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Home My WebLink About211-037CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: WNS CD3-128 (PTD #211-037-0) Gas injection monitor period Date:Thursday, June 1, 2023 1:14:13 PM Attachments:image001.png From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, June 1, 2023 11:39 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: WNS CD3-128 (PTD #211-037-0) Gas injection monitor period Chris, CRU CD3-128 (PTD #211-037-0) extended 30 day monitor ends tomorrow. The well has stabilized and shows integrity. CPAI will submit necessary documents to cancel AA AIO 18C.009. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: WNS Integrity Sent: Thursday, April 27, 2023 3:09 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com> Subject: RE: WNS CD3-128 (PTD #211-037-0) Gas injection monitor period Chris, CRU CD3-128 (PTD #211-037-0) is showing high IA while on gas. CPAI plans to bleed the well and extend the 30 day monitor to prove well integrity. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: Well Integrity Specialist CPF2 Sent: Wednesday, March 29, 2023 8:00 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com> Subject: WNS CD3-128 (PTD #211-037-0) Gas injection monitor period Chris- WNS injector CD3-128 (PTD #211-037-0) recently had a rig work over completed to mitigate the known TxIA communication while on gas injection. CPAI intends to return the well to gas injection for 30 days to verify the RWO mitigated the known TxIA communication. If TxIA integrity is proven while on gas injection AIO 18C.009 will be canceled and the well will be returned to normal injection status. Attached is the current post RWO well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: WNS CD3-128 (PTD #211-037-0) Gas injection monitor period Date:Thursday, April 27, 2023 3:10:53 PM Attachments:image001.png From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, April 27, 2023 3:09 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com> Subject: RE: WNS CD3-128 (PTD #211-037-0) Gas injection monitor period Chris, CRU CD3-128 (PTD #211-037-0) is showing high IA while on gas. CPAI plans to bleed the well and extend the 30 day monitor to prove well integrity. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: Well Integrity Specialist CPF2 Sent: Wednesday, March 29, 2023 8:00 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com> Subject: WNS CD3-128 (PTD #211-037-0) Gas injection monitor period Chris- WNS injector CD3-128 (PTD #211-037-0) recently had a rig work over completed to mitigate the known TxIA communication while on gas injection. CPAI intends to return the well to gas injection for 30 days to verify the RWO mitigated the known TxIA communication. If TxIA integrity is proven while on gas injection AIO 18C.009 will be canceled and the well will be returned to normal injection status. Attached is the current post RWO well bore schematic. Please let me know if you have any questions or disagree with the plan. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD3-128 COLVILLE RIV UNIT CD3-128 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/12/2023 CD3-128 50-103-20638-00-00 211-037-0 G SPT 6745 2110370 1686 3744 3745 3745 3745 854 960 959 960 INITAL P Austin McLeod 4/12/2023 MITIA after RWO. On gas for 30 day monitor for possible AA cancellation of AIO 18C.009. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD3-128 Inspection Date: Tubing OA Packer Depth 1180 2500 2460 2450IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230412184516 BBL Pumped:2 BBL Returned:2.2 Friday, May 12, 2023 Page 1 of 1           STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED By Kayla Junke at 3:12 pm, Apr 12, 2023 1. Operations Susp Well Insp ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Install Whipstock ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Mod Artificial Lift 17 Perforate New Pool ❑ Repair Well 0 Coiled Tubing Ops❑ Other: Replace Tubing 0 2. Operator Name 4. WeII Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Explorator�❑ Stratigraphic ❑ ServiceR 211-037 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99610 50-403-20638-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL25538, ADL372105 CRU CD3-128 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Alpine Oil Pool (COW 0610612523) N/A Colville River Field/ ' 11. Present Well Condition Summary: Total Depth measured 20387' feet Plugs measured 12353' feet true vertical 7083' feet Junk measured None feet Effective Depth measured 12822' feet Packer measured 12311', 12596' feet true vertical 6948' feet true vertical 6745', 6876' feet Casing Length Size MD ND Burst Collapse Conductor 77' 16" 114' 114' Surface 2953' 9-5/81, 2989' 2451' Production 12976' 7" 13009' 7083' Liner 5990, 4-1/2" 18685' 7062' Open Hole 1702' 6-1/81, 20387' 7083' Perforation depth Measured depth 12476-12496', Alternating 4.78' Pert Pups 13217-18637' True Vertical depth 6824-6833', Alternating 4.78' Pert Pups 6691-7062' Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 12739' 6926' Packers and SSSV (type, measured and true vertical depth) Packers: Baker Premier Packer 123111, 12596' 6745', 6876' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1 0 2000 938 2550 Subsequent to operation: 0 1 1964 0 1212 3738 13b. Pools active after work: 14. Attachments (required per 20 AAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations 71 Exploratory ❑ Development ❑ Servicep Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG p GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 323-041 (CDW 06/06/2023) Digitally signed by Adam Klem Adam Klem Date.2023.04.1214.14.04 Authorized Name and -08'00' Digital Signature with Date: Contact Name: Adam Klem Contact Email: dam.klemnconocoohillios.com Authorized Title: Staff RWO/CTD Engineer Contact Phone: (907) 263-4529 Sr Pet Eng: ISr Pet Geo: I JSr Res Eng: DSR-4/13/2J COW 06/06/2023 RBDMS JSB N1323 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov U Un C N_ p_ O. O1 L_ O) N W M N O — O. ° u a J 3 m .(u c m 0LU E a) ° Z r C @ a) N 2 0 L @ p a) F i0 r � L-. 00 N 'O C Oi a) in 'y Q O N Q O N m C 3 0 N 3 @ N= i0 O_ N o �^ 'LO' Q 2 2 a' O N �0., Y m (n C-iLp n Ln L� wO� ��~� �� c N N N V ,-, 3 5 N m M 0 y.0> d d YZ 0 4) d' N '6 LL' Q OY (D (V MO a@ N 3y mo �d a` m0 (L)— J� d-0 dm wm U 0 @ @mod em 4) n rn� wyi°KdQ p c� d @ m `..� a) O m U— O�LL ain'0 . co _OJ m Y a) CL W 0@@ � p_Y2a) C LL J O — O O_ O LO 0 J N -0a) U LL C UN NW C, M� M M 040NCm — maO �@ @ 0 O d Zp(V j °W0 JwHW Qcu LU Na "3L °'W W2@Mova OO OW L°U)io Er a>4)0 Cl) O C a) @ O @ C O U? (j �`') O p N 0 O p_ Q p (n O C U U CL 1°L.j Q N.0 p)N 3 0=m 04 YO 0 c.O(n d U i .@. Q m � CD C M ik @ 0 '00 c J - �L, 0 3 W d Y O C N a) N O1)N N L yN O_N p)0 cc nOM C C 3 p@ @ C Z N 0 LO 2 N O@ d 0@ N N Z N mU O O" a) U @ 0 m d _J Cl) O ?� Cl) o? 0)N T22 � �O'O a) TNm 0 a) m@_ d C co N co U 3 0 N@ a) F F W t` w j d W ,L„ @ 2 a O C (6 0a 204!T N N LQ N=YQZm Op wu 0— O N O O O O O O O O 2 O O wwWWWW H w O w J J J J J J J F J J O O O O O O O a O O w w w w w w w IL w w a 0 0 0 0 0 0 0 0 0 0 o I 1 o Cl) Cl) M Cl) M M Cl) Cl) Cl) Cl) N N N N N N N N N N N Cl) V LO (O r r O 0) O O O O O O O O O O co co co co co N N N N N p p p p p p p p p p U U U U U U U U U 0 Operations Summary (with Timelog Depths) CD3-128 9.6 RIG RELEASE DATE 3/19/2023 Ctm.a>hiOips Rig: DOYON 142 Job: RECOMPLETION Time Log Stim Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (fi End Depth (ftKB) 3/11/2023 3/11/2023 4.00 MIRU, MOVE MOB P Disconnect interconnects between 0.0 0.0 18:00 22:00 modules. Disconnect hydraulic lines in BOP deck. Raise landings and stairs between mod's. Disconnect Rock Washer from pits. Electrician unplug power boards. 3/11/2023 3/11/2023 0.50 MIRU, MOVE MOB P Trucks on location. Pull Rock Washer 0.0 0.0 22:00 22:30 out with CAT 3/11/2023 3/11/2023 0.50 MIRU, MOVE MOB P Raise pipe shed. Attach to Sow and pull 0.0 0.0 22:30 23:00 1 1 away from rig. 3/11/2023 3/12/2023 1.00 MIRU, MOVE MOB P Attach motor complex on Sow and pull 0.0 0.0 23:00 00:00 forward. Move rig mats. 3/12/2023 3/12/2023 2.00 MIRU, MOVE MOB P Set Motor complex on rig mats and 0.0 0.0 00:00 02:00 unhook Truck. Jack up Pump room and Pits. Attach trucks and pull both complexes away from Sub. 3/12/2023 3/12/2023 1.00 MIRU, MOVE MOB P SPRING FORWARD 0.0 0.0 02:00 03:00 3/12/2023 3/12/2023 2.00 MIRU, MOVE MOB P PJSM. Skid rig floor to move position. 0.0 0.0 03:00 05:00 1 1Raise and secure Sub Stomper feet. 3/12/2023 3/12/2023 1.00 MIRU, MOVE MOB P Raise and pin cellar wall and install 0.0 0.0 05:00 06:00 towing tongue on Sub 3/12/2023 3/12/2023 4.00 MIRU, MOVE MOB P Pull Sub off of Well CD3-114. Stage Sub 0.0 0.0 06:00 10:00 on pad while moving rig mats and herculite. Move Sub and spot over Well CD3-128. 3/12/2023 3/12/2023 2.00 MIRU, MOVE MOB P Shim Sub for level. Lower and set 0.0 0.0 10:00 12:00 Stompers. Remove tow tongue.. Skid rig floor into drilling position. 3/12/2023 3/12/2023 1.50 MIRU, MOVE MOB P Move Pits module into position 0.0 0.0 12:00 13:30 3/12/2023 3/12/2023 1.00 MIRU, MOVE MOB P Move Pump module into position 0.0 0.0 13:30 14:30 3/12/2023 3/12/2023 0.50 MIRU, MOVE MOB P Move Motor module into position. 0.0 0.0 14:30 15:00 3/12/2023 3/12/2023 0.50 MIRU, MOVE MOB P Move Rock Washer into position 0.0 0.0 15:00 15:30 3/12/2023 3/12/2023 1.00 MIRU, MOVE MOB P Move Pipe Shed into position. 0.0 0.0 15:30 16:30 3/12/2023 3/12/2023 4.50 MIRU, MOVE MOB P Shim Pipe Shed. Plug in electrical 0.0 0.0 16:30 21:00 panels throughout rig. Hook up interconnects. Spot cutting tank. Remove extra rig mats. Secure herculite around cellar. Lay out herculite for back cellar door 3/12/2023 3/13/2023 3.00 MIRU, MOVE MOB P Shim Pump module for interconnect 0.0 0.0 21:00 00:00 alignment. Hook up interconnects from pump to pits. Lower BOP deck landing. Hook up Sub interconnects. 3/13/2023 3/13/2023 9.00 MIRU, MOVE MOB P Hook up interconnects, service lines and 0.0 0.0 00:00 09:00 mud lines. Open steam up to all modules. Install skate rails and connect power cables. Function test Skate. Insulate gaps between modules. Satisfy Rig Acceptance Checklist. Accept rig @ 09:00 firs 3/13/2023 3/13/2023 3.00 MIRU, WELCTL RURD P Take on sea water to pits. Remove 12,287.0 12,287.0 09:00 12:00 flanges from tubing and annulus valves on tree and install 1502 flanges. R/U circulating manifold and all HP lines from rig to tree to tiger tank. R/U FMC lubricator. Obtain RKB's Page 115 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) CD3-128 9.6 RIG RELEASE DATE 3/19/2023 Ctm.a>hil ips Rig: DOYON 142 Job: RECOMPLETION Time Log Stim Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (fi End Depth (ftKB) 3/13/2023 3/13/2023 1.00 MIRU, WELCTL MPSP P Pull BPV with lubricator per FMC. 12,287.0 12,287.0 12:00 13:00 3/13/2023 3/13/2023 1.50 MIRU, WELCTL DISP P Check rigging and ensure proper line up 12,287.0 12,287.0 13:00 14:30 in cellar. Prime mud pumps. Blow air thru hardline to tiger tank to ensure line is open.Find ice plug in choke house. R/U Tioga heaters to thaw blockage. 3/13/2023 3/13/2023 0.25 MIRU, WELCTL MPSP P Fluid pack line to Tiger tank. Test 12,287.0 12,287.0 14:30 14:45 1hardline to 1000 psi. Good test. 3/13/2023 3/13/2023 2.75 MIRU, WELCTL DISP P Pump 40 bbls of 8.5 ppg sea water 12,287.0 12,287.0 14:45 17:30 down IA taking returns out tubing to the Tiger tank. 4 bpm = 570 psi. Swap valves and pump 437 bbls of sea water down tubing, taking returns out IA 4 bpm = 709 psi. Blow down lines in cellar. 3/13/2023 3/13/2023 0.50 MIRU, WELCTL OWFF P OWFF. Well is static. 12,287.0 12,287.0 17:30 18:00 Tubing = 0 psi, IA = 0 psi, CA= 550 psi 3/13/2023 3/13/2023 1.00 MIRU, WELCTL MPSP P Install BPV R/U and test BPV from 12,287.0 12,287.0 18:00 19:00 below to 1000 psi, 10 min on chart. Good test 3/13/2023 3/13/2023 0.50 MIRU, WHDBOP RURD P Blow down and RID circ lines in cellar. 12,287.0 12,287.0 19:00 19:30 L/D FMC lubricator from rig floor. 3/13/2023 3/13/2023 1.50 MIRU, WHDBOP NUND P N/D Tree per FMC reps. Install blanking 12,287.0 12,287.0 19:30 21:00 plug. Document tree orientation before removal. 3/13/2023 3/14/2023 3.00 MIRU, WHDBOP NUND P N/U BOPE. M/U adapter flange and 12,287.0 12,287.0 21:00 00:00 stack to wellhead. Torque all flange bolts with Sweeney. Install Dutch riser and drill riser 3/14/2023 3/14/2023 6.00 MIRU, WHDBOP NUND P Torque all BOP and adapter flange 12,287.0 12,287.0 00:00 06:00 bolts. M/U Choke and Kill lines at mud cross. M/U FOSV and Dart valve for testing. M/U test fitting on Top drive. R/U 20,000 psi test pump to test Kill line to 7500 psi. R/U testjoint. 3/14/2023 3/14/2023 0.75 MIRU, WHDBOP SEQP P Test kill line to 7500 psi. Found leak, 12,287.0 12,287.0 06:00 06:45 tighten and re -test. No visual leaks. Good test. 3/14/2023 3/14/2023 1.25 MIRU, WHDBOP BOPE P Plug gaps in herculite cellar back wall. 12,287.0 12,287.0 06:45 08:00 Re-route heater trunks in cellar to keep choke line and stack warm. Finish R/U test equipment. Grease choke manifold 3/14/2023 3/14/2023 1.00 MIRU, WHDBOP BOPE P Fill stack, choke manifold and lines with 12,287.0 12,287.0 08:00 09:00 fresh water. Shell test to 4500 psi. 3/14/2023 3/14/2023 4.00 MIRU, WHDBOP BOPE P Test ROPE. 12,287.0 12,287.0 09:00 13:00 Test annular to 250 psi low, 3500 psi high, 5 min each.. Test all rams, HCR's, choke valves, IBOP'S, and floor valves to 250 psi low, 4500 psi high, 5 min each. Test manual and super choke to 2000 psi. Use 3 1/2" test joint. Chart all tests Perform accumulator draw down test. Test PVT's gain/loss and flow paddle. Test gas alarms. AOGCC inspector Brian Bixby waived states right of witness. 3/14/2023 3/14/2023 2.50 MIRU, WHDBOP BOPE P RID test equipment. blow down all lines. 12,287.0 12,287.0 13:00 15:30 M/U floor valve XO's 3/14/2023 3/14/2023 1.00 MIRU, WHDBOP MPSP P Retrieve blanking plug per FMC. Pull 12,287.0 12,287.0 15:30 16:30 BPV from hanger. Page 215 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) CD3-128 9.6 RIG RELEASE DATE 3/19/2023 Co..;p imps Rig: DOYON 142 Job: RECOMPLETION Time Log Shm Time ErM Time Dur(hr) Phase Activity Cotle Time P-T-X Operation Stan Depth(WB) Emi Depth(ftKB) 3/14/2023 3/14/2023 2.50 MIRU, WHDBOP SLPC P Hang blocks. Cut and slip drilling line. 8 12,287.0 12,287.0 16:30 19:00 wraps = 117'. Un-hang blocks and calibrate. 3/14/2023 3/14/2023 1.00 COMPZN, RPCOMP RURD P Change over to 3 1/2" handling 12,287.0 12,287.0 19:00 20:00 equipment R/U Casing tongs. R/U control line spooler. M/U crossover and TIW to landing joint. R/U bale extensions. 3/14/2023 3/14/2023 1.50 COMPZN, RPCOMP THGR P M/U landing joint to hanger. Back out 12,287.0 12,249.0 20:00 21:30 LDS by FMC. Pull hanger to rig floor. PUWT = 106K with no over pulls. R/D bale extensions. Install side door elevators. 3/14/2023 3/15/2023 2.50 COMPZN, RPCOMP PULL P UD 3 1/2" 9.3 # L-80 EUE tubing 12,249.0 11,796.0 21:30 00:00 F/12249'to 11796' MD. PUWT = 95K. Write number and well name on each joint. 3/15/2023 3/15/2023 2.00 COMPZN, RPCOMP PULL P UD 31/V 9.3# L-80 EUE tubing F/11,796' 11,796.0 10,070.0 00:00 02:00 and to 10,070' md. PUWT= 86K. Write number and well name on each joint. Remove control line off SSSV. Total bands removed - 72. 3/15/2023 3/15/2023 8.00 COMPZN, RPCOMP PULL P UD 31/V 9.3 # L-80 EUE tubing F/ 10,070.0 5,095.0 02:00 10:00 10,070' and to 5,095' MD. PUWT = 64K. Write number and well name on each joint. 3/15/2023 3/15/2023 1.00 COMPZN, RPCOMP OTHR P Empty pipeshed of 3 YV 9.3 # L-80 5,095.0 5,095.0 10:00 11:00 EUE. Load 35 jts of 3% 9.2# L80 HYD563 to warm up to process. 3/15/2023 3/15/2023 3.25 COMPZN, RPCOMP PULL P UD 31/2" 9.3 # L-80 EUE tubing F/ 5,095' 5,095.0 2,880.0 11:00 14:15 and to 2,880' MD. PUWT = 59K. Write number and well name on each joint. 3/15/2023 3/15/2023 2.50 COMPZN, RPCOMP OTHR P Empty pipeshed of 3 %" 9.3 # L-80 2,880.0 2,880.0 14:15 16:45 EUE. Load 63 jts of 3% 9.2# L80 HYD563 to warm up to process. 3/15/2023 3/15/2023 4.25 COMPZN, RPCOMP PULL P UD 31/2" 9.3 # L-80 EUE tubing F/ 2,880' 2,880.0 0.0 16:45 21:00 and to surface. Write number and well name on each joint. 3/15/2023 3/16/2023 3.00 COMPZN, RPCOMP OTHR P Empty pipeshed of 3 %" 9.3 # L-80 0.0 0.0 21:00 00:00 EUE. Process 98 jts of 3% 9.2# L80 HYD563. 3/16/2023 3/16/2023 0.50 COMPZN, RPCOMP OTHR P Finish processing 3% 9.2# L80 HYD563. 0.0 0.0 00:00 00:30 3/16/2023 3/16/2023 8.50 COMPZN, RPCOMP PUTB P RIH with 31/29.2# L80 HYD563 seal 0.0 5,778.0 00:30 09:00 assembly as per detail to 5,778' md. S/O wt - 77k 3/16/2023 3/16/2023 2.50 COMPZN, RPCOMP OTHR P Remove old tree from the BOP deck. 5,778.0 5,778.0 09:00 11:30 Bring in new tree to the BOP deck to allowtothaw. Bring4%HYD563 hanger to the rig floor. Process 31/2 HYD563 pups in the shed for spaceout. 3/16/2023 3/16/2023 8.50 COMPZN, RPCOMP PUTB P RIH with 3%9.2# L80 HYD563 seal 5,778.0 12,280.0 11:30 20:00 assembly as per detail from 5,778' and to 12,280' md. up wt - 107k, s/o wt - 85k Page 315 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) CD3-128 9.6 RIG RELEASE DATE 3/19/2023 Co..31' ➢rips Rig: DOYON 142 Job: RECOMPLETION Time Log Stim Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/16/2023 3/16/2023 1.50 COMPZN, RPCOMP HOSO P Pick up jt #402. M/U xo and kelly up 12,280.0 12,285.0 20:00 21:30 with the tap drive. Circulate at 1.5 bpm, 46 psi, 18% f/o. Slack off to PBR. Observe psi increase at 12,306' md. Shut down pumps. Continue to slack of. P/U jt #403 and cont to slack off to no- go at 12,325.5' md. Pick up 1' off no-go and mark the pipe. Repeat to confirm no go at 12,325.5' md. (good) Pooh to 12,256' md. Pick up space out joint 29.49. 3/16/2023 3/16/2023 1.25 COMPZN, RPCOMP THGR P M/U landing jt w/ circ xo for cement line, 12,285.0 12,285.0 21:30 22:45 M/U landing jt to the hanger and xo. 3/16/2023 3/17/2023 1.25 COMPZN, RPCOMP CRIH P PJSM, Displace well to Cl brine. Pump 12,285.0 12,285.0 22:45 00:00 at 5bpm, 212 gpm, 659 psi, 26% f/o. Total stks pumped - 4370 (440 bbls). 3/17/2023 3/17/2023 0.50 COMPZN, RPCOMP CRIH P Continue to circulate Cl brine @ 210 0.0 12,285.0 00:00 00:30 gpm, 647 psi, 26% f/o. Total stks pumped - 4,370(440) bbls. 3/17/2023 3/17/2023 1.00 COMPZN, RPCOMP THGR P RIH from 12,285' and to 12,324' and and 12,285.0 12,324.0 00:30 01:30 1 1 land hanger. RILDS as per fmc. 3/17/2023 3/17/2023 1.00 COMPZN, RPCOMP THGR P Pressure test hanger seals to 5,000 psi 0.0 0.0 01:30 02:30 for 30 charted min. Shut in and switch to FMC pump in cellar. Hold for 15 min. CPAI rep witnessed test. 3/17/2023 3/17/2023 0.75 COMPZN, RPCOMP PRTS P Pressure test Tbg to 4,000 psi for 30 0.0 0.0 02:30 03:15 min. (Failed). 3/17/2023 3/17/2023 4.75 COMPZN, RPCOMP PRTS T Chase leaks on the rig floor. Add double 0.0 0.0 03:15 08:00 block valve to rig up. Change out sensator and hoses. Re -test multiple times to no success. 3/17/2023 3/17/2023 1.50 COMPZN, RPCOMP PRTS P Pressure test IAto 3,000 psi. Apply 0.0 0.0 08:00 09:30 2,000 psi to tbg, then pressure up IA to 3,000 psi and hold for 30 charted min (good). Bleed off IA then tbg to not shear the SOV. 3/17/2023 3/17/2023 0.50 COMPZN, RPCOMP RURD P Blow down and rig down testing 0.0 0.0 09:30 10:00 equipment in the cellar and rig floor. 3/17/2023 3/17/2023 3.25 COMPZN, RPCOMP RURD P Rig down doyon csg. Send FMC tools 0.0 0.0 10:00 13:15 off the rig floor. 3/17/2023 3/17/2023 3.25 COMPZN, RPCOMP SLKL T Rig up Halliburtion slick line. 0.0 0.0 13:15 16:30 3/17/2023 3/17/2023 2.25 COMPZN, RPCOMP SLKL T Round trip with 2.77 OD gauge ring. 0.0 0.0 16:30 18:45 Land out at 12,315' MD slick line measurement. 3/17/2023 3/18/2023 5.25 COMPZN, RPCOMP SLKL T Decision made to RIH with 2.77 OD 0.0 0.0 18:45 00:00 compression block to verify tag on top of xx plug in the hole. Tag at 12,315' MD. POOH. 3/18/2023 3/18/2023 1.75 COMPZN, RPCOMP SLKL T RIH with 2.05 od gauge ring. Land out 0.0 0.0 00:00 01:45 on top of the xx plug at 12,363' md. POOH. 3/18/2023 3/18/2023 1.75 COMPZN, RPCOMP SLKL T RIH with 2.74 od gauge ring. Land out 0.0 0.0 01:45 03:30 on top of the xx plug at 12,363' md. POOH. 3/18/2023 3/18/2023 5.00 COMPZN, RPCOMP SLKL T Make up Quadco RBP and rih. Set at 0.0 0.0 03:30 08:30 12,353' md. POOH. 3/18/2023 3/18/2023 0.50 COMPZN, RPCOMP RURD P Rig up to test tbg. 0.0 0.0 08:30 09:00 3/18/2023 3/18/2023 0.75 COMPZN, RPCOMP PRTS P PT tubing to 4,000 psi for 30 charted 0.0 0.0 09:00 09:45 min (good). 3/18/2023 3/18/2023 0.75 COMPZN, RPCOMP SLKL T Rig down HES slick line. 0.0 0.0 09:A 10:30 Page 415 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) 9.6 CD3-128 RIG RELEASE DATE 3/19/2023 CorrocoPhIDips Rig: DOYON 142 Job: RECOMPLETION Time Log Stah Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (ftKB) End Depth (ftKB) 3/18/2023 3/18/2023 0.50 COMPZN, RPCOMP CIRC P Pressure up on the IA to shear the SOV 0.0 0.0 10:30 11:00 at the GUM. Observe shear out at 2,000 psi. Pump 10 bbls of Cl brine @j 2 bpm, 618 psi, 14%f/o. 3/18/2023 3/18/2023 1.50 COMPZN, RPCOMP RURD P Blow down testing lines. Rig down 0.0 0.0 11:00 12:30 same. Lay down the landing jt. 3/18/2023 3/18/2023 0.25 COMPZN, RPCOMP MPSP P Install H-BPV as per FMC via T bar. 0.0 0.0 12:30 12:45 3/18/2023 3/18/2023 0.25 COMPZN, RPCOMP PRTS P PT from below the BPV to 1,000 psi for 0.0 0.0 12:45 13:00 1 110 min (good). 3/18/2023 3/18/2023 1.00 COMPZN, RPCOMP RURD P Blow down and rig down testing 0.0 0.0 13:00 14:00 equipment in the cellar. Blow down the hole fill, mud line, injection line, and choke and kill lines. 3/18/2023 3/18/2023 4.00 COMPZN, WHDBOP NUND P Nipple down the BOPE. 0.0 0.0 14:00 18:00 3/18/2023 3/18/2023 3.00 COMPZN, WHDBOP NUND P Remove alpine speedhead and adpter 0.0 0.0 18:00 21:00 flanges. Nipple up tree as per FMC reps. 3/18/2023 3/18/2023 1.50 COMPZN, WHDBOP PRTS P Fill tree with diesel. Test tree to 250 low, 0.0 0.0 21:00 22:30 5,000 hight for 5/5 charted min. Poor test on chart. Shut in and monitor pressure at wellhead. FMC pump up to 5,000 psi for 5 min.(good) Witnessed by CPAI rig supervisor. 3/18/2023 3/18/2023 0.50 COMPZN, WHDBOP MPSP P Pull BPV as per FMC 0.0 0.0 22:30 23:00 3/18/2023 3/19/2023 1.00 COMPZN, WHDBOP RURD P Rig up tree, tiger tank, and squeeze 0.0 0.0 23:00 00:00 manifod to freeze protect well. Simops - spot LRS 3/19/2023 3/19/2023 1.50 COMPZN, WHDBOP FRZP P PJSM. Rig up LRS. PT lines to 2000 0.0 0.0 00:00 01:30 psi. Pump 80 bbls of diesel down IA taking returns out tubing to the tiger tank at 2 bpm = 1030 psi. Blow down hardline to Tiger tank. Rig down LRS. 3/19/2023 3/19/2023 1.00 COMPZN, WHDBOP FRZP P Line up IA to the tubing and allow the 0.0 0.0 01:30 02:30 well to u-tube. 3/19/2023 3/19/2023 0.50 COMPZN, WHDBOP MPSP P Install BPV as per FMC. 0.0 0.0 02:30 03:00 3/19/2023 3/19/2023 3.00 DEMOB, MOVE RURD P Blow down and rig down all circulating 0.0 0.0 03:00 06:00 equipment. Remove all 1502 flanges and install gauges on tubing and IA valves. Housekeeping in the cellar. Release the rig. Page 515 Report Printed: 3/24/2023 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Susp Well Insp ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Install Whipstock ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Mod Artificial Lift ❑ Perforate New Pool ❑ Repair Well 0 Coiled Tubing Ops❑ Other: Replace Tubing 0 2. Operator Name 4. WeII Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Explorator�❑ Stratigraphic ❑ ServiceR 211-037 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99610 50-403-20638-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL25538, ADL372105 CRU CD3-128 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field/ Fiord Nechelik Oil Pool 11. Present Well Condition Summary: Total Depth measured 20387' feet Plugs measured 12353' feet true vertical 7083' feet Junk measured None feet Effective Depth measured 12822' feet Packer measured 12311', 12596' feet true vertical 6948' feet true vertical 6745', 6876' feet Casing Length Size MD ND Burst Collapse Conductor 77' 16" 114' 114' Surface 2953' 9-5/81, 2989' 2451' Production 12976' 7" 13009' 7083' Liner 5990, 4-1/2" 18685' 7062' Open Hole 1702' 6-1/8" 20387' 7083' Perforation depth Measured depth 12476-12496', Alternating 4.78' Pert Pups 13217-18637' True Vertical depth 6824-6833', A:ternating 4.78' Pert Pups 6691-7062' Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 12739' 6926' Packers and SSSV (type, measured and true vertical depth) Packers: Baker Premier Packer SSSV: 123111, 12596' 6745', 6876' Camco TRMAXX-5E 2179' 2014' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 2000 938 2550 Subsequent to operation: 0 1964 0 1212 3738 13b. Pools active after work: 14. Attachments (required per 20 AAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations F1 Exploratory ❑ Development ❑ Servicep Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG p GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Adam Klem Contact Email: dam.klemnconocoohillios.com Authorized Title: Staff RWO/CTD Engineer Contact Phone: (907) 263-4529 Sr Pet Eng: ISr Pet Geo: I I Sr Res Eng: Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov U Un C N_ p_ O. O1 L_ O) N W M N O — O. ° u a J 3 m .(u c m 0LU E a) ° Z r C @ a) N 2 0 L @ p a) F i0 r � L-. 00 N 'O C Oi a) in 'y Q O N Q O N m C 3 0 N 3 @ N= i0 O_ N o �^ 'LO' Q 2 2 a' O N �0., Y m (n C-iLp n Ln L� wO� ��~� �� c N N N V ,-, 3 5 N m M 0 y.0> d d YZ 0 4) d' N '6 LL' Q OY (D (V MO a@ N 3y mo �d a` m0 (L)— J� d-0 dm wm U 0 @ @mod em 4) n rn� wyi°KdQ p c� d @ m `..� a) O m U— O�LL ain'0 . co _OJ m Y a) CL W 0@@ � p_Y2a) C LL J O — O O_ O LO 0 J N -0a) U LL C UN NW C, M� M M 040NCm — maO �@ @ 0 O d Zp(V j °W0 JwHW Qcu LU Na "3L °'W W2@Mova OO OW L°U)io Er a>4)0 Cl) O C a) @ O @ C O U? (j �`') O p N 0 O p_ Q p (n O C U U CL 1°L.j Q N.0 p)N 3 0=m 04 YO 0 c.O(n d U i .@. Q m � CD C M ik @ 0 '00 c J - �L, 0 3 W d Y O C N a) N O1)N N L yN O_N p)0 cc nOM C C 3 p@ @ C Z N 0 LO 2 N O@ d 0@ N N Z N mU O O" a) U @ 0 m d _J Cl) O ?� Cl) o? 0)N T22 � �O'O a) TNm 0 a) m@_ d C co N co U 3 0 N@ a) F F W t` w j d W ,L„ @ 2 a O C (6 0a 204!T N N LQ N=YQZm Op wu 0— O N O O O O O O O O 2 O O wwWWWW H w O w J J J J J J J F J J O O O O O O O a O O w w w w w w w IL w w a 0 0 0 0 0 0 0 0 0 0 o I 1 o Cl) Cl) M Cl) M M Cl) Cl) Cl) Cl) N N N N N N N N N N N Cl) V LO (O r r O 0) O O O O O O O O O O co co co co co N N N N N p p p p p p p p p p U U U U U U U U U 0 Operations Summary (with Timelog Depths) CD3-128 9.6 RIG RELEASE DATE 3/19/2023 Co..;p imps Rig: DOYON 142 Job: RECOMPLETION Time Log Stim Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (fi End Depth (ftKB) 3/11/2023 3/11/2023 4.00 MIRU, MOVE MOB P Disconnect interconnects between 0.0 0.0 18:00 22:00 modules. Disconnect hydraulic lines in BOP deck. Raise landings and stairs between mod's. Disconnect Rock Washer from pits. Electrician unplug power boards. 3/11/2023 3/11/2023 0.50 MIRU, MOVE MOB P Trucks on location. Pull Rock Washer 0.0 0.0 22:00 22:30 out with CAT 3/11/2023 3/11/2023 0.50 MIRU, MOVE MOB P Raise pipe shed. Attach to Sow and pull 0.0 0.0 22:30 23:00 1 1 away from rig. 3/11/2023 3/12/2023 1.00 MIRU, MOVE MOB P Attach motor complex on Sow and pull 0.0 0.0 23:00 00:00 forward. Move rig mats. 3/12/2023 3/12/2023 2.00 MIRU, MOVE MOB P Set Motor complex on rig mats and 0.0 0.0 00:00 02:00 unhook Truck. Jack up Pump room and Pits. Attach trucks and pull both complexes away from Sub. 3/12/2023 3/12/2023 1.00 MIRU, MOVE MOB P SPRING FORWARD 0.0 0.0 02:00 03:00 3/12/2023 3/12/2023 2.00 MIRU, MOVE MOB P PJSM. Skid rig floor to move position. 0.0 0.0 03:00 05:00 1 1Raise and secure Sub Stomper feet. 3/12/2023 3/12/2023 1.00 MIRU, MOVE MOB P Raise and pin cellar wall and install 0.0 0.0 05:00 06:00 towing tongue on Sub 3/12/2023 3/12/2023 4.00 MIRU, MOVE MOB P Pull Sub off of Well CD3-114. Stage Sub 0.0 0.0 06:00 10:00 on pad while moving rig mats and herculite. Move Sub and spot over Well CD3-128. 3/12/2023 3/12/2023 2.00 MIRU, MOVE MOB P Shim Sub for level. Lower and set 0.0 0.0 10:00 12:00 Stompers. Remove tow tongue.. Skid rig floor into drilling position. 3/12/2023 3/12/2023 1.50 MIRU, MOVE MOB P Move Pits module into position 0.0 0.0 12:00 13:30 3/12/2023 3/12/2023 1.00 MIRU, MOVE MOB P Move Pump module into position 0.0 0.0 13:30 14:30 3/12/2023 3/12/2023 0.50 MIRU, MOVE MOB P Move Motor module into position. 0.0 0.0 14:30 15:00 3/12/2023 3/12/2023 0.50 MIRU, MOVE MOB P Move Rock Washer into position 0.0 0.0 15:00 15:30 3/12/2023 3/12/2023 1.00 MIRU, MOVE MOB P Move Pipe Shed into position. 0.0 0.0 15:30 16:30 3/12/2023 3/12/2023 4.50 MIRU, MOVE MOB P Shim Pipe Shed. Plug in electrical 0.0 0.0 16:30 21:00 panels throughout rig. Hook up interconnects. Spot cutting tank. Remove extra rig mats. Secure herculite around cellar. Lay out herculite for back cellar door 3/12/2023 3/13/2023 3.00 MIRU, MOVE MOB P Shim Pump module for interconnect 0.0 0.0 21:00 00:00 alignment. Hook up interconnects from pump to pits. Lower BOP deck landing. Hook up Sub interconnects. 3/13/2023 3/13/2023 9.00 MIRU, MOVE MOB P Hook up interconnects, service lines and 0.0 0.0 00:00 09:00 mud lines. Open steam up to all modules. Install skate rails and connect power cables. Function test Skate. Insulate gaps between modules. Satisfy Rig Acceptance Checklist. Accept rig @ 09:00 firs 3/13/2023 3/13/2023 3.00 MIRU, WELCTL RURD P Take on sea water to pits. Remove 12,287.0 12,287.0 09:00 12:00 flanges from tubing and annulus valves on tree and install 1502 flanges. R/U circulating manifold and all HP lines from rig to tree to tiger tank. R/U FMC lubricator. Obtain RKB's Page 115 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) CD3-128 9.6 RIG RELEASE DATE 3/19/2023 Ctm.a>hil ips Rig: DOYON 142 Job: RECOMPLETION Time Log Stim Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (fi End Depth (ftKB) 3/13/2023 3/13/2023 1.00 MIRU, WELCTL MPSP P Pull BPV with lubricator per FMC. 12,287.0 12,287.0 12:00 13:00 3/13/2023 3/13/2023 1.50 MIRU, WELCTL DISP P Check rigging and ensure proper line up 12,287.0 12,287.0 13:00 14:30 in cellar. Prime mud pumps. Blow air thru hardline to tiger tank to ensure line is open.Find ice plug in choke house. R/U Tioga heaters to thaw blockage. 3/13/2023 3/13/2023 0.25 MIRU, WELCTL MPSP P Fluid pack line to Tiger tank. Test 12,287.0 12,287.0 14:30 14:45 1hardline to 1000 psi. Good test. 3/13/2023 3/13/2023 2.75 MIRU, WELCTL DISP P Pump 40 bbls of 8.5 ppg sea water 12,287.0 12,287.0 14:45 17:30 down IA taking returns out tubing to the Tiger tank. 4 bpm = 570 psi. Swap valves and pump 437 bbls of sea water down tubing, taking returns out IA 4 bpm = 709 psi. Blow down lines in cellar. 3/13/2023 3/13/2023 0.50 MIRU, WELCTL OWFF P OWFF. Well is static. 12,287.0 12,287.0 17:30 18:00 Tubing = 0 psi, IA = 0 psi, CA= 550 psi 3/13/2023 3/13/2023 1.00 MIRU, WELCTL MPSP P Install BPV R/U and test BPV from 12,287.0 12,287.0 18:00 19:00 below to 1000 psi, 10 min on chart. Good test 3/13/2023 3/13/2023 0.50 MIRU, WHDBOP RURD P Blow down and RID circ lines in cellar. 12,287.0 12,287.0 19:00 19:30 L/D FMC lubricator from rig floor. 3/13/2023 3/13/2023 1.50 MIRU, WHDBOP NUND P N/D Tree per FMC reps. Install blanking 12,287.0 12,287.0 19:30 21:00 plug. Document tree orientation before removal. 3/13/2023 3/14/2023 3.00 MIRU, WHDBOP NUND P N/U BOPE. M/U adapter flange and 12,287.0 12,287.0 21:00 00:00 stack to wellhead. Torque all flange bolts with Sweeney. Install Dutch riser and drill riser 3/14/2023 3/14/2023 6.00 MIRU, WHDBOP NUND P Torque all BOP and adapter flange 12,287.0 12,287.0 00:00 06:00 bolts. M/U Choke and Kill lines at mud cross. M/U FOSV and Dart valve for testing. M/U test fitting on Top drive. R/U 20,000 psi test pump to test Kill line to 7500 psi. R/U testjoint. 3/14/2023 3/14/2023 0.75 MIRU, WHDBOP SEQP P Test kill line to 7500 psi. Found leak, 12,287.0 12,287.0 06:00 06:45 tighten and re -test. No visual leaks. Good test. 3/14/2023 3/14/2023 1.25 MIRU, WHDBOP BOPE P Plug gaps in herculite cellar back wall. 12,287.0 12,287.0 06:45 08:00 Re-route heater trunks in cellar to keep choke line and stack warm. Finish R/U test equipment. Grease choke manifold 3/14/2023 3/14/2023 1.00 MIRU, WHDBOP BOPE P Fill stack, choke manifold and lines with 12,287.0 12,287.0 08:00 09:00 fresh water. Shell test to 4500 psi. 3/14/2023 3/14/2023 4.00 MIRU, WHDBOP BOPE P Test ROPE. 12,287.0 12,287.0 09:00 13:00 Test annular to 250 psi low, 3500 psi high, 5 min each.. Test all rams, HCR's, choke valves, IBOP'S, and floor valves to 250 psi low, 4500 psi high, 5 min each. Test manual and super choke to 2000 psi. Use 3 1/2" test joint. Chart all tests Perform accumulator draw down test. Test PVT's gain/loss and flow paddle. Test gas alarms. AOGCC inspector Brian Bixby waived states right of witness. 3/14/2023 3/14/2023 2.50 MIRU, WHDBOP BOPE P RID test equipment. blow down all lines. 12,287.0 12,287.0 13:00 15:30 M/U floor valve XO's 3/14/2023 3/14/2023 1.00 MIRU, WHDBOP MPSP P Retrieve blanking plug per FMC. Pull 12,287.0 12,287.0 15:30 16:30 BPV from hanger. Page 215 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) CD3-128 9.6 RIG RELEASE DATE 3/19/2023 ConoWPhillips Rig: DOYON 142 Job: RECOMPLETION Time Log Shmt Time ErM Time Dur(hr) Phase Aotrvity Cotle Time P-T-X Operation Stan Depth(WB) Entl Depth(ftKB) 3/14/2023 3/14/2023 2.50 MIRU, WHDBOP SLPC P Hang blocks. Cut and slip drilling line. 8 12,287.0 12,287.0 16:30 19:00 wraps = 117'. Un-hang blocks and calibrate. 3/14/2023 3/14/2023 1.00 COMPZN, RPCOMP RURD P Change over to 3 1/2" handling 12,287.0 12,287.0 19:00 20:00 equipment R/U Casing tongs. R/U control line spooler. M/U crossover and TIW to landing joint. R/U bale extensions. 3/14/2023 3/14/2023 1.50 COMPZN, RPCOMP THGR P M/U landing joint to hanger. Back out 12,287.0 12,249.0 20:00 21:30 LDS by FMC. Pull hanger to rig floor. PUWT = 106K with no over pulls. R/D bale extensions. Install side door elevators. 3/14/2023 3/15/2023 2.50 COMPZN, RPCOMP PULL P UD 3 1/2" 9.3 # L-80 EUE tubing 12,249.0 11,796.0 21:30 00:00 F/12249'to 11796' MD. PUWT = 95K. Write number and well name on each joint. 3/15/2023 3/15/2023 2.00 COMPZN, RPCOMP PULL P UD 31/V 9.3# L-80 EUE tubing F/11,796' 11,796.0 10,070.0 00:00 02:00 and to 10,070' md. PUWT= 86K. Write number and well name on each joint. Remove control line off SSSV. Total bands removed - 72. 3/15/2023 3/15/2023 8.00 COMPZN, RPCOMP PULL P UD 31/V 9.3 # L-80 EUE tubing F/ 10,070.0 5,095.0 02:00 10:00 10,070' and to 5,095' MD. PUWT = 64K. Write number and well name on each joint. 3/15/2023 3/15/2023 1.00 COMPZN, RPCOMP OTHR P Empty pipeshed of 3 YV 9.3 # L-80 5,095.0 5,095.0 10:00 11:00 EUE. Load 35 jts of 3% 9.2# L80 HYD563 to warm up to process. 3/15/2023 3/15/2023 3.25 COMPZN, RPCOMP PULL P UD 31/2" 9.3 # L-80 EUE tubing F/ 5,095' 5,095.0 2,880.0 11:00 14:15 and to 2,880' MD. PUWT = 59K. Write number and well name on each joint. 3/15/2023 3/15/2023 2.50 COMPZN, RPCOMP OTHR P Empty pipeshed of 3 %" 9.3 # L-80 2,880.0 2,880.0 14:15 16:45 EUE. Load 63 jts of 3% 9.2# L80 HYD563 to warm up to process. 3/15/2023 3/15/2023 4.25 COMPZN, RPCOMP PULL P UD 31/2" 9.3 # L-80 EUE tubing F/ 2,880' 2,880.0 0.0 16:45 21:00 and to surface. Write number and well name on each joint. 3/15/2023 3/16/2023 3.00 COMPZN, RPCOMP OTHR P Empty pipeshed of 3 %" 9.3 # L-80 0.0 0.0 21:00 00:00 EUE. Process 98 jts of 3% 9.2# L80 HYD563. 3/16/2023 3/16/2023 0.50 COMPZN, RPCOMP OTHR P Finish processing 3% 9.2# L80 HYD563. 0.0 0.0 00:00 00:30 3/16/2023 3/16/2023 8.50 COMPZN, RPCOMP PUTB P RIH with 31/29.2# L80 HYD563 seal 0.0 5,778.0 00:30 09:00 assembly as per detail to 5,778' md. S/O wt - 77k 3/16/2023 3/16/2023 2.50 COMPZN, RPCOMP OTHR P Remove old tree from the BOP deck. 5,778.0 5,778.0 09:00 11:30 Bring in new tree to the BOP deck to allowtothaw. Bring4%HYD563 hanger to the rig floor. Process 31/2 HYD563 pups in the shed for spaceout. 3/16/2023 3/16/2023 8.50 COMPZN, RPCOMP PUTB P RIH with 3%9.2# L80 HYD563 seal 5,778.0 12,280.0 11:30 20:00 assembly as per detail from 5,778' and to 12,280' md. up wt - 107k, s/o wt - 85k Page 315 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) CD3-128 9.6 RIG RELEASE DATE 3/19/2023 Cori.a>hiOips Rig: DOYON 142 Job: RECOMPLETION Time Log Stim Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/16/2023 3/16/2023 1.50 COMPZN, RPCOMP HOSO P Pick up jt #402. M/U xo and kelly up 12,280.0 12,285.0 20:00 21:30 with the tap drive. Circulate at 1.5 bpm, 46 psi, 18% f/o. Slack off to PBR. Observe psi increase at 12,306' md. Shut down pumps. Continue to slack of. P/U jt #403 and cont to slack off to no- go at 12,325.5' md. Pick up 1' off no-go and mark the pipe. Repeat to confirm no go at 12,325.5' md. (good) Pooh to 12,256' md. Pick up space out joint 29.49. 3/16/2023 3/16/2023 1.25 COMPZN, RPCOMP THGR P M/U landing jt w/ circ xo for cement line, 12,285.0 12,285.0 21:30 22:45 M/U landing jt to the hanger and xo. 3/16/2023 3/17/2023 1.25 COMPZN, RPCOMP CRIH P PJSM, Displace well to Cl brine. Pump 12,285.0 12,285.0 22:45 00:00 at 5bpm, 212 gpm, 659 psi, 26% f/o. Total stks pumped - 4370 (440 bbls). 3/17/2023 3/17/2023 0.50 COMPZN, RPCOMP CRIH P Continue to circulate Cl brine @ 210 0.0 12,285.0 00:00 00:30 gpm, 647 psi, 26% f/o. Total stks pumped - 4,370(440) bbls. 3/17/2023 3/17/2023 1.00 COMPZN, RPCOMP THGR P RIH from 12,285' and to 12,324' and and 12,285.0 12,324.0 00:30 01:30 1 1 land hanger. RILDS as per fmc. 3/17/2023 3/17/2023 1.00 COMPZN, RPCOMP THGR P Pressure test hanger seals to 5,000 psi 0.0 0.0 01:30 02:30 for 30 charted min. Shut in and switch to FMC pump in cellar. Hold for 15 min. CPAI rep witnessed test. 3/17/2023 3/17/2023 0.75 COMPZN, RPCOMP PRTS P Pressure test Tbg to 4,000 psi for 30 0.0 0.0 02:30 03:15 min. (Failed). 3/17/2023 3/17/2023 4.75 COMPZN, RPCOMP PRTS T Chase leaks on the rig floor. Add double 0.0 0.0 03:15 08:00 block valve to rig up. Change out sensator and hoses. Re -test multiple times to no success. 3/17/2023 3/17/2023 1.50 COMPZN, RPCOMP PRTS P Pressure test IAto 3,000 psi. Apply 0.0 0.0 08:00 09:30 2,000 psi to tbg, then pressure up IA to 3,000 psi and hold for 30 charted min (good). Bleed off IA then tbg to not shear the SOV. 3/17/2023 3/17/2023 0.50 COMPZN, RPCOMP RURD P Blow down and rig down testing 0.0 0.0 09:30 10:00 equipment in the cellar and rig floor. 3/17/2023 3/17/2023 3.25 COMPZN, RPCOMP RURD P Rig down doyon csg. Send FMC tools 0.0 0.0 10:00 13:15 off the rig floor. 3/17/2023 3/17/2023 3.25 COMPZN, RPCOMP SLKL T Rig up Halliburtion slick line. 0.0 0.0 13:15 16:30 3/17/2023 3/17/2023 2.25 COMPZN, RPCOMP SLKL T Round trip with 2.77 OD gauge ring. 0.0 0.0 16:30 18:45 Land out at 12,315' MD slick line measurement. 3/17/2023 3/18/2023 5.25 COMPZN, RPCOMP SLKL T Decision made to RIH with 2.77 OD 0.0 0.0 18:45 00:00 compression block to verify tag on top of xx plug in the hole. Tag at 12,315' MD. POOH. 3/18/2023 3/18/2023 1.75 COMPZN, RPCOMP SLKL T RIH with 2.05 od gauge ring. Land out 0.0 0.0 00:00 01:45 on top of the xx plug at 12,363' md. POOH. 3/18/2023 3/18/2023 1.75 COMPZN, RPCOMP SLKL T RIH with 2.74 od gauge ring. Land out 0.0 0.0 01:45 03:30 on top of the xx plug at 12,363' md. POOH. 3/18/2023 3/18/2023 5.00 COMPZN, RPCOMP SLKL T Make up Quadco RBP and rih. Set at 0.0 0.0 03:30 08:30 12,353' md. POOH. 3/18/2023 3/18/2023 0.50 COMPZN, RPCOMP RURD P Rig up to test tbg. 0.0 0.0 08:30 09:00 3/18/2023 3/18/2023 0.75 COMPZN, RPCOMP PRTS P PT tubing to 4,000 psi for 30 charted 0.0 0.0 09:00 09:45 min (good). 3/18/2023 3/18/2023 0.75 COMPZN, RPCOMP SLKL T Rig down HES slick line. 0.0 0.0 09:A 10:30 Page 415 Report Printed: 3/24/2023 Operations Summary (with Timelog Depths) 9.6 CD3-128 RIG RELEASE DATE 3/19/2023 C.hoa>hillips Rig: DOYON 142 Job: RECOMPLETION Time Log Stah Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (ftKB) End Depth (ftKB) 3/18/2023 3/18/2023 0.50 COMPZN, RPCOMP CIRC P Pressure up on the IA to shear the SOV 0.0 0.0 10:30 11:00 at the GLM. Observe shear out at 2,000 psi. Pump 10 bbls of Cl brine @j 2 bpm, 618 psi, 14%f/o. 3/18/2023 3/18/2023 1.50 COMPZN, RPCOMP RURD P Blow down testing lines. Rig down 0.0 0.0 11:00 12:30 same. Lay down the landing jt. 3/18/2023 3/18/2023 0.25 COMPZN, RPCOMP MPSP P Install H-BPV as per FMC via T bar. 0.0 0.0 12:30 12:45 3/18/2023 3/18/2023 0.25 COMPZN, RPCOMP PRTS P PT from below the BPV to 1,000 psi for 0.0 0.0 12:45 13:00 1 110 min (good). 3/18/2023 3/18/2023 1.00 COMPZN, RPCOMP RURD P Blow down and rig down testing 0.0 0.0 13:00 14:00 equipment in the cellar. Blow down the hole fill, mud line, injection line, and choke and kill lines. 3/18/2023 3/18/2023 4.00 COMPZN, WHDBOP NUND P Nipple down the BOPE. 0.0 0.0 14:00 18:00 3/18/2023 3/18/2023 3.00 COMPZN, WHDBOP NUND P Remove alpine speedhead and adpter 0.0 0.0 18:00 21:00 flanges. Nipple up tree as per FMC reps. 3/18/2023 3/18/2023 1.50 COMPZN, WHDBOP PRTS P Fill tree with diesel. Test tree to 250 low, 0.0 0.0 21:00 22:30 5,000 hight for 5/5 charted min. Poor test on chart. Shut in and monitor pressure at wellhead. FMC pump up to 5,000 psi for 5 min.(good) Witnessed by CPAI rig supervisor. 3/18/2023 3/18/2023 0.50 COMPZN, WHDBOP MPSP P Pull BPV as per FMC 0.0 0.0 22:30 23:00 3/18/2023 3/19/2023 1.00 COMPZN, WHDBOP RURD P Rig up tree, tiger tank, and squeeze 0.0 0.0 23:00 00:00 manifod to freeze protect well. Simops - spot LRS 3/19/2023 3/19/2023 1.50 COMPZN, WHDBOP FRZP P PJSM. Rig up LRS. PT lines to 2000 0.0 0.0 00:00 01:30 psi. Pump 80 bbls of diesel down IA taking returns out tubing to the tiger tank at 2 bpm = 1030 psi. Blow down hardline to Tiger tank. Rig down LRS. 3/19/2023 3/19/2023 1.00 COMPZN, WHDBOP FRZP P Line up IA to the tubing and allow the 0.0 0.0 01:30 02:30 well to u-tube. 3/19/2023 3/19/2023 0.50 COMPZN, WHDBOP MPSP P Install BPV as per FMC. 0.0 0.0 02:30 03:00 3/19/2023 3/19/2023 3.00 DEMOB, MOVE RURD P Blow down and rig down all circulating 0.0 0.0 03:00 06:00 equipment. Remove all 1502 flanges and install gauges on tubing and IA valves. Housekeeping in the cellar. Release the rig. Page 515 Report Printed: 3/24/2023 WNS ]NJ WELLNAME CD3-128 WELLBORE CD3-128 GnirocOPIIlllps Alaska, Inc. RONIZONTAL.CDs-120, 4111NOI VeNUl cnan de pool) ..�................ XANGER: ie.&u a .............. CWn9 Render, 3B.0. a M CONDUCTOR NS. AY; ffiL Nipple Lending12.1ee.e IW VALVE; 2,19a8 Fleet CONr, 2.910 P20121 new GM1m; 2,6a3.T-2,re8.0 BVRFACE 29.A2,M0P� Mandrel -GAG DFT; 12,2A1.2 Pan 12.19 .1 aeeembn: l0.aaa.a PACKER; u,a1P.NIPPLE; 23ex GAs uFr; t2 adaz RPERF; 12,476 e,124eG.0 NIPPLE: X4HGER; SE .BE. BE Emit Flow CNIM, Fled SMa; PRODUCT PERFP Feel PI PERFP %it Pup PERFP mad lap PEREP Pen wp PERFP Peel Fup PERFP Pen Pup PERFP Peel Pup PERFP Pen Rap PERFP Feel Pup PERFP Pen Pup PERFP Ped Pup PERFP Peep Pup Pied Pope PERFP PERFP Ped Low PERFP Pled Fup PERFP: Pal Pup: S. LINER: OPEN HOLE: OPEN ROLE: Well Attributes Max Angle S Field Nam! Well New APFUWI WBImON Sletue InCl l°) MOIRKBI FIORD NECHELIK 5010320fi3800 INJ 9179 19,23070 MD ITO flCI Bfm IRKB] 20,387.0 Comment X251pped Date Amwbd ui Entl Oate KB�Gm SSSV'. TRDP Lear WO'. 3/112023 36.80 IRj RR Dum 4I30I2011 Other Flex... Promotion Depmpulth I Wage End Date Lasi Mod By Lan Tag: SUM 12,822.0 CD3-128 &t4/2012 osborl Last Rev Reason nomination Wellbore 1 End Ome 1 Last Mod By REV Reason Post Rig, SOVIDMY, Pull REP, Pull XX plug, SERF, Set Inl Vale CD3-128 I3/3W2023 jecourr Notes: General & Safety Assumption End Dale Last Mod By NOTe Well suspended after original drlluWmplerlon 2011; arentered and Oulled cheaper, WO, W12 11212012 osborl General Notes: Last 3 entries Co. Dine Last Mod ay Slickline was unable to Pass through the seal bore assembly with a 2 ]] be Orin. Rana 27] och 3 a"i-23 es"readon block and didnt see anything to determine the issue. Ran 2.74 pch drift so..Atully. Ran 2.725 max cd Lp and set without issue. d142cm Casing Strings Ong Des OD llnl ID (in) Top (RKB) Bet Detail Set (RKB) ITVD)(BKB) Depth WOLen(Ib'n) Grade Top Thread CONDUCTOR INS. 42" 16 15.25 36.8 114.0 114.0 62.50 H40 WELDED SURFACE 95IR 8.92 WA 2,989.0 2,451.1 MOD J-55 BTC-M PRODUCTION ] 6.28 32.8 13,001 6,980.4 26,00 L-80 BTC-M OPEN HOLE 6118 18,68.5.0 20,38].0 7,0826 LINER 4112 3.96 12,5947 1816850 7,061.9 12,60 L-80 IBTM Tubing Strings: string max indicates LONGEST segment of string Top IRKB) Set OeplM1_. aH 0¢plb.. sWng Me... T.E.N. Desciption W1 RbIR) Grade Top Conne[tian ID (in) 32.d 12,324.0 6751.E 312 Tubing -Gas lnledion IA20 L-8r1 Hyd563 299 Completion Details: excludes tubing, pup, space out, thread, III... Tmp IRKB) Top Onto) IRKBI lxi lncl I°) Nem Des OD Nominal aid Cone Make Model Nominal ID (in) 2,18SA 2,020.5 48.37 Nipple- Landing 3.500 3.5-MCX 12.81-X-Lock set N3003 HER XNipple 2.813 12,241.2 6,710.8 60.68 Mandrel - GAS LIFT 3.51X1 Cameo KBG-2 GEM 2.%2 12,305c 6,742.2 60.45 Seal assembly 3.500 H453-01-0065-Pan No. GBH-22 (Baker) Bonded Locating seal a d embl y 2.992 Tap IRKB) SH Depth...$N 12.28].8 12,]38.5 DzpIM1... String Me... Tubing Description WI(IW Dade Top Connection Isla) 6,92fi.0 312 Tubing - Production 9.30 L-80 EUE MOtl 2.99 Completion Details: excludes tubing, pup, space out, thread, Ill... Top IRKB) TOp Rod) (.Kai Topinsl I°) in Des OD Nominal IIn) Cmm Make Model Nominal ID (in) 12.287.8 6,7337 60.29 PBR 5.020 BAKER ffi80-0O PBR Baker 8040 4.000 12,310S 6745.2 60.51 PACKER 5.960 BAKER PREMIER PACKER Baker Premier 2.970 12,353E 6,765.0 60.89 NIPPLE 4.500 HESX NIPPLE Hellibult On X 2.813 12,396.2 6786.6 61.33 GAS LIFT 5.390 CAMCO,KBMGGLM CAMCO KBMG 2.920 12,44)] 6,811.1 61.9d BLAST RING 4.000 SCC TUBING wI BUST RING INSTALLED, TOP 2992 12,4]6.] 6,824.7 6236 BLAST RING 4.000 SEC TUBING wI BIAST RING INSTALLED, BOTTOM 2.992 12545S 6,855.5 64.65 SLEEVE-C 4.500 BAKER CMD SLIDING SLEEVE wI 2.812-X PROFILE (CLOSED 5252013)-ATTEMPTEDTO OPEN SLEEVE, 42M KEYS DID NOT ENGAGE; UNCERTAIN IF SLEEVE OPENED OR CLOSED (8I132013) 2.810 12,596c 6,8]6.3 66.29 PACKER 5.970 BAKER PREMIER PACKER Baker Premier 2.870 12,6654 6,502.5 69.60 NIPPLE 4.500 HES XN NO GO NIPPLE Halliburl on %N 2.750 12,104.2 6,915.5 71.W LOCATOR 5.010 GI LOCATOR SPACED OUT Baker 7 ABOVE FULLY LOCATED GI 2.960 12,727.1 6.922.6 72.41 SEAL ASSV 3.990 SPACER TUBE SEAL SUB Baker 3.000 12,736.5 6.925.4 72.87 SEAL ASSV 3.980 LOWER SEAL SUBS Baker 3.000 12,738.0 6.925.9 72.94 SHOE 3.9811 MULE SHOE Baker 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top IM1KBI op ITVO)IRKB) Tmph-Hpi Des Co. Make I Model I SN I Run Dine IDIM) 2,TELLE 2,02Q5 48.W 1 INJ VALVE 3.5'MCxon2.81"X-10ck Hallibud on MC% 4301E 51 3I3W2023 1.100 Mandrel Inserts : excludes pulled inserts Top (flK8) TogftKB) lIKBI Be aH Top ed Incl C) No gem Valse Type LrtcM1 Type OD IIn) TRORun ("1) Run Dale Com Make Model port Six tin) 12,241.2 6,710.8 Ol 1 DMV BK 1 0.0 3l2&2023 CA MCO KBMG O.IX10 12.396.2 6.786.6 61.331 4 GOBLET IDMY IBK 1 1 0.0 5UW13 I0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top IRKB) Top KBl (RKe) TOP Ind (°) Icem Do. oD NOgir d ln) Co. Mike Model NomImIID IIn) 12,894.] 6,912.4 )0.90 SLEEVE 5.]90 RED LINER SETTING SLEEVE 5.250 r®� WN$ ]NJ WELLNAME CD3-128 WELLBORE CD3-128 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: WNS CD3-128 (PTD #211-037-0) Gas injection monitor period Date:Wednesday, March 29, 2023 9:39:10 AM Attachments:image001.png CD3-128.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, March 29, 2023 8:00 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com> Subject: WNS CD3-128 (PTD #211-037-0) Gas injection monitor period Chris- WNS injector CD3-128 (PTD #211-037-0) recently had a rig work over completed to mitigate the known TxIA communication while on gas injection. CPAI intends to return the well to gas injection for 30 days to verify the RWO mitigated the known TxIA communication. If TxIA integrity is proven while on gas injection AIO 18C.009 will be canceled and the well will be returned to normal injection status. Attached is the current post RWO well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 12,822.0 CD3-128 8/14/2012 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set ISO sleeve pre RWO CD3-128 3/6/2023 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: Well suspended after original drill/completion 2011; re-entered and drilled deeper, WO, 2012 2/21/2012 osborl General Notes: Last 3 entries Com Date Last Mod By Slickline was unable to pass throught the seal bore assembly with a 2.77 od drift. Ran a 2.77 od comression block and didnt see anything to determine the issue. Ran 2.74 od drift successfully. Ran 2.725 max od rbp and set without issue. 3/18/2023 d142cm Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR INS. 42" 16 15.25 36.8 114.0 114.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 36.4 2,989.0 2,451.1 36.00 J-55 BTC-M PRODUCTION 7 6.28 32.8 13,009.0 6,980.4 26.00 L-80 BTC-M OPEN HOLE 6 1/8 18,685.0 20,387.0 7,082.6 LINER 4 1/2 3.96 12,694.7 18,685.0 7,061.9 12.60 L-80 IBTM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 32.4 Set Depth … 12,324.0 Set Depth … 6,751.6 String Ma… 3 1/2 Tubing Description Tubing – Gas Injection Wt (lb/ft) 9.20 Grade L-80 Top Connection Hyd563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,188.8 2,020.5 48.37 Nipple - Landing 3.500 HES X Nipple 2.813 12,241.2 6,710.8 60.68 Mandrel – GAS LIFT 3.500 Camco KBG-2 GLM 2.992 12,305.0 6,742.2 60.45 Seal assembly 3.500 H453-01-0065 - Part No. GBH-22 (Baker) Bonded locating seal assembl y 2.992 Top (ftKB) 12,287.8 Set Depth … 12,738.5 Set Depth … 6,926.0 String Ma… 3 1/2 Tubing Description Tubing - Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,287.8 6,733.7 60.29 PBR 5.020 BAKER 20' 80-40 PBR Baker 80-40 4.000 12,310.9 6,745.2 60.51 PACKER 5.960 BAKER PREMIER PACKER Baker Premier 2.970 12,353.5 6,766.0 60.89 NIPPLE 4.500 HES X NIPPLE Halliburt on X 2.813 12,396.2 6,786.6 61.33 GAS LIFT 5.390 CAMCO, KBMG GLM CAMCO KBMG 2.920 12,447.7 6,811.1 61.94 BLAST RING 4.000 SCC TUBING w/ BLAST RING INSTALLED, TOP 2.992 12,476.7 6,824.7 62.36 BLAST RING 4.000 SCC TUBING w/ BLAST RING INSTALLED, BOTTOM 2.992 12,545.9 6,855.5 64.66 SLEEVE-C 4.500 BAKER CMD SLIDING SLEEVE w/ 2.812" X PROFILE (CLOSED 5/25/2013) - ATTEMPTED TO OPEN SLEEVE, 4280 KEYS DID NOT ENGAGE; UNCERTAIN IF SLEEVE OPENED OR CLOSED (8/13/2013) 2.810 12,596.0 6,876.3 66.29 PACKER 5.970 BAKER PREMIER PACKER Baker Premier 2.870 12,665.4 6,902.5 69.60 NIPPLE 4.500 HES XN NO GO NIPPLE Halliburt on XN 2.750 12,704.2 6,915.5 71.33 LOCATOR 5.010 GBH-22 LOCATOR SPACED OUT 2' ABOVE FULLY LOCATED Baker GBH-22 2.960 12,727.1 6,922.6 72.41 SEAL ASSY 3.990 SPACER TUBE SEAL SUB Baker 3.000 12,736.5 6,925.4 72.87 SEAL ASSY 3.980 LOWER SEAL SUBS Baker 3.000 12,738.0 6,925.9 72.94 SHOE 3.980 MULE SHOE Baker 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 12,353.0 6,765.7 60.89 PLUG XX PLUG 1/21/2023 0.000 12,353.0 6,765.7 60.89 PACKER Quadco 3½ PIIP RBP. OAL - 8.03 Quadco 3½ PIIP RBP 3/18/2023 BPV Set in tree after u-tue 3/19/2023 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 12,241.2 6,710.8 60.68 1 INJ SOV BK 1" 2,000.0 3/17/2023 Schlumb erger KBMG 12,396.2 6,786.6 61.33 4 GAS LIFT DMY BK 1 0.0 5/7/2013 0.000 HORIZONTAL, CD3-128, 3/24/2023 8:53:05 AM Vertical schematic (actual) OPEN HOLE; 18,685.0-20,387.0 LINER; 12,694.7-18,685.0 PERFP; 18,633.0-18,637.0 PERFP; 18,266.0-18,270.0 PERFP; 17,904.0-17,908.0 PERFP; 17,541.0-17,546.0 PERFP; 17,172.0-17,177.0 PERFP; 16,804.0-16,808.0 FRAC; 13,217.0 PERFP; 16,440.0-16,445.0 PERFP; 16,070.0-16,075.0 PERFP; 15,705.0-15,710.0 PERFP; 15,342.0-15,347.0 PERFP; 14,975.0-14,980.0 PERFP; 14,611.0-14,616.0 PERFP; 14,236.0-14,240.0 PERFP; 13,875.0-13,880.0 PERFP; 13,508.0-13,512.0 PERFP; 13,217.0-13,222.0 PRODUCTION; 32.8-13,009.0 PACKER; 12,596.0 RPERF; 12,476.0-12,496.0 GAS LIFT; 12,396.2 PLUG; 12,353.0 PACKER; 12,310.9 Seal assembly; 12,305.0 Mandrel – GAS LIFT; 12,241.2 SURFACE; 36.4-2,989.0 Nipple - Landing; 2,188.8 CONDUCTOR INS. 42"; 36.8- 114.0 Tubing hanger; 32.4 WNS INJ KB-Grd (ft) 36.80 RR Date 4/30/2011 Other Elev… CD3-128 ... TD Act Btm (ftKB) 20,387.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032063800 Wellbore Status INJ Max Angle & MD Incl (°) 91.79 MD (ftKB) 19,230.70 WELLNAME WELLBORECD3-128 Annotation Last WO: End Date 2/21/2012 H2S (ppm) DateComment SSSV: TRDP Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,694.7 6,912.4 70.90 SLEEVE 5.790 HRD LINER SETTING SLEEVE 5.250 12,706.9 6,916.4 71.45 NIPPLE 5.000 RS PACK-OFF SEAL NIPPLE Baker RS 4.250 13,068.8 6,986.3 85.44 Swell Packer 4.500 TAM FREECAP SWELL PACKER FSC-11 w/ 5.875" OD CEMENTRALIZER TAM 3.920 13,123.3 6,989.7 87.36 Swell Packer 4.500 TAM FREECAP SWELL PACKER FSC-11 w/ 5.875" OD CEMENTRALIZER TAM 3.920 13,174.1 6,991.3 88.90 XO THREAD 4.500 Crossover 4-1/2" 12.6 ppf L-80 SLHT x 4-1/2" 12.6 ppf L-80 IBTM 3.958 18,685.0 7,061.9 89.51 OPEN HOLE 6.125 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 12,476.0 12,496.0 6,824.3 6,833.5 Kuparuk, CD3- 128 5/5/2011 12.0 RPERF 4 5/8" 39 gm, 60 deg phase 13,217.0 13,222.0 6,991.7 6,991.7 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 13,508.0 13,512.0 6,991.7 6,991.7 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 13,875.0 13,880.0 7,000.4 7,000.6 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 14,236.0 14,240.0 7,007.4 7,007.5 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 14,611.0 14,616.0 7,014.2 7,014.2 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 14,975.0 14,980.0 7,015.6 7,015.6 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 15,342.0 15,347.0 7,017.5 7,017.6 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 15,705.0 15,710.0 7,023.3 7,023.4 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 16,070.0 16,075.0 7,023.8 7,023.9 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 16,440.0 16,445.0 7,034.3 7,034.4 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 16,804.0 16,808.0 7,042.3 7,042.3 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 17,172.0 17,177.0 7,044.3 7,044.3 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 17,541.0 17,546.0 7,046.4 7,046.5 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 17,904.0 17,908.0 7,049.1 7,049.2 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 18,266.0 18,270.0 7,052.6 7,052.7 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 18,633.0 18,637.0 7,061.5 7,061.6 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 13,217.0 20,387.0 1 FRAC 3/9/2012 0.0 0.00 0.00 HORIZONTAL, CD3-128, 3/24/2023 8:53:06 AM Vertical schematic (actual) OPEN HOLE; 18,685.0-20,387.0 LINER; 12,694.7-18,685.0 PERFP; 18,633.0-18,637.0 PERFP; 18,266.0-18,270.0 PERFP; 17,904.0-17,908.0 PERFP; 17,541.0-17,546.0 PERFP; 17,172.0-17,177.0 PERFP; 16,804.0-16,808.0 FRAC; 13,217.0 PERFP; 16,440.0-16,445.0 PERFP; 16,070.0-16,075.0 PERFP; 15,705.0-15,710.0 PERFP; 15,342.0-15,347.0 PERFP; 14,975.0-14,980.0 PERFP; 14,611.0-14,616.0 PERFP; 14,236.0-14,240.0 PERFP; 13,875.0-13,880.0 PERFP; 13,508.0-13,512.0 PERFP; 13,217.0-13,222.0 PRODUCTION; 32.8-13,009.0 PACKER; 12,596.0 RPERF; 12,476.0-12,496.0 GAS LIFT; 12,396.2 PLUG; 12,353.0 PACKER; 12,310.9 Seal assembly; 12,305.0 Mandrel – GAS LIFT; 12,241.2 SURFACE; 36.4-2,989.0 Nipple - Landing; 2,188.8 CONDUCTOR INS. 42"; 36.8- 114.0 Tubing hanger; 32.4 WNS INJ CD3-128 ... WELLNAME WELLBORECD3-128 Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request: Change Approved ProgramPull TubingOther StimulatePerforateSuspend Perforate New Pool Re-enter Susp Well Other: Replace TubingAlter CasingPlug for Redrill 5. Permit to Drill Number:4. Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. Well Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? NoWill planned perforations require a spacing exception? Yes Current Pools:10. Field:9. Property Designation (Lease Number): 11. Junk (MD):Plugs (MD):MPSP (psi):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft): None20387' CollapseCasing Structural Conductor Surface Production Liner Open Hole Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch 15. Well Status after proposed work:14. Estimated Date for WDSPLWINJOILCommencing Operations:Suspended WAGGASDate:16. Verbal Approval:SPLUGGSTOR AOGCC Representative: GINJ AbandonedOp Shutdown Contact Name: Contact Email: Contact Phone: Authorized Title: Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? NoYes Spacing Exception Required? Subsequent Form Required:NoYes APPROVED BY Date:COMMISSIONERApproved by:THE AOGCC Sr Res EngSr Pet GeoSr Pet EngComm.Comm. 7083'20387' 12476-12496' Alternating 4.78' Perf Pups: 13217-18637' 1702' 6824-6833' Alternating 4.78' Perf Pups: 6692-7062' 3-1/2" 6-1/8' 16" 9-5/8" 77' 2953' Perforation Depth MD (ft): 4-1/2"5990' 7"12976' 114' 2989' 18685' 6980'13009' 114' 2451' 7062' SizeLength Proposed Pools: BurstTVD PRESENT WELL CONDITION SUMMARY None4401 psi6948'12822'7083' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL25538, ADL372105 211-037 P.O. Box 100360, Anchorage, AK 99510 50-103-20638-00-00 ConocoPhillips Alaska, Inc. CRU CD3-128 Fiord Nechelik Oil PoolFiord Nechelik Oil PoolColville River Field N/A Tubing MD (ft):Tubing Grade: 12311' MD and 6745' TVD 12596' MD and 6876' TVD 2179' MD and 2014' TVD Tubing Size:Perforation Depth TVD (ft): 12738'L-80 Packer: Baker Premier Packer Packer: Baker Premier Packer SSSV: Camco TRMAXX-5E Sfty Vlv 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: AOGCC USE ONLY Sydney Long sydney.long@conocophillips.com (907) 265-6312 RWO/CTD Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 02/28/2023 By Samantha Carlisle at 3:31 pm, Jan 24, 2023 323-041 X X DSR-1/26/23 10-404X DLB 01/25/2023 X BOP test to 4500 psig Annular preventer test to 2500 psig VTL 2/7/2023GCW 02/07/23 JLC 2/7/2023 2/7/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.07 15:18:12 -09'00' RBDMS JSB 020823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 24, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Sydney Long RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over WNS Injector CD3-128 (PTD# 211-037). Well CD3-128 was drilled and completed in 2012 as an producer of the Kuparuk C and Fiord Nechelik. In 2014 it was converted to an injector. The well is currently experiencing tubing by IA leak on MI, limiting it water injection only, and therefore a RWO candidate to regain MI capability. If you have any questions or require any further information, please contact me at 907-265-6321. The tubing will be cut and pulled above the current production packer. A new 3.5" completion, with a non sealing overshot and new packer, will be ran. CD3-128 RWO Procedure Fiord Nechelik Injector Pull and Replace Tubing PTD #211-037 Remaining Pre-Rig Work 1. T&IC-PPPOT and T&IC-POT tests. 2. Set plug in nipple at 12,353’ MD 3. MIT-T, MIT-IA 4. Pull GLV for circulation 5. Prepare well for rig arrival within 48-72 hours of rig arrival. Rig Work MIRU 1. MIRU Doyon 142 on CD3-128. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/4,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing out of seals at 12,283’ Install new 3-½” Tubing 6. MU 3 ½” completion with seal assembly, GLM and nipple profile 7. RIH with completion. Stab into sealbore 8. Space out as needed. Land tubing and RILDS. Test packoffs. 9. Pressure test tubing to 4000 psi for 30 minutes and chart. 10. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 11. Confirm pressure tests, then shear out SOV with pressure differential. 12. Install BPV. Test BPV as needed. 13. ND BOPE. NU tree. 14. Pull BPV, freeze protect well if necessary. 15. RDMO. Post-Rig Work 16. Pull SOV. Install DV 17. MITT 18. Pull plug set in nipple 19. Install A1 injection valve in shallow nipple 20. Turn over to operations. General Well info: Wellhead type/pressure rating:FMC Horizontal, 5M psi top flange Production Engineer:Mark Shulman Reservoir Development Engineer:Adam Childs Estimated Start Date:02/28/2023 Page 1 of 2 CD3-128 RWO Procedure Fiord Nechelik Injector Pull and Replace Tubing PTD #211-037 Page 2 of 2 Workover Engineer: Sydney Long (907-265-6321 / Sydney.Long@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion from sealbore. Run new 3-1/2” completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MITT: planned pre rig MITIA: passed 2/14/22 IC POT & PPPOT planned pre rig TBG POT & PPPOT planned pre rig MPSP: 4401 psi using 0.1 psi/ft gradient Static BHP: 5086 psi / 6851 TVD measured on 1/20/2023 CD3-128 Proposed RWO Completion PROPOSED TUBING COMPLETION •3-½" 9.3# L-80 HYD 563 •3-½" 2.813" DS landing nipple @ ~2,180' MD •3-½" Camco KBMG gas lift mandrel @ ~12,228' MD •3-½" Seal assembly@ ~12,311' MD REMAINING COMPLETION LEFT IN HOLE •Baker Premier Packer w/ 20' PBR @ 12,311' MD •HES 2.813" X Nipple @ 12353' MD •Baker CMD w/ 2.812" X profile @ 12,545' MD •Baker Premier Packer @ 12,596' MD •HES 2.75" XN nipple @ 12,666' MD •GBH-22 locator @ 12,704' 9-5/8" 36# J-66 shoe @ 2,989' MD 7" 26# L-80 shoe @ 13,009' MD 16" 62.5# H-40 shoe @ 114' MD 4.5" 12.6# L-80 Liner 12,695'-18,685' MD Cc V Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 12,822.0 8/14/2012 CD3-128 osborl Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: CORRECTED DV MISSED @12,396' 5/7/2017 CD3-128 pproven Casing Strings Casing Description CONDUCTOR INS. 42" OD (in) 16 ID (in) 15.25 Top (ftKB) 36.8 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.4 Set Depth (ftKB) 2,989.0 Set Depth (TVD) … 2,451.1 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC-M Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 32.8 Set Depth (ftKB) 13,009.0 Set Depth (TVD) … 6,980.4 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-M Casing Description OPEN HOLE OD (in) 6 1/8 ID (in) Top (ftKB) 18,685.0 Set Depth (ftKB) 20,387.0 Set Depth (TVD) … 7,082.6 Wt/Len (l…Grade Top Thread Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 12,694.7 Set Depth (ftKB) 18,685.0 Set Depth (TVD) … 7,061.9 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,694.7 6,912.4 70.90 SLEEVE HRD LINER SETTING SLEEVE 5.250 12,706.9 6,916.4 71.45 NIPPLE RS PACK-OFF SEAL NIPPLE 4.250 12,709.5 6,917.2 71.56 HANGER DG FLEX-LOCK LINER HANGER 4.360 12,718.8 6,920.1 72.01 SBE SEAL BORE EXTENSION 4.000 13,068.8 6,986.3 85.44 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w/ 5.875" OD CEMENTRALIZER 3.920 13,123.3 6,989.7 87.36 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w/ 5.875" OD CEMENTRALIZER 3.920 Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 30.6 Set Depth (ft… 12,738.5 Set Depth (TVD) (… 6,926.0 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 30.6 30.6 0.00 HANGER FMC TUBING HANGER 4.500 115.9 115.9 0.18 XO Reducing CROSSOVER 4.5 x 3.5, 9.3, L-80, EUE-MOD 3.500 2,179.5 2,014.3 48.05 SAFETY VLV CAMCO TRMAXX-5E SAFETY VALVE w/ 2.813" X PROFILE 2.812 12,282.9 6,731.3 60.27 SEAL ASSY BAKER SEAL ASSEMBLY LOCATOR 3.000 12,287.8 6,733.7 60.29 PBR BAKER 20' 80-40 PBR 4.000 12,311.0 6,745.2 60.51 PACKER BAKER PREMIER PACKER 2.970 12,353.6 6,766.0 60.89 NIPPLE HES X NIPPLE 2.813 12,447.7 6,811.1 61.94 BLAST RING SCC TUBING w/ BLAST RING INSTALLED, TOP 2.992 12,476.7 6,824.7 62.36 BLAST RING SCC TUBING w/ BLAST RING INSTALLED, BOTTOM 2.992 12,545.9 6,855.5 64.67 SLEEVE-C BAKER CMD SLIDING SLEEVE w/ 2.812" X PROFILE (CLOSED 5/25/2013) - ATTEMPTED TO OPEN SLEEVE, 4280 KEYS DID NOT ENGAGE; UNCERTAIN IF SLEEVE OPENED OR CLOSED (8/13/2013) 2.810 12,596.0 6,876.3 66.29 PACKER BAKER PREMIER PACKER 2.870 12,665.5 6,902.5 69.60 NIPPLE HES XN NO GO NIPPLE 2.750 12,704.3 6,915.5 71.33 LOCATOR GBH-22 LOCATOR SPACED OUT 2' ABOVE FULLY LOCATED 2.960 12,727.1 6,922.6 72.41 SEAL ASSY SPACER TUBE SEAL SUB 3.000 12,736.5 6,925.4 72.87 SEAL ASSY LOWER SEAL SUBS 3.000 12,738.1 6,925.9 72.94 SHOE MULE SHOE 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 12,476.0 12,496.0 6,824.3 6,833.5 Kuparuk, CD3- 128 5/5/2011 12.0 RPERF 4 5/8" 39 gm, 60 deg phase 13,217.0 13,222.0 6,991.7 6,991.7 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 13,508.0 13,512.0 6,991.7 6,991.7 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 13,875.0 13,880.0 7,000.4 7,000.6 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 14,236.0 14,240.0 7,007.4 7,007.5 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 14,611.0 14,616.0 7,014.2 7,014.2 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 14,975.0 14,980.0 7,015.6 7,015.6 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 15,342.0 15,347.0 7,017.5 7,017.6 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 15,705.0 15,710.0 7,023.3 7,023.4 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 16,070.0 16,075.0 7,023.8 7,023.9 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 16,440.0 16,445.0 7,034.3 7,034.4 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 16,804.0 16,808.0 7,042.3 7,042.3 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 17,172.0 17,177.0 7,044.3 7,044.3 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 17,541.0 17,546.0 7,046.4 7,046.5 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 17,904.0 17,908.0 7,049.1 7,049.2 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS HORIZONTAL, CD3-128, 5/28/2020 4:19:56 PM Vertical schematic (actual) OPEN HOLE; 18,685.0-20,387.0 LINER; 12,694.7-18,685.0 PERFP; 18,633.0-18,637.0 PERFP; 18,266.0-18,270.0 PERFP; 17,904.0-17,908.0 PERFP; 17,541.0-17,546.0 PERFP; 17,172.0-17,177.0 PERFP; 16,804.0-16,808.0 FRAC; 13,217.0 PERFP; 16,440.0-16,445.0 PERFP; 16,070.0-16,075.0 PERFP; 15,705.0-15,710.0 PERFP; 15,342.0-15,347.0 PERFP; 14,975.0-14,980.0 PERFP; 14,611.0-14,616.0 PERFP; 14,236.0-14,240.0 PERFP; 13,875.0-13,880.0 PERFP; 13,508.0-13,512.0 PERFP; 13,217.0-13,222.0 PRODUCTION; 32.8-13,009.0 SHOE; 12,738.1 SEAL ASSY; 12,736.5 SEAL ASSY; 12,727.1 LOCATOR; 12,704.3 NIPPLE; 12,665.5 PACKER; 12,596.0 SLEEVE-C; 12,545.9 RPERF; 12,476.0-12,496.0 GAS LIFT; 12,396.2 NIPPLE; 12,353.6 PACKER; 12,311.0 PBR; 12,287.8 SEAL ASSY; 12,282.9 GAS LIFT; 12,228.6 GAS LIFT; 9,972.6 GAS LIFT; 5,097.5 SURFACE; 36.4-2,989.0 SAFETY VLV; 2,179.5 CONDUCTOR INS. 42"; 36.8- 114.0 HANGER; 30.6 WNS INJ KB-Grd (ft) 36.80 Rig Release Date 4/30/2011 CD3-128 ... TD Act Btm (ftKB) 20,387.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032063800 Wellbore Status INJ Max Angle & MD Incl (°) 91.79 MD (ftKB) 19,230.70 WELLNAME WELLBORECD3-128 Annotation Last WO: End Date 2/21/2012 H2S (ppm) DateComment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 18,266.0 18,270.0 7,052.6 7,052.7 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS 18,633.0 18,637.0 7,061.5 7,061.6 Nechelik, CD3- 128 2/22/2012 1.0 PERFP 4.78' PERF PUPS Frac Summary Start Date 3/9/2012 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 3/9/2012 Top Depth (ftKB) 13,217.0 Btm (ftKB) 20,387.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 5,097.5 3,401.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/1/2013 2 9,972.6 5,588.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/1/2013 3 12,228.6 6,704.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 4/11/2017 4 12,396.2 6,786.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/7/2013 Notes: General & Safety End Date Annotation 5/25/2015 NOTE: ICE PLUG AT 3691 SLM 2/21/2012 NOTE: Well suspended after original drill/completion 2011; re-entered and drilled deeper, WO, 2012 5/3/2011 NOTE: View Schematic w/ Alaska Schematic9.0 HORIZONTAL, CD3-128, 5/28/2020 4:19:57 PM Vertical schematic (actual) OPEN HOLE; 18,685.0-20,387.0 LINER; 12,694.7-18,685.0 PERFP; 18,633.0-18,637.0 PERFP; 18,266.0-18,270.0 PERFP; 17,904.0-17,908.0 PERFP; 17,541.0-17,546.0 PERFP; 17,172.0-17,177.0 PERFP; 16,804.0-16,808.0 FRAC; 13,217.0 PERFP; 16,440.0-16,445.0 PERFP; 16,070.0-16,075.0 PERFP; 15,705.0-15,710.0 PERFP; 15,342.0-15,347.0 PERFP; 14,975.0-14,980.0 PERFP; 14,611.0-14,616.0 PERFP; 14,236.0-14,240.0 PERFP; 13,875.0-13,880.0 PERFP; 13,508.0-13,512.0 PERFP; 13,217.0-13,222.0 PRODUCTION; 32.8-13,009.0 SHOE; 12,738.1 SEAL ASSY; 12,736.5 SEAL ASSY; 12,727.1 LOCATOR; 12,704.3 NIPPLE; 12,665.5 PACKER; 12,596.0 SLEEVE-C; 12,545.9 RPERF; 12,476.0-12,496.0 GAS LIFT; 12,396.2 NIPPLE; 12,353.6 PACKER; 12,311.0 PBR; 12,287.8 SEAL ASSY; 12,282.9 GAS LIFT; 12,228.6 GAS LIFT; 9,972.6 GAS LIFT; 5,097.5 SURFACE; 36.4-2,989.0 SAFETY VLV; 2,179.5 CONDUCTOR INS. 42"; 36.8- 114.0 HANGER; 30.6 WNS INJ CD3-128 ... WELLNAME WELLBORECD3-128 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission rTo: Jim Rper DATE: Wednesday, February 26, 2020 71 47 1P.1. Supervisor I \ G' Z(p &qW SUBJECT: Mechanical Integrity Tests Rel Insp Num: ConocoPhillips Alaska, Inc. CD3 -128 FROM: Brian Bixby COLVILLE RIV FIORD CD3 -128 Petroleum Inspector CD3 -128 Type Inj Ste: Inspector TVD Reviewed By: Tubing P.I. Suprv,TP,2 NON -CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3 -128 API Well Number 50-103-20638-00-00 Inspector Name: Brian Bixby Permit Number: 211.037-0 Inspection Date: 2/25/2020 Insp Num: mi[BD6200226062541 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3 -128 Type Inj w ' TVD 6745 - Tubing 2692 2692 2692 292 2110370 Type Test SPT Test psi 3000 IA 960 3300 3270 3211 - JPTD BBL Pumped: 3.1 - BBL Returned: 3.4 OA 548 766 719 as Interval REQVAR P/F P Notes: MITIA as per AID 18C.009 Wednesday, February 26, 2020 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 20,2018 TO: Jim Regg Z� P.I.Supervisor `� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD3-128 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-128 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 17517--- NON-CONFIDENTIAL V1NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-128 API Well Number 50-103-20638-00-00 Inspector Name: Lou Laubenstein Permit Number: 211-037-0 Inspection Date: 2/11/2018 - Insp Num: mitLOL180212125348 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - -- ----- - -- -- Well 1 CD3-128 I Tubing I 2396 'I' W TVD 2396 I 2396 2397 ' Type Test SPT Test psi 3000 IA 920 3300 ' 3260' 3240 - BBL Pumped: 3 3 IBBL Returned: 3 - OA 576 • 769 , 759 - 751 Interval REQVAR P/F P ✓ Notes: MITIA per AIO 18c.009 to Maximum anticipated injection pressure ./ SCANNED Tuesday,February 20,2018 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Saturday, June 3, 2017 6:07 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: CD3-128 (PTD# 211-037,AA# 18C.009) Update Attachments: CD3-128 90 day TIO 6-3-17.docx Chris, CD3-128 (PTD#211-037, AA# 18C.009) previously had a tubing patch installed to address the TxIA communication that appears during MI injection service. The well passed a state-witnessed MITIA on April 24, 2017 after the patch was set. The well was then put on a 30-day MI injection monitor period to demonstrate that the patch had restored tubing integrity to gas. Approximately two weeks into the MI monitor period, the IA pressure indicated that the TxIA communication on gas had not been eliminated by the patch. CPAI subsequently WAG'd the well to water. At present, the well is and will continue injecting only water in accordance with AA# 18C.009. If CPAI decides to pursue another option,the necessary paperwork/notifications will be submitted at that time. Attached is a 90-day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNaa JUN , 22017 • I N accw w woD y LOo g •idaT 1 Y N r_co W N CC O. 'O o x W m yoo W 00 0 G CCU, N N- W O O _, N h V N N G co co (NI CsJ J M W p p V U EJ El El El L3 It r, El 36aj SWPE 1 / es r- Z � V O C es es d � O = t`z 2 N N e O O • N O, O I a.qqu o I e- �S n — t w p ..:• n76 'vs un �Ow isd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: P.I. DATE: Wednesday,May 03,2017 Jim Regg PSupervisor t��1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-1 28 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-128 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry r:77->e— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-128API Well Number 50-103-20638-00-00 Inspector Name: Lou Laubenstein Permit Number: 211-037-0 Inspection Date: 4/24/2017 Insp Num: mitLOL170425104217 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-128 - Type Inj W . TVD 6745 - Tubing 1950 1950 _ 1950 - 1950 - PTD 2110370 Type Test SPT Test psi 3000 IA 80 3300 - 3260 - 3250 - BBL Pumped: a5 - BBL Returned: 4 5 - OA 540 810 - 810 - 810 - Interval OTHER 1P/F P Notes: MITIA post patch per Sundry 317-135,MITIA to MAIP SCANNED AuG AUG2 4 2017 Wednesday,May 03,2017 Page 1 of 1 P ® 2\�-03'1 R ECEIVE • MAY 10 2017 WELL LOG TRANSMITTAL# AOGCC To: Alaska Oil and Gas Conservation Comm. April 12, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED /%/2011 Anchorage, Alaska 99501 M.K.BENDER RE: Leak Detect Log with ACX: CD3-128 Run Date: 3/4/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-128 Digital Data in LAS format,Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20638-00 Leak Detect Log with ACX 1 Color Log 50-103-20638-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. m AT 2 6 it! Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:f ,,a/2124t� „EAk; STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COMIIOION MAY 0 8 2017 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LiPlug Perforations U Fracture Stimulate LIPull Tubing LiAOaTrons shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Tubing Patchn 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska,Inc. Development ❑ Exploratory ❑ 211-037 3.Address: P.O.Box 100360 Stratigraphic ❑ Service Q 6.API Number: Anchorage,AK 99510 50-103-20638-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025538,ADL0372105 CRU CD3-128 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 20387 feet Plugs measured NA feet true vertical 7083 feet Junk measured NA feet Effective Depth measured 20387 feet Packer measured 12311 feet true vertical 7083 feet true vertical 6745 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16 114' 114' Surface 2953' 9-% 2989' 2451' 3520 2020 Intermediate Production 12976' 7 13009' 6980' 7240 5410 Liner 5990' 4-'/2 18685' 7062' 7780 6350 Perforation depth Measured depth 13217-20387 feet .rVyi �y'�_� '„-N�� True Vertical depth 6824-7083 feet Tubing(size,grade,measured and true vertical depth) 3-'/z' L-80 12739'MD 6926'TVD Patch: Weatherford WP LE 2156'MD 1999'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier 12311'MD 6745'TVD SSSV: Camco TRMAXX-5E 2180'MD 2014'TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data . Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development❑ Service [] Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-135 Authorized Name: Travis Smith Contact Name: Travis Smith/Rachel Kautz Authorized Title: We ity Supervi •r Contact Email: N2549@cop.com Authorized Signature: 'llreio Date: ,>A/7 Contact Phone: 265-7126 v'ri..- 5/ib /1 Form 10-404 Revised 4/2017 RBDMS 1.V t.-", ? - 9 2017 Submit Original Only / ?X% n.,r. • • Recent Well History CD3-128 Con+ccoPhillips`, Legal WellName API/UWI Field Name CD3-128 5010320638 FIORD NECHELIK Well Type Orig KB/RT(ft) Well Status Development 49.40 INJ Start Date Last 24hr Sum 4/24/2017 STATE WITNESS MIT-IA**PASSED**TO 3300 PSI,PUMPED 4.5 BBLS DSL DWN IA TO REACH TEST PRESSURE, 1ST 15 MIN IA LOST 40 PSI,2ND 15 MIN IA LOST 10 PSI,BLED BACK 4.5 BBLS,(JOB COMPLETE) 4/24/2017 (SW)SW-MITIA(LOU LAUBENSTEIN)PASSED TO 3300 PSI. 4/13/2017 SET 24.55'x 3 1/2"WEATHERFORD PATCH ASS'Y(WP LE PACKER,17.8'SPACER PIPE,2.82"NO-GO,AND SEAL STINGER)@ 2156'RKB. COMPLETE. 4/12/2017 SET DV @ 12,228'RKB. MITIA 2500 PSI(PASSED). PULLED AVA CATCHER FROM XX PLUG. PULLED 2.81"XX PLUG FROM 12,354'RKB. GAUGED TBG 2.84"TO 2179'RKB. IN PROGRESS. 4/11/2017 CIRCOUT DWN TBG TAKING RETURNS UP IA,355BBL CRW-SW&8OBBL DSL,U-TUBE FREEZE PROTECT TBGXIA,(JOB COMPLETE) 4/11/2017 BRUSHED&FLUSHED TBG TO 12,354'RKB. SET 2.81"XX PLUG @ 12,354'RKB, SET 2.75"AVA CATCHER ON PLUG. PULLED DV FROM 12,228'RKB. READY FOR CIRC OUT. IN PROGRESS. Page 1/1 Report Printed: 5/3/2017 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(a.alaska.gov; AOGCC.Inspectors(aialaska.clov; phoebe.brooksAalaska.gov chris.wallace(oalaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD!UNIT/PAD: Alpine/CRU/CD3 PAD DATE: 04/24/17 OPERATOR REP: Miller/Beck AOGCC REP: Lou Laubenstein Well CD3-128 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2110370 Type Inj W Tubing 1950 1950 1950 1950 Type Test P Packer TVD 6745 BBL Pump 4.5 IA 80 3300 3260 3250 Interval 0 Test psi 3000 BBL Return 4.5 OA 540 810 810 810 Result P Notes: MITApost patch per Sundry#317-135 AIO 18C.009 MIT-IA to maximum anticipated injection pressure Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT CRU CD3-128 04-24-17.xlsx I.'" WNS INJ • CD3-128 Conocoi'hillipsL&. Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) erp 501032063800 FIORD NECHELIK INJ 9179 19,230.70 20,387.0 ... Comment H25(ppm) Date Annotation End Date K9-Grd(ft) Rig Release Date HORIZONTAL-CD3-128.5/1/2017700:04 PM SSSV:TRDP Last WO: 2/21/2012 36.80 4/30/2011 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;30.6 7--,v7.gT Last Tag:SLM 12,822.0 8/14/2012 Rev Reason:GLV CIO&SET PATCH pproven 5/1/2017 `i. 7....._._..Casing Strings - Casing Description OO(in) ID(in) Top(ftKR) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ............_................__._...........,............. CONDUCTOR INS.42" 16 15.250 36.8 114.0 114.0 62.50 H-40 WELDED -- ' PI-- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WELen(I...Grade Top Thread SURFACE 95/8 8.921 36.4 2,989.0 2,451.1 36.00 J-55 BTC-M CONDUCTOR INS.42%38,8- 4.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread _ PRODUCTION 7 6.276 32.8 13,009.0 6,980.4 26.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)..,Wt/Len(I...Grade Top Thread PATCH;2,758.0 OPEN HOLE 61/8 18,685.0 20,387.0 7,082.6 SAFETY VLV;2,179.5 ► , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 12,694.7 18,685.0 7,061.9 12.60 L-80 /BTM Liner Details Nominal ID SURFACE;36,4-2,989,0-1 Top(910) Tap(TVD)(ftKB) Top Incl(°) Item Dec Com (in) 12,694.7 6,912.4 70.90 SLEEVE HRD LINER SETTING SLEEVE 5250 GAS LIFT;5,097.5 a 12,706.9 6,916.4 71.45 NIPPLE RS PACK-OFF SEAL NIPPLE 4.250 12,709.5 6,917.2 71.56 HANGER DG FLEX-LOCK LINER HANGER 4.360 0 12,718.8 6,920.1 72.01 SBE SEAL BORE EXTENSION 4.000 GAS LIFT;9,972.6 13,068.8 6,988.3 85.44 Swell Packer TAM FREECAP SWELL PACKER FEC-11 w/5,875" 3.920' ® OD CEMENTRALIZER GAS LIFT;12,228.6 IC 13,123,3 6,989.7 87.38 Swell Packer TAM FREECAP SWELL PACKER FEC-11 w/5.875" 3.920 OD CEMENTRALIZER SEAL ASSY;12,282.9 I. Tubing Strings PBR;12,287.6 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 3 1/2 2.992 30.6 12,738.5 6,926.0 9.30 L-80 EUE Mod PACKER;12,311.0 2' Completion Details Nominal ID NIPPLE;12,353,6 Top MOB) Top(TVD)(ftKB) Top Ino/(°) Item Des Com (in) 30.6 30.6 0.00'HANGER FMC TUBING HANGER 4,500 GAS LIFT;12,398.2 I,, 115.9 115,9 0.18 XO Reducing CROSSOVER 4.5 x 3.5,9.3,L-80,EUE-MOD 3.500 tt 2,179.5 2,014.3 48.05 SAFETY VLV CAMCO TRMAXX-5E SAFETY VALVE w/2.813"X 2.812 PROFILE RPERF;72,476.0-12,4R0.0 -. 12 282.9 6,731.3 60.27 SEAL ASSY BAKER SEAL ASSEMBLY LOCATOR 3.000 8= NE 12,287.8 6,733.7 60.29 PBR BAKER 2V 80-40 PBR 4.000 SLEEVE-C;12,545,9 6 ) 12,311.0 6,745.2 60.51 PACKER BAKER PREMIER PACKER 2.970 IM 12,353.6 6,766.0 60.89 NIPPLE HES X NIPPLE 2.813 PACKER;12,596.0 12,447.7 6,811.1 61.94 BLAST RING SCC TUBING wl BLAST RING INSTALLED,TOP 2.992' NIPPLE;12,665.5PIM 12,476.7 6,824.7 62.36 BLAST RING SCC TUBING w/BLAST RING INSTALLED,BOTTOM 2.992 l 12,545.9 6,855.5 64.67 SLEEVE-C BAKER CMD SLIDING SLEEVE w/2.812'X PROFILE 2.810 LOCATOR;12,704.3 (CLOSED 5/25/2013)-ATTEMPTED TO OPEN SLEEVE, 4280 KEYS DID NOT ENGAGE;UNCERTAIN IF SLEEVE OPENED OR CLOSED(8/13/2013) SEAL ASSY;12,727.1 -- SEAL ASSY;1z,736.sMI 12,596.0 6,876.3 66.29 PACKER . BAKER PREMIER PACKER 2.870 SHOE;12,738.1 M 12,665.5 6,902.5 69.60 NIPPLE HES XN NO GO NIPPLE 2.750 12,704.3 6,915.5 71.33 LOCATOR GBH-22 LOCATOR SPACED OUT 2'ABOVE FULLY 2.960 • LOCATED 12,727.1 6,922.6 72,41 SEAL ASSY SPACER TUBE SEAL SUB 3.000 PRODUCTION;32,8-13,009.0 12,736.5 6,925.4 72.87 SEAL ASSY LOWER SEAL SUBS 3,000 12,738.1 6,925.9 72.94 SHOE MULE SHOE 3.000 rarl Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top incl Top(ftKB) (809) (°) Des Com Run Date 10(in) 2,156.0 1,998,5 4724 PATCH WEATHERFORD PATCH ASS'Y(31/2"UPPER WP 1/20/2016 1.750 LE PACKER,17.8'SPACER PIPE,2.82"NO-GO, PERFP;13,217.0-13,222.0 AND SEAL STINGER)(PATCH OAL=24.55',MIN ID =1.75') PERFP;13,508.0-13,512.0 ;N� i Perforations&Slots [= Shot Dens j PERFP;13,875,0-13,880.0 Itili Ill Top(RKB) Stat(ftKB) Top(ftKB)u) B ) (sh DIKED Zone Date t) Type Com 7 12,476.0 12,496.0 6,824.3 6,833.5 Kuparuk,CD3 5/5/2011 12.0 RPERF 4 5/8"39 gm,60 deg PERFP;74,236.0-14,2411.0 4;I; -128 phase IIIII 13,217.0 13,222.0 6,991.7 6,991.7 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;14,611,0-14,616,0 ;ISI;I -126 - 13,508.0 13,512.0 6,991.7 6,991.7 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;14,975.0-14,980.0 (El' -128 t t 13,875.0 13,880.0 7,000.4 7,000.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;15,342.0-15,347.0 Mir -128 Ell PERFP;75,705.0-15,770.0 - 14,236.0 14,240.0 7,007.4 7,007.5 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS 1 -128 III PERFP;78,070.0-16,575.0 14,611.0 14,616.0 7,014.2 7,014.2 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS igil' -128 El 14,975.0 14,980.0 7,015.6 7,015.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;16,440.0-18,445,0 i{({) -126 FRAC;13,217.0 In(j 15,342.0 15,347.0 7,017.5 7,017.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS lt�t� PERFP;16,804.0-16,808.0 -128 MI t 15,705.0 15,710.0 7,023.3 7,023.4 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;17,172.0-17177.0 :I{{:yy:' -128 SUf PERFP;17,541.0-77,546.0 16,070.0 16,075.0 7,023.8 7,023.9 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS IMM -128 PERFP;17,904.0-17,908,0 - Mt. 16,440.0 16,445.0 7,034.3 7,034.4 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;18,268.0.78,270.0 SIRE -128 -" 16,804.0 16,808.0 7,042.3 7,042.3 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;18,633,0-18,637,0 a , -128 LINER;12,694.7-18,685.0 ---Y1- ° OPEN HOLE;18,685,0-20,387.0 SINS INJ CD3-128• r ` ConotoP;hillips At -, Alaska,Inc. •• HORIZONTAL-CD3-128,5/1/2017 7:00:06 PM Vertical schematic(actual) HANGER;30.6-■FCU ti b+9 1 L�I -perforations&Slots Shat Dens • , r - Top(MB) Btm(DEB) Top(ftKD) ) B B) fttm KB D) Zone Date (shutoffl' Type Com CONDUCTOR INS.42';369-_. s i 17,172.0 17,177.0 7,044.3 7,044.3 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS 114.0 _'- -128 17,541.0 17,546.0 7,046.4 7,046.5 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PATCH;2,156.0 -128 SAFETYVLV;2,179.5 rte; 17,904.0 17,908.0 7,049.1 7,049.2 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 1 I 18,266.0 18,270.0 7,052.6 7,052.7 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 SURFACE;36.4-2,989,0_A 18,633.0 18,637.0 7,061.5 7,061.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS GAS LIFT;5,097.5 -; -128 Stimulations R Treatments r= Proppant Designed(Ib) I Proppant In Formation(Ib) I Date 3/9/2012 GAS LIFT;9,972.6 [ Stimulations&Treatments Slg 8 I Top MKS) I Blm(kVol CleanKB) Date I StimlTront Fluid (bbl)Pump Vol Slurry(bbl) GAS LIFT;12.226.6 1 • 1 13,217.0 20,387.0 3/9/2012 Mandrel Inserts SEAL ASSY;12,2829 St PBR;12,287.8 ) jati an Top(NO) Valve Latch Port Size TRO Run PACKER;12,311.0 N Top(kKB) (68KB) Make Model 00119) Sere Type Type on) (psi) Run Date Com 1 5,097.5 3,401.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/1/2013 NIPPLE;12,353.6 2 9,972.6 5,588.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/1/2013 3 12,228.6 6,704.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 4/11/2017 GAS LIFT;12,396.2 4 12,396.2 6,786.6 CAMCO KBMG 1 GAS LIFT HFCV BEK 0.000 0.0 8/13/2012 Notes:General&Safety End Date Annotation RPERF;72,478.0-12,495.0-� 5/3/2011 NOTE:View Schematic w/Alaska Schematic9.0 2/21/2012 NOTE:Well suspended after original drill/completion 2011;re-entered and drilled deeper,WO,2012 SLEEVE-C;12,545.9 1 I 5/25/2015 NOTE:ICE PLUG AT 3691 SLM PACKER;12,596.0 NIPPLE;12,665.5 LOCATOR;12,704.3 1 i 9I SEAL ASSY;12,727.1 SEAL ASSY:12,736.5, MN SHOE;12,738.1 Ili PRODUCTION;32.8-13,009.0 I PERFP;13,217.0-13,222.0 I lir PERFP;13,508.0-13,512.0 _;'.)7!{j PERFP;13,876.0-13,880.0 MIN in 11111 PERFP:14,236.0-14,240.0 )Illi PERFP;14,611.0-14,618.0 '[el) PERFP;14,975.0-14,980.0 :11: IIII PERFP;15,342.0-15,347.0 gni :: : PERFP;15,705.0-15,710.0 :lelij. PERFP;18,070.0-16,075.0 .1 PERFP;16,440.0-16,445.0 i FRAC;13,217.0 '- PERFP;16,004.0-16,808.0 PERFP;17,172.0-17,177.0 �ig- ;Ll: PERFP;17,541.0-17,546.0Egg PERFP;17,904.0.17,908.0Mg PERFP;18,266.0-18,270.0 Ili 111111 PERFP;18,633.0-18,637.0 •(a1• LINER;12,694.7-18,685.0 f OPEN HOLE;18,685.0-20,387.0 I • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, May 2, 2017 10:37 AM To: NSK Well Integrity Supv CPF3 and WNS Cc: Senden, R.Tyler Subject: RE:CRU CD3-128 (PTD#211-037) Travis, As discussed on the phone yesterday and in this email, I agree with the approach outlined below and feel it prudent to verify the integrity to MI before looking to modify or cancel the existing AA. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907) 276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Well Integrity Supv CPF3 and WNS [mailto:n2549@conocophillips.com] Sent:Tuesday, May 2, 2017 8:45 AM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:CRU CD3-128(PTD#211-037) SCANNED MAY 1 0 201, Chris— CRU injection well CD3-128(PTD#211-037) had a tubing patch installed (Sundry number 317-135)to address a leak that was observed on gas injection service. After the patch was installed,the well passed a State-witnessed MIT-IA on April 24, 2017. Currently,CD3-128 operates under AIO 18C.009 which allows only water injection. The patch procedure was intended to eliminate the TxIA communication on gas service. In order to demonstrate the tubing patch is competent in gas injection service,CPAI would like a 30-day monitoring period of MI injection. If this monitoring period is successful,we will apply for a cancellation of the AA. If the well still shows TxIA communication on gas injection,we will notify the AOGCC and continue to operate as a water-only injection well. Please advise if this plan is acceptable. Thank you very much, Travis Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 i • 8.,OF T�� • SAP\�\�I/j,* THE STATE Alaska Oil and Gas ft 0„s__ 11 of ® Conservation Commission k:it Sitz i� 333 West Seventh Avenue 'Ir t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "4 Main: 907.279.1433 O4bALAgY'� Fax: 907.276.7542 www.aogcc.alaska.gov Travis Smith Well Integrity Supervisor ConocoPhillips Alaska, Inc. „:, t P.O. Box 100360 SCA%�ED ' ; • �= ,1, .3 Anchorage,AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3-128 Permit to Drill Number: 211-037 Sundry Number: 317-135 Dear Mr. Smith: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,4,1e,t ,6-- Cathy P. oerster Chair DATED this 4- ay of April, 2017. RBDMS C.' - APR - 4 2017 • RECEIVED . STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 3 1 2017 APPLICATION FOR SUNDRY APPROVALS 4O/GGC 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well [ Operations shutdow n r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r I- pthe7 /-34leJ rV" 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 211-0370 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20638-00 ' 7.If perforating, NA 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No II pf3 CRU CD3-128 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025538 ADL0372105 ' Colville River Field/Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective DepthMp: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 20387 7083 4o 3s? 7 0E5' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16 114' 114' SURFACE 2953' 9 5/8 2989' 2451' 3520 2020 PRODUCTION _ 12976' 7 13009' 6980' 7240 5410 LINER 5990' 4 1/2 18685' 7062' 7780 6350 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Perf Pups: 13217'-18637' " 6824'-7062' 3 1/2 L-80 12737' Open Hole: 18685'-20387' - 7062'-7083' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SAFETY VLV=CAMCO,TRMAXX-5E SSSV w/2.813"X"Profile MD=2170'TVD=2008' PACKER=BAKER PREMIER PACKER MD=12311'TVD=6745' 12.Attachments: Proposal Summary p7 WellBore Schematic 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service Iv' 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: 04/03/17 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG ^ GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Travis Smith/Rachel Kautz Printed Name Travis Smith Phone:659-7126 Email: n2549(c�conocophillips.com C,// Title: Well Integrity Supervisor /7%,Signature / Date: jAylz. Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Ski— 13;- :-aC'C- LI k Its Rug Integrity r BOP Test r Mechanical Integrity Test Location Oearance !— Other: RBDMS l L PR - 4 2011 Post Initial Injection MIT Req'd? Yes No r Spacing Exception Required? Yes r No r,/ Subsequent Form Required: w L— 4 - APPROVED BY Approved by: / 1)141)/iii---4-/4-/if COMMISSIONER THE COMMISSION Date:4,.. 4'— '7 �'r� y 3 /7- 7 L 4-/4/1 7-- o RivGliN.A Subsin Form ane Form 10-403 Revised 11/2015 alid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPh i l l i ps RECEIVED Alaska MAR 31 2017 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AO CC March 24, 2017 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 from ConocoPhillips Alaska, Inc. well CD3-128 (PTD#211- 0370) for a proposed retrievable tubing patch. Please contact Travis Smith or Rachel Kautz at 659-7126 if you have any questions. Sincerely, 14 Ail 41f Travis Smith Well Integrity Supervisor ConocoPhillips Alaska, Inc. • CD3-128 DESCRIPTION SUMMARY OF PROPOSAL Tubing Patch for CRU CD3-128: CRU CD3-128 (PTD#211-0370) is currently a water-only injection well under AIO 18C.009 because of TxIA communication on gas injection. Recently CPAI ran an acoustic leak detect log with the tubing filled with nitrogen. This LDL indicated a leak was present in the well at 2,169' RKB in the top connection of a pup joint just above the SSSV. CPAI proposes setting a retrievable tubing patch over the leak found on the LDL. Because the well routinely passes MITIAs when on water service, we propose a 30-day monitoring period on MI injection after the patch has been set. If no communication is seen on MI injection, we propose to return the well to normal WAG injection service. . WNS INJ CD3-128 • ConocoPhillips it Well Attributes Max Angle&MD TD Alaska,Inc, We Ignore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r.vocowvMpc 501032063800 FIORD NECHELIK INJ 91.79 19,230.70 20,387.0 """ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date HORIZONTAL-CD3-128,2/1220161:31:00 PM SSSV:TRDP Last WO: 2/21/2012 36.80 4/30/2011 vanicel schematic(actual) Annotation Depth(ftKB) End Data Annotation Last Mod By End Date HANGER;30.6 Feyy.p-�■ Last Tag:SLM 12,822.0 8/14/2012 Rev Reason:PULL,PLUG,FISH,MILLED ICE pproven 2/16/2016 PLUG 1 ' Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread IC1. 1111 , CONDUCTOR Insulated 16 15.250 36.8 114.0 114.0 62.50 H-40 WELDED `._ 1 42" IlI Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 4z.: SURFACE 95/8 8.921 36.4 2,989.0 2,451.1 36.00 J-55 BTC-M 36.8-114.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TOO)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 32.8 13,009.0 6,980.4 26.00 L-80 BTC-M Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SAFETY VLV;2,179.5 ® OPEN HOLE 61/8 18,685.0 20,387.0 7,082.6 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TOO)...Wt/Len(I...Grade Top Thread 1 LINER 41/2 3.958 12,694.7 18,685.0 7,061.9 12.60 L-80 IBTM Liner Details SURFACE;36.4-2,989.0- Nominal ID GAS LIFT;5,097.5 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 12,694.7 6,912.4 70.90 SLEEVE HRD LINER SETTING SLEEVE 5.250 12,706.9 6,916.4 71.45 NIPPLE RS PACK-OFF SEAL NIPPLE 4.250 GAS LIFT;9,972.6 -.._1H 12,709.5 6,917.2 71.56 HANGER DG FLEX-LOCK LINER HANGER 4.360 12,718.8 6,920.1 72.01 SBE SEAL BORE EXTENSION 4.000 GAS LIFT;12,228.6 13,068.8 6,986.3 85.44 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w/5.875" 3.920 OD CEMENTRALIZER SEAL HOST'12.2132s - 13,123.3 6,989.7 87.36 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w/5.875" 3.920 OD CEMENTRALIZER PER;12,287.8 PACKER;12,311.0 I Tubing Strings Tubing Description String Ma...ID(in) Top(ft613) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 31/2 2.992 30.6 12,738.5 6,926.0 9.30 L-80 EUE Mod NIPPLE;12,353.6 L,. Completion Details GAS LIFT;12,396.2 Nominal ID Top(OKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) ' 30.6 30.6 0.00 HANGER FMC TUBING HANGER 4.500 a 115.9 115.9 0.18 XO Reducing CROSSOVER 4.5 x 3.5,9.3,L-80,EUE-MOD 3.500 RPERF;12,476.0-12,456.0 II-or 2,179.5 2,014.3 48.05 SAFETY VLV CAMCO TRMAXX-5E SAFETY VALVE w/2.813"X 2.812 ___ PROFILE SLEEVE-C;12,545.9 -- 12,282.9 6,731.3 60.27 SEAL ASSY BAKER SEAL ASSEMBLY LOCATOR 3.000 12,287.8 6,733.7 60.29 PBR BAKER 20'80-40 PBR 4.000 PACKER;12,596.0 - 12,311.0 6,745.2 60.51 PACKER BAKER PREMIER PACKER 2.970 Pli12,353.6 6,766.0 60.89 NIPPLE HES X NIPPLE 2.813 NIPPLE;12,665.5 12,447.7 6,811.1 61.94 BLAST RING SCC TUBING w/BLAST RING INSTALLED,TOP 2.992 le i 12,476.7 6,824.7 62.36 BLAST RING SCC TUBING w/BLAST RING INSTALLED,BOTTOM 2.992 LOCATOR;12,704.3 1- 12,545.9 6,855.5 64.67 SLEEVE-C BAKER CMD SLIDING SLEEVE w/2.812"X PROFILE 2.810 l,f. (CLOSED 5/25/2013)-ATTEMPTED TO OPEN SLEEVE, 4280 KEYS DID NOT ENGAGE;UNCERTAIN IF SEAL ASSY;12,727.1 ; SLEEVE OPENED OR CLOSED(8/13/2013) SEAL ASSY;12,736.5 la SHOE;12,738.1 12,596.0 6,876.3 66.29 PACKER BAKER PREMIER PACKER 2.870 12,665.5 6,902.5 69.60 NIPPLE HES XN NO GO NIPPLE 2.750 I I 12,704.3 6,915.5 71.33 LOCATOR GBH-22 LOCATOR SPACED OUT 2'ABOVE FULLY 2.960 ILOCATED PRODUCTION;32.8-13,009.0- 12,727.1 6,922.6 72.41 SEAL ASSY SPACER TUBE SEAL SUB 3.000 12,736.5 6,925.4 72.87 SEAL ASSY LOWER SEAL SUBS 3.000 LI12,738.1 6,925.9 72.94 SHOE MULE SHOE 3.000 Perforations&Slots Shot Dens PERFP;13,217.0-13,222.0 I1.. Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com Ill 12,476.0 12,496.0 6,824.3 6,833.5 Kupamk,CD3 5/5/2011 12.0 RPERF 4 5/8"39 gm,60 deg PERFP;13,508.0-13,512.0 '44' -128 phase III13,217.0' 13,222.0 6,991.7 6,991.7 Nechelik,CD3 2/22/2012 1.0'PERFP 4.78'PERF PUPS PERFP;13,875.0-13,880.0 a -128 El 13,508.0 13,512.0 6,991.7 6,991.7 Nechelik,CD3 2/22/2012 1.0'PERFP '4.78'PERF PUPS PERFP;14,236.0-14,240.0 ;1�t1 1; -128 13,875.0 13,880.0 7,000.4 7,000.6 Nechelik,CD3 2/22/2012 1.0 PERFP -4.78'PERF PUPS PERFP;14,811.0-14,616.0 -� -128 '81' 14,236.0 14,240.0 7,007.4 7,007.5 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS . -128 PERFP;14,975.0-14,980.0 ,i,1 14,611.0 14,616.0 7,014.2 7,014.2 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS III -128 PERFP;15,342.0-15,347.0 1'1: 14,975.0 14,980.0 7,015.6 7,015.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS El -128 PERFP;15,705.0-15,710.0 '°��(, � 15,342.0 15,347.0 7,017.5 7,017.6 Nechelik,CO3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;16,070.0-16.075.0 1'k 15,705.0 15,710.0 7,023.3 7,023.4 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS - -128 PERFP;16,440.0-18,445.0 II;�:,I 16,070.0 16,075.0 7,023.8 7,023.9 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS FRAC;13,217.0 �t -128 PERFP;16,804.0-16,808.0 �:�[Y}' 16,440.0 16,445.0 7,034.3 7,034.4 Nechelik,CD3'2/22/2012 1.0 PERFP 4.78'PERF PUPS III -128 PERFP;17,172.0-17,177.0 Eli . 16,804.0' 16,808.0 7,042.3 7,042.3 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS • -128 PERFP;17,541.0-17,546.0 -INN 33Is 17,172.0 17,177.0 7,044.3 7,044.3 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;17,904.0-17,908.0 i 11:F1:', -128 PERFP;18,266.0-18,270.0 :1:1? ; 17,541.0 17,546.0 7,046.4 7,046.5 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;18,633.0-18,637.0 17,904.0 17,908.0 7,049.1 7,049.2 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS ; ;' -128 LINER,12,694.7-18,885.0 OPEN HOLE;18,685.0-20,387.0 ....-.. • WNS INJ CD3-128 • ConocoPhillips 4 Alaska,Inc. CvncaPl■1pc ••• HORIZONTAL-CD3-128,2/12/20161:31:04 PM Vertical schematic(actual) HANGER;30.6-■:- - ■ .• Perforations&Slots Shot ........ ._.. ..... ..._ Dens .fat Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone _ Dale t) Type Com CONDUCTOR Insulated 4z; 18,266.0 18,270.0 7,052.6 7,052.7 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS 36.8-114.0 ' -128 18,633.0 18,637.0 7,061.5 7,061.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 SAFETY VLV;2,179.5 Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) SURFACE;36.4-2,989.0 (ftKB) (6KB) (ftKB) (ftKB) Type Date Com 13,217.0 20,387.0 6,991.7 7,082.6 FRAC 3/9/2012 Performed fracturing treatment,pumping five main GAS LIFT;6097.5 frac stages consisting of 0-6 ppa stages separated by four Bioball ball drop sequences.Pumped 220-bbl breakdown with 25-lb linear gel,followed by main frac of 467,219-lbs of 16/20 Carbolite in 259 crosslink gel -J � (87%design).During last frac stage,extended the 4- GAS LIFT;9,972.6 A ppa stage to 420-bbl Mandrel Inserts GAS LIFT;12,228.6 St ati To Valve Latch Port Size TRO Run "` on MIN SEAL ASSY;12,282.9 p D) N. Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Dale Com MR;12,287.8 1 5,097.5 3,401.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/1/2013 PACKER;12,311.0 2 9,972.6 5,588.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/1/2013 • 3 12,228.6 6,704.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/5/2013 NIPPLE;12,353.6r 4 12,396.2 6,786.6 CAMCO KBMG 1 GAS LIFT HFCV BEK 0.000 0.0 803/2012 { Notes:General&Safety GAS LIFT;12,396.2 End Dale Annotation 5/3/2011 NOTE:View Schematic w/Alaska Schematic9.0 2/21/2012 NOTE:Well suspended after original drill/completion 2011;re-entered and drilled deeper,WO,2012 RPERF;12,476.0-12,496.0 5/25/2015 NOTE: ICE PLUG AT 3691 SLM SLEEVE-C;12,545.9 � PACKER;12,596.0 _" NIPPLE;12,665.5 LOCATOR;12,704.3 1:11111= SEAL ASSY;12,727.1 SEAL ASSY;12,736.5 . IPP SHOE;12,738.1 ft I I I I PRODUCTION;32.8-13,009.0 PERFP;13,217.0-13,222.0 ;.'.�. 1111 PERFP;13,508.0-13,512.0 11 f1. PERFP;13,875.0-13,880.0 (I.I)■■ Ill(lltf PERFP;14,236.0-14,240.0 :C1r PERFP;14,611.0-14,818.0 :4I: PERFP;14,975.0-14,980.0 ■ PERFP;15,342.0-15,347.0 '.151: PERFP;15,705.0-15,710.0 1111 PERFP;16,070.0-16,075.0 , lull■ PERFP;16,440.0-16,446.0 FRAC;13,217.0 PERFP;16,804.0-16,808.0 :I� PERFP;17,172.0-17,177.0 .IEE mmo PERFP;17,541.0-17,546.0 PERFP;17,904.0-17,908.0 tl/li PERFP;18,266.0-18,270.0 { 111 PERFP;18,633.0-18,637.0 LINER;12,694.7-18,685.0 OPEN HOLE;18,685.0-20,387.0 .. .. • • Bettis, Patricia K (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Friday, March 31, 2017 10:22 AM To: Bettis, Patricia K (DOA) Subject: RE: CRU CD3-128 (PTD 211-037): Sundry Application Hello Patricia— The open hole of CD3-128 has not been plugged back or otherwise limited. Effective Depth: 20,387' MD, 7,083'TVD Sorry about that omission. Please let me know if you need any other information. Thanks very much! Travis From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, March 31, 2017 10:05 AM To: NSK Well Integrity Supv CPF3 and WNS<n2549@conocophillips.com> Subject: [EXTERNAL]CRU CD3-128 (PTD 211-037): Sundry Application Good morning Travis, On Form 10-403, Box 11, the effective depth of the well (both MD and TVD)was left off. Please provide the current effective depth of the well, both MD and TVD, as soon as possible. Thank you, Patricia Patricia Bettis AOGCC Senior Staff Geologist (907) 793-1238 1 •OF � • ywa \ I�1/4" THE STATE Alaska Oil and Gas ALAsKAF Conservation Commission titt 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wa Main: 907.279.1433 �F ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ron Phillips r Drilling Engineer �CANKO A ' CI 4 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3-128 Permit to Drill Number: 211-037 Sundry Number: 317-094 Dear Mr. Phillips: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this / day of March, 2017. • • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 2 O17 APPLICATION3 ' G FOR SUNDRY APPROVALS l � 1 / 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q • Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter CasingCI❑ Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Conocophillips Alaska,Inc. Exploratory ❑ Development ❑ 211-037-0 3.Address: Stratigraphic ❑ Service Q 6.API Number: PO Box 100360,Anchorage,Alaska 99510 50-103-20638-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A CRU CD3-128 • Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL25538, 372105 a Colville River Field/Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 20387' 7083 - 18685 • 7063 ` 3927 none none Casing Length Size MD TVD Burst Collapse Conductor 77 16 114 114 1640 670 Surface 2953 9.625 2989 2451 3520 2020 Production 12975 7 13009 6980 7240 5410 Liner 5990 4.5 18685 7063 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12476'-18637' . 6824'-7062' 3-1/2" L-80 12739' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Premier Packer,Baker Premier Packer&CAMCO TRMAXX-5E SSSV 12311'MD/6745'TVD, 12596'MD/6876'TVD&2180'MD/2014'TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 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: 3/12/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑., • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Ron Phillips @ 265-6312 Email Ron.L.Phillips(a�cop.com Printed Name Ron Phillips @ 265-6312 Title Drilling Engineer .�. e a/;' $ /?D 17 Signature r Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ CI Test Er Mechanical Integrity Test [V Location Clearance Other: Sop 'SCS I y /4, 5-0 /9-v1 r, v!a r p rt' 1(<4,t/✓�t c5I irt �OZ✓ao �' 5 Post Initial Injection MIT Req'd? Yes 1No ❑ Spacing Exception Required? Yes El Nod Subsequent Form Required: `0 -4 0 MAR APPROVED BY / // Approved by: 1y� l COMMISSIONER THE COMMISSION RSDNIS LL--Date: 3-IID F rm 10-40 R d 2015 �J �A ra�rEGpil o Ate,Ld for 12 months from the date of a roval. n,., PP Attachments in Duplicate /� 31©I/IT 40, 3//7 • • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 FEB 2 8 2097 February 28th,2017 AOGCC Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Alpine CD3 Colville River Field Injector CD3-128(PTD#211-037-0). CD3-128 was originally planned as a Nechelik injector but the ice road timing forced the RDMO early.Also 9' of Kuparuk C sand justified the CD3-128 be completed in 2011 as a Kuparuk C sand producer.The following 2012 ice season the Nechelik was drilled out and the well was completed as a Kuparuk/Nechelik selective oil development well. In 2013,the well was converted to a WAG Injector Sundry 313-040.In May 2015,there was an unexplained increase in IA pressure. In Jan.2017,diagnostics confirmed both the upper and lower metal to metal seals failed. The MIT-IA,IA draw down test,tubing positive pressure pack off test and both the IC and pack off tests passed in 2016. The proposed workover scope for CD3-128 is to pull the existing 3-1/2"completion out of the PBR at 12,288'MD. A new 3-1/2"tubing string will then be run in the hole and stung into the PBR that was run in 2012 and MWAG injection resumed. If you have any questions or require any further information,please contact me at 265-6312. Sincerely, 6-?0,..1 67114 Ron Phillips Senior RWO Engineer CPAI Drilling and Wells • • • CD3-128 Rig Workover Pull and Replace 3-1/2"tubing (PTD#:211-037) Current Status: SI Jan. 14,2017 until RWO is complete.This well is a WAG injector into the Kuparuk C and Nechelik sands at CD3 that currently has a tubing leak and tubing hanger seal leak. Scope of Work: Pull the existing 3-1/2"tubing from the PBR at 12,288' and run 3-1/2"tubing. General Well info: Well Type: Injector MPSP: 3,927 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 4,594 psi/6,903' TVD(12.8 ppg EMW)measured on Jan.2,2017 Wellhead type/pressure rating: FMC Alpine Gen 2, 11"5M psi BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MITIA passed—May 17,2015,suspected tubing leak to gas but not fluids. Known tubing hanger upper and lower M2M seals leaking. Earliest Estimated Start Date: March 12th,2017 Production Engineer: John Cookson Workover Engineer: Ron Phillips(265-6312/Ron.L.Phillips@cop.com) Pre-Rig Work 1. RU Slickline: Lock out SSSV. Set plug in X-nipple @ 12,353'. PT plug to 3,500 psi, perform NFT on plug. 2. MIT-IA to 3,000 psi, to cofirm packer is sealing. 3. Set BPV with in 24 hrs of rig arrival. Workover Procedure 4. MIRU. 5. Pull BPV. Reverse circulate seawater. Obtain SITP & SICP, if still seeing pressure at surface, calculate KWF and repeat circulation as necessary. Verify well is dead. 6. Set BPV& blanking plug or two-way check, PT to 1,000 psi from below if possible, ND tree, NU BOPE &test to400 psi high/250 psi low. 7. Pull blanking plug & BPV or two-way check. 8. RU to pull tubing, MU landing joint, BOLDS's, POOH laying down tubing. 9. RIH w/new tubing and seal assembly to fully engage the PBR. 10. Space out, mark the pipe, and pull out of PBR. 11. Install space out pups below the hanger and MU hanger. 12. Load the well with corrosion inhibited brine. 13. PT the tubing for 10 min. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 14. Pull the landing joint, install BPV or two-way check. PT BPV or two-way check to 1,000 psi from below. 15. ND BOPE. NU tree. If BPV is installed, pull BPV& install tree test plug. Test tree. Pull test plug/two-way check. 16. Freeze protect well w/diesel. Install BPV. 17. RDMO. Post-Rig Work 18. Pull BPV. 19. RU Slickline: Install catcher, change SOV for DV, pull catcher, pull the ball and rod, pull plug body. 20. Turn well over to operations. 1 WNS INJ III CD3-128 ConocoPhillips t Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cvweoPrvl, 501032063800 FIORD NECHELIK INJ 91.79 19,230.70 20,387.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date HORIZONTAL-CD3-128,2/12/20161'.31:00 PM SSSV:TRDP Last WO: 2/21/2012 36.80 4/30/2011 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mad By End Date HANGER;30.6r-burp-i o Last Tag:SLM 12,822.0 8/14/2012 Rev Reason:PULL,PLUG,FISH,MILLED ICE pproven 2/16/2016 PLUG TE__ 1 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread "'CONDUCTOR Insulated 16 15.250 36.8 114.0 114.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 42";� SURFACE 95/8 8.921 36.4 2,989.0 2,451.1 36.00 J-55 BTC-M 36.8-114.6 4E-17' Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I PRODUCTION 7 6.276 32.8 13,009.0 6,980.4 26.00 L-80 BTC-M Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WELen(I...Grade Top Thread SAFETY VLV;2,179.5 -qUill OPEN HOLE 61/8 18,685.0 20,387.0 7,082.6 - Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' LINER 41/2 3.958 12,694.7 18,685.0 7,061.9 12.60 L-80 IBTM Liner Details SURFACE;38.4-2,989.0-A Nominal ID GAS LIFT;5,097.5 1, 12,694.7 (ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 12,694.7 6,912.4 70.90 SLEEVE HRD LINER SETTING SLEEVE 5.250 -i st 12,706.9 6,916.4 71.45 NIPPLE RS PACK-OFF SEAL NIPPLE 4.250 GAS LIFT;9,872.6 _ 12,709.5 6,917.2 71.56 HANGER DG FLEX-LOCK LINER HANGER 4.360 -- 12,718.8 6,920.1 72.01 SBE SEAL BORE EXTENSION 4.000 GAS LIFT;12,228.6 L 13,068.8 6,986.3 85.44 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w/5.875" 3.920 OD CEMENTRALIZER SEAL ASSY;12,282.9 13,123.3 6,989.7 87.36 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w/5.875" 3.920 OD CEMENTRALIZER PBR;12,287.8 � PACKER;12,311.0 fir. Tubing Strings Tubing Description String Ma...ID(in) Top(MB) Set Depth(ft..l Set Depth(ND)(...Wt(IbHI) Grade Top Connection TUBING WO 31/2 2.992 30.6 12,738.5 6,926.0 9.30 L-80 EUE Mod NIPPLE;12.353.6 Il3 Completion Details GAS LIFT;12,396.2 R Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com Nominal ID 30.6- 30.6 0.00 HANGER FMC TUBING HANGER 4.500 115.9 115.9 0.18 X0 Reducing CROSSOVER 4.5 x 3.5,9.3,L-80,EUE-MOD 3.500 RPERF;12,478.0-12,49c.0-,, 2,179.5 2,014.3 48.05 SAFETY VLV CAMCO TRMAXX-5E SAFETY VALVE w/2.813"X 2.812 PROFILE SLEEVE-C;12.5452 (I I 12,282.9 6,731.3' 60.27 SEAL ASSY BAKER SEAL ASSEMBLY LOCATOR 3.000 12,287.8 6,733.7 60.29 PBR BAKER 20'80-40 PBR 4.000 PACKER;12,59fi.0 - 12,311.0 6,745.2 60.51 PACKER BAKER PREMIER PACKER 2.970 12,353.6 6,766.0 60.89 NIPPLE HES X NIPPLE 2.813 NIPPLE;12,665.5 �:: 12,447.7 6,811.1 61.94 BLAST RING SCC TUBING w/BLAST RING INSTALLED,TOP 2.992 p 1 12,476.7 6,824.7 62.36 BLAST RING SCC TUBING w/BLAST RING INSTALLED,BOTTOM 2.992 LOCATOR;12,704.3 yG ylV 12,545.9 6,855.5 64.67 SLEEVE-C BAKER CMD SLIDING SLEEVE w/2.812"X PROFILE 2.810 (CLOSED 5/25/2013)-ATTEMPTED TO OPEN SLEEVE, 4280 KEYS DID NOT ENGAGE;UNCERTAIN IF SEAL ASSY;12,727.1 SLEEVE OPENED OR CLOSED(8/13/2013) SEAL ASSY;12.736.5-. SHOE;12,738.1 12,596.0 6,876.3 66.29 PACKER BAKER PREMIER PACKER 2.870 12,665.5 6,902.5 69.60 NIPPLE HES XN NO GO NIPPLE 2.750 12,704.3 6,915.5 71.33 LOCATOR GBH-22 LOCATOR SPACED OUT 2'ABOVE FULLY 2.960 LOCATED PRODUCTION;32.8-13,009.0--,4 4 12,727.1 6,922.6 72.41 SEAL ASSY SPACER TUBE SEAL SUB 3.000 12,736.5 6,925.4 72.87 SEAL ASSY LOWER SEAL SUBS 3.000 lj12,738.1 6,925.9 72.94 SHOE MULE SHOE 3.000 Perforations&Slots Shot Dens PERFP;13,217.0-13,222.0 .;(•'. Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com I- 12,476.0 12,496.0 6,824.3 6,833.5 Kuparuk,CD3 5/5/2011 ' 12.0 RPERF 4 5/8"39 gm,60 deg PERFP;13,508.0-13,512.0j{A -128 phase `- 13,217.0 13,222.0 6,991.7 6,991.7 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;13,875.0-13,880.0 ■ ({,I,' -128 f- 13,508.0 13,512.0 6,991.7 6,991.7 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;14,238.0-14,240.0 126 ` 13,875.0 13,880.0 7,000.4 7,000.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS IN -128 PERFP;14,611.0-14,616.0 1 ,si 14,236.0 14,240.0 7,007.4 7,007.5 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;14,975.0-14.980.0 ;,'A' 14,611.0 14,616.0 7,014.2 7,014.2 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;15,342.0-15,347.0 '7?E . 14,975.0 14,980.0 7,015.6 7,015.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS M -128 PERFP;15,705.0-15,710.0 ' ef) I 15,342.0 15,347.0 7,017.5 7,017.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;16,070.0-16,075.0 , Illi 1 15,705.0 15,710.0 7,023.3 7,023.4 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS - -128 PERFP;18,440.0-16,445.0 illi 1 16,070.0 16,075.0 7,023.8 7,023.9 Nechelik,CD3 2/22/2012 - 1.0 PERFP 4.78'PERF PUPS FRAC;13,217.0 In -128 PERFP;16,804.0-16,808.0 Ill 16,440.0 16,445.0 7,034.3 7,034.4 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;17,172.047,177.0 •, 16,804.0 16,808.0 7,042.3 7,042.3 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;17,541.0-17,548.0 17,172.0 17,177.0 7,044.3 7,044.3 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP;17,904.0-17,908.0 331i -128 Pimi PERFP;18,266.0-18,270.0 I.}, 17,541.0 17,546.0 7,046.4 7,046.5 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS I. -128 PERFP;18,633.0-16,837.0y 17,904.0 17,908.0 7,049.1 7,049.2 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS ;11; -128 LINER;12,694.7-18,685.0 OPEN HOLE;18,685.0-20,387.0 -...-.. • WNS INJ CD3-128 ConocoP fillips Alaska,Inc. cmocontelTpc HORIZONTAL-CD3-128,2/12/2016 1:31:04 PM Vertical schematc(actual) HANGER;30.6 /F-' a 1 Il Perforations&Slots Shot ......_.. ..........._ Dens I♦jq- Top(TVD) Btm(TVD) (shota/f - Top(ftKB) BM(ftKB) (ftKB) (ftKB) Zone Date t) Type Com CONDUCTOR Insulated 42'; 18,266.0 18,270.0 7,052.6 7,052.7 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS 36.8-114.0 -128 f 18,633.0 18,637.0 7,061.5 7,061.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 SAFETY VLV;2,179.5 Stimulations&Treatments 1] Min Top Max Blot Depth Depth Top(TVD) Btm(TVD) SURFACE;36.4-2,989.0— , (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 13,217.0 20,387.0 6,991.7 7,082.6 FRAC 3/9/2012 Performed fracturing treatment,pumping five main GAS LIFT;5,097.s • frac stages consisting of 0-6 ppa stages separated by four Bioball ball drop sequences.Pumped 220-bbl breakdown with 25-lb linear gel,followed by main frac of 467,219-lbs of 16/20 Carbolite in 25#crosslink gel GAS LIFT;9,972.6 (87%design).During last frac stage,extended the 4- ppa stage to 420-bbl Mandrel Inserts GAS LIFT;12,228.6 .. St atl SEAL ASSY;12,282.9 - on N TopTop(ND) Valve Latch Pod Size TRO Run (ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com PBR;12.287.8 1/ ( 1 5,097.5 3,401.2 CAMCO KBMG - 1 GAS LIFT DMY BK 0.000 0.0 11/1/2013 PACKER;12,311.0 ■'I 2 9,972.6 5,588.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/1/2013 3 12,228.6 6,704.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/5/2013 NIPPLE;12,353.6 !gi 4 12,390.2 6,786.6 CAMCO KBMG 1 GAS LIFT HFCV BEK 0.000 0.0 8/13/2012 GAS LIFT;12,398.2 Notes:General&Safety fik End Date Annotation 5/3/2011NOTE:View Schematic w/Alaska Schematic9.02/21/2012NOTE:Well suspended after original drill/completion 2011;re-entered and drilled deeper,WO,2012 RPERF;12,478.0.12,496.0- 5/25/2015 NOTE: ICE PLUG AT 3691 SLM SLEEVE-C;12,545.9 PACKER;12,598.0 Il 1: NIPPLE;12,865.5 LOCATOR;12,704.3— ■ SEAL ASSY;12,727.1 - SEAL ASSY;12,738.5-, SHOE;12,738.1 a I I I I PRODUCTION;32.8-13,009.0 PERFP;13,217.0-13,222.0 ■ PERFP;13,508.0-13,512.0 • PERFP;13,875.0-13,880.0 111111 PERFP;14,236.0-14,240.0 flI` PERFP;14,611.0-14,616.0 Min PERFP;14,975.0-11,980.0 ; ■ PERFP;15,342.0-15,347.0 hili' II{ID PERFP;15,705.0-15,7100 PERFP;18,070.0.18,075.0 IIII, PERFP;18,410.0-16,445.0 FRAC;13,217.0 ��j PERFP;16,804.0-16,808.0 )fl) PERFP;17,172.0-17,177.0 • PERFP;17,541.0-17,548.0 ere PERFP;17,904.0-17,908.0Elili PERFP;18,266.0-18,270.0 11111, PERFP;18,833.0-18,637.0 gg ffi LINER;12,894.7-18,685.0 OPEN HOLE;18,685.0-25,387.0 !---- s • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, March 05, 2016 1:20 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: FW: Alpine Injector CD3-128 (PTD #211-037) unexplained increase in IA pressure. Attachments: CD3-128.pdf; CD3-128 90 Day TIO plot 5 March 16.JPG Chris- CRU WAG injector CD3-128 (PTD#211-037-0) is currently 13 days into a 30 day gas injection monitor period. The IA was bled down yesterday and it has since increased in pressure. It is CPAI's intentions to leave the well on gas injection for up to the remainder of the 30 day gas injection period to see if the IA will stabilize below the DNE of 2400 psi. This information will provide CPAI with the data that will be collected in regards to being a candidate for the future TxIA communication while on gas injection proposal. If the IA will stabilize below the DNE of 2400 psi the well will be WAG'd back to water injection at the end of the 30 day monitor period and an AA application for water injection only will be submitted until the TxIA proposal can be completed and submitted. If the IA reaches the DNE of 2400 psi the IA will be bled and the psi/day build up rate will be measured to provide the information needed to evaluate the number of bleeds per amount of time will be needed to remain within the well operating guidelines. When the psi/day rate has been established or the well reaches the end of the 30 day monitor the well will be WAG'd back to water and an AA application for water injection only will be submitted until the TxIA proposal can be completed and submitted. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO plot and well bore schematic Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 4WELLS TEAM SCANNED MAR 1 5 2016 ConocoPhillips From: NSK Problem Well Supv Sent—iMednesday, February 03, 2016 10:54 AM To: Wallach, C tom' -QDOA) Cc: Senden, R. Tyler;��SK�roblem Well Supv Subject: RE: Alpine Injector CO -128 (PTD #211-037) unexplained increase in IA pressure. Chris- This \, email is to serve as an update to Alpine's inje CD3-128 (PTD#211-037). Most recently CTU cleared the well bore of the ice plug in which delayed the diagnostics. The down tubing plug was pulled and reset and DHD performed a passing MIT-T concurrently with a passing IA-DDT. They then perfor simultaneous T and IA DDT which showed no pressure build up on the IA. The tubing pressure continued to drop; howeve tubing did not show indications of communication with the IA. It is CPAI's intentions to bring the well on gas injection for-agi: day monitor period. If TxIA communication is apparent while injecting gas the well will be WAG'd to water injection for a-3Q day monitor period with intent to AA for water injection only. Please let me know if you have any questions or disagree with the plan. Attached are the current 90 Day TIO plots, well bore schematic and results from the most recent diagnostic testin . 1 g ❑' [T' W UI U = L1.1 [Y n a r- LL Li a, tp • W a' c; foe w ['y N Z Q W m to W Cir .! C of ry ❑, U, w q1 to uJ o c- 2 tV 4v C+ ' o a) J r, U U U v O CJ U ',2.A6ap I I I I I I I I t I _- f!1 Li- a) 11 alI co, —411111p 7 to V � O dKt <t <t E Z .Z 4 fo* V fA � m C imam 4 - o co N O CO Q) 0 V r M _ O a �} 7 s = G m b I I I I U CD U U V U U U V c= 1 I U V U U U U V U V UUU OOOO U, U U, U U, U U, C., U,Z 0 p Od iB halal inow ISd • i Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, February 03, 2016 10:54 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: RE: Alpine Injector CD3-128 (PTD#211-037) unexplained increase in IA pressure. Attachments: CD3-128 TIO plot.JPG; CD3-128.pdf; CD3-128 Diagnostic Tests 30 Jan 16.xls Chris- This email is to serve as an update to Alpine's injector CD3-128 (PTD#211-037). Most recently CTU cleared the well bore of the ice plug in which delayed the diagnostics. The downhole tubing plug was pulled and reset and DHD performed a passing MIT-T concurrently with a passing IA-DDT. They then performed simultaneous T and IA DDT which showed no pressure build up on the IA. The tubing pressure continued to drop; however the tubing did not show indications of communication with the IA. It is CPAI's intentions to bring the well on gas injection for a 30 day monitor period. If TxIA communication is apparent while injecting gas the well will be WAG'd to water injection for a 30 day monitor period with intent to AA for water injection only. Please let me know if you have any questions or disagree with the plan. Attached are the current 90 Day TIO plots, well bore schematic and results from the most recent diagnostic testing. Dusty Freeborn I Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 WELLS TEAM %OW MAY 1 9 ZQ1S ConocoPhillips From: NSK Problem Well Supv Sent: Wednesday, May 20, 2015 12:30 PM To: Wallace, Chris D (DOA) Cc: Senden, R.-TyIer; NSK Problem Well Supv Subject: FW: Alpine CD3-128 (PTD #211-037) unexplained increase in IA pressure. Chris- Alpine injector CD3-128 (PTD#211-O37) initial diagnostics have been completed. Both the upper and lower metal to metal seal and tubing negative pack off tests-failed. The MIT-IA, IA draw down test, tubing positive pressure pack off test, and both IC pack off tests passed. However the`A has continued to build pressure over night and has exceeded the DNE of 2400 psi. The IA was reported at"'2700 psi todaq T e well has 7" 26 lb L-80 pipe which is rated to 7240 psi. It is CPAI intentions to WAG the well to water injection for no more than 7 days to both help manage the IA pressure by reducing the tubing pressure and to sweep the wellbore and near wellbore of MI to reduce the risk while the intervention work is in process. Slick line will be mobilized as soon as reasonably possible to secure the well and start on diagnostics to identify the leak source. Please let me know if you have any ques-tior disagree with the plan. Attached are a well bore schematic and a 90 day TIO plot. �. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. 1 ` W in IF . U! -u.--: Q _ V N 'Si a' 0 a C u: p un W x1 Iv V v a qi W m y W re n. U a I- u, co W o 2 EN F o C n, �I IV J J W CI U U U U U Ch co r— co sem' II, I I t I I t I I I I -i t LL LL C 1 '2-9 b N C1 C ..."'".....‘-*-."1:1'' 03 a) Go ..,,..\:......„ in I cv ICV Q 0 dQca E 22 Z Z E i at qt at at 0 U L N 03 w 7 a b Z Lc) co CO N O e— 1 � N O OI M m f:-..1 I 0 ..... 4.1 i V .,..:;,1 _ o CL n- R1II . x 01 a= X0 IIIII d I ( ( , J iI I I II V c inO V, U V, V U, V U. ^ T 0, 4. .D .n ♦ ..1 ,4 O O u U u U u U O D 0 00 .* V S, CV Ci ad la tam N 76 m }a cisd naw Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, May 20, 2015 12:30 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: FW: Alpine Injector CD3-128 (PTD#211-037) unexplained increase in IA pressure. Attachments: image001.png; CD3-128 Schematic.pdf; CD3-128 90 Day TIO plot.JPG Chris- Alpine injector CD3-128 (PTD#211-037) initial diagnostics have been completed. Both the upper and lower metal to metal seal and tubing negative pack off tests failed. The MIT-IA, IA draw down test, tubing positive pressure pack off test, and both IC pack off tests passed. However the IA has continued to build pressure over night and has exceeded the DNE of 2400 psi. The IA was reported at'2700 psi today. The well has 7" 26 lb L-80 pipe which is rated to 7240 psi. It is CPAI intentions to WAG the well to water injection for no more than 7 days to both help manage the IA pressure by reducing the tubing pressure and to sweep the wellbore and near wellbore of MI to reduce the risk while the intervention work is in process. Slick line will be mobilized as soon as reasonably possible to secure the well and start on diagnostics to identify the leak source. Please let me know if you have any questions or disagree with the plan. Attached are a well bore schematic and a 90 day TIO plot. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 SCANNED MAY 2 2 2015 441WELLS TEAM ConocoPhillips From: NSK Problem Well Supv Sent: Wednesday, May 13, 2015 9:09 AM To: Wallace(Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Alpine Injj for CD3-128 (PTD #211-037) unexplained increase in IA pressure. Chris- Alpine Injector CD3-128 (PTD#211-037) I s.peen reported with an unexplained increase in IA pressure. The IA was showing signs of pressure increase and operatiorIL tempted to travel to the pad to bleed the IA. The well was shut in due to the fog and remote location of CD3 not allowing access to the pad to investigate the IA pressure increase. The IA has not continued to increase in pressure but did not experience the pressure fall off typically seen when a well is shut in and the thermal effects are trending down. CPAI intends to perform initial diagnostics as soon as logistically possible. Depending on the results of the initial diagnostics testing the appropriate paperwork for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Attached are a well bore schematic and 90 day TIO plot. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. 1 WNS INJ CD3-128 ConocOPI 1iIIips f Well Attributes Max Angle&MD TD Alaska Inc Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) "Act Btm(ftKB) t nax 'InIhp. 501032063800 FIORD NECHELIK INJ 91.79 19,230.70 20,387.0 .-. V Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date HORIZONTAL-CD3-128,11/18/20138:00.16 AM SSSV.TRDP Last WO: 2/21/2012 36.80 4/30/2011 Venice soMman(actual) _ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;so.O-■ - r,n-i a Last Tag;SLM 12,822.0 8/14/2012 Rev Reason.CHANGE WELL STATUS TO INJ hipshkf 11/18/2013 I _ Casing Stnngs Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)...Wt/Len(I...Grade Top Thread "'--'------' CONDUCTOR Insulated 16 15.250 36.8 114.0 114.0 62.50 H-40 WELDED MP 42" Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread CONDUCTOR Insulated 42"._,. SURFACE 95/8 8.921 36.4 2,989.0 2,451.1 36.00 J-55 BTC-M 38.8-114.0 Casing Description OD (in) ID fin) T op(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 32.8 13,009.0 6,980.4 26.00 L-80 BTC-M ® Casing Deeoripllon OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)... Wt/Len(I...Grade Top Thread SAFETY VLV,2.179.5 _ OPEN HOLE 61/8 18,685.0 20,387.0 7,082.6 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) "Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 41/2 3.958 12,694.7 18,685.0 7,061.9 12.60 L-80 IBTM SURFACE,38.4-2.989 0 L Liner Details Nominal ID GAS LIFT;5,097.5 . Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 12,694.7 6,912.4 70.90 SLEEVE HRD LINER SETTING SLEEVE 5250 12,706.9 6,916.4 71.45 NIPPLE RS PACK-OFF SEAL NIPPLE 4.250 12,709.5' 6,917.2 71.56 HANGER DG FLEX-LOCK LINER HANGER 4.360 GAS LIFT;9,872.6 •/ 12,718.8 6,920.1 72.01 SBE SEAL BORE EXTENSION 4.000 13,068.8 6,986.3 85.44 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w/5.875" 3.920 GAS LIFT;12.228M OD CEMENTRALIZER 13,123.3' 6,989.7 87.36 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w/5.875" 3.920 SEAL ASSY;12,282.9 41MI OD CEMENTRALIZER I PBR;12,287.8 ) { Tubing Strings PACKER;12,311.0 Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 3 1/2 2.992 30.6 12,738.5 6,926.0 9.30 L-80 EUE Mod NIPPLE;12.353.6 I..IC Completion Details Nominal ID GAS LIFT;12,390.2 L1 Top(ftKB) Top(TVD)(ftKB) Top Ind(`) Item Des Corn (in) 30 6 30.6' 0.00 HANGER FMC TUBING HANGER 4.500 115.9 115.9' 0.18 XO Reducing CROSSOVER 4.5 x 3.5,9.3,L-80,EUE-MOD 3.500 RPERF;12,470.0-12,490.0- 2,179.5 2,014.3 48.05 SAFETY VLV CAMCO TRMAXX-SE SAFETY VALVE w/2.813"X 2.812 `�� PROFILE �"�' 12,282.9 6,731.3 60.27 SEAL ASSY BAKER SEAL ASSEMBLY LOCATOR 3.000 SLEEVE-c:12,545.9 () 11 12,287.8 6,733.7' 60.29 PBR BAKER 20'80-40 PBR 4.000 12,311.0 6,745.2 60.51 PACKER BAKER PREMIER PACKER 2.970 PACKER;12,596.0 lli 12,353.6 6,766.0 60.89 NIPPLE HES X NIPPLE 2.813 NIPPLE;12,585.5 12,447.7 6,811.1' 61.94 BLAST RING SCC TUBING w/BLAST RING INSTALLED,TOP 2.992 -II 12,476.7 6,824.7' 62.36 BLAST RING SCC TUBING w/BLAST RING INSTALLED,BOTTOM 2.992 LOCATOR;12,704.3 4 $ 12,545.9 6,855.5 64.67 SLEEVE-C BAKER CMD SLIDING SLEEVE w/2.812"X PROFILE 2.810 W (CLOSED 5/252013)-ATTEMPTED EN SLEEVE, 4280 KEYS DID NOT ENGAGE;UNCERTAIN IF SEAL ASSY,12,727.1SLEEVE OPENED OR CLOSED(8/1312TO 0OP13) SEAL ASSY;12,730.5.. SHOE;12,738,1 12,596.0 6,876.3- 66.29 PACKER BAKER PREMIER PACKER 2.870 12,665.5 6,902.5' 69.60 NIPPLE HES XN NO GO NIPPLE 2.750 12,704.3 6,915.5' 71.33 LOCATOR GBH-22 LOCATOR SPACED OUT 7 ABOVE FULLY 2.960 LOCATED PRODUCTION;328-13,009.0-• • 12,727.1 6,922.6 72.41 SEAL ASSY SPACER TUBE SEAL SUB 3.000 g 12,736.5 6,925.4' 72.87 SEAL ASSY LOWER SEAL SUBS 3.000 I I 12,738.1 6,925.9" 72.94 SHOE MULE SHOE 3.000 Perforations&Slots Shot Dens PERFP;13,217.0.13.222.0 meed Top(/UC8) Bbn(ftKB) VOW) (TVD) Btm(TVD) VOW) 90(B)KB) Zone Date Q Type Cam �$� 12,476.0 12,496.0 6,824.3 6,833.5 Kuparuk,CD3 5/5/2011 (ehobll 12.0 RPERF 4 5/8"39 gm,60 deg PERFP;19,508.0.13,512.0 -128 phase 113 1 13,217.0 13,222.0 6,991.7 6,991.7 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;13.875.0.13.8800 13,508.0 13,512.0 6,991.7 6,991.7 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;14,230.0-14,240.0114 13,875.0 13,880.0 7,000.4 7,000.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS 1� -128 PERFP;14,011.0.11,810.0 �Kpp 14.236.0 14,240.0 7,007.4 7,007.5 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS � I -128 PERFP;14,975.0-14,980.0 lir 14,611.0 14,616.0 7,0142 7,0142 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS 1111 -128 PERFP;15,342.0.15.347.0 14,975.0 14,980.0 7,015.6 7,015.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS - -128 PERFP;15,705.0.15,710.0 fl: 15,342.0 15,347.0 7,017.5 7,017.6 Nechelik,CD3 2/22/2012 1,0 PERFP 4.78'PERF PUPS - -128 PERFP;10,070.0.10,075.0 ;ll;l, 15,705.0 15,710.0 7,023.3 7,023.4 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS I -128 PERFP:10.440.0-15.445.0 :t$'f'' 16,070.0 16,075.0 7,023.8 7,023.9 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS FRAC:13,217.0 t -128 PERFP;16,804.0.10,800.0 I SI, 16,440.0 16,445.0 7,034.3 7,034.4 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;17,172.0.17,177.0 IED 16,804.0 16,808.0 7,042.3 7,042.3 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS -128 PERFP;17841.0-17,540.0 KM 17,172.0 17,177.0 7,044.3 7,044.3 Nechelik,CD3 2/22/2012 1,0 PERFP 4.78'PERF PUPS PERFP;17,904.0.17,908.0 KM -128 PERFP;18,200.0.18,270.0 lek"S➢ 17,541,0 17,546.0 7,046.4 7,046.5 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS �q0 -128 PERFP;19,833.0-16,097.0 17,904.0 17,9080 7.049.1 7,049.2 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS '#'#' -128 LINER;12,094.7-18,0850 !--_-"I OPEN HOLE;18,685.0-20,3870 WNS INJ CD3-128 ConocoPhillips Alaska,Inc. (cnuraltellmm HORIZONTAL-CD3-128,11/18/2013 8 DO 18 AM Vertical schematic(acNal) HANGER.30 6 •F-elerd-I y • _ Perforations&Slots Shot MEP Top(TVD( Btm(TVD) Dena (shota/f Top(KKB) Btm(ftKB) (11KB) (RKB) Zone Date 1) Type Com CONDUCTOR Insulated 42-; 18,266.0 18,270.0 7,052.6 7,052.7 Nechelik,CD3 2222012 1.0 PERFP 4.78'PERF PUPS 36.8-114.0 -128 18,633.0 18,637.0 7,061.5 7,061.6 Nechelik,CD3 2/22/2012 1.0 PERFP 4.78'PERF PUPS SAFETY VLV:2,170.5 ® -128 _ Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) SURFACE,30 a-2,9890—� )KKB) (KKB) (RKB) (KKB) Type Date Corn 13,217.0 20,387.0 6,991.7 7,082.6 FRAC 3/9/2012 Performed fracturing treatment,pumping five main GAS LIFT,5,097 5 4 -I frac stages consisting of 0-6 ppa stages separated by -- four Bioball ball drop sequences.Pumped 220-bbl breakdown with 25-lb linear gel,followed by main frac of 467,219-lbs of 16/20 Carbolite in 25#crosslink gel OAS LIFT;9,072.6 (87%design).During last frac stage,extended the 4- ppa stage to 420-bbl Mandrel Inserts GAS LIFT;12.228.8 St ati C on Top(TVD) Valva Latch Port SMe TRO Run SEAL ASSY;12,282.9 Top(KKB) (KKB) Make Model OD(in) Sery Type Type (in) (pal) Run Date m PBR:12,287.e { 1 5,097.5 3,401.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/1/2013 PACKER;12,371.0 2 9,972.6 5,588.9 CAMCO KBMG _ 1 GAS LIFT DMY BK 0.000 0.0 11/1/2013 - 3 12,228.6 6,704.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/52013 4 12,396.2 6,786.6 CAMCO KBMG 1 GAS LIFT HFCV BEK 0.000 0.0 8/132012 NIPPLE;12,353.0 Notes:General&Safety OAS LIFT;12.398.2 - End Date Annotation 5/3/2011 NOTE,View Schematic wl Alaska Schematic9.0 2/21/2012 NOTE:Well suspended after original drill/completion 2011,re-entered and drilled deeper,WO,2012 RPERF;12,476.0-12.498.0— I I iSLEEVE-C;12,646.0 PACKER;12,598.0 IIll1 NIPPLE;12,005.5 LOCATOR;12.7043 I I SEAL ASSY;12,727.1 SEAL ASSY;12,730 54. SHOE;12,738.1 PRODUCTION;32.8-13009.0 e PERFP;13,217.0.13,222.0 PERFP;13,508C-13,512.0 PERFP;13,875.0.13,880.0 PERFP;14,236.0-14.240.0 PERFP;14,011.0.14.016.0 PERFP;14,975.0-14,9800 PERFP;15,342.0-15,3470 • PERFP;15,705.0-15,710.0 PERFP;16,070.0-16,075.0 IIII' PERFP;16,440.0.10,445.0 {J FRAC;13,2170 I_ PERFP;10,804.0-10.8080 PERFP;17,172.0.17,177.01.15 yy ii PERFP:17,641.0.17.548.0 PERFP:17,004.0.17,908.0 1:1 PERFP;18,260.0.16,270.0 PERFP;18,033.0.18,037.0 { LINER;12,804.7-18,685.0 OPEN HOLE;18,885.0.20.387.0 u1 is rJ w U)co co lx Ix i W W . W 11.1 _ 1_ O = OOJ N .f 'r, ,r, a 1._,4 okr, r- m cc CV i M CSI a O N CD R L.0 ..-- Tr; V W CS, 1".•- !rr C` Cr CT) CO t`-- CI: .0 o as x N W E N O 07 O CV - - - - O .- (V O. CN `? r 'T K r N —1 ,r, kr, K 0 0 0 0 W CV [VN CV I- .- C" .- ii) C. CV C.J C CO CO CO CO –� 04 fV N CV J M f'r, M (`'7 U.' GOO O U U U U 0 0 0 0 0 0 0 I"- -A6ap0 o 0 0 0 v, m 0 0 0 I 1 i 1 1 i 1 4 4 1 a u. 0 S 5 4C• • 141 a) C CO Z 3 len C (N7N J 4 a CO V D �-` n C ?--"-----1>. C ` .'...., Q Q Q Q E Z Z Z Z E at at at at p U b MI N d .7 ' � u1 Q -p Y, v_ r Ll, in NI c, CI1 •''" N2N ❑ N ✓ N In 0 ' ? o � � III1I CO E 2 Qs I1 g o o .- g In QQ xx �5CC QQ 1• 4 O u> o ^, 0 N Y Y X S Y -ai _ ❑ 14 •s eh N ry �' 0 Odii hl3N r op :° ''*0 isd D S > ❑ w v Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, May 13,,2015 9:09 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Alpine Injector CD3-128 (PTD #211-037) unexplained increase in IA pressure. Attachments: image001.png; CD3-128 90 Day TIO plot.JPG; CD3-128 Schematic.pdf Chris- Alpine Injector CD3-128 (PTD#211-037) has been reported with an unexplained increase in IA pressure. The IA was showing signs of pressure increase and operations attempted to travel to the pad to bleed the IA. The well was shut in due to the fog and remote location of CD3 not allowing access to the pad to investigate the IA pressure increase. The IA has not continued to increase in pressure but did not experience the pressure fall off typically seen when a well is shut in and the thermal effects are trending down. CPAI intends to perform initial diagnostics as soon as logistically possible. Depending on the results of the initial diagnostics testing the appropriate paperwork for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Attached are a well bore schematic and 90 day TIO plot. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 MAY 2 2 2015 ;WELLS TEAM N53 ConocoPhillips 1 W U_ > — cc t- w c4 Ui u CL W Q U Cl) c, w ,n CC a ii d O H '7 U..1 r- ¢ Co a -c o a a) W W d r --t a c[ i— v, Ir, 0 M F N ,_ 1 J w p U O CJ U chip C, [D 2-I •1 CI [!J C> CJ C] <]UI I,. -- — t» CO t-- t. I I I I 1 1 I I IVa / ....0'...1 i LIIL II t......4)1. u W °° o IP a `caa E zzzz E U to 0 07 O C C Q V, LA le) CO N C C e— N C N 1 CI N aM-- 1.0 Ca7 O. p0 f g ,n m ii , i iii i r. t9 R o o v v v v c, v v C, :ri �, O u o w C) u C) u C) u naie Vixi t J, v •, C. C. cv C sl ,, CO= isd Sj to UJ Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (al L - 03Well History File Identifier Organizing(done) Two-sided III I1111111111 ❑ Rescan Needed II ll lilt I III III TRE AN DIGITAL DATA OVERSIZED (Scannable) C or Items: ❑ Diskettes, No. ❑ Ma s: Greyscale Items: pZher, No/Type: cp No, 1 ther Items Scan able by a Large Scanner 1_,05`S ❑ Poor Quality Originals: L1 OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: M Date: 3 ' /s/ ni p Project Proofing II 1111111111 11111 BY: dapDate: /s/ tylf Scanning Preparation 7 x 30 = aIO + ,s- = TOTAL PAGES ca.1---C" (Count does not include cover sheet) ofBY: - - Date: 3 `� /s/ Production Scanning I 1111111111 11111 Stage 1 Page Count from Scanned File: al& (Count does include cove sheet) Page Count Matches Number in Scanning reparation: YES NO ® BY: !p Date: 7/3 /L /s/O// Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II 1111111111 II ReScanned I 1111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked I 411111 IIIIII o I 1 I o co H c. ° U 0 Q lL U JL g Q � � CO CO M a 0 La W C tab .O N j w j L W 0 �Uco0 o a w CL m c 0 >°' 4 wo 8 0 o a `� cc U Ce �o� L 0< 0 o = > olrn U� 63 -0 a 0 a) y mu- AZ aZ R'Za �n > m E'IN oE0 OQ wQ Ua 21.1- OU 0U (1'U'es I m Z SII, o U �� O�� H 0H �o to p� 00 Zp� �� Y. co ° O c<w 2U 1-U ce� as 2< - < 0<0 Q v o d N N N O O .> e- d 6) J N to y!N N N N N N N N N N N 0 O (° (° (O v v O) O) O) U . Q J U) U) U) N N N N N Z (p a0 CO (� M M M 4 2 - C C C c O C c O C c C E i6 C = =I N N N o to N o Cl) a) N N E Q in Y OU!O O O a. co O O U O O O o N J : 0 LL. a ca - 0 0 0 in o o co N- N- N- O a o o 0 0 °Mo co0 0 r00i CO CO d N M rn 0 0 0 ay E /� J U 67 ;c' (0 N N N CL _J N W = a0. v V) Z X 0. c t Icn o� 0 0 10co (O Ln IL 0 iil V V T M M N O W Z O V O > • o Z ° co Q CL Z ' d' t_ co J a.O m 1° ZI�CN C � g 0 0 0 0 i G0 L.= itNIW O N a E 5II a)To Ed N co N 10 (0N N U a)HUe, co J N U) , Q M 0 V ow co G LL N t6 2 m w �� t J u) ' t Q J • o 1 o U I''''' O Q o a zI w w Zo ) U o C N to V) Z Z N N N E J 1 j O Cl) N V) 'O = = q) 4) Cl) N � CU) U) 0 C W W WZ 0 m N 6 O d I 2 , 6) O O O C O O N C O C O O E E > .j .j .o N .0 .0 O o u o C a ce z v) 0 E co h -_--, _ - 0 5 5 d _ E _ 0 0 �, E o 0M > 0 J «. v) a co n 0 ( .2 co f- I ` ° E o v' c Q Z L C f6 3 N N ce w O W 0 I N O m N O IO P o R a y W E , E co CO ELLZ g uwLLy U) vo N pJ CO < J s J yZ N _Zr \ 0 5 < U> J OJ _ d � � w 0 d a.• 2 : W Q a OA >. a W J J W 2 w o3JOF I Ce 3 0 1 I 9 a IIc co cl co 1 N >- I o 0 1', O O N Z Q U O Z_ $` cas r� J co O IL Q y 0 N a '5 Z Z U a. J J W = 1IL a 0 v U cU en co J N r QM I— U i— oTS_ coLON W > p W J N A.5 iii o Q U g E Q c a Z E D E 0 ao Z • M ooO Z ` 0 N.• I—(77_,) CO N O : ; :;o o. , 0 N 0 0 ct y N y CO (R > h- 0 E a Q 0 a a d d 5 a 'S 0 Q W U 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMu.JoION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Repair Well LI Plug Perforations ❑ Perforate Other 0 Convert Prod to W Performed: Alter Casing 0 Pull Tubing 0 Stimulate-Frac 0 Waiver 0 Time Extension 0 Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other LI Re-enter Suspended Wen 0 2.Operator ConocoPhillips Alaska,Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development Q Exploratory 0 211-037-0 . 3.Address: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic❑ Service ❑ 6.API Number: 50-103-20638-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25538,372105 CD3-128 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Water Flow Log Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 20387 feet Plugs measured none feet true vertical 7083 feet Junk measured none feet Effective Depth measured 18685 feet Packer measured 12311,12596 feet true vertical 7063 feet true vertical 6745,6876 feet Casing Length Size MD ND Burst Collapse Structural Conductor 77 16 114 114 Surface 2953 9.625 2989 2451 ECEIVED Intermediate r_ Production 12976 7 13009 6980 w Liner 5990 4.5 18685 7063 ��E(' 2013 Perforation depth Measured depth 12476 to18637 feet AOGCC True Vertical depth 6824 to 7062 feet Tubing(size,grade,measured and true vertical depth) 3.5 L-80 12739 MD 6926 ND Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer @ 12311 MD and 6745 ND Packer-Baker Premier Packer @ 12596 MD and 6876 ND SSSV-Cameo TRMAXX-5E SSV @ 2180 MD and 2014 ND 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: 826 711 572 1159 324 Subsequent to operation: 0 0 5557 335 1286 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Water Flow Log ExploratoryL Development Service Q Stratigraphic 0 Daily Report of Well Operations 16.Well Status after work: Oil LI Gas ❑ WDSPL❑ GSTOR ❑ WINJ LI WAG p✓ GINJ LI SUSP❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-040 Contact Kerry Freedman Email Ker,y.C.Freedmanc COP.com Printed Name Kerry Freedman Title Production Engineer Signature nG=PjK - -ivy- jeer r {'r eeP /4265-6579 Date � 20is For 101 Rcviccd 10/2012LI Fligligtal Qt 1t 2 0 1 HALLIBURTON I Wireline Perforating Oxygen Activation Log Evaluation Company: ConocoPhillips Alaska, Inc. Well: CD3-128 Field: Colville River Unit Borough: North Slope State: Alaska Formation and Reservoir Solutions — Anchorage AK Analyst : Fanny A. Sari Email : fannyartika.sari@halliburton.com Office : 907-275-2605 Report : 12/06/2013 HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA,CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT,FOR ANY LOSS,DAMAGES,OR EXPENSES RESULTING FROM THE USE THEREOF. HALLIBURTON ConocoPhiIIips TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY 3 2.0 SPECTRAFLOW LOG EVALUATION 4 2.1 IMPULSE TESTS 7 Impulse test#1 at depth 12465 ft. MD, 5500 BWPD injection rate 7 Impulse test#2 at depth 12465 ft. MD, 5500 BWPD injection rate 8 Impulse test#3 at depth 12465 ft. MD, 5500 BWPD injection rate 9 Impulse test#1 at depth 12585 ft. MD, 5500 BWPD injection rate 10 Impulse test#2 at depth 12585 ft. MD, 5500 BWPD injection rate 11 Impulse test#3 at depth 12585 ft. MD, 5500 BWPD injection rate 12 Impulse test#1 at depth 12465 ft. MD,4250 BWPD injection rate 13 Impulse test#2 at depth 12465 ft. MD, 4250 BWPD injection rate 14 Impulse test#3 at depth 12465 ft. MD, 4250 BWPD injection rate 15 Impulse test#1 at depth 12585 ft. MD, 4250 BWPD injection rate 16 Impulse test#2 at depth 12585 ft. MD, 4250 BWPD injection rate 17 Impulse test#3 at depth 12585 ft. MD,4250 BWPD injection rate 18 3.0 WELL DIAGRAM 19 Page 2 of 20 HALLIBURTON ConocoPhillips 1.0 EXECUTIVE SUMMARY Well: CD3-128 Oxygen Activation Evaluation Survey date: 03 Dec 2013 Logging Objective Monitor water up-flow movement while the well was injecting on 5500 and 4250 BWPD Conclusions The SpectraFlow Tool was run using impulse tests at two depth 12465 and 12585 ft MD. Three impulse tests were performed in each depth at two different injection rates, 5500 BWPD and 4250 BWPD. The tool was run in normal mode configuration (generator positioned below detectors) for water up flow detection. The survey data from the SpectraFlow showed no up flow water movement in this well. The interpretation was using far detector and GR sensor. Near detector was not used in the interpretation due to proximity to generator. Page 3 of 20 HALLIBURTON ConocoPhillips 2.0 SPECTRAFLOW LOG EVALUATION The SPFL was run using stationary impulse tests across the zones of interest. Water flow can be detected by measuring gamma rays originating from activated oxygen within any water flowing past the neutron generator(activation)then moving past the detector section (decay). The fluid/water velocity is estimated from oxygen activation using impulse test data. The flow direction is determined by the position of the sensor relative to the neutron generator. The flow region, near or far, is derived by the ratio of Compton backscatter gamma rays compared to original gamma ray counts from activated oxygen. Lower Compton ratio indicates a flow region further from the tool i.e. behind the next string of pipe. Total oxygen activation will be a function of: • volume of water in the region of neutron cloud • flow velocity of water • tool speed • flow distance to detector • time exposure Below is a representation of the sequence of radioactive excitation and subsequent relaxation of Oxygen. X16 (6,13 FM1eV) Spectral Beta Gamma Ray Ois. Decay Detector • N18 7.13-sec Haff-Lite High Energyr+ Oxygen (14-MeV) ^ ~ Activation Neutron Generator' 016 Figure 1: Sequence events of oxygen activation The tool is configured in the inverted mode with the neutron generator above the detector section. In the inverted configuration, water will only be detected when moving down relative to the Spectral Flow tool, in both the stationary impulse mode and continuous mode. Any oxygen activation detected by near and far detector should be from water flow down. If there is water flow in the upward direction the GR sensor above the neutron generator will detect the activated oxygen. Page 4 of 20 HALL IBURT'`. ConocoPhillips i GR 11111 • SII Far detector lull Near detector GEN is 7. dm II.. , , , I: I. Figure 2: Flow scenario related to spectra flow log tool Stationary Impulse Method This technique is basically a travel-time measurement and has the significant advantage of not requiring any calibration of the detectors. When the tool is stationary at a specified depth, the generator is turned on and allowed to stabilize. The count rate in each detector is then recorded for one or two minutes, at which time the generator is shut down. At some time later (depending on the fluid flow velocity and distance from the various detectors to the source), the count rate recorded in the detectors will drop to background level. The count rate will drop to nearly zero in the spectral window encompassing the oxygen peak. The surface computer records the various detector count rates, steps down the generator, measures the time until the recorded count rates fall to one-half full value, and then computes a velocity from the travel time. The fluid velocity is the distance from the source to the detector divided by the time between the count-rate drop and the time when the generator was shut down. The procedure is completely automated. Page 5 of 20 HALLIBURTON ConocoPhillips The spectral data can be processed to provide fluid velocity in one step because the count rate falls essentially to zero after the activation passes. Processing the total gamma ray count rates requires two steps. The natural background must be measured for approximately one minute after the drop to correct for the nonzero background activity. Fig. 3 is a graphical representation of the timing cycle used by the stationary impulse method. 110 OAI Curve 100 A 90 80 Generator '/ Value Voltage E 70 0 ce > 60 o 50 0 °1 = 40 C9 30 Distance to Detector 20 Velocity = io AT 0 -- 0 50 100 150 200 Time/Seconds Figure 3: Stationary Impulse timing sequence The rate computation: Casing ID = 2.992 inch (3.5"tubing), tool OD = 1.6875 inch. Vavg = average water velocity Qw(bpd) =Vavg (ft/min)x 1.4 x(CasinglD2 (inch)—ToolOD2(inch)) Page 6 of 20 HALLIEtURTON ConocoPhillips 2.1 Impulse tests Impulse test #1 at depth 12465 ft. MD at 5500 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1:600 CRATF TFA CA.IF 0153 17' SECS. 0 10'0 1000 0 100'0 2dII GENV 1wt 0A114 2a0, 0A194 6ad o tad FAR ACT 240 ■Nlni■■■■■ INIMIiiiii IMMUNE ■v ur i■■■■■ ■ :■Cu■■■■■ ■W!.'■■■■■■ ININIOMMOM IMIAMMIMMI INIUMMEMEM INNEAMOMMI 111111 : ■■!K■■■■■■IMOKIMIMMI , ■■ILAM■■■■ ■■l fuG■■ ■■!may■■■M■ ■■l��i■■■li■ = ■■■moi■■■■■ 1■■ca■■■li■ • 1i � i■■f:i■■■■■ 1rlrrJL. ■■!ci■■■i! _. !ri FAR ACT GRH2 OA194 0A114 e. c. 1600 CRATF TFA ORIF 0153 SECS. .- '1. 1 11111 Impulse test#1 at depth 12465 ft. MD, 5500 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12465_5500_ljn.cls TOOL DEPTH = 12465 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.10 0.00 UNDETECTABLE UP TFA 82.62 0.12 UNDETECTABLE UP GR 52.10 0.00 UNDETECTABLE UP GR 197.58 0.57 413.33 DOWN CRATF 0.70 Page 7 of 20 HALLIBURTON ConocoPhillips Impulse test #2 at depth 12465 ft. MD at 5500 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1600 CRATF TFA OAIF 0153 1SJ SECS. 0 10a 10000 1000 24f GENV 0A114 a 6 a 56R 0A194 2A13 FAR ACT 0 240 ■I1■'•'_■■■■■■ — ■I1■�1■■■■■■ t . ■iii ■■■■■■ . . - ■I1■L■■■■■■ 1111112111111 ■IJi..■■■■ ` ■!1!i■■■■■■ 11110 111111111111111 ■■■:i■■■■■■ ■I1Eii■■■■■ ■I1■I■■■■■■ ■[u ■■■■■■11111141.1.-41•1111111 =■r� ■■■■■■ ■■■-41■■■■■ ■■■E:■■■■;i■ ■■■►■■■■�■■ ==- -=-:= ■■■r.!■■Iu■ ----- ■■■1A■■■■■ ■■i1■■■! �. FAR ACT GRd2 0A194 41 GENV 0A114 0 100 1 • vs 1:600 CRATFo OAIF 0153 111=111 ' SECS. i•• 1,1 Impulse test#2 at depth 12465 ft. MD, 5500 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12465_5500_2.jn.cls TOOL DEPTH = 12465 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW' GEN. ON INDEX (FT/M) DIR OAIF 0.13 0.00 UNDETECTABLE UP TFA 79.36 0.11 UNDETECTABLE UP GR 51.96 0.04 UNDETECTABLE UP GR 191.92 0.57 310.00 DOWN CRATF 1.21 Page 8 of 20 HALLIBURTON ConocoPhillips Impulse test #3 at depth 12465 ft. MD at 5500 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1600 CRATFTFA OAIF 0153 TsQ SECS. 6 _ 10 0 1000 0 "TWO Tat' GENV 00 U 0A114 � d 50ff o 0A194 23R FAR ACT 240 ih1■1i■■■■■ i[1■1■■■■■■ ■$;■:i■■■■■ ui1■ i■■■■■ ■iii■■■■■ ■011%11■■■■■ iti■Cii■■■■■ ■I1■c+_u■■■■■ ILi%U■■■■■ • - 1 1■Vii■■■■■ i■■ai■■■■■ • ■■iii■■■■■ ■■EI!JI■■■■■ ■■r��■■■■■■ mon: 1•11011111111 - - MIAMI= ■■■►1■■■■li■ ■■`4■■■■i■ �. FAR ACT ' GR 42 0A194 0A114 • 1:600 CRATF TFA OAIF 0153 SECS. . I. .r. . Impulse test#3 at depth 12465 ft. MD, 5500 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12465_5500_3jI1.cls TOOL DEPTH = 12465 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.07 0.00 UNDETECTABLE UP TFA 79.13 0.13 UNDETECTABLE UP GR 51.79 0.00 UNDETECTABLE UP GR 188.47 0.55 NC DOWN CRATF 0.64 Page 9 of 20 HALLIBURTON ConocoPhillips Impulse test #1 at depth 12585 ft. MD at 5500 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1.600 CRATF TFA OAIF 0153 loo SECS. Cr iJ u loaf u iuo o 24U GENV 0A114 64a loa 0A194 2IIQ 506 3 200 FAR ACT 245 Ri■■■■■■■ ■ti■■■■■■■ Eti ■■■■ti i� ■■ iiiii E ■F■■■■■■■■ uL1■■■■■■■■ _J1 tN■■■■■■■ �� IEa■■■■■■■ ■ti■■■■■■■ tF illi■■■■ tF■■■■■■■■ J � [N■■■■■■■ s Ir4■ ■■■■■■ J` . til■iiiiiU MOM C:C::IC: ■EE■■■■■rI■ - _ ■F97■■■■■J■ ■,i■■■■■li■ -. - ■f i■■■■■i■ ■crJ■■■■■i■IIIIIINIE J` ■R ■■■■■■■ FAR ACT r, GR$2 0A194 r n GENV 0A114 too vu ' 1600 CRATF TFA OAIF 0153 SECS. 11111111111,111111111111, Impulse test#1 at depth 12585 ft. MD, 5500 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12585_5500_1-Jn.cls TOOL DEPTH = 12585 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.12 0.00 UNDETECTABLE UP TFA 35.96 0.34 UNDETECTABLE UP GR 27.39 0.02 UNDETECTABLE UP GR 117.17 0.59 NC DOWN CRATF 0.96 Page 10 of 20 HALLIBURTON ConocoPhillips Impulse test #2 at depth 12585 ft. MD at 5500 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1 600 CRATF TFA OAIF 0153 3 1 SECS. 0 103 1770 7 -- - _-100 3 GENV 0A114 0 333 a 0A194 333 3 77 FAR ACT D 233 10111■■■■■■ iii.i■■■1■ II11111■■1■■ I[1■■11■■■■■ 5f11011■■■■■ PPL.— P4- if!■■■■■■■ JJ� � ILS■■1■■■■■ � i1i■1111■■■■■ ■■1111■■■■ i if■■■■■■■1 I �� if■■11■■■■■ � 11.111111■1111■ ^ ICRIM■■■!■ J it■111■■■■■ Jam. 1111191:=11111 �`� IC::: ;; 11rE1■!■■1111■ 11Fi■1■■■i■ 11111111111111M IF lI■■■I= ■[FJ■■■■■:i■ ■!►i■■■■■i■ _____ Et A FAR ACT GRI42 0A194 11 11 lOD GENV 0A114 vs 1:600 CRATF TFA OAIF 0153 1/1111 SECS. • iD s 11 1 -111 1 Impulse test#2 at depth 12585 ft. MD, 5500 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12585_5500_2jn.cls TOOL DEPTH = 12585 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.15 0.00 UNDETECTABLE UP TFA 37.63 0.37 UNDETECTABLE UP GR 27.47 0.03 UNDETECTABLE UP GR 116.37 0.60 NC DOWN CRATF 0.79 Page 11 of 20 HALLIBURTON ConocoPhillips Impulse test #3 at depth 12585 ft. MD at 5500 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1600 CRATF TFA OAIF 0153 101 SECS. 0 10 a 1000 0 TOO U 24J GENVOA 1 14 3 - - -__ u 0 20U 0 64a 500 U GA194 FAR ACT ( 0 203 i`f�■■■■■■■■ i*i■■■■■■■■ hfillIIMIN i■■■■■■■ iti■■■■■■■ — 1TI■■■■■■■ — IKEIMINM iii■■■■■■■ iu1■■■■■■■■ [G■■■■■■■■ _ i[■■■■■■■■ -��._ L ii11111MII Iil■■■■■■■ ■ e!■■::ai■ Jt , 151.10111111111111 ILIAII■■■I 3 ■',1■■■■■i■■ ■F4]■■■■■II --- , ■[ti■■■■■Ill =_-- MOM= MOM= I ■1 uIU■■I■■ 1 -. ■��G1■■■■■Ii■ -_ 1 . E3 n FAR ACT ' GRk2 0A194 ' ' 0A114 1:600 -- SECS .__CRATF_ T. TFA OAIF 0153 MEM ---- i. . "' Impulse test#3 at depth 12585 ft. MD, 5500 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12585_5500_3jn.cls TOOL DEPTH = 12585 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.15 0.00 UNDETECTABLE UP TFA 36.70 0.33 UNDETECTABLE UP GR 27.11 0.00 UNDETECTABLE UP GR 119.54 0.59 NC DOWN CRATF 0.77 Page 12 of 20 HALLIBURTON ConocoPhillips Impulse test #1 at depth 12465 ft. MD at 4250 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1600 CRATF TFA OAIF 0153 'r SU SECS. 0- 10 0 _.-------1030 2- RHI 0 240 GENV tau 0A114 0A194 aro' '3G FAR ACT 0 240 ■II■��■■■■■ ■11 1■■■■■ ■111117■■■■ ■i■!a■■■■■ ■'i■`i■■■■■ ■1■CH■■■■■ ■t]■■!■■■■■ IMM■! ■■■■■ ■r�■■�■■■■■ t ■E�■s1■■■■■ ■'1111■■■■■ ■iM■C1■■■■■ ■t!�■ea■■■■ ■■■■�■■■■■ 11111111111111 = I ■■■■A■■ ■ - ■■��c�■■ ■ ■■E;■e,■■ ■ ■■I1E4■■■1■ - w ■■!■��■■■■■ ■■ip1.- • FAR ACT GRI2 0A19461 GENV 0A114 100 • vis 1:600 CRATF TFA OAIF 0153 , SECS. .---- --10 0- -----_ .rl I -150 Impulse test#1 at depth 12465 ft. MD, 4250 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12465_4250_1_m.cls TOOL DEPTH = 12465 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.16 0.00 UNDETECTABLE UP TFA 82.64 0.12 UNDETECTABLE UP GR 62.58 0.01 UNDETECTABLE UP GR 137.51 0.57 1000.00 DOWN CRATF 1.48 Page 13 of 20 HALLIBURTDN ConocoPhillips Impulse test #2 at depth 12465 ft. MD at 4250 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1.600 CRATF TFA OAIF 0153 mr SECS. rma Tann M7 --Tr GENV _ 0A114 o a 100 2aQ 0A194 -0 FM li 240 FAR ACT ` 2alf ■ill .■■■■ ■i■M■■■■ ■1■h7■■■■■ ■.■ER1■■■■■ ■,■!�'r■■■■■■ .. ■i■C,i�■■■■■ ■�i■E■■■■■■ ■i■Ci■■■■■ ■;M■!A■■■■■ ■OMMI■■■■ 1i15'■■■■■ ■u■ga■■■■■ ■i■ri■■■■■ ■7■Ei■■■■■ ■N■! ■■■■■ ■■EE:■■■■■■ ■■F■j■■N■ ■■L■0■■H■ -_ ■■[IEM■H■ ■■iI■■■H■ ■■Lull■N■ , _ ■■Raid■■ ■ ■■is:�■■ ■ - ----- 111214.1 ■ ■■ER ■ ■ ►■: FAR ACT GRN2 0A194111111/111 0A114 V10,-TS 1:600 CRATF TFA OAIF 0153 SECS. ' Impulse test#2 at depth 12465 ft. MD, 4250 BWPD injection rate SPECTRAFLOW RESULTS FILEe 12465_4250_2.jn.cls TOOL DEPTH = 12465 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.11 0.00 UNDETECTABLE UP TFA 82.27 0.12 UNDETECTABLE UP GR 61.84 0.00 UNDETECTABLE UP GR 139.58 0.57 744.00 DOWN CRATF 0.69 Page 14 of 20 HALL IBUR'i ConocoPhillips Impulse test #3 at depth 12465 ft. MD at 4250 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1:600 CRATF TFA OAIF to 0153 1b0 SECS. S 10 9 _ 1000 0 11 240 GENV 0A114 D 741 dka 0A194 0 an ti FAR ACT U 24U ■■■ci■■■■■ s ■i■■cg■■■■■ ■1lip111■■■ ■i■ci■■■■■ IMAM= ■■■n■■■■■ ■i■■11■■■■■MIAMI `~ IMAM= ■iHA■■■■■ ■fi■i7■■■■■ • ■■■Ci■■■■■ '■■i7■■■■■ ■.1■101■■■■■ ■■ir3r:■■■ J ■■L,i■■■■■ J� 11111,11:411111111 > J ■■[LI■■■■■ ■■Ei1■■■■■ ___:_ ■■E■a■■■1■ 1■r€!■■■1■ ■■HCS■■■■■ ■■pFi■■■u FAR ACT GR42 0A194 0A114 1:600 CRATF TFA OAIF 0153 • - .•� SECS. • �' , Impulse test#3 at depth 12465 ft. MD, 4250 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12465_4250_3_m.cls TOOL DEPTH = 12465 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.08 0.00 UNDETECTABLE UP TFA 80.35 0.09 UNDETECTABLE UP GR 61.46 0.00 UNDETECTABLE UP GR 140.42 0.57 NC DOWN CRATF 0.52 Page 15 of 20 HALLIBURTON ConocoPhillips Impulse test #1 at depth 12585 ft. MD at 4250 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1:600 CRATF TFA OAIF 0153 717 SECS. 0 t0� _..._--000TD IOU 0 t4J GENV 100 0A114 240 6 d 0A194 tau FAR ACT zaJ tri■■■■■■■ l51■■■■■■■■ !!1■■■■■■■ i !Li■■■■■■■ ![I■■■■■■■■ i 1 � !!1■■■■■■■ - !■l■■■■■■■ 4 —_ !E■■■■■■■■ RI]■■■■■■■ Ri ■■■■■■ !ti■■■■■■■ ■[7■iii■■■ ■E0]■■■■■;l■ I■i1■■■■■l■ _ 1■i■■■■■■■ 1■i7■■■■■;■■ - - ■cr�■■■■■,�■ - 1!?M■■■■■■■ ■EI■■■■■!1■ ■L'!1■■■■■!1■ FAR ACT GRN2 OA194 4. GENV 0A114 • t00 vs 1:600 CRATF OAIF 0153 • SECS. • 1.* "11111111111W Impulse test#1 at depth 12585 ft. MD, 4250 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12585_4250_11n.cls TOOL DEPTH = 12585 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.10 0.00 UNDETECTABLE UP TFA 37.84 0.33 UNDETECTABLE UP GR 28.76 0.08 UNDETECTABLE UP GR 121.57 0.61 930.00 DOWN CRATF 0.71 Page 16 of 20 • HALLIBUR` 'DN ConocoPhillips Impulse test #2 at depth 12585 ft. MD at 4250 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1600 CRATF TFA OAIF 0153 ibJ SECS. a" 10o nut a 1 .b 24L1 GENV 0A114 64 lar 13 0A194 717 0 SbII 4 _- 7dR FAR ACT U 24u ILS ■■■■■■ iu■■■■■■■ I&j■■■■■■■■ Ki■■■■■■■■ !ti■■■■■■■ ■!■■■■■■■■ R!■■■■■■■ if■■■■■■■■ iri■■■■■■■■ E[■f■■■■■■ i!■■■■■■■■ Ii■I■■■■■■ MUM= t [L■I■■■■■■ ■F� G■i■1■ ILFUiIIIII ■�t�■■■■H■ ■Ei1■■■■i;!■ ■LM■■■■•U■ � ■[EM■■■■O!■ ■h��l■■■■■E■ ■E�1■■■■■'■■ ■ETi■■■■e'■■ E: A FAR ACT GRd2 0A194 0A114 1:600 CRATF TEA OAIF ' 0153 1.11/1 SECS. . 1Q 1000 0 r.. Impulse test#2 at depth 12585 ft. MD, 4250 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12585_4250_2Jn.cls TOOL DEPTH = 12585 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.12 0.00 UNDETECTABLE UP TFA 35.71 0.33 UNDETECTABLE UP GR 27.69 0.00 UNDETECTABLE UP GR 125.67 0.61 NC DOWN CRATF 0.90 Page 17 of 20 HALLIBURTON ConocoPhillips Impulse test #3 at depth 12585 ft. MD at 4250 BWPD injection rate shows no water flowing up as indicated by the far detector. Far detector read no oxygen activation when the generator is on. GR sensor above SPFL tool does not shows different readings during generator on and off, indicating no water flow upward. While GR sensor below the SPFL tool shows different reading during generator on and off, indicating that there is water flow downward. GR 1:600 CRATF TFA OAIF 0153 iou SECS. T iso woo'o iuo u 24s GENV 0A114 5-----_---------- 100 '0 217 614456d ,� 0A194 237 FAR ACT r4s ! 111111111111M K II■■■■■■ II'■■■■■■■■ 131111■■■■■ Ir■1■■■■■■ ^� ■L■■■■■■■■ 1� I�J■■■■■■■■ ItM1■■■■■■ It■■u■■■■■ 1111■■■■■■ lel■■■■■■■ I111■■■■■■ � l[i■■■■■■■ � It1■1■■■■■ IF7■■■■■■■ ItlIiiiii■ - ------� M■■■■1i1■ l[C■■■■■EI■ ------ IF.1J■■■■■1■ _-- • 1UI■■■ii■ ____ Itkl■■■■■il■ 1`'1■■1■■■■ ■[t]■■■■■1■ ■EN11■IE1■ FAR ACT GR142 0A194 GENV 0A114 100 vs 1:600 CRATF TFA OAIF 0153 SECT. �Rimmili Impulse test#3 at depth 12585 ft. MD, 4250 BWPD injection rate SPECTRAFLOW RESULTS FILE= 12585_4250_3_m.cls TOOL DEPTH = 12585 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT/M) DIR OAIF 0.13 0.00 UNDETECTABLE UP TFA 39.19 0.36 UNDETECTABLE UP GR 27.99 0.05 UNDETECTABLE UP GR 127.60 0.61 930.00 DOWN CRATF 0.75 Page 18 of 20 HALLI ON UkA � ConocoPhillips 3.0 WELL DIAGRAM WNS INJ CD3-128 ConocoPhillips 1)Aim Attributes w.Aid.&MD TD j^ 18'''83."178.:01-1-1 In Ie.lM�h� 191/5�p]�IIn•;9,7.R',1."""" 'ltl:`• ... Com.555*T4H�, r.,, 10.• 2131'8.00 2)1,2]•2 A.4ae411 366 ".11.17?" vir 7(9U110..4.' Anrwm.n 10 I Foal'p 46!21910 law Mee 884•w. 6666. 4.1110630711. :v,CEAAGEVIFII STATUS TO 183 fig-1a1 •'.:14'1'.'2 MVGEV T6-pe 1..7•1la;i 211: 666 6 7618 "'7 IL-.Ile _..T ----_.....-_..._, lit 41,r,„ jCas 215127x85 jD Foes OO onl Dor, pIn691 Fo Daen 1751 So OOA IT114 G muLon0 aPT1 A (:.. 01114.40881-1 + 5.50111 316 1.13 t 4: 625 -1 •FILED I 344046 3n8e*1 OD Ono 0 ont Top 0105 SO09M014.1 9.46114,(7001. MAM4 04N 340 T14e4a4 104g141D90W1.1O', 21488.E 92. 8.l i 36,4 2.9790 7451. 36,0 1 10 ' 810.4 81.11 C0.,0•4400881 OD 771 DOM Tp MID I0017111 MKS, Is 0114,11501...1160,*'8..Ga4. Top 111•4241 11i0D,0/1)08. 1 67/6 32.8 11,0080 6.980.4 25.10 IA8'. FI 11.72 5.4°51Y�L'%,2119 ..ql 7.4e.611110071.0 D0881 OOM Tp OM070 .) 1411111 44, {. 11 9.3050..511.10.Ora4p . Top _� ':158.8045 6'.8 '6.685.3 23.360 7.082,6 6666. C0,8/00400600 OO On! 0011 ?0701411 140 090.M.1 w 0114,173'01 'Vnlan0 0,40. 1.714.640 {i 10.512 1':1 1.'348. '7,h04r 18.,645.3 I,Of,!..S ^.1.8 13,11: 4'8468;8.iia:98?9�• J Yr IInt.0614115 9.0^447.699; ---III ?.608681 )ep(907001/ p 1 T96 .7 14"I 000 12,694.) 0,912,4 10,01 SI Et-V18 •10741NEI:SE1111.0SIEEVE 66.66 '2,106.9 09'6.4. 714:735135 AS 1,084'0+SEAI 18I11E 4.,.. OAS IEl,9912E -# '2,129.5 6,9:1.2 715E FRASEii OG11E24.OCK tINEN,AN6E14 4.363 '.2.718.8 6,923.1 72.2 SEAL.74013EEk0EASICA 4.001 '3.0686 6,08E 3 8544 544e11 7'.uken IA51713Et:3373P OWl)!546145771St-II 0:5.7-)3 3.92: GA0LI1,17210 OU 0EME8114N VEH .1 3,311 81.10 Se1,154,el INV 8H88CAPSWEt 4 PACxER 860.'10.58,- 3.31' BFA1A557,122112 OD 051/64.113.442511 88002246/1 _. Tubing SInngs 883769,12)110 1 y O < r l61n0p 0,6 . .60+Fp M.l �1e 0MA M1�1M Dp11 Pw11 11 110711 0.4 Ip 14070.®.7 1 7077 'n'. 3?! t},338 697 1 .8 t.'-J Ma96,22X11_-,-. _ Completion 6411111 0.50,41,1286. --{. 84018551 8•611182106813)34064141 OmL L. <.'n 76146PM 014 30.6 306 003 HAEIGEH PVC 1201.',841.^-8I. 4-5:.1 1153 '15.9 0.16 003,314146.4 C.HOSS0v8H 4 5•15,9.1,1.70,51.E-0,^:N0 3.50' 0,4977.12411012A960...--_. 9l 2.'19.5 2,014.3 48.05 SAFE1V VLV6•241601116•241601111438:68.5E 540E1v VALVE 012613-6 25'.2 kkk-�� P110861. 77829 6,131.3 60.77 34741.4022 6876674 SEN 4475EA'61 v 10G1014 36^71 9.44041.194?9 .7.27:6 6.733.1 6029 Fri 6419577 20 81.43 34854 4.110 PAGER 125960 '5,31'0 6,145.} 60.51 P4,6151, 6A181-1.11,81.418 A YACKEH 7.917 '7,313.6 6,765.0 6063 5.15158 H-901,11141E 2.8, *PRE.126665 I '1.44).) 6,8'1.4 6'31 BLASI HIND SCC IU7818i*•61851 HMOINSIALLFU,101' 2.03) '2.416.7 6,824.7 62,31 BLASTH17.C: 'SCC 13,8420081.ASIPoAG INSTAL/ED.1OT12184 2.997 4.03.8105.127041 {---j '2.545.9 6,655.5 61.67 SLEEVES. 83AI485CM1)SWING SLEEVE*12.817 K PROFILE 2,871 461.06.61)5112013;•.411614167110 10 N SLEEVE, 4280 51-`35 LSO NOI ENRAGE,U12NC1 OPEN F r10.44511812227 1 SI FEW 0858.50 OH 61.0556 16''670131 £µ%45v.12739.. 10076,12781 '2,630.1 6,876.1 6653 PACKER BAKER PREMIER PACKER 2.8:1 .. - 6,0025 69.62 MPH. 83,0 AI.AO 3020'1'1 E 2.15' C,415 5.' I'll I OC1.1011 6,80-.121.q141 4514 Save.,n CA:)2 A18091-ELM v 2.96^_ I3 41EU ''-.0I4:7116.92411009 • ♦ 0:2/1 6,9}2.E 15.4'98 PI ASSY 614A:E6 II.AE 6841.SI,., 3.01.." 6,9554 1).71 Si.AI 8259 5604814444.1 91,60 13"1Lai . 6,975_.0 0734 580E silt 6161E P08107*?ons&$tots 0407 Ter 1207 116 ,.11 61 FS97P1321T0112i.' 107111164 .01 011.1 0.1.1 110(.1137 Zane Doe n Typo <an c' 12.476,0 12.436.0 6.72.3 6.6335 Kupaluk CO3 5,62011 120 485.643, 459 39 . 986'.60 deg 08910,13X*613517' '126 11217.0 13,7121 6.091 6,991,7 Aec6010.COS 77220'.] 1.0 15R 4 FP 1.)5.758/8123 1 _ -178 85750.11376 0110&' It II' 11,906.0 11.5720 5,991.) 6,331.%12:,67)4,,1:113 2022 2312 1,1 145.8188 116 PENS 811841. 8 4'3776,1478014210' '. 11,815,0 13,686.0 1000 1,0006 2111764E^:413 )122117 1.0 17E1.1EP• 4 18 853,8 114.2 M 089471,14 814 0 14 911' '4276.1 21,216 1,3018 1,001.5 8.ecnel1.307 732,221? 1.0 141-1458EHE BP 117!' P14'S .1X 01675..14090312*. T}I 14,1'.0 1466'60 1.5142 1014.2 14ec8.e7*,2_110 241'2312 1.6 8E4166' 418 453,E 862-. NI -111 P6077,163010.10741, 14,375.3 14,9800 7,0'5 6 1016.6 8.1,6,414.603 2.72.2012 10 750678 1.76 351:77 81:145 . -126 M97P,15)01016)1< 153420 15,341:" 1.1'7S 7,017,6 8.74341*.003 212.1012 1.0 851451` 4.1t tSRF 8115 1111111 •128 06760,15 690 086576' I 15705.0 157'1^1 1„",03 3 7.0234 34e04.eld,0/03 24 85 7:2012 1.0 1153 4 1?3785 826" a' -128 019747,16,44001644, a.a 16,2.10.2 16.0,6^ :,721.4 7,023.9 8.e511A414,003 272/2012 1C 41-6E13 478 131-141.1,4•S 7944,132170 ill .126 111175.647)9104040'15808 16,440.0 15,442.3 7'34.1 %,034,4 l,711IA,601 2722012 10 55051' 4./9 PEHB 5141/. •128 •11437,17172 017371. it 16,604.0 16,8151 7,1423 1.342.3 Ised8614,603 74217017 1,0 14E141-6' 4.111153,E I114'S •1)9 UM 419581781101754' o 4 11,112.3 51,11).0 1,044.3 7,044.3 Ne31111,603 1422317 1.3 VE1431, 4.781'E07 14.82 .5970,119010173(6. .111 111.1 870,18 216 D18284. -_4'.0 11,548.0 7,3/6.4 1,340.5 14e31e11,603 2722113 10 15)371' 4.18478478 111.06 III -171 7970,19,6,'091157• 4 133;4.1 10180 7,543.1 7,049.2 Asti's/4,003 2/22,2012 1015RrI' 4./8{514610611. ai -/2B u0t6120)47ISOM' t u'P71E18046010.4470 Page 19 of 20 1 HALLIBURTON ConocoPhillips WNS INJ CD3-128 ConocoPhillips ,Q ••• Hlpt£044 00315.Iv2(44.51a11-`• *Meows IRYA 14V0:ER.397 - —rervore6ons&dots M 04r, Ia 90 TopITOD >I aITVOt Top Rslf e.a pnel 400 fall Zr. Ose le� Typo 04. COOt1OOHEB1uC 172%0 16,7)0.0 7.04.7.6 7,062.7 Fe:to*.003 3.727117 1;.mntr I)e,Pl.fir PUPS 16,6110 /6,63),6 7,561.5 7,361,6 0...:t,.4.•-f 1,3 PPOIPP d.76 9111411 1-5l115, 3,•97'.'3 N+17796 Stimulations&Treatments I poMag eu Dean 300* I uI Ow IJ, 0.r3x,E 764151150. • 1IH11 RPM 6(4.4t3 �6l Tr$e One Con qr5 ti7,f097 +1x21.0 2_,36>.: G4011 ),.^BI.E rPAZ 50:25'2 0.0.07 iradtenpe's,IrentrantRl36n ow, t+pe'4tnsDtsN rra spenaerssed Dv t.,nn etupPoc*.T DS 0.214 seeen:.es.Psc,..IJ 7204,0 .n672.nl PA,25.11:Wow Get 1:ec1Rd by ran fin- CAS .1e d 1670CStme n 2Y mos..pN GRS IFI.snJ. t ,*TV4ent423-Wpiee inc.s,7,1. sn4.1Pu.4. OASIS 1225 M_ Mandrel Inserts St MA, von L M Poet Nae MO Run 51345653.12263' 7p rt, r141A IMdw r1or Typo Typo en Ow I R., 0FDie m P ,'2207 5'.;:.` 1:'.2 C;RA v.N;", • .. NI IN.•'. 001140133110 17 `.,`14$.9 Cn C, I:FI.': :111(111 41,,r, 'F 5914: 7,J'J(,IZAA Fact. OCt01 hr *10370'2367 4 73c1.2 471476 CAW() 010.46 Notes:General&Safely wstr7.+J3�7 e�Tr' Osto . En. <-n- .555:5.s _ 4.0TE Wet.nYen PA oh, 11 16 rrl.Ar 110.17 not 0el.1doy rl:..... cIEK,12!f6017!%D— 11e _ SLEEVE 1.12$*, 1 MrrER,I,$%0 a 14PPLE,126651 1 1010110_I220* �# 8G4ee54,13721I MAL 4433.127375_ MOO AIDE,137111 (4797110X,170172111— I. ss 1,40,03.5170.1123 1YP1P,11.55011513 PRIM,130760.41497' 1Pp,04:M601420 1-Earl,14bI104461E- 70013,l49194440 PEPEP.1633015247' _gyp 70000115,7 05 0.15110 lye. Purr.1446VIso3i at 1111 083110,16.40016!0' MMC,172170 0010,16 84 0 6105 ftgrP 17,172012217 .W11? 0175* 11001,175400)5(6- ofG,11$014270' eel1{ 4EPfp,106301110611TI 4•P 2114,12047101.1 0000KYE197e10Yllc". _ Page 20 of 20 WELL LOG TRANSMITTAL DATA LOGGED Li`/2013 M K BENDER To: Alaska Oil and Gas Conservation Comm. December 9, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED DEC 132013 RE: Injection Profile with Spectra Flow: CD3-128 AOGCC Run Date: 12/3/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-128 Data in DLIS format, Digital Log file, Interpretation report 1 CD Rom 50-103-20638-00 Injection Profile with Spectra Flow (Field Print) 1 Color Log 50-103-20638-00 SpectraFlow Oxygen Activation Log(Processed Print) 1 Color Log 50-103-20638-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: ‘2.1 43 Signed: 7\9 CR-a_ Ct).3 17,6 Prb 2-110 370 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, December 04, 2013 9:32 PM ►`efi/ 144 3 To: Grimaldi, Louis R (DOA); NSK DHD Field Supervisor; DOA AOGCC Prudhoe Bay Subject: RE: CD3-128 State witnessed MITIA Attachments: MIT CRU CD3-128 pre injection conversion 11-05-13.xls; MIT CRU CD3-128 pre-witnessed post conversion 11-19-13.xls Lou, Roger has already gone to bed. Yes this is post conversion. It returned to injection 11-7-13. We did 2 recent unwitnessed MITIA's. 1 test before injection began (dated 11-5) and 1 test after injection started (dated 11-19). I've attached forms for your reference. We will check to see if a special flight can be arranged, but as you know this is CD3 and we can only do but so much, outside the normal 2 scheduled flights a week; logistics can be a hurdle even in the best of circumstances. Roger will get back with you tomorrow. Thnks Kelly From: Grimaldi, Louis R(DOA) [mailto:lou.grimaldiftalaska.gov] Sent: Wednesday, December 04, 2013 8:54 PM To: NSK DHD Field Supervisor; DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv Subject: [EXTERNAL]RE: CD3-128 State witnessed MITIA I did not realize the return flight is so late on Sunday. I changeout Monday morning and that is too close. I am the only inspector up here this week and we are quite busy now.Taking two days for a single MIT is out of the question, especially when there is only one inspector up here. What is the possibility of flying over Saturday morning and returning that afternoon. Friday is also open (kind of) but I can't dedicate two days for this test. The CD3 situation is becoming more difficult as things progress Just to be clear this is the post conversion initial MIT correct? Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.Grimaldi(a�Alaska.gov From: NSK DHD Field Supervisor [mailto:NSKDHDFieldSupervisor@conocophillips.com] Sent: Wednesday, December 04, 2013 8:21 PM To: DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv Subject: CD3-128 State witnessed MITIA Lou, I am being informed I cannot get anyone the 0600 flight Sunday from Deadhorse to Alpine. I am requesting information about latest flight Saturday from Deadhorse.Also requesting for overnight billeting @ Alpine on Saturday night. With CD3 flight Sunday morning @ 0645 AM and return flight to arrive @ Deadhorse^'1815 pm Sunday night. Please let me know if this acceptable for you,or if other arrangements need to be made for scheduling. 1 Respectfully Roger Mouser/Ron Wilson CPAI DHD Field Supervisor N2238@COP.com (907)-659-7022(Office) (907)-943-0167(Cell) 2 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reop@alaska.gov• AOGCC.Inspectors(rD.alaska.00vi phoebe.brooks@alaska.00v chris.wallace(rDalaska.00v OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/CRU/CD3 Pad DATE: 11/05/13 OPERATOR REP: Richwine/Miller AOGCC REP: not witnessed Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3-128 ' Type Inj. W ' TVD '6,745' Tubing 290 290 290 290 Interval 0 - P.T.D. 2110370 ' Type test P Test psi 1686.25 Casing 580 '3,500 "3,450 " 3,440 P/F P Notes: pre-injection conversion MITIA OA 260 260 260 260 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT CRU CD3-128 pre injection conversion 11-05-13.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(rDalaska.gov AOGCC.InspectorsCa?alaska.gov; phoebe.brooksAalaska.aov chris.wallaceaalaska.00v OPERATOR: ConocoPhillips Alaska,Inc ,.--?) Jq iz �r3 FIELD/UNIT/PAD: Kuparuk/CRU/CD3 Pad l% DATE: 11/19/13 OPERATOR REP: Richwine/Miller AOGCC REP: not witnessed Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3-128 Type Inj. W _ TVD ' 6,745' Tubing 340 350 330 330 Interval 0 P.T.D. 2110370 - Type test P Test psi '1686.25 Casing 560 2,505 -2,475 2,466 P/F P Notes: MITIA Pre-witnessed post conversion OA 415 455 465 465 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F - Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT CRU CD3-128 pre-witnessed post conversion 11-19-13.xls PTD til - 237 Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Wednesday, October 16, 2013 8:58 AM To: 'Freedman, Kerry C' Subject: Alpine well CD3-128(PTD 211-037, Sundry 313-040) Please see comments in red. Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson[a�alaska.gov From: Freedman, Kerry C [mailto:kerry.c.freedman@)conocoohillips.com] Sent: Tuesday, October 15, 2013 2:47 PM To: Ferguson, Victoria L(DOA) Subject: Alpine well CD3-128 Victoria, We are preparing to convert the subject well to WAG injection as per Sundry number 313-040. We have discussed this well on prior occasions,but I wanted to clarify a couple of details for our operations benefit as follows: 1. The sundry states a requirement for a state-witnessed MIT-IA after stabilized injection. It also states the requirement for a water flow log after stabilized injection,but does not mention witnessing of that log. Does the log need to be witnessed as well?No 2. The well is completed in 2 sands(Kuparuk and Nechelik)within the same pool. We plan to inject commingled into both sands. Does the water flow log need to be run across/directly above the Kuparuk sand only(the shallower sand,selective completion in casing)or does it also need to be run directly above the Nechelik sand too(the deeper sand/openhole lateral )?The water flow log should be run across/above the Kuparuk sand. We want to see if there is any flow above the Kuparuk. Thanks in advance for your assistance in clarifying the above. Please let me know if any further information is needed on this. Regards, Kerry C. Freedman Principal Production Engineer ConocoPhillips Alaska,Inc. 700 G Street,ATO 1760 1 STATE OF ALASKA - AL A OIL AND GAS CONSERVATION CM' SION REPORT OF SUNDRY WELL OPERA(IONS 1.Operations Performed: Abandon r Repair w ell E Rug Perforations r Perforate r • Other AT. Scale Inhibition Alter Casing )— Pull Tubing rStimulate-Frac Waiver r Time Extension r Treatment Change Approved Program EOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Development I✓ , Exploratory f 211-037-0 ' 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic ( Service 50-103-20638-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25538,372105 CD3-128 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 20387 • feet Plugs(measured) none true vertical 7083 feet Junk(measured) none Effective Depth measured 18685 • feet Packer(measured) 12311, 12596 true vertical 7063 feet (true vertical) 6745, 6876 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN: 77 16 114 114 SURFACE 2953 9.625 2989 2451 PRODUCTION 12976 7 13009 6980 LINER 5990 4.5 18685 7063RECEr4V ;. , M4Y 3 1 2U43 Perforation depth: Measured depth: 12476 to 18637 True Vertical Depth: 6824 to 7062 O G C C Tubing(size,grade,MD,and TVD) 3.5, L-80, 12739 MD,6926 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 12311 MD and 6745 ND PACKER-BAKER PREMIER PACKER @ 12596 MD and 6876 ND SSSV-CAMCO TRMAXX-5E SSSV @ 2180 MD and 2014 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12476'-12496' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1013 2140 560 -- 322 Subsequent to operation 2029 3252 16 — 348 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory 1.— Development I✓ • Service I" Stratigraphic 16.Well Status after work: Oil 1i . Gas f WDSPL fl Daily Report of Well Operations XX GSTOR r WIND r WAG r GINJ r SUSP E SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Jack Walker(a 265-6268 Email Jack.A.Walker@cop.com Printed Name Jack Walker Title Supervisor WNS Production Engineering Signature tiL) Phone:265-6268 Date 3 U V` i-' RBDMS MAY 31 2013'` /� 61,40Form 10-404 Revised 10/2012 6.//41`3 //�"' Submit Original Only CD3-128 Scale Inhibition Treatment: 5/10/2013 Initial pressure TBG/IA/OA-1412/1614/412; Facility pumped 50 bbls SW preflush; LRS pumped 2.6 bbls WAW5206 (109 gal)at 0.15 bpm while facility pumped 23 bbls SW at 1.5 bpm, 2446/1592/478; LRS pumped 26.2 bbls SCW4004 (1100 gal) at 0.2 bpm while facility pumped 148 bbls of SW at 1.3 bpm, 2481/1545/514;facility pumped 153 bbls of SW over-displacement. Final pressures: 2481/1545/514. Intervals treated: 12476'—12496' 1 i WNS CD3-128 --- ConocoPhillips Well Attributes Max Angle&MD TD Alaska 61c Wellbore APVUWI Field Name Well Status Incl(°) MD(ftKB) Act Bbn(ftKB) 501032063800 FIORD KUPARUK PROD 91.79 19,230.70 20,387.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Dale "Well Con99"HORIZONTAL-CD3-128,1129/20121240:28 PM SSSV:TRDP Last WO: 2/21/2012 36.80 4/30/2011 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date HANGER,31_-- Last Tag:SLM 12,822.0 8/14/2012 Rev Reason:WELL REVIEW/PERFS/FRAC osborl 11/29/2012 Casing Strings It Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.250 36.8 114.0 114.0 62.50 H-40 Insulated 42" CONDUCTOR ' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd Insubt.d 42-, SURFACE 95/8 8921 36.4 2,989.0 2,451.1 36.00 J-55 BTC-M 37-114 ; Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 32.8 13,009.0 6,980.3 26.00 L-80 BTC-M SAFETY VLV, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd 2,180 -"1 OPEN HOLE 6 1/8 18,685.0 20,387.0 7,082.6 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd D 3 LINER 41/2 3.958 12,694.7 18,685.0 7,061.9 12.60 L-80 IBTM SURFACE, • • Liner Details 38-2.999 Top Depth GAS UFT, (TVD) Top Incl Nomi... 5.098 Top(ftKB) (RKB) F) Item Description Comment ID(in) 12,694.7 6,912.3 70.84 SLEEVE HRD LINER SETTING SLEEVE 5.250 Ilifi r 12,707.0 6,916.4 71.43 NIPPLE RS PACK-OFF SEAL NIPPLE 4.250 GAS LIFT• 12,709.5 6,917.2 71.56 HANGER DG FLEX-LOCK LINER HANGER 4.360 9,973 12,718.8 6,920.1 72.01 SBE SEAL BORE EXTENSION -4.000 GAS LIFT, f 13,068.8 6,985.5 85.76 Swell Packer TAM FREECAP SWELL PACKER FSC-11 WI 5.875"OD 3.920 12,229 CEMENTRALIZER SEAL ASSY, 13,123.3 6,989.7 87.39 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w15.875"OD 3.920 12,293 CEMENTRALIZER PER 12.28e PACKER, ;" Tubing Strings 12,311 4r Tubing Description String 0... String ID...Top OMB) .Set Depth It...Set Depth(TVD)...String Wt...String... String Top Thrd NIPPLE,12.354ill TUBING WO 3 1/2 2.992 30.6 12,738.5 6,925.9 9.30 L-80 EUE Mod GAS LIFT, [Completion Details 12,396 F - Top Depth IMMIF (TVD) Top Incl Nomi... 'r Top(RKB) IRKS) el Item Description Comment ID(in) RPERF, 11$ � 30.6 30.6 -0.01 HANGER FMC TUBING HANGER 4.500 12.478-12,496 .II 30.6 115.9 0.32 XO Reducing CROSSOVER 4.5 x 3.5,9.3,L-80,EUE-MOD 3.500 att: 2,179.5 2,014.3 48.10 SAFETY VLV CAMCO TRMA)0(-5E SAFETY VALVE w/2.813"X PROFILE .2.812 SLEEVE,% at tz 12,282.9 6,731.3 60.27 SEAL ASSY BAKER SEAL ASSEMBLY LOCATOR 3.000 12,287.8 6,732.9 60.06 PBR BAKER 20'80-40 PBR 4.000 PACKER. 12596 12,311.0 6,744.7 60.33 PACKER BAKER PREMIER PACKER 2.970 Alis "' 12,353.6 6,765.9 60.83 NIPPLE HES X NIPPLE 2.813 NIPPLE.12,665 qpfl 111 12,447.7 6,811.1 61.94 BLAST RING SCC TUBING w/BLAST RING INSTALLED,TOP 2.992 LOCATOR AO, tl 11 12,476. 7 6,824.1 62.25 BLAST RING SCC TUBING w/BLAST RING INSTALLED,BOTTOM 2.992 12'704 12,545.9 6,855.4 64.67 SLEEVE BAKER CMD SLIDING SLEEVE w/2.812"X PROFILE(OPENED 5/5/12) 2.810 SEALASSY, 12,596.0 6,876.1 65.91 PACKER BAKER PREMIER PACKER 2.870 12.727 SEAL ASSY,-"--. �` 1 I 12665.5 6,901.6 69.42 NIPPLE HES XN NO GO NIPPLE P o h/ 15 2.750 SHOE.12,738 �� 12,704.3 6,915.5 71.30 LOCATOR GBH-22 LOCATOR SPACED OUT 2'A FULLY LO� '�TED 2.960 )NL 12,727.1 6,922.5 72.41 SEAL ASSY SPACER TUBE SEAL SUB 3.000 2°(3 12,736.5 6,925.3 72.87 SEAL ASSY LOWER SEAL SUBS 3.000 PRODUCTION, 12,738.1 6,925.7 72.94 SHOE MULE SHOE 3.000 33-13.009 Perforations&Slots 1 Shot Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (RKB) (ftKB) Zone Date Intl- Type Comment 12,476.0 12,496.0 6,823.7 6,833.3 Kuparuk, 5/5/2011 12.0 RPERF 4 5/8"39 gm,60 deg phase CD3-128 13,217.0 13,222.0 6,991.7 6,991.4 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP, CD3-128 13,217-13.222 t. 13,508.0 13,512.0 6,991.7 6,990.2 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP, CD3-128 13,508-13.512 --- 41 - 13,875.0 13,880.0 7,000.4 7,000.6 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP. ,_.. CD3-128 13,875-13.880 1111P14,236.0 14,240.0 7,007.3 7,007.4 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP, =. CD3-128 14,236-14.240 -'1-1,'-" MIL, 14,611.0 14,616.0 7,014.1 7,014.1 Nechelik 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP. - CD3-128 14,6t1-14,616 14 14,975.0 14,980.0 7,015.6 7,015.6 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS PERFP, 1.111.-_ CD3-128 14,975-14.980 -!it - 15,342.0 15,347.0 7,018.3 7,0182 Nechelik, 2222012 1.0 PERFP 4.78 PERF PUPS PERFP. Ul!_- CD3-128 15,342-15.397 mi a 15,705.0 15,710.0 7,025.9 7,025.8 Nechelik, 2/22/2012 1.0 PERFP 4.78 PERF PUPS n PERFP. ... ,-: CD3-128 15,705.15.710 - 11 PERFP, __-- Mandrel Details 18,070-18.075 '11- Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run PERFP18,440-6,445Stn Top(ftKB) IRKB) (°) Make Model lin) Sem Type Type (In) (psi) Run Date Com... A-14. 1 5,097.5 3,401.2 63.67 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,845.0 3/12/2012 FRAC,13,217 PERFP• `I.1 ;I 2 9,972.6 5,588.9 63.69 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,883.0 3/12/2012 18,80418,808 3TC PERFP, 3 12,228.6 6,704.7 60.81 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 3/11/2012 -- :. 17,172-17,177 ",It,__: 4 12,396.2 6,786.6 61.33 CAMCO KBMG 1 GAS LIFT CV BK 0.000 0.0 5!5/2012 PERFP,_ 17,541-17.548 PERFP, 17,904-17,908 ars PERFP, _r I 18,268-18.270 a PERFP, 18,633-18,637 N LINER, 12,69518,885 OPEN HOLE. _ 18,68520.3877 N TD,20,38 - WNS CD3-128 ConocoPhilips Alaska.Inc. _ ux:d4„Il I. KB-Grd(R) Rig Release Date 36.80 4/30/2011 Well ConlA HORIZONTAL-CD3-128,11/29/2012 12:4028 PM Schematic-Actual HANGER,31 '® _ Perforations&Slots Shot ----- -- - Top(ND) Btm(TVD) Dens Top(1tKB),Btm(RKB)_ (RKB) (RKB) Zone Date (oh••• Type Comment 16,070.0 16,075.0 7,023.8 7,023.9 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS CONDUCTOR CD3-128 Insulated 42". 37-114 16,440.0 16,445.0 7,034.2 7,034.4 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS CD3-128 SAFETY vw. _ p 16,804.0 16,808.0 7,042.3 7,042.4 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS 2.180 JEW CD3-128 Li 9 17,172.0 17,177.0 7,044.2 7,044.2 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS SURFACE. r CD3-128 -2'9e9 17,541.0 17,546.0 7,046.5 7,046.6 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS GAS LIFT. tr' CD3-128 5,098 17,904.0 17,908.0 7,049.1 7,049.1 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS CD3-128 GAS LIFT. 18,266.0 18,270.0 7,052.6 7,052.7 Nechelik, 2/22/2012 1.0 PERFP 4.78'PERF PUPS 9.973 MIME CD3-128 18,633.0 18,637.0 7,061.7 7,061.7 Nechelik, 2/22/2012 1.0 PERFP 4.7$PERF PUPS GA S1;11•6 LIFT. _ :_ CD3-128 OEM SEALASSV, Stimulations&Treatments 12,283 Bottom P08,12,288 1 I Min Top Max Blot Top Depth Depth PACKER, Depth Depth (ND) (ND) 12,311 (ftKB) (RKB) (ftKB) (MB) Type Date Comment 13,217.0 20,387.0 6,991.7 7,082.6 FRAC 3/9/2012 Performed fracturing treatment,pumping five main NIPPLE.12.354 1=: frac stages consisting of 0-6 ppa stages separated by GAS LIFT. awn four Bioball ball drop sequences.Pumped 220-bbl 12.398 breakdown with 25-lb linear gel,followed by main 11� frac of 467,219-lbs of 16/20 Carbolate in 25#crosslink gel(87%design). During last frac stage,extended the 4-ppa stage to 420-bbl 12,476-12,RPE496 - I 1 Notes:General&Safety End Date Annotation SLEEVE, 12.548VE. e • 5/3/2011 NOTE:View Schematic w/Alaska Schematc9.0 2/21/2012 NOTE:Well suspended after original drill/completion 2011;re-entered and drilled deeper,WO,2012 mom PACKER, 12.596 s NIPPLE.12,885 LOCATOR. 12.704 SEAL ASST. I' 12,727 SEAL ASSY, . 12.736 SHOE,12,738 , PRODUCTION. 33-13,009 tlll� I 13,217-13,2ERF22 PP, Win PERFP. 13,508-13.512 , PERFP. 13,875-13,880 PERFP, _.._ 14.236-14,240 00 1 111M PERFP, --- 14.611-14,616 111 PERFP. 14,975.14.980 i PERFP. I MI 15.342-15.347 11111 PERFP, } 15,705-15.710 ig11_� ' ce■ PERFP. p 18,070-18.075 9 "' PERFP, 16,440-16,445 FRAC,13,217 MINE PERFP, 16,804-16.808 PERFP. i 17,172-17,177 !IRE: PERFP. 17,541-17,546 t 11 11.4 PERFP, 17,904-17,908 PERFP, 18.266-18,270 1-LL PERFP. 18,633-18,637 - U.095-113.685 LINER. 12095-18.685 OPEN HOLE. 18.880,5-20,20,387387 7 _ 5w��V/77,v THE STATE Alaska Oil and Gas fALASIc:A �'►�.csiJl� GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS". Main: 907.279.1433 Fax: 907.276.7542 Tim Nelson Staff Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 a I ` - 101 7 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-128 Sundry Number: 313-040 Dear Mr. Nelson: 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, C .athy Poerster Chair DATED this'1 i day of May, 2013. Encl. STATE OF ALASKA9i4r� . A .,<A OIL AND GAS CONSERVATION COMA. .ON c,1/ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon E Plug for Redrill I— Perforate New Pool r Repair well E Change Approved Program E Suspend E Plug Perforations r Perforate E Pull Tubing E Time Extension r Operational Shutdown E Re-enter Susp.Well E Stimulate E Alter casing I— Other:Convert Prod to WAQ:• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F - Exploratory r 211-037-0 - 3.Address: 6.API Number: Stratigraphic E Service r P.O. Box 100360,Anchorage,Alaska 99510 50-103-20638-00• 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F CD3-128. 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25538,372105 Colville River Field/Fiord 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): • 20387 • 7083 18685' 7062' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2953 9.625 2989' 2451' RECEIVED PRODUCTION 12976 7 13009' 6980' �[L i.� LINER 5990 4.5 18685' 7062' JAN 2'+9 20''�J AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12476-12496' 6825'-6834' 3.5 L-80 12739 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER MD=12311 TVD=6745 PACKER-BAKER PREMIER PACKER MD=12596 TVD=6876 SSSV-CAMCO TRMAXX-5E SSSV MD=2180 TVD=2014 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service F14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/1/2013 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG F• Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Nelson @ 265-6859 Email: Tim.J.Nelson(o�conocoohillios.com Printed Name Tim n Title: Staff Production Engineer Signature Phone:266-6859 Date is J`w 11 Commission Use Only Sundry Number vv jl -.10t4O Conditions of approval: Notify Commission so that a representative may witnessit �.J Plug Integrity r BOP Test r Mechanical Integrity Test }°" Location Clearance r Other: 4 Ni1Y- /f� 1---e- v ✓e•Q cf Fttr �tA b11/ re; re lcc "f - �a lav, SSc A-1-C) 3 , - 3 ✓ / 'i t/:-,-, G i- i-.J t c ha►-, v - cle r RBDMS MAY 3 1 1f+;3 Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: i/c_4c 4_ yVG. fcf- f)aw foci a ft-ty S/zih) 113re/ i-f'cct/al-, reeTi/ r-tcl . /J e- J al BY Approved by: COMMISSIONER ,--S-1-2-5 THE COMMISSION Date: — Approved aplication is valid for 12 months from the date of approval. r 1 -GGINt12) �L ?le' IIS Submit Form and ttac en .n Duplicate 3-f2 9/43 �I�`tz '0:,L 0 (_, t ./ Q (^`B o) • W • E CO r Cl'''\ISSS>8'' ' �' 2 QM O N o FA v Q .31 g4 ® o N Q U t 0 U • g 41 w. .. r 7 a c Iti mt ..:477/ m c 5 3 i 0 4-'t— i.u \ _ _ . . . p1I1// i | \ � '01 11111 4 y -:, �— - \ ill \ \y2\. w./ ":iii - \ I �� \ k . \y. \\� , 1 \ » b . < . . . y DI 4 111 i \\ .// �. »^ ƒ%\\ �/ W4 /n/ 9� _ \�� l ,�rct. &rf ei s - �\ ofn ! ("/m., I\ \ f r -/facktevr ken i/ 7 -=..,_��= ha \ [ iL' !E ki I. § \ £g ! - $[ ƒ *s: Ferguson, Victoria L (DOA) From: Nelson, Tim J <Timothy.J.Nelson©conocophillips.com> Sent: Wednesday, May 08, 2013 10:21 AM To: Ferguson, Victoria L(DOA) Cc: Walker, Jack A Subject: RE: CD3-128(PTD 211-037, Sundry 313-040)Conversion to WAG Attachments: CD3-128 Drilling Program 1st stg cementing.pdf; CD3-128 cementing1.pdf Victoria, The bond log was run with the original completion in the hole—it stopped at the tubing tail. Attached are the cementing portion of the drilling program and the rig report for the cementing. This data combined with the bond log to 12360' showing good cement at that point would indicate that we have cement to at least the 11948', 500' above the Kuparuk,that was planned (40%excess was pumped over this plan). Upon approval to inject water we would run a water flow log to demonstrate there is no movement above the Kuparuk zone. Please let me know if you have other questions or need additional information. Ti N From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson©alaska.gov] Sent: Tuesday, May 07, 2013 2:41 PM To: Nelson,Tim) Subject: [EXTERNAL]RE: CD3-128(PTD 211-037, Sundry 313-040) Conversion to WAG Tim, The cement bond log you supplied starts abruptly at 12360'MD. The packer is at 12311' MD, 165'above the top perforation. Area Injection Order 30 reads '...the production casing cement volume shall be sufficient to ensure cement placement a minimum of 300' MD above the planned packer depth." Why wasn't a bond log run to TOC? What can you provide that will convince us that the TOC is 300' MD above the packer? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W. 7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonalaska.qov From: Nelson,Tim J [mailto:Timothy.J.Nelson@)conocophillips.com] Sent:Thursday, May 02, 2013 10:18 AM To: Ferguson, Victoria L(DOA) Cc: Walker,Jack A Subject: RE: CD3-128(PTD 211-037, Sundry 313-040) Conversion to WAG Victoria, 1 Now that the ice road is winding down I've got time to re-address this project. Attached are the documents you require. Another MITIA will be done when the well is converted–then, within 30 days of starting injection we will have a State witnessed MITIA. I have attached the daily rig report for the day the initial MITIA was done. Please give me a call if you have any questions. Thanks TJ N From: Ferguson, Victoria L(DOA) Sent:Thursday,January 31, 2013 11:39 AM To: 'tim.j.nelson@conocophillips.com' Subject: CD3-128(PTD 211-037, Sundry 313-040) Conversion to WAG Tim, Please provide the following: 1. Map with 1/4 mile radius shown around target injection zone 2. A readable CBL and an engineering interpretation of cement quality in subject well and wells within 1/4 mile radius. 3. Wellbore schematic 4. Mechanical condition of proposed injection well 5. MIT-IA 6. Well summary Some AOR guidelines are provided below: Area of Review—Injection or Service Wells The construction and abandonment requirements for wells drilled in Alaska are not dependent on whether the well is a producer or injector. However, verification of the adequacy of the construction or abandonment of any well is subject to greater scrutiny if a well is proposed as a service well. This verification process is known as the Area of Review (AOR) and it applies to all wells, whether active or abandoned, that are within 1/4 mile radius of a service well. The process also applies when annular disposal is proposed for a well. See: 20 AAC 25.080(b)(4), 25.252(c)(1) and (c)(12) and 25.402(b) and (b)(1). The verification process for the well to be drilled or converted is not very difficult. Generally sufficient information can be developed and gathered while drilling the new well or the existing information in the well file is sufficient to make the determination. For some conversions, a cement evaluation log may be needed to 2 verify current wellbore conditions. In some cases, follow-up logs (temperature, water flow, etc.) may also be needed to confirm placement and confinement of the injected fluids. In order to perform an effective AOR, it is critical that all proximate wellbores and wellbore sections be identified including existing and abandoned wells,plugbacks and "lost" hole sections. For purposes of the assessment, the reference point used to establish an AOR for a proposed injection well is the point at which the wellbore penetrates the productive horizon or for annular disposal, the surface casing shoe. For horizontal service wells, the 'A mile radius continues along the well path through the reservoir to TD. Any wellbore or section identified within an AOR must not provide a pathway that could allow fluids to escape from the receiving zone. Where multiple producing formations are penetrated by a well, an AOR for each zone may need to be assessed. Review of your application by the AOGCC will be facilitated if the drilling or production engineer is familiar with these regulatory requirements and submits adequate AOR documentation as part of the application. Please contact an AOGCC representative with any questions. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonaalaska.gov 3 Nelson, Tim J From: Paul Alldredge <Paul.Alldredge@Halliburton.com> Sent: Friday,April 26,2013 2:39 PM To: Nelson,Tim 1 Subject: [EXTERNAL]CD3-128 CBL interpretation comments. Attachments: CD3-128 RCBL 4-MAY-11.pdf Tim, The following is my interpretation of the CD3-128 Radial Bond Logging Tool response: The Radial Cement Bond Logging tool ran on CD3-128, on the 4th of May 2011, response indicates the following: Throughout the interval survey (12360'to 12854'),the omni-directional amplitude response remains under 10 MV throughout the majority of the interval indicating good acoustic coupling of cement to the pipe. There is also evidence of formation wave forms on the Micro Seismograph (MSG) indicating good acoustic bonding to the formation also. The response of the 6 sectored ultra-sonic transducers response in the"sector map" indicates no presence of any channels or vuggy bond throughout the surveyed interval. In summary, it is my opinion that there are indications that there is adequate zonal isolation throughout the 12360'to 12854' interval in well CD3-128 as it was logged on the 4th of May 2011. Tim, I give you permission to use my name for this too. Thanks, Paul Alldredge Account Leader Halliburton 6900 Arctic Blvd. Anchorage, AK 99518 Office: 907-263-4529 Cell: 907-301-3242 Paul.AlldredgeHalliburton.com From: Alldredge, Paul (Halliburton) [mailto:Paul.Alldredge@contractor.conocoohillips.com] Sent: Friday,April 26, 2013 12:16 PM To: Paul Alldredge Subject: FW: bond log Paul Alldredge Account Leader Halliburton Office: ATO-1307 Office: 907-263-4529 Cell: 907-301-3242 1 • • ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 15,2012 03 7 Commissioner Dan Seamount (9j Alaska Oil& Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU),and the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404,Report of Sundry Operations. The cement was pumped in the spring of 2012. The corrosion inhibitor/sealant was pumped in the months of April and May 2012. The attached spreadsheet presents the well name,top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, tfiri/ Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 5/15/2012 WD,CD2,CD3,CD4,PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal WD-02 50103202850000 1982580 2' n/a 2' n/a 13.6 4/11/2012 CD2-77 50103206290000 2101790 SF n/a 17" n/a 2.1 4/13/2012 CD3-128 50103206380000 2110370 21' n/a 21' n/a 90.7 4/13/2012 CD3-198 50103206370000 2110240 28" n/a 28" n/a 47.6 4/13/2012 CD3-199 50103206350000 2110100 SF n/a 11" n/a 2.9 4/13/2012 CD4-03 50103206410000 2111130 29" n/a 29" n/a 9.4 4/11/2012 CD4-298 50103206230000 2101300 28" n/a 28" n/a 28.9 4/11/2012 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑✓ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: February 23,2012 • 211-037/311-387 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 April 11,2011 50-103-20638-00 4a Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 4027'FNL, 1205'FEL,Sec.5,T12N, R5E, UM February 13,2012 CD3-128 Top of Productive Horizon: 8. KB(ft above MSL): 48.4'RKB • 15.Field/Pool(s): 1811'FNL, 4765'FEL,Sec.7,T12N, R5E, UM GL(ft above MSL): 12.6'AMSL, Colville River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2731'FNL, 818'FEL,Sec. 18,T12N, R5E, UM 18685'MD/7063'TVD Fiord Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-387838 - y- 6003753 • Zone-4 , 20387'MD/7083'TVD, ADL 25538, 372105 TPI: x-378962 y- 6000827 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-382835 • y- 5994566 • Zone-4 SSSV @ 2180'MD/2014'TVD LAS2112 18.Directional Survey: Yes No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1150'MD/1142'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 36.8' 114' 36.8' 114' 42" 8 yards+5.5 sx Ready Mix 9.625" 36# J-55 _ 36' _ 2989' 36' _ 2451' 12.25" 822 sx AS LiteCrete,231 sx Class G 7" _ 26# L-80 32.8' 13009' 32.8' 6980.3' 8.75" 215 sx Class G,225 sx Class G 4.5" 12.6# L-80 12695' 18685' 6912' 7063' 6.125" liner 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 12739' 12311'MD/6745'TVD and 12596'MD/6876'TVD 12476'-12496'MD 6824'-6834'TVD 5 spf 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. RECEIVED . INTERVAL(MD)- AMOUNT AND KIND OF MATERIAL USED 13,218'to 18,678' 467,219 lbs.of 16/20 Carbolite MAR 2 3 2012 Masks Rii&Gas Cons.Commission 27. Andlorcge PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) March 16,2012 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 3/18/2012 12 hours Test Period--> 1627 1398 23 84/64 859 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 527 psi 1759 psi 24-Hour Rate-> 3254 2795 46 29 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. j � J NONE RSDMS APR 0 2 2011 Form 10-407 Revised 12/2009va- CONTINUE ON REVERSE Submit original only r, w 02_0/z0) -2_, ,,,ww..K.,._ 3,i ° 6 28. GEOLOGIC MARKERS(List all formations and mares_., encountered): 29. FORMATION TESTS NAME MD TVD Well tested? 2 Yes Q✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1150' 1142' needed,and submit detailed test information per 20 AAC 25.071. C-30 3044' 2475' C-20 3909' 2861' K-3 6116' 3852' K-2 6494' 4022' K-1 12319' 6748' Top Kuparuk C 12477' 6825' Nechelik 12913' 6966' N/A Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. roz/Contact: Nina Anderso @ 265-6403 • 4L�V\"ip f Printed Name L. v rd Title: Alaska Drilling Manager �- Signature Phone 265-6120 Date 0 3 2 3 t Z Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 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 production from each pool completely segregated. Each segregated pool is a completion. RECEIVED Item 4b: TPI(Top of Producing Interval). MAR 2 3 ZO1Z 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. MAI Oil&Gos Cons,CommissionItem 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). l nwhercge 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 interval to be separately produced,showing the data pertinent to such interval). 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 list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 �L, WNS CD3-128 ConocoPhillips .wes.* Well Attributes Max Angle&MD TD Inc. Wellbore API/UWI Field Name Well Status Incl C) MD(ftKB) Act Btm(MB) Alaska. ,_ - 501032063800 FIORD KUPARUK PROD 91.79 19,230.71 13,020.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:TRDP Last WO: 2/21/2012 36.80 4/30/2011 Well Coils-CD3-128,27'2:2.0,123'.54'07 PM -- ---- 8chematk- Annotation Depth(ItKB) End Date Annotation Last Mod...-End Date Last Tag:SLMt� 12,836.0 5/22/2011 Rev Reason:GLV C/O,SET SLEEVE ninam 2/29/2012 -1-1-ANGER C. ._J Casing Strings Casing Description String 0... String ID...Top(BOO) Set Depth(t...Set Depth(TVD)...String Wt...String... String Top Thrd cf, / CONDUCTOR 16 15.250 36.8 114.0 114.0 62.50 H-40 ty.,. Insulated 42" Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd --_----_- -- - --SURFACE 95/8 8.921 36.4 2,989.0 2,451.1 36.00 J-55 BTC-M Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.000 32.8 13,009.0 6,980.3 26.00 L-80 BTC-M MI Tubing Strings CONDUCTOR Tubing Description String 0... String ID...Top Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd Insulated 42, TUBING 31/2 2992 30 30.66 12,738.5 I 6,925.9 I 9.30 I L-80 I EUE Mod 37114 Completion Details Top Depth Il (ND) Top Incl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) SAFETY VLV, If 30.6 30.6 -0.01 HANGER FMC TUBING HANGER 4.500 2.180"N F SLEEVE,2,180 1 ': 115.9 115.9 0.32 XO Reducing CROSSOVER 4,5 x 3.5,9.3,L-80,EUE-MOD 3.500 2,179.5 2,014.3 48.10 SAFETY VLV CAMCO TRMAXX-5E SAFETY VALVE w/2.813"X PROFILE 2.812 12,282.9 6,731.3 60.27 SEAL ASSY BAKER SEAL ASSEMBLY LOCATOR 3.000 II--� J 12287.8 6,732.9 60.06 PBR BAKER 217 8040 PBR 4.000 LI 12,311.0 6,744.7 60.33 PACKER BAKER PREMIER PACKER 2.970 12,353.6 6,765.9 60.83 NIPPLE HES X NIPPLE 2.813 SURFACE, I I 66 12,447.7 6,811.1 61.94 BLAST RINGS SCC TUBING w/BLAST RINGS INSTALLED,TOP 2.992 lr 12,476.7 6,824.1 62.25 BLAST RINGS SCC TUBING w/BLAST RINGS INSTALLED,BOTTOM 2.992 GAS LIFT' 5,098 { 12,545.9 6,855.4 64.67 SLEEVE BAKER CMD SLIDING SLEEVE w/2.812'X PROFILE 2.810 12,596.0 6,876.1 65.91 PACKER BAKER PREMIER PACKER 2.870 12,665.5 6,901.6 69.42 NIPPLE HES XNIPPLE 2.750 I. 12,704.3 6,915.5 71.30 Locator GBH-22 LOCATOR SPACED OUT 2 ABOVE FULLY LOCATED 2.960 12,727.1 6,922.5 72.41 SEAL ASSY SPACER TUBE SEAL SUB 3.000 IFT, 12,736.5 6,925.3 72.87 SEAL ASSY LOWER SEAL SUBS 3.000 GAS L 5 973 I_ 12,738.1 6,925.7 72.94 MULE SHOE MULE SHOE 3.000 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth IND) Top Incl GAS LIFT, �! Top(ftKB) (ft") CI Description Comment Run Date ID(in) 12.229 7 2,179 2,014.3 48.10 SLEEVE FRAC SLEEVE(OAL=57",2.85"NO GO) 2/26/2012 2.300 Perforations&Slots Shot id SEAL ASSY, Top(TVD) B[m(TVD) Dens 12,283 To ftKB etm(ftKB) (ftKB) (ftKB) Zone Date (oh... T Comment P(ftKB) 1 1 1 Type PBR.12.288 { 12,476 12,496 6,823.7 6,833.3 5/5/2011 6.0 IPERF Shot WI25 Millenium Guns PACKER, `-r�_ Notes:General&Safety 12311 _- End Date Annotation 5/3/2011 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE,12,354 I I, GAS LIFT �� 12.395 } IPE E I �I 12.43'6-12.496 1 I II tII SLEEVE, -1, i 12 46 PACKER, 12,596 , _ NIPPLE.12.665 I Locator,12.704 - --{ l _ Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top(i1KB) (ftKB) (') Make Model (in) hers Type Type (in) (psi) Run Date Com... SEAL ASSY, 1 5,097.5 3,401.2 63.67 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/21/2012 12,727 2 9,972.6 5,588.9 63.69 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/21/2012 SEAL 7z73t' 3 12,228.6 6,704.7 60.81 CAMCO KBMG 0 GAS LIFT SPG 0.000 0.0 2/26/2012 MULE SH12738 4 12,396.2 6,786.6 61.33 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/21/2012 PRODUCTION, 33-13.009 TD(CD3-128), 13,020 LINER, 12,89518.685 1 • ' WNS CD3-128L1 • ConocoPhillips ' ' Well Attributes Max Angle&MD TD Alaska Inc. Wellbore APUUWI Field Name Well Status Incl(") MD(MB) Act Btm(FMB) 5010320638 FIORD KUPARUK PROD 91.79 19,230.70 20,387.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date ••• Well Confl9:-CD3-128L1 2292012355:11 PM SSSV:TRDP Last WO: 2/21/2012 36.80 4/30/2011 • Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag SLM 12,836.0 5/22/2011 Rev Reason:GLV C/O,SET SLEEVE ninam 2/29/2012 HANGER,31 IllMISENNIS -- 11111 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...•String Wt...String...String Top Thrd LINER 41/2 3.958 12,694.7 18,685.0 7,062.8 12.60 L-80 IBTM Liner Details Top Depth (ND) Top Incl Noel... CONDUCTOR Top(ftKB) (RKB) (") Item Description Comment ID(In) Inwot37-114110 12,694.7 6,913.0 70.79 SLEEVE HRD LINER SETTING SLEEVE 5.250 12,707.0 6,917.0 71.39 NIPPLE RS PACK-OFF SEAL NIPPLE 4.250 SAFETY VLV, j. -1.-2,180N. 12,709.5 6,917.9 71.51 HANGER DG FLEX-LOCK LINER HANGER 4.360 SLEEVE.2.180 1--j.11 12,7188 6,920.8 71.96 SBE SEAL BORE EXTENSION 4.000 13,068.8 6,986.4 85.76 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w/5.875"OD 3.920 CEMENTRALIZER 13,1233 6,990.5 87.39 Swell Packer TAM FREECAP SWELL PACKER FSC-11 w/5.875"OD 3.920 SU36-2,989RFACE, I I CEMENTRALIZER GAS LIFT, 5.098 I I GAS 9L,973IFT, GAS LIFT. 12,229 SEAL ASSY, 12.283 POR,12,288 PACKER, - 12,311 NM NIPPLE,12,354 illi GAS LIFT, 12.396 Mir OPP alts RF,6� 1 '' II12.476-1IP2E.49 i am am SLEEVE. - I I 12,546 PACKER, 12.596 NIPPLE,12.665 -- Locator,12,704 - { SEAL ASSY, t 12,SY. SEAL ASSY, j�-�1HOE. MULE SHOE, 12.738 PRODUCTION. , ( , 33-13,009 ltd ME CIOC CIOC 4I I a.a Mandrel Details Top Depth Top Port a a.• (ND) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (%K3) I") Make Model (in) Sery Type Type (in) (psi) Run Date Com... ••a 1 5,097.5 3,401.2 63.67 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/21/2012 ■IN IN 2 9,972.6 5,588.9 63.69 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/21/2012 •I•IIII 3 12,2286 6,704.7 60.81 CAMCO KBMG 0 GAS LIFT SPG 0.000 0.0 2/26/2012 .El■ 4 12,396.2 6,786.6 61.33 CAMCOIKBMG 1 GAS LIFT DMY IBK-5 0.000 0.0 2/21/2012 •.■ IMMI ■1MOM ■ 11 MI 111 ■-U LINER, III 12,695-18,885 •I S• TD (CD3-128L1), II 20,387 CD3-128 Pre Rig Well Work DATE SUMMARY 1/8/12 PRE RWO T-POT(PASSED), PPPOT(PASSED), IC-POT(PASSED), I` _ PPOT (PASSED), FT LDS(ALL FUNCTIONAL) 1/16/12 DRIFT w/2.74"TO 12,865' SLM. PERFORMED SBHPS @ 12,864' RKB. (MAX PSI=3184 MAX TEMP=162*) PULLED OV @ 12,235' RKB. NO EROSION/CORROSION. PULLED CATCHER @ 12,355' SLM. READY FOR FLUSH. 1/20/12 SET 3"XPO PLUG @ 12359' RKB (ASSY=XN-LOCK,X-EQ SUB &XPO PUMP OPEN SUB/5 PINS/2800#TO SHEAR/S/N: G2047101-M101041314/OAL= 33"). SET 2.85" NO- GO FRAC SLEEVE (MIN ID=2.265"/OAL= 55") @ 2170' RKB. READY FOR BPV. 1/21/12 BLED ENERGIZED FLUID OFF IA f/ 1500 psi>>>400 psi. SET 3.5" BPV. TESTED XPO PLUG & BPV TO 1000 psi (188 BBLS TO FILL UP). **PASS** READY FOR RIG. ConocoPhiIIips Time Log & Summary We/View Web Reporting Report Well Name: CD3-128 RigName: DOYON 19 Job Type: DRILLING SIDETRACK Rig Accept: 1/31/2012 11:59:00 PM YP Rig Release: 2/23/2012 4:00:00 PM Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 01/21/2012 24 hr Summary Released rig f/CD4-27-Moved pipe shed-ball mill-pit&motro compleses away f/sub-trouble shoot sub base CAT motor 18:00 00:00 6.00 MIRU MOVE MOB P Seperate pipe shed&move to east end of pad-Hook up to ball mill& pull away from pit complex- Moved motor&pit complexes away from sub base-Trouble shoot sub base Cat motor 01/22/2012 Move pit&motor complexes in close to sub base&hook up air to sub-Trouble shoot sub base CAT motor- Rig move on weather hold-Working on work orders- frequent walk arounds checking running equipment 00:00 00:00 24.00 MIRU MOVE SFTY T Move pit&motor complexes in close to sub base&hook up air to sub- Trouble shoot sub base CAT motor- Rig move on weather hold-Working on work orders- frequent walk arounds checking running equipment 01/23/2012 Wait on weather-Working on work orders-Trouble shooting sub base CAT engine 00:00 00:00 24.00 MIRU MOVE MOB T Cont.to trouble shoot sub base CAT engine-Working on work orders- Rig move on weather hold-Cont.to make frequent checks on running equipment for any leaks 01/24/2012 Weather hold-Working on work orders-Trouble shooting sub base CAT engine and pipe shed cold start engine 00:00 00:00 24.00 MIRU MOVE MOB T Cont.to trouble shoot sub base CAT engine and pipe shed cold start- Working on work orders-Rig move on weather hold-Cont.to make frequent checks on running equipment for any leaks 01/25/2012 Weather hold-Working on work orders-Trouble shooting sub base CAT engine and pipe shed cold start engine. -Cont.to make frequent checks on running equipment for any leaks.Work on SCR's#1,#2 and#3. Note:Cat engine#5 in the sub appears to be running fine after using warmer inside air. Pipe shed engine running. Page 1 of 25 Time Logs Date From To Dur S.Depth Depth Phase Code Subcode T Comment 00:00 00:00 24.00 MIRU MOVE MOB T Cont.to trouble shoot sub base CAT engine and pipe shed cold start- Working on work orders-Rig move on weather hold-Cont.to make frequent checks on running equipment for any leaks.Work on SCR's#1,#2 and#3. Note:Cat engine#5 in the sub appears to be running fine after using warmer inside air. Pipe shed engine running fine. 01/26/2012 Working on work orders-Rig move on weather hold-Cont.to make frequent checks on running equipment for any leaks,checking tire pressures. 00:00 00:00 24.00 MIRU MOVE MOB T Working on work orders-Rig move on weather hold-Cont.to make frequent checks on running equipment for any leaks,checking tire pressures. 01/27/2012 Rig move on weather hold-Cont.to make frequent checks on running equipment for any leaks,checking tire pressures. Disconnect electric(Pits&Mtrs)f/sub,move pits and mtrs back,skid rig floor to moving position, Raise cellar back wind wall and stomper feet,trouble shoot moving system(not staying running),trying to roll tires and warm up hydraulic oil with wheels u.. 00:00 06:00 6.00 MIRU MOVE MOB P Disconnect electric(Pits&Mtrs)f/ sub,move pits and mtrs back,skid rig floor to moving position. 06:00 18:00 12.00 MIRU MOVE MOB T Rig move on weather hold-Cont.to make frequent checks on running equipment for any leaks,checking tire pressures. 18:00 20:00 2.00 MIRU MOVE MOB P Raise back cellar wind wall. Raise stomper feet. 20:00 21:00 1.00 MIRU MOVE MOB P Engage hydraulics for Columbia moving system on sub. Roll front and back tires to warm up hydraulic oil (wheels up). 21:00 00:00 3.00 MIRU MOVE MOB P Trouble shoot moving system(not staying running),trying to roll tires and warm up hydraulic oil with wheels up. 01/28/2012 Move sub off well-down the pad-set down,pickup matting boards,sending misc to CD3. Load MI Swaco Ball Mill,move to CD3, prepare modules and sub to move to CD3. Hooking up trucks and cats for the move. 00:00 00:15 0.25 MIRU MOVE MOB P Pre job safety meeting. 00:15 00:30 0.25 MIRU MOVE MOB P Move sub off well CD4-27. 00:30 01:30 1.00 MIRU MOVE MOB P Maneuver sub,move down pad. 01:30 01:45 0.25 MIRU MOVE MOB P Lower sub down to ground. Page 2 of 25 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 06:00 4.25 MIRU MOVE MOB P Pickup mats, load out to CD3.Clean up around cellar area.Ship out 6 pieces(upper and lower RCD, new bearing section,lubricator skid, lubricator hose reel and aluminum tool box(8'x 4"x 3')of Schlumberger MPD pieces to J1,so more work can be performed by Schlumberger rep Paul. 06:00 15:00 9.00 MIRU MOVE MOB P Load ball mill on Peak Sow. Prepare to move off pad. Electricain working on temperary power f/the MI Swaco ball mill. Disconnect f/rig power, connect to standby generator. Standby generator was not 600 volt. Part arrived to fix engine/generator in the ball mill.Cummings rep install new part,fixed power source in the ball mill. 15:00 19:00 4.00 MIRU MOVE MOB P Leave CD4 with ball mill to move to CD3 pad.Set ball mill down. Petunia road back to CD4 pad. 19:00 20:30 1.50 MIRU MOVE MOB P Prepare to move pit module,motor module and sub.Apply weights to two Peak Sows.Crews preparing sub to move. Drive sub back and forth on the pad,checking out moving system. 20:30 00:00 3.50 MIRU MOVE MOB P Two weighted Sows on location,two more cats coming(ETA 2300 hrs+). Hooking up pit and motor complex's. 01/29/2012 Move pits, motors f/CD4 to CD3. Maneuver into preliminary position, hook up lines.Moving sub f/CD4. Had a hydraulic line leak about 3 miles from CD4. Fixed hose,continued moving.While climbing up the mats on the ice bridge,the#5 Cat engine/generator died.Trouble shoot engine. 00:00 00:15 0.25 MIRU MOVE MOB P Pre job safety meeting. 00:15 00:30 0.25 MIRU MOVE MOB P Prepare pits(use 2 D-8 cats and weighted Sow)and motors(use 1 D9 cat and a weighted SOW) to move off pad. Prepare sub f/move.Travel down the pad with modules. 00:30 06:30 6.00 MIRU MOVE MOB P Left CD4 pad w/pits @ 0030 hrs, motors left 0045 hrs and the sub @ 0100 hrs.Tavel approx 4 miles with motors and pits(CD4 intersection). Refuel and make checks from 0400 hrs to 0445 hrs.Continue to move towards CD-2.Off the gravel road with both complex's @ 0630 hrs. Subbase had a hydraulic line failure about 0430 hrs, 1 mile prior to reaching CD4 intersection.Working to repair hose. Page 3 of 25 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:30 18:00 11.50 MIRU MOVE MOB P Repair hose on sub,continue to move towards CD-3.Sub was at mile 4 on the ice road @ 1800 hrs. Continue to move pits and motors from CD2/ice road to CD-3. Motors and pits were at CD-3 at 1600-1700 hrs. Maneuver onto mats. 18:00 23:00 5.00 MIRU MOVE MOB P Continue moving sub f/mile 4 on the ice road to CD3. Moving engine/generator(Cat#5),engine shut down while moving sub up onto ice bridge mats. Maneuver pits and motors into preliminary position on the mats. Hooking up lines between modules. 23:00 00:00 1.00 MIRU MOVE MOB P Trouble shoot#5 Cat engine/generator.Crew change. 01/30/2012 Trouble shoot Cat#5 with sub at the ice bridge/matting boards(13 miles f/CD4).Continue to move rig sub to CD3,maneuver and set down over well CD3-128. Lower stomper feet&back cellar wind wall.Skid rig to drilling •osition. Spot pits and motors, Riggin up. Move camp f/CD4 to CD3. 00:00 02:00 2.00 MIRU MOVE MOB P Continue to trouble shoot#5 Cat Iengine/generator. 02:00 05:30 3.50 MIRU MOVE MOB P Continue moving:move sub up onto ice bridge mats(approx 13 miles from CD-4).Off of the mats @ 0230 hrs,continue and off the bridge @ 0250 hrs.Moving towards CD3. Arrived at the ice pad @ 0420 hrs, onto gravel pad @ 0440 hrs,and over the well CD3-128 @ 0530 hrs. 05:30 12:00 6.50 MIRU MOVE MOB P Set rig down over well CD3-128. Lower stomper feet. Lower cellar back windwall.Jack rig to drilling position. Spot pits and motors up to rig. Prepare and move camp f/CD4 pad to CD3 ice pad. 12:00 00:00 12.00 MIRU MOVE MOB P Rig up lines f/sub to the pits and motors. Rig up lines and hoses on sub. Moving camp f/CD4 pad to CD3 ice pad. Return to move and get shop, electricians shack and casing van. Set shop,electric house.Casing shack was loaded backwards on trailer.Offload and load from the other end to set properly. 01/31/2012 Set MI Swaco ball mill w/Peak sow and cat. Hook up to pipe shed @ CD4.Travel pipe shed f/CD4 to CD3 w/weighted Sow and cat,spot and rig up pipe shed and heater.Weather hold. 00:00 00:15 0.25 MIRU MOVE MOB P Pre job safety meeting on setting MI Swaco ball mill. 00:15 01:45 1.50 MIRU MOVE MOB P Peak move and set MI Swaco ball mill. Set down. 01:45 02:00 0.25 MIRU MOVE MOB P PJSM on moving pipe shed f/CD4 to CD3. Page 4 of 25 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:00 04:00 2.00 MIRU MOVE MOB P Load Sow w/pallets of MI-Wate for traction.Travel to CD4. Hook up to pipe shed w/Sow(weighted w/ pallets of barite)and D8 cat. 04:00 14:00 10.00 MIRU MOVE MOB P Peak travel f/CD4 to CD 3 with pipe shed. 14:00 15:30 1.50 MIRU MOVE MOB P Peak spot the pipe shed. 15:30 21:30 6.00 MIRU MOVE MOB P Prepare to and move pipe shed into position, rig up. 21:30 00:00 2.50 MIRU MOVE MOB T Continue rig up while weather hold due to extreme cold. 02/01/2012 Wait on weather, prep pipe shed,perform maitenance work orders, RU and pull BPV with FMC, lay out high line cable. 00:00 12:00 12.00 SLOT RPCOM MOB T Wait on weather, prep pipe shed, perform maintenace work orders. Rig accepted 00:01 Hrs 2/1/12. RT-ULDS=30.77' RT-LLDS=33.81' RT-GL=35.80' 12:00 00:00 12.00 SLOT RPCOM RURD T Continue waiting on weather, PJSM, RU,test and pull BPV with FMC lubricator, lay out highline cable. Test rig evacuation alarm. 02/02/2012 Continue wait on weather, Load 4"DP to shed, RU tiger tank,test hanger seals, RU to and displace out diesel,crude and seawater with 9.3 ppg brine.Attempt to vac tiger tank,truck broke down, PU and stand back 4"DP while wait on replacement vac truck.Suck tank and continue displacing to 9.3 brine,observe well static with 9.3 brine around,spot 31 bbls 9.6 brine on bottom, U-tube to balance and observe well static for 30 min. 00:00 06:00 6.00 SLOT MOVE MOB T Continue wait on weather. 06:00 08:00 2.00 SLOT RPCOM OTHR P Load pipe shed w/4"drill pipe. 08:00 10:00 2.00 SLOT RPCOM RURD P Rig up secondary containment,tank and hardline. Run steam through lines to tank.Test lines w/air-OK. 10:00 10:15 0.25 SLOT RPCOM DHEQ P Test hanger seals to 5000 psi f/10 minutes-good. 10:15 12:00 1.75 SLOT RPCOM RURD P Rig up lines for displacement. 12:00 12:15 0.25 SLOT RPCOM SFTY P Pre job safety meeting on testing lines for displacment. 12:15 12:45 0.50 SLOT RPCOM RURD P Continue to rig up f/dispalcement. 12:45 13:30 0.75 SLOT RPCOM PRTS P Pressure test lines to 2000 psi-OK. 13:30 13:45 0.25 SLOT RPCOM SFTY P Pre job safety meeting on displacement. 13:45 14:30 0.75 SLOT RPCOM DISP P Displace,pump 39 bbls 9.3 ppg with Safe Surf-O follwed by 241 bbls 9.3 ppg brine at 250 gpm, 1350 psi.Shut down to strap and empty tank.Vac truck broke down. 14:30 16:00 1.50 SLOT RPCOM RURD P Blow down and rig down lines. 16:00 16:15 0.25 SLOT RPCOM SFTY P Pre job safety meeting, PU mouse hole and RU to PU 4"DP Page 5 of 25 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 16:15 17:00 0.75 SLOT RPCOM PULD P PU and standback 4"DP via mouse hole. 17:00 17:30 0.50 SLOT RIGMNI SVRG P Service top drive and drawworks. 17:30 19:45 2.25 SLOT RPCOM PULD P Continue PU 4"DP via mousehole, replacement vac truck sucked tiger tank. 19:45 20:45 1.00 SLOT RPCOM RURD P RU to continue displacing,pressure test lines. 20:45 21:45 1.00 SLOT RPCOM DISP P Continue displacing to 9.3 ppg brine, pumped 200 bbls at 4 bpm. ICP 570 psi, FCP 820 psi. 21:45 23:15 1.50 SLOT RPCOM OWFF P Blow down lines, U-tube well and observe well static for 30 min while vac truck suck 90 bbls from tiger tank. 23:15 00:00 0.75 SLOT RPCOM DISP P Pump 31 bbls 9.6 ppg brine,spot and balance with 99 bbls 9.3 ppg brine continue taking returns to tiger tank. 02/03/2012 U-Tube to balance,observe well static 30 minutes, RD lines,set and test BPV, ND Tree, NU adapter, DSA and BOPs, remove BOP's and DSA,shorten DSA studs, reinstall DSA and BOP's, RU to test BOPs, RD Riser, replace API ring, RU riser. RU and test BQP's. 00:00 00:30 0.50 COMPZ RPCOM OWFF P U-tube to balance fluids. 00:30 01:00 0.50 COMPZ RPCOM OWFF P Observe well static for 30 minutes. 01:00 01:30 0.50 COMPZ RPCOM RURD P Blow down and rig down lines, pull tree cap 01:30 01:45 0.25 COMPZ WHDBO PRTS P FMC set BPV with dry rod 01:45 02:30 0.75 COMPZ WHDBO PRTS P RU and test BPV from direction of flow to 1,000 psi for 10 minutes pumping into IA through GLM against plug in XN nipple. Blow down and rig down. 02:30 04:15 1.75 COMPZ WHDBO NUND P PJSM, ND tree, FMC install blanking plug, RD control line from wellhead. 04:15 10:30 6.25 COMPZ WHDBO NUND P Remove spool from BOP, NU Alpine speed head adapter, DSA and BOP's. DSA bolts too long. 10:30 12:30 2.00 COMPZ WHDBO NUND T PJSM,remove BOP's,shorten DSA studs. 12:30 17:45 5.25 COMPZ WHDBO NUND T PJSM, NU BOP's 17:45 18:45 1.00 SLOT WHDBO NUND P Remove spool from BOP landing. 18:45 19:15 0.50 SLOT WHDBO RURD P Blow down choke and top drive 19:15 20:00 0.75 SLOT WHDBO RURD P PJSM,RU for BOP test w/4-1/2" test jt 20:00 22:00 2.00 SLOT WHDBO BOPE T PJSM, LD test jt, RD riser and bell nipple,change out leaking API ring, install riser, lines. 22:00 22:45 0.75 SLOT WHDBO RURD T Install test Jt and RU to test Page 6 of 25 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 22:45 00:00 1.25 SLOT WHDBO BOPE P Test BOPE as follows:Annular to 250/2500 psi, upper rams with 4-1/2" test joint.Auto/man IBOP.Choke manifold valves 1-5-14-14-16-2-10-13, needle valve to 250/3500.Test HCR kill,test dart/TIW valve. 02/04/2012 Continue TEST BOPE,pull BPV, RU to and shear plug in XN with 2700 psi,bullhead 20 bbls into perfs,bleed off,monitor pressure, RU, BOLDS and pull tubing free with 140K, u-tubing over tubing, land back out, RU and screw in top drive, pull hgr to floor,CBU x 2,some gas at BU,cont circ,weight up from 9.3 to 9.6,observe well slight loss at 6 bph, LD Hgr and tubing to 8710'.70 of 71 SS bands recovered. 00:00 04:00 4.00 COMPZ WHDBO BOPE P Continue test BOPE,Test choke valves 7-11-12-6-9-8-3-4, HCR choke, 4"Demco on kill,manual choke/kill, lower rams with 4-1/2"test joint, blind rams to 250/3500 psi,test annular to 250/2500 psi upper/lower rams to 250/3500 psi with 3-1/2"test joint,accumulator test,function test gas alarms,draw down test on manual and super choke.AOGCC_ Bob Noble waived witness. 04:00 05:00 1.00 COMPZ WHDBO RURD P Retrieve FMC blanking plug. Blow down lines. 05:00 05:15 0.25 COMPZ WHDBO OTHR P Pull back pressure valve. 05:15 05:30 0.25 COMPZ RPCOM SFTY P Pre job safety meeting. 05:30 06:30 1.00 COMPZ RPCOM RURD P Change elevators to 4-1/2"tubing. Make up landing joint, remove pup from the top of landing joint.Make up headpin. 06:30 06:45 0.25 COMPZ RPCOM SFTY P Pre job safety meeting. 06:45 07:00 0.25 COMPZ RPCOM CIRC P Test mud lines to 3500 psi-good. Pressure up to shear plug in the XN nipple @ 12359'.Sheared at 2700 psi. 07:00 07:15 0.25 COMPZ RPCOM CIRC P Pump 20 bbls into the formation (perfs @ 12476'to 12496'). Pumping 2 bpm w/initial circ pressure of 1540 psi and final of 2130 psi. 07:15 08:00 0.75 COMPZ RPCOM OWFF P Bleed off pressure,shut in w/build up to 320 psi in 7 minutes,bleed off, shut in-built to 200 psi in 5 minutes, bleed off,shut in-built to 120 psi in 4 minutes,bleed off pressure,shut in-built to 80 pis in 5 minutes,bleed off,shut in-built to 30 psi in 10 minutes. 08:00 09:30 1.50 COMPZ RPCOM OWFF P Monitor pressure while changing out a 4"demco valve on the standpipe. 20 psi to 10 psi.Monitor annulus pressure @ 10 psi. 09:30 10:30 1.00 COMPZ RPCOM RURD P Blow down lines. Rig up lines and headpin. Install 4-1/2"IBT pup joint back to top of landing joint. Page 7 of 25 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10:30 10:45 0.25 COMPZ RPCOM PULL P Latch onto landing joint w/elevators. Back out lockdown screws. Pull, tubing free w/140k on weight indicator. 10:45 12:00 1.25 12,312 12,282 COMPZ RPCOM RURD P Flowing up tubing once hanger clear of tubing spool. Land string.remove bell guide, make up headpin. Attempt again,"U"tubing from annulus to tubing. PJSM,then rig up to screw top drive w/crossover into tubing. Pull 30'to get hanger above rig floor. PU wt 140k. 12:00 14:00 2.00 12,282 12,282 COMPZ RPCOM CIRC P Circulate 9.3 brine. Pumping 6 bpm w/880-890 psi. Observed some gas on bottoms up,continuing until surface to surface volume pumped. 14:00 14:45 0.75 12,282 12,282 COMPZ RPCOM CIRC P Continue to circulate 6 bpm w/890 psi. 14:45 16:45 2.00 12,282 12,282 SLOT RPCOM CIRC P Slow rate to 5 bpm w/650 psi. Weight up f/9.3 ppg to 9.6 ppg for trip margin. 16:45 17:45 1.00 12,282 12,183 SLOT RPCOM PULL P Break off landing joint, hanger,then two joints of 4-1/2"12.6 ppf L-80 IBT tubing,break crossover(4-1/2"IBT-m x 3-1/2"EUE-m). Line up on trip tank to monitor well. Spooling Camco 1/4"control line, removing stainless steel bands. 17:45 18:00 0.25 12,183 12,183 SLOT RPCOM RURD P Change elevators to 3-1/2".Monitor well on the trip tank.6 bph static loss rate. 18:00 21:30 3.50 12,183 10,123 SLOT RPCOM PULL P Lay down 3-1/2"tubing from 12,183' to 10,123'. 21:30 21:45 0.25 10,123 10,123 SLOT RPCOM SSSV P Remove control line from SSSV, remove control line spool from floor, LD SSSV. 70 of 71 SS bands recovered. 21:45 00:00 2.25 10,123 8,710 SLOT RPCOM PULL P Lay down 3-1/2"tubing from 10.123' to 8710' 02/05/2012 Continue laying down 3-1/2"EUE-m completion f/8710'. Break UD x-o's on the top of landing joint RU/then test BOPE equipment w/4"test jt. MU fishing BHA,sin le in the hole w/4"dp to 8989'. 00:00 06:00 6.00 8,710 2,910 SLOT RPCOM PULL P Lay down 3-1/2"tubing from 8710'to 2910'.295 jts+jewlery layed down. Monitor well on trip tank.Avg 4 bph losses over calculated. 06:00 10:00 4.00 2,910 0 SLOT RPCOM PULL P Lay down 3-1/2"tubing from 2910'to 0'..384 jts of 3-1/2"+jewelry layed down.Monitor well on trip tank.Avg 4 bph losses over calculated. Calculated 41.5 bbls,actual 103 bbls. Note:A total of 42 joints of 3-1/2" were identified w/bad threads.These were marked. Page 8 of 25 Time Logs Date From To Dur ,S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:45 0.75 0 0 SLOT RPCOM RURD P Change out elevators to 4"dp. Pick up the 4-1/2"landing joint"A". Break out the headpin and crossovers on top. Change elevators, lay down landing joint"A". 10:45 11:00 0.25 0 0 SLOT RPCOM OTHR P Clear equipment from the floor. 11:00 11:30 0.50 0 0 SLOT WHDBO RURD P Rig up to test BOPE w/4"test joint. Drain stack,set test plug, rig up to test. Rig up to circ and keep hole full under the test plug w/the trip tank. 11:30 14:00 2.50 0 0 SLOT WHDBO BOPE P Fill hole w/water,work air out of system.Test bottom pipe rams (3-1/2"x 6"VBR's),top pipe rams (3-1/2"x6")to 250 psi low and 3500 ,psi high.Test annular to 250 psi low and 2500 psi high. Hold each test f/ 5 minutes.Charted tests. 14:00 14:45 0.75 0 0 SLOT RPCOM RURD P Pull test joint, install 8-3/4"ID wear bushing. Install bell guide on top drive. 14:45 17:00 2.25 0 216 SLOT WELLPF PULD P Pick up fishing BHA to 216' 17:00 00:00 7.00 216 8,989 SLOT WELLPF TRIP P Single in the hole w/BHA on 4"XT39 drill to 8989' PUW=175 SOW=135 02/06/2012 Con't RIH w/fishing BHA, single in the hole w/4"dp f/8989'to 11176,monitor well,slip and cut drill line, con't trip in,engage fish Cad 12287',work fish free,circ 2 BU's,monitor well, POOH w/fish f/12365'to 216', UD BHA, UD fish, replace wear bushing, PU/MU 6-1/8"drilling BHA. Initialize MW), 00:00 01:30 1.50 8,989 11,176 COMPZ RPCOM TRIP P Continue to single in the hole w/ BHA on 4"XT39 drill from 8989'to 11176'. PUW= 175 SOW= 135 01:30 01:45 0.25 11,176 11,176 COMPZ RPCOM SFTY P Pre job safety meeting. 01:45 02:00 0.25 11,176 11,176 COMPZ RPCOM OWFF P Monitior well-static losses 3.5 bph. 02:00 03:00 1.00 11,176 11,176 COMPZ RIGMNI SLPC P Slip and cut 53'of 1-3/8"drilling line. Service rig.Set Totco block height. 03:00 04:00 1.00 11,176 12,225 COMPZ RPCOM TRIP P Continue trip in the hole f/pipe shed w/fishing BHA Trio in f/11176'to 12225' 04:00 04:15 0.25 12,225 12,225 COMPZ RPCOM OWFF P Monitior well 04:15 04:30 0.25 12,225 12,287 COMPZ RPCOM TRIP P Continue trip in the hole f/derrick w/ fishing BHA.Trip in f/12225'to 12287'.Calculated displacement f/ trip 81.2 bbls,actual 28.5 bbls. Lost 52.7 bbls in 13.25 hrs(approx 4 bph losses). III Page 9of25 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04:30 05:00 0.50 12,287 12,365 COMPZ RPCOM FISH P Break circulation @ 3bpm w/330 psi.Obtain parameters: PU wt 205k, SO wt 148k, Rot wt 175k w/40 rpm and 10.5k ft lbs of torque. Engage fish. Pull to 230k,wait on jars to bleedof f/5 minutes. Pull to 270k. Work pipe from 280k to 210k. Packer released @ 280k.Verify free and allow elements to relax. 05:00 05:15 0.25 12,365 12,365 COMPZ RPCOM OWFF P Monitor well-slight losses. 05:15 08:45 3.50 12,365 12,365 COMPZ RPCOM CIRC P Circulate 3 bpm w/380 psi.After 90 bbls pumped,pressured up to 500 psi. Shut down,work string,allow packer elements to relax.Continue to circulate,after 20 more bbls, pressure up to 600 psi.Again shut down,allowed to relax,continued to circulate 3 bpm w/380 psi. Circulated two bottom's up.Observed gas to surface after 1/2 bottoms up. 08:45 09:00 0.25 12,365 12,365 COMPZ RPCOM OWFF P Monitor well-4 bph static losses. 09:00 09:15 0.25 12,365 12,290 COMPZ RPCOM TRIP P Stand back a stand, blow down the top drive. 09:15 12:00 2.75 12,290 8,970 COMPZ RPCOM TRIP P Trip out of the hole slow on the trip tank f/12290'to 8970'. 12:00 12:15 0.25 8,970 8,970 COMPZ RPCOM OWFF P Pull slips and stripper rubber. Monitor well. Fluid dropping. Calculated 3.5 bph losses. 12:15 17:45 5.50 8,970 216 COMPZ RPCOM TRIP P Continue to POOH w/fish f/8970'to 21ST. 17:45 18:00 0.25 216 216 SLOT RPCOM OWFF P Monitor well.fluid still dropping at 3.5 `ph+/- 18:00 19:45 1.75 216 0 SLOT RPCOM PULD P LD fishing BHA, retrieved complete fish, PBR/FHL packer assy,joint 3-1/2"tubing,XN nipple,3-1/2"pup, WLEG, LD same 19:45 20:30 0.75 0 0 SLOT RPCOM RURD P Change out elevators, clear and clean floor. 20:30 21:00 0.50 0 0 SLOT RPCOM RURD P PJSM,change out wear ring to 7"ID 21:00 23:00 2.00 0 103 PROD1 WELLPF PULD P MU 5200 Geo Pilot drilling assy 23:00 00:00 1.00 103 103 PROD1 WELLPF PULD P Intialize MWD 02/07/2012 M l BHA#7-RIH to 8491'-POOH to MWD reload MWD-RIH to 9920' w/ BHA#8(same components a_s BHA#7) 00:00 01:30 1.50 103 424 INTRM1 CEMEN"PULD P Cont. MU BHA#7-MU float sub- PU NM flex DC's-jars-1 jt HWDP- Drilling bumper sub-4 jts. HWDP-2 jts 4"DP to 424' 01:30 02:00 0.50 424 424 INTRMI CEMEN"OTHR P Shallow pulse test MWD @ 200 gpm 2 750 psi-rotate string to break in GeoPilot bearings 02:00 08:00 6.00 424 6,584 INTRMI CEMEN"TRIP P Blow down TD-Flow ck-RIH f/424' to 6584'(picking up 4"DP f/shed)- fill pipe every 20 stds Page 10 of 25 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:30 0.50 6,584 6,584 INTRM1 CEMEN"CIRC P Circ pipe volume @ 5 bbls/min @ 1250 psi 08:30 09:45 1.25 6,584 8,491 INTRM1 CEMEN"TRIP P Blow down TD-Flow Ck-RIH f/ 6584'to 8491'-filling pipe ever 20 stds. 09:45 10:15 0.50 8,491 8,491 INTRM1 CEMEN"OWFF T Monitor well-while waiting on decision on MWD tool from Anchorage 10:15 11:30 1.25 8,491 8,491 INTRM1 CEMEN"CIRC T Circ DP&annular volume for trip @ 220 gpm @ 1400 psi 11:30 16:00 4.50 8,491 393 INTRM1 CEMEN'TRIP T Blow down TD-POOH on TT f/8491' to 393' 16:00 16:45 0.75 393 103 PROD1 CEMEN'TRIP T Flow ck(fluid level dropping slowly- Std back HWDP-LD bumper sub- Std back NM flex DC's-Change elevators for 3 1/2"BHA 16:45 17:15 0.50 103 103 PROD1 CEMEN"OTHR T Plug into MWD&reprogram ADR 17:15 18:00 0.75 103 393 PROD1 CEMEN"TRIP T Change elevators-RIH w/NM flex DC's-HWDP-jars&bumper sub to 393' 18:00 18:15 0.25 393 393 PROD1 CEMEN"CIRC T Shallow pulse test MWD tools @ 210 gpm @ 800 psi 18:15 22:45 4.50 393 8,491 PROD1 CEMEN"TRIP T RIH f/393'to 8491'-Filling pipe every 20 stds 22:45 00:00 1.25 8,491 9,920 PROD1 CEMEN"TRIP P RIH f/8491'to 9920'-PW wt 160 SO wt 133 02/08/2012 FIT na perfs to 12.4 pm-Drilled shoe track+new hole to 13,040'-FIT to 12.4 ppq-Drilled 6 1/8"hole _f/13,040'to 13,544' 00:00 01:45 1.75 9,920 12,856 PROD1 CEMEN"TRIP P RIH with 6 1/8"Rotary Steerable assembly from 9,920'to 12,856', tagged cement-PUW 215K SOW 150K 01:45 03:30 1.75 12,856 12,856 PROD1 CEMEN"CIRC P Establish circulation-Pumped 35 bbls of high vis spacer and displace well to 9.6 ppgFlo-Thru mud @ 210 gpm ICP-1970 psi FCP-2090 psi 03:30 04:00 0.50 12,856 12,844 PROD1 CEMEN"OWFF P Laid down 1 single-blow down top drive-monitor well for 30 minutes- static 04:00 04:45 0.75 12,844 12,844 PROD1 CEMEN"FIT P PJSM-Pump 35 bbls of high vis mud with 30 ppb LCM-(10 ppb Dyna rPrl fine 10 oob Dvnared med., 10 ppb Nutplug fine)and displace into annulus across and above Kuparuk C perforations to prepare for FIT of Perfs. 04:45 06:00 1.25 12,844 12,844 PROD1 CEMEN'FIT P Blow down top drive-RU and Perform FIT to 12.4 ppg EMW-blow down lines-RD hose and valves. Page 11 of 25 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:00 09:00 3.00 12,844 13,010 PROD1 CEMEN"DRLG P Drill out cement, baffle collar,FC, FS.and clean out rathole to 13010' Drill pipe measurements Drill pipe measurements Baffle @ 12,861', FC @ 12,903'and FS @ 12,990' 200 gpm/2170 psi/80 rpm @ 14K torque PUW 215K SOW 150K Rt.Wt. 172K 09:00 09:30 0.50 13,010 13,040 PROD1 CEMEN"DDRL P Drill 30'of new hole from 13,010'to 13,040'MD 6984'TVD -200 gpm/ 2180 psi/80 rpm @ 13.5 K torque- ADT=.5 hrs 09:30 11:00 1.50 13,040 12,970 PROD1 CEMEN"CIRC P CBU-200 gpm/2160 psi/80 rpm @ 13K toque-mud wt.in&out 9.6 ppg-Pull bit to 12,970'-Flow check well-slight flow from annulus-blow down top drive-slight flow continued from annulus-drill pipe full-Mu TIW valve and top drive-circulate additional 150 bbls-Mud wt. in& out at 9.6 ppg 11:00 12:15 1.25 12,970 12,970 PROD1 CEMEN"SIPB T Shut down pumps-bleed off standpipe-close TIW valve-monitor well for 10 minutes slight flow throughout no visual reduction in rate -shut in well with top pipe rams @ 11:10 hrs-blow down top drive-rig up to monitor pressures-pump across well with kill line to fill choke manifold and gas buster-monitor gauges for pressure for 20 minutes drill pipe and casing @ zero psi- opened bleeder on choke manifold and drill pipe and visually confirmed no flow for 10 minutes-open pipe rams 12:15 13:00 0.75 12,970 12,970 PROD1 CEMEN"FIT P Blow down choke line-RU and perform FIT to 12.4 ppg EMW- Bleed off-blow down and rig down valves and lines. 13:00 13:15 0.25 12,970 13,040 PROD1 DRILL WASH P Washed down f/12,970'to 13040'@ 210 gpm @ 2040 psi w/80 rpm's @ 13 k torque Page 12 of 25 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 00:00 10.75 13,040 13,544 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/Geo-Pilot f/ 13,040'to 13,544'MD 6992'TVD ADT-6.03 hrs. ECD-11.28 ppg Footage-504' WOB 8/12 k RPM 110 GPM 210 @2140 psi String wt. PU 209 SO 150 ROT 175 Torque on/off btm.-14/12 k ft/lbs Note: @ 13,512'observed increase in flow f/20%to 25%-PU off btm- Flow ck well static-Cont.to drill remainder of kelly down to 13,544'- Circulated btms up f/13,512'- Observed no gas @ btms up 02/09/2012 Drilled 6 1/8"hole w/GP f/13,544'to 14,974' 00:00 12:00 12.00 13,544 14,250 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/13,544'to 14.250'MD 7008'ND ADT-8.39 hrs. ECD-11.27 ppg Footage-706' WOB 5/10 k RPM 110 GPM 210 @ 2390 psi String wt PU 213 SO 150 ROT 180 Torque on/off btm.-13/11.5 k ft/lbs 12:00 00:00 12.00 14,250 14,974 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/14,250'to 14,974'MD 7016'ND ADT-7.84 hrs ECD-11.34 ppg Footage-724' WOB 6/10 k RPM 110 GPM 210 @2310 psi String wt PU 212 SO 148 ROT 179 Torque on/off btm.-12.5/11.5 k ft/lbs 02/10/2012 Drilled 6 1/8"hole w/GP f/14,974'to 16,309' 00:00 12:00 12.00 14,974 15,642 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/14,974'to 15,642'MD 7024'ND ADT-8.31 hrs ECD-11.48 ppg Footage-668' WOB 8/10 k RPM 120 GPM 210 @ 2380 psi String wt PU 215 SO 145 ROT 180 Torque on/off btm.-12.5/11.0 k ft/lbs Page 13 of 25 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 15,642 16,309 PROD1 DRILL DDRL P grilled 6 1/8"hole w/GP f/15,642'to 16.309'MD 7031'ND ADT-7.86 hrs ECD-11.52 ppg Footage-667' WOB 8/12 k RPM 120 GPM 210 @ 2470 psi String wt. PU 222 SO 144 ROT 182 Torque on/off btm.-12.5/11.5 k ft/lbs 02/11/2012 Drilled 6 1/8"hole w/GP f/16,309'to 17,739' 00:00 12:00 12.00 16,309 17,072 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/16,309'to 17,072'MD 7039'ND ADT-8.4 hrs ECD-11.49 ppg Footage-763' WOB 8/12 k RPM 120 GPM 210 @ 2520 psi String wt. PU 228 SO 142 ROT 180 Torque on/off btm.-12.5/12.5 k ft/lbs 12:00 00:00 12.00 17,072 17,739 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/17,072'to 17,739'MD 7053'ND ADT-7.07 hrs. ECD-11.59 ppg Footage-667' WOB 8/13 k RPM 120 GPM 210 @2610 psi String wt. PU 225 SO 143 ROT 180 Torque on/off btm.-14.5/12.5 k ft/lbs Note-Hole has been taking small amount of seepage losses-lost total of 168 bbls over the last 3 days 02/12/2012 Drilled 6 1/8"hole f/17,739'to 19.010' 00:00 12:00 12.00 17,739 18,407 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/17,739'to 18.407'MD 7058'ND ADT-8.1 hrs. ECD-11.80 ppg Footage-668' WOB 8/12 k RPM 120 GPM 210 @ 2760 psi String wt. PU 233 SO 138 ROT 183 Torque on/off btm.-14.0/13 k ft/lbs Page 14 of 25 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 12:00 00:00 12.00 18,407 19,010 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/18,407'to 19,010'MD 7073'TVD ADT-8.08 hrs ECD-11.70 ppg Footage-603' WOB 8/14 k RPM 120 GPM 210 @ 2730 psi String wt. PU 240 SO 134 ROT 180 Torque on/off btm.- 14.5/13 k ft/lbs Lost 144 bbls to formation last 24 hrs.-total losses-312 bbls 02/13/2012 Drilled 6 1/8"hole f/19,010'to 20,378'(TD of section)Circ hole clean for trip 00:00 12:00 12.00 19,010 19,710 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/19,010'to 19,710'MD 7072'TVD ADT-8.49 hrs ECD-11.65 ppg Footage-700' WOB 8/12 k RPM 120 GPM 210 @ 2650 psi String wt. PU 245 SO 120 ROT 180 Torque on/off btm.- 15.5/14.5 k ft/lbs 12:00 23:00 11.00 19,710 20,387 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/19,710'to 20,387'MD 7082'TVD • ADT-7.91 hrs. ECD-11.67 ppg Footage-677' WOB 8/15 k RPM 120 GPM 210 @ 2680 psi String wt. PU 248 SO 115 ROT 183 Torque on/off btm.-17/15 k ft/lbs Lost xxx bbls. last 24 hrs -total losses 23:00 00:00 1.00 20,387 20,387 PROD1 CASING CIRC P Take SPR's-Obtain T&D data&@ TD survey-Begin to circ 3 X btms. up @ 210 gpm @ 2630 psi @100 rpm's 13 k torque\ Note-Lost 192 bbls last 24 hrs.- Total losses to date 504 bbls 02/14/2012 Circ 3 X btms up-POOH w/pump top 12,875'-Change well voer to 9.7 ppg brine-POOH on TT to 5822' 00:00 r 04:30 4.50 20,387 19,647 PROD1 CASING CIRC P CBU X3 at 210 gpm-2610 psi-100 rpm-13k Torque.Stand back one stand every 30 min from 20,387'to 19,647'. 04:30 15:30 11.00 19,647 12,875 PROD1 CASING TRIP P Flow check well. POH with pump at 210 gpm from 19,647'to 12,875'. 15:30 16:30 1.00 12,875 12,875 PROD1 CASING OWFF P Blow down TD-Monitor well for 30 mins.-fluid dropped 3'in annulus - PJSM on changing over to brine Page 15 of 25 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 16:30 18:45 2.25 12,875 12,875 PROD1 CASING CIRC P Displace well f/9.6 ppq Flow-Thru tq 9.7 ppg brine @ 210 gpm @ 1600 psi w/100 rpm's @ 10 k torque- pumped calc.volume+50% PU wt.200 SO wt 132 ROT wt 165 18:45 19:30 0.75 12,875 12,875 PROD1 CASING OWFF P Blow down TD-Monitor well for 30 mins.-fluid level dropped in annulus 19:30 00:00 4.50 12,875 5,822 PROD1 CASING TRIP P POOH on TT f/12,875'to 5822' 02/15/2012 POOH f/5822'to 1246'-S&C drill line-POOH to 393'-LD BHA-RU&Ran 4 1/2"liner to 10,758' 00:00 01:45 1.75 5,822 1,246 PROD1 CASING TRIP P POOH on TT f/5822'to 1246'-hole took proper fill 01:45 03:15 1.50 1,246 1,246 PROD1 CASING SLPC P Flow ck well for 10 mins-fluid level dropped 1 '-Slip&cut drill line 83'- Service rig-Set block height(lost 1 bbls during S&C ops) 03:15 03:45 0.50 1,246 393 PROD1 CASING TRIP P POOH on TT f/1246'to 393' 03:45 04:15 0.50 393 196 PROD1 CASING PULD P Flow ck(static)Std back HWDP- LD drilling bumper sub&Jars 04:15 06:15 2.00 196 0 PROD1 CASING PULD P LD NM flex DC"S-Plug into MWD &Down load data-Finish laying down MWD tools-GeoPilot&bit Hole took 60 bbls over calculated displacement on trip out f/19,647' 06:15 06:45 0.50 0 0 PROD1 CASING OTHR P Housekeeping on rig floor-clear floor of BHA components 06:45 07:00 0.25 0 0 COMPZ CASING SFTY P Held pre job meeting on rigging up to run 4 1/2"liner 07:00 08:15 1.25 0 0 COMPZ CASING RURD P RU to run 4 1/2"liner 08:15 08:30 0.25 0 0 COMPZ CASING SFTY P Held pre job safety&Ops meeting on running 4 1/2"liner Page 16 of 25 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:30 18:00 9.50 0 5,998 COMPZ CASING RUNL P Ran 4 1/2"12.6#L-80 IBT-M liner a� follows:,4 1/2"Orange peel shoe-1 jt liner-1 perf pup jt-9 jts liner-1 perf pup jt.-9 jts liner-1 perf pup-9 jts liner-1 perf pup-9 jts. liner-1 perf pup-9 jts liner-1 perf pup jt.-9 jts. liner-1 perf pup-9 jts liner-1 perf pup-9 jts. liner-1 perf pup-9 jts. liner -1 perf pup-9 jts liner-1 perf pup-9 jts liner-1 perf pup-9 jts liner-1 perf pup-9 jts liner-1 perf pup-9 jts liner-1 perf pup-7 jts liner-1 perf pup-1 jt liner-XO pup(4 1/2"IBT pin x 4 1/2"SLHT box-1 jt liner(4 1/2"12.6#L80 SLHT)-Tam Free Cap Swell packer assembly(FSC-11)w/5.875"OD cementralizer on top&btm pups-1 jt liner(4 1/2"12.6#L-80 SLHT)- TAM Free Cap Swell packer assembly(FSC-11)w/5.875"OD cementralizers on top&btm pups-8 jt. liner(4 1/2"12.6#L-80 SLHT)- Baker Sael bore Extension -Baker DG Flex Lock Liner Hanger assembly-Mix up Pal Mix&spot into liner tie back sleeve-wait for Pal mix to set up Ran 135 jts of 4 1/2"IBT-M&10 jts 4 1/2"SLHT liner-16 perf pups 18:00 18:45 0.75 5,998 5,998 COMPZ CASING RURD P RD liner running equipment-Change elevators 18:45 00:00 5.25 5,998 10,758 COMPZ CASING RUNL P RIH f/5998'to 6088'-Circ btms up @ 3 bbls/min @ 360 psi-Blow down TD-RIH to 10,758'w/4 1/2" liner on DP-fill pipe every 20 stds 02/16/2012 RIH w/4 1/2"liner f/10,758'to 12,925'-Circ DP vol.-RIH w/liner f/12,925'to 18,685'-Set liner w/shoe A 18,685'&top @ 12694.73'-Release f/liner-Circ clean 9.7 ppg brine-POOH-LD running tool-RU&Begin testingBOPE 00:00 01:30 1.50 10,758 12,952 COMPZ RPCOM RUNL P RIH f/10,758'to 12,952'w/4 1/2" liner on DP-fill pipe every 20 stds. 01:30 02:00 0.50 12,952 12,952 COMPZ RPCOM CIRC P Circulate pipe volume at 4 bpm-640 psi. Blow down top drive. Flow check well.OK. li 02:00 06:15 4.25 12,952 18,685 COMPZ RPCOM RUNL P RIH f/12,952'to 18,685'w/4 1/2" liner on DP.250k up wt-125k do wt. Calculated displacement-105.5 bbls.Actual displacement-82 bbls. 06:15 06:30 0.25 18,685 18,685 COMPZ RPCOM CIRC P Flow check well. Break circulation at 3 bpm-530 psi. Page 17 of 25 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 06:30 07:30 1.00 18,685 18,685 COMPZ RPCOM PACK P Drop ball. Pumped ball down at 3-1 bpm. Pressure DP to 2500 psi. Slack-off on liner. Liner slipped down hole with 30k wt. Reposition liner. Pressure DP to 2500 psi. Slack-off on liner with same results. Blow down top drive. 07:30 08:45 1.25 18,685 12,590 COMPZ RPCOM PACK P Reposition liner. Cycle DP pressure to 2500 psi 4 time.Stack out 55k wt on liner hanger. Pressure DP to 3500 psi to release from hanger. Pressure DP to 4190 psi to shear ball seat. LD single and stand back 1 std. 08:45 10:30 1.75 12,590 12,590 COMPZ RPCOM CIRC P Pump 36 bbls hi-vis pill followed by 610 bbls 9.7 clean brine at 8 bpm 1900 psi. 10:30 12:00 1.50 12,590 10,960 COMPZ RPCOM TRIP P Blow down TD-Flow ck-Drop 2.37" OD hollow drift-POOH on TT f/ 12,581'to 10,960'-PU wt 230 SO wt. 135 12:00 18:30 6.50 10,960 0 COMPZ RPCOM TRIP P POOH on TT f/10,960'to Liner running tool- 18:30 19:00 0.50 0 0 COMPZ RPCOM TRIP P Change elevators-LD Baker liner running tool 19:00 19:30 0.50 0 0 COMPZ RPCOM BOPE P Pull wear bushing-Set test plug 19:30 20:30 1.00 0 0 COMPZ RPCOM BOPE P RU to test BOPE-Tie into annulus to keep hole full during tsting- 20:30 00:00 3.50 0 0 COMPZ RPCOM BOPE P Test BOPE as follows:Tested annular to 250&2500 psi-Tested upper pipe rams, HRC kill valves- Choke manifold valves(1 thru 16) floor safety&dart valve,TD IBOP valves-to 250&3500 psi 02/17/2012 Finish testing BOPE-Service Auto IBOP-Atempt to retest-No good-Change out Auto IBOP-Retest (Good)-MU TCP BHA-RIH to 9331' 00:00 03:30 3.50 0 0 COMPZ RPCOM BOPE P Cont.testing BOPE-Tested Choke line HCR&manual valves-4" Demco valve on kill line, lower pipe rams to 250&3500 psi-Performed accumulator recovery test- Functioned remote panel f/boiler room-Pulled 4"test jt.-tested blind rams to 250&3500 psi-Tested annular-upper&lower pipe rams w/ 4 1/2"&3 1/2"test jts.-Tested hydralic&manual chokes-Tested gas alarms-Test witnessed by Chuck Ssheve AOGCC 03:30 03:45 0.25 0 0 COMPZ RPCOM BOPE P Blow down lines-RD testing equipment 03:45 04:15 0.50 0 0 COMPZ RPCOM BOPE P Pull test plug-Set tubing running wear bushing 04:15 06:30 2.25 0 0 COMPZ RPCOM BOPE P Service Auto IBOP-Attempt to test to 250&3500 psi-No good 06:30 10:30 4.00 0 0 COMPZ RPCOM RGRP T Remove elevators&bails-Change grab heads to 5"-Change auto IBOP Page 18 of 25 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 10:30 11:00 0.50 0 0 COMPZ RPCOM BOPE P Test Auto IBOP to 250&3500 psi- Good test 11:00 13:30 2.50 0 0 COMPZ RPCOM RGRP T Install clamps&accuator guards- Change grab heads bak to 4"-PU bails&elevators-Install bell guide 13:30 14:00 0.50 0 0 COMPZ PERF PULD P PU tools for TCP to rig floor 14:00 14:15 0.25 0 0 COMPZ PERF SFTY P Held pre-job safety meeting on making up TCP tool string 14:15 15:00 0.75 0 185 COMPZ PERF PULD P MU TCP system BHA to 185' 15:00 00:00 9.00 185 9,331 COMPZ PERF TRIP P RIH w/TCP BHA f/185 to 9331' PU wt. 183 SO wt 125 02/18/2012 RIH w/TCP system on 4"DP f/9331'to 12,576'-Locate Top of liner a 12,694'-Space out to run E line- Ran GR/CCL to correlate depth for perf guns-POOH&RD E line-Drop&pump down ball-Pressure up to fire nuns-Circ-Flow ck-POOH-LD perf guns 00:00 03:15 3.25 9,331 12,694 COMPZ PERF TRIP P RIH w/TCP BHA f/9331'to 12,964' PU wt.230k SO wt 137k. Locate into TOL at 12,964.Stacked out 10k wt to shear pins. PU 23'to next tool jt. 03:15 03:30 0.25 12,694 12,671 COMPZ PERF RURD P MU xo and TIW valve. 03:30 04:00 0.50 12,671 12,671 COMPZ PERF OWFF P Monitor well on trip tank. 04:00 05:30 1.50 12,671 12,671 COMPZ PERF RURD P PJSM. RU Halliburton wireline. 05:30 08:15 2.75 12,671 12,671 COMPZ PERF ELOG P RIH w/GR/CCL. Log from 12,550'to 12,130'to correlate depth. POH. 08:15 09:00 0.75 12,671 12,671 COMPZ PERF RURD P RD Halliburton WL. 09:00 09:30 0.50 12,671 12,496 COMPZ PERF TRIP P POH and strap 169'of DP to place perf guns on depth. 12,476'-12,496' 09:30 10:45 1.25 12,496 12,496 COMPZ PERF PERF P Drop ball. Pump ball down at 1 bpm. Swivel pkg leaking on top drive. LD 2 jts DP that were above rig floor. RU pump in sub and cement hose. 10:45 11:00 0.25 12,496 12,496 COMPZ PERF PERF P Pressure DP to 1970 psi.Guns fired: Establish circulation at 2 bpm-180 psi.Shut down.Monitor well.Slight fluid loss. 11:00 12:30 1.50 12,496 12,496 COMPZ PERF CIRC P Circ surface to surface volume @ 6 bbls/min @ 1280 psi-Spot hi vis pill -Flow ck(static)Blow down cmt line -RD circ equipment 12:30 13:15 0.75 12,496 11,999 COMPZ PERF TRIP P POOH to 11,999'on TT 13:15 14:45 1.50 11,999 11,999 COMPZ PERF SVRG P Flow ck(static)Change swivel packing-Install bell guide-Test swivel packing to 3500 psi-Blow down TD 14:45 22:30 7.75 11,999 185 COMPZ PERF TRIP P POOH f/11,999'to 185'on TT 22:30 23:30 1.00 185 0 COMPZ PERF PULD P LD perforating BHA-(XO's&guns) All shots fired-Clear rig floor of perf equipment 23:30 00:00 0.50 0 0 COMPZ RPCOM OTHR P RU to MU clean out assembly Page 19 of 25 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02/19/2012 24 hr Summary MU Clean out assembly&RIH to 12,737'w/mule shoe to btm of Seal Bore extension below liner top @ 12,694'-Circulated @ 4105'&7920'-Worked scraper thru area where packers will be set&thru the perf zone-Pumped a Hi-Vis sweep&circulated it around-POOH to 2198'on TT-Slip&Cut drill line 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR P Break out mule shoe f/perf gun run assembly-PU Baker tools for clean out run assembly to rig floor 01:00 03:30 2.50 0 298 COMPZ RPCOM PULD P Change elevators to 3 1/2"-MU clean out assembly-Mule shoe jt- shear type locator assembly- watermelon mill-2 boot baskets-7" csg scraper-2 string magnets- bumper sub-jars-6(4 3/4")drill collars-pump out sub(298.03') 03:30 06:00 2.50 298 4,105 COMPZ RPCOM TRIP P Change elevators to 4"-RIH w/CO assembly on 4"DP f/298'to 4105' 06:00 06:30 0.50 4,105 4,105 COMPZ RPCOM CIRC P Circ btms up @ 4105'@ 6 bbls/min @ 590 psi- Blow down TD- PU wt 123 SO wt 112 06:30 08:30 2.00 4,105 7,920 COMPZ RPCOM TRIP P Cont. RIH w/CO assembly f/4105' to 7920' 08:30 09:15 0.75 7,920 7,920 COMPZ RPCOM CIRC P Circ btms up @ 7920'@ 6 bbls/min @ 890 psi -Blow down TD- PU wt 165 SO wt. 123 09:15 14:00 4.75 7,920 12,684 COMPZ RPCOM TRIP P Cont. RIH w/CO assembly f/7920' to 12,737'(btm of seal bore extension below liner hanger)-Made 3 passes w/scraper f/12,228'to 12,638'covering area where pacers will be set and across perfs-Tagged liner top w/No-Go @ 12,694'/20 k- PU wt 230 SO wt 145-PU to 12,684' 14:00 15:45 1.75 12,684 12,684 COMPZ RPCOM CIRC P Pumped Hi-Vis sweep&Circ sweep around f/12,684'@ 7.5 bbls/min @ 1650 psi-Monitor well far losses- well static-Blow Down TD 15:45 23:00 7.25 12,684 2,198 COMPZ RPCOM TRIP P POOH w/CO assembly on TT f/ 12864'to 2198' 23:00 00:00 1.00 2,198 2,198 COMPZ RPCOM SLPC P Slip&Cut drill line 02/20/2012 Finish S&C drill line-Finish POOH&LD clean out assembly-RU to run 3 1/2"completion-Ran 3 1/21' , completion to 10,563'(as per completion detail) 00:00 00:15 0.25 2,198 2,198 COMPZ RPCOM SLPC P Finish slip and cut drilling line. 00:15 01:15 1.00 2,198 2,198 COMPZ RPCOM SVRG P Service top drive and drawworks. Clear rig floor. 01:15 02:15 1.00 2,198 298 COMPZ RPCOM TRIP P Un-hang blocks. POH with 4"DP to 298'. 02:15 05:00 2.75 298 0 COMPZ RPCOM PULD P Change elevators. POH and LD scraper, magnets, no-go and mule shoe jts. No excess metal recovery. 05:00 07:00 2.00 0 0 COMPZ RPCOM RURD P Clear floor of all BHA tools. RU to run 3 1/2"completion equipment. 07:00 07:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM with all personnel on running 3 1/2"completion equipment. Page 20 of 25 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 07:30 23:15 15.75 0 10,563 COMPZ RPCOM RCST P Ran 3 1/2"upper completion as follows: Baker GBH-22 production seal assembly-1 jt.3 1/2"9.3#L-80 EUE-M tbg-HES"XN"nipple w/RHC plug installed-1 jt 3 1/2"9.3#L-80 EUE-M tbg-Baker 3 1/2"x 7" Premier Packer assembly-1 jt.3 1/2"9.3#L-80 EUE-M tbg-Baker CMD Sliding sleeve w/2,812" X profile-1 jt.3 1/2"9.3#L-80 EUE-M tbg-XO pup jt. EUE p X Hydril 563 b -2 jts 3 1/2"9.3#L-80 Hydril 563 SCC tbg w/carbide blast rings installed as per program-XO pup jt. Hydril 563 p X EUE b-1 jt 3 1/2" 9.3#L-80 EUE-M tbg-Camco KBMG GLM assembly w/dummy valve-1jt.3 1/2"9.3#L-80 EUE-M tbg-HES"X"nipple-1 jt. 3 1/2" 9.3#L-80 EUE-M tbg-Baker 3 1/2" x 7"Premier Packer assembly w/20' PBR-1 jt 3 1/2"9.3#L-80 EUE-M tbg-Camco KBGM GLM assembly w/DCK2 shear valve-71jts.3 1/2" 9.3#L-80 EUE-M tbg-Camco KBMG GLM assembly w/dummy valve-155 jts.3 1/2"9.3#L-80 EUE-M tbg-Camco KBMG GLM assembly w/dummy valve-92 jts.3 1/2"9.3#L-80 EUE-M tbg 23:15 00:00 0.75 10,563 10,563 COMPZ RPCOM SSSV P PU Camco TRMAXX-5E SSSV- Clear riig floor to bring up Camco spool unit 02/21/2012 RU Camco Control line spool,connect&test to 6500 psi,con't to run compl to 12612',Continue to run to tag @ 12727',work past,slack off while pumping to 12752',press up,shut down,slack off and locate,space out,drop ball and rod, rig up, press to 2700 psi to set upper packer, pressure to 4000 psi and set lower packer,slack off to confirm packers are set. PU 23.5', lay down a joint, MU x-o,pump 25.5 bbls of inhibited brine follow w/100 bbls of uninhibited brine.Space out w/5.82'4-1/2"12.6 ppf L-80 IBT-m pup and two joints of 4-1/2"IBT-m tubing, retrieve wear bushing,MU hanger and landing joint"A",test control line to 6000 psi f/ 5 minutes, PU wt 145k, SO wt 115k. Land tubing, RILDS, RU lines to test,test IA to 1000 psi f/5 minutes-good,monitor well f/30 min-static, L/D landing joint"A",set TWC, MU Lnd jt"B",test hanger seals to 250 psi f/5 min,and 5000 psi f/10 min-good, L/D Ind jt"B",pull TWC,MU landing joint"A", RU hardline, PT lines to 4000 psi,test tubing to 4000 psi f/30 min-good,bleed down to 2000 psi,test annulus to 3500 psi f/30 min-good, bleed ann and tbg to zero. Press ann to 3200 psi to shear DCK-2 valve in lower glm. L/D landing joint"A",set TWC,test to 1000 psi f/10 min-good,monitor well f/30 min-good, N/D BOPE. 00:00 00:45 0.75 10,563 10,563 COMPZ RPCOM SSSV P PU Camco TRMAXX-5E SSSV- Clear rig floor to bring up Camco spool unit. Rig up line through sheave, install line to SSSV.Test control line to 6500 psi f/15 minutes. Check f/leaks-good. 00:45 01:15 0.50 10,563 10,563 COMPZ RPCOM SSSV P Test control line to 6500 psi f/15 minutes.Check f/leaks-good. 01:15 05:00 3.75 10,563 12,612 COMPZ RPCOM RCST P Continue running 3.5"9.3 ppf L-80 'EUE-m completion f/10563'to 12612'. PU wt 145k, SO wt 110k. Page 21 of 25 Time Logs Date From To Dur S Depth E. Depth Phase Code Subcode T Comment 05:00 07:15 2.25 12,612 12,738 COMPZ RPCOM RCST P Space out w/jts 392-395. Make up 3.5"EUE x 4"XT39 crossover,then make up the top drive.Slack off 'pumping 1 bpm w/50 psi.Stacked out w/mule shoe 17.5'in on jt#395 (TOL)(12696'DPM). Increase pump rate to 2 bpm w/140 psi,stack 15k down,then put 1 wrap in string. Worked torque down and was able to get past TOL.Make up jt#396,then pump 1 bpm w/50 psi,slack off and observe seals go in @ 12'in on jt# 396(12721.75'DPM).Shut down pumps,slack off, locate. Lay down jt #396. Remove top drive and blow li down lines. MU 10'pup. Lay down 10'pup. 07:15 07:30 0.25 12,738 12,738 COMPZ RPCOM SFTY P Pre job safety meeting. Drop ball and rod. 07:30 07:45 0.25 12,738 12,738 COMPZ RPCOM RURD P Rig up crossover, headpin, hose, valves and pressure sensor to chart test.Allow ball and rod to fall f/30 minutes 07:45 08:30 0.75 12,738 12,738 COMPZ RPCOM DHEQ P Pressure up to 2700 psi to set upper packer, hold f/15 minutes, record on chart recorder. Pressure up to 4000 psi to set lower packer, hold f/15 minutes, record on chart recorder. Bleed off pressure. Blow down and :rig down lines. 08:30 09:00 0.50 12,738 12,283 COMPZ RPCOM RCST P Slack off to confirm packers set. Pick up 23.5'. Break and lay down jt #396. 09:00 10:00 1.00 12,283 12,283 COMPZ RPCOM CIRC P Make up 3.5"EUE-m x 4"XT39 crossover. Make a top drive connection. Break circulation. Pump inhibited 9.7 ppg brine w/mud pump #2. Pumping 2 bpm w/130 psi. Pumped a total of 25.5 bbls.Shut down,then chase w/9.7 ppg uninhibited brine @ 6 bpm w/860 psi. Pumped a total of 100 bbls un-inhibited 9.7 ppg.Shut down. Break top drive and blow down same. 10:00 10:15 0.25 12,283 12,283 COMPZ RPCOM SFTY P Pre job safety meeting. 10:15 10:45 0.50 12,283 12,283 COMPZ RPCOM HOSO P Lay down jts 395, 394 and 393. PJSM.Change out elevators f/3.5" tbg to 4.5"tubing.Make up 3.5" EUE-m x 4.5"IBT-m crossover. Install a 5.820'4.5"IBT-m space out pup,follow w/(2)4-1/2"12.6 ppf L-80 IBT-m jts(37.91 &37.86'). 10:45 11:00 0.25 12,283 12,283 COMPZ RPCOM SFTY P Pre job safety meeting. 11:00 11:15 0.25 12,283 12,283 COMPZ RPCOM OTHR P Make up FMC wear ring pulling tool, slack off and retrive wear bushing. 11:15 11:30 0.25 12,283 12,283 COMPZ RPCOM SFTY P Pre job safety meeting. Page 22 of 25 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 11:30 12:00 0.50 12,283 12,283 COMPZ RPCOM RCST P Make up FMC landing joint"A", FMC hanger and control line.A total of 72 stainless steel bands were run on control line. 12:00 12:15 0.25 12,283 12,283 COMPZ RPCOM SFTY P Pre job safety meeting. 12:15 1• 3:15 1.00 12,283 12,305 COMPZ RPCOM SSSV P Test Schlumberger/Camco control line to 6000 psi f/5 minutes-good. Land tubing, run in lockdown screws. PU wt 145k, SO wt 115k. 13:15 13:30 0.25 12,305 12,305 COMPZ RPCOM SFTY P Pre job safety meeting. 13:30 15:30 2.00 12,305 12,305 COMPZ RPCOM RURD P Rig up lines to the cellar for pumping and testing. Rig up manifold on rig floor.Clear floor of unnecessary tools. 15:30 15:45 0.25 12,305 12,305 COMPZ RPCOM DHEQ P Test tbg x casing annulus to 1000 psi f/5 minutes-good.Chart test. 15:45 1• 6:15 0.50 12,305 12,305 COMPZ RPCOM OWFF P Monitor well f/30 minutes-static. 16:15 1• 6:30 0.25 12,305 12,305 COMPZ RPCOM SFTY P Pre job safety meeting. 16:30 17:00 0.50 12,305 12,305 COMPZ RPCOM DHEQ P Lay down FMC landing joint"A".Set two way check.Make up landing joint"B".Test Two way check and hanger seals to 250psi f/5 minutes and 5000 psi f/10 minutes f/top side.Chart test. Good. 17:00 17:15 0.25 12,305 12,305 COMPZ RPCOM SFTY P Pre job safety meeting. 17:15 17:30 0.25 12,305 12,305 COMPZ RPCOM RURD P Rig down testing equipment. Lay down landing joint"B". Pull two way check. Pick up landing joint"A". Rig up hardlines. 17:30 17:45 0.25 12,305 12,305 COMPZ RPCOM SFTY P Pre job safety meeting. 17:45 18:15 0.50 12,305 12,305 COMPZ RPCOM PRTS P Pressure test lines to 4000 psi- good. 18:15 18:30 0.25 12,305 12,305 COMPZ RPCOM SFTY P Pre job safety meeting. 18:30 19:00 0.50 12,305 12,305 COMPZ RPCOM DHEQ P Test tubing to 4000 psi f/30 minutes. Chart test.Good test. 19:00 20:00 1.00 12,305 12,305 COMPZ RPCOM DHEQ P Bleed tubing to 2000 psi.Then test annulus to 3500 psi f/30 minutes. Chart test. Good test. 20:00 20:30 0.50 12,305 12,305 COMPZ RPCOM DHEQ P Bleed annulus to zero,bleed tubing to zero.Then pressure up annulus to shear DCK-2 shear valve in GLM. Sheared at 3200 psi w/700 psi on the tubing. Bleed off pressure. 20:30 20:45 0.25 12,305 12,305 COMPZ RPCOM SFTY P Pre job safety meeting. 20:45 21:00 0.25 0 COMPZ RPCOM DHEQ P Lay down FMC landing joint"A".Set Two way check.Test by pumping into the IA.Test to 1000 psi f/10 minutes.Chart test.Good. Blow down lines. 21:00 21:30 0.50 0 0 COMPZ RPCOM OWFF P Monitor well for 30 minutes-static. 21:30 21:45 0.25 0 0 COMPZ RPCOM SFTY P Pre job safety meeting. Page 23 of 25 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 21:45 00:00 2.25 0 0 COMPZ RPCOM NUND P Blow down lines. Nipple down 13-5/8"BOPE. 02/22/2012 N/D BOPE, NU FMC tree,test void to 5000,test tree to 5000-charted,pull TWC, RU to freeze protect, PJSM, attempt to circ down tbg-no go-1000 psi,check surface equipment-ok,circ down annulus-ok-1 bpm w/520 psi, pressure up to 1500 psi while pumping down tubing,pump down annulus-ok-2 bpm w/1050 psi, PJSM, R/D lines,secure well, PJSM, L/D 4"dp from derrick. Note:Will freeze protect w/50 bbls of diesel down annulus after laying down 4"dp f/derrick. 00:00 02:00 2.00 COMPZ WHDBO NUND P Change grabs on top drive.Change saver sub to 4-1/2"IF.Nippling down BOPE. Nipple up FMC tree. 02:00 02:15 0.25 COMPZ WHDBO DHEQ P Test FMC hanger void to 5000 psi f/ 10 minutes-good. 02:15 03:45 1.50 COMPZ WHDBO RURD P Rig up to test tree w/rig test pump. Pressure was bleeding off chart recorder,change pressure sensor. 03:45 04:00 0.25 COMPZ WHDBO DHEQ P Test tree to 5000 psi f/10 minutes. 04:00 04:30 0.50 COMPZ WHDBO OTHR P Rig down testing equipment.Suck out diesel f/tree. Pull FMC two way check. 04:30 04:45 0.25 COMPZ RPCOM SFTY P Pre job safety meeting on rigging up to freeze protect. 04:45 05:45 1.00 COMPZ RPCOM RURD P Rig up to pump freeze diesel. Use squeeze manifold,hoses and hardlines. 05:45 06:00 0.25 COMPZ RPCOM SFTY P Pre job safety meeting on testing lines,then pumping 164 bbls of diesel down the tubing. 06:00 07:00 1.00 COMPZ RPCOM FRZP T Dowell attempt to establish circulation,pumping down the tubing. Pressured up to 1000 psi w/no returns.Shut down, bleed off, investigate surface equipment-OK. Line up to circulate down the 7"x 3-1/2"annulus,establish circulation w/1 bpm w/520 psi.Shut down. Line up to circ down tbg,pressured up to 1500 psi w/no returns.Shut down and bleed off pressure. Line up, then circ down annulus, pumping 2 bpm w/1050 psi.Shut down. 07:00 07:15 0.25 COMPZ RPCOM FRZP T Pre job safety meeting on rigging down lines. 07:15 08:00 0.75 COMPZ RPCOM FRZP T Blow down, rig down hard lines, hoses and hardline to squeeze manifold.Shut master and swab valves on tree.Close annulus valves, install tree cap. 08:00 08:15 0.25 COMPZ RPCOM SFTY P Pre job safety meeting on laying down 4"dp f/derrick. 08:15 00:00 15.75 COMPZ RPCOM PULD P Lay down 4"drill pipe from derrick via mouse hole.Total of 140 stands layed down,75 stands left in derrick to lay down. Page 24 of 25 Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 02/23/2012 24 hr Summary Finish L/D 4"dp from derrick. Rig up,then Dowell pump 50 bbls diesel down 7"x 3-1/2"annulus. Blow down lines. rio down.Suck fluid to below tubing hanger, install BPV,fill tree w/diesel.Clear floor,secure well. Pick _.up cellar Disconnect service lines. oreoaare to move riq f/CD3-128 to CD3-119(180'move hole to hole). Rig released f/CD 3-128 @ 1600 hrs 2-23-2012. 00:00 04:30 4.50 COMPZ RPCOM PULD P Lay down 4"drill pipe f/derrick using mouse hole. 30 stands left to lay down. 04:30 05:00 0.50 COMPZ RIGMN1 SVRG P Service rig 05:00 08:15 3.25 COMPZ RPCOM PULD P Lay down 4"drill pipe f/derrick using mouse hole. 08:15 08:30 0.25 COMPZ RPCOM SFTY P Pre job safety meeting on rigging up to freeze protect. 08:30 09:00 0.50 COMPZ RPCOM RURD P Lay down mouse hole. Rig up 2" hardlines,squeeze manifold,valves, Tee's and hoses. 09:00 09:15 0.25 COMPZ RPCOM SFTY P Pre job safety meeting on pumping freeze protect diesel. 09:15 10:30 1.25 COMPZ RPCOM FRZP P Dowell pressure test lines to 2000 psi-ok. Pump diesel down 7"x 3-1/2" annulus,pumping 2 bpm w/2100 psi. Exceeded pressure test presure. Shut down.Test to 3350 psi-ok. Dowell continue pumping 1 bpm w/ 720 psi,increased rate to 1.5 bpm w/ initial circ pressure of 1180 psi,final circ pressure of 1980 psi. Pumped a total of 50 bbls into annulus. 10:30 10:45 0.25 COMPZ RPCOM SFTY P Pre job safety meeting on rigging down freeze protect lines. 10:45 11:15 0.50 COMPZ RPCOM RURD P Blow down lines. Rig down 2" hardlines,squeeze manifold,valves, Tee's and hoses. Suck fluid out of tubing to below tubing hanger. 11:15 12:00 0.75 COMPZ WHDBO SEQP P FMC set BPV. Fill tree w/diesel to freeze protect. Page 25 of 25 WELL LOG TRANSMITTAL 2`- 037 To: Alaska Oil and Gas Conservation Comm. January 3, 2013 Attn.: Makana Bender gyp) 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: CD3-128 Run Date: 12/17/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-128 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20638-00 Production Profile t Color Log 50-103-20638-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: Signed: RE-COVED Halliburton JAN 1 6 2013 Sperry Drilling 69AnOchArctic Blvd orage, AK 99518 AC Jan. 10, 2013 AOGCC Makana Bender ©�J 333 W. 7th Ave., Suite 1011 � Anchorage, AK 99501 0► ` V Dear Sir or Madam:(/.. Subject: CD3-119/CD3-128/CD1-48A/CD4-03 Definitive Survey Reports Enclosed are one hard copy(NAD83 and NAD27) of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Avinash.Ramjit@Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling ATTN: Avinash Ramjit 6900 Arctic Blvd Anchorage, AK •e•18 Received by:gal 1' I 1 9 4t1.Date: Please contact me at 907.263.465 ith questions or concerns. Regards, Avinash Ramjit DA/ .,1 ) a 007 r d • 0 3 7 ;,,,, . , . 3 - . -, V 3 1 lit ConocoPhillips(Alaska) Inc. -WNS Western North Slope 0 CD3 Fiord Pad 3 4 CD3-128 501032063800 -, A' 4 N vi l SperryDrilling V Definitive Survey Report ` 23 March, 2012 1 I - ,ti uv,LLV i , / i ' /it--- 4.,)TN i 2-Th ' 3 o 7 , . , I i ! vi:: f .0141 I e HALLIEURTDN Sperry Drilling 1 4 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope ND Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12,6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well CD3-128 Well Position +N/-S 0.00 ft Northing: 6,003,500.08 ft Latitude: 70°25'7.902 N' +E/-W 0.00 ft Easting: 1,527,870.01 ft Longitude: 150°55'0.769 WI Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60ft Wellbore CD3-128 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 2/1/2012 20.21 80.87 57,613 Design CD3-128 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,975.44 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 35.80 0.00 0.00 155.00 Survey Program Date 3/23/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 79.00 1,100.00 CD3-128 Gyro(R100)(CD3-128(IntermE CB-GYRO-SS Camera based gyro single shot 4/12/2011 12:C 1,148.28 2,946.82 CD3-128 MWD(R300)(CD3-128(Interm MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/12/2011 12:C 3,045.13 12,975.44 CD3-128 MWD(R400)(CD3-128(Interm MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/16/2011 12:C 13,029.53 20,353.07 CD3-128 MWD(R700)(CD3-128) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/14/2012 12:C Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 35.80 0,00 0.00 35.80 -12.60 0.00 0.00 6,003,500.08 1,527,870.01 0.00 0.00 UNDEFINED 79.00 0.05 284.95 79.00 30.60 0.00 -0.02 6,003,500.09 1,527,869.99 0.12 -0.01 CB-GYRO-SS(1) 170.00 0.37 6.10 170.00 121.60 0.31 -0.03 6,003,500.39 1,527,869.99 0.40 -0.29 CB-GYRO-SS(1) 263.00 0.45 8.32 263.00 214.60 0.97 0.06 6,003,501.05 1,527,870.08 0.09 -0.85 CB-GYRO-SS(1) 291.00 0.44 358.14 291.00 242.60 1.18 0.07 6,003,501.26 1,527,870.10 0.28 -1.04 CB-GYRO-SS(1) 321.00 0.52 5.76 321.00 272.60 1.43 0.08 6,003,501.51 1,527,870.11 0.34 -1.27 CB-GYRO-SS(1) 351.00 0.57 357.16 350.99 302.59 1.72 0.09 6,003,501.80 1,527,870.12 0.32 -1.52 CB-GYRO-SS(1) 355.00 0.72 12.68 354.99 306.59 1.76 0.09 6,003,501.84 1,527,870.13 5.72 -1.56 CB-GYRO-SS(1) 381.00 0.67 4.70 380.99 332.59 2.07 0.14 6,003,502.15 1,527,870.18 0.42 -1.82 CB-GYRO-SS(1) 411.00 0.73 346.99 410,99 362.59 2,43 0.11 6,003,502.51 1,527,870.16 0.75 -2.16 CB-GYRO-SS(1) 441.00 0.95 336.11 440.99 392.59 2.85 -0.03 6,003,502.93 1,527,870.02 0.90 -2.59 CB-GYRO-SS(1) 3/23/2012 9:40:02AM Page 2 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD' TVDSS +N/-S +El-W Northing Easting` DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/1001 (ft) Survey Tool Name 448.00 1.19 338.52 447.98 399.58 2.97 -0.08 6,003,503.05 1,527,869.97 3.49 -2.73 CB-GYRO-SS(1) 471.00 1.46 322.24 470.98 422.58 3.42 -0.35 6,003,503.51 1,527,869.71 2.00 -3.25 CB-GYRO-SS(1) 479.00 1.55 323.18 478.98 430.58 3.59 -0.48 6,003,503.68 1,527,869.59 1.17 -3.45 CB-GYRO-SS(1) 486.00 1.80 316.66 485.97 437.57 3.75 -0.61 6,003,503.83 1,527,869.46 4.49 -3.65 CB-GYRO-SS(1) 501.00 1.83 314.59 500.97 452.57 4.09 -0.94 6,003,504.18 1,527,869.13 0.48 -4.10 CB-GYRO-SS(1) 1 516.00 1.98 313.17 515.96 467.56 4.43 -1.30 6,003,504.53 1,527,868,78 1.05 -4.57 CB-GYRO-SS(1) 531.00 2.24 309.79 530.95 482.55 4.80 -1.71 6,003,504.90 1,527,868.37 1.92 -5.07 CB-GYRO-SS(1) 540.00 2.71 308.40 539.94 491.54 5.04 -2.02 6,003,505.15 1,527,868.07 5.26 -5.42 CB-GYRO-SS(1) 546.00 2.45 308.72 545.93 497.53 5.21 -2.23 6,003,505.32 1,527,867.86 4.34 -5.66 CB-GYRO-SS(1) 561.00 2.60 311.20 560.92 512.52 5.63 -2.73 6,003,505.75 1,527,867.36 1.24 -6.26 CB-GYRO-SS(1) 633.00 4.82 294.43 632.76 584.36 7.96 -6.72 6,003,508.14 1,527,863.41 3.40 -10.05 CB-GYRO-SS(1) 724.00 5.67 284.50 723.38 674.98 10.67 -14.55 6,003,510.96 1,527,855.62 1.36 -15.82 CB-GYRO-SS(1) 815.00 6.27 282.47 813.89 765.49 12.87 -23.75 6,003,513.30 1,527,846.45 0.70 -21.70 CB-GYRO-SS(1) 909.00 8.07 284.86 907.15 858.75 15.67 -35.14 6,003,516.27 1,527,835.11 1.94 -29.05 CB-GYRO-SS(1) 1,004.00 11.26 289.11 1,000.79 952.39 20.41 -50.36 6,003,521.25 1,527,819.97 3.44 -39.78 CB-GYRO-SS(1) 1,100.00 11.43 287.01 1,094.92 1,046.52 26.27 -68.31 6,003,527.37 1,527,802.11 0.47 -52.67 CB-GYRO-SS(1) 1,148.28 12.53 285.03 1,142.15 1,093.75 29.02 -77.94 6,003,530.27 1,527,792.52 2.43 -59.24 MWD+IFR-AK-CAZ-SC(2) 1,245.64 14.20 278.60 1,236.87 1,188.47 33.55 -99.95 6,003,535.13 1,527,770.58 2.29 -72.65 MWD+IFR-AK-CAZ-SC(2) 1,339.98 18.95 274.82 1,327.27 1,278.87 36.57 -126.67 6,003,538.55 1,527,743.91 5.16 -86.68 MWD+IFR-AK-CAZ-SC(2) 1,434.36 22.98 272.49 1,415.38 1,366.98 38.66 -160.36 6,003,541.15 1,527,710.26 4.36 -102.81 MWD+IFR-AK-CAZ-SC(2) 1,528,94 26.95 267.63 1,501.12 1,452.72 38.57 -200.24 6,003,541.66 1,527,670.39 4.72 -119.59 MWD+IFR-AK-CAZ-SC(2) 1,623.32 30.89 266.80 1,583.71 1,535.31 36.33 -245.82 6,003,540.11 1,527,624.79 4.20 -136.82 MWD+IFR-AK-CAZ-SC(2) 1,717.75 34.05 264.21 1,663.37 1,614.97 32.31 -296.34 6,003,536.85 1,527,574.22 3.66 -154.52 MWD+IFR-AK-CAZ-SC(2) 1,810.86 37.07 263.42 1,739.11 1,690.71 26.47 -350.16 6,003,531.82 1,527,520.32 3.28 -171.97 MWD+IFR-AK-CAZ-SC(2) 1,907.24 38.24 261.27 1,815.42 1,767.02 18.61 -408.51 6,003,524.84 1,527,461.86 1.82 -189.51 MWD+IFR-AK-CAZ-SC(2) 2,001.83 41.08 258.23 1,888.24 1,839.84 7.82 -467.88 6,003,514.96 1,527,402.34 3.64 -204,83 MWD+IFR-AK-CAZ-SC(2) 2,096.83 45.21 257.78 1,957.54 1,909.14 -5.68 -531.42 6,003,502.41 1,527,338.62 4.36 -219.43 MWD+IFR-AK-CAZ-SC(2) 2,191.22 48.45 258.55 2,022.11 1,973.71 -19.79 -598.79 6,003,489.32 1,527,271.05 3.48 -235.12 MWD+IFR-AK-CAZ-SC(2) 2,285.65 51.30 259.96 2,082.96 2,034.56 -33.23 -669.72 6,003,476.95 1,527,199.93 3.23 -252.92 MWD+IFR-AK-CAZ-SC(2) 2,380.02 53.97 262.48 2,140.23 2,091.83 -44.65 -743.83 6,003,466.66 1,527,125.66 3.54 -273.89 MWD+1FR-AK-CAZ-SC(2) 2,474.81 56.88 262.15 2,194.02 2,145.62 -55.09 -821.17 6,003,457.38 1,527,048.17 3.08 -297.11 MWD+IFR-AK-CAZ-SC(2) 2,566.43 58.46 262.76 2,243.01 2,194.61 -65.25 -897.91 6,003,448.38 1,526,971.29 1.81 -320.34 MWD+IFR-AK-CAZ-SC(2) 2,663.51 58.56 260.62 2,293.73 2,245.33 -77.21 -979.82 6,003,437.65 1,526,889.22 1.88 -344.11 MWD+IFR-AK-CAZ-SC(2) 2,757.77 59.89 259.61 2,341.96 2,293.56 -91.12 -1,059.60 6,003,424.95 1,526,809.25 1.68 -365.22 MWD+IFR-AK-CAZ-SC(2) 2,852.26 61.24 259.06 2,388.39 2,339.99 -106.35 -1,140.47 6,003,410.94 1,526,728.17 1.52 -385.59 MWD+IFR-AK-CAZ-SC(2) 2,946.82 63.44 258.90 2,432.29 2,383.89 -122.36 -1,222.67 6,003,396.18 1,526,645.74 2.33 -405.83 MWD+IFR-AK-CAZ-SC(2) 3,045.13 63.69 259.67 2,476.05 2,427.65 -138.73 -1,309.17 6,003,381.12 1,526,559.01 0.75 -427.55 MWD+IFR-AK-CAZ-SC(3) 3,136.78 63.00 258.90 2,517.17 2,468.77 -153.95 -1,389.65 6,003,367.11 1,526,478.32 1.06 -447.76 MWD+IFR-AK-CAZ-SC(3) 3,232.89 62.27 258.45 2,561.35 2,512.95 -170.72 -1,473.34 6,003,351.61 1,526,394.39 0.87 -467.94 MWD+IFR-AK-CAZ-SC(3) 3,325.63 62.10 258.77 2,604.62 2,556.22 -186.91 -1,553.75 6,003,336.63 1,526,313.75 0.36 -487.24 MWD+IFR-AK-CAZ-SC(3) 3/23/2012 9:40:02AM Page 3 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc,-WNS Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design:; CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (%100') (ft) Survey Tool Name 3,418.05 64.04 259.61 2,646.48 2,598.08 -202.36 -1,634.68 6,003,322.40 1,526,232.60 2.25 -507.44 MWD+IFR-AK-CAZ-SC(3) 3,512.48 64.26 258.77 2,687.65 2,639.25 -218.30 -1,718.15 6,003,307.73 1,526,148.91 0.83 -528.27 MWD+IFR-AK-CAZ-SC(3) 3,606.46 64.25 259.59 2,728.47 2,680.07 -234.19 -1,801.30 6,003,293.09 1,526,065.54 0.79 -549.01 MWD+IFR-AK-CAZ-SC(3) 3,700.00 64.40 260.06 2,769.00 2,720.60 -249.08 -1,884.28 6,003,279.45 1,525,982.35 0.48 -570.58 MWD+IFR-AK-CAZ-SC(3) 3,792.75 63.78 260.01 2,809.53 2,761.13 -263.52 -1,966.44 6,003,266.26 1,525,899.99 0.67 -592.22 MWD+IFR-AK-CAZ-SC(3) 3,887.38 63.28 260.87 2,851.71 2,803.31 -277.59 -2,049.98 6,003,253.45 1,525,816.26 0.97 -614.77 MWD+IFR-AK-CAZ-SC(3) I 3,980.21 63.00 260.05 2,893.65 2,845.25 -291.32 -2,131.64 6,003,240.96 1,525,734.40 0.84 -636.85 MWD+IFR-AK-CAZ-SC(3) 4,069.84 62.65 259.39 2,934.59 2,886.19 -305.54 -2,210.10 6,003,227.92 1,525,655.74 0.76 -657.11 MWD+IFR-AK-CAZ-SC(3) 4,163.00 62.79 259.84 2,977.28 2,928.88 -320.47 -2,291.54 6,003,214.22 1,525,574.09 0,45 -678.00 MWD+IFR-AK-CAZ-SC(3) 4,257.78 63.06 260.90 3,020.43 2,972.03 -334.59 -2,374.74 6,003,201.36 1,525,490.70 1.04 -700.37 MWD+IFR-AK-CAZ-SC(3) 4,350.75 63.36 261.44 3,062.33 3,013.93 -347.32 -2,456.75 6,003,189.86 1,525,408.51 0.61 -723.49 MWD+IFR-AK-CAZ-SC(3) 4,444.73 63.27 261.17 3,104.53 3,056.13 -360.02 -2,539.76 6,003,178.42 1,525,325.33 0.27 -747.06 MWD+IFR-AK-CAZ-SC(3) 4,535.89 63.08 260.76 3,145.67 3,097.27 -372.79 -2,620.10 6,003,166.86 1,525,244.82 0.45 -769.44 MWD+IFR-AK-CAZ-SC(3) 4,627.50 62.67 260.71 3,187.44 3,139.04 -385.92 -2,700.57 6,003,154.95 1,525,164.16 0.45 -791.55 MWD+IFR-AK-CAZ-SC(3) 4,723.24 62.34 260.76 3,231.64 3,183.24 -399.59 -2,784.39 6,003,142.54 1,525,080.16 0.35 -814.58 MWD+IFR-AK-CAZ-SC(3) 4,816.62 62.66 260.99 3,274.76 3,226.36 -412.73 -2,866.17 6,003,130.64 1,524,998.19 0.41 -837.23 MWD+IFR-AK-CAZ-SC(3) 4,911.41 63.14 261.36 3,317.94 3,269.54 -425.67 -2,949.55 6,003,118.96 1,524,914.63 0.61 -860.74 MWD+IFR-AK-CAZ-SC(3) 5,005.65 63.42 260.99 3,360.31 3,311.91 -438.59 -3,032.73 6,003,107.30 1,524,831.27 0.46 -884.19 MWD+IFR-AK-CAZ-SC(3) 5,100.37 63.68 260.59 3,402.50 3,354.10 -452.16 -3,116.44 6,003,094.99 1,524,747.37 0.47 -907.27 MWD+IFR-AK-CAZ-SC(3) 5,193.53 63.48 260.13 3,443.95 3,395.55 -466.13 -3,198.69 6,003,082.26 1,524,664.93 0.49 -929.37 MWD+IFR-AK-CAZ-SC(3) 5,288.20 63.56 259.69 3,486.17 3,437.77 -480.98 -3,282.12 6,003,068.68 1,524,581.29 0.42 -951.17 MWD+IFR-AK-CAZ-SC(3) 5,382.42 64.24 260.39 3,527.62 3,479.22 -495.61 -3,365.46 6,003,055.30 1,524,497.75 0.98 -973.13 MWD+IFR-AK-CAZ-SC(3) 5,477.93 63.84 259.83 3,569.43 3,521.03 -510.36 -3,450.05 6,003,041.83 1,524,412.95 0.67 -995.51 MWD+IFR-AK-CAZ-SC(3) 5,572.24 63.41 258.99 3,611.32 3,562.92 -525.89 -3,533.10 6,003,027.56 1,524,329.68 0.92 -1,016.54 MWD+IFR-AK-CAZ-SC(3) 5,666.13 64.10 258.68 3,652.84 3,604.44 -542.19 -3,615.72 6,003,012.50 1,524,246.84 0.79 -1,036.68 MWD+IFR-AK-CAZ-SC(3) 5,761.79 63.90 258.40 3,694.78 3,646.38 -559.28 -3,699.99 6,002,996.70 1,524,162.33 0.34 -1,056.81 MWD+IFR-AK-CAZ-SC(3) 5,855.82 63.90 259.58 3,736.15 3,687.75 -575.40 -3,782.87 6,002,981.82 1,524,079.22 1.13 -1,077.22 MWD+IFR-AK-CAZ-SC(3) 5,950.97 63.56 258.51 3,778.26 3,729.86 -591.61 -3,866.64 6,002,966.88 1,523,995.22 1.07 -1,097.93 MWD+IFR-AK-CAZ-SC(3) 6,045.23 63.77 259.92 3,820.08 3,771.68 -607.42 -3,949.62 6,002,952.32 1,523,912.02 1.36 -1,118.67 MWD+IFR-AK-CAZ-SC(3) 6,140.84 63.43 259.12 3,862.59 3,814.19 -623.00 -4,033.83 6,002,938.02 1,523,827.59 0.83 -1,140.14 MWD+IFR-AK-CAZ-SC(3) I 6,234.47 63.00 259.74 3,904.78 3,856.38 -638.33 -4,115.99 6,002,923.93 1,523,745.21 0.75 -1,160.97 MWD+IFR-AK-CAZ-SC(3) 6,329.26 62.94 259.96 3,947.86 3,899.46 -653.21 -4,199.11 6,002,910.30 1,523,661.89 0.22 -1,182.61 MWD+IFR-AK-CAZ-SC(3) 6,423.76 62.72 261.12 3,991.01 3,942.61 -667.03 -4,282.04 6,002,897.74 1,523,578.77 1.12 -1,205.13 MWD+IFR-AK-CAZ-SC(3) 6,517.93 62.89 261,19 4,034.05 3,985.65 -679.91 -4,364.80 6,002,886.11 1,523,495.83 0.19 -1,228.44 MWD+IFR-AK-CAZ-SC(3) 6,612.56 63.01 261.46 4,077.09 4,028.69 -692.62 -4,448.11 6,002,874.66 1,523,412.34 0.28 -1,252.13 MWD+IFR-AK-CAZ-SC(3) 6,707.21 62.79 260.82 4,120.20 4,071.80 -705.60 -4,531.37 6,002,862.94 1,523,328.91 0.65 -1,275.55 MWD+IFR-AK-CAZ-SC(3) 6,801.45 61.89 259.80 4,163.95 4,115.55 -719.64 -4,613.64 6,002,850.13 1,523,246.44 1.35 -1,297.59 MWD+IFR-AK-CAZ-SC(3) 6,895.58 62.05 260.17 4,208.19 4,159.79 -734.09 -4,695.47 6,002,836.92 1,523,164.41 0.39 -1,319.08 MWD+IFR-AK-CAZ-SC(3) 6,988,94 62.59 260.25 4,251.56 4,203.16 -748,15 -4,776.94 6,002,824.10 1,523,082.75 0.58 -1,340.77 MWD+IFR-AK-CAZ-SC(3) 7,084.18 63.61 259.77 4,294,65 4,246.25 -762.88 -4,860.58 6,002,810.62 1,522,998.90 1.16 -1,362.76 MWD+IFR-AK-CAZ-SC(3) 3/23/2012 9:40:02AM Page 4 COMPASS 2003.16 Build 69 • • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°11o0') (ft) Survey Tool Name 7,179.67 63.64 260.45 4,337.07 4,288.67 -777.58 -4,944.86 6,002,797.20 1,522,914.41 0.64 -1,385.06 MWD+IFR-AK-CAZ-SC(3) 7,274.24 63.49 260.67 4,379.17 4,330.77 -791.47 -5,028.39 6,002,784.58 1,522,830.69 0.26 -1,407.78 MWD+IFR-AK-CAZ-SC(3) 7,368.35 63.01 259.06 4,421.53 4,373.13 -806.25 -5,111.12 6,002,771.04 1,522,747.76 1.61 -1,429.34 MWD+IFR-AK-CAZ-SC(3) 7,461.58 63.22 259.77 4,463.69 4,415.29 -821.53 -5,192.86 6,002,757.00 1,522,665.80 0.72 -1,450.04 MWD+IFR-AK-CAZ-SC(3) 7,556.95 63.35 260.16 4,506.56 4,458.16 -836.37 -5,276.74 6,002,743.43 1,522,581.71 0.39 -1,472.04 MWD+IFR-AK-CAZ-SC(3) 7,652.07 63.48 259.92 4,549.13 4,500.73 -851.08 -5,360.52 6,002,729.98 1,522,497.72 0.26 -1,494.11 MWD+IFR-AK-CAZ-SC(3) 7,745.94 63.43 260.28 4,591.08 4,542.68 -865.52 -5,443.25 6,002,716.79 1,522,414.80 0.35 -1,515.99 MWD+IFR-AK-CAZ-SC(3) 7,840.37 63.41 260.04 4,633.33 4,584.93 -879.95 -5,526.45 6,002,703.62 1,522,331.39 0.23 -1,538.07 MWD+IFR-AK-CAZ-SC(3) 7,934.48 63.47 259.88 4,675.41 4,627.01 -894.63 -5,609.34 6,002,690.19 1,522,248.30 0.16 -1,559.80 MWD+IFR-AK-CAZ-SC(3) 8,029.88 63.62 260.39 4,717.91 4,669.51 -909.26 -5,693.49 6,002,676.83 1,522,163.95 0.50 -1,582.10 MWD+IFR-AK-CAZ-SC(3) 8,125.01 63.49 260.46 4,760.28 4,711.88 -923.43 -5,777.48 6,002,663.93 1,522,079.76 0.15 -1,604.76 MWD+IFR-AK-CAZ-SC(3) 8,219.94 62.87 259.03 4,803.11 4,754.71 -938.51 -5,860.84 6,002,650.11 1,521,996.19 1.49 -1,626.32 MWD+IFR-AK-CAZ-SC(3) 8,313.67 63.36 259.64 4,845.50 4,797.10 -953.98 -5,943.00 6,002,635.89 1,521,913.82 0,78 -1,647.02 MWD+IFR-AK-CAZ-SC(3) 8,409.14 63.15 259.69 4,888.46 4,840.06 -969.27 -6,026.87 6,002,621.86 1,521,829.73 0.22 -1,668.60 MWD+IFR-AK-CAZ-SC(3) 8,501.33 62.93 259.59 4,930.26 4,881.86 -984.05 -6,107.70 6,002,608.30 1,521,748.69 0.26 -1,689.37 MWD+IFR-AK-CAZ-SC(3) 8,597.83 62.93 259.51 4,974.17 4,925.77 -999.64 -6,192.20 6,002,593.99 1,521,663.97 0.07 -1,710.96 MWD+IFR-AK-CAZ-SC(3) 8,691.83 63.15 259.84 5,016.79 4,968.39 -1,014.65 -6,274.63 6,002,580.22 1,521,581.33 0.39 -1,732.19 MWD+IFR-AK-CAZ-SC(3) 8,786.72 63.28 259.72 5,059.55 5,011.15 -1,029.68 -6,358.00 6,002,566.45 1,521,497.76 0.18 -1,753.80 MWD+IFR-AK-CAZ-SC(3) 8,881.13 63.91 260.25 5,101.54 5,053.14 -1,044.39 -6,441.27 6,002,553.01 1,521,414.28 0.84 -1,775.66 MWD+IFR-AK-CAZ-SC(3) 8,974.95 64.25 261.13 5,142.55 5,094.15 -1,058.04 -6,524.54 6,002,540.62 1,521,330.82 0.92 -1,798.48 MWD+IFR-AK-CAZ-SC(3) 9,070.43 63.97 261.68 5,184.24 5,135.84 -1,070.87 -6,609.47 6,002,529.06 1,521,245.71 0.60 -1,822.74 MWD+IFR-AK-CAZ-SC(3) 9,163.46 63.76 261.78 5,225.22 5,176.82 -1,082.89 -6,692.12 6,002,518.30 1,521,162.90 0.25 -1,846.78 MWD+IFR-AK-CAZ-SC(3) 9,257.30 63.28 261.47 5,267.06 5,218.66 -1,095.12 -6,775.22 6,002,507.32 1,521,079.63 0.59 -1,870.81 MWD+IFR-AK-CAZ-SC(3) 9,353.92 63.36 260.58 5,310.44 5,262.04 -1,108.59 -6,860.49 6,002,495.14 1,520,994.17 0.83 -1,894.65 MWD+IFR-AK-CAZ-SC(3) 9,447.18 63.21 260.08 5,352.37 5,303.97 -1,122.58 -6,942.61 6,002,482.39 1,520,911.86 0.51 -1,916.67 MWD+IFR-AK-CAZ-SC(3) 9,541.97 62.81 259.48 5,395.39 5,346.99 -1,137.57 -7,025.74 6,002,468.66 1,520,828.52 0.70 -1,938.22 MWD+IFR-AK-CAZ-SC(3) 9,636.40 63.00 259.06 5,438.40 5,390.00 -1,153.22 -7,108.33 6,002,454.25 1,520,745.71 0.44 -1,958.94 MWD+IFR-AK-CAZ-SC(3) 9,731.37 63.35 258.30 5,481.25 5,432.85 -1,169.86 -7,191.43 6,002,438.87 1,520,662.37 0.80 -1,978.98 MWD+IFR-AK-CAZ-SC(3) 9,825.81 63.49 258.21 5,523.51 5,475.11 -1,187.05 -7,274.13 6,002,422.93 1,520,579.44 0.17 -1,998.35 MWD+IFR-AK-CAZ-SC(3) 9,920.32 63.51 258.83 5,565.68 5,517.28 -1,203.88 -7,357.01 6,002,407.35 1,520,496.31 0.59 -2,018.12 MWD+IFR-AK-CAZ-SC(3) 10,014.74 63.84 260.12 5,607.55 5,559.15 -1,219.34 -7,440.21 6,002,393.15 1,520,412.90 1.27 -2,039.27 MWD+IFR-AK-CAZ-SC(3) 10,109.23 63.84 260.03 5,649.21 5,600.81 -1,233.96 -7,523.76 6,002,379.80 1,520,329.15 0.09 -2,061.33 MWD+IFR-AK-CAZ-SC(3) 10,203.46 63.56 260.31 5,690.96 5,642.56 -1,248.38 -7,606.99 6,002,366.63 1,520,245.71 0.40 -2,083.44 MWD+IFR-AK-CAZ-SC(3) 10,297.98 63.22 258.27 5,733.30 5,684.90 -1,264.08 -7,690.02 6,002,352.18 1,520,162.46 1.96 -2,104.30 MWD+IFR-AK-CAZ-SC(3) 10,392.73 62.30 254.78 5,776.68 5,728.28 -1,283.70 -7,771.93 6,002,333.81 1,520,080.28 3.42 -2,121.14 MWD+IFR-AK-CAZ-SC(3) 10,487.05 60.77 251.66 5,821.65 5,773.25 -1,307.61 -7,851.30 6,002,311.09 1,520,000.56 3.33 -2,133.00 MWD+IFR-AK-CAZ-SC(3) 10,581.34 60.63 248.32 5,867.80 5,819.40 -1,335.74 -7,928.55 6,002,284.13 1,519,922.90 3.09 -2,140.16 MWD+IFR-AK-CAZ-SC(3) 10,675.66 59.63 243.68 5,914.79 5,866.39 -1,368.98 -8,003.25 6,002,252.03 1,519,847.72 4.40 -2,141.60 MWD+IFR-AK-CAZ-SC(3) 10,770.17 58.63 238.64 5,963.31 5,914.91 -1,408.07 -8,074.28 6,002,214.01 1,519,776.11 4.70 -2,136.19 MWD+IFR-AK-CAZ-SC(3) I 10,866.01 56.80 234.67 6,014.51 5,966.11 -1,452.57 -8,141.96 6,002,170.54 1,519,707.78 3.99 -2,124.46 MWD+IFR-AK-CAZ-SC(3) 3/23/2012 9:40:02AM Page 5 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey fiy ,= . ','�,��-. ,o tiyo ,a. fgx :. �w, rb - dte xi tc .ar c^'1 gym ; Map Map Vertical � MD Inc Azi ND TVDSS +NI-S +EI-W Northing Easting DLS Section 7-7 (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,960.39 56.12 230.93 6,066.67 6,018.27 -1,500.11 -8,204.60 6,002,123.96 1,519,644.43 3.38 -2,107.85 MWD+IFR-AK-CAZ-SC(3) 11,055.50 57.02 227.78 6,119.08 6,070.68 -1,551.81 -8,264.81 6,002,073.18 1,519,583.45 2.92 -2,086.44 MWD+IFR-AK-CAZ-SC(3) 11,150.12 57.84 223.75 6,170.03 6,121.63 -1,607.43 -8,321.91 6,002,018.43 1,519,525.52 3.69 -2,060.17 MWD+IFR-AK-CAZ-SC(3) 11,244.60 59.28 219.35 6,219.33 6,170.93 -1,667.75 -8,375.34 6,001,958.93 1,519,471.20 4.26 -2,028.08 MWD+IFR-AK-CAZ-SC(3) 11,339.05 59.06 215.13 6,267.75 6,219.35 -1,732.29 -8,424.41 6,001,895.14 1,519,421.17 3.84 -1,990.32 MWD+IFR-AK-CAZ-SC(3) 11,432.57 59.18 211.21 6,315.76 6,267.36 -1,799.45 -8,468.30 6,001,828.65 1,519,376.26 3.60 -1,948.00 MWD+IFR-AK-CAZ-SC(3) 11,527.59 59.49 209.14 6,364.22 6,315.82 -1,870.11 -8,509.38 6,001,758.63 1,519,334.13 1.90 -1,901.33 MWD+IFR-AK-CAZ-SC(3) 11,621.98 61.41 204.81 6,410.79 6,362.39 -1,943.27 -8,546.59 6,001,686.04 1,519,295.83 4.48 -1,850.74 MWD+IFR-AK-CAZ-SC(3) 11,717.12 61.18 201.57 6,456.50 6,408.10 -2,019.96 -8,579.44 6,001,609.87 1,519,261.82 3.00 -1,795.13 MWD+IFR-AK-CAZ-SC(3) 11,811.39 61.12 197.34 6,502.00 6,453.60 -2,097.79 -8,606.94 6,001,532.47 1,519,233.16 3.93 -1,736.21 MWD+IFR-AK-CAZ-SC(3) 11,906.13 61.41 195.24 6,547.55 6,499.15 -2,177.52 -8,630.23 6,001,453.10 1,519,208.67 1.97 -1,673.79 MWD+IFR-AK-CAZ-SC(3) 12,000.10 60.34 194.59 6,593.29 6,544.89 -2,256.84 -8,651.36 6,001,374.12 1,519,186.35 1.29 -1,610.83 MWD+IFR-AK-CAZ-SC(3) 12,094.88 60.86 194.95 6,639.81 6,591.41 -2,336.68 -8,672.42 6,001,294.60 1,519,164.10 0.64 -1,547.37 MWD+IFR-AK-CAZ-SC(3) 12,189.14 61.20 195.25 6,685.47 6,637.07 -2,416.30 -8,693.90 6,001,215.33 1,519,141.42 0.46 -1,484.29 MWD+IFR-AK-CAZ-SC(3) 12,284.04 60.26 194.76 6,731.87 6,683.47 -2,496.26 -8,715.33 6,001,135.71 1,519,118.78 1.09 -1,420.88 MWD+IFR-AK-CAZ-SC(3) 12,378.29 61.12 194.55 6,778.01 6,729.61 -2,575.77 -8,736.12 6,001,056.52 1,519,096.79 0.93 -1,357.60 MWD+IFR-AK-CAZ-SC(3) 12,472.59 62.23 195.81 6,822.75 6,774.35 -2,655.88 -8,757.86 6,000,976.76 1,519,073.85 1.66 -1,294.19 MWD+IFR-AK-CAZ-SC(3) 12,522.26 63.84 195.78 6,845.27 6,796.87 -2,698.48 -8,769.91 6,000,934.35 1,519,061.16 3.24 -1,260.68 MWD+IFR-AK-CAZ-SC(3) 12,567.21 65.41 194.92 6,864.53 6,816.13 -2,737.64 -8,780.66 6,000,895.36 1,519,049.83 3.90 -1,229.72 MWD+IFR-AK-CAZ-SC(3) 12,612.80 66.81 192.93 6,883.00 6,834.60 -2,778.10 -8,790.69 6,000,855.06 1,519,039.19 5.04 -1,197.30 MWD+IFR-AK-CAZ-SC(3) 12,661.68 69.43 191.69 6,901.21 6,852.81 -2,822.41 -8,800.35 6,000,810.91 1,519,028.86 5.85 -1,161.22 MWD+IFR-AK-CAZ-SC(3) 12,710.99 71.63 190.00 6,917.65 6,869.25 -2,868.06 -8,809.10 6,000,765.39 1,519,019.43 5.51 -1,123.54 MWD+IFR-AK-CAZSC(3) 12,756.30 73.83 187.69 6,931.10 6,882.70 -2,910.81 -8,815.74 6,000,722.75 1,519,012.14 6.88 -1,087.60 MWD+IFR-AK-CAZ-SC(3) 12,802.74 75.57 186.68 6,943.35 6,894.95 -2,955.25 -8,821.34 6,000,678.40 1,519,005.87 4.29 -1,049.69 MWD+IFR-AK-CAZ-SC(3) 12,850,76 77.59 184.32 6,954.50 6,906.10 -3,001.74 -8,825.82 6,000,631.99 1,519,000.70 6.37 -1,009.45 MWD+IFR-AK-CAZ-SC(3) 12,903.27 79.48 182.55 6,964.94 6,916.54 -3,053.11 -8,828.90 6,000,580.68 1,518,996.85 4.89 -964.20 MWD+IFR-AK-CAZ-SC(3) 12,945.65 81.74 181.38 6,971.85 6,923.45 -3,094.89 -8,830.33 6,000,538.93 1,518,994.78 5.99 -926.94 MWD+IFR-AK-CAZ-SC(3) 12,975.44 81.92 181.50 6,976.09 6,927.69 -3,124.37 -8,831.07 6,000,509.47 1,518,993.60 0.72 -900.53 MWD+IFR-AK-CAZ-SC(3) 13,029.53 84.06 181.42 6,982.69 6,934.29 -3,178.03 -8,832.44 6,000,455.83 1,518,991.42 3.96 -852.47 MWD+IFR-AK-CAZ-SC(4) 13,128.34 87.54 182.18 6,989.92 6,941.52 -3,276.51 -8,835.53 6,000,357.42 1,518,986.84 3.60 -764.53 MWD+IFR-AK-CAZ-SC(4) 13,221.62 90.32 181.04 6,991.66 6,943.26 -3,369.73 -8,838.15 6,000,264.26 1,518,982.82 3.22 -681.15 MWD+IFR-AK-CAZ-SC(4) 13,319.56 89.99 177.66 6,991.40 6,943.00 -3,467.65 -8,837.04 6,000,166.35 1,518,982.45 3.47 -591.94 MWD+IFR-AK-CAZ-SC(4) 13,414.61 90.00 171.26 6,991.41 6,943.01 -3,562.21 -8,827.87 6,000,071.67 1,518,990.20 6.73 -502.36 MWD+IFR-AK-CAZ-SC(4) 13,509.13 89.69 168.73 6,991.66 6,943.26 -3,655.28 -8,811.45 5,999,978.37 1,519,005.21 2.70 -411.07 MWD+IFR-AK-CAZ-SC(4) 13,606.64 88.32 165.19 6,993.36 6,944.96 -3,750.24 -8,789.46 5,999,883.09 1,519,025.77 3.89 -315.71 MWD+IFR-AK-CAZ-SC(4) 13,701.05 88.58 160.18 6,995.91 6,947.51 -3,840.31 -8,761.38 5,999,792.62 1,519,052.48 5.31 -222.21 MWD+IFR-AK-CAZ-SC(4) 13,753.81 88.45 157.61 6,997.28 6,948.88 -3,889.51 -8,742.39 5,999,743.14 1,519,070.73 4.88 -169.60 MWD+IFR-AK-CAZ-SC(4) 13,796.77 88.58 155.69 6,998.39 6,949.99 -3,928.94 -8,725.37 5,999,703.46 1,519,087.15 4.48 -126.67 MWD+IFR-AK-CAZ-SC(4) 13,892.25 88.39 152.87 7,000.92 6,952.52 -4,014.92 -8,683.95 5,999,616.87 1,519,127.26 2.96 -31.24 MWD+IFR-AK-CAZ-SC(4) 13,987.69 88.76 149.13 7,003.29 6,954.89 -4,098.35 -8,637.70 5,999,532.76 1,519,172.24 3.94 63.92 MWD+IFR-AK-CAZ-SC(4) 3/23/2012 9:40:02AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-128 • Ct: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Weft: CD3-128 North Reference: True Welffxore:., CD3-128 Survey Calculation Method: Minimum Curvature s: CD3-128 Database: CPAI EDM Production Survey s MIS inc Azi Tv i Ts �8 +Elm` `fVdtiftCi'*g ;,EOt : �I?LS Se t�) (°} t ) ttt} �= w (ft) (ft) (ft) (ft) 14,082.08 89.75 145.99 7,004.52 6,956.12 -4,178.00 -8,587.08 5,999,452.37 1,519,221.65 3.49 157.49 MWD+IFR-AK-CAZSC(4) 14,178.63 88.51 142,63 7,005.99 6,957.59 -4,256.39 -8,530.77 5,999,373.14 1,519,276.77 3.71 252.34 MWD+IFR-AK-CAZ-SC(4) 14,272.65 88.82 140.48 7,008.18 6,959.78 -4,330.01 -8,472.33 5,999,298.66 1,519,334.09 2.31 343.76 MWD+IFR-AK-CAZ-SC(4) 14,368.15 88.26 142.14 7,010.61 6,962.21 -4,404.52 -8,412.66 5,999,223.26 1,519,392.63 1.83 436.51 MWD+IFR-AK-CAZ-SC(4) 14,463.49 89.01 144.06 7,012.88 6,964.48 -4,480.74 -8,355.43 5,999,146.20 1,519,448.69 2.18 529.77 MWD+IFR-AK-CAZ-SC(4) 14,557.71 89.63 144.09 7,014.00 6,965.60 -4,557.03 -8,300.15 5,999,069.09 1,519,502.81 0.66 622.27 MWD+IFR-AK-CAZ-SC(4) 14,654.02 90.31 141.61 7,014.05 6,965.65 -4,633.79 -8,242.00 5,998,991.47 1,519,559.80 2.67 716.42 MWD+IFR-AK-CAZ-SC(4) 14,750.48 89.43 140.29 7,014.27 6,965.87 -4,708.69 -8,181.23 5,998,915.66 1,519,619.42 1.64 809.99 MWD+IFR-AK-CAZ-SC(4) 14,845.21 89.38 141.13 7,015.25 6,966.85 -4,782.01 -8,121.25 5,998,841.46 1,519,678.29 0.89 901.78 MWD+IFR-AK-CAZ-SC(4) 14,941.01 90.19 141.28 7,015.61 6,967.21 -4,856.67 -8,061.22 5,998,765.91 1,519,737.17 0.86 994.82 MWD+IFR-AK-CAZ-SC(4) 14,991.60 89.68 141.62 7,015.67 6,967.27 -4,896.24 -8,029.70 5,998,725.87 1,519,768.10 1.21 1,044.00 MWD+IFR-AK-CAZ-SC(4) 15,035.95 90.31 142.03 7,015.67 6,967.27 -4,931.10 -8,002.29 5,998,690.60 1,519,794.98 1.69 1,087.18 MWD+IFR-AK-CAZ-SC(4) 15,132.00 89.56 142.54 7,015.78 6,967.38 -5,007.08 -7,943.53 5,998,613.75 1,519,852.58 0.94 1.180.88 MWD+IFR-AK-CAZ-SC(4) 15,226.60 89.69 144.35 7,016.40 6,968.00 -5,083.07 -7,887.19 5,998,536.93 1,519,907.76 1.92 1,273.55 MWD+IFR-AK-CAZ-SC(4) 15,322.37 89.25 143.50 7,017.29 6,968.89 -5,160.47 -7,830.80 5,998,458.69 1,519,962.97 1.00 1,367.53 MWD+IFR-AK-CAZ-SC(4) 15,417.57 89.25 141.86 7,018.53 6,970.13 -5,236.17 -7,773.09 5,998,382.14 1,520,019.53 1.72 1,460.53 MWD+IFR-AK-CAZ-SC(4) 15,512.34 88.57 143.86 7,020.34 6,971.94 -5,311.70 -7,715.88 5,998,305.76 1,520,075.59 2.23 1,553.16 MWD+IFR-AK-CAZ-SC(4) 15,608.00 89.69 144.19 7,021.79 6,973.39 -5,389.10 -7,659.70 5,998,227.53 1,520,130.59 1.22 1,647.06 MWD+IFR-AK-CAZ-SC(4) 15,704.39 88.57 146.07 7,023.25 6,974.85 -5,468.17 -7,604.60 5,998,147.64 1,520,184.49 2.27 1,742.00 MWD+IFR-AK-CAZ-SC(4) 15,799.66 90.56 146.49 7,023.98 6,975.58 -5,547.41 -7,551.72 5,998,067.63 1,520,236.17 2.13 1,836.16 MWD+IFR-AK-CAZ-SC(4) 15,895.28 89.93 144.04 7,023.57 6,975.17 -5,625.98 -7,497.24 5,997,988.25 1,520,289.45 2.65 1,930.40 MWD+I F R-AK-CAZ-SC(4) 15,990.62 90.43 142.72 7,023.27 6,974.87 -5,702.50 -7,440.37 5,997,910.89 1,520,345.15 1.48 2,023.78 MWD+IFR-AK-CAZ-SC(4) 16,085.21 88.56 140.90 7,024.10 6,975.70 -5,776.83 -7,381.89 5,997,835.69 1,520,402.50 2.76 2,115.87 MWD+IFR-AK-CAZ-SC(4) 16,180.25 88.26 140.57 7,026.74 6,978.34 -5,850.39 -7,321.77 5,997,761.24 1,520,461.50 0.47 2,207.94 MWD+IFR-AK-CAZ-SC(4) 16,275.54 88.83 143.44 7,029.16 6,980.76 -5,925.45 -7,263.13 5,997,685.31 1,520,519.00 3.07 2,300.75 MWD+IFR-AK-CAZ-SC(4) 16,370.55 87.89 144.21 7,031.88 6,983.48 -6,002.11 -7,207.08 5,997,607.82 1,520,573.88 1.28 2,393.92 MWD+IFR-AK-CAZ-SC(4) 16,466.46 88.27 143.67 7,035.09 6,986.69 -6,079.60 -7,150.65 5,997,529.49 1,520,629.13 0.69 2,487.99 MWD+I F R-AK-CAZ-SC(4) 16,561.28 87.77 144.58 7,038.37 6,989.97 -6,156.39 -7,095.12 5,997,451.88 1,520,683.49 1.09 2,581.05 MWD+IFR-AK-CAZ-SC(4) 16,656.75 89.26 145.69 7,040.84 6,992.44 -6,234.69 -7,040.57 5,997,372.77 1,520,736.85 1.95 2,675.08 MWD+IFR-AK-CAZ-SC(4) 16,751.76 89.56 145.28 7,041.82 6,993.42 -6,312.97 -6,986.73 5,997,293.70 1,520,789.50 0.53 2,768.77 MWD+IFR-AK-CAZ-SC(4) j 16,847.59 89.31 145.15 7,042.76 6,994.36 -6,391.67 -6,932.07 5,997,214.19 1,520,842.97 0.29 2,863.20 MWD+I F R-AK-CAZ-SC(4) 16,941.44 90.00 145.16 7,043.33 6,994.93 -6,468.69 -6,878.45 5,997,136.37 1,520,895.42 0.74 2,955.67 MWD+IFR-AK-CAZ-SC(4) 17,038.65 89.31 145.89 7,043.92 6,995.52 -6,548.83 -6,823.42 5,997,055.42 1,520,949.22 1.03 3,051.55 MWD+IFR-AK-CAZ-SC(4) 17,134.41 90.06 145.69 7,044.44 6,996.04 -6,628.02 -6,769.58 5,996,975.44 1,521,001.85 0,81 3,146.07 MWD+I F R-AK-CAZ-SC(4) 17,229.39 90.74 144.48 7,043.78 6,995.38 -6,705.90 -6,715.22 5,996,896.75 1,521,055.03 1.46 3,239.63 MWD+IFR-AK-CAZ-SC(4) 17,325.09 89.06 142.06 7,043.95 6,995.55 -6,782.59 -6,658.00 5,996,819.22 1,521,111.09 3.08 3,333.32 MWD+I FR-AK-CAZ-SC(4) 17,420.52 89.19 141.67 7,045.40 6,997.00 -6,857.64 -6,599.07 5,996,743.29 1,521,168.87 0.43 3,426.24 MWD+IFR-AK-CAZ-SC(4) 17,514.36 89.81 142.21 7,046.22 6,997.82 -6,931.52 -6,541.23 5,996,668.55 1,521,225.59 0.88 3,517.65 MWD+IFR-AK-CAZ-SC(4) 17,609.41 88.44 143.29 7,047.67 6,999.27 -7,007.17 -6,483.70 5,996,592.05 1,521,281.96 1.84 3,610.52 MWD+IFR-AK-CAZ-SC(4) 17,703.60 89.94 145.12 7,049.01 7,000.61 -7,083.56 -6,428.62 5,996,514.85 1,521,335.88 2.51 3,703.03 MWD+IFR-AK-CAZ-SC(4) 3/23/2012 9:40:02AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +Ei-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 17,801.00 90.06 145.81 7,049.01 7,000.61 -7,163.79 -6,373.40 5,996,433.80 1,521,389.88 0.72 3,799.09 MWD+IFR-AK-CAZ-SC(4) 17,896.18 89.81 145.88 7,049.11 7,000.71 -7,242.56 -6,319.97 5,996,354.24 1,521,442.12 0.27 3,893.05 MWD+IFR-AK-CAZ-SC(4) 17,991.92 90.06 146.39 7,049.22 7,000.82 -7,322.06 -6,266.62 5,996,273.96 1,521,494.26 0.59 3,987.65 MWD+IFR-AK-CAZ-SC(4) 18,087.23 89.81 147.93 7,049.33 7,000.93 -7,402.13 -6,214.93 5,996,193.12 1,521,544.72 1.64 4,082.06 MWD+IFR-AK-CAZ-SC(4) 18,182.64 88.88 143.45 7,050.42 7,002.02 -7,480.91 -6,161.17 5,996,113.54 1,521,597.29 4.80 4,176.19 MWD+IFR-AK-CAZ-SC(4) 18,277.44 88.01 143.54 7,052.99 7,004.59 -7,557.09 -6,104.80 5,996,036.53 1,521,652.50 0.92 4,269.05 MWD+IFR-AK-CAZ-SC(4) 18,373.88 87.58 143.93 7,056.70 7,008.30 -7,634.79 -6,047.79 5,995,957.99 1,521,708.32 0.60 4,363.56 MWD+IFR-AK-CAZ-SC(4) 18,469.04 89.45 144.24 7,059.17 7,010.77 -7,711.83 -5,992.00 5,995,880.12 1,521,762.95 1.99 4,456.96 MWD+IFR-AK-CAZ-SC(4) 18,564.81 88.88 144.74 7,060.57 7,012.17 -7,789.78 -5,936.37 5,995,801.35 1,521,817.38 0.79 4,551.11 MWD+IFR-AK-CAZ-SC(4) 18,659.04 89.75 145.05 7,061.69 7,013.29 -7,866.86 -5,882.19 5,995,723.47 1,521,870.40 0.98 4,643.87 MWD+IFR-AK-CAZ-SC(4) 18,754.34 88.88 141.77 7,062.83 7,014.43 -7,943.36 -5,825.39 5,995,646.12 1,521,926.02 3.56 4,737.21 MWD+IFR-AK-CAZ-SC(4) 18,848.80 87.70 141.24 7,065.65 7,017.25 -8,017.26 -5,766.63 5,995,571.36 1,521,983.67 1.37 4,829.02 MWD+IFR-AK-CAZ-SC(4) 18,943.50 87.21 142.84 7,069.86 7,021.46 -8,091.85 -5,708.43 5,995,495.91 1,522,040,72 1.77 4,921.21 MWD+IFR-AK-CAZ-SC(4) 19,039.75 88.40 144.33 7,073.54 7,025.14 -8,169.24 -5,651.34 5,995,417.66 1,522,096.64 1.98 5,015.49 MWD+IFR-AK-CAZ-SC(4) 19,135.46 90.44 145.86 7,074.51 7,026.11 -8,247.72 -5,596.58 5,995,338.37 1,522,150.20 2.66 5,109.76 MWD+IFR-AK-CAZ-SC(4) 19,230.70 91.79 145.85 7,072.66 7,024.26 -8,326.53 -5,543.14 5,995,258.78 1,522,202.45 1.42 5,203.77 MWD+IFR-AK-CAZ-SC(4) 19,326.21 90.30 143.66 7,070.92 7,022.52 -8,404,51 -5,488.03 5,995,179.98 1,522,256.37 2.77 5,297.73 MWD+IFR-AK-CAZSC(4) 19,421.64 90.43 141.27 7,070.31 7,021.91 -8,480.18 -5,429.90 5,995,103.45 1,522,313.35 2.51 5,390.88 MWD+IFR-AK-CAZ-SC(4) 19,517.32 89.37 140.93 7,070.48 7,022.08 -8,554.64 -5,369.82 5,995,028.10 1,522,372.30 1.16 5,483.75 MWD+IFR-AK-CAZ-SC(4) 19,612.36 89.32 142.18 7,071.56 7,023.16 -8,629.07 -5,310.73 5,994,952.79 1,522,430.25 1.32 5,576.18 MWD+IFR-AK-CAZ-SC(4) 19,710.70 90.31 142.94 7,071.88 7,023.48 -8,707.15 -5,250.95 5,994,873.83 1,522,488.84 1.27 5,672.21 MWD+IFR-AK-CAZSC(4) 19,804.02 89.37 143.52 7,072.14 7,023.74 -8,781.90 -5,195.09 5,994,798.25 1,522,543.57 1.18 5,763.57 MWD+IFR-AK-CAZ-SC(4) 19,899.73 89.63 144.29 7,072.97 7,024.57 -8,859.23 -5,138.70 5,994,720.08 1,522,598.77 0.85 5,857.48 MWD+IFR-AK-CAZ-SC(4) 19,994.92 88.69 146.02 7,074.37 7,025.97 -8,937.34 -5,084.32 5,994,641.17 1,522,651.96 2.07 5,951.26 MWD+IFR-AK-CAZ-SC(4) 20,091.32 88.64 145.02 7,076.62 7,028.22 -9,016.79 -5,029.77 5,994,560.92 1,522,705.31 1.04 6,046.31 MWD+IFR-AK-CAZ-SC(4) 20,186.53 88.14 145.48 7,079.29 7,030.89 -9,094.98 -4,975.52 5,994,481.92 1,522,758.37 0.71 6,140.11 MWD+IFR-AK-CAZ-SC(4) 20,282.36 89.39 147.25 7,081.36 7,032.96 -9,174.75 -4,922.45 5,994,401.37 1,522,810.22 2.26 6,234.83 MWD+IFR-AK-CAZ-SC(4) 20,353.07 89.25 146.34 7,082.20 7,033.80 -9,233.91 -4,883.73 5,994,341.64 1,522,848.04 1.30 6,304.81 MWD+IFR-AK-CAZ-SC(4) 20,387.00 89.25 146.34 7,082.64 7,034.24 -9,262.15 -4,864.93 5,994,313.12 1,522,866.42 0.00 6,338.35 PROJECTED to TD 3/23/2012 9:40:02AM Page 8 COMPASS 2003.16 Build 69 1 , . - / ( • 037 11 ConocoPhillips(Alaska) Inc. 4 Western North Slope CD3 Fiord Pad CD3-128 501032063800 IIS t Sperry Drilling Definitive Survey Report I 23 March, 2012 0 2_12_ id0 10 " 4 ALLIEURTD Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report •,. a k Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3-128 -- - ---Well Position +NI-S 0.00 ft Northing: 6,003,752.89ft Latitude: 70°25'9.068 N, +E/-W 0.00 ft Easting: 387,838.10 ft Longitude: 150°54'49.392 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60ft Wellbore CD3-128 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) , BGG M2011 2/1/2012 20.21 80.87 57,613 Design CD3-128 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,975.44 Vertical Section: Depth From(TVD) +N/-S +E!-W Direction (ft) (ft) (ft) le) I 35.80 0.00 0.00 155.00 Survey Program Date 3/23/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 79.00 1,100.00 CD3-128 Gyro(R100)(CD3-128(IntermECB-GYRO-SS Camera based gyro single shot 4/12/2011 12:C 1,148.28 2,946.82 CD3-128 MWD(R300)(CD3-128(Interm MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/12/2011 12:C 3,045.13 12,975.44 CD3-128 MWD(R400)(CD3-128(Interm MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/16/2011 12:C 13,029.53 20,353.07 CD3-128 MWD(R700)(CD3-128) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/14/2012 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/108') (ft) Survey Tool Name 35.80 0.00 0.00 35.80 -12.60 0.00 0.00 6,003,752.89 387,838.10 0.00 0.00 UNDEFINED 79.00 0,05 284.95 79.00 30.60 0.00 -0.02 6,003,752.89 387,838.08 0.12 -0.01 CB-GYRO-SS(1) 170.00 0.37 6.10 170.00 121.60 0.31 -0.03 6,003,753.19 387,838.08 0.40 -0.29 CB-GYR0-SS(1) 263.00 0.45 8.32 263.00 214.60 0.97 0.06 6,003,753.85 387,838.17 0.09 -0.85 CB-GYRO-SS(1) 291.00 0.44 358.14 291.00 242.60 1.18 0.07 6,003,754.07 387,838.19 0.28 -1.04 CB-GYRO-SS(1) 321.00 0.52 5.76 321.00 272.60 1.43 0.08 6,003,754.32 387,838.20 0.34 -1.27 CB-GYRO-SS(1) 351.00 0.57 357.16 350.99 302.59 1.72 0.09 6,003,754.60 387,838.21 0.32 -1.52 C8-GYRO-SS(1) 355.00 0.72 12.68 354.99 306.59 1.76 0.09 6,003,754.65 387,838.22 5.72 -1.56 CB-GYRO-SS(1) 381.00 0.67 4.70 380.99 332.59 2.07 0.14 6,003,754.96 387,838.27 0.42 -1.82 CB-GYRO-SS(1) 411.00 0.73 346.99 410.99 362.59 2.43 0.11 6,003,755.32 387,838.25 0.75 -2.16 CB-GYRO-SS(1) 441.00 0.95 336.11 440.99 392.59 2.85 -0,03 6,003,755.73 387,838.11 0.90 -2.59 CB-GYRO-SS(1) 3/23/2012 12:28:02PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey I Map Map Vertical MD Inc Azi:. TVD TVDSS +NI-S. +EI-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°I1oo') (ft) Survey Tool Name 448.00 1.19 338.52 447.98 399.58 2.97 -0.08 6,003,755.86 387,838.06 3.49 -2.73 C8-GYRO-SS(1) I 471.00 1.46 322.24 470.98 422.58 3.42 -0.35 6,003,756.31 387,837.80 2.00 -3.25 CB-GYRO-SS(1) 479.00 1.55 323.18 478.98 430.58 3.59 -0.48 6,003,756.48 387,837.68 1.17 -3.45 CB-GYRO-SS(1) 486.00 1.80 316.66 485.97 437.57 3.75 -0.61 6,003,756.64 387,837.55 4.49 -3.65 CB-GYRO-SS(1) 501.00 1,83 314.59 500.97 452.57 4.09 -0.94 6,003,756.98 387,837.22 0.48 -4.10 CB-GYRO-SS(1) 516.00 1.98 313.17 515.96 467.56 4.43 -1.30 6,003,757.34 387,836.87 1.05 -4.57 CB-GYRO-SS(1) 531.00 2.24 309.79 530.95 482.55 4.80 -1.71 6,003,757.71 387,836.46 1.92 -5.07 CB-GYRO-SS(1) I 540.00 2.71 308.40 539.94 491.54 5.04 -2.02 6,003,757.96 387,836.16 5.26 -5.42 CB-GYRO-SS(1) I 546.00 2.45 308.72 545.93 497.53 5.21 -2.23 6,003,758.13 387,835.95 4.34 -5.66 CB-GYRO-SS(1) 561.00 2.60 311.20 560.92 512.52 5.63 -2.73 6,003,758.56 387,835.45 1.24 -6.26 CB-GYRO-SS(1) 633.00 4.82 294.43 632.76 584.36 7.96 -6.72 6,003,760.95 387,831.50 3.40 -10.05 CB-GYRO-SS(1) 724.00 5.67 284.50 723.38 674.98 10.67 -14.55 6,003,763.77 387,823.71 1.36 -15.82 CB-GYRO-SS(1) 815.00 6.27 282.47 813.89 765.49 12.87 -23.75 6,003,766.11 387,814.54 0.70 -21.70 CB-GYRO-SS(1) 909.00 8.07 284.86 907.15 858.75 15.67 -35.14 6,003,769.08 387,803.20 1.94 -29.05 CB-GYRO-SS(1) 1,004.00 11.26 289.11 1,000.79 952.39 20.41 -50.36 6,003,774.05 387,788.06 3.44 -39.78 CB-GYRO-SS(1) 1,100.00 11.43 287.01 1,094.92 1,046.52 26.27 -68.31 6,003,780.17 387,770.20 0.47 -52.67 CB-GYRO-SS(1) 1,148.28 12.53 285.03 1,142.15 1,093.75 29.02 -77.94 6,003,783.07 387,760.61 2.43 -59.24 MWD+IFR-AK-CAZ-SC(2) 1,245.64 14.20 278.60 1,236.87 1,188.47 33.55 -99.95 6,003,787.93 387,738.67 2.29 -72.65 MWD+IFR-AK-CAZ-SC(2) 1,339.98 18.95 274.82 1,327.27 1,278.87 36.57 -126.67 6,003,791.35 387,712.00 5.16 -86.68 MWD+IFR-AK-CAZ-SC(2) 1,434.36 22.98 272.49 1,415.38 1,366.98 38.66 -160.36 6,003,793.94 387,678.35 4.36 -102.81 MWD+IFR-AK-CAZ-SC(2) 1,528.94 26.95 267.63 1,501.12 1,452.72 38.57 -200.24 6,003,794.46 387,638.47 4.72 -119.59 MWD+IFR-AK-CAZ-SC(2) 1,623.32 30.89 266.80 1,583.71 1,535.31 36.33 -245.82 6,003,792.91 387,592.87 4.20 -136.82 MWD+IFR-AK-CAZ-SC(2) 1,717.75 34.05 264.21 1,663.37 1,614.97 32.31 -296.34 6,003,789.64 387,542.30 3.66 -154.52 MWD+IFR-AK-CAZ-SC(2) 1,810.86 37.07 263.42 1,739.11 1,690.71 26.47 -350.16 6,003,784.61 387,488.40 3.28 -171.97 MWD+IFR-AK-CAZ-SC(2) 1,907.24 38.24 261.27 1,815.42 1,767.02 18.61 -408.51 6,003,777.63 387,429.95 1.82 -189.51 MWD+IFR-AK-CAZ-SC(2) 2,001.83 41.08 258.23 1,888.24 1,839.84 7.82 -467.88 6,003,767.74 387,370.42 3.64 -204.83 MWD+IFR-AK-CAZ-SC(2) 2,096.83 45.21 257.78 1,957.54 1,909.14 -5.68 -531.42 6,003,755.19 387,306.70 4.36 -219.43 MWD+IFR-AK-CAZ-SC(2) 2,191.22 48.45 258.55 2,022.11 1,973.71 -19.79 -598.79 6,003,742.10 387,239.13 3.48 -235.12 MWD+IFR-AK-CAZ-SC(2) 2,285.65 51.30 259.96 2,082.96 2,034.56 -33.23 -669.72 6,003,729.72 387,168.01 3.23 -252.92 MWD+IFR-AK-CAZ-SC(2) 2,380.02 53.97 262.48 2,140.23 2,091.83 -44.65 -743.83 6,003,719.42 387,093.75 3.54 -273.89 MWD+IFR-AK-CAZ-SC(2) 2,474.81 56.88 262.15 2,194.02 2,145.62 -55.09 -821.17 6,003,710.15 387,016.27 3.08 -297.11 MWD+IFR-AK-CAZ-SC(2) 2,566.43 58.46 262.76 2,243.01 2,194.61 -65.25 -897.91 6,003,701.14 386,939.38 1.81 -320.34 MWD+IFR-AK-CAZ-SC(2) 2,663.51 58.56 260.62 2,293.73 2,245.33 -77.21 -979.82 6,003,690.41 386,857.31 1.88 -344.11 MWD+IFR-AK-CAZ-SC(2) 2,757.77 59.89 259.61 2,341.96 2,293.56 -91.12 -1,059.60 6,003,677.70 386,777.34 1.68 -365.22 MWD+IFR-AK-CAZ-SC(2) 2,852.26 61.24 259.06 2,388.39 2,339.99 -106.35 -1,140.47 6,003,663.69 386,696.26 1.52 -385.59 MWD+IFR-AK-CAZ-SC(2) 2,946.82 63.44 258.90 2,432.29 2,383.89 -122.36 -1,222.67 6,003,648.92 386,613.83 2.33 -405.83 MWD+IFR-AK-CAZ-SC(2) 3,045.13 63.69 259.67 2,476.05 2,427.65 -138.73 -1,309.17 6,003,633.85 386,527.11 0.75 -427.55 MWD+IFR-AK-CAZ-SC(3) 3,136.78 63.00 258.90 2,517.17 2,468.77 -153.95 -1,389.65 6,003,619.84 386,446.41 1.06 -447.76 MWD+IFR-AK-CAZ-SC(3) 3,232.89 62.27 258.45 2,561.35 2,512.95 -170.72 -1,473.34 6,003,604.34 386,362.49 0.87 -467.94 MWD+IFR-AK-CAZ-SC(3) 3,325.63 62.10 258.77 2,604.62 2,556.22 -186.91 -1,553.75 6,003,589.35 386,281.85 0.36 -487.24 MWD+IFR-AK-CAZ-SC(3) 3/23/2012 12:28:02PM Page 3 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope ND Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N!-S tEl Northing Easting DLS Section IF (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) 01001 (ft) Survey Tool Name 3,418.05 64.04 259.61 2,646.48 2,598.08 -202.36 -1,634.68 6,003,575.12 386,200.70 2.25 -507.44 MWD+IFR-AK-CAZ-SC(3) 3,512.48 64.26 258.77 2,687.65 2,639.25 -218.30 -1,718.15 6,003,560.44 386,117.01 0.83 -528.27 MWD+IFR-AK-CAZ-SC(3) 3,606.46 64.25 259.59 2,728.47 2,680.07 -234.19 -1,801.30 6,003,545.80 386,033.64 0.79 -549.01 MWD+IFR-AK-CAZ-SC(3) 3,700.00 64.40 260.06 2,769.00 2,720.60 -249.08 -1,884.28 6,003,532.16 385,950.45 0.48 -570.58 MWD+IFR-AK-CAZ-SC(3) 3,792.75 63.78 260.01 2,809.53 2,761.13 -263.52 -1,966.44 6,003,518.96 385,868.09 0.67 -592.22 MWD+IFR-AK-CAZ-SC(3) 3,887.38 63.28 260.87 2,851.71 2,803.31 -277.59 -2,049.98 6,003,506.15 385,784.36 0.97 -614.77 MWD+IFR-AK-CAZ-SC(3) 3,980.21 63.00 260.05 2,893.65 2,845.25 -291.32 -2,131.64 6,003,493.65 385,702.50 0.84 -636.85 MWD+IFR-AK-CAZ-SC(3) 4,069.84 62.65 259.39 2,934.59 2,886.19 -305.54 -2,210.10 6,003,480.61 385,623.85 0.76 -657.11 MWD+IFR-AK-CAZ-SC(3) 4,163.00 62.79 259.84 2,977.28 2,928.88 -320.47 -2,291.54 6,003,466.91 385,542.20 0.45 -678.00 MWD+IFR-AK-CAZ-SC(3) 4,257.78 63.06 260.90 3,020.43 2,972.03 -334.59 -2,374.74 6,003,454.04 385,458.80 1.04 -700.37 MWD+IFR-AK-CAZ-SC(3) 4,350.75 63.36 261.44 3,062.33 3,013.93 -347.32 -2,456.75 6,003,442.54 385,376.62 0.61 -723.49 MWD+IFR-AK-CAZ-SC(3) 4,444.73 63.27 261.17 3,104.53 3,056.13 -360.02 -2,539.76 6,003,431.10 385,293.44 0.27 -747.06 MWD+IFR-AK-CAZ-SC(3) 4,535.89 63.08 260.76 3,145.67 3,097.27 -372.79 -2,620.10 6,003,419.53 385,212.92 0.45 -769.44 MWD+IFR-AK-CAZ-SC(3) 4,627.50 62.67 260.71 3,187.44 3,139.04 -385,92 -2,700.57 6,003,407.61 385,132.27 0.45 -791.55 MWD+IFR-AK-CAZ-SC(3) 4,723.24 62.34 260.76 3,231.64 3,183.24 -399.59 -2,784.39 6,003,395.20 385,048.26 0.35 -814.58 MWD+IFR-AK-CAZ-SC(3) 4,816.62 62.66 260.99 3,274.76 3,226.36 -412.73 -2,866.17 6,003,383.30 384,966.30 0.41 -837.23 MWD+IFR-AK-CAZ-SC(3) 4,911.41 63.14 261.36 3,317.94 3,269.54 -425.67 -2,949.55 6,003,371.61 384,882.74 0.61 -860.74 MWD+IFR-AK-CAZ-SC(3) 5,005.65 63.42 260.99 3,360.31 3,311.91 -438.59 -3,032.73 6,003,359.95 384,799.38 0.46 -884.19 MWD+IFR-AK-CAZ-SC(3) 5,100.37 63.68 260.59 3,402.50 3,354.10 -452.16 -3,116.44 6,003,347.63 384,715.48 0.47 -907.27 MWD+IFR-AK-CAZ-SC(3) 5,193.53 63.48 260.13 3,443.95 3,395.55 -466.13 -3,198.69 6,003,334.90 384,633.04 0.49 -929.37 MWD+IFR-AK-CAZ-SC(3) 5,288.20 63.56 259.69 3,486.17 3,437.77 -480.98 -3,282.12 6,003,321.31 384,549.40 0.42 -951.17 MWD+IFR-AK-CAZ-SC(3) 5,382.42 64.24 260.39 3,527.62 3,479.22 -495.61 -3,365.46 6,003,307.93 384,465.87 0.98 -973.13 MWD+IFR-AK-CAZ-SC(3) 5,477,93 63.84 259.83 3,569.43 3,521.03 -510.36 -3,450.05 6,003,294.46 384,381.06 0.67 -995.51 MWD+IFR-AK-CAZ-SC(3) 5,572.24 63.41 258.99 3,611.32 3,562.92 -525.89 -3,533.10 6,003,280.18 384,297.79 0.92 -1,016.54 MWD+IFR-AK-CAZ-SC(3) 5,666.13 64.10 258.68 3,652.84 3,604.44 -542.19 -3,615.72 6,003,265.12 384,214.95 0.79 -1,036.68 MWD+IFR-AK-CAZ-SC(3) 5,761.79 63.90 258.40 3,694.78 3,646.38 -559.28 -3,699.99 6,003,249.31 384,130.45 0.34 -1,056.81 MWD+IFR-AK-CAZ-SC(3) 5,855.82 63.90 259.58 3,736.15 3,687.75 -575.40 -3,782.87 6,003,234.43 384,047.33 1.13 -1,077.22 MWD+IFR-AK-CAZ-SC(3) 5,950.97 63.56 258.51 3,778.26 3,729.86 -591.61 -3,866.64 6,003,219.48 383,963.34 1.07 -1,097.93 MWD+IFR-AK-CAZ-SC(3) 6,045.23 63.77 259.92 3,820.08 3,771.68 -607.42 -3,949.62 6,003,204.92 383,880.14 1.36 -1,118.67 MWD+IFR-AK-CAZ-SC(3) 6,140.84 63.43 259.12 3,862.59 3,814.19 -623.00 -4,033.83 6,003,190.62 383,795.71 0.83 -1,140.14 MWD+1FR-AK-CAZ-SC(3) 6,234.47 63.00 259.74 3,904.78 3,856.38 -638.33 -4,115.99 6,003,176.52 383,713.33 0.75 -1,160.97 MWD+IFR-AK-CAZ-SC(3) 6,329.26 62.94 259.96 3,947.86 3,899.46 -653.21 -4,199.11 6,003,162.89 383,630.01 0.22 -1,182.61 MWD+IFR-AK-CAZ-SC(3) 6,423.76 62.72 261.12 3,991.01 3,942.61 -667.03 -4,282.04 6,003,150.32 383,546.89 1.12 -1,205.13 MWD+IFR-AK-CAZ-SC(3) 6,517.93 62.89 261.19 4,034.05 3,985.65 -679.91 -4,364.80 6,003,138.69 383,463.95 0.19 -1,228.44 MWD+IFR-AK-CAZ-SC(3) 6,612.56 63.01 261.46 4,077.09 4,028.69 -692.62 -4,448.11 6,003,127.23 383,380.46 0.28 -1,252.13 MWD+IFR-AK-CAZ-SC(3) 6,707.21 62.79 260.82 4,120.20 4,071.80 -705.60 -4,531.37 6,003,115.51 383,297.03 0.65 -1,275.55 MWD+IFR-AK-CAZ-SC(3) 6,801.45 61.89 259.80 4,163.95 4,115.55 -719.64 -4,613.64 6,003,102.70 383,214.56 1.35 -1,297.59 MWD+IFR-AK-CAZ-SC(3) 6,895.58 62.05 260.17 4,208.19 4,159.79 -734.09 -4,695.47 6,003,089.48 383,132.54 0.39 -1,319.08 MWD+IFR-AK-CAZ-SC(3) 6,988.94 62.59 260.25 4,251.56 4,203.16 -748.15 -4,776.94 6,003,076.65 383,050.87 0.58 -1,340.77 MWD+IFR-AK-CAZ-SC(3) 7,084.18 63.61 259.77 4,294.65 4,246.25 -762.88 -4,860.58 6,003,063.18 382,967.02 1.16 -1,362.76 MWD+IFR-AK-CAZ-SC(3) 3/23/2012 12:28:02PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD " Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,179.67 63.64 260.45 4,337.07 4,288.67 -777.58 -4,944.86 6,003,049.75 382,882.54 0.64 -1,385.06 MWD+IFR-AK-CAZ-SC(3) 7,274.24 63.49 260.67 4,379.17 4,330.77 -791.47 -5,028.39 6,003,037.12 382,798.81 0.26 -1,407.78 MWD+IFR-AK-CAZ-SC(3) 7,368.35 63.01 259.06 4,421.53 4,373.13 -806.25 -5,111.12 6,003,023.58 382,715.88 1.61 -1,429.34 MWD+IFR-AK-CAZ-SC(3) 7,461.58 63.22 259.77 4,463.69 4,415.29 -821.53 -5,192.86 6,003,009.54 382,633.93 0.72 -1,450.04 MWD+IFR-AK-CAZ-SC(3) 7,556.95 63.35 260.16 4,506.56 4,458.16 -836.37 -5,276.74 6,002,995.96 382,549.84 0.39 -1,472.04 MWD+IFR-AK-CAZ-SC(3) 7,652.07 63.48 259.92 4,549.13 4,500.73 -851.08 -5,360.52 6,002,982.51 382,465.85 0.26 -1,494.11 MWD+IFR-AK-CAZ-SC(3) 7,745.94 63.43 260.28 4,591.08 4,542.68 -865.52 -5,443.25 6,002,969.31 382,382.93 0.35 -1,515.99 MWD+IFR-AK-CAZ-SC(3) 7,840.37 63.41 260.04 4,633.33 4,584.93 -879.95 -5,526.45 6,002,956.14 382,299.52 0.23 -1,538.07 MWD+IFR-AK-CAZ-SC(3) 7,934.48 63.47 259.88 4,675.41 4,627.01 -894.63 -5,609.34 6,002,942.71 382,216.43 0.16 -1,559.80 MWD+IFR-AK-CAZ-SC(3) 8,029.88 63.62 260.39 4,717.91 4,669.51 -909.26 -5,693.49 6,002,929.34 382,132.08 0.50 -1,582.10 MWD+IFR-AK-CAZ-SC(3) 8,125.01 63.49 260.46 4,760.28 4,711.88 -923.43 -5,777.48 6,002,916.44 382,047.89 0.15 -1,604.76 MWD+IFR-AK-CAZ-SC(3) 8,219.94 62.87 259.03 4,803.11 4,754.71 -938.51 -5,860.84 6,002,902.62 381,964.32 1.49 -1,626.32 MWD+IFR-AK-CAZ-SC(3) 8,313.67 63.36 259.64 4,845.50 4,797.10 -953.98 -5,943.00 6,002,888.38 381,881.95 0.78 -1,647.02 MWD+IFR-AK-CAZ-SC(3) 8,409.14 63.15 259.69 4,888.46 4,840.06 -969.27 -6,026.87 6,002,874.35 381,797.86 0.22 -1,668.60 MWD+IFR-AK-CAZ-SC(3) 8,501.33 62.93 259.59 4,930.26 4,881.86 -984.05 -6,107.70 6,002,860.79 381,716.83 0.26 -1,689.37 MWD+IFR-AK-CAZ-SC(3) 8,597.83 62.93 259.51 4,974.17 4,925.77 -999.64 -6,192.20 6,002,846.48 381,632.11 0.07 -1,710.96 MWD+IFR-AK-CAZ-SC(3) 8,691.83 63.15 259.84 5,016.79 4,968.39 -1,014.65 -6,274.63 6,002,832.70 381,549.47 0.39 -1,732.19 MWD+IFR-AK-CAZ-SC(3) 8,786.72 63.28 259.72 5,059.55 5,011.15 -1,029.68 -6,358.00 6,002,818.93 381,465.90 0.18 -1,753.80 MWD+IFR-AK-CAZ-SC(3) 8,881.13 63.91 260.25 5,101.54 5,053.14 -1,044.39 -6,441.27 6,002,805.48 381,382.42 0.84 -1,775.66 MWD+IFR-AK-CAZ-SC(3) 8,974.95 64.25 261.13 5,142.55 5,094.15 -1,058.04 -6,524.54 6,002,793.08 381,298.96 0.92 -1,798.48 MWD+IFR-AK-CAZ-SC(3) 9,070.43 63.97 261.68 5,184.24 5,135.84 -1,070.87 -6,609.47 6,002,781.52 381,213.85 0.60 -1,822.74 MWD+IFR-AK-CAZ-SC(3) 9,163.46 63.76 261.78 5,225.22 5,176.82 -1,082.89 -6,692.12 6,002,770.75 381,131.04 0.25 -1,846.78 MWD+IFR-AK-CAZ-SC(3) 9,257.30 63.28 261.47 5,267.06 5,218.66 -1,095.12 -6,775.22 6,002,759.77 381,047.77 0.59 -1,870.81 MWD+IFR-AK-CAZ-SC(3) 9,353.92 63.36 260.58 5,310.44 5,262.04 -1,108.59 -6,860.49 6,002,747.59 380,962.31 0.83 -1,894.65 MWD+IFR-AK-CAZ-SC(3) 9,447.18 63.21 260.08 5,352.37 5,303.97 -1,122.58 -6,942.61 6,002,734.83 380,880.00 0.51 -1,916.67 MWD+IFR-AK-CAZ-SC(3) 9,541.97 62.81 259.48 5,395.39 5,346.99 -1,137.57 -7,025.74 6,002,721.10 380,796.66 0.70 -1,938.22 MWD+IFR-AK-CAZ-SC(3) 9,636.40 63.00 259.06 5,438.40 5,390.00 -1,153.22 -7,108.33 6,002,706.69 380,713.85 0.44 -1,958.94 MWD+IFR-AK-CAZ-SC(3) 9,731.37 63.35 258.30 5,481.25 5,432.85 -1,169.86 -7,191.43 6,002,691.30 380,630.52 0.80 -1,978.98 MWD+IFR-AK-CAZ-SC(3) 9,825.81 63.49 258.21 5,523.51 5,475.11 -1,187.05 -7,274.13 6,002,675.36 380,547.58 0.17 -1,998.35 MWD+IFR-AK-CAZ-SC(3) 9,920.32 63.51 258.83 5,565.68 5,517.28 -1,203.88 -7,357.01 6,002,659.77 380,464.46 0.59 -2,018.12 MWD+IFR-AK-CAZ-SC(3) 10,014.74 63.84 260.12 5,607.55 5,559.15 -1,219.34 -7,440.21 6,002,645.57 380,381.04 1.27 -2,039.27 MWD+IFR-AK-CAZ-SC(3) 10,109.23 63.84 260.03 5,649.21 5,600.81 -1,233.96 -7,523.76 6,002,632.21 380,297.30 0.09 -2,061.33 MWD+IFR-AK-CAZ-SC(3) 10,203.46 63.56 260.31 5,690.96 5,642.56 -1,248.38 -7,606.99 6,002,619.04 380,213.86 0.40 -2,083.44 MWD+IFR-AK-CAZ-SC(3) 10,297.98 63.22 258.27 5,733.30 5,684.90 -1,264.08 -7,690.02 6,002,604.59 380,130.61 1.96 -2,104.30 MWD+IFR-AK-CAZ-SC(3) 10,392.73 62.30 254.78 5,776.68 5,728.28 -1,283.70 -7,771.93 6,002,586.21 380,048.43 3.42 -2,121.14 MWD+IFR-AK-CAZ-SC(3) 10,487.05 60.77 251.66 5,821.65 5,773.25 -1,307.61 -7,851.30 6,002,563.49 379,968.71 3.33 -2,133.00 MWD+IFR-AK-CAZ-SC(3) 10,581.34 60.63 248.32 5,867.80 5,819.40 -1,335.74 -7,928.55 6,002,536.53 379,891.05 3.09 -2,140.16 MWD+IFR-AK-CAZ-SC(3) 10,675.66 59.63 243.68 5,914.79 5,866.39 -1,368.98 -8,003.25 6,002,504.42 379,815.87 4.40 -2,141.60 MWD+IFR-AK-CAZ-SC(3) 10,770.17 58.63 238.64 5,963.31 5,914.91 -1,408.07 -8,074.28 6,002,466.40 379,744.27 4.70 -2,136.19 MWD+IFR-AK-CAZ-SC(3) 10,866.01 56.80 234.67 6,014.51 5,966.11 -1,452.57 -8,141.96 6,002,422.93 379,675.94 3.99 -2,124.46 MWD+IFR-AK-CAZ-SC(3) 3/23/2012 12:28:02PM Page 5 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production .,rya rM.4M M,•w^ „,r,d =g- Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (it) 0100') (ft) Survey Tool Name 10,960.39 56.12 230.93 6,066.67 6,018.27 -1,500.11 -8,204.60 6,002,376.34 379,612.59 3.38 -2,107.85 MWD+IFR-AK-CAZ-SC(3) 11,055.50 57.02 227.78 6,119.08 6,070.68 -1,551.81 -8,264.81 6,002,325.55 379,551.62 2.92 -2,086.44 MWD+IFR-AK-CAZ-SC(3) 11,150.12 57.84 223.75 6,170.03 6,121.63 -1,607.43 -8,321.91 6,002,270.80 379,493.69 3.69 -2,060.17 MWD+IFR-AK-CAZ-SC(3) 11,244.60 59.28 219.35 6,219.33 6,170.93 -1,667.75 -8,375.34 6,002,211.30 379,439.37 4.26 -2,028.08 MWD+IFR-AK-CAZ-SC(3) 11,339.05 59.06 215.13 6,267.75 6,219.35 -1,732.29 -8,424.41 6,002,147.51 379,389.34 3.84 -1,990.32 MWD+IFR-AK-CAZ-SC(3) 11,432.57 59.18 211.21 6,315.76 6,267.36 -1,799.45 -8,468.30 6,002,081.02 379,344.44 3.60 -1,948.00 MWD+IFR-AK-CAZ-SC(3) I 11,527.59 59.49 209.14 6,364.22 6,315.82 -1,870.11 -8,509.38 6,002,010.99 379,302.31 1.90 -1,901.33 MWD+IFR-AK-CAZ-SC(3) 11,621.98 61.41 204.81 6,410.79 6,362.39 -1,943.27 -8,546.59 6,001,938.40 379,264.01 4.48 -1,850.74 MWD+IFR-AK-CAZ-SC(3) 11,717.12 61.18 201.57 6,456.50 6,408.10 -2,019.96 -8,579.44 6,001,862.22 379,230.01 3.00 -1,795.13 MWD+IFR-AK-CAZ-SC(3) 11,811.39 61.12 197.34 6,502.00 6,453.60 -2,097.79 -8,606.94 6,001,784.82 379,201.36 3.93 -1,736.21 MWD+IFR-AK-CAZ-SC(3) 11,906.13 61.41 195.24 6,547.55 6,499.15 -2,177.52 -8,630.23 6,001,705.46 379,176.86 1.97 -1,673.79 MWD+IFR-AK-CAZ-SC(3) 12,000.10 60.34 194.59 6,593.29 6,544.89 -2,256.84 -8,651.36 6,001,626.47 379,154.55 1.29 -1,610.83 MWD+IFR-AK-CAZ-SC(3) 12,094.88 60.86 194.95 6,639.81 6,591.41 -2,336.68 -8,672.42 6,001,546.96 379,132.30 0.64 -1,547.37 MWD+IFR-AK-CAZ-SC(3) 12,189.14 61,20 195.25 6,685.47 6,637.07 -2,416.30 -8,693.90 6,001,467.68 379,109.62 0.46 -1,484.29 MWD+IFR-AK-CAZ-SC(3) 12,284.04 60.26 194.76 6,731.87 6,683.47 -2,496.26 -8,715.33 6,001,388.06 379,086.99 1.09 -1,420.88 MWD+IFR-AK-CAZ-SC(3) 12,378.29 61.12 194.55 6,778.01 6,729.61 -2,575.77 -8,736.12 6,001,308.87 379,065.01 0.93 -1,357.60 MWD+IFR-AK-CAZ-SC(3) 12,472.59 62.23 195.81 6,822.75 6,774.35 -2,655.88 -8,757.86 6,001,229.11 379,042.07 1.66 -1,294.19 MWD+IFR-AK-CAZ-SC(3) 12,522.26 63.84 195.78 6,845.27 6,796.87 -2,698.48 -8,769.91 6,001,186.70 379,029.38 3.24 -1,260.68 MWD+IFR-AK-CAZ-SC(3) 12,567.21 65.41 194.92 6,864.53 6,816.13 -2,737.64 -8,780.66 6,001,147.71 379,018.05 3.90 -1,229.72 MWD+IFR-AK-CAZ-SC(3) 12,612.80 66.81 192.93 6,883.00 6,834.60 -2,778.10 -8,790.69 6,001,107.41 379,007.42 5.04 -1,197.30 MWD+IFR-AK-CAZ-SC(3) 12,661.68 69.43 191.69 6,901.21 6,852.81 -2,822.41 -8,800.35 6,001,063.25 378,997.09 5.85 -1,161.22 MWD+IFR-AK-CAZSC(3) 12,710.99 71.63 190.00 6,917.65 6,869.25 -2,868.06 -8,809.10 6,001,017.74 378,987.66 5.51 -1,123.54 MWD+IFR-AK-CAZ-SC(3) 12,756.30 73.83 187.69 6,931.10 6,882.70 -2,910.81 -8,815.74 6,000,975.10 378,980.38 6.88 -1,087.60 MWD+IFR-AK-CAZ-SC(3) 12,802.74 75.57 186.68 6,943.35 6,894.95 -2,955.25 -8,821.34 6,000,930.75 378,974.11 4.29 -1,049.69 MWD+IFR-AK-CAZ-SC(3) 12,850.76 77.59 184.32 6,954.50 6,906.10 -3,001.74 -8,825.82 6,000,884.34 378,968.94 6.37 -1,009.45 MWD+IFR-AK-CAZ-SC(3) 12,903.27 79.48 182.55 6,964.94 6,916.54 -3,053.11 -8,828.90 6,000,833.03 378,965.09 4.89 -964.20 MWD+IFR-AK-CAZ-SC(3) 12,945.65 81.74 181.38 6,971.85 6,923.45 -3,094.89 -8,830.33 6,000,791.27 378,963.03 5.99 -926.94 MWD+IFR-AK-CAZ-SC(3) 12,975.44 81.92 181.50 6,976.09 6,927.69 -3,124.37 -8,831.07 6,000,761.81 378,961.84 0.72 -900.53 MWD+IFR-AK-CAZ-SC(3) 13,029.53 84.06 181.42 6,982.69 6,934.29 -3,178.03 -8,832.44 6,000,708.18 378,959.67 3.96 -852.47 MWD+IFR-AK-CAZ-SC(4) l 13,128.34 87.54 182.18 6,989.92 6,941.52 -3,276.51 -8,835.53 6,000,609.77 378,955.09 3.60 -764.53 MWD+IFR-AK-CAZ-SC(4) 13,221.62 90.32 181.04 6,991.66 6,943.26 -3,369.73 -8,838.15 6,000,516.61 378,951.07 3.22 -681.15 MWD+IFR-AK-CAZ-SC(4) 13,319.56 89.99 177.66 6,991.40 6,943.00 -3,467.65 -8,837.04 6,000,418.69 378,950.71 3.47 -591.94 MWD+IFR-AK-CAZ-SC(4) 13,414.61 90.00 171.26 6,991.41 6,943.01 -3,562.21 -8,827.87 6,000,324.02 378,958.46 6.73 -502.36 MWD+IFR-AK-CAZ-SC(4) 13,509.13 89.69 168.73 6,991.66 6,943.26 -3,655.28 -8,811.45 6,000,230.71 378,973.48 2.70 -411.07 MWD+IFR-AK-CAZ-SC(4) 13,606.64 88.32 165.19 6,993.36 6,944.96 -3,750.24 -8,789.46 6,000,135.44 378,994.04 3.89 -315.71 MWD+IFR-AK-CAZ-SC(4) 13,701.05 88.58 160.18 6,995.91 6,947.51 -3,840.31 -8,761.38 6,000,044.96 379,020.76 5.31 -222.21 MWD+IFR-AK-CAZ-SC(4) 13,753.81 88.45 157.61 6,997.28 6,948.88 -3,889.51 -8,742.39 5,999,995.49 379,039.01 4.88 -169.60 MWD+IFR-AK-CAZ-SC(4) 13,796.77 88.58 155.69 6,998.39 6,949.99 -3,928.94 -8,725.37 5,999,955.81 379,055.44 4.48 -126.67 MWD+IFR-AK-CAZSC(4) 13,892.25 88.39 152.87 7,000.92 6,952.52 -4,014.92 -8,683.95 5,999,869.23 379,095.55 2.96 -31.24 MWD+IFR-AK-CAZ-SC(4) 13,987.69 88.76 149.13 7,003.29 6,954.89 -4,098.35 -8,637.70 5,999,785.12 379,140.54 3.94 63.92 MWD+IFR-AK-CAZ-SC(4) 3/23/2012 12:28:02PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (11001 (ft) Survey Tool Name 14,082.08 89.75 145.99 7,004.52 6,956.12 -4,178.00 -8,587.08 5,999,704.73 379,189.95 3.49 157.49 MWD+IFR-AK-CAZ-SC(4) 14,178.63 88.51 142.63 7,005.99 6,957.59 -4,256.39 -8,530.77 5,999,625.50 379,245.08 3.71 252.34 MWD+IFR-AK-CAZ-SC(4) 14,272.65 88.82 140.48 7,008.18 6,959.78 -4,330.01 -8,472.33 5,999,551.03 379,302.40 2.31 343.76 MWD+IFR-AK-CAZ-SC(4) 14,368.15 88.26 142.14 7,010.61 6,962.21 -4,404.52 -8,412.66 5,999,475.63 379,360.94 1.83 436.51 MWD+IFR-AK-CAZ-SC(4) 14,463.49 89.01 144.06 7,012.88 6,964.48 -4,480.74 -8,355.43 5,999,398.57 379,417.01 2.16 529.77 MWD+IFR-AK-CAZ-SC(4) 14,557.71 89.63 144.09 7,014.00 6,965.60 -4,557.03 -8,300.15 5,999,321.46 379,471.13 0.66 622.27 MWD+IFR-AK-CAZ-SC(4) 14,654.02 90.31 141.61 7,014.05 6,965.65 -4,633.79 -8,242.00 5,999,243.85 379,528.12 2.67 716.42 MWD+IFR-AK-CAZ-SC(4) 14,750.48 89.43 140.29 7,014.27 6,965.87 -4,708.69 -8,181.23 5,999,168.04 379,587.75 1.64 809.99 MWD+IFR-AK-CAZ-SC(4) 14,845.21 89.38 141.13 7,015.25 6,966.85 -4,782.01 -8,121.25 5,999,093.84 379,646.62 0.89 901.78 MWD+IFR-AK-CAZ-SC(4) 14,941.01 90.19 141.28 7,015.61 6,967.21 -4,856.67 -8,061.22 5,999,018.29 379,705.51 0.86 994.82 MWD+IFR-AK-CAZ-SC(4) 14,991.60 89.68 141.62 7,015.67 6,967.27 -4,896.24 -8,029.70 5,998,978.26 379,736.44 1.21 1,044.00 MWD+IFR-AK-CAZ-SC(4) 15,035.95 90.31 142.03 7,015.67 6,967.27 -4,931.10 -8,002.29 5,998,942.99 379,763.32 1.69 1,087.18 MWD+IFR-AK-CAZ-SC(4) 15,132.00 89.56 142.54 7,015.78 6,967.38 -5,007.08 -7,943.53 5,998,866.14 379,820.92 0.94 1,180.88 MWD+IFR-AK-CAZ-SC(4) 15,226.60 89.69 144.35 7,016.40 6,968.00 -5,083.07 -7,887.19 5,998,789.32 379,876.11 1.92 1,273.55 MWD+IFR-AK-CAZ-SC(4) 15,322.37 89.25 143.50 7,017.29 6,968.89 -5,160.47 -7,830.80 5,998,711.09 379,931.32 1.00 1,367.53 MWD+IFR-AK-CAZ-SC(4) 15,417.57 89.25 141.86 7,018.53 6,970.13 -5,236.17 -7,773.09 5,998,634.54 379,987.89 1.72 1,460.53 MWD+IFR-AK-CAZ-SC(4) 15,512.34 88.57 143.86 7,020.34 6,971.94 -5,311.70 -7,715.88 5,998,558.16 380,043.95 2.23 1,553.16 MWD+IFR-AK-CAZ-SC(4) 15,608.00 89.69 144.19 7,021.79 6,973.39 -5,389.10 -7,659.70 5,998,479.93 380,098.96 1.22 1,647.06 MWD+IFR-AK-CAZ-SC(4) 15,704.39 88.57 146.07 7,023.25 6,974.85 -5,468.17 -7,604.60 5,998,400.05 380,152.86 2.27 1,742.00 MWD+IFR-AK-CAZ-SC(4) 15,799.66 90.56 146.49 7,023.98 6,975.58 -5,547.41 -7,551.72 5,998,320.04 380,204.54 2.13 1,836.16 MWD+IFR-AK-CAZ-SC(4) 15,895.28 89.93 144.04 7,023.57 6,975.17 -5,625.98 -7,497.24 5,998,240.66 380,257.83 2.65 1,930.40 MWD+IFR-AK-CAZ-SC(4) 15,990.62 90.43 142.72 7,023.27 6,974.87 -5,702.50 -7,440.37 5,998,163.30 380,313.53 1.48 2,023.78 MWD+IFR-AK-CAZ-SC(4) 16,085.21 88.56 140.90 7,024.10 6,975.70 -5,776.83 -7,381.89 5,998,088.10 380,370.88 2.76 2,115.87 MWD+IFR-AK-CAZ-SC(4) 16,180.25 88.26 140.57 7,026.74 6,978.34 -5,850.39 -7,321.77 5,998,013.66 380,429.89 0.47 2,207.94 MWD+IFR-AK-CAZ-SC(4) 16,275.54 88.83 143.44 7,029.16 6,980.76 -5,925.45 -7,263.13 5,997,937.73 380,487.39 3.07 2,300.75 MWD+IFR-AK-CAZ-SC(4) 16,370.55 87.89 144.21 7,031.88 6,983.48 -6,002.11 -7,207.08 5,997,860.24 380,542.28 1.28 2,393.92 MWD+IFR-AK-CAZ-SC(4) 16,466.46 88.27 143.67 7,035.09 6,986.69 -6,079.60 -7,150.65 5,997,781.92 380,597.53 0.69 2,487.99 MWD+IFR-AK-CAZ-SC(4) 16,561.28 87.77 144.58 7,038.37 6,989.97 -6,156.39 -7,095.12 5,997,704.32 380,651.90 1.09 2,581.05 MWD+IFR-AK-CAZ-SC(4) 16,656.75 89.26 145.69 7,040.84 6,992.44 -6,234.69 -7,040.57 5,997,625.21 380,705.26 1.95 2,675.08 MWD+IFR-AK-CAZ-SC(4) 16,751.76 89.56 145.28 7,041.82 6,993.42 -6,312.97 -6,986.73 5,997,546.14 380,757.91 0.53 2,768.77 MWD+IFR-AK-CAZ-SC(4) 16,847.59 89.31 145.15 7,042.76 6,994.36 -6,391.67 -6,932.07 5,997,466.63 380,811.38 0.29 2,863.20 MWD+IFR-AK-CAZ-SC(4) 16,941.44 90.00 145.16 7,043.33 6,994.93 -6,468.69 -6,878.45 5,997,388.82 380,863.84 0.74 2,955.67 MWD+IFR-AK-CAZ-SC(4) 17,038.65 89.31 145.89 7,043.92 6,995.52 -6,548.83 -6,823.42 5,997,307.87 380,917.64 1.03 3,051.55 MWD+IFR-AK-CAZ-SC(4) 17,134.41 90.06 145.69 7,044.44 6,996.04 -6,628.02 -6,769.58 5,997,227.89 380,970.28 0.81 3,146.07 MWD+IFR-AK-CAZ-SC(4) 17,229.39 90.74 144.48 7,043.78 6,995.38 -6,705.90 -6,715.22 5,997,149.21 381,023.46 1.46 3,239.63 MWD+IFR-AK-CAZ-SC(4) 17,325.09 89.06 142.06 7,043.95 6,995.55 -6,782.59 -6,658.00 5,997,071.67 381,079.52 3.08 3,333.32 MWD+IFR-AK-CAZ-SC(4) 17,420.52 89.19 141.67 7,045.40 6,997.00 -6,857.64 -6,599.07 5,996,995.75 381,137.31 0.43 3,426.24 MWD+IFR-AK-CAZ-SC(4) 17,514.36 89.81 142.21 7,046.22 6,997.82 -6,931.52 -6,541.23 5,996,921.01 381,194.03 0.88 3,517.65 MWD+IFR-AK-CAZ-SC(4) 17,609.41 88.44 143.29 7,047.67 6,999.27 -7,007.17 -6,483.70 5,996,844.51 381,250.41 1.84 3,610.52 MWD+IFR-AK-CAZ-SC(4) 17,703.60 89.94 145.12 7,049.01 7,000.61 -7,083.56 -6,428.62 5,996,767.32 381,304.33 2.51 3,703.03 MWD+IFR-AK-CAZ-SC(4) 3/23/2012 12:28:02PM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12,6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (11001 (ft) Survey Tool Name 17,801.00 90.06 145.81 7,049.01 7,000.61 -7,163.79 -6,373.40 5,996,686.27 381,358.33 0.72 3,799.09 MWD+IFR-AK-CAZ-SC(4) 17,896.18 89.81 145.88 7,049.11 7,000.71 -7,242.56 -6,319.97 5,996,606.72 381,410.58 0.27 3,893.05 MWD+IFR-AK-CAZ-SC(4) 17,991.92 90.06 146.39 7,049.22 7,000.82 -7,322.06 -6,266.62 5,996,526.43 381,462.72 0.59 3,987.65 MWD+IFR-AK-CAZ-SC(4) 18,087.23 89.81 147.93 7,049.33 7,000.93 -7,402.13 -6,214.93 5,996,445.60 381,513.19 1.64 4,082.06 MWD+IFR-AK-CAZ-SC(4) 18,182.64 88.88 143.45 7,050.42 7,002.02 -7,480.91 -6,161.17 5,996,366.02 381,565.76 4.80 4,176.19 MWD+IFR-AK-CAZ-SC(4) 18,277.44 88.01 143.54 7,052.99 7,004.59 -7,557.09 -6,104.80 5,996,289.02 381,620.98 0.92 4,269.05 MWD+IFR-AK-CAZ-SC(4) 18,373.88 87.58 143.93 7,056.70 7,008.30 -7,634.79 -6,047.79 5,996,210.48 381,676.80 0.60 4,363.56 MWD+IFR-AK-CAZ-SC(4) 18,469.04 89.45 144.24 7,059.17 7,010.77 -7,711.83 -5,992.00 5,996,132.61 381,731.43 1.99 4,456.96 MWD+IFR-AK-CAZ-SC(4) 18,564.81 88.88 144.74 7,060.57 7,012.17 -7,789.78 -5,936.37 5,996,053.84 381,785.87 0.79 4,551.11 MWD+IFR-AK-CAZ-SC(4) 18,659.04 89.75 145.05 7,061.69 7,013.29 -7,866.86 -5,882.19 5,995,975.96 381,838.89 0.98 4,643.87 MWD+IFR-AK-CAZ-SC(4) 18,754.34 88.88 141.77 7,062.83 7,014.43 -7,943.36 -5,825.39 5,995,898.62 381,894.52 3.56 4,737.21 MWD+IFR-AK-CAZ-SC(4) 18,848.80 87.70 141.24 7,065.65 7,017.25 -8,017.26 -5,766.63 5,995,823.86 381,952.17 1.37 4,829.02 MWD+IFR-AK-CAZ-SC(4) 18,943,50 87.21 142.84 7,069.86 7,021.46 -8,091.85 -5,708.43 5,995,748.41 382,009.23 1.77 4,921.21 MWD+IFR-AK-CAZ-SC(4) 19,039.75 88.40 144.33 7,073.54 7,025.14 -8,169.24 -5,651.34 5,995,670.17 382,065,15 1.98 5,015.49 MWD+IFR-AK-CAZ-SC(4) 19,135.46 90.44 145.86 7,074.51 7,026.11 -8,247.72 -5,596.58 5,995,590.88 382,118.72 2.66 5,109.76 MWD+IFR-AK-CAZ-SC(4) 19,230.70 91.79 145.85 7,072.66 7,024.26 -8,326.53 -5,543.14 5,995,511.29 382,170.97 1.42 5,203.77 MWD+IFR-AK-CAZ-SC(4) 19,326.21 90.30 143.66 7,070.92 7,022.52 -8,404.51 -5,488.03 5,995,432.49 382,224.89 2.77 5,297.73 MWD+IFR-AK-CAZ-SC(4) 19,421.64 90.43 141.27 7,070.31 7,021.91 -8,480.18 -5,429.90 5,995,355.97 382,281.87 2.51 5,390.88 MWD+IFR-AK-CAZ-SC(4) 19,517.32 89.37 140.93 7,070.48 7,022.08 -8,554.64 -5,369.82 5,995,280.62 382,340.83 1.16 5,483.75 MWD+IFR-AK-CAZ-SC(4) 19,612.36 89.32 142.18 7,071.56 7,023.16 -8,629.07 -5,310.73 5,995,205.32 382,398.78 1.32 5,576.18 MWD+IFR-AK-CAZ-SC(4) 19,710.70 90.31 142.94 7,071.88 7,023.48 -8,707.15 -5,250.95 5,995,126.36 382,457.38 1.27 5,672.21 MWD+IFR-AK-CAZ-SC(4) 19,804.02 89.37 143.52 7,072.14 7,023.74 -8,781.90 -5,195.09 5,995,050.78 382,512.11 1.18 5,763.57 MWD+IFR-AK-CAZ-SC(4) 19,899.73 89.63 144.29 7,072.97 7,024.57 -8,859.23 -5,138.70 5,994,972.61 382,567.32 0.85 5,857.48 MWD+IFR-AK-CAZ-SC(4) 19,994.92 88.69 146.02 7,074.37 7,025.97 -8,937.34 -5,084.32 5,994,893.70 382,620.51 2.07 5,951.26 MWD+IFR-AK-CAZ-SC(4) 20,091.32 88.64 145.02 7,076.62 7,028.22 -9,016.79 -5,029.77 5,994,813.46 382,673.86 1.04 6,046.31 MWD+IFR-AK-CAZ-SC(4) 20,186.53 88,14 145.48 7,079.29 7,030.89 -9,094.98 -4,975.52 5,994,734.46 382,726.93 0.71 6,140.11 MWD+IFR-AK-CAZ-SC(4) 20,282.36 89.39 147.25 7,081.36 7,032.96 -9,174.75 -4,922.45 5,994,653.91 382,778.78 2.26 6,234.83 MWD+IFR-AK-CAZ-SC(4) 20,353.07 89.25 146.34 7,082.20 7,033.80 -9,233.91 -4,883.73 5,994,594.18 382,816.61 1.30 6,304.81 MWD+IFR-AK-CAZ-SC(4) 20,387.00 89.25 146.34 7,082.64 7,034.24 -9,262.15 -4,864.93 5,994,565.67 382,834.98 0.00 6,338.35 PROJECTED to TD 3/23/2012 12:28:02PM Page 8 COMPASS 2003.16 Build 69 ConocoPhillips(Alaska) Inc. OP Western North Slope CD3 Fiord Pad CD3-128 501032063800 Sperry Definitive Survey Report 20 February, 2012 RECEIVED MAR 2 3 2012 Alaska Oil&Gas Cons. Commission An,:tercge Amos= HALLIBURTON Sperry Drilling III a ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: ='CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3-128 Well Position +N/-S 0.00 ft Northing: 6,003,752.89 ft - Latitude: 70°25'9.068 N +E/-W 0.00 ft Easting: 387,838.10 ft - Longitude: 150°54'49.392 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60 ft Wellbore CD3-128 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2011 2/1/2012 20.21 80.87 57,613 Design CD3-128 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,975.44 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 35.80 0.00 0.00 207.71 Survey Program Date 2/20/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 79.00 1,100.00 CD3-128PB1 Gyro(R100)(CD3-128PB1 CB-GYRO-SS Camera based gyro single shot 4/12/2011 12:C 1,148.28 2,946.82 CD3-128PB1 MWD(R300)(CD3-128PB MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/12/2011 12:C 3,045.13 12,975.44 CD3-128PB1 MWD(R400)(CD3-128PB MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/16/2011 12:C 13,029.53 20,353.07 CD3-128(R700)(CD3-128) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/20/2012 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 35.80 0.00 0.00 35.80 -12.60 0.00 0.00 6,003,752.89 387,838.10 0.00 0.00 UNDEFINED 79.00 0.05 284.95 79.00 30.60 0.00 -0.02 6,003,752.89 387,838.08 0.12 0.00 CB-GYRO-SS(1) 170.00 0.37 6.10 170.00 121.60 0.31 -0.03 6,003,753.19 387,838.08 0.40 -0.26 CB-GYRO-SS(1) 263.00 0.45 8.32 263.00 214.60 0.97 0.06 6,003,753.85 387,838.17 0.09 -0.88 CB-GYRO-SS(1) 291.00 0.44 358.14 291.00 242.60 1.18 0.07 6,003,754.07 387,838.19 0.28 -1.08 CB-GYRO-SS(1) 321.00 0.52 5.76 321.00 272.60 1.43 0.08 6,003,754.32 387,838.20 0.34 -1.31 CB-GYRO-SS(1) 351.00 0.57 357.16 350.99 302.59 1.72 0.09 6,003,754.60 387,838.21 0.32 -1.56 CB-GYRO-SS(1) 355.00 0.72 12.68 354.99 306.59 1.76 0.09 6,003,754.65 387,838.22 5.72 -1.60 CB-GYRO-SS(1) 381.00 0.67 4.70 380.99 332.59 2.07 0.14 6,003,754.96 387,838.27 0.42 -1.90 CB-GYRO-SS(1) 411.00 0.73 346.99 410.99 362.59 2.43 0.11 6,003,755.32 387,838.25 0.75 -2.21 CB-GYRO-SS(1) 441.00 0.95 336.11 440.99 392.59 2.85 -0.03 6,003,755.73 387,838.11 0.90 -2.51 CB-GYRO-SS(1) 2/20/2012 10:56:57AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical ' MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 448.00 1.19 338.52 447.98 399.58 2.97 -0.08 6,003,755.86 387,838.06 3.49 -2.59 CB-GYRO-SS(1) 471.00 1.46 322.24 470.98 422.58 3.42 -0.35 6,003,756.31 387,837.80 2.00 -2.87 CB-GYRO-SS(1) 479.00 1.55 323.18 478.98 430.58 3.59 -0.48 6,003,756.48 387,837.68 1.17 -2.96 CB-GYRO-SS(1) 486.00 1.80 316.66 485.97 437.57 3.75 -0.61 6,003,756.64 387,837.55 4.49 -3.03 CB-GYRO-SS(1) 501.00 1.83 314.59 500.97 452.57 4.09 -0.94 6,003,756.98 387,837.22 0.48 -3.18 CB-GYRO-SS(1) 516.00 1.98 313.17 515.96 467.56 4.43 -1.30 6,003,757.34 387,836.87 1.05 -3.32 CB-GYRO-SS(1) 531.00 2.24 309.79 530.95 482.55 4.80 -1.71 6,003,757.71 387,836.46 1.92 -3.45 CB-GYRO-SS(1) 540.00 2.71 308.40 539.94 491.54 5.04 -2.02 6,003,757.96 387,836.16 5.26 -3.52 CB-GYRO-SS(1) 546.00 2.45 308.72 545.93 497.53 5.21 -2.23 6,003,758.13 387,835.95 4.34 -3.58 CB-GYRO-SS(1) 561.00 2.60 311.20 560.92 512.52 5.63 -2.73 6,003,758.56 387,835.45 1.24 -3.72 CB-GYRO-SS(1) 633.00 4.82 294.43 632.76 584.36 7.96 -6.72 6,003,760.95 387,831.50 3.40 -3.92 CB-GYRO-SS(1) 724.00 5.67 284.50 723.38 674.98 10.67 -14.55 6,003,763.77 387,823.71 1.36 -2.68 CB-GYRO-SS(1) 815.00 6.27 282.47 813.89 765.49 12.87 -23.75 6,003,766.11 387,814.54 0.70 -0.34 CB-GYRO-SS(1) 909.00 8.07 284.86 907.15 858.75 15.67 -35.14 6,003,769.08 387,803.20 1.94 2.47 CB-GYRO-SS(1) 1,004.00 11.26 289.11 1,000.79 952.39 20.41 -50.36 6,003,774.05 387,788.06 3.44 5.34 CB-GYRO-SS(1) 1,100.00 11.43 287.01 1,094.92 1,046.52 26.27 -68.31 6,003,780.17 387,770.20 0.47 8.51 CB-GYRO-SS(1) 1,148.28 12.53 285.03 1,142.15 1,093.75 29.02 -77.94 6,003,783.07 387,760.61 2.43 10.55 MWD+IFR-AK-CAZ-SC(2) 1,245.64 14.20 278.60 1,236.87 1,188.47 33.55 -99.95 6,003,787.93 387,738.67 2.29 16.78 MWD+IFR-AK-CAZ-SC(2) 1,339.98 18.95 274.82 1,327.27 1,278.87 36.57 -126.67 6,003,791.35 387,712.00 5.16 26.53 MWD+IFR-AK-CAZ-SC(2) 1,434.36 22.98 272.49 1,415.38 1,366.98 38.66 -160.36 6,003,793.94 387,678.35 4.36 40.35 MWD+IFR-AK-CAZ-SC(2) 1,528.94 26.95 267.63 1,501.12 1,452.72 38.57 -200.24 6,003,794.46 387,638.47 4.72 58.97 MWD+IFR-AK-CAZ-SC(2) 1,623.32 30.89 266.80 1,583.71 1,535.31 36.33 -245.82 6,003,792.91 387,592.87 4.20 82.14 MWD+IFR-AK-CAZ-SC(2) 1,717.75 34.05 264.21 1,663.37 1,614.97 32.31 -296.34 6,003,789.64 387,542.30 3.66 109.19 MWD+IFR-AK-CAZ-SC(2) 1,810.86 37.07 263.42 1,739.11 1,690.71 26.47 -350.16 6,003,784.61 387,488.40 3.28 139.40 MWD+IFR-AK-CAZ-SC(2) 1,907.24 38.24 261.27 1,815.42 1,767.02 18.61 -408.51 6,003,777.63 387,429.95 1.82 173.48 MWD+IFR-AK-CAZ-SC(2) 2,001.83 41.08 258.23 1,888.24 1,839.84 7.82 -467.88 6,003,767.74 387,370.42 3.64 210.64 MWD+IFR-AK-CAZ-SC(2) 2,096.83 45.21 257.78 1,957.54 1,909.14 -5.68 -531.42 6,003,755.19 387,306.70 4.36 252.14 MWD+IFR-AK-CAZ-SC(2) 2,191.22 48.45 258.55 2,022.11 1,973.71 -19.79 -598.79 6,003,742.10 387,239.13 3.48 295.96 MWD+IFR-AK-CAZ-SC(2) 2,285.65 51.30 259.96 2,082.96 2,034.56 -33.23 -669.72 6,003,729.72 387,168.01 3.23 340.84 MWD+IFR-AK-CAZ-SC(2) I 2,380.02 53.97 262.48 2,140.23 2,091.83 -44.65 -743.83 6,003,719.42 387,093.75 3.54 385.41 MWD+IFR-AK-CAZ-SC(2) 2,474.81 56.88 262.15 2,194.02 2,145.62 -55.09 -821.17 6,003,710.15 387,016.27 3.08 430.62 MWD+IFR-AK-CAZ-SC(2) 2,566.43 58.46 262.76 2,243.01 2,194.61 -65.25 -897.91 6,003,701.14 386,939.38 1.81 475.30 MWD+IFR-AK-CAZ-SC(2) 2,663.51 58.56 260.62 2,293.73 2,245.33 -77.21 -979.82 6,003,690.41 386,857.31 1.88 523.98 MWD+IFR-AK-CAZ-SC(2) 2,757.77 59.89 259.61 2,341.96 2,293.56 -91.12 -1,059.60 6,003,677.70 386,777.34 1.68 573.39 MWD+IFR-AK-CAZ-SC(2) 2,852.26 61.24 259.06 2,388.39 2,339.99 -106.35 -1,140.47 6,003,663.69 386,696.26 1.52 624.48 MWD+IFR-AK-CAZ-SC(2) 2,946.82 63.44 258.90 2,432.29 2,383.89 -122.36 -1,222.67 6,003,648.92 386,613.83 2.33 676.88 MWD+IFR-AK-CAZ-SC(2) 3,045.13 63.69 259.67 2,476.05 2,427.65 -138.73 -1,309.17 6,003,633.85 386,527.11 0.75 731.59 MWD+IFR-AK-CAZ-SC(3) 3,136.78 63.00 258.90 2,517.17 2,468.77 -153.95 -1,389.65 6,003,619.84 386,446.41 1.06 782.49 MWD+IFR-AK-CAZ-SC(3) 3,232.89 62.27 258.45 2,561.35 2,512.95 -170.72 -1,473.34 6,003,604.34 386,362.49 0.87 836.25 MWD+IFR-AK-CAZ-SC(3) 3,325.63 62.10 258.77 2,604.62 2,556.22 -186.91 -1,553.75 6,003,589.35 386,281.85 0.36 887.98 MWD+IFR-AK-CAZ-SC(3) 2/20/2012 10:56:57AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/1001 (ft) Survey Tool Name 3,418.05 64.04 259.61 2,646.48 2,598.08 -202.36 -1,634.68 6,003,575.12 386,200.70 2.25 939.29 MWD+IFR-AK-CAZ-SC(3) 3,512.48 64.26 258.77 2,687.65 2,639.25 -218.30 -1,718.15 6,003,560.44 386,117.01 0.83 992.22 MWD+IFR-AK-CAZ-SC(3) 3,606.46 64.25 259.59 2,728.47 2,680.07 -234.19 -1,801.30 6,003,545.80 386,033.64 0.79 1,044.95 MWD+IFR-AK-CAZ-SC(3) 3,700.00 64.40 260.06 2,769.00 2,720.60 -249.08 -1,884.28 6,003,532.16 385,950.45 0.48 1,096.72 MWD+IFR-AK-CAZ-SC(3) 3,792.75 63.78 260.01 2,809.53 2,761.13 -263.52 -1,966.44 6,003,518.96 385,868.09 0.67 1,147.71 MWD+IFR-AK-CAZ-SC(3) 3,887.38 63.28 260.87 2,851.71 2,803.31 -277.59 -2,049.98 6,003,506.15 385,784.36 0.97 1,199.00 MWD+IFR-AK-CAZ-SC(3) 3,980.21 63.00 260.05 2,893.65 2,845.25 -291.32 -2,131.64 6,003,493.65 385,702.50 0.84 1,249.13 MWD+IFR-AK-CAZ-SC(3) 4,069.84 62.65 259.39 2,934.59 2,886.19 -305.54 -2,210.10 6,003,480.61 385,623.85 0.76 1,298.21 MWD+IFR-AK-CAZ-SC(3) 4,163.00 62.79 259.84 2,977.28 2,928.88 -320.47 -2,291.54 6,003,466.91 385,542.20 0.45 1,349.30 MWD+IFR-AK-CAZ-SC(3) 4,257.78 63.06 260.90 3,020.43 2,972.03 -334.59 -2,374.74 6,003,454.04 385,458.80 1.04 1,400.48 MWD+IFR-AK-CAZ-SC(3) 4,350.75 63.36 261.44 3,062.33 3,013.93 -347.32 -2,456.75 6,003,442.54 385,376.62 0.61 1,449.89 MWD+IFR-AK-CAZ-SC(3) 4,444.73 63.27 261.17 3,104.53 3,056.13 -360.02 -2,539.76 6,003,431.10 385,293.44 0.27 1,499.73 MWD+IFR-AK-CAZ-SC(3) 4,535.89 63.08 260.76 3,145.67 3,097.27 -372.79 -2,620.10 6,003,419.53 385,212.92 0.45 1,548.40 MWD+IFR-AK-CAZ-SC(3) 4,627.50 62.67 260.71 3,187.44 3,139.04 -385.92 -2,700.57 6,003,407.61 385,132.27 0.45 1,597.44 MWD+IFR-AK-CAZ-SC(3) 4,723.24 62.34 260.76 3,231.64 3,183.24 -399.59 -2,784.39 6,003,395.20 385,048.26 0.35 1,648.52 MWD+IFR-AK-CAZ-SC(3) 4,816.62 62.66 260.99 3,274.76 3,226.36 -412.73 -2,866.17 6,003,383.30 384,966.30 0.41 1,698.18 MWD+IFR-AK-CAZ-SC(3) 4,911.41 63.14 261.36 3,317.94 3,269.54 -425.67 -2,949.55 6,003,371.61 384,882.74 0.61 1,748.41 MWD+IFR-AK-CAZ-SC(3) 5,005.65 63.42 260.99 3,360.31 3,311.91 -438.59 -3,032.73 6,003,359.95 384,799.38 0.46 1,798.52 MWD+IFR-AK-CAZ-SC(3) 5,100.37 63.68 260.59 3,402.50 3,354.10 -452.16 -3,116.44 6,003,347.63 384,715.48 0.47 1,849.47 MWD+IFR-AK-CAZ-SC(3) 5,193.53 63.48 260.13 3,443.95 3,395.55 -466.13 -3,198.69 6,003,334.90 384,633.04 0.49 1,900.08 MWD+IFR-AK-CAZ-SC(3) 5,288.20 63.56 259.69 3,486.17 3,437.77 -480.98 -3,282.12 6,003,321.31 384,549.40 0.42 1,952.02 MWD+IFR-AK-CAZ-SC(3) 5,382.42 64.24 260.39 3,527.62 3,479.22 -495.61 -3,365.46 6,003,307.93 384,465.87 0.98 2,003.73 MWD+IFR-AK-CAZ-SC(3) 5,477.93 63.84 259.83 3,569.43 3,521.03 -510.36 -3,450.05 6,003,294.46 384,381.06 0.67 2,056.12 MWD+IFR-AK-CAZ-SC(3) 5,572.24 63.41 258.99 3,611.32 3,562.92 -525.89 -3,533.10 6,003,280.18 384,297.79 0.92 2,108.49 MWD+IFR-AK-CAZ-SC(3) 5,666.13 64.10 258.68 3,652.84 3,604.44 -542.19 -3,615.72 6,003,265.12 384,214.95 0.79 2,161.34 MWD+IFR-AK-CAZ-SC(3) 5,761.79 63.90 258.40 3,694.78 3,646.38 -559.28 -3,699.99 6,003,249.31 384,130.45 0.34 2,215.65 MWD+IFR-AK-CAZ-SC(3) 5,855.82 63.90 259.58 3,736.15 3,687.75 -575.40 -3,782.87 6,003,234.43 384,047.33 1.13 2,268.47 MWD+IFR-AK-CAZ-SC(3) 5,950.97 63.56 258.51 3,778.26 3,729.86 -591.61 -3,866.64 6,003,219.48 383,963.34 1.07 2,321.77 MWD+IFR-AK-CAZ-SC(3) 6,045.23 63.77 259.92 3,820.08 3,771.68 -607.42 -3,949.62 6,003,204.92 383,880.14 1.36 2,374.35 MWD+IFR-AK-CAZ-SC(3) 6,140.84 63.43 259.12 3,862.59 3,814.19 -623.00 -4,033.83 6,003,190.62 383,795.71 0.83 2,427.30 MWD+IFR-AK-CAZ-SC(3) 6,234.47 63.00 259.74 3,904.78 3,856.38 -638.33 -4,115.99 6,003,176.52 383,713.33 0.75 2,479.08 MWD+IFR-AK-CAZ-SC(3) 6,329.26 62.94 259.96 3,947.86 3,899.46 -653.21 -4,199.11 6,003,162.89 383,630.01 0.22 2,530.90 MWD+IFR-AK-CAZ-SC(3) 6,423.76 62.72 261.12 3,991.01 3,942.61 -667.03 -4,282.04 6,003,150.32 383,546.89 1.12 2,581.70 MWD+IFR-AK-CAZ-SC(3) 6,517.93 62.89 261.19 4,034.05 3,985.65 -679.91 -4,364.80 6,003,138.69 383,463.95 0.19 2,631.59 MWD+IFR-AK-CAZ-SC(3) 6,612.56 63.01 261.46 4,077.09 4,028.69 -692.62 -4,448.11 6,003,127.23 383,380.46 0.28 2,681.58 MWD+IFR-AK-CAZ-SC(3) 6,707.21 62.79 260.82 4,120.20 4,071.80 -705.60 -4,531.37 6,003,115.51 383,297.03 0.65 2,731.78 MWD+IFR-AK-CAZ-SC(3) 6,801.45 61.89 259.80 4,163.95 4,115.55 -719.64 -4,613.64 6,003,102.70 383,214.56 1.35 2,782.48 MWD+IFR-AK-CAZ-SC(3) 6,895.58 62.05 260.17 4,208.19 4,159.79 -734.09 -4,695.47 6,003,089.48 383,132.54 0.39 2,833.32 MWD+IFR-AK-CAZ-SC(3) 6,988.94 62.59 260.25 4,251.56 4,203.16 -748.15 -4,776.94 6,003,076.65 383,050.87 0.58 2,883.65 MWD+IFR-AK-CAZ-SC(3) 7,084.18 63.61 259.77 4,294.65 4,246.25 -762.88 -4,860.58 6,003,063.18 382,967.02 1.16 2,935.59 MWD+IFR-AK-CAZ-SC(3) 2/20/2012 10:56:57AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project Western North Slope TVD Reference`. 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical ' MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,179.67 63.64 260.45 4,337.07 4,288.67 -777.58 -4,944.86 6,003,049.75 382,882.54 0.64 2,987.79 MWD+IFR-AK-CAZ-SC(3) 7,274.24 63.49 260.67 4,379.17 4,330.77 -791.47 -5,028.39 6,003,037.12 382,798.81 0.26 3,038.93 MWD+IFR-AK-CAZ-SC(3) 7,368.35 63.01 259.06 4,421.53 4,373.13 -806.25 -5,111.12 6,003,023.58 382,715.88 1.61 3,090.48 MWD+IFR-AK-CAZ-SC(3) 7,461.58 63.22 259.77 4,463.69 4,415.29 -821.53 -5,192.86 6,003,009.54 382,633.93 0.72 3,142.02 MWD+IFR-AK-CAZ-SC(3) 7,556.95 63.35 260.16 4,506.56 4,458.16 -836.37 -5,276.74 6,002,995.96 382,549.84 0.39 3,194.16 MWD+IFR-AK-CAZ-SC(3) 7,652.07 63.48 259.92 4,549.13 4,500.73 -851.08 -5,360.52 6,002,982.51 382,465.85 0.26 3,246.15 MWD+IFR-AK-CAZ-SC(3) 7,745.94 63.43 260.28 4,591.08 4,542.68 -865.52 -5,443.25 6,002,969.31 382,382.93 0.35 3,297.40 MWD+IFR-AK-CAZ-SC(3) 7,840.37 63.41 260.04 4,633.33 4,584.93 -879.95 -5,526.45 6,002,956.14 382,299.52 0.23 3,348.87 MWD+IFR-AK-CAZ-SC(3) 7,934.48 63.47 259.88 4,675.41 4,627.01 -894.63 -5,609.34 6,002,942.71 382,216.43 0.16 3,400.40 MWD+IFR-AK-CAZ-SC(3) 8,029.88 63.62 260.39 4,717.91 4,669.51 -909.26 -5,693.49 6,002,929.34 382,132.08 0.50 3,452.49 MWD+IFR-AK-CAZ-SC(3) 8,125.01 63.49 260.46 4,760.28 4,711.88 -923.43 -5,777.48 6,002,916.44 382,047.89 0.15 3,504.08 MWD+IFR-AK-CAZ-SC(3) 8,219.94 62.87 259.03 4,803.11 4,754.71 -938.51 -5,860.84 6,002,902.62 381,964.32 1.49 3,556.20 MWD+IFR-AK-CAZ-SC(3) 8,313.67 63.36 259.64 4,845.50 4,797.10 -953.98 -5,943.00 6,002,888.38 381,881.95 0.78 3,608.10 MWD+IFR-AK-CAZ-SC(3) 8,409.14 63.15 259.69 4,888.46 4,840.06 -969.27 -6,026.87 6,002,874.35 381,797.86 0.22 3,660.64 MWD+IFR-AK-CAZ-SC(3) 8,501.33 62.93 259.59 4,930.26 4,881.86 -984.05 -6,107.70 6,002,860.79 381,716.83 0.26 3,711.31 MWD+IFR-AK-CAZ-SC(3) 8,597.83 62.93 259.51 4,974.17 4,925.77 -999.64 -6,192.20 6,002,846.48 381,632.11 0.07 3,764.40 MWD+IFR-AK-CAZ-SC(3) 8,691.83 63.15 259.84 5,016.79 4,968.39 -1,014.65 -6,274.63 6,002,832.70 381,549.47 0.39 3,816.02 MWD+IFR-AK-CAZ-SC(3) 8,786.72 63.28 259.72 5,059.55 5,011.15 -1,029.68 -6,358.00 6,002,818.93 381,465.90 0.18 3,868.09 MWD+IFR-AK-CAZ-SC(3) 8,881.13 63.91 260.25 5,101.54 5,053.14 -1,044.39 -6,441.27 6,002,805.48 381,382.42 0.84 3,919.83 MWD+IFR-AK-CAZ-SC(3) 8,974.95 64.25 261.13 5,142.55 5,094.15 -1,058.04 -6,524.54 6,002,793.08 381,298.96 0.92 3,970.64 MWD+IFR-AK-CAZ-SC(3) 9,070.43 63.97 261.68 5,184.24 5,135.84 -1,070.87 -6,609.47 6,002,781.52 381,213.85 0.60 4,021.50 MWD+IFR-AK-CAZ-SC(3) 9,163.46 63.76 261.78 5,225.22 5,176.82 -1,082.89 -6,692.12 6,002,770.75 381,131.04 0.25 4,070.57 MWD+IFR-AK-CAZ-SC(3) 9,257.30 63.28 261.47 5,267.06 5,218.66 -1,095.12 -6,775.22 6,002,759.77 381,047.77 0.59 4,120.04 MWD+IFR-AK-CAZ-SC(3) 9,353.92 63.36 260.58 5,310.44 5,262.04 -1,108.59 -6,860.49 6,002,747.59 380,962.31 0.83 4,171.62 MWD+IFR-AK-CAZ-SC(3) 9,447.18 63.21 260.08 5,352.37 5,303.97 -1,122.58 -6,942.61 6,002,734.83 380,880.00 0.51 4,222.19 MWD+IFR-AK-CAZ-SC(3) 9,541.97 62.81 259.48 5,395.39 5,346.99 -1,137.57 -7,025.74 6,002,721.10 380,796.66 0.70 4,274.11 MWD+IFR-AK-CAZ-SC(3) 9,636.40 63.00 259.06 5,438.40 5,390.00 -1,153.22 -7,108.33 6,002,706.69 380,713.85 0.44 4,326.38 MWD+IFR-AK-CAZ-SC(3) 9,731.37 63.35 258.30 5,481.25 5,432.85 -1,169.86 -7,191.43 6,002,691.30 380,630.52 0.80 4,379.75 MWD+IFR-AK-CAZ-SC(3) 9,825.81 63.49 258.21 5,523.51 5,475.11 -1,187.05 -7,274.13 6,002,675.36 380,547.58 0.17 4,433.42 MWD+IFR-AK-CAZ-SC(3) 9,920.32 63.51 258.83 5,565.68 5,517.28 -1,203.88 -7,357.01 6,002,659.77 380,464.46 0.59 4,486.86 MWD+IFR-AK-CAZ-SC(3) 10,014.74 63.84 260.12 5,607.55 5,559.15 -1,219.34 -7,440.21 6,002,645.57 380,381.04 1.27 4,539.24 MWD+IFR-AK-CAZ-SC(3) 10,109.23 63.84 260.03 5,649.21 5,600.81 -1,233.96 -7,523.76 6,002,632.21 380,297.30 0.09 4,591.03 MWD+IFR-AK-CAZ-SC(3) 10,203.46 63.56 260.31 5,690.96 5,642.56 -1,248.38 -7,606.99 6,002,619.04 380,213.86 0.40 4,642.50 MWD+IFR-AK-CAZ-SC(3) 10,297.98 63.22 258.27 5,733.30 5,684.90 -1,264.08 -7,690.02 6,002,604.59 380,130.61 1.96 4,695.01 MWD+IFR-AK-CAZ-SC(3) 10,392.73 62.30 254.78 5,776.68 5,728.28 -1,283.70 -7,771.93 6,002,586.21 380,048.43 3.42 4,750.46 MWD+IFR-AK-CAZ-SC(3) 10,487.05 60.77 251.66 5,821.65 5,773.25 -1,307.61 -7,851.30 6,002,563.49 379,968.71 3.33 4,808.55 MWD+IFR-AK-CAZ-SC(3) 10,581.34 60.63 248.32 5,867.80 5,819.40 -1,335.74 -7,928.55 6,002,536.53 379,891.05 3.09 4,869.37 MWD+IFR-AK-CAZ-SC(3) 10,675.66 59.63 243.68 5,914.79 5,866.39 -1,368.98 -8,003.25 6,002,504.42 379,815.87 4.40 4,933.53 MWD+IFR-AK-CAZ-SC(3) 10,770.17 58.63 238.64 5,963.31 5,914.91 -1,408.07 -8,074.28 6,002,466.40 379,744.27 4.70 5,001.17 MWD+IFR-AK-CAZ-SC(3) 10,866.01 56.80 234.67 6,014.51 5,966.11 -1,452.57 -8,141.96 6,002,422.93 379,675.94 3.99 5,072.03 MWD+IFR-AK-CAZ-SC(3) 2/20/2012 10:56:57AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 10,960.39 56.12 230.93 6,066.67 6,018.27 -1,500.11 -8,204.60 6,002,376.34 379,612.59 3.38 5,143.25 MWD+IFR-AK-CAZ-SC(3) 11,055.50 57.02 227.78 6,119.08 6,070.68 -1,551.81 -8,264.81 6,002,325.55 379,551.62 2.92 5,217.02 MWD+IFR-AK-CAZ-SC(3) 11,150.12 57.84 223.75 6,170.03 6,121.63 -1,607.43 -8,321.91 6,002,270.80 379,493.69 3.69 5,292.81 MWD+IFR-AK-CAZ-SC(3) 11,244.60 59.28 219.35 6,219.33 6,170.93 -1,667.75 -8,375.34 6,002,211.30 379,439.37 4.26 5,371.05 MWD+IFR-AK-CAZ-SC(3) 11,339.05 59.06 215.13 6,267.75 6,219.35 -1,732.29 -8,424.41 6,002,147.51 379,389.34 3.84 5,451.01 MWD+IFR-AK-CAZ-SC(3) 11,432.57 59.18 211.21 6,315.76 6,267.36 -1,799.45 -8,468.30 6,002,081.02 379,344.44 3.60 5,530.89 MWD+IFR-AK-CAZ-SC(3) 11,527.59 59.49 209.14 6,364.22 6,315.82 -1,870.11 -8,509.38 6,002,010.99 379,302.31 1.90 5,612.54 MWD+IFR-AK-CAZ-SC(3) 11,621.98 61.41 204.81 6,410.79 6,362.39 -1,943.27 -8,546.59 6,001,938.40 379,264.01 4.48 5,694.61 MWD+IFR-AK-CAZ-SC(3) 11,717.12 61.18 201.57 6,456.50 6,408.10 -2,019.96 -8,579.44 6,001,862.22 379,230.01 3.00 5,777.78 MWD+IFR-AK-CAZ-SC(3) 11,811.39 61.12 197.34 6,502.00 6,453.60 -2,097.79 -8,606.94 6,001,784.82 379,201.36 3.93 5,859.47 MWD+IFR-AK-CAZ-SC(3) 11,906.13 61.41 195.24 6,547.55 6,499.15 -2,177.52 -8,630.23 6,001,705.46 379,176.86 1.97 5,940.89 MWD+IFR-AK-CAZ-SC(3) 12,000.10 60.34 194.59 6,593.29 6,544.89 -2,256.84 -8,651.36 6,001,626.47 379,154.55 1.29 6,020.94 MWD+IFR-AK-CAZ-SC(3) 12,094.88 60.86 194.95 6,639.81 6,591.41 -2,336.68 -8,672.42 6,001,546.96 379,132.30 0.64 6,101.41 MWD+IFR-AK-CAZ-SC(3) 12,189.14 61.20 195.25 6,685.47 6,637.07 -2,416.30 -8,693.90 6,001,467.68 379,109.62 0.46 6,181.89 MWD+IFR-AK-CAZ-SC(3) 12,284.04 60.26 194.76 6,731.87 6,683.47 -2,496.26 -8,715.33 6,001,388.06 379,086.99 1.09 6,262.64 MWD+IFR-AK-CAZ-SC(3) 12,378.29 61.12 194.55 6,778.01 6,729.61 -2,575.77 -8,736.12 6,001,308.87 379,065.01 0.93 6,342.70 MWD+IFR-AK-CAZ-SC(3) 12,472.59 62.23 195.81 6,822.75 6,774.35 -2,655.88 -8,757.86 6,001,229.11 379,042.07 1.66 6,423.73 MWD+IFR-AK-CAZ-SC(3) 12,522.26 63.84 195.78 6,845.27 6,796.87 -2,698.48 -8,769.91 6,001,186.70 379,029.38 3.24 6,467.05 MWD+IFR-AK-CAZ-SC(3) 12,567.21 65.41 194.92 6,864.53 6,816.13 -2,737.64 -8,780.66 6,001,147.71 379,018.05 3.90 6,506.72 MWD+IFR-AK-CAZ-SC(3) 12,612.80 66.81 192.93 6,883.00 6,834.60 -2,778.10 -8,790.69 6,001,107.41 379,007.42 5.04 6,547.20 MWD+IFR-AK-CAZ-SC(3) 12,661.68 69.43 191.69 6,901.21 6,852.81 -2,822.41 -8,800.35 6,001,063.25 378,997.09 5.85 6,590.92 MWD+IFR-AK-CAZ-SC(3) 12,710.99 71.63 190.00 6,917.65 6,869.25 -2,868.06 -8,809.10 6,001,017.74 378,987.66 5.51 6,635.41 MWD+IFR-AK-CAZ-SC(3) 12,756.30 73.83 187.69 6,931.10 6,882.70 -2,910.81 -8,815.74 6,000,975.10 378,980.38 6.88 6,676.34 MWD+IFR-AK-CAZ-SC(3) 12,802.74 75.57 186.68 6,943.35 6,894.95 -2,955.25 -8,821.34 6,000,930.75 378,974.11 4.29 6,718.29 MWD+IFR-AK-CAZ-SC(3) 12,850.76 77.59 184.32 6,954.50 6,906.10 -3,001.74 -8,825.82 6,000,884.34 378,968.94 6.37 6,761.52 MWD+IFR-AK-CAZ-SC(3) 12,903.27 79.48 182.55 6,964.94 6,916.54 -3,053.11 -8,828.90 6,000,833.03 378,965.09 4.89 6,808.43 MWD+IFR-AK-CAZ-SC(3) 12,945.65 81.74 181.38 6,971.85 6,923.45 -3,094.89 -8,830.33 6,000,791.27 378,963.03 5.99 6,846.09 MWD+IFR-AK-CAZ-SC(3) 12,975.44 81.92 181.50 6,976.09 6,927.69 -3,124.37 -8,831.07 6,000,761.81 378,961.84 0.72 6,872.53 MWD+IFR-AK-CAZ-SC(3) 13,029.53 84.06 181.42 6,982.69 6,934.29 -3,178.03 -8,832.44 6,000,708.18 378,959.67 3.96 6,920.68 MWD+IFR-AK-CAZ-SC(4) 13,128.34 87.54 182.18 6,989.92 6,941.52 -3,276.51 -8,835.53 6,000,609.77 378,955.09 3.60 7,009.30 MWD+IFR-AK-CAZ-SC(4) 13,221.62 90.32 181.04 6,991.66 6,943.26 -3,369.73 -8,838.15 6,000,516.61 378,951.07 3.22 7,093.04 MWD+IFR-AK-CAZ-SC(4) 13,319.56 89.99 177.66 6,991.40 6,943.00 -3,467.65 -8,837.04 6,000,418.69 378,950.71 3.47 7,179.22 MWD+IFR-AK-CAZ-SC(4) 13,414.61 90.00 171.26 6,991.41 6,943.01 -3,562.21 -8,827.87 6,000,324.02 378,958.46 6.73 7,258.66 MWD+IFR-AK-CAZ-SC(4) 13,509.13 89.69 168.73 6,991.66 6,943.26 -3,655.28 -8,811.45 6,000,230.71 378,973.48 2.70 7,333.43 MWD+IFR-AK-CAZ-SC(4) 13,606.64 88.32 165.19 6,993.36 6,944.96 -3,750.24 -8,789.46 6,000,135.44 378,994.04 3.89 7,407.27 MWD+IFR-AK-CAZ-SC(4) 1 13,701.05 88.58 160.18 6,995.91 6,947.51 -3,840.31 -8,761.38 6,000,044.96 379,020.76 5.31 7,473.96 MWD+IFR-AK-CAZ-SC(4) 13,753.81 88.45 157.61 6,997.28 6,948.88 -3,889.51 -8,742.39 5,999,995.49 379,039.01 4.88 7,508.68 MWD+IFR-AK-CAZ-SC(4) 13,796.77 88.58 155.69 6,998.39 6,949.99 -3,928.94 -8,725.37 5,999,955.81 379,055.44 4.48 7,535.67 MWD+IFR-AK-CAZ-SC(4) 13,892.25 88.39 152.87 7,000.92 6,952.52 -4,014.92 -8,683.95 5,999,869.23 379,095.55 2.96 7,592.53 MWD+IFR-AK-CAZ-SC(4) 13,987.69 88.76 149.13 7,003.29 6,954.89 -4,098.35 -8,637.70 5,999,785.12 379,140.54 3.94 7,644.89 MWD+IFR-AK-CAZ-SC(4) 2/20/2012 10:56:57AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope ND Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 14,082.08 89.75 145.99 7,004.52 6,956.12 -4,178.00 -8,587.08 5,999,704.73 379,189.95 3.49 7,691.86 MWD+IFR-AK-CAZ-SC(4) 14,178.63 88.51 142.63 7,005.99 6,957.59 -4,256.39 -8,530.77 5,999,625.50 379,245.08 3.71 7,735.08 MWD+IFR-AK-CAZ-SC(4) 14,272.65 88.82 140.48 7,008.18 6,959.78 -4,330.01 -8,472.33 5,999,551.03 379,302.40 2.31 7,773.07 MWD+IFR-AK-CAZ-SC(4) 14,368.15 88.26 142.14 7,010.61 6,962.21 -4,404.52 -8,412.66 5,999,475.63 379,360.94 1.83 7,811.29 MWD+IFR-AK-CAZ-SC(4) 14,463.49 89.01 144.06 7,012.88 6,964.48 -4,480.74 -8,355.43 5,999,398.57 379,417.01 2.16 7,852.16 MWD+IFR-AK-CAZ-SC(4) 14,557.71 89.63 144.09 7,014.00 6,965.60 -4,557.03 -8,300.15 5,999,321.46 379,471.13 0.66 7,894.00 MWD+IFR-AK-CAZ-SC(4) 14,654.02 90.31 141.61 7,014.05 6,965.65 -4,633.79 -8,242.00 5,999,243.85 379,528.12 2.67 7,934.91 MWD+IFR-AK-CAZ-SC(4) 14,750.48 89.43 140.29 7,014.27 6,965.87 -4,708.69 -8,181.23 5,999,168.04 379,587.75 1.64 7,972.97 MWD+IFR-AK-CAZ-SC(4) 14,845.21 89.38 141.13 7,015.25 6,966.85 -4,782.01 -8,121.25 5,999,093.84 379,646.62 0.89 8,009.98 MWD+IFR-AK-CAZ-SC(4) 14,941.01 90.19 141.28 7,015.61 6,967.21 -4,856.67 -8,061.22 5,999,018.29 379,705.51 0.86 8,048.17 MWD+IFR-AK-CAZ-SC(4) 14,991.60 89.68 141.62 7,015.67 6,967.27 -4,896.24 -8,029.70 5,998,978.26 379,736.44 1.21 8,068.53 MWD+IFR-AK-CAZ-SC(4) 15,035.95 90.31 142.03 7,015.67 6,967.27 -4,931.10 -8,002.29 5,998,942.99 379,763.32 1.69 8,086.65 MWD+IFR-AK-CAZ-SC(4) 15,132.00 89.56 142.54 7,015.78 6,967.38 -5,007.08 -7,943.53 5,998,866.14 379,820.92 0.94 8,126.60 MWD+IFR-AK-CAZ-SC(4) 15,226.60 89.69 144.35 7,016.40 6,968.00 -5,083.07 -7,887.19 5,998,789.32 379,876.11 1.92 8,167.67 MWD+IFR-AK-CAZ-SC(4) 15,322.37 89.25 143.50 7,017.29 6,968.89 -5,160.47 -7,830.80 5,998,711.09 379,931.32 1.00 8,209.97 MWD+IFR-AK-CAZ-SC(4) 15,417.57 89.25 141.86 7,018.53 6,970.13 -5,236.17 -7,773.09 5,998,634.54 379,987.89 1.72 8,250.15 MWD+IFR-AK-CAZ-SC(4) 15,512.34 88.57 143.86 7,020.34 6,971.94 -5,311.70 -7,715.88 5,998,558.16 380,043.95 2.23 8,290.42 MWD+1FR-AK-CAZ-SC(4) 15,608.00 89.69 144.19 7,021.79 6,973.39 -5,389.10 -7,659.70 5,998,479.93 380,098.96 1.22 8,332.82 MWD+IFR-AK-CAZ-SC(4) 15,704.39 88.57 146.07 7,023.25 6,974.85 -5,468.17 -7,604.60 5,998,400.05 380,152.86 2.27 8,377.20 MWD+IFR-AK-CAZ-SC(4) 15,799.66 90.56 146.49 7,023.98 6,975.58 -5,547.41 -7,551.72 5,998,320.04 380,204.54 2.13 8,422.76 MWD+IFR-AK-CAZ-SC(4) 15,895.28 89.93 144.04 7,023.57 6,975.17 -5,625.98 -7,497.24 5,998,240.66 380,257.83 2.65 8,466.98 MWD+IFR-AK-CAZ-SC(4) 15,990.62 90.43 142.72 7,023.27 6,974.87 -5,702.50 -7,440.37 5,998,163.30 380,313.53 1.48 8,508.28 MWD+IFR-AK-CAZ-SC(4) 16,085.21 88.56 140.90 7,024.10 6,975.70 -5,776.83 -7,381.89 5,998,088.10 380,370.88 2.76 8,546.90 MWD+IFR-AK-CAZ-SC(4) 16,180.25 88.26 140.57 7,026.74 6,978.34 -5,850.39 -7,321.77 5,998,013.66 380,429.89 0.47 8,584.06 MWD+IFR-AK-CAZ-SC(4) 16,275.54 88.83 143.44 7,029.16 6,980.76 -5,925.45 -7,263.13 5,997,937.73 380,487.39 3.07 8,623.25 MWD+IFR-AK-CAZ-SC(4) 16,370.55 87.89 144.21 7,031.88 6,983.48 -6,002.11 -7,207.08 5,997,860.24 380,542.28 1.28 8,665.05 MWD+IFR-AK-CAZ-SC(4) 16,466.46 88.27 143.67 7,035.09 6,986.69 -6,079.60 -7,150.65 5,997,781.92 380,597.53 0.69 8,707.41 MWD+IFR-AK-CAZ-SC(4) 16,561.28 87.77 144.58 7,038.37 6,989.97 -6,156.39 -7,095.12 5,997,704.32 380,651.90 1.09 8,749.57 MWD+IFR-AK-CAZ-SC(4) 16,656.75 89.26 145.69 7,040.84 6,992.44 -6,234.69 -7,040.57 5,997,625.21 380,705.26 1.95 8,793.52 MWD+IFR-AK-CAZ-SC(4) 16,751.76 89.56 145.28 7,041.82 6,993.42 -6,312.97 -6,986.73 5,997,546.14 380,757.91 0.53 8,837.80 MWD+IFR-AK-CAZ-SC(4) 16,847.59 89.31 145.15 7,042.76 6,994.36 -6,391.67 -6,932.07 5,997,466.63 380,811.38 0.29 8,882.05 MWD+IFR-AK-CAZ-SC(4) 16,941.44 90.00 145.16 7,043.33 6,994.93 -6,468.69 -6,878.45 5,997,388.82 380,863.84 0.74 8,925.30 MWD+IFR-AK-CAZ-SC(4) 17,038.65 89.31 145.89 7,043.92 6,995.52 -6,548.83 -6,823.42 5,997,307.87 380,917.64 1.03 8,970.66 MWD+IFR-AK-CAZ-SC(4) 17,134.41 90.06 145.69 7,044.44 6,996.04 -6,628.02 -6,769.58 5,997,227.89 380,970.28 0.81 9,015.73 MWD+IFR-AK-CAZ-SC(4) 17,229.39 90.74 144.48 7,043.78 6,995.38 -6,705.90 -6,715.22 5,997,149.21 381,023.46 1.46 9,059.40 MWD+IFR-AK-CAZ-SC(4) 17,325.09 89.06 142.06 7,043.95 6,995.55 -6,782.59 -6,658.00 5,997,071.67 381,079.52 3.08 9,100.69 MWD+IFR-AK-CAZ-SC(4) 17,420.52 89.19 141.67 7,045.40 6,997.00 -6,857.64 -6,599.07 5,996,995.75 381,137.31 0.43 9,139.73 MWD+IFR-AK-CAZ-SC(4) 17,514.36 89.81 142.21 7,046.22 6,997.82 -6,931.52 -6,541.23 5,996,921.01 381,194.03 0.88 9,178.24 MWD+IFR-AK-CAZ-SC(4) 17,609.41 88.44 143.29 7,047.67 6,999.27 -7,007.17 -6,483.70 5,996,844.51 381,250.41 1.84 9,218.46 MWD+IFR-AK-CAZ-SC(4) 17,703.60 89.94 145.12 7,049.01 7,000.61 -7,083.56 -6,428.62 5,996,767.32 381,304.33 2.51 9,260.48 MWD+IFR-AK-CAZ-SC(4) 2/20/2012 10:56:57AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: 35.8+12.6 @ 48.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design:; CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 17,801.00 90.06 145.81 7,049.01 7,000.61 -7,163.79 -6,373.40 5,996,686.27 381,358.33 0.72 9,305.83 MWD+IFR-AK-CAZ-SC(4) 17,896.18 89.81 145.88 7,049.11 7,000.71 -7,242.56 -6,319.97 5,996,606.72 381,410.58 0.27 9,350.71 MWD+IFR-AK-CAZ-SC(4) 17,991.92 90.06 146.39 7,049.22 7,000.82 -7,322.06 -6,266.62 5,996,526.43 381,462.72 0.59 9,396.29 MWD+IFR-AK-CAZ-SC(4) 18,087.23 89.81 147.93 7,049.33 7,000.93 -7,402.13 -6,214.93 5,996,445.60 381,513.19 1.64 9,443.14 MWD+IFR-AK-CAZ-SC(4) 18,182.64 88.88 143.45 7,050.42 7,002.02 -7,480.91 -6,161.17 5,996,366.02 381,565.76 4.80 9,487.89 MWD+IFR-AK-CAZ-SC(4) 18,277.44 88.01 143.54 7,052.99 7,004.59 -7,557.09 -6,104.80 5,996,289.02 381,620.98 0.92 9,529.11 MWD+IFR-AK-CAZ-SC(4) 18,373.88 87.58 143.93 7,056.70 7,008.30 -7,634.79 -6,047.79 5,996,210.48 381,676.80 0.60 9,571.40 MWD+IFR-AK-CAZ-SC(4) 18,469.04 89.45 144.24 7,059.17 7,010.77 -7,711.83 -5,992.00 5,996,132.61 381,731.43 1.99 9,613.65 MWD+IFR-AK-CAZ-SC(4) 18,564.81 88.88 144.74 7,060.57 7,012.17 -7,789.78 -5,936.37 5,996,053.84 381,785.87 0.79 9,656.80 MWD+IFR-AK-CAZ-SC(4) 18,659.04 89.75 145.05 7,061.69 7,013.29 -7,866.86 -5,882.19 5,995,975.96 381,838.89 0.98 9,699.84 MWD+IFR-AK-CAZ-SC(4) 18,754.34 88.88 141.77 7,062.83 7,014.43 -7,943.36 -5,825.39 5,995,898.62 381,894.52 3.56 9,741.16 MWD+IFR-AK-CAZ-SC(4) 18,848.80 87.70 141.24 7,065.65 7,017.25 -8,017.26 -5,766.63 5,995,823.86 381,952.17 1.37 9,779.25 MWD+IFR-AK-CAZ-SC(4) 18,943.50 87.21 142.84 7,069.86 7,021.46 -8,091.85 -5,708.43 5,995,748.41 382,009.23 1.77 9,818.23 MWD+IFR-AK-CAZ-SC(4) 19,039.75 88.40 144.33 7,073.54 7,025.14 -8,169.24 -5,651.34 5,995,670.17 382,065.15 1.98 9,860.20 MWD+IFR-AK-CAZ-SC(4) 19,135.46 90.44 145.86 7,074.51 7,026.11 -8,247.72 -5,596.58 5,995,590.88 382,118.72 2.66 9,904.22 MWD+IFR-AK-CAZ-SC(4) 19,230.70 91.79 145.85 7,072.66 7,024.26 -8,326.53 -5,543.14 5,995,511.29 382,170.97 1.42 9,949.13 MWD+IFR-AK-CAZ-SC(4) 19,326.21 90.30 143.66 7,070.92 7,022.52 -8,404.51 -5,488.03 5,995,432.49 382,224.89 2.77 9,992.55 MWD+IFR-AK-CAZ-SC(4) 19,421.64 90.43 141.27 7,070.31 7,021.91 -8,480.18 -5,429.90 5,995,355.97 382,281.87 2.51 10,032.50 MWD+IFR-AK-CAZ-SC(4) 19,517.32 89.37 140.93 7,070.48 7,022.08 -8,554.64 -5,369.82 5,995,280.62 382,340.83 1.16 10,070.48 MWD+IFR-AK-CAZ-SC(4) 19,612.36 89.32 142.18 7,071.56 7,023.16 -8,629.07 -5,310.73 5,995,205.32 382,398.78 1.32 10,108.90 MWD+IFR-AK-CAZ-SC(4) 19,710.70 90.31 142.94 7,071.88 7,023.48 -8,707.15 -5,250.95 5,995,126.36 382,457.38 1.27 10,150.23 MWD+IFR-AK-CAZ-SC(4) 19,804.02 89.37 143.52 7,072.14 7,023.74 -8,781.90 -5,195.09 5,995,050.78 382,512.11 1.18 10,190.43 MWD+IFR-AK-CAZ-SC(4) 19,899.73 89.63 144.29 7,072.97 7,024.57 -8,859.23 -5,138.70 5,994,972.61 382,567.32 0.85 10,232.67 MWD+IFR-AK-CAZ-SC(4) 19,994.92 88.69 146.02 7,074.37 7,025.97 -8,937.34 -5,084.32 5,994,893.70 382,620.51 2.07 10,276.54 MWD+IFR-AK-CAZ-SC(4) 20,091.32 88.64 145.02 7,076.62 7,028.22 -9,016.79 -5,029.77 5,994,813.46 382,673.86 1.04 10,321.50 MWD+IFR-AK-CAZ-SC(4) 20,186.53 88.14 145.48 7,079.29 7,030.89 -9,094.98 -4,975.52 5,994,734.46 382,726.93 0.71 10,365.50 MWD+IFR-AK-CAZ-SC(4) 20,282.36 89.39 147.25 7,081.36 7,032.96 -9,174.75 -4,922.45 5,994,653.91 382,778.78 2.26 10,411.44 MWD+IFR-AK-CAZ-SC(4) 20,353.07 89.25 146.34 7,082.20 7,033.80 -9,233.91 -4,883.73 5,994,594.18 382,816.61 1.30 10,445.81 MWD+IFR-AK-CAZ-SC(4) 20,387.00 89.25 146.34 7,082.64 7,034.24 -9,262.15 -4,864.93 5,994,565.67 382,834.98 0.00 10,462.07 PROJECTED to TD 2/20/2012 10:56:57AM Page 8 COMPASS 2003.16 Build 69 HALLIBURTON Sperry Drilling WELL LOG TRANSMITTAL To: State of Alaska March 27, 2012 Alaska Oil and Gas Conservation Commission Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-128 AK-MW-0009113884 CD3-128 50-103-20638-00 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5"TVD TRIPLE COMBO Logs: 1 Color Log Digital Log Images & LWDG-formatted LIS Data w/verification listing: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com Date: bi 15/'t 2 Signed: ( j i . ° 0 . STATE OF ALASKA t AL \OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r;, Rug Perforations r Perforate r Other r Alter Casing r Rill Tubing r Stimulate-Frac I✓ Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r - 211-037-0 3.Address: 6.API Number: Stratigraphic r Service I-- P. O. Box 100360,Anchorage,Alaska 99510 — 50-103-20638-00 00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 25538,372105 -CD3-128 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 20387 feet Plugs(measured) None true vertical 7083 feet Junk(measured) None Effective Depth measured 18685 feet Packer(measured) 12311, 12596 true vertical 7063 feet (true vertucal) 6745,6876 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2953 9.625 2989 2452 PRODUCTION 12976 7 13009 6982 LINER 7692 4.5 20387 7077 eV ED REC pP R 112012 Perforation depth: Measured depth: 12476-12496' True Vertical Depth: 6825'-6834' e tOGGC Tubing(size,grade,MD,and TVD) 3.5, L-80, 12739 MD,6926 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 12311 MD and 6745 ND PACKER-BAKER PREMIER PACKER @ 12596 MD and 6876 ND SSSV-CAMCO TRMAXX-5E SSSV @ 2180 MD and 2014 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12476'-12496' Treatment descriptions including volumes used and final pressure: 467219#of 16/20 carbolite 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 474 1482 363 -- 351 Subsequent to operation 2047 2793 9 -- 349 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development J . Service r Stratigraphic r 16.Well Status after work: „Oil ri Gas r WDSPL r Daily Report of Well Operations XXX GSTOR j-"- WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-070 Contact T. Senden 265-1544 Printed Na T. Sen en Title Staff Wells Engineer Signature &V\ Phone:265-1544 Date 4/101 ii_ Form 10-404 ised 11/2011RBDMS APR 112012 71L- 6/17.12- Sub it Original Only CD3-128 Frac Summary DATE SUMMARYOPS 2/24/12 PULL BALL& ROD @ 12665 ._..B. FREEZE PROTECT TBG w/25 BBLS _.VSEL. IN PROGRESS. 2/25/12 PULLED SOV @ 12229' RKB (DART NOT LOCKED IN OPEN POSITION). IN PROGRESS. 2/26/12 SET HES SPG (BATTERY CONNECTED @ 12:47 pm ON 2-26-2012/5 MIN SAMPLES FOR 5 DAYS/ 1 SEC SAMPLES FOR 11.5 DAYS/GAUGES WILL STOP RECORDING ON 3-15- 2012) @ 12229' RKB. MITIA TO 3500 psi (10 BBLS TO PRESSURE UP). **PASS**. PULLED 2.81" RHC PLUG BODY @ 12665' RKB. SET FRAC SLEEVE (2.85" NO-GO/2.30" ID/OAL= 57") @ 2180' RKB. READY FOR FRAC. 3/7/12 Completed rig-up of frac unit and support equipment; finished heating seawater and diesel. Encountered standby time to make-up riser to top of treesaver due to temperature below specification for man-lift operation (-20 deg F), and for scaffolding to thus be erected at wellhead. Pushed start time finally due to problems with treating iron at the PRV. 3/8/12 Unable to acheive passingPressure test due to leaking treating equipment. Ordered more heated diesel for attempt at restart tomorrow. 3/9/12 Performed fracturing treatment, pumping five main frac stages consisting of 0-6 ppa stages separated by four Bioball ball drop sequences. Pumped 220-bbl breakdown with 25-lb linear gel, followed by main frac of 467,219-lbs of 16/20 Carbolite in 25#crosslink gel (87% design). During last frac stage, extended the 4-ppa stage to 420-bbl, but then had to go to flush 11.4- bbl into final 5-ppa stage(and omitted 6-ppa stage) due to wash-out in the low pressure re-circ line between POD slingers and discharge. Flushed job to volume design including diesel freeze-protect. 3/11/12 PULLED FRAC SLV @ 2180' RKB. SET CATCHER @ 12,666' RKB. PULLED SPARTEK GAUGE AND SET 1/4" OV @ 12,229' RKB. PULLED DV @ 5098' RKB. IN PROGRESS. 3/12/12 PULLED DV & SET GLV(TRO=1883 PORT=3/16") @ 9973' RKB. SET GLV (TRO=1845 PORT=3/16") @ 5098' RKB. PULLED CATCHER @ 12,674' SLM. SET FRAC SLEEVE IN SSSV @ 2180' SLM. READY FOR FLOW BACK. 3/21/12 PULLED 2.81" FRAC SLEEVE @ 2179' RKB. JOB COMPLETE. • WNS CD3-128 ConocoPhillips aWee Well Attributes Max Angle&MD TD Alaska I•r • Wellbore API/UWI Field Name Well Status Incl(°) MD(RKB) Act Btm(RKB) • 501032063800 FIORD KUPARUK PROD 91.79 19,230.71 13,020.0 Comment H2S(ppm) Date Annotation End Date K8-Ord(R) Rig Release Date "' -SSSV:TRDP Last WO: 2/21/2012 36.80 4/30/2011 Well Confi9:-CD3-128 327/2012 3.00:57 PM Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 12,836.0 5/22/2011 Rev Reason:SET SLEEVE,GLV C/O ninam 3/27/2012 HANGER,31- a. Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.250 36.8 114.0 114.0 62.50 H-40 Insulated 42" Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 36.4 2,989.0 2,451.1 36.00 J-55 BTC-M ® - Casing Description String 0... String ID...Top(Po(B) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.000 32.8 13,009.0 6,980.3 26.00 L-80 BTC-M Tubing Strings CONDUCTOR Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd Insulated 421.- TUBING 31/2 2.992 30.6 12,738.5 6,925.9 9.30 L-80 EUE Mod 37-114 Completion Details Top Depth • (TVD) Top Incl Nomi... k, Top(RKB) (BBB) (°) Item Description Comment ID(in) SAFETY VLV. ice,. 30.6 30.6 -0.01 HANGER FMC TUBING HANGER 4.500 2.180 SLEEVE.2.180 115.9 115.9 0.32 XO Reducing CROSSOVER 4.5 x 3.5,9.3,L-80,EUE-MOD 3.500 2,179.5 2,014.3 48.10 SAFETY VLV CAMCO TRMAXX-5E SAFETY VALVE w/2.813"X PROFILE 2.812 12,282.9 6,731.3 60.27 SEAL ASSY 'BAKER SEAL ASSEMBLY LOCATOR 3.000 . 12,287.8 6,732.9 60.06 PBR BAKER 20'80-40 PBR 4.000 12,311.0 6,744.7 60.33 PACKER BAKER PREMIER PACKER 2.970 12,353.6 6,765.9 60.83 NIPPLE HES X NIPPLE 2.813 su2 soli r 12,447.7 6,811.1 61.94 BLAST RINGS SCC TUBING w/BLAST RINGS INSTALLED,TOP 2.992 I 12,476.7 6,824.1 62.25 BLAST RINGS SCC TUBING w/BLAST RINGS INSTALLED,BOTTOM 2.992 GAS LIFT, { ° 12,545.9 6,855.4 64.67 SLEEVE BAKER CMD SLIDING SLEEVE w/2.812'X PROFILE 2.810 5.098 I ` 12,596.0 6,876.1 65.91 PACKER BAKER PREMIER PACKER 2.870 12,665.5 6,901.6 69.42 NIPPLE HES XNIPPLE 2.750 I 12,704.3 6,915.5 71.30 Locator GBH-22 LOCATOR SPACED OUT 2 ABOVE FULLY LOCATED 2.960 12,727.1 6,922.5 72.41 SEAL ASSY SPACER TUBE SEAL SUB 3.000 GAS LI/I _ 12,736.5 6,925.3 72.87 SEAL ASSY LOWER SEAL SUBS 3.000 9'973 12,738.1 6,925.7 72.94 MULE SHOE MULE SHOE 3.000 • Cther In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl GAS LIFT, Top(fiRS) (RKB) (°) _ Description Comment _ Run Date ID(in) 12.229 2,179 2,014.3 48.10 SLEEVE FRAC SLEEVE(OAL=57") 3/12/2012 MI Perforations&Slots MIN Shot SEAL ASSY. _ Top(TVD) Btm(TVD) Dens 12,283 Top(RKB) Btm(RKB) MB) (RKB) Zone Date WI-. Type Comment PBR,12.288 I I 12,476 12,496 6,823.7 6,833.3 5/5/2011 6.0 IPERF Shot w/2.5 Millenium Guns I J Notes:General&Safety PACKER, End Date Annotation 12,311 5/3/2011 NOTE:View Schematic w/Alaska Schematic9.0 - NIPPLE.12.354 IIII GAS LIFT. 12.396 IN MN :l I, NIPPLE 12,665 Locator,12.704- - { • Mandrel Details Top Depth Top Port (TVD) Ino! OD Valve Latch Size TRO Run Stn Top(RKB) (RKB) r) Make Model _ (in) _ Sent Type Type (in) sEAussv, �- (psi) Run Date Com... 1 5,097.5 3,401.2 63.67 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,845.0 3/12/2012 12.727 - 2 9,972.6 5,588.9.63.69.CAMCO KBMG 1'GAS LIFT'GLV BK 0.188 1,883.03/12/2012 SEAL 17736 = 3 12,228.6 6,704.7 60.81 CAMCO KBMG 0 GAS LIFT .SPG 0.000 0.0 2/26/2012 MULE szoid Pip,' 4 12,396.2 6,786.6 61.33 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/21/2012 / PRODUCTION. 33-13.009 TD(CD3-128), 13.020 LINER. 12,69518,885 t 1 U ; / sEANPARNELLGovERNoR fip ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 T. Senden n -3/1 Staff Wells Engineer 1 ConocoPhillips Alaska, Inc. O'. P.O. Box 100360 Anchorage, Alaska 99510 Re: Colville River Field, Fiord Oil Pool, CD3-128 Sundry Number: 312-070 Dear Mr. Senden: 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, Ali OP' Daniel T. Seamount, Jr. J O Chair DATED this ' day of February, 2012. Encl. • STATE OF ALASKA (�'� '✓ T A (A OIL AND GAS CONSERVATION COM, ON `4'wL)'�� %C APPLICATION FOR SUNDRY APPROVALS '' ti 20 AAC 25.280 fig. • 7"'_- 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r e�./s. Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r • Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r,-,-, Exploratory r 211-037-0 • 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20638-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r CD3-128 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25538,372105 Colville River Field/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 20387 7077 Casing Length Size MD TVD u ------ r^ila�se CONDUCTOR 77 16 114' 114' RECEIVED F SURFACE 2953 9.625" 2989' 2452' RL V C PRODUCTION 12976 7" 13010' 6982' FEB 2 4 2012 Il LINER 4.5" 20387' 7077' Alaska Oil& Ga, Cr, ' elan do gon Anchorage I Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: • i 12476-12496' 6825'-6834' 3.5 L-80 12371 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER PREMIER PACKER MD=12327 ND=6753' PACKER-BAKER PREMIER PACKER MD=12601 TVD=6879' SSSV-CAMCO TRMAXX-5E MD=2160 TVD=2000' 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/5/2012 • Oil r • Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ty Senden @ 265-1544 Printed Name T. enden Title: Staff Wells Engineer Signature , Phone:265-1544 Date *02_ \ Commission Use Only Sundry Number:3i2-01 b Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /6 — Li WI f APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:2/2/// 2 , Form 10-47 Revised 1/2510 'y""Zia/ IDMS MAR Well Submit in Duplicate R.il, Overview: CD3-128 was completed as an pre perforated pup completion in the Nechelik zone in.21:14r Fracture stimulation of the Nechelik zone is planned to increase production. Intermediate String: N Intermediate 7"casing was drilled and set in 4/11. Cementing details are as follows: L e' 4/26/11: PJSM on Second Stage Cementing - Cement Second Stage as Follows: Pump 31.8 Bbls CW 100 @ 3.5 BPM w/280 Psi, Pump 27.3 Bbls 12.5 PPG Mud Push @ 4 BPM w/ (11" Z 330 Psi, Pump 46.5 Bbls 15.8 PPG Class G Cement w/Additives @ 5.3 BPM w/300 Psi, `re•OG (S'� ' Drop Closing Plug, Pump 20 Bbls Wash Water Behind Plug. Displace Cement w/ 259 5''W" Bbls of 11.3 PPG Mud @ 7 BPM w/390 to 520 Psi; Slowed Rate t/4 BPM w/320 Psi w/ 245 Bbls Pumped-Observed Plug Land -Increased Pressure to 2000 Psi to Close Stage Collar- Release Pressure-Verify Stage Collar Closure-OWFF(Static)-CIP @ 0255. 2/8/12: Drill out cement, baffle collar, FC, FS. and clean out rathole to 13010' Drill pipe measurements Drill pipe measurements Baffle @ 12,861', FC @ 12,903'and FS @ 12,990' 200 gpm/2170 psi/80 rpm @ 14K torque PUW 215K SOW 150K Rt.Wt. 172K. Drill 30' of new hole from 13,010'to 13,040' MD 6984'TVD -200 gpm/2180 psi /80 rpm @ 13.5 K torque-ADT=.5 hrs. Blow down choke line- RU and perform FIT to 12.4 ppg EMW-Bleed off-blow down and rig down valves and lines. Pre-Frac Wellwork: 1. Pull BPV 2. RU Slickline and pull ball and rod from XN nipple at 12,628' MD. " 3. Freeze protect tubing with 20 bbls of dead crude. ' 4. Pull DCK shear-out valve from GLM #3 at 12,287' MD and replace with a Spartek SPG programmed to collect data every second. - ? 5. Pressure test IA to 3500 psi.✓ ' . 6. Pull the RHC plug body from the nipple at 12,628' MD.' / 7. Set ISO sleeve across the SSSV at 2160' MD. • Frac Procedure: 1. MIRU twelve (12) clean insulated frac tanks with a berm surrounding the tanks that holds a single tank volume plus 10%. Load tanks with seawater from the injection system (approximately 5300 bbls are required for the treatment) 2. Rig up Schlumberger equipment and stab Stinger Tree Saver. 3. Pressure test surface lines to 8000 psi - 4. Pump the 220 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. Step down pumps and obtain ISIP and Pc. Monitor pressures for 30 mins. 5. Pump the following schedule at-20 BPM with a maximum expected pressure of-7000 psi, add breaker as per lab results. Maintain 3500 psi on the IA during the treatment. 1. 300 bbls YF125ST Pad 2. 100 bbls YF125ST w/ 1 ppa 16/20 Carbolite 3. 100 bbls YF125ST w/2 ppa 16/20 Carbolite 4. 240 bbls YF125ST w/4 ppa 16/20 Carbolite 5. 140 bbls YF125ST w/5 ppa 16/20 Carbolite 6. 100 bbls YF125ST w/6 ppa 16/20 Carbolite 7. Drop 18 Bioballs 8. Repeat steps 1 -7 twice more(3 total) ,e 9. 340 bbls YF125ST Pad 10. 150 bbls YF1253 /2 ppa 16/20 Carbolite 11. 300 bbls YF125S w/4 ppa 16/20 Carbolite 12. 240 bbls YF125ST w/5 ppa 16/20 Carbolite 13. 140 bbls YF125ST w/6 ppa 16/20 Carbolite 14. Drop 18 Bioballs 15. 380 bbls YF125ST Pad 16. 150 bbls YF125ST w/2 ppa 16/20 Carbolite 17. 340 bbls YF125ST w/4 ppa 16/20 Carbolite 18. 280 bbls YF125ST w/5 ppa 16/20 Carbolite 19. 100 bbls YF125ST w/6 ppa 16/20 Carbolite 20. Flush with linear fluid and freeze protect Total Sand: —540,000 lbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min if the well does not screen out. 7. Rig down equipment, (and prep for next well frac) move off location. FCO if required with slick diesel. Colville River Field CD3-128 Proposed Schematic CD3-128 Nechelik Injector Well Completion J . _ 16" HWelded MD TVD Condu65#ct-40or to el114' Upper Completion: 1)3-'/z Camco TRMAXX-5E w/ 2160' 2000' 4-1/2" 12.6#L-80 IBTM to 2.812 X Profile 110'MD/110'TVD with'/4 control line to surface, banded to tbg w/SS bands 0 sssv 2)3'/ x 1 Camco KBMG GLM w/DV(64°) 5086' 3400' 3)344 x 1 Camco KBMG GLM w/DV(64°) 9982' 5600' 9-5/8"40#L-80 BTC-M 4)344 x 1 Camco KBMG GLM w/DCK2(60°) 12287' 6733' Surface Casing Pinned for 2500 psi casing to tbg shear to 2989'MD/2452'TVD OGL J cemented to surface 5)Baker Premier Packer(60°) 12327' 6753' w/20'80-40 PBR above it TOC at least 500'MD over Top Qannik 6)HES 2.812"X Profile(61°) 12347' 6763' Top Qannik 7 3-% x 1"Camco KBMG Mandrel w/DV(61°) 12399' 6788' 6490'MD/ ) ( ) O Q, 4022'TVD 8)Carbide Blast Rings(401 12471' 6482' ES Cementer on 2 jts 3-% special clearance Hydril 563 @ 7230'MD/4360'TVD Set below Base Qannik 9)Baker 3'/: CMD w/2.812 X-profile (65°) 12547' 6856' 10)Baker Premier Packer(66°) 12601' 6879' Packer Fluid mix: Inhibited Kill weight Brine 11)HES 2.812"XN Profile w/2.75"No-Go(67°) 12628' 6889' O GL J with 2000'TVD diesel cap w/RHC plug body 12)80-40 Seal Assembly 12679' 6907' Lower Completion: 3-1/2" 9.3#L-80 EUE-8RD-M 13)Baker Flexiock Liner Hanger 12680' 6908' to 12,679'MD/6907'TVD w/20'tieback extension above it 14)TAM Swell Packer,FreeCap-I FSC-14 13060' 6988' 5.75"OD,5'Seal,w/5.875"OD Cementralizers Calculated TOC @ 11,977'MD/6582'MD 15)TAM Swell Packer,FreeCap-I FSC-14 13110' 6992' 0 TOC at least 300'MD above Packer&500' 5.75"OD,5'Seal,w/5.875"OD Cementralizers C) MD above Kuparuk C. il 16)4-% 12.6#L-80 IBT-M Liner w/Pre-Perforated 13110' 6992' 4j\2,476 Kuparuk C Perforations Pups every 350'(1St pup-100'from 2nd swell pkr) 'MD/6825 TVD to O 4* 412,496'MD/6834'TVD 17)Orange Peel Shoe 20387' 7077' 7"26#L-80to 13,010'MD/6982'TVD 4'/z 12.6#L-80 IBT-M Liner Top 165HRw/Pre-Perforated Pups every 350' DO 181 11888'MD/6539'TVD ��. to 20,387'MD/7077'TVD Top Kuparuk C 12,481'MD/6827'TVD //O ► ©r ■ 000 l0001 1000001 1000°l 1°00°1 �? _� 00 0 0 0 0 0 0 0 Top Nechelik 12,913'MD/6967'TVD 10 11 0® 1s 00 I 411 4-1/= 12.6#L-80 SLHT Liner 6-1/8 Hole,TD at From below liner hanger to 2nd at 20,387'MD/ swell packer 7077'TVD 1'.\\\ rvK pLib\ H L A �SEAN PARNELL,GOVERNOR ALASKA OIL A1VI) GAS 333 W.7th AVEENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAG ,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Nina Anderson Drilling Engineer .� ConocoPhillips Alaska, Inc. t \ �'� P.O. Box 100360c), Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-128 Sundry Number: 311-387 Dear Ms. Anderson: 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, 10.17 Daniel T. Seamount, Jr. Chair r, DATED this Z 1day of December, 2011. Encl. t , ConocoPhillips Alaska, Inc. 1PP7 Poct Offe Box 100360 a995 ConocoPhillips Anchorage,Alaska 99510-0360 Telephone 907-276-1215 December 15th, 2011 Alaska Oil andhRECEIVE:Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 DEC 16 2011 Re: Sundry Permit-- Request to Re-Enter CD3-128 (permit no. 211-037) Alaska Oii & Gas Cons. Commission Dear Sir or Madam: Anchorage ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to re-enter well CD3-128 and resume drilling • operations with Doyon Rig 19. Estimated date to resume operations on CD3-128 is January 8th, 2012. CD3-128 was suspended at the intermediate casing point due to the timing of the ice road season. The 8- 3/4" intermediate hole section was drilled with 7" intermediate casing landed and cemented in the Nechelik sand. The Kuparuk sand was perforated and an upper completion with packer was run to enable production. • Once the ice road from CD2 to CD3 is completed, Doyon 19 will move onto CD3-128 to de-complete and drill the horizontal lateral as per Permit to Drill number 211-037. The BHP of the Kuparuk is estimated to be . equal to the BHP of the Nechelik reservoir. Therefore, the Kuparuk perforations will remain open while drilling the lateral. CD3-128 will be completed as a selective single to allow comingled production from both the Kuparuk and • 6Y Nechelik reservoirs which are within the Fiord oil pool. Once completed, the well will be flowed back to mitigate reservoir damage and then hooked up to begin pre-production. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10-403 2. A proposed re-entry and de-complete program 3. CD3-128 Current Schematic 4. CD3-128 Final Schematic with proposed selective single completion Application information already on file with the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Nina Anderson at 265-6403 or Chip Alvord at 265-6120. Sincerely, / f/,/! Nina Anderson Drilling Engineer cc: CD3-128 Well File/Sharon Allsup Drake ATO 1530 Brian Noel ATO 1700 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation NTE OF ALASKA JI ' 4` . I t ' ALAS. JIL ANL .S CONSERVATION COMMIS:. A 11,7A'1I !9 .�� APPLICATION FOR SUNDRY APPROVALS t 20 AAC 25.280 a fro 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r. Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well F . Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p. Exploratory r 211-037 , 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20638-00-00• 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No F • CD3-128 i 9.Property Designation(Lease Number): 10.Field/Pool(s): ADK 25538,372105' Colville River Field/Fiord 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): 13020 6983 13010' 6980' Casing Length Size MD TVD Burst Collapse Conductor 77 16" 114' 114' Surface 2953' 9-5/8" 2989' 2452' RE EIVEDS Production 12976' 7" 13009' 6982' DEC 1 7.01 auks Gill &Gds Cons.Commission A iGti'OCtige Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12,476 6,824 3-1/2" L-80 12371 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) FHL Retrievable Packer 12,316'MD/6,748'TVD Camco,TRMaxx-5E SSSV 2,170'MD/2,008'TVD 12.Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/8/2012 Oil F • Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nina Anderson @ 265-6403 Printed Name • Nina Anderson Title: Drilling Engineer (/ Signature 4—Pd2eAV Phone:265-6403 Date 1 2"I 5--?Oil oii Commission Use Only 3( ....581 Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other: 3,"9 QST Jp 7.- T x- ow. ; .,,P P rb ( 2-11-o5? 1 S-'p J4ak 4-- 4:kl4r • Subsequent Form Required: / ó— f' ' rt pc#-*-.) O , APPROVED BY Approved by: V COMMISSIONER THE COMMISSION Date: 12-(2 Z I " Form 10-40RB MS(2)'1 2220e, GINASubmin Duplicate/2- O R �., �� /2-n0 � ,w Dovon 19 CD3-128 Re-Entry Procedure The proposed scope of work for this sundry application includes: 1. MIRU Doyon 19. 2. Circulate diesel freeze protect over to kill weight fluid. 3. Confirm well static. Set BPV. . 4. Rig up to pump down the IA to confirm a pressure test of the BPV in the direction of flow. Monitor for 30 minutes. ,-5. ND Tree. Install blanking plug. NU BOPE to 250 psi low and 3500 psi high. Test annular to 2500 psi. 6. Remove blanking plug and BPV. 7. MU fishing BHA; Spear tubing hanger and pull the upper 3-1/2"tubing from the seal assembly. 8. PU DP. MU fishing BHA with PBR retrieving tool and RIH. 9. Release packer. Circulate bottoms up prior to POOH. 10. POOH with fishing BHA and lower 3-1/2" completion with packer and PBR. 11. Pick up remainder of DP needed to drill 6.125" lateral hole section. 12. Refer to CD3-128 approved PTD (#50-103-20638-00-00)for continued operations to pick up 6.125" drilling BHA and drill the Nechelik reservoir. CD3-128 Current Schematic '-...� WNS CD3-128 fl CooCp� 8 iiips Well Attributes Max Angle&MD TI) A 5kA.111C WnA00114111nA00114111YO 1 plain . MP51ru. Inel In ro('rlrtbj An WOMAN! ....,ifl,lq 601030800 FIORD IECHELIK PROD 81.92 12,976.4 13.070.0 Cprnnml Kmrpm.) Cell. Annah10o Ella O.long n. 6'0130 11 bwalb W.'Cold-CL3-'JI in7WT.yT ORA 6850 TRDP LAR WO: I 36 80 4'36.'2077 SA..rc-PAM Annoerllon 05001 MOM End bolo Arnold/Jan LM AIcd...till Cello LIO Tap. Ray Ramon PER F6 nram 0117.2011 �el2O,N • !'dY� 501150.- Mang Ib..Nippunli 5.1 0.904{-5r 6.I crab....5015 r1.snap sump Top Thor! CONDUCT�elO.R.-.4I� 16 16.290 368 In 0 114.0 62 50 H-40 ifY RSC 42' L--I C 0 ..crplbSeo eo 0..-'511150 IIY 8._Tap OR90 I 5.1 D. (1..560 D.rlr IWO)_.50np MS L. lo .. !Plop Top hod 77 SURFACE 9518 8.921 364 2,969.0 2,461.6 3600 J-66 BTC-M CYNrg d.nipllon 50np 0.. Trim V2..Top Mil Sr Copp 1..Sol Doak 11101...50np rt.01e5... Shim Top Thr4 ,_ _____PRODUCTION 7 6.000 328 13,009.0 6,981.7 2600 LSO BTC-IA tiemTubing Strings - - - 141150 0el.cronlan Seg 0.. Mlrl50 d.. Top Pillai 5.1 MOO n..5r agar 11101...String Wt.5000.. 111150 Top Thr" 907 TUBING 31!2 2.992 306 12,3712 6,776.1 923 L-EO EUE Cowletian Details Top D.pth 11501 top loll Mont.. Top 7509) 1".01 17 In..00.0490' Conner! 10101 306 306 A131 HANGER FSK TUBING HANGER 4000 cOnW:cg 0.44av 1100 110.0 0.32 X0 R.Oxlp X0.4",;113114 632111 by 3.'1-,EUE Pin 2937 3.114 2.1096 2,0079 47.77 SAFETY VIM CALICO.TRMAXX-5E 688V wi 2.613'X'Pr0N. 2812 12,2922 5,7345 60.07 LOCATOR LOCATOR Spaced Cu D'Fuer Local.d 3000 12,2932 6,736.1 60.11 CBR 90-00 P05.lyd Bore RRLepnd*5180-40 680 4000 S.ItTY 511.V12,3109 5,747.7 60.37 PACKER FHL RETRIEVABLE PACKER 2920 I 21CP 10 12,358.5 6,709.1 60.58 NIPPLE /ES 7(N'MPPLE 2813 12,370.7 6,7748 61.02'WLEG M18 Lar 0,10011®! 9000 C1 Perforations&Slots . WHO Te/(11C1 Mu Rel Como Pn TeDnuM an 1010511111101 1116, San. aro 111.- rip. 1,606.01 Ill JI 17.175 12498 6,624.2 6.6338 Sr6.''20.11 60 IPERF Shin'w123M1109Dm Gum Notes:General&Safety '14505111 ' ' Cod05. Anlvlrlen 03.2011 - NOTE:Mint Scaemallcvs,Anna 6cnomax90 002 leo cos-TT]R 0 S I ,♦ til GAL-IT fps . I 1.1 cAS-IT 27!5 . OP . A3*10! '2200 - : MR'2SO )- � I 1 PyC4R iiiiiiii- '2314 . AMU'2 MA - WI . WlDO'31+1 -- Mandrel Details Tap 6ylh Ty - ' - ' pen POW . ITe1 InH 00 YM. ISO Ric. TRO Kw 17104'2 URIII e"..! in T�11105) 3910) �I Yrw Yell Inn 6.11 0)90 Typo Mini (PO Run ai. [.n.. I 5662.6 3389,2 63 07 CAMCO KBMG 1 PROD CMV 010.6 0100 0.0 4'292011 2 2973.3 6680.7 63.00 CAMCO 1(81110 I PROD WY 810.0 0 MO 00 41222011 3 12.736.2 6.707.8 011.81.CA/ACO KBMG I PROD OV BK 0261- OD 6.302711 ' ,O0011,10.1 A ` 31.3 MO 13.3 WD CD3-128 Proposed New Schematic with Selective Single Completion Colville River Field CD3-128 Proposed Schematic CD3-128 Nechelik Injector Well Completion 16"65#H-40 Welded1112Conductor to 114' Upper Completion: 1)3-W Camco TRMAXX-5E w/ 2160' 2000' 2.812"X Profile with Y,"control line to surface, banded to tbg w/SS bands SSS 2)3'/2"x 1"Camco KBMG GLM w/DV(64°) 5086' 3400' 3)3-W x 1"Camco KBMG GLM w/DV(64°) 9982' 5600' 9-518"40#L-80 BTC-M 4)3-W x 1"Camco KBMG GLM w/DCK2(60°) 12287' 6733' Surface Casing to 2989'MD/2452'TVD Pinned for 2500 psi casing to tbg shear O cL J cemented to surface 5)20'Seal Assembly and PBR(60°) 12307' 6744' TOC at least 6)Baker Premier Packer(60°) 12327' 6753' 500'MD over Top Qannik Top Qannik 7)HES 2.812"X Profile(61°) 12347' 6763' / 6490'MD/ a Q C) Q 4022'TVD 8)3-'A"x 1"Camco KBMG Mandrel w/DV(61°) 12399' 6788' ES Cementer @ 7230'MD/4360'TVD 9)Carbide Blast Rings(30') 12471' 6482' Set below Base Qannik 10)Baker 3-%"CMD w/2.812 X-profile (65°) 12547' 6856' 11)Baker Premier Packer(66°) 12601' 6879' Packer Fluid mix: Inhibited Kill weight Brine 12)HES 2.812"XN Profile wl 2.75"No-Go(67°) 12628' 6889' O GL J with 2000'TVD diesel cap w/RHC plug body 14)Fluted Wireline Entry Guide w/Pinned Locator 12679' 6907' Lower Completion: 3-1/2" 9.3#L-80 EUE-8RD-M 13)Baker Flexlock Liner Hanger wl Tieback 12680' 6908' to 12,679'MD/6907'TVD Sleeve(Lower Completion) 15)4-W 12.6#L-80 IBT-M Liner 12711' 6918' Calculated TOC @ 11,977'MD/6582'MD 16)4-1/2"12.6#L-80 IBT-M Liner w/Pre-Perforated 13010' 6982' TOC at least ' Pups every 350' 0 IIMD300above MD Kuparuabovek CPacker&500'. 17)Orange Peel Shoe 20387' 7028' Kuparuk C Perforations 12,476'MD/6825'TVD to % N\iiv // 12,496'MD/6 6837 6#L-80 BTC-M Q ' to 13,010'MD/6982'TVD 4-'/:"12.6#L-80 IBT-M Liner w/Pre-Perforated Pups every 350' Top HRZ / pto20,387'MD/7028'TVD 11,888'MD/6539'TVD /OTop Kuparuk C % '�� 112,481'MD/6827'TVD �` I°°ol I°°ol to°ol to°ol 10°o1 2 J Top Nechelik 12,913'MD/6967'TVD ®® 0 0 o 6-1/8"Hole,TD at at 20,387'MD/ 7028'TVD Sclec;,z Cc,.... 1- Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, December 14, 2011 12:41 PM To: 'Anderson, Nina M' Subject: RE: Sundry for CD3-128 The procedure steps as you have it written have enough detail... as you stated please include the changes to the program in your sundry application. Guy Schwartz CSS r Senior Petroleum Engineer 4—4re'~� AOGCC . . C- -s'"-) r2,�.� 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent: Wednesday, December 14, 2011 12:19 PM To: 'Anderson, Nina M' Subject: RE: Sundry for CD3-128 Nina, What are the changes to the drilling procedure and new completion due to having the Kuparuk open?. Are you going to complete the well as an injector or pre-produce the Nechilik? Kuparuk plans? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Anderson, Nina M [mailto:Nina.Anderson@conocophillips.com] Sent: Wednesday, December 14, 2011 11:52 AM To: Schwartz, Guy L (DOA) Cc: Samuel!, JG (John G) Subject: Sundry for CD3-128 Guy- Below is an outline I plan to put in the sundry application for CD3-128. In addition to the 403 and the cover letter, I also plan to attach an updated wellplan (which has the same coordinates as original PTD) along with a final completion schematic. Please review and advise if more detail is needed. Thanks. Doyon 19 CD3-128 Re-Entry Procedure The proposed scope of work for this sundry application includes: 1. MIRU Doyon 19. 2. Circulate diesel freeze protect over to kill weight fluid. 3. Confirm well static. Set BPV, 12/19/2011 Page 2 of 2 4. Rig up to pump down the IA to confirm a pressure test of the BPV in the direction of flow. Monitor for 30 minutes. 5. ND Tree. Install blanking plug. NU BOPE to 250 psi low and 3500 psi high. Test annular to 2500 psi. 6. Remove blanking plug and BPV. 7. MU fishing BHA; Spear tubing hanger and pull the upper 3-1/2"tubing from the seal assembly. 8. PU DP. MU fishing BHA with PBR retrieving tool and RIH. 9. Release packer. Circulate bottoms up prior to POOH. 10. POOH with fishing BHA and lower 3-1/2"completion with packer and PBR. 11. Pick up remainder of DP needed to drill 6.125" lateral hole section. 12. Refer to CD3-128 approved PTD(#50-103-20638-00-00)for continued operations to pick up 6.125"drilling BHA and drill the Nechelik reservoir. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907)229-4008 12/19/2011 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 16, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record/ Bottom Hole Pressure Survey: CD3-128 Run Date: 5/5/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-128 Digital Data in LAS format, Digital Log Image file . 1 CD Rom 50-103-20638-00 1 q PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 Klinton Wood@halliburton.com Date: 3 � 01-1 Signed: °al/ Halliburton Sperry Drilling 6900 Arctic Blvd Anchorage, AK 99518 August 23, 2011 AOGCC Christine Mahnken 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Sir or Madam: Subject: CD3-128 Definitive Survey Reports Enclosed are two hard copies(NAD83 and NAD27)of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Avinash.Ramjit@Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling ATTN: Avinash Ramjit 6900 Arctic Blvd Anchorage, AK 8 Oli Received by: Date:4) Please contact me at 907.263.4657with questions or concerns. Regards, Avinash Ramjit pall-- ba 2 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 16, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: CD3-128 Run Date: 5/4/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3-128 Digital Data in LAS format, Digital Log Image file g ( 'f 7 3 1 CD Rom 50-103-20638-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 Klitkrttiocom Date: JUN' 1 3 2011 Signed: A, Alaska ON&Gas Cons.commission oofl Anchorage 0‘ ? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ . Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development O • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: May 5,2011 211-037/311-148 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 April 11,2011 50-103-20638-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1254'FSL, 1205'FEL,Sec.5,T12N,R5E,UM April 22,2011 CD3-128 - Top of Productive Horizon: 8.KB(ft above MSL): 2.6'RKB 15.Field/Pool(s): 1814'FNL, 18'FWL,Sec.7,T12N,R5E,UM GL(ft above MSL): 4 49.4'AMSL i.0 Colville River Field Total Depth: 9.Plug Back Depth(MD+ND): 1919'FNL, 15'FNL,Sec.7,T12N, R5E,UM 12875'MD/6961'TVD Fiord Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: • Surface: x-387838 y- 6003753 Zone-4 , 13020'MD/6983'ND . ADL 25538,372105 TPI: x-378965 y- 6000824 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-378960 y- 6000719 Zone-4 SSSV @ 2170'MD/2008'ND LAS2112 18.Directional Survey: Yes E No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1150'MD/1142'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 36.8' 114' 36.8' 114' 42" 5.5 sx Ready Mix 9.625" 36# J-55 36' 2989' 36' 2452' 12.25" 822 sx AS LiteCrete,231 sx Class G 7" 26# L-80 34' 13009' 33' 6982' 8.75" 215 sx Class G,225 sx Class G 24.Open to production or injection? Yes ❑✓ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 12371' 12316'MD/6748'ND 12476-12496'MD 6825-6834'ND 6 spf 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. rt +c�>ul'�cr1cu� K� pu,.�( pe•A'tf ', DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED N_. el) �! el) D2 « /J ie 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) May 8,2011 flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/20/2011 12 hours Test Period--> 450 840 0 100% 2179 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 339 psi 988 24-Hour Rate-> 813 1771 0 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+ND 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. RECEIVED1 NONE J U CN 0 3 2011 RBDMS JUN 0 3 2011 Alaska Oil&nitA Cans.Wionission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ,t1Cf}ePirQB Submit original only j 1 1 e'Z' Z7 . zo .it ., -`k` g I s1t8. GEOLOGIC MARKERS(List all formations and markers ntered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1150' 1142' needed,and submit detailed test information per 20 AAC 25.071. C-30 3044' 2475' C-20 3909' 2861' K-3 6116' 3852' K-2 6494' 4022' K-1 12319' 6748' Top Kuparuk C 12477' 6825' Nechelik 12913' 6966' N/A Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nina Anderson @ 265-6403 ANa Scbr N � tIz1t \ Printed Name G.L.Alvord Title: Alaska Drilling Manager Signature / �. Phone 265-6120 Date 6 12-(�� r /+ Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 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 production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 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 interval to be separately produced,showing the data pertinent to such interval). 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 list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 WNS CD3-128 C+O i.?0Pit p5 Well Attributes Max Angle&MD TD _-- Mas ia. Wellbore APUUWI Field Name Well Stat (1Incl MD(ftKB) Act Bbn(SKS) cAnncQNl9tn v 5010320638011 FIORD NECHELIK !PROD 81.92 L 12,97644 13,020.0 Comment H2S(ppm) 1Date Annotation End Date KB-Grd(N) Rig Rohm*Data Well Q0E 9LL-4 j2B,58620111031.4o AM SSSV TRDP I', Last WO. .I 36.80 4/30/2011 "`""-�� saapetk,Acluel Annotation Depth(ftKB) End Date Annotation Last Mod. End Date Last Tag /Rev Reason:NEW WELL,GLV C/O,Pull RHC Imosbor 5/3/2011 .,..,. Casing Strings Casing Description String 0... String ID...Top(FMB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER,31-------- CONDUCTOR 16 15.250 36.8 114.0 114.0 62.50 H-40 I 1 4,. I Insulated 42" Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD) .String Wt...String...String Top Thrd SURFACE 9 5/8 8.921 36.4 2,989.0 2,451.6 36.00 J-55 BTC-M Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD) String Wt...String...String Top Thil INTERMEDIATE 7 6.000 32.8 13,009.0 6,981.7 26.00 L-80 BTC-M ITubing Strings .- i .., ,. ..,.....,_,,,.,Tubing Description Sing 0... String ID fop OMB) Set Depth(f...Set Depth(TVD) (String Wt.. String. String Top Thrd TUBING 31/2 29921 306 j_12,371.21 6775.1 I 9.20 L-80 EUE Completion Details Top Depth (TVD) Top Incl Top(ftKB) (6KB) (') /tom Dsoription Comment ID(in) 30.6 30.6 -0.12 HANGER FMC TUBING HANGER 4.000 CONDUCTOR Y.:, 110.0 110.0 0.32 XO Reducing X0,4 9a"IBTM(Box)by 3'A",EUE Pin 2.937 Insulated 421, I __... 37-n4 l i1 2,169.6 2,007.9 47.77 SAFETY VLV CAMCO,TRMAXX-5E SSSV w/2.813""X"Profile 2.812 12,290.2 6,734.6 60.07 LOCATOR LOCATOR Spaced Out fI Fully Located 3.000 12,293.2 6,736.1 60.11 SBR 80-40 Polished Bore Receptacle w/80400 0 SBE 4. 0 12,315.9 6,747.7 60.37 PACKER FHL RETRIEVABLE PACKER 2.920 SAFETVViv, 12,358.9 6,769.1 6088 NIPPLE 'HES"XN"NIPPLE 2.813 2,170 12,370.7 6,7;4.8 61.02 WLEG Wire Line Entry Guide 3.000 Notes General&Safety(:-.4' .4'2441:1'. ^_` v` x4; 8 <. End Date Annotation 5/3/2011 NOTE:View schematic w/Alaska Schematic9.0 1. �J SU36-2,969RFACE, GAS LIFT, 5,063 i ate': GAS LIFT, 9,973 1 I GAS LIFT._ t 2,235 __. '. ,,.' I. LOCATOR, 12,290 --_ . SBR,12,293 PACKE _- 12,316R. NIPPLE,12,359- Mandrel Details Top Dep1li Top 1 Port I 1 (TVD) Incl OD Valve Lath Size TRO Run WLEG,12,371 - --- Cl Model (in) Sery Type Typo (n) (p ) Run Date Corn... ICStn To. ftKB (MKB) 5,062.6 3,386263.57CAMCO KBMG 1I PROD DMY BK-5 0.000 004/29/2011 9,973.3 5,589.8 63.84 CAMCO KBMG 1 PROD DMY BKS 0.000 0.0 4/292011 12,235.2 Q708.5 60.75 CAMCO KBMG 1 PROD OV BK 0.250 0.0 5/2/2011 NTERMEDIATE, A 33-13,009 TD,13,020 ConocoPhiIIips Time Log & Summary Wenview Web Reporting Report Well Name: CD3-128 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 4/10/2011 5:00:00 PM Rig Release: 4/30/2011 12:00:00 PM Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 04/09/2011 24 hr Summary Release rig from CD3-125. Rig down and prepare for rig move. Replace rheostats for draw works and pump#2.Change out electric brake on draw works. 17:00 00:00 7.00 0 0 MIRU MOVE MOB P Prepare for rig move. Replace rheostats for draw works and pump #2. Change electric brake on draw works. Change brushes on traction motors on pump#2. 04/10/2011 Rig move. Spot rig and complexes over CD3-128 conductor. Pull power cable thru cable tray for top drive. Change air line out below rig floor.Jack rig floor over well slot.Accept rig at 17:00 hrs. Install mousehole. PU HWDP, DC's&jars. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Prepare to move rig.Move rig and complexes to CD3-128 conductor slot. Pull power cable for top drive through cable tray. 12:00 14:30 2.50 0 0 MIRU MOVE MOB P Finish pulling power cable through cable tray. Replace main air line under rig floor. Jack rig floor over CD3-128 conductor slot. Spot pit and motor complexes. 14:30 17:00 2.50 0 0 MIRU MOVE MOB P Hook up service lines. Connect rig to hi-line power at 17:00 hrs. Accept rig on CD3-128 at 17:00 hrs 4/10/2011. 17:00 18:00 1.00 0 0 MIRU DRILL RURD P Test run equipment. 18:00 23:30 5.50 0 0 MIRU DRILL PULD P Install mousehole.Move 4"DP to driller's side. PU 18 jts 5"HWDP and stand back. PU 2 NMDC&jars. 23:30 00:00 0.50 0 0 MIRU WHDBO NUND P Install riser on conductor. 04/11/2011 Finish NU riser,MU BHA#1 Spud well at 07:15 hrs. Drill to 588'MD.Surveys show well is getting very near hardline close approach to well CD3-127. POH and LD motor and MWD. RIH with UBHO above bit sub to 581'. Run gyro survey and survey out from 562'to 292'to increase survey confidence. MU bit, motor, MWD tools. RIH to 581'. Run gyro survey and survey from 562'-292'. POH. MU drilling BHA with same bit, 1.83 deg motor&MWD. 00:00 01:45 1.75 0 0 MIRU WHDBO NUND P Finish NU riser on conductor. Hook up flowline. Page 1 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 02:45 1.00 0 0 MIRU DRILL PULD P Bring BHA components to rig floor. Install battery and transmitter in ABI sub on motor. Chg Iron Roughneck heads and mud bucket rubbers. 02:45 04:30 1.75 0 0 SURFA( DRILL PULD P PJSM. PU BHA#1 with: -12.25"HTC VM-3 tri-cone bit -8"SperryDrill ABI motor -Float sub -10.75"NM Stab -MWD -Pulser -UBHO -2 x Flex collar -Jars -5"HWDP 04:30 06:00 1.50 0 0 SURFA( DRILL PULD P Upload MWD tools. Hang sheave for wireline gyro in derrick. 06:00 06:45 0.75 0 0 SURFA( DRILL PRTS P Hold pre-spud meeting with crews and service company employees. Fill riser and test lines to 3500 psi. Blow down top drive. 06:45 07:15 0.50 0 0 SURFA( DRILL PULD P MU flex collars&jars to string. 07:15 12:00 4.75 0 454 SURFA( DRILL DDRL P Spud well at 07:15 hrs. Drill out conductor and drill 12 1/4" hole from 114'to 454'MD. ADT=2.19 hrs. Footage below conductor=340'. RPM=60 GPM=450 @ 700 psi. PUW= 100k. SOW=95k. ROT=100 k. TQ ON=6 k ftlbs. TQ OFF=5 k ftlbs. 12:00 14:15 2.25 454 588 SURFA( DRILL DDRL P Drill ahead in 12 1/4"hole to 588' MD. Extrapolation of surveys indicates well may be getting close to adjacent well CD3-127 and may cross hard line if directional trend continues. 14:15 15:30 1.25 588 588 SURFA( DRILL CIRC P Circ and clean hole while discussing plan forward with Anch office. 15:30 16:30 1.00 588 85 SURFA( DRILL TRIP T Flow check well-static. POH to 85'. 16:30 18:00 1.50 85 0 SURFA( DRILL PULD T Download MWD. LD motor,MWD collar. 18:00 19:30 1.50 0 581 SURFA( DRILL TRIP T MU BHA#2-bit, bit sub, UBHO and flex collars to put gyro survey depth 19'behing bit. RIH to 581'MD. 19:30 20:30 1.00 581 581 SURFA( DRILL SRVY T Run HES gyro and survey out from 562'to 472'every 15'and from 442'to 292'every 30'. 20:30 22:15 1.75 581 0 SURFA( DRILL TRIP T Flow check well-static. POH with BHA. 22:15 00:00 1.75 0 104 SURFA( DRILL PULD T MU BHA-same as first BHA run. Upload MWD. Page 2 of 19 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 04/12/2011 24 hr Summary MU drlg BHA. RIH and wash to btm. Drill ahead from 588'to 2427'MD/2168'ND. 00:00 00:30 0.50 104 184 SURFA( DRILL TRIP T Continue making up BHA#3. 00:30 01:15 0.75 184 588 SURFA( DRILL TRIP T RIH to 547'. Run gyro survey&orient tool face. 01:15 12:00 - 10.75 588 1,198 SURFA( DRILL DDRL P Wash down from 547'to 588'. Start drilling.Survey at 634'survey depth-4.82 deg inc and 295.88 deg azi. Shows wellbore trending away from CD3-127 close approach. Continue drilling ahead to 1198'MD. Gyro surveys every stand down to 1101'. AST= 2.24 hrs.ART=2.46 hrs. ADT=4.7 hrs. Footage=610'. WOB=15/25 klbs. RPM=60. GPM=525 @ 1300 psi. String Wts: UP= 125k. SO=124k. ROT=125 k. TQ ON/OFF=6000/5500 ft lbs. 12:00 00:00 12.00 1,198 2,427 SURFA( DRILL DDRL P Drill ahead from 1198'to 2427' MD/2168'ND. ART=3.91 hrs.AST=3.14 hrs. ADT=7.05 hrs. Footage= 1229'. WOB=18/25 klbs. RPM=60. 600 gpm @ 1900 psi. String Wts: PU=140 klbs. SO=130 klbs. ROT=138 klbs. TQ ON/OFF=7500/6000 ft lbs. 04/13/2011 Drill surface hole to TD at 2999'MD/2456'ND.Circ hole clean-600 gpm @ 2100 psi. Backream out to 919'. Circ and clean hole-500 gpm @ 1250 psi. RIH to btm. Circ&weight up to 10.0 ppg. POH to run 9 5/8"casing. LD BHA. Download MWD. 00:00 05:45 5.75 2,427 2,804 SURFA( DRILL DDRL P Drilled 12 1/4"hole w/motor f/2427' to 2804'MD 2386'ND ADT-5.05 hrs=ART-3.96 hrs AST- 1.09 hrs-Footage-377' WOB 20-25 k RPM 60 GPM 600 @ 2190 psi String wt-PU 137 SO 130 ROT 135 Torque off btm.-6.5 k 05:45 06:45 1.00 2,804 2,804 SURFA( DRILL CIRC P Service rig&TD while trouble shooting problem with pump#1. Page 3 of 19 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:45 07:45 1.00 2,804 2,804 SURFA( DRILL CIRC T Circ @ 350 gpm @ 800 psi-while repairing pump#1 -cleaned out suction chamber&changed 2 seats &valves 07:45 10:30 2.75 2,804 2,999 SURFA( DRILL DDRL P Drilled 12 1/4"hole w/motor f/2804' 1/ to 2999'MD 2456'TVD ADT-1.73 hrs=ART-1.28 hrs AST- .45 hrs WOB 20-25 k RPM 60 GPM 600 @2100 psi String wt. PU137 SO 130 ROT 135 Torque off btm.-6.5 K Bumped mud wt to 9.8 ppg 10:30 11:15 0.75 2,999 2,999 SURFA( DRILL CIRC P Circ btms up @ 600 gpm @ 2100 psi w/60 rpm's-6.5 k torque-PU wt 130 SO wt 135 Rot 135 11:15 15:15 4.00 2,999 919 SURFA( DRILL WPRT P Wiper trip f/2999'to 919'w/pumps @ 600 gpm @ 1910 psi(slowed pump to 500 gpm @ 1270 psi f/ 1387'to 919')w/60 rpm's 15:15 15:45 0.50 919 919 SURFA( DRILL CIRC P Circ btms up @ 919'@ 500 gpm- Flow check well-static. Blow down top drive. 15:45 18:00 2.25 919 2,999 SURFA( DRILL TRIP P RIH f/919'to 2999'-no problems or tight spots. 18:00 19:30 1.50 2,999 2,999 SURFA( DRILL CIRC P Stage pumps up to 600 gpm and circulate while weighting up to 10 ppg for casing run. 19:30 22:30 3.00 2,999 200 SURFA( DRILL TRIP P POH for casing Minor overpulls of 10-25 klbs. Drop back down and work these areas as needed-all were cleaned up after going back down and pulling up through each one again. 22:30 00:00 1.50 200 0 SURFA( DRILL PULD P Handle BHA-LD jars,flex collars. Download MWD&LD same. 04/14/2011 RU to run 9 5/8"casing.MU shoe track. Run 72 jts casing to 2989'MD.Circ&cond mud. Pump 300 bbls LiteCrete lead and 48 bbls Class G tail slurry. Displace and get 38 bbls cmt returns to surface. NU wellhead &BOPE. PU 5"DP. 00:00 01:15 1.25 0 0 SURFA( DRILL PULD P Finish LD BHA components Break off bit. Dull grading: 1-3-BT-2-E-1/8-ER-TD. Clean&clear floor of BHA components. 01:15 02:45 1.50 0 0 SURFA(CASING RURD P Bring casing tools to rig floor and RU to run 9 5/8"surface casing. 02:45 03:00 0.25 0 0 SURFA(CASING SFTY P PJSM for running casing Page 4 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 07:15 4.25 0 1,650 SURFA(CASING RNCS P Ran 9 5/8"40#L-80&9 5/8'36# J-55 casing as follows: Float shoe (Ray Oil Tools Silver bullet)2 jts.40# L-80 casing-float collar(Halliburton Super Seal)1 jt 40# L-80 casing&1 jt 36#J-55 casing to 159'(first 4 connections made up w/BakerLoc- filled pipe&checked floats)33 jts 36#J-55 casing&3 jts 40#L-80 casing to 1650'(40 jts total in hole) Installed Bowspring centrallizers on jts.1-13&1 bowspring cent.every other jt f/#15 to#39 07:15 07:30 0.25 1,650 1,650 SURFA(CASING CIRC P Establish circulation&circ btms up- staging pup up to 6 bbls/min @ 380 psi-PU wt 125 SO wt 110 07:30 10:00 2.50 1,650 2,989 SURFA(CASING RNCS P Cont.to run 9 5/8'40#L-80 casing f/ 1650'to 2950'(72 jts total in hole) PU landing jt&FMC fluted mandrel hanger-Landed casing on landing ring w/shoetg'�2989'&Float collar @ 2911' PU wt. 160 SO wt 125 Installed 1 bowspring centralizer every other jt f/#41 to#69 10:00 10:45 0.75 2,989 2,989 SURFA(CEMEN"RURD P Rig down fill up tool&casing equipment-RU cement head&lines 10:45 12:30 1.75 2,989 2,989 SURFA(CEMEN"CIRC P Establish circulation&stage pump up to 6 bbls/min @ 430 psi-circ& condition hole&mud for cement job -final pressure 6 bbls/min @ 300 psi -Mud-10.Oppg /YP19/PV18/ Gels 10 sec.6-10 min. 11 -PU wt 160 SO wt. 142 12:30 12:45 0.25 2,989 2,989 SURFA(CEMEN"SFTY P Held pre job meeting w/crew on cement job Page 5 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:45 15:30 2.75 2,989 2,989 SURFA( CEMEN'CMNT P Cemented 9 5/8"casing as follows:, Pumped 70 bbls 10.0 ppg mud w/ nut plug&35 bbls biozan water w/ nut plug for marker w/rig pumps- µ'( Switched over to Dowell-Pumped 3 C -k bbls water-Tested lines to 3270 psi- A� 5 l Aligned valves on cement head to s_ drop bottom plug-Dropped bottom Cf�" plug w/50 bbls 10.5 ppg MudPush iR ISS @ 4.7 bbls/min @ 150 psi-Mixed& pumped lead slurry(AS Crete)@ ri 'a 11.0 ppg-pumped 290 bbls and observed nut plug marker @ shakers -pumped down surge can-300 bbls total lead pumped(822 sks)- Switched over to tail slurry(Class G w/0.2%DO46,0.3%DO65,&1% SOO1)&pumped 48 bbls(231 sks) @ 15.8 ppg-Dropped top plug w/20 bbls water f/Dowell-Switched over to rig pumps&dispalced cement w/ 202.3 bbls 10.0 ppg LSND mud @ 6 bbls/min @ 700 psi-Slowed pumps to 3.5 bbls/min for last 12.3 bbls @ 550 psi-bumped plug w/1120 psi- CIP @ 1530 hrs-Checked floats OK Full circulation&reciprocation throughout job-38 bbls 11.0 ppg cement returns to surface 15:30 17:00 1.50 2,989 2,989 SURFA(CEMEN-RURD P PJSM. RD cement head&lines. Clear floor. LD landing jt. 17:00 18:00 1.00 2,989 2,989 SURFA(WHDBO RURD P ND riser and bell nipple. 18:00 21:30 3.50 2,989 2,989 SURFA(WHDBO NUND P PJSM. NU FMC wellhead and orient same. Test metal-to-metal seal to 1000 psi for 10 min-OK. NU BOPE. 21:30 22:15 0.75 2,989 2,989 SURFA( DRILL RURD P Install mousehole. PU bails and elevators. 22:15 00:00 1.75 2,989 2,989 SURFA( DRILL PULD P LD 2 stands 5"HWDP from derrick. Start picking up 5"DPand MU stands via mousehole for 8 3/4"hole section. 04/15/2011 PU total of 85 stds 5"DP via mousehole. Pull wear bushing&set test plug.Test BOPE to 250/3500 psi. Pull test plug&install wear bushing. 00:00 04:30 4.50 2,999 2,999 SURFA( DRILL PULD P Continue PU 5"DP via mousehole. 04:30 05:00 0.50 2,999 2,999 SURFA( RIGMN1 SVRG P Service rig-TD&draw works 05:00 09:15 4.25 2,999 2,999 SURFA( DRILL PULD P Continue to PU 5"DP f/shed& stand back in derrick(85 stds total) 09:15 09:30 0.25 2,999 2,999 SURFA(WHDBO SFTY P PJSM on rigging up for BOP test 09:30 10:45 1.25 2,999 2,999 SURFA(WHDBO RURD P RU for BOP test-,Changed rubber on test plug-Set test plug-Change out water valve for test pump 10:45 11:00 0.25 2,999 2,999 SURFA(WHDBO SFTY P PJSM on BOP testing Page 6of19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 14:00 3.00 2,999 2,999 SURFA(WHDBO BOPE P Test annular preventer to 250/2500 psi for 5 min each test.Adjust turnbuckles on BOP stack. 14:00 16:30 2.50 2,999 2,999 SURFA(WHDBO BOPE T Start test on rams and choke manifold. Observed slight drip at clamp connection between wellhead&BOP stack. Attempt to tighten clamp connector segments&re-test-no success. ND and lift BOP stack off wellhead. Found small metal debris in ring groove.Chg out API ring&clean ring groove. NU stack&tighten clamp connector. 16:30 21:30 5.00 2,999 2,999 SURFA(WHDBO BOPE P Test BOPE as follows: Choke manifold valves 1-16. 4"standpipe valve. AO I TIW valve,dart sub.Auto&manual IBOP. Upper&lower VBR's. Blind rams. Annular preventer. Hydraulic&manual K&C line valves. BOP and choke manifold components tested to 250/3500 psi for 5 min ea test. Used 5"test jt on pipe ram tests. 21:30 22:30 1.00 2,999 2,999 SURFA(WHDBO BOPE P Flush gas buster.Circ thru hydraulic &manual chokes and close each one to verify they are operational by observing pressure increase on pump gauge. Function BOP control panel in motor complex. Blow down lines. Witnessing of test waived by Bob Noble AOGCC Had problem w/methane gas sensor in pit room.Will monitor with hand held gas meter until parts can be shipped and sensor repaired- Contacted Bob Noble with AOGCC about problem 22:30 23:00 0.50 2,999 2,999 SURFA(WHDBO BOPE P Unseat&pull test plug. Install wear bushing. 23:00 00:00 1.00 2,999 2,999 SURFA( DRILL PULD P PU handling equipment. PJSM. MU motor BHA#4 with 8 3/4" HTC HCD605Z PDC bit. 04/16/2011 MU BHA#4. PU 60 jts 5"DP to—2670'.CBU.Test 9 5/8"casing to 2500 psi for 30 min-OK. Wash down to 2880'. Drill out shoe track and 20'new hole to 3019'MD/2465'ND. Circ&cond mud to 9.7 ppg in/out. Perform FIT to 790 psi over 9.7 ppg MW. Leak off at 15.9 ppg EMW. Displace well to new 9.6 ppg LSND mud. Drill ahead with motor assembly to 4023'MD. 00:00 01:00 1.00 114 114 SURFA( DRILL PULD P Continue to MU BHA#4 01:00 01:45 0.75 114 114 SURFA( DRILL OTHR P Plug in&up load MWD Page 7 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 02:30 0.75 114 144 SURFA( DRILL PULD P Continue to MU BHA#4-PU 1 NM flex DC to 144'-Shallow pulse test MWD tools @ 500 gpm @ 900 psi 02:30 03:00 0.50 144 144 SURFA( DRILL OTHR P PJSM on laoding RA sources-Load RA sources in MWD tools 03:00 03:45 0.75 144 761 SURFA( DRILL PULD P Cont.MU BHA#4-PU 2 NM flex DC's-HWDP-Jars-RIH w/HWDP to 761' 03:45 05:30 1.75 761 2,625 SURFA( DRILL TRIP P RIH w/BHA#4-picking up remaining 60 jts of 5"DP f/pipe shed to 2625'-PU wt 145 SOwt120 05:30 06:00 0.50 2,625 2,625 SURFA( DRILL CIRC P Circ btms up @ 2625'for casing test @ 500 gpm @ 1320 psi 06:00 07:30 1.50 2,625 2,625 SURFA( DRILL PRTS P RU&test 9 5/8"casing to 2500 psi, _for 30 mins.-RD&blow down lines 07:30 09:00 1.50 2,625 2,625 SURFA( RIGMNT SVRG P PJSM on slip&cut of drill line-Slip &cut drill line&Service rig 09:00 09:30 0.50 2,625 2,880 SURFA( DRILL WASH P Wash down f/2625 to 2880'@ 500 gpm @ 1320 psi w/40 rpm's- Torque 8 k 09:30 10:45 1.25 2,880 2,999 SURFA(CEMENT.DRLG P Drill shoe track-Drill cmt f/2880'to 2911'Drilled float collar to 2912'- Drilled cmt to 2987'-Drilled float shoe to 2989'-Clean out rat hole to 2999' 10:45 11:00 0.25 2,999 3,019 SURFA( DRILL DRLG P Drill 20'-8 3/4"hole w/motor to 3019'MD 2464'ND ECD-10.10 ppg ADT-.12 hrs WOB 8/10 k RPM 40 GPM 550 @ 1550 psi 11:00 11:30 0.50 3,019 3,019 SURFA( DRILL CIRC P Circ hole clean for FIT/LOT @ 550 gpm @ 1550 psi w/40 rpm's-torque 8.5 k 11:30 12:30 1.00 3,019 3,019 SURFA( DRILL LOT P RU&perform FIT-Pressured up to 790 psi w/9.7 ppg mud @ 2452' ND-observed leak-off-Shut in& monitor pressure for 10 mins.-Bled off pressure&RD test equipment EMW-15.9 pp Page 8 of 19 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12:30 00:00 11.50 3,019 4,023 INTRM1 DRILL DDRL P Drilled 8 3/4"hole w/motor f/3019' to 4023'MD/2914'TVD. Drilling Parameters: AST=0.64 hrs.ART=5.43 hrs. ADT=6.07 hrs. Footage=1004'. ECD=10.7 ppg. WOB=8-13 klbs. RPM=90-100. 650 gpm @ 1780 psi. String Wts: PUW=160 klbs. SOW= 130 klbs. ROT=145 klbs. TQ ON/OFF=9500/8000 ft lbs. BHA has slight LH walk tendency. Pump hi-vis sweeps w/nutplug at 3333',3650'and 3930'which brought back a significant additional amount of cuttings. Changed over to 9.6 ppg LSND mud while drilling f./3019'to 3088' 04/17/2011 Drilling 8 3/4"hole from 4023'to 6183'MD. 00:00 12:00 12.00 4,023 5,144 INTRM1 DRILL DDRL P Drilled 8 3/4"hole w/motor f/4023' to 5144'MD 3422'TVD ADT-7.03 hrs=ART-5.92 hrs AST- 1.11 hrs ECD-11.3 ppg Footage-1121' WOB 8/12 k RPM 100 GPM 675 @ 2260 psi String wt. PU170 SO 134 ROT 150 Torque on/off btm.-10.5/9.5 k 12:00 00:00 12.00 5,144 6,183 INTRM1 DRILL DDRL P Drilled 8 3/4"hole w/motor f/5144' to 6183'MD/3820'ND. Drilling parameters: ART=5.91 hrs.AST=0.54 hrs. ADT=6.45 hrs. Footage=1039'. ECD=11.3 ppg. WOB=5-15 klbs. RPM=100. 675 GPM @ 2340 psi. String Wts: PUW=175 klbs. SOW=150 klbs. ROT=165 klbs. TQ ON/OFF BTM=10000/8500 ft lbs. 275 bbl whole mud dilutions at 4790', 5460',6030'to maintain MBT<20. Sweeps every 3 stands are bringing back significant additional cuttings. Page 9 of 19 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 04/18/2011 24 hr Summary Drilling 8 3/4"hole from 7317'to 8451'MD/4874'TVD. 00:00 12:00 12.00 6,183 7,317 INTRM1 DRILL DDRL P Drilled 8 3/4"hole w/motor f/6183' to 7317'MD 4399'TVD ADT-7.10 hrs=ART-5.79 hrs. AST-1.31 hrs. ECD-11.0 ppg Footage-1134' WOB 8/12 k RPM 100 GPM 675 @ 2200 psi String wt. PU 184 SO 159 ROT 170 Torque on/off btm.-10/8 k ft/lbs 275 bbl whole mud dilutions at 6515' and 7265. 12:00 00:00 12.00 7,317 8,451 INTRM1 DRILL DDRL P Drill 8 3/4"hole from 7317'to 8451' MD/4874'TVD. Footage= 1134'. Drilling Parameters: ART=5.47 hrs.AST=1.78 hrs. ADT=7.25 hrs. ECD=11.0 ppg. WOB=8-12 klbs. RPM=100. 675 GPM @ 2450 psi. String Wts: PUW=203 klbs SOW= 164 klbs. ROT=185 klbs. TQ ON/OFF BTM=11000/10000 ft lbs. ECD has been holding in the 10.9 to 11.0 ppg range. 04/19/2011 Drilled 8 3/4"hole w/motor f/8451'to 10,531'MD/5,842'ND 00:00 12:00 12.00 8,451 9,491 INTRM1 DRILL DDRL P Drilled 8 3/4"hole w/motor f/8451' to 9491'MD 5372'ND ADT-6.23 hrs.=ART-5.18 hrs. AST-1.05 hrs. ECD-11.1 ppg Footage-1040' WOB 10/15 k RPM 100 GPM 675 @ 2450 psi String wt. PU 223 SO 168 ROT 192 Torque on/off btm.-14/13.5 k ft/lbs. Page 10 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 00:00 12.00 9,491 10,531 INTRMI DRILL DDRL P Drilled 8'/."Hole f/9,491'to 10,531' MD ADT 6.72,AST 2.12,ART 4.6 P/U 240,S/O 170, Rot 203 Torque On/Off 17/17 670 GPM @ 2570 Psi RPM 100;WOB 10-14 ECD 10.8 PPGE SPR's at 10,247'MD#1 30-330, 40-390/#2 30-330,40-390 04/20/2011 Drilled 8 3/4"hole w/motor f/10,531'to 11,476'-Circ 3X btms up-standing back 4 stds DP to 11,098'-Flow ck(static)-Wiper trip f/11,098'to 4,743'MD;Wiped Through the Following Spots 10,912, 10,862, 10,153, 10,086, 10,052,8,003,7,036,6,775,6,530 and 5,590'MD-Unable to Wipe Through Spot @ 4,743'MD- Stage Pump Up f/2 BPM U 8 BPM w/40-70 RPM-Worked/Reamed Stand f/4,766 to 4,672 MD; Stalled Top Drive and Pulled Tight Several Times Appeared to be Cuttings Beds-RIH U 4,766'MD-Staged Pumps Up U 13 BPM-Pump High Vis Nut Plug Sweep-Significant Increase in Cuttings Size and Quantity 00:00 11:30 11.50 10,531 11,476 INTRM1 DRILL DDRL P Drilled 8 3/4"hole w/motor f/10,531' to 11,476'MD 6338'ND ADT-6.41 hrs.=ART-1.86 AST- 4.55 hrs ECD-10.9 ppg Footage-945' WOB 10/14 k RPM 100 GPM 690 @ 2710 psi String wt. PU 255 SO 177 ROT 212 Torque on/off btm.-18/18 k 11:30 14:30 3.00 11,476 11,098 INTRM1 DRILL CIRC P Circ 3 X btms up @ 690 gpm @ 2300 psi w/75 rpm-PU wt.SO wt 177-Torque 17-Pumped hi-vis sweep(observed very little increaes in cuttings when sweep came back) stood back 4 stds DP while circulating to 11,098'-Flow ck(well static-Blow down TD 14:30 21:30 7.00 11,098 4,743 INTRM1 DRILL WPRT P Conduct Wiper Trip f/11,098'to 4,743'MD; Pulled 25K Over P/U and Wiped Through the Following Spots 10,912, 10,862, 10,153, 10,086, 10,052,8,003,7,036,6,775,6,530 and 5,590'MD-Pulled Into Hard Spot @ 4,743'MD, Pulled Up to 50K Over(Unable to Wipe Through) 21:30 00:00 2.50 4,743 4,672 INTRM1 DRILL CIRC P Stage Pump Up f/2 BPM U 8 BPM w/50-70 RPM-Worked/Reamed Stand f/4,766 to 4,672 MD;Stalled Top Drive and Pulled Tight Several Times but Appeared to be Cuttings Beds-RIH U 4,766'MD-Staged Pumps Up U 13 BPM w/70 RPM- Pump High Vis Nut Plug Sweep- Significant Increase in Cuttings Size and Quantity-Blow Down Top Drive- OWFF(Static) Page 11 of 19 • Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 04/21/2011 24 hr Summary Continue Wiper Trip; POOH on Elevators f/4,672'to 3,275'MD-Stage Pumps Up and Work Through Sticky Hole f/3,275'to 2,997'MD-Circulate High Vis/Nut Plug Sweep; Noted Increased Cuttings Quantity-OWFF (Static)-RIH on Elevators U 11,381'MD-Precautionary Wash/Ream U 11,476'MD-Displace Mud w/10.5 PPG Mud w/Glydril Additive-Drill 8'/:'Hole f/11,476'to 12,068'MD 00:00 01:00 1.00 4,672 3,275 INTRM1 DRILL WPRT P Continue to POOH on TT f/4,766'to 3,275'MD;Wiped Tight Spots @ 4,438',3,743'to 3,717'MD(Hole Pulled Tight Unable to Wipe Through @ 3,275'MD) 01:00 03:00 2.00 3,275 2,997 INTRM1 DRILL REAM P Stage Pumps Up U 8 then 13 BPM w/50 RPM-Wash/Ream Tight Hole f/3,275'to 2,997'MD(Casing 8'Out of Casing Shoe);Significant Increase in Cuttings Quantity(Small Size) 03:00 03:30 0.50 2,997 2,997 INTRM1 DRILL CIRC P Circulate High Vis, Nut Plug Sweep @14BPM w/1280 Psi-Vast Increase in Cuttings Quantity and Size w/Sweep Return 03:30 03:45 0.25 2,997 2,997 INTRM1 DRILL OWFF P OWFF(Static)-Change Elevators 03:45 10:00 6.25 2,997 11,381 INTRM1 DRILL WPRT P RIH on TT f/2,997'to to 11,381'-no problems-filled pipe every 20 stds- PU wt.260 SO wt 170 10:00 10:30 0.50 11,381 11,476 INTRM1 DRILL WASH P Break circulation&wash down f/ 11,381'to 11,476'@ 650 gpm @ 2560 psi w/60 rpm's-15 k torque 10:30 13:30 3.00 11,476 11,476 INTRM1 DRILL CIRC P Circ&condition mud for drilling HRZ &on to TD-added Glydrill @ black product dilution @ 650 gpm @ 2980 psi-wt. up to 10.5 ppg-Stand back DP to 11,381'-RIH f/11,381'to 11,476'-Obtain SPR's 13:30 00:00 10.50 11,476 12,068 INTRM1 DRILL DDRL P Drilled 8 3/4"hole w/motor f/11.476' to 12,068'MD; Noted Increased Pressure and Torque on Back Ream at 11,985'MD-Double Back Ream Spot ADT 5.64,AST 2.68,ART 2.96 P/U 265, SIO 180, Rot 216 Torque On/Off 16.5/14 630 GPM @ 3330 Psi; ECD 11.8 PPGE WOB 12-18; RPM 100 SPR's#1 30-430/40-510-#2 30-410/40-500 04/22/2011 Drilled 8 3/4"hole w/motor f/12,068'to 13,020'MD(TD)-CBU X3-Pump 11.8 PPG Weighted Sweep-CBU X1 -Perform Wiper Trip to 11,696'MD-Begin Staging Pumps Up to Circ and Condition Mud Page 12 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 12:00 12.00 12,068 12,705 INTRM1 DRILL DDRL P Drilled 8 3/4"hole w/motor f/12,068' to 12,705'MD 6917'TVD ADT-6.66 hrs. =ART-3.36 hrs AST-3.30 hrs. ECD-11.6 ppg Footage-637' WOB 8/12 k RPM 95 GPM 630 @ 3440 psi String wt.-PU 280 SO 177 ROT 220 Torque on/off btm.-18.5/11.5 k Pumping nut plug sweeps to aid sliding Geo pick's-Base of HRZ-12,215' MD 6698'ND-K-1 marker-12,319' MD 6748'ND-Kup"C"12,481'MD 6826'ND 12:00 18:30 6.50 12,705 13,020 INTRM1 DRILL DDRL P Drilled 8 3/4"hole w/motor f/12,705' to 13.020'MD 6983'ND(TD) ADT 3.32,ART.48,AST 2.84 P/U 285,S/O 175, Rot 220 Torque On/Off 18/17 RPM 100;WOB 14 630 GPM @ 3360 Psi ECD 11.6 Geo pick's-Top of Nechelik-12 913' MD 6965.9'TVD 18:30 21:30 3.00 13,020 13,020 INTRMI DRILL CIRC P Circulate Bottoms Up X3, Pump Weighted(11.8 PPG)Viscosified Sweep,and 1 Additional Bottoms Up @ 610 GPM w/3400 Psi and 40 RPM 21:30 23:45 2.25 13,020 11,696 INTRMI DRILL WPRT P Perform Wiper Trip to 11,696'MD(2 Stands Above the Top of the HRZ)- Minor Tight Hole @ Bit Depth 11,886' MD(Top of HRZ); Pulled 20 Over 23:45 00:00 0.25 11,696 11,696 INTRMI DRILL CIRC P Stage Pumps Up t/605 GPM- Pump Viscosified Sweep and CBU X2 04/23/2011 Continue to CBU X2-RIH t/12,641'MD-MAD Pass f/12,641'to 11,975'MD-RIH V 12,926'MD-Wash Down V 13,020'MD(Precautionary)-Circulate and Condition Mud While Increasing MW t/11.5 PPG-OWFF (Static)-POOH Spotting WBS Pill f/13,020'to 11,760'MD(Tight Spot @ Top of HRZ 11,886'MD)-OWFF (Static)-POOH on Elevators f/11,760'to 4,492'MD;Wiped Numberous Tight Spots 00:00 01:45 1.75 11,696 11,696 INTRM1 DRILL CIRC P Continue circ&condition mud 2 X pumps up-@ 600 gpm @ 2900 psi w/60 rpm's-16 k torque-ECD-11.3 .PP9 01:45 02:30 0.75 11,696 12,641 INTRM1 DRILL WPRT P RIH f/11,696'to 12,641'-No problem 02:30 07:30 5.00 12,641 11,975 INTRM1 DRILL SRVY P MAD pass f/12,641'to 11,975'- pumping 2 bbls/min @ 320 psi w/20 rpm's-16.5 k torque 07:30 08:00 0.50 11,975 12,926 INTRM1 DRILL TRIP P RIH f/11.975'to 12,926'-PU wt 280 SO wt 170-No problems Page 13 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:15 0.25 12,926 13,020 INTRMI DRILL WASH P Wash down f/12,926'to 13,020'- staging pump up to 600 gpm @ 2780 psi @ 60 rpm's-16.5 k torque 08:15 13:00 4.75 13,020 13,020 INTRM1 DRILL CIRC P Circ&wt up f/10.5 ppg to 11.5 ppg for hole stability for running 7"casing 13:00 15:15 2.25 13,020 11,760 INTRMI DRILL TRIP P POOH Spotting WBS Pill f/13,020' to 11,760'MD-3 BPM @ 350 Psi 15:15 15:30 0.25 11,760 11,760 INTRMI DRILL OWFF P OWFF(Static) 15:30 00:00 8.50 11,760 4,492 INTRM1 DRILL TRIP P POOH on Elevators f/11,760'to 4,492'MD Wiped Through the Following Tight Spots: 11,886'(Top of HRZ), 10,734', 9,452',9,300',9,220',9,064',8,994', 8,684',8,606',7,827',6,890',6,775', 6,435',5,650',5,555',5,520',5,092', 5,030',4,995',4,964'MD 04/24/2011 Continue to POOH f/4,492'to 2,997'MD;Wiped Tight Spots-OWFF(Static)Pump Viscosified Sweep- OWFF(Static)-POOH f/2,997'to 206'MD-UD BHA#4-Flush BOPE Stack-Slip and Cut Drill Line- Change Upper Rams t/7"Solid Body-Test Upper Rams t/250/3500 Psi-R/U and Run 7"Casing t/5,131' MD; Stopping to Circulate @ 170',2,971'and 5,131'MD 00:00 00:45 0.75 4,492 2,997 INTRMI DRILL TRIP P POOH f/4,492'to 2,997'MD-P/U 135,S/O 124 Wiped Through Tight Spots:4,390', 4,295',4,216'and 3,960'MD 00:45 01:45 1.00 2,997 2,997 INTRM1 DRILL CIRC P Stage Pumps Up t/575 GPM w/ 1860 Psi and Rotated 40-60 RPM- Pump Viscosified Nut Plug Sweep Around;Moderate Increase in Cuttings Size and Quantity 01:45 02:00 0.25 2,997 2,997 INTRM1 DRILL OWFF P Blow Down the Top Drive and Monitor the Well(Static) 2,997 INTRM1 DRILL TRIP P POOH f/2,997'to 02:00 03:15 1.25 206 176 INTRM1 CASING PULD P LD 2 NM flex DC's-PJSM on RA sources-Remove RA sources f/ MWD-LD NM flex DC to 176' 03:15 04:15 1.00 176 176 INTRMI CASING OTHR P Plug in&down load MWD data 1 2 176 0 INTRMI CASING PULD P Finish lain down BHA 04:15 05:30 5 laying 05:30 06:00 0.50 0 0 INTRM1 CASING OTHR P Clean up rig floor&remove BHA tools from rig floor 06:00 06:30 0.50 0 0 INTRMI CASING OTHR P MU stack washer&flush BOP stack @ 10 bbls/min @ 160 psi-function rams-LD stack washer 06:30 08:00 1.50 0 0 INTRM1 CASING SLPC P PJSM-Slip&cut drill line-service TD 08:00 09:00 1.00 0 0 INTRM1 WHDBO OTHR P_Changed top pipe rams f/VBR to 7" , solid body 09:00 11:00 2.00 0 0 INTRM1 WHDBO PRTS P Pull wear bushing-set test plug- RU test equipment-Test upper pipe rasm to 250&3500P si-RD tes equipment-Pull test plug set thin wall wear bushing 11:00 12:15 1.25 0 0 INTRM1 CASING RURD P RU to run 7'casing Page 14 of 19 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12:15 12:30 0.25 0 0 INTRM1 CASING SFTY P PJSM on running 7"casing 12:30 13:00 0.50 0 170 INTRMI CASING RNCS P Ran 7"26#I-RO BTC-mod casino as follows: Float shoe(Ray Oil Tools silver bullet)2 jts casing-float collar (Halliburton Super Seal II w/baffle adaptor installed) 1 jt casing-Baffle collar(Halliburton)1 jt casing(first 4 jts made up w/BakerLoc-filled pipe &checked floats)to 170' 13:00 16:15 3.25 170 2,971 INTRM1 CASING RNCS P Continue to Run 7"Casing f/170'to 2,971'MD(69 Jts in Hole) P/U 130,S/O 124 16:15 17:15 1.00 2,971 2,971 INTRM1 CASING CIRC P Stage Pumps up U 5 BPM @ 270 Psi and Circulate Casing Volume 17:15 20:15 3.00 2,971 5,131 INTRM1 CASING RNCS P Continue to Run 7"Casing f/2.971' to 5,131'MD(120 Jts of 302 In Hole) P/U 165,S/O 130 20:15 21:00 0.75 5,131 5,131 INTRM1 CASING CIRC P Stage Rate Up U 5 BPM @ 370 Psi and CBU 21:00 00:00 3.00 5,131 5,561 INTRM1 CASING RNCS P Continue to Run 7"Casing f/5,131' to 5,561'MD(130 Jts of 302 In Hole) P/U 175,S/O 132 04/25/2011 Continue to Run 7"Casing f/5,561'to 13,010'MD;Stopping to CBU @ 7,282',9,440',and 11,594'MD-R/U Cement Head and Circulate and Condition Mud to Lower YP to<20 and MW to 11.3 PPG-Cement Intermediate Casing Shoe(1st Stage)w/45.6 Bbls 15.8 PPG Class G Cement; ETOC 11,977'MD 00:00 02:15 2.25 5,561 7,287 INTRMI CASING RNCS P Continue to Run 7"Casing f/5,561' to 7,287'MD(170 Jts of 302 In Hole) P/U 205,S/O 138 02:15 03:30 1.25 7,287 7,282 INTRM1 CASING CIRC P Stage Rate Up to 5 BPM w/450 Psi and CBU 03:30 07:00 3.50 7,282 9,440 INTRM1 CASING RNCS P Continue to Run 7"Casing f/7,282' to 9440'(220 jts of 302 to run) PU wt.247 SO wt 147 07:00 08:45 1.75 9,440 9,440 INTRM1 CASING CIRC P Stage pump up to 5 bbls/min @ 460 psi&circ btms up 08:45 12:00 3.25 9,440 11,594 INTRMI CASING RNCS P Continue RIH w/7"26#L-80 BTC-mod casing f/9440'to 11,594' (270 jts of 302 to run) PU wt.290 SO wt-155 12:00 14:00 2.00 11,594 11,594 INTRM1 CASING CIRC P Stage pump up to 5 bbls/min @ 540 psi-circ btms up+conditioning mud 14:00 17:00 3.00 11,594 13,010 INTRM1 CASING RNCS P Continue RIH w/7"26#L-80 BTC mod casing f/11594'to 12973'(302 jts total in hole)PU FMC fluted mandral hnager&landing jt.- Landed casing on hanger in wellhead w/shoe @ 13,009.79'-Fc @ 12,922.79'-Baffle collar @ 12,880.82'-Stage collar @ 7230.34' 17:00 17:30 0.50 13,010 13,010 INTRM1 CEMEN.RURD P R/U Cement Head and Lines Page 15 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 21:30 4.00 13,010 13,010 INTRMI CEMEN"CIRC P Circulate and Condition Mud Until YP <20;MW 11.3 PPG-SIMOPS: Hold PJSM for First Stage Cement Job 5 BPM @ 650 Psi 194- 21:30 SX21:30 22:30 1.00 13,010 13,010 INTRMI CEMEN"CMNT P Pump 1st Stage Cement as Follows: Pump 2 Bbls CW 100-Pressure Test Surface Lines V 3700 Psi- Pump 30 Bbls 8.4 PPG CW 100 @ 4 BPM w/500 Psi-Pump 30 Bbls 12.5 PPG Mud Push @ 4.5 BPM w/ 550 Psi-Pump 45.6 BBIs 15.8 PPG Class G Cement w/Additives-Pump 20 Bbls Water Behind Top Plug 22:30 00:00 1.50 13,010 13,010 INTRMI CEMEN"DISP P Begin Displacing Cement Fluid Train w/11.3 PPG Mud @ 5 BPM w/600 Psi-Slowed Pumps to 3 BPM w/ 530 Psi w/468 BBIs of Mud Pumped -Bumped Plug @ 474 Bbls-Held 1150 Psi f/5 Minutes-Checked Floats(Good)-CIP 0005 4/26/2011 04/26/2011 Open HES Cementer-CBU Through Open Stage Collar-Cement Qannik w/46.5 Bbls Class G Cement w/ Additives(CIP @ 0255)-Install and Test 7"Pack Off V 5,000 Psi f/10 minutes-L/D 5"DP-Change Upper Rams and Test Upper, Lower and Annular w/3%2'and 4"Test Joints-Continue to L/D 5"DP 00:00 00:30 0.50 13,010 13,010 INTRM1 CEMEN"RURD P Pressusre Up to 3540 Psi to Open Stage Collar-R/U for Second Stage -Load Closing Plug 00:30 01:15 0.75 13,010 13,010 INTRMI CEMEN"CIRC P CBU Through Open HES Cementer @7BPM w/450 Psi 01:15 02:15 1.00 13,010 13,010 INTRMI CEMEN"CMNT P PJSM on Second Stage Cementing- Cement Second Stage as Follows: Pump 31.8 Bbls CW 100 @ 3.5 BPM w/280 Psi, Pump 27.3 Bbls 2 12.5 PPG Mud Push @ 4 BPM w/ st—Y2' 330 Psi, Pump 46.5 Bbls 15.8 PPG Class G Cement w/Additives @ 5.3 BPM w/300 Psi, Drop Closing Plug, Pump 20 Bbls Wash Water Behind Plug 02:15 03:00 0.75 13,010 13,010 INTRMI CEMEN"DISP P Displace Cement w/259 Bbls of 11.3 PPG Mud @ 7 BPM w/390 to 520 Psi;Slowed Rate V 4 BPM w/320 Psi w/245 Bbls Pumped-Observed Plug Land-Increased Pressure to 2000 Psi to Close Stage Collar- Release Pressure-Verify Stage Collar Closure-OWFF(Static)-CIP @ 0255 03:00 06:00 3.00 13,010 13,010 INTRM1 CEMEN"RURD P R/D Cementing Equipment-L/D Landing Joint-Change Bales& Elevators-Install Wear Ring- SIMOPS: Install Pack Off in Well Head and Test V 5,000 Psi f/10 Minutes 06:00 12:45 6.75 0 0 INTRM1 DRILL PULD P LID 5"DP Via the Mouse Hole Page 16 of 19 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12:45 13:45 1.00 0 0 INTRMI WHDBO SEQP P Hold PJSM and Change Upper Rams t/31/2'by 6"Variable Rams 13:45 14:15 0.50 0 0 INTRMI RIGMNTSVRG P Service Rig 14:15 15:00 0.75 0 0 INTRM1 RIGMNT RGRP T Work on Top Drive Brushes 15:00 17:30 2.50 0 0 INTRMI WHDBO BOPE P Test Upper/Lower Rams and Annular w/3%"and 4 Test Joint t/250/3500 Psi and 250/2500 Psi 17:30 00:00 6.50 0 0 INTRM1 DRILL PULD P Continue to UD 5"DP via the Mouse Hole 04/27/2011 Continue to L/D 5"DP Using the Mouse Hole-M/U 6 1/8"Clean Out BHA and Single-In-Hole t/7,061'MD- Pressure Test Casing Above Stage Collar t/1,000 Psi f/10 Minutes-RIH then Wash Down U 7,199'MD- Clean Out Stage Collar and Wash Down t/7,632'MD-Continue to RIH on 4"DP U 12,765'MD-Wash Down and Clean out Cement t/12,875'MD-CBU X2-Test 7"Casing U 3,500 Psi f/30 Minutes(Charted)- Displace Well f/11.2 PPG WBM to 9.6 PPG Brine-POOH f/12,875'to 12,595'MD 00:00 00:45 0.75 0 0 INTRMI CEMEN"PULD P Continue to L/D 5"DP via the Mouse Hole 00:45 02:00 1.25 0 0 INTRMI DRILL RURD P Change Saver Sub, Iron Roughneck Dies and Elevators 02:00 02:15 0.25 0 0 INTRMI DRILL PULD P P/U 6 Jts of 4"DP and Stand Back 02:15 02:45 0.50 0 0 INTRM1 DRILL PULD P M/U Clean Out BHA: Bit, Bit Sub, Stabilizer,XO 02:45 10:00 7.25 0 7,061 INTRMI DRILL TRIP P RIH w/Clean Out Assembly to 7,061' MD P/U 168,S/O 115 10:00 10:45 0.75 7,061 7,061 INTRMI DRILL PRTS P Pressure Test Casing t/1,000 Psi f/ 10 Minutes 10:45 11:00 0.25 7,061 7,156 INTRM1 DRILL TRIP P Continue to RIH t/7,156'MD 11:00 14:45 3.75 7,156 7,632 INTRM1 CEMEN"COCF P Wash Down to 7,199'MD-Tagged Cement-Clean Out Cement Through Stage Collar V 7,234'MD-Wash& Ream t/7,632'MD 7 BPM w/1400 Psi and 100 RPM 14:45 18:30 3.75 7,632 12,785 INTRMI DRILL TRIP P RIH U 12,785'MD 18:30 19:00 0.50 12,785 12,875 INTRM1 DRILL WASH P Wash Down U 12,875'MD(Found Qood Cement) 7 BPM @ 2600 Psi and 100 RPM 19:00 20:30 1.50 12,875 12,875 INTRM1 DRILL CIRC P CBU X2 @ 8 BPM w/3100 Psi and 100 RPM 20:30 21:30 1.00 12,875 12,875 INTRM1 DRILL PRTS P Tested 7"Casing t/3500 Psi f/30 Minutes 21:30 23:00 1.50 12,875 12,875 INTRM1 DRILL CIRC P PJSM then Displace Well f/11.2 PPG WBM to 9.6 PPG Bine @ 6 BPM w/2000 Psi and 80 RPM 23:00 00:00 1.00 12,875 12,595 INTRM1 DRILL TRIP P POOH f/12,875'to 12,595'MD 04/28/2011 POOH f/12,595'to 10'MD-UD Clean Out BHA-R/U and Run 3 1/2'Completion Tubing U 12,259'MD(384 Jts+Jewelry) 00:00 04:00 4.00 12,595 10 INTRM1 DRILL TRIP P Continue to POOH f/12,595'to 10' MD 04:00 04:15 0.25 10 0 INTRM1 DRILL PULD P UD Clean Out BHA Page 17 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:15 05:45 1.50 0 0 INTRM1 RPCOM RURD X Pull Drilling Wear Ring and Install Thin Walled wear Ring-R/U to Run Completion Tubing 05:45 18:45 13.00 0 10,186 INTRMI RPCOM RCST X Run 3'/i'EUE Upper Completion t/ 10,186'MD as Follows:WLEG,3 1/2' EUE Pup Jt,"XN"Nipple w/RHC Plug, 1 Jt Tubing, FHL Packer,80-40 PBR/SBE, 1 Jt Tubing,GLM w/ DCK-2 SOV,71 Jts Tubing,GLM w/ DV, 155 Jts Tubing,GLM w/DV,91 Jts Tubing 18:45 19:45 1.00 10,186 10,186 INTRM1 RPCOM RURD X R/U SLB Spooling Unit and M/U Control Line to TRMAXX-5E SSSV- Functioned Valve and Tested Line U 6500 Psi f/5 Minutes 19:45 23:30 3.75 10,186 12,259 INTRMI RPCOM RCST X Continue to Run 3'/2'Upper Completion U 12,259'MD as Follows:65 Jts Tubing 23:30 00:00 0.50 12,259 12,259 INTRM1 RPCOM RURD X M/U 3' EUE to 4"XT-39 XO and R/D Tubing Handling Equipment P/U and Rabbit 10'/15'DP Pups 04/29/2011 Space Out Packer Setting Depth w/4"DP-Spot Corrosion Inhibited Brine Below Lower GLM-Set Packer- Test IA U 1,000 Psi f/15 Minutes-Shear Out of PBR-M/U Remaining Tubing and Hanger-Land Tubing in Well Head-Set TWC-Test Hanger Seals U 5,000 Psi f/10 Minutes-R/U Circulating Manifold-Test Tubing U 3,500 Psi f/30 Minutes-Test IA U 3,500 Psi f/30 Minutes-Shear Valve in Lower GLM-Set TWC-Test TWC and Hanger in Direction of Flow U 2,600 Psi f/10 Minutes-OWFF(Static)-N/D BOPE-N/U Tree- Test Tree U 5,000 Psi f/10 Minutes-Displace Well Bore Fluid w/434 Bbls of Diesel-UD 4"DP 00:00 01:00 1.00 12,259 12,371 INTRM1 RPCOM HOSO X XO to 4"DP and Space Out to Place Packer on Depth @ 12,315'MD 01:00 02:00 1.00 12,371 12,371 INTRM1 RPCOM CIRC X Pump 15 Bbls of Inhibited Brine Followed by 110 Bbls of Neat Brine- Spotted Inhibited Brine f/WLEG to Bottom of Lower GLM 3 BPM @ 290 Psi 02:00 02:45 0.75 12,371 12,371 INTRM1 RPCOM PACK X Drop Ball and Rod and Allow to Fall- Pressure Up U 2,000 Psi f/5 Minutes,then Increase Pressure to 2,500 Psi f/5 Minutes-Verify Packer Set Top of SBE 12,293'MD,Top of Packer 12,315'MD,XN Nipple 12,358'MD and WLEG 12,371'MD 02:45 03:30 0.75 12,371 12,371 INTRM1 RPCOM PRTS X R/U then Close Annular and Pressure Test Packer and Seal U 1,000 Psi f/15 Minutes- 03:30 04:00 0.50 12,371 12,371 INTRM1 RPCOM TRIP X Shear PBR and UD 4"DP Pups and S/B 1 Stand 04:00 05:00 1.00 12,371 12,371 INTRM1 RPCOM RCST X M/U 3%2'EUE to 4%"IBTM XO,2 Jts 4' "IBTM Jts, and Wear Ring Puller-Pull Wear Ring Page 18 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:00 06:30 1.50 12,371 12,371 INTRM1 RPCOM HOSO X M/U Tubing Hanger,Terminate SSSV Control Line,Test Void U 5,000 Psi f/10 Minutes-Land Tubing Hanger in Well Head and RILDS P/U 155,S/O 107 06:30 07:45 1.25 12,371 12,371 INTRM1 WHDBO PRTS X Install TWC and Test Hanger Seals t/ 250 Psi f/5 Minutes and 5,000 Psi f/ 10 Minutes-Pull TWC 07:45 08:30 0.75 12,371 12,371 INTRM1 RPCOM RURD X R/U Circulating Manifold&Lines 08:30 12:00 3.50 12,371 12,371 INTRM1 RPCOM PRTS X PJSM-Test Surface Lines U 4,000 Psi-Test Tubing U 3,500 Psi f/30 Minutes-Bleed Tubing V 2,000 Psi-. ‘ Test IA U 3,500 Psi f/30 Minutes- Bleed Tubing to 0 Psi;SOV Did Not Shear-Pressured Up IA U 3,500 Psi X3-Valve Sheared on 3rd Attempt- Install TWC 12:00 12:30 0.50 12,371 12,371 INTRM1 WHDBO PRTS X Test Tubing Hanger and TWC in Direction of Flow U 2,600 Psi f/10 Minutes 12:30 13:45 1.25 12,371 12,371 INTRM1 WHDBO NUND X N/D Riser and BOPE 13:45 15:15 1.50 12,371 12,371 INTRM1 WHDBO NUND X N/U Tree 15:15 16:00 0.75 12,371 12,371 INTRM1 WHDBO PRTS X Test Tree Void U 5,000 Psi f/10 Minutes-Test Body t/5,000 Psi f/ 10 Minutes-Terminate Control Line 16:00 16:30 0.50 12,371 12,371 INTRM1 RPCOM RURD X R/U to Displace to Diesel 16:30 21:15 4.75 12,371 12,371 INTRMI RPCOM CIRC X Displace 9.6 PPG Brine to Diesel- Pumped 434 bbls of Diesel 3 BPM @ 2100 Psi 21:15 00:00 2.75 0 0 INTRM1 RPCOM PULD X UD 4"DP 04/30/2011 Laid down all tubulars from derrick for pad to pad rig move-prepare rig for move 00:00 10:00 10.00 0 INTRMI RPCOM PULD X Lay down 4"drill pipe and hwdp from Derrick for Pad to Pad move. 10:00 12:00 2.00 0 INTRM1 RPCOM DMOB X Clean drill pipe drip pans and rotary table pollution pan-prepare rig for move-Released rig @ 1200 hrs Page 19 of 19 CD3-128 Well Work Summary DATE SUMMARY '•5/1/11'ASSIST FMC IN REMOVING BPV. f CATCHER ON B&R @ 12,359' RKB. IN PROGRESS. 5/2/11 PULLED SOV @ 12,235' RKB& REPLACED WITH OV. MIT TBG TO 3500 PSI. PASS. PULLED CATCHER, B&R & RHC PLUG BODY @ 12,359' RKB. DRIFT TBG W/20'x 2.5" DMY GUNS TO 12,600' SLM. READY FOR E-LINE. 5/4/11 RIH WITH RADIAL CEMENT BOND LOGGING TOOL TO DEPTH OF 12854'. BEGIN LOGGING THE 7"CASING UP TO THE TUBING TAIL @ 12371'. PULL MAIN/REPEAT LOG SECTIONS AND ROH WITH THE LOGGING TOOLS. PREP FOR PERFORATING NEXT DAY. 5/5/11 RIH WITH 20' x 2 '" 6 SPF 60DEG, DP MILLENIUM PERFORATING GUN AND SHOOT FROM ✓" 12476-12496'. INITIAL T/IA/OA = 0/0/350 AFTER PERFORATING T/IA/OA= 700/25/350. RIH r� WITH PRESSURE/TEMP TOOLS TO DEPTH OF 12485' (TEMP/PRESS=159/3202) PULL UPHOLE TO 12400' (TEMP/PRESS= 157/3182) ROH c fk 3 g 1I x g 4ti ConocoPhillips(Alaska) Inc. a 4 Western North Slope 4 I CD3 Fiord Pad 0 CD3-128 501032063800 ,a L_r 2 w r4 2 • 3-1 t• i Sperry Drilling Definitive Survey Report • ta- 02 May, 2011 f III Etl III g 4 t • 7 N. • g o 41 I1I: I ▪ a 53 to HALLIBURTON 1 Sperry Drilling 1 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: Rig:36.8+12.6 @ 49.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig:36.8+12.6 @ 49.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3-128 Well Position +N/-S 0.00 ft Northing: 6,003,752.89 ft Latitude: 70°25'9.068 N +El-W 0.00 ft Easting: 387,838.10 ft Longitude: 150°54'49.392 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.60ft Wellbore CD3-128 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 4/20/2011 20.64 80.83 57,604 Design CD3-128 Audit Notes: i i Version: 1.0 Phase: ACTUAL Tie On Depth: 36.80 'Vertical Section: Depth From(TVD) +N/S +E/-W Direction (ft) (ft) (ft) (°) 36.80 0.00 0.00 155.00 Survey Program Date From To' (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 80.00 1,101.00 CD3-128 Gyro(R100)(CD3-128) CB-GYRO-SS Camera based gyro single shot 4/12/2011 12.0 1,149.28 2,947.82 CD3-128 MWD(R300)(CD3-128) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/12/2011 12:C 3,046.13 12,976.44 CD3-128 MWD(R400)(CD3-128) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/16/2011 12:C Survey. Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.80 0.00 0.00 36.80 -12.60 0.00 0.00 6,003,752.89 387,838.10 0.00 0.00 UNDEFINED 80.00 0.05 284.95 80.00 30.60 0.00 -0.02 6,003,752.89 387,838.08 0.12 -0.01 CB-GYRO-SS(1) 171.00 0.37 6.10 171.00 121.60 0.31 -0.03 6,003,753.19 387,838.08 0.40 -0.29 CB-GYRO-SS(1) 264.00 0.45 8.32 264.00 214.60 0.97 0.06 6,003,753.85 387,838.17 0.09 -0.85 CB-GYRO-SS(1) 292.00 0.44 358.14 292.00 242.60 1.18 0.07 6,003,754.07 387,838.19 0.28 -1.04 CB-GYRO-SS(1) 322.00 0.52 5.76 322.00 272.60 1.43 0.08 6,003,754.32 387,838.20 0.34 -1.27 CB-GYRO-SS(1) 352.00 0.57 357.16 351.99 302.59 1.72 0.09 6,003,754.60 387,838.21 0.32 -1.52 CB-GYRO-SS(1) 356.00 0.72 12.68 355.99 306.59 1.76 0.09 6,003,754.65 387,838.22 5.72 -1.56 CB-GYRO-SS(1) 382.00 0.67 4.70 381.99 332.59 2.07 0.14 6,003,754.96 387,838.27 0.42 -1.82 CB-GYRO-SS(1) 412.00 0.73 346.99 411.99 362.59 2.43 0.11 6,003,755.32 387,838.25 0.75 -2.16 CB-GYRO-SS(1) 442.00 0.95 336.11 441.99 392.59 2.85 -0.03 6,003,755.73 387,838.11 0.90 -2.59 CB-GYRO-SS(1) 449.00 1.19 338.52 448.98 399.58 2.97 -0.08 6,003,755.86 387,838.06 3.49 -2.73 CB-GYRO-SS(1) 5/2/2011 10:36:15AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: Rig:36.8+12.6 @ 49.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig:36.8+12.6 @ 49.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 472.00 1.46 322.24 471.98 422.58 3.42 -0.35 6,003,756.31 387,837.80 2.00 -3.25 CB-GYRO-SS(1) 480.00 1.55 323.18 479.98 430.58 3.59 -0.48 6,003,756.48 387,837.68 1.17 -3.45 CB-GYRO-SS(1) 487.00 1.80 316.66 486.97 437.57 3.75 -0.61 6,003,756.64 387,837.55 4.49 -3.65 CB-GYRO-SS(1) i 502.00 1.83 314.59 501.97 452.57 4.09 -0.94 6,003,756.98 387,837.22 0.48 -4.10 CB-GYRO-SS(1) 517.00 1.98 313.17 516.96 467.56 4.43 -1.30 6,003,757.34 387,836.87 1.05 -4.57 CB-GYRO-SS(1) 532.00 2.24 309.79 531.95 482.55 4.80 -1.71 6,003,757.71 387,836.46 1.92 -5.07 CB-GYRO-SS(1) 541.00 2.71 308.40 540.94 491.54 5.04 -2.02 6,003,757.96 387,836.16 5.26 -5.42 CB-GYRO-SS(1) 1 547.00 2.45 308.72 546.93 497.53 5.21 -2.23 6,003,758.13 387,835.95 4.34 -5.66 CB-GYRO-SS(1) 562.00 2.60 311.20 561.92 512.52 5.63 -2.73 6,003,758.56 387,835.45 1.24 -6.26 CB-GYRO-SS(1) 634.00 4.82 294.43 633.76 584.36 7.96 -6.72 6,003,760.95 387,831.50 3.40 -10.05 CB-GYRO-SS(1) 725.00 5.67 284.50 724.38 674.98 10.67 -14.55 6,003,763.77 387,823.71 1.36 -15.82 CB-GYRO-SS(1) 816.00 6.27 282.47 814.89 765.49 12.87 -23.75 6,003,766.11 387,814.54 0.70 -21.70 CB-GYRO-SS(1) 910.00 8.07 284.86 908.15 858.75 15.67 -35.14 6,003,769.08 387,803.20 1.94 -29.05 CB-GYRO-SS(1) 1,005.00 11.26 289.11 1,001.79 952.39 20.41 -50.36 6,003,774.05 387,788.06 3.44 -39.78 CB-GYRO-SS(1) i 1,101.00 11.43 287.01 1,095.92 1,046.52 26.27 -68.31 6,003,780.17 387,770.20 0.47 -52.67 CB-GYRO-SS(1) 1,149.28 12.53 285.03 1,143.15 1,093.75 29.02 -77.94 6,003,783.07 387,760.61 2.43 -59.24 MWD+IFR-AK-CAZSC(2) 1,246.64 14.20 278.60 1,237.87 1,188.47 33.55 -99.95 6,003,787.93 387,738.67 2.29 -72.65 MWD+IFR-AK-CAZ-SC(2) 1,340.98 18.95 274.82 1,328.27 1,278.87 36.57 -126.67 6,003,791.35 387,712.00 5.16 -86.68 MWD+IFR-AK-CAZ-SC(2) 1,435.36 22.98 272.49 1,416.38 1,366.98 38.66 -160.36 6,003,793.94 387,678.35 4.36 -102.81 MWD+IFR-AK-CAZ-SC(2) 1,529.94 26.95 267.63 1,502.12 1,452.72 38.57 -200.24 6,003,794.46 387,638.47 4.72 -119.59 MWD+IFR-AK-CAZ-SC(2) 1,624.32 30.89 266.80 1,584.71 1,535.31 36.33 -245.82 6,003,792.91 387,592.87 4.20 -136.82 MWD+IFR-AK-CAZ-SC(2) 1,718.75 34.05 264.21 1,664.37 1,614.97 32.31 -296.34 6,003,789.64 387,542.30 3.66 -154.52 MWD+IFR-AK-CAZ-SC(2) 1,811.86 37.07 263.42 1,740.11 1,690.71 26.47 -350.16 6,003,784.61 387,488.40 3.28 -171.97 MWD+IFR-AK-CAZ-SC(2) 1,908.24 38.24 261.27 1,816.42 1,767.02 18.61 -408.51 6,003,777.63 387,429.95 1.82 -189.51 MWD+IFR-AK-CAZ-SC(2) 2,002.83 41.08 258.23 1,889.24 1,839.84 7.82 -467.88 6,003,767.74 387,370.42 3.64 -204.83 MWD+IFR-AK-CAZ-SC(2) 2,097.83 45.21 257.78 1,958.54 1,909.14 -5.68 -531.42 6,003,755.19 387,306.70 4.36 -219.43 MWD+IFR-AK-CAZ-SC(2) 2,192.22 48.45 258.55 2,023.11 1,973.71 -19.79 -598.79 6,003,742.10 387,239.13 3.48 -235.12 MWD+IFR-AK-CAZ-SC(2) 2,286.65 51.30 259.96 2,083.96 2,034.56 -33.23 -669.72 6,003,729.72 387,168.01 3.23 -252.92 MWD+IFR-AK-CAZ-SC(2) 1 2,381.02 53.97 262.48 2,141.23 2,091.83 -44.65 -743.83 6,003,719.42 387,093.75 3.54 -273.89 MWD+IFR-AK-CAZ-SC(2) 2,475.81 56.88 262.15 2,195.02 2,145.62 -55.09 -821.17 6,003,710.15 387,016.27 3.08 -297.11 MWD+IFR-AK-CAZ-SC(2) 2,567.43 58.46 262.76 2,244.01 2,194.61 -65.25 -897.91 6,003,701.14 386,939.38 1.81 -320.34 MWD+IFR-AK-CAZ-SC(2) 2,664.51 58.56 260.62 2,294.73 2,245.33 -77.21 -979.82 6,003,690.41 386,857.31 1.88 -344.11 MWD+IFR-AK-CAZ-SC(2) 2,758.77 59.89 259.61 2,342.96 2,293.56 -91.12 -1,059.60 6,003,677.70 386,777.34 1.68 -365.22 MWD+IFR-AK-CAZ-SC(2) 2,853.26 61.24 259.06 2,389.39 2,339.99 -106.35 -1,140.47 6,003,663.69 386,696.26 1.52 -385.59 MWD+IFR-AK-CAZ-SC(2) 2,947.82 63.44 258.90 2,433.29 2,383.89 -122.36 -1,222.67 6,003,648.92 386,613.83 2.33 -405.83 MWD+IFR-AK-CAZ-SC(2) 3,046.13 63.69 259.67 2,477.05 2,427.65 -138.73 -1,309.17 6,003,633.85 386,527.11 0.75 -427.55 MWD+IFR-AK-CAZ-SC(3) 3,137.78 63.00 258.90 2,518.17 2,468.77 -153.95 -1,389.65 6,003,619.84 386,446.41 1.06 -447.76 MWD+IFR-AK-CAZ-SC(3) 3,233.89 62.27 258.45 2,562.35 2,512.95 -170.72 -1,473.34 6,003,604.34 386,362.49 0.87 -467.94 MWD+IFR-AK-CAZ-SC(3) 3,326.63 62.10 258.77 2,605.62 2,556.22 -186.91 -1,553.75 6,003,589.35 386,281.85 0.36 -487.24 MWD+IFR-AK-CAZ-SC(3) 3,419.05 64.04 259.61 2,647.48 2,598.08 -202.36 -1,634.68 6,003,575.12 386,200.70 2.25 -507.44 MWD+IFR-AK-CAZ-SC(3) 5/2/2011 10:36:15AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: Rig:36.8+12.6 @ 49.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig:36.8+12.6 @ 49.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,513.48 64.26 258.77 2,688.65 2,639.25 -218.30 -1,718.15 6,003,560.44 386,117.01 0.83 -528.27 MWD+IFR-AK-CAZ-SC(3) 3,607.46 64.25 259.59 2,729.47 2,680.07 -234.19 -1,801.30 6,003,545.80 386,033.64 0.79 -549.01 MWD+I FR-AK-CAZ-SC(3) 3,701.00 64.40 260.06 2,770.00 2,720.60 -249.08 -1,884.28 6,003,532.16 385,950.45 0.48 -570.58 MWD+I FR-AK-CAZ-SC(3) 3,793.75 63.78 260.01 2,810.53 2,761.13 -263.52 -1,966.44 6,003,518.96 385,868.09 0.67 -592.22 MWD+IFR-AK-CAZ-SC(3) 3,888.38 63.28 260.87 2,852.71 2,803.31 -277.59 -2,049.98 6,003,506.15 385,784.36 0.97 -614.77 MWD+IFR-AK-CAZ-SC(3) 3,981.21 63.00 260.05 2,894.65 2,845.25 -291.32 -2,131.64 6,003,493.65 385,702.50 0.84 -636.85 MWD+IFR-AK-CAZ-SC(3) 4,070.84 62.65 259.39 2,935.59 2,886.19 -305.54 -2,210.10 6,003,480.61 385,623.85 0.76 -657.11 MWD+IFR-AK-CAZ-SC(3) 4,164.00 62.79 259.84 2,978.28 2,928.88 -320.47 -2,291.54 6,003,466.91 385,542.20 0.45 -678.00 MWD+IFR-AK-CAZ-SC(3) 4,258.78 63.06 260.90 3,021.43 2,972.03 -334.59 -2,374.74 6,003,454.04 385,458.80 1.04 -700.37 MWD+IFR-AK-CAZ-SC(3) 4,351.75 63.36 261.44 3,063.33 3,013.93 -347.32 -2,456.75 6,003,442.54 385,376.62 0.61 -723.49 MWD+IFR-AK-CAZ-SC(3) 4,445.73 63.27 261.17 3,105.53 3,056.13 -360.02 -2,539.76 6,003,431.10 385,293.44 0.27 -747.06 MWD+IFR-AK-CAZ-SC(3) 4,536.89 63.08 260.76 3,146.67 3,097.27 -372.79 -2,620.10 6,003,419.53 385,212.92 0.45 -769.44 MWD+IFR-AK-CAZ-SC(3) 4,628.50 62.67 260.71 3,188.44 3,139.04 -385.92 -2,700.57 6,003,407.61 385,132.27 0.45 -791.55 MWD+IFR-AK-CAZ-SC(3) 4,724.24 62.34 260.76 3,232.64 3,183.24 -399.59 -2,784.39 6,003,395.20 385,048.26 0.35 -814.58 MWD+IFR-AK-CAZ-SC(3) 4,817.62 62.66 260.99 3,275.76 3,226.36 -412.73 -2,866.17 6,003,383.30 384,966.30 0.41 -837.23 MWD+IFR-AK-CAZ-SC(3) 4,912.41 63.14 261.36 3,318.94 3,269.54 -425.67 -2,949.55 6,003,371.61 384,882.74 0.61 -860.74 MWD+IFR-AK-CAZ-SC(3) 5,006.65 63.42 260.99 3,361.31 3,311.91 -438.59 -3,032.73 6,003,359.95 384,799.38 0.46 -884.19 MWD+IFR-AK-CAZ-SC(3) 5,101.37 63.68 260.59 3,403.50 3,354.10 -452.16 -3,116.44 6,003,347.63 384,715.48 0.47 -907.27 MWD+I F R-AK-CAZ-S C(3) 5,194.53 63.48 260.13 3,444.95 3,395.55 -466.13 -3,198.69 6,003,334.90 384,633.04 0.49 -929.37 MWD+IFR-AK-CAZ-SC(3) 5,289.20 63.56 259.69 3,487.17 3,437.77 -480.98 -3,282.12 6,003,321.31 384,549.40 0.42 -951.17 MWD+IFR-AK-CAZ-SC(3) 5,383.42 64.24 260.39 3,528.62 3,479.22 -495.61 -3,365.46 6,003,307.93 384,465.87 0.98 -973.13 MWD+IFR-AK-CAZ-SC(3) 5,478.93 63.84 259.83 3,570.43 3,521.03 -510.36 -3,450.05 6,003,294.46 384,381.06 0.67 -995.51 MWD+IFR-AK-CAZ-SC(3) 5,573.24 63.41 258.99 3,612.32 3,562.92 -525.89 -3,533.10 6,003,280.18 384,297.79 0.92 -1,016.54 MWD+IFR-AK-CAZ-SC(3) 5,667.13 64.10 258.68 3,653.84 3,604.44 -542.19 -3,615.72 6,003,265.12 384,214.95 0.79 -1,036.68 MWD+IFR-AK-CAZ-SC(3) 5,762.79 63.90 258.40 3,695.78 3,646.38 -559.28 -3,699.99 6,003,249.31 384,130.45 0.34 -1,056.81 MWD+IFR-AK-CAZ-SC(3) 5,856.82 63.90 259.58 3,737.15 3,687.75 -575.40 -3,782.87 6,003,234.43 384,047.33 1.13 -1,077.22 MWD+IFR-AK-CAZ-SC(3) 5,951.97 63.56 258.51 3,779.26 3,729.86 -591.61 -3,866.64 6,003,219.48 383,963.34 1.07 -1,097.93 MWD+IFR-AK-CAZ-SC(3) 6,046.23 63.77 259.92 3,821.08 3,771.68 -607.42 -3,949.62 6,003,204.92 383,880.14 1.36 -1,118.67 MWD+IFR-AK-CAZ-SC(3) 6,141.84 63.43 259.12 3,863.59 3,814.19 -623.00 -4,033.83 6,003,190.62 383,795.71 0.83 -1,140.14 MWD+IFR-AK-CAZ-SC(3) 6,235.47 63.00 259.74 3,905.78 3,856.38 -638.33 -4,115.99 6,003,176.52 383,713.33 0.75 -1,160.97 MWD+IFR-AK-CAZ-SC(3) 6,330.26 62.94 259.96 3,948.86 3,899.46 -653.21 11,199.11 6,003,162.89 383,630.01 0.22 -1,182.61 MWD+IFR-AK-CAZ-SC(3) 6,424.76 62.72 261.12 3,992.01 3,942.61 -667.03 -4,282.04 6,003,150.32 383,546.89 1.12 -1,205.13 MWD+IFR-AK-CAZ-SC(3) 6,518.93 62.89 261.19 4,035.05 3,985.65 -679.91 -4,364.80 6,003,138.69 383,463.95 0.19 -1,228.44 MWD+IFR-AK-CAZ-SC(3) 6,613.56 63.01 261.46 4,078.09 4,028.69 -692.62 -4,448.11 6,003,127.23 383,380.46 0.28 -1,252.13 MWD+IFR-AK-CAZ-SC(3) 6,708.21 62.79 260.82 4,121.20 4,071.80 -705.60 -4,531.37 6,003,115.51 383,297.03 0.65 -1,275.55 MWD+IFR-AK-CAZ-SC(3) 6,802.45 61.89 259.80 4,164.95 4,115.55 -719.64 -4,613.64 6,003,102.70 383,214.56 1.35 -1,297.59 MW D+I F R-AK-CAZ-SC(3) 6,896.58 62.05 260.17 4,209.19 4,159.79 -734.09 -4,695.47 6,003,089.48 383,132.54 0.39 -1,319.08 MWD+IFR-AK-CAZ-SC(3) 6,989.94 62.59 260.25 4,252.56 4,203.16 -748.15 -4,776.94 6,003,076.65 383,050.87 0.58 -1,340.77 MWD+IFR-AK-CAZ-SC(3) 7,085.18 63.61 259.77 4,295.65 4,246.25 -762.88 -4,860.58 6,003,063.18 382,967.02 1.16 -1,362.76 MWD+IFR-AK-CAZ-SC(3) 7,180.67 63.64 260.45 4,338.07 4,288.67 -777.58 -4,944.86 6,003,049.75 382,882.54 0.64 -1,385.06 MWD+IFR-AK-CAZ-SC(3) 5/2/2011 10:36:15AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: Rig:36.8+12.6 @ 49.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig:36.8+12.6 @ 49.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,275.24 63.49 260.67 4,380.17 4,330.77 -791.47 -5,028.39 6,003,037.12 382,798.81 0.26 -1,407.78 MWD+IFR-AK-CAZ-SC(3) 7,369.35 63.01 259.06 4,422.53 4,373.13 -806.25 -5,111.12 6,003,023.58 382,715.88 1.61 -1,429.34 MWD+IFR-AK-CAZ-SC(3) 7,462.58 63.22 259.77 4,464.69 4,415.29 -821.53 -5,192.86 6,003,009.54 382,633.93 0.72 -1,450.04 MWD+IFR-AK-CAZ-SC(3) 7,557.95 63.35 260.16 4,507.56 4,458.16 -836.37 -5,276.74 6,002,995.96 382,549.84 0.39 -1,472.04 MWD+IFR-AK-CAZ-SC(3) 7,653.07 63.48 259.92 4,550.13 4,500.73 -851.08 -5,360.52 6,002,982.51 382,465.85 0.26 -1,494.11 MWD+IFR-AK-CAZ-SC(3) 7,746.94 63.43 260.28 4,592.08 4,542.68 -865.52 -5,443.25 6,002,969.31 382,382.93 0.35 -1,515.99 MWD+IFR-AK-CAZ-SC(3) 7,841.37 63.41 260.04 4,634.33 4,584.93 -879.95 -5,526.45 6,002,956.14 382,299.52 0.23 -1,538.07 MWD+IFRAK-CAZ-SC(3) 7,935.48 63.47 259.88 4,676.41 4,627.01 -894.63 -5,609.34 6,002,942.71 382,216.43 0.16 -1,559.80 MWD+IFR-AK-CAZ-SC(3) 8,030.88 63.62 260.39 4,718.91 4,669.51 -909.26 -5,693.49 6,002,929.34 382,132.08 0.50 -1,582.10 MWD+IFR-AK-CAZ-SC(3) 8,126.01 63.49 260.46 4,761.28 4,711.88 -923.43 -5,777.48 6,002,916.44 382,047.89 0.15 -1,604.76 MWD+IFR-AK-CAZ-SC(3) 8,220.94 62.87 259.03 4,804.11 4,754.71 -938.51 -5,860.84 6,002,902.62 381,964.32 1.49 -1,626.32 MWD+IFR-AK-CAZ-SC(3) 8,314.67 63.36 259.64 4,846.50 4,797.10 -953.98 -5,943.00 6,002,888.38 381,881.95 0.78 -1,647.02 MWD+IFR-AK-CAZ-SC(3) 8,410.14 63.15 259.69 4,889.46 4,840.06 -969.27 -6,026.87 6,002,874.35 381,797.86 0.22 -1,668.60 MWD+IFR-AK-CAZ-SC(3) 8,502.33 62.93 259.59 4,931.26 4,881.86 -984.05 -6,107.70 6,002,860.79 381,716.83 026 -1,689.37 MWD+IFR-AK-CAZ-SC(3) 8,598.83 62.93 259.51 4,975.17 4,925.77 -999.64 -6,192.20 6,002,846.48 381,632.11 0.07 -1,710.96 MWD+IFR-AK-CAZ-SC(3) 8,692.83 63.15 259.84 5,017.79 4,968.39 -1,014.65 -6,274.63 6,002,832.70 381,549.47 0.39 -1,732.19 MWD+IFR-AK-CAZ-SC(3) 8,787.72 63.28 259.72 5,060.55 5,011.15 -1,029.68 -6,358.00 6,002,818.93 381,465.90 0.18 -1,753.80 MWD+IFR-AK-CAZ-SC(3) 8,882.13 63.91 260.25 5,102.54 5,053.14 -1,044.39 -6,441.27 6,002,805.48 381,382.42 0.84 -1,775.66 MWD+IFR-AK-CAZ-SC(3) 8,975.95 64.25 261.13 5,143.55 5,094.15 -1,058.04 -6,524.54 6,002,793.08 381,298.96 0.92 -1,798.48 MWD+IFR-AK-CAZ-SC(3) 9,071.43 63.97 261.68 5,185.24 5,135.84 -1,070.87 -6,609.47 6,002,781.52 381,213.85 0.60 -1,822.74 MWD+IFR-AK-CAZ-SC(3) 9,164.46 63.76 261.78 5,226.22 5,176.82 -1,082.89 -6,692.12 6,002,770.75 381,131.04 0.25 -1,846.78 MWD+IFR-AK-CAZ-SC(3) 9,258.30 63.28 261.47 5,268.06 5,218.66 -1,095.12 -6,775.22 6,002,759.77 381,047.77 0.59 -1,870.81 MWD+IFR-AK-CAZ-SC(3) 9,354.92 63.36 260.58 5,311.44 5,262.04 -1,108.59 -6,860.49 6,002,747.59 380,962.31 0.83 -1,894.65 MWD+IFR-AK-CAZ-SC(3) 9,448.18 63.21 260.08 5,353.37 5,303.97 -1,122.58 -6,942.61 6,002,734.83 380,880.00 0.51 -1,916.67 MWD+IFR-AK-CAZ-SC(3) 9,542.97 62.81 259.48 5,396.39 5,346.99 -1,137.57 -7,025.74 6,002,721.10 380,796.66 0.70 -1,938.22 MWD+IFR-AK-CAZ-SC(3) 9,637.40 63.00 259.06 5,439.40 5,390.00 -1,153.22 -7,108.33 6,002,706.69 380,713.85 0.44 -1,958.94 MWD+IFR-AK-CAZ-SC(3) 9,732.37 63.35 258.30 5,482.25 5,432.85 -1,169.86 -7,191.43 6,002,691.30 380,630.52 0.80 -1,978.98 MWD+IFR-AK-CAZ-SC(3) 9,826.81 63.49 258.21 5,524.51 5,475.11 -1,187.05 -7,274.13 6,002,675.36 380,547.58 0.17 -1,998.35 MWD+IFR-AK-CAZ-SC(3) 9,921.32 63.51 258.83 5,566.68 5,517.28 -1,203.88 -7,357.01 6,002,659.77 380,464.46 0.59 -2,018.12 MWD+IFR-AK-CAZ-SC(3) 10,015.74 63.84 260.12 5,608.55 5,559.15 -1,219.34 -7,440.21 6,002,645.57 380,381.04 1.27 -2,039.27 MWD+IFR-AK-CAZ-SC(3) 10,110.23 63.84 260.03 5,650.21 5,600.81 -1,233.96 -7,523.76 6,002,632.21 380,297.30 0.09 -2,061.33 MWD+IFR-AK-CAZSC(3) 10,204.46 63.56 260.31 5,691.96 5,642.56 -1,248.38 -7,606.99 6,002,619.04 380,213.86 0.40 -2,083.44 MWD+IFR-AK-CAZ-SC(3) 10,298.98 63.22 258.27 5,734.30 5,684.90 -1,264.08 -7,690.02 6,002,604.59 380,130.61 1.96 -2,104.30 MWD+IFR-AK-CAZ-SC(3) 10,393.73 62.30 254.78 5,777.68 5,728.28 -1,283.70 -7,771.93 6,002,586.21 380,048.43 3.42 -2,121.14 MWD+IFR-AK-CAZ-SC(3) 10,488.05 60.77 251.66 5,822.65 5,773.25 -1,307.61 -7,851.30 6,002,563.49 379,968.71 3.33 -2,133.00 MWD+IFR-AK-CAZ-SC(3) 10,582.34 60.63 248.32 5,868.80 5,819.40 -1,335.74 -7,928.55 6,002,536.53 379,891.05 3.09 -2,140.16 MWD+IFR-AK-CAZ-SC(3) 10,676.66 59.63 243.68 5,915.79 5,866.39 -1,368.98 -8,003.25 6,002,504.42 379,815.87 4.40 -2,141.60 MWD+IFR-AK-CAZ-SC(3) 10,771.17 58.63 238.64 5,964.31 5,914.91 -1,408.07 -8,074.28 6,002,466.40 379,744.27 4.70 -2,136.19 MWD+IFR-AK-CAZ-SC(3) 10,867.01 56.80 234.67 6,015.51 5,966.11 -1,452.57 -8,141.96 6,002,422.93 379,675.94 3.99 -2,124.46 MWD+IFR-AK-CAZ-SC(3) 10,961.39 56.12 230.93 6,067.67 6,018.27 -1,500.11 -8,204.60 6,002,376.34 379,612.59 3.38 -2,107.85 MWD+IFR-AK-CAZ-SC(3) 5/2/2011 10:36:15AM Page 5 COMPASS 2003.16 Build 69 i ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD3-128 Project: Western North Slope TVD Reference: Rig:36.8+12.6 @ 49.40ft(Doyon 19) Site: CD3 Fiord Pad MD Reference: Rig:36.8+12.6 @ 49.40ft(Doyon 19) Well: CD3-128 North Reference: True Wellbore: CD3-128 Survey Calculation Method: Minimum Curvature Design: CD3-128 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,056.50 57.02 227.78 6,120.08 6,070.68 -1,551.81 -8,264.81 6,002,325.55 379,551.62 2.92 -2,086.44 MWD+IFR-AK-CAZ-SC(3) 11,151.12 57.84 223.75 6,171.03 6,121.63 -1,607.43 -8,321.91 6,002,270.80 379,493.69 3.69 -2,060.17 MWD+IFR-AK-CAZ-SC(3) 11,245.60 59.28 219.35 6,220.33 6,170.93 -1,667.75 -8,375.34 6,002,211.30 379,439.37 4.26 -2,028.08 MWD+IFR-AK-CAZ-SC(3) 11,340.05 59.06 215.13 6,268.75 6,219.35 -1,732.29 -8,424.41 6,002,147.51 379,389.34 3.84 -1,990.32 MWD+IFR-AK-CAZ-SC(3) 11,433.57 59.18 211.21 6,316.76 6,267.36 -1,799.45 -8,468.30 6,002,081.02 379,344.44 3.60 -1,948.00 MWD+IFR-AK-CAZ-SC(3) 11,528.59 59.49 209.14 6,365.22 6,315.82 -1,870.11 -8,509.38 6,002,010.99 379,302.31 1.90 -1,901.33 MWD+IFR-AK-CAZ-SC(3) 11,622.98 61.41 204.81 6,411.79 6,362.39 -1,943.27 -8,546.59 6,001,938.40 379,264.01 4.48 -1,850.74 MWD+IFR-AK-CAZ-SC(3) 11,718.12 61.18 201.57 6,457.50 6,408.10 -2,019.96 -8,579.44 6,001,862.22 379,230.01 3.00 -1,795.13 MWD+IFR-AK-CAZ-SC(3) 11,812.39 61.12 197.34 6,503.00 6,453.60 -2,097.79 -8,606.94 6,001,784.82 379,201.36 3.93 -1,736.21 MWD+IFR-AK-CAZ-SC(3) 11,907.13 61.41 195.24 6,548.55 6,499.15 -2,177.52 -8,630.23 6,001,705.46 379,176.86 1.97 -1,673.79 MWD+IFR-AK-CAZ-SC(3) 12,001.10 60.34 194.59 6,594.29 6,544.89 -2,256.84 -8,651.36 6,001,626.47 379,154.55 1.29 -1,610.83 MWD+IFR-AK-CAZ-SC(3) 12,095.88 60.86 194.95 6,640.81 6,591.41 -2,336.68 -8,672.42 6,001,546.96 379,132.30 0.64 -1,547.37 MWD+IFR-AK-CAZ-SC(3) 12,190.14 61.20 195.25 6,686.47 6,637.07 -2,416.30 -8,693.90 6,001,467.68 379,109.62 0.46 -1,484.29 MWD+IFR-AK-CAZ-SC(3) 12,285.04 60.26 194.76 6,732.87 6,683.47 -2,496.26 -8,715.33 6,001,388.06 379,086.99 1.09 -1,420.88 MWD+IFR-AK-CAZ-SC(3) 12,379.29 61.12 194.55 6,779.01 6,729.61 -2,575.77 -8,736.12 6,001,308.87 379,065.01 0.93 -1,357.60 MWD+IFR-AK-CAZ-SC(3) 12,473.59 62.23 195.81 6,823.75 6,774.35 -2,655.88 -8,757.86 6,001,229.11 379,042.07 1.66 -1,294.19 MWD+IFR-AK-CAZ-SC(3) 12,523.26 63.84 195.78 6,846.27 6,796.87 -2,698.48 -8,769.91 6,001,186.70 379,029.38 3.24 -1,260.68 MWD+IFR-AK-CAZ-SC(3) 12,568.21 65.41 194.92 6,865.53 6,816.13 -2,737.64 -8,780.66 6,001,147.71 379,018.05 3.90 -1,229.72 MWD+IFR-AK-CAZ-SC(3) 12,613.80 66.81 192.93 6,884.00 6,834.60 -2,778.10 -8,790.69 6,001,107.41 379,007.42 5.04 -1,197.30 MWD+IFR-AK-CAZ-SC(3) 12,662.68 69.43 191.69 6,902.21 6,852.81 -2,822.41 -8,800.35 6,001,063.25 378,997.09 5.85 -1,161.22 MWD+IFR-AK-CAZ-SC(3) 12,711.99 71.63 190.00 6,918.65 6,869.25 -2,868.06 -8,809.10 6,001,017.74 378,987.66 5.51 -1,123.54 MWD+IFR-AK-CAZ-SC(3) 12,757.30 73.83 187.69 6,932.10 6,882.70 -2,910.81 -8,815.74 6,000,975.10 378,980.38 6.88 -1,087.60 MWD+IFR-AK-CAZ-SC(3) 12,803.74 75.57 186.68 6,944.35 6,894.95 -2,955.25 -8,821.34 6,000,930.75 378,974.11 4.29 -1,049.69 MWD+IFR-AK-CAZ-SC(3) 12,851.76 77.59 184.32 6,955.50 6,906.10 -3,001.74 -8,825.82 6,000,884.34 378,968.94 6.37 -1,009.45 MWD+IFR-AK-CAZ-SC(3) 12,904.27 79.48 182.55 6,965.94 6,916.54 -3,053.11 -8,828.90 6,000,833.03 378,965.09 4.89 -964.20 MWD+IFR-AK-CAZ-SC(3) 12,946.65 81.74 181.38 6,972.85 6,923.45 -3,094.89 -8,830.33 6,000,791.27 378,963.03 5.99 -926.94 MWD+IFR-AK-CAZ-SC(3) 12,976.44 81.92 181.50 6,977.09 6,927.69 -3,124.37 -8,831.07 6,000,761.81 378,961.84 0.72 -900.53 MWD+IFR-AK-CAZ-SC(3) 13,020.00 81.92 181.50 6,983.21 , 6,933.81 -3,167.48 -8,832.20 6,000,718.73 378,960.07 0.00 -861.94 PROJECTED to TD ) ill 5/2/2011 10:36:15AM Page 6 COMPASS 2003.16 Build 69 HALLIBURTON 1 Sperry Drilling WELL LOG TRANSMITTAL To: State of Alaska May 2, 2011 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-128 AK-MW-0007896849 CD3-128 50-103-20638-00 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log Digital Log Images & LWDG-formatted LIS Data w/verification listing: 1 CD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 3 09 5 / Bran [3uri!Ida*AM --------DrIlki062011 /2 _, Date ;,:i3:,,,1 Signed: (1_1\ -/-..-7/71 0 [F 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 Nina Anderson Drilling Engineer n ConocoPhillips Alaska, Inc. \ Q 3 ,/ P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-128 Sundry Number: 311-148 Dear Ms. Anderson: 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, fr Daniel T. Seamount, Jr. Chair 2r DATED this J day of May, 2011. Encl. ConocoPflhllips Alaska Post Office Box 100360 Anchorage,Alaska 99510-0360 N.Anderson RECEIVE Phone(907)265-6403 April 28, 2011O Qj� f ss Ceras.mission Anctorgle Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval CD3-128 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a Sundry Approval for an Alpine well, CD3-128. A scope change for CD3-128 was made to complete and produce the Kuparuk zone. The original CD3- 128 scope was to drill and complete the Nechelik zone with a horizontal hole as an injector. Ice road timing prevents drilling and completing the Nechelik horizontal in 2011. Approximately 9' of Kuparuk C sand was found in CD3-128, which justifies completion as a producer, and the weather forecast indicates the ice road will last long enough to complete the shallower Kuparuk zone and safely move the Doyon 19 rig. Recompleting the CD3-128 well as a Nechelik injector as originally proposed will still be an option for winter 2012 or later. Doyon 19 has cased and cemented the 7" intermediate casing in CD3-128 as originally planned. The planned change to the program is shown in the attached wellbore schematic. The completion will include a single retrievable packer, an SSSV, and gas lift mandrels. The Kuparuk C sand will be perforated after the rig moves off. Tentative perforation target is 12476'-12496' MD per the open hole logs. If you have any questions or require any further information, please contact me at 265-6403. Sincerely, Nina Anderson Alpine Drilling Engineer Attachments: 10-403 Sundry CD3-128 Revised Program for Kuparuk Completion Kuparuk Producer Completion • STATE OF ALASKA O , (V ALASKA`._AND GAS CONSERVATION COMMISSIG. '5 dil APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r-- Repair w ell r Change Approved Program r. Suspend IT Rug Perforations IT Perforate F • Pull Tubing fl Time Extension r- Operational Shutdown r Re-enter Susp.Well IT Stimulate fi Alter casing Other: C 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F.'...... • Exploratory r 211-037• 3.Address: 6.API Number: Stratigraphic fi Service r P. 0. Box 100360,Anchorage,Alaska 99510 50-103-20638-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r• No F.7 CD3-128 9.Property Designation(Lease Number): 10.Field/Pool(s): ADK 25538,•372105 Colville River Field/Fiord 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): 13020 6983 13010' 6980' Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 114' 114' Surface 2909' 9-5/8" 2989' 2452' Production 12980' 7" 13010' 6980' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none none - - Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r" BOP Sketch r Exploratory Development •r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/10/2011 Oil rl • Gas I WDSPL in Suspended IT 16.Verbal Approval: Date:04/28/2011 WINJ IT GINJ r• WAG n, Abandoned T Commission Representative:Guy Schwartz GSTOR 17 SPLUG IT 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nina Anderson @ 265-6403 Printed Name ina Anderson Title: Drilling Engineer dN) Signature NeL-" e Phone:265-6403 Date �l-,98-(9o)( Commission Use Only Sundry Number:5 \- I Conditions of approval: Notify Commission so that a representative may witness RECEIVED SED Plug Integrity IT BOP Test IT Mechanical Integrity Test T Location Clearance IT \pp 2 6 IU`I Other: Alaska Gil&Gas Cans.6om issioi1 Subsequent Form Required: IO-•L(67 é_:4_. çie. ./J ca." 4.44.0...) .{pcma(ge APPROVED BY 4 , Approved by: OMMISSIONER THE COMMISSION Date: 5-13 // / RBDMS MAY 0 41011 y.2,•cc s� q• zcj• /i Form 10-403 Revised 1/2010 RIG I N A L Submit inDyplic�1 Fiord Kuparuk: CD3-128 ReviseProgram for Kuparuk Completion Procedure 1. Move rig onto CD3-128. 2. Rig up riser. 3. Drill 12-1/4" hole to surface casing point as per the directional plan (Directional/GR/RES) 4. Run and cement 9-5/8"surface casing. 5. Install BOPE and test to 3,500 psi high and 250 psi low. 6. Pick up and run in the hole with 8-3/4"drilling BHA. 7. Pressure test casing to 2,500 psi. 8. Drill out 20' of new hole and perform leak off test. 9. Drill 8-3/4" hole to intermediate casing point into the Nechelik reservoir sand (MWD/PWD/GR/RES/Dens/Neut). 10. Run and cement 7" casing as per drilling program. If needed, a second stage cement job will be pumped to isolate the K2 (Qannik)formation. 11. Perform a leak off test down the 9-5/8"x 7" annulus to confirm the fracture pressure referenced to the surface casing shoe. Freeze protect casing annulus to surface. 12. Drill out HES cementing tool used to isolate the Qannik formation. 13. Continue running in hole to TD with milling assembly. Circulate bottoms up 14. Pressure test 7" intermediate casing to 3,500 psi for 30 mins. 15. Displace the drilling mud to 9.6 ppg brine. Trip out of hole. 16. Run upper completion: 3-1/2", 9.3 ppf, L-80 tubing with DB Profile, GLM, Baker FHL Packer, PBR, and XN nipple. _STA 17. Drop ball and rod to set packer. Hold pressure on the tbg and shear PBR. C1141,"" 18. Sting in, space out, and land hanger. - 1 ° 19. Install two way check valve and pressure test hanger seals to 5,000 psi. Tests will be recorded. • 20. Pull TWC. 21. Test tbg to 3500 psi for 30 minutes. Bleed down tbg to 2000 psi and pressure test annulus to 3500 psi for 30 minutes. Bleed tbg to 0 psi to sheer casing to tbg DCK-2 SOV. Bleed tubing and annulus pressure to zero. 22. Install TWC and pressure test through SOV to 2600 psi to test in the direction of flow. Nipple down BOP. 23. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 24. Circulate tubing and IA to diesel through sheared DCK-2 valve. 25. Set BPV and secure well. Move rig off CD3-128. 26. Pull BPV after rig moves. 27. Rig up slickline, pull sheared DCK-2 valve, install orifice valve, pull ball-and-rod, pull RHC plug body, drift for p E-line perf guns. Rig down slickline. 1 D`�� 28. Rig up E-line. Run slim hole cement bond log. Tie in pert guns, underbalance perforate Kuparuk C sand 43, from 12477-12494' MD-RKB. Measure static bottom hole pressure. Rig down E-line. • Colville River Field CD3-128 Kuparuk Producer Well Completion 16" 62.6#Welded Conductor Note: Casing Details are As-Run. to 114'MD Tubing details are As-Planned. Schematic Up To Date as of 4/27/2011 4-1/2" 12.6#L-80 IBT-M to—130'MD 3-1/2" 9.3#L-80 EUE-8RD-Mod below (Planned) sssv Upper Completion(planned): MD TVD 1)3-1/2 Camco TRMAXX-5E w/ 2160' 2000' 2.812 X Profile control line to surface, 9-5/8"40 ppf L-80 BTC-Mod with 1/4 Surface Casing banded to tbg w/SS bands (45.2°) @ 2989'MD/2451'TVD/63.5° O GL J cemented to surface 2)3-'/ x 1 Camco KBMG GLM w/DV(63.3°) 5086' 3400' 3)3-1/ x 1 Camco KBMG GLM w/DV(63.3°) 9982' 5600' Calculated TOC @ 5990'MD/3796'TVD/63.6° 4)3-1/ x 1 Camco KBMG GLM w/DCK2(60.3°) 12287' 6733' Pinned for 2500 psi casing to tbg shear Top Qannik 0 O 0 6494'MD/4022'TVD 5)Baker FHL Packer and 20'PBR(60.6°) 12327' 6753' ES Cementer @ 6)HES 2.812"XN Profile w/2.75"No-Go(61°) 12367' 6772' 7230'MD/4360'TVD/63.6° w/RHC plug body kk 7)Wireline Entry Guide (61.1°) 12377' 6777' O GI_ _I Top HRZ 11888'MD/6539'TVD/61.4° Calculated TOC @ 11,977'MD/6582'TVD/60.6° 0 Top Kuparuk C �� 12477'MD/6825'TVD/62.3° _, Planned Perforations -10-© 12477'MD(6825'TVD/62.3°)-12494'MD(6832'TVD)62.9° (Kuparuk C Sand) O Top Nechelik O 12913'MD/6967'TVD/80° 6 O , TD @ 13020'MD/6983'TVD 7"26#L-80 BTC-Mod 13010'MD/6980'TVD/81.9° Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, April 29, 2011 11:12 AM To: 'Hunt, Hai L' Cc: 'Anderson, Nina M' Subject: RE: CD3-128: 10-403 for Scope Change (Reference: PTD#211-037) Nina/Hai, You have verbal approval to proceed with the plan as outlined in your emailed sundry document. The change of scope includes perforating the Kuparuk Zone and completing the well to flow"C sand" until rig comes back to drill out the Nechelik horizontally. As stated below you will have to submit a revised PTD to re-enter the well and complete as a Nechelik well. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 27, 2011 11:33 AM To: 'Hunt, Hai L' Cc: Anderson, Nina M Subject: RE: CD3-128: 10-403 for Scope Change (Reference: PTD#211-037) Hai, The Sundry is pretty close to what we need. I would also send a revised outline of the rig procedure for completing the well as a Kuparuk producer. The normal 407 will follow with the operational details... . When you decide to drill out into the Nechelik you will need to resubmit a revised PTD. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Hunt, Hai L [mailto:Hai.L.Hunt@conocophillips.com] Sent: Wednesday, April 27, 2011 11:21 AM To: Schwartz, Guy L (DOA) Cc: Anderson, Nina M Subject: CD3-128: 10-403 for Scope Change (Reference: PTD#211-037) Guy, Please take a look at this and let us know what we need to do to make sure the correct form is filled out correctly. Hai Hunt Completion Engr ConocoPhillips Alaska,Inc. 4/29/2011 Page2of2 Office:(907)263-4674 Cell: (907)317-6342 Email: Hai.L.Hunt©ConocoPhillips.com 4/29/2011 4111 Page 1 of 1 Regg, James B (DOA) From: Doyon 19 Tool Pusher[doyon13@conocophillips.com] 11 Sent: Monday, May 02, 2011 11:31 AM Pri)To: Regg, James B (DOA) Z�l Cc: Doyon 19 Company Man • Subject: Rig 19 methane detector Jim, The methane detector above the shakers that failed during the previous BOP test(4-15)was repaired on 4:16. The electrician found a connection that was not properly attached. He retested it at that time and its functioned properly ever since. He also tested all of the alarms after the rig move last night(5-1) and ✓ all of them are working. If you need any more information, let me know. John Welsh Tool Pusher rig 19 670-4302 • 5/2/2011 suciE LimamA SEAN PARNELL, GOVERNOR O ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-128 ConocoPhillips Alaska, Inc. Permit No: 211-037 Surface Location: 4027' FNL, 1205' FEL, SEC. 05, T12N, R5E, UM Bottomhole Location: 2731' FNL, 802' FEL, SEC. 18, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 0/ Daniel T. Seamount, Jr. Chair DATED this g day of March, 2011. cc: Department of Fish 85 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED' STATE OF ALASKA IQR 0 4 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL erica Oil&GesCons. 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone Q 1c.Specify if we l for: Drill Q Re-drill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG El Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • CD3-128 , 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:20439' . TVD: 7077' . Colville River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): 4027'FNL, 1205'FEL,Sec. 5,T12N, R5E, UM ADL 25538,372105 ' Fiord Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2069'FNL,67'FEL, Sec. 12,T12N, R4E, UM LAS2112 4/1/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2731'FNL, 802'FEL,Sec. 18,T12N, R5E, UM 2560 +/-1.5 miles to ADL 391451 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: .. 49.1 feet 15.Distance to Nearest Well Open Surface:x- 387837.5 ' y- • 6003752.7 Zone- 4 GL Elevation above MSL: . 12.8 feet to Same Pool: CD3-118,2027 16.Deviated wells: Kickoff depth: 400 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 89.06° deg Downhole:3300 psig • Surface:2592 psig , 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD/ TVD MD V TVD (including stage data) 24" 16" 62.5 H-40 Welded 71 37 37 108 108 Pre Installed 12.25" 9.625" 40 L-80 BTC 2934 37 37 2971 2450 425 sx AS Lite 3,232 sx 15.8'G' 8.75" 7" 26 L-80 BTC-M 13167 37 37 13204 6947 1st-285 sx 15.8'G' 2nd-190 sx 15.8 G 4.5" 12.6 L-80 IBT-M 12922 32 32 12954 6907 Tubing 6.125" 4.5" 12.6 L-80 SLHT 12129 8300 6923 20429 7077 Slotted liner with blanks 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective 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❑ BOP Sketch❑ Drilling Program❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21.Verbal Approval: Commission Representative: Date: d�� 22. I hereby certify that the foregoing is true and correct. Contact Nina Anderson @ 265-6443{^ Printed Name Chip Alvord Title Alaska Drilling Manager Signature gra 6111-1 I-f.N row.e0: „... ....c., Phone 265-6120 Date C. -t.la Atvo'K-O 3is/2o1/ Commission Use Only Permit to Drill API Number: �7� Permit Approval See cover letter Number: .7/037 50-/O -,Zi S c J"� Date: (�I 1 1 for other requirements Conditions of approval: If box is checked may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: ►r 1 - 3500/054 (301' f 5 Samples req'd: Yes ❑ No Ri Mud log req'd: Yes ❑ No Er Other: *ZSO& ps;. An.,IA<a.t !e•s -C 1I S measures: Yes ❑ No G f Directional svy req'd: Yes 2' No ❑ D%dtr.k.✓ L J4/ae.Q /tom Lo AAc ZS03J)(z) 4 MIT E C5L re744.Cre.f. 1r' u�4�Yh�/4. pQ��.Oh f t rt CC-'0,- 1�W !'4,'o 303 , ' •;" ED BY THE COMMISSION J&'',i1 1 DATE: �_ A ` COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for mon hs from the date of approval(20 • • 25.005(g) ,0 ` in[&1Dlicate ConocoPhillips Alaska, Inc. Post Office Box 100360 1111V Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 March 3rd, 2011 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MAR 0 4 2011 Re: Application for Permit to Drill CD3-128 Wks Oil&6 s Cons.Com tinthorage Dear Sir or Madam: , ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshor ion well from the CD3 (Fiord) pad. The intended spud date for this well is April 1st, 2011. It is intended that Doyon Rig 19 be used to drill the well. CD3-128 will penetrate the reservoir horizontally. After setting the 7" intermediate casing, the horizontal section will be drilled and the well completed as a Nechelik injector. Once completed, the well will be flowed back to mitigate reservoir damage and then hooked up to begin injection. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. It is , planned to pump lead cement through the intermediate casing shoe and then open a stage tool and pump a second cement job to isolate the K2 formation with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. This will be the 7th winter season of drilling on the Fiord pad and there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program with request for approval of annular pumping operations 3. A proposed completion diagram 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Nina Anderson at 265-6403, or Chip Alvord at 265-6247. Sincerely, Nina Andersen Drilling Engineer Attachments cc: CD3-128 Well File/Sharon Allsup Drake ATO 1530 Liz Galiunas ATO 1500 Ryan Robertson ATO 1702 Mike A Winfree ATO 1708 Lanston Chin Kuukpik Corporation • CD3-128 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Employ gyro single shots and traveling cylinder diagrams. Gas Hydrates Low Monitor well at base of permafrost, increase mud • weight, decreased mud viscosity, increase circulating times, control drilling rates and low mud temperatures. Running Sands and Gravel Low Maintain planned mud parameters, increase mud weight if needed and use weighted sweeps. Abnormal Pressure in Low Increase mud weight to 9.6—9.8 ppg. Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, thin mud rheology, pump LCM pills and use of low density cement slurries. 8-3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills. Mud weight of 9.6 ppg or higher. Flow Surface Formations checks during connections. Mud weight increase if >2000' TVD needed. Lost.circulation Low Reduced pump rates and trip speeds. Real time equivalent circulating density(ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties. Ensure proper hole fill. Pump out of hole if needed. Monitor real time equivalent circulating density(ECD). Use of weighted sweeps. Abnormal Reservoir Low Well control drills. Increase mud weight. No mapped Pressure faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills. Detection systems and alarms. Use standard well control practices. Employ mud • scavengers. 6-1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates and trip speeds. Real time equivalent circulating density(ECD) monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced trip speeds. Pump out to 7" shoe. Engineered mud properties. Ensure proper hole fill. Pump out of hole if need. Monitor real time equivalent circulating density(ECD). Use weighted sweeps. Abnormal Reservoir Medium BOPE drills. Keep mud weight above 9.0 ppg. Pressure Check for flow during connections and if needed. • Increase mud weight if necessary. Perform well control drills. Hydrogen Sulfide gas Low H2S drills. Detection systems and alarms. Use standard well control practices. Employ mud • U R c V��r 1i L Fiord Nechelik : CD3-128 Procedure 1. Move rig onto CD3-128. 2. Rig up riser. Nb p - 1.1.1a.tvcoQ) 3.7.1r 3. Drill 12-1/4" hole to surface casing point as per the directional plan (Directional/GR/RES) • 4. Run and cement 9-5/8"surface casing. 5. Install BOPE and test to 3,500 psi high and 250 psi low. . 6. Pick up and run in the hole with 8-3/4"drilling BHA.• 7. Pressure test casing to 2,500 psi. ' 8. Drill out 20' of new hole and perform leak off test. 9. Drill 8-3/4" hole to intermediate casing point into the Nechelik reservoir sand (MWD/PWD/GR/RES/Dens/Neut). R,4Ms Tb 7" 10. Run and cement 7" casing as per drilling program. If needed, a second stage cement job will be pumped to isolate the K2 (Qannik)formation. • 11. Perform a leak off test down the 9-5/8" x 7" annulus to confirm the fracture pressure referenced to the surface casing shoe. Freeze protect casing annulus to surface. 12. Perform BOPE test to 3,500 psi high and 250 psi low. • 13. Pick up and run in hole with 6-1/8"drilling BHA. 14. Drill out HES cementing tool used to isolate the Qannik formation. 15. Pressure test 7" intermediate casing to 3,500 psi. • 16. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. . 17. Perform MADD pass with BAT Sonic tool while tripping to bottom to ensure first stage cement quality G84 lerl- ‘-o4 7 /leoo •1.4.0, 4. IA-IC- co+., 18. Displace well to Flo-Thru mud system. Sem -roc_ f 7•a 19. Drill 6-1/8" horizontal section to well TD (LWD Program: MWD/PWD/GR/RES/BATSonic for cement eval) 20. Circulate hole clean and pull out of hole. ° 21. Run lower completion-4-1/2", 12.6 ppg, L-80 slotted liner with blanks across shale. • 22. Run upper completion: 4-1/2", 12.6 ppf, L-80 tubing with DB Profile, GLM, Premier Packer, and XN nipple. ° 23. Drop ball and rod to set packer. Sting in, space out, and land hanger. ° 24. Install two way check valve and pressure test hanger seals to 5,000 psi. Pull TWC. ° 25. Test tbg to 3500 psi for 30 minutes. Bleed down tbg to 2000 psi and pressure test annulus to 3500 psi for 30 minutes. Bleed tbg to 0 psi to sheer casing to tbg DCK-2 SOV. Bleed tubing and annulus pressure to zero. 26. Install TWC and pressure test throu h SOV to 1000 psi in the direction of flow. Nipple down BOP. 27. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. • 28. Circulate tubing to diesel and install freeze protection in the annulus. • 29. Set BPV and secure well. Move rig ff D -1 8 Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. CD3-118 is the closest existing well with a clearance factor less than 2.0. Ellipse to ellipse separation is 47.85' @ 2141' MD. Drilling Area Risks: There are not any high risk events anticipated. . No over pressured zones are expected. . Faulting within the Nechelik reservoir is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with any drilling fluid losses to the drilled formations. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3-128 will be injected into a permitted annulus on the CD3 pad, or the class 1 disposal well on CD1 pad. The CD3-128 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000'TVD. Significant hydrocarbon zones include the Nechelik reservoir, and potentially the Qannik and Kuparuk reservoir. There will be 500' of cement fill placed above the top of the Kuparuk reservoir, along with 500' of cement above and below the Qannik reservoir as per regulations. Once CD3-128 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure= (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg)*(0.052) * (2450') + 1,500 psi = 3028 psi Pore Pressure = 1,108 psi Therefore Differential = 3028— 1108 = 1920 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and.intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85%of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi 2,626 psi 5,750 psi 4,887 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL S ° Area Injection Order ,/r 7'/l There are not any wells that are within a %mile radius of the planned CD3-128 Nechelik injector that-faA-ia-a- (,? b-different pool., Refer to the closest in pool diagrams found in the Directional Packet. —~" r r( .1. iv.' tut-. ' CD4-16 is an Alpine A producer well that has a cemented intermediate casing shoe. CD3-319 is a Kuparuk well C ,that also has a cemented intermediate casing shoe, and is geologically isolated from the Alpine reservoir. Nanuq 3 .tom{d..d is an exploration well that was plugged and abandoned in 2007. This well was never completed although it does 4k 7 H<<t- 4�s•'' have intermediate casing and all hydrocarbon zones cemented. a tea At( wY Ck DRILLING FLUID PROGRAM +, SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point-8-3/4" Section-6-1/8" point- 12-1/4" Density 8.7- 10.0 ppg . 9.6- 10.2 ppg PV 10- 16 7- 12 YP 30-60 13-16 upper clays, 10 - 15 18-22 in lower section Funnel Viscosity 70-300 4-8 Initial Gels 10 Sec 8 - 10 6 -9 10 minute gels < 20 8 - 12 API Filtrate NC- 10 cc/30 min < 5 cc/30 min HPHT Fluid Loss at 160 < 8 cc/30 min by HRZ < 10 cc/30 min PH 8.5-9.0 9.0- 10.0 9.0-9.5 KCL <20 3 % MBT Surface Hole: A standard high viscosity fresh water gel spud mud is planned for the surface interval. Flow line viscosity will be kept at ± 300 sec/qt while drilling gravels. Viscosity prior to cementing will be reduced to ± 80-100 sec/qt. Mud weight will be maintained at <9.8 ppg by use of solids control system and dilution where necessary. Using cold make up water will help keep the flow line temperature as low as possible. Intermediate Hole Section: A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists, particularly after the Nechelik reservoir is penetrated. Mud weight will be maintained at or below 10.2 ppg to minimize losses, and lost , circulation material will be introduced to the system if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)will all be beneficial in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a MI Swaco's Flo-Thru drill-in fluid. The base fluid will consist of 3% KCI, with calcium carbonate bridging material to minimize formation damage. Flowzan Polymer and Thrutrol starch will be used for viscosity and fluid loss control respectively. Kiagard will be used for inhibition. ECD's will be monitored with real time PWD data, and controlled by maintaining fluid rheology and pump rates within specifications. ORIGINAL Completion Schematic Colville River Field CD3-128 Nechelik Injector Well Completion 16"Conductor to 114' Updated 03/03/2011 ODB Nipple @ 2147'MD/2000'TVD Sperry Drilling Services CD3-128wp03 4-1/2" 12.6 ppf IBT M tubing run with Jet Lube Run'n'Seal pipe dope MIL 9-5/8"40 ppf L-80 BTC-Mod Surface Casing 2971'MD/2450'TVD cemented to surface TOC @ +/- 5973' MD/ A 77.7 3798'TVD Qannik interval top+/-6473' MD/4023'TVD Ibex I. J ES Cementer +/-7017' MD/I •0 0 0 4267'TVD 4 Upper Completion MD TVD 1)Tubing Hanger 32' 32' 2)4-'/2"12.6#/ft IBT-Mod Tubing 3)Camco DB Landing Nipple(3.813"ID) 2154' 2000' 4)4-'/2'12.6#/ft IBT-Mod Tubing 5)Camco 4-Y2"KBG-2 GLM with DV(3.883"ID) 12000' 6603' 6) 4-1/2"12.6#/ft IBT-Mod Tubing (2 joints) 7) Baker 4.5"X 7"Premier Packer 12060' 6629' 8) 4-'/" 12.6#/ft IBT-Mod Tubing (1 joints) 9) HES No-Go"XN"(3.725"min ID)@ 66° 12100' 6645' 10) 4-'/2' 12.6#/ft IBT-Mod Tubing 11) 4-'/z' 12.6#/ft IBT-Mod flutted WLEG 12954' 6907' Lower Completion: Toa MD TVD 12) HRD Setting Sleeve w/10'Tie back extension 12954' 6907' 13) Baker 5"x7"Flexlock Liner Hanger w/setting sleeve 12970' 6910' 14) 4-1/2"12.6#/ft L-80 SLHT blank&Slotted liner 15)Orange Peel Shoe with 4-'/z' 12.6#L-80 Box Up 20429' 7077' TOC Calculated +/- 11,760' MD/6488'TVD © (300'above packer&500' MD above Kuparuk) \iA 14 4 `17,44 a Eta E- )CD Top Kuparuk C at 12587'MD/6817'TVD 9 Top Nechelik at 13204' MD/6947'TVD 7"26 ppf L-80 BTC Mod Casing 6-1/8"Well TD 13204'/6947'TVD 20439' MD / 7077'TVD ORIGINAL • CD3-128 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (lbs. /gal) (psi) (psi) 16 114/ 114 10.9 52 53 9 5/8 2971 /2450 14.5 1109 1602 7" 13204/6947 16.0 3143 2592 N/A 20439/7077 16.0 3300 ** N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. • ** NOTE: Pore Pressure for production interval is estimated reservoir pressure PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) -0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052)—0.1] D = [(10.9 x 0.052)—0.1] x 114 = 53 psi OR ASP = FPP—(0.1 x D) = 1109—(0.1 x 2450') = 864 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1] x 2450 = 1602 psi OR ASP = FPP—(0.1 x D) = 3143—(0.1 x 6947') =2448 psi 3. Drilling below intermediate casing (7") ASP = Reservoir Pressure— (0.1 x D) = 3300—(0.1 x 7077') = 2592 psi • ORIGINAL • Cementing Program: 9 5/8" Surface Casing run to 2971' MD /2450' TVD. Cement from 2971' MD to 2471' (500' of fill)with Class G +Adds @ 15.8 PPG, and from 2471' to surface with Arctic Set Lite 3. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1234' MD). Lead slurry: (2471'-1234') X 0.3132 ft3/ft X 1.5 (50% excess) = 581 ft3 below permafrost (1234' -80') X 0.3132 ft3/ft X 3.5 (250% excess) = 1265 ft3 above permafrost ConductorVolume = 80' X 0.7632 ft3/ft = 61 ft Total volume = 581 + 1265 + 61 = 1907 ft3 => 425 Sx @ 4.49 ft3/sk System: 425 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.49 ft3/sk Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) =235 ft3 annular volume 80' X 0.4258 ft3/ft= 34 ft3 shoe joint volume Total volume =235 + 34 =269 ft3 =>232 Sx @ 1.16 ft3/sk System: 232 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.16 ft3/sk 7" Intermediate Casing run to 13204' MD /6947' TVD: Cemented in two stages Cement from 13204' MD to 11760' MD (300' MD above the packer& minimum 500' MD above top of Kuparuk reservo ri with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage: Lead: (13204' - 11760') X 0.1503 ft3/ft X 1.4 (40% excess) = 304 ft3 annular vol. 120' X 0.2148 ft3/ft=26 ft3 shoe joint volume Total volume = 304 + 26 = 330 ft3 =>285 Sx @ 1.16 ft3/sk System: 285 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a stage tool set 500' below the Qannik(K2) interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (7017' - 5973') X 0.1503 ft3/ft X 1.4 (40% excess) =220 ft3 annular vol. Total Volume= 220 ft3=> 190 Sk @ 1.16 ft3/sk ✓ System: 190 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.16 ft3/sk ORIGINAL P ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad Plan: CD3-128 Plan: CD3-128 Plan: CD3-128wp03 Adjusted to account for AC changes after drilling CD3-127. Changed kick-off depth. 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I �I 1 1 1sat l I , Q see e I (I) � R (u!/b 009Z)41dea 120iJa/awl o ORIGINALo 0 0 to Oppi _ 0 1 —o > r000 r x C o 1000 oo - Ln •000 `O cQc o ! 4000 61V —0 — J 1 0 0 .000 6) o 00 0 _o + rn 000 00c' w o6, J 000 00 - ' o °' o<3, 22 o 00 O a 000 0 .e x MN D00 om! M O CL O 100p0 000 -Lo s ti Z00 000'`N o 0, CO ^moo o s N 0 V' -o i o M 0 co VcO oo x 0 0 0 0 0 0 0 0 0 0 0 0 0 0 to o to o to o co d- co ti rn (U!/14 0050 (+)LIpoN/(-)1I , o 0 O £OdM8Z6-£a3 o0 —Lc) a) .. o3 > 6£170Z co C 00002 1( x _o N co O M IIMIll ♦ma 00061- (i) 0066V o (u _o 00086 c 0 000L1- o 0 -o M o O O 6 00096 L O (6 O , O 00056 U U U) OC6 o 0 U ZD o M o a o 000t76 a) 03N p oo —o > M ,,C?' a 006 - Q ho o 000c m oo� Oo 1r co o O O cOx N ^ ADO O�� O�z O CO -� O O� x N Id �' o M _o 0 M 0 0 0 Lc, 1 0 00 0 0 0 0 0 0 0 0 ir) 0 0 LU co co h- (uii1 0090 uadaa Ie3!TJOA anal ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-128 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) ' Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-128 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-128 Design: CD3-128wp03 Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor 1 Site CD3 Fiord Pad Site Position: Northing: 469.98ft Latitude: 53°58'43.652 N From: Map Easting: -401.27 ft Longitude: 152° 19'30.231 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -1.88° Well Plan:CD3-128 Well Position +N/-S 0.00 ft Northing: 6,003,752.67 ft - Latitude: 70°25'9.066 N +El-W 0.00 ft Easting: 387,837.53 ft • Longitude: 150°54'49.408 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.80ft , Wellbore Plan:CD3-128 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2009 2/24/2011 16.35 79.74 57,380 Design CD3-128wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 `Vertical Section: Depth From(TVD) +N/-S +E/-W Direction Ir (ft) (ft) (ft) (0) 36.30 0.00 0.00 155.00 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (0/100ft) (0/100ft) (0/100ft) (°) 36.30 0.00 0.00 36.30 -12.80 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 350.90 0.00 0.00 0.00 0.00 0.00 0.00 600.09 3.00 295.00 600.00 550.90 2.21 -4.75 1.50 1.50 0.00 295.00 901.89 9.04 295.00 900.00 850.90 15.58 -33.42 2.00 2.00 0.00 0.00 1,101.89 14.92 282.50 1,095.59 1,046.49 27.81 -72.84 3.20 2.94 -6.25 -30.00 1,600.94 29.43 263.77 1,557.00 1,507.90 28.42 -258.67 3.20 2.91 -3.75 -35.00 2,800.94 63.30 260.00 2,373.20 2,324.10 -100.45 -1,104.57 2.83 2.82 -0.31 -6.04 10,227.29 63.30 260.00 5,710.00 5,660.90 -1,252.52 -7,638.26 0.00 0.00 0.00 0.00 11,803.48 59.77 204.00 6,510.00 6,460.90 -2,045.45 -8,672.02 3.10 -0.22 -3.55 -108.00 12,173.30 67.16 204.00 6,675.10 6,626.00 -2,347.51 -8,806.51 2.00 2.00 0.00 0.00 13,204.07 83.00 170.00 6,947.10 6,898.00 -3,317.93 -8,914.54 3.52 1.54 -3.30 -69.55 13,254.07 83.00 170.00 6,953.19 6,904.09 -3,366.80 -8,905.92 0.00 0.00 0.00 0.00 13,481.80 90.00 164.00 6,967.10 6,918.00 -3,588.03 -8,854.80 4.04 3.07 -2.63 -40.78 13,980.29 89.06 144.08 6,971.23 6,922.13 -4,033.95 -8,637.71 4.00 -0.19 -4.00 -92.76 20,438.67 89.06 144.08 7,077.10 7,028.00 -9,263.60 -4,849.53 0.00 0.00 0.00 0.00 2/25/2011 5:27:36PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-128 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-128 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-128 Design: CD3-128wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -12.80 36.30 0.00 0.00 36.30 -12.80 0.00 0.00 6,003,752.67 387,837.53 0.00 0.00 100.00 0.00 0.00 100.00 50.90 0.00 0.00 6,003,752.67 387,837.53 0.00 0.00 200.00 0.00 0.00 200.00 150.90 0.00 0.00 6,003,752.67 387,837.53 0.00 0.00 300.00 0.00 0.00 300.00 250.90 0.00 0.00 6,003,752.67 387,837.53 0.00 0.00 400.00 0.00 0.00 400.00 350.90 0.00 0.00 6,003,752.67 387,837.53 0.00 0.00 Start Build 1.50 TFO 295 500.00 1.50 295.00 499.99 450.89 0.55 -1.19 6,003,753.24 387,836.35 1.50 -1.00 600.00 3.00 295.00 599.91 550.81 2.21 -4.74 6,003,754.95 387,832.82 1.50 -4.01 600.09 3.00 295.00 600.00 550.90 2.21 -4.75 6,003,754.95 387,832.82 1.50 -4.01 Start Build 2.00 700.00 5.00 295.00 699.66 650.56 5.16 -11.07 6,003,757.99 387,826.55 2.00 -9.35 800.00 7.00 295.00 799.11 750.01 9.58 -20.54 6,003,762.55 387,817.14 2.00 -17.36 900.00 9.00 295.00 898.13 849.03 15.46 -33.15 6,003,768.62 387,804.62 2.00 -28.02 901.89 9.04 295.00 900.00 850.90 15.58 -33.42 6,003,768.75 387,804.35 2.00 -28.25 Start DLS 3.20 TFO-30.00 1,000.00 11.86 287.34 996.47 947.37 21.85 -50.03 6,003,775.26 387,787.84 3.20 -40.94 1,100.00 14.87 282.57 1,093.76 1,044.66 27.70 -72.36 6,003,781.45 387,765.60 3.20 -55.69 1,101.89 14.92 282.50 1,095.59 1,046.49 27.81 -72.84 6,003,781.56 387,765.13 3.20 -55.99 Start DLS 3.20 TFO-35.00 1,200.00 17.59 276.53 1,189.77 1,140.67 32.23 -99.90 6,003,786.39 387,738.13 3.20 -71.43 1,232.95 18.51 274.91 1,221.10 1,172.00 33.25 -110.06 6,003,787.56 387,727.99 3.20 -76.65 Base Permafrost 1,300.00 20.44 272.05 1,284.31 1,235.21 34.58 -132.37 6,003,789.22 387,705.71 3.20 -87.28 1,400.00 23.37 268.64 1,377.09 1,327.99 34.73 -169.65 6,003,789.94 387,668.43 3.20 -103.17 1,500.00 26.37 265.96 1,467.81 1,418.71 32.69 -211.65 6,003,788.53 387,626.42 3.20 -119.07 1,600.00 29.40 263.79 1,556.19 1,507.09 28.47 -258.21 6,003,785.01 387,579.80 3.20 -134.93 1,600.94 29.43 263.77 1,557.00 1,507.90 28.42 -258.67 6,003,784.97 387,579.34 3.20 -135.08 Start DLS 2.83 TFO-6.04 1,700.00 32.22 263.22 1,642.06 1,592.96 22.66 -309.10 6,003,779.96 387,528.83 2.83 -151.17 1,800.00 35.04 262.74 1,725.31 1,676.21 15.88 -364.06 6,003,774.01 387,473.78 2.83 -168.25 1,900.00 37.86 262.33 1,805.74 1,756.64 8.15 -422.97 6,003,767.17 387,414.77 2.83 -186.14 2,000.00 40.68 261.96 1,883.15 1,834.05 -0.51 -485.66 6,003,759.46 387,351.96 2.83 -204.79 2,100.00 43.50 261.63 1,957.35 1,908.25 -10.08 -552.00 6,003,750.89 387,285.49 2.83 -224.15 2,200.00 46.33 261.34 2,028.16 1,979.06 -20.53 -621.82 6,003,741.48 387,215.53 2.83 -244.18 2,300.00 49.15 261.07 2,095.41 2,046.31 -31.85 -694.95 6,003,731.27 387,142.24 2.83 -264.83 2,400.00 51.97 260.83 2,158.93 2,109.83 -44.00 -771.21 6,003,720.26 387,065.82 2.83 -286.05 2,500.00 54.80 260.60 2,218.57 2,169.47 -56.95 -850.41 6,003,708.50 386,986.43 2.83 -307.79 2,600.00 57.62 260.39 2,274.17 2,225.07 -70.68 -932.37 6,003,696.01 386,904.28 2.83 -329.98 2,670.93 59.63 260.25 2,311.10 2,262.00 -80.86 -992.06 6,003,686.73 386,844.45 2.83 -345.98 C-40 2,700.00 60.45 260.19 2,325.62 2,276.52 -85.14 -1,016.88 6,003,682.82 386,819.57 2.83 -352.59 2,800.00 63.27 260.00 2,372.78 2,323.68 -100.31 -1,103.74 6,003,668.96 386,732.50 2.83 -375.55 2,800.94 63.30 260.00 2,373.20 2,324.10 -100.45 -1,104.57 6,003,668.83 386,731.68 2.83 -375.77 Start 7426.35 hold at 2800.94 MD 2,900.00 63.30 260.00 2,417.71 2,368.61 -115.82 -1,191.72 6,003,654.77 386,644.31 0.00 -398.67 2/25/2011 5:27:36PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-128 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8©49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-128 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-128 Design: CD3-128wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) (°) (') (ft) ft (ft) (ft) (ft) (ft) 2,400.90 2,971.87 63.30 260.00 2,450.00 2,400.90 -126.97 -1,254.95 6,003,644.58 386,580.93 0.00 -415.29 9-5/8"x 12-1/4" 3,000.00 63.30 260.00 2,462.64 2,413.54 -131.33 -1,279.70 6,003,640.58 386,556.11 0.00 -421.80 3,038.86 63.30 260.00 2,480.10 2,431.00 -137.36 -1,313.89 6,003,635.07 386,521.84 0.00 -430.78 C-30 3,100.00 63.30 260.00 2,507.57 2,458.47 -146.85 -1,367.68 6,003,626.40 386,467.92 0.00 -444.92 3,200.00 63.30 260.00 2,552.51 2,503.41 -162.36 -1,455.66 6,003,612.21 386,379.72 0.00 -468.04 3,300.00 63.30 260.00 2,597.44 2,548.34 -177.87 -1,543.64 6,003,598.02 386,291.53 0.00 -491.16 3,400.00 63.30 260.00 2,642.37 2,593.27 -193.39 -1,631.62 6,003,583.83 386,203.33 0.00 -514.28 3,500.00 63.30 260.00 2,687.30 2,638.20 -208.90 -1,719.60 6,003,569.64 386,115.14 0.00 -537.41 3,600.00 63.30 260.00 2,732.23 2,683.13 -224.41 -1,807.58 6,003,555.45 386,026.94 0.00 -560.53 3,700.00 63.30 260.00 2,777.16 2,728.06 -239.93 -1,895.56 6,003,541.27 385,938.74 0.00 -583.65 3,800.00 63.30 260.00 2,822.10 2,773.00 -255.44 -1,983.54 6,003,527.08 385,850.55 0.00 -606.77 3,882.35 63.30 260.00 2,859.10 2,810.00 -268.22 -2,055.99 6,003,515.39 385,777.92 0.00 -625.82 C-20 3,900.00 63.30 260.00 2,867.03 2,817.93 -270.95 -2,071.52 6,003,512.89 385,762.35 0.00 -629.90 4,000.00 63.30 260.00 2,911.96 2,862.86 -286.47 -2,159.50 6,003,498.70 385,674.16 0.00 -653.02 4,100.00 63.30 260.00 2,956.89 2,907.79 -301.98 -2,247.48 6,003,484.51 385,585.96 0.00 -676.14 4,200.00 63.30 260.00 3,001.82 2,952.72 -317.49 -2,335.46 6,003,470.32 385,497.77 0.00 -699.26 4,300.00 63.30 260.00 3,046.76 2,997.66 -333.01 -2,423.44 6,003,456.14 385,409.57 0.00 -722.38 4,400.00 63.30 260.00 3,091.69 3,042.59 -348.52 -2,511.42 6,003,441.95 385,321.38 0.00 -745.51 4,500.00 63.30 260.00 3,136.62 3,087.52 -364.03 -2,599.40 6,003,427.76 385,233.18 0.00 -768.63 4,600.00 63.30 260.00 3,181.55 3,132.45 -379.55 -2,687.38 6,003,413.57 385,144.99 0.00 -791.75 4,700.00 63.30 260.00 3,226.48 3,177.38 -395.06 -2,775.36 6,003,399.38 385,056.79 0.00 -814.87 4,800.00 63.30 260.00 3,271.42 3,222.32 -410.57 -2,863.34 6,003,385.19 384,968.59 0.00 -837.99 4,900.00 63.30 260.00 3,316.35 3,267.25 -426.08 -2,951.32 6,003,371.01 384,880.40 0.00 -861.12 5,000.00 63.30 260.00 3,361.28 3,312.18 -441.60 -3,039.30 6,003,356.82 384,792.20 0.00 -884.24 5,100.00 63.30 260.00 3,406.21 3,357.11 -457.11 -3,127.28 6,003,342.63 384,704.01 0.00 -907.36 5,200.00 63.30 260.00 3,451.14 3,402.04 -472.62 -3,215.26 6,003,328.44 384,615.81 0.00 -930.48 5,300.00 63.30 260.00 3,496.08 3,446.98 -488.14 -3,303.24 6,003,314.25 384,527.62 0.00 -953.61 5,400.00 63.30 260.00 3,541.01 3,491.91 -503.65 -3,391.22 6,003,300.06 384,439.42 0.00 -976.73 5,500.00 63.30 260.00 3,585.94 3,536.84 -519.16 -3,479.20 6,003,285.88 384,351.23 0.00 -999.85 5,600.00 63.30 260.00 3,630.87 3,581.77 -534.68 -3,567.18 6,003,271.69 384,263.03 0.00 -1,022.97 5,700.00 63.30 260.00 3,675.80 3,626.70 -550.19 -3,655.16 6,003,257.50 384,174.83 0.00 -1,046.09 5,800.00 63.30 260.00 3,720.73 3,671.63 -565.70 -3,743.14 6,003,243.31 384,086.64 0.00 -1,069.22 5,900.00 63.30 260.00 3,765.67 3,716.57 -581.22 -3,831.12 6,003,229.12 383,998.44 0.00 -1,092.34 6,000.00 63.30 260.00 3,810.60 3,761.50 -596.73 -3,919.10 6,003,214.93 383,910.25 0.00 -1,115.46 6,092.37 63.30 260.00 3,852.10 3,803.00 -611.06 -4,000.36 6,003,201.83 383,828.79 0.00 -1,136.82 K-3 6,100.00 63.30 260.00 3,855.53 3,806.43 -612.24 -4,007.08 6,003,200.75 383,822.05 0.00 -1,138.58 6,200.00 63.30 260.00 3,900.46 3,851.36 -627.76 -4,095.06 6,003,186.56 383,733.86 0.00 -1,161.70 6,300.00 63.30 260.00 3,945.39 3,896.29 -643.27 -4,183.04 6,003,172.37 383,645.66 0.00 -1,184.83 6,400.00 63.30 260.00 3,990.33 3,941.23 -658.78 -4,271.02 6,003,158.18 383,557.47 0.00 -1,207.95 6,421.75 63.30 260.00 4,000.10 3,951.00 -662.16 -4,290.15 6,003,155.09 383,538.28 0.00 -1,212.98 K-3 Basal 2/25/2011 5:27:36PM PaGel rt COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTOIV Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-128 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-128 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-128 Design: CD3-128wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,974.00 6,472.94 63.30 260.00 4,023.10 3,974.00 -670.10 -4,335.19 6,003,147.83 383,493.14 0.00 -1,224.81 K-2 6,500.00 63.30 260.00 4,035.26 3,986.16 -674.30 -4,359.00 6,003,143.99 383,469.27 0.00 -1,231.07 6,600.00 63.30 260.00 4,080.19 4,031.09 -689.81 -4,446.98 6,003,129.80 383,381.08 0.00 -1,254.19 6,699.95 63.30 260.00 4,125.10 4,076.00 -705.32 -4,534.91 6,003,115.62 383,292.92 0.00 -1,277.30 K-2 Basal 6,700.00 63.30 260.00 4,125.12 4,076.02 -705.32 -4,534.96 6,003,115.62 383,292.88 0.00 -1,277.32 6,800.00 63.30 260.00 4,170.05 4,120.95 -720.84 -4,622.94 6,003,101.43 383,204.68 0.00 -1,300.44 6,900.00 63.30 260.00 4,214.99 4,165.89 -736.35 -4,710.92 6,003,087.24 383,116.49 0.00 -1,323.56 7,000.00 63.30 260.00 4,259.92 4,210.82 -751.86 -4,798.90 6,003,073.05 383,028.29 0.00 -1,346.68 7,100.00 63.30 260.00 4,304.85 4,255.75 -767.38 -4,886.88 6,003,058.86 382,940.10 0.00 -1,369.80 7,200.00 63.30 260.00 4,349.78 4,300.68 -782.89 -4,974.86 6,003,044.67 382,851.90 0.00 -1,392.93 7,300.00 63.30 260.00 4,394.71 4,345.61 -798.40 -5,062.84 6,003,030.49 382,763.71 0.00 -1,416.05 7,400.00 63.30 260.00 4,439.65 4,390.55 -813.92 -5,150.82 6,003,016.30 382,675.51 0.00 -1,439.17 7,500.00 63.30 260.00 4,484.58 4,435.48 -829.43 -5,238.80 6,003,002.11 382,587.32 0.00 -1,462.29 7,600.00 63.30 260.00 4,529.51 4,480.41 -844.94 -5,326.78 6,002,987.92 382,499.12 0.00 -1,485.41 7,700.00 63.30 260.00 4,574.44 4,525.34 -860.46 -5,414.76 6,002,973.73 382,410.92 0.00 -1,508.54 7,800.00 63.30 260.00 4,619.37 4,570.27 -875.97 -5,502.74 6,002,959.54 382,322.73 0.00 -1,531.66 7,900.00 63.30 260.00 4,664.30 4,615.20 -891.48 -5,590.72 6,002,945.36 382,234.53 0.00 -1,554.78 8,000.00 63.30 260.00 4,709.24 4,660.14 -907.00 -5,678.70 6,002,931.17 382,146.34 0.00 -1,577.90 8,100.00 63.30 260.00 4,754.17 4,705.07 -922.51 -5,766.68 6,002,916.98 382,058.14 0.00 -1,601.03 8,200.00 63.30 260.00 4,799.10 4,750.00 -938.02 -5,854.66 6,002,902.79 381,969.95 0.00 -1,624.15 8,300.00 63.30 260.00 4,844.03 4,794.93 -953.53 -5,942.64 6,002,888.60 381,881.75 0.00 -1,647.27 8,400.00 63.30 260.00 4,888.96 4,839.86 -969.05 -6,030.62 6,002,874.41 381,793.56 0.00 -1,670.39 8,500.00 63.30 260.00 4,933.90 4,884.80 -984.56 -6,118.59 6,002,860.23 381,705.36 0.00 -1,693.51 8,600.00 63.30 260.00 4,978.83 4,929.73 -1,000.07 -6,206.57 6,002,846.04 381,617.17 0.00 -1,716.64 8,700.00 63.30 260.00 5,023.76 4,974.66 -1,015.59 -6,294.55 6,002,831.85 381,528.97 0.00 -1,739.76 8,800.00 63.30 260.00 5,068.69 5,019.59 -1,031.10 -6,382.53 6,002,817.66 381,440.77 0.00 -1,762.88 8,900.00 63.30 260.00 5,113.62 5,064.52 -1,046.61 -6,470.51 6,002,803.47 381,352.58 0.00 -1,786.00 9,000.00 63.30 260.00 5,158.56 5,109.46 -1,062.13 -6,558.49 6,002,789.28 381,264.38 0.00 -1,809.13 9,100.00 63.30 260.00 5,203.49 5,154.39 -1,077.64 -6,646.47 6,002,775.09 381,176.19 0.00 -1,832.25 9,200.00 63.30 260.00 5,248.42 5,199.32 -1,093.15 -6,734.45 6,002,760.91 381,087.99 0.00 -1,855.37 9,300.00 63.30 260.00 5,293.35 5,244.25 -1,108.67 -6,822.43 6,002,746.72 380,999.80 0.00 -1,878.49 9,400.00 63.30 260.00 5,338.28 5,289.18 -1,124.18 -6,910.41 6,002,732.53 380,911.60 0.00 -1,901.61 9,481.94 63.30 260.00 5,375.10 5,326.00 -1,136.89 -6,982.50 6,002,720.90 380,839.33 0.00 -1,920.56 Albian 97 9,500.00 63.30 260.00 5,383.21 5,334.11 -1,139.69 -6,998.39 6,002,718.34 380,823.41 0.00 -1,924.74 9,600.00 63.30 260.00 5,428.15 5,379.05 -1,155.21 -7,086.37 6,002,704.15 380,735.21 0.00 -1,947.86 9,700.00 63.30 260.00 5,473.08 5,423.98 -1,170.72 -7,174.35 6,002,689.96 380,647.01 0.00 -1,970.98 9,800.00 63.30 260.00 5,518.01 5,468.91 -1,186.23 -7,262.33 6,002,675.78 380,558.82 0.00 -1,994.10 9,900.00 63.30 260.00 5,562.94 5,513.84 -1,201.75 -7,350.31 6,002,661.59 380,470.62 0.00 -2,017.22 10,000.00 63.30 260.00 5,607.87 5,558.77 -1,217.26 -7,438.29 6,002,647.40 380,382.43 0.00 -2,040.35 10,100.00 63.30 260.00 5,652.81 5,603.71 -1,232.77 -7,526.27 6,002,633.21 380,294.23 0.00 -2,063.47 10,200.00 63.30 260.00 5,697.74 5,648.64 -1,248.29 -7,614.25 6,002,619.02 380,206.04 0.00 -2,086.59 2/25/2011 5:27:36PM Page 5 COMPASS 2003.16 Build 69 OIL • ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-128 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-128 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-128 Design: CD3-128wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 5,660.90 10,227.29 63.30 260.00 5,710.00 5,660.90 -1,252.52 -7,638.26 6,002,615.15 380,181.97 0.00 -2,092.90 Start DLS 3.10 TFO-108.00 10,300.00 62.62 257.59 5,743.06 5,693.96 -1,265.10 -7,701.79 6,002,603.53 380,118.27 3.10 -2,108.34 10,400.00 61.76 254.22 5,789.72 5,740.62 -1,286.63 -7,787.56 6,002,583.29 380,032.19 3.10 -2,125.08 10,500.00 60.99 250.80 5,837.63 5,788.53 -1,313.00 -7,871.26 6,002,558.19 379,948.11 3.10 -2,136.56 10,517.42 60.86 250.20 5,846.10 5,797.00 -1,318.08 -7,885.61 6,002,553.32 379,933.68 3.10 -2,138.02 Albian 96 10,600.00 60.30 247.33 5,886.67 5,837.57 -1,344.12 -7,952.65 6,002,528.29 379,866.27 3.10 -2,142.75 10,700.00 59.70 243.82 5,936.69 5,887.59 -1,379.92 -8,031.48 6,002,493.69 379,786.91 3.10 -2,143.62 10,800.00 59.20 240.27 5,987.53 5,938.43 -1,420.27 -8,107.53 6,002,454.48 379,710.27 3.10 -2,139.19 10,900.00 58.79 236.68 6,039.06 5,989.96 -1,465.07 -8,180.58 6,002,410.79 379,636.57 3.10 -2,129.45 11,000.00 58.49 233.07 6,091.11 6,042.01 -1,514.19 -8,250.40 6,002,362.73 379,566.02 3.10 -2,114.45 11,100.00 58.28 229.44 6,143.55 6,094.45 -1,567.47 -8,316.80 6,002,310.45 379,498.83 3.10 -2,094.22 11,200.00 58.18 225.79 6,196.21 6,147.11 -1,624.77 -8,379.59 6,002,254.11 379,435.20 3.10 -2,068.82 11,300.00 58.19 222.14 6,248.93 6,199.83 -1,685.92 -8,438.56 6,002,193.86 379,375.32 3.10 -2,038.33 11,400.00 58.30 218.50 6,301.58 6,252.48 -1,750.73 -8,493.57 6,002,129.89 379,319.35 3.10 -2,002.84 11,500.00 58.51 214.87 6,353.99 6,304.89 -1,819.02 -8,544.44 6,002,062.38 379,267.47 3.10 -1,962.44 11,600.00 58.82 211.26 6,406.00 6,356.90 -1,890.59 -8,591.02 6,001,991.52 379,219.82 3.10 -1,917.26 11,700.00 59.24 207.67 6,457.47 6,408.37 -1,965.23 -8,633.18 6,001,917.53 379,176.54 3.10 -1,867.44 11,800.00 59.75 204.12 6,508.25 6,459.15 -2,042.71 -8,670.79 6,001,840.63 379,137.77 3.10 -1,813.11 11,803.48 59.77 204.00 6,510.00 6,460.90 -2,045.45 -8,672.02 6,001,837.90 379,136.50 3.10 -1,811.14 Start DLS 2.00 TFO 0.00 11,862.31 60.94 204.00 6,539.10 6,490.00 -2,092.17 -8,692.82 6,001,791.51 379,115.01 2.00 -1,777.60 Top HRZ 11,900.00 61.70 204.00 6,557.19 6,508.09 -2,122.37 -8,706.27 6,001,761.52 379,101.11 2.00 -1,755.90 12,000.00 63.70 204.00 6,603.05 6,553.95 -2,203.55 -8,742.41 6,001,680.90 379,063.75 2.00 -1,697.61 12,100.00 65.70 204.00 6,645.79 6,596.69 -2,286.13 -8,779.18 6,001,598.89 379,025.74 2.00 -1,638.30 12,173.30 67.16 204.00 6,675.10 6,626.00 -2,347.51 -8,806.51 6,001,537.93 378,997.50 2.00 -1,594.23 Start DLS 3.52 TFO-69.55-Base HRZ 12,200.00 67.50 203.05 6,685.39 6,636.29 -2,370.09 -8,816.35 6,001,515.50 378,987.33 3.52 -1,577.91 12,300.00 68.79 199.51 6,722.63 6,673.53 -2,456.56 -8,850.01 6,001,429.55 378,952.37 3.52 -1,513.77 12,323.57 69.10 198.69 6,731.10 6,682.00 -2,477.35 -8,857.21 6,001,408.88 378,944.86 3.52 -1,497.98 K-1 12,400.00 70.15 196.04 6,757.71 6,708.61 -2,545.72 -8,878.59 6,001,340.84 378,922.46 3.52 -1,445.05 12,439.97 70.71 194.67 6,771.10 6,722.00 -2,582.04 -8,888.56 6,001,304.68 378,911.94 3.52 -1,416.35 Top Kuparuk D 12,500.00 71.58 192.63 6,790.50 6,741.40 -2,637.24 -8,901.97 6,001,249.69 378,897.71 3.52 -1,371.98 12,587.12 72.87 189.71 6,817.10 6,768.00 -2,718.62 -8,918.03 6,001,168.57 378,880.43 3.52 -1,305.02 Top Kuparuk C 12,600.00 73.07 189.28 6,820.87 6,771.77 -2,730.76 -8,920.06 6,001,156.46 378,878.22 3.52 -1,294.87 12,607.68 73.18 189.03 6,823.10 6,774.00 -2,738.02 -8,921.23 6,001,149.22 378,876.94 3.52 -1,288.79 LCU 12,675.39 74.23 186.79 6,842.10 6,793.00 -2,802.39 -8,930.17 6,001,085.00 378,867.04 3.52 -1,234.23 Top Nuiqsut I 12,700.00 74.61 185.98 6,848.71 6,799.61 -2,825.94 -8,932.80 6,001,061.49 378,864.05 3.52 -1,213.99 2/25/2011 5:27:36PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-128 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8©49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-128 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-128 Design: CD3-128wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (°) (ft) ft (ft) (ft) (ft) (ft) 6,824.81 12,800.00 76.20 182.73 6,873.91 6,824.81 -2,922.42 -8,940.14 6,000,965.14 378,855.26 3.52 -1,129.65 12,830.67 76.70 181.74 6,881.10 6,832.00 -2,952.22 -8,941.31 6,000,935.37 378,853.65 3.52 -1,103.14 Base Nuiqsut 12,900.00 77.83 179.53 6,896.38 6,847.28 -3,019.83 -8,942.05 6,000,867.78 378,851.89 3.52 -1,042.18 13,000.00 79.50 176.36 6,916.04 6,866.94 -3,117.80 -8,938.53 6,000,769.78 378,853.94 3.52 -951.90 13,100.00 81.20 173.23 6,932.80 6,883.70 -3,215.96 -8,929.58 6,000,671.50 378,861.41 3.52 -859.15 13,200.00 82.93 170.13 6,946.60 6,897.50 -3,313.95 -8,915.24 6,000,573.32 378,874.28 3.52 -764.29 13,204.07 83.00 170.00 6,947.10 6,898.00 -3,317.93 -8,914.54 6,000,569.33 378,874.92 3.52 -760.38 Start 50.00 hold at 13204.07 MD-Top Nechelik-7"x 8-3/4" 13,254.07 83.00 170.00 6,953.19 6,904.09 -3,366.80 -8,905.92 6,000,520.34 378,882.80 0.00 -712.45 Start DLS 4.04 TFO-40.78 13,300.00 84.41 168.78 6,958.23 6,909.13 -3,411.67 -8,897.52 6,000,475.35 378,890.53 4.04 -668.23 13,400.00 87.48 166.15 6,965.30 6,916.20 -3,509.02 -8,875.86 6,000,377.69 378,910.71 4.04 -570.85 13,481.80 90.00 164.00 6,967.10 6,918.00 -3,588.03 -8,854.80 6,000,298.38 378,930.58 4.04 -490.34 Start DLS 4.00 TFO-92.75 13,500.00 89.97 163.27 6,967.11 6,918.01 -3,605.49 -8,849.67 6,000,280.85 378,935.45 4.00 -472.35 13,600.00 89.77 159.28 6,967.33 6,918.23 -3,700.18 -8,817.58 6,000,185.70 378,966.11 4.00 -372.97 13,700.00 89.58 155.28 6,967.90 6,918.80 -3,792.40 -8,778.96 6,000,092.92 379,003.34 4.00 -273.07 13,800.00 89.39 151.29 6,968.79 6,919.69 -3,881.70 -8,734.02 6,000,002.95 379,046.93 4.00 -173.14 13,900.00 89.21 147.29 6,970.01 6,920.91 -3,967.65 -8,682.96 5,999,916.25 379,096.69 4.00 -73.66 13,980.29 89.06 144.08 6,971.23 6,922.13 -4,033.95 -8,637.71 5,999,849.29 379,140.93 4.00 5.55 13,980.36 89.06 144.08 6,971.23 6,922.13 -4,034.01 -8,637.67 5,999,849.23 379,140.97 0.00 5.62 Start 6459.06 hold at 13980.36 MD 14,000.00 89.06 144.08 6,971.55 6,922.45 -4,049.91 -8,626.15 5,999,833.16 379,152.25 0.00 24.90 14,100.00 89.06 144.08 6,973.19 6,924.09 -4,130.89 -8,567.49 5,999,751.32 379,209.68 0.00 123.08 14,200.00 89.06 144.08 6,974.83 6,925.73 -4,211.86 -8,508.84 5,999,669.48 379,267.11 0.00 221.25 14,300.00 89.06 144.08 6,976.47 6,927.37 -4,292.84 -8,450.18 5,999,587.64 379,324.53 0.00 319.43 14,400.00 89.06 144.08 6,978.11 6,929.01 -4,373.81 -8,391.53 5,999,505.80 379,381.96 0.00 417.61 14,500.00 89.06 144.08 6,979.75 6,930.65 -4,454.78 -8,332.87 5,999,423.96 379,439.39 0.00 515.78 14,600.00 89.06 144.08 6,981.39 6,932.29 -4,535.76 -8,274.22 5,999,342.12 379,496.81 0.00 613.96 14,700.00 89.06 144.08 6,983.03 6,933.93 -4,616.73 -8,215.56 5,999,260.28 379,554.24 0.00 712.14 14,800.00 89.06 144.08 6,984.67 6,935.57 -4,697.71 -8,156.91 5,999,178.44 379,611.67 0.00 810.31 14,900.00 89.06 144.08 6,986.30 6,937.20 -4,778.68 -8,098.25 5,999,096.60 379,669.09 0.00 908.49 15,000.00 89.06 144.08 6,987.94 6,938.84 -4,859.66 -8,039.60 5,999,014.76 379,726.52 0.00 1,006.67 15,100.00 89.06 144.08 6,989.58 6,940.48 -4,940.63 -7,980.94 5,998,932.92 379,783.95 0.00 1,104.84 15,200.00 89.06 144.08 6,991.22 6,942.12 -5,021.61 -7,922.29 5,998,851.08 379,841.38 0.00 1,203.02 15,300.00 89.06 144.08 6,992.86 6,943.76 -5,102.58 -7,863.63 5,998,769.24 379,898.80 0.00 1,301.20 15,400.00 89.06 144.08 6,994.50 6,945.40 -5,183.56 -7,804.98 5,998,687.40 379,956.23 0.00 1,399.37 15,500.00 89.06 144.08 6,996.14 6,947.04 -5,264.53 -7,746.32 5,998,605.56 380,013.66 0.00 1,497.55 15,600.00 89.06 144.08 6,997.78 6,948.68 -5,345.51 -7,687.67 5,998,523.72 380,071.08 0.00 1,595.73 15,700.00 89.06 144.08 6,999.42 6,950.32 -5,426.48 -7,629.01 5,998,441.88 380,128.51 0.00 1,693.90 15,800.00 89.06 144.08 7,001.06 6,951.96 -5,507.45 -7,570.35 5,998,360.04 380,185.94 0.00 1,792.08 15,900.00 89.06 144.08 7,002.70 6,953.60 -5,588.43 -7,511.70 5,998,278.20 380,243.36 0.00 1,890.26 16,000.00 89.06 144.08 7,004.34 6,955.24 -5,669.40 -7,453.04 5,998,196.36 380,300.79 0.00 1,988.43 16,100.00 89.06 144.08 7,005.98 6,956.88 -5,750.38 -7,394.39 5,998,114.52 380,358.22 0.00 2,086.61 2/25/2011 5:27:36PM Page 7 COMPASS 2003.16 Build 69 ORIGINAL • ConocoPhillips HALLIBURTONJ Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-128 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-128 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-128 Design: CD3-128wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EJ-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,958.52 16,200.00 89.06 144.08 7,007.62 6,958.52 -5,831.35 -7,335.73 5,998,032.68 380,415.65 0.00 2,184.79 16,300.00 89.06 144.08 7,009.25 6,960.15 -5,912.33 -7,277.08 5,997,950.84 380,473.07 0.00 2,282.96 16,400.00 89.06 144.08 7,010.89 6,961.79 -5,993.30 -7,218.42 5,997,869.00 380,530.50 0.00 2,381.14 16,500.00 89.06 144.08 7,012.53 6,963.43 -6,074.28 -7,159.77 5,997,787.16 380,587.93 0.00 2,479.31 16,600.00 89.06 144.08 7,014.17 6,965.07 -6,155.25 -7,101.11 5,997,705.32 380,645.35 0.00 2,577.49 16,700.00 89.06 144.08 7,015.81 6,966.71 -6,236.23 -7,042.46 5,997,623.48 380,702.78 0.00 2,675.67 16,800.00 89.06 144.08 7,017.45 6,968.35 -6,317.20 -6,983.80 5,997,541.64 380,760.21 0.00 2,773.84 16,900.00 89.06 144.08 7,019.09 6,969.99 -6,398.17 -6,925.15 5,997,459.80 380,817.63 0.00 2,872.02 17,000.00 89.06 144.08 7,020.73 6,971.63 -6,479.15 -6,866.49 5,997,377.96 380,875.06 0.00 2,970.20 17,100.00 89.06 144.08 7,022.37 6,973.27 -6,560.12 -6,807.84 5,997,296.13 380,932.49 0.00 3,068.37 17,200.00 89.06 144.08 7,024.01 6,974.91 -6,641.10 -6,749.18 5,997,214.29 380,989.92 0.00 3,166.55 17,300.00 89.06 144.08 7,025.65 6,976.55 -6,722.07 -6,690.53 5,997,132.45 381,047.34 0.00 3,264.73 17,400.00 89.06 144.08 7,027.29 6,978.19 -6,803.05 -6,631.87 5,997,050.61 381,104.77 0.00 3,362.90 17,500.00 89.06 144.08 7,028.93 6,979.83 -6,884.02 -6,573.22 5,996,968.77 381,162.20 0.00 3,461.08 ' 17,600.00 89.06 144.08 7,030.57 6,981.47 -6,965.00 -6,514.56 5,996,886.93 381,219.62 0.00 3,559.26 17,700.00 89.06 144.08 7,032.20 6,983.10 -7,045.97 -6,455.91 5,996,805.09 381,277.05 0.00 3,657.43 17,800.00 89.06 144.08 7,033.84 6,984.74 -7,126.95 -6,397.25 5,996,723.25 381,334.48 0.00 3,755.61 17,900.00 89.06 144.08 7,035.48 6,986.38 -7,207.92 -6,338.60 5,996,641.41 381,391.90 0.00 3,853.79 18,000.00 89.06 144.08 7,037.12 6,988.02 -7,288.89 -6,279.94 5,996,559.57 381,449.33 0.00 3,951.96 18,100.00 89.06 144.08 7,038.76 6,989.66 -7,369.87 -6,221.29 5,996,477.73 381,506.76 0.00 4,050.14 18,200.00 89.06 144.08 7,040.40 6,991.30 -7,450.84 -6,162.63 5,996,395.89 381,564.19 0.00 4,148.32 18,300.00 89.06 144.08 7,042.04 6,992.94 -7,531.82 -6,103.98 5,996,314.05 381,621.61 0.00 4,246.49 18,400.00 89.06 144.08 7,043.68 6,994.58 -7,612.79 -6,045.32 5,996,232.21 381,679.04 0.00 4,344.67 18,500.00 89.06 144.08 7,045.32 6,996.22 -7,693.77 -5,986.66 5,996,150.37 381,736.47 0.00 4,442.85 18,600.00 89.06 144.08 7,046.96 6,997.86 -7,774.74 -5,928.01 5,996,068.53 381,793.89 0.00 4,541.02 18,700.00 89.06 144.08 7,048.60 6,999.50 -7,855.72 -5,869.35 5,995,986.69 381,851.32 0.00 4,639.20 18,800.00 89.06 144.08 7,050.24 7,001.14 -7,936.69 -5,810.70 5,995,904.85 381,908.75 0.00 4,737.38 18,900.00 89.06 144.08 7,051.88 7,002.78 -8,017.67 -5,752.04 5,995,823.01 381,966.17 0.00 4,835.55 19,000.00 89.06 144.08 7,053.52 7,004.42 -8,098.64 -5,693.39 5,995,741.17 382,023.60 0.00 4,933.73 19,100.00 89.06 144.08 7,055.16 7,006.06 -8,179.62 -5,634.73 5,995,659.33 382,081.03 0.00 5,031.91 19,200.00 89.06 144.08 7,056.79 7,007.69 -8,260.59 -5,576.08 5,995,577.49 382,138.46 0.00 5,130.08 19,300.00 89.06 144.08 7,058.43 7,009.33 -8,341.56 -5,517.42 5,995,495.65 382,195.88 0.00 5,228.26 19,400.00 89.06 144.08 7,060.07 7,010.97 -8,422.54 -5,458.77 5,995,413.81 382,253.31 0.00 5,326.44 19,500.00 89.06 144.08 7,061.71 7,012.61 -8,503.51 -5,400.11 5,995,331.97 382,310.74 0.00 5,424.61 19,600.00 89.06 144.08 7,063.35 7,014.25 -8,584.49 -5,341.46 5,995,250.13 382,368.16 0.00 5,522.79 19,700.00 89.06 144.08 7,064.99 7,015.89 -8,665.46 -5,282.80 5,995,168.29 382,425.59 0.00 5,620.97 19,800.00 89.06 144.08 7,066.63 7,017.53 -8,746.44 -5,224.15 5,995,086.45 382,483.02 0.00 5,719.14 19,900.00 89.06 144.08 7,068.27 7,019.17 -8,827.41 -5,165.49 5,995,004.61 382,540.44 0.00 5,817.32 20,000.00 89.06 144.08 7,069.91 7,020.81 -8,908.39 -5,106.84 5,994,922.77 382,597.87 0.00 5,915.50 20,100.00 89.06 144.08 7,071.55 7,022.45 -8,989.36 -5,048.18 5,994,840.93 382,655.30 0.00 6,013.67 20,200.00 89.06 144.08 7,073.19 7,024.09 -9,070.34 -4,989.53 5,994,759.09 382,712.73 0.00 6,111.85 20,300.00 89.06 144.08 7,074.83 7,025.73 -9,151.31 -4,930.87 5,994,677.25 382,770.15 0.00 6,210.03 20,400.00 89.06 144.08 7,076.47 7,027.37 -9,232.28 -4,872.22 5,994,595.41 382,827.58 0.00 6,308.20 20,438.67 89.06 144.08 7,077.10 . 7,028.00 -9,263.60 -4,849.53 5,994,563.76 382,849.79 0.00 6,346.17 CD3-J 25May10 Toe 2/25/2011 5:27:36PM Page 8 COMPASS 2003.16 Build 69 f 'r I U H 6 Ai"� L, ConocoPhillips H A LLI B LI RTO N Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-128 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-128 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-128 Design: CD3-128wp03 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (0) (0) (ft) (ft) (ft) (ft) (ft) CD3-J 25May10 Toe 0.00 0.00 7,077.10 -9,263.60 -4,849.53 5,994,563.76 382,849.79 -plan hits target center -Circle(radius 100.00) CD3-J 25May10 Heel 0.00 0.00 6,947.10 -3,565.68 -8,950.70 6,000,322.16 378,835.04 -plan misses target center by 88.68ft at 13435.07ft MD(6966.51 TVD,-3542.98 N,-8867.20 E) -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") C') 2,971.87 2,450.00 9-5/8"x 12-1/4" 9-5/8 12-1/4 13,204.07 6,947.10 7"x 8-3/4" 7 8-3/4 20,439.42 7,077.11 3-1/2"x 6-1/8" 3-1/2 6-1/8 ------- ---- Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (0) (0) 12,587.12 6,817.10 Top Kuparuk C 12,323.57 6,731.10 K-1 3,882.35 2,859.10 C-20 10,517.42 5,846.10 Albian 96 2,670.93 2,311.10 C-40 0.00 12,439.97 6,771.10 Top Kuparuk D 6,421.75 4,000.10 K-3 Basal 9,481.94 5,375.10 Albian 97 12,675.39 6,842.10 Top Nuiqsut 6,092.37 3,852.10 K-3 1,232.95 1,221.10 Base Permafrost 0.00 12,173.30 6,675.10 Base HRZ 13,204.07 6,947.10 Top Nechelik 11,862.31 6,539.10 Top HRZ 6,472.94 4,023.10 K-2 6,699.95 4,125.10 K-2 Basal 12,607.68 6,823.10 LCU 12,830.67 6,881.10 Base Nuiqsut 3,038.86 2,480.10 C-30 2/25/2011 5:27:36PM Page 9 COMPASS 2003.16 Build 69 OR ( GtNAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD3-128 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+12.8 @ 49.10ft(Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: Plan:CD3-128 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD3-128 Design: CD3-128wp03 ' Plan Annotations I Measured Vertical Local Coordinates Depth Depth +N/-S +EJ-W (ft) (ft) (ft) (ft) Comment 400.00 400.00 0.00 0.00 Start Build 1.50 TFO 295 600.09 600.00 2.21 -4.75 Start Build 2.00 901.89 900.00 15.58 -33.42 Start DLS 3.20 TFO-30.00 1,101.89 1,095.59 27.81 -72.84 Start DLS 3.20 TFO-35.00 1,600.94 1,557.00 28.42 -258.67 Start DLS 2.83 TFO-6.04 2,800.94 2,373.20 -100.45 -1,104.57 Start 7426.35 hold at 2800.94 MD 10,227.29 5,710.00 -1,252.52 -7,638.26 Start DLS 3.10 TFO-108.00 11,803.48 6,510.00 -2,045.45 -8,672.02 Start DLS 2.00 TFO 0.00 12,173.30 6,675.10 -2,347.51 -8,806.51 Start DLS 3.52 TFO-69.55 13,204.07 6,947.10 -3,317.93 -8,914.54 Start 50.00 hold at 13204.07 MD 13,254.07 6,953.19 -3,366.80 -8,905.92 Start DLS 4.04 TFO-40.78 13,481.80 6,967.10 -3,588.03 -8,854.80 Start DLS 4.00 TFO-92.75 13,980.36 6,971.23 -4,034.01 -8,637.67 Start 6459.06 hold at 13980.36 MD 20,439.42 TD at 20439.42 2/25/2011 5:27:36PM 1age T L COMPASS 2003.16 Build 69 ZN m a ° C. 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ILL- PI i aa o M M i/Cg '��A F a >.si dill �6,ti i oO 0 04 1 F Iiiio 8vo 0 n O 3 ' N QC °8VOO 4118 I 0 N I- fg; sgee rIA/ OR1 M i �R� HALLIBURTON Conoco`Phillips CD3-128wp03 __- Alaska Sperry Drilling ANTI-COLLISION SETTINGS 11:14,February 25 2011 Interpolation Method: MD, interval: 25.00 Depth Range From: 36.30 To 20439.42 Results Limited By: Centre Distance: 2240.31 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1250.00 CD3-128wp03(Plan: CD3-128) CB-GYRO-SS 1250.00 2971.87 CD3-128wp03(Plan: CD3-128) MWD+IFR-AK-CAZ-SC 2971.87 13204.07 CD3-128wp03(Plan: CD3-128) MWD+IFR-AK-CAZ-SC 13204.07 20439.42 CD3-128wp03(Plan: CD3-128) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2450.00 2971.87 9-5/8"x 12-1/4" 9-5/8 6947.10 13204.07 7"x 8-3/4" 7 7077.10 20439.42 3-1/2"x 6-1/8" 3-1/2 az;�N .£2 nr, 00 V pi I 060 • i 0 eL - • �IIII ami -II iI , j' l:.l1l 11' 1 030 22 1 1111F 11111 E. 1111, CD pI, 1- jll 0 : 1 I I I 1 I I I I l 1 I 1 I 1 I 1 I I I I 1 1 1 1 1 1 1 l 0 3000 6000 9000 12000 15000 18000 21000 Measured Depth LEGEND CD3-124,CO3-124,CD3-124 VO -e- CD3-316,CD3-316A,CD3-316A VO -0- CD3-117,CO3-117,CD3-117 VO Plan:CD3-126,Plan:CD3-126,CD3-126wp04 VO -1- Plan:CD3-129,Ran:CD3-129,CD3-129wp01 VO -- Rig:CO3.127,Rig:CD3-127,Rig CD3-127 VO - Plan:CD3-119,Plan:CD3-119,CD3-119wp07 VO -A- Plan:CD3-120,Ran:CD3-120,CD3-120wp06 VO -X- CD3-118,CO3-118,CD3-118 VO $- CD3-121,CD3-121,CD3-121 VO -48o- Rig:CD3-125,Rig:CD3-125,Rig CD3-125 VO -A- CD3-123,CO3-123,CD3-123 VO CD3-115,CO3-115,CD3-115 VO -X- Rig:CD3-125,Rig:CD3-125,CO3-125wp06 VO -X- Rig:CD3-127,Rig:CD3-127,CD3-127wp04 VO - -- CD3-316,CD3-316,CD3-316 VO -e- CD3-122,CD3-122,CD3-122 VO -0- CD3-128wp03 -9- CD3-316,CD3-316APB1,CD3-316APB1 VO -s-- CD3-114,CD3-114,CD3-114 V14 ORIGINAL • HALLIBURTON . ConocoPhilluaps CD3-128wp03 ska Sperry Drilling ANTI-COLLISION SETTINGS 11:14,February 25 2011 Interpolation Method: MD, interval: 25.00 Depth Range From: 36.30 To 20439.42 Results Limited By: Centre Distance: 2240.31 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1250.00 CD3-128wp03(Plan: CD3-128) CB-GYRO-SS 1250.00 2971.87 CD3-128wp03(Plan: CD3-128) MWD+IFR-AK-CAZ-SC 2971.87 13204.07 CD3-128wp03(Plan: CD3-128) MWD+IFR-AK-CAZ-SC 13204.07 20439.42 CD3-128wp03(Plan: CD3-128) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2450.00 2971.87 9-5/8"x 12-1/4" 9-5/8 6947.10 13204.07 7"x 8-3/4" 7 7077.10 20439.42 3-1/2"x 6-1/8" 3-1/2 1O e r ;4 N i 74 2' � N !%, V m V 0 C 0 U III 1 1 I A r � 7 1 1� OJI � Liallinli i� .60 - 11aml1lIIIIIII1R I II IHu u , r I i .1 iI•■v111Hh11IIlI 10° iI30 .- Iii' m Ili. , a • tillillilll'V11111111VII � ' CD3 127wp04 . I li1i1 .. o j1111 ....Si 0 500 1000 1500 2000 2500 3000 3500 Measured Depth CD3-127 LEGEND -A- CO3-124,CD3-124,CD3-124 VO -e- CD3-316,CD3-316A,CD3-316A VO -0- CD3-117,CD3-117,CD3-117 VO Plan,CD3-126,Plan:CD3-126,CD3-126wp04 VO --X-- Plan:CD3-129,Plan:CD3-129,CD3-129wp01 VO -e- Rig:CD3-127,Rig:CD3-127,Rig CD3-127 VO -e- Plan:CD3-119,Plan:CD3-119,CD3-119wp07 VO Plan:CD3-120,Plan:CD3-120,CD3-120wp06 VO -X- CD3-118,CD3-118,CD3-118 VO -40- CD3-121,CD3-121,CD3-121 VO -480- Rig:CD3-125,Rig:CD3-125,Rig CD3-125 VO -A- CD3-123,CD3-123,CD3-123 VO -g- CD3-115,CD3-115,CD3-115 VO -X- Rig:CD3-125,Rig:CD3-125,CD3-125wp06 VO -X- Rig:CD3-127,Rig:CD3-127,CD3-127wp04 VO CD3-316,CD3-316,CD3-316 VO $ CD3-122,CD3-122,CD3-122 VO -4- CD3-128wp03 -8- CD3-316,CD3-316APB1,CD3-316APB1 VO -- CD3-114,CD3-114,CD3-114 V14 ORIGINAL HALLIBURTON ConocoPhillips CD3-128wp03 Alaska Sperry Drilling ANTI-COLLISION SETTINGS 11:16,February 25 2011 Interpolation Method: MD, interval: 25.00 Depth Range From: 36.30 To 20439.42 CD3-127wp04 IS Results Limited By: Centre Distance: 2240.31 p > Using user defined selection&filtering criteria hidden. SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1250.00 CD3-128wp03(Plan: CD3-128) CB-GYRO-SS 1250.00 2971.87 CD3-128wp03(Plan: CD3-128) MWD+IFR-AK-CAZ-SC 2971.87 13204.07 CD3-128wp03(Plan: CD3-128) MWD+IFR-AK-CAZ-SC 13204.07 20439.42 CD3-128wp03 (Plan: CD3-128) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2450.00 2971.87 9-5/8" x 12-1/4" 9-5/8 6947.10 13204.07 7"x 8-3/4" 7 7077.10 20439.42 3-1/2"x 6-1/8" 3-1/2 , 3 1 N N CI 7 go c a o . V U K Q 1r k Ej1 C U - . y I / .tel y/ 0 I l i l I l l l I I l I I I - I I I I I I l l 1 l 1 T 1 1 0 500 1000 1500 2000 2500 3000 3500 Measured Depth LEGEND -A- CD3-124,CD3-124,CD3-124 VO -e- CD3-316,CD3-316A,CD3-316A V0 -0- CD3-117,CD3-117,CD3-117 VO Plan:CD3-126,Plan:CD3-126,CD3-126wp04 VO --X- Plan:CD3-129,Plan:CD3-129,CD3-129wp01 VO _e_ Rig:CD3-127,Rig:CD3-127,Rig CD3-127 VO -e- Plan:CD3-119,Plan:CD3-119,CD3-119wp07 VO -A-- Plan:CD3-120,Plan:CD3-120,CD3-120wp06 VO �- CD3-118,CD3-118,CD3-118 VO -0- CD3-121,CD3-121,CD3-121 VO -9- Rig:CD3-125,Rig:CD3-125,Rig CD3-125 VO -A- CD3-123,CD3-123,CD3-123 VO CD3-115,CD3-115,CD3-115 VO --X(- Rig:CD3-125,Rig:CD3-125,CD3-125wp06 VO -0-- CD3-128wp03 CD3-316,CD3-316,CD3-316 VO -s-- CD3-122,CD3-122,CD3-122 VO CD3-316,CD3-316APB1,CO3-316APB1 VO -e- CD3-114,CD3-114,CD3-114 V14 ORIGINAL Northing (4000 ft/in) ' I I I I I I I I I I i i i i 1 i 1 1 i 1 I l l 1 1 1 1 1 1 1 1 1 I I I l l I Him 1 1 1 1 1 1 1 1 1 1 1 1 1 1 , I I 1 1 1 I IIIII - o - N - - N — N R -1 d {L — Q - 3 m CO - 1.6 d M - co¢ A M U - m M o ❑ n. 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TRANSMITTAL LETTER CHECKLIST WELL NAME 602u 6,D 3- /zg PTD# 2/1 a3 7 Development Service Exploratory Strati ra hic Test Non-ConventionaltiWell FIELD: &:)/1/7(14 iet)er POOL: ,4 / / e)/ Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to 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 ( 3Cn D 0 0 . 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No special effort has been made to chronologically organize this category of information. 2tl-oI 111 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ ®��`V,� Mon Mar 19 14:33:44 2012 RECEIVED Reel Header MAR 2 9 2012 Service name LISTPE ^�� Date 12/03/19 AOGCC STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 12/03/19 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF <E stow Comment Record TAPE HEADER Alpine MWD/MAD LOGS WELL NAME: CD3-128 API NUMBER: 501032063800 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 19-MAR-12 JOB DATA MWD RUN 1 MWD RUN 3 MWD RUN 4 JOB NUMBER: -XX-0009113884 -XX-0009113884 -XX-0009113884 LOGGING ENGINEER: TYLER RITCHE TYLER RITCHE TYLER RITCHE OPERATOR WITNESS: DAVE BURLEY DAVE BURLEY DAVE BURLEY MAD RUN 4 MWD RUN 7 JOB NUMBER: -XX-0009113884 -XX-0009113884 LOGGING ENGINEER: TYLER RITCHE TYLER RITCHE OPERATOR WITNESS: DAVE BURLEY DAVE BURLEY SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: 4027 FSL: FEL: 1205 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 48.40 GROUND LEVEL: 12.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS • BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 16.000 114 .0 2ND STRING 8.750 9. 625 2989.0 3RD STRING 6.125 7.000 12992.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) , UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUNS 1-4 WERE DRILLED IN APRIL 2011. THE WELL WAS SUSPENDED DUE TO TIME CONSTRAINTS FOR THE ICE ROAD. THE EXISTING WELLBORE WAS RE-ENTERED AND THE DRILLING COMPLETED IN FEBRUARY 2012. 4 . MWD RUNS 1,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZ- ING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESIS- TIVITY PHASE-4 (EWR-P4) , DRILL STRING DYNAMICS SENSOR (DDSr) , AND AT-BIT-INCLINATION (ABI) . MWD RUN 2 WAS A GYRO RUN - NO FOOTAGE WAS DRILLED. 5. MWD RUN 4 COMPRISED DIRECTIONAL, DGR, EWR-P4, DDSr, COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AZIMUTHAL LITHO-DENSITY (ALD) , PRESSURE WHILE DRILLING (PWD) , AND ACOUSTIC CALIPER (ACAL) . MAD PASS DATA WERE ACQUIRED OVER THE INTERVAL 12, 610,MD/6883'TVD - 11, 980'MD/6583'TVD WHILE POOH AFTER COMPLETING MWD RUN 4. THESE DATA ARE PRESENTED. 6. NO PROGRESS WAS MADE ON MWD RUNS 5 & 6. 7. MWD RUN 7 COMPRISED DIRECTIONAL,GAMMA MODULE (GM) , AZIMUTHAL DEEP RESISTIVITY (ADR) , DDSr, PWD, AND GEO-PILOT ROTARY STEERABLE BHA (GP) . 8. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SD) ON 27 APRIL 2005. THE MAD DATA FROM RUN 4 WERE CORRECTED (SHIFTED) TO THE MWD DATA. 9. THERE WAS A DEPTH DISCREPANCY RE: THE DEPTH OF THE 7" CASING SHOE BETWEEN THE 2011 (13, 009'MD/6980'TVD) AND 2012 (12, 992'MD/6978'TVD) DRILLING/MWD DATA. AFTER DISCUSSIONS WITH CPAI, IT 410 WAS AGREED TO USE THE 2012 DEPTH. IT ALSO APPEARED (FROM BOTH DRILLING AND MWD DATA) THAT DRILLING OUT OF THE 7" SHOE NEW FORMATION WAS ENCOUNTERED AT ABOUT 13, 011'MD, SO THIS DEPTH WAS USED FOR THE START OF MWD RUN 7. 10. MWD RUNS 1-7 REPRESENT WELL CD3-128 WITH API #50-103-20638-00. THIS WELL REACHED A TOTAL DEPTH OF 20, 387'MD/7082'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION RSPD TOOL RUNNING SPEED WHEN RIH OR POOH DGRC DGR OR GM COMBINED GAMMA RAY R09P 9 INCH PHASE RESISTIVITY R15P 15 INCH PHASE RESISTIVITY R27P 27 INCH PHASE RESISTIVITY R39P 39 INCH PHASE RESISTIVITY EWXT EWR FORMATION EXPOSURE TIME AH1P/ARH16P AVG 16 INCH 2M PHASE RESISTIVITY AH2P/ARH32P AVG 32 INCH 2M PHASE RESISTIVITY AM3P/ARM48P AVG 48 INCH 500K PHASE RESISTIVITY ADXT ADR FORMATION EXPOSURE TIME TNPS CTN POROSITY - SANDSTONE TNFA CTN FAR AVERAGE COUNT RATE TNNA CTN NEAR AVERAGE COUNT RATE ACDL/ALCDLC ALD LCRB COMPENSATED DENSITY ADCL/ALDCLC ALD LCRB DENSITY CORRECTION APEL/ALPELC ALD LCRB Pe FACTOR ALRP/ALRPM ALD RPM (NON-SLIDE INDICATOR) AHSI/ALHSI ALD HOLE SIZE INDICATOR ACHD ACOUSTIC CALIPER AN 'M' SUFFIX ON MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: FIXED - 8.75" BIT MUD WEIGHT: 9.45-11.5 PPG WHOLE MUD CHLORIDES: 650-1200 PPM FORMATION WATER SALINITY: 14,545 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2. 65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER • • FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 43.0 20310.5 RPX 110.0 12967.5 RPS 110.0 12967.5 RPM 110.0 12967.5 FET 110.0 20333.0 RPD 110.0 12967.5 ROP 120.0 20387.0 PEF 2979.0 12934 .5 DRHO 2979.0 12934.5 FCNT 2979.0 12920.5 RHOB 2979.0 12934 .5 CALN 2979.0 12934 .5 NCNT 2979.0 12920.5 NPHI 2979.0 12920.5 CALA 10624.5 12924 .0 AH1P 12980.0 20333.0 AH2P 12980.0 20333.0 AM3P 12980.0 20333.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 43.0 588.0 MWD 3 588.0 2999.0 MWD 4 2999.0 13011.0 MWD 7 13011.0 20387.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD IN 4 1 68 4 2 RHOB MWD G/CC 4 1 68 8 3 DRHO MWD G/CC 4 1 68 12 4 CALN MWD IN 4 1 68 16 5 PEF MWD B/E 4 1 68 20 6 AH1P MWD OHMM 4 1 68 24 7 AH2P MWD OHMM 4 1 68 28 8 AM3P MWD OHMM 4 1 68 32 9 GR MWD API 4 1 68 36 10 FET MWD HR 4 1 68 40 11 • • RPX MWD OHMM 4 1 68 44 12 RPS MWD OHMM 4 1 68 48 13 RPM MWD OHMM 4 1 68 52 14 RPD MWD OHMM 4 1 68 56 15 ROP MWD FPH 4 1 68 60 16 FONT MWD CP30 4 1 68 64 17 NCNT MWD CP30 4 1 68 68 18 NPHI MWD PU 4 1 68 72 19 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 43 20387 10215 40689 43 20387 CALA MWD IN 8. 6134 11.7484 9.34435 4507 10624 .5 12924 RHOB MWD G/CC 0.187 3.101 2.39396 19912 2979 12934.5 DRHO MWD G/CC -3.549 0.366 0.0626211 19912 2979 12934.5 CALN MWD IN 8.25 12.7 8.87109 14805 2979 12934.5 PEF MWD B/E -5.03 44.29 3.31136 19912 2979 12934 .5 AH1P MWD OHMM 0.1 57.07 11.5568 14707 12980 20333 AH2P MWD OHMM 0.04 301.73 12.1573 14707 12980 20333 AM3P MWD OHMM 0.02 1466.24 12.7577 14707 12980 20333 GR MWD API 10.22 449.11 87.7562 40536 43 20310.5 FET MWD HR 0.2 7004 .41 15.2318 40352 110 20333 RPX MWD OHMM 0.89 1757.26 6. 61339 25645 110 12967.5 RPS MWD OHMM 0.53 1759.43 8.43833 25645 110 12967.5 RPM MWD OHMM 0.13 1831.72 11.1923 25645 110 12967.5 RPD MWD OHMM 0.14 2000 15.1765 25645 110 12967.5 ROP MWD FPH 0.25 5302.56 132.612 40535 120 20387 FONT MWD CP30 425. 62 1801.81 751.543 19884 2979 12920.5 NCNT MWD CP30 90122.6 156733 113621 19884 2979 12920.5 NPHI MWD PU 16.35 65. 98 34.7799 19884 2979 12920.5 First Reading For Entire File 43 Last Reading For Entire File 20387 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 I EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY III • PBU TOOL CODE START DEPTH STOP DEPTH RAT 11851.0 12610.0 NPHI 11878.0 12542.5 NCNT 11878.0 12542.5 FCNT 11878.0 12542.5 CALA 11880.5 12544.5 CALN 11891.0 12556.0 PEF 11891.0 12557.0 DRHO 11891.0 12557.0 RHOB 11891.0 12557.0 GR 11914.0 12579.0 RPM 11922.5 12588.5 FET 11922.5 12588.5 RPX 11922.5 12588.5 RPS 11922.5 12588.5 RPD 11922.5 12588.5 $ MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 4 1 11980.0 12610.0 $ REMARKS: MERGED MAD PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MAD IN 4 1 68 4 2 RHOB MAD G/CC 4 1 68 8 3 DRHO MAD G/CC 4 1 68 12 4 CALN MAD IN 4 1 68 16 5 PEF MAD B/E 4 1 68 20 6 GR MAD API 4 1 68 24 7 FET MAD HR 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 RPS MAD OHMM 4 1 68 36 10 RPM MAD OHMM 4 1 68 40 11 RPD MAD OHMM 4 1 68 44 12 RAT MAD FPH 4 1 68 48 13 FCNT MAD CP30 4 1 68 52 14 NCNT MAD CP30 4 1 68 56 15 NPHI MAD PU 4 1 68 60 16 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11851 12610 12230.5 1519 11851 12610 CALA MAD IN 8. 6216 9. 9411 9.21679 1131 11880.5 12544.5 RHOB MAD G/CC 2.234 3.27 2.45465 1333 11891 12557 DRHO MAD G/CC -0.035 0.265 0.038898 1333 11891 12557 CALN MAD IN 8.62 11.05 9.23479 1331 11891 12556 PEF MAD B/E 2.33 10.05 3.55483 1333 11891 12557 GR MAD API 54.69 458.78 191.037 1331 11914 12579 FET MAD HR 17. 62 34.88 26.3965 1333 11922.5 12588.5 • • RPX MAD OHMM 2.09 26. 69 4.15125 1333 11922.5 12588.5 RPS MAD OHMM 2.35 24.6 4.462 1333 11922.5 12588.5 RPM MAD OHMM 2.71 21.73 5.02476 1333 11922.5 12588.5 RPD MAD OHMM 2.61 23.25 5.15853 1333 11922.5 12588.5 RAT MAD FPH 12.35 269. 99 109.093 1519 11851 12610 FONT MAD CP30 564. 688 1593.49 733.497 1330 11878 12542.5 NCNT MAD CP30 104374 152162 112343 1330 11878 12542.5 NPHI MAD PU 18.51 48.41 37.1579 1330 11878 12542.5 First Reading For Entire File 11851 Last Reading For Entire File 12610 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 43.0 522.0 R15P 110.0 532.0 R27P 110.0 532.0 EWXT 110.0 532.0 R09P 110.0 532.0 R39P 110.0 532.0 ROPA 120.0 588.0 LOG HEADER DATA DATE LOGGED: 11-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 588.0 TOP LOG INTERVAL (FT) : 42.0 BOTTOM LOG INTERVAL (FT) : 588.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 1. 6 • • 1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718512 EWR4 ELECTROMAG. RESIS. 4 113423 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLER'S CASING DEPTH (FT) : 114 .0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 8. 90 MUD VISCOSITY (S) : 300.0 MUD PH: 8.8 MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3) : 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.800 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 3. 680 53.2 MUD FILTRATE AT MT: 2.620 72.0 MUD CAKE AT MT: 3.500 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 FET MWD010 HR 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 43 588 315.5 1091 43 588 GR MWD010 API 10.22 99.08 48.7228 959 43 522 FET MWD010 HR 0.26 1.72 0.856379 845 110 532 RPX MWD010 OHMM 1.27 1757.26 29.8094 845 110 532 RPS MWD010 OHMM 1.29 1759.43 48.4696 845 110 532 RPM MWD010 OHMM 1.27 1819.19 72.7461 845 110 532 RPD MWD010 OHMM 1.23 2000 105.68 845 110 532 • ROP MWD010 FPH 20.08 358.56 161.395 937 120 588 First Reading For Entire File 43 Last Reading For Entire File 588 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 522.5 2933.5 EWXT 532.5 2943.0 R15P 532.5 2943.0 R27P 532.5 2943.0 RO9P 532.5 2943.0 R39P 532.5 2943.0 ROPA 588.5 2999.0 LOG HEADER DATA DATE LOGGED: 13-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 2999.0 TOP LOG INTERVAL (FT) : 588.0 BOTTOM LOG INTERVAL (FT) : 2999.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 4 .8 MAXIMUM ANGLE: 63.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718512 EWR4 ELECTROMAG. RESIS. 4 113423 • i BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLER'S CASING DEPTH (FT) : 114.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 9.00 MUD VISCOSITY (S) : 200.0 MUD PH: 8.5 MUD CHLORIDES (PPM) : 1350 FLUID LOSS (C3) : 1.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 3.100 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.950 81.4 MUD FILTRATE AT MT: 3.000 75.0 MUD CAKE AT MT: 3.400 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .lIN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 FET MWD030 HR 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 522.5 2999 1760.75 4954 522.5 2999 GR MWD030 API 15.78 199.6 93.782 4823 522.5 2933.5 FET MWD030 HR 0.2 12.31 1.03594 4822 532.5 2943 RPX MWD030 OHMM 1.24 51.3 7. 93033 4822 532.5 2943 RPS MWD030 OHMM 1.2 125.41 13.3889 4822 532.5 2943 RPM MWD030 OHMM 1.16 270. 69 21.7602 4822 532.5 2943 RPD MWD030 OHMM 1.19 1225.23 29.763 4822 532.5 2943 ROP MWD030 FPH 1.91 5302.56 168.244 4822 588.5 2999 First Reading For Entire File 522.5 Last Reading For Entire File 2999 • i i File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 2934.0 12957 .5 ADCL 2979.0 12934.5 R15P 2979.0 12967.5 R09P 2979.0 12967.5 APEL 2979.0 12934 .5 AHSI 2979.0 12934.5 EWXT 2979.0 12967.5 R27P 2979.0 12967.5 ACDL 2979.0 12934.5 TNFA 2979.0 12920.5 TNNA 2979.0 12920.5 TNPS 2979.0 12920.5 R39P 2979.0 12967.5 ROPA 2999.5 13011.0 ACHD 10624.5 12924 .0 LOG HEADER DATA DATE LOGGED: 23-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 13011.0 TOP LOG INTERVAL (FT) : 2999.0 BOTTOM LOG INTERVAL (FT) : 13011.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 56.1 MAXIMUM ANGLE: 81.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 11241795 CTN COMP THERMAL NEUTRON 244601 . • • ALD Azimuthal Litho-Dens 10603721 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2989.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.50 MUD VISCOSITY (S) : 43.0 MUD PH: 9.6 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3) : 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.450 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .760 148.5 MUD FILTRATE AT MT: 2.100 70.0 MUD CAKE AT MT: 1.750 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD040 IN 4 1 68 4 2 RHOB MWD040 G/CC 4 1 68 8 3 DRHO MWD040 G/CC 4 1 68 12 4 CALN MWD040 IN 4 1 68 16 5 PEF MWD040 B/E 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 RPS MWD040 OHMM 4 1 68 36 10 RPM MWD040 OHMM 4 1 68 40 11 RPD MWD040 OHMM 4 1 68 44 12 ROP MWD040 FPH 4 1 68 48 13 FCNT MWD040 CP30 4 1 68 52 14 NCNT MWD040 CP30 4 1 68 56 15 NPHI MWD040 PU 4 1 68 60 16 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2934 13011 7972.5 20155 2934 13011 CALA MWD040 IN 8.6134 11.7484 9.34435 4507 10624 .5 12924 RHOB MWD040 G/CC 0.187 3.101 2.39396 19912 2979 12934.5 III III DRHO MWD040 G/CC -3.549 0.366 0.0626211 19912 2979 12934 .5 CALN MWD040 IN 8.25 12.7 8.87109 14805 2979 12934.5 PEF MWD040 B/E -5.03 44.29 3.31136 19912 2979 12934 .5 GR MWD040 API 32. 63 449.11 119.069 20048 2934 12957.5 FET MWD040 HR 0.22 74 .82 0.957415 19978 2979 12967.5 RPX MWD040 OHMM 0.89 1538.43 5.31442 19978 2979 12967.5 RPS MWD040 OHMM 0.53 1735.44 5.55026 19978 2979 12967.5 RPM MWD040 OHMM 0.13 1831.72 6.03804 19978 2979 12967 .5 RPD MWD040 OHMM 0.14 2000 7.82787 19978 2979 12967.5 ROP MWD040 FPH 0.25 366.36 157.388 20024 2999.5 13011 FCNT MWD040 CP30 425.62 1801.81 751.543 19884 2979 12920.5 NCNT MWD040 CP30 90122.6 156733 113621 19884 2979 12920.5 NPHI MWD040 PU 16.35 65.98 34.7799 19884 2979 12920.5 First Reading For Entire File 2934 Last Reading For Entire File 13011 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 Physical EOF File Header Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GMGR 12958.0 20310.5 AH2P 12980.0 20333.0 ADXT 12980.0 20333.0 AM3P 12980.0 20333.0 AH1P 12980.0 20333.0 ROPA 13011.5 20387.0 $ LOG HEADER DATA DATE LOGGED: 13-FEB-12 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 20387.0 TOP LOG INTERVAL (FT) : 13011.0 BOTTOM LOG INTERVAL (FT) : 20387.0 • . BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 84.1 MAXIMUM ANGLE: 91.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 10450012 ADR Azimuthal Deep Resis BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.125 DRILLER'S CASING DEPTH (FT) : 12992.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9. 60 MUD VISCOSITY (S) : 47.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 68000 FLUID LOSS (C3) : 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .100 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .040 176.0 MUD FILTRATE AT MT: .100 68.0 MUD CAKE AT MT: .110 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FET MWD070 HR 4 1 68 4 2 AH1P MWD070 OHMM 4 1 68 8 3 AH2P MWD070 OHMM 4 1 68 12 4 AM3P MWD070 OHMM 4 1 68 16 5 GR MWD070 API 4 1 68 20 6 ROP MWD070 FPH 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12958 20387 16672.5 14859 12958 20387 FET MWD070 HR 0.49 7004.41 40.1026 14707 12980 20333 AH1P MWD070 OHMM 0. 1 57.07 11.5568 14707 12980 20333 AH2P MWD070 OHMM 0.04 301.73 12.1573 14707 12980 20333 III • AM3P MWD070 OHMM 0.02 1466.24 12.7577 14707 12980 20333 GR MWD070 API 23.87 63.24 45. 6381 14706 12958 20310.5 ROP MWD070 FPH 1.16 129.89 85.5074 14752 13011.5 20387 First Reading For Entire File 12958 Last Reading For Entire File 20387 File Trailer Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Next File Name STSLIB.007 Physical EOF File Header Service name STSLIB.007 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/03/19 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RSPD 11851.0 12610.0 TNFA 11878.0 12542.5 TNNA 11878.0 12542.5 TNPS 11878.0 12542.5 ACHD 11880.5 12544.5 ACDL 11891.0 12557.0 ADCL 11891.0 12557.0 APEL 11891.0 12557.0 AHSI 11891.0 12556.0 DGRC 11914.0 12579.0 R39P 11922.5 12588.5 EWXT 11922.5 12588.5 R09P 11922.5 12588.5 R27P 11922.5 12588.5 R15P 11922.5 12588.5 $ LOG HEADER DATA DATE LOGGED: 23-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 12610.0 TOP LOG INTERVAL (FT) : 11980.0 BOTTOM LOG INTERVAL (FT) : 12610.0 • BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 56.1 MAXIMUM ANGLE: 81. 9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 11241795 CTN COMP THERMAL NEUTRON 244601 ALD Azimuthal Litho-Dens 10603721 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2989.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.50 MUD VISCOSITY (S) : 43.0 MUD PH: 9.6 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3) : 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.450 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .760 148.5 MUD FILTRATE AT MT: 2.100 70.0 MUD CAKE AT MT: 1.750 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MAD041 IN 4 1 68 4 2 RHOB MAD041 G/CC 4 1 68 8 3 DRHO MAD041 G/CC 4 1 68 12 4 CALN MAD041 IN 4 1 68 16 5 PEF MAD041 B/E 4 1 68 20 6 GR MAD041 API 4 1 68 24 7 FET MAD041 HR 4 1 68 28 8 RPX MAD041 OHMM 4 1 68 32 9 RPS MAD041 OHMM 4 1 68 36 10 RPM MAD041 OHMM 4 1 68 40 11 RPD MAD041 OHMM 4 1 68 44 12 RAT MAD041 FPH 4 1 68 48 13 FCNT MAD041 CP30 4 1 68 52 14 III NCNT MAD041 CP30 4 1 68 56 150 16 III NPHI MAD041 PU 4 1 68 First Last NEService Unit Min Max Mean Nsam Reading Reading DEPTT FT 11851 12610 12230.5 1519 11851 12610 CALA MAD041 IN 8. 6216 9.9411 9.21679 1131 11880.5 12544 .5 RHOB MAD041 G/CC 2.234 3.27 2.45465 1333 11891 12557 0.265 0.038898 1333 11891 DRHO MAD041 G/CC -0.035 CALN MAD041 IN 8.62 11.05 9.23479 1331 11891 1255691 12556 PEF MAD041 B/E 2.33 10.05 3.55483 1333 11118891 12579 GR MAD041 API 54. 69 458.78 191.037 1331 FET MAD041 HR 17.62 34 .88 26.3965 1333 11922.5 12588.5 RPX MAD041 OHMM 2.09 26.69 4.15125 1333 11922.5 12588.5 2.35 24. 6 4.462 1333 11922.5 12588.5 RPS MAD041 OHMM 2.71 21.73 5.02476 1333 11922.5 12588.5 RPM MAD041 OHMM 2. 61 23.25 5.15853 1333 11922.5 12588.5 RPD MAD041 OHMM 12610 RAT MAD041 FPH 12.35 269.99 109.093 1519 11851 FONT MAD041 CP30 564 . 688 1593.49 733.497 1330 11878 12542.5 1330 11878 12542.5 NCNT MAD041 CP30 104374 152162 11878 12542.5 NPHI MAD041 PU 18.51 48.41 37.1579 1330 First Reading For Entire File 118511151 Last Reading For Entire File File Trailer STSLIB.007 Service name Service Sub Level Name1 0 0 Version Number 12/03/190 Date of Generation Maximum Physical Record6O535 File Type Next File Name STSLIB.008 Physical EOF Tape Trailer ISTPE Service name LISTPE19 Date 12/03/ STS Origin Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer ISTPE Service name LISTPE19 Date 12/03/ STS Origin Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon May 02 14 :04:32 2011 Reel Header Service name LISTPE Date 11/05/02 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/05/02 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: CD3-128 API NUMBER: 501032063800 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 02-MAY-11 JOB DATA MWD RUN 1 MWD RUN 3 MWD RUN 4 JOB NUMBER: K-MW-000789684 K-MW-000789684 K-MW-000789684 LOGGING ENGINEER: PAUL ORTH PAUL ORTH TYLER RITCHE OPERATOR WITNESS: DAVID BURLEY DAVID BURLEY DON MICKEY MAD RUN 4 JOB NUMBER: K-MW-000789684 LOGGING ENGINEER: TYLER RITCHE OPERATOR WITNESS: DON MICKEY SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: 4027 FSL: FEL: 1205 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 49.40 GROUND LEVEL: 12. 60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 16.000 120.0 2ND STRING 8.750 9. 625 2989.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD) . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUN 100 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , AT-BIT INLINATION (ABI)AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 4 . MWD RUN 200 WAS A GYRO SURVEY RUN WITH NO MWD TOOLS. NO FOOTAGE DRILLED. 5. MWD RUN 300 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , AT-BIT INLINATION (ABI)AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 6. MWD RUN 400 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AZIMUTHAL LITHO-DENSITY (ALD) ) , ACOUSTIC CALIPER (ACAL) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 7. A MAD PASS WAS PERFORMED TO ACQUIRE CALIPER DATA WHILE POOH AT THE END OF MWD RUN 400 FROM 11, 850' MD, 6521' TVD TO 12, 610' MD, 6, 883' TVD (BIT DEPTHS. ) ALL LOGGING DATA AVAILABLE HAS BEEN PRESENTED FOR THIS MAD PASS. 8. CD3-128 WAS SUSPENDED AFTER DRILLING THE INTERMEDIATE SECTION AND I" WILL BE RE-DRILLED AT A LATER DATE. FINAL TRANSMITTALS COMPLIED FOR DISTRIBUTION AS PER AN E-MAIL REQUEST FROM CATHERINE ROSO (CPAI) TO BRYAN BURINDA (SDS) ON 26 APRIL 2011. 9. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 10. MWD RUNS 100 - 400 REPRESENTS WELL CD3-128 WITH API 50-103-20638-00. THIS WELL REACHED A TOTAL DEPTH OF 13, 020' MD, 6, 983' TVD. MNEMONIC CURVE DESCRIPTION RO9P 9in Phase Resistivity R15P 15in Phase Resistivity R27P 27in Phase Resistivity R39P 39in Phase Resistivity EWXT EWR Formation Exp Time ROPA Avg Rate of Penetration DGRC DGR Combined Gamma Ray APEL ALD LCRB Pe Factor ACDL ALD LCRB Comp Density ADCL ALD LCRB Den Correction TNPS CTN Porosity Sandstone TNFA CTN Far Avg Count Rate TNNA CTN Near Avg Count Rate ACHD ACAL Hole Diameter ALRPM ALD RPM PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: 8.75" FIXED. MUD WEIGHT: 9.6 - 10.5 PPG WHOLE MUD CHLORIDES: 650 - 1, 200 PPM CL FORMATION WATER SALINITY: 14, 545 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2. 65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR GAMMA RAY AND ROP. THESE CURVES ARE SMOOTHED WITH A 1. 1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. { DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 43.0 12957.5 RPD 110.0 12967.5 RPS 110.0 12967.5 RPM 110.0 12967.5 RPX 110.0 12967.5 FET 110.0 12967.5 ROP 120.0 13020.0 FCNT 2979.0 12920.5 NCNT 2979.0 12920.5 NPHI 2979.0 12920.5 DRHO 2979.0 12934 .5 CALN 2979.0 12934 .5 RHOB 2979.0 12934 .5 PEF 2979.0 12934 .5 CALA 10624.5 12924 .0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # I MERGED DATA SOURCE i PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 43.0 588.0 MWD 3 522.5 2999.0 MWD 4 2934 .0 13020.0 $ , REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined , Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 j Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD IN 4 1 68 4 2 RHOB MWD G/CC 4 1 68 8 3 DRHO MWD G/CC 4 1 68 12 4 CALN MWD IN 4 1 68 16 5 PEF MWD B/E 4 1 68 20 6 GR MWD API 4 1 68 24 7 FET MWD HR 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 RPS MWD OHMM 4 1 68 36 10 , RPM MWD OHMM 4 1 68 40 11 RPD MWD OHMM 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 FCNT MWD CP30 4 1 68 52 14 NCNT MWD CP30 4 1 68 56 15 NPHI MWD PU 4 1 68 60 16 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 43 13020 6531.5 25955 43 13020 CALA MWD IN 8. 6134 11.7484 9.34435 4507 10624 .5 12924 RHOB MWD G/CC 0. 187 3. 101 2.39396 19912 2979 12934.5 DRHO MWD G/CC -3.549 0.366 0.0626211 19912 2979 12934.5 CALN MWD IN 8.25 12.7 8. 87109 14805 2979 12934.5 PEF MWD B/E -5.03 44 .29 3.31136 19912 2979 12934 .5 GR MWD API 10.22 449. 11 111.736 25830 43 12957.5 FET MWD HR 0.2 74 .82 0. 969567 25645 110 12967.5 RPX MWD OHMM 0.89 1757.26 6. 61339 25645 110 12967.5 RPS MWD OHMM 0.53 1759.43 8.43833 25645 110 12967.5 RPM MWD OHMM 0. 13 1831.72 11. 1923 25645 110 12967.5 RPD MWD OHMM 0.14 2000 15. 1765 25645 110 12967.5 ROP MWD FPH 0.25 5302.56 159.533 25801 120 13020 FCNT MWD CP30 425. 62 1801. 81 751.543 19884 2979 12920.5 NCNT MWD CP30 90122. 6 156733 113621 19884 2979 12920.5 NPHI MWD PU 16.35 65. 98 34 .7799 19884 2979 12920.5 First Reading For Entire File 43 Last Reading For Entire File 13020 File Trailer Service name STSLIB.001 1 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 1 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RAT 11850.0 12610.0 NPHI 11877.0 12542.0 FCNT 11877.0 12542.0 NCNT 11877.0 12542.0 CALA 11879.5 12544 .0 RHOB 11890.0 12555.5 DRHO 11890.0 12555.5 PEF 11890.0 12555.5 CALN 11890.0 12554 .5 GR 11913.0 12579.0 RPX 11922.5 12588.5 RPD 11922.5 12588 .5 RPM 11922.5 12588.5 RPS 11922.5 12588.5 FET 11922.5 12588.5 $ 1 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 4 1 2934 .0 13020.0 REMARKS: MERGED MAD PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . lIN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MAD IN 4 1 68 4 2 RHOB MAD G/CC 4 1 68 8 3 DRHO MAD G/CC 4 1 68 12 4 CALN MAD IN 4 1 68 16 5 PEF MAD B/E 4 1 68 20 6 GR MAD API 4 1 68 24 7 FET MAD HR 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 RPS MAD OHMM 4 1 68 36 10 I RPM MAD OHMM 4 1 68 40 11 RPD MAD OHMM 4 1 68 44 12 RAT MAD FPH 4 1 68 48 13 FCNT MAD CP30 4 1 68 52 14 NCNT MAD CP30 4 1 68 56 15 NPHI MAD PU 4 1 68 60 16 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11850 12610 12230 1521 11850 12610 CALA MAD IN 8. 6216 9. 9411 9.21958 1132 11879.5 12544 RHOB MAD G/CC 2.234 3.27 2.45433 1332 11890 12555.5 DRHO MAD G/CC -0.035 0.265 0.0387252 1332 11890 12555.5 CALN MAD IN 8. 62 11.05 9.23449 1330 11890 12554 .5 PEF MAD B/E 2. 33 10.05 3. 5597 1332 11890 12555.5 GR MAD API 54 . 69 458.78 191. 156 1333 11913 12579 FET MAD HR 17. 62 34 . 88 26.3905 1333 11922.5 12588.5 RPX MAD OHMM 2.09 26. 69 4 . 11335 1333 11922.5 12588.5 RPS MAD OHMM 2.35 24 . 6 4 .42264 1333 11922.5 12588.5 RPM MAD OHMM 2.71 21.73 4 . 98629 1333 11922.5 12588.5 RPD MAD OHMM 2. 61 23.25 5. 12517 1333 11922.5 12588.5 RAT MAD FPH 12. 35 269. 99 109.015 1521 11850 12610 FCNT MAD CP30 564 . 688 1593.49 733.782 1331 11877 12542 NCNT MAD CP30 104374 152162 112354 1331 11877 12542 NPHI MAD PU 18 .51 48. 41 37 . 1234 1331 11877 12542 First Reading For Entire File 11850 Last Reading For Entire File 12610 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 43.0 522.0 R09P 110.0 532.0 R15P 110.0 532.0 R39P 110.0 532.0 EWXT 110.0 532.0 R27P 110.0 532.0 ROPA 120.0 588.0 LOG HEADER DATA DATE LOGGED: 11-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88 .2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 588. 0 TOP LOG INTERVAL (FT) : 120. 0 BOTTOM LOG INTERVAL (FT) : 588 . 0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 1. 6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718512 EWR4 ELECTROMAG. RESTS. 4 113423 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLER'S CASING DEPTH (FT) : 108.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 8. 90 MUD VISCOSITY (S) : 300.0 MUD PH: 8 .8 MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3) : 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.800 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 3. 679 53.2 MUD FILTRATE AT MT: 2. 620 72.0 MUD CAKE AT MT: 3.500 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 FET MWD010 HR 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 43 588 315.5 1091 43 588 GR MWD010 API 10.22 99.08 48.7228 959 43 522 FET MWD010 HR 0.26 12. 17 0.878106 845 110 532 RPX MWD010 OHMM 1.27 1757.26 29.8094 845 110 532 RPS MWDO10 OHMM 1.29 1759.43 48.4696 845 110 532 RPM MWD010 OHMM 1.27 1819. 19 72.7461 845 110 532 RPD MWD010 OHMM 1.23 2000 105. 68 845 110 532 ROP MWD010 FPH 20.08 358.56 161.395 937 120 588 First Reading For Entire File 43 Last Reading For Entire File 588 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 522.5 2933.5 EWXT 532. 5 2943.0 R27P 532.5 2943.0 R09P 532. 5 2943.0 R39P 532.5 2943.0 ROPA 588.5 2999.0 LOG HEADER DATA DATE LOGGED: 13-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 2999.0 TOP LOG INTERVAL (FT) : 588 .0 BOTTOM LOG INTERVAL (FT) : 2999.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 4 . 8 MAXIMUM ANGLE: 63. 4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718512 EWR4 ELECTROMAG. RESIS. 4 113423 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLER'S CASING DEPTH (FT) : 108 .0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 9.00 MUD VISCOSITY (S) : 300.0 MUD PH: 8.5 MUD CHLORIDES (PPM) : 1350 FLUID LOSS (C3) : 13.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 3. 100 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 2. 950 81. 4 MUD FILTRATE AT MT: 3.000 75. 0 MUD CAKE AT MT: 3.400 75. 0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 FET MWD030 HR 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPM MWD030 OHMM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 ROP MWD030 FPH 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 522.5 2999 1760.75 4954 522.5 2999 GR MWD030 API 15.78 199. 6 93.782 4823 522.5 2933.5 FET MWD030 HR 0.2 12.31 1.03594 4822 532.5 2943 RPX MWD030 OHMM 1.24 51.3 7. 93033 4822 532.5 2943 RPM MWD030 OHMM 1. 16 270. 69 21.7602 4822 532.5 2943 RPD MWD030 OHMM 1. 19 1225.23 29.763 4822 532.5 2943 ROP MWD030 FPH 1. 91 5302.56 168.244 4822 588.5 2999 First Reading For Entire File 522.5 Last Reading For Entire File 2999 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Previous File Name STSLIB. 004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 2934 .0 12957.5 EWXT 2979.0 12967.5 R09P 2979.0 12967.5 R39P 2979.0 12967.5 AHSI 2979.0 12934 .5 R27P 2979.0 12967.5 ADCL 2979.0 12934 .5 APEL 2979.0 12934 .5 TNFA 2979.0 12920.5 R15P 2979.0 12967.5 ACDL 2979.0 12934 .5 TNNA 2979.0 12920. 5 TNPS 2979.0 12920.5 ROPA 2999.5 13020. 0 ACHD 10624 .5 12924 .0 LOG HEADER DATA DATE LOGGED: 23-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 13020.0 TOP LOG INTERVAL (FT) : 2999.0 BOTTOM LOG INTERVAL (FT) : 13020.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 56. 1 MAXIMUM ANGLE: 81. 9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 11241795 CTN COMP THERMAL NEUTRON 244601 ALD Azimuthal Litho-Dens 10603721 $ I! # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8 .750 DRILLER'S CASING DEPTH (FT) : 2989.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.50 MUD VISCOSITY (S) : 43.0 MUD PH: 9. 6 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3) : 2.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.450 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .758 148.5 MUD FILTRATE AT MT: 2. 100 70.0 MUD CAKE AT MT: 1.750 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : . i EWR FREQUENCY (HZ) : REMARKS: $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD040 IN 4 1 68 4 2 RHOB MWD040 G/CC 4 1 68 8 3 DRHO MWD040 G/CC 4 1 68 12 4 CALN MWD040 IN 4 1 68 16 5 PEF MWD040 B/E 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 RPS MWD040 OHMM 4 1 68 36 10 RPM MWD040 OHMM 4 1 68 40 11 RPD MWD040 OHMM 4 1 68 44 12 ROP MWD040 FPH 4 1 68 48 13 FCNT MWD040 CP30 4 1 68 52 14 NCNT MWD040 CP30 4 1 68 56 15 NPHI MWD040 PU 4 1 68 60 16 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2934 13020 7977 20173 2934 13020 CALA MWD040 IN 8. 6134 11.7484 9.34435 4507 10624 .5 12924 RHOB MWD040 G/CC 0. 187 3. 101 2.39396 19912 2979 12934 .5 DRHO MWD040 G/CC -3.549 0.366 0.0626211 19912 2979 12934 . 5 CALN MWD040 IN 8.25 12.7 8.87109 14805 2979 12934 .5 PEF MWD040 B/E -5.03 44 .29 3.31136 19912 2979 " 12934 .5 GR MWD040 API 32. 63 449. 11 119.069 20048 2934 12957 .5 FET MWD040 HR 0.22 74 .82 0. 957415 19978 2979 12967.5 RPX MWD040 OHMM 0.89 1538.43 5.31442 19978 2979 12967 .5 RPS MWD040 OHMM 0.53 1735.44 5.55026 19978 2979 12967.5 a RPM MWD040 OHMM 0. 13 1831.72 6.03804 19978 2979 12967.5 RPD MWD040 OHMM 0. 14 2000 7. 82787 19978 2979 12967.5 ROP MWD040 FPH 0.25 366.36 157.35 20042 2999.5 13020 FONT MWD040 CP30 425. 62 1801.81 751. 543 19884 2979 12920.5 NCNT MWD040 CP30 90122. 6 156733 113621 19884 2979 12920.5 NPHI MWD040 PU 16.35 65. 98 34 .7799 19884 2979 12920.5 First Reading For Entire File 2934 Last Reading For Entire File 13020 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 Physical EOF File Header Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RSPD 11850.0 12610.0 TNFA 11877.0 12542.0 TNNA 11877.0 12542. 0 TNPS 11877 .0 12542.0 ACHD 11879.5 12544 .0 ADCL 11890.0 12555.5 AHSI 11890.0 12554 .5 ACDL 11890.0 12555.5 APEL 11890.0 12555.5 DGRC 11913.0 12579.0 R27P 11922.5 12588.5 R39P 11922.5 12588.5 R15P 11922.5 12588.5 EWXT 11922.5 12588.5 LOG HEADER DATA DATE LOGGED: 23-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 13020.0 TOP LOG INTERVAL (FT) : 2999.0 BOTTOM LOG INTERVAL (FT) : 13020.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 56. 1 MAXIMUM ANGLE: 81. 9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 11241795 CTN COMP THERMAL NEUTRON 244601 ALD Azimuthal Litho-Dens 10603721 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2989.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 10.50 MUD VISCOSITY (S) : 43.0 MUD PH: 9. 6 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3) : 2.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.450 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .758 148.5 MUD FILTRATE AT MT: 2. 100 70.0 MUD CAKE AT MT: 1.750 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: • Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down . f Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MAD041 IN 4 1 68 4 2 RHOB MAD041 G/CC 4 1 68 8 3 DRHO MAD041 G/CC 4 1 68 12 4 PEF MAD041 B/E 4 1 68 16 5 GR MAD041 API 4 1 68 20 6 FET MAD041 HR 4 1 68 24 7 RPS MAD041 OHMM 4 1 68 28 8 RPM MAD041 OHMM 4 1 68 32 9 RPD MAD041 OHMM 4 1 68 36 10 RAT MAD041 FPH 4 1 68 40 11 FCNT MAD041 CP30 4 1 68 44 12 NCNT MAD041 CP30 4 1 68 48 13 NPHI MAD041 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11850 12610 12230 1521 11850 12610 CALA MAD041 IN 8. 6216 9. 9411 9.21958 1132 11879. 5 12544 RHOB MAD041 G/CC 2.234 3.27 2. 45433 1332 11890 12555.5 DRHO MAD041 0/CC -0.035 0.265 0. 0387252 1332 11890 12555.5 PEF MAD041 B/E 2.33 10.05 3.5597 1332 11890 12555.5 GR MAD041 API 54 . 69 458 .78 191. 156 1333 11913 12579 FET MAD041 HR 17. 62 34.88 26.3905 1333 11922.5 12588.5 RPS MAD041 OHMM 2.35 24 . 6 4 .42264 1333 11922.5 12588 .5 RPM MAD041 OHMM 2.71 21.73 4 . 98629 1333 11922.5 12588 .5 RPD MAD041 OHMM 2. 61 23.25 5. 12517 1333 11922.5 12588. 5 RAT MAD041 FPH 12.35 269. 99 109.015 1521 11850 12610 FCNT MAD041 CP30 564 . 688 1593. 49 733.782 1331 11877 12542 NCNT MAD041 CP30 104374 152162 112354 1331 11877 12542 NPHI MAD041 PU 18.51 48.41 37 . 1234 1331 11877 12542 First Reading For Entire File 11850 • I Last Reading For Entire File 12610 File Trailer Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/02 Maximum Physical Record65535 File Type LO Next File Name STSLIB.007 Physical EOF Tape Trailer Service name LISTPE Date 11/05/02 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/05/02 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File