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Home My WebLink About212-144Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:212-144 6.50-029-20282-02-00 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 12719 12683 9022 9487 12400, 12664, 12674 None 8177 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" 29 - 109 29 - 109 1530 520 Surface 2667 13-3/8" 28 - 2695 28 - 2695 4930 2670 Intermediate 10028 9-5/8" 26 - 10055 26 - 8635 8150 / 6870 5080 / 4760 Tie-Back Liner 9569 7" 24 - 9593 24 - 8264 7240 5410 Liner 685 3-1/2" x 3-3/16" 9691 - 10376 8342 - 8886 10160 10530 Perforation Depth: Measured depth: 11640 - 12660 feet True vertical depth:9005 - 9021 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 22 - 9800 22 - 8431 9487 8177Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 3079 2-3/8" 9715 - 12719 8362 - 9023 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2419806013 1632577 1012 1 1408 310 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. Sr Operations Manager Operations Performed1. Abandon Plug Perforations 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 measured9023 Sundry Number or N/A if C.O. Exempt: 321-033 Junk Packer Printed and Electronic Fracture Stimulation Data 5 CTU Extended Perf, Pull LTP/Liner Operations shutdown Change Approved Program 5 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 0028311 PBU 06-02B 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 12:13 pm, Aug 24, 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: 2021.08.24 08:26:57 -08'00' Bo York MGR01SEP2021 DSR-8/25/21 SFD 8/24/2021RBDMS HEW 8/25/2021 ACTIVITYDATE SUMMARY 7/8/2021 CTU6 1.5" CT Job Objective: Log & Extended Adperf. MIRU CTU6. MU NS MHA & PT to 3700 psi. MU SLB logging tools and RIH. Tagged up at 10,647' and had to work coil while pumping to get free. Discussed with OE and decided to POOH and RDMO due to history of cement sheath in the well causing issues. On surface w/BHA. Begin weekly BOP testing. ***Job in Progress*** 7/9/2021 CTU6 1.5" CT Job Objective: Log & Extended Adperf. Completed weekly BOP testing. Finish RDMO CTU6. ***Job not completed, postponed*** 7/10/2021 ***WELL S/I ON ARRIVAL*** (Perforating) DRIFT TO 45KB LINER TOP PACKER AT 9,628' MD W/ 3.80" SWAGE (Good ring). LATCH & SHEAR OFF 45KB LINER TOP PACKER AT 9,606' SLM (Poor action & High PUW's). BRUSH & FLUSH (Hot) FROM SURFACE TO LINER TOP PACKER AT 9,628' MD. ***LDFN, WELL S/I & SECURED, CONTINUED ON 7/11/21 WSR*** 7/10/2021 T/I/O= 900/830/475/150. LRS unit 72 Assist Slickline (PERFORATING) Brush and Flush the TBG with 130 bbls of 180* F crude and 10 bbls of 100* F diesel. Final T/I/O/OO= 2450/860/560/150. 7/11/2021 ***CONTINUED FROM 7/10/21 WSR*** (Perforating) PULL BAKER 45KB LINER TOP PACKER FROM 9,628' MD (Hung up in X-nipple at 9,511' MD). JAR FOR 3.5 HRS ON BAKER 45KB LTP AT 9,493' SLM / 9,511' MD (No movement). JOB INCOMPLETE, INSTRUCTED TO RDMO FOR CTU TO COME PULL 45KB LTP. ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 7/12/2021 CTU #6 w/1.5" CT Job Objective: Fish LTP, Ext Adperf. MIRU CTU6. MU BOT fishing BHA, RIH and latch fish. Begin working jars and Bi-Di Hipp Tripper. At 48 cycles - 47 jar licks, no movement of fish. Pump off fish and Pooh w/BHA. Discuss plan forward w/OE. ***Job in Progress*** 7/13/2021 CTU #6 w/1.5" CT Job Objective: Fish LTP, Ext Adperf. On surface w/BOT fishing BHA. Inspect BHA w/Baker rep, 4" Hyd G-spear missing 5 collet dogs. Cut 140' of 1.5" coiled tubing. MU & RIH w/BOT BHA w/venturi & snorkel (2" ID). Work venturi 9370' to 9520'. POOH and MU BOT fishing BHA with weight bars. Latch LTP and perform 50 jar licks, based on depth it appears to have moved ~4.5' up hole. Consult with OE and decide to make one more jar run. Pooh w/BHA. Cut 140' of pipe. MU BOT fishing BHA & RIH. Latch LTP, begin jarring up. ***Job in Progress*** 7/14/2021 CTU #6 w/1.5" CT Job Objective: Fish LTP, Ext Adperf. Continue jarring on LTP 25-29k. At 50 cycles, no movement of fish. Pump off fish. Pooh w/BHA. FP well with 38bbls of diesel. RDMO CTU6. ***Job not completed, LTP left in X-nipple @ 9,511' MD, 5 dogs from 4" Hydraulic GS left in hole*** Daily Report of Well Operations PBU 06-02B Daily Report of Well Operations PBU 06-02B 7/16/2021 ***WELL S/I ON ARRIVAL***(perforating) RAN DOGLESS 4 1/2" PRGS TO LTP @ 9500' SLM; CONFIRMED ABILITY TO SHEAR. SWAP TO 1/4" BRAIDED LINE. RAN 4 1/2" PRGS TO LTP @ 9485' BLM. HIT 6000 - 7000# OJ LICKS FOR 1 HR; STRIPPED PRGS DOGS. SET OLD STYLE 45KB SPEAR IN LTP @ 9480' BLM. HIT 5000 - 6000# OJ LICKS FOR 45 MINS; SHEARED GS. ***WSR CONTINUED ON 7-17-21*** 7/17/2021 ***WSR CONTINUED FROM 7-16-21*** JAR ON 45 KB LTP @ 9,480' BLM FOR 3 HRS & 15MIN (fishing neck stripped off gs core) RAN 3.7" BARBELL CENTRALIZERS W/ 2.25" BLIND BOX TO 9,480' BLM TO SHEAR GS PIN. (swiveled off @ spangs). SWAP TO SLICKLINE. RAN 3.68" BELL GUIDE AND GUTTED 2.5" JD. RECOVERED SPANGS & BLIND BOX ASS'Y FROM 9490' SLM. RAN 3.55" OVERSHOT W/ 2.68" GRAPPLE. RECOVERED 3 1/2" GS (W/ CORE) FROM 9501' SLM. (all components accounted for). ***WSR CONTINUED ON 7-18-21*** 7/18/2021 ***WSR CONTINUED FROM 7-17-21*** RELEASED & PULLED SPEAR FROM 45 KB @ 9,500' SLM JARRED DOWN ON LTP @ 9,500' SLM FOR 4 HOURS W/ NO MOVEMENT. ***WSR CONTINUED ON 7-19-21*** 7/19/2021 ***WSR CONTINUED FROM 7-18-21*** BEAT LTP DOWN OUT OF X NIPPLE @ 9511' RKB. (5 HOURS OF JARRING TOTAL). PULLED 45 KB LTP (missing 2 1/2 elements) RAN 4 1/2" BRUSH, AND 3.74" WIRE GRAB TO 9634' SLM. (recovered large chunk of rubber element) RAN 2 7/8" BRUSH AND 2.23" WIRE GRAB TO 9637' SLM (NO RECOVERY) RAN 2 7/8" BRUSH AND SWORD MAGNET TO 9638' SLM. (NO RECOVERY). ATTEMPT TO RUN 1.84" MAGNET PAST DEPLOYMENT SLEEVE @ 9,640' MD (appears as though an element pulled up hole & fell off @ st#1 @ 9,408' md). MADE MULTIPLE 4 1/2" BRUSH AND 3.74" WIRE GRAB RUNS THROUGH GLM's TO 9632' SLM. (NO RECOVERY). RAN 1.75" PUMP BAILER TO 9703' SLM (RECOVERED 2 CHUNKS OF RUBBER, AND METAL MARKS ON BAILER BTM). ***WSR CONTINUED ON 7-20-21*** 7/20/2021 ***WSR CONTINUED FROM 7-19-21*** MADE MULTIPLE ATTEMPTS TO FISH COIL GS DOGS FROM 9,705' SLM W/ BAILERS, GRABS & MAGNETS. recovered small metal & rubber pieces ***WSR CONTINUED ON 7-21-21*** Daily Report of Well Operations PBU 06-02B 7/21/2021 ***WSR CONTINUED FROM 7-20-21*** VARIOUS RUNS FISHING DOGS & ELEMENT STUCK @ 9,705' SLM RAN WIRE GRAB SPEAR TO 9,705' SLM & PULLED UP WHAT APPEARS TO BE 77' OF 2 3/8" LINER (shook liner off of spear) 3 1/2" DOGLESS GS RUN TO ENSURE WE CAN SHEAR OFF DEPLOYMENT SLEEVE RAN 3 1/2" GR & PICKED LINER UP FROM 9,733' SLM & SHEARED OFF ROG DOWN FOR RIG JOB & UNTIL WE CAN GET A 3RD PARTY CRANE ***JOB INCOMPLETE, DSO NOTIFIED OF STATUS*** 7/23/2021 ***WELL S/I ON ARRIVAL*** (pull parted liner) PULLED 75.4' OF PARTED 2 3/8" LINER FROM 9618' SLM. ***WSR CONTINUED ON 7-24-21*** 7/24/2021 ***WSR CONTINUED FROM 7-23-21*** RAN 1.86" CENT, 5' x 1.5" STEM, AND 1.77" SWAGE. DRIFTED CLEANLY INTO PARTED 2 3/8" LINER; S/D @ 10,505' SLM (61* DEVIATION). *** WELL S/I ON DEPARTUE; READY FOR COIL*** 8/4/2021 CTU #6, 1.5" CT - 25.7 bbl, Job Objective: Extended Addperf. MIRU. RIH with 1.90" convex mill. ...Continued on 05-AUG-2021 WSR... 8/5/2021 CTU #6, 1.5" CT - 25.7 bbl, Job Objective: Extended Addperf. Continue to RIH with 1.90" convex mill. Made it to 12400' ctm and became bit stuck (in the perfs), able to get free, pump 3bbl gel pill while pooh. GS dogs floating around in front of us likely did no favors. Discuss plan forward with town and they are good with not going deeper due to limited pull cabalilities. Pump final gel pill off bottom and chase OOH. MU/RIH w/ READ memory GR/CCL. Log from 12250 to 9450. Paint red/white/blue flag at 11,900'. RBIH to flag and kill well from bottom. Circulate in 200bbl of 1%KCl for well kill. POOH. ...In Progress... 8/6/2021 CTU #6, 1.5" CT - 25.7bbl, Job Objective: Extended Addperf. Confirm good data on log. Perforating BHA is too long, could not reach flag. RIH with 1.75" JSN. Paint new red/white/red flag 11500' corr EOP. POOH. MU/RIH w/ 320' of SLB 1.56 PJ guns. Perforate 11868'-12018 and 12033-12188'. (reference log Baker MWD 1/13/13 depths 11880-12030 and 12045-12200). Well has little injectivity post shot. POOH holding positive WHP. Undeploy perf run #1. Deploy perf run #2. RIH with 145' of SLB 1.56" PJ1606 guns. ...In Progress... 8/7/2021 CTU #6, 1.75" CT - 25.7bbl, Job Objective: Extended Addperf Continue to RIH with perf run #2. Perforate 11,628' - 11,773' (reference log Baker MWD 1/13/13 depths 11,640' - 11,785'). Bullhead 15bbl of 1%KCl down the backside for injectivity test of 0.5bpm at 1000psi. POOH. Undeploy guns. FP well with 38bbl of diesel. Pad op to stack well out in prep for portable well testers. RDMO ***Complete*** 8/12/2021 LRS Well Test Unit 6. Post Perf Flowback. Begin WSR 8/12/21, Perform Unit Move, Spot Unit, Initiate Permit, Rig Up, PT, POP, Flow Well. Inlet W ell 06-02, Outlet Well 06-03. Job in Progress, Continued on WSR 8/13/21 8/13/2021 LRS Well Test Unit 6. Post Perf Flowback. Continue from WSR 8/12/21, Continue to Flow Well. Divert into WPS, Purge, Begin 12 Hr Piggyback Well Test, Abort Test Due to Equipment Issue, Continue Flowback, 5 Hr Piggyback Test Results (Data Tab), Begin 8 Hr Piggyback Test. Inlet Well 06-02, Outlet Well 06-03. Job in Progress, Continued on WSR 8/14/21 8/14/2021 LRS Well Test Unit 6. Post Perf Flowback. Continue from WSR 8/13/21, Complete 8 Hr Piggyback Test. BD, RD. Inlet Well 06-02, Outlet Well 06-03. Job Complete, End WSR on 8/14/21. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:212-144 6.API Number:50-029-20282-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028311 Property Designation (Lease Number):10. 8. PBU 06-02B 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 Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12719 Effective Depth MD: 13Cr80 11. 4/28/2021 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: 5OtherAlter 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): 9023 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 55Perforate Perforate New Pool 9487 , 8177 No SSSV Installed Date: Liner 3079 2-3/8"9640 - 12719 8301 - 9023 11200 11780 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 29 - 109 26 - 10055 26 - 8635 14. Estimated Date for Commencing Operations: BOP Sketch 28 - 2695 Conductor 7240 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 12310 - 12660 9012 - 9021 4-1/2" 12.6# 13Cr80 22 - 9800 Liner 12683 9022 none 12664 , 12674 28 - 2695 2670 9-5/8" 7" Contact Phone:(907) 564 - 5280 Date:4-19-21 5410 2667 493013-3/8"Surface 5080 / 4760 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 80 20"29 - 109 520 Intermediate 10028 8150 / 6870 Tie-back Liner 9569 24 - 9593 24 - 8264 685 3-1/2" x 3-3/16" 9691 - 10376 8342 - 8886 10160 10530 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst 1530 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2406 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. CTU extended perforating By Samantha Carlisle at 3:41 pm, Apr 19, 2021 321-201 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.19 11:16:20 -08'00' Bo York DSR-4/19/21DLB 04/19/2021 X MGR22APR2021 10-404Yesion Required? Comm 4/23/21 dts 4/22/2021 RBDMS HEW 4/26/2021 Extended Add Perf 06-02B PTD: 212-144 Well Name:06-02B API Number:500292028202 Current Status:Shut-In Rig:CTU & Surface Deployed TCP Guns Estimated Start Date:4/28/21 Estimated Duration:2 Days Reg.Approval Req’std?10-403, 10-404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Carrie Janowski Permit to Drill Number:212-144 First Call Engineer:Ryan Thompson 907-564-5280 / 907-301-1240 Second Call Engineer:Dave Bjork 907-564-4672 / 907-440-0331 AFE Number:IOR 240 Current Bottom Hole Pressure:3286 psi @ 8,800’ TVD 7.2 PPGE |7/19/14 Max. Anticipated Surface Pressure:2406psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:780 psi (Taken on 1/6/21) Min ID:1.78” ID @ 9643’ MD Max Angle:93 Deg @ 11,890’ Tie In Log: SLB MCNL 3/24/13 Brief Well Summary: In the summer 2018 gas rates jumped from 15 mmscfd to ~40 mmscfd. A subsequent caliper was run identifying holes in the liner and a organoseal/squezecrete job ensued. Following the squeeze the well would not flow and SL identified an obstruction at ~10,424’. In January 2021 coil performed a FCO to ~12,620’ but the well still will not flow. Assuming formation damage, the toe perfs were re-perfed in February 2021. The well came on low rate with little formation gas and needed gas lift to flow. Objective: The objective of this program is to add additional perforations in the horizontal of the well to bring in more rate. Cerberus Modelling suggests making TD with ~560’ of 1.56” guns w/ 1.5” coil tubing (.109 wall thickness). Extended Add Perf 06-02B PTD: 212-144 Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perf 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 and spot ancillary equipment. 2. MU and RIH with GR/CCL logging tools and ~1.7” nozzle. Pull jewelry log for tie in. 3. Circulate ~235 bbls of 8.4 ppg 1% KCl or 8.5 ppg seawater to kill the well as the well has limited injectivity. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perfs = ~156 bbls 4. POOH and confirm good data. 5. Contact OE prior to perforating for final approval of tie-ins. 6. Freeze protect tubing as needed. 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 or 8.5 ppg as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. 8. Pickup 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 and blanks per schedule below. 06-02B Addperf Schedule (tie in log depths) Re-Perf Interval Perf Length 11628- 11773 145 11868 - 12018 150 12033 - 12188 155 ***Note reference log depths are 11640 – 11785, 11880 – 12030, & 12045 – 12200 (Baker MWD 1/13/13). There is a -12’ shift from the reference log to the tie in log. Please note reference log depths in AWGRS*** 10. RIH with perf gun and tie-in. Pickup and perforate intervals per Perf Schedule above. POOH. a. Note any tubing pressure change in WSR. 11. POOH. Stop at surface to reconfirm well is dead and hole is full. * *See note above regarding kill methods if pressure observed on surface after perforating. Standing orders flowchart included in this program for well flowing while picking up guns. Extended Add Perf 06-02B PTD: 212-144 12. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 13. RDMO CTU. 14. 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 Extended Add Perf 06-02B PTD: 212-144 As-built Schematic Extended Add Perf 06-02B PTD: 212-144 Proposed Schematic Extended Add Perf 06-02B PTD: 212-144 Coiled Tubing BOPs Extended Add Perf 06-02B PTD: 212-144 Equipment Layout Diagram Extended Add Perf 06-02B PTD: 212-144 Standing Orders for Open Hole Well Control during Perf Gun Deployment Standing Orders for Service Coiled Tubing Operations While Deploying Extended Length Perforating BHA WELL BEGINS FLOWING DURING OPEN HOLE DEPLOYMENT Pull BHA above blind/shear rams, and close blind/shears. Space out BHA with safety joint above slip bowl, set hand slips Install safety joint with open TIW Can BHA be pulled above blind/shear rams in a single pick? Pull hand slips YES NO Begin Notifications Close Upper Pipe/Slip Ram Close TIW Close choke valves, monitor and record SIWHP Close choke line. Monitor and record SIWHP Lower safety joint and space out over BOP, set hand slips Begin Notifications Extended Add Perf 06-02B PTD: 212-144 Tie-In Log Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:212-144 6.50-029-20282-02-00 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 12719 12683 9022 9487 12664,12674 none 8177 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" 29 - 109 29 - 109 1530 520 Surface 2667 13-3/8" 28 - 2695 28 - 2695 4930 2670 Intermediate 10028 9-5/8" 26 - 10055 26 - 8635 8150 / 6870 5080 / 4760 Tie-back Liner 9569 7" 24 - 9593 24 - 8264 7240 5410 Liner 685 3-1/2" x 3-3/16" 9691 - 10376 8342 - 8886 10160 10530 Perforation Depth: Measured depth: 12310 - 12660 feet True vertical depth:9012 - 9021 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 22 - 9800 22 - 8431 9487 8177Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 3079 2-3/8" 9640 - 12719 8301 - 9023 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 28053000 5848 1600 0 106 303 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 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 measured9023 Sundry Number or N/A if C.O. Exempt: 321-033 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 028311 PBU 06-02B 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 no SSSV By Samantha Carlisle at 10:04 am, Mar 04, 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: 2021.03.03 19:45:59 -09'00' Bo York DSR-3/4/21 SFD 3/12/2021RBDMS HEW 3/5/2021MGR12MAR2021 ACTIVITYDATE SUMMARY 2/7/2021 T/I/O/OO = SSV/280/340/140. Temp = SI. Bled IAP to 800 psi (Pre coil). IAP blelow 800 psi. Bleed not needed. Monitored WHPs SV, MV, SSV = C. MV = O. IA, OA, OOA = OTG. 03:30 2/14/2021 CTU #9 - 1.50" Coil Job Objective: Extended AddPerf MIRU CTU. PT Safety joint and pump 1.0" drift ball through coil. Make up GR/CCL drift/log BHA and RIH. POOH from 8900 after BOP hose leak. ...Job Continued on 2/15/2021...... 2/15/2021 CTU #9 - 1.50" Coil ....Continued from 2/14/2021... Job Objective: Extended AddPerf Continue POOH with logging tools. OOH with logging tools and make repairs to hydraulic leak. RIH with logging tools. Tag in GLM #2 at 8330' CTMD. Unable to pass, POOH. Lay down tools and trim coil. Standby for weather. Make up drift/logging BHA #2 and RIH. Tagged at 10594 and became detained. Stopped operation due to temperature. ...Job in Progress...... 2/16/2021 CTU #9 -1.50" Coil **Cont. from WSR 2-15-21** Job Objective: Extended AddPerf Return to work after low temps. Circulate Powervis at high rate and able to POOH. Lay down logging BHA. Standby for low temps. Make up 1.69" venturi. RIH. ...Job Continued on 2/17/2021.... 2/17/2021 CTU #9 -1.50" Coil **Cont. from WSR 2-16-21** Job Objective: Extended AddPerf Continue RIH with 1.69" venturi BHA, max OD 1.70". Run venturi from liner top to 12630' CTMD. Recip up above LNR top chasing gel sweep. Slow to a creep while circing gel sweep to surface. Shut down pumps and dry drift to 12650' CTMD with no issues. POOH. Recovered chunks of rubber from venturi. RIH with logging BHA and log fromn12650 to 11850. Pipe flagged at 12249.9. Circulate well kill and freeze protect well with 60/40. Go on weather standby due to low temps. ...Job Continued on 2/18/2021....cp 2/19/2021 CTU 9 1.5" CT Job Scope: Log and Extended Add Perf. Off weather hold at 08:00 hours, Recover good data from memory tool. Corrolate depth with SLB Memory compensted neutron log. 24-MARCH-2013. Depth correction of -2'; OE- Ryan Thompson, verified. Deploy and MU 290' of 1.56" Geo Razor TCP guns to end of pipe. RIH to flag on CT for depth correlation. Correct depth to bottom shot on BHA. Run past target depth and pull back up to shooting depth using bottom shot. 12588' corrected depth. Launch 1/2" aluminum ball. Perforate 12310-12600 per reference log Baker MWD 1/13/13. Got detained 300' up from perf interval. Circ out and coil is free. While circulating, took gas returns at surface. Perform injectivity test - .4bpm at 1700psi. Circulate in well kill. POOH. ...Job Continued on 2/20/2021... 2/20/2021 CTU 9 1.5" CT Job Scope: Log and Extended Add Perf. Continue POOH after well kill. Retrieve 290' of perf guns. Well freeze protected with 38bbl of 60/40. DSO notified of well status. RDMO. ...Job Complete...cp Daily Report of Well Operations PBU 06-02B Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:212-144 6.API Number:50-029-20282-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028311 Property Designation (Lease Number):10. n/a 8. PBU 06-02B 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 Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12719 Effective Depth MD: 13Cr80 11. 2-10-2021 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: 55OtherAlter 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): 9023 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9487 / 8177 No SSSV Installed Date: Liner 3079 2-3/8"9640 - 12719 8301 - 9023 11200 11780 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 29 - 109 28 - 2695 28 - 2695 14. Estimated Date for Commencing Operations: BOP Sketch 28-2695 Conductor 7240 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 12310 - 12660 9012 - 9021 4-1/2" 12.6# 13Cr80 22 - 9800 Liner 12683 9022 none 12664,12674 28 - 2695 2670 9-5/8" 7" Contact Phone:(907)564-5280 Date: 1-14-2021 5410 2667 493013-3/8"Surface 5080 / 4760 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 80 20"29 - 109 520 Intermediate 10028 8150 / 6870 Tie-back Liner 9569 24 - 9593 24 - 8264 685 3-1/2" x 3-3/16" 9691 - 10376 8342 - 8886 10160 10530 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst 1530 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2406 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. CTU & surface deployed TCP guns By Samantha Carlisle at 9:17 am, Jan 19, 2021 321-033 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.15 12:20:22 -09'00' Bo York X DLB 01/19/2021MGR19JAN21 DSR-1/19/21 10-404Yeon Required? Comm 1/22/21 dts 1/20/2021 JLC 1/22/2021 RBDMS HEW 1/27/2020 Extended Add Perf 06-02B PTD: 2121440 Well Name:06-02B API Number: Current Status:Shut-In Rig:CTU & Surface Deployed TCP Guns Estimated Start Date:02/10/2021 Estimated Duration:2 Days Reg.Approval Req’std?10-403, 10-404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Carrie Janowski Permit to Drill Number:2121440 First Call Engineer:Ryan Thompson 907-564-5280 / 907-301-1240 Second Call Engineer:Dave Bjork 907-564-4672 / 907-440-0331 AFE Number:205-04002 IOR 300 Current Bottom Hole Pressure:3286 psi @ 8,800’ TVD 7.2 PPGE |7/19/14 Max. Anticipated Surface Pressure:2406psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:780 psi (Taken on 1/6/21) Min ID:1.78” ID @ 9643’ MD Max Angle:93 Deg @ 11,890’ Reference Log: SLB MCNL 3/24/13 Brief Well Summary: In the summer 2018 gas rates jumped from 15 mmscfd to ~40 mmscfd. A subsequent caliper was run identifying holes in the liner and a organoseal/squezecrete job ensued. Following the squeeze the well would not flow and SL identified an obstruction at ~10,424’. In January 2021 coil performed a FCO to ~12,620’ but the well still will not flow. Current injectivity is .1 bbl/min @3000 psi. Objective: The objective of this program is to re-perforate 290’ of existing perforations to remove skin damage and get the well to flow. Cerberus Modelling suggests making TD with ~300’ of 1.56” guns w/ 1.5” coil tubing (.109 wall thickness). Extended Add Perf 06-02B PTD: 2121440 Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perf 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 and spot ancillary equipment. 2. Bullhead ~235 bbls of 8.4 ppg 1% KCl or 8.5 ppg seawater down the tubing to the formation. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perfs = ~156 bbls 3. MU and RIH with GR/CCL logging tools and ~1.7” nozzle. Tag PBTD prior to logging OOH. Last tag was ~12,621’ CTMD. 4. POOH and confirm good data. 5. Contact OE prior to perforating for final approval of tie-ins. 6. Freeze protect tubing as needed. 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 or 8.5 ppg as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. 8. Pickup 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 and blanks per schedule below. 06-02B Addperf Schedule Re-Perf Interval Perf Length Gun Length 12310 - 12600 290 290 10. RIH with perf gun and tie-in. Pickup and perforate intervals per Perf Schedule above. POOH. a. Note any tubing pressure change in WSR. 11. POOH. Stop at surface to reconfirm well is dead and hole is full. 12. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 13. RDMO CTU. 14. RTP or FP well. Standing orders flow chart included with this sundry request. * *See note above regarding kill methods if pressure observed at surface after perforating. assure excess fluids available. Extended Add Perf 06-02B PTD: 2121440 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 Extended Add Perf 06-02B PTD: 2121440 As-built Schematic Extended Add Perf 06-02B PTD: 2121440 Proposed Schematic Extended Add Perf 06-02B PTD: 2121440 Coiled Tubing BOPs Extended Add Perf 06-02B PTD: 2121440 Equipment Layout Diagram Extended Add Perf 06-02B PTD: 2121440 Standing Orders for Open Hole Well Control during Perf Gun Deployment Standing Orders for Service Coiled Tubing Operations While Deploying Extended Length Perforating BHA WELL BEGINS FLOWING DURING OPEN HOLE DEPLOYMENT Pull BHA above blind/shear rams, and close blind/shears. Space out BHA with safety joint above slip bowl, set hand slips Install safety joint with open TIW Can BHA be pulled above blind/shear rams in a single pick? Pull hand slips YES NO Begin Notifications Close Upper Pipe/Slip Ram Close TIW Close choke valves, monitor and record SIWHP Close choke line. Monitor and record SIWHP Lower safety joint and space out over BOP, set hand slips Begin Notifications Extended Add Perf 06-02B PTD: 2121440 Tie-In Log STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ld Re-enter Susp Well ❑ Other: Cement Squeeze - Liner 2. Operator Name: BP Exploration (Alaska), Inc 1 4, Well Class Before Work Development m Exploratory ❑ 5. Permit to Drill Number: 212-144 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20282-02-00 7. Property Designation (Lease Number): ADL 028311 8. Well Name and Number: PBU 06-02B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL RECEIVEE 11. Present Well Condition Summary: Total Depth: measured 12719 feet Plugs measured None feet OCT 2 2 2019 true vertical 9023 feet Junk measured 12664, 12674 feet Effective Depth: measured 12683 feet Packer measured 9487 feet true vertical 9022 feet Packer true vertical 8177 feet gOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" 29-109 29-109 1530 520 Surface 2667 13-3/8" 28-2695 28-2695 4930 2670 Intermediate 10028 9-5/8" 26-10054 26-8634 8150/6870 5060 / 4760 Tie -back Liner 9569 7" 24-9593 24-8264 7240 5410 Liner 685 3-1/2" x 3-3/16" 9691-10376 8342-8886 10160 10530 Liner 3079 2-3/8" 9640-12719 8301 -9023 11200 11780 Perforation Depth: Measured depth: 12310 - 12660 feet True vertical depth: 9012 - 9021 feet feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 22-9800 22-8431 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Penn Packer 9487 8177 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Cement Squeeze performed on 9127/19 to shut off holes in the liner Park Coil at 9550' (above TOL). Bullhead Kill well w/ 1% KCL w/ Safelube. Pump Organoseal & displace viith Diesel down backside. Pump 25bbls of 15.8ppg Squeeze Crete. Squeeze 24bbls away, achieve 3000psi squeeze pressure. Plugs/debris milled and pushed below open perfs. Intervals treated (measured): 9714'- 9877' (Liner Holes) Treatment descriptions including volumes used and final pressure: 25bbls 15.8ppg Squeeze Crate. Final Pressures: OA: 187 psi, IA: 811 psi, TBG: 841 psi 13. Representative Daily Average Production or Injection Data Oil -B01 Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 608 39058 72 0 765 Subsequent to operation: 5 14046 0 0 800 14. Attachments: (required per 20 nnc 25.070.25.071, &25283) 15. Well Class after work: Daily Report of Well Operations EI Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil IZ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Thompson, Ryan Contact Name: Thompson Ryan Authorized Title: Petroleum Contact Email: RYAN.THOMPSONLQbp.com /Engineer n Authorized Signature: f'" /t_ Date: I O �Z I / Contact Phone: +1 907 564 4535 Form 10-404 Revised 04/2017 / 3 B DMS} OCT 2 2 2019 T ,411,11f Submit Original Onq ***WELL FLOWING ON ARRIVAL*** (Cement squeeze) RIG UP SWCP 4516 TO DRIFT TO DEVIATION W/ 1.75" SAMPLE BAILER. 9/16/2019 ***JOB IN PROGRESS, CONTINUED ON 9/17/19 WSR*** ***CONTINUED FROM 9/16/19 WSR*** (Cement squeeze) DRIFT TO DEVIATION AT 10,627' SLM W/ 1.75" S-BLR (No issues or sample). SET 4-1/2" WHIDDON C -SUB ON 4-1/2" LTP AT 9,623' SLM / 9,628' MD. PULL BK-DGLV FROM ST #3 (6,788' MD) & BK-LGLV FROM ST #4 (3,529' MD). SET BK-DGLV AT ST #4 (3,529' MD). LRS LOADED IA W/ 145 BBLS OF CRUDE. SET BK-DGLV AT ST #3 (6,788' MD). PULL EMPTY 4-1/2" WHIDDON CATCHER SUB FROM 9,928' MD. INSTRUCTED TO RDMO DUE TO RIG JOB ON AAO -111. 9/17/2019 ***HAND WELL OVER TO LRS, NOTIFIED DSO OF WELL STATUS*** T/I/O 2500/2500/275. OOA= 88 psi. (LRS Unit 46 - Assist Slickline: Load and Kill / Injectivity Test / MIT -IA) Pumped 5 bbls 60/40, followed by 145 bbls crude down IA to load. Slow rate at 120 bbls away to 1 bpm. Slickline to set DGLV. Slickline called off for another job. Perform the rest of the job stand alone. Load wellbore w/ 156 bbls crude to fluid pack well. Establish the following injectivity rates w/ an additional 119 bbls crude: 1 bpm = — 215 psi / 3 bpm =—550psi / 5 bpm =-945 psi 2 bpm = —400 psi / 4 bpm = —737 psi Freeze protected FL with 5 bbls 60/40 meth followed by 63 bbls crude. SI IGV Pressured FL to 1500 psi. MIT -IA PASSED to 2326 psi Max Applied Pressure=2500 Target Pressure=2250 psi) Pressured IA to 2429 psi with 2.17 bbls of crude.MlT-IA lost 90 psi in the first 15 minutes and 13 psi in the 2nd 15 minutes for a total of 103 psi during a 30 min test. **Tubing to IA Surface Differential (if needed) not met due to slickline being called off for another job and subsequently not setting a plug** 9/17/2019 WSR continued on 09/18/19*** *** WSR continued from 09/17/19*** (LRS Unit 46 - Load and Kill / Injectivity Test / MIT -IA) Bled IA pressure to 362 psi rcovering — 2.1 bbls. Rigged down. SVANV/SSV=C MV=O CV's=OTG. Hung 9/18/2019 tags on WV/IA CV. AFE sign hung on MV FWHP's=280/400/180/110 CTU #8 1.50" Coil - OrganoSeal/SqueezeCrete MIRU. MU 1.75" DJN drift. Open well and RIH while killing well with 1 % KCI w/ Safelube. 9/19/2019 *** In Progress *** CTU #8 1.50" Coil - OrganoSeal/SqueezeCrete RIH with READ logging BHA - caliper/GR/CCL. Log from 12663ft to 9350ft. POH. MIT -IA to 2380 psi - Passed. Confirm good data and correct -10.5 to tie-in log. Freeze protect well. RD and go to maintenance while waiting on acid transport and pump crew. 9/20/2019 *** Incomplete *** CTU #8 - 1.50" coil, 0.109" WT / Job objective: OranoSeal/SqueezeCrete MIRU. MU & RIH w/ nozzle BHA. Pump 20bbls 12% HCL & jet across holes from 9707ft to 9870ft. POH. 9/24/2019 ***In Progress' CTU #8 - 1.50" coil, 0.109" WT / Job objective: OrganoSeal/SqueezeCrete Continue to POH. MU & RIH w/ BOT 2-3/8" CBP. Set top of CBP at 12,275ft. Injectivity test. POOH. MU 1.50" JSN with No Checks and RIH. ag at an H to 7500'. 9/25/2019 ***In Progress' Daily Report of Well Operations PBU 06-02B CTU #8 - 1.50" coil, 0.109" WT / Job objective: OrganoSeal/SqueezeCrete Continue to wait on OrganoSeal Lab Testing_ Park Coil at 9550' (above TOL). Bullhead Kill well w/ 1% KCL w/ Safelube. Pump Organoseal & displace with Diesel down backside. Pump 25bbls of 15.8ppg Squeeze Crete. Squeeze 24bbls away, achieve 3000psi squeeze pressure. Begin cleaning out. 9/26/2019 ***In Progress*** CTU #8 - 1.50" coil, 0.109" WT / Job objective: OrganoSeal/SqueezeCrete Attempt to contaminate/cleanout cement down to plug. Tag hard cement at 10992', unable to jet thru. Pump 19 bbl gel pill. Lay in gel in liner above TOC. Chase ooh at 80%. Jet TOL & jewelry on way ooh. Lay in 50/50 Methanol Freeze Protect from 2500' tvd. Rig down CTU. TOC Depth — 10992'. 9/27/2019 ***Job Cam lete*** T/1/0=102/vac/255 Temp SI MIT T (Post cement) MIT TBG Pass (0 1375 psi Tar et 1350 psi Max applied 1500 psi) Pumped 0.28 bbls 80* Crude to reach test psi. Ran test out for 4 15 min sections. In 3rd 15 min TBG lost 22psi and in the 4th 15min TBG lost 20 psi for a total loss of 42 psi in a 30 9/30/2019 min test. *****Job continued on 10/01/19*** CTU#8 1.5" CT. Job Scope: Mill Cement & CBP MIRU CTU. MU & RIH w/ Baker 1.69" Milling BHA w/ 1.75" Junk Mill. Take returns while rih. Dry Tag TOC at 10857'. Mill cement down to 11407'. 10/1/2019 ***Continue Job on 10/2/2019 WSR*** Job continued from 09/30/19 (MIT -T post cement Job) Rigged down job post passing MIT -T. 10/1/2019 SVNW/SSV= Shut MV/IA/OA= Open FWHPs=500/60/261 CTU#8 1.5" CT. Job Scope: Mill Cement & CBP Continue milling cement down to 12260'. Pump gel sweep & circulate btms up. Mill CBP and push to 12345' ctm. 10/2/2019 ***In Progress' CTU#8 1.5" CT. Job Scope: Mill Cement & CBP Push CBP to 12355' then quit making progress. Pooh to inspect tools. At surface, mill was worn & circ -sub was leaking. Stack down & change packoffs/chain inspection. Trim 115' of pipe. MU & RIH w/ Baker 1.69" Milling Assy w/ 1.75" Junk Mill. Dry tag plug at 12362'._ Mill/push plug to 12664CTM. Open circ sub and chase gel pill al the way to surface. 10/3/2019 ***In Progress' CTU#8 1.5" CT. Job Scope: Mill Cement & CBP Continue to chase gel pill al the way to surface. Freeze protect well with 38bbl of 50/50. Mill had nominal wear around the edge and zero wear on the face. RDMO. 10/4/2019 ***Job Com lete*** TREE = 4" FMC 120 ar,t v= MD KOP= 3200' Max Angle = 94" @ 11890' H40, Datum MD = 1036T D =19.124" Datum ND= 880(y ss 9-5/8• CSG, 474, SOFT RS -95 XO 7014-80 BUTT 09/17/19 3 13-3/8• CSG, 72#, J&L "0 BUTT, D = 12.347- 19-5/8- CSG, 47#, "0 XO TO SOFT RS -95 BUTT 8216' 4-1/2• TBG RJNCH (12/16/121 9401' Note: Minimum ID =1.781" @ 9643' 2-3/8" R NIPPLE IN LTP w/PTSA -5/8" FOC -5/8" FOC EST TOP OF CEMENT (07, r.A.R i rTUAmnaci a ST MD ND DEV TWE VLV LATCH PORT DATE 4 3529 3516 17 KBG-2 DMY BK 0 09/17/19 3 6788 5992 41 KBG-2 DMY BK 0 09/17/19 2 8410 7295 36 KBG-2 DMY BK 0 07/19/03 1 9408 8113 35 KBG-2 DMY BK 0 07/19/03 4-12" HES X NP, ID = 3.813" 9487' 1-17" X 4-12" SKR S-3 PKR, D = 7" T1EBK LNR, 26#, L-80 BTC -M, 9593' 9628' 4-12' LTP w /N. SOLUTIO .0383 bpf, D = 6.276" NP @ 9643' (10/26/17) 9640' 2-7 X 2.25" BIR DEPLOY I Ka 9691' —13.70" BKR DEPLOY SLV, D = 3.( L-80 STL, .0087 bpf, D = 2.992" 9744' 9712' 3-1/2" OTts X NP, D = 2.812' 9744' 3-12" X 3-3/16• XO. D = 2.786" 12" TBG, 12.6#, 13CR VAM ACE,9800' 152 bpf, D= 3.958- 9-5/8- CSG, 47#, SOFT RS -95 9977' XO TO SOFT 14-80 BUTT 70, SOFT N-80 BUTT, D=8.681• —10064 3-3/16• BKR WHIPSTOCK(12/14/12) 10380' 62#, 1-80 TCA, .0087 bpf. D = 2.80"� 4 PERFORATON SUMMARY REFLOG: ANGLE ATTOP PERF: 12310° @ 88' 0325/13 Pi 12683' L-80 STL, .0039 bpf, D = 1.995" 12719• HES XN ---- I_ .,_ --- BEHIND 9899' CASING HOLE 9896'- 9929' LNR (RIG SOZ 0122/90) MLLOUT WINDOW (06-02A) 10054' - 10064' MLLOUT WINDOW (06-028) 10376'- 10382' 12664' CTM DATE REV BY COMMENTS DATE REVBY COMMENTS 10130/78 N1ES NIT0IL COMPLETION 0528!13 7J/PJC FINAL ODE APPROVAL O7N9103 N4ES RWO 10!31/17 CJN/J., SETLTPWPTSA&RNPPLE 0604)05 JOMWJC CTU 93-12• LNR 09/18/19 JPKUMD GLV CIO (09/17/19) 05)07N7 NORDIC CTD SIDETRACK (06-02A) 10)02/19 TFA/JMD SETCBP&CMTPLUG 0126H3 ORDIC CTD SIDETRACK (06-026) 10)07/19 JDM/JMD MLLED CMT & PLUG -SET FISH 0326M3 ORDIC PERFORATIONS (06-028) CEMENT PLUG & CBP MILLED (10/0'. BROKEN MILL FROM COIL PUSHED V FROM 10548' SLM (03/13/131 PRUDHOE BAYUNIr WELL: 06-02B PERMIT No: '2121440 AN No: 50-029-20282-02 T10N, R14E, 607' FSL & 1164' FEL BP Exploration (Alaska) RECEIVED STATE OF II ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed V 7 ?O1( Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operatio t n ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change A" ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well II Re-enter Susp Well 0 Other: Set Liner Top Packer EL 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work . 5. Permit to Drill Number: 212-144 3. Address: P.O.Box 196612 Anchorage, Development 10 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20282-02-00 7. Property Designation(Lease Number): ADL 0028311 8. Well Name and Number: PBU 06-02B 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 12719 feet Plugs measured feet true vertical 9023 feet Junk measured 12674 feet Effective Depth: measured 12683 feet Packer measured 9487 feet true vertical 9022 feet Packer true vertical 8177 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2671 13-3/8"72#N-80 28-2699 28-2699 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 12310-12660 feet True vertical depth: 9012-9021 feet feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 22-9805 22-8434 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): nn Treatment descriptions including volumes used and final pressure: CANNED - V . 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 787 36896 32 ' 389 818 Subsequent to operation: 620 10460 26 412 817 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.2831 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 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 Authorized Name: Odom,Kristine Contact Name: Odom,Kristine Authorized Title: DS 06&13 PE Contact Email: Kristine.Odom@bp.com Authorized Signature: 4.-___— Date:,44V 17 2Q97 Contact Phone: (907)564-5365 Form 10-404 Revised 04/2017 it:W.7 V TL 11 -/12- RE:Z.3 \ 1 i.,' ,' i I. ::-:. -i-7 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary November 17, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Liner Top Packer for Well 06-02B, PTD # 212-144. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • 210 CD CD CD CD co CD CD w 000 cp r- 15 CD N C- D Ns ct O O N- . co co O O () +L *i.:(3 'C) O- 53 CC) N- O CO CO M T- 00 C N- cOCOOD0000TOoOD O OD O O CO QD Ql M CO U CD CO CD N- O Co) N co co M CO N N T CO CO O M CflTT NOON N- 000OOOCDODOCO I— CA O QD CO - N CD C D OD CO 0) N- O O V O N N N N N N T CO M M N N N- CO 00 00 00 OD 4.0 CD cp CO CD CDN CO 0tr)CD T- in O T- CO C D N CU3 CV NO 00) O O N CD O CD A- TT TT T- o MM 2 I 1 1 1 I 1 1 1 1 1 1 1 W N CA OT- OO e- CO O CD 00 O Cn N 00 E t O) N- N N N N N N ONO OO) O OO) O0) CC) N MM_ : W O O CI. 0 C O cn CD O O O C) Co o � � OD aDaDODVO a ".2 C N N J 4t 4t4 N- M I •� N O V �t 4 r- .4- O N N_ O C.) O M \0� 00 M C N N '- O d) C3) N M V- M 4 J: _ 01 CO CD O Ns Ns v-Ns N CO CO N- Ns N ONO J CO co CD up N Q0 co M M N CD w w w w w w Q Q Q Q Q Q c 0 0 0 0 0 0 •Nowwwwwww o u_ cC cC or cC pc or or or or z zrWI- I- I- 1Wwwwm ODZZZZZZzzzI_ • • Packers and SSV's Attachment PBU 06-02B SW Name Type MD TVD Depscription 06-02B TBG PACKER 9486.92 8177.15 4-1/2" Baker S-3 Perm Packer 06-02B PACKER 9634 8296.52 4-1/2" Baker KB LT Packer • 40 0 2 o $ a) a J co _ 0, 3 o Eo O O _oo W CO CO I70 .(7) "� � O °D v N C 0 Q a II • C Cl)u' > EE cuLnO a 0 w = = 15 .- cca E 2 J 0_ 0_ c " a) ao coo w o _Ic/) aa-0 E - a) 0 •N 41 ) C) m 3 0 - p 7w a cq a) O Q H v- 1- '5 •a Ia) ..- > 700 c W O N < . a u) ° C C 2 Cn E @ O � � o Dam rn o «- C ccdi 0 C° rn0 F-- g -� 0 2 O >- `E J C ��O`` U W L J _ >W> a) O N 0 NC E 4+ Q' (/) O N V 0 0 d N › 0 -1 O 0 .... c., E i Q 0 o o m w a-) Z Z ,-,z C° IL 22 1-1--0 = m m m Q CD a) a 22 ,� _ °) > a) � p � °) O � � a Orn Cl) >, fl- 2 ,« F- mv2@� W •co co kw N 3 -0 O rnco NH c v- O m a f/) O E W J W Q o w m w c0 N O 0_ 11 = 6 -0 NO d I j o a) O W a H o W J ,c N p 0 2 w CD * O co) oCL -I a0 z ? 0O ja - 0 IN 0 JH oa0 � wF- w0w0Z - 0- 4-' <- M O M < N O * Rw gip ? 2wuL ' O -C xMJ OdE � � iaP � Oai32LH0 JQ �o = m re wO __, .N - O a/ ZQ - N „ m mLox , ZD II 0 m § 0 ,,, p � , OU _i - NN ---6-- (7, , , 0, -0 E M •� ZH A w m N >N a (n C7 �' N O U ND-40 .c _ 1- ,O N Lo N > W O0 _cJo la. ,- N p �O2tm >Z O 0 Z 1- m o N w ” _M5 E - m N Y U > Wm OmJZ Z ~ ce 'co2 ZUO M a) O Z p 2 0 > w w c) o-� crbo 0 °° "- U) w' O_0L c -I : -3 - -) 00 0wcl c 0 c � oiN mmv .2 ca JYF- Y1= iJi0 OOCOLULL vm -O 1- a) m J Q C a) a) m a a) W -10 O LL Ch C _1 O m m 0 W N 45 O 0 0 0 O O a) � V - Ocoz -ozwzvi- w __I 0 v w N ac mv10 'O - a) a) O O m : Q : _1Ix •rnrx _iccaoicwn -Ja : I- Nc00 ddto = 0co0 w QIN. 0 0 0 0 0CD >- NN N N 0 N- 1- 0 1.0 0 0 m , O N 5 NN N N F O OO 0 0 ,- .- r- r- TREE= 4"FMC 120 • WTiLI-EAD= FMC 06-02 B SA IV NOTES: WELL ANGLE>70"@ 10555'. ACTUATOR= BAKER C ***4-1/2"CHROME TBG*** NTlAL KB.FILE 64' ( ELJ:V= 2 20"COLD, H 100' KOP= 3200 ' I_ 2121' J 14 1/2"1€S X NP,D=3.813" __-- Max Angle= 94'@ 11890' 94/1,H-40, Datum MD= 10363' 0=19.124" 2316' H9-5/8"FOC Datum TVD= 8800'SS II 2441' ---I 9 5/8"FOC 19:5/8"CSG,47#,SOFT RS-95 XO TO N-80 BUTT H 2296' 3160' HEST TOP OF Ca ENT(07/19/03 RWO) 13-3/8'CSG,72#„.18.L.N-80 BUTT,D=12.347' H 2696' 4. 4 4 GAS LFT MOURELS .' � ST MD TVD DEV TYPE VLV LATCH PORT DATE 1. ►: 4 3529 3516 17 KBG-2 OOME BK 16 04/06/13 19-5/8"CSG.47#,N-80 XO TO SOFT RS-95 BUTT 1—I_ 8216' 1— 4 L ►, ♦ 3 6788 5992 41 KBG-2 SO BK 24 04/06/13 � 4-1/2"TBG RICH(12/16/12) —{0101*-9106' /. ►•• M'2 8410 7295 36 KBG-2 DMY BK 0 07/19/03 •s. 0 '• 1 9408 8113 35 KBG-2 OBK 0 07/19/03 • 4' , • 9466' — BS-14-1/2"FX NP,D=3.813- Minimum ID =1.781" x@9643' .� ;• 2-3i8" R NIPPLE IN LTP w/PTSA 1!, _ 9487' H7-x 4-1/2"BKR S-3 RCR D=3.875' I • �4 , ;. 9611' I—I4-1/2-HES X NP,D=3.813' I / • 7"TFEBK LNR,26#,L-80 BTC-M, — 9593' '� � 9628' I 4-1/2"LTPw/N.SOLUTIONS PISA&R .0383 bpf,D=6.276" NP@ 9643'(10/26/17) X41. 9640' 12-7 X 2.25"BKR DEPLOY SLV,D=2.250" '41 ` w/SCOOP GUIDE(TOL) 16 ,I1 I- MI= 3.70"BKR DEPLOY SLV,D=3.00- 1,- ' ' 9712' I3-1/2"OTIS X HP,D=2.812- 3 1/2"LFR,9.3#,L-80 STL,.0087 bpf,D=2.992' 9744' I �4 y ` 9744' --I 3-1/2"X 3-3/16-XO,D=2.786' ,J` ` 9778* —i4-1/2'HES XN NP,MILLED TO 3.80(4/12/11) 4-1/2'113G,12.61/,13CR VAM ACE 9800' I .0152 bpf,I)=3.958' ��1 '4,.Z J." 9800' 4 1/2'WLEG,D=3.958" BEHIND �� 44 'I�I�I 989W I- CASING HOLE 9898'-9929' LNR ��I�I1 ISI i 9-5/8"CSG,47#,SOFT RS-95 H 9977' 1- i, *'1 r t (RIG SQZ 01/22/90) III II XO TO SOFT N-80 BUTT ►a:%.1 .�.r ►'VV 1 ;VIC III 1 Ate.„ CSG,47#,SOFT N-80 BUTT,D=8681" -I -10064 - � MLLOUT WADOW(06-02A) 10054'-10064' 1 3-3/16'BKRINFPSTOCK(12/14/12) —I 10380' %N., 1 1 1 MLLOUT WNDOW(06-02B) 10376'-10382' 3-3116'LNR,6.2#,L-80 TC/,.0087 bpf,D=2.80" H —10382 I----- 41 N PERFORATION Sl8A1ARY REF LOG: ANGLE AT TOP PERF:12310"@ 88' Note:Refer to Production DB for historical perf data — SIZE SFF INTERVAL OPWSOZ SHOT SQZ 1.56" 6 12310-12660 0 03/25/13 I PBTD)I—L 12683' I 4' 12674'Ctm 1 FISH BROKEN MILL FROM COL PUSHED :•w DOWN FROM 10548'SLM(03/13/13) 2-318-LNR,4.7#,L-80 SIL,.0039 bpf,D=1.995' --{ 1271W DATE REV BY COJU'fTS DATE REV BY COMMENTS R&EHOEBAY UNT 10/30/78 NIES INTIAL COMPLETION 04/23/13 SWC IAC GLV CIO(04/06/13) WELL: 06-02B 01/19(03 N4ES FANO 05/28/13 TJ/PJC FINAL ODE APPROVAL PERMIT No:12121440 06/14/05 JGM/PJC CTU 9 3-1/2"LM 07/30/14 MGS/JMD SET 45 KB LTP(07/25/14) AR No: 50-029-20282-02 05/07/11 NORDIC CTD SIDETRACK(06-02A) 01/13/15 JMG/JMD RLL 45KB LTP(01/11/15) SEC 2,T1ON,R14E,607'FSL&1164'FEL 01/25/13 rNORDIC:CTD SIDETRACK(06-02B) 10/31/17 CJWJMD SET LTPw/PTSA&R N TLE 03/26113 NORDIC:PERFORATIONS(06-02B) BP Exploration(Alaska) STATE OF ALASKA • A .KA OIL AND GAS CONSERVATION COMP. :ION • REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon LI Repair Well ❑ Plug Perforations ❑ Perforate Other D Pull LTP Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver El Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WE 2 Operator 4 Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development D Exploratory 212-144-0 3 Address P O Box 196612 Stratigraphic ❑ Service❑ 6.API Number Anchorage,AK 99519-6612 50-029-20282-02-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028311 PBU 06-02B 9 Logs(List logs and submit electronic and printed data per 20AAC25 071), 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12719 feet Plugs measured None feF'E C E I V E D true vertical 9022 95 feet Junk measured 12674 feet JAN 2 7 2015 Effective Depth measured 12683 feet Packer measured 9486 92 feet �� true vertical 9022 01 feet true vertical 8177 15 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 24 75-104 75 24.75-104 75 1530 520 Surface 2670 8 13-3/8"72#N-80 24.25-2695 05 24 25-2695.01 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 9574.43 7"26#L-80 18 25-9592.68 18 25-8263.13 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12310-12660 feetr,l'LI 5Cp�� True Vertical depth 9011 97-9021 37 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 17 25-9799.68 17.25-8430 45 Packers and SSSV(type,measured and true vertical depth) 4-1/2"Baker S-3 Perm Packer 9486 92 8177 15 Packer None None None SSSV 12 Stimulation or cement squeeze summary' Intervals treated(measured) Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 653 20539 22 460 346 Subsequent to operation 1?" FOW14, 17707 'as' O9 920 X25' 717 14 Attachments x'15 Well Class after work /0 Copies of Logs and Surveys Run Exploratory ❑ Development D Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil D Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C O.Exempt N/A Contact Garry Catron Email Garry.Catron(a�BP.Com Printed Name Garryr/CCatronn Title PDC PE Signature r3� tr // Phone 564-4424 Date 1/27/2015 VTI, a /« / 'S Y/5-7/, Form 10-404 Revised 10/2012 RBbliittng I On(yn N i 0 2015 • CU • 0• o o 0 c � 01 0 0 0 fC N P tiLot 6- OLS O O O to N f- 0 0 OO ` 0 000 c. (1) 0 0 0 CD • LO CO CO o o N CO M CO CO CO N Tr CO V N tf) •cr M1.0 N. CO Nr O a0 r O CO N V N L) C'M tri • co O co N 00 co co 6) co CO CO O CO CO N CO V' r co 00 O) 00 co co N CO F- I� N c- O N- L.0 . O N CO to LO LO N- C N N co N N N ✓ O N- O O r O a0 r N N IC) CO CO CO — N N (0 (0 (0 (0 (0 a) 4 Lc) CA CO LO � r tO V 10 CA O N O O N O min CO a0 L • COr• 2 QM LO r` O CO tO rn � 'r r--- CO CO N N O c) 01 CO CO N • N N O O) O) 6) CO 0 0 000) 00002 , CO oeo o) CO co 0 O U Z J J M cO Z M ( C N CO N �$ �N fn 4 V 4 4 O N O) - - - - O N 00 OO CO 00 N U N tf) to M N CA N Cr) M CA V -C +' co N D'O N CO I� r N N- co C o0 co CO V O LO Cb to CO N- d U) CO N O N 6) -J w w F- F- Z C UH 0 0 0 O w www U Z w w w w w w O m O H1- HZZZc JD U ZZZ � J J � � F- / \ 77 \ f 0 E E 2 / TD 22 I / \ \ \ \ / \ I $ / \ )ri 4 o t / \ / $ f 2 = / Ci) k § • rX - 6 7 L $ / - - a / / $ 0- Iww = mmo W m a o \ / / / D -§ - J o ma § t 0 0 / / \ _ / c- / \ \ - a 2 0 0 / » \ 5 / 9 Q 2 / / 0 � / -0 � $ 4J ) CO- C) ƒ \- C / \/\ < 0- / 0 E / O 2 \ mZO E \ ® 22 14.' / / n t •� \ r // � " 0)U. �0I, : 1_0 < t - R ± G / % \ -0. # Li j <7 - m _1 \ S/ 7 / oo E cc' ca a \ \ \ / % a » e O n < ,_ _ < ,— ƒ 6 $ \ 6c2 / § / . ./ \ } ZCN \ / E = \ � � RRpIE ƒ & 9 = < , , _m % —1 —1 —1 —I o \ E LO CD0Z Z / 7 / bo (/) / / o = e I Z Z 0 = 2 ± t / 2 2 2 + 5 2 / .e 2 2 ± I .g = I E , 0-0 \ c - OGUoca 0 = - - 0 >'- up 2 = - - 2 0 .- O O O O - ± _ ® �� 0 u 7 \ \ G e R ¥ @ R R R $ H / -1 < » u 2CL = 2IIII < n -1 0 ,_ m L n n a 0 m 7 O0) 0) 0) 0) ® o L / $ % $ 2 2 2 2 _ 0 D 2 2 D z O S $ 6 co } J J ƒ i i \ o- co ƒ % co ƒ / / { 1. r r r r \ `- 0 / \ a 6 2 2 TREE= 4"FICC 120 WELLHEAD= FMC 0 6_0 2 B S i. /(NOTES: WELL ANGLE>70°@ 10555'. CTUATOR= BAKER C INITIAL KB.ELE 64' 1I =BF.EI_EV- 20'COND, --I 100' / • 2121' -14-1/2-FES X NP D=3.813" KOP= 3200 Max Angle= 94'0 11890' 94#,H-40, Datum MD= 10363' D=19.124" 2316' -9-5/8'FOC Datum ND= 8800'SS ^� 2441' H9-5/8"FOC 9-5/8"CSG,47#,SOFT RS-95 XO TO N•80 BUTT H 2295' 13-3/8'CSG,72#,J&L N-80 BUTT,D=12.347" H 2695' 3150' -I EST TOP OF CElug lT(07/19/03 FRWD) ► ND GAS LFT MANDRELS • • ST MD ND DEV TYPE VLV LATCH FORT DATE ►� 4 3529 3516 17 KBG-2 DOME BK 16 04/06/13 9-5/8"CSG,47#,N-80 XO TO SOFT FRS 95 BUTT --- 1--1 $216' � L ►� ►� 3 6788 5992 41 KBG-2 SO BK 24 04/06/13 4-112"TBG PUNCH(12/16/12) 9101'-9106' • ►� 2 8410 7295 36 KBG-2 DM( BK 0 07/19/03 0i� 1 9408 8113 35 KBG-2 DMY BK 0 07/19/03 Ii ►� 9466' H4-1/2-FES x NV,D=3.813' Minimum ID =2.250" @ 9640' • BKR DEPLOYMENT SLEEVE r 948T HrX4-112-BKR '-3PKR,D=3.875' ' • F9611- -{4-1/2'HES X KIP,D=3.813" r TEBK LW,26#,L-80 BTC-M, -I 9593' .0383 bpf,D=6276" 9640' -12-7 X 225"BKR DEPLOY SLV,D=2.250' ? w/SCOOP GUDE(TOL) '..1.1„,' 1 9691' --13 70'BKR OFROY St V,D=300" 1 a ti 9712' —13-1/2"OTIS X NP,D=2.812' 31/2"LW,9.3#,L-80 SEL,.0087 bpf,D=2.992' H 9744' 11 "til 9744' -13-1/2'X 3-3/16"X0,D=2.786' 1 II 4. L 9778' -I4-1/2"HES XN NP,WILED TO 3.80(4/12/11) 4-1/2'TBG,12.6#,13CR VAM AC, -I 9800' �_"Ito!' h_ _ 9800' --14-1/2"WLEG,D=3.958" BEHIND .0152 bpf,D=3.958' N 1 ikj0�V 001.1 4► _ Ae 1 9899' CASING HOLE 9898'-9929' LNR 9-5/8"CSG,47#,SOFT RS-95 --I 9977' F— jII I� '4, 1 1 ♦ (RIG 50Z 01/22/90) XO TO SOFT N-80 BUTT �,I,I1 I-*I` I•IVq I' �I�• 9-5/8"CSG,47#,SOFT N-80 BUTT,D=8.681' H -10054 MLLOUT WINDOW(06-02A) 10054'-10064' 3-3/16"BKR W-IPSTOCK(12/14/12) H 10380' MLLOUT WINDOW(06-02B) 10376'-10382' 3-3/16"LNR,6.2#,L-80 TCl,.0087 bpf,D=2.80" -I -10382 ' PERFORATION SUMMARY FEF LOG: ANGLE AT TOP FERE:12310"0 88' Note:Refer to Production DB for historical perf data - SIZE SPF P1T RAL OPWSOZ SHOT SOZ 1.56" 6 12310-12660 0 03/25/13 PBTD -1 12683' ,° j 12674'ctm lFISFt BROKEN MILL FROM COL PUSHBD ... DOWN FROM 10548'SLM(03/13/13) 2-3/8"LNR,4.7#,L-80 SIL,.0039 bpf,D=1.995' -{ 12719' '. DATE REV BY COM43sITS DATE REV BY COMAENTS PRUDHOE BAY UNIT 10/30/78 NIES INTIAL COMPLETION 04/23/13 SWClJMC GLV CIO(04/06/13) WELL 06-02B 07/19/03 N4ES RWO 05/28/13 TJ/PJC MAL L ODE APPROVAL PERMIT No: 2121440 06/14/05 JGM/PJC CTU 9 3-1/2"LNR 07/30/14 6.43S/JM)SET 45 KB LTP(07/25/14) AR Nb: 50-029-20282-02 05107111 NORDIC CTT)SIDETRACK(06-02A) 01/13/15 JMG/JMD PILL 45KB LTP(01/11/15) SEC 2,T10N,R14E,607'FSL&1164'FE. 01/25/13 NORDIC/CTD SIDETRACK(06-02B) 03/26/13 NORDIC 9 PERFORATIONS(06-029) BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Qi ca - 114 Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RE AN: OVERSIZED: NOTES: /'Color Items: ❑ Maps: Grayscale Items: ❑ Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: CM Date: 0. `q /s/ mi° Project Proofing BY: darZODate: `a, ` /s/ ii4p Scanning Preparation j_ x 30 = It? () + 11 = TOTAL PAGES / (Count does not include cove sheet) ��p BY: Date: l� d"� /i' /s/ r/�/ Production Scanning 7c . Stage 1 Page Count from Scanned File: (Count does include cover sh et) Page Count Matches Number in Scannin Preparation: YES NO BY: 1110 Date: J del I 1-j- /s/ (YJ1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc C ' N m m m -J -J -J C N IIS, Z I I I W W W cJ N i W M O 0 WI WI LLI N co O W W W W J J J `• N Z C J I LL. 1 I Q ¢ Q 7 N '� O) W I 1 I Z Z Z o) 0 ail 2 . ~ Q Q Q LL LL U ¢ Q } m Z Z Z �I UI UI A N p a WI WI LSI u) U) U) _ I a� ami v 6 O 2 2N a E0 MI @ Ol MI I MI MI MI MIa)J O O O O Of4 _a7 C •_� LL W Z Z Z Z Z a) -O '�I Q Q Q Q QOOJcvj M c.Mj N VI OU U (g¢ O'- O O O CD(,-.2 OV () O D o F F- a) 0-2 a m Z win ai NI ai 0 ai o ai 0I E a� y1 ?_ u) u) a^0 `� 0w1� iii � � iii iii E iii iiE i ,n d E a) a) O LL U u 0- 0 1 u lc .0 I U ID) 0 I o v_ 1 c 0 rn E o o EZ + El' 'EW ECL Er Ex c) 'EcKv 'Eix a l� N to 0) O L -c a)t J 2Jm 20E 20E 20w 207 207 207 J J U m 'm 0 Z 0 d MI CV el a) ''• aa)i NI an d m1 a aa)i ml ml m ml CU ml ml Ce Q o 2 2 21- 2 Woo wog wog wog woo wo0 wI IP o0 Z O/� 0 U co M co_ co_ M_ _M _M _M _M co_ M_ CL Y > Oo 0 O O O O O O O O O .0. 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U U I m 2 '� ° u -i 'm a •2 y U U 0O a -U'o o i _ a co y E a `m 0 0 c m m LL o 2 ami 0 o d E o a 2 J J W W ,Z 0 a 0 , 0 0 CY I 0 0 STATE OF ALASKA ALAS )IL AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Lf Repair Well V�(d else l V‘i( r'tU Perforate Li Other U Set LTP Performed' Alter Casing ❑ Pull Tubing❑ giA Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work. 5.Permit to Dnll Number Name. BP Exploration(Alaska),Inc Development Exploratory ❑ 212-144-0 3 Address. P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-20282-02-00 7 Property Designation(Lease Number): 8.Well Name and Number: ADL0028311 PBU 06-02B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071)• 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary' RECEIVED ECEIVED Total Depth measured 12719 feet Plugs measured None feet true vertical 9022 95 feet Junk measured 12674 feet AUG 18 2014 Effective Depth measured 12683 feet Packer measured See Attachment feet AC GC() true vertical 9022.01 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 25-105 25-105 1530 520 Surface 2671 13-3/8"72#N-80 24-2695 24-2694.96 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 9574 7"26#L-80 25-9599 25-8268 24 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12310-12660 feet True Vertical depth 9011.97-9021.37 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 26-9808 26-8437 17 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary. Intervals treated(measured): Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation. 653 20539 22 -15 346 Subsequent to operation: 517 35 33 -15 225 14.Attachments. 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U Gas ❑ WDSPC GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.SummerhaysAbp.com Printed Name Nita Summerh- s Title Petrotechnical Data Engineer Signal %/� j�� / __ Phone 564-4035 Date 8/18/2014 r1.—F RBCMS AUG 19 1Q'; Form 10-404 Revised 10/2012 /0 ,�� Submit Onginal Only • Daily Report of Well Operations ADL0028311 ACTIVITYDATE E SUMMARY YI 111 . . . V. proiem.. SWCP LL-11 STAND BY FOR QC& RIG UP CREW. 7/23/2014 ***CONT ON 7/24/14 WSR*** ***CONT FROM 7/23/14 WSR***(profile mod). DRIFT W/ 10'x 3.70" DMY WHIPSTOCK, 3.50" LIB TO BKR DEPLOY SLV @ 9,618' SLM (9,640' MD).(picture of clean deploy sly). DRIFT W/ 1.75" CENT, 1-1/2" SAMPLE BLR TO 9,800' SLM (No issues, bailer empty). RAN PDS 24 ARM CALIPER FROM 9,750' SLM TO 9,400' SLM (Good data). LRS LOADED TBG W/ 175 BBLS OF CRUDE. DRIFT W/ KB PACKER DRIFT W/2.24" STINGER. 7/24/2014 ***CONT ON 7/25/14 WSR*** 171/0=2370/408/482 Temp=SI Assist Slickline Load and set LTP (PROFILE MODIFICATION) Pumped 5 bbls of 60/40 and 175 bbls of 110*crude down Tbg to 7/24/2014 load. ***Job cont. to 7-25-14 WSR*** ***Job cont. from 7-24-14 WSR*** S/L ASSIST (LTP set) Pumped 5 bbls Crude to 7/25/2014 assist S/L in setting packer ***CONT FROM 7/24/14 WSR***(profile mod.) BRUSH W/3.746 CENT&2.24" BRUSH @ 9640' MD SET BKR 45 KB LTP W/2.24" STINGER (oal lih=9.42'), @ 9,622' SLM (9,640' MD). RAN 24 ARM PDS CALIPER ACROSS BKR 45 KB LTP @ 9,622' SLM (9,640' MD) PER PROCEDURE. 7/25/2014 ***WELL S/I ON DEPARTURE*** FLUIDS PUMPED BBLS 1 DIESEL 180 CRUDE 5 METH 186 TOTAL m Q o 0 0 0 m m o 0 0 O NYLONY '- O� Cn N N- U ` OOQ0o , 000 = 1.00O3- 00 _ O CV 0) v mCOaoM Nr CO M LOo LON o 0 CO N CO N u 00 N- M O a0 N W CO 0) M CO 00 O M N CO V N W CO O M 00 N O l l l l l ! III I- N- (DN- 10 O M r- M M M N- O O V' N N N N N LOCO M M N 00 (0 0000 C • CO Crr•-- CD tf O In 00 N O O N I- In CO2 _cO O N O V 0 4-1 r 2 QV In O O Cf) V O N N N m m m N N N Co la Co M I— 0 Q om000 moo O CO COCO aoo 00 0 C) Z 2 Z J J a0 Z M C CIk (1) * * ; • N I# I� * N- M N C13 w• O) - 00 00 00 CV U 1.0 - lnM -I - N O) N C r- t O N 431 O N M co I� 00 C 00 O) M O O In LU CO f. 0> U7 MM 0) C'40) J W W W c H 0 0 0 O w •NUwww UU UoCYCCCtryaou.. z z w w w w w O rxm 101- 1- 1- zz » Uzzz J Jd (n _ Packers and SSV's Attachment ADL0028311 SW Name Type MD TVD Depscription 06-02B PACKER 9487 8113.21 4-1/2" Baker S-3 Perm Packer 06-02B PACKER 9634 8232.52 4-1/2" Baker KB LT Packer t FELL= 4"AMC 120 0 0 2 VUH_LFfAD= FMC _ SAFE. TES: WELL ANGLE>70°@ 10555'. ACTUATOR= BAKERC "`4-1/I-CHROME TBG*** NTTIAL KB.ELE 64' I BE ELEV= KOP= 3200 20"CONE), H 100' 1 2 ' 2121 ' —4-1/2"HES X NP,ID=3.813" Max Angle= 94'@ 11890' 94#,1349, Datum M)= 10363' D=19.124" x 2316' —9-5/8"FOC I Datum ND= 8800'SS - I `I 2441' 9 5/s"FOCI 9-518"CSG,47#,SOFT RS-95 XO TO N-80 BUTT — 2295' 13-3/8"CSG,72#,J&L N-80 BUTT,D=12.347" — 2695' 3150' _ EST TOP OF CEMENT(07/19/03 RVNO) * GAS LFT MANDRELS ST MD ND DEV}TYPE VLV LATCH PORT DATE ► 4 3529 3516 17 KBG-2 DOME BK 16 04/06/13 N- 9-5/8"CSG,47#, 80 XO TO SOFT RS-95 BUTT — 8216' - ♦ ►P 3 6788 5992 41 KBG-2 SO BK 24 04/06/13 4 1/2"TBG FUNCH(12116/12) — 9101'-9106' • 2 8410 7295 36 KBG-2 DMY BK 0 07/19/03 0 1 9408 8113 35 KBG-2 DMY BK 0 07/19/03 • • 9466' —14-1/2"HES X NP,D=3.813" Minimum ID =1.81" @ 9634' • • 4-112" 45 KB LINER TOP PACKER �•r_� ''''i• 948T -17"x4-1/2"BKR S-3 FKR D=3.875" $ 4 , :. 1 9511' —,4-1/2"HES X NP,D=3.8131 Al r vi ,, 7"TE3K LNR 26#,L-80 BTC-M, --I 9593' / .0383 bpf,D=6.276" 9634' —4-1/2"45 KB LW,0=1.81'(07/25/14) 9640' —2-7 X 2.25"BKR DEPLOY SLV,13=2.250" w/SCOOP GUDE(TOL) 9691' -13 70'RKR 1 OY SI V,ID=3 00" 1I a tN: 3-1/2"LNR 9.3#,L-80 STL,.0087 bpf,D=2.992" — 9744' q 9712' H3-1/2"/2"OTIS X NP,D=2.812" it 9744' —3-1/2"X 3-3/16"XO,D=2.786" 1 N ,J 9778' —4-1/2"HES XN NP,MILLED TO 3.80(4/12/11) TB 4-1/2" G, 12.6#,13CR VAM ACE, H 9800' I '.440� , ``� 9800' H4-1/2"WLEG,D=3.958" BEHIND i.0152bpf,D=3.958" e♦� 'V% ►�j`.4 y+j 9899' —CASING HOLE 9898'-9929' I LNR 9-5/8"CSG,47#,SOFT RS-95 — l { 9977' - Z 1 (RIG SQZ 01/22/90) XO TO SOFT N-80 BUTT 9-5/8"CSG,47#,SOFT N-80 BUTT,ID=8.681" —{ —10054 ..•-f,•*. 5 .-.4,:.-.4,:-.‘- MFLOUT WINDOW(06-02A) 10054'- 10064' I . 3-3/16"BKR W-IPSTOCK(12/14/12) H 10380' 1 I aP. MLLOUT WINDOW(06-028) 10376'-10382' 3-3/16"LNR,6.2#,L-80 TCI,.0087 bpf,ID=2.80" H —10382 I /! PERFORATION SUMMARY FEF LOG: ANGLE AT TOP PE32F: 12310'@ 88' Note:Refer to Production DB for historical perf data — SIZE SPF INTERVAL OPN/SQZ SHOT SOZ 1.56" 6 12310-12660 0 03/25/13 PBTD —{ 12683' ' 12674'ctm —FISH BROKEN MLL FROM COL RJSHED J DOWN FROM 10548'SLM(03/13/13) 2-3/8"LNR 4.7#,L-80 STL, .0039 bpf,D=1.995" —I 12719' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY INT 10/30/78 N1 ES INTIAL COMPLETION 04/23/13 SWC/JM)GLV GO(04/06/13) WELL: 06-02B 07/19/03 N4ES RWO 05/28/13 TJ/PJC FINAL ODE APPROVAL PERMT Na: 2121440 06/14/05 JGM/PJC CTU 9 3-1/2"LNR 07/30/14 MGS/JM) SET 45 KB LTP(07/25114) AR No: 50-029-20282-02 05/07111 NORDIC CTD SIDETRACK(06-02A) SEC 2,T1ON,R14E,607'FSL&1164'Fa 01/25/13 NORDIC 2 CTD SIDETRACK(06-02B) 03/26/13 NORDIC 2 PERFORATIONS(06-02B) BP Exploration(Alaska) 2-k2 -r\ q--2-5 D3 0 nn 0 0i,Elin 0'0 !0.!010 Ea 0jQi0I0'0I00 010I�, I�7. v r r .. Ir ;r 'r 'r r 'ir !r !r 'r lr Ir r Ir r'Ir V '. .-1 r 0, 1 1 "W O V { i ` ` f�tj O R1 LL' •`4t4 i i { �� l ch 1"7 II O kZ i , . � I ll\/ Y (�,J _"`I r r r it r.Ir Ir !� jr 'r r r .• .r it �r ,r r' \l 0 N. 4O . , . ;i i v i , j � j 2 2 o 01 W m c� ; j i , I a j i i un �n U cd m ®C j 4 j I fo ��11 ..��1I rwI 1 � NI Q CV (tJ IW M MIM �M �M M ;M M 'M IM .M N.N MSN.N VM M .M Cl" m •.• .r 1 r Lulu P r ,ra- '� r' .�Ir r r (NIr 'r 'r !�IrIr 'r . fV Clj OD ;) j.. A co r' � : 03 ! C .ma c �; c ' c 1.0 I � ; � C C.;V 5 1.- L y. 0� C 'td «i 0 V,, 2 co 2 ;2 .7 u_ RiLL . co (010 , 0 , 0106 a: a a LL ��- o }...I 0 i , 7 eZ 7 e 1Q Q f0 ,_ U 1 03 P III r ,N NN N , N �� 'N � N M N Q rts CU m Cl }y�fir. ^ i f 'X I . IVO-. fr).....4), .,i ., i ' J ' . LL 0 LL ' LL >'" I" m 1 a' m ,R' :GC '.J '� � 'J � X a O . a 'v a 'n ' :a 'w •o Q m a ,c� : a ,a ,J ,�' a '� w a r4 cO 1: J JJ :O0 .J,0 . 0 .Ola ,aAOJJ' JJ Z H Z;Z ;2 2 :Z,12 ;,ey 2 21i ix'2 Z Z IH Z M r;; 0 y 0 0 'w .w U ;w 'w w w ;mm ;w ,U 'U ;a 0 ,0 j m oo tye - 1 I Q � D X X XIX ' X . X X X X N i;M I • Q 14 Xj .,;cFe } e . • • ea N_:/•A ' J ..1 t. (Ns It) _ W M co M r 00 O co w' r h Q'� -4,,- 4K co0 Q) r N M •CP M N O M .N r 'M .M 'O � ' YO y 4 r O C.n co 'O cc M Z CD o r 0 0 N r r 0 o r 61 o 0 0 0 0 0 0 0 !O 0 0 052000 ° 0 > 'a s me Co 0 0 0 '0 0 -0 .0 — O 0 0 0 0 0 0 0 0 9 . a o -1y:.eQLLaiU '� QLLmQQmQ a) -I e in .d 0 U • ) p oo � � cc � "Cs Lis C0 ' m N `n m Ql m f° 7, izo N O^ {. et c C a a a`) CO ., a O1 uuu m Q 0 CO m w J U 0 0 r m Nso, m J m Q m = "� o a) y , = _a ai ai ,sti ., et r n C M c?v Or r h N .C M O Na O r .u) h Y cc c d0 E w O O r e" _ r N O CJ J N N s z �° o 0 Z 00 (� •,11-, a w U J .aro ri c W O v u m o U- Q. y .L Lo N u r®O N a Op C v CO H D Nn § cw Q " ! x a m rn Q Letter of Transmittal ru- - , . --T BAKER Date: March 4, 2013 HUGHES _ __ oZ a , To: From: State of Alaska AOGCC Baker Hughes INTEQ 333 W. 7th Ave., Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Bill Michaelson Please find enclosed the directional survey data for the following well(s): j 14-02CL 1 a.0- f /S 01-17C 05-35AL2PB 1,1055--3 -35B`g 13 0 i-s. 07-29E a 1 3 o o 1 P- et 1 d. -- 06-02B — 1) 06-22BPB l,1.- : / - ( s co 06-24BPB1, 06-24B a ( 90 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. J RECEIVED BY: �/ to of Alaska AOGCC DATE: bp1 1 Date: 06/20/2013 JUN 2 2013 Transmittal Number:93295 AOGC BPXA WELL DATA TRANSMITTAL AOGCC: Makana Bender Enclosed are the materials listed below. , 9 Lo If you have any questions, please contact BreAnne Hovley: 907-564-5349 or breanne.hovley@bp.com Color Well Name Date Company Log Description Prints CD Baker 15-17 2/15/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker 01-20 4/17/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker F-06A 4/17/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker L5-23 4/17/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker Gic 06-02B 4/19/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker B-27B 5/8/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker 15-34A 6/10/13 Hughes ,RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker Z-08A 6/10/13 Hughes ,RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker Z-05 6/11/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker F-13B 6/13/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker 15-29B 6/17/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 p D L�.L Please S'gn and Re rn one c@y of this transmittal. ma jk Thank You, BreAnne 3-fovfey Petrotechnical Data Center Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 ITA BAKER PRINT DISTRIBUTION LISTN 10 2O'e3 HUGHES AOC COMPANY BP Exploration(Alaska)Inc. INTERMEDIATE FINAL Yes (mandatory) 2_ 14 WELL NAME 06 - o 2 RUN NUMBER L (mandatory) 22� CJ3 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: 6/5/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: BP Exploration(Alaska)Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Ur PHIN I S #OF COPIES #OF COPIES 1 BP Exploration(Alaska)Inc. I 3 I 1 I I Petrotechnical Data Center LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I I 1 I I I Attn Ricky Elgarico PO Box 100360 Anchorage,Alaska 99510 3 ExxonMobil,Alaska I 1 I 1 I I Attn Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 Anchorage,Alaska 99503 7 4 State of Alaska-AOGCC I 'I I 1 1 I I Christine Shartzer 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas I I 1 I I I Attn:Sean Clifton 550 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 Hunt, Jennifer L (DOA) From: Lastufka, Joseph N [Joseph.Lastufka@bp.com] Sent: Tuesday, May 14, 2013 8:36 AM To: Hunt, Jennifer L (DOA) Cc: Ramos, Tania ((Udelhoven Oilfield System Services (UOSS)) Subject: PBU 06-02B/ PTD#212-144 Hi Jennifer, RBDMS MAY 14 2013 Please reference the following well: Well Name: PBU 06-02B Permit#: 212-144 API #: 50-029-20282-02-00 Date of Test: 5/6/13 Type of Test: IPT (Initial Production Test) Choke Size: 85 Choke Unit: Production Method: Flowing Duration (Hours Tested): 12 Top Reference (Top Perf MD): 12310' Bottom Reference (Bottom Perf MD): 12660' Tubing Flowing (Pressure): 864 Casing Pressure: 1250 Total Test(Rate f/0, W, G): 517/ 11 /6284 24-Hour Rate (0, W, G): 1033/22/ 12568 Gravity (Oil, API): Not Available GOR (Gas-Oil Ratio): 12166 This well began Production on Method of Operations on this date: 5/6/2013 1 RECEIVED STATE OF ALASKA APR 2 2 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOukitQGCC la. Well Status: ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended lb. Well Class 2OAAC 25105 20AAC 25 110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One IN Development 0 Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 3/26/2013 212-144 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 1/8/2013 50-029-20282-02-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 1/12/2013 PBU 06-02B 607'FSL, 1164' FEL, Sec.02,T1 ON, R14E, UM 8. KB(ft above MSL): 15.Field/Pool(s) Top of Productive Horizon: 4255'FSL,3477' FEL, Sec. 02,T10N, R14E, UM GL(ft above MSL): Prudhoe Bay/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) 3256'FSL, 5013' FEL, Sec. 02,T10N, R14E, UM 12683' 9022' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 685818 y- 5941201 Zone- ASP4 12719' 9023' ADL 028311 TPI: x- 683412 y- 5944792 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 681901 Y- 5943755 Zone- ASP4 None 18.Directional Survey: ®Yes ❑No 19.Water depth,if offshore: 20. Thickness of Permafrost(ND): (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 MDlTVD: MWD/GR/RES,GR/CCL/RMP 10376' 8886' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND' HOLE AMOUNT CASING WT.PER FT. GRADE Top BOTTOM Top BOTTOM /' SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 100' Surface 100' 32" 269 sx Permafrost 13-3/8" 72# N-80 Surface 2695' Surface 2695' 17-1/2" 7200 sx Arcticset II 9-5/8" 47# N-80/RS95 Surface 10054' Surface 8634' 12-1/4" 1200 sx Class'G' 7" 26# L-80 Surface 9593' Surface 8263' Inside Pipe 835 sx Class'G' 3-1/2"x 3-3/16" 9.3#/6.2# L-80 9691' 10376' 8343' _ 8886' 4-1/4" 145 sx Class'G' 2-3/8" 4.7# L-80 9640' 12719' 8301' 9023' 3" 97 sx Class'G' 24. Open to production or injection? IS Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): _ ,,)_ 1.56"Gun Diameter,6 spf 4-1/2", 12.6#, 13Cr80 9800' 9487'/8177' IGOMPLE11014 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 12310'-12660' 9012'-9021' 31zD1�"13j ®WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes No VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 01 12674' Fish: Broken Mill From Coil 2000' Freeze Protect w/40 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes IN No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RSDMS APR 25 2013,` .. Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit Original Only rest-F$/J q/? 7:2,z. G 29. GEOLOGIC MARKERS(List all formations ani :ers encounter 30. FORMATION TESTS NAME MD ND Well Tested? ❑Yes IS 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. Base of CGL/Zone 2C 10360' 8875' None Base of CGL/Zone 2C 10378' 8887' (Kicked off from Parent Well) 23SB/Zone 2B 10438' 8925' 22TS 10550' 8983' Formation at Total Depth: 22TS/Zone 2B 10550' 8983' 31.List of Attachment Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Troy Jakabosky,5 868 Email: Troy.Jakabosky@bp.com Printed Name: Title: Drilling Technologist Joe a fka Signature: _ Phone 564-4091 Date: 416/13 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 1 a: 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 ND 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 MC 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 10/2012 Submit Original Only TREE= 4"FMC 120 06-02B SAFI JOTES: WELL ANGLE>70°@ 10555', ACTUATOR= BAKER C PJC DRAFT ***4-112"CHROME TBG*** {tl INITIAL KB.IME 64' ) I I KO Ell 3200' 120"COND, H 100' , ' 2121' H4-1/2"HES X NIP,D=3.813" Max Angle= 94°@ 11890' 94#, H-40, Datum MD= 10363' ID=19.124" (1 >< 2316' —19-5/8"FOC Datum TVD= 8800'SS 2441' —I9-5/8"FOC 9-5/8'CSG,47#,SOFT RS-95 XO TO N-80 BUTT —I 2295' 13-3/8"CSG,72#,J&L N-80 BUTT,ID=12.347" H 2695' 3150' —1 EST TOP OF CEMENT(07/19!03 R1/U0) GAS LET MANDRELS • ST MD TVD DEV TYPE VLV LATCH PORT DATE I ►�• 4 3529 3516 17 KBG-2 DMY BK 0 05/27/12 9-5/8"CSG,47#,N-80 XO TO SOFT RS-95 BUTT H 8216' 'y �,� 3 6788 5992 41 KBG-2 DMY BK 0 05/27/12. ►• 2 8410 7295 36 KBG-2 DMY BK 0 07/19/03 4-1/2"TBG RJNCT1(12/16/12) H 9101' -9106' ►• U • 1 9408 8113 35 KBG-2 DMY BK 0 107/19/03 • ►� 9466' —I4-112"HES X NIP, ID=3.813" Minimum ID = 1.920" @ 9645' . I 1 • 2-3/8" PUP JOINT . • r• `-� = 9487' --I 7"X 4-1/2"BKR S-3 PKR,ID=3.875" ► 9511' H4-1/2"HES X NIP,D=3.813" • ,P 7"TIEBK LNR,26#,L-80 BTC-M, —I 9593' s .0383 bpf,ID=6.276" i r 9640'_I-12-7 X 2.25"BKR DEPLOY SLV,ID=2.250" w/SCOOP GLIDE(TOL) 9691' --I 3 70"BKR fXPt.(OV SI_V,ID=3 00" 1 JI 3-112"LNR 9.3#,L-80 STL,.0087 bpf,D=2.992" —I 9744' IC V 9712' -I3-1/2"OTIS X NIP,D=2.812" 9744' —I3-1/2"X 3-3/16"XO,0=2.786" ,40 _-'1 9778' —14-1/2"HES XN MP,MILLED TO 3.80(4/12/11) 41/2"TBG,12.6#, 13CRVAMACE, — 9800' A-�- 9800' —J�4-112"WLEIa,ID=3.958" BEHIND .0152 bpf,ID=3.958" , } # 1, } 9899'�—CASING HOLE 9898' 9929' LNR 9-5/8"CSG,47#,SOFT RS-95 H 9977' (RIG SQZ 01/22/90) XO TO SOFT N-80 BUTT 4. 9-5/8"CSG,47#,SOFT N-80 BUTT,ID=8.681" H i -(0054 No' J MLLOUT WINDOW(06-02A) 10054'-10064' 3-3/16"BKR W-UPSTOCK(12/14/12) —I 10380' I§ . 11 • MILLOUT WINDOW(06-02B) 10376'-10382' 3-3116"LNR 6.2#,L-80 TCI,.0087 bpf,0=2.80" —I —10382 Il PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF:12310°@ 88' Note:Refer to Production DB for historical perf data — SIZE SPF '1TER'VAL OFN/SQZ SHOT SQZ 1.56" 6 12310-12660 0 03/25/13 ,. , 12674' ctm —FISH: BROKEN MLL FROM COIL PUSHED PBTD — 12683' DOWN FROM 10548'SLM(03/13/13) 2-3/8"LNR 4.7#,L-80 STL, .0039 bpf,ID=1.995" H 12719' 101'.. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/30/78 NIES INITIAL COMPLETION 03/29/13 PJC DRLG DRAFT CORRECTIONS WRL: 06-02B 07/19/03 N4E5 RWO 04/12/13 JNUJMD CORRECTED TOP OF MLLOUT DI FERMI-No:"2121440 06/14/05 JGM/PJC CTU 9 3-1/2"LNR 04/22/13 JNLJJMD CORRECTED TOP OF MLLOUT DI API No: 50-029-20282-02 05/07/11 NORDIC 'CTD SIDETRACK(06-02A) SEC2,T10N,R14E,607'FSL&1164'FEL 01/25/13 NORDIC 2'CTD SIDETRACK(06-02B) 03126/13 NORDIC 2 PERFORATIONS(06-02B) BP Exploration(Alaska) North America-ALASKA-BP Page 1 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1/4/2013 20:00 - 22:00 2.00 MOB P PRE BEGIN RON EVENT V ITH NORDIC 2 CTD RIG AT XXXX ON 01/04/13. 1 HOLD PJSM WITH CREWS. 1 VERIFY PRE MOVE CHECK LISTS ARE COMPLETE. BACK RIG OFF WELL P-17L1. SPOT RIG ON P PAD 22:00 - 00:00 2.00 MOB P 1 PRE CLEAR RIG MATS FROM AROUND WELL.IAP= 0 PSI,OAP=0 PSI. TP AND DRILLER COMPLETE ROUTE DRIVE. 1/5/2013 00:00 - 03:00 3.00 MOB P PRE MOVE RIG OFF OF P PAD,DOWN P PAD ACCESS ROAD,TO U PAD ACCESS ROAD. _ 03:00 - 06:00 3.00 MOB P PRE MOVE RIG TO N PAD,TO SPINE AND CC2A. 06:00 - 14:00 1 8.00 MOB P PRE CONTINUE MOVING ON SPINE ROAD TO DS-06. l 14:00 - 16:00 2.00 MOB P PRE ARRIVE DS-06. SPOT RIG MATS AROUND WELL. 16:00 - 17:00 1.00 MOB P PRE MOVE OVER WELL.**ACCEPT RIG AT 16:00.** 17:00 - 19:30 2.50 RIGU -P PRE SPOT SAT CAMP,PREP CELLAR AND OUTSIDE OF RIG 19:30 - 20:00 0.50 BOPSUR P PRE LEAK TIGHT TEST OF SWAB.REMOVE TREE CAP 20:00 - 00:00 4.00 BOPSUR P PRE PJSM ND TREE CAP NU BOPE GREASE CHOKE AND KILL MANIFOLD. SLB l MECHANICS CHANGE 2 PIECES OF HARDLINE IN INJECTOR HYDRAULIC SYSTEM AND TEST,CHANGE REEL MOTOR ON REEL PUMP IN POWER PACK. HARDLINE CREW SPOT FLOWBACK TANK AND RIG UP HARDLINE AND TEST. 1/6/2013 00:00 - 01:00 1.00 BOPSUR P PRE MU AND INSTALL LUBRICATOR RISER ON BOPE 01:00 - 02:30 1.50 BOPSUR P PRE PJSM,PICK UP GOOSENECK AND INJECTOR, STAND BACK INJECTOR 02:30 - 03:00 0.50 BOPSUR P T PRE PJSM FOR BOPE TEST.MEASURE RKB.FILL STACK 03:00 - 04:00 1.00 BOPSUR P PRE PJSM.RAISE 2"REEL INTO REEL HOUSE. 04:00 - 04:30 0.50 BOPSUR P PRE SHELL TEST BOPE,GOOD TEST. 04:30 - 05:00 0.50 BOPSUR P PRE H2S RIG EVAC DRILL WITH AAR.ALL HANDS MUSTERED APPROPRIATELY. 05:00 - 09:00 4.00 BOPSUR P PRE PRESSURE TEST BOPE PER ADWOP AND AOGCC REGULATIONS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH.- PRESSURE TEST ANNULAR PREVENTER WITH 2"TEST JOINT-FUNCTION TEST KOOMEY ACCUMULATOR UNIT PER BP WELL CONTROL MANUAL AND NORDIC PROCEDURE.-TEST AND CALIBRATE GAS ALARMS.-FUNCTION ALL COMPONENTS FROM BOTH REMOTE STATIONS-TEST WITNESS IS WAIVED BY AOGCC INSPECTOR LOU GRIMALDI.-SEE ATTACHED DOCUMENTATION REPORT AND CHARTS. 09:00 - 10:00 1.00 BOPSUR P PRE TEST GAS ALARMS. Printed 4/8/2013 11:20:34AM North America-ALASKA-BP Page 2 of 131, Operation Summary Report Common Well Name:06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor.NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00©64.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) 10:00 - 10:30 0.50 BOPSUR N RREP PRE FINISH BOP TEST. ALL ELEMENTS PASS EXCEPT UPPER 2"COMBIS.PURGE STACK TO CHANGE OUT 2"COMBI RAMS. 10:30 - 11:30 1.00 BOPSUR P PRE PJSM FOR PULLING CT ACROSS AND INTO INJECTOR.PULL CT ACROSS AND INTO INJECTOR.PUT INJECTOR BACK IN CIRC HOLE ON RIG FLOOR TO COMPLETE BOP TEST. 11:30 - 11:40 0.17 BOPSUR N , RREP PRE I PRESURE TEST UPPER 2"COMBIS,FAILA SECOND TIME.PREP TO OPEN BOP DOORS AGAIN. 11:40 - 14:00 2.33 BOPSUR P ' PRE CONDUCT RIG EVAC WITH DAY CREW.LIFT UP INJECTOR AND TEST WIRE,GOOD. PREP TO INSTALL CT CONNECTOR. 14:00 - 14:40 0.67 BOPSUR P PRE PULL TEST CONNECTOR TO 35KLBS,GOOD. INSTALL BHI CABLE HEAD. 14:40 - 15:40 1.00 BOPSUR N RREP PRE PUT INJECTOR BACK IN CIRC HOLE ON RIG FLOOR TO COMPLETE BOP TEST.GETA GOOD LOW AND HIGH PRESSURE TEST. 15:40 - 18:00 2.33 BOPSUR P PRE PREP TO FILL CT WITH MEOH THEN 1%KCL WATER.FILL CT WITH 5 BBLS MEOH FOLLOWED BY KCL WATER. 18:00 - 19:00 1.00 BOPSUR P PRE -BLOW BACK COIL FOR PULLING TWC AND BULLHEAD. STAND BACK INJECTOR FILL STACK 19:00 - 21:15 2.25 BOPSUR P PRE PJSM,PICK UP DSM LUBRICATOR AND EXTENSION RODS.INSTALL AND PRESSURE TEST LUBRICATOR TO 250/3500 PSI. 21:15 - 21:45 0.50 BOPSUR P PRE HOLD H2S/RIG EVAC DRILL WITH NEW CREW TO SLOPE.ALL MUSTERED APPROPRIATELY WITH MR. 21:45 - 22:00 0.25 BOPSUR P PRE MOTOR ON HYDRAULIC PUMP OF SSV SYSTEM MALFUNCTION.SLB MECHANICS INSPECTED AND BACK ONLINE. 22:00 - 23:00 1.00 BOPSUR P i PRE STING INTO TWC,2080 PSI BELOW.CLOSE SSV AND SWAB.BLEED OFF AND RD LUBRICATOR.RECOVER TWC. 23:00 - 00:00 1.00 BOPSUR P PRE FILL STACK WITH MEOH,INSTALL CTD RISER CAP AND PRESSURE TEST SAME.UNABLE TO TEST,NO LEAKS ON SURFACE.GREAE CREW GREASE SWAB AND SSV,FLUSH FLUID THROUGH STACK TO TIGER TANK AND FILL STANK ABOVE SWAB WITH MEOH. 1/7/2013 '00:00 - 02:20 2.33 BOPSUR P PRE CONTINUE TROUBLESHOOTING TREE VALVES.TEST RISER CAP AGAINST CLOSED SWAB AND SSV TO 350/3500 PSI.GOOD TEST. 02:20 - 05:00 2.67 KILLW P WEXIT PJSM,OPEN SWAB AND SSV,2060 PSI ON WELL. BULLHEAD 240 BBLS KCL AT 5 BPM AND 3500 PSI,DROP RATE DOWN SEQUENTIALLY TO 3 BPM TO KEEP BELOW 3500 PSI.PUMP 160 BBLS 8.6 PPG MUD AT 3500 PSI AND 3 BPM. 05:00 - 05:15 0.25 KILLW P WEXIT FLOW CHECK WELL,FLOW AND GAS ALARM IN PITS,SI WELL AT CHOKE. 05:15 - 07:00 1.75 KILLW P WEXIT CONTINUE BULLHEADING WITH MUD AT 3.25 BPM AND 3500 PSI. Printed 4/8/2013 11:20:34AM North America-ALASKA-BP Page 3 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay ' Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UW:500292028200 Active datum:2:02 5/1/1978 00:00(@64.00usft(above Mean Sea Level) Date 1 From-To 1 Hrs Task 1 Code ; NPT NPT Depth Phase Description of Operations 1 (hr) 1 (usft) 07:00 - 09:00 2.00 KILLW P 1 ' WEXIT SHUT DOWN AND ALLOW PRESSURE TO BLEED DOWN.MONITOR WELL.FLUID LEVEL SLOWLY FALLING IN STACK,LOSING ABOUT 1 BBL/HR. 09:00 - 09:30 0.50 STWHIP P WEXIT MAKE UP BHA#1-2.74"WINDOW MILL, STRING REAMER,2.12 MOTOR,2 JTS 2.06 I CSH,2.375"COILTRAK.CONFIRM MILL IS 2.74 'GO,2.73 NO-GO.BHA OAL=110.76 FT. 09:30 - 11:30 i 2.00 STWHIP I P WEXIT PRESSURE TEST QTS SUB.RIH,ROUTE ' I I RETURNS THROUGH MGS AS A PRECAUTION. 11:30 - 12:40 j 1.17 STWHIP P WEXIT START LOGGING GR FROM 10070 FT.TIE-IN TO SHUBLIKAAT 10,050'WITH(-35)' i CORRECTION.TRIP SHEET IS-6 BBLS TO THIS POINT.DRY TAG WHIPSTOCK AT 10378 FT. 12:40 13:00 0.33 STWHIP P WEXIT GET SLOW PUMP PRESSURES WITH BOTH PUMPS.BRING UP PUMP TO 1.55 BPM/3200 PSI FREE SPIN.START TIME MILLING FROM 10376.0 FT.SEE VERY SLIGHT AMOUNT OF GAS CUT MUD BACK FROM B/U BELOW I LINER LAP.GO BACK TO NORMAL FLOW PATH AFTER RETURNS CLEAN UP. 13:00 - 13:30 0.50 STWHIP P WEXIT 10376.29 FT 3241 PSI OK DWOB. 13:30 - 14:20 0.83 STWHIP P WEXIT 10376.60 FT 3190 PSI 0.31K DWOB 14:20 - 15:10 0.83 STWHIP P WEXIT 10377.20 FT 3350 PSI 1.87K DWOB 15:10 - 16:00 0.83 STWHIP P WEXIT 10377.62 FT 3303 PSI 1.89K DWOB 16:00 - 18:00 2.00 STWHIP P WEXIT 10378.00 FT 3278 PSI 1.95K DWOB CONTINUE TIME MILL TO 10379.5 18:00 - 21:00 3.00 STWHIP P WEXIT TIME MILLING WINDOW AT 1 FPH AT 3250 PSI AND 1.5 BPM OF 8.57 PPG POWERPRO FROM 10,379.5'TO 10382.1'.FS 3250 PSI,DHWOB: 2.1-0.4 K LBS,9.9 PPG ECD,IAP UP TO 900 PSI BLEED TO 200 PSI. 21:00 - 21:45 0.75 STWHIP P WEXIT TIME MILL TO 10382.6',STRING REEMER EXIT CASING,TIME MILL 1ST FOOT OF FORMATION ' AT 1 FPH. PRELIMINARY TOW 10,376.4,BOW 10381.6'. 21:45 - 23:00 1.25 STWHIP P WEXIT DRILL FORMATION FROM 10384.6'TO 10392' AT 8 FPH,1.5 BPM AND 3370 PSI. 23:00 - 00:00 1.00 STWHIP P WEXIT BACK REEM WINDOW,THEN REEM UP AND DOWN 2 TIMES AT 1 FPM.PUMPING 1.5 BPM AT 3120 PSI. 1/8/2013 00:00 - 00:50 0.83 STWHIP P WEXIT REEM WINDOW ONE ADDITIONAL TIME,DRY DRIFT WITH NO WEIGHT DROP. 00:50 - 01:05 0.25 STWHIP P WEXIT FLOW CHECK FOR 10 MIN,NO FLOW. 01:05 - 02:45 1.67 STWHIP P WEXIT OPEN EDC,POH FROM 10,370'PUMPING 2.3 BPM AT 3450 PSI. AT 1800'2-WAY CHICKSAN ON REEL LINE STARTED LEAKING,BRING PUMP RATE DOWN TO 1.25 BPM AND 1870 PSI,LEAK STOPPED. 02:45 - 03:15 0.50 STWHIP P WEXIT PJSM FOR LAYING DOWN MILLING BHA.TAG UP AT SURFACE,FLOW CHECK,NO FLOW. - - STAND BACK INJECTOR. Printed 4/8/2013 11:20:34AM • North America-ALASKA-BP Page 4 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 I Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To Hrs Task I Code , NPT NPT Depth 1 Phase Description of Operations (hr) (usft) 03:15 - 04:00 0.75 STWHIP P WEXIT CIRC BHA TO WATER,LAY DOWN MWD TOOLS,2 JTS CSH,MILL AND STRING MILL GUAGED 2.72"GO/2.73"NO-GO. CHANGE OUT CHICKSAN ON REEL IRON, PRESSURE TEST AGAINST INNER REEL VALVE TO 4000 PSI,GOOD TEST. FLUSH MGS.CHECK TREE BOLTS,1 REQUIRED TORQUE 104:00 - 04:30 0.50 DRILL P PROD1 MU BUILD DRILLING BHA WITH HCC 2.7°X 3.0" BIT AND 1.7 AKO MOTOR. GET ON WELL,PRESSURE TEST QTS TO 250/3500 PSI. 04:30 - 07:30 3.00 DRILL P 1 PROD1 RIH WITH BUILD BHA 07:30 - 09:00 1.50 DRILL P PROD1 DRILL BUILD FROM 10390 FT. 09:00 - 10:00 1.00 DRILL P PROD1 CONTINUE DRILLING TO 10450 FT. PVT=393 BBLS. PICK UP HERE AND GET SPPS: PUMP#1-1.01 BPM=2018 PSI,0.52 BPM= 1560 PSI PUMP#2-1.01 BPM=2010 PSI,0.52 BPM= 1556 PSI 10:00 - 13:05 3.08 DRILL P PROD1 CONTINUE DRILLING PAST 10480 FT. HOLD • 60LTF FOR NOW TO BUILD ANGLE AND GET POINTED TOWARDS POLYGON. ROP IS 50-60 FT/HR WITH 0.7K DWOB. 1.57/1.56 BPM,8.58/8.62 PPG. PVT=391 BBLS. _ 13:05 - 13:15 0.17 DRILL P 1 PROD1 DRILL TO 10600 FT. PULL BHA WIPER AFTER 150 FT DRILLED. CLEAN PASS UP AND DOWN. 13:15 - 14:30 1.25 DRILL P PROD1 CONTINUE DRILLING PAST 10605 FT. HOLD 30L TF TO BUILD ANGLE AND LAND BUILD SECTION. 1.60/1.59 BPM(412900 PSI FREE SPIN. 8.59/8.64 PPG. ROP IS 30 FT/HR WITH 1.1K DWOB. BLEED OFF OOA FROM 690 PSI TO 130 PSI. DRILL TO END OF BUILD,10660 FT. 14:30 - 14:50 0.33 DRILL P PROD1 WIPER TRIP TO WINDOW. 14:50 - 14:55 0.08 DRILL P PROD1 PULL THROUGH WINDOWAND OPEN EDC. FLOW CHECK WELL. 14:55 - 16:40 1.75 DRILL P PROD1 FLOW CHECK IS GOOD. POOH,PUMP 2.3 BPM/3400 PSI. 16:40 - 17:00 0.33 DRILL P PROD1 FLOW CHECK WELL AT SURFACE,GOOD. OPEN CT RISER AND PULL REMAINING 50 FT TO SURFACE. 17:00 - 18:00 1.00 DRILL P PROD1 UD BHA#2,BIT IS 1-1 WITH 1 CHIPPED CUTTER,SOME RINGING ON THE NOSE. MAKE UP BHA#3,LATERAL ASSY WITH RESISTIVITY. 18:00 - 20:00 2.00 DRILL P PROD1 MAKE UP CT RISER AND PRESSURE TEST QTS CONNECTION,GOOD. RIH WITH BHA#3. 20:00 - 22:30 2.50 DRILL P PROD1 LOG FROM 10120'TO 10400'AT 150 FPM. PUMP MIN RATE AT 1350 PSI. TIE-IN IS(-37)'CORRECTION CONFIRM TOW IS 10377.5',BOW IS 10382.5' Printed 4/8/2013 11:20:34AM North America-ALASKA-BP Page 5 of 13 Operation Summary Report Common Wet Name:06-02 ;AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM 1 Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA j UWI:500292028200 Active datum:2:02 5/1/1978 00:00©64.00usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 22:30 - 22:45 0.25 DRILL P PROD1 RIH TO DRILLING DEPTH OF 10660,TAG.PU FOR SPP'S AT 10650'. PUMP#1:0.5 BPM=1598 PSI,1.0 BPM=2161 PSI,1.7 BPM=3208 PSI PUMP#2:0.5 BPM=1560 PSI,1.0 BPM=2080 PSI,2.5 BPM=3175 PSI 22:45 - 00:00 1.25 DRILL P PROD1 DRILL AHEAD FROM 10,660'WITH 1.7 BPM IN/OUT AT 3300 PSI 2.0 DHWOB,9.65 PPG ECD,3200 PSI FREESPIN,50-70 FPH. KICK WHILE DRILLING DRILL W/AAR. DRILL TO 10,737' 1/9/2013 00:00 - 01:50 1.83 DRILL P PROD1 DRILL AHEAD FROM 10,737'to 10785'. PUMPING 1.68 BPM IN/OUT AT 3220 PSI ROP 30-50 FPH. 01:50 - 02:45 0.92 DRILL P PROD1 I ROP SLOW TO 12 FPM AT 10785',DHWOB 1.4K,1.66 BPM IN/OUT AT 3260 PSI. IAP 588 PSI,OAP 128 PSI,OOA 128 PSI FIRE DRILL W/AAR. 02:45 - 05:00 2.25 DRILL P PROD1 AT 10,800',PULL UP TO MAD PASS THE BUILD SECTION WITH RESISTIVITY. LOG UP FROM 10,690'TO 10,385'AT 200 FPH. 05:00 - 08:30 3.50 DRILL P PROD1 .DRILLAHEAD FROM 10,800'AT 1.7 BPM IN/OUT AT 3160 PSI WITH 8.6 PPG POWER PRO DHWOB 1.3K#,ECD 9.62 PPG,ROP 15 FPH. DRILL TO 10830'. 08:30 - 09:00 0.50 DRILL P PROD1 CONTINUE DRILLING AT 10830 FT. 1.69/1.69 BPM CO 3100 PSI FREE SPIN. ROP IS AROUND 10 FT/HR WITH 2K DWOB. STALLING EASILY. 8.59/8.62 PPG. ECD=9.92 PPG. 09:00 - 10:40 1.67 DRILL P PROD1 'DRILL TO 10833 FT. REPEATED STALLING, CAN'T MAKE ANY PROGRESS. POOH. PULL THROUGH WINDOWAT MIN RATE AND PERFORM A 100 FT JOG AT FULL RATE,THEN OPEN EDC. 'FLOW CHECK WELL ABOVE WINDOW FOR 5 MIN,GOOD. OPEN EDC AND PUMP 2.3 BPM FOR TRIP OOH. 10:40 - 11:20 0.67 DRILL P PROD1 CONDUCT PJSM WHILE POOH NEAR SURFACE. TRIP SHEET IS-2 BBLS AT THIS POINT. FLOW CHECK AT SURFACE IS GOOD. 11:20 - 12:20 1.00 DRILL P PROD1 POOH REMAINING WAY TO SURFACE. L/D BHA#3. BIT IS 3-3 WITH MOST OF THE CUTTERS ON NOSE AND WING CHIPPED. MAKE UP BHA#4 WITH REBUILD HCC BICENTER,SAME MOTOR. 12:20 - 14:20 2.00 DRILL P PROD1 PRESSURE TEST QTS THEN RIH. PUMP 0.53 BPM/1450 PSI THROUGH OPEN EDC. - 14:20 - 15:00 0.67 DRILL P I PROD1 LOG GR FROM 10120 FT. CORRECT-37 FT. Printed 4/8/2013 11:20:34AM • North America-ALASKA-BP Page 6 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM •Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 18:00 3.00 DRILL P PROD1 DRILL FROM 10834 FT. HOLD 15OR TF FOR NOW TO LEVEL OUT AND CONTINUE RH TURN. ROP IS 50 FT/HR WITH 1.3K DWOB. 1.64/1.62 BPM @ 3000 PSI FREE SPIN. 8.60/8.63 PPG. 18'00 - 20:00 2.00 DRILL P PROD1 DRILL FROM 11,000'. '1.68 BPM IN/OUT 3400 PSI WITH 8.6 PPG POWER PRO 1.5K#DHWOB,ECD 9.72 PPG PVT 457 PSI,IAP 770 PSI,OAP 140 PSI,OOAP 1400 PSI SAMPLE AT 11,050'IS-30%CHERT. 20:00 - 22:00 2.00 DRILL P PROD1 DRILL FROM 11,140'. 1.7 BPM IN/OUT AT 3400 PSI,ECD 9.72 PPG I2K#DHWOB,-ROP 50 FPH. 22:00 - 23:20 1.33 DRILL P PROD1 I DRILL FROM 11,220'. 1.7 BPM IN/OUT AT 3380 PSI 11.6-2.2#K DHWOB 23:20 - 00:00 0.67 DRILL P PROD1 iAT 11,265'LOST SOME RETURNS:1.7 BPM IN/ 1.3 BPM OUT AT 3420 PSI. DRILL AHEAD TO 11,270' 1/10/2013 00:00 - 01:30 1.50 DRILL P PROD1 .DRILL FROM 11270'.AT 11,275'LOSES :INCREASE TO 30 BPH,LOSES START TO HEAL IMMEDIATELY 1.7 BPM IN/1.3 BPM OUT. ROP DECREASING TO 15 FPH AS CHERT • PERCENTAGE REMAINS-30%IN SAMPLES 1 ROP INCREASE TO 35 FPH.1.7 BPM IN/1.5 i BPM OUT. 01:30 - 02:45 1.25 DRILL P PROD1 IAT 11,300'WIPER TRIP TO WINDOW LOG ACROSS WINDOW AT 100 FPH.TIE-IN TO RA TAG WITH(+2.5)'.RIH TO DRILLING 1 1DEPTH 02:45 - 04:15 1.50 DRILL P PROD1 OBTAIN SPRAT 11,290': PUMP#1:0.5 BPM=1696 PSI,1.0 BPM=2150 PSI,1.7 BPM=3100 PSI PUMP#2:0.5 BPM=1655 PSI,1.0 BPM=2110 PSI,2.5 BPM=3100 PSI DRILL AHEAD FROM 11,300' 1.7 BPM IN/1.65 BPM OUT AT 3570 PSI, DHWOB 1.6 K# 9.84 PPG ECD,IAP 337 PSI,OAP 144 PSI, OOAP 490 PSI 04:15 - 06:00 1.75 DRILL P PROD1 START NEW MUD FROM PIT 1 DOWN THE COILAT 11350' DRILLING AT 50 FPH AT 1.75 BPM IN/1.7 BPM OUT NEW MUD IMPROVES SLIDING 06:00 - 06:40 0.67 DRILL P PROD1 CONTINUE DRILLING TO 11393 FT. ROP IS SUSTAINED AROUND 10 FT/HR WITH HIGH -------- --- --- DWOB TO ACHIEVE THAT. 06:40 08:40 2.00 DRILL P PROD1 POOH TO CHECK BIT. PULL THROUGH WINDOW AND PERFORM JOG ABOVE WINDOW,THEN OPEN EDC. FLOWCHECK IS GOOD. POOH,PUMP 2.1 BPM/3100 PSI. Printed 4/8/2013 11:20:34AM • North America-ALASKA-BP Page 7 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 I End Date:3/23/2013 X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 I Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA I UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) +- (usft) 08:40 - 09:00 0.33 DRILL P PROD1 PJSM NEAR SURFACE WHILE POOH FOR Ii LAYING DOWN BHA. I I TRIP SHEET IS-5 BBLS TO THIS POINT. PERFORM JOG AT SURFACE. FLOW CHECK WELL AT 200 FT,GOOD. 109:00 - 09:20 0.33 DRILL P PROD1 LID BHA#4. BIT IS 6-2,CORED ON THE NOSE. 109:20 - 09:40 0.33 DRILL P i 1 PROD1 i FUNCTION TEST BOPS FROM DRILLERS • y I CONSOLE ON RIG FLOOR. - 09:40 - 12:00 2.33 DRILL P PROD1 MAKE UP BHA#5,LATERAL DRILLING ! ASSEMBLY. !PRESSURE TEST QTS THEN RIH. •PUMP 0.8 BPM/1600 PSI THROUGH OPEN EDC. 12:00 - 13:00 1.00 DRILL P I PROD1 TIE-IN DEPTH FROM 10120 FT. CORRECT-36 FT. CLOSE EDC AND PASS THROUGH WINDOW. 13:00 - 15:00 2.00 T DRILL P PROD1 I DRILL FROM 11390 FT. HOLD 90L TF FOR NOW TO HOLD INC AND CONTINUE LH TURN I IN POLYGON. I '1.55/1.54 BPM @ 3000 PSI FREE SPIN. INITIAL ROP IS 40 FT/MIN. START SWAP TO NEW MUD. 15:00 - 16:20 i 1.33 DRILL P 1 PROD1 CONTINUE DRILING PAST 11540 FT. NEW ' MUD IS ALL THE WAY AROUND. GET SLOW PUMP PRESSURES WITH NEW I MUD SYSTEM. DRILL TO 11610 FT. 16:20 - 16:30 0.17 DRILL P PROD1 BHA WIPER FROM 11610 FT,CLEAN PAASS UP AND DOWN. 16:30 - 18:35 2.08 DRILL P I PROD1 DRILL TO 11620 FT. SLOW ROP WITH HIGH DWOB AND LITTLE MOTOR WORK,ACTING LIKE A SHALE. PICK UP AND CIRCULATE A SAMPLE UP TO I CONFIRM. 'GEOS CONSULT WITH TOWN. 18:35 - 20:00 ! 1.42 ! DRILL P 1 PROD1 DRILL AHEAD AT 11,620'. 1.67 BPM IN/OUT AT 3410 PSI,9.72 PPG ECD. '1.5 K#DHWOB,PVT=395 BBLS ROP 80 FPH 20:00 - 20:15 0.25 DRILL P PROD1 PULL UP TO GET SURVEYS AT 11647'AND 11677',BHA VIBRATION DIDN'T ALLOW TO SURVEY WHEN DRILLING. 20:15 - 20:40 0.42 DRILL P PROD1 DRILL AHEAD TO BHA WIPER DEPTH OF 11750'.BHA WIPER. 20:40 - 00:00 3.33 DRILL P PROD1 I DRILL AHEAD FROM 11,750'.1.5 BPM IN/OUT AT 3036 PSI. I 1 ROP SLOW TO 10 FPH AROUND 11810', !SAMPLE IS-65% 1.55 BPM IN/1.5 BPM OUT,2.6 K#DHWOB, 9.83 PPG ECD 1/11/2013 00:00 - 01:25 1.42 DRILL P PROD1 POH FOR BIT CHANGE 1.54 BPM IN/OUT FLOW CHECK ABOVE WINDOW,OPEN EDC CIRC AT 2.4 BPM THROUGH EDC AT 3650 PSI. 01:25 - 01:45 0.33 DRILL P PROD1 KICK WHILE TRIPPING DRILL WITH POWER OUTAGE COMPLEX DRILL WITH AAR. 01:45 - 03:00 1.25 DRILL P PROD1 POH FROM 9100'. 03:00 - 03:20 I 0.33 I DRILL P 1 PROD1 PJSM FOR LAYING DOWN BHA.JOG AT SURFACE.FLOW CHECK AT 200'. Printed 4/8/2013 11:20:34AM NorthAmerica-ALASKA-BPxr Page8 f13 Operation Summary Report Common Wet Name.06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor.NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00©64.00usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations - (hr) (usft) 03:20 - 03:50 0.50 DRILL P PROD1 STAND BACK INJECTOR. LAY DOWN BHA#5,BIT RATED 4-2 AND CORED. 03:50 - 06:30 2.67 DRILL P PROD1 CUT OFF COIL CONNECTOR,RIG UP HYDRAULIC CUTTER,CUT 50'OF COIL,RIG DOWN CUTTER,CUT 46'OF E-LINE. INSTALL COIL CONNECTOR,HEAD UP E-LINE FOR BHI. i 06:30 - 07:30 1.00 DRILL P PROD1 PRESSURE TEST QTS CONNECTION THAT WAS BROKEN APART TO CUT COIL TEST 250/3700 PSI AND CHART,GOOD. PRESSURE TEST CT CONNECTOR TO 300/ 3600 PSI,GOOD. 07:30 - 08:20 0.83 DRILL i P PROD1 MAKE UP BHA#6. LATERAL DRILLING ASSEMBLY WITH RESISTIVITY. BHA OAL=69.62 FT. MAKE UP CT RISER,PRESSURE TEST QTS. 08:20 - 09:50 1.50 DRILL I P PROD1 RIH BHA#6. - PUMP 0.4 BPM/1300 PSI THROUG OPEN EDC. 09:50 - 11:00 1.17 DRILL P PROD1 - TIE-IN DEPTH FROM 10120 FT. CORRECT-33.5 FT. CLOSE EDC. RIH AND PASS THROUGH WINDOW. 11:00 - 11:30 0.50 DRILL P PROD1 RECORD SLOW PUMP PRESSURES AT 11750 FT. 11:30 - 12:40 1.17 DRILL P PROD1 DRILL FROM 11810 FT. INITIAL ROP IS 30-50 FT/HR. PVT=359 BBLS. 12:40 - 13:30 0.83 DRILL P PROD1 CONTINUE DRILLING PAST 11818 FT,SLOW ROP. 1.66/1.58 BPM @ 3100 PSI FREE SPIN. ROP IS AROUND 10 FT/HR. PVT=348 BBLS. 13:30 - 14:30 1.00 DRILL P PROD1 AFTER 11830 FT ROP INCREASES. DRILL TO 11867 FT. 14:30 - 15:30 1.00 DRILL P PROD1 PICK UP AND CIRCULATE DUE TO GEOLOGIC UNCERTAINTY. APPEAR TO HAVE BEEN DRILLING A LONG SHALE INTERVAL. 15:30 - 18:00 2.50 DRILL P PROD1 CONTINUE DRILLING FROM 11867 FT. 18:00 - 20:00 2.00 DRILL P PROD1 DRILL FROM 11925' 1.68 BPM IN/1.62 BPM OUT AT 3760 PSI,10.1 PPG ECD 2.9 K#DHWOB,50-60 FPH ROP F LOSSES 4 BPH 20:00 - 22:00 2.00 DRILL I P PROD1 DRILL AHEAD FROM 12,100'. 1.57 BPM IN/1.48 BPM OUT,2.0K#DHWOB ROP 60 FPH BHA WIPER AT 12170' 22:00 - 00:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 12,170' 1.56 BPM IN/1.52 BPM OUT AT 3470 PSI. 1.8K#DHWOB,ROP 45 FPH. DRILL TO 12,265'. 1/12/2013 00:00 - 02:25 2.42 DRILL P PROD1 AT 12,265'WIPER TRIP TO WINDOW LOG AND TIE-IN AT WINDOW WITH(+2.5)' CORRECTION RIH TO DRILLING DEPTH Printed 4/8/2013 11:20:34AM • North America-ALASKA-BP Page 9 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:OOAM Rig Release:3/26/2013 Rig Contractor.NORDIC CALISTA UVN:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date I From-To Hrs 1 Task I Code ; NPT NPT Depth Phase � Description of Operations I (hr) (usft) 02:25 - 04:30 2.08 DRILL P PROD1 OBTAIN SPRSAT 12250' I ;PUMP#1:0.5 BPM=1950 PSI,1.0 BPM=2430 PSI,1.5 BPM=3120 PSI I PUMP#2:0.5 BPM=1959 PSI,1.0 BPM=2402 • II PSI,1.5 BPM=3102 PSI i i DRILLAHEAD FROM 12265'. I 1 1 11.5 BPM IN/1.46 BPM OUT,AT 3474 PSI WITH ECD 9.83 PPG 2.5 K#DHWOB,ROP 30-50 FPH 04:30 - 06:40 2.17 DRILL P PROD1 DRILL AHEAD AT 12320' 1.63 BPM IN/1.57 BPM OUT AT 3690 PSI � 2.8K#DHWOB,10.1 PPG ECD LOSSES 4-5 BPH. 06:40 - 09:00 2.33 DRILL P PROD1 DRILL TO 12398 FT,MAKING LITTLE , PROGRESS. POOH TO CHECK BIT. 5-7K OVERPULL WITH MOTOR WORK PULLING THROUGH SHALE INTERVAL FROM 11850-11780 FT. CONTINUE POOH. 09:00 - 09:30 1 0.50 DRILL P PROD1 DISCUSS WITH ODE OPTIONS FOR HANDLING EXPOSED SHALE INTERVAL, EITHER WEIGHTING UP MUD SYSTEM OR SETTING A BILLET. DECISION IS MADE TO SETA BILLET. 09:30 - 10:10 0.67 DRILL , P PROD1 RIH FOR CLEANOUT DOWN TO BILLET SETTING DEPTH. 10:10 - 10:50 0.67 DRILL P PROD1 MORE DISCUSSION AND DECISION IS MADE I NOT TO SETA BILLET. POOH FOR BIT CHANGE. 10:50 - 11:30 0.67 DRILL P PROD1PJSM AT 2000 FT FOR CHANGE OUT BIT. I TRIP SHEET IS-7 BBLS TO THIS POINT. 11:30 - 12:30 1.00 DRILL P PROD1 I TAG STRIPPER AND L/D BHA. BIT IS 4-2, I RUNG OUT. 2 MISSING NOSE CUTTERS,THE REST CHIPPED. i I M/U BHA#7 WITH NEW HCC BIT. CHANGE I I I OUT FLOAT SUB,HOURED OUT. M/U CT RISER AND PRESSURE TEST QTS, GOOD. 12:30 - 14:20 1.83 DRILL P ' PROD1 RIH BHA#7. , PUMP 0.6 BPM/1400 PSI THROUGH OPEN EDC. 14:20 - 15:35 1.25 DRILL P I PROD1 LOG TIE-IN FROM 10120 FT. CORRECT-35 FT. CONSISTENT WITH EARLIER CORRECTIONS. 15:35 - 16:00 0.42 DRILL P ( PROD1 PASS THROUGH WINDOW,RIH TO BOTTOM. REDUCE PUMP RATE GOING THROUGH SHALE FROM 11800 FT TO 11900 FT. STACK WT AND PICK UP AT 11815 FT,11850 FT,11880 FT,11890 FT. I PUSH THROUGH SHALE ZONE PAST 12100 FT GAIN 300 PSI ON ANNULUS,PICK UP TO CLEAR. 16:00 - 17:00 1.00 DRILL P PROD1 START NEW MUD DOWN THE CT. CONTINUE PICKING UP SLOWLY UNTIL NEW MUD IS AT BIT. 17:00 - 19:00 2.00 DRILL P PROD1 DRILL FROM 12400 FT. INITIAL ROP IS AROUND 120 FT/HR WITH GOOD WT TRANSFER. BHA WIPER AT 12,550'.CLEAN PICK UP. Printed 4/8/2013 11:20:34AM North America-ALASKA-BP Page 10 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 I Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM 1 Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA �UWI:500292028200 Active datum:2:02 5/1/1978 00:00©64.00usft(above Mean Sea Level) Date 1 From-To 1 Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) 1 (usft) 19:00 - 21:00 2.00 DRILL P PROD1 DRILL FROM 12,600 AT 150 FPH. 1.7 BPM IN/OUT AT 3620 PSI, 1.5-2#K DHWOB,10.1 PPG ECD } BHA WIPER AT 12,650'. 21:00 - 23:00 2.00 DRILL P PROD1 DRLL AHEAD AT 12,700'WITH VERY LOW i ROP.200 PSI MOTOR WORK BUT NO FORWARD PROGRESS PAST 12,710'. BHA WIPER,DROP PUMP RATE TO 1.5 BPM i IN/OUT,DRILL TO 12,721',CALL TD. 23:00 - 00:00 1.00 DRILL i P PROD1 WIPER TRIP TO WINDOW.OVERPULLS AT 12,020'AND 11,828'WITH MOTOR WORK. 1/13/2013 00:00 - 00:30 0.50 DRILL P PROD1 WIPER TRIP TO WINDOW 00:30 - 00:50 0.33 DRILL P PROD1 LOG TIE-IN AT WINDOW WITH(+4)' CORRECTION. - 00:50 - 02:15 1.42 DRILL P PROD1 RIH AND CONFIRM TD AT 12,719'. 02:15 - 03:30 1.25 DRILL P PROD1 POH FROM TD,FLOW CHECK,GOOD. LOSSES 4 BPH. 03:30 - 06:30 3.00 DRILL N WAIT PROD1 CIRCULATE ABOVE WINDOW WAITING ON WEATHER.UNABLE TO SWAP REELS WITH GUSTS UP TO 50 MPH AND PHASE 2 CONDITIONS. I 06:30 - 07:10 0.67 DRILL P PROD1 'POOH. 07:10 - 08:30 i 1.33 DRILL P PROD1 AT 7300 FT TRIP SHEET IS+2 BELS. STOP HERE AND 5 MIN FLOW CHECK IS GOOD,NO FLOW. 1 DISCUSS WITH DRILLER AND SLB SUPERVISOR,IDENTIFY REASON FOR DISCREPANCY. CONTINUE POOH. 08:30 - 09:30 1.00 DRILL P PROD1 PJSM FOR UD BHAAT 2000 FT. TRIP SHEET IS-3 BBLS TO THIS POINT. i PERFORM JOG AT SURFACE. FLOW CHECK WELL AT 200 FT,GOOD. 1 ! !TAG STRIPPER,L/D BHA#7. BIT IS 6-2,RUNG OUT. 09:30 - 10:00 0.50 DRILL P PROD1 DISCUSS PLAN FORWARD WITH ODE. DECIDE TO RUN LINER WITH THE E-LINE CT, WIND IS TOO HIGH TO SWAP REELS. 110:00 - 18:00 8.00 DRILL N 1 WAIT PROD1 IIPHASE 3 IS CALLED. STOP WORK ON RIG EXCEPT FOR CHECKING GENERATORS AND BOILERS PERIODICALLY. 1 i CIRCULATE ACROSS TOP TO KEEP HOLE i I FULL. LOSING ABOUT 1 BBLJHR. 18:00 - 00:00 6.00 DRILL N f WAIT PROD1 WAIT ON WEATHER,PHASE 3. CIRCULATE THROUGH COIL AND ACROSS THE TOP OF THE WELL.LOSS RATE 1-2 BPH. 1/14/2013 00:00 - 06:00 6.00 DRILL N WAIT PROD1 WAIT ON WEATHER,PHASE 3. CIRCULATE THROUGH COIL AND ACROSS THE TOP OF THE WELL.LOSS RATE 1-2 BPH. 06:00 - 18:00 12.00 DRILL N WAIT PROD1 CONTINUE WAITING ON PHASE 3 WEATHER. CIRC ACROSS TOP OF WELL,TAKING ABOUT 1 BBUHR. CIRC THROUGH CT. ,18:00 - 00:00 6.00 DRILL N WAIT PROD1 CONTINUE WAITING ON PHASE 3 WEATHER. AFTER 18:00 IMT NOT ALLOWING ANY TRAVEL IN THE FIELD,NO SHIFT CHANGE. Printed 4/8/2013 11:20:34AM North America-ALASKA-BP '.*.:',.,;.'''''' ''-Vi'' Page 11 of 13 Operation Summary Report Common Well Name.06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C.(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time 5/1/1978 12:00.00AM Rig Release:3/26/2013 Rig Contractor NORDIC CALISTA UWI:500292028200 Active datum.2:02 5/1/1978 00:00©64.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations (hr) ' (usft) 1/15/2013 00 00 - 05:00 5.00 DRILL N WAIT PROD1 CONTINUE WAITING ON PHASE 3 WEATHER. I AFTER 18:00 IMT NOT ALLOVv1NG ANY TRAVEL IN THE FIELD,NO SHIFT CHANGE. 05 00 - 05:45 0.75 DRILL N WAIT PROD1 CREW CHANGE WITH LOADER ESCORT. 05.45 - 07:00 1.25 DRILL N WAIT PROD1 CONTINUE TO WAIT ON PHASE 3 WEATHER I CONDITIONS. 07.00 - 09:00 2.00 DRILL N WAIT I PROD1 DISCUSS PLAN FORWARD FOR GOING BACK TO WORK WITH INCIDENT MANAGEMENT I . TEAM(IMT),ODE AND TOWN MORNING CALL. MAKE CHECKS AND WALKAROUNDS THROUGHOUT RIG. 09:00 - 11:00 2.00 DRILL N DPRB PROD1 PREP MWD TOOLS FOR CLEANOUT RUN, TEST CHECKS. 1 CHANGEOUT WITH NORDIC CREW FROM II TOWN. WARM-UP SECOND GENERATOR AND BRING POWERPACK ONLINE. 11.00 - 13:00 2.00 DRILL N DPRB PROD1 CONTINUE CLEARING PAD,ON HOLD FOR I PROCEEDING IN THE HOLE FROM IMT. WAITING UNTIL EMERGENCY SERVICES, I SPILL RESPONSE AND WELL CONTROL EQUIPMENT IS AVAILABLE IF NEEDED. 13:00 - 14:00 1.00 DRILL N DPRB 1PROD1 PJSM,PU BHA#8 COILTRAK CLEANOUT IASSEMBLY 14:00 - 14:20 , 0.33 DRILL N , DPRB PROD1 GET ON WELL WITH INJECTOR PRESSURE TEST QTS TO 250/3500 PSI. 14:20 - 16:15 I 1.92 1 DRILL N I DPRB PROD1 RIH WITH CLEANOUT BHA I PUMPING AT MIN RATE AND 140 PSI. 16:15 - 16:30 0.25 DRILL N DPRB PROD1 LOG GR TIE IN FROM 10,075'. SUBTRACT 35' CORRECTION. 16:30 - 19:30 3.00 DRILL N DPRB PROD1 RUN IN TO OPEN HOLE. 3040 PSI FS AT 1.58 BPM IN/1.68 BPM OUT. 32K#UP,8-9K#ON WT. TAKE WT AND MOTOR WORK THROUGH SEVERAL INTERVALS STARTING AT 11,800'. MOSTLY SMOOTH WITH PUMPS OFF. REAM AND BACK REAM SEVERAL INTERVALS DOWN TO TD AT 12723'. 19:30 - 21:00 1.50 DRILL N I DPRB PROD1 MAKE WIPER TRIP BACK TO 10,400'. I I 3630 PSI AT 1.57 BPM IN. PVT:235 BBLS. 5-8K#OVERPULLS FROM 11,860'TO 11,800'. SOME MOTOR WORK. '21:00 - 23:00 2.00 DRILL N DPRB PROD1 RIH BACK TO TD,HOLE IS CLEAN. PUMPING AT MIN RATE. 23:00 - 00:00 1.00 DRILL N DPRB PROD1 POH FROM TD OF 12719'.LAY IN 40 BBL LINER RUNNING PILL. 1/16/2013 00:00 - 02:00 2.00 DRILL N DPRB PROD1 FLOW CHECK ABOVE WINDOW,OPEN EDC. POH TO 1500'. 02:00 - 02:30 0.50 DRILL N DPRB PROD1 PJSM FOR BHA. i PERFORM JOG AT SURFACE,AT 200'CLOSE EDC AND POWER DOWN MWD TOOLS. FLOWCHECK FOR 5 MIN,NO FLOW. 02:30 - 03:30 1.00 DRILL N DPRB PROD1 GET OFF WELL,BLOW DOWN CLEANOUT BHA. LAYDOWN BHA#8 I SPOT NITROGEN UNIT FOR REEL BLOW DOWN. CONTINE ON CON EVENT 06-02B 01/16/13 Printed 4/8/2013 11:20:34AM North America-ALASKA-BP Page 12 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 'X3-012FV-C:(2,464,021.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date i From-To 1 Hrs 1 Task 1 Code I NPT I NPT Depth Phase Description of Operations (hr) (usft) 3/22/2013 01:30 - 05:00 3.50 MOB N DPRB PRE MOVE OFF WELL 06-08B,AT 02:30,PULL AND LAY RIG MATS,PREP 06-02B,MOVE OVER WELL AND SET DOWN. 05:00 - 05:30 0.50 MOB N DPRB PRE ACCEPT NORDIC 2 RIG CTD AT 05:30 ON 03/22/2013 05:30 - 06:00 ' 0.50 BOPSUR N DPRB PRE NIPPLE UP BOPS,RIG UP BY HAND. 06:00 - 06:30 0.50 BOPSUR N DPRB PRE CREW CHANGE. DISCUSS EQUIPMENT STATUS. 06:30 - 11:30 I 5.00 BOPSUR N DPRB ' PRE CONTINUE TO NU BOPS. INSTALL RISER AND NIGHT CAP. CONTINUE TO SPOT AND RU EXTERIOR EQUIPMENT. 11:30 - 13:00 1.50 BOPSUR N DPRB � PRE FILL BOPS. OBTAIN SHELL PRESSURE TEST TO 4950 PSI. SERVICE CT INJECTOR. 13:00 - 18:00 5.00 BOPSUR N DPRB PRE BEGIN PRESSURE TEST OF ALL BOP EQUIPMENT. AOGCC REP.C.SCHEVE ON RIG TO WITNESS TEST. TEST AS PER AOGCC REGULATIONS AND CRT-AK-10-45. CHART ALL TESTS. 18:00 - 19:00 1.00 BOPSUR N DPRB PRE CREW CHANGE.DISCUSS EQUIPMENT STATUS.INSPECT EQUIPMENT PERFORM WALK AROUND EQUIPMENT INSPECTIONS.CLEANED HI PRESSURE SCREENS,PREPARE TO TEST INNER REEL VALVE. 19:00 - 20:00 1.00 BOPSUR N SFAL PRE PUMP 7 BBLS KCL THRU COIL.REVERSE CIRCULATE THRU COIL WITH 3 BBLS KCL.COIL PRESSURED UP,UNABLE TO PUMP THRU COIL EITHER DIRECTION.DECIDED TO CUT COIL TO FIND ICE PLUG IN THE LINE. 20:00 - 21:30 1.50 BOPSUR N DPRB PRE HELD PJSM FOR CUTTING COIL.CUT 110'FT. OF COIL. R/D COIL CUTTER,PREPARE TO INSTALL BAKER THRU TUBING COIL CONNECTOR. '21:30 - 22:30 1.00 BOPSUR N DPRB PRE PULL/PRESSURE TEST COIL CONNECTOR. 22:30 - 23:00 0.50 BOPSUR N DPRB PRE PERFORM EVACUATION DRILL.ALL PERSONEL REPORTED TO THE PRIMARY MUSTER AREA.HELD MR AND DISCUSSED HIGH POINTS OF EVAC DRILL. 23:00 - 00:00 1.00 BOPSUR N DPRB PRE PJSM,PU EQUIPMENT TO RIG FLOOR AND RIG UP LUBRICATOR 3/23/2013 05:00 - 06:00 1.00 RIGU N DPRB PRE MU NOZZLE BHA.RIH WITH NOZZLE THRU CHOKE WHILE HOLDING 1500 PSI BACK _ PRESSURE ON WELLHEAD. 00:00 - 00:30 0.50 RIGU N DPRB PRE RU LUBRICATOR 00:30 - 01:30 1.00 BOPSUR N DPRB PRE PT LUBRICATOR,250PSI LOW FOR 5 MIN, 3500PSI HIGH FOR 5MIN Printed 4/8/2013 11:20:34AM North America-ALASKA-BP Page 13 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/4/2013 End Date:3/23/2013 X3-012FV-C:(2,464,021.00) I Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 II Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00©64.00usft(above Mean Sea Level) Date From-To Hrs Task Code , NPT NPT Depth Phase Description of Operations (hr) _ I T„ (usft) 01:30 - 02:30 1.00 BOPSUR 1 N DPRB PRE PULL TWC,EQUALIZE PRESSURE IN LUBRICATOR WITH FORMATION PRESSURE AT 1500 PSI.RIH WITH 'LUBRICATOR,SCREW INTO TWC, PULL TING,CLOSE SWAB&MASTER VALVE, LEAK TIGHT TEST PER 1 PROCEDURE.R/D LUBRICATOR. 02:30 - 05:00 2.50 BOPSUR N 1 SFAL j i PRE ,QTS SEAL OBSERVED LEAKING,CHANGED I SEAL AT ATTEMPT TO RE-TEST. QTS SEAL STILL LEAKING,INSTALL ANOTHER SEAL AND RE-TEST. REMOVE QTS,INSTALL 3'LUBRICATOR EXTENTION AND TEST SAME. _ I NO VISIBLE LEAKS FOUND-PASS TEST. 06:00 - 06:30 0.50 RIGU N DPRB PRE CREW CHANGE. DISCUSS KILL OPERATION. CHECK EQUIPMENT AND MAKE ROUNDS. CONTINUE TO CIRCULATE IN TO WELL WHILE RIH. 06:30 - 09:30 3.00 RIGU N DPRB PRE RUN IN HOLE. CIRC 20 BBLS MEOH TO TIGER TANK WHILE RIH THROUGH GAS CAP. RIH AT 50 FPM DUE TO DRY 13 CR TBG. ITP:1650 PSI. 09:30 - 11:00 1.50 RIGU N DPRB PRE •CIRCULATE WELL TO TIGER TANK HOLD 1600 PSI WHP. 1350 PSI CIRC PRESS I (INDICATES SUBSTANTIAL GAS STILL IN TBG) _ 11:00 - 12:00 1.00 RIGU N DPRB PRE REDUCE WHP TO 750 PSI. CBU. ESTABLISH I FULL RTNS KCL. 1230 PSI AT 1.5 BPM. FLOW CHECK AFTER CBU. SOME GAS. 12:00 - 13:30 1.50 RIGU N DPRB ! PRE CIRCULATE BTMS UP THROUGH MGS HOLDING 300 PSI WHP. FLOW CHECK FOR 20 MIN. WELL STABLE. 13:30 - 16:00 2.50 RIGU N DPRB PRE PJSM WITH NORDIC DRILLER. CIRCULATE OUT OF HOLE. 16:00 - 16:30 0.50 RIGU N DPRB PRE AT SURFACE. FLOW CHECK PJSM. GET OFF WELL.UNSTAB COIL. PULL BACK INJECTOR. 16:30 - 17:30 1.00 RIGU N ' DPRB PRE I INSTALL QTS SUB ON SLB RISER. PRESSURE TEST TO 250 AND 3600 PSI. CHART. PASSED. Printed 4/8/2013 11:20:34AM North America-ALASKA-BPS - ,.-<. .,;. Page 1 of 13} nay t Operation Summary Report ,_, . Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:1/16/2013 End Date:1/25/2013 IX3-012FV-C:(1,302,011.00) Project:Prudhoe Bay Site:PB DS O6 Rig Name/No.:NORDIC 2 Spud Date/lime:5/1/1978 12:00:OOAM Rig Release:3/26/2013 Rig Contractor.NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To Hrs I Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1/16/2013 03:30 - 04:00 0.50 CASING P RUNPRD PRESSURE TEST NITROGEN UNIT LINE TO 1250/3500 PSI FOR 5 CHARTED MIN. , I PUT INJECTOR BACK ON WELL,CLOSE SWAB VALVE FOR REEL BLOW DOWN. 04:00 - 04:20 0.33 CASING P RUNPRD 'PJSM FOR PUMPING NITROGEN. 04:20 - 05:00 0.67 CASING P RUNPRD 'CIRCULATE FLUID IN REEL PRIOR TO BLOW i DOWN:30 BBLS OF FRESH WATER,10 BBLS _ OF INHIBITED WATER,10 BBLS OF MEOH. 05:00 - 06:00 1.00 CASING P RUNPRD !RIG DOWN NITROGEN UNIT,PREP TO PULL COIL ACROSS.___ 06:00 - 06:30 0.50 CASING P RUNPRD CREW CHANGE. DISCUSS CURRENT AND PAST OPS. MAKE EQUIPMENT CHECKS INSIDE AND OUTSIDE RIG. CONTINUE TO PREP TO UNSTAB COIL. 06:30 - 11:15 4.75 CASING P RUNPRD HOLD PJSM. UNSTAB AND SECURE COIL TO REEL W/SHIPPING BAR. HOLD PJSM WITH CHILL DRIVERS. SPOT TRAILER. LOWER REEL FROM RIG AND SECURE ON TRAILER. _ 11:15 - 15:00 3.75 CASING _ P RUNPRD SPOT E-FREE REEL UNDER RIG. ATTACH LIFT SLINGS. LIFT REEL IN TO PLACE AND SECURE TO REEL STAND. INSTALL HARDLINE COMPONENTS IN REEL. 15:00 - 17:00 2.00 CASING P RUNPRD INSTALL GRAPPLE. PULL COIL ACROSS AND STAB IN INJECTOR. 17:00 - 20:30 3.50 CASING P I RUNPRD INSTALL BTT SLIP TYPE COIL CONNECTOR, FILL COIL WITH FLUID:MEOH,WATER AND THEN MUD. PRESSURE TEST CTC TO 250/3800 PSI,PULL TEST SAME TO 35K LBS.INSTALL DART j CATCHER ON CTC. 20:30 - 21:00 0.50 CASING P I RUNPRD I PRESSURE TEST INNER REEL VALVE AND PACK-OFF TO 250/3500 PSI FOR 5 CHARTED MIN. 21:00 - 21:50 0.83 CASING P I RUNPRDLAUNCH PEE WEE DART TO DRIFT COIL. I �DART LANDED AT 43.3 BBLS PUMPED, SHEARED DART CATCHER AT 3400 PSI. UNSTAB INJECTOR,SET ON LEGS. 21:50 - 22:15 0.42 CASING P RUNPRD I FUNCTION TEST BOPE FROM DRILLER'S 1 PANEL WITH 2'TEST JOINT. OPEN UP SWAB AND FILL HOLE WITH 1.3 BBLS 22:15 - 22:35 0.33 CASING P RUNPRD PJSM FOR RUNNING LINER WITH RIG CREW, i _TP,WSLAND BTT REP. 22:35 - 00:00 1.42 CASING P RUNPRD MU GUIDE SHOE,FLOAT COLLAR,1 JT OF 2-3/8"LINER,FLOAT AND LATCH COLLAR. MU 30 JOINTS OF 2-3/8°STL LINER.TORQUE ' MU 600 FT-LBS.DRIFT EACH CONNECTION WITH 1.80 DRIFT. STAB SAFETY JOINT AND FILL LINER. 1/17/2013 00:00 - 04:15 4.25 CASING P RUNPRD CONTINUE MAKING UP 2-3/8"LINER DRIFTING EACH CONNECTION WITH 1.80"DRIFT. 04:15 - 04:35 0.33 CASING i P RUNPRD MU LINER RUNNING TOOL. ' 'GET ON WELL,PRESSURE TEST QTS TO 250/3500 PSI. Printed 4/8/2013 11.21:10AM North America-ALASKA-BP Page 2 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) j Start Date:1/16/2013 ! End Date:1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:_2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 04:35 - 06:00 1.42 CASING P RUNPRD I RIH WITH LINER. 06:00 - 06:15 0.25 CASING P RUNPRD CREW CHANGE. DISCUSS CURRENT AND PAST OPS. MAKE EQUIPMENT CHECKS AND ROUNDS. CONTINUE TO RUN IN HOLE WITH 2-3/8" SOLID LINER. 06:15 - 09:30 3.25 CASING P RUNPRD RUN IN HOLE WITH 2-3/8"LINER. CIRC AT MIN RATE. BOUNCE THROUGH 22N SHALE AT 11,800-850% SHALE AT 12,040 ALOT MORE DIFFICULT TO WORK THROUGH. SLOWLY WORK LINER DOWN TO 12,542'. 09:30 - 10:30 1.00 CASING P RUNPRD PUMP 10 BBLS MINERAL OIL. DISPLACE AT 0.75 BPM AT 2650 PSI. RTNS STABILIZE AT 0.46 BPM. '10:30 - 11:15 0.75 CASING P RUNPRD BEGIN WORKING PIPE DOWN FROM 12,542'. MAKE AND LOSE FOOTAGE,BUT SLOWLY GAINING ON IT. WITH MOST OF MINERAL OIL OUT,WEIGHT TRANSFER IMPROVED DRAMATICALLY, FROM-3-5k#TO+3-5K#. ESTIMATE TOP OF MIN OIL WAS AT+/-9500'WHEN WEIGHT TRANSFER IMPROVED. TAG TD AT 12,749'UNCORRECTED. SUBTRACT ESTIMATED 30'CORRECTION PUTS LINER SHOE AT 12,719'. 26K#UP,5K#DN WT AT TD. 11:15 - 12:15 1.00 CASING P RUNPRD I MEASURE AND DROP 5/8"STEEL BALL. VERIFY MOVING IN REEL,THEN OVER GOOSENECK. 0.99 BPM AT 2651 PSI. OUT RATE:0.7 BPM. SLOW RATE TO 0.53 BPM IN/0.2 OUT. BALL ON SEAT AT 37.9 BBLS. PRESSURE TO 4350 PSI. SEAT SHEARED. PU COIL TO NEUTRAL WT. NEW UP WT 19K#. OFF LINER. 12:15 - 16:45 4.50 CASING P RUNPRD DISPLACE WELL TO 1%KCL. 1747 PSI. 1.36 BPM IN/1.0 BPM OUT. LOAD PITS WITH KCLAND SPOT BIO VAC _TRUCK. 16:45 - 18:00 1.25 CASING P RUNPRD HOLD PJSM WITH ALL HANDS IN CEMENT 1 JOB. DISCUSS PUMP SCHEDULE,COMMS, SAFE AREA,EXTERNAL TRAFFIC CONTROL, COLD WEATHER OPS,ROLES& RESPONSIBILITIES. TAKE ON WATER TO PT HARDLINE FROM SLB TO RIG. PUMP 5 BBLS FRESH WATER. LOW PT TO 310 PSI FOR 5 MIN. HIGH PT TO 6200 PSI FOR 5 MIN. CHART TESTS. PASSED. Printed 4/8/2013 11:21:10AM • North America-ALASKA-BP Page 3 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) I Start Date:1/16/2013 ; End Date:1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay I Site:PB DS 06 Rig Name/No.:NORDIC 2 1 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase i Description of Operations (hr) (usft) 18:00 - 20:00 2.00 CASING P , RUNPRD BATCH UP 12 BBLS OF 15.8 PPG CLASS G I CEMENT.BATCH UP TIME 18:30.LOAD 12 BBLS CEMENT IN COIL FROM CEMENTERS. SEND BIOZAN TO CEMENTERS FOR CLEANUP.LOAD DART IN COIL.DISPLACE CEMENT WITH BIOZAN AT 1.8 BPM AND 2900 PSI,SLOW RATE TO 1 BPM BEFORE PEE WEE DART LANDS,ZERO THE OUT MICROMOTION WHEN CEMENT AT SHOE. I CIRC PRESSURE INCREASING AS CEMENT IS 1 I PUMPED UP BACKSIDE AT 1 BPM.SHEAR 1 j I LINE WIPER PLUG AT 4100 PSI AND 58 BBLS PUMPED.DROP RATE DOWN TO 0.25 BPM FOR FINAL DISPLACEMENT.OVER DISPLACE BY 1 BBL AND SHUTDOWN PUMP.CHECK 1 FLOATS,NO FLOW.CEMENT IN PLACE AT 120:00 WITH 8.2 BBLS CEMENT BEHIND LINER. I I NOTE:AT THE END OF THE CEMENT DISPLACEMENT AS THE LWP PASSED I THROUGH THE LAST 10 CONNECTIONS OF 2-3/8"LINER,THERE WERE PRESSURE SPIKES EVEN THOUGH EACH CONNECTION I OF THE LINER HAD BEEN DRIFTED WITH A I 1.8"DRIFT AFTER MAKE UP. 20:00 - 22:00 2.00 CASING P RUNPRD UNSTING FROM LINER,IMMEDIATELY CIRCULATE 5 BBLS BIOZAN AT LINER TOP. POH CIRCULATING 0.6 BPM AND 700 PSI 22:00 - 23:00 1.00 CASING P RUNPRD PJSM FOR LAYING DOWN CEMENTING BHA. 'FLOW CHECK AT SURFACE FOR 5 MIN,GET OFF WELL. I LAY DOWN CEMENTING/LINER RUNNING BHA. RECOVER 5/8"BALL. 23:00 - 00:00 I 1.00 EVAL P • OTHCMP MU CLEANOUT BHA WITH 1.75"HCC MILL. 'PICK UP 1"CSH FROM PIPE SHED,DRIFTING WHEN PICKING UP. PUMP THROUGH EVERY 30 JOINTS. 1/18/2013 00:00 - 03:30 3.50 EVAL P OTHCMP I PICK UP 1"CSH FROM PIPE SHED,DRIFT WHEN PICKING UP. PUMP THROUGH EVERY 30 JOINTS. 108 TOTAL JOINTS OF CSH PICKED UP. 03:30 - 04:00 0.50 EVAL P OTHCMP I PICK UP INJECTOR,GET ON WELL. PRESSURE TEST QTS TO 250/3500 PSI. 04:00 - 05:30 1.50 EVAL P OTHCMP ;RIH WITH CLEANOUT BHA 05:30 - 05:40 0.17 EVAL P OTHCMP ABOVE LINER TOP AT-9640',UP WEIGHT IS 19K LBS. SPRS: PUMP 1:0.5 BPM=670 PSI,1.0 BPM=2074 I PSI PUMP 2:0.5 BPM=641 PSI,1.0 BPM=2000 I PSI -I-- 05:40 - 07:45 2.08 EVAL P OTHCMP I CLEANOUT INSIDE LINER PUMPING 1 BPM AT 2080 PSI. 2238 PSI AT 1.06 BPM IN. PVT:241 BBLS. RIH AT 25-30 FPM. TAG PBTDAT 12,707'.UNCORRECTED. VERIFY NOT CEMENT. Printed 4/8/2013 11:21:10AM North America-ALASKA-BP Page 4 of 13 Operation Summary Report Common Wet Name:06-02 AFE No Event Type:COM-ONSHORE(CON) I Start Date:1/16/2013 End Date:1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor.NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00©64.00usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:45 - 11:00 3.25 EVAL P OTHCMP CIRCULATE OUT OF LINER. 2025 PSI AT 1.06 BPM IN. PVT:237 BBLS.27 FPM. FLOW CHECK AT LINER TOP. CONTINUE TO POOH. AT SURFACE. 11:00 - 14:00 3.00 EVAL P OTHCMP FLOW CHECK. HOLD PJSM. STAND BACK 54 STANDS OF 1"CSH IN DERRICK. 14:00 - 15:30 1.50 EVAL P OTHCMP LAY DOWN LINER CLEAN OUT TOOLS. CLEAN UP FLOOR AREA. 15:30 - 17:00 1.50 EVAL P I OTHCMP HOW DETAILED PJSM WITH ATLAS LOGGERS AND CREW. BRING TOOLS TO FLOOR. MAKE UP LOGGING TOOLS STRING. • 17:00 - 20:20 3.33 EVAL P OTHCMP RUN CSH FROM DERRICK 108 TOTAL JOINTS. 20:20 - 20:40 0.33 EVAL P OTHCMP PICK UP INJECTOR,GET ON WELL PRESSURE TEST QTS TO 250/3500 PSI. 20:40 - 22:00 1.33 EVAL P OTHCMP RIH WITH BAKER LOGGING TOOL ON CSH. - STOP AT 4500'TO VERIFY DEPTH CONTROL • 22:00 - 00:00 2.00 EVAL P OTHCMP AT 9250'STOP FOR 10 MIN TO BEGIN LOGGING INTERVAL ON TOOL LOG FROM 9300'AT 10 FPM PUMPING 0.4 BPM AT 650 PSI. 1/19/2013 00:00 - 03:00 3.00 EVAL P OTHCMP LOG DOWN AT 10 FPM PUMPING 0.4 BPM AT 650 PSI. 03:00 - 04:30 1.50 EVAL P OTHCMP TAG UP AT 12315',CONFIRM TAG 2 MORE TIMES,RECIPROCATE PIPE WHILE CIRCULATING OUT PERF PILL CALL ODE TO DISCUSS PLAN FORWARD. 04:30 - 06:00 1.50 EVAL P OTHCMP WAIT 5 MIN TO START UP HOLE LOG.LOG UP FROM 12320'AT 10 FPM. OVER PULL OF 10K LBS AT 12,250'.LOG UP AT 10 FPM. 06:00 - 06:30 0.50 EVAL P OTHCMP CREW CHANGE. DISCUSS PAST AND CURRENT OPS. MAKE EQUIPMENT CHECKS. COMMUNICATE WITH SLB SIMOP ON 6-24. CONTINUE LOGGING RUN. 06:30 - 09:30 3.00 EVAL P OTHCMP CONTINUE TO LOG UP PASS AT 10 FPM. 516 PSI AT 0.46 BPM IN. 24k#UP WT AT 9960'. LOG TO 9300'. 09:30 - 11:00 1.50 EVAL P OTHCMP FLOW CHECK PJSM. _PULL OUT OF HOLE WITH LOGGING TOOLS. 11:00 - 13:30 2.50 EVAL P OTHCMP AT SURFACE. FLOW CHECK. BET OFF WELL. UNSTAB COIL. STANDBACK CSH IN DERRICK 13:30 - 14:30 1.00 EVAL P OTHCMP PJSM. POWER DOWN AND REMOVE LOGGING TOOLS FROM WELL. LOWER TOOLS FROM RIG TO GROUND. 14:30 - 15:00 0.50 EVAL N DPRB 12,319.98 OTHCMP MU 1.875"DIAMOND MILL ON 1-11/16"MOTOR. 15:00 - 17:00 2.00 EVAL N DPRB 12,319.98 OTHCMP RUN 108 JOINTS OF 1"CSH FROM DERRICK STAB COIL. GET ON WELL. PT QTS TO 260 AND 3550 PSI. PASSED. 17:00 - 18:30 1.50 EVAL N DPRB 12,319.98 OTHCMP RUN IN HOLE. 604 PSI AT 0.41 BPM IN. PVT:361 BBLS. Printed 4/8/2013 11:21:10AM North America-ALASKA-BP Page 5 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:1/16/2013 End Date:1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UW:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 21:30 3.00 EVAL N DPRB 12,319.98 OTHCMP r ENTER LINER ABD CLEANOUT AT 25 FPM PUMPING 1.1 BPM AT 2160 PSI.PUMP 14 BBL HI-VIS SWEEP FOLLOWED BY 20 BBL HI-VIS SWEEP NEAR BOTTOM OF LINER.FROM 12,200 CLEANOUT AT 12 FPM. 21:30 23:30 2.00 EVAL N DPRB 12,319.98 I OTHCMP TAG 12,624'STALL,PICK UP AND RIH TO TAG PBTD. TAG PBTD AT 12,709'. POH LAYING IN 20 BBL PERF PILL. PAINT FLAG AT 8700'EOP 23:30 - 00:00 0.50 EVAL N DPRB 10,717.98 OTHCMP UNABLE TO POH FROM 10710'. 'OVER PULL 14K,SET 12K DOWN,NO PIPE (MOVEMENT. 1/20/2013 00:00 - 04:00 ' 4.00 EVAL N DPRB 10,717.98 OTHCMP WORK PIPE AT 10,718'. OVER PULL 14K,SET 12K DOWN,NO PIPE MOVEMENT. PUMP 20 BBL HI-VIS SWEEP. WORK PIPE FROM 20K OVER TO 15K DOWN. WORK PIPE 20 TIMES.NO PROGRESS DISCUSS PLAN WITH BP SUPT AND ODE. PUMP SECOND 20 BBLS HI VIS PILL AT 0.9 BPM AND 4500 PSI. 04:00 - 06:00 2.00 EVAL N DPRB 10,717.98 I OTHCMP WAIT ON DIRECTION. 06:00 - 06:30 0.50 EVAL N DPRB 10,717.98 OTHCMP CREW CHANGE. DISCUSS CURRENT OPERATIONS. MAKE EQUIPMENT CHECKS AND ROUNDS. DISCUSS PLAN FORWARD WITH TOWN. 06:30 - 08:30 2.00 EVAL N DPRB 10,717.98 OTHCMP PRESSURE CT ANNULUS TO 1000 PSI. DUMP PRESSURE WHILE PULLING 45K#. PRESSURE CT ANN TO 2000 PSI. DUMP AND PULL 45K#. SET DN IN BETWEEN ATTEMPTS. NO MOVEMENT. 08:30 - 11:00 2.50 EVAL N DPRB 10,717.98 OTHCMP CIRCULATE 20 BBLS MINERAL OIL DOWN COIL. SPOT 5 BBLS OUT SIDE PIPE. PULL 50K#. WORK PIPE. SPOT ADDITIONAL 5 BBLS AROUND COIL. PULL 55K#.NO MOVEMENT. 11:00 - 13:30 2.50 EVAL N DPRB 10,717.98 OTHCMP PUMP 5/8"ALUMINUM BALL DOWN REEL. 3200 PSI AT 0.80 BPM. BALL ON SEAT AT 41 BBLS(COIL VOL:43.5 BBLS) PRESSURE AND RELEASE FROM MOTOR FISH. 13:30 - 15:00 1.50 EVAL N DPRB 10,717.98 ( OTHCMP PJSM. FLOW CHECK.CIRCULATE OUT OF HOLE. AT SURFACE. 15:00 - 16:45 1.75 EVAL N DPRB 10,717.98 OTHCMP GET OFF WELL UNSTAB COIL STAND BACK CSH. PIPE PULLING WET. RECOVE UPPER HALF OF DISCONNECT. LD TOOLS. CLEAN UP RIG FLOOR. 16:45 - 17:30 0.75 BOPSUR P OTHCMP PERFORM LEAK TIGHT TEST PRIOR TO INSPECTING BOPS RAMS. 17:30 - 22:00 4.50 BOPSUR P OTHCMP OPEN UP RAM DOORS FOR INSPECTION CHANGE OUT TOP AND NOSE SEALS ON BLIND/SHEARS. FILL STACK 22:00 - 00:00 2.00 BOPSUR P OTHCMP PJSM FOR BOPE TEST. SHELL TEST BOPE.FUNCTION TEST FROM BOTH REMOTE PANELS. Printed 4/8/2013 11:21:10AM North America-ALASKA-BP Page 6 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:1/16/2013 End Date:1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase j Description of Operations (hr) (usft) 1/21/2013 00:00 - 03:00 3.00 BOPSUR P OTHCMP PRESSURE TEST BOPE PER ADWOP AND AOGCC REGULATIONS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH.- PRESSURE TEST ANNULAR PREVENTER WITH 2"TEST JOINT-FUNCTION TEST KOOMEY ACCUMULATOR UNIT PER BP WELL I CONTROL MANUAL AND NORDIC PROCEDURE.-FUNCTION ALL COMPONENTS FROM BOTH REMOTE STATIONS-TEST WITNESS IS WAIVED BY AOGCC INSPECTOR CHUCK SCHEVE.-SEE ATTACHED DOCUMENTATION REPORT AND CHARTS. 1 FAILURE:ANNULAR ELEMENT. 03:00 - 04:30 1.50 BOPSUR N RREP OTHCMP PJSM AND REVIEW PROCEDURE. REPLACE ANNULAR ELEMENT.RETEST ANNULAR AND SHELL TEST OF BOPE. TRACTION REPORT CREATED FOR BOPE FAILURE:IR 4335378 04:30 - 06:00 1.50 BOPSUR P OTHCMP CONTINUE BOPE TEST WITH INNER REEL VALVE AND PACK-OFF TEST. TEST AND CALIBRATE GAS ALARMS. 06:00 - 06:30 0.50 BOPSUR P OTHCMP CREW CHANGE. DISCUSS CURRENT OPS. MAKEEQUIPMENT CHECKS AND OUTSIDE ROUNDS. CONTINUE TO TEST BOPS. 06:30 - 07:30 1.00 BOPSUR P OTHCMP CONTINUE INNER REEL VALVE AND PACKOFF TEST. COLD WEATHER REQUIRES SPLITTING LOW AND HIGH PRESSURE TESTS,TO ALLOW COIL TO WARM UP.CHART TESTS. PASSED. 07:30 - 09:00 1.50 EVAL P OTHCMP CUT 100'OF COIL FOR CHROME MANAGEMENT. 09:00 - 12:00 3.00 EVAL N DPRB 10,718.98 OTHCMP HOLD PJSM WITH BTT REP AND CREW. MU 2"GS SPEAR WITH BOWEN OIL JAR WEIGHT BAR,AND ACCELERATOR. RUN ON 36 JOINTS OF CSH. STAB COIL. GET ON WELL. PT QTS CONNECTION. PASSED. 12:00 - 14:30 2.50 EVAL N DPRB 10,718.98 OTHCMP RUN IN HOLE. 0.61 BPM IN AT 1198 PSI. PVT:382 BBLS. Printed 4/8/2013 11:21:10AM � �� ` Nor i Arrierica-ALASKA BP 1'ag� 3 Operation Summary Report Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) I Start Date:1/16/2013 I End Date:1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 18:00 3.50 EVAL N DPRB 10,718.98 OTHCMP RUN IN LINER. WT CHECK ABOVE FISH:26K#UP, 10K#DN WT. CIRCULATE AT 3105 PSI AT 1.02 BPM IN TO WAH DOWN TO FISH. TAG FISH AT 10,712'. PU. FISH ENGAGED. SET DN TO 5K JAR DOWN 4 TIMES. FISH POPPED FREE DOWN. RIH TO 10,732'. STACK OUT. PU TO 110,701'. FISH STOPPED/STUCK AGAIN. WORK FISH UP AND DOWN 5 TIMES. UNABLE TO GET ABOVE 10701'. RELEASE FROM FISH AND WASH UP 100'AT 1.0 BPM @3100 PSI. RIH. ENGAGE FISH WITH GS SPEAR. CONTINUE TO WORK UP AND DOWN. ABLE TO POOH TO 10,655'WITH 43K#OVERPULLS. WORK DOWN TO LIMIT OF 1"CSH INSIDE LINER TO 10,759' DISCUSS WITH TOWN. AGREE TO GET ROUGHER WITH IT. WORKUP TO 10,655'. UNABLE TO GO UP OR DOWN. CIRC EVERY 10 MINUTES. CONTINUE TO WORK COIL.WORK FISH .DOWN TO 10733'AND PUMP OFF OF IT TO CIRCULATE COIL.FISH IS LOOSE IN WELL. 18:00 - 19:15 1.25 EVAL N DPRB 10,718.98 OTHCMP DISCUSS PLAN FORWARD WITH ODE,ETL AND WTL. 19:15 - 21:00 1.75 EVAL N DPRB 10,718.98 OTHCMP POH FROM 10,500',FLOW CHECK ABOVE WINDOW,NO FLOW. POH AND TAG UP,FLOW CHECK,NO FLOW. 21:00 - 21:30 0.50 EVAL N DPRB 10,718.98 OTHCMP PJSM FOR BHA. UNSTAB AND STAND BACK INJECTOR. 21:30 - 00:00 2.50 EVAL N DPRB 10,718.98 OTHCMP STAND BACK 38 JTS OF CSH,LAY DOWN BTT FISHING BHA,GS SPEAR IN GOOD CONDITION. 1/22/2013 00:00 - 03:30 3.50 EVAL N DPRB 10,709.98 OTHCMP MU MOTOR AND MILL,1 JT CSH,JARS ON 107 JTS OF CSH. 03:30 - 04:00 0.50 EVAL N DPRB 10,709.98 OTHCMP GET ON WELL. PRESSURE TEST QTS TO 250/3500 PSI 04:00 - 05:00 1.00 I EVAL N DPRB 10,709.98 OTHCMP RIH WITH BHA#14 TO CLEANOUT AND ATTEMPT PUSHING FISH TO BOTTOM 05:00 - 05:15 0.25 EVAL N DPRB 10,709.98 OTHCMP GET SPRS AT 9600' PUMP 1:0.5 BPM=1007,1.0 BPM=2366 PUMP 2:0.5 BPM=1000,1.0 BPM=2281 05:15 - 06:30 1.25 EVAL N DPRB 10,709.98 OTHCMP ENTER LINER,PUMP 10 BBL HI-VIS PILL. UP WEIGHT 21K,RUN IN WEIGHT 11K FREESPIN 2500 PSI AT 1.06 BPM CLEANOUT FROM LINER TOP AT 9640'TO 10,700'. NO MOTOR WORK 06:30 - 07:00 0.50 EVAL N DPRB 10,709.98 OTHCMP CREW CHANGE. DISCUSS OPS. MAKE RIG CHECKS AND ROUNDS. CONTINUE CLEAN OUT ABOVE FISH AT 10,730' 07:00 - 08:00 1.00 EVAL N DPRB 10,709.98 OTHCMP CONTINUE TO CLEAN OUT LINER. 2850 PSI AT 1.06 BPM IN. 08:00 - 08:30 0.50 EVAL N DPRB 10,709.98 OTHCMP TAG FISH AT+/-10730'. PUSH DOWN HOLE TO 10,785'. TAKE WEIGHT.SET 6-8K#DN. JAR 2x. NO ADDITIONAL DOWNWARD MOVEMENT.TOP OF FISH AT 10,785' Printed 4/8/2013 11:21:10AM North America-ALASKA-BPPage 8 of 13' Operation Summary Report h Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:1/16/2013 End Date.1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To I Hrs I Task Code ' NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 10:30 2.00 I EVAL N DPRB 10,784.98 , OTHCMP PJSM. FLOW CHECK CIRCULATE OUT OF LINER AND HOLE. 2531 PSI AT 1.06 BPM IN. AT SURFACE. 10:30 13:30 3.00 EVAL N 1 DPRB 10,784.98 OTHCMP PJSM. FLOW CHECK. GET OFF WELL WITH { INJECTOR. UNSTAB COIL. STAND BACK 54 STANDS OF 1"CS HYDRIL. LAY DOWN BHA#14,1.875"OD MILL AND I MOTOR. NO DAMAGE TO MILL. CLEAN AND CLEAR RIG FLOOR(PIPE PULLED WET) 13:30 - 14:00 0.50 EVAL N DPRB 10,784.98 OTHCMP MAKE UP BHA#15,2""GS"HYDRAULIC RELEASE SPEAR. HYDRAULIC DISCONNECT,JARS, ACCELERATOR,HI-LOAD HYDRAULIC DISCONNECT AT TOP OF BHA. 14:00 - 15:30 1.50 EVAL N DPRB 10,784.98 OTHCMP RIH WITH FISHING BHA#15 ON 1"CS HYDRIL • PIPE FROM THE DERRICK 15:30 - 15:45 0.25 EVAL N DPRB 10,784.98 OTHCMP PICK UP INJECTOR HEAD.MAKE COIL UP ONTO 1"CS HYDRIL. 15:45 - 16:00 0.25 EVAL N DPRB 10,784.98 OTHCMP STAB INJECTOR HEAD ONTO WELL. CONNECT AND TEST OTS. 16:00 - 18:00 2.00 EVAL N DPRB 10784.98 OTHCMP -RIH WITH 1"CS HYDRIL AND FISHING BHA ON COIL.TAG FISH,LATCH UP 18:00 - 19:30 1.50 EVAL N DPRB 10,784.98 OTHCMP WORK TO FREE FISH UP/DOWN 8 LICKS UP,2 DOWN, FREE FISH AND POH TO WINDOW W/MAX OVERPULL 45K,FLOW CHECK 19:30 - 21:00 1.50 EVAL N DPRB . 10,784.98 OTHCMP PJSM,POOH TO CSH,FLOW CHECK AND STAND BACK INJECTOR 21:00 - 00:00 3.00 EVAL N DPRB 10,784.98 OTHCMP STAND BACK CSH IN DERRICK 1/23/2013 00:00 - 01:00 1.00 EVAL N DPRB 10,784.98 OTHCMP LD BHA#15 AND GAUGE MILL. DAMAGE TO 1.875"MILL-MISSING 1 CUTTER FROM BACK RAKE ROW. GAUGED WITH 1.88"GAUGE RING-TIGHT. CLEANED RIG FLOOR-PREPARE TO PU BHA #16. 01:00 - 04:00 3.00 EVAL N DPRB 10,784.98 OTHCMP MU BHA#16 AND BEGIN RIH F/Cr-3350'MD. 04:00 - 04:30 0.50 EVAL N DPRB 10,784.98 OTHCMP GET ONTO WELL WITH INJECTOR. PRESSURE TEST QTS-GOOD. 04:30 - 07:45 3.25 EVAL N DPRB 10,784.98 OTHCMP RIH MILL BHA ON COIL AT 30 FPM PUMPING AT 1 BPM. STACKED OUT AT 10,630'.STALL MOTOR. PICK UP 20'TO FREE PIPE. RUN IN AT 1 FPM.TAKING WEIGHT AT 10,630'. MAKE SEVERAL ATTEMPTS TO GO DOWN WITH NO PROGRESS. JARS FIRED UP ONCE WHILE WORKING TIGHT PIPE. PIPE FREE TO GO UP AND DOWN. DECISION MADE TO POH AND CHANGE TO SMALLER MILL SIZE. 07:45 - 09:30 1.75 EVAL N DPRB 10,784.98 OTHCMP POH MILLING BHA WITH COIL TO TOP OF 1" CS HYDRIL 09:30 - 09:45 0.25 EVAL N DPRB 10,784.98 OTHCMP DISCONNECT INJECTOR FROM WELL.STAND BACK ON STAND. Printed 4/8/2013 11.21.10AM North America-ALASKA-BP Page 9 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) j Start Date:1/16/2013 End Date:1/25/2013 `X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay I Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM I Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA !UW:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations _i_ (hr) i_ (usft) 09:45 - 11:15 1.50 EVAL N 1 DPRB 10,784.98 OTHCMP !PON WITH MILLING BHA ON 1"CS HYDRIL ,AND STAND BACK IN DERRICK LAY DOWN BHA. DISCOVERED THE 1.875"OD MILL BROKEN 3" DOWN FROM THE PIN. THE PIN AND 3"OF THE MILL BODY STILL SCREWED INTO THE MOTOR. 11:15 - 20:30 I 9.25 EVAL I N DPRB 10 629.98 i OTHCMP 'DISCUSS FORWARD PLAN WITH ODE AND TOWN TEAM. BAKER THROUGH TUBING WORKING UP A SUGGESTED BHA AND PLAN.DECISION MADE TO PICK UP HIPP-TRIPPER AND CSH 20:30 - 21:45 1.25 EVAL N DPRB 10,629.98 OTHCMP PJSM,PICKUP HIPP-TRIPPER BHA#17,AND 36-JTS OF CSH 21:45 - 22:15 0.50 EVAL N DPRB 10,629.98 OTHCMP PICK UP INJECTOR,QTS TEST-PASS, 22:15 - 00:00 1.75 EVAL N DPRB 10,629.98 OTHCMP RIH,TAG @ 9,705',PICK UP TO 9,600',SLACK BACK OFF AND GO RIGHT BY,CONTINUE TO RIH 1/24/2013 00:00 - 00:30 0.50 EVAL N DPRB 10,630.00 OTHCMP RIH TO 10,500'MD WITH FISH PUSH 'ASSMEBLY. 00:30 - 02:30 2.00 EVAL ,N DPRB 10 524.00 , OTHCMP ESTABLISHED NEUTRAL PARAMETERS BEFORE ATTEMPTING TO PUSH FISH DOWNHOLE. PU 25K,SO 12.5K,BPM/PSI 0.5/600,0.8/ 980,1.0/1490,1.25/1890 RIH TAG UP ON FISH @ 10,524'MD.STALL,PU & ADJUST PUMP RATE. RIH AND STALL @ 10,522'MD,ADJUST PUMP RATES AND WOB. RIH AND STALL @ 10,517'MD,ADJUST PUMP RATES AND WOB. CONTINUED WORKING THE TOP OF FISH ' ATTEMPTING TO PUSH FISH DOWN WITH NO , PROGRESS NOTED.IMMEDIATE PRESSURE INCREASE NOTICED AS SOON AS THE BULL NOSE ON THE PUSH ASSEMBLY MAKES I CONTACT WITH THE FISH. SEE ATTACHED PICTURES OF BROKEN MILL 02:30 - 10:00 7.50 EVAL N DPRB 10,524.00 OTHCMP I NOTIFIED ODE OF CURRENT SITUATION, I DISCUSSED OPTIONS OF PLAN FORWARD. WAIT ON ORDERS. 1 ,FURTHER DISCUSSION WITH THE TOWN TEAM. DECISION MADE TO STOP WORKING ON THE I !WELL. CLEAN KCL ORDERED.TRUCKS ROLLING AT 106:30 10:00 - 11:00 1.00 EVAL N DPRB ' 10,524.00 OTHCMP SUCK DOWN PITS AND OFF LOAD TO TRUCKS. 11:00 - 13:00 2.00 EVAL N DPRB 10,524.00 1 OTHCMP DISPLACE WELL FROM TOP OF LINER AT 9639'TO SURFACE WITH NEW 8.5 PPG 2% 1 SLICK KCL WITH 0.6%SAFE LUBE. 13:00 - 14:30 1.50 EVAL N DPRB 10,524.00 OTHCMP POH FISH PUSHING/CLEAN OUT BHA ON COIL TO TOP OF 1"CS HYDRIL. Printed 4/8/2013 11:21:10AM North America-ALASKA-BP Page 10 of 13 Operation Summary Report --AiiiiiikidTh Ai,: Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) I Start Date:1/16/2013 End Date:1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay i Site:PB DS 06 Rig Name/No.:NORDIC 2 j Spud Date/Time:5/1/1978 12:00:00AM I Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 @64.00usft(above Mean Sea Level) Date 1 From-To 1 Hrs Task Code I NPT I NPT Depth Phase Description of Operations (hr) (usft) l 14:30 - 15:15 0.75 EVAL N DPRB 10,524.00 OTHCMP 1 DISCONNECT COIL FROM 1"TUBING.STAND BACK INJECTOR HEAD ON STAND. FLOW CHECK. AMBIENT TEMPERATURE DROPPING BELOW I j 1 I 30F. I I CIRCULATE THROUGH COIL. 15:15 - 16:30 � 1.25 1 EVAL N DPRB 10,524.00 OTHCMP I POH WITH 1"CS HYDRIL AND STAND BACK — LAY DOWN FISHING/CLEAN OUT BHA. 16:30 - 17:00 0.50 EVAL P 1 OTHCMP CLEAN AND CLEAR RIG FLOOR.INSTALL CAP ON LUBRICATOR AT FLOOR. 17:00 - 17:15 0.25 EVAL P 1 OTHCMP I RIG UP TO PRESSURE TEST THE 2 3/8"LINER I TOP. FILL SYSTEM WITH CLEAN KCL.BLEED OFF I AIR. 17:15 - 17:45 0.50 EVAL P OTHCMP PRESSURE TEST 23/8"LINER TOP AT 9639'. THE VOLUME REQUIRED TO PRESSURE THE 41/2"TUBING AND 2 3/8"LINER TO 12,682'IS CALCULATED TO BE 1.37 BBL. AFTER PUMPING 5.3 BBL THE PRESSURE ROSE TO 1600 PSI. PUMP WAS STOPPED AND THE PRESSURE FELL TO 1100 PSI IN THREE MINUTES. SEE ATTACHED CHART. NOTIFIED THE FIELD SUPERINTENDENT,ODE AND WTL. APPROVAL RECIEVED TO CONTINUE WITH THE OPERATION. 17:45 - 18:30 0.75 EVAL P OTHCMP RIG DOWN PRESSURE TEST LINES AND I I EQUIPMENT.MU INJECTOR 18:30 - 19:00 0.50 I EVAL P OTHCMP HOT OILER.SPOT LRS TRUCK AND LOAD DEISEL BACK INTO TRANSPORT 19:00 - 20:00 1.00 EVAL N RREP I OTHCMP I PJSM TO FREEZE PROTECT.ICE PLUG IN 1 TIGER TANK HARD LINE,CLEAR 'OBSTRUCTION FITH STEAM LINE 20:00 - 21:30 1.50 I EVAL P OTHCMP PUMP FREEZE PROTECT INTO WELL,WHILE POOH FROM 2500'MD TO 0'MD 21:30 - 00:00 2.50 EVAL P OTHCMP BLOW DOWN ALL LINES BACK TO TIGER TANK,PJSM WITH SLB N2,RIG UP AND BEGIN COOLING DOWN N2 UNIT 1/25/2013 00:00 - 03:30 3.50 BOPSUR P 1 OTHCMP PJSM WITH CREW,RU SLB N2 UNIT AND I TEST SAME-PASS. BLOW DOWN COIL WITH N2 PER PROCEDURES,BLEED PRESSURE OFF OF COIL.RIG DOWN SLB N2 UNIT. NOTIFIED AOGCC OF UPCOMING BOP TEST ON WELL 06-22B FOR SATURDAY JAN 26,2013. RECEIVED ACKNOWLEDGEMENT OF NOTIFICATION 03:30 - 04:00 . 0.50 BOPSUR P , 1 OTHCMP I PJSM WITH VALVE CREW,GREASE TREE I AND INSTALL BPV. 04:00 - 05:00 1.00 BOPSUR P OTHCMP I FREEZE PROTECT TREE WITH MEOH. I BLOW DOWN LINES. 05:00 - 05:30 T 0.50 BOPSUR P 1 r&HCMP PERFORM LEAK TIGHT TEST BETWEEN SSV I &SWAB-CONFIRM BREAKING 1 CONTAINMENT BARRIERS GOOD. Printed 4/8/2013 11:21:10AM North America-ALASKA-BP Page 11 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:1/16/2013 End Date:1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor:NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 0164.00usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 09:00 3.50 BOPSUR P OTHCMP I PULL COIL THROUGH THE INJECTOR HEAD AND ACROSS TO THE REEL HOUSE WITH THE GRAPPLE AND TUGGER LINE.SECURE END OF COIL TO THE SHIPPING BAR. RIG DOWN INNER REEL HARDLINE. DISCONNECT REEL MOTOR AND REEL PLATE. RIG DOWN AND READY REEL FOR LOWERING. 09:00 - 09:45 0.75 BOPSUR P OTHCMP PJSM WITH NORDIC,SLB AND CH2MHILL CREWS ON LOWERING THE 2"COIL TO A LOW BOY. OPEN REEL HOUSE BOMB BAY DOOR. LOWER REEL OUT OF REEL HOUSE ONTO LOW BOY. SECURE LOAD.CLOSE DOOR. 09:45 - 11:15 1.50 BOPSUR P OTHCMP REMOVE 2"COIL.BACK IN 2"E-COIL ON LOW BOY. 11:15 - 11:30 0.25 BOPSUR P OTHCMP OPEN BOMB BAY DOOR.LOWER BRIDGE CRANE. ATTACH BRIDG CRANE TO 2"E-COIL. LIFT COIL TO REEL HOUSE AND CLOSE DOOR. 11:30 - 13:45 2.25 BOPSUR P OTHCMP CONNECT COIL TO REEL MOTOR AND REEL PLATE. CONNECT INNER REEL HARD LINE. RIG UP REEL. CREW INSPECT BOP RAMS 13:45 - 14:30 0.75 BOPSUR P OTHCMP PULL COIL ACROSS FROM REEL HOUSE TO INJECTOR HEAD WITH TUGGER LINE. RIG DOWN TUGGER LINES. SET BACK INJECTOR ON STAND. CREW INSPECT BOP RAMS. 14:30 - 16:00 1.50 BOPSUR P OTHCMP '.REMOVE LUBRICATOR EXTENSION. I INSPECT BOP RAMS. CLOSE ALL RAM DOORS. NIPPLE DOWN BOP AND HANG OFF UNDER FLOOR. 16:00 - 19:30 3.50 BOPSUR P OTHCMP INSTALL TREE CAP FLANGE AND TEST TO 200 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES EACH TEST. 19:30 - 20:00 0.50 BOPSUR P I OTHCMP INSPECT DRIVE SYSTEM.RELEASE RIG AT 2000 HRS. SEE RON REPORT#1 DS 06-22B 3/23/2013 17:30 - 19:30 2.00 EVAL N DPRB 12,718.00 OTHCMP PREP FLOOR,GATHER LOGGING TOOLS AND CREW CHANGE 19:30 - 00:00 4.50 EVAL N DPRB 12,718.00 OTHCMP HELD PJSM WITH LOGGING CREW,MU LOGGING TOOLS,RIH PICKING UP 100 JTS 1" CSH. 3/24/2013 00:00 - 00:30 0.50 EVAL N DPRB 12,718.00 OTHCMP STAB COIL,GET ON THE WELL,PRESSURE TEST QTS 250 LOW/3500 HIGH. 00:30 - 01:30 1.00 EVAL N DPRB 12,718.00 OTHCMP RIH ON COIL TO 9,300'.BEGIN LOGGING RUN WITH SLB MEMORY LOGGERS. 01:30 - 04:15 2.75 EVAL N DPRB 12,718.00 OTHCMP LOG DOWN F/9,300'-12,686'MD el 30'FPM. LOG UP F/12,686'-12,504'MD t 60'FPM. LOW GAS ALARM SOUNDS SHUT IN WELL(120 PSI TRAPPED PRESSURE SEEN AT WELLHEAD) Printed 4/8/2013 11:21:10AM North America-ALASKA-BP Page 12 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:1/16/2013 End Date:1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor.NORDIC CALISTA UWI:500292028200 Active datum:2:02 5/1/1978 00:00 t 64.00usft(above Mean Sea Level) Date : From-To Hrs I Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) 04:15 - 04:30 I 0.25 EVAL N DPRB 12,718.00 OTHCMP MONITOR THE WELL,BLEED OFF TRAPPED PRESSURE, MICRO MOTION PLUGGED,BLOW DOWN MICRO MOTION 04:30 - 05:30 1.00 EVAL N DPRB 12,718.00 OTHCMP NOTIFY WOS,OPEN WELL,FLOW CHECK- NO FLOW. CLOSE CHOKE,0 PRESSURE BUILD UP OBSERVED. LINE UP TO MUD GAS SEPERATOR, CIRCULATE THROUGH MGS AT 1 BPM. 05:30 - 09:00 3.50 EVAL j N DPRB 12,718.00 OTHCMP CIRCULATE THRU MGS AT 1 BPM. MIX REPLACEMENT PERF PILL IN PIT 4. 09:00 - 10:00 1.00 EVAL N DPRB 12,718.00 OTHCMP MAKE SLB CNL-GR LOGGING PASS UP FROM PBTD. TAGGED PBTD AT 12675' (UNCORRECTED) LOG AT 60 FPM. LOG TO 9100'. PAINT EOP FLAG AT 9200'. 10:00 - 11:30 1.50 EVAL N DPRB 12,718.00 OTHCMP FLOW CHECK. HOLD PJSM. CIRCULATE OUT OF HOLE. 11:30 - 14:00 2.50 EVAL N DPRB 12,718.00 OTHCMP AT SURFACE. FLOW CHECK. PJSM. UNSTAB COIL. GET OFF WELL. PULL 90 JOINTS CSH. 14:00 - 14:30 ! 0.50 EVAL N DPRB 12,718.00 OTHCMP .WEEKLY CREW CHANGE. HOLD DETAILED HANDOVER. HOLD PJSM WITH SLB LOGGERS AND CREW. 14:30 - 16:00 1.50 EVAL N DPRB 12,718.00 OTHCMP CONTINUE TO PULL AND STANDBACK CSH. CLEAR FOR AS LOGGING TOOLS NEAR SURFACE. PULL SAME. REMOVE SOURCE. LD LOGGING TOOLS. 16:00 - 17:00 1.00 PERFOB P OTHCMP CIRCULATE THROUGH CHOKE TO VERIFY IT IS CLEAR. FILL HOLE. 1/2 BBL. 17:00 - 17:30 I 0.50 PERFOB P I OTHCMP PJSM. LOAD PIPE SHED WITH PERF GUNS. 17:30 - 19:30 2.00 EVAL P OTHCMP DOWN LOAD LOGGING DATAAND PREP TO RUN GUNS, BRING GUN BOXES TO RIG FLOOR 19:30 - 00:00 4.50 PERFOB P OTHCMP PU 17EA 1.56"OD GUNS,AND FIRING HEAD RIH 45 STANDS 1"CSH, STAB COILAND CONTINUE TO RIH 3/25/2013 00:00 - 01:30 1.50 PERFOB P OTHCMP RIH WITH TCP GUNS TO 12,422'MD,TIE IN AT EOP FLAG WITH(-7')CORRECTION. CORRECTED DEPTH 12,415'MD. 01:30 - 02:00 0.50 PERFOB P OTHCMP RIH F/12,415'-12,699'MD.LIGHTLY TAG PBTD. 02:00 - 03:00 1.00 PERFOB P OTHCMP PICK UP FROM 12,699'-12,600'MD.START FIRING SEQUENCE AND ATTEMPT TO FIRE PERF GUNS.DID NOT RECEIVE GOOD INDICATION OF SHOTS BEING FIRED.RE-SET TOOLS AND MADE SECOND ATTEMPT TO FIRE GUNS.POSITIVE INDICATION OF SHOTS FIRED,SLIGHT INCREASE IN WEIGHT WHILE POOH. 03:00 - 04:30 1.50 PERFOB P OTHCMP POOH F/12,600'-6,375'MD WHILE HOLDING 200-300 PSI BACK PRESSURE ON WELLHEAD. LOSS(-5 BBLS)WHILE PULLING OUT OF LINER.FLOW CHECK WELL-NO FLOW OBSERVED. 04:30 - 06:00 1.50 PERFOB P OTHCMP CONTINUE POOH F/6,375'-3227'MD.GET OFF OF WELL WITH INJECTOR. Printed 4/8/2013 11:21:10AM North America-ALASKA-BP Page 13 of 13 Operation Summary Report Common Well Name:06-02 AFE No Event Type:COM-ONSHORE(CON) Start Date:1/16/2013 End Date:1/25/2013 X3-012FV-C:(1,302,011.00) Project:Prudhoe Bay Site:PB DS 06 Rig Name/No.:NORDIC 2 Spud Date/Time:5/1/1978 12:00:00AM Rig Release:3/26/2013 Rig Contractor.NORDIC CALISTA UVI:500292028200 Active datum:2:02 5/1/1978 00:00©64.00usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) 06:00 - 06:30 0.50 PERFOB P OTHCMP AT SURFACE. CREW CHANGE. MAKE RIG CHECKS AND ROUNDS. DISCUSS HANDLING CSH AND GUNS. 06:30 - 09:30 3.00 PERFOB P OTHCMP PULL AND LAY DOWN 1"CSH SINGLES IN PIPE SHED. FILL HOLE EVERY 20 JOINTS. 09:30 - 11:00 1.50 1 PERFOB P OTHCMP PJSM WITH SLB AND RIG CREW. PULL REMAINIGNCSH. PULL AND LD PERF GUNS. ALL SHOTS FIRED. LEAVE GUNS IN PIPE SHED TO DRAIN. 11:00 - 13:00 I 2.00 PERFOB P OTHCMP RUN IN HOLE WITH 1"CSH LEFT IN DERRICK POOH AND LD SINGLES. FILL HOLE. 13:00 - 16:00 3.00 BOPSUR P POST PJSM. SPOT DIESEL VAC TRUCK MU NOZZLE BHA WITH CHECKS AND STINGER. GET ON WELL. RUN IN HOLE. FREEZE PROTECT WELL FROM 2000'WTIH • DIESEL. POOH. 16:00 - 19:00 3.00 BOPSUR P POST RU SLB N2 TRUCK. DISCUSS TRIP AND POP OFF SETTINGS. TRIPS TESTED AT 4000 PSI. POP OFF SET FOR 10,000 PSI. .HOLD PJSM WITH CREW. COOL DOWN PUMP UNIT. DISPLACE COIL TO N2. TAKE RTNS TO TIGER TANK RIG DOWN N2 UNIT 19:00 - 20:00 1.00 WHSUR P POST PERFORM PJSM,GREASE TREE,SET BPV. 20:00 - 20:30 0.50 WHSUR P POST FREEZE PROTECT TREE. 20:30 - 22:30 2.00 WHSUR P POST LEAK TIGHT TEST MASTER AND SWAB. 22:30 - 00:00 1.50 BOPSUR P POST PJSM,OPEN BOP DOORS,INSPECT RAMS AND DOOR SEALS. 3/26/2013 00:00 - 03:00 3.00 BOPSUR P POST ND BOPS,INSTALL NIGHT CAP AND TEST-PASSED,RDMO 03:00 - 03:00 0.00 RIGD P POST RELEASED FROM DS6-02B FOR MOVE TO E-25B RELEASE NORDIC 2 CTD RIG AND END COMPLETION EVENT AT 03:00 ON 3/26/2013 PREP RIG TO MOVE TO NEXT WELL E-25B ALL TREE AND WELLHEAD VALVE LEFT CLOSED WITH PRESSURE GAUGES FINAL IA/OA=100/0 TREE WELLHEAD AND CELLAR CLEAN. WELLWORK TRANSFER PERMIT CLOSED WITH PAD OPERATOR WELL HANDOVER COMPLETED WITH WELLS _IGROUP Printed 4/8/2013 11:21:10AM 06-02B, Well History Date Summary 01/24/13 T/I/O=0/0/0. Conduct PJSM with rig personnel. Barriers= KWF&Cement. Start Barrier list. Dry rod 4" CIW'H' BPV#142 on Nordic 2. RKB=24.62 plus 2'ext.. RDMO. 02/16/13 TAGGED BPV W/1.75" LIB. RIGGED DOWN SLICKLINE, BPV NEEDS TO BE PULLED. 02/17/13 T/I/O=0/0/0 Conducted PJSM. Barriers= Swab&SSV. Start barriers list. Performed LTI test on Swab& SSV independently, Pass. Removed tree cap, attached lubricator, PT'd against Swab& SSV 250/Iow..3500/high..5 min. each..pass. PULLED 4" CIW"H"TWC#142 THRU TREE using 1-1'ext. Tagged @ 112" Post Nordic 2. no problems. 02/19/13 R/U SWCP 4518. 02/20/13 RAN 1.85"CENT& 1.75" LIB. TAG TOP OF FISH @ 10,503'SLM. IMPRESSION SHOWS A JAGGED TOP OF THE FISH @ AN ANGLE JAR DOWN W/ 1.80" BLIND BOX FOR A TOTAL OF 42 MINS MOVE FISH FROM 10,503' SLM TO 10,548' SLM (-45' of movement). 03/12/13 CT-8 1 1/2" Scope: Push fish to bottom. Move to DS-06, Spot unit and cut 2700'of pipe. Move unit to 06- 02 and RU. MU BOT MHA&Tempress Agitator tool assembly. 1.69"assembly OAL-13.82'. HP increasing w/choke cracked RIH, returned 90 bbl fluids to tank.APE informed&we discussed plans forward. RIH to Liner top. 03/13/13 CT-8 1 1/2"Scope: Push fish to bottom. Cont, RIH w/BOT TEMPRESS Agitator assembly.Tagged mill @ 10550'. Work fish free, push to PBTD, 12674' CTD, POOH, FP CT w/Meth. MU Venturi BHA-Max OD 1.75"x OAL 18.76'. RIH. Set down @ 10692', attempt to work past.Venturi down to 10721. Cont. RIH. Set down twice @ 11803', Venturi to 11830', RIH to fish @ 12676', Reciprocate venturi 12650'- 12675', POOH to TOL, Dry drift from 9380'to 12675', POOH, LD BHA, Venturi recovered 1 piece of metal debris aprox. 7/8" long x 7/32"diameter, RD. 03/17/13 T/I/O=?NAC/160/40. Temp=S/I. IA, OA, OOA F/Ls(Pre CTD). No scaffolding on well. IA FL @ 90' (1.6 bbls). OA FL @ 110' (2.8 bbls). OOA FL @ Surface. SV, WV MV=?. SSV=C. IA, OA, OOA=OTG. NOVP. 1420 hrs. 03/17/13 T/I/O/00=1620/0/180/40 MIT IA*`*PASSED***to 3000 psi CMIT OA x OOA***PASSED***to 1000 psi (CTD) Pump 5 bbls diesel down IA to test pressure. IAP lost 76 psi 1st 15 min, 18 psi 2nd 15 min. Bled back—3.5 bbls to 0 psi. Pump 5.5 bbls diesel down OA/OOA to test pressure. OA/OOAP lost 9/26 psi 1st 15 min, OA/OOAP lost 4/13 psi 2nd 15 min. Bled OA/OOAP to 0 psi.Valve postions=SV WV SSV closed IA,OA,00A OTG FWHP=1600/0/100//100. 03/18/13 T/1/0=1500/0/150. Conduct PJSM. Barriers=SV and SSV. Start barriers list= Performed LTT on closed Swab valve and SSV independently. (Passed) R/U Gray BPV lubricator with 4"CIW"H"TWC#259. Pressure tested lubricator to 300 psi low and 3500 psi high for 5 min each. (Passed, charted and saved to TRP folder). Set 4"TWC at 112". Verified TWC holding. Torqued all tree flanges to API spec. R/U lubricator with"H"pulling tool. Pressure tested tree to 300 psi low and 5000 psi high for 5 min each. (Passed charted and saved to TRP folder) Pulled 4"TWC. R/D lubricator. Pressure tested bottom of Swab valve through wing valve with SSV closed to 3000 psi for 5 min. (Passed, charted and saved to TRP folder.) Bled to 0 psi. all valves closed. Page 1 of 2 06-02B, Well History Date Summary 03/18/13 T/I/O/00 =260/30/130/100. Temp= SI. Bleed IAP&OAP to 0 psi (Pre CTD). No well house or Flowline. T FL near surface, IA FL @ surface, OA FL near surface&OOA FL @ surface. Bled IAP to 0 psi, Bled OAP to 0 psi& Bled OOAP to 0 psi. Monitored for 30 min. IAP unchanged, OAP increased 3 psi&OOAP increased 2 psi. Job incomplete. Final WHPs=SSV/0/3/2 SV, WV, SSV=C. MV= 0. IA, OA, OOA= OTG. NOVP. 16:10. 03/20/13 T/I/0= 1500/0/0 Conduct PJSM with Crew. Barriers= SV and SSV Start barriers list.Verified by bleeding tubing off SSV and SV independently LTT Pass. RU Ciw lubricator W/4"TWC#260 Test lubricator against SV Low of 300 PSI and High of 3500 PSI for 5 Min each Pass(For each Break). RIH and set TWC#260 Tagging at 124" . PT TWC to low of 300 PSI and high of 5000 PSI for 5 Min each PASS charted and documented. RDMO. 03/23/13 T/I/0=1500/0/0. Conduct PJSM with Rig crew. Barriers= SSV and Swab. Start Barriers list=performed LTT on SSV and Swab idependently. (Passed) R/U CIW lubricator with (3)5'ext and CIW"H"pulling tool. Tested against Swab to 300 psi low and 3500 psi high for 5 min each. (Passed) Pulled 4"CIW TWC #260 at 135". SSV and Swab passed LTT. R/D lubricator and trun well back over to rig. 03/26/13 T/I/O=0/0/0 Conducted PJSM. Barriers= KWF,Tree valves, & BOP's. Start barriers list.Well was deemed static by WSL.Attached 4"CIW"H" BPV#111 to dry rod. Measured dry rod into well. SET 4"CIW BPV #111. RKB=24.43'+ riser=2.00' Nordic 2 RDMO no problems. 03/27/13 T/I/O=Vac/0/0 Conduct PJSM. Barriers=BPV and SV. Verified LTT on BPV and SV independently. (Passed) Removed non tapped blind flange and installed tapped blind.Torqued all tree bolts to API spec. R/U gray lubricator with 4""H"pulling tool. Pressure test to 300 psi low and 3500 psi high for 5 min each. (Passed) Pulled 4" BPV#111 at 112"with 1 1'ext. RID lubricator. Changed pulling tool to setting tool with 4"TWC . Pressure test to 300 psi low and 3500 psi high for 5 min each. (Passed) Set 4"TWC#288 at 112"with 1 1'ext. Changed setting tool to pulling tool. Pressure tested tree through lubricator to 300 psi low and 5000 psi high for 5 min each. (Tests passed, charted and saved to TRP folder.Tests also count for lubricator test) Pulled 4"TWC. Left all tree valves shut in. Notified operator. 04/03/13 T/I/0=240/0/5/72. Temp=SI. Pump 5 bbl neat spear down TBG, pump 240 bbls Diesel down TBG. SwabV, WingV=closed, SSV, MV=Open, IA/OA=OTG. FWHP=640/0/58. 04/06/13 SET WHIDDON CATCHER SUB @ 9,616'SLM. PULLED STA.#3 BK-DGLV©6,778'SLM (6,788' MD). PULLED STA.#4 BK-DGLV @ 3,517' SLM (3,529' MD). SET STA.#4 BK-LGLV(16/64" ports, 1,650# tro) ©3,529' MD. SET STA.#3 BK-OGLV(24/64" ports) ©6788' MD. PULLED EMPTY WHIDDON CATCHER SUB FROM 9616'SLM. Page 2 of 2 E.■ BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 06 06-02 - Slot 02 500292028200 06-02B Survey: MWD Survey Report - Geographic 18 January, 2013 Qbp Mill BAKER HUGHES Survey Report-Geographic 0 by INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 06-02-Slot 02 Project: Prudhoe Bay TVD Reference: 2:02 5/1/1978 00:00 @ 64.00ft(generic drilling ri Site: PB DS 06 MD Reference: 2:02 5/1/1978 00:00 @ 64.00ft(generic drilling ri Well: 06-02 North Reference: True Wellbore: 06-02B Survey Calculation Method: Minimum Curvature Design: 06-02B 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 06,TR-10-14 Site Position: Northing: 5,941,880.59ff Latitude: 70°14'46.529 N From: Map Easting: 684,674.88ft Longitude: 148°30'29.22 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.40 ° Well 06-02 API No 500292028200 Well Position +N/-S 0.00 ft Northing: 5,941,201.36 ft Latitude: 70°14'39.574 N +EI-W 0.00 ft Easting: 685,817.66 ft Longitude: 148°29'56.49 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 37.00ft Wellbore 06-02B API No 500292028202 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2012 12/21/2012 20.72 81.00 57,632 Design 06-02B Audit Notes: Version: Phase: ACTUAL Tie On Depth: 10,368.52 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 27.00 0.00 0.00 304.50 Survey Program Date: 1/14/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 10,055.00 Gyro Survey(06-02) GYD-CT-CMS Gyrodata cont.casing m/s 10,085.68 10,368.52 MWD(06-02APB1) MWD MWD-Standard 10,377.50 12,719.00 MWD(06-02B) MWD MWD-Standard 1/18/2013 9:18:56AM Page 2 COMPASS 2003.16 Build 73 BAKERby HUGHES Survey Report-Geographic 0 INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 06-02-Slot 02 Project: Prudhoe Bay TVD Reference: 2:02 5/1/1978 00:00 c@i)64.00ft(generic drilling ri Site: PB DS 06 MD Reference: 2:02 5/1/1978 00:00©64.00ft(generic drilling ri Well: 06-02 North Reference: True Wellbore: 06-02B Survey Calculation Method: Minimum Curvature Design: 06-02B 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 10,368.52 47.96 319.74 8,880.66 3,611.84 -2,279.60 5,944,755.68 683,449.85 70°15'15.093 N 148°31'2.80 W TIP 10,377.50 49.11 318.84 8,886.61 3,616.94 -2,283.99 5,944,760.67 683,445.34 70°15'15.143 N 148°31'2.93 W KOP 10,391.03 50.45 318.50 8,895.34 3,624.69 -2,290.81 5,944,768.26 683,438.32 70°15'15.219 N 148°31'3.13 W 10,420.47 50.57 310.00 8,914.09 3,640.52 -2,307.06 5,944,783.68 683,421.69 70°15'15.375 N 148°31'3.60 W 10,450.45 52.30 302.00 8,932.79 3,654.26 -2,326.01 5,944,796.95 683,402.41 70°15 15.510 N 148°31'4.15 W 10,480.46 55.66 294.73 8,950.45 3,665.75 -2,347.36 5,944,807.91 683,380.79 70°15'15.623 N 148°31'4.77 W 10,510.37 60.88 288.79 8,966.19 3,675.14 -2,370.97 5,944,816.71 683,356.95 70°15'15.715 N 148°31'5.46 W 10,540.33 67.42 286.80 8,979.25 3,683.36 -2,396.63 5,944,824.29 683,331.10 70°15'15.796 N 148°31'6.20 W 10,570.38 73.10 281.83 8,989.40 3,690.33 -2,424.02 5,944,830.58 683,303.55 70°15'15.864 N 148°31'7.00 W 10,600.30 79.51 279.16 8,996.48 3,695.61 -2,452.59 5,944,835.16 683,274.86 70°15'15.916 N 148°31'7.83 W 10,630.41 85.43 275.68 9,000.42 3,699.46 -2,482.17 5,944,838.28 683,245.19 70°15'15.954 N 148°31'8.69 W 10,665.02 88.93 272.69 9,002.13 3,701.98 -2,516.64 5,944,839.95 683,210.68 70°15'15.978 N 148°31'9.70 W 10,692.66 90.21 270.03 9,002.33 3,702.63 -2,544.27 5,944,839.92 683,183.04 70°15'15.985 N 148°31'10.50 W 10,722.29 89.75 267.00 9,002.34 3,701.86 -2,573.89 5,944,838.42 683,153.46 70°15'15.977 N 148°31'11.36 W 10,750.60 91.04 269.62 9,002.15 3,701.03 -2,602.18 5,944,836.89 683,125.19 70°15'15.969 N 148°31'12.18 W 10,780.18 91.93 273.67 9,001.38 3,701.88 -2,631.73 5,944,837.01 683,095.63 70°15'15.977 N 148°31'13.04 W 10,814.54 92.51 279.60 9,000.05 3,705.84 -2,665.82 5,944,840.13 683,061.46 70°15'16.016 N 148°31'14.04 W 10,840.91 90.64 282.25 8,999.32 3,710.84 -2,691.70 5,944,844.49 683,035.46 70°15'16.065 N 148°31'14.79 W 10,870.98 90.31 286.25 8,999.07 3,718.24 -2,720.84 5,944,851.17 683,006.15 70°15'16.138 N 148°31'15.64 W 10,891.06 89.94 289.04 8,999.03 3,724.32 -2,739.97 5,944,856.78 682,986.88 70°15'16.198 N 148°31'16.19 W 10,920.98 90.12 293.65 8,999.02 3,735.21 -2,767.83 5,944,866.98 682,958.76 70°15'16.304 N 148°31'17.00 W 10,950.88 89.45 291.56 8,999.13 3,746.70 -2,795.43 5,944,877.78 682,930.89 70°15'16.417 N 148°31'17.81 W 10,980.83 88.71 289.31 8,999.61 3,757.16 -2,823.49 5,944,887.54 682,902.58 70°15'16.520 N 148°31'18.62 W 11,012.44 88.37 285.89 9,000.41 3,766.71 -2,853.61 5,944,896.35 682,872.24 70°15'16.614 N 148°31'19.50 W 11,040.78 88.56 282.10 9,001.17 3,773.56 -2,881.09 5,944,902.52 682,844.59 70°15'16.681 N 148°31'20.30 W 11,070.69 89.45 280.15 9,001.69 3,779.33 -2,910.43 5,944,907.57 682,815.12 70°15'16.738 N 148°31'21.15 W' 11,101.86 92.24 278.56 9,001.23 3,784.40 -2,941.18 5,944,911.87 682,784.26 70°15'16.788 N 148°31'22.05 W 11,129.48 88.38 273.87 9,001.08 3,787.39 -2,968.62 5,944,914.18 682,756.75 70°15'16.817 N 148°31'22.84 W 11,160.18 87.58 270.69 9,002.17 3,788.61 -2,999.28 5,944,914.65 682,726.08 70°15'16.829 N 148°31'23.74 W 11,195.26 89.54 267.02 9,003.05 3,787.91 -3,034.33 5,944,913.08 682,691.06 70°15'16.822 N 148°31'24.76 W 11,219.48 89.66 263.72 9,003.22 3,785.95 -3,058.47 5,944,910.53 682,666.98 70°15'16.802 N 148°31'25.46 W 11,254.28 90.06 260.13 9,003.30 3,781.06 -3,092.92 5,944,904.80 682,632.66 70°15'16.754 N 148°31'26.46 W 11,285.12 92.48 256.91 9,002.62 3,774.93 -3,123.13 5,944,897.92 682,602.61 70°15'16.694 N 148°31'27.34 W 11,321.42 92.79 254.31 9,000.95 3,765.92 -3,158.25 5,944,888.05 682,567.73 70°15'16.605 N 148°31'28.36 W 11,350.55 89.08 250.66 9,000.47 3,757.15 -3,186.01 5,944,878.60 682,540.19 70°15'16.519 N 148°31'29.17 W 11,380.82 89.36 245.19 9,000.89 3,745.78 -3,214.05 5,944,866.55 682,512.44 70°15'16.407 N 148°31'29.98 W 11,414.39 90.52 242.27 9,000.92 3,730.93 -3,244.15 5,944,850.95 682,482.72 70°15'16.260 N 148°31'30.86 W 11,442.81 90.00 239.82 9,000.79 3,717.17 -3,269.02 5,944,836.59 682,458.20 70°15'16.125 N 148°31'31.58 W 11,472.79 89.33 236.40 9,000.97 3,701.33 -3,294.47 5,944,820.13 682,433.15 70°15'15.969 N 148°31'32.32 W 11,500.99 89.14 232.85 9,001.34 3,685.01 -3,317.45 5,944,803.25 682,410.57 70°15'15.809 N 148°31'32.99 W 11,520.86 88.83 230.69 9,001.70 3,672.72 -3,333.06 5,944,790.57 682,395.28 70°15'15.688 N 148°31'33.44 W 11,543.44 88.28 228.98 9,002.27 3,658.16 -3,350.31 5,944,775.60 682,378.39 70°15'15.544 N 148°31'33.95 W 11,571.66 88.10 231.55 9,003.16 3,640.13 -3,372.00 5,944,757.04 682,357.16 70°15'15.367 N 148°31'34.58 W 11,590.68 88.28 233.62 9,003.76 3,628.58 -3,387.10 5,944,745.12 682,342.35 70°15'15.253 N 148°31'35.02 W 11,609.80 88.34 236.03 9,004.32 3,617.57 -3,402.72 5,944,733.73 682,327.00 70°15'15.145 N 148°31'35.47 W 11,639.88 87.67 234.73 9,005.37 3,600.50 -3,427.45 5,944,716.05 682,302.70 70°15'14.977 N 148°31'36.19 W 11,669.88 87.88 231.58 9,006.53 3,582.52 -3,451.44 5,944,697.49 682,279.16 70°15'14.800 N 148°31'36.89 W 11,699.60 86.23 227.13 9,008.06 3,563.19 -3,473.96 5,944,677.61 682,257.13 70°15'14.610 N 148°31'37.54 W 11,729.64 87.61 223.89 9,009.68 3,542.18 -3,495.35 5,944,656.08 682,236.26 70°15'14.403 N 148°31'38.16 W', 11,769.46 86.81 219.18 9,011.62 3,512.41 -3,521.72 5,944,625.67 682,210.64 70°15'14.110 N 148°31'38.93 W 11,800.64 87.24 214.69 9,013.24 3,487.53 -3,540.42 5,944,600.34 682,192.55 70°15'13.865 N 148°31'39.47 W 11,830.26 88.28 211.74 9,014.39 3,462.77 -3,556.63 5,944,575.19 682,176.96 70°15'13.622 N 148°31'39.94 W 11,860.10 90.25 210.65 9,014.78 3,437.25 -3,572.09 5,944,549.30 682,162.14 70°15'13.371 N 148°31'40.39 W 1/182013 9:18:56AM Page 3 COMPASS 2003.16 Build 73 BAKER HUGHES Survey Report-Geographic 0 bp INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 06-02-Slot 02 Project: Prudhoe Bay TVD Reference: 2:02 5/1/1978 00:00 @ 64.00ft(generic drilling ri Site: PB DS 06 MD Reference: 2:02 5/1/1978 00:00 @ 64.00ft(generic drilling ri Well: 06-02 North Reference: True Wellbore: 06-02B Survey Calculation Method: Minimum Curvature Design: 06-02B Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 11,890.25 93.53 206.05 9,013.78 3,410.74 -3,586.39 5,944,522.45 682,148.50 70°15'13.110 N 148°31'40.81 W 11,920.34 93.16 201.01 9,012.02 3,383.21 -3,598.38 5,944,494.63 682,137.19 70°15'12.839 N 148°31'41.16 W 11,950.38 90.40 197.41 9,011.09 3,354.86 -3,608.25 5,944,466.05 682,128.02 70°15'12.560 N 148°31'41.44 W 11,980.38 90.37 192.76 9,010.89 3,325.91 -3,616.06 5,944,436.91 682,120.93 70°15'12.275 N 148°31'41.67 W 12,010.17 88.47 187.68 9,011.19 3,296.60 -3,621.34 5,944,407.48 682,116.37 70°15'11.987 N 148°31'41.82 W 12,040.32 90.06 191.85 9,011.58 3,266.90 -3,626.46 5,944,377.67 682,111.99 70°15'11.695 N 148°31'41.97 W 12,060.31 89.14 194.82 9,011.72 3,247.45 -3,631.07 5,944,358.11 682,107.86 70°15 11.504 N 148°31'42.11 W 12,094.47 87.88 198.77 9,012.61 3,214.76 -3,640.93 5,944,325.20 682,098.81 70°15'11.182 N 148°31'42.39 W 12,120.43 88.74 202.32 9,013.37 3,190.47 -3,650.04 5,944,300.69 682,090.30 70°15'10.943 N 148°31'42.66 W 12,151.53 91.23 206.14 9,013.38 3,162.12 -3,662.80 5,944,272.03 682,078.25 70°15'10.664 N 148°31'43.03 W 12,180.24 93.07 210.83 9,012.30 3,136.91 -3,676.47 5,944,246.49 682,065.20 70°15'10.416 N 148°31'43.43 W 12,210.25 90.61 214.56 9,011.34 3,111.67 -3,692.67 5,944,220.87 682,049.63 70°15'10.168 N 148°31'43.90 W 12,240.10 90.77 218.71 9,010.98 3,087.73 -3,710.48 5,944,196.49 682,032.42 70°15'9.932 N 148°31'44.41 W1 12,270.16 89.11 221.49 9,011.01 3,064.74 -3,729.84 5,944,173.03 682,013.63 70°15'9.706 N 148°31'44.98 W 12,300.28 88.07 222.21 9,011.75 3,042.31 -3,749.93 5,944,150.11 681,994.10 70°15'9.486 N 148°31'45.56 W 12,330.21 88.62 218.01 9,012.62 3,019.43 -3,769.20 5,944,126.77 681,975.40 70°15'9.261 N 148°31'46.12 W 12,360.04 88.65 213.37 9,013.33 2,995.22 -3,786.59 5,944,102.14 681,958.61 70°15'9.022 N 148°31'46.63 W 12,392.07 87.88 207.55 9,014.30 2,967.63 -3,802.81 5,944,074.16 681,943.08 70°15'8.751 N 148°31'47.10 W 12,420.55 88.96 203.70 9,015.08 2,941.97 -3,815.12 5,944,048.21 681,931.40 70°15'8.498 N 148°31'47.46 W 12,450.65 89.45 200.35 9,015.50 2,914.07 -3,826.41 5,944,020.04 681,920.81 70°15'8.224 N 148°31'47.78 W 12,480.65 88.93 195.94 9,015.93 2,885.57 -3,835.75 5,943,991.32 681,912.18 70°15'7.944 N 148°31'48.05 W 12,510.83 88.04 191.82 9,016.72 2,856.29 -3,842.98 5,943,961.87 681,905.66 70°15'7.656 N 148°31'48.26 W 12,540.94 87.45 187.26 9,017.91 2,826.63 -3,847.97 5,943,932.10 681,901.41 70°15'7.364 N 148°31'48.41 W 12,570.63 88.77 183.38 9,018.89 2,797.09 -3,850.72 5,943,902.50 681,899.39 70°15'7.073 N 148°31'48.49 W 12,600.61 87.48 177.35 9,019.87 2,767.14 -3,850.91 5,943,872.56 681,899.94 70°15'6.779 N 148°31'48.49 W 12,630.43 89.02 178.99 9,020.78 2,737.35 -3,849.96 5,943,842.80 681,901.62 70°15'6.486 N 148°31'48.47 W 12,660.64 88.31 181.75 9,021.49 2,707.15 -3,850.15 5,943,812.61 681,902.17 70°15'6.189 N 148°31'48.47 W 12,683.79 88.50 183.85 9,022.13 2,684.04 -3,851.28 5,943,789.48 681,901.61 70°15'5.962 N 148°31'48.50 W 12,718.97 88.50 183.85 9,023.05 2,648.95 -3,853.65 5,943,754.34 681,900.12 70°15'5.616 N 148°31'48.57 W PRODUCTION LINER 1 12,719.00 88.50 183.85 9,023.05 2,648.92 -3,853.65 5,943,754.32 681,900.12 70°15'5.616 N 148°31'48.57 W TD-2 3/8" 1/18/2013 9.18:56AM Page 4 COMPASS 2003.16 Build 73 113 L06 O- 21z14-t4-0 Itegg, James B (DOA) From: Newlon, David B [David.Newlon2@BP.com] Sent: Monday, March 25, 2013 10:16 AM To: DOA AOGCC Prudhoe Bay 3�7� �� Subject: Nordic 2 issue on DS 6-02B Attachments: Nordic 2 BOPE usage 3-24-2013.doc Misidentification of well events by Nordic Driller lead to DS 6-02B well being shut in to a closed choke HCR. Additional training involving Schlumberger Coil tubing operators and Nordic drillers will be done so as prevent this event. Thanks Dave Newlon RWO &CTD Operations Superintendent (907) 659-5329 Deadhorse Office (907) 748-5821 Mobile Harmony 2157 (For dialing a harmony, 1-907-659-3106 then 1 then 758-2157 ) David.Newlon2(u'BP.com 1 Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. 1Q0iAc Z--- Field Field Superintendent Name: David Newlon Wellsite Leader Name: Gary Goodrich Contact Number: 907-715-5821 Contact Number: 907-659-4393 Traction Number: Well Location & Name: Drill Site 6 Well 02B Permit To Drill (PTD) Number: 2121440 Date and Time of Incident: 05:00 3-24-13 Original Scope of Work: Lay in a liner perf pill from PBTD prior to logging a GR-CNL up pass. Operational Description Leading up to Well Control Event: A low level methane gas alarm at the shaker began to sound. A verbal exchange in the Operations Cab between the SLB supervisor and WSL discussed the need to perform a Flow check of the well. Communication error between Ops cab coil operator and Nordic Driller on when the pump was shut down led the Nordic Driller to believe that the well was flowing and he shut the well in to a closed Choke HCR. There was zero SICP or SIDP, no flow from formation and no pit gain. BOPE Used and Reason: Misidentification of well events by Nordic Driller Is a BOPE Test Required after use ( Yes / No): If no, why? No, BP has determined not a Well Control Event 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: Circulated bottoms up to verify well was dead and and static. Resume rig operations Additional Comments: Additional training with rig personnel on Shut in Procedures Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bavAalaska.gov Email CC List Well Integrity Team Leader Ryan Daniel HSE Advisor Jeff Kilfoyle Engineering Team Leader Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager Steve Rossberg Wells Intervention Manager Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC August 2, 2010 HRE 1 • „\�\0,r,��4,s,, THE STATE Alaska Oil and Gas °fALASKA Conservation Commission wti - GOVERNOR SEAN PARNELL 333 West Seventh Avenue O -to+ Anchorage, Alaska 99501-3572 ALAS"- Main: 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 06-02B BP Exploration (Alaska), Inc. Permit No: 212-144 Surface Location: 607' FSL, 1164' FEL, SEC. 02, T1ON, R14E, UM Bottomhole Location: 1998' FNL, 5091' FEL, SEC. 02, T1ON, 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, Cathy . Foerster Chair DATED this S day of October, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALAS. )IL AND GAS CONSERVATION COMM, 3N SEP 1 3 2012 PERMIT TO DRILL Alaska Oil& Gas Cons. Commission 20 AAC 25.005 la.Type of work: 1 b.Proposed Well Class: ®Development Oil 0 Service-Winj ®Single Zone . lc. SpeltfMaliagOroposed for: ' 0 Drill N Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates 0 Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp ❑Shale Gas 2 Operator Name: 5 Bond: ®Blanket 0 Single Well 11 Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 • PBU 06-02B • 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 12716' TVD 8962'ss Prudhoe Bay/Prudhoe Bay • 4a Location of Well(Governmental Section). 17. Property Designation(Lease Number): Surface: ADL 028311 • 607' FSL, 1164' FEL, Sec.02, T1ON, R14E, UM • Top of Productive Horizon: 8. Land Use Permit. 13. Approximate Spud Date: 4319' FSL,3560' FEL, Sec. 02,T1ON, R14E, UM November 1,2012 Total Depth: 9 Acres in Property: 14.Distance to Nearest Property: 1998' FNL,5091' FEL, Sec.02,T1ON, R14E, UM 2560 . 24150' 4b Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 64' feet 15.Distance to Nearest Well Open Surface. x- 685818 ' y-5941201 • Zone- ASP4 GL Elevation above MSL: feet to Same Pool. 800' 16.Deviated Wells: Kickoff Depth: 10368' •feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3250 • Surface. 2370 • 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Couplings Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 STL 3066' 9650' 8245'ss 12716' 8962'ss 53 sx Class'G' • • 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) I Total Depth MD(ft): Total Depth TVD (ft): Plugs(measured): Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured): 11450' 9042' 10630' 10630' 9020' None Casing Length Size Cement Volume MD TVD Conductor/Structural 118' 20" 269 sx Permafrost 118' 118' Surface 2695' 13-3/8" 7200 Arctic Set II 2695' 2695' Intermediate 10054' _ 9-5/8" 1200 sx Class'G' 10054' 10054' Production Liner Tieback Liner 9593' 7" 835 sx Class'G' 9593' 8263' Liner 1771' 3-1/2"x 3-3/16"x 2-7/8" 145 sx Class'G' 9679'- 11450' 8333'-9042' Perforation Depth MD(ft): 10582'- 11350' Perforation Depth TVD(ft)• 8998'-9041' 20.Attachments: 0 Property Plat ®BOP Sketch IN Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ®Diverter Sketch 0 Seabed Report ®Drilling Fluid Program N 20 AAC 25.050 Requirements 21 Verbal Approval: Commission Representative: Date: 22 I hereby certify that the fore ing is true and correct. Contact Zach Sayers, 564-5790 Printed Name John le /?4, Title Engineering Team Leader Prepared By Name/Number Signature Phone 564-4711 Date .I4/e— Joe Lastufka,564-4091 Commission Use Only Permit To Drill (/. API Number: Permit A va Dpte See cover letter for Number: 2 /T 50-029-20282-02-00 � � I , 2, other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coal ed methane,gas hydrates,or gas contained shales: C3, Other. A4 3 s-00JO pz. got 7Z-.51-- Samples Req'd: ❑Yes p No Mud Log Req'd. s Er/No H2S Measures: [vetOyes Yes 0 No Directional Survey Req'd: p Yes 0 No a/4 ), PPROVED BY THE COMMISSION Date/Q -5 -(?i ��ir�jC r__� ,COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 monthfrpo7�NatAtprg4al(20 AAC 25.005(g)) Submit In Duplicate�� xv To: Alaska Oil & Gas Conservation Commission From: Zach Sayers CTD Engineer 0 bp Date: September 12, 2012 Re: 06-02B Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well 06-02. CTD Drill and Complete 06-02B program: Rig Start Date: November 1th, 2012 Pre-Rig Work: (scheduled to begin October 15th, 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 Pull KB Liner Top Packer at 9,679' MD. 4. S Dummy WS drift to 10,500' MD (47° Inc). 5. F Load and kill well with 1% KCI. 6. E Set 3-3/16" Packer whipstock at —10,368' MD using CCL to locate mid joint. PSA 7. F Test packer 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. A, Rig Work: (scheduled to begin November 1th, 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 2.80" window at 10,368 and 10' of rathole. Swap the well to PowerVis. 3. Drill Build: 3" OH, 250' (24.5°/100 planned). 4. Drill Lateral: 3" OH, 2,060' (12° /100 planned) with resistivity. 5. Run 2-3/8" L-80 liner leaving TOL at 9,650' MD. 6. Pump primary cement leaving TOC at 9,650' MD (TOL), 11 bels of 15.8 ppg liner cmt planned. Ai"") 7. Cleanout liner and run RPM/GR/CCL log. — 53 skes• rrp 8. Test liner lap to 2,400 psi. ► ` 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-'/2" liner top packer, and test to 2,400 psi (If liner lap test fails). 3. Generic GLV's. 4. Test separator. Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg PowerVis for milling window and drilling (687 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: 3.0" Liner Program: • 2-3/8", 4.7#, L-80, STL Solid Liner 9,650' MD - 12,716' MD • A minimum of 11_bbls of 15.8 ppg cement will be used for liner cementing. (TOC 9,650' 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 91°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • • Distance to nearest property- 24,150'. • Distance to nearest well within pool - 800' (14-03A). Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Cased hole GR/CCL/RPM logs will be run. N re,, - B 7°01 �C. i y•rz- Perforating: su o••� • SWS 1.56", 6 spf, perf guns, 1 " CSH work string, & 2-1/16" CSH. • 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 anti-collision failures. Hazards • The maximum recorded H2S level on DS 6 was 300 ppm on well 06-14B on 5/12/2011. Reservoir Pressure • The reservoir pressure on 06-02B is expected to be 3,250 psi at 8,811' 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 / Joseph Lastufka TREE= FMC GEN 1 f WELLHEAD= FMC 0 6 _0 2 A SAF. QUOTES: WELL ANGLE>70°@ 10710'. ACTUATOR= AXELSON '""4-112"CHROME TBG"" KB ELEV= 64' I BF ELEV= 20"COND. —1 100' ) 2121' —I4-1/2"HES X NIP,ID=3.813" KOP= 3200' 94#, Max Angle= 105°@ 12037' H-40, Datum MJ= 10363' ID=19.124" , • 2316' 9-5/8"FOC Datum TVD= 8800'SS 2441' H9-5/8"FOC 9-5/8"CSG,47#,SOFT RS-95 XO TO N-80 BUTT H 2295' 13-3/8"CSG,72#,J&L N-80 BUTT,ID=12.347" H 2695' (, A 3150' HEST TOP OF CEMENT(07/19/03 RWO) • 1. 1• / GAS LIFT MANDRELS 11 ST MD TVD DEV TYPE VLV LATCH PORT DATE 9-5/8"CSG,47#,N-80 XO TO SOFT RS-95 BUTT H 8218' 4 A 4 3529 3516 17 KBG-2 DMY BK 0 05/27/12 //• 3 6788 5992 41 KBG-2 DMY BK 0 0527/12 1♦1 2 8410 7295 36 KBG-2 DMY BK 0 07/19/03 1/• 1 9408 8113 35 KBG-2 DMY BK 0 07/19/03 Minimum ID = 2.377" @ 9679' A 9466' —14-1/7'HES X NIP, ID=3.813" KB LINER TOP PACKER ' A 1, / /_• 9487' H7"X 4-1/2"BKR S-3 PKR,ID=3.875" / '// 9511' --j4-1/7'HES X NIP, ID=3.813" 7"T1EBK LNR,26#,L-80 BTC-M, H 9593' 1, 0 0383 bpf,ID=6.276" 4 ♦� .4 `/ 967W ELM H KB LNR TOP PKR,ID=2.377" la la.ill 9691' —13.70"BKR DEPLOY SLV,ID=3.00" � / 9712' H3-1/2"OTIS X NIP,ID=2.812' 3-1/2°LNR 9.3#,L-80 STL, .0087 bpf,ID=2.992' H 9744' 0ill 1 $ 0' 0 09744' 3-1/2"X 3-3/16"XO,ID=2.786' A ♦i , 41/2 TBG, 12.6#,13CR VAM ACE 9800' • / 9778' --I4-12"HES XN NIP,MLLED TO 3-80(4/12/11) .0152 bpf,ID=3.958" ..i ♦ _ 9800' —14-12"WLEG, ID=3.958" BEHIND • .••�•�• .•••�•�• 9899' CA SING HOLE 9898'-9929' LNR •�•♦•i ••♦•. (RIG SQZ 0122/90) 9-5/8'CSG,47#,SOFT RS-95 9977' ►��i�i '4.41" XO TO SOFT N-80 BUTT .••••• •♦�♦�• ♦♦♦' •♦♦• WHIPSTOCK(04/15/11) H 10054' ►�♦:♦±�_ \♦kii •••• ••• MLLOUT WINDOW(06-02A) 10055'-10064' •9-5/8"CSG,47#,SOFT N-80 BUTT,ID=8.681" I— —10064 00...... •. PERFORATION SUMMARY '��•- - \ 10630' —{3-12"CIBP(04/04/12) •�♦�♦�♦�♦�♦�♦�♦�♦• REF LOG SLB MCNU GR/CCL ON 05/04/11 '•-•-•)••••4:*_�_* ANGLE AT TOP PERF.58° 41 10582' t•• I •• / 11114' H3-3/16"X 2-7/8"XO,ID=2.377" Note: Refer to Production DB for historical perf data 0•♦•4 i♦4 SIZE SPF INTERVAL Opn/Sqz DATE ►•�•�4 ►•••� 2" 6 10582-10592 0 04/02/12 •.•A:- 1X4. 2" 6 10800-10950 0 05105/11 • 2" 6 11000-11350 0 05105/11 17176576557191, 33/16'LNR,6.2#,L-80 TCII,.0087 bpf,ID=2.80" H 11114' - \ PBTD H 11412' 1 41111, 2.7/8"LNR,6.4#,6.80 STL,.0058 bpf,ID=2.441" --{ 11450' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/30178 N1 ES ORIGINAL COMPLETION 05/27/11 PJC .DRLG DRAFT CORRECITONS WELL: 06-02A 01/30/90 AUDI MO 06/26/11 AK/PJC FINAL DRLG CORRECTIONS PERT Nb:' 110260 07119103 N4ES IWVO 04/03/12 TTR/PJC:ADPERFS(42/12) API No: 50-029-20282-01 06/11/05 JGM/PJC CTU 9 3-112"LNR 04/05/12 TTR/JMD SET CIBP(04/04/12) SEC 2,T1ON,R14E,607'FSL&1164'FEL 05/07/11 NORDIC CTD SIDETRACK(06-02A) 05/30/12 MSS/JMD GLV C/O(0527/12) 05/25/11 PJC DRLG HO CORRECTIONS BP Exploration (Alaska) TREE= FMC GEN 1 VIIELLFEAD= FMC 0 6_0 21i( b SA4-1/2"NOTES:CHROWELLTLANGLE>70°@ 10710'. ACTUATOR= AXELSON *** KB.REV= 64' BF.BEV= 20"COND, H 100' 1 ' 2121' —14-1/2"HES X NP,D=3.813" KOP= 3200' li Max Angle= 105°@ 12037' 94# 1440, Datum MD= 10363' D=19.124" x 2316' H 9-5/8"FOC Datum ND-;-----. 8800'SSIL 2441' —19-5/8"FOC 9-5/8"CSG,47#,SOFT RS-95 XO TO N-80 BUTT H 2295' 13-3/8"CSG,72#,J&L N-80 BUTT,ID=12.347" —1 2695' • 3150' HEST TOP OF CEMENT(07/19/03 RWO) • GAS LIFT MANDRELS • ST MD TVD DEV TYPE VLV LATCH PORT DATE • • 4 3529 3516 17 KBG-2 DMY BK 0 05/27/12 9-5/8"CSG,47#,N-80 XO TO SOFT RS-95 BUTT H 8216' L 4 3 6788 5992 41 KBG-2 DMY BK 0 05/27/12 • • • 2 8410 7295 36 KBG-2 DMY BK 0 07/19/03 • • 1 9408 8113 35 KBG-2 DMY BK 0 07/19/03 • Minimum ID =2.377" @ 9679' • , , : 9466' H4-1/2"HES X NP,D=3.813" KB LINER TOP PACKER • 'Ar •• 9487' H7"X 4-1/2"BKR S-3 PKR,ID=3.875" ~• • 9511' —14-1/2"HES X NP,ID=3.813" 7"TlEBK LNR,26#,L-80 BTG-M, —1 9593' 1 ' • • .0383 bpf,U=6.276" • • TOL/TOC 9,650' MD 36° INC 0 0 9691' —13.70"BKR DEPLOY SLV,ID=3.00" 3-1/2"LNR,9.3#,L-80 STL,.0087 bpf, D=2.992" 9744' 0 ' 0 4 ' ; 971T --I3-1/2"OTIS X NIP,ID=2.812" P .� 9744' H3-1/2"X 3-3/16"XO,D=2.786" t 9778' —14-1/2"HES XN NIP,MLLED TO 3.80(4/12/11) 4-1/2"TBG,12.6#,13CR VAM ACE, — 9800' \ t ! i • .0152 bpf,D=3.958" :�• •. 9800'9800' —14-1/2"WD 4-1/2" LEG, =3.958" BEHIND •••••• •••••• 9899' CASNG HOLE 9898'-9929' LNR ••• i•• 9-5/8"CSG,47#,SOFT RS-95 H 9977' .�••• j•••j (RIG SOZ 01/22/90) XO TO SOFT N-80 BUTT �•�•0 •• ••••• •�•�• ••�•� MILLOUT WINDOW(06-02A) 10055'-10064' WHIPSTOCK(04/15/11) -1 10054' ❖•• . �• •4 TSGR- 9,890' MD 9-5/8"CSG,47#,SOFT N-80 BUTT, D=8.681" -10064 ••••• `� • ••••i 23/8"4.7#, L80Liner •••�•• ` 3 3/16" Packer WS ••i ` / 10,368' • TD 12,716' MD . 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U 0 \ \I I 1 11 I II I I"I ill I I IIII"I II I I I I I I I:IP N [ ran BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 06 06-02 500292028200 06-02B Plan 5 Travelling Cylinder Report 07 September, 2012 Øbp BAKER HUGHES Travelling Cylinder Report 0 bp INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 06-02-Slot 02 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 06 MD Reference: 2:02 5/1/1978 00:00 @ 64.00ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: 06-02 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 06-02B Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 5 Offset TVD Reference: Offset Datum Reference Plan 5 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 10,368.52 to 12,716.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,468.90ft Error Surface: Elliptical Conic Survey Tool Program Date 7/6/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 10,055.00 Gyro Survey(06-02) GYD-CT-CMS Gyrodata cont.casing m/s 10,085.68 10,368.52 MWD(06-02APB1) MWD MWD-Standard 10,368.52 12,716.00 Plan 5(06-02B) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 12,716.00 8,962.14 2 3/8" 2.375 3.000 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) PB DS 02 02-40-02-40-02-40 10,950.00 12,800.00 773.32 160.28 614.42 Pass-Major Risk PB DS 06 06-02-06-02-06-02 10,386.87 10,400.00 74.60 13.19 63.01 Pass-Major Risk 06-02-06-02A-06-02A 10,375.00 10,375.00 0.00 1.07 -1.07 FAIL-Major Risk 06-02-06-02APB1 -06-02APB1 10,375.00 10,375.00 0.00 1.07 -1.07 FAIL-Major Risk 06-03_DIMS-06-03A-06-03A Out of range 06-21 06-21 B-06-21 B 12,475.00 11,735.00 1,268.72 280.61 1,000.58 Pass-Major Risk PB DS 07 07-19-07-19-07-19 11,500.00 11,755.00 963.17 614.30 356.48 Pass-Major Risk 07-19-07-19A-07-19A 11,525.00 11,275.00 1,199.42 548.11 662.19 Pass-Major Risk PBDS14 14-04-14-04A-14-04A 11,950.00 13,745.00 673.01 254.86 418.38 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/7/2012 4:00:21PM Page 2 of 12 COMPASS 2003.16 Build 73 C LL a '' a rc Q- g LL a Y S N 0 3 11.1p 4 1 ° W eI Y I 1111 g ie . ; U s tie ii EE O II I II I d mY mro 1!, ,„„,... i i a . to —I i ; Y + Y U p ` C 3 �U N Y 0 '',T z12 a I I4 `. 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TRANSMITTAL LETTER CHECKLIST WELL NAME 06 '02.4S PTD# 12— 1z / / Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: y-��C 1�1's-� POOL: i�7 4-‘d (OfCheck Box for Appropriate Letter/Paragraphs to be Included in Transmal 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 7 To co tT 0 a) 0- (i) (/)(i) N o ',-,-, 5 5 c • Q y. a , m, as E L L y. �. w to .. 0o O ° E O 0 o. 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