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212-067
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Development Exploratory Service 5 Permit to Drill Number:212-067 6.50-029-22811-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11298 11560 9041 8293,8432,8889 unknown 10560 8169,8586,8673 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 32 - 110 32 - 110 1490 470 Surface 3361 9-5/8" 31 - 3392 31 - 3376 5750 3090 Intermediate 8625 7" 28 - 8653 28 - 8473 7240 5410 Production Perforation Depth: Measured depth: 8656 - 11200 feet True vertical depth:8475 - 9024 feet Tubing (size, grade, measured and true vertical depth)4-1/2" L-80 26 - 11298 26 - 9027 8293 , 8432 8169 , 8286Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3, 4-1/2" Baker SB-3A Liner 2814 4-1/2"x3-1/2"x3-3/ 8484 -11298 8330 - 9027 8430, 10160, 1057 7500, 10160, 1116 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 10250370266 249611883 0 35819 109 950 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9027 Sundry Number or N/A if C.O. Exempt: 320-494 No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028309 PBU 07-35A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:38 pm, May 26, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.26 13:48:21 -08'00' Bo York SFD 6/15/2021MGR30JUL2021RBDMS HEW 6/9/2021 DSR-5/26/21 ACTIVITYDATE SUMMARY 5/4/2021 CTU #9 1.75" CT Job Objective: Drift/Log, Set CIBP, Adperf MIRU CTU. Bullhead 205 bbls of 1% SKL w/ safelube. MU & RIH with HES 2.20" GR/CCL logging carrier w/ 2.25" DJN. ***Continued on 05/05/21*** 5/5/2021 CTU #9 1.75" CT Job Objective: Drift/Log, Set CIBP, Adperf Continue RIH with HES 2.20" logging carrier & 2.25" DJN. Set down at 10003'. Tried jetting and made it down to 10245', quit making hole, Pooh. Make up BOT milling assembly with 2.29" diamond parabolic and string reamer. Dry drift passed known restriction at 9,936'md. Begin to clean out liner starting at 9,800'. Minimal motor work, but unable to dry drift passed max depth after milling. Milling ahead at 10,335' at midnight. ...Continued on 6-May-21... 5/6/2021 CTU #9 1.75" CT Job Objective: Drift/Log, Set CIBP, Adperf Continue milling 2-7/8" liner, at 10,335' at midnight. Continue milling down to 10581, OE approves higher set depth of CIBP. Pull up above liner and bullhead well with safelube. Dry drift liner. POOH and freeze protect coil. Swap lubricator, trim 60'. RIH with HES GR/CCL logging tools in 2.20" carrier, 2.25" DJN. ...Continued on 7-May-21... 5/7/2021 CTU #9, 1.75" CT Job Objective: Drift/Log, Set CIBP, Adperf RIH with HES GR/CCL logging tools in 2.20" carrier, 2.25" DJN. Logged from tag at 10,591' to liner top. Flagged pipe at 10,533.3' (white). OOH with log and show a +10' correction, making corected EOP 10,534.24'. Make up and RIH with Northern Solutions 2-7/8" CIBP. Set CIBP at 10,560'. Injection did not change after plug set (4bpm at 1,100psi). OE elects to set another CIBP. Currently RIH with Baker 2-7/8" CIBP. ...Continued on 8-May-21... 5/8/2021 CTU #9, 1.75" CT, Job Objective: Drift/Log, Set CIBP, Adperf Continue to RIH with Baker 2-7/8" CIBP. Unable to enter liner top at 8877' ctm. Multiple unsuccessful attempts at different speeds, pumping down CT, pumping down backside. POOH. Upper set of slips broken off the CIBP. Complete weekly BOP test. Make up and RIH with 3.68" venturi. Reciprocate venturi at liner top at 8872'ctm, no recovery. Trim 100'. Replace leaking reel swivel. RIH with 2.20" venturi. ...Continued on 9-May-21... 5/9/2021 CTU #9, 1.75" CT, Job Objective: Drift/Log, Set CIBP, Adperf Continued RIH with 2.20" venturi with muleshoe. Venturi from 8850'ctm to tag at liner top, 8873'. Multiple unsucessful attempts to enter liner top. Reciprocate venturi at liner top, pooh. No recovery in venturi. RIH with 2.25" DJN. Corrected depth at liner top flag and then tagged plug on depth. PUH and circulate in KWF. POOH and make up 2" HES Maxforce perf gun #1. Perforate 10385'-10422' and 10474-10517'. PUH to 8800', new injectivity is 4bpm at 1350psi. POOH. ...Continued on 10-May-21... 5/10/2021 CTU #9, 1.75" CT. Job Objective: Drift/Log, Set CIBP, Adperf. POOH and lay down gun run #1. MU gun run #2, RIH and tag CIBP, correct depth to bottom shot. PUH and perforate interval 10,136'-10,290' with 2" HES Max Force guns. POOH and lay guns down. RDMO ***Job Complete*** Daily Report of Well Operations PBU 07-35A Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:212-067 6.API Number:50-029-22811-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028309 Property Designation (Lease Number):10. Co341I 8. PBU 07-35A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations 55 Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11298 Effective Depth MD: L-80 11. 12/15/2020 Commission Representative: 15. Suspended Contact Name: Ryan Thompson Contact Email: Ryan.Thompson@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9027 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8293,8432,8889/8169,8286,8673 No SSSV Installed Date: Well Status after proposed work: 16. Verbal Approval: Change Approved Program 31 - 3392 31 - 3376 14. Estimated Date for Commencing Operations: BOP Sketch 32 - 110 Structural 7240 Proposal Summary 13. Well Class after proposed work: 4-1/2" Basker S-3, 4-1/2" SB-3A HYD, 4-1/2" D&D Liner Top 8656 - 11200 8475 - 9024 4-1/2"11298 Liner 11258 9025 none unknown depth 32 - 110 470 9-5/8" 7" Contact Phone:907-564-5280 Date: 5410 78 149020"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 5750 Intermediate 28 - 8653 28 - 8473 4-1/2"x3-1/2"x3-3/16"x2-7/8" 8484 -11298 8330 - 9027 8430, 10160, 10570 7500, 10160, 11160 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 2814 3361 8625 2420 coil extended perforating 55 By Samantha Carlisle at 11:02 am, Nov 19, 2020 320-494 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.11.19 10:41:15 -09'00' Bo York DLB11/19/2020 10-404 MGR23NOV2020 X DSR-11/23/2020 Yes equired? Comm. 11/24/2020 dts 11/23/2020 JLC 11/24/2020 RBDMS HEW 11/25/2020 Plug and Add Perf 07-35A PTD: 2053545 Well Name: 07-35A Extended Perforating API Number: 500292281101 Current Status: Online Rig: CTU & Surface Deployed TCP Guns Estimated Start Date: 12/15/2020 Estimated Duration: 2 days Reg.Approval Req’std? 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Carrie Janowski Permit to Drill Number: 2120670 First Call Engineer: Ryan Thompson Office: 907-564-5280 Cell: 907-301-1240 Second Call Engineer: Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 AFE Number: 2053545 IOR 130 Current Bottom Hole Pressure: 3300 psi @ 8,800’ TVD 7.2 PPGE | Based on offset wells Max. Anticipated Surface Pressure: 2420psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 2460 psi (Taken on 10/14/20) Min ID: 2.313” X Nipple @ 8887’ MD Max Angle: 95° @ 10,093’ Reference Log: SLB MCNL 7/11/12 Brief Well Summary: 07-35A was CTD sidetracked in July 2012 and is currently shut in for HGOR. SAG adperfs were added in 2017 for insitu lift for the well. Well comments: Coil was in the well in 2015 and got to 10696' with a 2.2" mill so all tools/swell will be this OD or smaller for this job. There is a fish from the 2 7/8” plug left in the well by SL on 5/5/20. After pulling the plug, SL drifted to deviation without issue. Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit w/ 1.75“ coil and spot ancillary equipment. 2. Drift w/ 2.2" nozzle & GR/CCL to TD (or may sit down high around ~10696' based on 10/6/15 AWGRS). POOH and confirm good data. 3. Bullhead 200 bbls of 8.4 ppg 1% KCl. a. Wellbore volume to top perf = ~132 4. Confirm well is dead. Freeze protect tubing as needed. 5. Set 2.10" OD Alpha Oil tools (or similar) CIBP @ ~10625'. 6. At surface, prepare for deployment of TCP guns. 7. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ 8.4 ppg 1% KCl as needed. Maintain minimum 0.5 bbls/min continuous hole fill taking returns to tank until lubricator connection is reestablished. Assure excess fluids available if needed to keep hole full. * Plug and Add Perf 07-35A PTD: 2053545 8. Pickup 1.75” safety joint and TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 9. Break lubricator connection at QTS and begin makeup of TCP guns per Table 1 below. Table 1: 07-35A Proposed Ad-Perf Gun Runs Gun Run # Perf Top Perf Bottom Perf Length Blank Top Blank Bottom Blank Length 1 10385 10422 37 1 10422 10474 52 1 10474 10517 43 2 10136 10290 154 Gun run #1 has been optimized for 6 sticks of 22’ carriers (132’) 10. RIH with Gun Run 1 and tag CIBP at ±10625’ MD correlation. Pickup and perforate. POOH. a. Note any tubing pressure change in WSR. 11. POOH. Stopping at surface to reconfirm well is dead and hole full. If not, kill well per step 4 and monitor. 12. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 13. Lay down perf guns. 14. Pick up gun run #2 as outlined in Table 1. 15. RIH with Gun Run 2 and tag CIBP at ±10625’ MD correlation. Pickup and perforate. POOH. b. Note any tubing pressure change in WSR. 16. POOH. Stopping at surface to reconfirm well is dead and hole full. If not, kill well per step 4 and monitor. 17. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 18. Lay down perf guns. 19. RDMO CTU. 20. RTP or FP well. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Tie In Log/Perf Sheet Standing orders flow chart included with this sundry request. *See not above in red regarding kill methods if pressure observed. Plug and Add Perf 07-35A PTD: 2053545 Plug and Add Perf 07-35A PTD: 2053545 Proposed Schematic Plug and Add Perf 07-35A PTD: 2053545 Coiled Tubing BOPs Plug and Add Perf 07-35A PTD: 2053545 Equipment Layout Diagram Plug and Add Perf 07-35A PTD: 2053545 Standing Orders for Open Hole Well Control during Perf Gun Deployment Plug and Add Perf 07-35A PTD: 2053545 15-32C Tie-In Log 07-35A Tie-In Log: Plug and Add Perf 07-35A PTD: 2053545 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMICN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Sus We0 Other:Pulle &oved Program ❑ P &ReSet LTP m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work Development 0 Exploratory5. Permit to Drill Number: 212-067 3. Address: P.O.Box 196612 Anchorage, P ❑ AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-22811-01-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-35A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL „,-.4., ".�+, sw 11.Present Well Condition Summary: # Total Depth: measured 11297 feet Plugs measured feet O(,11 7 C true vertical 9027 feet Junk measured feet ���G? Effective Depth: measured 11258 feet Packer AOGCC "�"C measured See Attachment feet true vertical 9025 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20”91.5#H-40 32-110 32-110 1490 470 Surface 3360 9-5/8"40#L-80 31 -3392 31-3376 5750 3090 Intermediate 8626 7"26#L-80 28-8653 28-8473 7240 5410 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10700-10730 feet 10730-10760 feet 10760-10790 feet 10850-10880 feet 10880-10910 feet 10910-10940 feet 10950-11200 feet True vertical depth: 9026-9025 feet feet 9025-9025 feet 9025-9026 feet 9025-9025 feet 9025-9025 feet 9025-9026 feet 9026-9024 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED MAR 0 22017, 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: 240 21652 652 420 977 Subsequent to operation: 313 7929 677 1300 988 14.Attachments:(required per 20 AAC 25.070.25 071,8 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature .lI 1 Phone +1 907 564 4424 Date 10/17/16 Form 10-404 Revised 5/2015 17'rL, f0 /2-0 /`Y RBDMS (, OCTZ Submit Original Only 9 • d 2 Q) � L 1 W a) N a O a a c0 •Q" L2 a- fA d M ~ Ch U) U) .� L L -J N a) CO CO 05 CO m 0 N N N V Q Q > CO CO 000 ti U) I— N CO M Ococo / ti (q a (77 00 L N M Q . rn co ✓ coocoo � Y Y CC m• U U W a d U (9O co co 1— l— a)a) E Q Q Q co 0 0 LC) Z C7 CO CO 7. 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U m m a 1-- a)a, E < < < ca Ln 10 1n Z M M O O O N 40 41 00 z O z 0 rx c7 2z E o o m Q CC LU u) ZLU H z w E e o H O Q 0 Q cn cn W _ o X 0 W 0 in 0000 Z 0 d O Lu J b L a� E w > _ 3 Q U) w o O O N Z Q M I (-Ow W W cn U coN cc Lu W 0 Cl) II � oo O m m•cr Lu QO � (n CC O- J o J a oz Z N m m N W (L11 0 H c Q 0:1J N - 2 2 (E C J W 0 F ( '' H O Z (n � � � U U Q3 +J z Q O J a) 2z 2 _-I > Q J o p -O CO W J Q L L N y W 2 Q ° Q 0 c O >- - o H II J J (1) 13‘ 0m6 0) = J - H 2 o N ',=. 2z -1 U U U M O >- D m ^2 �W in 0 �� W Q U' U' coso '++ ,, W 2wJOJ o W oo8Q -§ _ o = o co Q * JC2 W a) V) W LU rn � 3 _0N oM d a � 0 � - W co Ya �000 � > >- a) ,:r >, c ii D O Oma * m Z v c � * U O W d u) u) Y "0 -0 0 Q O < W W Cho M W O w o �w < � Z 00 �w Q Q Q N _0 Q o � = �` Z w U Q O W' J J J O C (� p O V (� W _10:11-U N W ' W Q w 0 W O - 0 Y = Q > J (nom Q ~ J � cc ccO U _c §- N `� WF- DU ,- W J - ,e � pUWui wWYWWcc 0_ W � � o O n m J oQr- (� wl- Lij Ea) W Y X Q co a� 0 d o QY a) a � CCHNwW < m � � = w ¢ _1D D , * o co ca a) _ Q m (A m `J 0 * O J p W > W > °� > o_Oo Z z W > 0 z Z (v z � N m L0c c i N � oac° �wmo � Qm � � Q � m � pOOMO �n ol- � = Q _ < 11 DD rz> 4 \ °) U O 7 Z w O -I (a W D , N N 0 O M Q D Q J _J ° __103 E E "' 0 E 620) c)— � W uQ (OHm < 00 ° 0 ----Z007:30 -5 Q � 2ZW � Z �- Q � pJQF c_� � o �- (nom 002c� (nXzW � � : Qo z co O w Q w Q D O Q Q U o ,- ---- ON- Z o � .o N wJzZ �' Zw wm (AQwEOZmfx < mm UE0 = 2m2 W Z '.� O CCN _2 O J = Z UE1) 1111- O OU Q UO �,._ m W Q m J W W Q O W W W W D W W --I W W 0 N o c W _, Wmmwm _ in0c) hW (� JZZ u� zW0 � > 00HzOODOc� Z � � � a) a) OO O z DQ II OozmQNJpzzozoQ (n � p) c c Ur �' -1U -) oJ _ ZZZz_ ZQUOUwZZUZZQZZ2z n * D * * ¢ « * D I- Q Q Q I- Q W' - 3 W Q Q W Q Q W Q Q J Q J *, O o o U : Eo : : 2I' : W (AWWWwWQ * H * JWWW W' W' QW' Q' (/) WwI' * - -cT (7 W H p CO (0 m m (0 co 0 0 OO 0 0 O N NN N N CO 0 NN 00 C) N 0 O O Q • • k= _ D 60- C:00 -° W® � \ 2 Lori-r,, 0- Ne3 � f k / c x o o HE \ 2 / ƒ CO 65 / \ > » /$ i ƒ \ $ R .e .E c / c c / p ( co / _ƒ \ __lc ©i \ ƒ q 2 \ \ & a@ X / u o m o c o g n m m $ D _ & t / y (1) ;'- o G �\ / fes p\ I �� � ƒ ---10 .c (7) / ƒ ® \ k 2 - a c < frO L « w0ELCA D / c / c e § - - , E 2 o I U O 3 ± 7 ° , fa- / / \ 2 cisL. § / 7 \ / ® G / ® E _ © 0-% [ / ƒ » / ® ® 2 / % O « / ® / �/ f / \ � 2 / \ R _ & £ 7 R a R CC - / O / & 5 a) iny # ,- 2 / 0w a -JR -I 2 14. CT) R e aI U 2 m O m o ® r@o o / i-1 % \OM22 .g # / E \ ± u - = O 00 / \� / ° tO ° ƒ \ / / p/ a \ / \ t / 0_/ E % � ƒ / / / ) / /� \ _ \ O < , E \ � O I « k / / �/ _/ / W 2 » / 0) / 0 / £ / % / E / / / / / \ - 0- - 2 I = I R x ± / i / / U 0 7 \ 7 clo G -1 6 2 ® R a % / O / x ± O w \ 2 M u m — _ £ 2 - E ± O A O m m 2 # ® 2 E / E 0 C U ± / / ) ) \ / / / \ z / / \ Z \ / \ f / / i o o 2 O f a_ E O $ f ƒ i O- 62 / f / \ / — / / 2 / TREE= OW 1111 AIIKNOTES: WELL ANGLE>70*@ 9392'. VVEIU-EAD= FMC 07-35A ...GLM'S HAVE LOWER PSI RATE THAN NORMAL ,ACTUATOR- BAKI32 C ***CHROME TUBING*** NTIAL KB ELS. 57.0' BF.ELEV= 27.9(Y I 2074'--9-5/8"HES CEMENTER KOP= 1998' Max Angle= 96"@ 10093' 20"COND, —1 —110 I I 2094' —4-1/2"FES X NIP,ID=3.813" Datum MD= 9137 915411-40 Datum TVD 8800'SS GAS LFT MANDRELS U)-19.124" ST MD TVD DEV TYPE VLV LATCH FORT DATE [9-5/8'CSG,40#,L-80 BTC,CI=8.835" _i- 3388' .0 1 3725 3710 1 KBG2-IR DOME BK 16 07/28/12 2 6226 6210 0 KBG2-IR SO BK 20 07/28/12 3 8095 8004 33 KBG2-IR DMY BK 0 05/27/08 Minimum ID =2.31" @ 8887' 1 I 8258' —14-1/2"HES X NP,D=3.813" 14-1/2" NS D&D LTP w/X NIPPLE 8288' —17"X 4-1/2"BKR S-3 PKR,13=3.875" X ><- 4-1/2"TBG,12,64,13CR-80 VA M TOP, H 8385' I I 8322' —14-112 HES X M3,113=3.813" --_______ .0152 bpf,ID=3.958" ] 8400' —1-17*X 4-1/2"UNIQUE OVMSHOT 1 MG STUB(05/24/08)Na --"*"............- 8429* —7 X 4-1/T BKR S-3 PKR,ID=3.875" Z 2 - I I 8463. —4-1/2"HES XN NIP,MILLED TO 3.80" (06/14/12) 8481' —7"X 5"BKR ZXP FKR TOP OF 4-1/T LM 2 — 8481' - w/7,11TIEBK SLV,E)=4400" 4-1/2"TBG,12.64,L-80,_0152 bpf,ID=3.958" H 8485' i 1 8485' '1H4-1'2 WLEG,D=3.958" H ELM()TT NOT LOGGED 7'CSG,26#,L-80 BTC,13=6.276" —1 8650' E-411 \ 8496' Hr X 5-BKR HMC HGR,ID=4.400' 8601' H5'X 4-1/7'XO,D=3.958" j --------- 8887' H4-1/2'NS D&D UP VW X NP,ID=2.31"(10/05/16) I 8905' H3.70"BKR DEPLOY SLV,D=3.00" 8926* —3-1/2"HES X NP,ID=2.813" 3-1/2"LP,9.3.4,L-80 Slt,.0087 bpf,ID=2.992" —1 8958' 6: 1/2"BKR WHPSTOCK w/PKR(TA GED07/03/12) _[ 9161G ' 4-1/2"LNR,12.64,L-80 BTC-M, — trptID=3.958' [ * —9162 .0152 , 4 . 8958' H3-1/2"X 3-3/16"XO,D=2.786" 44141 : NLLOUT WINDOW(07-35A) 9152'-9161' 3-1/4"LNR,6.64,L-80 TC11,.0079 bpf,ID=2.85" —I PERFORATION SUMMARY 9699' --I3-3/16"X 2-7/8"XO,ID=2.377" REF LOG:SLB CCL/GR/MCNL ON 07/11/12 9936' HREs1RICTioN-SEE WSR 10/04/15 ANGLE AT TOP FERE 90"@ 10700' Note:Refer to Production DB for historical perf data STZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 10700-10790 0 01/20/16 I 1.56" 6 10850-10880 0 10/09/15 I 1.56" 6 10880-10910 0 10/08/15 1.56" 6 10910-10940 0 10/07/15 I 2" 6 10950-11200 0 07/12/12 I I PBTD -H 11258' 2-7/8"LNR,6.5.#,L-80 STL.,.0058 bpf,D=2.441" — 11298' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12108/97 0141 ORIGINAL COMPLETION 01/25/16BLS/JMD ADFERFS&RESTFXTION(01/20/16) WELL: 07-35A 05/27/08 DI 6 RWO 10/10/16-NLW/TLH LNR TOP PKR C/0(10/05/16) PERtv11'fsb:° 120670 07115/12 NORDIC 2 CTD SICETRACK(07-35A) API No: 50-029-22811-01 . . 09/16/12 AK/PJC ANAL DRLG CORRECTIONS SEC 34,T11N,R14E,1802'Rt.&676'FWL 09/19/12 JMID GLV 00 DATE CORRECTION 11/05/15 ATO/JMD A DPERFS(10/07-09/15) BP Exploration(Alaska) • N STATE OF ASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 2 2 2016 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate (3 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 212-067 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22811-01-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-35A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11297 feet Plugs measured feet true vertical 9027 feet Junk measured feet Effective Depth: measured 11258 feet Packer measured See Attachment feet true vertical 9025 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"91.5#H-40 32-110 32-110 1490 470 Surface 3360 9-5/8"40#L-80 31-3392 31 -3376 5750 3090 Intermediate 8626 7"26#L-80 28-8653 28-8473 7240 5410 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10700-10730 feet 10730-10760 feet 10760-10790 feet 10850-10880 feet 10880-10910 feet 10910-10940 feet 10950-11200 feet True vertical depth: 9026-9025 feet feet 9025-9025 feet 9025-9026 feet 9025-9025 feet 9025-9025 feet 9025-9026 feet 9026-9024 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) ., 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 'SCANNEDA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 205 19015 911 450 911 Subsequent to operation: Shut-In 380 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature .P" I Phone +1 907 564 4424 Date 2/22/16 Form 10-404 Revised 5/2015 V17 " jy7� 3/ii I t - RBDMS Lu FEB 2 3 2016 Submit Original Only • • d 2 ee - W o L O co a Y 4 } N ▪ = d N M m O. • M L L L (0 f0 CO CO CO CO N N N r � � A CO N Q O C • N O M co co co (n CO • U) O CO L N co W c Q O) N �t CO co co CL Y Y m O O d A U m m H d E d Q Q to LC) LO Z M M M O O O • . a) 0 0 0 0 co (0 0 co N QrLo ' oo U CO LO 0 L J-(") (O co0 0 o IO N- co O O (b (b O co CO I"- CO M V I- N- CO N CO N CO CO CO Cr 00 O O N C7 CO CO CO CO 0) (3) CO OD Cl I-- O CO 00 N N- CO CO CO N CO (0 Ln CO CO N CO (O f- O N N CO CO CO (A CO W O N Cr) N CO CA LO 00 CO Cr) CA LO L CO CO O) CO 0) CO CO C.) 0 /� `V Q 11111111 NI- LOCOCY) v- 444 Q M N N- CO CO O LC) 0 CO 0) CO CO N 0) (3) LC) (N CO (0 (0 (00) CO 0 • co O O O ao co o c o L o G� , cp JJ aoJ = ( N �# .N N *k CV N ON ctI (/� CO c O) (O N c- CV co H CO I` N I co CO N t a)CO CO N '' ' N- N- = 1� co COO L[) V (fl co CA J co co co (3 co W - c W • U0 w O O u_ CreCCCc Z Z Z w W W W W 00 C0 0 j F- z_ z z_ z j j 0 U) Z J J J J H H • • J b Cu 0 „,...9, M a) a) = - Oinr Ita X -0 c r . co U C a = 0 , oo0) cY0I Cl) c ro cCO }- 0o Q � w c N • Dr Y W VI � ... a a 0o z 2 0 o o � � a �.U a) ' N 't 2 co o d L CO- "a N a) � p er ch ✓ I- r 4) 0 U -6 , U (n U 0 ' o 0--) c Y o ca E U L c 0 W 0 U b >, C D ca j V O -0 inN ca 10--0 bo 0) - (n min- E c a2ic° (AD -I a) m a) o EU0 I Qom o — a) • N- O - - to Q H , o a) LE `t ch E a Zo L"N -0 0 p in c6 a) a) ✓ 0 iu I- r o - ,, m c ta d 0-c) J r . i Z N 0 +L-, U �_ N ' c E 'nJ0) b ,. o_=v „...a) o N Er a) N r5 co • D Ci CD = 0- ))D al E L D Q-0 C Z 00Do (n -o = a It 0U m om O >- co -( Et (0 Cl) c 0) , c U ~ ca As Q ~ c a F- L c 0: co E L in2ZZ � o � Ui � CC m m 0 •_ - Q E a) Q _ D Q U o2S Lf) J a Q p O p Q N U _p J 0 W O -0 E Q D I d o Z 0 _5 d U0 rn� p a) 0_ Q OO) Uco 0 co 2 O 0 2 O W c N CO �o Et W cacy) ca CO O m a) O a) o) 0 : 0-t Cm o .o 3 aa)) a o 0 � a) ,a- cn o_ L m o m c 0. N (a L C) 0)CO Co * N 0) - N 00 * N d U O a) is v _is fp) U ui Q Q OO Q N c Ce N II o aN0 p ' 0 0 r ON (V CO ' V Q O r CII a) O Urnao E v QZi 0_ ' Ct UrnoO VjfY - Urn * m H 0 (n Q c N rn F uj d co H in o f ca Ot < _ o0 `o , M cn0 USN H0_ viWU ' Ya) _� � to pI0tf) 0)U T LL o r o_*kmQ 5, bI c Q0 a) o Q._ a) ' c N a c r• I— o d 0 ° -0 a o_ c J � ¢ + �oIt aa) oF � � n � Q f: v_ cud m \ Q -' E -cY r > -p a) o "- C I- J N •c 1 J J ' a) o U a) 0 CO . _0 J (a 7 U d U) C .2 n O U ch O C co .,> p) � .� � a0i +I w00 0 c � � 3 0 00000 2 * ch o 0 c 0 0 1- 17) a m - 0z -(n )* *, H -= o ��I� -, �Dr� o *, HID_C * 0 UOW 3 0 -0J 0_Y ; 00 - Oo ( r : 000 Coos) W I- 00 CD CO N._ r r OCNI 0 0 (n N 0 H 9) o 7o o co r N N m N d- N- U Q TREE= 11110 •(2VVSAFETY NOTES: WELL ANGLE>70°@ 9392'. iWELEENR= BAKER C 07-3 5A ... 'S HAVE LOWER PSI RATE THAN NORMAL CHROME TUBING*** INITIAL KB.EL.EL 57.0' BF.ELEV= 27.90' I LI [ 2074' --9-5/8"HES CEMENTER KOP= 1998' Max Angle= 96°@ 10093' 20"COPD. —110 I I 2094' H4-1/2"HES X NP,D=3.813" Datum MD= 9137' 91.5#,1+40, Datum ND= 8800'SS GAS LFT MANDRELS D=19.124" ST MD ND DEV TYPE VLV LATCH PORT DATE 9-518"CSG,40#,L-80 BTC,D=8.835" 3388' TO 1 3725 3710 1 KBG2-IR DOME BK 16 07/28/12 2 6226 6210 0 KBG2-IR SO BK 20 07/28/12 3 8095 8004 33 KBG2-IR DMY BK 0 05/27/08 Minimum ID =2.36" @ 8894' I ri 8258' —4-1/2"HES X NP,D=3.813" 4-1/2" BKR KB LTP 2K > 8288' _Hr X 4-1/2"BKR S-3 PKR,D=3.875" 8322' —4-1/2"HES X NP,D=3.813" 4-1/2"TBG,12.67r,13CR-80 VAM TOP, — 8385' 1� .0152 bpf,D=3.958" 1 T8G STUB(05/24/08)f— 8388• ../......--- $400' 7"X 4-1/2"UNIQUE OVERSHOT 8429'_ ' ' ]-17"X 4-1/2'BKR S-3 PKR,ID=3.875'1 Z [_._8463' -14-1/2"HES XN NIP,MILLED TO 3.80" (06/14/12) 8481' —7"X 5"BKR ZXP PKR TOP OF 4-1/2"LNR I—_ 8481' w/7.11'TRK SLV,D=4.400" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" --I 8485' 8485' {—4-1/2"W.EG,D=3.958" 1 \iri- HE-MD TT NOT LOGGED 7"CSG,26#,L-80 BTC,D=6.276" -1_ 8650' 8495' —{7"X 5"BKR HMC HGR,D=4.400' 8501' —H 5"X 4-1/2"XO,D=3.958" I .- 8894' H4-1/2"BKR KB LTP,ID=2.36"(07127/12) } 8905' —{3.70"BKR DEPLOY SLV,D=3.00" 8926' H3-1/2*HES X NP,D=2.813" 3-1/2"LNR,9.3.4,L-80 STL,.0087 bpf,D=2.992" —1 8958' 4-1/2"BKR WHPSTOCK w/PKR(TAGGED07/03/12) !— 9151' - 4-1/2"LN12.6#,L-80 BTC-M, 9152-- R ------- .0152 bpf,ID=3.958" lii ,t.\ 8958' - —I3-1/2"X 3-3116"XO,D=2.786" MLLOUT WHtDOW(07-35A) 9152'-9161' 3-1/4'LNR 6.61/,L-80 TC11,.0079 bpf,D=2.85" 9599' PERFORATION SUMMARY9699' —13-3/16"X 2-7/8"XO,D=2.377" REF LOG:SLB CCU GR/MCN_ON 07/11/12 ANGLE AT TOP PERF: 90°@ 10700' 9936' —'RESTRICTION-SEE WSR 10/04/15 Note:leer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 10700-10790 0 01/20/16 I 1.56" 6 10850-10880 0 10/09/15 ' 1.56" 6 10880-10910 0 10/08/15 1.56" 6 10910- 10940 0 10/07/15 I 2" 6 10950-11200 0 07/12/12 I ' PBTD —I 11258' 2-7/8"LNR 6.5.#,L-80 STL,.0058 bpf,D=2.441" — 11298' GATE REV BY COMMENTS DATE I REV BY COMMENTS PRtDHOE BAY MT 12/08/97 D141 'ORIGINAL COMPLETION 01/25/16 BLS/JMD ADPERFS&RESTRICTION(01/20/16) WH1: 07-35A 05/27/08 016 RWO PERMIT No: 2120670 07/15/12 NORDIC 2 CTD SIDETRACK(07-35A) API No: 50-029-22811-01 09/16/12 AK/PJC FINAL ORLG CORRECTIONS SEG 34,T11N,R14E,1802'FN_&676'FWL 09/19/12 JMD GLV CJO DATE CORRECTION 11/05/15 ATO/JMD ADPERFS(10/07-09/15) BP Exploration(Alaska) STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COWAN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Ea Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 212-067 3. Address: P.O.Box 196612 Anchorage, Development l Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22811-01-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-35A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: R E E PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: /� tt Total Depth: measured 11297 feet Plugs measured feet NOV� �* F■V■ true vertical 9027 feet Junk measured feet N 0 0 6 2 Q 15 Effective Depth: measured 11258 feet Packer measured See Attachment feet true vertical 9025 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"91.5#H-40 32-110 32-110 1490 470 Surface 3360 9-5/8"40#L-80 31 -3392 31-3376 5750 3090 Intermediate 8626 7"26#L-80 28-8653 28-8473 7240 5410 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10850-10880 feet 10880-10910 feet 10910-10940 feet 10950-11200 feet True vertical depth: 9025-9025 feet 9025-9025 feet 9025-9026 feet 9026-9024 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): g� t Treatment descriptions including volumes used and final pressure: R�Q�E� JAI`1 1016 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 180 16443 452 420 1033 Subsequent to operation: 272 17908 1032 450 916 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 10 Exploratory 0 Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil B Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ["✓,�st-4,, l Phone +1 907 564 4424 Date 11/6/15 Form 10-404 Revised 5/2015 C Z RBDMS 1O V 101015 Submit Original Only • S d N - W .2 a_ Y } U Q (D L = a a' co Y • M CD CO Lo p fn (n .1- L L (D (D co CO CO m N N N CDr � r (n u '- N 1,13 M co co CO ti ( ) O C •D a C cv N rn a) L N co .1- (1) Qw CI M N Y 2 rn M co M ✓ CO co a Lt Y Y m 0 0 in 0.d o_ H U co m F- m E < < < LO L.0 in Z M co M O O O • • M 10 QOO O O 0 0 R 0 0 0 0 ll I� cam- N- N- O U O O � rn � � COCO OMCO O 3 I� C ='"'" m r In N- 00 CO CO O CO M r"-- 00 I� M V O N CO N CO CO M CO N- O O N M CO CO CO 00 6) 07 CO CO 0 1 1 1 1 1 1 1 1 1 H O CO CO N ,- 00 M 00 N CO CO Ln CO CO N CO CO N- O N N 00 CO CO 01 CO Q� O NM N CO O) 10 CO O) co co co 07 O 00 co co O LO •4t CO CO O CO O) CO CO ✓ p I MLO Q In 00 O) x•--• M N co 00 O 10 6) CO 0) CO CO C O) O) N CO C (0 (0 (00) CO • • co J 00 J J J J �$ = N �$ J O CV N• .4- Cfl •(/� a N O Cfl N • fn _ CO O _ N N (n i co i M CO N V t CO13) Cfl N `ct `- O) r- I� I� M co O Ln co co O) co 00 O CO '- CO J W f F- of 0 C l- W o ' U W zWWWWWmm ODf— zzzzDD w Z J J • • 6 _c§ y % 2 / 77 \ k ƒ f\ tr q 6 e c t 7 \ E e cn e CO g oE2 _ 0_ t 0 o I / E S f ± ƒ L.L. G _C \ 2 O / O R° \ J E \/ % o -, ± mo \/ > %/ / n ± E o e Gq � / '- >= ®o \_ ¥ okIc3 /f E ± aCo / fes 736E C >- 6 U w \.2 o o w E tr, ® 7 2 \ = 2 s \ E _ cco 2c CD C0i0 7 2 / % C. 2 6 = -J 2 c m co -1 cn R D a)/ \ / 7 / § ƒ 7 � � a < o 2 7 C < E \ § ± 97 O3� o ± r O \ - k / / k 1.1 / R/ o0- _ \ cco72 / \ = G CD \ � / / / \ � � _/ / \ qfk re \ k \ / N— E J 6) \ \ ® >, > _ > 2 / c) Tu ® / > ir a) a) / . R o R c o o R m k p -x -/ / / [ I ƒ �/ .k § / 4 0 ƒ / E 5 \ / \ § 0 \ \ / f \ / � / / � 0 � / \ / � � � \ .-§- � ) j / -.-• � k& j % j / 2 / 2 ? ® / &co = m k £ Cr) R _ _ 4 t 2 ® a e * cab > c ® § ® c -- ,_ _ o I— I- 3o o \ ± / \ / / / � \ k / / 0 CY E U : Q E ± * E : O : CC = I ; e L < r r n \ (N //\ $r-- a) c '- / \ / \ U < Tar.= Cl1N ! TY NOTES: WELL ANGLE>70°@ 9392'. WELLHEAD= FMC 07-35A 7_35A •*"GLM'S HAVE LOWER PSI RATE THAN NORMAL ACTUATOR= BAKER C """CHROME TUBING*** U11AL KB.ELEL 57.0' BF.ELEV= 27.90' 1 2074' H9-5/8"HES CEMENTER KOP= 1998' Max Angle= 6"@ 10093' 20'CONDUCTOR, — —110 I I 2094' —141/2"HES X NP,D=3.813" Datum MD= 9137' 915#,H-40, Datum TVD= 8800'SS D=19 124" GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE [9-5/8°CSG,40#,L-80 BTC,D=8.835" -` 3388' I 1 3725-3710 1 KBG2-IR DOME BK 16 07/28/12 2 6226 6210 0 KBG2-fit SO BK 20 07/28/12 3 8095 8004 33 KBG2-IR DMY BK 0 05/27/08 — Minimum ID =2.36" @ 8894' 1 1 8258' —14-1/2"HES x nom,D=3.813" 4-1/2" BKR KB LTP _ 8288' —17"X 4-1/2"BKR S-3 PKR,D=3.875' 4-1/2"TBG,12.6#,13CR-80 VAM TOP, H 8385' 1 1 8322' 1-14-1/2'HES X NP,D=3.813" .0152 bpf,D=3.958" TBG STUB(05/24/08)1— 8388' Zi ]/ 8400 7"X 4-1/2"UNIQUE OV ERSFK)T] 8429' H7"X 4-1/2"BKR S-3 PKR,ID=3.875" 1 1 8463' 4.1/2"HES XN NIP,MILLED TO 3.80" (06/14/12) 8481' —7"X 5"BKR ZXP PKR TOP OF 4-1/2"Lt'R H 8481' w/7.11'TIEBK SLV,D=4.400" 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" -H 8485' 848 —4102"1/1/LEG,D=3.958" —I ELMD TT NOT LOGGED 7"CSG,26#,L-80 BTC,D=8.276" H 8650' 8495' —{7"X 5"BKR HMC HGR,D=4.d00' 8501' --15"X 4-112"xO,D=1958* --------- 8894' H4-1/2"BKR KB LTP,D=2.36"(07/27/12) 8905' -H3.70"BKR DEPLOY SLY,D=3.00' 8926' —3-1/2"HES X NIP,V=2.813" 3-1/2"LNR,9.3.#,L-80 STL,.0087 bpf,ID=2.992" H 8958' 4-112"BKR WHPSTOC K w/PKR(TAGGED07/03112) — 9151' 8958' _—{3 1/2"X 3-3116"X0,113=2.786" y ..4 4-1/2'LNR,12.6#,L-80 BTC-M, —9152 w 0152 bpf.D=3.958" �l ;r MLLOUT WINDOW(07-35A) 9152'-9161' , . PERFORATION SUMMARY a REF LOG:SLB CCLI GR/MCNL ON 07/11/12 ANGLE AT TOP PERF: 90°@ 10850' 'slate:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 1.56" 6 10850-10880 0 10/09/15 1.56" 6 10880- 10910 0 10/08/15 9699' —13-3116"X 2-7/8"X0,D=2.377" 1.56" 6 10910- 10940 0 10/07/15 2" 6 10950-11200 0 07/12/12 , 3-1/4"LNR,6.6#,L-80 TC11,.0079 bpf,D=2,85' 9599' PBTD —1 11258' 2-7/$"LNR,6.5.#,L-80 STL,.0058 bpf,D=2.441" H 11298' i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/08/97 D141 ORIGINAL COMPLETION 07/30/12 GJB/JMD GLV 00(07/28/12) WELL 07-35A 05/27/08 D16 RWO 09/16/12 AK/PJC FINAL DRLG CORRECTION'S PERMIT No:`2120670 07/15/12 NORDIC 2 CTD SIDETRACK(07-35A) 09/19/12 JM) GLV 00 DATE CORRECTION T1ON AR Na: 50-029-22811-01 07/15/12 PJC DRLG HO CORRECTIONS 11/05/15 ATO/JMD ADPERFS(10/07-09/15) SEC 34,T11N,R14E, 1802'FNL&676'FWL 07/16/12 PJC DRLG DRAFT CORRECTIONS 07/30/12 GJF/JM7 SET 4-1/2"KB LIP(07/27/12) BP Exploration(Alaska) • i 40,6, rA�- BAKER PRINT DISTRIBUTION LIST NIJGNES Please sign and return one copy of this transmittal fc COMPANY BP Exploration Alaska Inc BP Exploration (Alaska) Inc. (mandatory) Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME 07-35A 900 E. Benson Blvd. vd/30/2015 (mandatory) �`' Anchorage, Alaska 99508 M.K.BENDER FIELD Prudhoe Bay Unit!RE OV .,t t to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough 0`j 2 9 NO LOG TYPE RPM-Wireline (mandatory) (mandatory) STATE Alaska O1 t r'e BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: October 7,2015 TODAYS DATE: 27-Oct-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: CANIZARES EMAIL: (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY A B C D ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) L.I.S. FILM PERSON ATTENTION #OF PRINTS #OF COPIES#OF COPIES#OF COPIES#OF COPIES#OF COPIES 4 4 4 4 4 4 4 1 ConocoPhillips Alaska Inc. 1 I 1 1 1 Attn:Ricky Elgaricio A= 07-35A_MRPM_PNC3D_RAW_07OCT2015_BHI.meta ATO 3-344 700 G Street \ Anchorage,AK 99510 B= *(Folder 1 on cd/dvd) 07-35A_MRPM_PNC3D_RAW_07C 2 ExxonMobil,Alaska 1 1 1 1 I Attn:Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr.Suite 600 Anchorage,AK 99503 ,-• ---..-- 3 State of Alaska-AOGCC 1 1 1 1 Attn:Makana Bender ;333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 SCANNED P A NNED A U r 1 1 2016 4 DNR-Division of Oil&Gas 0 I 0 L, 1 I 1 I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 5 I I I I TOTALS FOR THIS PAGE: 3 1 1 1 0 0 TOTALS FOR ALL PAGES: 3 1 1 1 0 0 1 M co o >+ co N q co E w cc) ,p r I E m w N ;ta) L E CC o Im 0 aZ a 22 0 al > 0 aoU INI IoJ + U N IIcoN c 0) wNU QIn —x 0_° >Q 13 >+ — .N �' L On . LL T O Z Z j a) o El' E_1 11) E w? a Z c cn 0 a a`) a)LL w co Q m Co Coco -o o Co + iii f6 Li —I Q Q c Co c a) co O 0 a) co _ in Ln Q J vii o' a ii c -m co co J U O W O U a) a C O O V O' O C <j U a E OC) -c• a) 0 C to aNj —"Ii N N ?_ r a' ZC7 oy a) o � E g E a it ii •' co) a E o o ali U `—° aJ �= c •�o .� v aa)) a y Eo L L E Z Z.y E. E U co c 'c•c c O c 'c E N To co U' C c ) o �:. U� 0 Oa 2< 2 2 E r U J 'Co 'Co O Z a0i a 0 0 O CO a an d .LD P. d 1-) 0 Ce a o �H a � � �� LI Li." Lo c) w w 0 w O O c 'C N N M co co co M N N N p.++ d a. U Y > 0 0 0 0 0 0 0 0 0 o EN E NW co fa V!'N CO (� CO CO CO (D CO N U) Z it 0 a.I n I M f7 co co co 0 r a X c c c c c c c c a W w J I I a) a a) a) a) a) a a a) o m J0 O0IO O O O O O O O > Z co ami CL < Coco 1 _ 01N N —as cr) co - N N N M N Ja O OI 'I 1 c Z C t I 0 CO(D COcn o 0 0 U) 0 0 S Om r ......O 14 N M_ M co to (OD rn G Q y U) O) CO CO O) O) O) 00 CO 0N al1 a) c�0 E v U U 1 E co, coc W o O J „Q Z z a) Q C? a I- 0. J co O O E IN 1 o J 2 0 0 0 co • / N I 0 m a d /� Q N / J os co r W Wr— 1 /U J CO N N N N C t' oo / � Cl) O M co Q ac. w a ZI / ce Q C E z O U w w > 0 E 0 O aa)aa) > > > I V / Z N fA N Z OU) co a) a) T a) g ' a a Co a' co co co C1) Co (.,ii. as N C E o o c c o o m o O O O I c I / ZII� a > > > > E a ° ~ ~ IIIta I o ; Z H rn ` a) a) 0 c a 0 0 co o O I; o n O J m a o 0 0 0 o a) a) u� u) w co « a In u) N- N. N. a) a) N u) !I c > N Q N O B E M co N- N. I• Is I. N N — ' W N CCe O O Q W Ci Z III N N NN N N N N N N N Nal W Q G CO" r a y 1 a' I OLL € m E E E Z a�j — CG '� w y LL N "O V "O co Z 10 Cs /� o o u .E o d ¢ a a s I n a U .. W LL a) m I U Z W o 2IU 0 U U 0 U U Io ce cn J U o C 3 d za 2re J ~ W a J GW J cn J W W W WW WW l f o 1 on o Q / Z N'o N Q ?'/Z Z CO Z >- >- >- � VI Z). m N H d) U_ a) I I csia com c I� o a) o n 0 Z L r o F. 0 a m Q a) a) o o o N o 0 J J O Z Z < / a Z Z di I— • - v / 0 cL Q aa p it om m • 0^_ i.7- a i w g o O N co a LL E LU X W a) w U J vi a m o _ 3 E 1 I z �; :? co Q r O co co O MI w J n c Ja) = v E '1 1 /� O 2 0 0 H Om M c I C o G N I 1 n l O N E• / Z 2 NI w 00 a) 1 o Jr >- r E N Q M o o Is. / C.) a o ca r ~Z N w 2 >- =N- .a. za II M m N a) E N- o I- E 1 O a) c rn N I w CO I `° °' 1r o o c- o ! o a 1" g .E "11! 4:t Z n O E T o E- v _ O • 0 Eo 2 O co m 1 1,\Z N • N- < o Z Nlithi a) \ N ›- ›- > N n 19 N � / o/ I I m> m II co u) v N r m D a) _ a) Cl) N Y W ( a' O °o) a Cl) f0 o a a? c o CN c- o Z c 0 0 C u c U — '- .0 a J 'd a) C d CO ._ a) V n 7 o a a to u E a E E o o ,e E a) ai E E Q Cl) 0 a (0 0 0 E O U U VA&ill FAKER PRINT DISTRIBUTION LIS)T o 6 2013 HUGHES AOGCC COMPANY BP Exploration(Alaska)Inc. INTERMEDIATE FINAL Yes (mandatory) Z�Z 0 b l WELL NAMEn��3�A RUN NUMBER 2-2-T1(man atory) FIELD Prudhoe Bay BH SALESMAN Okechukwu(Okey)Anyanwu (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: TODAYS DATE: 5/31/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: BP Exploration(Alaska)Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY D FIELD FINAL (digital il ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #O F'HiN i S #OF COPIES #OF COPIES U U U U U BP Exploration(Alaska)Inc. I 3 I 1 I I Petrotechnical Data Center LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 2 IConocoPhillips Alaska Inc. I I I 1 I Attn Ricky Elgarico IPO Box 100360 1Anchorage,Alaska 99510 � 1 3 ExxonMobil,Alaska 1 1 I Attn Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 Anchorage,Alaska 99503 4[tate of Alaska-AOGCC I- 1 I 1 I I ` I Christine Shartzer 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 5iDNR-Division of Oil&Gas I I 1 I I Attn:Sean Clifton 1550 W.7th Ave,Suite 800 Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: 0 5 5 0 0 0 TOTALS FOR ALL PAGES: 0 5 5 0 0 0 z_-0_ ce,) bp Date 10-04-2012 0 Transmittal Number: 93260 J --° (0) RECEIVED BPXA WELL DATA TRANSMITTAL OCT 442012 .' Enclosed are the materials listed below. AOGCC (BPXA FIELD LOG DATA) .) )`-1 OJ (� If you have any questions, please contact Doug Dortch at the PDC at 564-4973 11 / Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: - , Z-%2 v£?s- .517-35A '7 - a-- ( 1345A ' 13-15APB1 --217 /2-6 PDF1 /= cY-/A / , A..v /� d i�j' l S 4/4-;.�� 1315APB2 1, --C)5 L - Zl Z-c.)--X) B-20A 'Z - -c) v C-01B • z12-mac 3 C-01 BPB1 • C-27C 2t z-)�Z F-08B 2i2_,-�VD j;D C/O_,?Oez.. j0c-0, , �/.D 7UL?)clz 2/(- (2.4 6•/7 /j Please Sign and Return one copy of this transmittal. Thank You, Doug Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Shartzer 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E.Benson Blvd.PO Box 196612 Anchorage,AK 99519-6612 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 2 2 2012 WELL COMPLETION OR RECOMPLETION REPORT ANDCC 1 a. Well Status. ®Oil 0 Gas ❑SPLUG 0 Other 0 Abandoned 0 Suspended lb. Well CI 2OAAC 25 105 20AAC 25110 ®Development ❑Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No of Completions One 0 Service ❑Stratigraphic 2 Operator Name: 5.Date Comp,Susp.,or Aband. 12 Permit to Drill Number. BP Exploration (Alaska) Inc. 7/27/2012 212-067 3 Address: 6. Date Spudded. 13. API Number. P.O. Box 196612,Anchorage,Alaska 99519-6612 7/04/2012 50-029-22811-01-00 4a. Location of Well(Governmental Section) 7.Date T.D Reached. 14. Well Name and Number: Surface. 7/9/2012 PBU 07-35A 3478' FSL,4604' FEL, Sec. 34,T11N, R14E, UM 8. KB(ft above MSL)' 57' 15. Field/Pool(s). Top of Productive Horizon: 4353' FSL,4934' FEL, Sec. 34,T11N, R14E, UM GL(ft above MSL). 27.5' Prudhoe Bay/Prudhoe Bay Total Depth* 9. Plug Back Depth(MD+TVD): 2619' FSL,4402' FEL, Sec. 34,T11N, R14E, UM 11298' l ' 9027' 4b Location of Well(State Base Plane Coordinates,NAD 27). 10.T al Depth(MD+ D). 16. Property Designation Surface. x- 676893 y- 5949139 Zone- ASP4 11258' 9025' ADL 028309 TPI: x- 676540 y- 5950006 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit Total Depth.x- 677116 y- 5948285 Zone- ASP4 None 18 Directional Surve Y ®Yes ❑No 19.Water depth,if offshore 20 Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 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: MWD/GR/RES, GR/CCL/MCNL 9152' 8867' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 260 sx Arctic Set(Approx.) 9-5/8" 40# L-80 28' 3388' 28' 3373' 12-1/4" 2418 sx CS III, 335 sx Class'G' 7" 26# L-80 25' 8650' 25' 8470' 8-1/2" 302 sx Class'G' 4-1/2" 12.6# L-80 8481' 9152' 8328' 8867' 6" 440 sx Class'G' 3-1/2"x 3-1/4" 9.3#/6.6# L-80 8894' 11298' 8678' 9027' 4-1/4" 129 sx Class'G' x 2-7/8" /6.5# 24. Open to production or injection? ®Yes 0 No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ (MD+TVD of Top&Bottom;Perforation Size and Number) TVD) 2"Gun Diameter,6 spf 4-1/2", 12.6#, 13Cr80/L-80 8485' 8288'/8164' MD TVD MD TVD 8429'/8283' 10950'-11200' 9026'-9024' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. COh1LzT;r fi DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED II _ 2500' Freeze Protect w/Diesel 1 ikuu 'ae I - 7!A 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc): July 31,2012 Flowing Date of Test. Hours Tested: Production For OIL-BBL' GAS-MCF WATER-BBL' CHOKE SIZE: GAS-OIL RATIO' 8/1/2012 8 Test Period ♦ 223 925 715 75 4159 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR) Press. 270 1550 24-Hour Rate 4 668 2776 2145 N/A 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RRDMS AUG 2 3 2012 , Form 10-407 Revised 12/2009 Y L`= S,/ll113 CONTINUED ON REVERS o1��✓ /� Submit Original Only 29. GEOLOGIC MARKERS(List all formations ar 'rkers encountered). 30 FORMATION TESTS NAME .J TVD Well Tested'' J Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25 071 23SB/Zone 2B 9177' 8884' None 22TS 9242' 8931' 21TS/Zone 2A 9313' 8977' Formation at Total Depth (Name): 21 TS/Zone 2A 9313' 31.List of Attachments. Summary of Daily Drilling Reports,Well Schematic Diagram, Surveys 32. I hereby certify that the for ing is tr - - orrect to the best of my knowledge 8/ I��. Signed Joe Lastufka � Title: Drilling Technologist Date: PBU 07-35A 212-067 Prepared By Name/Number Joe Lastufka, 564-4091 Well Number Permit No./Approval No Drilling Engineer Zach Sayers, 564-5790 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 la: 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 elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13. The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00) Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26 (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25 071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only TREE= CAN SA NOTES: WELL ANGLE>70'@ 9392'. WELLHEAD= FMC 07-35A `"*GLM'S HAVE LOWER PSI RATE THAN NORMAL ACTUATOR= BAKER C ""•CHROME TUBING**" INITIAL KB.ELE, 570' PJC ®RFT BF. ELEV 2790' i I 2074' —j9-5/8"HES CEMENTER KO P= 1998' Max Angle= 96"@ 9842 20"CONDUCTOR, — --110 ' ' 2094' H 4-112"HES X NIP,ID=3,813" Datum MJ= 9137' 91.5#, H-40, Datum TVD= 8800'SS ID=19.12.4" GAS LIFT MANDRELS ST MD -VD DEV TYPE VLV LATCH PORT DATE [9-518"CSG,40#,L-80 BTC, ID=8.835" 1— 3388' ED 1 3725 3710 1 KBG2-IR DOME BK 16 07/28/12 2 6226 6210 0 KBG2-IR SO BK 20 07/28112 3 8095 8004 33 KBG2-IR DMY BK 0 01/15/07 Minimum ID = 2.36" @ 8894' ' ' 8258' --14-1/2"HES XNIP,ID=3.813" 4-112" BKR KB LTP X X 8288' H7"X 4-1/2"BKR S-3 PKR, ID=3.875" 4-1/2"TBG, 12,6#, 13CR-80 VAM TOP, H 8385' j' 8322' —j 4-1/2"HES X NIP,ID=3.813" I 0152 bpf,ID=3.9$8" 8400' —17"X 4-1/2"UNIQUE OVERSHOT TBG STUB(05/24/08) — 8388' S 8429' —74'X 4-1/2"BKR S-3 PKR,ID=3.875" ' ' 8463' -4-1f2"HES XN NIP, MILLED TO 3.80" I (06/14/12) 1 4� 8481' —7"X5"BKRZXPPKR TOP OF 4-1/2"LNR — 8481' w/7.11'TIEBK SLV, ID=4.400" 4-1J2"TBG, 12.6#, L-80, .0152 bpf, [0=3.958" -{ 8485' T 8485' H4-1/2"WLEG,10=3.958" EL MD TT NOT LOGGED 7"CSG,26#, L-80 BTC, ID=6.276" H 8650' 1—• ► 8495' 17"X 5"BKR HMC HGR, ID=4.400" 8501' —15"X 4-112"XO,ID=3.958" 8894' ----14-1/2"BKR KB LTP, ID=2.36"(07/27/12) el " 8905' --{3.70"BKR DEPLOY SLV,ID=3.00" , 8926' J—{3-1/2"HES X NIP,ID=2.813" 3-1/2"LNR,9.3.#,L-80 STL,.0087 bpf, ID=2.992" — 8958' 4-1/2"BKR WHPSTOCK w/PKR(TAGGED07/03112) 9151' , 8958' ---13-1/2"' X 3-3/16"XO,ID=2.786" 4-1/2"LNR,12.6#, L-80 BTC-M, H 9152 .0152 bpf,ID=3.958" MILLOUT WINDOW(07-35A) 9152'-9161' , PERFORATION SUMMARY REF LOG:BHCS ON 11/28/97 ANGLE AT TOP PERF: 89"@ 10950' Note: Refer to Production DB for historical perf date SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10950-11200 0 07/12/12 9699' --13-3/16"X 2-7/8"XO,ID=2.377" 3-1/4"LNR;6,6#,L-80 TC11, .0079 bpf, ID=2.85" H 9599' PBTD --I 11258' 11 2-7/8" LNR,6.5.#,L-80 STL, .0058 bpf, ID=2.441" — 11298' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT • 12108197 D141 ORIGINAL COMPLETION 07/30/12 GJB/JMD GLV C10(07/28/12) WELL: 07-35A 05127108 D16 RWO PERMIT Nb:t120670 07115112 NORDIC 2 CTDSIDETRACK(07-35A) API No: 50-029-22811-01 07/15/12 PJC ORLG HO CORRECTIONS SEC 34,T11 N,R14E, 1802'FNL&676'FWL 07/16/12 , PJC DRLG DRAFT CORRECTIONS + 07/30/12 GJF/JMD SET 4-1/2"KB LTP(07/27/12) BP Exploration(Alaska) North America-ALASKA- BP Page 1 of 10 Operation Summary Report Common Well Name:07-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:6/30/2012 End Date: 7/9/2012 X3-01252-C: (2,012,775.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:NORDIC 2 Spud Date/Time: 11/7/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501'W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/30/2012 18:00 - 22:00 4.00 MOB P PRE BEGIN RON EVENT FOR 07-35A WITH NORDIC 2 CTD RIG AT 18:00 HRS ON 6/30/2012. MOVE OFF OF B-05C AND SPOT RIG ON PAD, CLEAN AREA AROUND WELL AND CLOSE OUT WWT PERMIT WITH PAD OPERATOR. 22:00 - 22:20 0.33 MOB P PRE "PJSM WITH SECURITY PRIOR TO MOVING RIG TO DS7 22:20 - 00:00 1.67 MOB P PRE MOBILIZE RIG TO SPINE ROAD 7/1/2012 00:00 - 02:00 2.00 MOB P PRE MOVE RIG TO DS 7-35-4.7 MILES-ARRIVE _ON LOCATION @ 02:00 02:00 - 08:00 6.00 RIGU P PRE PLACE HERCULITE AND MATS,STAGE ANCILLARY EQUIPMENT.MOVE SATELITTE CAMP TO DS 7. 08:00 - 09:30 1.50 RIGU P PRE PJSM AND LIFT NEW 2 3/8"REEL INTO RIG WHILE WAITING FOR 40 MAN CAMP TO PASS 09:30 - 10:30 1.00 RIGU P PRE PJSM AND MOVE RIG OVER WELL WITH NORDIC SUPT,TOOL PUSHER,AND BP WSL ON SITE RIG ACCEPTED AT 10:30 FIRS -07/01/2012 10:30 - 13:30 3.00 RIGU P PRE ATTEMPT TO TEST TREE CAP-SWAB VALVE LEAKING-CALL OUT GREASE CREW AND SERVICE TREE-RE-TEST TREE CAP TO 250# /3500#-PASSED-REMOVE TREE CAP 13:30 - 18:00 4.50 RIGU P PRE NIPPLE UP BOP STACK-COMMS DROPPING IN/OUT-CALL GCI TO COME AND GET DIALED IN 18:00 - 21:00 3.00 RIGU P PRE PJSM, INSTALL PACK-OFF 21:00 - 00:00 3.00 RIGU P PRE FILL STACK, INSTALL BULKHEAD,PRESSURE TEST NEW 2"MICROMOTION LINE AND BY-PASS LINE, PREP TO PULL COIL OVER THE TOP. PRESSURE WASH REEL TO GET RID OF MUD COVERING IT.CHECK KOOMEY BOTTLES. 7/2/2012 00:00 - 01:30 1.50 BOPSUR P PRE CLEAN COIL OF EXTERNAL MUD FROM TRANSPORT, INSTALL GRAPPLE CONNECTOR. 01:30 - 03:00 1.50 BOPSUR P PRE PJSM,PULL COIL ACCROSS THE TOP TO RIG FLOOR.2 HOUR NOTICE TO AOGCC REP, BOB NOBLE.HE MAY COME FOR TEST. 03:00 - 03:45 0.75 BOPSUR P PRE PJSM FOR BOPE TEST, PERFORM SHELL TEST. 03:45 - 12:00 8.25 BOPSUR P PRE BOPE TEST.STATE INSPECTOR,BOB NOBLE, ON LOCATION AT 0500.ALL COMPONENTS TESTED 250#/3500#-BOTH REMOTE PANELS FUNCTIONED.NO FAILURES- INSTALL COIL CONNECTOR AND BHI HEAD BEFORE TESTING INNER REEL VALVE AND PACK OFF 12:00 - 13:30 1.50 BOPSUR P PRE FLUID PACK COIL WITH 1%KCL Printed 8/6/2012 10:38:09AM North America-ALASKA- BP 2 of 10 Operation Summary Report Common Well Name:07-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:6/30/2012 End Date:7/9/2012 X3-01252-C: (2,012,775.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:00AM Rig Release: Rig Contractor NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501'W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 15:00 1.50 BOPSUR P PRE ATTEMPT TO TEST INNER REEL VALVE- E-LINE BULKHEAD PACKING LEAKING- TIGHTEN PACKING AND TRY AGIAN- LEAKING-PULL AND REPLACE PACKING AND RE-TEST-STILL LEAKING-PULL PACKING AND REMOVE AND REPLACE BULKHEAD AND PACKING 15:00 - 17:45 2.75 BOPSUR N SFAL PRE CONTINUE TO WORK ON BULKHEAD,START NPT AT 1500. 17:45 - 19:00 1.25 BOPSUR N SFAL PRE NEW BULKHEAD INSTALLED-WAITING FOR SEALANT ON E-LINE TO CURE 19:00 - 00:00 5.00 BOPSUR N SFAL PRE PRESSURE TEST AGAIN WITH LEAK IN UPPER SEAL OF THE BULKHEAD.SLB TECHNICAL ADVISOR ON LOCATION TO HELP WITH REBUILD AND TESTING.AFTER MULTIPLE ATTEMPTS AT TIGHTENING PACKING AND'REDRESSING,FOUND WIRE ON LOWER SEAL OF THE BULKHEAD WAS DAMAGED CREATING A FLOWPATH FOR WATER TO LEAK OUT FROM UPPER SEAL. 7/3/2012 00:00 - 02:00 2.00 BOPSUR N SFAL PRE CONTINUE WORKING ON BULKHEAD AFTER FINDING DAMAGED E-LINE,THE OUTER ARMORS WERE FLARED. REMOVE 2'PIPE INSERT TO PLACE DAMAGED SECTION OF E-LINE ABOVE THE BULKHEAD. INSTALL BULKEAD PACKING AND RETEST TO 250 LOW AND 4000 PSI HIGH. 02:00 - 02:30 0.50 BOPSUR P • PRE FINISH TESTING BOPE COMPONENTS WITH PACK-OFF AND INNER REEL VALVE TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN,GOOD TEST. 02:30 - 04:15 1.75 BOPSUR P PRE INSTALL BAKER CHECKS AND TEST TO - _ 250/3500 PSI. 04:15 - 04:45 0.50 BOPSUR P PRE RIG EVAC DRILL WITH AAR.ALL CREW MEMBERS AND THIRD PARTY PEOPLE MUSTERED IN A TIMELY MANNER.DRILLER NOTIFIED CREW MEMBERS WORKING IN A NOISEY AREA OF THE EVACUATION SINCE THEY COULDN'T HEAR THE ALARM. 04:45 - 06:00 1.25 BOPSUR P PRE PJSM WITH VALVE CREW TO PULL TWC. LOAD,MU AND PRESSURE TEST LUBRICATOR TO 250/3500 PSI. 06:00 - 07:30 1.50 BOPSUR P PRE PULL TWC-STACK FULL OF FLUID AND WELL IS ON A VERY SLIGHT VACUUM-RD AND LOAD OUT LUBRICATOR 07:30 - 08:30 1.00 BOPSUR P PRE PT NIGHT CAP 08:30 - 09:30 1.00 BOPSUR P PRE RIG EVACUATION DRILL W/AAR-ALL PERSONNEL RESPONDED, INCLUDED VAC TRUCK DRIVERS-ALARMS WERE CLEARLYY HEARD BY ALL-COMMUNICATE ADDITIONAL INFORMATION FROM TOWN PRE-SPUD WITH CREWS 09:30 - 10:00 0.50 STWHIP P WEXIT MONITOR WELL PRIOR TO PU BHA-NO FLOW 10:00 - 11:30 1.50 STWHIP P WEXIT PU MILLING BHA#1 11:30 - 12:30 1.00 STWHIP P WEXIT RIH PUMPING MINIMUM RATE,0.4 BPM X 140 PSI,TO EDC DEPTH OF 4200'-BIT AT 4320'- RETURNS TO TIGER TANK EQUAL 5BBL/ 1000'AS EXPECTED Printed 8/6/2012 10.38:09AM North America -ALASKA- BP ;; Page 3 of 10 Operation Summary Report Common Well Name:07-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:6/30/2012 End Date: 7/9/2012 X3-01252-C: (2,012,775.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501"W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 13:00 0.50 STWHIP P WEXIT OPEN EDC AND DISPLACE FREEZE PROTECT AT 2.6 BPM X 1950#TAKING RETURNS TO THE TIGER TANK -FINAL OUT DENSITY=8.3 PPG TAKE 60 BBLS SLIGHTLY GAS CUT MUD TO TIGER TANK. 13:00 - 14:00 1.00 STWHIP P WEXIT CONTINUE TO RUN IN HOLE. 14:00 - 15:00 1.00 STWHIP P WEXIT LOG GR TIE IN FROM 8750'. SUBTRACT 4' CORRECTION TO PDC LOG. 15:00 - 16:00 1.00 STWHIP P WEXIT RUN IN HOLE. TAG WHIPSTOCK AT 9152'. PLANNED TAG WAS 9130' CALL TOWN TO DISCUSS REVISION TO DIRECTIONAL PLAN. CONTINUE TO DISPLACE WELL TO FLO VIS MUD. 16:00 - 17:30 1.50 STWHIP P WEXIT WAIT ON DIRECTIONAL PLAN REVISION FROM TOWN. DETERMINE PLAN WILL REQUIRE 3 DEG/100 WHICH IS NOT VERY DIFFERENT FROM THE ORIGINAL PLAN OF 29 DEG/100'. GET VERBAL APPROVAL TO PROCEED. 17:30 - 17:45 0.25 STWHIP P WEXIT RECORD SLOW PUMP RATES. RUN IN HOLE TO WHIPSTOCK. 17:45 - 21:00 3.25 STWHIP P WEXIT TAG WHIPSTOCK AT 9152' 2842 PSI FS AT 2.54 BPM IN/OUT. DHWOB: 0.2-0.4K# TIME MILL AT 1'/HR TO 9154.8' 21:00 - 23:00 2.00 STWHIP P WEXIT CONTINUE MILLING WINDOW AT 9154.8'.to 9156.6'PUMPING 2.52 BPM IN/OUT,DHWOB: 1.5-2.5K#,20-200 PSI MOTOR WORK. 23:00 - 00:00 1.00 STWHIP P WEXIT TIME MILL WINDOW AT 1'/HR PUMPING 2.49 BPM IN/OUT AT 2770 PSI. 7/4/2012 00:00 - 02:30 2.50 STWHIP P WEXIT TIME MILL WINDOW FROM 9158 TO 9161 AT 1'HR,PUMPNIG 2.51 BPM IN/OUT OF 8.7 PPG POWERVIS.DHWOB: 1.2-2.6K#.SAMPLE AT 9158'SHOWED 40%FORMATION. 02:30 - 03:30 1.00 STWHIP P WEXIT OUT OF LINER AT 9161'WITH SIGNS OF MILLING OFF OF BOTTOM,TIME MILL 1ST FOOT OF FORMATION FROM 9161'TO 9162' AT 1'/HR. 03:30 - 06:00 2.50 STWHIP P WEXIT MILL REST OF RATHOLE FROM 9162'TO 9171' PUMPING 2.54 BPM IN/OUT AT 2880 PSI,150 PSI MW,DHWOB:2.5-3.0K#. 06:00 - 07:30 1.50 STWHIP P WEXIT DRESS WINDOW. MAKE THREE UP AND DOWN PASSES. 2629 PSI FS AT 2.56 BPM IN/OUT. DRY DRIFT. WINDOW SMOOTH. 07:30 - 09:45 2.25 STWHIP P WEXIT OPEN EDC. CIRCULATE OUT OF HOLE. DEBRIS CLOGGING MICRO MOTION OUT. BLOW DOWN SAME. CONTINUE TO CIRCULATE TO SURFACE. HOLD PJSM NEAR SURFACE. 09:45 - 10:30 0.75 STWHIP P WEXIT FLOW CHECK. GET OFF WELL. UNSTAB COIL. LAY DOWN BHA. MILL GAUGES BOTH 3.79"GO,3 78"NO-GO. Printed 8/6/2012 10:38:09AM North America-ALASKA- BP Page 4 of 10 Operation Summary Report Common Well Name: 07-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 6/30/2012 End Date: 7/9/2012 X3-01252-C: (2,012,775.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501'W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 11:30 1.00 DRILL P PROD1 MU DRILLING BUILD BHA. RUN HYC BICENTER(3.75"X 4.25")WITH ZONE 2/3 ROP BUTTONS. RUN A 3.1 AKO X-TREME MTR. STAB COIL. TEST TOOLS. GET ON WELL. PT QTS SUB TO 300 AND 3500 PSI. PASSED. _ 11:30 - 12:30 1.00 DRILL P PROD1 -RUN IN HOLE. HOLD UN-ANNOUNCED PIT GAIN DRILL. STOP COIL AND MONITOR WELL. HOLD AAR TO REVIEW CREW RESPONSE. CONTINUE TO RUN IN HOLE. 12:30 - 13:00 0.50 DRILL P PROD1 LOG GR TIE IN FROM 8450'. SUBTRACT 6'CORRECTION. 13:00 - 13:30 0.50 DRILL P PROD1 RUN IN HOLE. RECORD SLOW PUMP RATES. #1 0.5 BPM/1117 PSI 1.0 BPM/1384 PSI 2.5 BPM /2710 PSI #2 0.5 BPM/1121 PSI 1.0 BPM/1406 PSI 2.5 BPM/2703 PSI RUN THROUGH WINDOW. SMOOTH. 13:30 - 14:30 1.00 DRILL P PROD1 DRILL AHEAD FROM 9171' 2922 PSI FS AT 2.65 BPM IN/OUT. DRILL AND SURVEY FREQUENTLY TO MONOTIR DOGLEG AND PROJECTED INC. 14:30 - 15:00 0.50 DRILL P PROD1 SHORT WIPER TO WINDOW. CONTINUE TO GET"EXTRA"SURVEYS TO MONITOR BUID AND TO DETERMINE IF WHIPSTOCK ORIENTATION IS CORRECT. 15:00 - 18:30 3.50 DRILL P PROD1 DRILL AHEAD FROM 9250' VARY PUMP RATE TO ATTEMPT TO REDUCE BHA VIBRATION. 10-15%CHERT NOTED IN SAMPLES. DOGLEGS MEASURED ARE ADEQUATE TO CONTINUE BUILD/TURN SECTION. 2950 PSI FS AT 2.53 BPM IN/OUT. 200-300 PSI MTR WORK. 2-3K#DHWOB. IA/OA/PVT:420 PSI/143 PSI/397 BBLS. BHP/ECD/TVD:4557 PSI/9.85 PPG/8913' CONTINUE TO DRILL AHEAD TO 9400' 18:30 - 19:20 0.83 DRILL P PROD1 WIPER TRIP TO ABOVE THE WINDOW,ONCE ABOVE THE WINDOW OPEN EDC AND INCREASE PUMP RATE TO 3.4 BPM AND 3200 PSI TO CLEAN HOLE.PULL UP TO 8700'TO LOG SAG RIVER FOR TIE-IN. '19:20 - 21:30 2.17 DRILL P PROD1 RIH TO 8900'TO START PRIMARY DEPTH CONTROL LOG.LOG FROM 8900'TO RA TAG IN WHIPSTOCK AT 9159.5'AT 150'/HR.TOP OF WINDOW AT 9152', BOTTOM OF WINDOW AT 9160'. 21:30 - 21:50 0.33 DRILL P PROD1 OBTAIN SPRS AT 9350': #1 0.5 BPM/1145 PSI 1.0 BPM/1405 PSI 2.5 BPM /2740 PSI #2 0.5 BPM/1150 PSI 1.0 BPM/1439 PSI 2.5 BPM/2749 PSI RIG AND TAG 9400' 21:50 - 22:15 0.42 DRILL P PROD1 DRILL AHEAD FROM 9400'WITH FS=2790 PSI PUMPING 2.5 BPM IN/OUT,300 PSI MOTOR WORK,DHWOB=2.2-2.5K#.COLLECT SURVEY AT 9424'. Printed 8/6/2012 10.38:09AM North America -ALASKA- BP Page 5 of 10 Operation Summary Report Common Well Name:07-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) I Start Date:6/30/2012 End Date:7/9/2012 X3-01252-C: (2,012,775.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°3410.501"W Active Datum: Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date I From-To I Hrs Task I Code r NPT NPT Depth !, Phase j Description of Operations (hr) (ft) 22:15 - 22:30 0.25 DRILL P PROD1 KICK WHILE DRILLING DRILL W/AAR,ALL HANDS RESPONDED PROPERLY TO FAILED ACCUMULATOR PRESSURE BUILD(VALVE HANDLES IN NEUTRAL). 22:30 - 00:00 1.50 DRILL P PROD1 CONTINUE DRILLING BUILD PUMPING 2.5 BPM IN/OUT,300 PSI MOTOR WORK, DHWOB=2.2-2.5K#. LAND THE WELL AT 9475'.TAKE FINAL BUILD SURVEY. 7/5/2012 - DRILL P PROD1 WIPER TRIP AT 10100'UP PAST WINDOW, OPEN EDC AND CIRCULATE,TIE-IN WITH(+2)' CORRECTION.RIH TO 9950'AT 30 FPM PUMPING 2.5 BPM. DRILL P PROD1 DRILL AHEAD FROM 9950 TO 10100' ,00:00 - 02:30 2.50 DRILL P PROD1 POH AT 30 FPM IN OPEN HOLE. FLOW CHECK ABOVE WINDOW,GOOD. POH AT 90 FPM IN CASED HOLE. PJSM FOR LAYING DOWN BHA. FLOW CHECK WITH BHA BELOW BOP FOR 5 MIN,NO FLOW. 02:30 - 03:20 0.83 DRILL P PROD1 GET OFF THE WELL,ATTEMPT TO BLOWDOWN BHA,BHA PULLING HEAVY THROUGH THE STACK DUE TO 3.1 DEG AKO OF MOTOR. LAYDOWN BUILD BHA. 03:20 - 03:45 0.42 DRILL P PROD1 MU LATERAL BHA WITH COILTRACK, HOT, 2-7/8"ULTRA LS MOTOR WITH 1.2 DEG AKO, AND 4.125"HCC BI-CENTER BIT. BHA LENGTH =80.44'. 03:45 - 04:15 0.50 DRILL P PROD1 GET ON THE WELL, PRESSURE TEST QTS TO 250/3500 PSI. 04:15 - 06:00 1.75 DRILL P PROD1 RIH WITH LATERAL BHA 06:00 - 06:30 0.50 DRILL P PROD1 CREW CHANGE. DISCUSS OPERATIONS AND RIG STATUS. MAKE RIG CHECKS AND ROUNDS. iCONTINUE TO RIH. 06:30 - 07:00 0.50 DRILL P PROD1 ;LOG GR TIE IN. 07:00 - 08:00 1.00 DRILL P PROD1 RUN IN TO OPEN HOLE. WINDOW SMOOTH. PERFORM CHECK SHOT SURVEYS TO "COMPARE"DIRECTIONAL TOOLS. RESULTS SHOW SOME UNEXPECTED MAGNETIC DEVIATION. CALL INTEQ IN TOWN TO REVIEW DATA. CIRCULATE OFF BTM WHILE MOVING COIL. RECORD SPR DATA:#1:0.5/1.0 BPM 1121/1414 PSI #2:0.5/1.0 BPM 1134/1436 PSI DECIDE TO DRILL AHEAD 100'. 08:00 - 10:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 9475'. 2910 PSI FS AT 2.54 BPM IN/OUT. 200-300 PSI MTR WORK. DHWOB:2.0-2.5 K# IA/OA/PVT:549 PSI/208 PSI/387 BBLS. DRILL TO 9650'. 10:00 - 12:00 2.00 DRILL P PROD1 LOG MAD PASS FROM TD TO WINDOW. RECORD RESTIVITY DATA. HOLE SMOOTH. PVT:385 BBLS CALL FOR TRUCKS AND NEW MUD SYSTEM !TO BE DELIVERED TO RIG. 12:00 - 15:00 3.00 DRILL P PROD1 DRILL AHEAD FROM 9650'. 12910 PSI FS AT 2.48 BPM IN/OUT. 2.7 K# DHWOB. DRILL TO 9800'. Printed 8/6/2012 10:38:09AM North America -ALASKA- BP Page 6 of 10 Operation Summary Report Common Well Name:07-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/30/2012 End Date: 7/9/2012 X3-01252-C: (2,012,775.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:OOAM Rig Release: Rig Contractor NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501W Active Datum:Kelly Bushing/Rotary Table©57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 16:00 1.00 DRILL P PROD1 WIPER TRIP TO WINDOW. 2850 PSI AT 2.49 BPM. HOLE SMOOTH. _ 16:00 - 18:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 9800'. 2850 PSI FS AT 2.48 BPM IN/OUT. 200-300 PSI MTR WORK. 3.5K#DHWOB. PVT:VARIABLE DUE TO PREP FOR MUD SWAP. PREP PITS FOR MUD CHANGE. BEGIN MUD SWAP. 18:00 - 19:15 1.25 DRILL P PROD1 NEW MUD ALL THE WAY AROUND,OBTAIN SPRS WITH NEW SYSTEM. #1 0.5 BPM/1040 PSI 1.0 BPM/1340 PSI 2.5 BPM /2640 PSI #2 0.5 BPM/1030 PSI 1.0 BPM/1311 PSI 2.5 BPM/2633 PSI DRILL AHEAD FROM 9900'TO 9950'WITH 2.49 PSI IN/OUT AND 2.5-4.0 K#WOB 19:15 - 20:30 1.25 DRILL P PROD1 WIPER TRIP AT 9950'TO ABOVE WINDOW, TIE-IN TO RA TAG WITH(+2)'CORRECTION. RIH TO 9950'AT 30 FPM PUMPING 2.5 BPM. _ 20:30 - 23:00 2.50 DRILL P PROD1 DRILL FROM 9950'TO 10,100'AT 2.5 BPM IN/OUT AND 3100 PSI.DHWOB=2.3-4.9K#, ROP-60 FPH. 23:00 - 00:00 1.00 DRILL P PROD1 SHORT WIPER TRIP TO ABOVE WINDOW AND THEN RIH TO DRILLING DEPTH OF 10,100'._ 7/6/2012 00:00 - 03:15 3.25 DRILL P PROD1 BACK ON BOTTOM AT 10,100'DRILLING AHEAD AT 2.50 BPM I WOUT,3220 PSI CIRC PRESSURE.4.5K#DHWOB.DRILL TO 10,250'. -. , ROP-50 FPH.SAMPLE AT 10,000 HAD HOT. 03:15 - 04:45 1.50 DRILL P PROD1 WIPER TRIP TO BELOW WINDOW AT 9180'AT 30 FPM. 04:45 - 06:00 1.25 DRILL P PROD1 DRILLING AHEAD FROM 10,250'PUMPING 2.5 BPM IN/OUT,3500 PSI,DHWOB 4.5K#,70-80 FPM. 06:00 - 06:30 0.50 DRILL P PROD1 CREW CHANGE. DISCUSS OPERATIONS AND EQUIPMENT STATUS. MAKE CHECKS AND ROUNDS REVIEW PERMITTING NEEDS FOR PLANNED TOUR WORK. CONTINUE TO DRILL AHEAD. 06:30 - 10:00 3.50 DRILL P PROD1 DRILL AHEAD FROM 10,339'. 2923 PSI FS AT 2.54 BPM IN/OUT. IA/OA/PVT:239 PSI/215 PSI/414 BBLS. BHP/ECD/TVD:4652 PSI/9.86 PPG/8924' SLOW DRILLING THRU A SILTSONE INTERVAL FROM+/-10,340 TO 10352'. DRILL AHEAD TO 10,400'. _ 10:00 - 11:45 1.75 DRILL P PROD1 WIPER TRIP TO WINDOW. 3150 PSI AT 2.67 IN/OUT. PVT:407 BBLS. HOLE SMOOTH. 11:45 - 14:00 2.25 DRILL P PROD1 DRILL AHEAD FROM 10,400'. 3150 PSI FS AT 2.68 BPM IN/OUT, 200-300 PSI MTR WORK. DHWOB: 3.53 K#. MW:8.7 PPG IN/OUT. PVT:407 BBLS. DRILL TO 10,550'. Printed 8/6/2012 10:38:09AM North America -ALASKA- BP Page 7 of 10 Operation Summary Report Common Well Name:07-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:6/30/2012 End Date: 7/9/2012 X3-01252-C: (2,012,775.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:OOAM Rig Release: Rig Contractor NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501'W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 16:30 2.50 DRILL P PROD1 WIPER TRIP TO WINDOW. PVT:398 BBLS. HOLE SMOOTH. 16:30 - 19:00 2.50 DRILL P PROD1 DRILL AHEAD FROM 10550'TO 10,600'. 3210 PSI FS AT 2.74 BPM IN/OUT. 19:00 - 20:00 1.00 DRILL P PROD1 DRILL AHEAD TO 10,620 WITH HARD 'INTERVALS THAT TAKE SEVERAL MINUTES TO GET THROUGH. 20:00 - 20:15 0.25 DRILL P PROD1 OVERPULL TO 50K TO COME FREE AT 10638'. SHORT WIPER TO CLEAR BHA INTERVAL. 20:15 - 21:30 1.25 DRILL P PROD1 DRILL AHEAD FROM 10,638'TO 10,700' PUMPING 2.58 BPM IN/OUT WITH MW OF 8.7 PPG AT 3350 PSI WITH 2.5-4.7 WOB. 21:30 - 23:15 1.75 DRILL P PROD1 WIPER TRIP TO BELOW WINDOW AT 9180' PUMPING 2.49 BPM IN/OUT.RIH BACK TO 10,700'. 23:15 - 00:00 0.75 DRILL P PROD1 DRILL AHEAD FROM 10,700'TO 10,725'. 2.68 BPM IN/OUT,3200 PSI. WOB 1.8-3.0 K#,ECD 9.86 PPG. 7/7/2012 00:00 - 02:00 2.00 DRILL -P PROD1 DRILL AHEAD FROM 10,725'TO 10,800'AT 30-40 FPH. -2.64 BPM IN/OUT,2.5K#WOB,3270 PSI. 02:00 - 03:00 1.00 DRILL P PROD1 DRILL AHEAD FROM 10,800',2.75 BPM IN/OUT, 3130 PSI,9.86 ECD. HARD INTERVALS AT 10,803',AND 10,817' THAT REQUIRED SEVERAL MINUTES TO GET THROUGH. 03:00 - 05:00 2.00 DRILL P PROD1 ROP-14 FPH,WIPER TRIP AND LOOK AT NEXT SAMPLE TO SEE IF FORMATION CHANGE IS CAUSING OUR SLOW ROP. SAMPLE SHOWS 15-20%CHERT.TIE-IN AT RA TAG WITH(+5)'CORRECTION 05:00 - 06:00 1.00 DRILL P PROD1 BACK TO DRILLING AT 10,815'WITH 2.54 BPM IN/OUT,3200 PSI,4.75K#DHWOB,9.86 ECD. _ 06:00 - 06:30 0.50 DRILL P PROD1 CREW CHANGE. DISCUSS CURRENT OPERATIONS AND EQUIPMENT STATUS. MAKE RIG CHECKS AND ROUNDS. CONTINUE TO DRILL AHEAD._ 06:30 - 10:15 3.75 DRILL P PROD1 DRILL AHEAD. 3350 PSI FS AT 2.73 BPM IN/OUT. 200-300 PSI MTR WORK. DHWOB:2 49k#. IA/OA/PVT. 582 PSI /421 PSI/VARIABLE DUE TO MUD SWAP. BHP/ECD/TVD:4785 PSI/9.86 PPG/8968'. BEGIN MUD SWAP. DRILL TO 10,950'. 10:15 - 12:00 1.75 DRILL P PROD1 WIPER TRIP TO WINDOW. HOLE SMOOTH. CONTINUE MUD SWAP. MONITOR FLUIDS FROM ONE PIT. 12:00 - 14:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 10,950'. 3050 PSI FS AT 2.68 BPM IN/OUT. 250 PSI MTR WORK. DHWOB:4.51K# DRILL TO 11,039'. UNABLE TO GET GOOD SURVEYS. DGS DATA INDICATES TOOL VIBRATION,EVEN WITH PIPE STOPPED AND PUMPS OFF. Printed 8/6/2012 10:38:09AM North America -ALASKA- BP Page 8 of 10 Operation Summary Report Common Well Name:07-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:6/30/2012 End Date: 7/9/2012 X3-01252-C: (2,012,775.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501'W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 16:45 2.75 DRILL P PROD1 PJSM. WIPER TRIP OUT OF HOLE. 3365 PSI AT 2.66 BPM. DGS SURVEY TOOL BEGAN WORKING CORRECTLY. CONTINUE WIPER. TIGHT SPOT AT 10,545'. GET THROUGH BY REDUCING PUMP TO ZERO RATE. SURVEY TOOL WORKING OK ON BTM. 16:45 - 18:20 1.58 DRILL P PROD1 DRILL AHEAD FROM 11,039'. 3300 PSI FS AT 2.72 BPM IN/OUT. DRILL TO 11,100'. 18:20 - 21:30 3.17 DRILL P PROD1 OBTAIN SPRS: #1 0.5 BPM i1530 PSI 1.0 BPM/1880 PSI 2.5 BPM /3245 PSI #2 0.5 BPM/1507 PSI 1.0 BPM/1849 PSI 2.5 BPM/3230 PSI CONTINUE DRILLING AHEAD AT 11,100'. 2.62 BPM IN/OUT,3650 PSI,4.0K#WOB HARD SPOT AT 11,160'WITH NO PROGRESS • IN 45 MIN 21:30 - 00:00 2.50 DRILL P PROD1 WIPER TRIP TO WINDOW 9190'.PUMPING 2.4 BPM AT 30 FPM. 7/8/2012 00:00 - 01:00 1.00 DRILL PROD1 ATTEMPT TO DRILL AHEAD AT 11,160'WITH NO FORWARD PROGRESS.VARY PUMP RATES:2.7,2.5 AND 2.0 BPM WITH NO CHANGE.NO MOTOR WORK. 01:00 - 04:20 3.33 DRILL PROD1 POH FOR BIT CHECK.ONCE ABOVE THE WINDOW FLOW CHECK WELL FOR 5 MIN, OPEN THE EDC AND CIRC AT 3.25 BPM 3340 PSI. 04:20 - 04:30 0.17 DRILL PROD1 PJSM FOR LAYING DOWN BHA.FLOW CHECK AT SURFACE,NO FLOW. 04:30 - 06:00 1.50 DRILL PROD1 INSPECT COIL,LAYDOWN BHA,BIT SHOW SIGNIFICANT WEAR AND WAS RATED A 6.1 AND CORRED OUT. COIL INSPECTION REVEALS A FLAT SPOT, OUT OF TOLERANCE. 06:00 - 06:30 0.50 DRILL PROD1 CREW CHANGE. DISCUSS OPERATIONS AND RIG EQUIPMENT STATUS. MAKE RIG CHECKS AND ROUNDS. CONTINUE BHA CHANGEOUT. 06:30 - 07:30 1.00 BOPSUR PROD1 PERFORM WEEKLY BOP FUNCTION TEST. TEST COMPONENTS FROM RIG FLOOR AND OPS CAB STATIONS. NO FAILURES. 07:30 - 11:00 3.50 DRILL P PROD1 PJSM.REVIEW COIL CUTTING AND HANDLING PROCEDURE. RU HYDRAULIC CUTTER. CUT 100'OF COIL AND E-LINE. MU KENDAL CONNECTOR. PULL AND PT SAME. CHECK E-LINE AND RE-HEAD E-COIL. CHANGE PACKOFFS. INSTALL DFCV. PT PACKOFFS AND DFCV TO 300 AND 3500 PSI FOR 5 MIN.CHART SAME. PASSED. Printed 8/6/2012 10.38:09AM North America -ALASKA- BP Page 9 of 10 Operation Summary Report Common Well Name:07-35 AFE No Event Type. RE-ENTER-ONSHORE(RON) Start Date:6/30/2012 End Date: 7/9/2012 X3-01252-C: (2,012,775.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501'W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 12:30 1.50 DRILL P PROD1 MU LATERAL DRILLING BHA.WITH HYC 4.125" BICENTER AND 1.2 AKO MOTOR. STAB COIL. TEST TOOLS. GET ON WELL. PT QTS SUB TO 300 AND 3500 PSL CHART. PASSED 12:30 - 15:00 2.50 DRILL P PROD1 RUN IN HOLE. CIRC AT MIN RATE WITH EDC CLOSED. 15:00 - 15:30 0.50 DRILL P PROD1 LOG GR TIE IN FROM 8700'. SUBTRACT 7' CORRECTION. RUN IN HOLE. SLIGHT BOBBLE THROUGH WINDOW. 15:30 - 16:30 1.00 DRILL P PROD1 WIPER TO TD. MAINTAIN AS DRILLED TF. 3240 PSI AT 2.45 BPM. SET DN AT 10560'. PU. PASS THROUGH OK ON THIRD ATTEMP WITH NO PUMP RATE. CONTINUE TO WIPER IN HOLE. RECORD SLOW PUMP RATES AT 11020'. 16:30 - 18:00 1.50 DRILL P PROD1 DRILL AHEAD FROM 11,157'. 3210 PSI FS-AT 2.55 BPM IN/OUT.200-300 PSI MTR WORK. 2-3K#DHWOB. IA/OA PVT:73 PSI/17 PSI/337 BBLS. MW IN/OUT:8.71 PPG. .BHP/ECD/TVD:4965 PSI/9.86 PPG/8968'. DRILL TO 11,181'. 18:00 - 18:30 0.50 DRILL P PROD1 CREW CHANGE,MAKE RIG CHECKS AND ROUNDS.CONTINUE TO DRILL AHEAD FROM 11,181'. 18:30 - 21:30 3.00 DRILL P - PROD1 DRILL AHEAD FROM 11,181'TO 11,260' PUMPING 2.5 BPM AT 3700 PSI,3.15-4.8K# DHWOB.ROP VARIABLE FROM 20-40 FPM WITH A FEW STALLS. 21:30 - 22:30 1.00 DRILL P PROD1 SLOW DRILLING FROM 11,260 TO 11,268',2.5 BPM IN/OUT,3800 PSI,4.5K#WOB. 22:30 - 00:00 1.50 DRILL P PROD1 DRILL AHEAD FROM 11,268'WITH HIGHER ROP TO 11,282'. PUMPING 2.65 IN/OUT WITH 3.5K#WOB. 7/9/2012 '00:00 - 01:25 1.42 DRILL P PROD1 DRILL AHEAD TO 11,300'AT 2.4 BPM AND 3800 PSI,3.5-4.5K#WOB. 01:25 - 05:00 3.58 DRILL P PROD1 WIPER TRIP TO WINDOW. SLOW PUMP DOWN TO 1.9 BPM TO COME THROUGH THE SHALE SECTION AT 10,700 TO 10,530',WITH OVERPULL AND 100-200 PSI MOTOR WORK AT 10,570',OVERPULLS AT THE WINDOW WITH CIRC PRESSURE INCREASING.RIH TO PREVENT PACKING OFF.PULL UP TO WINDOW AND TIE-IN AT RA TAG WITH(+3.5)'CORRECTION.RIH. MICRO-MOTION PLUGGED OFF WITH SHALE FRAGMENTS WITH AT 10,950'.SLOW RIH RATE AND FLUSH MICRO-MOTION. 05:00 - 06:00 1.00 DRILL P PROD1 CIRCULATE AT 2.5 BPM AND 3800 PSI WHILE POH AT 10 FPM WHILE MIXING A HI-VIS PILL FOR HOLE CLEANING. 06:00 - 06:15 0.25 DRILL P PROD1 CREW CHANGE. REVIEW CURRENT OPERATIONS AND RIG EQUIPMENT STATUS. MAKE ALL CHECKS AND ROUNDS. CONTINUE WIPER TRIP TO WINDOW. CHASE HI-VIS SWEEP. 3900 PSI FS AT 2.72 BPM IN. Printed 8/6/2012 10:38:09AM North America-ALASKA- BP Page 10 of 10 Operation Summary Report Common Well Name:07-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) I Start Date:6/30/2012 End Date: 7/9/2012 'X3-01252-C: (2,012,775.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 10148°34'10.501"W Active Datum: Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:15 - 10:30 4.25 DRILL P PROD1 CONTINUE WIPER TRIP TO WINDOW. SEVERAL STALLS IN 10545'TO 10575' INTERVAL. MOTOR WORK AND OVERPULLS, BUT ABLE TO PULL CONTINUOUSLY THROUGH TIGHT SPOTS. MUD PROPERTIES APPARENTLY DETERIORATING. 3900 PSI FS AT 2.71 BPM IN. WIPER TRIP TO 8150'. OPEN EDC ABOVE WINDOW. 3705 PSI AT 3.05 BPM IN/OUT. MM OUT FREQUENTLY PLUGGING OFF. CIRCULATE BTMS UP FROM 9106'. 10:30 - 12:30 2.00 DRILL P PROD1 CONTINUE TO CIRCULATE ABOVE WINDOW TO CLEAN UP TUBING. WAIT ON MUD DELIVERY VAC TRUCKS. 12:30 - 13:00 0.50 DRILL P PROD1 CLOSE EDC.RIH. LOG GR TIE IN ACROSS RA TAG. ADD 3.5' CORRECTION. 13:00 - 14:30 1.50 DRILL P PROD1 CONTNIUE TO CIRCULATE IN HOLE. :3688 PSI AT 2.48 BPM IN. 1 HOLE PJSM FOR MUD DISPLACEMENT. MOTOR WORK AT 10,560-570'. GET THROUGH CIRCULATING AT MIN RATE. MOTOR WORK AT 10,587'. COME OFF PUMP. RUN THROUGH OK. CONTINUE WIPER TO BTM. MOTOR WORK AT 10,806', 10,889', CIRC PRESSURE DROPPED TO 2882 PSI AT 2.55 BPM IN PART DUE TO U-TUBING. TAG TD AT 11,298'. 14:30 - 18:15 3.75 DRILL P PROD1 CIRCULATE OUT OF HOLE. 13153 PSI AT 2.75 BPM IN COIL AND ANNULUS._ 18:15 - 20:00 1.75 DRILL P PROD1 1 PJSM AND FLOW CHECK WELL. NO FLOW. GET OFF WELL,LD LATERAL BHA#4.BIT RATED A 4.2.FLUSH MICRO-MOTION. DAYS PER 10K FROM WINDOW MILLING SPUD TO LD DRLG BHA=28.38 DAYS "END RON EVENT,CONTINUE TO RON EVENT 7-35 ON 7/9/12** Printed 8/6/2012 10:38:08AM North America -ALASKA- BP Page 1 of 7 Operation Summary Report Common Well Name: 07-35 AFE No Event Type: COM-ONSHORE(CON) Start Date:7/9/2012 End Date: 7/13/2012 X3-01252-C: (1,449,151.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:00AM Rig Release: Rig Contractor NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501"W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/9/2012 20:00 - 20:30 0.50 CASING P RUNPRD **CONTINUE FROM 07-35 RON EVENT 7/10/12** BEGIN CON EVENT AT 20:00 ON 7/9/2012 PUMP SLACK FORWARD, RECOVER 304'OF E-LINE PUMPING 3.65 BPM FOR 12.5 BBLS -TOTAL. 20:30 - 21:35 1.08 CASING P RUNPRD BOOT E-LINE AND INSTALL BTT CONNECTOR. PULL TEST SAME TO 35K,PRESSURE TEST TO LOW 250 AND HIGH 4000 PSI. 21:35 - 23:00 1.42 CASING P RUNPRD GET ON WELL,PT QTS TO 250/3500 PSI. LAUNCH 3/4"BALL IN 10 BBLS OF WATER. PUMP THROUGH COIL TO CATCHER. BALL IN CATCHER AT 47 BBLS PUMPED. RECOVERED BALL. 23:00 - 00:00 1.00 CASING P RUNPRD STAND BACK INJECTOR,RIG UP FLOOR TO RUN LINER. 7/10/2012 00:00 - 01:00 1.00 CASING P RUNPRD CONTINUE TO RIG UP FLOOR FOR RUNNING LINER,GET TONGS READY, RIG UP CIRULATING HOSE. 01:00 - 01:20 0.33 CASING P RUNPRD PJSM FOR RUNNING LINER WITH BTT, .NORDIC CREW,TP,WSL,SLB. 01:20 - 06:30 5.17 CASING P RUNPRD RUN 2-7/8"(54 JTS)X 3-1/4"(21 JTS)LINER WITH SELRT EQUIPMENT.MU 2-7/8"LINER TO 800#TORQUE,DRIFT FIRST 5 CONNECTIONS. FILL LINER EVERY 1000'BY STABBING SAFETY JOINT AND PUMPNG WATER THROUGH A 1"HOSE.PERFORM KICK WHILE TRIPPING DRILL WHEN FILLING LINER. 06:30 - 07:00 0.50 CASING P RUNPRD CREW CHANGE. DISCUSS CURRENT OPS AND RIG STATUS. MAKE INSIDE AND OUTSIDE ROUNDS. DISCUSS STATUS OF RUNNING LINER. 07:00 - 09:30 2.50 CASING P RUNPRD CONTINUE TO MU LINER. FILL LINER. MU BTT RUNNING TOOL. STAB COIL. GET ON WELL. TEST QTS TO 300 AND 3500 PSI. CHART. PASSED. 09:30 - 18:30 9.00 CASING N HMAN 11,298.00 RUNPRD NORDIC HAND FELL THROUGH OPEN PIT GRATING. SUSPEND WELL OPERATIONS TO TEND TO NORIDC HAND AND GATHER INFORMATION REGARDING THE INCIDENT. 18:30 - 22:15 3.75 CASING P RUNPRD RUN IN HOLE WITH 3-1/4"X 2-7/8"SOLID PRODUCTION LINER ON 2-3/8"COILED TUBING FROM LINER BHA TOTAL LENGTH AT 2533'MD TO PLANNED SETTING DEPTH AT 11298'MD;0.3 BPM,1500 PSI,30-60 FPM. DEPTH CORRECTED TO 11298'MD FROM ACTUAL TAG DEPTH OF 11304'MD. MINOR TIGHT SPOT AT 10628'MD REQUIRED TWO ATTEMPTS TO WORK THROUGH. SETDOWN 10KLBS WITH LINER ON DEPTH. ESTABLISH CIRCULATION AT 1.5 BPM,2170 PSI,FULL RETURNS. FINAL PICKUP WEIGHT WITH LINER ON BOTTOM=47 KLBS,SLACKOFF=23 KLBS. Printed 8/6/2012 10:38:29AM North America -ALASKA- BP Page 2 of 7 Operation Summary Report Common Well Name:07-35 AFE No Event Type:COM-ONSHORE(CON) Start Date: 7/9/2012 End Date:7/13/2012 X3-01252-C: (1,449,151.00) Project: Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501"W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:15 - 23:00 0.75 CASING P RUNPRD PUMP 10 BBLS 9.5 PPG KCL AND SHUT DOWN PUMPS. LAUNCH 5/8"STEEL BALL WITH 2500 PSI AND CIRCULATE DOWN COIL WITH 9.5 PPG KCL TO SELRT BALL SEAT AT 2 BPM,2290 PSI. SLOWDOWN RATE TO 0.75 BPM AT 40 BBLS AWAY(70%OF COIL VOLUME). BALL LANDS ON SEAT AT 46 BBLS AWAY(CALCULATED VOLUME=59.7 BBLS). SHEAR BALL SEAT WITH 4150 PSI. PICKUP TO NEW BREAKOVER WEIGHT OF 40 KLBS. CONFIRM LOSS OF 7 KLBS PICKUP WEIGHT. LINER IS FREE. SET DOWN WITH 10 KLBS DOWN WEIGHT. 23:00 - 00:00 1.00 CASING P RUNPRD CONTINUE TO CIRCULATE 9.5 PPG KCL TO DISPLACE WELL OVER FROM 9.5 PPG POWERVIS MUD. 7/11/2012 i 00:00 - 03:00 3.00 CEMT P RUNPRD DISPLACE WELL FROM 9.5 PPG POWERVIS MUD TO 9.5 PPG KCL. CIRCULATION PRESSURE AT 1.5 BPM=1040 PSI, FULL RETURNS. OFFLOAD MUD FROM PITS AND TAKE ON KCL IN PREPARATION FOR CEMENT JOB. • BUILD 130 BBLS BIOZAN KCL FOR CEMENT CONTAMINATION. MOVE IN AND RIG UP SCHLUMBERGER CEMENTERS. 03:00 - 03:30 0.50 CEMT P RUNPRD PRESSURE TEST SLB CEMENTING LINES AND MICRO MOTION BYPASS LINES ON HIGH PRESSURE MANIFOLD TO 250 PSI LOW AND 6000 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). VISUAL LEAKTIGHT CONFIRMATION OF LINES ACHIEVED PER TEMPORARY PIPEWORK PRESSURE TESTING SOP. 03:30 - 04:15 0.75 CEMT P RUNPRD COMPLETE FLUID MANAGEMENT IN PITS IN PREPARATION FOR CEMENT JOB. HOLD PJSM FOR CEMENTING. _CONTINUE CIRCULATING WELL AT 0.5 BPM 04:15 - 04:45 0.50 CEMT P RUNPRD BATCH UP 33 BBLS 15.8 PPG CEMENT. CONFIRM CEMENT DENSITY WITH BALANCE. Printed 8/6/2012 10:38:29AM North America -ALASKA- BP Page 3 of 7 Operation Summary Report Common Well Name:07-35 AFE No Event Type:COM-ONSHORE(CON) 1 Start Date: 7/9/2012 End Date: 7/13/2012 X3-01252-C: (1,449,151.00) Project: Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 10148°34'10.501"W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:45 - 06:30 1.75 CEMT P RUNPRD CEMENT 3-1/4"X 2-7/8"PRODUCTION LINER WITH BAKER GEN II SELRT TOOLS RUN ON 2-3/8"COILED TUBING(REEL VOLUME=59.2 BBLS)AS FOLLOWS: 04:55-SLB PUMP 26.7 BBLS 15.8 PPG CLSS G CEMENT; INITIAL CIRC PRESSURE(ICP)= 1750 PSI AT 2 BPM, FINAL CIRC PRESSURE (FCP)=2300 PSI AT 1.4 BPM. 05:10-ISOLATE COIL AND CLEANUP CEMENTING LINES TO SCHLUMBERGER TRUCKS. 05:20-ZERO MICROMOTION IN AND OUT METERS. RIG PUMPS DISPLACE CEMENT WITH 9.5 PPG BIOZAN KCL;2 BPM. ICP= 3365 PSI. 05:35-AT 33 BBLS AWAY.2 BPM.500 PSI. - CEMENT BEGINS TO ENTER SELRT. DROP RATE MOMENTARILY TO 1.4 BPM AS CEMENT ENTERS LINER AND THEN RESUME PUMPING AT 2 BPM. 05:45-AT 48.3 BBLS AWAY,CEMENT BEGINS TO ROUND CORNER. ZERO MICROMOTION OUT. CIRC PRESSURE AT 2 BPM= 1035 PSI. 05:50-AT 57.7 BBLS AWAY,9.4 BBLS ON THE OUT METER,2 BBLS OF CEMENT REMAIN ABOVE SELRT TOOLS. FCP= 1825 PSI AT 1 8 BPM. SHUT DOWN PUMPS. PICKUP TO NEUTRAL WEIGHT+ 14'TO EXPOSE DOGS. 05:55-RUN IN HOLE AND SET DOWN AT 10' HIGHER THAN PREVIOUS DEPTH WITH 10 KLBS DOWN. PRESSURE UP TO 900 PSI TO LATCH UP PEE-WEE DART WITH LINER WIPER PLUG. HOLD PRESSURE FOR 30 SEC. 06:00-PICK UP TO COIL WEIGHT+ 1'TO EXPOSE SIDE EXHAUST PORT. PRESSURE BLEEDS OFF TO 0 PSI. CIRCULATE 5 BBLS(2 BBLS CEMENT AND 3 BBLS BIOZAN KCL); 1.5 BPM,700 PSI COMPARED TO 1040 PSI EARLIER THROUGH LINER. SHUT DOWN ON PUMPS. 06:05-OPEN BAKER CHOKE. RUN BACK IN HOLE TO SAME DEPTH AS BEFORE TO NO-GO ON DOGS AND STACK 10 KLBS DOWN. CLOSE BAKER CHOKE. 06:10-LAUNCH LINER WIPER PLUG WITH 3150 PSI. DISPLACE PLUG WITH 15.2 BBLS (CALCULATED= 15.0 BBLS); 1.6 BPM UNTIL FINAL 1.5 BBLS. ICP AT 1.6 BPM= 1560 PSI. APPROXIMATELY 600 PSI LIFT PRESSURE OBSERVED DURING DISPLACEMENT. FINAL PLUG BUMP PRESSURE AT 1 BPM= 1390 PSI. FULL RETURNS DURING JOB. Printed 8/6/2012 10:38:29AM a - r. Operation Summary:Report Common Well Name.07-35 AFE No Event Type: COM-ONSHORE(CON) Start Date: 7/9/2012 End Date:7/13/2012 X3-01252-C: (1,449,151.00) Project: Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501"W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:20-CEMENT IN PLACE. PRESSURE UP TO 2300 PSI AND HOLD FOR 3 MIN. BLEED OFF PRESSURE TO CHECK FLOATS. FLOATS HOLDING. 06:25-PRESSURE UP LINER TO 1200 PSI. PICKUP 5'AND PRESSURE BLEEDS OFF. CIRCULATE 5 BBLS AT 0.5 BPM ON TOP OF LINER. 1 TOP OF CEMENT ESTIMATED AT TOP OF LINER AT 8905'MD. 06:30 - 08:30 2.00 CEMT P RUNPRD PULL OUT OF HOLE FROM LINER TOP AT 8905'MD TO BHA AT 139'. CONTAMINATE RESIDUAL CEMENT LEFT IN 4-1/2"TUBING ON TRIP OUT OF HOLE BY CIRCULATING BIOZAN FLUID AT COIL TUBING VOIDAGE+0.5 BPM; 60-100 FPM. FLOW CHECK AT BHA. WELL STATIC. 08:30 - 10:00 1.50 CEMT P RUNPRD LAYDOWN BAKER SELRT TOOLS. ALL TOOLS APPEAR TO HAVE FUNCTIONED PROPERLY. 10:00 - 11:00 1.00 EVAL P OTHCMP HOLD PJSM FOR HANDLING BHA AND SOURCES.PICK UP TOOLS FOR CLEAN OUT RUN AND MCNL LOGGING.. 11:00 - 15:00 4.00 'EVAL P OTHCMP MAKE UP MILL AND BAKER EXTREME 2.125-IN MOTOR WITH LOGGING CARRIER TO 2,614-FT.COMPRESIVE STRENGTH BETTER THAN 500 PSI. PERFORM KICK WHILE TRIPPING DRILL.TIME 1 MINUTE 40 SECONDS. 15:00 - 15:30 0.50 EVAL P OTHCMP MAKE UP QUICK TEST SUB TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH-PASS. 15:30 - 17:30 2.00 EVAL P OTHCMP RUN IN HOLE WITH LOGGING TOOLS ON COIL TO LINER TOP OF 8,905-FT MD. 17:30 - 19:30 2.00 EVAL P OTHCMP MEMORY LOG DOWN GR/CNL/CCL FROM 8,400-FT MD TO TD OF 11,258-FT MD AT 30 FPM. 19:30 - 20:30 1.00 EVAL P OTHCMP LOG UP FROM TAG DEPTH AT 11261'MD TO 8400'MD;60 FPM,0.5 BPM,450 PSI. LAY IN 9.5 PPG,100K LSRV PERFORATING PILL ON TRIP OUT OF HOLE. FLOW CHECK WELL AT ITOP OF LOGGING INTERVAL. WELL STATIC. 20:30 - 22:00 1.50 EVAL P OTHCMP PULL OUT OF HOLE FROM 8400'MD TO BHA AT 2614'MD;100 FPM. FLOWCHEC WELL PRIOR TO BHA ENTERING BOP STACK. WELL STATIC. UNSTAB INJECTOR AND SETBACK ION RIG FLOOR. 22:00 - 00:00 2.00 EVAL P OTHCMP RACK BACK 12 OUT OF 39 DOUBLE STANDS OF 1-1/4"CSH PIPE BY MIDNIGHT. CONTINUE ON 7/12/12. Printed 8/6/2012 10:38:29AM North America -ALASKA- BP Page 5 of 7 Operation Summary Report Common Well Name:07-35 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/9/2012 End Date: 7/13/2012 X3-01252-C: (1,449,151.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:OOAM Rig Release: Rig Contractor NORDIC CALISTA UWI:/Lat:07015'59.739"9 Long: 0148°3410.501'W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/12/2012 00:00 - 03:00 3.00 EVAL P OTHCMP RACK BACK REMAINING 27 DOUBLE STANDS OF 1-1/4"CSH PIPE OUT OF 39 TOTAL, INCLUDING MARKER PUP FOR 300'WARNING FOR RADIOACTIVE SOURCES APPROACHING SURFACE. HOLD KICK WHILE TRIPPING DRILL AND AAR. STAB SAFETY JOINT AND SIMULATE _ SHUTTING IN WELL IN 4 MIN 0 SEC. 03:00 - 04:00 1.00 EVAL P OTHCMP LAYDOWN MEMORY LOGGING AND CLEANOUT TOOLS. SLB MEMORY LOGGER DOWNLOADS AND CHECKS DATA. 04:00 - 05:00 1.00 CASING P RUNPRD PRESSURE TEST 3-1/4"X 2-7/8"PRODUCTION LINER,LINER LAP AND 4-1/2"LNR/TBG TO 250 PSI LOW FOR FIVE MIN(PASS). UNABLE TO ACHEIVE HIGH PRESSURE TEST OF 2400 PSI. TEST FAIL,SEE ATTACHED DOCUMENTATION. APPROVAL TO PROCEED RECEIVED FROM WELLS TEAM LEADER. -ESTABLISH INJECTION RATE AT 05 BPM, 1375 PSI FOR 1 BBL PRESSURE BLEEDS OFF TO FORMATION AT -200 PSVMIN 05:00 - 06:00 1.00 PERFOB P OTHCMP SCHLUMBERGER MEMORY LOGGERS PROCESSING GR/CCL/CNL DATA WITH ONSITE GEOLOGIST. RIG CREW LOAD PERFORATING GUNS INTO PIPE SHED. 06:00 - 11:00 5.00 PERFOB N WAIT 11,298.00 OTHCMP WORK ON PROJECTS FOR SUMMER MAINTENANCE WHILE WAITING ON GUN CREWS.JET STACK. PAINT INSPECTED METAL, OTHER PAINTING PROJECTS. PREP FOR GUN RUN. 11:00 - 14:00 3.00 PERFOB P OTHCMP HOLD PJSM WITH RIG CREW AND GUN CREW.PICK UP 12 GUNS AND MAKE UP BHA FOR PERFORATIONS. 14:00 - 14:30 0.50 PERFOB P OTHCMP MAKE UP COIL INJECTOR AND COIL CONNECTOR.MAKE UP QUICK CONNECT SUB AND TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. 14:30 - 15:30 1.00 PERFOB P OTHCMP RIH WITH GUN ASSEMBLY TO THE LINER EOP FLAG CORRECTED TO MINUS 8-FT. 15:30 - 17:00 1.50 PERFOB P OTHCMP TAG UP AT 11,253-FT MD CORRECT PLUS 6-FT.PULL UP TO 11,202-FT MD. Printed 8/6/2012 10:38:29AM North America -ALASKA- BP Page 6 of 7 Operation Summary Report Common Well Name: 07-35 AFE No Event Type:COM-ONSHORE(CON) Start Date: 7/9/2012 End Date: 7/13/2012 X3-01252-C: (1,449,151.00) Project: Prudhoe Bay Site:PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501"W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 17:30 0.50 PERFOB P OTHCMP PERFORM DRY RUN FOR FIRING SEQUENCE. ESTABLISH PUMP RATES OF.4 BPM WITH 215 PSI,AND 1.66 BPM WITH 2625 PSI. INITIATE FIRING SEQUENCE.WITH 20 SECONDS TO GO ON FINAL LOW PUMP RATE SLOWLY PULL UP TO POSITION AND FIRE GUNS ON DEPTH AT 11,200-FT MD,WHILE MOVING SLOWLY UPWARD.CONTINUE TO PULL UP HOLE AT 12 5 FPM AND ESTABLISH CIRCULATION. PUMP AT 1.0 BPM IN AND.86 BPM OUT. CHOKE SET TO HOLD 200 PSI WHP. -GOOD INDICATIONS OF FIRE ON SHOT INDICATOR AND WITH IMMEDIATE LOSS OF SEVERAL BBLS FLUID. PERFORATION SUMMARY: ZONE 2A: 10950 MD- 11200'MD(250'NET) 6 SPF,60 DEG PHASING 17:30 - 20:30 3.00 PERFOB -P OTHCMP POOH AT 30 FPM PUMPING AT 1.15 BPM IN AND.93 BPM OUT WITH 1414 PSI. HOLD WHP AT 200 PSI. LOSSES TO FORMATION HALTED DURING TRIP OUT OF HOLE. TRIP SHEET IS -6 BBLS TOTAL FOR TRIP OUT OF HOLE (PRIMARILY DUE TO INITIAL LOSS WHEN SHOTTING PERF GUNS). 20:30 - 00:00 3.50 PERFOB P OTHCMP LAYDOWN 10 JOINTS OF RENTAL 1-1/4"CSH PIPE. RACK BACK REMAINING 1-1/4"CSH • PIPE. HOLD PJSM WITH PERFORATORS AT 300'FROM SURFACE. LAYDOWN PERFORATING GUNS. 7/13/2012 00:00 - 00:30 0.50 PERFOB P OTHCMP COMPLETE LAYING DOWN 12 PERFORATING GUNS ALL SHOTS CONFIRMED TO HAVE FIRED MIRU LITTLE RED SERVICES. PRESSURE TEST LINES TO 250 PSI LOW AND 2500 PSI HIGH FOR FIVE MIN EACH PER TEMPORARY PIPEWORK SOP(VISUAL CONFIRMATION OF LEAKTIGHT LINES ACHEIVED). 00:30 - 01:30 1.00 WHSUR P POST MAKEUP NOZZLE BHA,OVERALL LENGTH= 10'. STAB ON WELL WITH INJECTOR. PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW,3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). 01:30 - 02:00 0.50 WHSUR P POST RUN IN HOLE WITH NOZZLE ASSEMBLY FROM BHA AT 10'TO 2500'MD. LITTLE RED SERVICES CIRCULATE DIESEL DOWN COIL ON TRIP IN HOLE. Printed 8/6/2012 10:38:29AM North America -ALASKA- BP Page 7 of 7 Operation Summary Report Common Well Name:07-35 AFE No Event Type:COM-ONSHORE(CON) Start Date: 7/9/2012 End Date: 7/13/2012 X3-01252-C: (1,449,151.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/7/1997 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.739"9 Long: 0148°34'10.501'W Active Datum:Kelly Bushing/Rotary Table @57.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 03:00 1.00 WHSUR P POST PULL OUT OF HOLE,LAYING IN 6.8 PPG,75 DEG F DIESEL 1:1 FROM 2500'MD/TVD TO SURFACE TO FREEZE PROTECT 4-1/2" PRODUCTION TUBING. FLOW CHECK WELL AT SURFACE. WELL STATIC. BREAKOFF INJECTOR AND SETBACK ON RIG FLOOR. LAYDOWN NOZZLE ASSEMBLY. RDMO LITTLE RED SERVICES PUMP TRUCK. CALCULATED OVERBALANCE TO FORMATION WITH 2500'6.8 PPG ON TOP OF 9.5 PPG KCUNACL BRINE=746 PSI 03:00 - 04:00 1.00 DHB P POST WELLS SUPPORT VALVE SHOP CREW ON LOCATION TO INSTALL 4"CIW TYPE H BPV WITH DRY ROD(WELL FLUID COLUMN STATIC). GREASE TREE VALVES. 04:00 - 06:30 2.50 WHSUR P POST DRAIN BOP STACK. SHUT MASTER,SSV AND SWAB VALVES. PRESSURE TEST MASTER AND SWAB VALVES INDEPENDENTLY FROM ABOVE WITH MEOH TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH TO ESTABLISH TWO BARRIERS FOR BREAKING -CONTAINMENT(PASSING TESTS,SEE ATTACHED CHART). 06:30 - 10:30 4.00 BOPSUR P POST OPEN BOP DOORS AND INSPECT RAMS. NIPPLE DOWN BOP STACK. 10:30 - 16:00 5.50 BOPSUR P POST CLEAN PITS. 16:00 - 18:00 2.00 BOPSUR P POST NIPPLE DOWN BOP STACK. 18:00 - 19:00 1.00 WHSUR P POST INSTALL TREE CAP WITH NEW RING GASKET AND PRESSURE TEST AGAINST CLOSED MV, SSV,&SV TO 250 PSI LOW,3500 PSI HIGH FOR FIVE MIN EACH(PASSING TEST,SEE ATTACHED CHART). 19:00 - 20:00 1.00 RIGD P POST GENERAL RIG DOWN OPERATIONS. RELEASE NORDIC 2 CTD RIG AND END COMPLETION EVENT AT 20:00 ON 7/13/2012. -ALL TREE AND WELLHEAD VALVES LEFT CLOSED TO PRESSURE GAUGES. -FINAL IA/OA=0/0 PSI -TREEM/ELLHEAD AND CELLAR CLEAN -WELLWORK TRANSFER PERMIT CLOSED OUT WITH DRILLSITE OPERATOR. -WELL HANDOVER COMPLETED WITH WELLS GROUP(NOTE: LINER TOP PACKER MUST BE SET POST RIG) 13.08 DAYS FROM RIG ACCEPT TO RIG RELEASE ORIGINAL PERFORMANCE TARGET=11.15 DAYS ORIGINAL AFE P50 TARGET=13.91 DAYS PREPARE TO MOVE RIG TO NEXT WELL DS07-22. Printed 8/6/2012 10:38:29AM 07-35A, Well History (Post Rig Sidetrack) Date Summary 07/27/12 DRIFTED W/13'x 1-7/8" STEM TO 9,200' SLM (no issues). RAN SLB GR-CCL MEMORY TOOL FROM 9,200' SLM TO 7,800' SLM. RAN 10'x 3.70" DUMMY WHIPSTOCK W/3.50" LIB TO TOP OF DEPLOYMENT SLEEVE @ 8880'SLM (good impression). BUSHED DEPLOYMENT SLEEVE W/3.65" CENT,4 1/2" BLB&3 1/2" BLB. SET BAKER KB LINER TOP PACKER @ 8,885' SLM (top of packer @ 8,877'slm, oal-16.5', 2.36" ID). 07/28/12 MIT-T to 2400 psi***PASS***. Pumped 3 bbls of crude down Tbg to bring Tbg up to test pressure of 2418 psi. 1st 15 mins Tbg lost 89 psi/IA lost 0 psi/OA lost 0 psi. 2nd 15 mins Tbg lost 28 psi/IA lost 0 psi/OA lost 0 psi.Total test Tbg lost 117 psi/IA lost 0 psi/OA lost 0 psi. ***PASS***Bled Tbg to 300 psi and got back 2.5 bbls. SLine in control of well per LRS departure. FWHP's=300/-6/0 CVs=OTG. 07/28/12 SET 45 KB TEST TOOL @ 8,863'SLM. LRS PERFORMED MIT OF PACKER TO 2400psi**PASS** PULLED STA#2 BK-DGLV FROM 6,211'SLM/6,226' MD. PULLED STA#1 BK-DGLV FROM 3,710' SLM/3,725' MD. SET STA#1 BK-LGLV @ 3,710' SLM/3,725' MD. SET STA#2 BK-OGLV @ 6,211' SLM/6,226' MD. PULLED LTTP FROM 8,863' SLM (empty). Page 1 of 1 .'.. BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 07 07-35 - Slot 35T / Lat: 070°15'59.739"9 Long: 0148°34'10.501"W 07-35A Survey: MWD Survey Report - Geographic 17 July, 2012 trI v # Hill , N,L HUGHES Survey Report-Geographic #•y- '+ by INTEQ "Ote Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-35-Slot 35T Project: Prudhoe Bay TVD Reference: 48:35T 8/13/1997 09:36 @ 57.00ft(Doyon 141) Site: PB DS 07 MD Reference: 48:35T 8/13/1997 09:36 @ 57.00ft(Doyon 141) Well: 07-35 North Reference: True Wellbore: 07-35A Survey Calculation Method: Minimum Curvature Design: 07-35A Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 07,TR-11-14 Site Position: Northing: 5,948,144.78ft Latitude: 70°15'49.847 N From: Map Easting: 677,382.28ft Longitude: 148°33'56.934 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.35 ° Well 07-35 API No 500292281100 Well Position +N/-S 0.00 ft Northing: 5,949,139.28 ft Latitude: 70°15'59.739 N +E/-W 0.00 ft Easting: 676,892.60 ft Longitude: 148°34' 10.501 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 27.50ft Wellbore 07-35A API No 500292281101 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 6/29/2012 20.97 81.02 57,657 Design 07-35A Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,135.49 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 29.50 0.00 0.00 166.67 Survey Program Date: 7/10/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 110.00 3,270.10 2:Gyrodata cont.drillpipe m/(07-35) GYD-CT-DMS Gyrodata cont.drillpipe m/s 3,377.15 9,135.49 3:MWD-Standard(07-35) MWD MWD-Standard 9,150.50 11,297.00 MWD(07-35A) MWD MWD-Standard 7/17/2012 9:56:00AM Page 2 COMPASS 2003.16 Build 73 .,.. by BAKER 11144..1) HUGHES Survey Report-Geographic INTEQ !!1 Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-35-Slot 35T Project: Prudhoe Bay TVD Reference: 48:35T 8/13/1997 09:36 @ 57.00ft(Doyon 141) Site: PB DS 07 MD Reference: 48:35T 8/13/1997 09:36 @ 57.00ft(Doyon 141) Well: 07-35 North Reference: True Wellbore: 07-35A Survey Calculation Method: Minimum Curvature Design: 07-35A Database: EDM.16-ANC Prod-WH24P ;Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +NI-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,135.49 45.63 319.78 8,855.64 839.51 -217.72 5,949,973.38 676,655.23 70° 16'7.995 N 148°34'16.839 W TIP 9,150.50 47.33 318.36 8,865.97 847.73 -224.86 5,949,981.43 676,647.91 70° 16'8.076 N 148°34'17.046 W KOP 9,152.00 47.13 317.83 8,866.99 848.55 -225.59 5,949,982.24 676,647.15 70° 16'8.084 N 148°34'17.068 W 9,182.06 43.62 306.46 8,888.14 862.90 -241.36 5,949,996.21 676,631.06 70° 16'8.225 N 148°34'17.527 W1 9,212.80 45.06 293.98 8,910.17 873.65 -259.86 5,950,006.52 676,612.30 70° 16'8.331 N 148°34'18.065 W 9,241.71 46.26 282.34 8,930.41 880.05 -279.45 5,950,012.46 676,592.57 70° 16'8.394 N 148°34'18.635 W 9,272.27 48.99 266.48 8,951.07 881.70 -301.82 5,950,013.59 676,570.17 70° 16'8.410 N 148°34'19.287 W 9,302.85 51.99 253.68 8,970.57 877.60 -324.96 5,950,008.94 676,547.13 70° 16'8.370 N 148°34'19.960 W 9,331.79 56.77 243.11 8,987.46 868.90 -346.75 5,949,999.74 676,525.55 70° 16'8.284 N 148°34'20.595 W 9,361.37 62.66 233.20 9,002.39 855.40 -368.37 5,949,985.73 676,504.27 70° 16'8.151 N 148°34'21.224 W 9,393.37 70.22 224.23 9,015.20 836.03 -390.32 5,949,965.86 676,482.78 70° 16'7.961 N 148°34'21.863 W 9,422.37 76.44 216.14 9,023.53 814.82 -408.19 5,949,944.23 676,465.41 70°16'7.752 N 148°34'22.383 W 9,453.11 82.86 208.15 9,029.05 789.24 -424.24 5,949,918.28 676,449.96 70° 16'7.501 N 148°34'22.850 W 9,483.17 87.79 200.37 9,031.51 761.95 -436.53 5,949,890.72 676,438.32 70°16'7.232 N 148°34'23.208 W 9,513.17 89.14 196.96 9,032.31 733.55 -446.13 5,949,862.09 676,429.39 70°16'6.953 N 148°34'23.487 W 9,543.19 90.52 193.34 9,032.40 704.58 -453.97 5,949,832.95 676,422.23 70°16'6.668 N 148°34'23.715 W 9,573.40 91.91 188.69 9,031.76 674.94 -459.74 5,949,803.18 676,417.16 70°16'6.377 N 148°34'23.883 W 9,603.30 92.46 184.83 9,030.62 645.27 -463.26 5,949,773.45 676,414.34 70°16'6.085 N 148°34'23.985 W 9,633.35 92.77 180.71 9,029.25 615.30 -464.71 5,949,743.45 676,413.60 70°16'5.790 N 148°34'24.028 W 9,663.06 91.44 178.30 9,028.16 585.61 -464.45 5,949,713.78 676,414.55 70°16'5.498 N 148°34'24.020 W 9,693.18 89.75 174.80 9,027.84 555.55 -462.64 5,949,683.77 676,417.07 70° 16'5.202 N 148°34'23.967 W 9,723.10 89.02 170.66 9,028.16 525.88 -458.85 5,949,654.20 676,421.55 70°16'4.911 N 148°34'23.857 W 9,763.10 87.79 164.86 9,029.28 486.82 -450.38 5,949,615.35 676,430.94 70°16'4.526 N 148°34'23.610 W 9,793.02 88.83 161.33 9,030.16 458.21 -441.69 5,949,586.96 676,440.30 70°16'4.245 N 148°34'23.357 W 9,822.89 89.48 158.34 9,030.60 430.18 -431.39 5,949,559.18 676,451.25 70°16'3.969 N 148°34'23.058 W 9,853.13 88.13 154.68 9,031.23 402.46 -419.34 5,949,531.75 676,463.95 70° 16'3.697 N 148°34'22.707 W 9,883.37 87.73 152.63 9,032.32 375.38 -405.93 5,949,504.99 676,477.99 70° 16'3.430 N 148°34'22.316 W 9,913.22 86.49 150.82 9,033.83 349.12 -391.81 5,949,479.08 676,492.72 70° 16'3.172 N 148°34'21.905 W 9,943.54 83.72 149.27 9,036.42 322.95 -376.73 5,949,453.27 676,508.41 70° 16'2.915 N 148°34'21.466 W 9,973.05 86.28 152.90 9,038.99 297.23 -362.52 5,949,427.88 676,523.22 70° 16'2.662 N 148°34'21.053 W 10,003.26 88.62 155.44 9,040.33 270.06 -349.37 5,949,401.04 676,537.00 70° 16'2.395 N 148°34'20.670 W 10,033.34 90.61 158.60 9,040.54 242.38 -337.63 5,949,373.64 676,549.39 70° 16'2.122 N 148°34'20.328 W 10,063.27 93.16 160.42 9,039.55 214.36 -327.16 5,949,345.88 676,560.52 70°16'1.847 N 148°34'20.023 W 10,093.16 95.38 160.36 9,037.33 186.28 -317.16 5,949,318.05 676,571.18 70° 16' 1.571 N 148°34'19.732 W 10,124.92 94.11 163.77 9,034.70 156.17 -307.42 5,949,288.18 676,581.62 70° 16' 1.275 N 148°34'19.449 W 10,153.42 93.37 168.20 9,032.84 128.59 -300.53 5,949,260.76 676,589.15 70°16'1.003 N 148°34'19.248 W 10,178.30 91.62 170.30 9,031.75 104.17 -295.90 5,949,236.46 676,594.36 70°16'0.763 N 148°34'19.113 W 10,203.99 90.28 170.68 9,031.33 78.84 -291.65 5,949,211.24 676,599.20 70°16'0.514 N 148°34'18.990 W 10,233.84 89.97 167.10 9,031.26 49.55 -285.90 5,949,182.10 676,605.64 70°16'0.226 N 148°34'18.822 W 10,269.56 89.48 163.26 9,031.44 15.03 -276.77 5,949,147.80 676,615.58 70° 15'59.886 N 148°34'18.556 W 10,301.88 90.21 159.90 9,031.52 -15.63 -266.56 5,949,117.39 676,626.51 70° 15'59.585 N 148°34'18.259 W 10,329.35 91.60 158.02 9,031.09 -41.27 -256.70 5,949,092.00 676,636.97 70° 15'59.333 N 148°34'17.972 W 10,367.36 90.89 149.58 9,030.26 -75.33 -239.93 5,949,058.34 676,654.52 70° 15'58.998 N 148°34'17.484 W 10,394.80 91.11 149.02 9,029.78 -98.92 -225.93 5,949,035.08 676,669.08 70° 15'58.766 N 148°34'17.077 W 10,422.27 90.46 144.61 9,029.41 -121.90 -210.89 5,949,012.46 676,684.65 70° 15'58.540 N 148°34'16.639 W 10,455.44 91.94 142.02 9,028.71 -148.49 -191.09 5,948,986.34 676,705.07 70° 15'58.278 N 148°34'16.062 W 10,487.26 92.49 140.17 9,027.48 -173.24 -171.12 5,948,962.08 676,725.62 70° 15'58.035 N 148°34'15.481 W 10,516.43 90.65 139.68 9,026.68 -195.55 -152.35 5,948,940.22 676,744.91 70°15'57.815 N 148°34'14.935 W 10,552.35 90.77 136.19 9,026.24 -222.21 -128.29 5,948,914.13 676,769.58 70°15'57.553 N 148°34' 14.235 W 10,587.62 91.29 134.51 9,025.60 -247.30 -103.50 5,948,889.64 676,794.95 70°15'57.307 N 148°34' 13.513 W 10,617.32 90.21 132.63 9,025.21 -267.76 -81.99 5,948,869.68 676,816.94 70°15'57.105 N 148°34' 12.887 W 10,647.22 89.60 129.97 9,025.26 -287.50 -59.53 5,948,850.48 676,839.85 70°15'56.911 N 148°34'12.233 W 10,677.08 89.39 127.32 9,025.53 -306.14 -36.21 5,948,832.39 676,863.60 70°15'56.728 N 148°34'11.555 W 7/17/2012 9:56:00AM Page 3 COMPASS 2003.16 Build 73 BAKER• #♦f� h HUGHES Survey Report-Geographic / it INTEQ 0•4+14 Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-35-Slot 35T Project: Prudhoe Bay TVD Reference: 48:35T 8/13/1997 09:36 @ 57.00ft(Doyon 141) Site: PB DS 07 MD Reference: 48:35T 8/13/1997 09:36 @ 57.00ft(Doyon 141) Well: 07-35 North Reference: True Wellbore: 07-35A Survey Calculation Method: Minimum Curvature Design: 07-35A Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 10,701.04 90.25 126.37 9,025.60 -320.51 -17.04 5,948,818.48 676,883.11 70° 15'56.587 N 148°34'10.997 W 10,727.24 90.46 129.95 9,025.44 -336.69 3.56 5,948,802.78 676,904.08 70° 15'56.427 N 148°34'10.397 W 10,756.84 89.75 134.81 9,025.39 -356.64 25.42 5,948,783.36 676,926.40 70° 15'56.231 N 148°34'9.761 W 10,787.04 89.60 139.78 9,025.56 -378.82 45.90 5,948,761.66 676,947.39 70° 15'56.013 N 148°34'9.165 W 10,817.24 91.81 147.34 9,025.18 -403.10 63.82 5,948,737.82 676,965.87 70° 15'55.774 N 148°34'8.644 W 10,847.72 90.37 150.05 9,024.60 -429.13 79.65 5,948,712.16 676,982.31 70° 15'55.518 N 148°34'8.183 W 10,877.08 89.82 153.78 9,024.56 -455.03 93.47 5,948,686.60 676,996.74 70° 15'55.264 N 148°34'7.781 W 10,908.24 89.36 157.48 9,024.78 -483.41 106.33 5,948,658.53 677,010.25 70° 15'54.984 N 148°34'7.406 W 10,938.80 88.01 159.43 9,025.48 -511.82 117.54 5,948,630.39 677,022.14 70° 15'54.705 N 148°34'7.080 W 10,969.17 91.29 160.19 9,025.67 -540.32 128.02 5,948,602.15 677,033.28 70° 15'54.425 N 148°34'6.775 W 11,005.87 90.46 166.55 9,025.10 -575.47 138.52 5,948,567.26 677,044.60 70° 15'54.079 N 148°34'6.469 W 11,034.48 90.09 168.16 9,024.97 -603.38 144.78 5,948,539.51 677,051.52 70° 15'53.804 N 148°34'6.287 W 11,062.90 90.55 172.03 9,024.81 -631.37 149.67 5,948,511.64 677,057.06 70° 15'53.529 N 148°34'6.145 W 11,082.00 90.86 174.09 9,024.57 -650.33 151.98 5,948,492.74 677,059.81 70° 15'53.343 N 148°34'6.078 W! 11,095.66 90.64 176.15 9,024.39 -663.94 153.14 5,948,479.17 677,061.29 70° 15'53.209 N 148°34'6.044 W 11,125.06 89.94 170.83 9,024.25 -693.14 156.47 5,948,450.06 677,065.31 70° 15'52.922 N 148°34'5.947 W 11,155.29 90.28 170.09 9,024.19 -722.95 161.48 5,948,420.37 677,071.02 70° 15'52.629 N 148°34'5.801 W 11,186.14 90.58 165.56 9,023.96 -753.10 167.99 5,948,390.39 677,078.23 70° 15'52.332 N 148°34'5.612 W, 11,215.57 90.74 163.38 9,023.62 -781.45 175.87 5,948,362.23 677,086.77 70° 15'52.053 N 148°34'5.383 W 11,245.11 87.05 159.64 9,024.19 -809.45 185.23 5,948,334.46 677,096.79 70° 15'51.778 N 148°34'5.110 W 11,297.00 87.05 159.64 9,026.86 -858.03 203.26 5,948,286.32 677,115.95 70° 15'51.300 N 148°34'4.586 W TD 7/17/2012 9:56:00AM Page 4 COMPASS 2003.16 Build 73 Letter of Transmittal ram __ BAKER Date: July 17, 2012 HUGHES To: J/ From: State of Alaska AOGCC ® Baker Hughes INTEQ 333 W. 7th Ave., Suite 100 6G ryc�ti� 795 East 94th Avenue Anchorage, Alaska 99501 \, I Anchorage, Alaska 99515 Bill Michaelson Please find enclosed the directional survey data for the following well(s): C-12CPB1 C-12C 0 2•5– C-27C 4;/ 1 2, • O t•-t2 C-01 BPB 1 C-01 B (P.,/ �' 0.58 1J-27B oZ l a.' O k 1 B-20A d''t L 7 7 -QSC_� ' O � 4 [ 07-35A49, 7 , (2`� —y Enclosed for each well(s): 2 hardcopy prints of directional survey reports 1 compact disk containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY:40 V d/ 7)70, State of Alaska AOGCC DATE: 1J/ \Cff 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 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-35A BP Exploration (Alaska), Inc. Permit No: 212-067 Surface Location: 3478' FSL, 4604' FEL, SEC. 34, T11N, R14E, UM Bottomhole Location: 2492' FSL, 4250' FEL, SEC. 34, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 7 day of June, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALAS,_ JIL AND GAS CONSERVATION COMM. ;ON & 1/ MAY 1 12012 PERMIT TO DRILL '� 20 AAC 25.005 V�� AOGCC 1 a.Type of work: lb.Proposed Well Class: ®Development Oil 0 Service-Winj ®Single Zone 1 c. Specify if well is proposed for: ❑ Drill ®Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 5.Bond: ® Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 • PBU 07-35A 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 11545' TVD 8791'ss Prudhoe Bay/Prudhoe Bay • 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface: ADL 028309 ' 3478'FSL,4604'FEL, Sec.34,T11 N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4282'FSL,4792'FEL, Sec. 34,T11 N, R14E, UM July 15,2012 . Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2492' FSL,4250' FEL, Sec. 34,T11 N, R14E, UM 2560 24500' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 57' ' feet 15.Distance to Nearest Well Open Surface: x- 676892 . y-5949140 • Zone- ASP4 GL Elevation above MSL: 27.5' feet to Same Pool: 1200' 16.Deviated Wells: Kickoff Depth: 9130' - feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 100 - degrees Downhole: 3250 . Surface: 2370 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 4-1/8" 3-1/4"x 2-7/8" 6.6#/6.5# • L-80 _Tc-II/STL 2645' 8900' 8626'ss 11545' 8791'ss 116 sx Class'G' • 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 ND(ft): Junk(measured): 12565' 903 ' 9798' 12481' 9033' 9798' Casing Length Size ! Cement Volume MD TVD Conductor/Structural 110' 20" 260 sx Arctic Set(Approx.) 110' 110' Surface 3360' 9-5/8" 2418 sx CS III.335 sx Class'G' 3388' 3373' Intermediate 8625' 7" 302 sx Class'G' 8650' 8470' Production Liner 4083' 4-1/2" 440 sx Class'G' 8481'- 12564' 8328'-9033' Perforation Depth MD(ft): 9220'' 12463' Perforation Depth ND(ft): 8909'-9032 20.Attachments: 0 Property Plat ® BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ® Diverter Sketch 0 Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Zach Sayers,564-5790 Printed Name Joh Ilen Title Engineering Team Leader Prepared By Name/Number Signature Phone 564-4711 Date 9/7/r2, Joe Lastufka,564 4091 Commission Use Only Permit To Dri API Number: Permit A ro I D See cover letter for Number: .7J-2_____(,_,--7 50-029-22811-01-00 T1 �� other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: Other: w 3 Coo f,:, P ( Samples Req'd: 0yes L'No Mud Log Req'd: ❑Yes No H2S Measures: Yes 0 No Directional Survey Req'd: 'Yes 0 No / Date - �� APPROVED BY THE COMMISSION / C� ,COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 months fr fAAC 25.005(g)) ubmit In Duplicate ,'4„i2" ,z 01TFN'AL #1150 L To: Alaska Oil & Gas Conservation Commission From: Zach Sayers 4:::t4::: CTD Engineer Date: May 10, 2012 Re: 07-35A Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well 07-35. CTD Drill and Complete 07-35A program: Rig Start Date: July 15th, 2012 Pre-Rig Work: (scheduled to begin May 25th, 2012) 1. F MIT- IA to 3,000 psi, MIT-OA to 2,000 psi 2. W Cycle LDS; PPPOT- T to 5,000 psi 3. S Dummy WS Drift to 9,167'MD (49° Inc) 4. E Mill XN nipple at 8,463' to 3.80"✓ 5. F Load and Kill well with 1% KCI 6. E Set 4-1/2" KB Whipstock at —9,130' MD using CCJ_ to locate mid joint 7. F Test KB whipstock to 2,400 psi for 30 min MIT ►/ 8. V PT MV, SV, WV 9. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange 10. 0 Remove wellhouse, level pad Rig Work: (scheduled to begin July 15th, 2012) A 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.80" window at 9,130' and 10' of rathole. Swap the well to PowerVis. 3. Drill Build: 4.125" OH, 680' (29 deg/100 planned) 4. Drill Lateral: 4.125" OH, 1,735' (12 deg/100 planned) with resistivity 5. Run 3-1/4" x 2-7/8" L-80 liner leaving TOL at 8,900' MD. 6. Pump primary cement leaving TOC at 8,900' MD (TOL), 24 bbls of 15.8 ppg liner cmt y planned -1,0 7. Cleanout liner and run MCNL/GR/CCL log. 8. Test liner lap to 2,400 psi. r 9. Perforate liner per asset instructions (-200') 10. Freeze protect well, set BPV, RDMO Post-Rig Work: 1. Re-install wellhouse, flowline and pull BPV. 2. Set 4-%" liner top packer, and test to 2,400 psi (If liner lap test fails) 3. Generic GLV's Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg PowerVis for milling window and drilling (686 psi over-balance). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.125" Liner Program: • 3-1/4", 6.6#, L-80, TC-II Solid Liner 8,900' MD — 9,600' MD • 2-7/8", 6.5#, L-80, STL Solid Liner 9,600' MD — 11,545' MD - • A minimum of 24 bbls of 15.8 ppg cement will be used for liner cementing. (TOC 8,900' MD) • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 100°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property—24,500'. / • Distance to nearest well within pool — 1,200'. Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section.` • Cased hole GR/CCL/MCNL logs will be run. Perforating: • SWS 2", 6 spf, pert guns, 1-1/4" CSH work string, & 2-3/8" PH6 • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti-Collision Failures • No Failures Hazards • The maximum recorded H2S level on DS 07 was 50 ppm on well 07-24 on 5/15/2005. Reservoir Pressure • The reservoir pressure on C-03C is expected to be 3,250 psi at 8,800' TVDSS. (7.1 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,370 psi. • An EMW of 8.4 ppg for this well will provide 595 psi over-balance to the reservoir. • Zach Sayers CC: Well File CTD Engineer Sondra Stewman/Terrie Hubble TREE= CW 07 3 5A SR\ NU I LS: WELL ANGLt> /U"L 9392' WELLHEAD= FMC - *** __ES HAVE LOWER PSI RATE THAN NORMAL ACTUATOR= BAKER C ***CHROME TUBING*** KB.ELEV= 57.0' proposed CTD sidetrack BF.ELEV= ? I I 2074' —19-5/8"HES CEMENTER KOP= 1998' Max Angle= 96°@ 9842' , ' 2094' H4-1/2"HES X NIP, ID=3.813" Datum MD= 9137' GAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV 'TYPE VLV LATCH_PORT DATE 1 3725 3710 1 KBG2-IR DOME BEK 16 05/30/08 9-5/8"CSG,40#,L-80 BTC, ID=8.835" }— 3388' 'I ,2 6226 6210 0 KBG2-IR SO BK 20 05/30/08 LI 3 8095 8004 33 KBG2-IR DMY BK 0 01/15/07 Minimum ID = 2.377" @ 9600' ' ' 8258' —14-1/2"HESX NIP, ID=3.813" 3-1/4" x 2-7/8" XO X X 8288' —17"X 4-1/2"BKR S-3 PKR, ID=3.875" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, H 8385' ----_____I 8322' H4-1/2"HES X NIP,ID=3.813" .0152 bpf, ID=3.958" ITBG STUB(05/24/08) H 8388' 8400' H7"X 4-1/2"UNIQUE OVERSHOT TSGR = 8,646' MD 8429' HI7"X 4-1/2"BKR S-3 PKR, ID=3.875" 8463' H4-1/2"HES XN NIP, ID=3.80" milled out TOP OF 4-1/2"LNR —I 8481' \:1--4''' Lam_ 8481' —17"X 5"BKR ZXP PKR T� w/7.11'TIEBK SLV, ID=4.400" 4-1/2"TBG, 12.6#, L-80, .0152 bpf, ID=3.958" H 8485' J 8485' —14-1/2"WLEG, U=3.958" —ELM TT NOT LOGGED 8495' H7"X 5"BKR HMC HGR, ID=4.400" 8501' H5"X 4-1/2"XO, ID=3.958" 7"CSG,26#,L-80 BTC, ID=6.276" H 8650' PERFORATION SUMMARY , REF LOG: BHCS ON 11/28/97 36° Top of 3-1/2"liner and cement @-8,900' ANGLE AT TOP PERF: 55°@ 9220' Note:Refer to Production DB for historical pert data 3-1/4"x 2-7/8"XO @-9,600' SIZE SPF INTERVAL Opn/Sqz DATE 1/2"x 3-1/4"XO ./ I 1--)--)3-3/8" 4 9220-9240 0 12/22/02 7--- 3-3/8" 3-3/8" 4 9280-9320 0 01/03/05 ` 3-3/8" 6 9310-9320 0 06/16/02 45° 2-7/8"liner TD @ 11,545'✓ 2-3/4" 4 9390-9440 0 12/04/97 9798' FISH-FASRILL DEBRIS 2-3/4" 4 9580-9750 0 12/04/97 (05/25/08 RWO) 2-3/4" 4 9870- 10243 12/04/97 1/2"packer whjpstock @ 9,130'MD 2-3/4" 4 10473-10870 C 12/04/97 ✓/ 3 311'410 9798' H CIBP(CTND)03/09/02 2-3/4" 4 10940-11120 C 12/04/97 s,,..N va-y /` 2-3/4" 4 11252-11491 C 12/04/97 ` 2-3/4" 4 11553-11613 C 12/04/97 2-3/4" 4 11650-11717 C 12/04/97 ` 2-3/4" 4 11762-12463 C 12/04/97 4-1/2"LNR, 12.6#,L-80 BTC-M, — 12564' .0152 bpf, ID=3.958" �� AltiVilks AttItmikr TD — 12565' "`�• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/08/97 D141 ORIGINAL COMPLETION 10/27/08 HB/JMD DRLG DRAFT CORRECTIONS WELL: 07-35A 05/27/08_ D16 RWO 01/15/09 /SV GLV CORRECTIONS PERMIT No: 1971770 05/30/08 KSB/PJC GLV C/O 04/19/12 WJH proposr_ ;TD sidetrack AR No: 50-029-22811-00 10/16/08 PJC GLV CORRECTIONS SEC 34,T11 N, R14E, 1802'FNL&676'FWL 10/20/08 PJC FASDRILL REMAINS(05/25/08) TREE= CM/ S? 'NOTES: WELL ANGLE>70°@ 9392' WELLHEAD= FMC ACTUATOR= BAKER C 0 7-3 5 ""`CHROME TUBING LOWER PSI RATE THAN NORMAL KB.ELEV= 57.0' ELEV= ? BF. 1998' I I 2074' —19-5/8"HES CEMENTER Max Angle= 96°@ 9842' ' t 2094' -�4-1/2"HES X NIP,ID=3.813" Datum MD= 9137' Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9-5/8"CSG,40#,L-80 BTC,ID=8.835" —I 3388' I 1 3725 3710 1 KBG2-IR DOME BEK 16 05/30/08 2 6226 6210 0 KBG2-IR SO BK 20 05/30/08 3 8095 8004 33 KBG2-IR DMY BK 0 01/15/07 Minimum ID = 3.725" @ 8463' ' ' 8258' -14-1/2"HES X NIP,ID=3.813" 4-1/2" HES XN NIP R X 8288' —17"X 4-1/2"BKR S-3 PKR,ID=3.875" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, —1 8385' 1- ' 8322' —4-1/2"HES X NIP,ID=3.813" — .0152 bpf,ID=3.958" . 1 TBG STUB(05/24/08) — 8388' 1 _ 8400' —17"X4-1/2"UNIQUE OVERSHOT I Z X 8429' —7"X 4-1/2"BKR S-3 PKR,ID=3.875" 8463' H4-1/2"HES XN NIP,ID=3.725" t" 1"-jr, 7a 3.ye TOP OF 4-1/2"LNR — 8481' 8481' —7"X 5"BKR ZXP PKR w/7.11'TIEBK SLV, ID=4.400" 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" H 8485' 8485' —4-1/2"WLEG,ID=3.958" H ELMD TT NOT LOGGED 8495' H 7"X 5"BKR HMC HGR, ID=4.400" 8501' —15"X 4-1/2"XO, ID=3.958" 7"CSG,26#,L-80 BTC,ID=6.276" —) 8650' INI PERFORATION SUMMARY REF LOG:BHCS ON 11/28/97 ANGLE AT TOP PERF: 55°@ 9220' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9220-9240 0 12/22/02 ` 3-3/8" 4 9280-9320 0 01/03/05 3-3/8" 6 9310-9320 0 06/16/02 ` 9798' 1 FISH-FASRILL DEBRIS 2-3/4" 4 9390-9440 0 12/04/97 (05/25/08 RWO) 2-3/4" 4 9580-9750 0 12/04/97 2-3/4" 4 9870- 10243 C 12/04/97 4 9798' —CIBP(CTMD)03/09/02 2-3/4" 4 10473-10870 C 12/04/97 // ` 2-3/4" 4 10940-11120 C 12/04/97 ` 2-3/4" 4 11252-11491 C 12/04/97 2-3/4" 4 11553-11613 C 12/04/97 ` 2-3/4" 4 11762-12463 C 12/04/97 2-3/4" 4 11650-11717 C 12/04/97 4-1/2"LNR, 12.6#,L-80 BTC-M, 12564' .0152 bpf,ID=3.958" * tit TD 12565' •`.��:` DATE REV BY COMMENTS DATE REV BY _ COMMENTS PRUDHOE BAY UNIT 12/08/97 0141 ORIGINAL COMPLETION 10/27/08 HB/JMD DRLG DRAFT CORRECTIONS WELL:Pb7-35 05/27/08 D16 RWO 01/15/09 /SV GLV CORRECTIONS PERMIT No:'1971770 05/30/08 KSB/PJC GLV C/O API No: 50-029-22811-00 10/16/08 PJC GLV CORRECTIONS SEC 34,T11N, R14E, 1802'FNL&676'FWL 10/20/08 PJC FASDRILL REMAINS(05/25/08) 10/25/08 PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) a _a 0 a_ co I Q co Q 0 0 J a)Q Ce I co v .0 i H QM M 'o Q G N c C N W tQ a LI II eig= 0 3CIML"; E a a `�; Z aaoo a CO o m = W E.0 Z H { ana za Z• \ _ - 0 � �• � ©o Lo • _ \ sr cr, / - - . - / / $ . ® 0& 2 Z0 0 ) t 0 H 2 c co \ - ) = � - 0 � » [ \ ) k • \ _ C) )I - \ ) / ` � cu iii(T) = coo / \ : e = § 0 _ °' Il) }\ \ ) - � § ; > \ \ o � / ) £ . 2� :,c, S � a) Lc • 2 i. , _ • . § E ] \ $ § § ( 2 oo ) \ § / k { _ _ _ it \ % = ceJ = a) 2 a ; = = o » \/ } \ \ 0 � { % Vj] § k k CV \\ jo \\ ' - 0)Ct \ � kC C o k @ 3 7 B 3 O . \ / § £ / CL 2 a) ev % af£ a / 2 - a f ƒ ; *.c.§ 22 � # 22 co ZLU f a)C1 —+ \ < } § CV ? cm / . ! 0 - . 0 _ 2 71. § / 2 __'S a . 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N — ID 0 R N N Ml BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 07 07-35 / Lat: 070°15'59.739"9 Long: 0148°34'10.501"W 07-35A Plan 3 Travelling Cylinder Report 07 May, 2012 /k 0 {-1 BAKER HUGHES Travelling Cylinder Report 11..11 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-35-Slot 35T Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 07 MD Reference: Kelly Bushing/Rotary Table @ 57.00ft Site Error: 0.00ft North Reference: True Reference Well: 07-35 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 07-35A Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 3 Offset TVD Reference: Offset Datum Reference Plan 3 Filter type: GLOBAL FILTER APPLIED:All welipaths within 200'+100/1000 of refer€ Interpolation Method: MD Interval 25.008 Error Model: ISCWSA Depth Range: 9,104.29 to 11,545.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,351.55ft Error Surface: Elliptical Conic Survey Tool Program Date 5/7/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 202.10 12,506.32 1 :MWD-Standard(07-35) MWD MWD-Standard 110.00 3,270.10 2:Gyrodata cont.drillpipe m/(07-35) GYD-CT-DMS Gyrodata cont.drillpipe m/s 3,377.15 9,104.29 3:MWD-Standard(07-35) MWD MWD-Standard 9,104.29 11,545.00 Plan 3(07-35A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 11,545.00 8,970.94 2 7/8" 2.875 4.125 i Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PBDS07 07-01 -07-01 -07-01 Out of range 07-01 -07-01A-07-01A Out of range 07-01 -07-01APB1 -07-01APB1 Out of range 07-01 -07-01B-07-01B Out of range 07 02 07 02 07 02 Out of range 07-02-07-02A-07-02A Out of range 07-02-07-02B-07-02B Out of range 07 05 07 05 07 05 Out of range 07 06 07 06 07 06 10,564.82 9,400.00 1,139.55 202.89 943.38 Pass-Major Risk 07-06-07-06A-07-06A 11,025.00 9,650.00 1,167.74 239.58 938.15 Pass-Major Risk 07-06-07-06B-07-06B 9,160.00 10,150.00 1,054.62 145.11 934.20 Pass-Major Risk 07-06-07-06B-7-06B WP06 9,160.00 10,150.00 1,048.02 143.81 929.42 Pass-Major Risk 07-15-07-15A-07-15A 9,300.00 8,850.00 943.92 143.02 872.58 Pass-Major Risk 07-18-07-18-07-18 Out of range 07-19-07-19-07-19 Out of range 07-19-07-19A-07-19A Out of range 07 20 07 20 07 20 Out of range 07-20-07-20A-07-20A Out of range 07-20-07-20B-07-20B Out of range 07-20-07-20B-Plan#4 Out of range 07 21 07 21 07 21 10,825.00 8,875.00 827.87 147.29 693.40 Pass-Major Risk 07 22 07 22 07 22 Out of range 07-35-07-35-07-35 9,149.99 9,150.00 0.35 4.08 -1.38 FAIL-Major Risk 07-36-07-36-07-36 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/7/2012 2:40:47PM Page 2 of 13 COMPASS 2003.16 Build 73 tl m 1211..1 J imis Y O • . , , M@ I ... ` .. ,K n 101 m N N _ _ .. !' 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These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIIfST WELL NAME i/(,( PTD# 2 -( `/Development Service Exploratory Stratigraphic Test Non-C nventional Well FIELD: POOL: ( LZ(--eI Check Box for Appropriate Letter I Paragraphs to be Included in Transmi al 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 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:9/09/2011 U N a°)i a N N_ O 0 O c0 L - N C • Q -p 7 E o) C 73 C '0 O N a) N o> L o V w... U a 00. 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