-ADP 3085 32 3016 67 2982 83 45.5 5584.95 3264.82 MinPts OP03-P05(Def Survey) Pass min 110.58®t'. 1495.61 64.00 64.00 MinPts Immol 109.76 108.66 110.47 244.00 244.00 MinPts 112.131 109.61' 108.80 85.82 299.00 299.00 MinPt-O-EOU 11216 109.61 108.83 83.96 304.00 304.00 MinPt-O-EOU 223.68 208.89 202.10®"' 1000.56 994.01 MinPt-0-SF b 2525.981 2407 27 2348 2348.41 21.45 8479.60 3670.93 MinPt-CICt 2525.9 2407.24 2348.41 21.45 8481.55 3671.19 MinPt-O-EOU 2525.98 2407.2 234840 21.45 8483.51 3671.45 MinPt-O-ADP 2526.48 2407.71 2348.8 21.44 8511.09 3675.13 MinPt-O-SF 3510.24 3401.38 3347.44 32 53 9404.53 3776.80 TD OP03-P05PB2(Def Survey) _ Pass . , 111.88 110.58 108 55 1495.67 64.00 64.00 MinPts 111.98 109.76 708 661 110.47 244.00 244.00 MinPts 112.13. 109.61 108.80 85.82 299.00 299.00 MinPt-O-EOU 112.16 109.61 108.83 83.96 304.00 304.00 MinPt-O-EOU 223.68 208.89 202.10 1640 1000.56 994.01 MinPt-O-SF 2528.00 2407.31 234846 21 451 8473.38 3670.10 MinPt-O-SF 11 2525.981 2407 301 2348.45 21.45 8479.59 3670.93 MinPts 2553.20 2434.78 2376.06 21.73 8646.10 3692.79 TD Oliktok Point 1-1(Def Survey) Pess 128.52 126.60 125.19 N/A 0.00 0.00 Surface 128,52 126.60 125.19 355942.90 40.10 40.10 MinPts 128 62 126.50 125.29 613.59 84.20 84.20 MinPt-O-EOU 347.18 333.22 327.20 MEM 997.12 990.69 MinPt-O-SF 4187.78 4143.74 4122.601 99.01 4000.00 3041.86 MinPt-O-SF 6575.10 6460.28 6403.76 5814 6738.78 3427.13 TD 7535.83 7508.17 7495.3011 1944.70 1851.23 MinPt-O-SF Oliktok Point 1-15-106(P5)(Def #7. d 1 Pess z Plan) ' w A' t 128.52 126.60 125.19 N/A 0.00 0.00 Surface 12952 126.60 125.19 355942.90 40.10 40.10 MinPts 128.62 126.50 125.29 613.59 84.20 84.20 MinPt-O-EOU 347.18 333.22 327.20 MEMO 997.12 990.69 MinPt-O-SF 6468.4 6331.85 6264.06 47.70 8365.20 3655.46 MinPt-CtCt 6468 69 6331.6011 6263.55 47.52 8378.22 3657.23 MinPt-O-EOU 6468.99 6331.6 6263. 47.44 8384.23 3658.05 MinPt-O-ADP 7024.24 6861.08 6779. 43.301 8948.52 3729.83 MinPt-O-SF 8089.94 7913.02 7825.05 45.98 9315.42 3768.61 TO 7898.85 7853.64 7831 531=12:EE 1945.28 1851.74 MinPt-O-SF SI35-W4(P2)(Def Plan) 17865.41'1111IE115 17832.601 6196.00 400.53 400.53 MlnPts 17872.02 17870.80 17839.21 N A 0.00 0.00 Surface 965.35 804.81 725.8811 19970.67 3740.69 MinPt-O-SF 1 773.531 654.99 59622 6.57 20247.43 3728.14 MinPt-CtCt 776.83 653.141 591.79 6.32 20282.03 3726.85 MinPt-O-EOU 787.51 655.51 590.011 6.00 20319.62 3725.44 MinPt-O-ADP 957.81 768.88 674.91 5.091 20525.26 3717.73 MinPt-O-SF 1870.74 1615.09 1487.76 7.34 21239.92 3660.30 TD SP36-W5(P2)(Def Plan) Pass 17866.5 17062.42 Z 6187.23 400.53 400.53 MinPts 1787283 17871.60 17840.02 N/A 0.00 0.00 Surface 1179.52 1019.98 941.6 =gm 19691.38 3747.92 MinP1-OSF 1 952.39 836.86 779.59 8.31 19996.12 3739.53 MinPt-C1Ct 953.36 836.331 778.30 8.21 20012.30 3738.80 MinPt-O-EOU 956.61 837.08 777.81 8.06 20030.28 3737.98 MinPt-O-ADP 1182.66 1001.38 911.2 6.551 20258.97 3727.71 MinPt-O-SF 2782.85 2525.63 2397.52 10.86 21239.92 3660.30 TD Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P14-S3\OP14-S3\OP14-S3(P5b) 3/31/2011 9:09 AM Page 7 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 0107-04(De(Survey) Pass 68.6 N/A 3.88 3.88 MinPts 72.23 IMMO 67,86 33.83 418.72 418.72 MinPt-O-EOU 72.28 68.92 mum 33.25 428.64 428.64 MinPt-O-ADP 172.26 159.65 153.9 '.1.11111141 959.89 954.68 MinPt-O-SF 1073.46 1035.12 1016.4:iwI 1961.53 1865.99 MinPt-O-SF 1238.80 1112.63 1050.04 8273.09 3642.79 MinPt-O-SF 1233.90 1108.56 1046.3: 9.91 8344.26 3652.59 MinPt-O-ADP 1233.:P=MET 1046.38 9.92 8347.10 3652.98 MinPt-O-EOU MEM 1108.60 1046.48 9.92 8355.62 3654.15 MinPt-C(Ct 3057.08 2961.81 2914.67 32.41 9903.95 3812.79 TD SP27-N1(P2)(Def Plan) Pass , 0T/)"-, 17858.8 ■imicf 1782602 6209.34 400.49 400.49 MinPts 17864.50 17863.28 17831.69 N/A 0.00 0.00 Surface L 2298.011 2026 921 1894 701 8.661 21239.92 3660.30 MinPte SI25-N2(P2)(Def Plan) 17856.001 17851.891 17823.1 6179.49 400.52 400.52 MinPts 5206.12 5002.36 4902.591 26.01 18080.01 3811.83 MinPt-O-SF 17862.95 17861,72 17830.14 N/A 0.00 0.00 Surface I 3052.101 2791.89 2864.91 11.99 20646.34 3713.20 MinPt-CtCt 3052.38 2791.551 2664.27 11.97 20676.09 3712.08 MinPt-O-EOU 1 3052.76 2791.62 266418 11.95 20690.96 3711.53 MinPt-O-ADP 314172 2869.53 2736.56 11.74 21239.92 3660.30 MinPt-O-SF Kigun 1(Def Survey) .:1,v1.5.,,,, -, 'Nor. 1713455 17131.83 17101.7 21413.27 162.14 162.14 MinPts 17134.70. 17131,71 17101.89 16061.53 197.17 197.17 MinPt-O-EOU 3915.69 3793.17 3732.72 32.37 21239.92 3660.30 TD L 17136.18 17131.2 17103.3 5677.71 456.38 456.38 MinPts 17136.1 17131.2 17103.38 565537 457.97 457.97 MinPt-O-EOU I 3919.97 3797.48 3737.03 32.41 1 21239.49 3660.35 MinPts SP23-N3(P2)(Def Plan) yf,`�,,,'n 1a",,';.yns,,,tw$";.. ..-, , n; "= Pam :�M r' :I'r -, :='.=, 6202.73 400.49 400.49 MinPts 17859.94 17858.71 17827.13 N/A 0.00 0.00 Surface I 3955.151 3723.97 3611.32 17.53 19396.35 3752.07 MinPt-CtCt 3967.69 3720.98 3600.55 16.45 20175.18 3731.37 MinPt-O-EOU 3968.52 3721.11 3600.33 16.40 20214.83 3729.56 MinPt-O-ADP 4050.71 3792.50 3666.31 16.0 20834.29 3702.66 MinPt-O-SF 4090.57 3829.85 3702.40 16.02 20978.03 3687.98 MinPt-O-SF 4172.92 3907.38 3777.50 16.04 21239.92 3660.30 TD SP24-SEI(P2)(Def Plan) Pass • 17866.22 17861.70 17833.41 400.54 400.54 MinPt-O-SF 17861.82 17857.2. 17829.01 5265.55 453.06 453.06 MinPts 17861.82 17857.1' 17829.01 5254.37 454.94 454.94 MinPt-O-EOU 17860.72 17859.49 17827.91 N/A 0.00 0.00 Surface ) :®.. l 17858.1.NEM 13439.82 198.80 198.80 MinPts 17860.99 17828.19 9585.38 253.80 253.80 MinPt-O-EOU 4189.59 4009.34 3921.96 23.94 12802.23 3817.00 MinPt-O-SF 4109 11 3903 23 3802.69 20.41 10452.61 3845.90 MinPt-O-ADP 4107.72 3902 92 3802.97 20.52 10474.33 3847.02 MinPt-O-EOU 4106.64 3904.04 3805.27 20.76 10517.78 3849.13 MinPt-CtCt I 5269.58 5007.31 487558 20.45 20931.53 369259 TD 4043.61 3844.72 3747. 'MIK 15039.86 3845.15 MinPt-O-SF 4029.51 3830.32 3732.8.=KEE 15152.59 3836.58 MinPt-O-SF 3976.52 3777.85 36805 , 15751.95 382327 MinPt-O-SF 3968.26 3771.45 MEM 20.66 15877.54 3820.96 MinPt-O-ADP 3967.99 INEEND 3675.60 20.69 15891.31 3820.53 MinPt-O-EOU 3967.80 3771.55 3675.98 20 73 15914.25 3819.71 MinPt-CICt 3972.44 3776.40 3681.03 20.80 16104.47 3810.19 MinPt-O-SF 4037.07 3839.04 3742.91 20.97 16799.08 3811.89 MinPt-O-SF 4100.40 3897.37 3798.71 20.77 17312.62 3818.84 MinPt-O-SF 4583.43 4337.17 4216.86 19.02 20075.86 3735.90 MinPt-O-SF ' 4230.281 4033 331 3936.69 21.8/ 13976.13 3836.47 MinPts SP18-N5(P2)(Def Plan) ry Pass 1 17849.321 17845 201 17816.521 p 6162.08 400.50 400.50 MinPts 5330.76 5128.58 5029.87 26.98 17873.39 3823.15 MinPt-CtCt 5330.77 5128.581 5029.851 26.97 17874.69 3823.12 MinPts 5388.38 5182.58 5081.90 26.74 18082.64 3811.59 MinPt-O-SF 17855.26 17854.03 17822.45 N/A 0.00 0.00 Surface 7361.67 7093.02 6960 47L1111111 21239.92 3660.30 MinPt-O-SF SD37-WDI(P2)(Def Plan) Pass i 17870 3.1 17841 801 5581.45 400.45 400,45 MinPts 17874.61 :I y 17841 81 5578.95 402.31 402.31 MinPt-O-EOU MEM 5177.19 5070.58 25.28 18757.88 3772.55 MinPt-CtCt 5395.38® 5070.47 25.27 1875597 3772.50 MinPt-O-EOU 5395.43 5177.14 MEC 25.26 18759.41 3772.48 MinPt-O-ADP 5405.62 5186.36 5079.18 18772.55 3771.91 MinPt-O-SF 6582.53 6382.70 6284.37 33.46 18885.94 3767.81 TD 17874.61 17873.50 17841 80 N/A 0.00 0.00 Surface 1 17870 311 17841 801 0 ;I] 398.80 398.80 MinPte S114-N6(P2)(Def Plan) Pass 17846.591f 17842 47 17813 78 6179.07 400.50 400.50 MinPts 5423.691 5216 78 5115.61 26.78 18094.27 3810.52 MinPt-CtCt 5423.70 5216.781 5115.59 26.78 18096.34 3810.33 MinPts 5432.05 5224.57 5123.07 26.741 18153.10 3805.09 MinPt-O-SF 17852.19 17850.97 17819.38 N/A 0.00 0.00 Surface Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP14-S3\OP14-S3\OP14-S3(P5b) 3/31/2011 9:09 AM Page 8 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 8495 81 823155 8100 84 32 41 21239.92 3660.30 MinPt-O-SF SP22-FN1(P2)(Def Plan) Pass 17864.21 17859.69 17831 40 5410.53 400.52 400.52 MinPt-O-SF 17860.26 17855.64 17827 45 5261.48 453.12 453.12 MinPts 17860.26 17855.64 17827.45 5250.50 455.00 455.00 MinPt-O-EOU 17859.15 17857.93 17826.34 N/A 0.00 0.00 Surface 1 17859 151 17856.6 17826. 13436.24 198.80 198.80 MinPts 17859.39 17856. 17826.58 9831.03 248.80 248.80 MinPt-O-EOU 1 5530.38 5263.87 5132.871 21.091 21239.92 3660.30 MinPts SP114N7(P2)(Del Plan) s + '+ 1 17842.99F17838.8 Eira3E 6117.20 400.51 400.51 MinPts MEM 5367.41 5270.87 28.80 17698.44 3822.81 MinPt-CtCt 5565.13®"'®r 28.80 17700.78 3822.63 MinPts 5574.54 5376.20 5279.3.aaa 17769.55 3823.30 MinPt-O-SF 5633.84 5428.87 5328.51 Min 18085.04 3811.37 MinPt-O-SF 17848.58 17847.35 17815.77 NSA 0.00 0.00 Surface 9707.72 9441.89 9310.0•Mir 21239.92 3660.30 MinPt-O-SF SI17-SE2(P2)(Def Plan) r 1,.`Y r.: t K:'k$-; a, , °', .04`filiO, a,, 17860.46 17855.90 17827.6 'MEEK11 400.54 400.54 MinPt-O-SF 17855.6 17851.0.'. 17822.8. 5240.04 455.18 455.18 MinPts 17855.6 17851.00 1782283 5229.11 457.07 457.06 MinPt-O-EOU 17854.50 17853.27 17821.69 N/A 0.00 0.00 Surface 17854.5 17851. 17821.8 13425.58 198.80 198.80 MinPts 17854 7 17851.71 17821.94 9797.86 248.80 248.80 MinPt-O-EOU 5405.12 5229.99 5144.7 Man 1280270 3816.99 MinPt-O-SF 1 5429.80 5248.43 5159.83 30.62 13500.72 3813.90 MinPt-CtCt =MIMI 5155.31 29.91 13654.13 3822.46 MinPt-O-EOU 5433.80 5246. ,MUM 29.58 13712.82 3825.49 MinPt-O-ADP 5313.85 5111. .MIME 26.75 10446.48 3845.57 MinPt-0-ADP 5312.2,MMI'% 5012.42 26.92 10467.84 3846.89 MinPt-O-EOU =ME 5112.25 5014.95 27.27 10509.04 3848.72 MinPt-CtCt 5764.30 5512.08 5388.32 23.27 20477.46 3719.52 TD 5332.11 5133.43 5035.5 EEIE 14797.48 3853.19 MinPt-O-SF 5323.16 5124.75 5027.0•ENEFEIE 14826.55 3853.14 MinPt-O-SF 5254.17 5057.51 4960.8 MEM 15152.54 3836.59 MinPt-O-SF 5198.80 5003.15 4907. 4 Ij 15753.35 3823.26 MinPt-O-SF 5190.55 4996.85 4902.09 27.37 15868.24 3821.24 MinPt-O-ADP 5190.2. 4996.78 4902.16 27.40 15882.03 3820.83 - MinPt-O-EOU 5190.06 4998.97 4902.55 27.48 15903.69 3820.10 MinPt-CtCt 5196.19 5003.56 49094.maim 16107.63 3810.02 MinP1-OSF 5268.55 5073.94 4979.0.MBE 16799.60 3811.90 MinPt-O-SF 5336.47 5136.60 5039.1. 1151i5 17312.09 3818.83 MinPt-O-SF 5696.93 5445.55 532227 IMMO 20410.82 3722.02 MinPt-O-SF 5119-FN2(P2)(Def Plan) Peas .t. 1 17862.03 17857 49 17829. 5383.8 400.52 400.52 MinPt-O-SF 85 177. 17853.1 17825.01 5244.32 455.09 455.09 MinPts 17857.8 17853.1 17825.02 5233.27 456.97 456.97 MinPt-O-EOU 17856.69 17855.47 17823.88 N/A 0.00 0.00 Surface 17858.6 17854.1 17823.8 13430.81 198.80 198.80 MinPts 17856.9 17853.9 17824.13 9809.04 248.80 248.80 MinPt-O-EOU I 5757.72 5491.00 5359.871 21.941 21239.92 3660.30 MinPts S120-N4(P2)(Def Plan) 1 17851.51 17847.391 17818.71 6179.40 400.50 400.50 MinPts 17857.54 17856.32 1782473 N/A 0.00 0.00 Surface 1 5197.881 4990.161 4888.68 25.59 18094.64 3810.48 MinPts 5197.89 4990.18 4888.68 25.59 1809490 3810.46 MinPt-O-ADP 5201.13 4993.16 4891.57 25. 1810227 3809.78 MinPt-O-SF 6020.62 5755.83 5625.65 23.11 21239.92 3660.30 MinPt-O-SF SP16-FN3(P2)(Def Plan) `, =; Pass 1785948 17854.91 17826.67011=1121 400.52 400.52 MinPt-O-SF 11 . 11t 17850.2 17822.08; 5235.70 455.21 455.21 MinPts 17854 89 17850.2, 17822.08 5225.14 457.10 457.10 MinPt-O-EOU 17853.73 17852.51 17820.93 N/A 0.00 0.00 Surface 0 17851.1:x.-1 13423.84 198.80 198.80 MlnPta 17853.9 MEM 17821.14 10052.02 243.80 243.80 MinPt-O-EOU 5967.02 5727.56 5610.00 25.36 19937.83 3742.19 MinPt-CtCt 5967.95 MEE 5608.00 25.16 20019.92 3738.45 MinPt-O-EOU 5969.05 5726.75 M2 25.07 20059.70 3736.63 MinPt-O-ADP 6062.68 5795.79 5664.54®.'. 21239.92 3660.30 MinPt-O-SF SP12-SE3(P2)(Def Plan) Pass 17856 07 17851 47 17823 26 MEM 400.54 400.54 MinPt-O-SF 17850.63 17845.9 17817.82. 5214.14 457.28 457.28 MinPts 17850.6 17845.9: 17817.83 5203.73 459.18 459.17 MinPt-O-EOU 17849.46 17848.23 17816.85 N/A 0.00 0.00 Surface n 17846.1. 13413.67 198.80 198.80 MinPts 17849.6'MaMIZE 17816.89 10012.47 243.80 243.80 MinPt-O-EOU 6610.77 6440.16 6356 79111.111021 12859.19 3815.55 MinPt-O-SF i 6630.0 6452.22 8364.99 37.98 13498.15 3813.77 MinPt-CtCt 6631.41 6450.101 8361.00 37.20 13626.83 3820.97 MinPt-O-EOU 6633.53 6450.55'. 8360.55 36.84 13670.56 3823.33 MinPt-O-ADP 6515.84 6317 151 33.32 10450.80 3845.80 MinPt-O-ADP 6514.09 6316.801 6219.79 33.56 10471.84 3846.89 MinPt-O-EOU 6318.21 6222.66 34.06 10512.63 3848.89 MinPt-CtCt 6190.:, 5967.01 5857.16 28.16 19346.56 3752.78 MinPt-CtCt 619251 MI= 585411 27.77 19472.50 3751.00 MinPt-O-EOU 6194.52 5965.910 27.59 19536.03 3750.11 MinPt-O-ADP Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP14-S3\OP14-S3\OP14-S3(P5b) 3/31/2011 9:09 AM Page 9 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft), EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 6189.34 5945.79 5826.19 25.86 20114.79 3734.12 MinPt-CtCt 6189.66 5945.421 5825.50 25.79 20140.65 3732.94 MinPt-O-EOU 6189.99 5945. 5825. 25.76 20150.62 3732.49 MinPt-O-ADP 6205.39 5958.57 5837.3 25.59j 20232.51 3728.76 MinPt-O-SF 6223.21 5975.99 5854.62 25 62 20242.06 3728.36 TD 6557.07 6359.57 6261.83 3374 14767.35 3852.97 MinPt-O-SF 6459.15 6264.61 6168.65 33 64 15153.58 3836.51 MinPt-O-SF 6398.88 6205.64 6110.57 33.64 15753.04 3823.28 MinPt-O-SF 6389.03 6198.021 6104.22 34.04 15872.46 3821.12 MinPt-O-ADP 6388.7 6197 95 6104.27 34.08 15884.55 3820.75 MinPt-O-EOU I 6388.5 6198.15 6104.71 34.17 15906.99 3819.98 MinPt-CtCt 6394.75 6204.81 6111.6! 16106.05 3810.10 Min Pt-O-SF 6278.27 6184.2; . 16797.89 3811.87 Min Pt-O-SF 6540.73 6343.03 624631 33 79 17312.76 3818.84 MinPt-O-SF 6223.81 5976.5:, 5855.2 20242.05 3728.36 MinPts 5113-FN4(P2)(Def Plan) Pass 1785745 17852.87 17824641 5319 81 400.52 400.52 MinPt-O-SF 17852.62 17847.98 17819.81 5219.48 457.19 457.19 MinPts 17852.6 17847 97, 17819.82 5208.80 459.08 459.08 MinPt-0-EOU 17851.46 17850.23 17818.65 N/A 0.00 0.00 Surface MIME 17848.'. 17818.6 13418.58 198.80 198.80 MinPts 17851.6; 17818.88 10031.69 243.80 243.80 MinPt-O-EOU ' ai 5825.84 5712.34 26.66 19609.52 3749.08 MinPt-CtCt 6057.74=ME 5711.16 26.53 19655.17 3748.43 MinPt-O-EOU 6058.49 5825.40®' 26.47 19678.47 3748.11 MinPt-O-ADP 6129.92 5883.86 5763.0.- 20243.86 3728.28 MinPt-O-SF 6339.58 6072.62 5941.28® 21239.92 3660.30 MinP1-0-SF SP01-SE7(P2)(Del Plan) y, g _ 1.. Pass 17841 96 17837.33 1780915 5243.930 400.46 400.46 MinPt-O-SF L17841.101 17836.491 17808.29 5272.57 429.06 429.06 MinPts 17840.80 17839.58 17807.99 N/A 0.00 0.00 Surface 17840. 17837.21 17807 9 7544.86 298.80 298.80 MinPts 17841. 17836.9 17808.23 631019 343.80 343.80 MinPt-O-EOU 11432.67 11272.79 11193.41' 12862.74 3815.49 MinPt-O-SF 11441.8 11269.74 11184.17 66.85 13508.53 3814.28 MinPt-CtCt 11443.4 11267.53 1118006 85.40 13607.18 381967 MinPt-O-EOU 11445.71 11267.98 11161 84.75 13636.44 3821.50 MInP1.0-ADP 11321.71 11128.7 11032.6 58.95 10443.40 3845.41 MinPt-O-ADP 11319.04 11128.16 11033.21 59.60 10463.86 3846.48 MinPt-O-EOU 11316.85 11130.36 11037.61 61.00 10505.65 3848.56 MinPt-CtCt 6382.79 6174.63 8072.44 31.21 1885841 3776.91 MinPt-CtCt 6382.87 6174.561 6072.30 31.19 18659131 3776.85 MinPt-O-EOU 6382.93 6174.571 6072.29 31.19 18860.28 3776.83 MinPt-O-ADP 6454.01 6241.53 6137.29 30.941 18716.58 3774.38 MinPt-O-SF 9909.48 967497 9559.05 42.73 19728.00 3747.41 TO 11429.31 11227.73 11127.43 56.97 14767.39 3852.97 MinPt-O-SF 11298.02 11102.97 11005.94 58.21 15152.49 3836.59 MinPt-O-SF 11220.34 11029.23 10934.16 59.01 15753.43 3823.28 MinPt-O-SF 11207.21 11019.47' 10926.00 59.99 15866.81 3821.28 MinPt-O-ADP 11206.4 11019.3 10926.07 60.08 1587727 3820.97 MinPt-O-EOU I 11206. 11019.63 10926.66 6027 15899.36 3820.25 MinPt-CtCt 11215.39 11029.60 10937.23. 60.68 16105.53 3810.13 MinPt-O-SF 11312.69 11124.30 11030.78 60.48 1679043 3811.90 MinPt-O-SF 11381.30 11186.25 11089.46 58 79 17311,73 3818.83 MinPt-O-SF L9914.071 9679.571 9563.65 42 75 19727.98 3747.41 MinPts 5102-SE6(P2)(Def Plan) ;'F. ,'.9'-',"i.7,'917(''''''-'''''--'1';':...-; '1.'1- Pgil)i 17848.12 17843 48 17815.31 5214.82 400.53 400.53 MinPt-O-SF 17842.7 17838. 17809.89 5192.15 457.63 457.63 MinPts 17842.7 17838.0 17809 89 5182.83 459.54 459.54 MinPt-O-EOU 17841.50 17840.28 17808.69 N/A 0.00 0.00 Surface 17841.5 17838.95 17808.6 13394.91 198.80 198.80 MinPts 17841 70 17838.73 17808 89 10222.83 238.80 238.80 MinPt-O-EOU 10228.77 10065.50 9984.80,M. 8 12859.22 3815.55 MinPt-O-SF 11 •EE 1 10066.97 9980.73 59.37 13507.57 3814.23 MinPt-CtCt 10242.07 10065.0' 9977.13 58.24 13604.82 3819.74 MinPt-O-EOU 10244.18 10065.•: 9976.6 57.67 13636.86 3821.52 MinPt-0-ADP 10121,62 9927.51 may;, 52.45 10447.26 3845.61 MinPt-O-ADP 10119. ;X16 9831.51 52.95 10466.88 3846.64 MinPt-O-EOU 9928.90 9835.28 54.03 10507.07 3848.63 MinPt-C1Ct 6409.81 6201.14 6098.69 31.26 18704.69 3774.88 MinPt-CIC1 6409.91 6201.07 6098.54 31.24 18707.33 3774.77 MinPt-O-EOU 6409.97 6201.08 6098.52 31.23 18708.23 3774.73 MinPt-O-ADP 6476.93 6263.29 6158.45' 18804.94 3770.49 MinPt-O-SF 8809.15 8568.85 8450.35 37.16 19980.65 3740.24 TD 10213.17 10012.82 9913.1,®j 14768.53 3852.98 MinPt-O-SF 10090.89 9896.06 9799.1- 15152.68 3836.58 MinPt-O-SF 10017.09 9825.41 9730.1-® 15753.54 3823.26 MinPt-O-SF 10004.62 9815.7•,..' 53.35 15871.16 3821.15 MinPt-O-ADP 10004.3.1' 9722.07 53.43 15882.58 3820.81 MinPt-O-EOU 10004.0:1 9815.88 972251 53.57 15901.62 3820.17 MinPt-CtCt 10012 18 9824.67 9731 76 53.87 16107.39 3810.03 MinPt-O-SF 10104.36 9914.28 9820.30 53 7 16799.86 3811.91 MinPt-O-SF 1018330 9988.83 9889.71 52 4 17312.55 381834 MinPt-O-SF M 8813.411_ 8573,121 845462 371 19980.64 3740.24 MinPts SP04SE5(P2)(Def Plan) Pass 1784417 17839.54 17811 36 5234.25 400.46 400.46 MinPt-O-SF 17843.1 17838.56 17810.36 5274.69 429.02 429.02 MinPts 17843.1 17838.56 17810.36 5272.88 430.92 430.92 MinPt-O-EOU 17842.86 1784164 17810.05 N/A 0.00 0.00 Surface Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP14-S3\OP14-S3\0P14-S3(P5b) 3/31/2011 9:09 AM Page 10 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft),EOU(ft) Dev.(ftL Fact. MD(ft) I TVD(ft) Alert I Minor I Major I 17842.86 17839.27 17810.05 7547.68 298.80 298.80 MinPts 17843.071 17839.07 17810.26 6426.62 338.80 338.80 MinPt-O-EOU 9045.04 8880.93 8800.091% 12882.24 3815.50 MinP1-OSF 9059 55 8885.52 8799.44 52.61 13520.26 3814.87 MInPt-CtCt 8883.72 8795.97 51.62 13819.71 3820.57 MinPt-O-EOU 9062.88 8884128888 51.14 13653.22 3822.41 MinPt-O-ADP 8928.39 8733.82 8637 38 46.28 10438.56 3845.15 MinPt-O-ADP 8926.2 Ogiagm 8637.82 46.70 10459.21 3846.24 MinPt-O-EOU =TM 8734.99 8641.14 47.53 10498.45 3848.21 MinPt-CtCt MEM 6110.17 6006.25 30.40 18795.58 3770.90 MinPt-CtCt 6322.03 6110.04 6005.99 30.36 18802.34 3770.60 MinPt-O-EOU 6322.18 6110.07 6005.95 30.34 18805,55 3770.46 MinPt-O-ADP 6529.02 6303.21 6192.418888888 ! 19251,36 3755.26 MinPt-O-SF 7528.42 7287.49 7168.95 31.74 19977.80 3740.37 TD 9016.67 8819.34 8721.16 45.9 14768.10 3852.98 MinPt-O-SF 8906.31 8713.52 8617.7 46.4 15152.10 3836.62 MinPt-O-SF 8841.82 8651.08 8556.53 46.7 15753.05 3823.26 MinPt-O-SF 8832.36 8643.888 8550 591 47.33 15858.22 3821.52 MinPt-O-ADP 8832 07 5643.071 8550.66 47.39 15869.32 3821.21 MinPt-O-EOU 1831 89f 8644.00 8551.04 47.50 15887.35 3820.66 MInPt-CICt 884149 8654.44 8562.03® 16107.27 3810.04 MinPt-O-SF 8933.69 8743.96 8650 43 Mara 16799.39 3811.90 MinPt-O-SF 9000.03 8804.16 8888[ 46.59 17308.05 3818.78 MinPt-O-ADP 9000.15 8804.21 8707.6 46 58 17312.18 3818.83 MinPt-O-SF =Ma MEM IffillErg=n1ra 19977.79 3740.37 MinPts 8107.564(P2)(Def Plan) Pass 17852.95 17848 31 17820.1 5229. 400.54 400.54 MinPt-O-SF 1 17846.911 17842 251 17814.1 5192.35 459.34 459.34 MinPts 17845.71 17844.49 17812.90 N/A 0.00 0.00 Surface 17845.71 17843.16 17812 90 13405.01 19080 198.80 MinPts 17845.9 17842.9 1781311 10255.10 238.80 238.80 MinPt-O-EOU 7813.40 7645.82 7563.6.® 12882.33 3815.50 MinPt-O-SF 7654.30 7567.80 45.24 13492.77 3813.53 MinPt-CtCt 7831.2r mum. 7563.93 44.34 13810.21 3820.04 MinPt-O-EOU 7833.35 7652 6:M7IM11. 43,91 13649.23 3822.20 MinPt-O-ADP 7718.52 752231.1Inni 39.83 10454.17 3845.98 MinPt-O-ADP 7716.561 985W52 7425.85 4016 10474.97 3847.05 MinPt-O-EOU MUM 7523.44 7428.99 40.83 10515.43 3849.02 MinPt-CtCt 111= 6105.58 6000.93 30.17 18911.23 3766.75 MinPt-CtCt 6318.98 6105.31 6000.43 30.10 18927.13 3766.22 MinPt-O-EOU 6319.28 6105.37 6000.36 30.07 18935.23 3765.94 MinPt-O-ADP 6639.82 6398.51 6279.96 8888888 48 20005.57 3739.10 MinPt-O-SF 6920.16 667456 6553.85 28.65 20179.11 3731.19 TD 7771.93 7574.46 7476.3 39.61 14768.36 3852.98 MinPt-O-SF 7664.31 7470.44 7374.''mom 15153.34 3836.53 MinPt-O-SF 7598.37 7406.15 7311.2 ■ 40.01 15752.82 3823.27 MinPt-O-SF 7586.75��1 7397.01 7303.53 40.55 15877.65 3820.96 MinPt-O-ADP 7588.4 7398.9-71 7303.60 40.61 15889.97 3820.57 MinPt-O-EOU 8 7586.2 7397.17 7304.02 40.71 15909.98 3819.87 MinPt-CtCt 7592.44 7403.77 7310.92 40.87 1610529 3810.14 MinPt-O-SF 7671.62 7480.54 7386.71 40.86 16799.54 3811.90 MinPt-O-SF 7743.92 7546.97 7450 26 40.02 17313.10 3818.85 MinPt-O-SF 6922 451 6676.86 6556.14, 28.66 20179.10 3731.19 MinPts SP10-F85(P2)(Def Plan) Pass 17854.40 17849.79 17821.5 5271.1 400.53 400.53 MinPt-O-SF 17849.11 17844.46 17816. 5209.25 457.35 457.34 MinPts 1784011 17844. 17816.30 5199.17 459.24 459.24 MinPt-O-EOU 17847.92 17846.70 17815.11 N/A 0.00 0.00 Surface 17847.9 17845.3 17815.11 13410.16 198.80 198.80 MinPts 17848.11 17845.16 17815.31 10284.75 238.80 238.80 MinPt-O-EOU 1 6208.90 5985.79 5876.30 28.33 19281.85 3754.91 MinPt-CtCt 6209.12 5985.281 5875.42 28.24 19289.79 3753.98 MinPt-O-EOU 6209.39 5985.32 5875.36 28.22 19298.86 3753.71 MinPt-O-ADP 6413.23 6167.52 6046.81 26.5 20227.29 3728.99 MinPt-O-SF 6759.74 6492.93 6361.61 25.72 21239.92 3660.30 MinPt-O-SF SP05-FN7(P2)(Def Plan) -). =''' Pass 17850.44 17845.80 1781764 5220 4611 400.53 400.53 MinPt-O-SF 17844.7 17840. 1781193 5187.93 459.44 459.44 MinPts 17844.7 17840.5 17811.94 5178.02 461.34 461.34 MinPt-O-EOU 17843.53 17842.31 17810.72 N/A 0.00 0.00 Surface 17843.5 17840.9 17810.7 13399.88 198.80 198.80 MinPts 17843.7 17840.7 17810.93 10241.78 238.80 238.80 MinP1-0-EOU 1 6326.87 6114.18 6009.79 30.28 18860.38 3768.47 MinP1-01Ct 8327.08 6114.001 6009.43 3023 18871.77 3768.09 MinPt-O-EOU 6327.33 6114.05 6009.38 3020 18878.72 3767.85 MinPt-O-ADP 6436.04 6210.49 6099.81 29.06 19302.44 3753.62 MinPt-O-SF 6647.97 6413.35 6298.17 28.84 19689.97 3747.94 MinPt-O-SF 6762.09 6522.53 6404.84 28.71 19913.88 3743.29 MinPt-O-SF 7383.85 7124.24 6996.42 28.87 20887.91 3697.50 MinPt-O-SF 7634.05 7367.33 7235.91 29.03 21239.92 3660.30 TD SI08-FN6(P2)(Def Plan) - Pass 17847.66 17843.04 17814.851 5256 21 400.46 400.46 MinPt-O-SF I17846.711 17842 111 17813 9 5283.77 428.94 428.93 MinPts 17846.41 17845.18 17813.60 N/A 0.00 0.00 Surface 17846.41 17842.8 17813.6 7552.45 298.80 298.80 MinPts 17846.61 17842.61 17813.80 6444.74 338.80 338.80 MinPt-O-EOU 1 6216.65 5997.09 5889.36 28.83 19091.82 3760.65 MinPt-CtCt 6217.42 5996.291 5887.80 28.63 19145.37 3758.84 MinPt-O-EOU 6218.30 599047 5887.631 28.55 19169.66 3758.02 MinPt-O-ADP Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP14-S3\OP14-S3\0P14-S3(P5b) 3/31/2011 9:09 AM Page 11 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(86) I TVD(ft) Alert I Minor I Major 6606.53 6360.73 6239.96k 27.33 20226.45 3729.03 MinPt-O-SF 7120.81 6853.83 6722.38 27.07 21239.92 3660.30 MinPt-O-SF Nikaitchuq 3PB1(Def Survey) u§ s 4„1y ?:ti ,,_; ,' 1: *r,; Pass 16512.85 18510 88 18480 0 I 379979.58 51.00 51.00 MinPts 18513.651 18509 91 18480.84 10151.17 25880 250.80 MinPt-O-EOU I 18514.71 18509 05 18481.901 4950.30 504.79 504.77 MinPts 18514.71 18509.05 1848190 4944.13 506.48 506.47 MinPt-O-EOU I 10917.98 10751.65 10670.57 67.30 14950.52 3850.15 MinPt-CtCt 10918.03 10751.611 10670.49 67.27 14951.36 3850.11 MinPt-O-EOU 10918.07 10751.61 10670.48 67.26 14951.68 3850.10 MinPt-O-ADP 10933.95 10766.89 10685.'•'•11 67.11 1495884 3849.73 MinPt-O-SF r 11548.74 11384.27 11303.76 71.70 15024.58 3846.18 TD I 10880.91 10816.83 85.81 13462.58 3812.26 MinPt-CtCt 11013.88 0880 8,1 10816.81 85.89 13462.90 3812.27 MInPt-O-EOU 11013.89 10880.941 108 85 89 13463.01 3812.27 MinPt-O-ADP 12037.30 10915 .69 1010,_ �' 13483.77 3813.12 MinPt-O-SF 13585.35 3818.62 MinPt-O-SF 11004.2 10883,97 10826.35 95.46 12883.71 3815.18 MinPt-CtCt 11004.2 10883 961, 10826.34 95.45 12883.88 3815.18 MinPt-O-EOU 11004.24 10883.96 10826. 95.44 12883.96 3815.17 MinPt-O-ADP 11041.91 10920.69 10862.5 9496 12897.42 3814.97 MinPt-O-SF 12006.58 11883.51 11822 7 98.8 13574.42 3817.98 MinP1-OSF Nikakchuq 3PB2(Def Survey) ® 18510 0.8 18481.94 51.00 - -1 1�� -� 8 �� i1 �_ 88 18480 0 379979 58 51.00 51 00 MinPts 18513 65 18509 91 18480.84 10151 17 250.80 250.80 MinPt-O-EOU 4950.30 504.79 504.77 MinPts 18514.71 18509..: 18481.90 4944.13 506.48 506.47 MinPt-O-EOU 10917.98 10751.65 10670.57 67.30 14950.52 3850.15 MinPt-CtCt 10918.03 MI= 10670.49 67.27 14951.36 3850.11 MinPt-O-EOU 10918.07 10751.61 10670.48 67.28 14951.68 385810 MinPt-O-ADP 1 10933.95 10766.89 10685.44®' ' 14959.84 3849.73 MinPt-O-SF 11548.74 11384.27 11303.76 71.70 15024.58 3846.18 TD I 11013.87 10880.91 10816.83 85.91 13462.58 3812.26 MinPt-CtCt 11013.'8"17 10880.81 10816.81 85.89 13462.90 3812.27 MinPt-O-EOU 11013.89 10880.9 10816 10816 81 I 85 89 13463.01 3812.27 MinPt-O-ADP 11049.66 10915.69 10851.08 85.47 13483.77 3813.12 MinPt-O-SF =M EE' 10883.97 10826.35 95.46 12883.71 3815.18 MinPt-CtCt 11004.2 IIMM 10826.34 95.45 12883.88 3815.18 MinPt-O-EOU 11004.24 10883.e:EITEM 95.44 12883.98 3815.17 MinPt-O-ADP 11041 91 10920.69 10862. :WE 12897.42 3814.97 MinPt-O-SF 11977.0 IMMO 11793 09 98.52 13573.84 381784 MinPts 11996 90 11873.42 1181248 MIZE 13584.31 381856 MinPt-O-SF Nikaitchuq 3PB3(Def Survey) s, -;, ,,a .-„ I.„ : 4; " ,y r' SM - .5 4' 1®.1 18510.8: 8480 0.1 379979.58 51.00 51.00 MinPts 18513.6 I 18509.91 18480.84 10151.17 250.80 250.80 MinPt-O-EOU FlEaCHIn 18509.4 NI= 4950.30 504.79 504.77 MinPts 18514.71 18509.0 18481.90 4944.13 506.48 506.47 MinPt-O-EOU 10917.98 10751.65 10670.57 67.30 14950.52 3850.15 MInPt-CtCt 10918.03 mcgm 10670.49 67.27 14951.36 3850.11 MinPt-O-EOU 10918.07 10751.61 10670.48 67.26 14951.68 3850.10 MinPt-O-ADP 10933.95 10766.89 10685.44®' ' 14959.84 3849.73 MinPt-O-SF 11548.74 11384.27 1130176 71.70 15024.58 3846.18 TD 11013.8 10880 91 10816.83 85.91 13462.58 3812.26 MinPt-CtCt 11013.8 10880.89- 10816.81 85.89 13482.90 3812.27 MinPt-O-EOU 11013.89 10880.90, 10816.81 85.89 13463.01 3812.27 MinPt-O-ADP 11049.66 10915.69 10851.0 85 471 13483.77 3813.12 MinPt-O-SF 11899.35 11837. 97 90 13584.93 3818.59 MinPt-O-SF 10883.97 10826.35 95 46 12883.71 3815.18 MinPt-CtCt 11004.2.Ma= 10826.34 95.45 12883.88 3815.18 MinPt-O-EOU 11004.24 10883.98 10826.3'' 95.44 12883.98 3815.17 MinPt-O-ADP 11041.91 10920.69 10862.58 M 12897.42 3814.97 MinPt-O-SF 11984.48 11860.34 11799.08 5:�' 13573.98 3817.95 MinPt-O-SF NikatChuq 3(Def Survey) Pass C: :6. 18510.88' 18480.0• 379979.58 51.00 51.00 MinPts 18513.6 18509.91 18480.84 10151.17 250.80 250.80 MinPt-O-EOU MEMO 18509.05 18481.90 4950.30 504.79 504.77 MinPts 18514.71 18509.0 1 18481.90 4944.13 506.48 506.47 MinPt-O-EOU 10917.98 10751.65 1067657 67.30 14950.52 3850.15 MinPt-CtCt 10918.4 Emu 10670.49 67.27 14951.36 3850.11 MinPt-O-EOU 10918.07 10751.61 10670.48 67.28 14951.68 3850.10 MinPt-O-ADP I 10933.95 10766.89 10685.44 14959.84 3849.73 MinPt-O-SF 11548.74 11384.27 11303.76 71.70 15024.58 3846.18 TD C1013.87 10880.91 10816.83 85.91 13462.58 3812.26 MinPt-CtCt 11013.8",11 10880.891 10816.81 85.89 13462.90 3812.27 MinPt-O-EOU 11013.89 10880. 10816.81 85.89 13463.01 3812.27 MinPt-O-ADP 11049.68 10915.69 10851.08 85.47 13483.77 3813.12 MinPt-O-SF 12901.28 12803.91 12756 03 134.721 11294.79 3868.46 MinPt-O-SF 12761.79 12661.81 12612 63 129.72 11687.17 3882.51 MinPt-O-SF 12023.76 11899.35 11837 95 97.90 13584.93 3818.59 MinPt-O-SF '�" 1 10883.97 10826.35 95 46 12883.71 3815.18 MinPt-CtCt 11004. M.1 10826.34 95 45 12883.88 3815.18 MinPt-O-EOU 11004.24 10883.96 10826 3, 95.44 12883.96 3815.17 MinPt-O-ADP 11041.91 10920.69 10862.58 94.96 12897.42 3814.97 MinPt-O-SF 11984.48 11860.34 11799 08 97.80 13573.98 3817.95 MinPt-O-SF Nikaitchuq 4PB1(Def Survey) Pass 18553 04 18551 081 18520 231 381434.50 51.00 51.00 MlnPis 18553 58 18550.73 18520.77 19852.66 165.92 165.92 MinPt-O-EOU MIMI 18550 13 me71 4972.25 51740 517.38 MinPts Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP14-S3\OP14-S3\OP14-S3(P5b) 3/31/2011 9:09 AM Page 12 of 13 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ftL Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 18555.79 18550.11 18522.98 4931.47 522.96 522.94 MinPt-O-EOU I 11159.17 11044.56 10989.78 101.80 12530.32 3830.00 MinPt-CtCt 11159.19 1104451 10989.72 101.75 12531.90 3829.93 MinPt-O-EOU 11159.22 11044.5 10989.711 101.73 12532.54 3829.90 MinPt-O-ADP 11299.25 11181.39 11124.'9"57 99.881 12854.69 3823.94 Min Pt-O-SF 11192.5 11054.30 10987.46 83.69 13638.14 3821.59 MinPt-CtCt 11192.5 11054.29 10987.45 83.69 13638.28 3821.60 MinPt-O-EOU 11192.59 11054.2 10987. 83.68 13638.35 3821.60 MinPt-O-ADP 11208.31 11069.45 11002.32 82,1 13646.96 3822.07 Min Pt-O-SF 11131.841 10966.17 10885.36 68.85 14860.95 3852.77 MinPt-CtCt 11131.85 10966.161 10885.35 68.85 14861.05 3852.77 MinPt-O-EOU 11131.85 10966.16 10885.34 68.85 14861.10 3852.77 MinPt-O-ADP 11142.95 10976.83 10895.79 68.731 14866.58 3852.67 Min Pt-O-SF 11712.82 11549.60 11469.71 73.28 14926.73 3851.07 TD Nikaitchuq 4(Def Survey) .'i'- -+- - 1, ® 18551 08 Ma= 381434.50 51.00 51.00 MinPts 1855358® 18520.77 19852.65 165.92 165.92 MinPt-O-EOU 8550 13 El Mal 4972.25 517.40 517.38 MinPts 18555.79®0 ' 18522.98 4931.46 522.96 522.94 MinPt-O-EOU 11299.25 11181 39 11124.8 ME= 12654.69 3823.94 Min Pt-O-SF I 11206.12 11069.65 11003.75 84.99 13585.99 3818.65 MinPt-MCI 11206.33 11069.56 11003.52 84.80 13593.30 3819.08 MinPt-O-EOU 11206.71 11069.6 11003.431 84.60 13600.97 3819.52 MinPt-O-ADP 11211067.00 11000.09 83.69 13636.07 3821.48 MinPt-CtCt 05.466 11066.9' 11000.04 83,66 13637.25 3821.54 MinPt-O-EOU 11205.48 11066.9' 11000 04 83.65 13637.63 3821.57 MinP1-0-ADP 11215.59 11076.68 11009 51 83.451 13648.31 3822.15 Min Pt-O-SF 11206.33 11070.5 I 11005 05 85.47 13558.03 3817.01 MinPt-O-ADP MEM 11059.16 NE= 100.47 12586.83 3827.25 MinPts 10933.96 10851.24 67.09 15182.33 3834.42 MinPt-CtCt 11103.7,MIERE ECM 67.08 15185.00 3834.23 MinPts 11130.62 10959.76 10876.: 66.86] 15333.73 3827.04 Min Pt-O-SF 11356.94 11178.86 11092.0 15753.36 3823.26 Min Pt-O-SF 11870.48 11687.29 11597.•0 M2:31}% 16106.38 3810.08 Min Pt-O-SF 12202.32 12016.92 11926.40 67.37 16272.91 3804.76 TD Nikaitchuq 1(Def Survey) Pass 11500.96 11365,33 11299.67 87.55 13595.26 3819.19 MI1Pt-CtCt i 11500.97 11365.32 11299.661 87.54 13595.67 3819.21 MinPts 11510.40 11374.52 11308.7 87.421 13610.35 3820.05 Min Pt-O-SF 11368.70 11310.65 98.92 12877.42 3815.27 MinPt-CtCt 11489.3'Emma 11310.63 98.91 12878.20 3815.26 MinP1-0-EOU 11489.41 11368.6'mg= 98.90 12879.00 3815.25 MinPt-O-ADP I 11417.251 11250.60 11169.15 70.06 15004.31 3847.42 MinPt-CtCt 11417.26 11250.60 11169.14 70.06 15004.70 3847.40 MInPt-O-EOU 11417.28 11250.60 11169.14 70.05 15005.10 3847.38 MinPt-O-ADP 11456.84 11289.05 11207.07 69. 15050.21 3844.42 MinPt-O-SF 11541.39 11371.52 1128851 69.50 15152.45 3836.59 MinPt-O-SF I 16124.34 15950.07 15863 74L 93.3 16113.17 3809.73 MinPt-O-SF Nikaitchuq 2(Def Survey) Pass 19100.59 19095.75 19067.7 6538.49 433.36 433.36 MinPts 19100.85 19095.49 19068.04 5548.63 559.03 558.97 MinPt-O-EOU 19101.5 17 9095.16 19068.76 4250.78 670.06 669.62 MinPt-O-EOU 19102.35 19095.15 19069.54 3618.45 717.39 716.61 MinPt-O-EOU 19318.09 19294.80 1928411 903.69] 1957.99 1862.89 MinPt-O-SF 111:1M 19116.9 19106.40 909.40 2049.70 1942.84 MinPts 19167.38 19144.31 19133.73 905.691 2091.12 1978.60 MinPt-O-SF 19196.12 19173.00 19162.40' 2116.71 2000.57 MinPt-O-SF imam=RIM INCEM 159.13 9416.26 3777.84 MinPts 14432.89 14338.35 14293.02=I= 9417.32 3777.93 MinPt-O-SF I 18718.27 18813.22 18561.5 =am 9833.29 3808.48 MinPt-O-SF Kigun 1 PB1(Def Survey) Ar,x.r,r--' 1,h, Pass 17134.55 17131 83 1710174 21413.27 162.14 162.14 MinPts 17134.70 17131.71 17101.89 16061.53 197.17 197.17 MinPt-O-EOU L17136.18 17131.25 17103 371 5677.71 456.38 456.38 MinPts 17136.19 17131.24 17103.38 5655.37 457.97 457.97 MinPt-O-EOU 17140.21 17134.86 17107.40®• ' 510.18 510.16 MinPt-O-SF Tuvaaq ST 1(Def Survey) 17134.55 17131.83 17101.74 21413.27 162.14 162.14 MinPts 17134.7 17131.71 17101.89 16061.53 197.17 197.17 MinPt-O-EOU I 17136.1 17131.2 17103.371 5677.71 456.38 456.38 MinPts 17136.19 17131.24 17103.38 5655.37 457.97 457.97 MinPt-O-EOU 17140.21 17134.86 17107.40 4987.05 510.18 510.16 MinPt-O-SF Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP14-S3\0P14-S3\OP14-S3(P5b) 3/31/2011 9:09 AM Page 13 of 13 Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP 14-53 Oriented EOU Dimension Field: Nikaitchuq .N NoGo Region Anti-Collision rule used: Structure: Oliktok Point Minor Risk-Se,aration Factor • ' = Date: March 31,2011 ','.. 0-2000 and North 350 0 10 4 A-di#lk ipsm,ol at, 3W,1'IS MZ-.d.W 330 , �� , �s 30..i_ •• 2-01 IT IM 320 '4.11 4.. ,l' ,'/, 93, ', 40 310 � , �` ��, 11 ► 1,W441 70 ,'450 P40 41,111; /I<5 11,x' ri i 300 � VOW_'� \\ �� l ��` -,,�� ll,��,r��%��i�!ie�' 60 _44A —�� \\41 1` r� �► `�� lea';__./r:;`,�' �P09-S1 (P3b) 290 ‘•44411111411024 1 tik40144S,A.,i,;$,::::SATN6-(31 )111 trWillaTilli /01 -"Ic4.,%°' C*-Y-Att.. 280 .m \7 ��',1 •, �,��`,' 80 Pi. p-1 „,„ia„. INssoiw ii W Nl6i ♦4 270 jprc* 6LI 260 Vi 4 •\`• i,=,lS atiVy�1 cZ' ., 100 50 /�� –Q(►5 ► w . ►/ `1 ` 110 2a�� .l��►��®'��s`I o°j 120 23k:14■lA1 a1,_1, k,�, •%` 42l14Iw, •'1 130 220 V`ht. :,4 4�-tp4 r A 140 210 `/�/"�,00 —e�� 10111050 200I�,1,,��` 160 1• '• .__ 17(1 Well Ticks Type: MD on OP14-S3(P5b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=20.00 ft Schlumberger 1RAVII.ING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP 14-S3 Oriented EOU Dimension Field: Nikaitchuq N NoGo Region Anti-Collision rule used: Structure: Date: Oliktok Point Minor Risk-Separation Factor Date: March 31,2011 0-2000 and North 350 0 10 17I 340 �c o �_`, 20 330+,/1.'_�i"��-��2.lrl!f�` ,.∎��,0�30 th 10 A v1��j "isi�-ip Vi,m,.._ 320 • i ,�� I ∎V:•1 a∎�� .�V4IPAVAt• 40 44 lowlklb,--,..,-.444;ii,•irlirfit.-‘-:_mria 4-....... e _4.6 k.—A0 ir' laV 4*.Aki , l}► �I�V , 310 , 10•�rE •d► jt Itti��4i t ��*4 1,Allif;gii* ..�a Pi'.,i, 50 t, �,� i�.� 6° a;x!//11 �� / �;. =�� 08-04P B1 fr ` `9r r 4. 48;410 ♦ t011',I• i .11 ••�♦ e•` �� 11I6-S604 0.,it,a'�° ! 4�� ,i► fila �/��,:,111-01PB1 300 1.4 1 �I;∎it �I�i i%:� "� 0.e1 A t$'41 I,> t .. � i ' �I `fit! ` FR011 07PB1 lipt ♦.,,-: t��.t„fli pl t AP y 'irk it, 'F !„!,: ` • `�� al\��►�'., :I`*t �i��1Q �. as� i �Ip00FlB1'1A 106(P5) .��,Ta 1 /r afe ii :: �'.�P09 S1 (P3b) 290 r r .♦�...' 1 .Ih1Z atrtIri1��f j�Q,4ja' �")�,,L 11. -":"ri►.� ■ 70 J' ...114 ,.,, -1 .. tip,.., , 1___,./. 280 �� ,, �QIV" ��/� \\I ! �W \' ��\i�I♦� ��e 1�",:' '�J7�'. 04 liEt W AMIN\ Acw.-4,svkiii!.7,270 IiI&1. 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II Nip iik .4,401t, • -„. .-.,. .,,,,,.4,,...44, ...., ,r /,4':-it:,;aim.- 4i::■:'\ A Vr /LOP'"f■lif 41 ,E'!�,sik.�- �„,,,„4 'v ,1` , ,''+��► �� N' v.--*,fly*,4,4f,w,,,,.4...,..„ 1, �,;,s;I(i rig ,�11� ��,.,� �0.•240 �;` ��i�11tar�I® �� 3!''. �i \,1 �\\� \�. 120 tit 2 30 ■ W� �� `'�lifk.*--..___ u=►'i��1 i v'Ain",�viii* - 130 ill 22N j . -wt..AO 111 $I,4.4k li�'4``of 44" g123-WW02 210 -��I III\14 „0.9,-,404 Ato,i 150 20�t larfr� �F∎� �0 160 190 187 ••r•r:•. , .1(P2) Well Ticks Type: MD on OP14-S3(P5b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP 14-53 Oriented EOU Dimension Field: Nikaitchuq N Structure: Oliktok Point NoGo Region Anti-Collision rule used: Minor Risk-Separation Factor • '' Date: March 31,2011 mirr'4 �I 2000 MD-TD L North 1 350 0 10 340 /.'1/4 `��i1��1oj1�0 r �� j f *:i 11,1 `� ` r�. s'`` 30 330 �� l,\�� 1��1-.11�/% 1 320 � ` �� ..� .r/!' l�.. ca.v o/ 7. '��, i ,P : :15-81P B1 310,... o�i �ir: ;*``� ,,�' 220 `\`.� I ��,.�`"%"-:: �b�r atA ► •: 200 ```.--��e, ., , . -, 300 . v.47►1►t w .a\4 60 Ii..-��`/�,`-`i�1/ •` � . �, � wt�,�/i*%�.Ii�i� P�d �tll��\� Z�'a�s6-DSP02 290 444 f1�A��.rio►�� 4440,4104.-►..-�. � �� f�/�/��i��11►,,��,70 280 $►.T'A�=e 1 Av," i,...,41.4.11'*-- PM 44'\' a,t`� 11' 411ENittlallittfr.vertVie01117 80 -t)- - / ' 4 ktAtiottalot Z * ► 1, I i 60 - �� `y`z"b rrjafkillr#i 40 : .kt ;- @�=®3�®9 270 r rtlw" = ►�=•.� 0 °a ' , i ��`I!,1 t �• �\� l,• 90 11/1&All isrPli-.. *,a. ow -.-4■.,- 'it Vet"Ilk log\'. , yr,4■4■4114%0 VrAt 260 ;. 0: d .v., g__ml,_.u oo/. . `�`k `,' % 100 b N\ItiN iki,kk.„ s.o..--\� ii=irk►► „, \ „ Np,250 i o1la1g 1l1t1P �t Ny;, \ 110 ,.."----S\IrikilM/p 47440/11.11”- it;Alk 40 240.,'1':.1: c.--c,-120.fr* 230 t'Alr 111,1116\ so.A, -1,,`\ ''�4 • y topo......., %'•��` =. f ,��,,,� 140 220 .4t..- ,W„ft, ..°_,,e4,4011,4119,14#,_k/44/ ir#403Stir 210 �/�t�11 lato g � 44 / 901F,0-1.0 150 �s. �` 200 \��\t�1\j 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 8-3/4" 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 Drilling Hazards Summary.doc 2/25/2011 11:02:00 AM I 1114 1 g 0 w ggg O p2 a. 1 1 R Yp O~ Y¢U~ Ogp~ u�~O~ aba ov�,� CO0ZCD pwp p�pCD _ W U 9 k �ZW ZZ --wZ zZ eo �z 2 8 J J Z J ��Ca-z J ��Z J IJJ ro b' �zWwN '�c'oo CD\-Z Zpv M I O I ;''D I cr�L '-',--J a�v C: N CY Z � 0 O L— v�Y c > Y >- cn I o >- w 2 in 2 2 -1 ". ‘' N y v N 7n 1 I N 3: o. m< 0 Lo oaL �_ a s J 1--.-_, h > io p J - W \w Y1 --oi 1 U II I Y, - i - - i - A, r- i — W Z 0 AA a a CC -__I I l! 1 1--__I L _1 I L— O .— _ — 'f' 't' + + ■ in a _ , � r -, r- Q Ft N oo 0 \ , V aNv A a rses I I -- I rV H N _ A o H co 12. _74 14 0 W Z m CL Z 3 O CC w 1 W C:) j 0 La.0 o U C O L, \W v �W CQ, I U 4-U M I li 141 1 W e, _J g j — III IU-- 0 W W ri 41 u. 1! Ji i Eli!■--■n l - Ilu c,CCa ® .,. I I - ,1 ® IJ ° ,,z ., I. O It g I o CO W % - o a 3h%y ti§ !' " il I O `0 i1n M W, h 1 G a X 33 §. A ry o _, <Z ■ • ■ . a z AA -i■ .A z O 1 A i= O Je3 Q �m f CD 111111111 I III I0 c., —_i cc„ a w fir h....Or 0 w LJ- x•111 lc. W' h I 4 1,0,j,s Lo Y h/l1,-,I3 I t awl y 0 o swill I . „_ __, ., , _ _. _, . . ,. , , , , , _ 7 . „ . . . . . . _ . , ... . ___. . .. . ... .. . _ _____ _.... . ._. _ _ ____.. .. ._, ,. ... ,... ____ . ... ...., .. _ ___. . . . . . ...,.., lL m v._, „, . .. ,,,, ,.. , ....., .. ,i_.i ,. N Cr) „ ,,.,._.,... . .,.. ... . ... 100. , ,- , . 7----,, ,,,,,,,, ..-.-- , -r..,,,,,,i,,, ., Lo•,..... ,, , . __ . \f a k •.,■\ ',..... .,-, 0 �i�, , �`. \ r . _ r_r,,,T.. . , -ili, • ,1111L....\1M\ ,. Ititi�� w ' \V ,_ CD C7 D o .;,r d as as N a © ' a)coD C C C cc „ O O O O ` p 12 �. O a) a) U (a J ca ca ca 3 , 0 U U u) IS , , .474; . fp....., tik, r•-■■ . .. „_...., 0 0 0 0 0 -..,,: 0 as CI r r r a) co V T r T T- 0 \ \ T \ > c ca a) T i. 0 4 N 4 M "c) m dim,” N Q > O T . C0 � C) = ca >+ c >, m y, crt t, a) 2E = E . J E O N O O I N Q U Z cc Z T _,__ _ D , ,_,_ o _...._. ,,,, .,,, '. _.'• .....„.,..' w Schlumberger CemCADE*well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : OP14-S3 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Joe Longo Location : North Slope-Alaska Proposal No. : Draft v2(P5b) Service Point : Prudhoe Bay,Alaska Date Prepared : 04/06/2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1©slb.com zl C 14UATE Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,maybe improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger Client : Eni Petroleum Well : OP14-S3 S hlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2321.2 ft BHST : 38 degF Bit Size : 16 in ft (x 1000) psi 0D 20.in ° © ft 0 fl 5 1.0 1.5 — 160 _ _ _ — Pore — — — Pore ' —- Siltstone—_ i • . o_ OD13.4in " " " " " " ' ° f�2321it --Siltstone _ ! Ili • • . . . . .Sandstone • • til • • • • • • • • • • • • • • ° ° LC 12241 ft (-4 Coal Shale 4 o ! ti o c,,_ Well Lithology Formation Press. Page 2 op14-s3 cade v1 4-6-11.cfw;04-06-2011; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 Si Imierier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 2241.0 ft Casing/liner Shoe MD : 2321.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2321.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 188.0 % Mean OH Equivalent Diameter: 20.023 in Total OH Volume : 841.8 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 1900.0 16.000 225.0 20.724 2321.0 16.000 35.0 16.822 2321.2 16.000 0.0 15.995 Page 3 op14-s3 cade v1 4-6-11 cfw:04-06-2011; LoadCase Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 SriImilirier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 35 deg Max. DLS : 3.512 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 305.0 0.000 100.0 100.0 0.0 305.0 0.000 200.0 200.0 0.0 305.0 0.000 300.0 300.0 0.0 305.0 0.000 400.0 400.0 0.0 305.0 0.000 500.0 500.0 1.5 305.0 1.500 600.0 599.9 4.3 305.0 2.750 700.0 699.4 7.0 305.0 2.750 703.1 702.4 7.1 305.0 2.903 800.0 798.3 9.8 305.0 2.745 900.0 896.4 12.5 305.0 2.750 961.5 956.2 14.2 305.0 2.748 1000.0 993.5 15.3 305.0 2.753 1100.0 1089.3 18.0 305.0 2.750 1200.0 1183.6 20.8 305.0 2.750 1237.5 1218.6 21.8 305.0 2.747 1300.0 1276.2 23.5 305.0 2.752 1383.4 1352.0 25.8 305.0 2.747 1400.0 1367.0 25.9 305.0 0.541 1500.0 1456.8 26.4 305.0 0.500 1600.0 1546.1 26.9 305.0 0.500 1700.0 1635.1 27.4 305.0 0.500 1769.9 1697.1 27.7 305.0 0.501 1800.0 1723.7 27.9 305.0 0.498 1900.0 1811.9 28.4 305.0 0.500 1945.6 1852.0 28.6 305.0 0.483 2000.0 1899.6 29.3 308.7 3.502 2100.0 1986.2 30.8 315.0 3.498 2139.6 2020.1 31.4 317.4 3.512 2200.0 2071.3 32.5 320.8 3.500 2300.0 2154.7 34.5 326.0 3.499 2321.2 2172.1 35.0 327.0 3.486 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 703.0 11.00 8.43 SV-4 Siltstone 962.0 11.20 8.43 SV-3 Sandstone 1237.0 11.50 8.43 SV-2 Siltstone 1770.0 11.80 8.43 SV-1 Sandstone 1900.0 12.00 8.43 Permafrost Base Shale 2140.0 12.30 8.43 Ugnu Top(UG4) Coal 2321.3 12.50 8.43 TD Shale Page 4 op14-s3 cade v1 4-6-11.cfw;04-06-2011; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 60 0.0 1900.0 1811.9 33 -1.5 2321.2 2172.1 38 -1.0 2321.3 2172.2 38 -1.0 ft degF 32 36 40 44 48 52 56 60 64 68 72 76 80 84 o — I - Geoth.FYofile - Tubular Fluids - Annulus O O- r4, O O O O LL7 O O O- N O O u7 - Temp. Profile At 181 min Page 5 op14-s3 cede v1 4-6-11.cfw;04-06-2011, LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 ScIolirler String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost and a competent shoe for drilling ahead. 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 335.5 bbl Total Volume 938.4 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:13.04Ibf/100ft2 Lead Slurry 429.0 1821.0 0.0 10.70 k:1.07E-1 lbf.sAn/ft2 n:0.226 Ty:1.09 Ibf/100ft2 12.5 DeepCRETE 73.8 500.0 1821.0 12.50 k:5.75E-3 lbf.s^n/ft2 n:0.890 Ty:14.35 Ibf/100ft2 Mud 335.5 0.0 9.50 k:8.28E-2 lbf.s^n/ft2 n:0.262 Ty:0.48lbf/100ft2 Static Security Checks: Frac 2 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2030 psi at 2241.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 52 ton • Page 6 op14-s3 cade v1 4-6-11.cfw;04-06-2011; LoadCase Surface Casing:Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 SekIokrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule 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 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4-Drop Bottom Plug Lead Slurry 5.0 429.0 85.8 429.0 80 13-Start Mixing Lead Slurry 12.5 DeepCRETE 4.0 73.8 18.4 73.8 80 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 325.5 38.3 325.5 80 49-Rig Pumps To Displace Mud 3.0 10.0 3.3 335.5 80 Slow Rate/Bump Plug Shut-In 0.0 0.0 5.0 0.0 80 Static period after Placement Total 02:55 938.4 bbl hr:mn End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 0 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2030 psi at 2241.0 ft Burst 4818 psi at 0.0 ft Temperature Results BHCT 59 degF Simulated Max HCT 74 degF Simulated BHCT 74 degF Max HCT Depth 2273.6 ft CT at TOC 67 degF Max HCT Time 02:55:53 hr:mn:sc Static temperatures: At Time 1 (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 67 degF 160 degF Bottom Hole (degF) 74 degF 38 degF Page 7 op14-s3 cede v1 4-6-11.cfw,04-06-2011; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 SeiIliberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing * CemCADE Client :Eni Petroleum Well :OP14S3 String : 13.375"Surface Casing District :Prudhoe Bay,Alaska Country :USA lb/gal ft 8 9 10 11 12 13 o —Hydrostatic —Mn.Hydrostatic ' —Max.Dynanic —Mn.Dynanic —Frac o —Fkre o— U) - of o a E S V e > l" O U)— U t N W J 1e O N E. N i O u O t N— Fluid Sequence Dynamic Well Security o ■MUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 Ibf.s^n/ft2 n=0.420 Ty=13.04 Ibf/100ft2 3 Lead Slurry 429.0 bbl 10.70 lb/gal Herschel:k=1.07E-1 Ibf.s^n/ft2 n=0.226 Ty=1.09 Ibf/100ft2 ■12.5 DeepCRETE 73.8 bbl 12.50 lb/gal Herschel:k=5.75E-31bf.s^n/ft2 n=0.890 Ty=14.35 Ibf/100ft2 ■Mud 335.5 bbl 9.50 lb/gal Herschel:k=8.28E-2 Ibf.s^n/ft2 n=0.262 Ty=0.48 Ibf/100ft2 Total Depth = 2321.2 ft Top of Cement= 0.0 ft 'Mark of Schlumberger Schlumb rpr Page 8 op14-s3 cade v1 4-6-11 cfw.04-06-2011; LoadCase Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 S Metier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ECD simulation at the Shoe: o Depth= 2321 ft_ ri N 0 Hydrostatic Dynamic Frac u) Pore t7_ E O O I O us- III w --T--T--T —T- 0 20 40 60 80 100 120 140 160 180 200 Time(min) ECD simulation at the previous shoe: Depth= 160 ft Fluids at 2321 ft_—__ — co U- I Hydrostatic Dynamic Frac Pore 03 03- V V od c 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 9 op14-s3 cede vl 4-6-11.cfw;04-06-2011; LoadCase Surface Casing,Version wcs-cem461 08 Client : Eni Petroleum Well : OP14-S3 Wrirggr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Temperature Model: al i —r° 1 rd $- 1 v _d P- CD -d fe-1 ■ -d 1 N First Sack Depth I eg (y_1 First Sack p. I� Last Sack Te Tempm . Last Sack Depth _v. R-1 _co. II�� I OD 1104 -N S N 1 6 �— -- —T— —T-- N 0 20 40 60 80 100 120 140 160 180 200 Time(min) Surface Pressure Model: 7=�Calc.pump Press. Cale.WHP QQf c§- I QI - I e a I 81 8_----..„,..... N. 8- 0 r i - r i 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 10 op14-s3 cade v1 4-6-11.cfw;04-06-2011; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 ScIimierger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Returns Rate: rn _ _ Fluids at 2321 ft -O Out -a 00-I r- c0- ia - O 20 40 60 80 100 120 140 160 180 200 Time (min) Anullar Velocity Model: Depth= 2321 ft Ed- •E Annular Velocity _ 8- C O_ O 0 -T--T--T--T-- 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 11 op14-s3 cade v1 4-6-11.cfw,04-06-2011, LoadCase Surface Casing.Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 ScImerger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo. Model : HERSCHEL_B. k :8.28E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.262 Ty :0.481bf/100ft2 Gel Strength :6.40 Ibf/100ft2 MUD Mud Type :WBM Job volume : 335.5 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.041bf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No:3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 1.07E-1 Ibf.s^n/ft2 At temp. : 74 degF n :0.226 Ty : 1.09 lbf/100ft2 Gel Strength : 14.25 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809(100 lb Mix Fluid : 10.367 gal/sk Job volume :429.0 bbl Dry Density : 106.26 Ib/ft3 Yield :2.33 ft3/sk Quantity : 1035.19 sk Sack Weight : 100 lbs Solid Fraction :40.4% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 10.367 gal/sk Page 12 op14-s3 cade v1 4-6-11.cfw:04-06-2011, LoadCase Surface Casing:Version wcs-cern461_08 Client : Eni Petroleum Well : OP14-S3 Sfinkerger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing 12.5 DeepCRETE DESIGN Fluid No:6 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k :5.75E-3 Ibf.s^n/ft2 At temp. :74 degF n :0.890 Ty : 14.35 lbf/100ft2 Gel Strength :49.10 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid :5.175 gal/sk Job volume : 73.8 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :269.40 sk Sack Weight : 100 lbs Solid Fraction :55.0% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid :5.175 gal/sk Additives Code Conc. Function D046 0.129%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Annulus ID: 13.375 in Flow Rate : 8.5 bbl/min - 12.5 DeepCRETE Lead Slurry _-MUDPUSH II ti — Mud u7 t0 O (0 O O I N V7 cL N ltd Lo C O U .0 LLNI- LO M O 15.9 16.0 16.1 16.2 16.3 16.4 16.5 16.6 16.7 16.8 16.9 17.0 17.1 Annulus OD (in) Page 13 op14-s3 cede v1 4-6-11.cfw;04-06-2011; LoadCase Surface Casing,Version wcs-cem461_06 Client : Eni Petroleum Well : OP14-S3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2301.0 ft Casing Shoe :2321.0 ft NB of Cent. Used :33 NB of Floating Cent. :33 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 1961.0 24 1/2 NW-TR-13 3/8-8-TR 3 W304 0.0 1901.0 2321.0 9 1/1 NW-TR-13 3/8-8-TR 3 W304 77.0 2321.0 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) (Ibf) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 Yes ok ft 0 20 40 60 80 100 o Between Cent. + +At Cent. 0 + + O- + +t 0 L t+ L _i 0 U, 0 0 O N O O LU N Well Pipe Standoff Page 14 op14-s3 cade v1 4-6-11.cfw;04-06-2011. LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 6: WELLCLEAN II Simulator ft 40 60 80 100 0 20 - 60 80 100 O 0 20 Std Bet Coverage u_ Std Betw Cent. Mud Contamination erage -. — Uncontaminated Slurry ------r C11.1 ---- "-." —----::: g :— 7----- Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z g g z g 0 o a 0 '._ 200- 200 200- 200 400- •UO d00 AGO s00- 600 600- 600 800- 800 C 800 800 1000- 1000 �. 1000 1000 a 1200- 1200 a n 1200 ` 0200 a • 1400- 1400 o o 1400 '. ,-- --- 1400 o 1600- 1600 1600 - '., 1600 1900- 1800 1900 1800 2000= 2000 2000 2000 2200 2200 2200 2200 _0 o _v e o e # o # # o # z z Mud Q Lead Slurry 111 High = Low 12.5 DeepCRETE 0 MUDPUSH II Medium = None Page 15 opt 4-s3 cade v1 4-6-11.cfw;04-06-2011; LoadCase Surface Casing;Version wcs-cem461_08 Schlumberger CemCAD E* well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : OP14-S3 Country : USA Field : Oliktok Point State : Alaska Prepared for : Mr.Joe Longo Location : Nabors 245E Proposal No. : Draftv2 Service Point : Prudhoe Bay,Alaska Date Prepared : 04/06/2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1 @slb.com OL gCLIRZE Disclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly, Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger Client : Eni Petroleum Well : OP14-S3 Schlumherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 10339.1 ft BHST : 54 degF Bit Size : 12114 in ft (x 1000) psi 00 20.in 0 1 2 3 °- @ 160ft =t • —Siltstone Frac— NI S Pore arrmstsmire ri •••••Sandstone..... M 100 13.4 in @2321ft . . . . . 0 o— • • •Sandstone • • - OD9.62in I (d 10339ft Shale - ..:Sandstone':: ■ ._ __ o o— - tb LC (a�10259 ft •.:Sandstone':: . - — Shale . t. o- ° I 0 Well Lithology Formation Press. Page 2 op14-s3 cade v1 4-6-11.cfw,04-06-2011, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 Sillerger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2321.0 13 3/8 68.0 12.415 Landing Collar MD : 10259.0 ft Casing/liner Shoe MD : 10339.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 10339.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 HYD 523 Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 1392.4 bbl (including excess) Max. Deviation Angle : 87 deg Max. DLS : 3.603 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 305.0 0.000 9500.0 3785.0 85.3 319.6 3.499 9600.0 3792.9 85.7 316.1 3.503 9700.0 3800.0 86.1 312.6 3.498 9789.0 3805.8 86.5 309.5 3.504 9800.0 3806.4 86.5 309.5 0.000 9900.0 3812.6 86.5 309.5 0.000 10000.0 3818.7 86.5 309.5 0.000 10089.8 3824.1 86.5 309.5 0.000 10100.0 3824.8 86.5 309.5 0.000 10200.0 3830.9 86.5 309.5 0.000 10282.5 3835.9 86.5 309.5 0.000 10289.0 3836.3 86.5 309.5 0.000 10300.0 3837.0 86.5 309.5 0.000 10339.1 3839.4 86.5 309.5 0.000 Page 3 op14-s3 cade v1 4-6-11.cfw:04-06-2011; LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 Schlumherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 703.0 11.00 8.43 SV-4 Siltstone 962.0 11.20 8.43 SV-3 Sandstone 1237.0 11.50 8.43 SV-2 Siltstone 1770.0 11.80 8.43 SV-1 Sandstone 1900.0 12.00 8.43 Permafrost Base Shale 2140.0 12.30 8.43 Ugnu Top(UG4) Coal 2321.0 12.50 8.43 Surf. Csg Shoe Shale 2711.0 12.00 8.43 UG-2 Coal 5341.0 12.50 8.43 L Ugnu Sandstone 6712.0 12.50 8.43 Schrader Bluff Shale 7489.0 12.50 8.43 N Seq Top Sandstone 7786.0 12.50 8.43 N Sand Top Sandstone 8266.0 12.50 8.43 N Sand Bottom Sandstone 9196.0 12.50 8.43 N Seq Base Sandstone 10090.0 12.50 8.43 OA Sand Top Shale 10283.0 12.50 8.43 OA Sbl 2 Sandstone 10340.0 12.50 8.43 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1900.0 1811.9 32 0.7 2327.0 2176.9 36 0.7 10340.0 3839.4 54 0.9 ft degF 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 o - I I I - - I I I I I I I I -Geoth.Prof ile -Tubular Fluids -Annulus 0 1 t . I Temp. Profile At 191 min Page 4 op14-s3 cade v1 4-6-Molly;04-06-2011; LoadCase 9-5/8 Intermediate Casing(al;Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 Schlumbergcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 2: fluid sequence Job Objectives: Zonal Isolation, TOC @ 6,786'(1,000'above the"N"Top) Original fluid Mud 9.30 lb/gal k : 5.97E-3 Ibf.s^n/ft2 n :0.616 Ty: 8.86 Ibf/100ft2 Displacement Volume 751.0 bbl Total Volume 1124.2 bbl TOC 6786.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 836.6 5949.4 10.50 k:5.23E-2 lbf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 DeepCRETE 303.1 3553.0 6786.0 12.50 k:1.45E-2 lbf.s^n/ft2 n:0.792 Ty:2.31Ibf/100ft2 Mud 751.0 0.0 9.30 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Static Security Checks: Frac 348 psi at 2711.0 ft Pore 98 psi at 2321.0 ft Collapse 4504 psi at 10259.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 75 ton Page 5 op14-s3 cade v1 4-6-11.cfw,04-06-2011. LoadCase 9-5/8 Intermediate Casing(a):Version wcscem461_08 Client : Eni Petroleum Well : 0P14-S3 ScIliberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) CemCADE Client :Eni Petroleum Well :OP14S3 String :9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA lb/gal ft 8 9 10 11 12 13 -Hydrostatic -Ain.Hydrostatic -Max.Dynamic -tiro.Dynamic -- Frac Fbre ct O E 0 Tr 3 - U C 0 U N 0 0 0 Fluid Sequence Dynamic Well Security ■MUDPUSH II 70.0 bbl 10.50 lb/gal Herschel:k=5.23E-2 Ibf.s^n/ft2 n=0.324 Ty=12.92 Ibf/100ft2 o ■DeepCRErE 303.1 bbl 12.50 lb/gal Herschel:k=1.45E-2 Ibf.s^n/ft2 n=0.792 Ty=2.31 Ibf/100ft2 ■Mud 751.0 bbl 9.30 lb/gal Herschel:k=5.97E-3 Ibf.s^n/ft2 n=0.616 Ty=8.86 Ibf/100ft2 Total Depth =10339.1 ft Top of Cement= 6786.0 ft *Mark of Schlumberger Schlunberpr Page 6 op14-s3 cede v1 4-6-11.cfw;04-06-2011, LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 S hlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 3: pumping schedule 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 70.0 14.0 70.0 80 Spacer Ahead Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Begin Mixing Slurry DeepCRETE 5.0 303.1 60.6 303.1 80 Mix&Pump Cement Slurry(3 to 7 BPM) Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.0 751.0 93.9 751.0 80 Kick-Out Plug Pause 0.0 0.0 5.0 0.0 80 Swap to Rig Pumps Pause 0.0 0.0 5.0 0.0 80 Pressure Test Casing Shut-In 0.0 0.0 1.0 0.0 80 Bleed off/Check Floats Total 03:09 hr:mn 1124.2 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 265 psi at 10339.0 ft Pore 98 psi at 2321.0 ft Collapse 4330 psi at 434.0 ft Burst 6439 psi at 0.0 ft Temperature Results BHCT 66 degF Simulated Max HCT 69 degF Simulated BHCT 47 degF Max HCT Depth 0.0 ft CT at TOC 47 degF Max HCT Time 02:59:30 hr:mn:sc Static temperatures : At Time (hr:mn) 00:01 hr:mn Geo.Temp. Top of Cement (degF) 47 degF 50 degF Bottom Hole (degF) _ 47 degF 54 degF Page 7 op14-s3 cade v1 4-6-11.cfw,04-06-2011: LoadCase 9-5/0 Intermediate Casing lal,Version wcs-cem461_O8 Client : Eni Petroleum Well : OP14-S3 ScIlmkrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ECD Simulation at the casing shoe: Depth= 10339 ft u, I N O Hydrostatic N Dynamic Frac Lt) Fore � I O � I in I `— O o1 O - cdl o w T T-- - 0 20 40 60 80 100 120 140 160 180 200 Time(min) ECD Simulation at the previous shoe: O — Depth= 2322 ft Fluids at 10339 ft_ cd U O I Hydrostatic 1 Dynarric Frac U) •Pore O 8- asas-1 O 1 of l O T--T--T T--T 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 8 op14-s3 cade v1 4-6-11.cfw:04-06-2011. LoadCase 9-5/8 Intermediate Casing(a),Version wcscem461_08 • Client : Eni Petroleum Well : OP14-S3 Winker!" String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Temperature Model: 0 First Sack Depth - First Sack Temp. -Last Sack Temp. -Last Sack Depth F N c - F� _ I I r r $ 41Ik C° O I � 0 30 60 90 120 150 180 210 Time(min) Surface Pressure Model: pCalc.Pump Press. Cale.WHP - 0 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 9 op14-s3 cade v1 4-6-11.cfw;04-06-2011, LoadCase 9-5/V Intermediate Casing(a(;Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 Sc Imbrier String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Return Rate: Fluids at 10339 ft 0 Out Q In f�- - C N— 0 T- --T--T--T-- 0 20 40 60 80 100 120 140 160 180 200 Time (min) Anullar Velocity Simulation: Depth= 10339 ft Annular Velocity 08- 8 8 F3- i3- 0 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 10 op14-s3 cade v1 4-6-11.cfw;04-06-2011; LoadCase 9-5/6 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 SciIsierger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo. Model : HERSCHEL_B. k :5.97E-3 lbf.s^n/ft2 At temp. :80 degF n :0.616 Ty :8.86lbf/100ft2 Gel Strength : 32.02 Ibf/100ft2 MUD Mud Type :WBM Job volume :751.0 bbl Water Type : Fresh VOLUME FRACTION Solids :6.0% Oil : 1.0% Water :93.0% 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. :65 degF n :0.324 Ty : 12.92 lbf/100ft2 Gel Strength :40.56 lbf/100ft2 Job volume : 70.0 bbl DeepCRETE DESIGN Fluid No:7 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.45E-2 lbf.sAn/ft2 At temp. :68 degF n :0.792 Ty :2.31 lbf/100ft2 Gel Strength :21.02 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid :5.180 gal/sk Job volume :303.1 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity : 1106.40 sk Sack Weight : 100 lbs Solid Fraction :55.0% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid :5.160 gal/sk Additives Code Conc. Function D167 0.250%BWOB Fluid loss D046 0.129%BWOB Antifoam D065 0.250%BWOB Dispersant D153 0.100%BWOB Antisettling Page 11 op14-s3 cade v1 4-6-11.cfw,04-06-2011, LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : OP14-S3 Scilimerger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Fluid Rheological Profile: Annulus ID: 9.625 in-OD: 12.250 in 0 o- DeepCRETE - MUDPUSH II - Mud O O) O Co 0 0 to N — N• Cfl c o Lc) LL O_ o M 3.9 4.2 4.5 4.8 5.1 5.4 5.7 6.0 6.3 6.6 6.9 7.2 7.5 7.8 8.1 Flow Rate (bblmin) Page 12 op14-s3 cade v1 4-6-11.cfw;04-06-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcscem461_08 Client : Eni Petroleum Well : OP14-S3 Schlumherger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: centralizer placement Top of centralization :7286.0 ft Bottom Cent. MD :10319.0 ft Casing Shoe :10339.0 ft NB of Cent. Used :48 NB of Floating Cent. :48 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 8219.0 23 1/1 HYDROFORM HFD 0.0 8201.0 9339.0 0 0/0 0.0 8219.0 10339.0 25 1/1 HYDROFORM HFD 0.0 9357.0 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) (lbf) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford(1) N.A. N.A. N.A. ft 0 20 40 60 80 100 O- < , -- > - Between Cent. + +At Cent. O O- • O O co O O O N Well Pipe Standoff Page 14 op14-s3 cade v1 4-6-11.cfw;04-06-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcscem461_08 Client : Eni Petroleum Well : OP14-S3 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 6: WELLCLEAN II Simulator ft % % § stdBetw.Cent. • 100 0 20 40 60 80 100 0 40 Mud Contamination N- - Cement Coverage - Uncontaminated Slurry I W.."." --T-- ED ., l l_ �7 Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z° g '3- z° g I _ , 7500 7500 7500- --- �... 7500 6000- -8000 6000- �.f`1 4h -6000 T.;_-- 8500- 8500 600- _ -8500 l0 9000- -9000 ° 0 woo- -9000 8 ° o° - f ° 9500- -9500 9500- 1 • -9500 10000- -10000 10000- -10000 • •• • L 3 ` 3 • } S 3 P O D = Mud 111 High ® Low DeepCRETE Medium None n MUDPUSHII Page 15 op14-s3 cede v1 46-11.ctw;04-06-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_06 Toot Oliktok Point Nikaitchuq Field North • 2nd petroleum 0P14-S3 Slope - Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD SIZE SPECS INFO Cement to Surface 1 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' I Driven Welded N/A N N GR/Res o Surface Csq Dir/PWD i 13-3/8" 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor Surface T/Tail Cement 1821 1742 u.1- L-80,BTC 8.8 -9.5 Lost Circulation w Hole Cleaning o Casing Sections KOP:400' ° Casing Wear DLS: B/Permafrost 1900 1812 0-3.51°/100' N in 9 el a a v n Hole Angle . N. 34.98 Deq 13-3/8" 2,321' 2,172' `,: 16" 50°F WBM GR/RES Neutron/Density/PWD inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40 lb/ft MW(ppg) Hole Cleaning L-80,Hydril 563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 81.91 Deg i BHA Expense Intermediate TOC 6,786' 3,434' — , Pick-up Top of Sand IMO N ul k-_-_- N Top 7,786' 3,575' O a A TOL 10,139' 3,827' 2. Hole Angle a 07.4 8 ik 6.50 Deg 9-5/8" 10,339' 3,839' ' 12.25" 85°F LSND GR/RES Neutron/Density/PWD Wellbore Stability Lost Circulation X ;lotted Liner Hole Cleaning 5-1/2" Torque&Drag 17 lb/ft MW(ppg) Casing Sections Xceed 675 co L-80,Hydril 521 8.7-9.4 Casing Wear E 4 BHA Expense 6i 'i a Hole Angle 96.07 Deg 5-1/2"Liner 21,240' 3,660' 8-3/4" 85°F MOBM > S P E O IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. En! E&P Division REVISION STAP-P-1-M-6140 0 1 1 1 1 1 1 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). S P E O IDENTIFICATION CODE PAG 207 OF 338 ENI S.p.A. eril E&P Division REVISION STAP-P-1-M-6140 0 I 1 I I I I 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 O IDENTIFICATION CODE PAG 208 OF 338 E&P Division REVISION STAP-P-1-M-6140 011 IIIIII 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. ENI S.p.A. S P E O IDENTIFICATION CODE PAG 209 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 1 LEAK-OFF TEST REPORT Report N° Date: WELL NPME: WELL CO DE: I CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud Twe: FWGELS Rig type: J.UPs Hole Clam ete r(in): 121/4 Weight(KgA): 1.3 R.K.B.elevation(m): 26 Last Csg.Shoe(m): 797 Marsh Viscosity(sec/Ot): 44 Water Depth(m): 24 Cs3.diameter(n): 13'3/8 P.V.(cps): 19 Pumps: 12-P-160 Grade: J-55 Y.P.Qb/100le): 5 Liners(in): 6.5 Weight Qb/t): 81 Gels(lb/100 V): 2/8 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/cm2I10 m Time Volume Pressure Time Volume Pressure Time Volume Pressure (min) (bbl) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 060 100 95 2 480 3 0.75 200 10 2 470 4 100 300 105 2 463 5 125 400 11 2 455 6 ISO 500 11.5 2 450 7 1.75 570 12 2 445 8 220 600 13 2 440 8 220 550 14 2 437 8.5 200 505 15 2 435 Not e: Pumped with a constant low rate of(bbl): Volume pumped(bbl): btiume returned(bbl): (ps) 1000 900 800 stop pump r• 700 • e 600 shut in curve S 500 ' S ~•_,,,+—• i —t�� • • • • U 400 r 18 minutes I E 300 - 200 100 0 0 0,25 0,5 0,75 1 1,25 1,5 1,75 i 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(WI) 14 OP Time mins RESULTS:(Press.mw+Press.w.)x1 OM epth=[(1.3 x 797 1 10)+(430 x 0.07))x10 1797=1.68(Kg/cm°/1 O m) Note: I Company Representative Figure 15-1 - Leak-Off Test Report REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 Oliktok OLIKTOK Point 0 INTAKE DOCK OPP THIS L_ MODULE R�P 15 SURVEY t. � Q TANK N '�"':` QP °� 't' *a DS-3R Q DEW ul / , SITE SIP i— , TANK OLIKTOK PoIN; MODULES I N)C STAGING AREA•, T13N, R9E DS-30 '‘\\ : 1' lig -C.f I.. SCALE: 1" = 150' u 1'�� D5°-,30 S TP PAD \ VICINITY MAP oo \ SCALE: 1" = 1 Mile o°po \ o°-o °�.. \ \\:.\\:\ 0,0 "t0 '° °90°'o 9093091 \ '.0 2 OLI K TOK \\ POINT PAD \ o• °-0 \ �s \ 0 1 n�� \ \ / \ SEE SHEET 3 FOR NOTES / \ \ U Existing Conductor LOUNSBURY �� & ASSOCIATES, INC. • Conductor Asbuilt this survey / S Lir ORS ENGINEERS MANNERS / AREA: MODULE: UNIT: Eno Petroleum roleu m OWELLO CONDUCTOR PAD UCTOR -Ifllp ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80—di I PART: 1 OF 3 I REV: 2 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP-11 6,036,332.70 1,656,791.89 70°30'39.015" 149°51'57.587" 2,052 1,519 12.1 4.0 OP-12 6,036,328.85 1,656,784.83 70°30'38.977" 149°51'57.795" 2,056 1,526 12.2 4.0 0P03-P05 6,036,325.10 1,656,777.76 70°30'38.940" 149°51'58.004" 2,059 1,533 12.2 4.0 OPO4-P07 6,036,321.43 1,656,770.69 70°30'38.904" 149°51'58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70°30'38.868" 149°51'58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70°30'38.831" 149°51'58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742,45 70°30'38.757" 149°51'59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 7D°30'38.720" 149°51'59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70°30'38.683" 149°51'59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70°30'38.647" 149°51'59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70°30'38.610" 149°51'59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70°30'38.573" 149°52'00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70°30'38.463" 149°52'00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70°30'38.426" 149°52'00.920" 2,112 1,633 12.2 3.5 • OP15 6,036,268.88 1,656,671.79 70°30'38.389" 149°52'01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70°30'38.353" 149° 52'01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70°30'38.316" 149°52'01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70°30'38.279" 149°52'01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70°30'38.205" 149°52'02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70°30'38.168" 149°52'02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70°30'38.132" 149°52'02.586" 2,141 1,689 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70°30'38.095" 149°52'02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70°30'38.058" 149°52'03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70°30'38.022" 149°52'03.209" 2,153 1,710 12.2 1.3 DISPOSAL WELLS • AK STATE PLANE (NAD83) LAT1TUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'Y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149°52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: EN 'r etroleum UKTCONDUCTOR K NT P D ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 _ NSK 6.80-d1 2 OF 3 _ 2 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L-2539 FOR NAD27 INFORMATION. SURVEYOR'S CERTIFICATE „` • • ) °j i = h /\ •• 1. / HEREBY CERTIFY THAT I AM PROPERLY • / REGISTERED AND LICENSED TO PRAC77CE 0 r •• • LAND SURVEYING IN THE STATE OF % J ROOKUS i ALASKA AND THAT THIS PLAT REPRESENTS • �' iP LS-803 • % A SURVEY DONE BY ME OR UNDER MY TF •. ,�,pp J4- DIRECT SUPERVISION AND THAT ALL "Ps p'�1. ° f!�''..�p s�• DIMENSIONS ORRECT AS OF DECEMBER 23, 2008. ,+,,`\r"�`V-•—��• LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE UNIT: r E nli Petiro11eiuiim WELLOCONDUCTOR D Cn� ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-di 3 OF 3 2 TRANSMITTAL LETTER CHECKLIST WELL NAME / 74 or/(74 PTD# _/ Development Service Exploratory Stratigraphic Test Non-Conventional Well / ,�/jai-�c�� /f � C-/tc� "�rile#4 FIELD: f� POOL: Circle Appropriate LetCer,/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 L ❑ w To co N a a)) n E N _N N a) ❑ co O 2 @ a 7 a) C m > T. 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No special effort has been made to chronologically organize this category of information. rflitit 2n Eiriiii ° FINAL WELL REPORT MUDLOGGING DATA NIKAITCHUQ OP14-S3 RECEIVED OLIKTOK POINT, ALASKA 30N 2 8 Zp11 i&Ges Gii* Gsr SSro11 gestka Qi Araecill le E: n } r 7t ... CANRIG I)rii:l\ Approved by Andrew Buchanan Compiled by: Lees F.BrowneJr. Jeff McBeth Dan Sherwood Dan Grunwald Distribution: June 27, 2011 Date: May 31, 2011 igth End Nikaitchuq OP14-S3 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT&CREW 3 1.1 Equipment Summary 3 1.2 Crew 4 2 WELL DETAILS 5 2.1 Well Summary 5 2.2 Hole Data 5 2.3 Well Synopsis 6 3 GEOLOGICAL DATA 7 3.1 Target and Offset Well Data 7 3.2 Formation Tops. 8 3.2.1 Surface and Intermediate Section 8 3.2.2 Production/Lateral Section 9 3.3 Lithologic Descriptions/Stratigraphy 10 3.4 Trip/Wiper Gas Summary 41 3.5 Sampling Program and Sample Dispatch 42 3.6 IsoTube®Chromatography/IsoJar®Geo Chemical Sampling 43 4 PRESSURE AND FORMATION STRENGTH DATA 44 4.1 Pore Pressure Gradient Evaluation 44 4.2 Quantitative Methods 44 5 DRILLING DATA 45 5.1 Daily Activity Summary 45 5.2 Survey Data 47 5.3 Bit Record 53 5.4 Mud Record: Surface and Intermediate Hole 54 5.5 Mud Record: Production Hole 55 6 DAILY REPORTS 56 Enclosures: 1 f 2" : 100' Formation Log (MD an TVD) 2" : 100' LWD Combo Log (MD TVD 2" : 100' Gas Ratio Log (MD) 2" : 100' Drilling Dynamics Log (MD)N1 Final Well Data on CD 2 CANRIG IrA 611 Nikaitchuq OP14-S3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type/Position Downtime Comments (hours) Casing Pressure Cable to 1502 transducer, 0 for BOP tests only. Driller's Monitor Azonics 0 Pitwatcher's Monitor Azonics 0 Computer for RigWatch Remote, HP Compaq 0 Company Man, camp (wireless connection) Computer for Company RigWatch Remote, HP Compaq 0 Man/Toolpusher, office (wireless connection) Computer for RigWatch Remote, HP Compaq 0 Mud Engineer Computers for RigWatch Remote, Cybernet, 0 Toolpusher(2) and RigReport, HP Compaq Computers for Mudlog compilation and editing, Mudloggers(3) RigWatch Master, &RigWatch 0 Remote, all HP Compaq QGM Gas Trap gas (mounted in mud trough), as Ditch Flame Ionization Detector(FID) 0 Total Gas and Chromatography. Hook Load/Weight on bit Drilling line sensor on rig floor 0 Mud Flow In Derived from pump rate&output 1* Mud Flow Out Flow line Sensor 1* Pit Volumes, Gain/Loss 10 radar pit sensors 0 Pump Pressure Standpipe Transducer 0 Pump stroke counters (3) 2 proximity sensors 1* Rate of penetration Drawworks Encoder 1" RPM PLC feed 1* Torque PLC feed 1* Wits In (ECD) LWD Computer to RigWatch 40** Master Computer *Selected sensor data not transmitted for less than an hour on both May 20th&26th until driller's console rebooted. **WITS data transmission was unreliable, particularly in surface and intermediate hole sections, with only sporadic data loss in the production hole section. 6d Nikaitchuq OP14-S3 1.2 Crew Unit Number: ML059 Unit Type: Arctic/Steel Mudloggers Years of Days at Sample Days at Technician Days at Experience OP14-S3 Catchers OP14-S3 OP14-S3 Lees Browne 31 9 Debra Bomar 26 Allen Williams 1 Jeff McBeth 3 6 Josh Dubowski 20 Dan Sherwood 5 26 Dean Kekaualua 8 Dan Grunwald 3 16 Emil Opitz 4 7 II it 4 CAMIG WA EN Nikaitchuq OP14-S3 2 WELL DETAILS 2.1 Well Summary Well: Nikaitchuq OP14-S3 API Index#: 50-029-23447-00 Field: Nikaitchuq Surface Co-Ordinates: 3167.5' FSL, 1,632.7' FEL, S5, T13N R9E, Umiat Meridian Borough: North Slope Primary Targets: OA Sand of the Schrader Bluff State: Alaska Primary Target Depth: 21,239' MD/-3,608.2' SSTVD Rig Name/Type: NAD 245E/Arctic Triple TD Depth: 21,340 MD/-3,618.4' SSTVD Spud Date: May 06, 2011 Ground Elevation: 12.20'AMSL TD Date: May 31, 2011 RT Elevation: 53.23'AMSL Days Drilling: 17 TD Formation: Schrader Bluff OA Sand Classification: Producer 2.2 Hole Data Maximum Depth Mud Shoe Depth Hole TD Dev. Casing/ MD TVD FIT Section MD TVD Formation Weight (zinc) Liner (PM) (ft) (pp9) (ft) (ft) Conductor 160 160 Recent N/A 0 20" 160 160 N/A 16" 2338 2174 Ugnu 9.1 36 13%" 2326 2165 12.5 Surface 12W Schrader Intermediate 10455 3848 Bluff, OA 9.4 86 9%" 10440 3847 13.0 Sand Schrader 8%" Production 21340 3672 Bluff, OA 9.4 89 5%" 21325 3674 N/A Sand 5 CMRIG irth 611 Nikaitchuq OP14-S3 2.3 Well Synopsis The OP14-S3 well was spudded on the 6th of May 2011,entering a pre-set conductor pipe previously driven to a depth of 160'. New 16"hole was drilled to a depth of 2338'MD; 13%",681b/ft L-80 surface casing was set at 2326'MD/2164.9'TVD/-2111.7'TVDSS. The float equipment and shoe were drilled out and 22'of new hole was drilled to 2360' MD. A Leak Off Test(LOT)was performed to an EMW of 12.5 ppg. The intermediate section was drilled with a hole diameter of 12W. At 6066' MD it was necessary to trip out of the hole due to the Xceed tool failure. A new BHA and drill bit assembly were picked up and run in the hole to resume drilling. A second trip out of the hole was completed at 8573' MD due to inability to achieve the planned turn. The same BHA with a new bit was used to finish drilling the intermediate section. The intermediate section was drilled to a depth of 10455'MD.The hole was back-reamed to the existing casing shoe and circulated clean. After laying down the drilling assembly, 9%", 40 lb/ft L-80 Hydril 563 casing was floated in dry and set at 10440'MD/3847.3'TVD/-3794.2'TVDSS. An 8%"bit and a drilling assembly were picked up and run in to the intermediate casing shoe. The casing shoe was drilled out with 25'of additional new hole to 10470' MD where a Formation Integrity Test(FIT)was performed yielding a 13.0 ppg EMW. Normal drilling was resumed using an 8%"PDC bit,and the borehole was extended to TD at 21340'MD/3671.6'TVD/-3618.4'TVDSS on May 31, 2011. 5 %" production liner was set at 21325' MD/3674'TVD/-3620.8'TVDSS. 6 CANRIG Pt Eli Nikaitchuq OP14-S3 3 GEOLOGICAL DATA 3.1 Target and Offset Well Data Reference Wells OP14-S3 Zone/Horizon OPO4-07 OP10-09 OP-12 PB01 OP26-DSPO2 Prognosis(P5b) TVDSS TVDSS TVDSS TVDSS TVDSS MD SV-4 -659 8 -657 8 — -659 1 -650.2 703.3 SV-3 -911.5 -907.7 — -902.8 -903.9 962 SV-2 -1.175.5 -1.171.1 -1.169.0 -1.163.2 -1,166.1 1,238 SV-1 -1,632.1 -1,640.5 -1.647.0 -1.648.1 -1,644.9 1,770 Permafrost Base -1.722.1 -1.725.0 -1.724.3 — -1,725.0 1,861 Uanu Top(UG4) -1.967.9 -1.974.0 -1,931.5 -1.957.2 -1,967.9 2,140 13%"SCP — — — — -2,120.0 2,402 UG-2 Coal Bed Marker -2.473.4 -2.456.6 -2,422.0 -2.428.2 -2,419.9 2,711 L Uanu -3.198.7 -3.162.2 -3.060.0 -3.122.5 -3,178.6 5,343 Schrader Bluff -3.516.4 -3.380.2 -3.341.9 -3.325.0 -3,371.1 6,711 Fault#1 — — — -3,379.4 6,711 Fault#2 — — — — -3,483.1 7,508 N Sequence Too -3.569.2 -3.428.0 -3.346.2 -3,480.4 7,489 N Sand Top -3.613.9 -3.472.0 -3.386.4 -3.382.6 -3,522.3 7,786 Fault#3 — — — — 3606.4 8,388 N Sand Bottom -3.628.0 -3.503.0 -3.424.4 -3.423.3 -3,656.3 8,771 N Sequence Base -3.705.5 -3.573.2 -3.458.5 — -3,704.7 9,197 OA Sand Too -3.779.7 -3.638.2 -3.518.2 -3.536.4 -3,771.9 10,090 0A2 -3.793.4 -3.646.3 — — -3,783.7 10,283 9%"ICP -3.504.0 — — — -3,787.2 10,339 Total Depth -3.882.1 — — — -3,608.2 21,239 7 CANRIG tili EN Nikaitchuq OP14-S3 3.2 Formation Tops: 3.2.1 Surface and Intermediate Section Depth (ft) Prognosed Depth (ft) Zone or Horizon MD TVD TVDSS MD TVDSS 20" Conductor Shoe 160.0 160.0 -106.8 160.0 -106.8 SV-4 710.8 709.8 -656.6 703.3 -650.2 SV-3 966.0 960.3 -907.1 962.0 -903.9 SV-2 1,240.0 1,221.2 -1,168.0 1,238.0 -1,166.1 SV-1 1,774.0 1,697.3 -1,644.1 1,770.0 -1,644.9 Permafrost Base 1,858.0 1,770.9 -1,717.7 1,861.0 -1,725.0 Ugnu Top(UG4) 2157.0 2,027.5 -1,974.3 2,140.0 -1,967.9 13%'Casing Shoe 2,326.2 2,164.9 -2,111.7 2,321.0 -2,120.0 UG-2 Coal Bed Marker 2,721.8 2,473.3 -2,420.1 2,711.0 -2,419.9 Lower Ugnu 5,154.0 3,204.8 -3,151.6 5,343.0 -3,178.6 Schrader Bluff 6,437.7 3,405.3 -3,352.1 6,711.0 -3,371.1 Fault#1 6,675.0 3,432.3 -3,379.1 6,771.0 -3,379.4 Fault#2 7,368.0 3,518.1 -3,464.9 7,508.0 -3,483.1 N Sequence Top 7,485.0 3,534.8 -3,481.6 7,489.0 -3,480.4 N Sand Top 7,918.0 3,596.2 -3,543.0 7,786.0 -3,522.3 N sbl 2 7,997.0 3,607.4 -3,554.2 n/a n/a N sbl 3 8,162.9 3,630.6 -3,577.4 8,267.0 -3,589.7 Fault#3 8,243.0 3,641.4 -3,588.2 8,388.0 -3,606.4 N sbl 3 8,487.0 3,671.7 -3,618.5 n/a n/a N Sand Bottom 8,690.0 3,690.7 -3,637.5 8,771.0 -3,656.3 Lower N Marker 9,414.0 3,749.0 -3,695.8 n/a n/a N Sequence Base 9,610.0 3,766.0 -3,712.8 9,197.0 -3,704.7 OA Sand Top 10,228.5 3,829.2 -3,776.0 10,090.0 -3,771.9 0A2 10,334.0 3,839.5 -3,786.3 10,283.0 -3,783.7 9%"Casing Shoe 10,440.0 3,847.3 -3,794.2 10,339.0 -3,787.2 OA sbl 3 10,455.0 3,848.0 -3,794.7 n/a n/a 8 CANRIG P Ed Nikaitchuq OP14-S3 3.2.2 Production/Lateral Section Depth(ft) Prognosed Depth (ft) Zone or Horizon MD TVD TVDSS MD TVDSS OP14-S3 Lat Fault 1 10,922.0 3,863.4 -3,810.2 10,500.0 -3,794.8 OA Bottom 11,267.0 3,864.6 -3,811.4 n/a n/a OA sbl 4 11,383.0 3,860.5 -3,807.3 n/a n/a OA sbl 3 11,994.0 3,839.0 -3,785.8 n/a n/a OA sbl 2 12,124.0 3,833.2 -3,780.0 n/a n/a OP14-S3 Lat Fault 2 12,143.5 3,832.4 -3,779.2 12,100.0 -3,808.8 OA sbl 4 13,519.0 3,845.7 -3,792.5 n/a n/a OA Bottom 13,636.0 3,850.9 -3,797.7 n/a n/a OA Bottom 13,745.0 3,851.2 -3,798.0 n/a n/a OA sbl 4 13,926.0 3,841.8 -3,788.6 n/a n/a OA sbl 3 14,578.0 3,808.7 -3,755.5 n/a n/a OA sbl 2 14,664.0 3,806.4 -3,753.2 n/a n/a OA sbl 2 15,603.0 3,803.4 -3,750.2 n/a n/a OA sbl 3 15,860.0 3,811.7 -3,758.5 n/a n/a OA sbl 4 16,398.0 3,809.7 -3,756.5 n/a n/a OA sbl 4 16,630.0 3,797.9 -3,744.7 n/a n/a OA sbl 3 17,345.0 3,761.0 -3,707.8 n/a n/a OA sbl 2 17,490.0 3,751.0 -3,697.8 n/a n/a OA sbl 2 18,589.0 3,719.3 -3,666.1 n/a n/a OP14-S3 Lat Fault 3 18,663.0 3,720.7 -3,667.5 n/a n/a OA sbl 3 19,520.0 3,687.3 -3,634.1 n/a n/a OA sbl 2 19,608.0 3,680.8 -3,627.6 n/a n/a OP14-S3 Lat Fault 4 20,146.0 3,667.9 -3,614.7 18,850.0 -3,715.6 OA Top 20,362.0 3,676.2 -3,623.0 n/a n/a OA sbl 2 20,425.0 3,681.5 -3,628.3 n/a n/a OA sbl 3 20,484.5 3,686.1 -3,632.9 n/a n/a TD 8 3/4"Borehole 21,340.0 3,671.6 -3,618.4 21,239.0 -3,608.2 9 CANRK] 611 Nikaitchuq OP14-S3 3.3 Lithologic Descriptions/Stratiqraphv PERMAFROST AND RECENT/QUATERNARY DEPOSITS SURFACE TO 2157.0'MD/-1974.3'TVDSS Samples were not collected and lithologies were not logged in the surface hole. However, the permafrost sections of correlated wells consist of interbedded sand and clay with sporadic conglomerates. Although no oil shows were seen, minor gas hydrates were encountered. This interval extends from surface down to the top of the Ugnu at 2157.0' MD/-1974.3 TVDSS and is comprised of a thick sequence of sands, conglomerates and claystones with occasional thin to massive siltstone and poorly developed coals and carbonaceous remains. Sand dominates the upper part of the section with claystone becoming predominant with depth Discrete fragments of sandstone were rarely observed; samples were typified by loose sand and conglomeratic pebble fragments with irregular globular clay masses.Clay masses commonly contained trace to abundant sand mechanically worked into the clay by drilling, circulation and shaker action, and had a surface coating of embedded loose sand. The formation consists of moderate to thick beds with locally abundant thinner interbeds. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 485 322 127 72 0 9 PEAKS Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 SV-4 710.8' MD/-656.6'TVDSS SV-3 966.0' MD/-907.1'TVDSS SV-2 1240.0' MD/-1168.0'TVDSS SV-1 1774.0' MD/-1644.0'TVDSS PERMAFROST BASE 1858.0 MD/-1717.7'TVDSS _611 Nikaitchuq OP14-S3 UGNU TOP(UG4)2157.0' MD/-1974.3'TVDSS The Ugnu Formation consists of two units, upper and lower Ugnu. The upper portion of the formation is essentially similar in nature and appearance to the overlying material. However, the sands are generally finer grained and exhibit slightly greater wear through transport/erosion. The section consists primarily of thickly bedded sand/sandstone occasionally grading to conglomeratic sandstone and conglomerate. Moderate to thin claystone and siltstone interbeds occur throughout. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 399 2 141 84 0 13 PEAKS Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 139/8" CASING SHOE 2326.2' MD/-2111.7' TVDSS TD 16" BOREHOLE 2338.0' MD/-2121.2' TVDSS Sand (2350-2430)= medium light gray to light gray; clast size range medium upper to fine upper; trace coarse grain; mean size medium lower; moderate developed sphericity with various discoidal, triaxial and equant grains; moderate sorting; impacted texture; mature nature; no visible cement; unconsolidated; grain supported; no visible matrix; composed of dominant quartz, secondary chert and scattered silica mudstone, greenstone and trace aggregate, disseminated and framboidal pyrite; good porosity and permeability; moderate light green even fluorescent grease in samples(30%); no fluorescent oil cut. Very Carbonaceous Silt,Clay and Shale(2430-2455)= black mottled dark reddish brown with various hues of brownish black; brittle to firm; earthy luster; sub platy to irregular fracture; composed of very carbonaceous clay, silt and shale with very low grade lignite; micro laminations of carbon siltstone; appears very detritish Sand/Conglomerate Sand(2455-2600)= light gray to very light gray; clast size coarse upper to fine upper; sub angular to sub round; scattered angular; moderate developed sphericity; moderate to poor sorting; impacted to chipped coarse grains; mature nature; scattered dense sandstone clusters+ conglomerate being tight; trace calcite; dominant grain support; composed of dominant quartz, minor chert with 20% dark gray hued silica mudstone, greenstone and aggregate+disseminated pyrite;fair to good porosity and permeability; 20% pale yellowish orange grease in samples decreasing with depth; light green even uv fluorescence but no cut. Conglomerate/Conglomerate Sand(2600-2700)= medium gray to light gray; clast size range coarse upper to medium lower; sub round occasionally sub angular' moderate to well developed sphericity; poor sorting; polished with slight chipped texture; sub mature to mature nature; scattered sandstone clusters= dense with moderate silica cement; slight clay/silt matrix; grain supported; composed of 40% quartz, 10% chert, 40% dark gray to light gray silic mud stone and aggregate pyrite; poor to fair porosity; fair permeability; appear as a sub graywacke; 10% light green uv fluorescence on greasy oil blebs; no oil cut; samples grading to medium grained sand in faster rop at 2680' UG-2 COALBED MARKER 2721.8' MD/-2420.1'TVDSS 11 CANRIG 611 Nikaitchuq OP14-S3 Sand (2700-2750)= light gray to very light gray; clast size coarse lower to fine lower; sub round to sub angular; moderate developed sphericity; some triaxial grains overall equant poor sorting; impacted texture; mature nature; unconsolidated; grain support; no visible matrix; good visible porosity and permeability in high rop; no show of oil fluorescence or cut; scattered beds of thin conglomerate sand from 2700 to 2720' Sand (2750-2850)= light gray to very light gray with abundant translucent to transparent grains; predominantly lower medium to upper fine grains with trace amounts of very coarse grains; sample consists largely of loose unconsolidated and disaggregated sand and few fragments of sandstone which exhibited a slight reaction to hcl; moderate sorting; sub angular to sub round; low sphericity; mostly grain supported with sandstone fragments being siliceous to slightly calcareous; thin bed of carbonaceous shale, mudstone to siltstone ranges from very hard to moderately firm; trace amounts of pyrite; no visible matrix; no petroleum odor or sample fluorescence. Sand (2850-2900)=translucent to transparent grains which are colorless to white to light gray; 80% quartz, 20% lithics; medium to fine grained; moderate to poor sorting; sub angular to sub round to angular; low to moderate sphericity; loose unconsolidated sands; grain supported; no visible cement; trace amounts of pyrite and white to green muscovite; no petroleum indicators present. Sand (2900-3000)=dominantly transparent and translucent grains with light gray to white to colorless hues; approximately 70% quartz, 20% lithics, 10% pulverulent and non cohesive claystone; lower coarse to lower medium grains with occasional lithic clast; moderate to well sorted; sub angular to angular; low to moderate sphericity; loose unconsolidated quartz grains with no apparent cement; grain supported; trace amounts of chert and pyrite; no petroleum indicators present. Sand (3000-3060)=white to light gray and dominantly translucent with occasional transparent which gives the sample a salt and pepper appearance due to darker lithics; approximately 60%quartz and 40% lithics; upper coarse to lower medium; sub angular to sub round; very low to low sphericity; loose unconsolidated sands with some disaggregated sandstone with slightly calcareous cement; majority of sample appears to be grain supported; trace amounts of pyrite and chert. Sand (3060-3150)=white to light gray to colorless translucents and transparents; 90%quartz, 10% lithics; upper to lower fine grained;well to moderate sorting; sub angular to sub round; moderate sphericity; loose unconsolidated sands with overall very slight to no reaction with hcl; sandstone fragments have very slight reaction with hcl; overall appears grain supported; common amounts of pyrite and chert; no petroleum odor; no visible staining; faint yellow fluorescence; slow yellow cut fluorescence; clear visible cut; no residue; no residue fluorescence. Sand (3150-3230)=white to very light gray to light gray with translucents and transparents; 90%quartz, 10% lithics; upper find to lower medium grained; well to moderate sorting; sub round to sub angular; moderate sphericity; loose unconsolidated grains; claystone in sample is slightly cohesive masses of mushy to pasty pulverulent clay with clayey to silty texture often appearing sucrosic due to embedded quartz grains;trace amounts of pyrite; no petroleum odor; no visible staining; faint yellow fluorescence; slow yellow cut fluorescence; clear visible cut; no visible residue; no residue fluorescence Sand (3230-3310)=very light gray to white with abundant translucents and transparents; lower medium to upper fine grained; well sorted; sub round to sub angular; moderate to high sphericity; loose unconsolidated quartz grains; 60% quartz and 40% lithics; grain supported; sample has salt and pepper appearance; claystone in sample appears as slightly cohesive, mushy to pasty clumps of pulverized clay; no petroleum odor; no visible staining; no fluorescence or other petroleum indicators. Sand (3310-3380)=white to very light gray to light gray with fair amount of translucents and transparents; 70%quartz and 30% lithics; lower fine to lower medium grain; moderate to well sorted; sub angular to sub round; low to moderate sphericity; predominantly loose unconsolidated quartz grains with no apparent cement; grain supported; exhibits salt and pepper appearance; sandstone fragments in sample have slightly calcareous cement; trace amount of pyrite. Claystone(3380-3430)= light gray to medium light gray; slightly cohesive to cohesive; slightly adhesive to adhesive; clumpy to lumpy mushy to pasty to occasionally stiff and tacky; generally pulverulent to 12 CANRIG 0 Ed Nikaitchuq OP14-S3 malleable to stiff; massive cuttings habit; dull to earthy to waxy luster; clayey to smooth texture often appearing sucrosic due to embedded quartz grains; no petroleum indicators. Sand (3430-3500)=white to colorless translucent to transparent quartz; 80%quartz, 20% lithics; upper to lower fine with occasional lower medium grain;well sorted; sub round to sub angular; moderate to high sphericity; loose unconsolidated quartz grains; no apparent cement; grain supported; trace amount of pyrite; no petroleum odor; no visible staining; no sample fluorescence; no cut fluorescence or other petroleum indicators. Sand (3500-3550)=white to very light gray to colorless translucent to transparent quartz; 90%quartz, 10% lithics; lower fine to lower medium;well to very well sorted; sub round to sub angular; moderate sphericity; loose unconsolidated quartz grains; grain supported; trace amount of pyrite; no petroleum indicators. Claystone(3550-3600)=very pale orange to pinkish gray and various hues of both colors; very soft to brittle; non to very slightly cohesive; non adhesive; very hydrophilic with most clay going into solution; amorphous fracture; amorphous habit; earthy luster colloidal texture;thin to thick beds of clay interbedded with fine to medium grain sand -unconsolidated. Claystone(3600-3650)=very pale orange to pinkish gray and various hues of both colors; very soft to brittle; non to very slightly cohesive; non adhesive; very hydrophilic with most clay going into solution; amorphous fracture; amorphous habit; earthy luster colloidal texture; thin to thick beds of clay interbedded with fine to medium grain sand -unconsolidated. Sand (3650-3750)=very light gray; clast size ranges from medium upper to fine lower; sub angular to sub round with scattered angular fragments; moderate developed sphericity; moderate to some poor sorting scattered; equant grain shape; mean size is medium lower; impacted texture; mature nature grading to sub mature in parts with increased clay content; unconsolidated; no visible cement; becoming interbedded with hydrophilic clays and thin clay beds; composed of 90%quartz, minor chert with trace silica dark mudstones, greenstone and aggregate pyrite; overall good porosity and fair to good permeability in clay imbedded sands; no show of oil fluorescence or oil cut. Sand (3750-3900)=very light gray; clast size ranges from medium lower to fine lower; sub angular to sub round; moderate developed sphericity; moderate to well sorted; equant grain shape with some scattered discoidal and porlated grains; impacted to some chipped texture mature nature; unconsolidated; no visible cement; very slight hydrophilic clay; dominant grain supported; composed of 90%quartz, secondary chert and trace dark silica mudstone and good estimated porosity and good permeability; no show of oil. Conglomerate Sand/Conglomerate(3900-3970)=very light gray and various hue of light and dark with depth; clast size range from very coarse upper to fine lower; sub round to sub angular; scattered round and angular bit impacted coarse grains; overall moderate developed sphericity with generally equant shape; very poor sorting; impact fine to medium grains to polished and chipped coarse grains; sub mature nature slight scattered tight silica fine to medium grain sandstone; composed of 80% quartz, 10%chert, 10%argillite, greenstone and a small very low grade coal around 3950'; fair porosity with fair to poor permeability; 20% dull blue green even greasy oil sample uv fluorescence; with no oil cut; visible very pale orange hue in white light with scattered greasy floaters. Clay(3970-4000)=yellowish gray; very soft to brittle; lumpy to clumpy; clustered to clotted; non to very slight cohesiveness; non to very slight adhesiveness; amorphous fracture; amorphous habit; earthy luster; colloidal texture; massive very hydrophilic slightly silty clay becoming interbedded with medium to very fine grain sand. Clay(4000-4050)=yellowish gray; very soft to brittle; lumpy to clumpy; clustered to clotted; non to very slight cohesiveness; non to very slight adhesiveness; amorphous fracture; amorphous habit; earthy luster; colloidal texture; massive very hydrophilic slightly silty clay becoming interbedded with medium to very fine grain sand. Claystone(4050-4100)=yellowish gray; very soft; lumpy to clumpy; clustered to clotted; mushy to pasty; various tenacity and consistencies; slightly cohesive; moderate adhesiveness; clay to colloidal texture; 13 CANRIG Erd Nikaitchuq OP14-S3 amorphous fracture; amorphous habit; earthy luster; massive bed of thick clay with interbedded fine to medium grain sand. Sand (4100-4220)= light gray; clast size ranges from medium lower to fine lower; sub round to sub angular; moderate developed sphericity; well to moderate sorting; impacted texture; sub mature nature; no visible cement; dominant clay matrix support and very hydrophilic; heterogeneous beds of clay and sand becoming interbedded; composed of predominantly quartz with minor chert and trace various lithic fragments; poor porosity and poor permeability; no show of oil fluorescence or oil cuts. Sand (4220-4250)=very light gray; clast size range from medium lower to fine lower; sub round to sub angular; moderate developed sphericity; moderate to some well developed sorting; impacted texture; mature nature; no visible cement; dominant grain support; no visible matrix; arenaceous; composed of >90% quartz, minor chert and trace various lithic fragments; good visible porosity and permeability; no show of oil fluorescence or oil cuts. Sand (4250-4350)=very light gray to light gray; clast size ranges from fine upper to fine lower; sub angular to sub round; moderate developed sphericity; well sorted; impacted texture; mature nature; no visible cement; loose grains; unconsolidated; dominant grain support; no visible matrix material; composed of 90% quartz, 10%chert and trace silica mudstone and various lithic fragments; good estimated porosity and good permeability; trace coal fragments at 4350'; no show of oil fluorescence or oil cuts. Sand (4350-4450)=very light gray to light gray; clast size ranges from fine upper to fine lower; sub angular to sub round; moderate developed sphericity; well sorted; impacted texture; mature nature; no visible cement; loose grains; unconsolidated; dominant grain support with possible secondary matrix support in parts; composed of predominantly quartz with secondary chert and trace various lithic fragments; fair to good estimated porosity and permeability; scattered coal fragments (<10%)at 4400' no show of oil fluorescence or oil cuts. Sand (4450-4500)= medium light gray to light gray; clast size ranges from medium lower to fine lower; sub round to sub angular; moderate developed sphericity; scattered porlated grains overall equant; moderate to well sorted; impacted to rare chipped textures; mature nature; no visible cement; non to very slight visible hydrophilic clay; dominant grain support; unconsolidated; composed of>90%quartz, minor chert and trace various dark lithic fragments; good visible estimated porosity and permeability; no show of fluorescence or oil cuts. Sand (4500-4550)=very light gray; clast size ranges from medium upper to fine lower; sub round to sub angular; moderate developed sphericity with overall equant grains; moderate to well sorted; impacted texture; mature nature; no visible cement; no visible matrix material; unconsolidated; dominant grain support; composed of>90% quartz with minor chert and trace various dark lithic fragments; good estimated visible porosity and permeability; no show of oil fluorescence or oil cuts. Sand (4550-4600)=very light gray; clast size ranges from medium lower to fine upper; sub angular to sub round; moderate developed sphericity; equant grains; moderate to well sorted; impacted textures; mature nature to local sub mature; no visible cement; non to slight visible hydrophilic clays; unconsolidated sand; dominant grain support; composed of>90% quartz, minor chert and trace dark silica mud stone and greenstone; fair to good estimated porosity and permeability; no show of oil fluorescence or any oil cuts. Sand (4600-4700)=very light gray; clast size ranges from medium lower to fine upper; sub angular to sub round; moderate developed sphericity; equant grains; moderate to well sorted; impacted textures; mature nature to local sub mature; no visible cement; non to slight visible hydrophilic clays; unconsolidated sand; dominant grain support; composed of>90% quartz, minor chert and trace dark silica mud stone and greenstone; fair to good estimated porosity and permeability; no show of oil fluorescence or any oil cuts; becoming arenaceous at 4700' Sand (4700-4760)=very light gray to white with abundant translucent to transparents; lower medium to upper fine grain; sub round to sub angular; moderate to well sorted; moderate sphericity; no visible cement; loose unconsolidated sand; sample contains hydrophilic, slightly cohesive pulverulent clays; composed 90% quartz and 10% lithics; trace amounts of chert, pyrite and greenstone; no oil indicators observed. 14 CANRIG Sith 6tl Nikaitchuq OP14-S3 Claystone(4760-4820)= light gray; slight to fairly cohesive; non to fairly adhesive; pasty to mushy lumps; pulverulent to malleable; no apparent fracture; massive cuttings habit;waxy to earthy luster; smooth to clayey texture; very poor induration; no petroleum odor; no sample fluorescence; no cut fluorescence; no other oil indicators observed. Sand (4820-4910)= light gray to very light gray with abundant translucents; >90%quartz; upper very fine to fine grain; well to very well sorted; sub angular to sub round; moderate sphericity; loose unconsolidated sands; no apparent cement; grain supported; sample contains pulverized non cohesive hydrophilic clays; no petroleum odor; trace amounts of light brown staining;faint to dull yellow-white sample fluorescence on 20%of sample, patchy distribution; dull translucent yellow-white cut fluorescence with slight yellow streamer; clear visible cut; no visible residue; faint yellow-white residue fluorescence. Claystone(4910-4960)= light gray to very light gray; fairly cohesive; fairly adhesive; very poorly indurated; mushy to pasty; pulverulent to brittle; no apparent fracture; massive cuttings habit;waxy to earthy luster; clayey to gritty texture; clays have do not exhibit and fluorescence or cut fluorescence or other hydrocarbon indicator. Sand (4960-5050)=very light gray to light gray with fair amount of translucents and transparents; >90% quartz framework; lower fine to upper very fine with occasional upper fine;well sorted; sub angular to sub round; moderate sphericity; loose unconsolidated quartz grains; no apparent cement; grain supported; no petroleum odor; trace amount of very light brown staining; faint dull white to yellow fluorescence over 30% of sample; dull translucent white-green cut fluorescence with faint white to yellow streamers; clear to pale straw visible cut; no visible residue; faint white-yellow residual fluorescence. Claystone(5050-5120)= light medium gray to medium gray; cohesive and adhesive; lumpy to clumpy; tacky to mushy to stiff; pulverulent to malleable tenacity; no apparent fracture; massive cuttings habit; waxy to earthy luster; smooth to clayey appearance with a gritty to granular texture due to embedded quartz grains; no hydrocarbon indicators associated with claystone. LOWER UGNU 5154.0' MD/-3151.6'TVDSS Sand (5120-5230)=very light gray to light gray with abundant translucents; >90% quartz with some lithics and carbonaceous shale; fine to lower medium grading to lower fine; well sorted; sub round to sub angular; moderate to high sphericity; loose unconsolidated quartz grains with no apparent cementing; grain supported; carbonaceous shale is brittle with no overall cutting habit thin laminae and fissile;trace amount pyrite; no petroleum odor; 10%sample has light brown to brown stain; 10%sample exhibits dull white-yellow fluorescence; faint yellow streamers with dull yellow-white cut fluorescence; clear to pale straw cut; no visible residue; dull yellow-orange residue fluorescence. Sand (5230-5310)= light gray to very light gray to white with translucents; 90% sand 10% lithics; upper to lower fine with occasional lower medium;well to moderately well sorted; sub round to sub angular; moderate sphericity; loose unconsolidated sands with no apparent cement; grain supported; approx 10% quartz grains show light brown staining; 10%of sample has dull white to yellow fluorescence; dull yellow to white cut fluorescence with faint yellow streamers; clear to pale straw visible cut; no visible residue; dull yellow-orange residue fluorescence. Sand (5310-5350)=very light gray; clast size medium lower to fine lower; sub angular to sub round; moderate developed sphericity; moderate to well sorted; impacted texture; mature nature; arenaceous; no visible cement; non to very slight hydrophilic clay matrix; grain supported; composed of 90% quartz 10% light green even sample fluorescence some greasy oil floater grains; no cut. Claystone/Carbon Clay/Coal(5350-5420)=gradational bedding of yellowish gray hydrophilic soft clays and interbedded medium to fine grain sand to 5395'; lithology change to very carbonaceous clay, silt and very low grade lignite coal; very earthy appearance; reddish brown mottled black; some lignite fragments with micro lamination of pyrite. 15 CANRIG Nikaitchuq OP14-S3 Sand (5420-5500)= medium dark gray salt+ pepper becoming light gray after 5460'; distinct sand color change from 5440-5460'; clast size medium upper to fine upper; sub angular to sub round; moderate developed sphericity equant; moderate to well sorted; impacted text; mature nature; no visible cement; grain support; unconsolidated; very slight hydrophilic clay; composed of 40%quartz 10%chert, 40% silica silty mudstone grains (gray to light gray)dominant micro disseminated pyrite coatings with trace loose aggregate and framboidal pyrite; fair to poor porosity and permeability overall; 10-30% bright light green even greasy oil fluorescence appears as pale yellowish orange grease grain cluster coatings; instant blue white transparent to translucent cuts; possible slow rop cavings from above? Sand (5500-5600)=very light gray; clast size medium upper to fine upper; some scattered coarse lower; sub angular to sub round; moderate developed sphericity; moderate to well sorted; impacted texture; mature nature; arenaceous; no visible cement; no matrix material; grain supported; composed of 90% quartz, minor chert trace dark gray silica mudstone, trace aggregated, disseminated and pyrite inclusions on the quartz grains; good porosity and permeability; 5% bright even light green sample fluorescence with trace oil cut. Sand (5600-5700)=very light gray to yellowish gray; clast size medium lower to fine lower; sub angular to such round moderate developed sphericity; moderate to well sorted; impacted texture; mature nature; arenaceous; no visible cement; no visible matrix material; dominant grain supported; composed of 90% quartz minor chert, trace silty dark gray silic silty mudstone; disseminated and aggreg pyrite noted; good estimated porosity permeability; 0-5% bright even light green sample fluorescence decreasing with depth; possible up hole carvings?; trace cut with no residue stain. Sand (5700-5750)=very light gray to yellowish gray; clast size medium upper to fine upper; sub angular to such round moderate developed sphericity; moderate to well sorted; impacted texture; mature nature; arenaceous; no visible cement; no visible matrix material; dominant grain supported; composed of 90% quartz minor chert, trace silty dark gray silic silty mudstone; disseminated and aggreg pyrite noted; good estimated porosity permeability; no show of oil fluorescence or oil cut. Sand (5750-5850)=very light gray to yellowish gray; clast size medium upper to fine upper; sub angular to sub round; moderate developed sphericity; moderate to well sorted; impacted texture; mature nature; arenaceous; no visible cement; no visible matrix material; dominant grain supported; composed of 90% quartz minor chert, trace silty dark gray silic silty mudstone; disseminated and aggreg pyrite noted; good estimated porosity and permeability; no show of oil fluorescence or oil cut; uniform formation with little change in samples. Sand (5850-5900)=very light gray to yellowish gray; clast size medium upper to fine upper; sub angular to sub round; moderate developed sphericity; moderate to well sorted; impacted texture; mature nature; arenaceous; no visible cement; no visible matrix material; dominant grain supported; composed of 90% quartz minor chert, trace silty dark gray silic silty mudstone; disseminated and aggreg pyrite noted; good estimated porosity and permeability; no show of oil Sand (5900-5950)=very light gray to yellowish gray; clast size medium upper to fine upper; sub angular to sub round; moderate developed sphericity; moderate to well sorted; impacted texture; mature nature; arenaceous; no visible cement; no visible matrix material; dominant grain supported; composed of 90% quartz minor chert, trace silty dark gray silic silty mudstone; disseminated and aggreg pyrite noted; good estimated porosity and permeability; no show of oil Sand (5950-6050)=very light gray to yellowish gray; upper medium to lower medium;well sorted; sub angular to angular; low to moderate sphericity; impact abrasion; loose unconsolidated quartz grains; >90% quartz with trace amounts of carbonaceous shale, silty mudstone, sandstone with calcareous cement, chert and pyrite; disaggregated quartz grains have no reaction to hcl; no petroleum odor; <10%sand has light brown staining; trace amount of faint white to yellow fluorescence; streaming dull to faint white to yellow cut fluorescence; clear to pale straw cut; no residue; faint yellow to orange residue fluorescence. Sand (6050-6100)=white, very light gray, medium gray to medium dark gray; grayish blue green; clear, translucent; approximately 65-70% quartz composition; upper medium to course grained; well sorted; sub angular to angular; low to moderate sphericity; unconsolidated loose, no visible cementation, trace 16 CANRIG Vitt Nikaitchuq OP14-S3 amounts of sandstone and mudstone; trace amounts of mica; scattered bright yellow fluorescence; trace amounts of staining; no detectable odor. Sand (6100-6250)=very light gray to light gray to white with abundant translucents and transparents; 80%quartz with varying amounts of carbonaceous shale, silty mudstone; chert and pyrite; predominantly upper medium to lower coarse; poorly sorted; sub angular to angular; low sphericity; impact abrasions; loose unconsolidated and disaggregated quartz grains; loose grains have no apparent cementation; fragments of calcareous sandstone becoming more abundant towards 6300' composed of primarily lower fine quartz grains and friable; large amounts of brown stained safe carb contaminating sample and giving fluorescence; no petroleum odor. Sand (6250-6340)= light gray to very light gray to white with abundant transparent and translucents; >80% quartz, <10% carbonaceous shale, <10%calcareous sandstone, trace to fair amounts of pyrite and mudstone; lower medium to lower coarse grain; poorly sorted; angular to subangular; low sphericity; loose unconsolidated and disaggregated quartz grains; impact abrasion; no apparent cementation on larger quartz grains; fine grain calcareous sandstone becoming more common; abundant amounts of brown stained safe carb with yellow to white fluorescence contaminating sample; no petroleum odor. Sand/Sandstone(6350-6450)= light gray to very light gray, clear, translucent and transparent, light bluish green, grayish orange due to oil staining, 65% quartz with remaining lithics; medium sorted with some coarse; subangular to rounded with moderate sphericity; soft to unconsolidated with argillaceous cementation; approx 5%very well cemented with calcareous cement; abundant lithic material; mica; coal fragments; light gray claystone throughout; grayish orange to dark yellowish brown stain on 15-20%, very good visible porosity on stained sandstone; bright yellow scattered fluorescence; fast streaming wispy cut and white ring; no detectable odor SCHRADER BLUFF 6,437.7' MD/-3,352.1'TVDSS The Schrader Bluff formation is the zone of interest in this well. At this location, it consists of two main sands, the"N" Sand and the"OA" Sand. At Oliktok Point, the Schrader Bluff is a turbidite deposit formed as sand lobes. In general, the"OA" Sands contain viscous crude with an API gravity between 16°and 19°. The"N" Sand was encountered at 7918.0' MD/-3543.0 TVDSS. Drill Rate(ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 275 6 128 385 0 61 PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 7980 331 67857 795 188 112 41 153 71 8168 385 105821 1351 360 93 18 112 12 8496 277 71750 1710 1782 1056 521 95 24 8603 239 62442 803 239 261 103 129 18 9494 181 35125 616 618 74 84 68 39 Sand/Sandstone(6450-6550)= light gray to very light gray, clear, translucent and transparent, light brownish gray, 60% quartz composition with increased amounts of lithics throughout this interval; upper medium to coarse grained; sub round to round; some subangular; moderately sorted; possible argillaceous cementation disaggregated and loose; light gray claystone throughout; grayish orange yellowish brown stain on 5-10%very good visible porosity on stained sandstone; bright yellow scattered fluorescence; fast streaming wispy cut and white ring; no detectable odor Sand/Sandstone(6550-6650)= light gray to very light gray, clear, translucent and transparent, light brownish gray, 50%quartz composition; upper medium to course grained; sub round to round; moderately sorted; the argillaceous cement/claystone is light gray to medium gray; lumpy to clumpy consistency 17 RI] Nikaitchuq OP14-S3 crumbly to crunchy tenacity; irregular open fracture; nodular; very silty texture;with the interbedded sand; abundant lithics, very trace amounts of mica and some coal are present; the grayish orange, yellowish brown stained sandstone is still present comprising approximately 5%of total sample volume; scattered bight yellowish white fluorescence; fast streaming wispy cut and white ring; no detectable petroleum odor FAULT#1 6675.0' MD/-3379.1' TVDSS Sand/Claystone(6650-6750)= light gray to very light gray, very pale orange hues, transparents and translucents, grayish blue green in places, light brownish gray, approximately 65-70%quartz composition; with abundant lithics throughout; medium grained; moderately sorted; round to sub round; high to moderate sphericity; unconsolidated; disaggregated; possible argillaceous claystone cementation and matrix; some silica cementation and gm support in the finer sandstone present; light gray to gray claystone; brittle and crumbly with moderate cohesion and adhesion; some oil staining present 5-10%of total sample; bright yellow green fluorescence; no detectable petroleum odor Claystone/Sand (6750-6800)= medium light gray to light gray, lumpy to mushy consistency, pulverulent when hydrated and brittle and crumbly when dry, nodular massive cuttings habit, dull earthy luster, silty gritty texture, cohesive and adhesive, disaggregated loose sand imbedded within claystone matrix, pyrite, abundant lithic material Claystone/Sand (6800-6850)= medium light gray to light gray, mushy consistency, pulverulent tenacity, massive cuttings habit, dull earthy luster; very silty clayey texture; good cohesion; interbedded disaggregated sand and lithics; abundant coal fractures; pyrite; trace amounts of mudstone; trace amounts of scattered fluorescence; no petroleum odor Claystone/Sand (6850-6900)= medium light gray to light gray, very mushy consistency, pulverulent mass; massive nodular cuttings habit; open irregular fracture; dull earthy luster; very silty texture when hydrated, sucrosic when allowed to dry, interbedded sand, abundant lithics, abundant coal fractures, trace amounts of pyrite, feldspar and mica, trace scattered bright yellow green pinpoint fluorescence, no detectable petroleum odor Claystone(6900-6950)= light gray to medium light gray, expansive with poor cohesion; lumpy to clumpy consistency; pulverulent mass; irregular open fracture; nodular cuttings habit; dull earthy luster; very silty texture; hydrophilic; interbedded quartz and lithics; coal fragments; trace amounts of pyrite; trace amounts of mica; no hydrocarbon indicators Claystone/Sand (7000-7050)= light gray to medium gray, poor cohesion lumpy to clumpy consistency, pulverulent mass, irregular open fracture, nodular cutting habit; dull earthy luster; very silty texture; increased amounts of sand in this sample interval; a very well stained sandstone is present;with increased amounts of bright yellow green fluorescence Claystone/Sand (7000-7150)= light gray to medium gray, poor cohesion lumpy to clumpy consistency, pulverulent mass, irregular open fracture, nodular cutting habit; dull earthy luster; very silty texture; increased amounts of sand in this sample interval; a heavy oil stained sandstone is present in this sample interval; predominantly quartz composition, upper fine grained, very well sorted; round to sub round, with high sphericity possible silica cementation, very poorly cemented with excellent visible porosity increased amounts of dark green fluorescence and slow streaming cut Sand/Claystone(7150-7200)= pale yellowish brown, very light smoky gray, brown, very light smoky gray, transparents and translucents; 65%quartz composition; upper fine to medium grained with abundant coarse grained; poorly sorted; sub round to round with moderate sphericity; unconsolidated with no visible cementation; abundant claystone; abundant lithic material; trace amounts of pyrite; liberated free oil visible in sample; 60% scattered dark green fluorescence; slow wispy streaming cut; no detectable odor Sand/Claystone(7200-7300)=grayish orange, pale yellowish orange, dark yellowish orange, moderate yellowish brown due to oil staining, translucents and transparents; very pale orange; some grayish blue green; medium grained with abundant course grains throughout; poorly sorted; round to sub round; 18 CANRIG Ell Nikaitchuq OP14-S3 moderated to high sphericity; unconsolidated with no apparent cementation; large amounts of claystone still present; good quantities of fractured coal and lithic material; liberated free oil visible in sample; 70% of sample with dull green scattered fluorescence; slow wispy streaming cut no detectable odor Claystone(7300-7350)= light gray to medium gray, poor cohesion lumpy to clumpy consistency, pulverulent mass, irregular open fracture, dull earthy luster; very silty texture; trace amounts of lightly oil stained quartz; bright white green scattered fluorescence on 35% of sample no detectable petroleum odor FAULT#2 7368.0' MD/-3464.9'TVDSS Claystone(7350-7400)= medium light gray to light gray; cohesive and non to slightly adhesive; mushy to pasty; amorphous; pulverulent; massive cuttings habit; earthy to dull luster; smooth to clayey texture with occasional quartz grains embedded; dull yellow fluorescence over 40%of sample; no free oil in sample; fluorescence possibly due to mud additive, lotorq. Claystone(7400-7450)= medium light gray to light gray; cohesive and non to slightly adhesive; mushy to pasty; amorphous; pulverulent; massive cuttings habit; dull to earthy luster; clayey to gritty texture with occasional quartz grains embedded; dull yellow fluorescence over 30% of sample; no free oil in sample; fluorescence possibly due to mud additive, lotorq. N SEQUENCE TOP 7485.0' MD/-3481.6'TVDSS Sand (7450-7530)= light gray to very light gray with translucents; 70% quartz and 30% lithics; lower medium to upper fine grained; fair to well sorted; sub angular to sub round; low to moderate sphericity; impacted texture; loose unconsolidated sands; majority of grains lay in a clay matrix; no free oil in sample; trace light brown stains; 10%of sample exhibits a faint yellow fluorescence; dull to faint,white to yellow cut fluorescence; clear visible cut; no visible residue;faint yellow residual cut. Sand (7530-7610)= light gray to very light gray with translucents and transparents; 60% quartz and 40% lithics and mudstone which gives the sample a salt and pepper appearance; lower to upper medium grained;well sorted; sub round to sub angular; moderate sphericity; impact abrasion; loose unconsolidated quartz grains; no apparent cementation; trace amounts of carbonaceous shales with thin fissile laminations; no petroleum odor; no free oil in sample; only safe carb appears to exhibit a light brown stain; lotorq appears to be bonding with safecarb; <10%faint yellow sample fluorescence. Claystone(7610-7690)= light gray to very light gray with occasional medium light gray hues; sample largely consists of cohesive clumps of pulverulent claystone; non to fairly adhesive; mushy to pasty; amorphous; no apparent fracture; massive cuttings habit; earthy to waxy luster; smooth to clayey texture with granular appearance due to embedded quartz and lithic grains; approximately 20-30%faint yellow sample fluorescence likely due to lotorq contaminated safe carb; no petroleum odor or free oil in sample. Sand (7690-7770)= light gray to very light gray with translucents and transparents; 70%quartz and 30% lithics and mudstone which gives the sample a salt and pepper appearance; upper fine to lower medium grained; moderate to well sorted; sub angular to sub round; low to moderate sphericity; impact abrasion; loose unconsolidated sands with no apparent cementation; fine grain calcareous sandstone fragments in sample amounting to<10%of sample; trace amounts of carbonaceous shale and pyrite in sample; <10% sample fluorescence; no petroleum odor; no free oil or stained quartz grains in sample;fluorescence likely due to mud additive lotorq. Sand (7770-7830)= light gray to medium light gray with bluish gray hues and abundant translucents and transparents; 80-90%quartz with mudstone and lithics in a clay matrix; upper fine to lower medium with increasing amounts of lower fine; well sorted; moderate to high sphericity; loose unconsolidated quartz; grain supported; no apparent cement; no petroleum odor; no other hydrocarbon indicators. 19 CANRIG _611 Nikaitchuq OP14-S3 N SAND TOP 7918.0' MD/-3543.0' TVDSS Sand (7830-7950)=very light gray to medium light gray with bluish gray hues and abundant translucent to transparent grains;fine to medium grain; moderate sorting; sub round to sub angular; moderate sphericity; loose unconsolidated quartz grains; no apparent cement; carbonaceous shale is crunchy to crumbly and generally platy to tabular cuttings with thin fissile laminations occasionally thin pyrite laminations interbedded; on occasion when shale was prodded, small dark pin head sized blobs of oil were released; fair amount of pyrite in sample; trace amount of free oil in sample; slight petroleum odor; no staining on quartz grains;fairly even, faint yellow to orange fluorescence over 70% of sample; translucent bluish white cut with fast white streamers; clear visible cut; light amount of pale straw residue; dull orange residue fluorescence. N SUBLOBE 2 7997.0' MD/-3554.2'TVDSS Sand (7950-8050)=very light gray to medium gray with bluish gray hues and abundant translucents and transparents; lower coarse to upper medium abundant medium grains; well sorted; sub round to sub angular; moderate sphericity; loose unconsolidated and disaggregated quartz grains; grain supported; <10% calcareous sandstone in sample, one fragment exhibited light brown staining and when prodded small black oil drop released; trace amount of free oil in sample; very slight petroleum odor; no staining on loose quartz grains; patchy faint yellow and spots of orange fluorescence over 50% of sample; instant translucent bluish white to white cut fluorescence; clear visible cut; light amount of pale straw residue; faint orange residue fluorescence. Sand (8050-8150)=very light gray to medium gray with bluish gray hues and abundant translucents and transparents; occasional dark greenish gray; occasional grayish blue green; fine to lower medium with numerous course grains; 75% quartz, 25% lithic composition; moderately well sorted; round to sub round with moderate sphericity; largely unconsolidated with no apparent cementation; dark yellowish brown oil stain on approximately 15%of sample; bright yellow green fluorescence on 45%of sample; very fast whitish blue cut N SUBLOBE 3 8162.9' MD/-3577.4'TVDSS FAULT#3 8243.0' MD/-3588.2'TVDSS Sand (8150-8250)=very light gray to medium gray with bluish gray hues and abundant translucents and transparents; occasional dark greenish gray; occasional grayish blue green; 60%quart 40% lithic; increased amounts of large fragmented lithics; medium to upper fine grained with numerous large grains; moderate to poorly sorted; sub round to round with numerous subangular grains; moderate to low sphericity; largely unconsolidated with no apparent cementation; dark yellowish brown stain on less than 5% of sample volume; bright yellow green fluorescence on 35%of sample; very fast whitish blue cut Sand (8250-8300)=very light bluish gray, bluish white, very pale orange, translucent and transparents, occasional pale green and pale blue green, approximately 85%quartz and 15% lithic composition; fine grained well sorted; round to well rounded; high sphericity; largely unconsolidated with no visible cementation; shell and coal fragments; decrease in oil stained quartz grains from last interval with less than 1% of sample with staining; yellow green scattered fluorescence. Sand (8300-8350)=very light bluish gray, bluish white, very pale orange, translucents and transparents, occasional pale green and pale blue green, approximately 85%quartz and 15% lithic composition; fine grained well sorted; round to well rounded; high sphericity; largely unconsolidated with no visible cementation; increased amounts of very silty claystone;trace amounts of coal and shell fragments; little to no oil staining is present; scattered pinpoint yellow green fluorescence; no detectable odor 20 CANRIG ilrot Ent Nikaitchuq OP14-S3 Sand (8350-8450)=very light gray, light bluish gray, very pale orange, bluish white, occasional grayish green grayish blue green, abundant translucents and transparents, 85%quartz 15% lithic composition, medium to upper fine grained with numerous course grains, moderate to well sorted; round; high sphericity; unconsolidated with no apparent cementation; shell fragments; very silty claystone; small amounts of oil stained grains; scattered bright yellow fluorescence; billowing fast white ring N SUBLOBE 3 8487.0' MD/-3618.5'TVDSS Sand(8450-8550)=very light gray, light bluish gray,very pale orange,bluish white,occasional grayish green grayish blue green, abundant translucents and transparents, 70% quartz 30% lithic composition, medium grained with some upper fine and large amounts of coarse grains;round to sub round;unconsolidated with no apparent cementation; small amounts of calcareous matter and cement;good amounts of oil staining; bright yellow fluorescence on 85%of sample volume; very fast white ring; moderate petroleum odor N SAND BOTTOM 8690.0' MD/-3637.5' TVDSS Sand (8550-8700)= primarily transparent and translucent, some light gray, some very light gray with smoky hues, occasional pale bluish green and grayish blue green; 95% quartz composition with 5% lithics, with lithics becoming more apparent through the sample interval; fine grained with some lower medium and some very fine; v well sorted becoming less well sorted through interval; well rounded; very high to high sphericity; unconsolidated with no apparent cementation; trace amounts of large quartz nodules and fractured cuttings, trace amounts of pyrite, some coal fragments and carbonaceous matter, very trace amounts of calcareous material, some shell fragments, claystone and silt; high amounts of oil staining and some free oil in sample with 75-80%of sample with staining; 75-80%dull yellow green occasionally white fluorescence becoming less apparent through interval; very fast streaming white cut and ring; strong petroleum odor Sand (8700-8800)= primarily transparent and translucent, some light gray, some very light gray with smoky hues, occasional pale bluish green and grayish blue green; 70%quartz composition with 30% lithics; fine grained well to very well sorted; round to well round; high sphericity; unconsolidated with no visible cementation; trace amounts of mica; claystone and silt becoming more apparent through sample interval; small amounts of staining and very trace amounts of residual free oil; approximately 5-15%of sample exhibits stain; scattered pinpoint dull yellow green fluorescence; very fast streaming white cut and ring; faint petroleum odor Sand (8800-8900)= primarily transparent and translucent, some light gray, some very light gray with smoky hues, occasional pale bluish green and grayish blue green; occasional light blue green, primarily quartz composition; 75%quartz and 25% lithic; fine grained with some lower medium; well to very well sorted; round to sub round; high to moderated sphericity; unconsolidated and loose with no apparent cementation; trace amounts of mica, trace pyrite; some carbonaceous material; trace amounts of feldspar; trace shell fragments; silt and claystone; very little oil stain; less than 5%of volume scattered moderated yellow green fluorescence Sand (8900-9000)= primarily transparent and translucent, some light gray, some very light gray with smoky hues, occasional pale bluish green and grayish blue green; occasional light blue green, primarily quartz composition; 70%quartz and 30% lithic; fine grained with some lower medium; well to very well sorted; round to sub round; high to moderated sphericity; unconsolidated and loose with no apparent cementation; trace amounts of mica; some carbonaceous matter; trace amounts of pyrite; silt and claystone volume increasing throughout sample interval; oil staining decreasing through interval with 5% of sample stained; dull yellow green fluorescence Sand/Claystone(9000-9100)= light gray to very light gray, translucent and transparent, very pale orange, occasional very pale bluish green; 85% quartz and 15% lithic composition; lower medium to upper fine grained with numerous course grains; moderately well sorted; sub round to round; moderate sphericity; 21 CANRIG 6d Nikaitchuq OP14-S3 unconsolidated; fair amounts of calcareous material; calcite; trace feldspar; increasing amounts of claystone and silt; oil stain on less than 5%of sample volume; scattered dull yellow green fluorescence Sand/Claystone(9100-9200)= light gray to very light gray, abundant translucent and apparents, very pale orange in places; trace blue green glauconitic grains; 85%quartz 15% lith lower medium to upper fine grained with numerous course grains; moderately well sorted; sub round to round; moderate sphericity; unconsolidated; bitumous coal fragments; carbonaceous matter; increasing amounts of claystone and silt; trace mica; very little oil stain with less than 5% of sample exhibiting staining; trace scattered fluorescence Sand/Claystone(9200-9250)= light gray to very light gray, some medium gray translucent and transparent, occasionally greenish gray, occasional dusky blue green; 80% quartz and 20% lithic composition; lower medium to upper fine grained with numerous coarse grains; moderately well sorted; round to sub round; with high sphericity; coal fragments and some carbonaceous matter; some calcareous material; claystone and silt; little to no oil staining Claystone/Sand (9250-9300)= light gray to medium light gray; expansive with poor cohesion; mushy to slimy consistency; pulverulent tenacity; irregular indeterminable fracture; massive cuttings habit; earthy greasy luster; silty clayey texture; very argillaceous with interbedded fractured coal and carbonaceous matter; interbedded sand; shell fragments and abundant lithic material; moderately calcareous; no visible oil stain; trace amounts of fluorescence possibly residual; very poor visible porosity Claystone/Sand (9300-9400)= light gray to medium light gray; expansive, poor cohesion; mushy consistency pulverulent tenacity; irregular indeterminable fracture; massive cuttings habit; dull earthy greasy luster; silty clayey texture; very argillaceous with interbedded fractured coal and carbonaceous matter; increasing amounts of interbedded sand; interbedded coal fractures and abundant lithic material; some carbonaceous matter; calcareous shell fragments and other calcareous matter; little to no visible porosity; no hydrocarbon indicators Claystone/Sand (9400-9450)= light gray to medium light gray; mushy, slimy consistency; pulverulent tenacity; irregular indeterminable fracture; massive cuttings habit; earthy greasy luster; very silty clayey texture abundant coal and carbonaceous matter; interbedded sand; some calcareous material; no visible porosity no visible oil staining LOWER N MARKER 9414.0' MD/-3695.8' TVDSS Claystone/Sand (9400-9450)= light gray to medium light gray; mushy, slimy consistency; pulverulent tenacity; irregular indeterminable fracture; massive cuttings habit; earthy greasy luster; very silty clayey texture abundant coal and carbonaceous matter; increasing amounts of sand throughout this sample interval; trace amounts of oil staining and trace amounts of very fine pin head free oil in sample; sample still contains very poor visible porosity Claystone/Sand (9500-9600)= light grey to very light grey with occasional light bluish hues; mushy; pulverulent; earthy fracture; no discernable cuttings habit; earthy to dull luster; clayey to silty to gritty texture on occasion; good cohesion; poor to slightly moderate adhesion; moderate hydrophobia; non calcareous; sand is predominantly clear to translucent quartz; well sorted; good sphericity; upper very fine to lower fine with occasional upper fine grains present; rounded to well rounded; oil stained grains present but not common; poor dark gold fluorescence on about 30%of the sample. N SEQUENCE BASE 9610.0' MD/-3712.8' TVDSS Claystone/Sand (9600-9700)=very light grey to light grey with blue to pinkish hues; poor induration; lumpy to curdy; pulverulent; earthy fracture; no discernable cuttings habit; earthy to dull luster; clayey to silty texture; good cohesion; poor to moderate adhesion; mildly hydrophobic but swells after sitting in water; the sand is comprised of clear to translucent quartz; lower fine to upper fine with upper very fine grains common; moderate sorting; good sphericity; rounded to well rounded; oil stained grains are 22 CANRK7 611 Nikaitchuq OP14-S3 uncommon; a black carbonaceous material is common but not abundant; pin drops of oil are visible; poor dark gold to yellow fluorescence visible on 40%of the sample. Claystone/Sand (9700-9860)=samples consist of a light brownish gray to pale olive gray pasty mass of disaggregated clay and very fine sand, along with some drilling mud; bulk samples exhibit moderate cohesion and fair to good plasticity; when dry, samples are yellowish gray and pulverulent; the clay is hydrophilic and mildly adhesive; the sand is moderately to well sorted with grain sizes ranging from upper to lower very fine-grained, grading into silt-sized particles; sand grains mostly consist of translucent to transparent very light gray quartz with minor dark gray siliceous lithics, trace blue green glauconite and rare pinkish orange shell fragments and pyrite clusters; grains are subrounded to subangular, and quartz grains are etched and pitted; samples are moderately calcareous, and rare calcite cemented sandstone cuttings can be found within the samples; free oil is visible on the shakers, and 10%of the samples are coated with a spotty oil stain, restricted to calcareous sands; 15%to 25% of the samples fluoresce bright yellow to gold; a streaming,weak to moderate white cut fluorescence is emitted. Sand/Claystone(9860-10050)=samples consist of a mushy, slightly lumpy, brownish gray slurry of loose sand and disaggregated clay; bulk samples exhibit moderate cohesion and poor to moderate plasticity; samples are light gray to yellowish gray and pulverulent when dry; clay rich lumps are extremely soft and mushy and no intact claystone is apparent;the sand is moderately to well sorted and very fine-to fine- grained, with a salt and pepper appearance; the sand is mostly comprised of translucent very light gray quartz with subordinate black siliceous lithics; trace to minor opaque blue green glauconitic lithics, trace pyrite clusters, and pale pinkish orange shell fragments are also scattered throughout the sand; grain sizes are predominantly upper very fine-grained to lowermost fine-grained, with lesser amounts of lower very fine-grained sand grading into silt-sized particles; grains are subrounded to angular, and sphericity is moderate on average; while angular, abraded grains are easy to spot, quartz grain surfaces are often etched and pitted; samples are very calcareous, and tiny, very rare, calcite cemented sandstone cuttings can be found; free oil is present on the shakers and 10%to 20%of the samples are lightly stained, though the amount of oil decreases with depth; bright yellow pinpoint fluorescence corresponds with the oil staining, and a streaming, dull white cut fluorescence is emitted. Sand/Claystone(10050-10200)=samples consist of a light brownish gray, pasty mass of disaggregated clay and very fine sand bulk samples display poor to moderate cohesion and fair to good plasticity, both of which increase with depth in relation to clay content; the sand is moderately to well sorted,with grain sizes predominantly along the boundary between upper very fine-to lower fine-grained, along with small amounts of upper fine sand and lower very fine sand that grades into silt; the sand mostly consist of light gray translucent quartz with subordinate black siliceous lithics,which impart a salt and pepper appearance to the sand; trace blue green glauconite and rare pyrite is present as well; grains are subrounded to subangular with moderate to poor sphericity on average, and quartz grain surfaces are etched and pitted; samples are moderately calcareous;trace light oil stain is visible and roughly 5% pinpoint yellow fluorescence corresponds with the staining; a streaming, dull white cut fluorescence is emitted. OA SAND TOP 10228.5' MD/-3776.0'TVDSS Drill Rate(ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 516 1 243 919 0 305 PEAKS Depth TG C1 C2 C3 C4I C4N C5I C5N 10310 486 149454 1650 544 376 336 236 49 10734 588 77873 556 115 79 101 70 64 10889 735 96931 816 100 72 80 58 41 11443 834 101964 451 158 0 0 0 0 11548 919 108269 493 238 10 11 10 3 11742 735 85890 629 81 57.655 62 58 15 12432 804 106411 781 167 115 _ 135 83 69 23 CANRIG 611 Nikaitchuq OP14-S3 12737 800 108957 1032 188 143 168 116 78 13245 813 116747 986 221 153 177 101 24 13943 604 77514 588 201 124 131 76 11 17261 530 _ 79067 624 255 161 189 118 108 Sand/Claystone(10200-10300)=samples consist of a mushy, light olive gray slurry of loose sand and disaggregated clay; the sand is a very fine-grained, moderately to well sorted quartz sand with minor black siliceous lithics, trace blue green glauconite, and rare pyrite and pale pinkish orange shell fragments; grain sizes range from upper fine-to lower very fine-grained; grains are subrounded to subangular with moderate sphericity; quartz grain surfaces are etched and pitted; samples are moderately calcareous, and rare bits of calcite cemented sandstone can be found; 5%to 10% light oil staining fluoresces bright yellow; a streaming, dull white cut fluorescence is emitted. OA SUBLOBE 2 10334.0' MD/-3786.3'TVDSS Claystone/Sandstone(10300-10450)=sample consist primarily of claystone and sandstone the claystone is light to medium light gray; moderately cohesive and adhesive; lumpy to clumpy consistency; flexible and malleable tenacity; irregular open fracture; massive cuttings habit; clayey silty texture; interbedded sand; interbedded lithics; interbedded coal fragments and some carbonaceous matter; pyrite; trace amounts of feldspar; glauconitic lithics a fine grained sandstone is also present 100%quartz composition; very well sorted sub angular to angular;with very low sphericity; easily friable with possible silica cementation; moderately cemented; 100%very light brown stain is present with moderate visible porosity; the sample overall exhibits 70%fluorescence with the sandstone at 100%fluorescence; an immediate light straw cut is emitted with high intensity; dull yellowish white residual fluorescence. 9 5/8"CASING SHOE 10440.0 MD/-3794.2' TVDSS OA SUBLOBE 3 10455.0' MD/-3794.7 TVDSS Sand (10450-10650)=samples consist of a slurry of fine to very fine sand with abundant calcium carbonate mud additive of similar size; the sand is well sorted and is almost entirely composed of translucent to transparent very light gray quartz with scattered pale yellow and orange grains; trace amounts of black siliceous lithics and rare blue green glauconite and orange lithics are also present; the crushed marble occurs as partial cleavage fragments that are difficult to distinguish from the quartz; grain sizes are centered about the boundary between fine-and very fine-grained,with abundant finer sand and scattered coarser sand up to rare coarse grains; the grains are subrounded to subangular with moderate sphericity on average and grain surfaces are etched and pitted; samples effervesce violently in acid, primarily due to the mud additive, though very rare, poorly indurated, intact sandstone cuttings are cemented by calcite; sparse free oil is visible on the shakers, largely masked by the oil-based mud; rare light oil staining is visible in the samples, and very occasional bits of tar are present; petroliferous odor is masked by the oil-a very dull, even white fluorescence is emitted, due in part to the calcite mud additive but accentuated by roughly 5% patchy yellow fluorescence; an immediate cut fluoresces milky white. Sand (10650-10850)= samples consist of a slurry of fine to very fine sand with sporadic small amounts of siltstone cuttings; the sand is a well sorted quartz sand with grain sizes mostly within the range of upper very fine-to lower fine grained, along with abundant lower very fine sand and scattered coarser sand up to rare coarse grains; the bulk of the sand is comprised of translucent to transparent very light gray quartz with a few pale yellow and orange grains; minor siliceous black lithics are also present, along with trace amounts of blue green glauconite and rare orange lithics and pale pinkish orange shell fragments; samples are heavily contaminated with cleavage fragments of calcium carbonate mud additive; the 24 CANRIG Nikaitchuq OP14-S3 introduced calcite causes samples to effervesce strongly in acid, though some very rare intact sandstone cuttings are weakly cemented by calcite; grains are mostly subangular to subrounded with moderate to good sphericity and quartz grain surfaces are etched and pitted; tabular siltstone cuttings are moderate to light brown, and softened by circulation up the hole oil-based mud; very light oil staining is scattered throughout the samples; oil-based mud scent masks any potential oily odor; an even, weak white fluorescence is emitted, due in large part to both oil-based mud residue and calcite mud additive; roughly 5% patchy weak yellow fluorescence is visible across the samples as well; an immediate cut fluoresces milky white. OP14-S3 LATERAL FAULT 1 10922.0' MD/-3810.2 TVDSS Sandstone/Siltstone(10850-11000)= light gray to medium light gray with smoky gray hues; abundant translucents and transparents; occasional light brownish gray with pinkish gray hues; bluish white to white with some light greenish gray; trace amounts of grayish blue green glauconitic sandstone primarily quartz composition; 85% quartz and 15% lithic; very fine to lower fine grained with some upper medium grains; very well sorted; round to very round; high to moderate sphericity; easily friable to friable; moderate cementation silica cement with some argillaceous cement in places; some grains support; medium dark gray to dark grey siltstone is also present; moderately firm with imbedded sand and lithics; a light brownish gray siltstone is also present; pulverulent to malleable consistency; pyrite; shell fragments; some coal fragments and carbonaceous material imbedded in siltstone; some framboidial pyrite; good quantities of silt; no petroleum odor is detectable and is most likely masked by drilling fluid; very little staining is visible through the sample interval; scattered bright yellow fluorescence again fluorescence is masked by oil based drilling fluid Siltstone/Sandstone(11000-11100)= medium light gray to medium gray occasionally medium dark, stiff to firm consistency, dense to sectile tenacity, mottled open fracture due to hydration; platy and flaky cuttings habit; earth dull luster; silty sucrosic texture; imbedded sand and quartz, thin carbonaceous laminae, imbedded carbonaceous material, imbedded framboidial pyrite, a secondary siltstone is also present dark yellowish brown to grayish orange, pulverulent due to hydration and very silty in texture; good quantities of very fine grained sandstone present as well; no detectable petroleum odor; no visible oil staining Siltstone/Sandstone(11100-11200)= medium light gray to light gray with some medium dark gray in places; moderately soft; malleable, pulverulent when dissolved from drilling fluids; open irregular fracture platy to flaky cuttings habit; dull earthy luster; silty to gritty texture sucrosic once dried; imbedded quartz and lithic fragments; imbedded carbonaceous material; imbedded pyrite; a grayish orange to dark yellowish orange siltstone is also present; mushy gelatinous consistency and pulverulent tenacity; large quantities of imbedded diatoms are present; good quantities of sandstone throughout interval; trace amounts of oil stained quartz; with no detectable odor; trace pinpoint fluorescence masked by drilling fluid OA BOTTOM 11267.0' MD/-3811.4 TVDSS Siltstone/Sandstone(11200-11300)= medium light gray to light gray with some medium dark gray in places; firm, stiff consistency; sectile and dense tenacity; blocky and planar fracture occasionally irregular due to hydration; flaky, blocky cuttings habit dull earthy luster; silty and gritty texture; large quantities of imbedded quartz and lithic material; large amounts of imbedded pyrite; trace amount of feldspar and limonite; shell fragment present throughout; good quantities of large quartz nodules and loose sand; bitumous coal fragments and some carbonaceous matter; sand and sandstone becoming more prevalent throughout interval; trace amounts of stained quartz with no detectable odor; trace amounts of pinpoint fluorescence 25 CANRIG k eat Nikaitchuq OP14-S3 OA SUBLOBE 4 11383.0' MD/-3807.3'TVDSS Sandstone/Siltstone(11300-11450)= light gray to medium light gray with smoky gray hues; abundant translucents and transparents; occasional grayish blue green glauconitic; primarily quartz composition, 90%quartz and 10% lithic; upper very fine to lower fine grained; very well to well sorted; round to well rounded; high sphericity; friable; moderately cemented with silica cementation; some grain support is present in sandstone matrix; abundant pyrite; coal fragments and carbonaceous matter; trace amounts of feldspar; excellent visible porosity; no detectable odor; trace amounts of oil stain on quartz; fluorescence is masked due to drilling masked due to oil based drilling fluid Sandstone/Siltstone(11450-11550)= light gray to medium light gray with smoky gray hues; abundant translucents and transparents; occasional grayish blue green glauconitic; primarily quartz composition, 90%quartz and 10% lithic; upper very fine to lower fine grained; very well to well sorted; round to well rounded; high sphericity; friable; moderately cemented with silica cementation; some grain support is present in sandstone matrix; sandstone cementation is disguised from drilling environment; abundant coal fragments and carbonaceous matter; trace amounts of feldspar,trace amounts of shell fragments; large quantities of pyrite; fair amounts of silt are still present with some siltstone becoming less apparent through interval; excellent visible porosity; no petroleum odor; no visible oil staining Sandstone(11550-11800)=samples consist of an olive brown to brownish gray slurry of loose sand and variable small amounts of siltstone cuttings; samples are highly contaminated with calcium carbonate additive; the sand primarily consists of transparent to translucent very light gray quartz with minor black siliceous lithics and trace blue green glauconitic lithics; as a whole, the components impart a salt and pepper appearance to the sand under the microscope; the sand is well sorted,with grain sizes mostly falling within a tight range from upper very fine-to lower fine-grained, along with minor lower very fine sand and sparse coarser grains up through rare grains of lower medium-grained sand; grains are mostly subrounded to subangular with moderate sphericity on average; quartz grain surfaces are commonly etched and pitted; grains of calcium carbonate additive similar in size to the sand grains and can be difficult to distinguish from the quartz, with the exception of planar cleavage faces on much of the calcite; the mud additive causes samples to effervesce violently in acid, although rare intact sandstone cuttings are weakly cemented by calcite; good visual porosity within the sandstone depending on the amount of calcite cementation; visual permeability appears to be fair;the siltstone cuttings are brown to grayish brown, subblocky to tabular, and crumbly; traces of faint oil staining are visible, and 1%to 2% of patchy yellow fluorescence is visible amongst an even, dull white background fluorescence attributable to residual oil-based mud and the ubiquitous calcite; an immediate cut fluoresces dull milky white; any potential petroliferous odor is masked by the scent of oil-based mud. OA SUBLOBE 3 11994.0' MD/-3785.8' TVDSS Sand (11800-12020)=samples consist of an olive brown to brownish gray slurry of loose sand with variable amounts of siltstone cuttings at intermittent intervals; the sand is a well sorted lithic-quartz sand with grain sizes mostly within a narrow range from upper very fine-grained to lower fine grained, as well as minor lower very fine sand and rare coarser grains as large as upper medium-grained; the quartz is a translucent very light gray to transparent and colorless; subordinate lithics are mostly black and siliceous, although trace blue green glauconite and pale orange dolomitic shell fragments are also scattered throughout the sand; samples are heavily contaminated with fine to very fine calcium carbonate additive which is difficult to discern from the quartz, although most of the calcite displays at least one or two planar cleavage faces; the sand grains are subrounded to subangular with moderate sphericity overall, and quartz grain surfaces are etched and pitted; the siltstone is olive brown, partly due to saturation with oil- based mud; siltstone cuttings are blocky to tabular and have a dull, earthy luster underlain by a silty texture; microscopic black, carbonaceous laminae are visible in some siltstone cuttings; a small amount of free oil on the shakers has separated from the oil-based mud, though staining is not evident in the samples; an even, dull white fluorescence is emitted, due in part to the crushed marble and residual oil- 26 CANRIG Nikaitchuq OP14-S3 based mud; very faint, dispersed patches of yellow fluorescence are perceptible; an immediate cut fluoresces milky white; oil-based mud scent masks any potential oily odor. OA SUBLOBE 2 12124.0' MD/-3780.0'TVDSS OP14-S3 LATERAL FAULT 2 12143.5' MD/-3779.2 TVDSS Sand (12020-12270)=samples consist of an olive brown slurry of loose sand with intermittent siltstone cuttings; samples are olive gray and pulverulent when dry; the sand is a well sorted quartz sand; the grain size of the bulk of the sand lies along the boundary between fine-and very fine-grained, though the full range of grain sizes extends from lower very fine-to rare lower medium-grained sand; grains are mostly comprised of translucent very light gray quartz,with minor amounts of dark lithics that impart a salt and pepper appearance to the samples under the microscope; the lithics mostly consist of very dark gray to black siliceous grains, along with trace to minor blue green glauconitic lithics and scattered trace pale orange shell fragments; samples also contain abundant cleavage fragments of crushed calcium carbonate, similar in size to the sand grains and difficult to discern from the quartz; the sand grains are mostly subrounded to subangular with moderate sphericity on average; quartz grain surfaces are etched and pitted; the siltstone is light grayish brown to olive gray, with a dull, earthy luster underlain by a silty texture; cuttings are subblocky to wedgelike or tabular, though all are rounded; the calcite contamination obscures true calcite content of the cuttings, but scattered intact sandstone cuttings and selected hard siltstone cuttings are calcareous, particularly in the lower half of this interval; oil staining is not readily apparent, and any potential petroleum odor is masked by oil-based mud scent; an even, dull white fluorescence is emitted, due in part to oil-based mud residue and the abundant crushed marble; the background fluorescence is accentuated by a weak, patchy, yellow fluorescence over less than 5%of the sample; an immediate cut fluoresces milky white. Sand (12270-12500)=samples consist of an olive gray to grayish brown slurry of loose sand with scattered small, soft siltstone cuttings; the sand is well sorted, with the vast majority of it falling within a tight range of upper very fine-grained to lower fine-grained; the remainder is mostly lower very fine- grained,with scattered coarser grains up to and including rare medium-grained sand; the sand is primarily composed of translucent very light gray quartz and subordinate dark lithics, which results in a salt and pepper appearance under the microscope; the dark lithics are mostly black and siliceous, along with trace blue green glauconitic lithics and pale orange shell fragments;with the exception of the latter, the sand grains are subrounded to subangular and display moderate sphericity on average; quartz grain surfaces are commonly etched and pitted; crushed calcium carbonate ubiquitous in the samples, and aside from planar cleavage surfaces, it is difficult to discern it from the quartz sand as it is similar in size; the siltstone cuttings are light grayish brown and vaguely wedgelike or tabular, with rounded edges;the siltstone is crumbly, with a dull, earthy luster and a silty texture, and some contain microscopic black, carbonaceous laminae; the crushed marble mud additive effectively prevents determination of the calcareous nature of the formation, although hard siltstone cuttings and rare, intact but delicate sandstone cuttings found near the top of this interval are cemented by calcite; no oil stain is evident, but a moderate, even white fluorescence is emitted from the samples, likely due in part to oil-based mud residue and the abundant calcite additive; an immediate cut fluoresces milky white. Sand (12500-12700)=samples consist of an olive gray slurry of loose sand with negligible amounts of scattered siltstone cuttings;the sand is a well sorted lithic-quartz sand, with most of the grains falling between upper very fine-and lower fine-grained; minor amounts of lower very fine-grained sand constitute much of the remainder, and coarser sand up to lower medium-grained are present in trace to minor amounts; translucent very light gray quartz constitutes the majority of the sand, and minor dark lithics make up the rest; crushed calcium carbonate is abundant in the samples, and aside from planar cleavage faces, it is difficult to differentiate from the quartz sand as it occurs in the same size fraction; the lithics are mostly very dark gray to black,which give the samples a salt and pepper appearance under the microscope; trace blue green glauconitic lithics and pale orange to pinkish orange shell fragments are also present in the sand; while the calcite cleavage fragments have a blocky appearance, the sand grains display moderate sphericity on average and are subangular to angular; quartz grain surfaces are 27 CANRIG Erd Nikaitchuq OP14-S3 commonly etched and pitted; oil staining is not readily apparent, and oily odor is imperceptible beyond oil- based mud scent; a moderate to dull white even fluorescence is emitted, due in part to the calcite mud additive and oil-based mud residue; an immediate cut moderately to strongly fluoresces milky white. Sandstone/Sand (12700-12850)= light gray to medium light gray with smoky gray hues; abundant translucents and transparents; occasional grayish blue green glauconitic; primarily quartz composition, 90%quartz and 10% lithic; upper very fine to lower fine grained; very well to well sorted; round to well rounded; high sphericity; friable; moderately cemented with silica cementation; some grain support is present in sandstone matrix; sandstone cementation is disguised from drilling environment; some cemented portions remained intact; some fragmented carbonaceous matter is present; trace amounts of shell fragments; some large quartz nodules as well as larger crystalline quartz; excellent visual porosity; no detectable petroleum odor; trace amounts of oil stain less than 1%of the total volume of sample; fluorescence is difficult to ascertain due to oil based drilling fluid; some pinpoint bright whitish yellow fluoresce is discernable beyond the background of the fluorescence induced from the fazepro mud. Sandstone/Sand (12850-13000)= primarily transparents and translucents light gray to medium light gray with smoky hues; some grayish green, grayish blue green, moderate blue green glauconitic grains are present; primarily quartz composition; 95%quartz and 5% lithics; some larger dark lithics present approx. 0.5-0.25 mm throughout; upper fine grained to lower fine grained with some larger crystalline and quartz nodules; very well to well sorted; round to sub round with high to moderate sphericity; friable to firmly friable with moderate cementation; cementation is disguised due to drilling environment some cemented sandstone fragments remain intact; silica cementation with some grain support; small coal fragment and other carbonaceous material; traces of medium light gray siltstone are present comprising less than 5%of sample volume; trace shell fragments; excellent visual porosity; no detectable petroleum odor; little to no oil staining; no fluorescence is visible beyond that of the artificial from the residual drilling fluid. Sandstone/Sand (13000-13150)= primarily transparents and translucents light gray to medium light gray with smoky light gray hues; some grayish blue green, moderate blue green glauconitic grains are present; primarily quartz composition; 90% quartz 10% lithics; increasing amounts of lithics through this interval; upper very fine to very fine grained;with some larger quartz grains apparent;well to very well sorted; round to well round; high sphericity; sample is loose and unconsolidated mostly due to drilling environment and bit action; some cemented fragments remain intact; they exhibit a friable to firmly friable hardness and silica cementation; some possible argillaceous cement; grain supported in some places; trace amounts of light to medium light gray siltstone; shell fragments; good amounts of carbonaceous matter and fractured coal; calcium carbonate additive is also readily apparent; no detectable petroleum odor; little to no oil stain is visible with less than 1% of sample volume exhibiting staining; no free oil is visible in sample; no fluorescence is apparent beyond the artificial fluorescence emitted by the fazepro oil based drilling fluid Sandstone/Sand (13150-13300)= light gray to medium light gray with smoky gray hues; abundant translucents and transparents; occasional grayish blue green glauconitic grains primarily quartz composition, 90%quartz and 10% lithic; upper very fine to lower fine grained; very well to well sorted; round to well rounded; high sphericity; friable; moderately cemented with silica cementation; some grain support is present in sandstone matrix; sandstone cementation is disguised from drilling environment; some cemented portions remained intact; some fragmented carbonaceous matter is present; trace amounts of shell fragments; some large quartz nodules as well as larger crystalline quartz; excellent visual porosity; no detectable petroleum odor beyond the smell emitted from the drilling fluid; little to no visible staining; occasional stain exist on quartz with less than 1%of sample volume exhibiting stain; sample fluorescence is completely masked by the artificial fluorescence from the oil based fazepro drilling fluid Sandstone/Sand (13300-13500)= primarily transparents and translucents with very light gray smoky hue; some white and whitish gray quartz grains some grayish green and pale green glauconitic grains; occasional moderate pale blue green; dark scattered assorted lithic grains; primarily quartz composition with 90%quartz and 10% lithic; upper very fine to lower fine grained with some course rounded quartz as well as some very angular course grains present;well to very well sorted; round to well rounded; high sphericity; sample appears to be loose and unconsolidated however some cemented fragments of the sandstone matrix remain intact; the cemented portions are soft to easily friable some are firmly friable in places; silica cementation with possible argillaceous cementation and consolidation in places; some grain support; trace amounts of light gray to medium light gray siltstone; some containing numerous black 28 CANRIG igth Ertl Nikaitchuq OP14-S3 laminae of carbonaceous matter; arenaceous siltstone is grading to sandstone in places; very trace amounts of pyrite; large quantities of coal fractures and less than 1 mm carbonaceous material.Amount of silt and siltstone increased through the sample interval; excellent visual porosity; no detectable petroleum odor; little to no oil stain is apparent with the oil stained quartz comprising less than 1%of sample volume; no fluorescence is detectable beyond the artificial fluorescence emitted by the oil based fazepro drilling fluid; no free oil in sample OA SUBLOBE 4 135190.0' MD/-3792.5' TVDSS OA BOTTOM 13636.0' MD/-3797.7' TVDSS Siltstone/Sandstone(13500-13650)=siltstone grading to sandstone medium light gray to medium gray; abundant translucent and transparent quartz grain mushy consistency; pulverulent tenacity due to bit action and drilling environment; irregular occasionally planar fracture depending upon degree of hydration; platy to scaly cuttings habit; dull earthy luster; silty gritty texture; very arenaceous and highly argillaceous; imbedded quartz and lithic fragments; some very fine thin black carbonaceous laminae are present; mica and pyrite are visible as well; grading more towards siltstone throughout the sample interval; abundant loose quartz and lithic sand is present; no detectable odor; decreased amount of porosity throughout interval with fair visible porosity; very trace amounts of oil stained quartz; no detectable fluorescence due to the oil based fazepro drilling fluid OA BOTTOM 13745.0' MD/-3798.0'TVDSS Siltstone/Sandstone(13650-13850)=siltstone grading to sandstone in places medium light gray to medium gray, medium dark gray in places, stiff, firm to moderately firm consistency, stiff to sectile tenacity, planar to open irregular fracture depending upon the amount of hydration, scaly to flaky occasionally nodular and blocky cuttings habit, dull earthy luster, very silty gritty granular texture, very arenaceous, imbedded sand and glauconitic sand, some very fine thin black carbonaceous laminae, imbedded large quartz nodules and angular quartz; several varieties of siltstone are present throughout this interval the light gray, as well as grayish orange to pale yellowish brown variety; large quantities of large transparent to translucent quartz, trace amounts of pyrite; large quantities of coal fragments and carbonaceous material; several varieties of sandstone increasing amounts of sand throughout the interval with the siltstone becoming less apparent; no detectable petroleum odor; moderate visible porosity; very trace amounts of oil stained quartz; any natural fluorescence is masked by the artificial fluorescence of the drilling fluid; large quantities of calcium carbonate drilling additive in samples. OA SUBLOBE 4 13926' MD/-3788.6'TVDSS Sand (13850-14120)=samples consist of a grayish brown to olive gray slurry of loose sand with scattered siltstone cuttings; the sand is well sorted,with much of it in a tight range from upper very fine-to lower fine-grained; the remainder is mostly lower very fine-grained with a small amount of scattered coarser grains up to rare upper medium-grained sand; the sand is primarily composed of quartz with subordinate lithics; the quartz is a translucent very light gray to transparent and colorless; the bulk of the lithics are very dark gray to black and siliceous; minor blue green glauconite and trace opaque reddish orange grains round out the remainder of the lithics; trace amounts of pale orange to pinkish orange shell fragments are also scattered throughout the samples; calcium carbonate additive is also prevalent in sample and is similar to the quartz sand in both size and appearance; the sand grains are subrounded to subangular with moderate sphericity on average, and quartz grain surfaces are etched and pitted;the crushed marble is distinguishable only by its form as calcite cleavage fragments, with good planar faces; the siltstone is olive gray with a brown tint resulting from oil-based mud; siltstone cuttings are vaguely wedgelike to tabular with rounded edges; fresh surfaces have a dull, earthy luster underlain by a silty texture; microscopic black, carbonaceous laminae are visible within the siltstone cuttings; samples effervesce violently in acid due to the heavy calcite contamination, but rare intact sandstone cuttings are weakly cemented by calcite; on the shakers, a small amount of free oil is liberated from the oil-based mud, but oil stain is not apparent in the samples; any potential petroliferous odor is masked by the scent of oil-based mud; an even, dull white 29 CANRIG E Nikaitchuq OP14-S3 fluorescence is due in part to oil-based mud residue and widespread calcite, accentuated by barely perceptible, dispersed patches of moderate white and faint yellow fluorescence; an immediate cut fluoresces milky white. Sand (14120-14350)= samples consist of a grayish brown slurry of loose sand and scattered siltstone cuttings;the sand is a well sorted quartz sand,with grain sizes mostly within the range of upper very fine- to lower fine-grained; a minor fraction of the sand is lower very fine-grained, while trace amounts of coarser grains are scattered about the samples, up to and including upper medium-grained sand; grains are mostly comprised of translucent very light gray quartz, along with subordinate dark lithics; the lithics are mostly black and siliceous, imparting a salt and pepper appearance to the sand under the microscope; trace blue green glauconite and rare opaque reddish orange grains round out the lithic content, and pale orange shell fragments are scattered throughout the samples as well; sand grains are mostly subrounded to subangular,with moderate sphericity on average; quartz grain surfaces are etched and pitted; cleavage fragments of calcium carbonate mud additive is ubiquitous in the sample and is difficult to differentiate from the quartz sand as they are similar in size and appearance, except for the good planar cleavage faces on the calcite; the abundant calcite contamination obscures determination of the calcite content of the samples, although just above the midway point of this interval, scattered cuttings of intact sandstone are weakly cemented by calcite; no oil staining is apparent, and only the scent of oil-based mud is detectable; samples display a weak, even white fluorescence, due in part to both oil-based mud residue and the abundant calcite; an opaque white cut fluorescence is emitted. Sand (14350-14530)= samples consist of a grayish brown slurry of loose sand with abundant admixed calcium carbonate additive and sporadic small amounts of siltstone cuttings; the sand is very well sorted with the bulk of the sand being upper very fine-grained, along with lesser lower very fine sand and trace lower fine sand; sand grains are primarily composed of translucent very light gray quartz with minor dark lithics which give the sand a salt and pepper appearance under the microscope; black siliceous grains comprise the majority of the lithics,with trace amounts of blue green glauconite; trace to minor amounts of pale orange shell fragments are also scattered throughout the samples; calcium carbonate additive is ubiquitous in the sample, mixed in with the sand, and aside from planar cleavage faces, the calcite is difficult to discern as its size and color are similar to the quartz sand; sand grains are subangular to subrounded with moderate sphericity on average, and quartz grain surfaces are etched and pitted; oil staining is not apparent, and the scent of oil-based mud masks any potential petroliferous odor; an even, dull white fluorescence is emitted across the samples, likely due in part to residual oil-based mud and the heavy amount of added calcite; an immediate cut emits an opaque white fluorescence. OA SUBLOBE 3 14578.0' MD/-3755.5' TVDSS OA SUBLOBE 2 14664.0' MD/-3753.2'TVDSS Sand (14530-14770)=samples consist of a light grayish brown slurry of loose sand with scattered small siltstone cuttings; when dry, samples are light olive gray and pulverulent; the sand is a very well sorted lithic-quartz sand with grain sizes constrained to upper very fine sand with lesser amounts of lower very fine sand and sparse grains of upper fine sand; grains primarily consist of translucent very light gray quartz with minor dark lithics, a combination that gives the sand a salt and pepper appearance under magnification; minor to trace amounts of pale orange to pinkish orange shell fragments are scattered throughout the sand;with the exception of the latter, grains are subrounded to subangular with moderate sphericity, and quartz grain surfaces are etched and pitted; samples are heavily contaminated with cleavage fragments of calcium carbonate additive which is difficult to distinguish from the quartz sand as it is similar in size and appearance, differentiated only by the planar, unetched cleavage surfaces; the siltstone is light grayish brown to olive gray and crumbly; fresh surfaces have a dull, earthy luster underlain by a smooth, silty texture; the cuttings are vaguely wedgelike to tabular with rounded edges, and most are crumbly; in the upper portion of this interval, a few hard siltstone cuttings and a trace amount of intact sandstone cuttings are cemented by calcite; otherwise, the mud additive obscures the true amount of calcite in the formation; the scent of oil-based mud masks any petroliferous odor, though a slight amount of free oil is visible in the shakers; no stain is apparent in the samples, but the samples emit an even, dull 30 CANRI] 6d Nikaitchuq OP14-S3 white fluorescence, due in part to residual oil-based mud and the abundant calcite additive; an immediate cut fluoresces a moderate, opaque white. Sand (14770-15010)=samples consist of a grayish brown slurry of loose sand containing scattered siltstone cuttings; the sand is very well sorted,with the grain size of the bulk of the sand at or near the boundary between upper very fine-and lower fine-grained; a minor amount of lower very fine sand is also within the samples, and rare coarser grains up to upper medium-grained sand can be found within the samples also; sand grains largely consist of translucent, very light gray quartz with minor dark lithics that impart a salt and pepper appearance to the sand upon examination under the microscope; the lithics mostly consist of black siliceous grains with trace amounts of blue green glauconite and rare reddish orange lithics; grains are subrounded to subangular with moderate sphericity overall, and quartz grain surfaces are etched and pitted; rare pale orange shell fragments are scattered throughout the sand as well; abundant cleavage fragments of calcium carbonate additive is ubiquitous in the sample, and it is very similar in size and appearance to the quartz sand with the exception of the planar cleavage faces; the siltstone cuttings are crumbly and wedgelike or tabular with rounded edges; fresh surfaces are light olive gray to light grayish brown, with a dull, earthy luster underlain by a smooth, silty texture; microscopic black, carbonaceous laminae are visible in the siltstone; although the calcium carbonate additive obscures the calcite content of the formation, individual siltstone cuttings effervesce in acid; trickles of free oil are visible on the shakers, though oil staining is not apparent in the samples; any potential oily odor is overwhelmed by the scent of oil-based mud;the samples emit an even, dull white fluorescence, and an immediate cut fluoresces white and opaque. Sandstone/Sand (15010-15150)= samples consist primarily of light gray to medium light gray with smoky gray hues; abundant translucent and transparents; occasional grayish blue green glauconitic grains primarily quartz composition, 90%quartz and 10% lithic; upper very fine to lower fine grained; very well to well sorted; round to well rounded; high sphericity; friable; moderately cemented with silica cementation; some grain support is present in sandstone matrix; sandstone cementation is disguised from drilling environment; some cemented portions remained intact; some fragmented carbonaceous matter is present; trace amounts of shell fragments; medium gray to medium dark gray siltstone is present becoming more apparent throughout the interval moderate visual porosity; no detectable petroleum odor beyond the smell emitted from the drilling fluid; little to no visible staining; occasional stain exist on quartz with less than 1% of sample volume exhibiting stain ; sample fluorescence is completely masked by the artificial fluorescence from the oil based fazepro drilling fluid Sandstone/Sand (15200-15350)= primarily transparents and translucents with very light gray smoky hue; some white and whitish gray quartz grains some grayish green and pale green glauconitic grains; occasional moderate pale blue green; dark scattered assorted lithic grains; primarily quartz composition with 90% quartz and 10% lithic; upper very fine to lower fine grained with some course rounded quartz as well as some very angular course grains present;well to very well sorted; round to well rounded; high sphericity; sample appears to be loose and unconsolidated however some cemented fragments of the sandstone matrix remain intact; the cemented portions are soft to easily friable some are firmly friable in places; silica cementation with possible argillaceous cementation and consolidation in places; some grain support;trace amounts of light gray to medium light gray siltstone; large amounts of calcium carbonate drilling additive; abundant shell fragments; excellent visual porosity; some detectable odor however it is most likely masked by the oil based drilling fluid; very minute trace amounts of oil stained quartz; some pinpoint fluorescence is visible beyond the background of the heavily fluorescent fazepro drilling fluid. Sand/Sandstone(15350-15550)= primarily transparents and translucents with light smoky gray hue; occasional pale yellowish orange hue; occasional very pale orange and pale yellowish brown hue; some grayish blue green and moderate blue green as well as dusky blue green glauconitic grains abundant scattered dark grey occasionally medium light and light gray lithics; primarily quartz composition 85% quartz and 15% lithics well sorted; upper very fine to fine grained with the occasional course and medium grains;well sorted; round to sub round with some very angular quartz and lithic grains; high sphericity; sample appears to be loose and unconsolidated due to bit action and drilling environment however some cemented consolidated pieces remain intact; moderately cemented with silica and possible occasional argillaceous cement friable to firmly friable; some grain support is present in samples; trace amounts of very light gray to light gray siltstone; shell fragments; trace amounts of pyrite; large quantities of calcium carbonate drilling additive; good to excellent visible porosity; little to no oil stain is visible with trace 31 CANRIG 611 Nikaitchuq OP14-S3 amounts on less than 1% of the quartz grains; slight petroleum odor it is however disguised by the oil based drilling fluid; sample fluorescence is dull white however most all fluorescence is most likely masked and overpowered by the fazepro drilling fluid OA SUBLOBE 2 15603.0' MD/-3750.2'TVDSS Sandstone/Sand (15550-15750)=an olive gray slurry of loose sand with negligible amounts of scattered siltstone cuttings; the sand is a well sorted lithic-quartz sand, with most of the grains falling between upper very fine-and lower fine-grained; minor amounts of lower very fine-grained sand constitute much of the remainder, and coarser sand up to lower medium-grained are present in trace to minor amounts; translucent very light gray quartz constitutes the majority of the sand, and minor dark lithics make up the rest; calcium carbonate additive is abundant in the samples, and aside from planar cleavage faces, it is difficult to differentiate from the quartz sand as it occurs in the same size fraction; the lithics are mostly very dark gray to black,which give the samples a salt and pepper appearance under the microscope; trace blue green glauconitic lithics and pale orange to pinkish orange shell fragments are also present in the sand;while the calcite cleavage fragments have a blocky appearance, the sand grains display moderate sphericity on average and are subangular to angular; quartz grain surfaces are commonly etched and pitted; oil staining is not readily apparent; some odor is detectable however most is primarily masked due to the oil based drilling fluid; very trace amounts of oil stained quartz through out; no visible free oil in sample; bright white fluorescence is emitted however any natural fluorescence is most likely masked by the artificial presence of the drilling fluid OA SUBLOBE 3 15860.0' MD/-3758.5' TVDSS Sandstone/Sand (15750-15950)= primarily transparents and translucents light gray to medium light gray with smoky hues; some grayish green, grayish blue green, moderate blue green glauconitic grains are present; primarily quartz composition; 95%quartz and 5% lithics; some larger dark lithics present approx. 0.5-0.25 mm throughout; upper fine grained to lower fine grained occasional medium and coarse grained quartz very well to well sorted; round to sub round with high to moderate sphericity; friable to firmly friable with moderate cementation; cementation is disguised due to drilling environment some cemented sandstone fragments remain intact; silica cementation with some grain support; small coal fragment and other carbonaceous material; traces of medium light gray very arenaceous siltstone are present comprising less than 2% of sample volume moderate orange pink to very pale orange occasionally pale yellowish orange shell fragments; very trace amounts of pyrite; good to excellent visible porosity; slight petroleum odor is detectable over the heavy background of the oil based drilling fluid; very minute trace amounts of oil stained quartz; natural fluorescence is difficult to ascertain due to drilling fluid the entire sample emits a dull white fluorescence Sandstone/Sand (15950-16150)=samples consist primarily of transparents and translucents with smoky gray hues; occasional pale green and moderate blue green; grayish blue green to light green glauconitic grains are scattered throughout; upper fine grained to lower fine grained occasional medium and coarse grained quartz very well to well sorted; round to sub round with high to moderate sphericity; friable to firmly friable with moderate cementation; silica cementation with possible argillaceous cement in places; slight reaction to hcl from cemented portion difficult to ascertain if cement is calcareous or the surrounding grains; primarily quartz composition with 90%quartz and 10% lithics; trace amounts of light gray to medium light gray occasionally medium dark gray siltstone; moderated orange pink to pale yellowish orange to very pale orange shell fragments increasing in regularity throughout the interval; abundant scattered dark lithics and fractured carbonaceous material;trace amounts of pyrite; large quantities of calcium carbonate drilling additive; very slight petroleum odor distinguishable over oil based drilling fluid; very slight traces of oil stained quartz; entire sample emits a dull white fluorescence; no visible free oil Sandstone/Sand (16150-16270)=transparents and translucents with smoky gray hues; occasional pale green and moderate blue green; grayish blue green to light green glauconitic grains are scattered 32 CANRJG _611 Nikaitchuq OP14-S3 throughout; upper fine grained to lower fine grained occasional medium and coarse grained quartz very well to well sorted; round to sub round with high to moderate sphericity; friable to firmly friable with moderate cementation; silica cementation with possible argillaceous cement in places; possible calcareous cement; some very angular course quartz is present some very pale orange to pale yellowish orange volcanic tuff is present; moderate orange pink to pale yellowish orange occasionally grayish orange pink and white shell fragments; some are highly calcareous and others have no reaction to hcl; very minute trace amounts of oil stained quartz; slight petroleum odor is detectable; entire sample emits a dull white fluorescence OA SUBLOBE 4 16398.0' MD/-3756.5'TVDSS Sand (16270-16500)=samples consist of an olive brown slurry of loose sand with negligible to trace amounts of siltstone cuttings; the sand is very well sorted, consisting mostly of upper fine-grained sand with a minor amount of finer sand and scattered, rare fine-grained sand; samples are also heavily contaminated with calcium carbonate additive of a similar size; the sand is primarily composed of translucent, very light gray quartz with a few transparent, colorless grains; minor amounts of dark lithics impart a salt and pepper appearance to the sand under magnification; the lithics are comprised of very dark gray to black, siliceous grains with lesser amounts of blue green glauconite and rare reddish orange lithics; the black lithics are occasionally pyritic; sand grains are subrounded to subangular with moderate sphericity on average; the calcite mud additive is distinguishable due to good planar cleavage faces on the calcium carbonate; very rare pinkish orange shell fragments are also found within the samples; siltstone cuttings are olive gray, sandy, rounded, and crumbly; microscopic black, carbonaceous laminae are visible in the siltstone; very rare intact sandstone cuttings are weakly cemented by calcite; though calcite content is otherwise obscured by the ubiquitous mud additive; free oil is visible on the shakers, but the scent of oil- based mud overpowers any potential petroliferous odor; oil staining is not apparent in the samples, though an even, dull white fluorescence is given off, likely due in part to residual oil-based mud and the abundant dispersed calcite; a brown cut fluoresces a translucent milky white. OA SUBLOBE 4 16630.0' MD/-3744.7' TVDSS Sand (16500-16710)=samples consist of a grayish brown slurry of loose sand with minor siltstone cuttings; the samples are light olive gray and pulverulent when dry; the sand is very well sorted and consists almost entirely of upper very fine-grained sand with a small amount of finer sand, trace fine sand, and very rare medium sand grains;the sand is primarily comprised of translucent very light gray quartz with minor black siliceous lithics and trace blue green glauconitic lithics; the composition gives the samples a salt and pepper appearance under the microscope; samples are also heavily contaminated with cleavage fragments of calcium carbonate additive which are similar in size and appearance to the quartz sand, though blocky, planar cleavage faces aid in differentiating the calcite; on the contrary, sand grains are subrounded to subangular with moderate sphericity, and quartz grain surfaces are often etched and pitted; siltstone cuttings are tiny, brownish gray, crumbly and rounded; although samples effervesce violently in acid due to the abundant contamination by mud additives, very rare firm to hard siltstone and intact sandstone cuttings are cemented by calcite;trickles of free oil are visible on the shakers, but potential oily odor is overwhelmed by the scent of oil-based mud; light brown dispersed oil staining is visible in the samples, and an even, dull white background fluorescence resulting from residual oil-based mud and widespread calcite is accentuated by diffuse patches of brighter white to faintly yellow fluorescence; an immediate cut fluoresces a translucent white. Sand (16710-16950)= samples consist of a grayish brown slurry of loose sand and scattered tiny (up to 1 millimeter)siltstone and sandstone cuttings which increase slightly near the base of this interval; the sand is a very well sorted lithic-quartz sand with grain sizes tightly clustered near the boundary of upper very fine-and lower fine-grained, with minor finer sand and scattered rare coarser grains; the bulk of the sand is composed of translucent to transparent very light gray quartz with subordinate dark lithics, a 33 CANRIG End Nikaitchuq OP14-S3 combination that gives the sand a salt and pepper appearance under magnification;the lithics primarily consist of very dark gray to black siliceous grains, with lesser blue green glauconite; quartz grains are subrounded to subangular while the lithics are subrounded to rounded, and sphericity is moderate on average; the surfaces of quartz grains are pitted; sparse pale orange shell fragments are also scattered throughout the samples; cleavage fragments of calcium carbonate additive are ubiquitous in the samples, and aside from the planar cleavage faces, the calcite is difficult to discern from the quartz grains; calcite content of the formation is obscured by the mud additive, although the slightly increased amount of sandstone cuttings beneath the middle of this interval are weakly cemented by calcite; a unique speck of pyrite cemented sandstone was also discovered in the samples; trickles of free oil are visible on the shakers; a slight petroliferous odor is perceptible amid the overwhelming scent of oil-based mud, and diluted oil staining is visibly dispersed across the samples; an even, moderate white fluorescence is emitted across the samples, and an immediate brown cut fluoresces a translucent white. Sand (16950-17150)=samples consist of a light grayish brown to olive gray slurry of loose sand with scattered siltstone cuttings; samples are light gray to olive gray and pulverulent when dry; the sand is well sorted and mostly very fine-grained, with a small amount of lower fine-grained sand; the majority of the grains consist of translucent very light gray quartz with subordinate dark lithics that give the sand a salt and pepper appearance when viewed under the microscope; the lithics are mostly composed of black siliceous grains, along with trace blue green glauconite; sand grains are subrounded to subangular with moderate sphericity on average; rare blocky, pale orange to pinkish orange shell fragments are also present; abundant cleavage fragments of calcium carbonate additive contaminate the samples and complicate sand estimation as the calcite is similar to the quartz grains in size and appearance except for the planar cleavage faces; siltstone cuttings are grayish brown,wedgelike and very soft and crumbly; overall, samples effervesce violently in acid due to the abundant calcite contamination, though sandstone cuttings at the base of this interval are weakly cemented by calcite; trickles of free oil coming over the shakers diminish with depth, and only the slightest of oily odors is perceptible beyond the oil-based mud scent; an even moderate to dull white fluorescence is given off across the samples, due in part to residual oil-based mud and the ubiquitous calcite; a brown cut fluoresces a translucent white. Sand (17150-17330)= samples consist of a grayish brown slurry of loose sand with scattered siltstone and sandstone cuttings; the sand is very well sorted,with grain sizes mostly ranging from lower very fine- grained to upper very fine-grained; grains primarily consist of very light gray quartz with minor dark lithics, a combination that gives the sand a salt and pepper appearance when viewed under magnification; the lithics primarily consist of very dark gray to black siliceous lithics, along with trace blue green glauconite; sand grains are subrounded to subangular with moderate sphericity on average; samples are heavily contaminated with calcium carbonate additive, which is difficult to discriminate from the quartz sand as the calcite cleavage fragments are similar in size and appearance, with the exception of the flat cleavage faces; samples are very effervescent in acid due to the mud additive, but intact sandstone cuttings display good effervescence as well and are weakly cemented by calcite; trickles of oil are visible on the shakers, though petroliferous odor is largely masked by oil-based mud scent; samples emit a moderate, even white fluorescence corresponding with faintly visible dispersed oil staining; a brown cut fluoresces milky white. OA SUBLOBE 3 17345.0' MD/-3707.8' TVDSS OA SUBLOBE 2 17490.0' MD/-3697.8'TVDSS Sandstone/Sand (17350-17500)= samples consist primarily of transparents and translucents with smoky gray hues; occasional pale green and moderate blue green; grayish blue green to light green glauconitic grains are scattered throughout; upper fine grained to lower fine grained occasional medium and coarse grained quartz very well to well sorted; round to sub round with high to moderate sphericity; friable to firmly friable with moderate cementation; silica cementation with possible argillaceous cement in places; some grain supported in areas; small amounts of medium to medium light fray siltstone and residual silt particles; very pale orange to pinkish white to white volcanic tuff; primarily nodular and occasionally blocky in habit; becoming less apparent and non existent through the described interval; small amounts of moderate orange pink to pale yellowish orange shell fragments becoming less apparent throughout 34 CAMIG I EN Nikaitchuq OP14-S3 interval; large quantities of fractured coal and other carbonaceous matter; good visible porosity; slight to moderate petroleum odor is perceptible beyond the oil based drilling fluid; very trace minute amounts of oil stained quartz; the entire sample emits a white green fluorescence; individual sandstone fragments release an immediate bright whitish green cut. Sandstone/Sand (17500-17700)= primarily transparents and translucents with very light gray smoky hue; some white and whitish gray quartz grains some grayish green and pale green glauconitic grains; occasional moderate pale blue green; dark scattered assorted lithic grains; primarily quartz composition with 90%quartz and 10% lithic; upper very fine to lower fine grained with some coarse rounded quartz as well as some very angular course grains present; well to very well sorted; round to well rounded; high sphericity; sample appears to be loose and unconsolidated however some cemented fragments of the sandstone matrix remain intact; the cemented portions are soft to easily friable some are firmly friable in places; silica cementation with possible argillaceous cementation and consolidation in places; some grain support; trace amounts of light gray to medium light gray siltstone; large amounts of calcium carbonate drilling additive; trace amounts of aggregated and occasionally crystalline pyrite; trace orange pink to pale yellowish orange sometimes very pale orange shell fragments; abundant amounts of fractured coal and carbonaceous material; residual silt particles; good visible porosity; slight petroleum odor; entire sample emits a dull white to whitish green fluorescence Sandstone/Sand (17700-17900)=olive brown slurry of loose sand with negligible to trace amounts of siltstone cuttings;the sand is very well sorted, consisting mostly of upper fine-grained sand with a minor amount of finer sand and scattered, rare fine-grained sand; samples are also heavily contaminated with calcium carbonate mud additive of similar size; the sand is primarily composed of translucent, very light gray quartz with a few transparent, colorless grains; minor amounts of dark lithics impart a salt and pepper appearance to the sand under magnification; the lithics are comprised of very dark gray to black, siliceous grains with lesser amounts of blue green glauconite and rare reddish orange lithics; the black lithics are occasionally pyritic; sand grains are subrounded to subangular with moderate sphericity on average; the calcite mud additive is distinguishable due to good planar cleavage faces on the marble fragments;very rare pinkish orange shell fragments are also found within the samples; siltstone cuttings are olive gray, sandy, rounded, and crumbly; the intact cemented sandstone is primarily cemented with silica and some possible argillaceous cementing good visible porosity throughout the sample interval; oil staining is almost non-existent with a few minor grains of quartz with a light to medium brown stain;very slight petroleum odor is detectable; the entire sample emits a dark white to whitish green fluorescence again is highly masked due to the oil based drilling fluid; intact cemented sandstone fragments release an immediate bright white milky cut Sandstone/Sand (17900-18150)= primarily transparents and translucents with very light gray smoky hue; some white and whitish gray quartz grains some grayish green and pale green glauconitic grains; occasional moderate pale blue green; dark scattered assorted lithic grains; primarily quartz composition with 95% quartz and 5% lithic; upper very fine to lower fine grained with very little variation in grains size shape very well sorted; round to well rounded with high sphericity: dark lithics and quartz give the sample a salt and pepper appearance; sample appears to be loose and unconsolidated however very trace amounts of the sandstone matrix are occasionally visible; these are moderately cemented with siliceous cement; and possibly in some areas a argillaceous type cement; they are easily friable; destruction of sandstone matrix is most likely due to bit action and the abrasive environment of the well bore itself; abundant calcium carbonate drilling additive is present throughout; abundant microscopic fragments of carbonaceous matter scattered throughout;trace amounts of metallic gemlike moderate brown flaky mica; sample has excellent visual porosity; a moderate petroleum odor is detectable over the heavy background of the oil based drilling fluid; trace amounts of light brown rounded quartz nodules are scattered throughout comprising less than 1%of sample volume; the entire sample emits a white to whitish green fluorescence Sandstone/Sand (18150-18300)= samples consist primarily of transparents and translucents with smoky gray hues; occasional pale green and moderate blue green; grayish blue green to light green glauconitic grains are scattered throughout; primarily quartz composition with 85%quartz and 15% lithics upper fine grained to lower fine grained quartz very well to well sorted; round to sub round with high to moderate sphericity; rare intact cemented fragments are friable and moderately cemented with siliceous cement; some grain supported in areas the darker lithics and abundant very small fractured carbonaceous material 35 CANRIG 611 Nikaitchuq OP14-S3 and small coal fragments give a salt and pepper appearance; some residual light gray to medium light gray very fine silt is visible: trace amounts of metallic gemlike flaky moderate brown mica; trace amounts of aggregated and disseminated pyrite; good porosity very trace amounts of light brown oil stained rounded quartz these grains as a whole are typically larger than the surrounding quartz grains; moderate petroleum odor is perceptible beyond the heavy background of the oil based drilling fluid; the entire sample emits a whitish green fluorescence Sandstone/Sand (18300-18480)=samples consist primarily of transparents and translucents with smoky gray hues; occasional pale green and moderate blue green; grayish blue green to light green glauconitic grains are scattered throughout; upper fine grained to lower fine grained occasional medium and coarse grained quartz very well to well sorted; round to sub round with high to moderate sphericity; friable to firmly friable with moderate cementation; silica cementation with possible argillaceous cement in places; some grain supported in areas; fair amounts of medium light gray residual very fine silt; moderate orange pink to pale yellowish orange shell fragments becoming more apparent through the sample interval; some are highly calcareous and others have no reaction to hcl; good quantities of fractured coal and other carbonaceous material; that give the sample a salt and pepper appearance; good visible porosity; moderate petroleum odor; trace amounts of oil stained quartz with the total volume less than 1%of sample volume; the entire sample emits a white to whitish green fluorescence OA SUBLOBE 2 18,589.0' MD/-3666.1' TVDSS OP14-S3 LATERAL FAULT 3 18663.0' MD/-3667.5'TVDSS Sand (18480-18680)=samples consist of a grayish brown slurry of loose sand and calcium carbonate additive with negligible siltstone cuttings; samples are light gray and pulverulent when dry; the sand is a very well sorted, very fine-grained quartz sand with minor dark lithics that impart a salt and pepper appearance to the sand when viewed under the microscope; the quartz is translucent and very light gray to rarely colorless and transparent; lithic grains primarily consist of very dark gray to black lithics along with lesser amounts of blue green glauconitic lithics; quartz grains are subrounded to subangular with moderate sphericity, while the lithics are subrounded to well rounded with good sphericity; the marble additive is difficult to differentiate from the quartz sand as it is similar in size and appearance, except for good calcite cleavage faces; by contrast, quartz grain surfaces are etched and pitted; the contamination with added calcite obscures the true calcite content of the formation, though the scattered siltstone and intact sandstone cuttings are weakly cemented by calcite; very rare re crystallized pyrite can also be found in the samples; a slight oily odor is largely masked by the overwhelming scent of oil-based mud; trickles of free oil coalesce at the ends of the shakers, but oil staining in the samples is very diffuse and barely perceptible; samples fluoresce an even, dull white to faint yellow, and a pale brown cut fluoresces a translucent white. Sand (18680-18840)=samples consist of a grayish brown slurry of loose sand and calcium carbonate mud additive with scattered microscopic siltstone and sandstone cuttings;the sand is very well sorted and very fine-grained, with only rare fine sand grains; the sand primarily consists of translucent very light gray quartz, with subordinate dark lithics that give the sand a salt and pepper appearance under the microscope; lithic grains are mostly very dark gray to black and siliceous, along with minor blue green glauconite; sand grains are subrounded to subangular with moderate to poor sphericity; quartz grain surfaces are etched and pitted; the calcium carbonate occurs as very fine to fine calcite cleavage fragments, and aside from planar faces, the additive is otherwise difficult to discern from the quartz sand; the calcite contamination also obscures the amount of calcite in the formation, though intact sandstone cuttings effervesce lightly in acid; no free oil is visible on the shakers, and no odor nor stain are detectable; samples fluoresce an even dull white, and a pale straw to brown cut weakly fluoresces white and transparent. Sand (18840-19030)= samples consist of an olive brown slurry of loose sand with minor siltstone and intact sandstone cuttings; when dry, samples are light grayish brown to light brown and pulverulent; the sand is a well sorted, very fine-grained lithic-quartz sand; the majority of the sand is lower very fine- grained,with subordinate upper very fine sand and only sporadic grains of lower fine-grained sand; very 36 CANRIG Iii 611 Nikaitchuq OP14-S3 light gray, translucent quartz comprises the bulk of the grains, along with minor black siliceous lithics and trace blue green glauconite; grains are subrounded to subangular, with moderate to good sphericity; the quartz grain surfaces are lightly etched and pitted; samples are heavily contaminated with cleavage fragments of calcium carbonate mud additive; as the grain size and appearance are similar,the calcite additive is nearly indistinguishable from the quartz grains except for the flat cleavage faces; though the true calcite content of the formation is obscured by the introduced material, thin, silty, pale brown slivers and flakes of re crystallized calcite are scattered throughout the lower portion of this interval; no free oil is evident on the shakers, and no oil stain nor odor are detectable; samples emit an even, dull white fluorescence, and a pale straw to brown cut fluoresces a translucent white. Sand (19030-19200)=samples consist of an olive brown to grayish brown slurry of loose sand and crushed marble mud additive with negligible siltstone or sandstone cuttings; when dry, samples are light brownish gray to light gray and pulverulent; the sand is very well sorted, with grain sizes entirely within the range of upper to lower very fine-grained; the majority of the grains are composed of very light gray quartz, with subordinate dark lithics that give the sand a salt and pepper appearance when viewed under the microscope; siliceous very dark gray grains comprise the bulk of the lithics, as well as trace amounts of blue green glauconite; the calcite additive occurs as cleavage fragments that are very similar to the quartz in both size and appearance; sand grains are subrounded to subangular with moderate to good sphericity; quartz grain surfaces are slightly etched and pitted, while the calcite fragments are distinguished only by planar cleavage faces that lack pockmarks; sparse free oil is present on the shakers, and staining is not apparent in the samples; oil-based mud scent largely overwhelms a faint petroliferous odor; samples display a dull, even white fluorescence, due in part to oil-based mud residue and to the ubiquitous calcite; a pale straw cut fluoresces white and transparent. Sandstone/Sand (19200-19400)= primarily transparents and translucents with very light gray smoky hue; some white and whitish gray quartz grains some grayish green and pale green glauconitic grains; occasional moderate pale blue green; dark scattered assorted lithic grains; primarily quartz composition with 95% quartz and 5% lithic; upper very fine to lower fine grained with very little variation in grains size shape very well sorted; round to well rounded with high sphericity: dark lithics and quartz give the sample a salt and pepper appearance; sample appears to be loose and unconsolidated however very trace amounts of the sandstone matrix are occasionally visible;these are moderately cemented with siliceous cement; and possibly in some areas a argillaceous type cement; they are easily friable; destruction of sandstone matrix is most likely due to bit action and the abrasive environment of the well bore itself; abundant calcium carbonate drilling additive is present throughout; abundant microscopic fragments of carbonaceous matter scattered throughout; small amounts of light gray to moderate light gray siltstone; no evidence of the low rop concreted zone is visible evident in the sample; good visual porosity; trace amounts of light brown stained quartz grains;the sample has a moderate petroleum odor over the heavy background of the oil based drilling fluid; the entire sample emits a whitish green fluorescence Sand/Sandstone/Siltstone(19400-19450)=primarily transparents and translucents with very light gray smoky hue; some white and whitish gray quartz grains some grayish green and pale green glauconitic grains; occasional moderate pale blue green; dark scattered assorted lithic grains; primarily quartz composition with 80%quartz and 20% lithic; primarily upper fine grained to lower fine however abundant amounts of medium and coarse grains are readily apparent throughout the sample; moderate to occasionally poor sorting; most grains and round to sub round however there are numerous subangular, angular and very angular quartz grains; moderate sphericity; appears to be unconsolidated and loose however large portion of cemented sandstone remain intact; there are several different sandstone present through this interval one is very fine grained and is the typical sandstone observed throughout most of the production section the other is larger grained and arenaceous grading to siltstone; yet another sandstone present is composed completely of clear to translucent quartz, all are moderately cemented and contains siliceous cement; the translucent quartz sandstone shows signs of overgrowths in addition to the siliceous cement;there are several varieties of siltstone present as well on is light to moderate grey and moderately firm; it contains abundant carbonaceous black inclusions as well as thin black and brown laminae; the other is a very pale orange and contains abundant microscopic carbonaceous inclusions; large quantities of moderate orange pink to very pale orange shell fragments throughout; good quantities of pyrite and larger glauconite nodules; large quantities of calcium carbonate drilling additive; a very faint petroleum odor; trace amounts of oil stained quartz and sandstone with visible free oil in the sample; the entire 37 CANRIG EN Nikaitchuq OP14-S3 sample emits a whitish green fluorescence OA SUBLOBE 3 19,520' MD/-3634.1'TVDSS OA SUBLOBE 2 19,608' MD/-3627.6' TVDSS Sandstone/Sand (19450-19850)= primarily transparents and translucents with very light gray smoky hue; some white and whitish gray quartz grains some grayish green and pale green glauconitic grains; occasional moderate pale blue green; dark scattered assorted lithic grains; primarily quartz composition with 90% quartz and 10% lithic; upper very fine to lower fine grained with very little variation in the size and shape; very well sorted round to well round with high sphericity sample appears to be loose and generally unconsolidated however some cemented fragments of the sandstone matrix remain intact; the cemented portions are soft to easily friable some are firmly friable in places; silica cementation with possible argillaceous cementation and consolidation in places; some grain support; trace amounts of medium gray to medium dark gray siltstone with small black and brown laminae as well as small carbonaceous inclusions; very trace minute residual amounts of a very pale orange siltstone with carbonaceous inclusions; large amounts of calcium carbonate drilling additive trace amounts of shell fragments becoming less apparent; trace pyrite and mica; the sand and sandstone has excellent visual porosity; a moderate petroleum odor is detectable; minute amounts of light brown oil stained quartz grains; the entire sample emits a whitish green fluorescence Sandstone/Sand (19850-20050)=transparents and translucents with smoky gray hues; occasional pale green and moderate blue green; grayish blue green to light green glauconitic grains are scattered throughout; pale yellowish brown to grayish orange sometimes pale brown quartz in places very well to well sorted; upper fine grained to lower finer grained;well sorted; round to sub round with moderate to high sphericity; friable to firmly friable with moderate siliceous cement; primarily quartz composition with 85%quartz and 15% lithics;trace amounts of a translucent to transparent sandstone with 100%quartz is also present it is well cemented moderately hard and has some overgrowths; very pale orange to white to pale yellowish orange nodular volcanic tuff cuttings are also present; pyrite; residual silt;trace iron oxide; large quantities of drilling additive calcium carbonate; large amounts of fractured carbonaceous matter; calcareous and non calcareous shell fragments; good visible porosity moderate petroleum odor; trace amounts of light brown stained quartz increasing over this interval still comprising less than 1%of the sample volume; entire sample emits a dull whitish green fluorescence with some pinpoint bright yellow green areas OP14-S3 LATERAL FAULT 4 20,146.0' MD/-3614.7'TVDSS Sandstone/Sand (20050-20150)= samples consist primarily of transparents and translucents with smoky gray hues; occasional pale green and light green glauconitic grains are scattered throughout; upper fine grained to lower fine grained very well to well sorted; round to sub round with high to moderate sphericity; friable to firmly friable moderately well cemented with siliceous cement; small amounts of shell fragments ; abundant scattered carbonaceous matter give the sample a salt and pepper appearance; good visible porosity trace amounts of light brown stained quartz; mild to moderate petroleum odor; the entire sample emits a whitish green fluorescence Sand/Sandstone/Siltstone(20150-20280)=transparents and translucents with smoky white gray hue and grayish orange hue; primarily quartz with 85%quartz and 15% lithics; primarily very fine to lower fine grained some medium and coarse grains are present; moderately sorted; round to sub round; moderate sphericity; easily friable to friable; good amounts of medium gray to medium dark gray very arenaceous siltstone grading to sandstone in some places; good quantities of shell fragments; abundant dark yellowish orange silt; large quantities of calcium carbonate drilling additive; moderate to poor visible porosity; trace amounts of oil stained quartz; very faint petroleum odor; entire sample emits a whitish green fluorescence OA TOP 20,362.0' MD/-3623.0'TVDSS 38 CANRIG 6d_ Nikaitchuq OP14-S3 OA SUBLOBE 2 20,425' MD/-3628.3' TVDSS Sand (20280-20430)= samples consist of a medium brown to grayish brown slurry of loose sand with abundant cleavage fragments of calcium carbonate additive and minor siltstone cuttings which decrease with depth; when dry, samples are light olive gray and pulverulent; the sand is a very well sorted, very fine- grained quartz sand with lesser lithics; the bulk of the lithics consist of very dark gray to black siliceous grains, along with trace blue green glauconitic lithics; sand grains are subangular to subrounded with moderate sphericity on average; quartz grain surfaces are only very slightly pitted; the calcite additive is similar to the quartz sand in both size and appearance, except for good flat cleavage facets; no free oil is visible on the shakers, and only the scent of oil-based mud is detected; staining is not apparent in the samples, though a dull white to slightly yellow fluorescence is given off evenly across the samples, likely due in part to oil-based mud residue and to the widespread calcite; a brown cut fluoresces a translucent, milky white. OA SUBLOBE 3 20,484.5' MD/-3632.9' TVDSS Sand (20430-20590)= samples consist of a medium brown to olive gray slurry of loose sand and calcium carbonate mud additive,with scattered tiny siltstone cuttings; the sand is very well sorted,with very fine sand comprising nearly the entire sample,with traces of lowermost fine-grained sand; grains are primarily composed of quartz, along with trace to minor dark lithics which impart a salt and pepper appearance to the sand under magnification; grains are subangular to subrounded with moderate sphericity, and quartz grain surfaces are lightly etched and pitted;the added calcite is difficult to discern from the quartz grains as it is similar in size and appearance, except for distinctive planar cleavage faces; though the abundant mud additive obscures the calcite content of the formation, siltstone cuttings effervesce mildly in acid; very rare pyrite cement can also be found; no free oil is visible on the shakers, and oil staining and odor are not detectable; an even, dull white fluorescence is emitted across the samples, due in part to oil-based mud residue and to the abundant very fine calcite; a pale brown residue fluoresces a translucent white, also likely due in part to residual oil-based mud. Sand (20590-20830)= samples consist of a grayish brown slurry of loose sand and calcium carbonate additive with scattered tiny cuttings of siltstone and sandstone, which increase with depth and dominate the base of the interval; when dry, samples are light olive gray and pulverulent;the sand is a very well sorted, very fine-grained, lithic-quartz sand; very light gray to pale yellow quartz constitute the majority of the sand,while minor dark lithics comprise the remainder, giving the sand a salt and pepper appearance under the microscope; the lithics mostly consist of very dark gray siliceous grains with lesser blue green glauconite and very rare reddish orange lithics; trace pale orange shell fragments occur with the sandstone at the base of the interval; sand grains are subangular to subrounded with moderate sphericity on average, and quartz grain surfaces are lightly etched and pitted; the crushed marble occurs as cleavage fragments that are mostly very fine-grained and are difficult to distinguish from the quartz except for cleavage facets on most of the grains; samples effervesce strongly in acid due to the added calcite, though the intact sandstone and siltstone cuttings are weakly cemented by calcite; rare chips of silty re crystallized calcite and rare pyrite cement are also present in the samples;the siltstone is medium brown to grayish brown and crumbly; siltstone cuttings contain microscopic black, carbonaceous laminae; a very faint petroliferous odor is largely overwhelmed by the scent of oil-based mud; slight trickles of free oil coalesce at the ends of the shakers, although no staining is evident in the samples; a dull white to slightly yellow fluorescence is emitted evenly across the samples, and a pale brown cut fluoresces white and translucent. Sand (20830-20950)=samples consist of a grayish brown slurry of loose sand and calcium carbonate mud additive with variable amounts of siltstone cuttings and traces of intact sandstone; the sand is a very well sorted, very fine-grained lithic-quartz sand; grains are comprised of quartz with subordinate dark lithics, so that the sand has a salt and pepper appearance upon examination under the microscope; the quartz is translucent and very light gray, while the lithics are mostly very dark gray and siliceous, along with trace blue green glauconite and rare reddish orange lithics; grains are subrounded to subangular with 39 CANRIG Etl Nikaitchuq OP14-S3 moderate to good sphericity; rare flakes of re crystallized, silty calcite are also present in the samples; no free oil is on the shakers, and no stain nor odor are noticeable; samples fluoresce an even, dull white, and a pale brown cut fluoresces a translucent white. Siltstone/Sand/Sandstone(20950-21050)=medium light gray to medium gray; stiff consistency; moderately firm; sectile to stiff tenacity; planar to blocky fracture; planar to flaky occasionally blocky cuttings habit; silty gritty texture; very arenaceous grading to sandstone in some places; imbedded coal and carbonaceous material;very thin black carbonaceous laminae; large quantities of sandstone and loose disaggregated sand; pyrite; shell fragments; trace amounts of volcanic tuff; large quantities of calcium carbonate drilling additive; no petroleum odor; sands and sandstone emit a dull green fluorescence with the siltstone emitting no fluorescence; trace amounts of oil stained quartz Sand/Sandstone/Siltstone(20050-21150)=transparents and translucents with smoky gray hue and grayish orange hue; primarily quartz with 85% quartz and 15% lithics; primarily very fine to lower fine grained some medium and course grains are present; moderately sorted; round to sub round; moderate sphericity; easily friable to friable; good amounts of medium gray to medium dark gray very arenaceous siltstone grading to sandstone in some places; trace amounts of volcanic tuff; large amounts of calcium carbonate drilling additive; moderate to good visible porosity; very slight petroleum odor; very minute amounts of oil stained quartz; dull whitish green fluorescence Sandstone/Sand/Siltstone(21150-21340)=primarily translucents and transparents with very light gray smoky hue; some very pale orange with tan hue; some grayish green and pale green glauconitic grains; occasional moderate pale blue green; dark scattered assorted lithic grains; primarily quartz composition with 80%quartz and 20% lithic; upper very fine to lower fine grained with some medium grained lithics and quartz; well sorted round to well round with moderate sphericity trace amounts of medium gray to medium dark gray siltstone with small black and brown laminae as well as small carbonaceous inclusions; small amounts of a very pale orange siltstone with carbonaceous inclusions large amounts of calcium carbonate drilling additive; moderate orange pink to very pale orange shell fragments trace pyrite; good quantities of very pale orange; white to pinkish white pale yellowish orange volcanic tuff nodules; occasionally platy and flaky; moderate visible porosity; very small amounts of light brown oil stained quartz; a moderate petroleum odor is detectable; samples emit a blotchy white green dull fluorescence with some bright white yellow pinpoints becoming less apparent over the sample interval TD 8 3/4" BOREHOLE 21,340.0' MD/-3618.4'TV 40 CANR Wits Ei Nikaitchuq OP14-S3 Connection Gas Summary 1 Unit=0.05% Methane Equivalent Depth (ft) Background Units C-1 C-2 C-3 C-4 C-5 Gas Above MD TVDSS (Units) Background (ppm) (ppm) (ppm) (ppm) (ppm) Note: No connection gases noted. The well was drilled slightly over balanced. 3.4 Trip/Wiper Gas Summary Depth at Trip(ft) Trip To Depth (ft) Max Gas Pumps Off Comments MD TVD MD TVD (units) (hours) 2338 2174 0 0 10 62 Surface casing point 8574 3579 0 0 46 31 Repair/replace directional tool 10455 3848 0 0 93 Intermediate Casing/Backream Gas 41 C4NIARIP Ot Eni Nikaitchuq OP14-S3 3.5 Sampling Program and Sample Dispatch Sample Program Dry samples (2 sets): Every 50'from 2350'to TD (21340' MD). Iso-Jars: Every 500'from 2500'to Total Depth and 50' in zones of interest. Iso-Tubes: Every 500'from 2500'to Total Depth and 50' in zones of interest. Set Processed As Frequency* Interval* Dispatched to Reference Samples Fugro Data Solutions A Washed, dried, and 50' 2350'to 21340' 3311 South U.S. Highway 77 stored in plastic vials. Set Owner: ENI Schulenburg, Texas 78956 Reference Samples AOGCC B Washed, dried, and 50' 2350'to 21340' 333 W. 7th Avenue, Suite 100 stored in plastic vials. Anchorage,Alaska 99501 Set Owner: AOGCC • 2500'to 7500' & Headspace Samples 500' 10450'to 21000' Weatherford Laboratories C Unwashed and 50' in zone 8845 Fallbrook Drive stored in Is°Jars® of interest 7500'to 10450' Houston, Texas 77064 Set Owner: ENI (N Sand) 500' 2500'to 7500' & Mud Gas Samples 10450'to 21000' Weatherford Laboratories D Stored in IsoTubes® 50' in zone 8845 Fallbrook Drive Set Owner: ENI of interest 7500'to 10450' Houston, Texas 77064 (N Sand) Sample frequency and interval may be altered locally according to on-site geologist. 42 CANRIG Es Nikaitchuq OP14-S3 3.6 IsoTube®Chromatography/lsoJar®Geo Chemical Sampling SAMPLE INTERVAL TOTAL GAS C-1 C-2 C-3 iC-4 nC-4 iC-5 nC-5 MD TVD(ft) (ft) (units) (pPm) (ppm) (ppm) (Ppm) (ppm) (ppm) (Ppm) 2500 2303 5 870 3000 2663 4 616 3500 2919 12 2053 4000 3039 17 3005 4500 3112 4 756 5000 3183 3 633 5500 3254 5 1004 6000 337 1 88 6500 3412 7 1191 36 9 7000 3470 9 1083 18 60 17 14 9 7 7500 3537 76 10894 8000 3607 131 26576 237 95 51 28 45 8500 3673 263 42324 635 181 0 0 0 0 9000 3713 49 11047 155. 184 106 31 57 16 9500 3757 172 33233 581 576 78 91 74 42 10000 3805 33 7728 46 42 34 40 45 32 10500 3849 343 47344 330 39 32 37 26 20 11000 3867 126 16809 125 19 10 10 7 6 11500 3857 353 43136 179 96 0 0 0 0 12000 3838 580 76273 606 84 65 76 55 38 12500 3825 599 77415 583 124 82 97 61 47 13000 3824 457 65354 597 118 86 101 65 33 13500 3844 202 26112 213 52 33 32 11 0 14000 3837 241 30837 241 79 49 52 31 7 14500 3812 433 55056 450 156 101 123 81 67 15000 3804 275 37415 307 99 66 82 51 32 15500 3801 347 48076 534 145 83 99 44 7 16000 3812 55 8033 84 25 14 7 0 0 16500 3805 236 32575 316 90 68 80 56 33 17000 3773 291 42534 364 114 84 92 62 46 17500 3751 244 36454 292 116 71 85 58 43 18000 3731 481 70864 634 240 140 178 120 70 18500 3718 352 53492 495 214 147 194 137 85 19000 3717 339 56760 483 191 116 150 92 55 19500 3690 124 21451 232 77 46 52 31 20 20000 3672 153 26378 299 100 57 68 46 22 20500 3687 234 43132 401 151 101 119 74 45 21000 3671 273 60074 598 229 130 147 92 59 43 CANRIG Ed Nikaitchuq OP14-S3 4 PRESSURE AND FORMATION STRENGTH DATA 4.1 Pore Pressure Gradient Evaluation Primary Secondary Top Of Interval Pore Pressure Formation Lithology (ft) (EMW, ppg) Trend Indicators Lithology (%) (%) MD TVDSS Min Max Trend Permafrost n/a n/a 1858 -1717 9.1 9.1 Even BG, MW Ugnu Sd/Cgl 60% Clyst/SI°tst/Sh 2157 -1974 9.4 9.4 Even BG, MW 40/0 Schrader Bluff Sd/Sdst 80% Sltst/Clyst 20% 6437 -3352 9.4 9.4+ SI Incr BG, MW 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight(MW)and effective circulating density(ECD), including increases in background gas(BG),appearance and trends of connection gas(CG), lost circulation(LC),and magnitudes of trip gas(TG)and wiper gas(WG). Regional pore pressure trends from sonic data,provided by client,and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD—(0.6-((.001*TLGSU)+(0.05*DX))) The formula has certain limitations,such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However,the formula proved useful in helping establish a PPG range,when establishing trends, as with DXC data,with data points in shale intervals. 44 CANRIG Ei Nikaitchuq OP14-S3 5 DRILLING DATA 5.1 Daily Activity Summary 5/06/2011: P/U 10,046'of DP and stand back. Picked up BHA#1 and washed down to conductor bottom at 160' MD. Picking up BHA#2. 5/07/2011: Slide drilling 20' and rotating 10' from 306' to 1160'. Slide drilling to 1947'/1787' TVD. Drilling ahead. 5/08/2011: Slide drilling to TD @ 233812174'TVD.Circulate and condition hole 4x BU. Backream to 499'.UD BHA. Rig up to run 13.75"casing. 5/09/2011: Cont RIH casing.Landed casing at 2284'MD.M/U Landing joint and hanger,land casing @ 2324'. Circulate and reciprocate casing. Pump cement job. Nipple up BOP stack. 5/10/2011: P/U test tools and test BOP. P/U BHA and RIH to 1055'and run shallow tool test. Cont RIH to 2107'and wash down to 2227'and tag plug. Drill shoe track. 5/11/2011: Cont drilling shoe track. Displace spud mud with LSND. Perform FIT with 12.5 EMW.Cont drilling ahead. 5/12/2011: Cont. drilling ahead. 5/13/2011: Cont.drilling ahead,encountered hard zones @ 5072'-5326'and 5990'-6021'.Troubleshooting and trip for directional tools. 5/14/2011: Drill to 6067'and POOH due to MWD failure, LID BHA, repair bit breaker, P/U new BHA, RIH. 5/15/2011: Drill from 6070'to 7000' 5/16/2011: Continue to drill from 7,000'-8,050'. 5/17/2011: Drill to 8560' and tag hard spot, unable to orient rotary steerable as per well plan, BROOH to casing shoe. Circulate and POOH LID BHA and wait on town to determine BHA configuration. 5/18/2011: P/U BHA, service rig, RIH, drill ahead F/8,573'TO 9,000'. 5/19/2011: Drill F/9000' MD to section TD of 10,455'. 5/20/2011: BROOH to casing shoe,circulate and condition,slug DP and POOH to surface,LID BHA and C/O rams to 9 5/8"and test accordingly. 5/21/2011: Finish testing BOP's, R/U to run 9 5/8"casing. RIH with casing to 9,144' MD. 5/22/2011: RIH w/9 5/8"csg to 10,444, R/U cement head,fill csg and break circ,Pump 12.5 ppg cement, R/D cement equipment. 45 RIG 6d Nikaitchuq OP14-S3 Daily Activity Summary, con't. 5/23/2011: N/D BOP's break stack apart set emergency slips and cut 9 5/8"casing.N/U BOP's and C/O rams to 4.5". Service rig and begin pipe management RIH with all the DP in derrick. L/D bad hardband. POOH installing WEI subs. 5/24/2011: Continue installing WEI subs on 5"DP and rack back in derrick. P/U 4.5"DP and RIH M/U WEI subs. POOH racking back in derrick. Begin testing BOP's 5/25/2011: Test choke and 4.5" and 5" rams. P/U MWD tools and BHA. P/U 4.5" DP and RIH to 2065'. Shallow pulse test MWD. Continue to single in hole with 4.5"to 9,517' Cont RIH to 10,348' and tag cement. Circulate and pressure test casing. 5/25/2011: Pressure test casing, Slip and cut D/L, Calibrate MWD depth encoder and block height. Drill cmt and shoe track f/ 10,352-10,444'. Drill to 10,475' and CBU. FIT = 9.4 EMW. Drill ahead to 11,164' and CBU.BROOH to 10,278'and RIH. Continue to drill ahead to 11,335'. 5/26/2011: Pressure test casing, slip and cut D/L, calibrate MWD depth encoder and block height. Drill cmt and shoe track f/10,352-10,444'. Drill to 10,475'and CBU. FIT=9.4 EMW. Drill ahead to 11,164'and CBU. BROOH to 10,278'and RIH. Continue to drill ahead to 11,335. 5/27/2011: Drill from 11,335'to 13,670'. 5/28/2011: Drilled from 13,500'to 16,000'. 5/29/2011: Drilled from 16,000'to 18,000'. 5/30/2011: Drilled from 18,000'to 19,900'. 5/31/2011: Drill from 19,900 to TD of 21,340' 6/1/2011: CBU racking one stand in derrick every bottoms up to 20,182'.BROOH to 19,001'. 6/2/2011: BROOH from 19,001'-11,329'. 6/3/2011: Continue to BROOH, at casing shoe circ btms up 7x, pump slug and POOH. 6/4/2011: Continue to POOH, L/D BHA, RIH w/4,100' % DP to clear WEI subs. S/C D/L. POOH removing WEI subs and racking back in derrick. Prepare to run 5.5"liner.RIH w/Liner to 2,553'. 6/5/2011: RIH with 5.5" liner to 10,970' M/U liner setting sleeve. RIH with 5.5" slotted liner on 4.5" DP to current depth of 18,374'. 46 CANRIG P 611 Nikaitchuq OP14-S3 5.2 Survey Data Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) 0100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 167.94 0.15 292.11 167.94 0.06 0.08 -0.20 0.09 258.82 0.03 11.10 258.82 0.13 0.15 -0.31 0.16 361.36 0.19 237.01 361.36 0.05 0.09 -0.44 0.21 452.48 0.71 286.79 452.48 0.08 0.17 -1.11 0.67 543.76 2.69 304.84 543.71 1.26 1.56 -3.42 2.22 635.10 6.32 309.26 634.75 5.16 5.98 -9.08 3.99 729.04 9.16 310.39 727.83 12.41 14.10 -18.79 3.03 826.21 10.40 311.43 823.59 22.10 24.92 -31.26 1.29 922.46 12.62 308.69 917.89 33.09 37.24 -45.98 2.37 983.80 12.74 306.38 977.74 40.33 45.44 -56.65 0.85 1079.61 15.63 306.61 1070.62 52.60 59.40 -75.52 3.02 1175.20 21.09 307.66 1161.31 68.64 77.61 -99.49 5.72 1266.19 24.73 308.59 1245.11 88.01 99.49 -127.34 4.02 1367.29 26.62 307.76 1336.22 111.97 126.55 -161.78 1.90 1461.99 27.40 307.32 1420.59 135.10 152.75 -195.88 0.85 1558.39 26.12 306.54 1506.66 158.06 178.84 -230.57 1.38 1654.14 27.77 305.05 1592.02 180.26 204.20 -265.77 1.86 1750.08 29.18 305.95 1676.35 203.48 230.76 -303.00 1.54 1845.40 28.47 305.55 1759.86 226.98 257.62 -340.30 0.77 1939.88 29.54 309.72 1842.50 251.69 285.60 -376.54 2.42 2037.37 30.99 315.93 1926.72 281.83 319.00 -412.49 3.54 2132.25 33.45 319.01 2006.99 316.01 356.29 -446.64 3.12 2225.94 35.68 323.34 2084.14 354.37 397.71 -479.90 3.54 2259.12 36.65 324.33 2110.93 369.12 413.52 -491.45 3.41 2321.87 36.23 325.85 2161.41 397.70 444.08 -512.78 1.59 2418.55 36.99 328.20 2239.02 443.15 492.45 -544.15 1.65 2513.79 38.37 333.11 2314.42 491.20 543.18 -572.62 3.47 2609.54 39.79 337.38 2388.75 543.60 597.98 -597.85 3.18 2705.42 41.89 341.38 2461.30 600.12 656.65 -619.88 3.50 2800.24 44.91 346.09 2530.20 660.82 719.17 -638.04 4.67 2896.84 48.14 351.72 2596.69 728.14 787.91 -651.43 5.39 2992.22 51.19 354.07 2658.42 799.22 860.05 -660.39 3.71 3087.05 53.14 355.61 2716.59 872.93 934.63 -667.11 2.42 3184.05 56.56 357.23 2772.43 951.34 1013.77 -672.04 3.78 3279.53 60.00 359.32 2822.62 1031.99 1094.94 -674.46 4.06 3375.69 63.42 0.45 2868.19 1116.31 1179.60 -674.61 3.70 3471.51 66.70 3.34 2908.60 1203.05 1266.41 -671.71 4.38 3567.87 69.43 3.76 2944.59 1292.39 1355.61 -666.17 2.86 3662.83 73.33 4.52 2974.90 1382.35 1445.35 -659.67 4.18 47 CANRIG P 6fi Nikaitchuq OP14-S3 Surveys(continued) Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) 0100ft) 3757.90 76.97 4.76 2999.27 1474.23 1536.93 -652.24 3.84 3853.72 80.42 5.07 3018.05 1568.18 1630.53 -644.19 3.61 3948.91 81.85 4.77 3032.72 1662.23 1724.23 -636.12 1.53 4044.36 81.90 4.21 3046.21 1756.72 1818.43 -628.72 0.58 4140.47 81.60 4.33 3060.00 1851.82 1913.28 -621.64 0.34 4236.26 81.48 7.00 3074.09 1946.56 2007.56 -612.29 2.76 4331.83 81.91 9.28 3087.90 2040.98 2101.17 -598.90 2.40 4428.19 81.60 10.10 3101.72 2136.02 2195.17 -582.85 0.90 4523.82 81.66 10.05 3115.64 2230.26 2288.32 -566.30 0.08 4619.51 81.88 10.18 3129.34 2324.59 2381.56 -549.67 0.27 4715.29 81.78 10.09 3142.95 2419.01 2474.88 -532.98 0.14 4811.27 81.72 9.68 3156.72 2513.66 2568.46 -516.68 0.43 4905.48 82.02 8.99 3170.04 2606.65 2660.49 -501.55 0.79 5001.03 81.89 9.23 3183.41 2701.02 2753.90 -486.57 0.28 5097.50 81.90 8.82 3197.02 2796.29 2848.23 -471.59 0.42 5192.60 81.84 8.29 3210.46 2890.25 2941.32 -457.58 0.56 5287.76 81.84 8.19 3223.97 2984.30 3034.55 -444.08 0.10 5384.33 81.87 9.11 3237.65 3079.70 3129.06 -429.70 0.94 5479.79 81.87 9.74 3251.15 3173.92 3222.28 -414.23 0.65 5576.01 81.70 9.39 3264.90 3268.85 3316.19 -398.41 0.40 5671.17 81.33 10.20 3278.94 3362.63 3408.93 -382.39 0.93 5766.99 80.57 10.11 3294.02 3456.88 3502.08 -365.71 0.80 5862.95 79.55 10.90 3310.58 3550.96 3595.01 -348.48 1.34 5958.14 78.35 11.73 3328.82 3643.82 3686.62 -330.15 1.52 6055.02 78.34 11.96 3348.40 3738.02 3779.48 -310.67 0.23 6150.52 79.42 12.43 3366.81 3830.99 3871.07 -290.88 1.23 6245.45 82.06 13.15 3382.09 3923.81 3962.43 -270.14 2.88 6342.03 83.32 12.27 3394.38 4018.73 4055.88 -249.06 1.59 6438.02 83.37 10.96 3405.50 4113.44 4149.26 -229.87 1.36 6533.75 83.46 8.22 3416.48 4208.23 4243.02 -214.03 2.84 6629.37 83.40 6.94 3427.42 4303.12 4337.18 -201.50 1.33 6726.08 83.70 6.88 3438.29 4399.16 4432.58 -189.93 0.32 6822.08 83.44 6.57 3449.04 4494.52 4527.32 -178.76 0.42 6917.00 82.80 6.50 3460.41 4588.72 4620.95 -168.04 0.68 7011.52 82.89 8.22 3472.18 4682.42 4713.96 -156.02 1.81 7107.89 82.76 8.85 3484.22 4777.85 4808.51 -141.83 0.66 7203.39 82.72 9.13 3496.29 4872.36 4902.08 -127.03 0.29 7299.39 82.25 10.10 3508.84 4967.22 4995.92 -111.13 1.11 7394.64 81.84 10.55 3522.03 5061.15 5088.72 -94.23 0.64 7490.39 81.66 10.93 3535.77 5155.43 5181.82 -76.57 0.44 Surveys(continued) 48 CANRK.7 Iro A 6d Nikaitchuq OP14-S3 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 7586.73 81.85 12.52 3549.58 5250.12 5275.18 -57.19 1.65 7683.24 81.69 13.16 3563.40 5344.74 5368.30 -35.97 0.68 7778.46 81.87 13.43 3577.01 5438.00 5460.02 -14.29 0.34 7874.49 82.24 12.23 3590.29 5532.21 5552.75 6.82 1.30 7970.51 81.56 11.13 3603.82 5626.63 5645.84 26.07 1.34 8065.87 82.09 8.38 3617.38 5720.69 5738.86 42.06 2.91 8162.21 82.04 5.44 3630.68 5816.04 5833.57 53.54 3.02 8258.14 82.46 5.58 3643.62 5911.09 5928.19 62.67 0.46 8353.20 82.37 3.28 3656.17 6005.31 6022.13 69.94 2.40 8449.06 83.65 0.26 3667.83 6100.29 6117.22 72.88 3.40 8496.32 83.87 0.28 3672.97 6147.11 6164.19 73.10 0.47 8536.55 84.20 359.39 3677.15 6186.96 6204.21 72.98 2.35 8632.65 85.03 357.93 3686.17 6282.05 6299.85 70.75 1.74 8728.70 85.81 354.31 3693.84 6376.62 6395.36 64.27 3.84 8824.51 86.40 349.59 3700.35 6469.72 6489.98 50.88 4.95 8920.26 85.90 345.07 3706.79 6560.72 6583.16 29.94 4.74 9015.91 84.96 341.41 3714.41 6649.26 6674.44 2.45 3.94 9111.72 84.54 337.22 3723.18 6735.22 6763.68 -31.24 4.38 9207.81 85.39 332.33 3731.62 6817.90 6850.24 -72.03 5.15 9304.11 85.42 327.70 3739.34 6896.52 6933.36 -119.99 4.79 9400.75 84.27 323.91 3748.02 6971.10 7012.96 -174.07 4.08 9495.01 85.00 321.32 3756.84 7040.41 7087.52 -231.04 2.84 9591.38 85.61 318.20 3764.73 7108.03 7160.82 -293.08 3.29 9687.21 84.40 313.19 3773.08 7170.26 7229.12 -359.74 5.36 9781.94 84.26 308.91 3782.44 7225.72 7291.01 -430.81 4.50 9876.89 83.74 305.67 3792.37 7276.16 7348.22 -505.92 3.44 9973.30 83.94 305.56 3802.71 7324.98 7404.04 -583.85 0.24 10069.20 83.97 304.57 3812.81 7372.75 7458.83 -661.90 1.03 10164.09 83.93 302.98 3822.82 7418.17 7511.28 -740.34 1.67 10258.93 84.14 302.13 3832.67 7461.81 7562.04 -819.84 0.92 10355.47 85.06 302.18 3841.76 7505.67 7613.19 -901.21 0.95 10384.51 86.07 303.18 3844.00 7519.12 7628.82 -925.58 4.89 10509.45 88.61 305.25 3849.80 7580.03 7698.99 -1028.77 2.62 10609.11 88.94 304.56 3851.93 7629.71 7756.01 -1110.48 0.77 10701.88 88.65 303.54 3853.88 7674.74 7807.94 -1187.33 1.14 10805.52 87.75 298.69 3857.14 7720.33 7861.45 -1275.99 4.76 10901.87 85.80 296.55 3862.56 7757.33 7906.05 -1361.21 3.00 11002.71 87.81 297.71 3868.18 7795.25 7951.96 -1450.81 2.30 11100.94 91.29 301.25 3868.95 7835.94 8000.28 -1536.29 5.05 11167.00 90.76 302.68 3867.77 7865.89 8035.25 -1592.33 2.31 Surveys(continued) �p�± 49 CAN RIG toOt Ed Nikaitchuq OP14-S3 Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 11261.57 92.52 304.92 3865.06 7911.43 8087.83 -1670.87 3.01 11363.04 91.75 305.53 _3861.28 7962.47 8146.32 -1753.70 0.97 11462.60 91.44 305.03 3858.51 8012.65 8203.80 -1834.95 0.59 11561.90 92.49 303.90 3855.11 8061.47 8259.96 -1916.77 1.55 11651.79 92.45 303.65 3851.23 8104.70 8309.88 -1991.41 0.28 11757.18 91.69 302.85 3847.43 8154.55 8367.63 -2079.49 1.05 __11857.52 91.44 303.65 3844.69 8202.02 8422.62 -2163.37 0.84 11953.26 92.65 304.65 _ 3841.27 8248.63 8476.33 -2242.55 1.64 12052.28 92.96 308.05 3836.42 8300.07 8534.94 -2322.20 3.44 12142.17 91.81 307.77 3832.68 8348.87 8590.12 -2393.06 1.32 12248.75 90.62 307.07 3830.42 8405.99 8654.87 -2477.68 1.30 _ 12347.40 91.89 309.08 3828.26 8459.81 8715.69 -2555.31 2.41 12446.73 90.48 308.29 3826.21 8514.89 8777.76 -2632.83 1.63 12544.17 90.21 305.96 3825.62 8566.70 8836.56 -2710.52 2.41 _12643.96 90.12 303.92 3825.33 8616.50 8893.71 -2792.31 2.05 12741.49 90.36 304.25 3824.92 8663.91 8948.37 -2873.09 0.42 12840.50 90.27 303.68 3824.38 8711.86 9003.68 -2955.20 0.58 12938.97 90.11 301.88 3824.05 8757.75 9056.99 -3037.99 1.84 13036.78 89.28 300.64 3824.57 8801.03 9107.75 -3121.60 1.53 13134.97 88.08 299.85 3826.84 8842.89 9157.19 -3206.39 1.46 _13233.84 88.15 299.27 3830.09 8883.96 9205.94 -3292.35 0.59 _13331.89 85.66 298.33 3835.38 8923.47 9253.11 -3378.14 2.71 13428.88 86.93 302.49 3841.65 8964.99 9302.09 -3461.59 4.48 13528.17 87.61 305.23 3846.38 9012.86 9357.34 -3543.94 2.84 __13626.40 86.96 307.45 3851.04 9063.89 9415.48 -3622.97 2.35 13724.58 91.60 307.82 3852.27 9116.82 9475.41 -3700.69 4.74 _13823.73 93.15 311.27 3848.16 9172.98 9538.47 -3777.07 3.81 _13921.98 93.68 311.78 3842.31 9231.35 9603.49 -3850.49 0.75 14021.54 92.41 308.56 3837.02 9288.61 9667.61 -3926.45 3.47 `14118.78 92.73 309.77 3832.66 9343.16 9728.96 -4001.77 1.29 14217.26 93.00 308.38 3827.73 9398.27 9790.96 -4078.12 1.44 14316.21 92.68 310.42 3822.83 9454.10 9853.68 -4154.49 2.08 14414.52 93.25 312.56 3817.74 9512.48 9918.72 -4228.03 2.25 _14512.42 93.52 314.76 3811.96 9573.53 9986.18 -4298.72 2.26 14611.66 91.14 317.86 3807.93 9638.97 10057.87 -4367.20 3.94 14707.84 91.63 318.78 _ 3805.60 9704.94 10129.68 -4431.14 1.08 14807.14 89.81 317.31 3804.36 9772.71 10203.52 -4497.52 2.36 14905.48 89.72 316.24 3804.76 9838.22 10275.18 -4564.87 1.09 15003.21 90.09 316.52 3804.92 9902.83 10345.92 -4632.29 0.47 Surveys(continued) Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth(ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 50 CAMIG II Os EN Nikaitchuq OP14-S3 15102.87 90.94 315.54 3804.03 9968.24 10417.65 -4701.47 1.30 15200.70 90.82 314.72 3802.52 10031.29 10486.97 -4770.48 0.85 15299.22 90.33 314.19 3801.53 10093.89 10555.96 -4840.80 0.73 15398.33 89.69 313.06 3801.52 10155.76 10624.34 -4912.55 1.31 15496.73 89.44 311.33 3802.26 10215.24 10690.43 -4985.44 1.78 15594.80 89.18 308.73 3803.45 10271.52 10753.50 -5060.52 2.66 15692.99 87.67 307.36 3806.14 10325.04 10813.98 -5137.82 2.08 15791.42 87.60 304.75 3810.21 10375.77 10871.86 -5217.32 2.65 15890.05 89.45 304.60 3812.75 10424.58 10927.95 -5298.40 1.88 15988.49 90.38 305.12 3812.89 10473.59 10984.22 -5379.17 1.08_ 16087.37 89.79 304.29 3812.74 10522.59 11040.51 -5460.46 1.03 16185.59 90.34 306.02 3812.63 10571.93 11097.07 -5540.76 1.85 16283.80 90.33 306.92 3812.06 10623.20 11155.44 -5619.74 0.92 16382.58 91.59 306.35 3810.40 10675.00 11214.37 -5698.99 1.40 16480.74 92.01 304.55 3807.32 10724.72 11271.28 -5778.91 1.88 16579.09 94.13 303.09 3802.05 10772.06 11325.93 -5860.49 2.62 16678.19 94.52 302.42 3794.58 10818.08 11379.40 -5943.60 0.78 16775.79 95.11 299.83 3786.39 10860.90 11429.67 -6026.84 2.71 16873.72 95.11 297.00 3777.66 10899.66 11476.08 -6112.63 2.88 16972.44 92.24 297.14 3771.33 10936.67 11520.91 -6200.34 2.91 17071.54 89.91 293.16 3769.47 10970.79 11563.00 -6290.01 4.65 17169.78 90.05 297.99 3769.51 11005.31 11605.40 -6378.59 4.92 17267.52 93.33 298.97 3766.63 11044.23 11651.98 -6464.46 3.50 17366.24 94.87 293.43 3759.56 11079.82 11695.44 -6552.77 5.81 17465.02 93.72 292.10 3752.17 11109.88 11733.55 -6643.59 1.78 17564.12 90.66 292.24 3748.38 11139.11 11770.92 -6735.29 3.09 17661.01 92.29 295.22 3745.88 11170.20 11809.89 -6823.95 3.50 17758.77 92.55 296.90 3741.76 11205.30 11852.80 -6911.69 1.74 17857.10 92.83 297.93 3737.14 11242.75 11898.02 -6998.87 1.08 17955.36 92.39 298.84 3732.67 11281.71 11944.68 -7085.23 1.03 18053.22 91.71 300.13 3729.17 11322.24 11992.82 -7170.36 1.49 18151.36 91.78 300.90 3726.18 11364.50 12042.63 -7254.87 0.79 18248.25 91.98 301.54 3723.00 11407.28 12092.82 -7337.68 0.69 18347.38 92.24 301.18 3719.35 11451.27 12144.37 -7422.27 0.45 18446.15 89.70 298.40 3717.68 11492.67 12193.43 -7507.96 3.81 18543.67 89.09 298.81 3718.71 11531.71 12240.11 -7593.57 0.75 18641.92 88.81 298.32 3720.51 11570.98 12287.08 -7679.85 0.57 18740.46 88.71 300.51 3722.64 11611.70 12335.47 -7765.66 2.22 Surveys(continued), Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) , (ft) N(+),S(-) E(+),W(-) _ (°/100ft) 18838.68 90.99 301.12 3722.90 11654.47 12385.78 -7850.01 2.40 51 CANRIG iiiik EN Nikaitchuq OP14-S3 18937.18 92.50 302.66 3719.90 11699.00 12437.79 -7933.60 2.19 19035.70 92.14 303.68 3715.91 11745.47 12491.64 -8015.99 1.10 19134.07 94.01 304.94 3710.63 11793.55 12547.01 -8097.13 2.29 19232.58 92.76 303.43 3704.82 11841.50 12602.26 -8178.47 1.99 19331.15 93.36 301.96 3699.55 11887.25 12655.42 -8261.30 1.61 19429.23 93.55 301.41 3693.64 11931.21 12706.85 -8344.61 0.59 19527.70 94.19 301.98 3687.00 11975.35 12758.46 -8428.20 0.87 19625.96 94.37 302.60 3679.66 12020.27 12810.81 -8511.04 0.66 19724.44 91.14 300.77 3674.93 12064.44 12862.46 -8594.73 3.77 19822.73 91.11 300.06 3673.00 12106.61 12912.21 -8679.47 0.72 19920.89 90.48 299.47 3671.64 12147.73 12960.94 -8764.67 0.88 20019.05 90.71 298.60 3670.62 12187.71 13008.58 -8850.49 0.92 20117.92 91.92 298.77 3668.35 12227.41 13056.02 -8937.20 1.24 20217.07 88.89 298.58 3667.65 12267.22 13103.59 -9024.18 3.06 20315.56 85.58 295.89 3672.40 12304.44 13148.60 -9111.63 4.33 20415.47 84.45 294.31 3681.08 12338.64 13190.83 -9201.76 1.94 20512.22 87.73 296.19 3687.68 12372.05 13231.99 -9289.04 3.91 20609.59 92.18 296.15 3687.76 12407.20 13274.93 -9376.41 4.57 20704.48 91.87 294.89 3684.40 12440.45 13315.78 -9461.99 1.37 20802.55 91.84 294.53 3681.23 12473.50 13356.76 -9551.03 0.37 20905.24 93.25 295.11 3676.67 12508.29 13399.82 -9644.14 1.48 21003.41 92.91 294.65 3671.39 12541.62 13441.06 -9733.07 0.58 21102.06 90.67 294.30 3668.31 12574.49 13481.91 -9822.80 2.30 21200.83 88.81 293.30 3668.76 12606.32 13521.76 -9913.17 2.14 21279.27 88.72 293.78 3670.45 12631.26 13553.08 -9985.06 0.62 21340.00 88.72 293.78 3671.81 12650.80 13577.57 -10040.62 0.00 52 CANRIG c) i ' 0 XLL XQ Q � X = i a) to Qo vim oo Qo ZZ Z U~ g m0 , U r — 1 i 1 i M i - i 1 r i— X Tr N C)aL N co N co 1- Q re = r v N CO r LO V! 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M N N r ( O U H 73 ") , O = Ey .r U5w• cn r O ` -- p'w0000Tr 000) V 0) Met (0Ois (OO AT O) N- 11 LLB Co 4- Q ; vrrr Ln Tr Tr Ln Tr co up up up up (O up up Tr up w II II d 3 .w O LL LL « cZ rNNNNM N MMd- cr .:1- (ONI- tt 'tt '7 C Q 2 0.ODO) Q) 0> MMM O) 0OjMMMO) O M OO - (n Vj 2 02 C O 0 Co O T d 3 � 0 t t00 (O (Of- "tN- N- 00 O 00 w - ' U (/_) > up Tr r- r- r-- co M co Tr co 1 00 O 00 0 0 00 0 O N O m > N � rNNNr M mTrco O (OMM M MM L U O `C 2J Q rrNNNNM M mmmmM my Uw LOW LO LO LO 3 w � � OOO - - c' CM OI� MctMMLnLn Ln LnLn N5 •N C Cl) O Ln N M N N 0) CO r (O O I� I- I� cY �f > 0 5 O ii � 2T- � NNNNTr CO (O (OCCOOOOD000000 O 00 > Ua C O 3 O N 0) l � LLa } W III 11 II II 'a d 00000000 00000000 00 > Cm +'' NNNNNNNN NNNNNNN N NN � 5a >- (Of� 000) OrNM TrLn (OIs000) Or NM O O O O \ - - - \ \ \ - - N N N N Ln Ln Ln n Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln V N U) up 3 0 U) O U) O) O UD N- U) U) N 0 0 c 42 O) CO U) N T- CO CO e- U) - U) CO W rCO '43' Nr U) U) N- CO CO f- CO CO O) CO 00 U) J 0 0 0 0 0 0 0 0 0 0 0 0 0 1 _ 0 0 0 0 0 0 0 0 0 0 0 0 0 V CD CD U) O U) O U) 0 0 0 0 0 0 0 EN � 0000 - M N Tf 0 - 0) 0) O) O) CA O) CO 00 CO CO CO CO CO N- r- a) NNNU) 0 � M U) U) OMf- 000000O) COM U) NN N- :j N v- N M M N N N ii I ' N0; IO-) 000 N U) . � � Tzi N Cj N N N T- N N M N r- r M M M M M M CO M M M M . U) M co TT ig U) U7 N O) Q NN N '- 0U) U) U1 CONNCV - - Nr •- ',- 4; MMCIMM \ MM M \ MMMM c) 82 COCOCO CCOCOCOCO CO COCOCOCOCO 15 a) I- 0 r.' NI- CO U) U) U) U) U) N- CA O) 4) 0eNr- N % Nv- Cf) T- % CONc- e- 7 U) 00 (1 '- C6 6) O) 00 O) T- 00 ' O) O) m co 0) c _T E („) N to d LL i i i i i i i i L•C "p �r� 0 N f6 O a ,i� 3 Q U Y 0 o <7 0 Z c,-) m U) R2 C ao Oo C R2 OO CO C C N d Rl R2 COe01000e CO R2 g2 up COe O C9 � vU)) CONCCOOCO CU) U) U) iii COCO in U) ti)0 Q 00 - U) 0) N- N- CO Tr U) M � U) ', C7) O 7 N Y E > CO CO 00) N- CO U) N � U) U) U) U) L N 1 II CL r- N U) 0 0 v) L Q Q 03 rr 0 - (U r O 0 u u 2 a a) °' � QVV � vvvvvv � � � � = Li- QO) Q) 6O) 6) 6) 6) Oi O) 0O) O) O) C O C CC) T =0 00N- (N 00U) M MCMCMCOOD '= w (I) _ U) U) CON0NN- N- NNNNN U) t co CO CO CO CO N- CO CO CO CO CO CO CO +' O O 15 a+ MMMCMMMM M 00 01 01 01 01 L U C 1 1 1 1 1 1 1 1 1 1 1 1 1 O'7•N U ++ w' U) U) � U) U) N- N- 000000 U) C EL � aU) U) O0 0 Ovvvvvv 5 5 � g � NN .- CO co MMMMM � OO � MU) OOO) U4 'a N NNNNN 73 C •y73 O 5 7 Cd 0) U - L- a } re 11 II II II > N 7 11 N N N N N N CD CD CD N N ( (N � ? a }tl- 2 ea � U) CCO � CO Q) 00 � NNNNN T- N M N N N N N N M M U) U) U) U) ►) C) 1 COCOCOCOCO V) N ENI PETROLEUM DAILY WELLSITE REPORT CANIRIG QP14-S3 REPORT FOR Keener/Goerlich/Buchanan DATE May 06,2011 DEPTH 307.00000 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 160.00000 24 HOUR FOOTAGE 306 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 258.2 .03 11.10 258.2 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16 Hughes MX-1 5191523 3x20,1x16 160 306 1.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 2192.2 @ 161.00000 62.3 @ 306.00000 62.8 97.88874 FT/HR SURFACE TORQUE 2297 @ 193.00000 686 @ 161.00000 794.9 729.86804 AMPS WEIGHT ON BIT 13 @ 213.00000 0 @ 161.00000 4.3 0.00000 KLBS ROTARY RPM 48 @ 307.00000 38 @ 198.00000 18.7 48.83029 RPM PUMP PRESSURE 472 @ 229.00000 301 @ 161.00000 204.3 414.15085 PSI DRILLING FLUIDS REPORT DEPTH 306 MW 8.8 VIS 160 PV 33 YP 32 FL 6.6 Gels 22/44/49 CL- - FC 2/- SOL 3 SD - OIL -/97 MBT 30 pH 9.3 Ca+ 100 CCI 900 MWD SUMMARY INTERVAL 160 TO TOOLS GyroPulse,PowerPulse GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 179.00000 0 @ 273.00000 0.1 TRIP GAS CUTTING GAS 0 @ 307.00000 0 @ 307.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 0 @ 307.00000 0 @ 307.00000 0.0 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 307.00000 0 @ 307.00000 0.0 AVG PROPANE(C-3) 0 @ 307.00000 0 @ 307.00000 0.0 CURRENT BUTANE(C-4) 0 @ 307.00000 0 @ 307.00000 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 307.00000 0 @ 307.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY P/U 10,046'of DP and stand back.Picked up BHA#1 and washed down to conductor bottom at 160'MD.Picking up BHA#2 CANRIG PERSONNEL ON BOARD 2 DAILY COST$3630 REPORT BY J.McBeth ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CANRIG REPORT FOR Keener/Goerlich/Buchanan 11 DATE May 15,2011 DEPTH 7000.00000 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 6070.00000 24 HOUR FOOTAGE 930 CASING INFORMATION 13 3/8"@ 2326' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6917 82.82 7.18 3460.61 6822.08 83.42 6.9 344924 SURVEY DATA 6726.08 83.67 7.12 3438.45 6629.37 83.4 7.15 3427.56 6533.75 83.45 8.79 3416.61 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25 Hycalog PDC E143367 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 200.4 @ 607920000 2.1 @ 6199.00000 112.0 116.81515 FT/HR SURFACE TORQUE 11011 @ 6073.00000 6126 @ 6088.00000 8540.5 8574.79980 AMPS WEIGHT ON BIT 21 @ 6127.00000 0 @ 6216.00000 8.3 10.38087 KLBS ROTARY RPM 123 @ 6991.00000 59 @ 6205.00000 108.0 122.51132 RPM PUMP PRESSURE 2020 @ 6997.00000 1183 @ 6323.00000 1773.6 1988.37952 PSI DRILLING FLUIDS REPORT DEPTH 6990 MW 9.35 VIS 54 PV 13 YP 27 FL 4.4 Gels 14/21/25 CL- 1600 FC 1/- SOL 4.6 SD OIL 3/92 MBT 13.75 pH 9.8 Ca* 80 CCI MWD SUMMARY INTERVAL 6070 TO 7000 TOOLS Xceed 900,ARC 825,NM ILS STAB,TELESCOPE GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 38 @ 6681.00000 0 @ 6387.00000 10.7 TRIP GAS CUTTING GAS 0 @ 7000.00000 0 @ 7000.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 5572 @ 6681.00000 41 @ 6387.00000 1604.9 CONNECTION GAS HIGH ETHANE(C-2) 88 @ 6681.00000 0 @ 6387.00000 26.4 AVG 10 PROPANE(C-3) 97 @ 6983.00000 0 @ 6387.00000 17.3 CURRENT 34 BUTANE(C-4) 47 @ 6985.00000 0 @ 6928.00000 1.9 CURRENT BACKGROUND/AVG 10 PENTANE(C-5) 25 @ 6985.00000 0 @ 6928.00000 1.0 HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Claystone PRESENT LITHOLOGY 90%Claystone,10%Sand DAILY ACTIVITY SUMMARY Drill from 6070'to 7000' CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3,545,Rigwatch$1200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT ��1RK3 OP14-S3 REPORT FOR Keener/Goerlich/Buchanan DATE May 16,2011 DEPTH 8550.00000 PRESENT OPERATION Drilling Ahead TIME 23:12:12 YESTERDAY 7000.00000 24 HOUR FOOTAGE 1550 CASING INFORMATION 13 3/8 2326'and `• DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8449.06 83.62 0.73 3668.27 8353.20 8228 3.71 3656.59 SURVEY DATA 8258.14 82.44 5.56 3644.03 8162.21 82.03 5.96 3631.07 8065.87 82.07 8.56 3617.74 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25 Hycalog PDC E143367 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG •,- RATE OF PENETRATION 235.7 @ 7564.00000 5.7 @ 7957.00000 129.4 115.16464 FT/HR SURFACE TORQUE 15066 @ 7954.00000 7217 0 7046.00000 10261.9 1081521777 AMPS WEIGHT ON BIT 23 @ 756420000 0 @ 8236.00000 10.4 11.83611 KLBS ROTARY RPM 122 @ 7063.00000 60 @ 7956.00000 116.7 117.56608 RPM PUMP PRESSURE 2354 @ 835620000 1316 @ 7109.00000 2094.5 1756.10278 PSI DRILLING FLUIDS REPORT DEPTH 8474 MW 9.4 VIS 56 PV 14 YP 27 FL 4.4 Gels 13/29/35 CL- 1790 FC 1/- SOL 6 SD OIL 3/91 MBT 18.75 pH 9.7 Ca+ 79 CCI MWD SUMMARY INTERVAL 6070 TO 8500 TOOLS Xceed 900,ARC 825,NM ILS STAB,TELESCOPE GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 385 @ 8168.00000 1 @ 7301.00000 862 TRIP GAS CUTTING GAS 0 @ 8550.00000 0 @ 8550.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 105821 @ 816820000 67 @ 8456.00000 13734.2 CONNECTION GAS HIGH ETHANE(C-2) 2207 @ 8491.00000 0 @ 7218.00000 141.7 AVG 75 PROPANE(C-3) 1414 @ 8485.00000 0 @ 7277.00000 68.0 CURRENT 39 BUTANE(C-4) 4206 @ 8485.00000 0 @ 7839.00000 104.0 CURRENT BACKGROUND/AVG 39 PENTANE(C-5) 328 @ 8485.00000 0 @ 8391.00000 21.9 HYDROCARBON (7906-8000)(8160-8240) SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 7906-8000 Sand/Claystone 100- VERY LIGHT GRAY TO MEDIUM GRAY WITH BLUISH GRAY HUES AND ABUNDANT TRANSLUCENTS AND TRANSPARENTS;LOWER COURSE TO 333u UPPER MEDIUM ABUNDANT MEDIUM GRAINS;WELL SORTED;SUB ROUND TO SUB ANGULAR;MODERATE SPHERICITY;LOOSE UNCONSOLIDATED AND DISAGGREGATED QUARTZ GRAINS;GRAIN SUPPORTED;TRACE AMOUNT OF FREE OIL IN SAMPLE;VERY SLIGHT PETROLEUM ODOR;NO STAINING ON LOOSE QUARTZ GRAINS;PATCHY FAINT YELLOW AND SPOTS OF ORANGE FLUORESCENCE OVER 50% OF SAMPLE;INSTANT TRANSLUCENT BLUISH WHITE TO WHITE CUT FLUORESCENCE;CLEAR VISIBLE CUT;LIGHT AMOUNT OF PALE STRAW RESIDUE;FAINT ORANGE RESIDUE FLUORESCENCE. LITHOLOGY Sand/Claystone PRESENT LITHOLOGY 90%Sand 10%Claystone DAILY ACTIVITY SUMMARY Sand/Claystone CANRIG PERSONNEL ON BOARD 4 DAILY COST Continue to drill from 7,000'-8,050' REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 cAIiRIG REPORT FOR Keener/Goerlich/Buchanan DATE May 17,2011 DEPTH 857100000 PRESENT OPERATION Servicing Rig TIME 01:10:53 YESTERDAY 8550.00000 24 HOUR FOOTAGE 23 CASING INFORMATION 13 3/8 2326' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25 Hycalog PDC 6667 8573 1906 35.3 2-3-BT-s-x-I-C7-BHA BHA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG • RATE OF PENETRATION 121.3 @ 8555.00000 5.5 @ 8566.00000 79.7 84.57592 FT/HR SURFACE TORQUE 11938 @ 8561.00000 9069 @ 8569.00000 11226.6 9389.44141 AMPS 1 WEIGHT ON BIT 17 @ 8566.00000 1 •@ 8568.00000 12.2 6.12751 KLBS . ROTARY RPM 117 @ 8553.00000 61 @ 8567.00000 91.6 61.92403 RPM PUMP PRESSURE 1772 @ 8555.00000 1709 @ 8571.00000 1820.3 1718.12769 PSI I DRILLING FLUIDS REPORT DEPTH 8573 MW 9.4 VIS 50 PV 14 YP 22 FL 5 Gels 9/20/27 CL- 1490 FC 1/- SOL 6 SD OIL 3/91 MBT 18.75 pH 9.7 Cal- 40 CCI MWD SUMMARY INTERVAL 6667 TO 8573 TOOLS Xceed 900,ARC 825,NM ILS STAB,TELESCOPE GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 184 @ 8567.00000 30 @ 8565.00000 96.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ 0 @ CONNECTION GAS HIGH ETHANE(C-2) @ 0 @ AVG PROPANE(C-3) @ 0 @ CURRENT N/A BUTANE(C-4) @ 0 @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ 0 @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Claystone PRESENT LITHOLOGY 90%Sand 10%Claystone DAILY ACTIVITY Drill to 8560'and tag hard spot,unable to orient rotary steerable as per well plan,BROOH to casing shoe.Circulate and POOH L/D BHA and wait on town to determine BHA • SUMMARY configuration. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3,545 Rigwatch$1,200 • REPORT BY Daniel Sherwood ICI ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 cJJRIc3 REPORT FOR Keener/GoerlichBuchanan DATE May 18,2011 DEPTH 9000.00000 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 8573.00000 24 HOUR FOOTAGE 427 CASING INFORMATION 13 3/8"@ 2236' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8920.26 85.89 345.4 6561.16 SURVEY DATA 8824.51 86.37 349.95 3700.44 8728.7 85.79 354.81 3693.89 8632.65 85.02 357.86 3686.19 8536.55 84.19 359.92 3677.16 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12.25 Hycalog PDC E143667 6x16 8573 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 274.5 @ 8576.00000 41.0 @ 8704.00000 145.4 99.32905 FT/HR SURFACE TORQUE 13106 @ 8731.00000 8061 @ 8608.00000 11713.0 11517.18457 AMPS WEIGHT ON BIT 21 @ 8608.00000 1 @ 8808.00000 12.6 15.02900 KLBS ROTARY RPM 120 @ 8669.00000 61 @ 8573.00000 118.6 119.50323 RPM PUMP PRESSURE 2327 @ 8645.00000 1718 @ 8573.00000 2040.1 2004.33960 PSI DRILLING FLUIDS REPORT DEPTH 8703 MW 9.4 VIS 57 PV 12 YP 20 FL 4.6 Gels 11/26/35 CL- 1540 FC 1/- SOL 4.5 SD OIL 4/92 MBT 17.5 pH 9.8 Ca+ 70 CCI MWD SUMMARY INTERVAL 8573 TO 9000 TOOLS Xceed 900,ARC 825,NM ILS STAB,TELESCOPE GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 239 @ 8603.00000 3 @ 8619.00000 75.7 TRIP GAS CUTTING GAS 0 @ 9000.00000 0 @ 9000.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 62442 @ 8603.00000 716 @ 8574.00000 17992.5 CONNECTION GAS HIGH ETHANE(0-2) 803 @ 8603.00000 9 @ 8574,00000 255.4 AVG 70 PROPANE(C-3) 445 @ 8838.00000 2 @ 8574.00000 195.3 CURRENT 49 BUTANE(C-4) 365 @ 8603.00000 0 @ 8799.00000 77.5 CURRENT BACKGROUND/AVG 20 PENTANE(C-5) 148 @ 8603.00000 0 @ 8799.00000 36.2 HYDROCARBON 8550-8700 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 8550-8700 SAND 100% 50- SAND(8550-8700)=PRIMARILY TRANSPARENT AND TRANSLUCENT,SOME LIGHT GRAY,SOME VERY LIGHT GRAY WITH SMOKEY HUES, 239 OCCASIONAL PALE BLUISH GREEN AND GRAYISH BLUE GREEN;95%QUARTZ COMPOSITION WITH 5%LITHICS,WITH LITHICS BECOMING MORE AVG APPARENT THROUGH THE SAMPLE INTERVAL;FINE GRAINED WITH SOME LOWER MEDIUM AND SOME VERY FINE;V WELL SORTED BECOMING 70 LESS WELL SORTED THROUGH INTERVAL;WELL ROUNDED;VERY HIGH TO HIGH SPHERICITY;UNCONSOLIDATED WITH NO APPARENT CEMENTATION;TRACE AMOUNTS OF LARGE QUARTZ NODULES AND FRACTURED CUTTINGS,TRACE AMOUNTS OF PURITE,SOME COAL FRAGMENTS AND CARBONACEOUS MATTER,VERY TRACE AMOUNTS OF CALCAREOUS MATERIAL,SOME SHELL FRAGMENTS,CLAYSTONE AND SILT;HIGH AMOUNTS OF OIL STAINING AND SOME FREE OIL IN SAMPLE WITH 75-80%OF SAMPLES WITH STAINING;75-80%DULL YELLOW GREEN OCCASIONALLY WHITE FLUORESCENCE BECOMING LESS APPARENT THROUGH INTERVAL;VERY FAST STREAMING WHITE CUT AND RING;STRONG PETROLEUM ODOR LITHOLOGY SAND/CLAYSTONE PRESENT LITHOLOGY 90%SAND 10%CLAYSTONE DAILY ACTIVITY SUMMARY P/U BHA,SERVICE RIG,RIH,DRILL AHEAD F/8,573'TO 9,000' CANRIG PERSONNEL ON BOARD 4 DAILY COST$3,454 REPORT BY DANIEL SHERWOOD ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CANRIG REPORT FOR Keener/Goerlich/Buchanan DATE May 19,2011 DEPTH 10455.00000 PRESENT OPERATION Ciro and Cond TIME 19:4923 YESTERDAY 9000.00000 24 HOUR FOOTAGE 1455 CASING INFORMATION 13 3/8"@ 2326' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10384.51 85.99 303.06 3844.06 10355.47 85.1 302.01 3841.80 SURVEY DATA 10258.93 84.16 302 3832.77 10164.09 83.93 303.07 3822.93 10069.2 83.96 304.32 3812.92 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 12.25 Hycalog PDC Et43667 6x16 8573 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 253.6 @ 10314.00000 14.3 @ 9455.00000 129.3 152.86382 FT/HR SURFACE TORQUE 16399 @ 10416.00000 10117 @ 9116.00000 12985.4 14154.00293 AMPS WEIGHT ON BIT 25 @ 9856.00000 0 @ 9473.00000 13.8 11.50814 KLBS ROTARY RPM 122 @ 9900.00000 61 @ 9105.00000 118.4 118.46115 RPM PUMP PRESSURE 2895 @ 10323.00000 1709 @ 9059.00000 2456.6 2803.25684 PSI DRILLING FLUIDS REPORT DEPTH 10455 MW 9.6 VIS 66 PV 17 VP 28 FL 4.6 Gels 17/41/51 CL- 1840 FC 1/- SOL 8 SD OIL 3/89 MBT 23.75 pH 9.8 Ca+ 64 CCI MWD SUMMARY INTERVAL 8573 TO 10455 TOOLS Xceed 900,ARC,MN ILS STAB,TELESCOPE GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 486 @ 10310.00000 2 @ 9102.00000 53.5 TRIP GAS CUTTING GAS 0 @ 10455.00000 0 @ 10455.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY ' METHANE(C-1) 149454 @ 10310.00000 537 @ 9102.00000 12454.2 CONNECTION GAS HIGH ETHANE(C-2) 1656 @ 10312.00000 7 @ 9102.00000 155.8 AVG 35 PROPANE(C-3) 618 @ 9494.00000 9 @ 9102.00000 125.7 CURRENT 10 BUTANE(C-4) 712 @ 10310.00000 0 @ 9454.00000 129.9 CURRENT BACKGROUND/AVG 10 PENTANE(C-5) 296 @ 10307.00000 0 @ 9454.00000 85.2 HYDROCARBON 10300-10450 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10300-10455 Claystone/Sandstone 50- CLAYSTONE/SANDSTONE=(10350-10450)SAMPLE CONSIST PRIMARILY OF CLAYSTONE AND SANDSTONE THE CLAYSTONE IS LIGHT TO MEDIUM 486 LIGHT GRAY;MODERATLEY COHESIVE AND ADHESIVE;LUMPY TO CLUMPY CONSISTENCY;FLEXIBLE AND MALLEABLE TENACITY;IRREGULAR OPEN FRACTURE;MASSIVE CUTTINGS HABIT;CLAYEY SILTY TEXTURE;INTERBEDDED SAND;INTERBEDDED LITHICS;INTERBEDDED COAL FRAGMENTS AND SOME CARBONACEOUS MATTER;PYRITE;TRACE AMOUNTS OF FELDSPAR;GLAUCONITIC LITHICS A FINE GRAIND SANDSTONE IS ALSO PRESENT 100%QUARTZ COMPOSTION;VERY WELL SORTED SUB ANGULAR TO ANGULAR;WITH VERY LOW SPHERICITY; EASILY FRIABLE WITH POSSIBLE SILCA CEMENTATION;MODERATLEY CEMENTED:100%VERY LIGHT BROWN STAIN IS PRESENT WITH MODERATE VISIBLE POROSITY;THE SAMPLE OVERALL EXHIBTS 70%FLOURESCENCE WITH THE SANDSTONE AT 100 FLOURESCENCEAN IMMEDIATE LIGHT STRAW CUT IS EMMITED WITH HIGH INTESITY;DULL YELLOWISH WHITE RESIDUAL FLUORESCENCE LITHOLOGY Sand/Sandstone/Claystone PRESENT LITHOLOGY 60%Sand 20%Sandstone 20%Claystone DAILY ACTIVITY SUMMARY Drill F/9000'and to section TD of 10,455' CANRIG PERSONNEL ON BOARD 4 DAILY COST 3,454 REPORT BY Daniel SHerwood ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CAIRIG REPORT FOR DATE May 20,2011 DEPTH 10455.00000 PRESENT OPERATION Testing BOP's TIME 00:00 YESTERDAY 10455.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@2326' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10455 86.07 303.18 3848.84 10384.51 86.07 303.18 3844 SURVEY DATA 10355.47 85.06 302.18 3841.76 10258.93 84.14 302.13 3832.67 10164.09 83.93 302.98 3822.82 • • BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25 Hycalog PDC E141127 12.25 8573 10455 1882 17.3 1-1-NO-A-X-I_NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 10455 MW 9.4 VIS 50 PV 12 YP 23 FL 5 Gels 12/31/41 CL- 1550 FC 1/- SOL 7 SD OIL 3/90 MBT 18.75 pH 9.9 Can 53 CCI MWD SUMMARY INTERVAL 8573 TO 10455 TOOLS Xceed 900,ARC,MN ILS STAB,TELESCOPE GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 93 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG 7 PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND/SANDSTONE/CLAYSTONE PRESENT LITHOLOGY 60%SAND 20%SANDSTONE 20%CLAYSTONE DAILY ACTIVITY SUMMARY BROOH to casing shoe,Circulate and Condition,Slug DP and POOH to surface,L/D BHA and C/O rams to 9 5/8"and test accordingly. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3,480,Rigwatch$1,200 I REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT Ci\NRIG OP14-S3 REPORT FOR Smith/Cormier/Buchanan DATE May 21,2011 DEPTH 10455.00000 PRESENT OPERATION Running 9 5/8"Casing TIME 00:00: YESTERDAY 10455.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2326' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10455 85.99 303.06 3844.06 10384.51 85.10 302.01 3841.80 SURVEY DATA 10355.47 84.16 302 3832.77 10258.93 83.93 303.07 3822.93 10164.09 83.96 304.32 3812.92 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25 Hycalog PDC E141127 6x16 8573 10455 1882 17.3 1-1-NO-AX-I-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 10455 MW 9.4 VIS 54 PV 11 YP 24 FL 5 Gels 10/27/37 CL- 1540 FC 1/- SOL 7 SD OIL 3/91 MBT 18.75 pH 9.8 Ca+ 44 CCI MWD SUMMARY INTERVAL 8573 TO 10455 TOOLS Xceed 900,ARC,MN ILS STAB,TELESCOPE • GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS I CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND/SANDSTONE/CLAYSTONE PRESENT LITHOLOGY 60%SAND/20%SANDSTONE/20%CLAYSTONE DAILY ACTIVITY SUMMARY Finish testing BOP'R/U to run 9 5/8"casing.RIH with casing to 9,144'and CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3,480 RIGWATCH$1,200 REPORT BY Daniel Sherw000d ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 cPJ'JRK3 REPORT FOR Smith/Cormier/Buchanan DATE May 22,2011 DEPTH 10455.00000 PRESENT OPERATION R/D cement head,prep BOP stack for lifting TIME 11:59:00 YESTERDAY 10455.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 10,444' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10455 85.99 303.06 3844.06 10384.51 85.10 302.01 3841.80 SURVEY DATA 10355.47 84.16 302 3832.77 10258.93 83.93 303.07 3822.93 10164.09 83.96 304.32 3812.92 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25 Hycalog PDC E141127 6x16 8573 10455 1882 17.3 -1-NO-AX-I-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 10455 MW 9.4 VIS 49 PV 11 YP 16 FL 5.4 Gels 7/24/30 CL- 1500 FC 1/- SOL 6.5 SD OIL 3/91 MBT 17.5 pH 9.7 Ca-i. 50 CCI MWD SUMMARY INTERVAL 8573 TO 10455 TOOLS Xceed 900,ARC,MN ILS STAB,TELESCOPE GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND/SANDSTONE/CLAYSTONE PRESENT LITHOLOGY 60%SAND/20%SANDSTONE/20%CLAYSTONE DAILY ACTIVITY SUMMARY RIH w/9 5/8"cog to 10,444,R/U cement head,fill csg and break circ,Pump 12.5 ppg cement.R/D cement equipment. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3,480 RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT CANRIG OP14-S3 REPORT FOR Smith/Cormier/Buchanan DATE May 23,2011 DEPTH 10455.00000 PRESENT OPERATION DP Managment TIME 24:00:00 YESTERDAY 10455.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10455 85.99 303.06 3844.06 10384.51 85.10 302.01 3841.80 SURVEY DATA 10355.47 84.16 302 3832.77 10258.93 83.93 303.07 3822.93 10164.09 83.96 304.32 3812.92 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25 Hycalog PDC E141127 6x16 8573 10455 1882 17.3 -1-NO-AX-I-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 10455 MW 9.4 VIS 57 PV 11 YP 16 FL 5.2 Gels 8/23/29 CL- 1500 FC 1/- SOL 7 SD OIL 3/91 MBT 17.5 pH 9.7 Ca+ 40 CCI MWD SUMMARY INTERVAL 8573 TO 10455 TOOLS Xceed 900,ARC,MN ILS STAB,TELESCOPE GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND/SANDSTONE/CLAYSTONE PRESENT LITHOLOGY 60%SAND/20%SANDSTONE/20%CLAYSTONE DAILY ACTIVITY N/D BOP's break stack apart set emergency slips and cut 9 5/8"casing.N/U BOP's and C/O rams to 4.5"Service rig and begin pipe mangment RIH with all the DP in derrick.L/D bad SUMMARY hardband.POOH installing intalling WEI subs. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3,480 RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT CANRAG OP14-S3 REPORT FOR Smith/Cormier/Buchanan DATE May 24,2011 DEPTH 10455.00000 PRESENT OPERATION Testing BOP's TIME 24:00:00 YESTERDAY 10455.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10455 85.99 303.06 3844.06 10384.51 85.10 302.01 3841.80 SURVEY DATA 10355.47 84.16 302 3832.77 10258.93 83.93 303.07 3822.93 10164.09 83.96 304.32 3812.92 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25 Hycalog PDC E141127 6x16 8573 10455 1882 17.3 -1-NO-AX-I-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 10455 MW 9.4 VIS 54 PV 16 YP 10 FL 11.1 Gels 4/5/5 CL- 91500 FC 1/- SOL 8.24 SD OIL 65/35 MBT pH Ca* CCI MWD SUMMARY INTERVAL 8573 TO 10455 TOOLS Xceed 900,ARC,MN ILS STAB,TELESCOPE GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND/SANDSTONE/CLAYSTONE PRESENT LITHOLOGY 60%SAND/20%SANDSTONE/20%CLAYSTONE DAILY ACTIVITY SUMMARY Continue installing WEI subs on 5"DP and rack back in derrick.P/U 4.5"DP and RIH M/U WEI subs.POOH racking back in derrcik.Begin testing BOP's CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3,560 RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CRIG REPORT FOR Keener/Goerlich/Buchanan DATE May 07,2011 DEPTH 1925.00000 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 307.00000 24 HOUR FOOTAGE 1618 CASING INFORMATION 20"160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1558.39 25.64 306.61 1508.79 SURVEY DATA 1654.14 27.02 305.15 1594.61 1750.08 28.34 305.96 1679.57 1845.4 27.81 305.39 1763.68 1939.88 28.77 310.17 1846.88 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16 Hughes MX-1 5191523 3x20,1x16 160 16:30 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 485.9 @ 309.00000 36.0 @ 1436.00000 135.6 184.54149 FT/HR SURFACE TORQUE 15037 @ 1135.00000 0 @ 1237.00000 1397.9 3331.37329 AMPS WEIGHT ON BIT 44 @ 776.00000 0 @ 593.00000 14.9 3.26518 KLBS ROTARY RPM 49 @ 313.00000 0 @ 1577.00000 18.5 40.59419 RPM PUMP PRESSURE 1224 @ 1081.00000 414 @ 307.00000 885.9 933.09033 PSI DRILLING FLUIDS REPORT DEPTH 1820 MW 9.10 VIS 109 PV 27 YP 28 FL 5.5 Gels 20/39/44 CL- - FC 2/- SOL 6 SD 0.25 OIL -/94 MBT 28 pH 9.5 Ca+ 100 CCI 2000 MWD SUMMARY INTERVAL 160 TO TOOLS GyroPulse,PowerPulse GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 72 @ 1798.00000 0 @ 1127.00000 8.1 TRIP GAS CUTTING GAS 0 @ 1925.00000 0 @ 1925.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 12280 @ 1798.00000 30 @ 886.00000 1469.7 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 1925.00000 0 @ 1925.00000 0.0 AVG PROPANE(C-3) 0 @ 1925.00000 0 @ 1925.00000 0.0 CURRENT BUTANE(C-4) 0 @ 1925.00000 0 @ 1925.00000 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 1925.00000 0 @ 1925.00000 0.0 HYDROCARBON SHOWS • INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Cuttings sampling begin after surface casing. PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Slide drilling 20'and rotating 10'from 306'to 1160'.Slide drilling to 194T/1787'TVD.Drilling ahead. CANRIG PERSONNEL ON BOARD 2 DAILY COST$3630 REPORT BY J.McBeth ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 c. JJRIG REPORT FOR Smith/Cormier/Buchanan DATE May 25,2011 DEPTH 10455.00000 PRESENT OPERATION Pressure Testing 9 5/8"Csg TIME 24:00:00 YESTERDAY 10455.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 95/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10455 85.99 303.06 3844.06 10384.51 85.10 302.01 3841.80 SURVEY DATA 10355.47 84.16 302 3832.77 10258.93 83.93 303.07 3822.93 10164.09 83.96 304.32 3812.92 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 10455 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 10455 MW 9.4 VIS 54 PV 16 YP 10 FL 10.0 Gels 4/5/5 CL- 92000 FC 1/- SOL 8.14 SD OIL 65/35 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 10455 TO TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND/SANDSTONE/CLAYSTONE PRESENT LITHOLOGY 60%SAND/20%SANDSTONE/20%CLAYSTONE DAILY ACTIVITY Test choke and 4.5"and 5"rams.P/U MWD tools and BHA.P/U 4.5"DP and RIH to 2065'.Shallow pulse test MWD.Continue to single in hole with 4.5"to 9,517'Cont RIH to 10,348' SUMMARY and tag cmnt.Circulate and pressure test casing. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3,560 RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT 0P14-S3 c1J'iRI3 REPORT FOR Smith/Cormier/Buchanan DATE May 26,2011 DEPTH 11200.00000 PRESENT OPERATION Drilling Ahead TIME 23:59:00 YESTERDAY 10444.00000 24 HOUR FOOTAGE 756 CASING INFORMATION 95/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11363.04 91.76 305.3 3861.21 11261.57 92.48 304.76 3864.96 SURVEY DATA 11167 90.82 302.44 3867.69 11100.94 91.22 30057 3868.86 11002.71 87.85 297.58 3868.06 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 516.3 @ 10798.00000 27.5 @ 10456.00000 212.8 155.08250 FT/HR SURFACE TORQUE 17388 @ 10753.00000 7145 @ 10477.00000 106815 10268.38086 AMPS WEIGHT ON BIT 33 @ 10771.00000 0 @ 10968.00000 11.7 954681 KLBS ROTARY RPM 121 @ 11063,00000 59 @ 10498.00000 103.0 119.48824 RPM PUMP PRESSURE 3611 @ 11117.00000 2240 @ 10504.00000 3214.0 3390.19312 PSI DRILLING FLUIDS REPORT DEPTH 11164 MW 9.45 VIS PV 20 YP 11 FL 10.8 Gels 5/6/7 CL- 90000 FC -/1 SOL 12 SD OIL 65/35 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 10444 TO 11,200 TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 735 @ 10889.00000 29 @ 11165.00000 255.3 TRIP GAS CUTTING GAS 0 @ 11200.00000 0 @ 11200.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 96931 @ 10889.00000 3971 @ 11165.00000 34705.2 CONNECTION GAS HIGH ETHANE(C-2) 816 @ 10889.00000 14 @ 11165.00000 250.4 AVG 260 PROPANE(C-3) 115 @ 10735.00000 4 @ 11165.00000 38.6 CURRENT 36 BUTANE(C-4) 180 @ 10735.00000 1 @ 11165.00000 58.3 CURRENT BACKGROUND/AVG 35 PENTANE(C-5) 135 @ 10735.00000 1 @ 11165.00000 41.0 HYDROCARBON (N/A) SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10,922-11,268 Crosssed fault @ 10,922'and SILTSTONE/SANDSTONE(11100-11200).MEDIUM LIGHT GRAY TO LIGHT GRAY WITH SOME MEDIUM DARK GRAY IN PLACES; went below OA sand and into MODERATELEY SOFT;MALLEABLE,PULVERULENT WHEN DISSOLVED FROM DRILLING FLUIDS;OPEN IRREGULAR FRACTURE PLATY TO Canning.Returned to OA @ FLAKY CUTTINGS HABIT;DULL EARTHY LUSTER;SILTY TO GRITTY TEXTURE SUCROSIC ONCE DRIED;IMBEDDED QUARTZ AND LITHIC 11,268' FRAGMENTS;IMBEDDED CARBONACEOUS MATERIAL;IMBEDDED PYRITE;A GRAYISH OARNGE TO DARK YELLOWISH OARNGE SILSTONE IS ALSO PRESENT;MUSHY GELATINOUS CONSISTENCY AND PULVERULENT TENACITY;LARGE QUANTITIES OF IMBEDDED DIATOMS ARE PRESENT;GOOD QUANTITIES OF SANDSTONE THROUGHOUT INTERVAL;TRACE AMOUNTS OF OIL STAINED QUARTZ; WITH NO DETECTABLE ODOR;TRACE PINPOINT FLOURESCENCE MASKED BY DRILLING FLUID LITHOLOGY Siltstone,Sand,Sandstone PRESENT LITHOLOGY 75%Siltstone 10%Sand 15%Sandstone DAILY ACTIVITY Pressure test casing,Slip and cut D/L,Callibrate MWD depth encoder and block height.Drill cmt and shoe track f/10,352-10,444'.Drill to 10,475'and CBU.FIT=9.4 EM W,Drill ahead to SUMMARY 11,164'and CBU.BROOH to 10,278'and RIH.Continue to drill ahead to 11,335'. CANRIG PERSONNEL ON BOARD 4 DAILY COST Rigwatch$1,200 DML$3,625 REPORT BY DML$3,625,RIGWATCH$1,200 ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CANRIG REPORT FOR Smith/Cormier/Buchanan DATE May 27,2011 DEPTH 13500.00000 PRESENT OPERATION Drilling Ahead TIME 23:59:00 YESTERDAY 11200.00000 24 HOUR FOOTAGE 2300 CASING INFORMATION 9 5/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13528.17 87.60 305.82 3845.90 SURVEY DATA 13428.88 86.94 303.20 3841.17 13331.89 85.75 298.65 3834.99 13233.84 88.13 299.18 3829.75 13134.97 88.11 299.78 3826.51 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 2568.7 @ 11285.00000 0.4 @ 11281.00000 277.2 313.76797 FT/HR SURFACE TORQUE 16165 @ 13446.00000 8630 @ 11481.00000 11212.7 12436.94824 AMPS WEIGHT ON BIT 32 @ 11281.00000 0 @ 12806.00000 6.9 1034430 KLBS ROTARY RPM 122 @ 1211930000 78 @ 11910.00000 119.1 121.43996 RPM PUMP PRESSURE 3754 @ 12459.00000 2108 @ 11636.00000 3371.5 335730444 PSI • DRILLING FLUIDS REPORT DEPTH 13295 MW 9.4 VIS PV 19 YP 15 FL 3.7 Gels 6/7/8 CL- 90500 FC -/1 SOL 8.16 SD OIL 67/33 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 10,444'TO 13500' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 I, GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 919 @ 11548.00000 15 @ 12796.00000 431.9 TRIP GAS CUTTING GAS 0 @ 13500.00000 0 @ 13500.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 116747 @ 13245.00000 2211 @ 12796.00000 57490.8 CONNECTION GAS HIGH ETHANE(C-2) 1032 @ 12738.00000 6 @ 11281.00000 440.3 AVG 500 PROPANE(C-3) 238 @ 11547.00000 3 @ 12796.00000 94.7 CURRENT 70 I BUTANE(C-4) 329 @ 13245.00000 0 @ 11277.00000 126.0 CURRENT BACKGROUND/AVG 500 PENTANE(C-5) 246 @ 11978.00000 0 @ 11277.00000 66.9 HYDROCARBON SHOWS Drilling has been entirely within production formation INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone,Sand,Siltstone PRESENT LITHOLOGY 99%Sand and Sandstone 1%Siltstone DAILY ACTIVITY SUMMARY Drill from 11,335'to 13,670' CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3,625,RIGWATCH$1,200 REPORT BY Daniel Sherwood • • • II ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 ` RIG REPORT FOR Simpson/Stout/Buchanan DATE May 28,2011 DEPTH 16000.00000 PRESENT OPERATION Drilling Ahead TIME 23:59:00 YESTERDAY 13500.00000 24 HOUR FOOTAGE 2500 CASING INFORMATION 9 5/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15988.49 90.36 305.88 3812.16 15890.05 89.44 305.30 3811.99 SURVEY DATA 15791.42 87.65 305.99 3809.49 15692.99 87.71 308.34 3805.50 15594.80 89.17 308.68 3802.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 418.5 @ 14911.00000 17.4 @ 14201.00000 253.3 65.87196 FT/HR SURFACE TORQUE 19265 @ 15488.00000 9611 @ 14183.00000 12863.5 17227.84180 AMPS WEIGHT ON BIT 28 @ 14871.00000 0 @ 14773.00000 9.3 20.04796 KLBS ROTARY RPM 123 @ 15179.00000 80 @ 15185.00000 119.3 82.62847 RPM PUMP PRESSURE 3899 @ 15282.00000 2951 @ 14973.00000 3654.5 3790.61328 PSI DRILLING FLUIDS REPORT DEPTH 15705 MW 9.4 VIS N/A PV 17 YP 19 FL 4.1 Gels 7/8/8 CL- 88K FC -/1 SOL 9.25 SD N/A OIL 68/32 MBT N/A pH N/A Ca+ N/A CCI N/A MWD SUMMARY INTERVAL 10,444'TO 16,000 TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 695 @ 14311.00000 24 @ 15820.00000 310.0 TRIP GAS CUTTING GAS 0 @ 16000.00000 0 @ 16000.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 90995 @ 14311.00000 4029 @ 13691.00000 34661.1 CONNECTION GAS HIGH ETHANE(C-2) 941 @ 14310.00000 25 @ 13767.00000 318.1 AVG 400 PROPANE(C-3) 243 @ 14311.00000 12 @ 13687.00000 97.4 CURRENT 454 • BUTANE(C-4) 308 @ 14311.00000 18 @ 13687.00000 129.7 CURRENT BACKGROUND/AVG 400 PENTANE(C-5) 188 @ 14403.00000 0 @ 13617.00000 67.4 HYDROCARBON Exited OA Sand at 13630'and drilled into Canning.Returned to OA @ 13,790'description below is of Canning. SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 13,630-13,790 Silstone/Sandstone 40- SILSTONE/SANDSTONE(13650-13850)SILSTONE GRADING TO SANDSTONE IN PLACES MEDIUM LIGHT GRAY TO MEDIUM GRAY,MEDIUM DARK 130u GRAY IN PLACES,STIFF,FIRM TO MODERATLEY FIRM CONSISTENCY,STIFF TO SECTILE TENACITY,PLANAR TO OPEN IRREGULAR FRACTURE DEPENDING UPON THE AMOUNT OF HYDRATION,SCALY TO FLAKY OCCASIONALLY NODULAR AND BLOCKY CUTTINGS HABIT,DULL EARTHY LUSTER,VERY SILTY GRITTY GRANULAR TEXTURE,VERY ARENACEOUS,IMBEDDED SAND AND GLUCONITIC SAND,SOME VERY FINE THIN BLACK CARBONACEOUS LAMINAE,IMBEDDED LARGE QUARTZ NODULES AND ANGULAR QUARTZ;SEVERAL VARITIES OF SILSTONE ARE PRESENT THROUGHOUT THIS INTERVAL THE LIGHT GRAY,AS WELL AS GRAYISH OARNGE TO PALE YELLOWISH BROWN VARIETY;LARGE QUANTITIES OF LARGE TRASPARENT TO TRANSLUCENT QUARTZ,TRACE AMOUNTS OF PYRITE;LARGE QUANTITIES OF COAL FRAGMENTS AND CARBONACEOUS MATERIAL;SEVERAL VARITIES OF SANDSTONE INCREASING AMOUNTS OF SAND THROUGHOUT THE DESCRIBED INTERVAL WITH THE SILSTONE BECOMING LESS APPARENT;NO DETECTABLE PETROLEUM ODOR;MODERATE VISIBLE POROSITY;VERY TRACE AMOUNTS OF OIL STAINED QUARTZ;ANY NATURAL FLOURESCENCE IS MASKED BY THE ARTIFICAL FLUORESCENCE OF THE DRILLING FLUID;LARGE QUANTITIES OF CALCIUM CARBONATE DRILLING ADDITIVE IN SAMPLES. LITHOLOGY Sandstone/Sand/Siltstone PRESENT LITHOLOGY 99%Sandstone 1%Siltstone DAILY ACTIVITY SUMMARY Drilled from 13,500'to 16,000' CANRIG PERSONNEL ON BOARD 5 DAILY COST COST DML$4,025, RIGWATCH$1,200 REPORT BY Daniel Sherw000d ENI PETROLEUM DAILY WELLSITE REPORT CANRIG OP14-S3 REPORT FOR Simpson/Stout/Buchanan DATE May29,2011 DEPTH 18000.00000 PRESENT OPERATION Drilling Ahead TIME 23:58:03 YESTERDAY 16000.00000 24 HOUR FOOTAGE 2000 CASING INFORMATION 95/8"@ 10440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 17955.36 92.38 298.46 3733.25 17857.10 92.81 297.60 3737.70 SURVEY DATA 17758.77 92.56 296.58 3752.31 17661.01 92.29 294.78 3746.44 17564.12 90.73 292.16 3749.00 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 518.1 @ 17725.00000 10.9 @ 16155.00000 263.9 307.37497 FT/HR SURFACE TORQUE 21220 @ 17398.00000 11768 @ 16649.00000 14809.7 15248.90137 AMPS WEIGHT ON BIT 25 @ 17135.00000 0 @ 17918.00000 9.6 7.19347 KLBS ROTARY RPM 123 @ 16653.00000 60 @ 17398.00000 118.6 120.40170 RPM PUMP PRESSURE 4117 @ 17968.00000 1946 @ 17469.00000 3887.1 3627.14136 PSI • DRILLING FLUIDS REPORT DEPTH 17808 MW 9.4 VIS PV 16 YP 17 FL 4.2 Gels 6/6/7 CL- 84500 FC -/1 SOL 9.45 SD N/A OIL 68/32 MBT N/A pH N/A Ca+ N/A CCI N/A MWD SUMMARY INTERVAL 10,444'TO 18000 TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 578 @ 16078.00000 5 @ 17472.00000 298.9 TRIP GAS CUTTING GAS 0 @ 18000.00000 0 @ 18000.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 84141 @ 16080.00000 805 @ 17472,00000 42587.3 CONNECTION GAS HIGH ETHANE(C-2) 893 @ 16080.00000 6 @ 17472.00000 376.2 AVG 280 PROPANE(C-3) 261 @ 16078.00000 2 @ 17472.00000 126.0 CURRENT 470 BUTANE(C-4) 371 @ 17185.00000 3 @ 17472.00000 180.6 CURRENT BACKGROUND/AVG 400 PENTANE(C-5) 254 @ 17182.00000 0 @ 16100.00000 100.7 HYDROCARBON 17500-18000 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 17500-18000 SANDSTONE/SAND 200- PRIMARILY TRANSPARENTS AND TRASNPARENTS WITH VERY LIGHT GRAY SMOKYE HUE;SOME WHITE AND WHITISH GRAY QUARTZ GRAINS • 562 SOME GRAYISH GREEN AND PALE GREEN GLAUCONITIC GRAINS;OCCASIONAL MODERATE PALE BLUE GREEN;DARK SCATTERED ASSORTED • LITHIC GRAINS;PRIMARILY QUARTZ COMPOSTION WITH 90%QUARTZ AND 10%LITHIC;UPPER VERY FINE TO LOWER FINE GRAINED WITH I SOME COURSE ROUNDED QUARTZ AS WELL AS RARE VERY ANGULAR COURSE GRAINS PRESENT;WELL TO VERY WELL SORTED;ROUND TO • • WELL ROUNDED;HIGH SPHERICITY;SAMPLE APPEARS TO BE LOOSE AND UNCONSOLIDATED HOWEVER SOME TRACE CEMENTED FRAGMENTS OF THE SANDSTONE MATRIX REMAIN INTACT;THE CEMENTED PORTIONS ARE SOFT TO EASILY FRIABLE SOME ARE FIRMLY FRIABLE IN PLACES;SILCA CEMENTATION WITH POSSIBLE AGRILLACEOUS CEMENTATION AND CONSOLIDATION IN PLACES;SOME GRAIN SUPPORT; l TRACE AMOUNTS OF LIGHT GRAY TO MEDIUM LIGHT GRAY SILSTONE;LARGE AMOUNTS OF CALCIUM CARBONATE DRILLING ADDITIVE;TRACE AMOUNTS OF AGGREGATED AND OCCASIONALLY CRYSTALINE PYRITE;TRACE OARNGE PINK TO PALE YELLOWISH OARNGE SOMETIMES VERY PALE OARNGE SHELL FRAGMENTS;ABUNDANT AMOUNTS OF FRACTURED COAL AND CARBONACEOUS MATERIAL;RESIDUAL SILT PARTICLES; GOOD VISIBLE POROSITY;SLIGHT PETROLEUM ODOR;ENTIRE SAMPLE EMITS A DULL WHITE TO WHITISH GREEN FLUORESCENE LITHOLOGY Sandstone/Sand/Siltstone PRESENT LITHOLOGY 99%Sandstone/Sand 1%Siltstone DAILY ACTIVITY SUMMARY Drilled from 16,000'to 18,000' . CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$4,095,RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 pJiRIc3 REPORT FOR Simpson/StoutBuchanan DATE May 31,2011 DEPTH 19900.00000 PRESENT OPERATION Drilling Ahead TIME 00:24:23 YESTERDAY 18000.00000 24 HOUR FOOTAGE 1900 CASING INFORMATION 95/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 19920.89 90.51 299.50 3672.94 19822.73 91.10 300.75 3674.32 SURVEY DATA 19724.44 91.18 300.66 3676.28 19625.96 94.29 302.45 3680.98 19527.70 94.18 301.83 3688.23 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC 043918 6x14 10,4444' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 698.2 @ 19110.00000 5.1 @ 18844.00000 257.5 285.40546 FT/HR • SURFACE TORQUE 22137 @ 19273.00000 12970 @ 18016.00000 16982.5 18240.27539 AMPS WEIGHT ON BIT 31 @ 18411.00000 0 @ 19198.00000 8.4 8.56627 KLBS ROTARY RPM 141 @ 18020.00000 63 @ 19613.00000 120.2 121.37316 RPM PUMP PRESSURE 4204 @ 18816.00000 3401 @ 19718.00000 4063.6 4181.69971 PSI DRILLING FLUIDS REPORT DEPTH 19687 MW 9.4 VIS N/A PV 15 YP 17 FL N/A Gels 6/7/7 CL- 83000 FC -/1 SOL 8.55 SD N/A OIL 68/32 MBT N/A pH N/A Ca+ N/A CCI N/A MWD SUMMARY INTERVAL 10,444'TO 19900 TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 538 @ 18089.00000 0 @ 19574.00000 281.3 TRIP GAS CUTTING GAS 0 @ 19900.00000 0 @ 19900.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 81020 @ 19863.00000 38 @ 19574.00000 45213.6 CONNECTION GAS HIGH ETHANE(C-2) 895 @ 19863.00000 0 @ 19574.00000 437.4 AVG 325 PROPANE(C-3) 291 @ 19863.00000 0 @ 19574.00000 164.0 CURRENT 219 BUTANE(C-4) 568 @ 18743.00000 0 @ 19574.00000 232.2 CURRENT BACKGROUND/AVG 375 • PENTANE(C-5) 508 @ 18741.00000 0 @ 19574.00000 136.6 HYDROCARBON 19,600,19,900' SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 19600-19800 Sandstone/Sand 130- PRIMARILY TRANSPARENTS AND TRASNPARENTS WITH VERY LIGHT GRAY SMOKY HUE;SOME WHITE AND WHITISH GRAY QUARTZ GRAINS 405u SOME GRAYISH GREEN AND PALE GREEN GLAUCONITIC GRAINS;OCCASIONAL MODERATE PALE BLUE GREEN;DARK SCATTERED ASSORTED LITHIC GRAINS;PRIMARILY QUARTZ COMPOSTION WITH 90%QUARTZ AND 10%LITHIC;UPPER VERY FINE TO LOWER FINE GRAINED WITH VERY LITTLE VARIATION IN THE SIZE AND SHAPE;VERY WELL SORTED ROUND TO WELL ROUND WITH HIGH SPHERICITY SAMPLE APPEARS TO BE LOOSE AND GENERALLY UNCONSOLIDATED HOWEVER SOME CEMENTED FRAGMENTS OF THE SANDSTONE MATRIX REMAIN INTACT;THE CEMENTED PORTIONS ARE SOFT TO EASILY FRIABLE SOME ARE FIRMLY FRIABLE IN PLACES;SILCA CEMENTATION WITH POSSIBLE AGRILLACEOUS CEMENTATION AND CONSOLIDATION IN PLACES;SOME GRAIN SUPPORT;TRACE AMOUNTS OF MEDIUM GRAY TO MEDIUM DARK GRAY SILSTONE WITH SMALL BLACK AND BROWN LAMINAE AS WELL AS SMALL CARBNACEOUS INCLUSIONS;VERY TRACE MINUTE RESIDUAL AMOUNTS OF A VERY PALE OARNGE SILSTONE WITH CARBONACEOUS INCLUSIONS;LARGE AMOUNTS OF CALCIUM CARBONATE DRILLING ADDITIVE TRACE AMOUNTS OF SHELL FRAGMENTS BECOMING LESS APPARENT;TRACE PYRITE AND MICA;THE SAND AND SANDSTONE HAS EXCELLENT VISUAL POROSITY;A MODERATE PETROLEUM ODOR IS DETECTABLE;MINUTE AMOUNTS OF LIGHT BROWN OIL STAINED QUARTZ GRAINS;THE ENTIRE SAMPLE EMITS A WHITISH GREEN FLUORESCNCE LITHOLOGY Sandstone/Sand/Siltstone PRESENT LITHOLOGY 99%Sandstone/Sand 1%Siltstone DAILY ACTIVITY SUMMARY Drilled from 18,000'-19,900' CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3,625,RIGWATCH$1,200 REPORT BY Daniel Sherwood • ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CAINIRAG REPORT FOR Simpson/Stout/Buchanan DATE May 31,2011 DEPTH 21339.00000 PRESENT OPERATION Circulating TIME 23:59:02 YESTERDAY 19900.00000 24 HOUR FOOTAGE 1439 CASING INFORMATION 9 5/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 21279.27 88.73 293.76 3671.74 SURVEY DATA 21200.83 88.84 293.09 3670.08 21102.06 90.67 294.23 3669.66 21003.41 92.87 294.62 3672.71 20905.24 93.21 294.87 3677.91 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 10,4444' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 467.1 @ 20577.00000 14.8 @ 20921.00000 235.8 214.32286 FT/HR SURFACE TORQUE 23351 @ 20889.00000 14591 @ 21167.00000 186122 17579.53906 AMPS WEIGHT ON BIT 22 @ 20773.00000 0 @ 20193.00000 9.9 5.60455 KLBS ROTARY RPM 123 @ 21215.00000 78 @ 20944.00000 119.7 117.38648 RPM PUMP PRESSURE 4224 @ 20097.00000 3618 @ 19914.00000 4100.7 4132.26855 PSI DRILLING FLUIDS REPORT DEPTH 21264 MW 9.4 VIS . N/A PV 12 YP 16 FL 4.4 Gels 5/6/7 CL- 82000 FC -/1 SOL 9.15 SD N/A OIL 69/31 MBT N/A pH N/A Ca+ N/A CCI N/A MWD SUMMARY INTERVAL 10,444'TO 21,308' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 • GAS SUMMARY(units) HIGH LOW AVERAGE '',, DITCH GAS 450 @ 19967.00000 6 @ 20921.00000 193.3 TRIP GAS li CUTTING GAS 0 @ 21339.00000 0 @ 21339.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 77619 @ 19967.00000 1479 @ 20921.00000 37292.1 CONNECTION GAS HIGH ETHANE(C-2) 876 @ 19967.00000 14 @ 20921.00000 381.9 AVG 200 PROPANE(C-3) 413 @ 20148.00000 5 @ 20921.00000 153.5 CURRENT 11 BUTANE(C-4) 767 @ 20148.00000 7 @ 20921.00000 208.5 CURRENT BACKGROUND/AVG 250 PENTANE(C-5) 611 @ 20148.00000 4 @ 20921.00000 130.7 • HYDROCARBON Exited top of OA sand @ 20,145'due to fault and returned at 20,362'description below is of the departure. SHOWS • INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 20150-20280 SAND/SANDSTONE/ 22- TRANSPARENTS AND TRASLUCENTS WITH SMOKEY WHITE GRAY HUE AND GRAYISH OARNGE HUE;PRIMARILY QUARTZ WITH 85%QUARTZ SILSTONE 182u AND 15%LITHICS;PRIMARILY VERY FINE TO LOWER FINE GRAINED SOME MEDIUM AND COURSE GRAINS ARE PRESENT;MODERATLEY SORTED;ROUND TO SUB ROUND;MODERATE SPHERICITY;EASILY FRIABLE TO FRIABLE;GOOD AMOUNTS OF MEDIUM GRAY TO MEDIUM DARK GRAY VERY ARENACEOUS SILSTONE GRADING TO SANDSTONE IN SOME PLACES;GOOD QUANTITIES OF SHELL FRAGMENTS; ABUNDANT DARK YELLOWISH OARNGE SILT;LARGE QUANTITIES OF CALCIUM CARBONATE DRILLING ADDITIVE;MODERATE TO POOR VISIBLE POROSITY;TRACE AMOUNTS OF OIL STAINED QUARTZ;VERY FAINT PETROULEUM ODOR;ENTIRE SAMPLE EMITS A WHITISH GREEN FLUORESCENCE LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY 95%SAND/SANDSTONE 5%SILSTONE DAILY ACTIVITY SUMMARY Drill from 19,900 to TD of 21,340' CANRIG PERSONNEL ON BOARD 4 DAILY COST$3,625,RIGWATCH$1,200 REPORT BY Daniel Sherwood I I ENI PETROLEUM DAILY WELLSITE REPORT OP14-53 c4A1RIG REPORT FOR Simpson/Wimmer/Buchanan DATE Jun 01,2011 DEPTH 21340.00000 PRESENT OPERATION BROOH TIME 23:59:00 YESTERDAY 21340.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 95/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 21340.00 88.72 293.78 3671.81 SURVEY DATA 2127927 88.72 293.78 3670.45 21200.83 88.81 293.30 3668.76 21102.06 90.67 294.30 3668.31 21003.41 92.91 294.65 3671.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6,14 10,4444' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 21,340' MW 9.4 VIS N/A PV 14 YP 14 FL N/A Gels 5/6/6 CL- 84000 FC -/1 SOL 11.5 SD N/A OIL 69/31 MBT N/A pH N/A Ca+ N/A CCI N/A MWD SUMMARY INTERVAL 10.444 TO 21,308' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 28 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY 95%SAND/SANDSTONE 5%SILSTONE DAILY ACTIVITY SUMMARY CBU racking one stnd in derrick every btms up to 20,182'.BROOH to 19,001'. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3,560,RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT OP14-53 cAIItJRIG REPORT FOR Simpson/Wimmer/Buchanan DATE Jun 02,2011 DEPTH 21340.00000 PRESENT OPERATION BROOH TIME 23:59:00 YESTERDAY 21340.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 21340.00 88.72 293.78 3671.81 21279.27 88.72 293.78 3670.45 SURVEY DATA 21200.83 88.81 293.30 3668.76 21102.06 90.67 294.30 3668.31 21003.41 92.91 294.65 3671.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 10,4444' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 21,340' MW 9.4 VIS N/A PV 15 YP 15 FL N/A Gels 5/6/6 CL- 80000 FC -/1 SOL 8.67 SD N/A OIL 68/32 MBT N/A pH N/A Ca+ N/A CCI N/A MWD SUMMARY INTERVAL 10.444 TO 21,308' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 43 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG 4 PROPANE(C-3) @ @ CURRENT 8 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 8 PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY 95%SAND/SANDSTONE 5%SILSTONE DAILY ACTIVITY SUMMARY BROOH from 19,001'-11,329'. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3,560,RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT - OP14-S3 CANRIG REPORT FOR Simpson/Wimmer/Buchanan DATE Jun 03,2011 DEPTH 21340.00000 PRESENT OPERATION POOH TIME 23:59:00 YESTERDAY 21340.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 21340.00 88.72 293.78 3671.81 21279.27 88.72 293.78 3670.45 SURVEY DATA 21200.83 88.81 293.30 3668.76 21102.06 90.67 294.30 3668.31 21003.41 92.91 294.65 3671.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 10,4444' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 21,340' MW 9.4 VIS N/A PV 15 YP 13 FL 3.9 Gels 5/5/6 CL- 84000 FC -/1 SOL 12 SD N/A OIL 69/31 MBT N/A pH N/A Ca-I- N/A CCI N/A MWD SUMMARY INTERVAL 10.444 TO 21,308' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 81 CUTTING GAS @ @ WIPER GAS 4110 CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG 8 PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY 95%SAND/SANDSTONE 5%SILSTONE DAILY ACTIVITY SUMMARY Continue to BROOH,at casing shoe circ btms up 7x,pump slug and POOH. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3,560,RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORCAN1RIG OP14-S3 REPORT FOR Keener/Goerlich/Buchanan DATE May 08,2011 DEPTH 2338.00000 PRESENT OPERATION RIH Casing TIME 24:00:00 YESTERDAY 1926.00000 24 HOUR FOOTAGE 412 CASING INFORMATION 20"@160' •, DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2037.37 30.99 315.93 1926.72 2132.25 33.45 319.01 2006.99 SURVEY DATA 2225.94 35.68 323.34 2110.93 2259.12 36.65 324.33 2110.93 2338.00 36.65 324.33 2174.22 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16 Hughes MX-1 5191523 3520,1516 160 2338 2178 19:40 1,1,WT,A,E,I,NO TD •' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 399.3 @ 2263.00000 32.0 @ 1979.00000 172.1 105.83702 FT/HR SURFACE TORQUE 19629 @ 2059.00000 0 @ 2284.00000 2182.5 4963.10596 AMPS WEIGHT ON BIT 40 @ 2070.00000 0 @ 2229.00000 14.7 18.93181 KLBS ROTARY RPM 59 @ 2318.00000 0 @ 2149.00000 20.6 58.87287 RPM PUMP PRESSURE 1802 @ 2329.00000 870 @ 1948.00000 1222.1 1674.25281 PSI DRILLING FLUIDS REPORT DEPTH 2338 MW 9.2 VIS 100 PV 23 YP 21 FL 5 Gels 17/24/38 CL- - FC 2/- SOL 6.4 SD 0.1 OIL -/94 MBT 27 pH 9.0 Ca+ 100 CCI 2100 MWD SUMMARY INTERVAL 160 TO 2338 TOOLS GyroPulse,PowerPulse GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 58 @ 2104.00000 0 @ 2156.00000 25.4 TRIP GAS CUTTING GAS 0 @ 2338.00000 0 @ 2338.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 11320 @ 2104.00000 87 @ 2156.00000 4714.3 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 2338.00000 0 @ 2338.00000 0.0 AVG PROPANE(C-3) 0 @ 2338.00000 0 @ 2338.00000 0.0 CURRENT BUTANE(C-4) 0 @ 2338.00000 0 @ 2338.00000 0.0 CURRENT BACKGROUND/AVG PENTANE(C-5) 0 @ 2338.00000 0 @ 2338.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Cutting sampling will begin after surface casing. PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Slide drilling to TD @ 233872174'TVD.Circulate and condition hole 4X BU.Backream to 499'.LD BHA.Rig up to run 13.75"casing. CANRIG PERSONNEL ON BOARD 2 DAILY COST$3630 REPORT BY J.McBeth ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 41JIIc3 REPORT FOR Simpson/Wimmer/Buchanan DATE Jun 04,2011 DEPTH 21340.00000 PRESENT OPERATION RIH w/5.5"Liner TIME 23:59:00 YESTERDAY 21340.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 21340.00 88.72 293.78 3671.81 SURVEY DATA 21279.27 88.72 293.78 3670.45 21200.83 88.81 293.30 3668.76 21102.06 90.67 294.30 3668.31 21003.41 92.91 294.65 3671.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 10,4444' 21340 10896 70.6 1-1-WT-A-X-I-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 21,340' MW 9.45 VIS N/A PV 15 YP 14 FL N/A Gels 6/6/7 CL- 79000 FC -/1 SOL 9.19 SD N/A OIL 69/31 MBT N/A pH N/A Ca-I. N/A CCI N/A MWD SUMMARY INTERVAL 10.444 TO 21,308' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY 95%SAND/SANDSTONE 5%SILSTONE DAILY ACTIVITY SUMMARY Continue to POOH,L/D BHA,RIH w/4,100'%DP to clear WEI subs.S/C D/L.POOH removing WEI subs and racking back in derrick.Prepare to run 5.5"Iiner.RIH w/Liner to 2,553'. CANRIG PERSONNEL ON BOARD 4 DAILY COST$3,560,RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 4JJRK3 REPORT FOR Simpson/Wimmer/Buchanan DATE Jun 05,2011 DEPTH 21340.00000 PRESENT OPERATION RIH w/5.5"Liner on 4.5"DP TIME 23:59•00 YESTERDAY 21340.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 10,440' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 21340.00 88.72 29378 3671.81 SURVEY DATA 21279.27 88.72 293.78 3670.45 21200.83 88.81 293.30 3668.76 21102.06 90.67 294.30 3668.31 21003.41 92.91 294.65 3671.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 10,4444' 21340 10896 70.6 1-1-WT-A-X-I-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/FIR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 21,340' MW 9.5 VIS N/A PV 15 YP 15 FL N/A Gels 6/7,7 CL- 79000 FC N/A SOL 9.19 SD N/A OIL 69/31 MBT N/A pH N/A Caa N/A CCI N/A MWD SUMMARY INTERVAL 10.444 TO 21,308' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY 95%SAND/SANDSTONE 5%SILSTONE DAILY ACTIVITY SUMMARY RIH with 5.5"liner to 10,970'M/U liner setting sleeve.RIH with 5.5"slotted liner on 4.5"DP to current depth of 18,374'. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2,620 RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM I DAILY WELLSITE REPORT OP14-S3 C, I\iFIG REPORT FOR Simpson/Wimmer/Buchanan DATE Jun 06,2011 DEPTH 21340.00000 PRESENT OPERATION RIH TIME 23:59:00 YESTERDAY 21340.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 95/8"@ 10440'5.5"@21,135' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 21340.00 88.72 293.78 3671.81 SURVEY DATA 21279.27 88.72 293.78 3670.45 21200.83 88.81 293.30 3668.76 21102.06 90.67 294.30 3668.31 21003.41 92.91 294.65 3671.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED • 4 8.75 Hycalog PDC E43918 6x14 10,4444' 21340 10896 70.6 1-1-WT-A-X-I-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 21,340' MW 9.1 VIS N/A PV N/A YP N/A FL N/A Gels N/A CL- N/A • FC N/A SOL N/A SD N/A OIL N/A MBT N/A pH N/A Ca+ N/A CCI N/A MWD SUMMARY INTERVAL 10.444 TO 21,308' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A ' PROPANE(C-3) @ @ CURRENT N/A ' BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY 95%SAND/SANDSTONE 5%SILSTONE DAILY ACTIVITY Cont to RIH w/5.5"slotted liner on DP.set liner hanger @ 10,198'.Drop ball and pump to 2300 PSI to set packer.Press test annular,Pull 225K and setting tool would not release.Shear SUMMARY and rack back one stnd.Displace OBM w/9.1 ppg brine.POOH UD D/P,UD BHA and RIH preparing to L/D. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML$2,620 RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CANRIG REPORT FOR Simpson/Wimmer/Buchanan DATE Jun 07,2011 DEPTH 21340.00000 PRESENT OPERATION LID DP/DP Managment TIME 23:59:00 YESTERDAY 21340.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 95/8"@ 10,440'5.5"@21,135' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 21340.00 88.72 293.78 3671.81 21279.27 88.72 293.78 3670.45 SURVEY DATA 21200.83 88.81 293.30 3668.76 21102.06 90.67 294.30 3668.31 21003.41 92.91 294.65 3671.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 10,4444' 21340 10896 70.6 1-1-WT-A-X-I-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 21,340' MW 9.05 VIS N/A PV N/A VP N/A FL N/A Gels N/A CL- N/A FC N/A SOL N/A SD N/A OIL N/A MBT N/A pH N/A Ca. N/A CCI N/A MWD SUMMARY INTERVAL 10.444 TO 21,308' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY 95%SAND/SANDSTONE 5%SILSTONE DAILY ACTIVITY RIH w/32 stnds 4.5 DP circ pipe clean,POOH L/D DP.LID mule shoe.RIH to 7089'withf 5"DP removing WEI subs.Circ DP clean and POOH L/D 5"DP to 3,671'.Repair iron SUMMARY rougneck. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML$2,620 RIGWATCH$1,200 REPORT BY Daniel Sherwood ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 cAIJIG REPORT FOR Simpson/Wimmer/Buchanan DATE Jun 08,2011 DEPTH 21340.00000 PRESENT OPERATION P/U Baker Comp Pump Assy TIME 23:59:00 YESTERDAY 21340.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 10,440'5.5"@21,135' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 21340.00 88.72 293.78 3671.81 SURVEY DATA 21279.27 88.72 293.78 3670.45 21200.83 88.81 293.30 3668.76 21102.06 90.67 294.30 3668.31 21003.41 92.91 294.65 3671.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.75 Hycalog PDC E43918 6x14 10,4444' 21340 10896 70.6 1-1-WT-A-X-I-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 21,340' MW 9.05 VIS N/A PV N/A VP N/A FL N/A Gels N/A CL- N/A FC N/A SOL N/A SD N/A OIL N/A MBT N/A pH N/A Ca+ N/A CCI N/A MWD SUMMARY INTERVAL 10.444 TO 21,308' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY 95%SAND/SANDSTONE 5%SILSTONE DAILY ACTIVITY SUMMARY Test BOP's,R/U GBR,R/U Baker Centertift,R/U Halliburton slickline,P/U Baker pump assy and test.R/U ESP control lines. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML$2,580 RIGWATCH$1,200 REPORT BY Daniel Sherwood • ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CANRIG REPORT FOR DATE June 9,2011 DEPTH 21340 PRESENT OPERATION N/D BOP's TIME 23:59:00 YESTERDAY 21340 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 10,440 5.5"@21,135' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 21340 MW 9.0 VIS N/A PV N/A YP N/A FL N/A Gels N/A CL- N/A FC N/A SOL N/A SD N/A OIL N/A MBT N/A pH N/A Ca+ N/A CCI N/A MWD SUMMARY INTERVAL 10.444 TO 21,308' TOOLS Xceed 6750,MN ILS STAB,TELESCOPE,PERISCOPE,ADN6 GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG N/A PROPANE(C-3) @ @ CURRENT N/A BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Siltstone PRESENT LITHOLOGY 95%SAND/SANDSTONE 5%SILSTONE DAILY ACTIVITY Hang control line sheave,RIH w/4.5"tubing to 505'repair spooling unit breaker.Cont to RIH with tubing testing ESP cable every 1000'to 7,774'.R/U compensator P/U 2 VIT jts.P/U landing SUMMARY jnt,M/U hanger,M/U penetrator.Make penetrator splice,hook up cap line and test ESP cable.Install wellheads and land tubing hanger.Test upper and lower seals to 5000 psi.L/D landing joint. N/D BOP's blow down lines and N/D choke. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML$2,580 RIGWATCH$1,200 REPORT BY Daniel Sherwood • • • ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CANRIG REPORT FOR Keener/Goerlich/Buchanan DATE May 09,2011 DEPTH 2338.00000 PRESENT OPERATION Nipple Up BOPs TIME 24:00:00 YESTERDAY 2338.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2324' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2259.12 36.65 324.33 2110.93 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 2324' MW 9.2 VIS 54 PV 14 YP 13 FL 5.2 Gels 9/10/12 CL- - FC 2/- SOL 5.8 SD - OIL -/94 MST 25 pH 9.0 Ca+ 110 CCI 1900 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 2338 0 @ 2338 0 TRIP GAS 10 CUTTING GAS 0 @ 2338.00000 0 @ 2338.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Cont RIH Casing.Landed Casing at 2284'MD.M/U Landing joint and hanger,land casing @ 2324'.Circulate and reciprocate casing.Pump cement job.Nipple up BOP stack. CANRIG PERSONNEL ON BOARD 2 DAILY COST 3830 REPORT BY J.McBeth ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 cANRIG REPORT FOR Keener/Goelich/Buchanan DATE May 10,2011 DEPTH 2338.00000 PRESENT OPERATION Drill shoe track TIME 24:00:00 YESTERDAY 2338.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2326' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2259.12 36.65 324.33 2110.93 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12.25 Hughes QD605XX PDC 7024093 0 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 2324' MW 9.2 VIS 46 PV 8 YP 19 FL 6.7 Gels 7/7/8 CL- - FC 1/- SQL 3 SD - OIL 2/95 MBT - pH 10 Ca.). 100 CCI 850 MWD SUMMARY INTERVAL 2338'TO TOOLS Xceed 900,ARC 825,NM ILS Stab,Telescope. GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY P/U and test tools and test BOP.P/U BHA and RIH to 1055'and run shallow tool test.Cont RIH to 2107'and wash down to 2227'and tag plug.Drill shoe track. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3545;Rigwatch$1250 REPORT BY J.McBeth ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 REPORT FOR Keener/Goerlich/Buchanan c .I6IJJRI3 DATE May 11,2011 DEPTH 3010.00000 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 2338.00000 24 HOUR FOOTAGE 672 CASING INFORMATION 20"@ 160' 13 3/8"@ 2236' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2609.54 39.8 337.51 2388.71 SURVEY DATA 2705.42 41.92 341.49 2461.23 2800.24 44.91 346.15 2530.12 2896.84 48.13 351.91 2596.61 2992.22 51.16 354.09 2658.37 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12.25 Hughes QDD605XX PDC 7024093 2338 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 358.5 @ 2687.00000 6,5 @ 2656.00000 168.9 168.90936 FT/HR SURFACE TORQUE 9315 @ 2987.00000 1456 @ 2665.00000 3793.6 4358.09521 AMPS WEIGHT ON BIT 18 @ 2872.00000 0 @ 2400.00000 4.0 5.27371 KLBS ROTARY RPM 122 @ 2784.00000 53 @ 2997.00000 96.6 55.64316 RPM PUMP PRESSURE 1439 @ 3008.00000 644 @ 2339.00000 1149.0 1380.54517 PSI DRILLING FLUIDS REPORT DEPTH 2993' MW 9.2 VIS 49 PV 11 YP 27 FL 6 Gels 12/15/16 CL- - FC 1/- SOL 3 SD - OIL 2/95 MBT 3.75 pH 10 Ca+ 80 CCI 800 MWD SUMMARY INTERVAL 2338'TO 3010' TOOLS Xceed 900,ARC 825,NM ILS Stab,Telescope. GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 24 @ 2718.00000 0 @ 2362.00000 8.3 TRIP GAS CUTTING GAS 0 @ 3010.00000 0 @ 3010.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 18314 @ 2697.00000 19 @ 2362.00000 1991.0 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 3010.00000 0 @ 3010.00000 0.0 AVG PROPANE(C-3) 0 @ 3010.00000 0 @ 3010.00000 0.0 CURRENT 7 BUTANE(C-4) 0 @ 3010.00000 0 @ 3010.00000 0.0 CURRENT BACKGROUND/AVG 7 PENTANE(C-5) 0 @ 3010.00000 0 @ 3010.30000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand,Conglomeritic Sand,Shale,Claystone PRESENT LITHOLOGY 100%Sand DAILY ACTIVITY SUMMARY Cont drilling shoe track.Displace Spud mud with LSND.Perform FIT with 12.5 EMW.Cont drilling ahead CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3545;Rigwatch$1200 REPORT BY J.McBeth ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CANRIG REPORT FOR Keener/Goerlich/Buchanan DATE May 12,2011 DEPTH 5051.00000 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 301020000 24 HOUR FOOTAGE 2041 CASING INFORMATION 20"@ 160'13 3/8"@ 2236' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4619.51 81.86 10.18 3129.07 SURVEY DATA 4715.29 81.77 10.17 3142.71 4811.27 81.71 9.78 3156.5 4905.48 82 9.12 3169.84 5001.03 81.88 9.12 3183.24 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12.25 Hughes ODD605XX PDC 7024093 2338 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 309.8 @ 4235.00000 8.6 @ 3033.00000 155.1 33.24932 FT/HR SURFACE TORQUE 8897 @ 3076.00000 1891 @ 3020.00000 4993.7 5106.60205 AMPS WEIGHT ON BIT 32 @ 3255.00000 0 @ 4605.00000 6.2 8.05874 KLBS ROTARY RPM 122 @ 3069.00000 53 @ 3028.00000 110.0 6173453 RPM PUMP PRESSURE 1749 @ 4995.00000 964 @ 3187.00000 14872 1708.23633 PSI DRILLING FLUIDS REPORT DEPTH 4963' MW 9.3 VIS 54 PV 13 YP 31 FL 4.6 Gels 15/21/- CL- - FC 1/- SOL 4.7 SD 0.05 OIL 3/92 MBT 11 pH 9.3 Ca+ 80 CCI MWD SUMMARY INTERVAL 2338'TO 5051' TOOLS Xceed 900,ARC 825,NM ILS Stab,Telescope GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 82 @ 4832.00000 0 @ 4943.00000 15.1 TRIP GAS CUTTING GAS 0 @ 5051.00000 0 @ 505120000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 16647 @ 4832.00000 37 @ 3733.00000 2674.7 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 5051.00000 0 @ 5051.00000 0,0 AVG 15 PROPANE(C-3) 0 @ 5051.00000 0 @ 5051.00000 0.0 CURRENT 4 BUTANE(C-4) 0 @ 5051.00000 0 @ 5051.00000 0.0 CURRENT BACKGROUND/AVG 4 PENTANE(C-5) 0 @ 5051.00000 0 @ 5051.00000 0.0 HYDROCARBON 4620'-5050' SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 4820'-5050' Sand/Claystone 4-83 NO PETROLEUM ODOR;TRACE AMOUNT OF VERY LIGHT BROWN STAINING;FAINT DULL WHITE TO YELLOW FLUORESCENCE OVER 30%OF units SAMPLE;DULL TRANSLUCENT WHITE-GREEN CUT FLUORESCENCE WITH FAINT WHITE TO YELLOW STREAMERS;CLEAR TO PALE STRAW VISIBLE CUT;NO VISIBLE RESIDUE;FAINT WHITE-YELLOW RESIDUAL FLUORESCENCE. LI THOLOGY Sand,Claystone,Sandstone,Conglomeritic Sand,Coal,Shale PRESENT LITHOLOGY 90%Sand,10%Claystone DAILY ACTIVITY SUMMARY Cont.Grilling ahead CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3545;Rigwatch$1200 REPORT BY J.McBeth ENI PETROLEUM DAILY WELLSITE REPORT COP14-S3 IRIG REPORT FOR Keener/Goerlich/Buchanan DATE May 13,2011 DEPTH 6050.00000 PRESENT OPERATION Tripping out due to tools TIME 24:00:00 YESTERDAY 5051.00000 24 HOUR FOOTAGE 999 CASING INFORMATION 20"@ 160'13 3/8"@ 2236' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5576.01 81.68 9.64 3264.6 SURVEY DATA 5671.17 81.3 10.24 3278.68 5766.99 80.56 10.39 3293.78 5862.95 79,54 11.03 3310.36 5958.14 78.38 11.76 3328.59 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12.25 Hughes 000605XX PDC 7024093 2338 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 339.4 @ 5552.00000 2.7 @ 5999.00000 101.1 133.78537 FT/HR SURFACE TORQUE 12808 @ 6021.00000 3870 @ 5214.00000 6763.5 7699.94287 AMPS WEIGHT ON BIT 20 @ 6018.00000 0 @ 5721.00000 4.5 0.61664 KLBS ROTARY RPM 119 @ 5935.00000 52 @ 5215.00000 80.5 79.45267 RPM PUMP PRESSURE 1848 @ 5561.00000 1182 @ 5267.00000 1749.2 1787.57678 PSI DRILLING FLUIDS REPORT DEPTH 6010 MW 9.2 VIS 49 PV 12 VP 24 FL 4.8 Gels 12/19/22 CL- 22 FC 1/- SOL 4.4 SD - OIL 3/93 MBT 12.5 pH 9.8 Ca+ 40 CCI 1450 MWD SUMMARY INTERVAL 2338'TO 6050' TOOLS Xceed 900,ARC 825,NM ILS Stab,Telescope GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 84 @ 5407.00000 0 @ 5150.00000 13.6 TRIP GAS CUTTING GAS 0 @ 6050.00000 0 @ 6050.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 15989 @ 5407.00000 18 @ 5150.00000 2550.1 CONNECTION GAS HIGH ETHANE(C-2) 5 @ 6046.00000 0 @ 6036.00000 0.1 AVG 13 PROPANE(C-3) 4 @ 6046.00000 0 @ 6036.00000 0.1 CURRENT 0 BUTANE(C-4) 0 @ 6050.00000 0 @ 6050.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 6050.00000 0 @ 6050.00000 0.0 HYDROCARBON 5950-6050 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 5950-6050' Sand 2-18 NO PETROLEUM ODOR;<10%SAND HAS LIGHT BROWN STAINING;TRACE AMOUNT OF FAINT WHITE TO YELLOW FLUORESCENCE; units STREAMING DULL TO FAINT WHITE TO YELLOW CUT FLUORESCENCE;CLEAR TO PALE STRAW CUT;NO RESIDUE;FAINT YELLOW TO ORANGE RESIDUE FLUORESCENCE. LITHOLOGY Sand,Sandstone,Claystone,Carbonaceous Shale,Coal PRESENT LITHOLOGY Sand DAILY ACTIVITY SUMMARY Cont.drilling ahead,encountered hard zones @ 5072'-5326'and 5990'-6021'.Troubleshooting and trip for directional tools. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3545;Rigwatch$1200 REPORT BY J.McBeth ENI PETROLEUM DAILY WELLSITE REPORT OP14-S3 CANRIG REPORT FOR Keener/Goerlich/Buchanan DATE May 14,2011 DEPTH 6067.00000 PRESENT OPERATION RIH TIME 24:00 YESTERDAY 6050.00000 24 HOUR FOOTAGE 17 CASING INFORMATION 133/8 @ 2324 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25 Hycalog PDC E143367 6067 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 261.0 @ 6057.00000 131.5 @ 6051.00000 207.1 169.15842 FT/HR SURFACE TORQUE 10237 @ 6067.00000 5916 @ 6054.00000 8478.2 10237.55859 AMPS WEIGHT ON BIT 5 @ 6059.00000 0 @ 6064.00000 2.4 5.48731 KLBS ROTARY RPM 79 @ 6052.00000 61 @ 6054.00000 69.6 61.61288 RPM PUMP PRESSURE 1835 @ 6064.00000 1753 @ 6062.00000 1898.1 1807.09558 PSI DRILLING FLUIDS REPORT DEPTH 6067 MW 9.3 VIS 53 PV 12 VP 31 FL 4.2 Gels 13/22/25 CL- 1500 FC 1/- SOL 4.5 SD OIL 3/93 MBT 15 pH 10 Ca+ 50 CCI MWD SUMMARY INTERVAL 2338 TO 6050 TOOLS Xceed 900,ARC 825,NM ILS Stab,Telescope GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 11 @ 6054.00000 5 @ 6053.00000 8.7 TRIP GAS CUTTING GAS 0 @ 6067.00000 0 @ 6067.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) 0 @ 6067.00000 0 @ 6067.00000 0.0 CONNECTION GAS HIGH ETHANE(C-2) 0 @ 6067.00000 0 @ 6067.00000 0.0 AVG 8 PROPANE(C-3) 0 @ 6067.00000 0 @ 6067.00000 0.0 CURRENT 0 BUTANE(C-4) 0 © 6067.00000 0 @ 6067.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 6067.00000 0 @ 6067.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand PRESENT LITHOLOGY 100%Sand DAILY ACTIVITY SUMMARY Drill to 6067'and POOH due to MWD failure,LID BHA,Repair Bit Breaker,P/U New BHA,RIH CANRIG PERSONNEL ON BOARD 4 DAILY COST$3545, Rigwatch$1200 REPORT BY Daniel Sherwood • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. 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