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208-102
227 sx LiteCrete, 169 sx G, 218 sx G Received by James B. on 12/11/2024 at 1:25pm Abandoned 11/3/2024 JSB RBDMS JSB 121624 xG DSR-4/7/25SFD 2/7/2025JJL 4/9/25 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2024.12.10 16:36:33 - 09'00' Sean McLaughlin (4311) ACTIVITYDATE SUMMARY 9/27/2024 ***WELL S/I ON ARRIVAL*** (Sidetrack) RIG UP POLLARD #60 ***CONTINUE ON 9/28/24 WSR*** 9/28/2024 ***CONTINUED FROM 9/27/24 WSR*** (Sidetrack) RAN 20' x 3.70" DUMMY WHIPSTOCK TO DOGLEG AT 8,720' SLM (unable to get further) RAN 3.50" CENT & 3" SAMPLE BAILER TO CIBP AT 8,840' ELMD (bailer empty) RAN READ 40 ARM CALIPER FROM 8,839' SLM TO SURFACE (good data) SET 4-1/2" WHIDDON ON XN NIPPLE AT 8,513' MD PULLED BK-OGLV AT ST# 3 (5,686' md) & BK-LGLV AT ST# 4 (3,476' md) SET BK-DGLV IN ST #4 AT 3,476' MD ***CONTINUE ON 9/29/24 WSR*** 9/28/2024 T/I/O=2363/2417/0 Temp=S/I (Assist SL with load and test) Pumped 120 bbls of Crude down the IA for sweep. ********WSR Continued on 9-29-2024******* 9/29/2024 *****WSR Continued from 9-29-2024******* (TFS unit 1 Assist SL with Load and test) Pumped 160 bbls of Crude down the TBG for load. Pumped an additional 7 BBLS of crude for testing. MIT-T ********PASSED*********** Pumped 6 BBLS of crude to reach max applied pressure of 2700 PSI with a target of 2500 PSI. TBG lost 35 PSI in the first 15 minutes and 12 PSI in the second 15 minutes for a total loss of 47 PSI in a 30 minute test. CMIT-TxIA *******PASSED********** Pumped 1 BBLS of crude to reach max applied pressure of 2700 PSI with a target of 2500 PSI. TBG/IA lost 30/15 PSI in the first 15 minutes and 7/7 PSI in the second 15 minutes for a total loss of 37/22 PSI in a 30 minutes test. Bleed TBG/IA down to 1000 PSI. Bleed back 4 BBLS. SL in control of well upon departure. Final WHPS=940/992/25 9/29/2024 ***CONTINUED FROM 9/28/24 WSR*** (sidetrack) T-BIRD LOADED IA W/ 120 BBLS CRUDE SET BK-DGLV IN ST# 3 AT 5,686' MD PULLED 4-1/2" WHIDDON AT 8,513' MD (empty) T-BIRD LOADED TBG W/ 160 BBLS CRUDE SET 4-1/2" PX IN X NIPPLE @ 8440' MD TBIRD CONDUCTED PASSING MIT-T & CMIT-TxIA PULLED PX FROM 8440' MD *** WELL LEFT S/I ON DEPARTURE *** 10/11/2024 *** WELL SI ON ARRIVAL (ELINE HOIST) *** MIRU YJ ELINE PT PCE 300/3000 PSI, FUNCTION WLV GOOD. CORRELATE TO WELLSKETCH JEWELRY TAG NIP W/ MILL AT 8513 FT, MILL NIP W/ 3.803" MILL PASSES THROUGH, LOG DOWN AND UP THROUGH JEWELRY. OBJECTIVE COMPLETE *** WELL SI ON DEPARTURE *** Daily Report of Well Operations PBU 06-19A Daily Report of Well Operations PBU 06-19A 10/24/2024 T/I/O = 2400/0/0 RU & test Lubicator set 4" ( H ) BPV # 140 RD Lubicator & Removed upper tree installed CDR tree #4 PT low 300 PSI High 5000 PSI against mastert Valve RU & PT Lubicator Pulled 4" ( H ) BPV # 140 RDMO FWP 2400/0/0 10/31/2024 T/I/O/OO = 2400/0+/5/5. Temp = SI. Bleed WHPs (pre rig). Wellhouse, grating, and flowline disconnected. CDR tree installed. OA & OOA FL near surface. Bled OAP & OOAP to 0 psi in <1 min (gas). Held open bleed for 90 min. Monitored for 30 min. WHPs increased <1 psi. Final WHPs = 2400/0+/0+/0+. SV, MV = C. IA, OA, OOA = OTG. 23:30 10/31/2024 T/I/O/OO = 2400/780/40/60. Temp = SI. Bleed IA, OA, & OOA to <50 psi (pre rig). Dryhole tree installed. Kill line rigged up to flowcross. Wellhouse and scaffolding removed. IA, OA, & OOA FL near surface. Bled IAP to BT to 0 psi in 10 min (gas). Held open bleed for 15 min. Bled OAP to BT to 0+ psi in 5 min (gas). Bled OOAP to BT to 0+ psi in 5 min (gas). Monitored for 30 min. IAP, OAP, & OOAP unchanged. Final WHPs = 2400/0/0+/0+. Well Support in control of well upon departure. 17:30 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Joseph Lastufka To:Joseph Lastufka Subject:FW:RE: PBU 06-19B (PTD #208-102) Sundry #324-392 Request for Extension Date:Wednesday, December 11, 2024 9:04:05 AM Attachments:image001.png From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Monday, December 2, 2024 3:58 PM To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: PBU 06-19B (PTD #208-102) Sundry #324-392 Request for Extension Joe, extension granted. -Wade Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907-793-1238 cell: 907-687-4468 From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent: Monday, December 2, 2024 3:07 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: PBU 06-19B (PTD #208-102) Sundry #324-392 Request for Extension Mel / Wade, Due to multiple plugbacks on PBU 06-19B (PTD #224-095), I’d like to request an extension to submit the 10-407 to close out PBU 06-19A (PTD #208-102), sundry #324-392 (Plug for Redrill, Other: Set Whipstock, Mill Window). The first milling of the window was 11/3/24,I’d like to wait until post TD / running of the liner and cementing to close out the sundry in the off chance another whipstock may be needed. Please let me know if you have any questions and I appreciate your help. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Sent: Monday, December 2, 2024 10:54 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Subject: PBU 06-19B (PTD# 244-095) - Plugback and Sidetrack Mel / Wade, PBU 06-19B (PTD# 244-095) Update: We set two billets and sidetracked due to hole conditions. This creates a PB1 and PB2 as shown below. Please let me know if you have any questions. Sidetrack details below: Sidetrack Date Depth Interval (ft) Length (ft) PB1 11/22/2024 9260 – 11,700 MD 2440 PB2 11/29/2024 9200 – 10,150 MD 950 Ryan Ciolkosz Drilling Engineer | C: 907.244.4357 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Drilling Manager 07/10/24 Monty M Myers 324-392 By Grace Christianson at 2:50 pm, Jul 10, 2024 DSR-7/10/24SFD 7/15/2024 MGR17JULY2024 Variance to 20 AAC 25.112(I). Approved for alternate plug placement with fully cemented liner on upcoming sidetrack. All drilling within the reservoir. WCB 7-17-2024 10-407 BOPE test to 3500 psi. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.01 14:38:24 -08'00'08/01/24 RBDMS JSB 080224 To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: July 10, 2024 Re:06-19A Sundry Request Sundry approval is requested to set a whipstock and mill a window in the 06-19A wellbore as part of the drilling and completion of the proposed 06-19B CTD lateral. Proposed plan: See 06-19A Sundry request for complete pre-rig details - Prior to drilling activities, slickline will drift for a whipstock and run a caliper (if needed), E-line will set a 4-1/2" packer whipstock, E-line or service coil will mill the XN nipple, and (if a unit is available) service coil will mill the 3.80" window. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2/CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will mill a single string 3.80" window + 10' of formation(if not done pre-rig). The well will kick off drilling in the Ivishak Zone 4 and drill an S-shaped well through Zones 2, 3, and 4 to TD. The proposed sidetrack will be completed with a 3-1/2" x 3-1/4" x 2-7/8" 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will target isolating and abandoning the parent Ivishak perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in August 1st, 2024) x Reference 06-19A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift and Caliper 2.Fullbore : MIT 3. E-Line : Set Whipstock at 8810' MD at 0 deg ROHS 4. Coil : Mill XN nipple and 3.80" Window (if window not possible, mill with rig) 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in November 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,387 psi). 2. Mill 3.80” Window (only if not done pre-rig) 3. Drill build section: 4.25" OH, ~174' (25 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2383' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 34 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Freeze protect well to a min 2,200' TVD. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) ,p completion will target isolating and abandoning the parent Ivishak perfs Sundry 324-392 PTD 224-095 Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig perforate (~30’) and RPM/CBL. The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: x A min EMW of 8.4 ppg KCL (~594 psi over-balance). KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. x Fluids >1% hydrocarbons or flammables must go to Pad 3. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be drilled with a 3.80” OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 10 AAC 25.036 c.4.C requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: x DS/Pad 06 is not an H2S pad. The last H2S reading on 06-19A:20 ppm on 04/16/2022 x Max H2S recorded on DS/Pad 06: 56 ppm. Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,267 psi at 8,800 TVD. (7.1 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,387 psi (from estimated reservoir pressure). x A min EMW of 8.4 ppg for this well will provide 540 psi over-balance to the reservoir. Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 Max H2S recorded on DS/Pad 06: 56 ppm Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 324-392 PRUDHOE BAY UNIT 06-19A SFD 7/15/2024 SFD 7/15/2024 208-102 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 06-19A Pulled patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-102 50-029-20791-01-00 11363 Conductor Surface Intermediate Production Liner 9035 83 2482 4983 4840 2851 8840 20" 13-3/8" 9-5/8" 7" 4-1/2" 8703 28 - 111 23 - 2505 22 - 5005 21 - 4861 8512 - 11363 28 - 111 23 - 2505 22 - 5005 21 - 4861 8395 - 9035 9089 , 11279 470 2670 4760 5410 7500 8840 , 9090 1490 5380 6870 7240 8430 8816 - 11270 4-1/2" 12.6# 13Cr80 22 - 8525 8683 - 9037 Structural 8406 8292 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com 907-564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028311 22 - 8408 433 1032 72516 57979 52 3 1097 1230 1066 1018 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:25 pm, Dec 28, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.12.28 11:16:11 - 09'00' Bo York (1248) DSR-1/26/24WCB 3-14-2024 RBDMS JSB 010324 ACTIVITYDATE SUMMARY 11/26/2023 ***WELL S/I ON ARRIVAL*** (Profile modification) PULLED 2-7/8" XXN PLUG AT 8,955' MD RAN 4-1/2" BRUSH & 3.65" G. RING TO 45KB FLOGUARD PATCH AT 8,841' MD (no issues) PULLED UPPER PATCH SECTION FROM 8,841' MD(Missing 1 element) RAN WIREGRABS & BAILERS ATTEMPTING TO RECOVER MISSING ELEMENT(Unsuccessful) ***CONTINUED ON 11/27/23 WSR*** 11/27/2023 ***CONTINUED FROM 11/26/23 WSR*** (Profile modification) PULLED LOWER 45 KB PKR AT 8,879' MD (missing mid element) RAN 4-1/2" BRUSH & 3.67" WIRE GRAB TO SUMP PKR AT 8,947' MD (no recovery) RAN 4-1/2" DOGLESS GS TO SUMP PKR AT 8,947' MD (not sheared) RAN 10' x 2.25" PUMP BAILER TO SUMP PKR AT 8,947' SLM (no recovery) RAN 4-1/2" BRUSH & 3.69" WIRE GRAB TO SUMP PKR AT 8,947' MD (no recovery) RAN 4-1/2' DOGLESS GS TO SUMP PKR AT 8,947' MD (sheared) PULLED 45 KB SUMP PKR AT 8,947' MD (recovered all elements - elements from other pkr still in-hole) RAN 3.70" CENT, 4-1/2" BRUSH & 3.69" 3-PRONG WIRE GRAB TO CIBP AT 9,090' MD (no recovery - used as CIBP drift) ***WELL S/I ON DEPARTURE*** 12/2/2023 ***WELL S/I ON ARRIVAL*** (SET 3.5'' NS PLUG AND PERFORATE 8' OF 2.75'' GEO RAZOR 6(spf) 60 DEG PHASE) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH RUN#1 W/CH/X2 1.69'' WB/ 2.75''GUN GAMMA-CCL/BAKER#10/NS 3.5'' CIBP MAX AOL=27.9' TO SET NS CIBP AT 8840' MD CCL TO MID ELEM=11.6' CCL STOP DEPTH=8828.4' MD RUN#2 W/CH/X2 1.69'' WB/ 2.75''GUN GAMMA-CCL/2.75'' X 8' GEO RAZOR GUN 6(spf) 60 DEG PHASE TO PERFORATE INTERVAL 8816'-8824' CCL TO TOP SHOT=9.3' CCL STOP DEPTH=8806.7' MD JOB COMPLETE ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU 06-19A PERFORATE INTERVAL 8816'-8824' () PULLED UPPER PATCH SECTION FROM 8,841' MD(Missing 1 element) SET NS CIBP AT 8840' MD () PULLED LOWER 45 KB PKR AT 8,879' MD (missing mid element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y Anne Prysunka at 9:26 am, Nov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a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perator Name:2. Development Exploratory Service 5 Permit to Drill Number:208-102 6.50-029-20791-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11363 9090 8890 8406 11279 9090 8292 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 83 20" 28 - 111 28 - 111 1490 470 Surface 2482 13-3/8" 23 - 2505 23 - 2505 5380 2670 Intermediate 4983 9-5/8" 22 - 5005 22 - 5005 6870 4760 Production 4840 7" 21 - 4861 21 - 4861 7240 5410 Perforation Depth: Measured depth: 8855 - 11270 feet True vertical depth:8715 - 9037 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 22 - 8525 22 - 8408 8406 8292Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 100019811231171 658593 1813 47254 951 912 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) 564-4535 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9035 Sundry Number or N/A if C.O. Exempt: n/a No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028311 PBU 06-19A 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 4:19 pm, Aug 11, 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: 2021.08.11 15:31:51 -08'00' Bo York MGR11AUG2021 2514 DSR-8/6/21 8395 - 90354-1/2" 2514 SFD 8/13/2021 8689 SD 8/13/2021 8512 - 11363 8566 RBDMS HEW 8/12/2021 ACTIVITYDATE SUMMARY 7/16/2021 ***WELL S/I ON ARRIVAL***(perforating). RAN 3.691" WRP DRIFT TO DEVIATION @ 9,342' SLM. RAN 20' x 3.5" DD BAILER TO 8,720' SLM (unable to pass dogleg). RAN 20' x 2-7/8" DMY PERF GUN TO DEVIATION @ 9,338' SLM. ***WELL LEFT S/I ON DEPARTURE, JOB COMPLETE*** 7/28/2021 ***WELL SHUT IN UPON ARRIVAL**** (ELINE SET PLUG AND ADPERF) SET 4-1/2" LEGACY PLUG @ 9090' MD PERFORATE INTERVAL @ 8855' - 8875' W/ 20' X 2-7/8" GEO RAZOR GUN RIG DOWN AND TURN WELL OVER TO PAD OP TO POP ***JOB COMPLETE*** Daily Report of Well Operations PBU 06-19A 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. Q~ - ~ Q ~, Well History File Identifier Organizing (done) RESC N Color Items: reyscale Items: ( ^ Poor Quality Originals: ^ Other: NOTES: ~wo-sided IIIII'IIIIIIIIIIIII DIG AL DATA Diskettes, No. ^ Other, No/Type: A,.~.~ ~roaa uuuuiriuiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: ] /s/ ~ Project Proofing ~ ~ II I I I ~I II I (II)I ((I ( „ BY' r, Maria Date: ~ ~' ~ I ~IO /sl ' r ~-~ Scannin Pre aration _ 0~, x 30 = ~I~ + ~ =TOTAL PAGES_ ~~..~- 9 (Count does not include cover sheet) BY: _ Maria Date:. ~. l I I l / rD /sl Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ /, ! V !s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: !s/ Scanning is complete at this point unless rescanning is required. (I I II'I II I II II IIIII ReScanned III 111111 IIIII II III BY: Maria Date: !s/ Comments about this file: Quality Checked III IIIII III III III 10/6/2005 Well History File Cover Page.doc ■ STATE OF ALASKA t AKA OIL AND GAS CONSERVATION COMM ION 4\U G 0 8 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon L] Repair Well Li Plug Perforations Li Perforate Ld Other❑ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extensions Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 0 Exploratory ❑ 208-102-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20791-01-00• 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028311 PBU 06-19A . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL, 11.Present Well Condition Summary: Total Depth measured 11363 feet Plugs measured None feet true vertical 9035.05 feet Junk measured 11279 feet Effective Depth measured 11279 feet Packer measured See Attachment feet true vertical 9037.12 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 2485 13-3/8"72#L-80 29-2514 29-2513.92 4930 2670 Intermediate 4977 9-5/8"47#L-80 28-5005 28-5004.69 6870 4760 Production 8662 7"26#L-80 27-8689 27-8566.48 7240 5410 Liner 2851 4-1/2"12.6#13Cr80 8512-11363 8395.4-9035.05 8430 7500 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment_ feet sc tit4ED NOV 8 2013 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-8525 24-8408.04 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 Prior to well operation: 0 4493 13 1299 216 Subsequent to operation: 8 126 662 2020 789 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El - Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil © . Gas ❑ WDSPLLi GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGO 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.SummerhayS(a)BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Signatu - 0j % �' �_ Phone 564-4035 Date 8/7/2013 �g 5 � RBDMS AUG 2 0 2 12,1113 Form 10-404 Revised 10/2012 Submit Original Only r • • Daily Report of Well Operations ADL0028311 x � f • . ive 01 u•in g - o Scope= aril o g e MIRU, pump slack management, pump drift ball. Perfom weekly BOP test. Make up logging head to coil. 7/12/2013 <<<Job continued on 7/13/13>>> CTU #9 1.75" Coil Tubing -Job Scope= Drift/Log/Add Pert«<Job continued from 7/12/13>>> RIH w/ext dimple ctc 2.25"x 0.56', ifc release sub(3/4" ball to release)2.125" x 0.50', ct head 2.125"x 0.39', ccl 2.125"x 1.97', gr 2.50"x 3.32', xover 2.125"x 0.68', xover 2.125"x 0.50', mha(7/16" ball to disconnect) 2.125"x 2.70', xover 2.125"x 0.42', drift nozzle 3.70"x 1.52'. OAL 16.23'. Dry tag 9850, washed down/up 1 bpm to 10200', puh and dry tag 10226', logged from 10226'-8350', corrected and flagged pipe. 7/13/2013 <<<Job continued on 7/14/13>>> CTU#9 1.75"ACTive Coil tubing -Job Scope=Add pert<<<Job continued from 7/13/13>>> Tied into coil flag and attempted to tie in to the collars, made to seperate passes at slower speeds (30 fpm) and no luck, made a 60 fpm pass and collars showed up better. Corrected depth. Fired 20' of 3.38"6 SPF 60 deg 3406 PJ HMX gun 10030- 10050 elm. Logged 10060'-9850'and fired 20' 3 3/8"6 spf 60 deg 3406 PJ HMX (Tie in log PPROF 9/19/2010) Reference log MD 7/12/2009 perf depth 10010'- 10030'. 2 HRS NPT due to tractor issues 7/14/2013 <<<Job in Progress>>> CTU#9 1.75"ACTive Coil Tubing -Job Scope =Add perf<<<Job continued from 7/14/13>>> 3.38"6 SPF 60 deg 3406 PJ HMX gun 9990-10010 elm. Freeze protected the well with 30 bbls of 50/50 methanol. Performed slack management of the IFC. RDMO. 5 HRS of NPT due to hydraulic pump failure 7/15/2013 <<<Job complete>>> FLUIDS PUMPED BBLS 133 1% KCL 55 1% SL KCL WITH SAFELUBE 30 50/50 METH 218 TOTAL , Perforation Attachment ADL0028311 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 06-19A 7/15/2013 APF 9990 10010 9032.82 9031.19 06-19A 7/14/2013 APF 10010 10030 9031.19 9029.86 06-19A 7/14/2013 APF 10030 10050 9029.86 9028.98 06-19A 6/6/2012 SQZ 10250 10380 9033.63 9036.87 06-19A 6/6/2012 SQZ 10420 10620 9037.38 9039.18 06-19A 6/6/2012 SQZ 10780 10790 9039.69 9040.2 06-19A 6/6/2012 SQZ 10790 10820 9040.2 9041.85 • 06-19A 6/6/2012 SQZ 10820 10930 9041.85 9044.47 06-19A 11/8/2011 PER 10980 11190 9044.07 9039.19 06-19A 11/8/2011 APF 11190 11260 9039.19 9037.57 06-19A 11/8/2011 PER 11260 11270 9037.57 9037.33 BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • . s • • Packers and SSV's Attachment ADL0028311 SW Name Type MD TVD Depscription 06-19A PACKER 4849 4783.43 7" Baker ZXP Top Packer 06-19A PACKER 8406 8226.62 4-1/2" Baker S-3 Perm Packer 06-19A PACKER 8512 8330.1 5" Baker ZXP Top Packer TREE= aw • WELLHEAD= FMC SA NOTES: ""WELL ANGLE>70°@ 9310"'* ACTUATOR= BAKER C -19 A ***4-112"CHROME TBG&NIPPLES*`*ORIG WELL NOT INMAL KB EL.E 74' SHOWN BELOW WHPSTOCK*** BF ELEV= ? I 1 r KOP= 5000' 2198' —14-1/7'h1ES X t+ ',D=3,813' Max Angle= 95°@ 1000tY Datum MD= 9051' iii Datum N D= 8800'SS L GAS LET MANDRELS 13-3/8"CSG,72#,L-80,0=12.347" — 2514' ST MD TVD DEV TYPE VLV LATCH FORT DATE 4 3476 3476 0 KBG2 DONE BK 16 06116/12 3 5686 5677 17 KBG2 SO BK 20 06/16/12 ESTTOC — 4300' 2 7222 7134 12 KBG2 DMY BK 0 07/15/08 �• ��� 1 8297 8185 11 KBG2 OMY BK 0 07/15/08• 7"LNR,26#,L-80 BTC-M, — 4847' :• •,• ¢649' F—9-5/8"X 7"ZXP LIP w/TEBACK SLV&BKR .0383 bpf,D=6.276" 0t�i �h� LNR HGR D=6.21" 1'• •• • �. 9-5/8'W-PSTOCK 5025' �••• �• `.', MILLOUT WPDOW(06-19A) 5005'-5021'• Minimum ID = 3.725" @ 8513' 't�'� 4-1/2" HES XN NIPPLE 9-5/8'CSG,47#,L-80,D=8.681" — 8620` 8375' —14-1/2-HES X NP,D=3.813" Ili 8406' —17"X 4-1/2"BKR S-3 PKR,0=3.870" * , $440' —4-1t2"HES X NP,D=3.813" Ili8512' —7"X 5"HR ZXP LW w/TEBACK SLV,D=4.350" X 8513' —4-1/2"HES XN NP,ID=3.725" 4-1t2"TBG,12.6#, 13-CRVAMTOP, H 8525' 8525' —4-1/2"WLEG,D=3.958" .0152 bpf.D=3.958" 4 8�' ��7"X 5"HMC LNR HGR,D=4.370' 7"CSG,26#,L-80 BTC-M,.0383 bpf,ID=6.276" 8689" • 8544• —5'X 4-1/2"X0,10=3.930" PERFORATION SUMMARY RFC LOG Revision After Sidetrack ANGLE AT TOP PEI -95"@ 10980' Note:Refer to Production DB for historical perf data 1111 SIZE SPF ttTTERVAL `Opn/Sgz SHOT SQZ 3-3/8" 6 9990-10050 0 07/14/13 2-7/8" 6 10250-10380 S 07/15/08 06/06/12 2-7/8" 6 10420-10620 S 07/15/08 06/06/12 2-7/8" 6 10250-10380 S 07/15/08 06/06/12 2-7/8' 6 10420-10620 S 07/15/08 06/06/12 ` 2-7/8" 6 10780-10930 S 07/15/08 06/06/12 —11279' FISH 4-1/2"CUP PARTS 3-3/8" 6 10790-10820 S 11/08/11 06/06/12 MLLED OUT(06/08/12) 2-7/8" 6 10980-11270 0 07/15/08 3-3/8" 6 11190-11260 0 11/08/11 16441 PBTD H 11279' 4-1/2'LNR,12.6#,13CR-80 VAM TOP,.0152 bpf,ID=3.958" H 11363' GATE REV BY COMMENTS - DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/19182 ORIGINAL COMPLEITON 06/20/12 DAS/JMD GLV CIO(06/16/12) WELL 06-19A 05106/96 LAST WORKOVR 07/05/12 LLVJMD SOZ FERFS/SET FISH(06106-08-12) PERMIT Na 2081020 07/15/08 N7E'S SIDETRACK(06-19A) 07/23113 SRDIJMD ADPERFS(07/14/13) API No: 50-029-20791-01-00 08/05/08 LJHIPJC GLV C/O(07/22/08) SEC 2,T10N,R14E,231'FSL&910'FI3 04/02/10 JR/JMD DRLG DRAFT CORRECTIONS 11/15/11 CJS/PJC ADPERFS(11/08/11) I BP Exploration(Alaska) STATE OF ALASKA RECEIVED ALl OIL AND GAS CONSERVATION COMMI ION AUG 0 8 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate u Other L AOG VC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other 151 Re -enter Suspended Well0 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 151 Exploratory ❑ 208 -102 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: _ Anchorage, AK 99519 -6612 50- 029 - 20791 -01 -00 7. Property Designation (Lease Number): - 8. Well Name and Number: ADL0028311 PBU 06 -19A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11363 feet Plugs measured None feet true vertical 9035.05 feet Junk measured 11279 feet Effective Depth measured 11279 feet Packer measured See Attachment feet true vertical 9037.12 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 2485 13 -3/8" 72# L -80 29 - 2514 29 - 2513.92 4930 2670 Intermediate 4977 9 -5/8" 47# L -80 28 - 5005 28 - 5004.69 6870 4760 Production 8662 7" 26# L -80 27 - 8689 27 - 8566.48 7240 5410 Liner 2851 4 -1/2" 12.6# 13Cr80 8512 - 11363 8395.4 - 9035.05 8430 7500 Perforation depth Measured depth 10980 - 11190 feet 11190 - 11260 feet 11260 - 11270 feet 10250 - 10380 feet 10420 - 10620 feet 10780 - 10790 feet 10790 - 10820 feet 10820 - 10930 feet True Vertical depth 9044.07 - 9039.19 feet 9039.19 - 9037.57 feet 9037.57 - 9037.33 feet 9033.63 - 9036.87 feet 9037.38 - 9039.18 feet 9039.69 - 9040.2 feet 9040.2 - 9041.85 feet 9041.85 - 9044.47 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 24 - 8525 24 - 8408.04 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): Acid Treatment: 10250' - 10380', 10420' - 10620', 10780' - 10930', 10980' - 11270' Squeeze Treatments (2 Squeeze Treatments, 6/2/12 & 6/6/12): 10250' - 10930', 10250' - 10930' z {. Treatment descriptions including volumes used and final pressure: Acid Treatment: 60 bbls 12% HCL, 53 bbls 9:1 Mud Acid; Final Pressue (12% HCL) = 2469 psi, Final Pressure (Mud Acid) = 2322 psi Squeeze Treatments: 152 bbls Organo Seal, 20 bbls Squeeze Crete, Final Pressure = 1100 psi 50 bbls Organo Seal, 26 bbls Squeeze Crete, Final Pressure = 2546 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 346 23247 28.93 625.68 337.16 Subsequent to operation: 0 3437 12 1219.1 239.04 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El ` Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil r 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ USP ❑ SPLUCO 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 Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature A et,47. a .-- - Phone 564 -4424 Date 8/8/2012 R13 0M5 AUG 0 9 2011 VI- IV v Form 10 -404 Revised 10/2010 ����Z Submit O riginal Only 0 • Packers and SSV's Attachment ADL0028311 SW Name Type MD TVD Depscription 06 -19A PACKER 4849 4783.43 7" Baker ZXP Top Packer 06 -19A PACKER 8406 8226.62 4 -1/2" Baker S -3 Perm Packer 06 -19A PACKER 8512 8330.1 5" Baker ZXP Top Packer • • Daily Report of Well Operations ADL0028311 ACTIVITYDATE 1 SUMMARY 01 u •rrtg - O. cope cis rt " e : - ;� g,. :s _ Organoseal /Cement N..**W' Arrived on location, RU and spot equipment. MU 3.7" drift BHA and RIH, filled CT with NH4C1. Tag at 10876ft with 10klbs, PU and tag again to confirm. Started pumping and jetted through restriction till 10922ft. PU and RIH dry - tag soft at 10922ft. PU with 110001bs overpul. Started pumping and POOH while pumping to 10000ft. No overpul observed while POOH and pumping. From 10000ft POOH without pumping. LD drift BHA, MU 2.5" JSN cleanout BHA and RIH. 5/30/2012 « <Job in progress »> CTU #9 1.75" Coil Tubing - Job Scope = Acid, Drift/Log, Set Bridge Plug, Organoseal /Cement . Cleaned out to 11278' with 2.50" nozzle. «« Continue from 05/30/12 »» RIH with 3.7" drift BHA and tagged at 10447ft. Jetted through restriction and drifted to 11280ft CTM. PU above perforations and performed dry drift to 11278ft CTM, no weight loses observed. POOH, LD drift BHA, PU acidizing 2.5" SJN BHA and RIH. Perform injectivity test 0.5 bpm thru 4 bpm . Pumped 60 bbis of 12% HCL acid and 53 bbls of 9:1 Mud acid recip across perf's. Perform post acid injectivity 5/31/2012 « <Job in progress »> CTU #9 1.75" Coil Tubing - Job Scope = Acid, Drift/Log, Set Bridge Plug, Organoseal /Cement «< Continued from 5/31/12 »> RIH with PDS GR /CCL logging tools with a 2.375" carrier and a 2.50" nozzle. Logged interval from 11277' to 8250' CTM, flagged coil at 11000'CTM. POOH. RIH w/ 3.66" HES Obsidian CBP. Tie into Ref Log SLB MEM PRODUCTION PROFILE dated 19- SEPT -2010. Correct to mid element at flag. PU to setting depth at 10945'CTM, launch 1/2" ball, and set CBP. Good indication of set. Tag CBP at 10945'CTM confirming set. POOH. Verify CMT field blend. RIH w / 2.30" BDJN. Pump 300 bbis of 1 %KCL 6/1/2012 perform injectivity test « <Job in Progress »> CTU #9 1.75" Coil Tubing - Job Scope = Acid, Drift/Log, Set Bridge Plug, OrganoSeal /Cement «< Continued from 6/1/12 »> Cement up to weight © 01:50. Pumped 114bbls of diesel down backside. Follow up w/ OrganoSeal. Pumped 152bbls of OrganoSeal into perfs and stopped pumping due to pressure approaching frac pressure. Pumped 20bbls of SqueezeCrete @14.09ppg laying in at 1:1. PUH to safety, start hesitation squeeze. Pressure falling off and stabilizing @ — 1200psi. Kept final squeeze pressure @ 1100psi for 2.5hrs. RIH and contaminate w/ Biozan to 10924 ctmd. Hard tag ©10924'. PUH. Layed out Biozan across perfs. POOH to surface jetting KCL @ 3bpm. Maintained 1:1 returns to surface trapped 1000 psi on well. Perform weekly BOP test. Sqeezed perf's form 10250' to 6/2/2012 10930' «< Job compete »> CTU #9 1.75" Coil Tubing - Job Scope = Acid, Drift/Log, Set Bridge Plug, 6/2/2012 Organoseal /Cement «< Continued from 6/1/12 »> Cement up to weight @ 01:50 • • Daily Report of Well Operations ADL0028311 CTU #9 1.75" Coil Tubing - Job Scope = Acid, Drift/Log, Set Bridge Plug, OrganoSeal /Cement «< Continued from 6/1/12 »> Cement up to weight @ 01:50. Pumped 114bbIs of diesel down backside. Follow up w/ OrganoSeal. Pumped 152bbts of OrganoSeal into perfs and stopped pumping due to pressure approaching frac pressure. Pumped 20bbls of SqueezeCrete @14.09ppg laying in at 1:1. PUH to safety, start hesitation squeeze. Pressure falling off and stabilizing @ — 1200psi. Kept final squeeze pressure @ 1100psi for 2.5hrs. RIH and contaminate w/ Biozan to 10924 ctmd. Hard tag 6/2/2012 @10924'. PUH. Layed out Biozan across perfs. POOH to surface jetting KCL @ 3bpm. CTU #9 1.75" Coil Tubing - Job Scope = Acid, Dntt/Log, Set Bridge Plug, OrganoSeal /Cement 6/3/2012 MIRU «« Job in progress »» CTU #9 1.75" Coil Tubing - Job Scope = Acid, Drift/Log, Set Bridge Plug, OrganoSeal /Cement «« Continue WSR from 6/3/12 »» PT squeeze to 1500psi. WHP leaks off rapidly. RIH w / Baker motor & 3.64" BO mill. Start milling cement @ 10792'. Milled cement to 10930ctmd w/ gel sweeps. POOH to safety. Started injectivity test. Established injection rate of 0.75 bpm at 1550psi. Decision was made to re- attempt OrganoSeal / cement squeeze. Reconfigured 6/4/2012 hardlines. Pump 113 bbls of diesel down BS RIH. « «Job in Progress »» CTU #9 1.75" Coil Tubing - Job Scope = Acid, Drift/Log, Set Bridge Plug, OrganoSeal /Cement «« Continue WSR from 6/4/12 »» Re- Squeeze pump 50 bbls of OrganoSeal. Pumped 113bbls of diesel in preparation for cement squeeze. Cement got to 100 Bc in 24 hrs 25 mins.Squeezed perf's from 10250' 6/5/2012 to 10930' «< Job in progress >» CTU #9 1.75" Coil Tubing - Job Scope = Acid, Dritt/Log, Set Bridge Plug, OrganoSeal /Cement «« Continue WSR from 6/5/12 »» Layed in 26 bbls of SqueezeCrete at 1:1. Squeezed 11 bbls behind pipe. Held squeeze pressure for 30 min. Start pressure was 2600 psi final pressure was 2546 psi total loss of 54 psi in 30 mins. Cleaned out to plug at 10948' with biozan and POOH chasing cement @ 80 %. FP well w/ 50bbls of 50/50. Trapped 1100psi WHP. RDMO. « «Job 6/6/2012 Complete »» CTU #9 w / 1.75" CT Job objective: Mill out cement / 3.66" CBP. Performed GWO exercise drill. Arrived on DS -6. RU hardlines. PT cement squeeze to 1540psi. Test passed w/ slow pressure bleed off rate. No injectivity at 1500psi. Pad operator has confirmed wing valve is leaking by. Open well still has 1017 psi on well since 17:00 hrs 2 1/2 hrs. no fluid loss. PU & RIH w/ motor & 3.64" BO mill. « <Job in 6/8/2012 Progress »> CTU #9 w / 1.75" CT Job objective: Mill out cement / 3.66" CBP. «« Continue WSR from 6/8/12 »» Milled thru plug 10945' with a 3.64" BO mill ..Copltinuentlling..past . plug set depth to 11001'. POOH and check mill. Mill is bald with a hard like plastic. SLB lab test results showed no cement/OrganoSeal content. Changed out 3.64" BO Mill to 3.7" PDC bit & RIH. Tagged @11008'. Start ? milling taking returns to suface @1:1. Hardly can see motor work. WOB erratic. Weight broke off @ 11045ctmd, gained 2klbs. Chased plug to TD w/ no motor work. Pumped 15bbls gel sweep at 11279 ' and chased it out. Performed injectivity test. 1 bpm @1460psi. Confirmed with town PE injectivity is good. POOH. Pumped 49bbls of 50/50 for FP. At surface. LD toolstring. 6/9/2012 Unable to RD due to high winds. Performed weekly BOP test. « <Job in Progress »» - TREE = CM/ III ACTUATOR= BAKER C 0 6 -1 9A SAFETY NOTES: """WELL ANGLE> 70° @ 9310'""* 4 -112" CHROME TBG & NIPPLES''ORIG WELL NOT KB. ELEV = 74' SHOWN BELOW WHIPSTOCK'*" BF. ELEV = ? 1 KOP = 5000' j li Max Angle = 95° 1D 10000' 2198' —14-1/2" HES X NIP, ID = 3.813" Datum MD = 9051' Datum TV D = 8800' S S GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2514' I ST NE) TV D DEV TYPE VLV LATCH PORT DATE 4 3476 3476 0 KBG2 DOME BK 16 06/16/12 3 5686 5677 17 KBG2 SO BK 20 06/16/12 (EST TOC H 43(X' � 1 4 4 2 8297 8185 11 KBG2 DIM BK 0 07/15/08 7" LNR, 26 # L -80 BTC-M, --1 4847` �� 1 4849' 1-' 9 -5 /8 "' X 7" ZXP LTP w /TIEBACK SLV & BKR .0383 bpf, ID = 6.276" le 7 h � LNR HGR, ID = 6.21'" 11 .'1 tti• I9 - 5/8" HIPSTOCK ---1 5025' * 4 ■ • W • ■ MILLOUT WINDOW (06 -19A) 5005' - 5021' Minimum ID = 3.725" @ 8513' 4 -1/2" HES XN NIPPLE 19-5/8" CSG, 47 #, L -80, ID = 8.681" H 8620' _A I 8375' H4_1/2" HES X MP, ID = 3.813" I PERFORATION SUMMARY 8406' Hr X 4-1/2" BKR S -3 PKR, ID = 3.870" REF LOG: Revision After Sidetrack 44 ANGLE AT TOP FERF: 88° © 1025D fi Il Note: Refer to Ftoduction DB for historical perf data 8440' — 141/2" HES X NIP, ID = 3.813" 1 SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10250 - 10380 S 06/06/12 8512' — 7" X 5" HR ZXP LTP w /TIEBACK 2-7/8" 6 10420 - 10620 S 06/06/12 SLV, ID = 4.350" 2 -7/8" 6 10780 - 10930 S 06/06/12 8513' J 1 4112" HES XN NIP, ID = 3.725" 3-3/8" 6 10790 - 10820 S 06/06/12 lir 2-7/8" 6 10980 - 11270 0 07/15/08 8525' „ I - 14-1/2" WLEG, ID = 3.958" 1 3 -3/8" 6 11190 - 11260 0 11/08/11 I 8534' I-17 " X 5" HMC LNR HGR, ID = 4.370" I 1 8544' I X 4 -1/2" XO, ID = 3.930" I 4-1/2" TBG, 12.6#, 13 -CR VAMTOP, —I 8525' .0152 bpf, ID = 3.958" 7" CSG, 26 #, L -80 BTC -M ,0383 bpf, ID = 6.276" I 8689' ` — 11279' I— FISFt 4 -1/2" CIBP PARTS MILLED OUT (06/08/12) PBTD 11279' tO° 14-1/2" LNR, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" 11363' DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 08119/82 ORIGINAL COM PLETION 01/07/12 CDJ/ PJC GLV C/O (12/22/11) WELL' 06-19A 05106/96 LAST WORKOVER 06/20 /12 DAS /JMO GLV C/0 (06/16/12) PERMIT No: `2081020 07/15108 N7ES SIDETRACK (06 -19A) 07/05/12 LLVJMD SQZ FERFS/SET FISH (06106- 08 -12) API No: 50- 029 - 20791 -01 -00 08/05/08 LJI -PJC GLV C/0 (07/22/08) SEC 2, T10N, R14E, 231' FSL & 910' FEL 04/02/10 JR/JMD DRLG DRAFT CORRECTIONS 11/15/11 CJSIPJC ADFERFS (11/08/11) 11 BP Exploration (Alaska) 2C)t3(Ozo Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelIIntegrityCoordinator @bp.com] Sent: Monday, August 06, 2012 11:15 PM Kqf e1 To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Youngmun, Alex Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: OPERABLE: Producer 06 -19A (2081020) Tubing Integrity Restored All, Producer 06 -19A (PTD #2081020) passed a TIFL on 08/06/2012. The passing test confirms the presence of two competent barriers in the wellbore. The well has been reclassified as Operable Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator SCANNED MAY 0 7 2013 Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinatora (�BP.com From: AK, D &C Well Integrity Coordinator Sent: Thursday, August 02, 2012 7:59 PM To: 'Schwartz, Guy L (DOA)'; 'Regg, James B (DOA)'; AK, OPS FS3 OSM; AK, OP- FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wirelin operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East We - Opt Engr; G GPB FS3 Drillsites; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OP. GC1 Wellpad Lead; AK, OPS Prod Controllers Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Producers with Sustained Casing P--ssure During Proration All, The following producers were found to have sus , ned casing pressure on the IA during proration. The immediate action is to perform a TIFL on each of the wells to ev -, uate for IA repressurization. If the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual I with a plan forward. 06 -19A (PTD #2081020) 14 -05A (PTD #1920010) F -43 (PTD #1910750) 1 Pat Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] l , / Sent: Thursday, August 02, 2012 7:59 PM 7 l (`z— To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS3 Drillsites; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Producers with Sustained Casing Pressure During Proration All, The following producers were found to have sustained casing pressure on the IA during proration. The immediate action is to perform a TIFL on each of the wells to evalt e fN A repressurization. If the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well with a plan forward. 06 -19A (PTD #2081020) 14 -05A (PTD #1920010) SC,AttED MAY 0 7 201 F -43 (PTD #1910750) All the wells listed above are reclassified as Not Operable until start-up o erations commence and are stable or the well passes a pressure test confirming integrity. A er s a -up, e we s will be reclassified as tinder Evaluation with POP parameters to prevent any over - pressure incidents if integrity has not been confirmed. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinator (cr�BP.com 1 F C* -IRA Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Sunday, December 25, 2011 7:28 AM " iz /4 To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Youngmun, Alex Cc: King, Whitney; LeBaron, Michael J; Wills, Shane M (Northern Solutions) Subject: OPERABLE: Producer 06 -19A (PTD #2081020) MIT -IA Passed All, Producer 06 -19A (PTD #2081020) passed an MIT -IA today after dummy gas lift valves were set. This passing test confirms the presence of two competent barriers in the wellbore. This well is being reclassified as Operable. Please be aware of the potential for thermal expansion when bringing the well online as the IA is fluid packed. Thank you, Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 • wr• From: AK, D &C Well Integrity Coordinator Sent: Friday, December 09, 2011 9:30 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites Cc: Walker, Greg (D &C); Olson, Andrew Subject: UNDER EVALUATION: 06 -19A (PTD #2081020) Sustained Casing Pressure on IA Over MO' P All. Producer 06 -19A (PTD #2081020) was found to have sustained .sing pressure over MOASP on the IA. The tubing /IA/OA were equal to 854/2320/140 on 12/08/11. A TIF failed confriming a lack of two competent barriers in the wellbore. The well is reclassified as Under Evaluation and ay remain online while diagnostics are conducted. The Plan Forward: 1. Slickline: Change out orifice gas lift valve 2. Downhole Diagnostics: TIFL A wellbore schematic and TIO plot are . ached for reference: « File: 06- 19A.pdf » « File: 0: -19A TIO 12- 09- 11.doc » Thank you, Mehreen Vazir (Alternate: Gerald Mur iy) 1 • z_c6 IGu) Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] ���� Z /���� Sent: Friday, December 09, 2011 9:30 PM / To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites Cc: Walker, Greg (D &C); Olson, Andrew Subject: UNDER EVALUATION: 06 -19A (PTD #2081020) Sustained Casing Pressure on IA Over MOASP Attachments: 06- 19A.pdf; 06 -19A TIO 12- 09- 11.doc All. Producer 06 -19A (PTD #2081020) was found to have sustained casing pressure over MOASP on the IA. The tubing /IA/OA were equal to 854/2320/140 on 12/08/11. A TIFL failed confriming a lack of two competent barriers in the wellbore. The well is reclassified as Under Evaluation and may remain online while diagnostics are conducted. The Plan Forward: • 1. Slickline: Change out orifice gas lift valve 2. Downhole Diagnostics: TIFL A wellbore schematic and TIO plot are attached for reference: i q- 5c f «06- 19A.pdf» «06 -19A TIO 12- 09- 11.doc» /.�yr = ( 7C j Thank you, 33,q)% Mehreen Vazir I °� (4 /tcr!xrte: (, ralt/ thripiV) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 •r' i l n ,1 Zn Email: AKDCWeIIIntegrityCoordinator @BP.com 1 PBU 06-19A PTD #2081020 12/9/2011 TIO Pressures Plot weft 06-19 4 WO - •••• 3.103 - • Tbg —II— IA 2U06 - SI O L000 - • 09/10/11 09/17/11 09/24/11 10/01/11 10/09/11 10/1 10122/11 10/29/11 11/05/11 11/1 11/19/11 11/26/11 12/03/11 TREE = CIW � • 1 SAFETY NOTES: * * *WEL ANGLE 70° @ 9310' * ** ACTUATOR = BAKER C 0 6 V * * *4 -112" CHROME TBG & NIPPLES * * *ORIG WELL NOT KB. ELEV = 74' SHOWN BELOW WHIPSTOCK * ** BF. ELEV = ? i f Ma xAngie = 95° @ 10000' 1 2198' 1-14-1/2" HES X NIP, ID = 3.813" I Datum MD = 9051' Datum TV D = 8800' SS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2514' I-A GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE r 4 3476 3476 0 KBG2 DOME BK 16 07/22/08 3 5686 5677 17 KBG2 SO BK 20 07/22/08 EST TOC I-I 4300' 2 7222 7134 12 KBG2 DMY BK 0 07/15/08 1 � � 4 1 8297 8185 11 KBG2 DMY BK 0 07/15/08 1 4 1 1' 7" LNR, 26 #, L -80 BTC-M, -I 4847' f 1 4849' I-- 9 -5/8" X 7" ZXP LTP w /TIEBACK SLV & BKR .0383 bpf, ID = 6.276" i # i� I j' LNR HGR, ID = 6.21" 9 -5/8" WHIPSTOCK H 5025' I ♦ 1 1 � `�� 1` ' ' MILLOUT WINDOW (06 -19A) 5005' - 5021' Minimum ID = 3.725" @ 8513' 4 -1/2" HES XN NIPPLE 19-5/8" CSG, 47 #, L -80, ID = 8.681" 1--) 8620' HI 8375' I-14 -1/2" HES X NIP, ID = 3.813" I Ms'lr= 6 7c':)., FE : PERFORATION SUMMARY 8406' I-17" X 4-1/2" BKR S -3 PKR, ID = 3.870" I REF LOG: Revision After Sidetrack I ANGLE AT TOP PERF: 88° @ 10250' t ' 8440' 14 -1/2" HES X NIP, ID = 3.813" I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 8512' 7" X 5" HR ZXP LTPw /TIEBACK 2 -7/8" 6 10250 - 10380 0 07/15/08 SLV, ID = 4.350" 2 -7/8" 6 10420 - 10620 0 07/15/08 2-7/8" 6 10780 - 10930 0 07/15/08 X 8513' H4-1/2" HES XN NIP, ID = 3.725" I 3 -3/8" 6 10790 - 10820 0 11/08/11 2 -7/8" 6 10980 - 11270 0 07/15/08 8525' I- 14 -1/2" WLEG, ID = 3.958" 3 -3/8" 6 11190 - 11260 0 11/08/11 O 8534' -.-J 7" X 5" HMC LNR HGR, ID = 4.370" I 0 8544' I-I 5" X 4-1/2" XO, ID = 3.930" I 4-1/2" TBG, 12.6 #, 13 -C R VA MTOP, --I 8525' .0152 bpf, ID = 3.958" 7" CSG, 26 #, L -80 BTC-M .0383 bpf, ID = 6.276" I 8689' I t l i I lli i If I PBTD I 11279' ∎*4,1 I4 -1/2" LNR, 12.64, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" I 11363' DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/19/82 ORIGINAL COMPLETION i WELL: 06 -19A 05/06/96 LAST WORKOVER PERMIT No: r 2081020 07/15/08 N7ES SIDETRACK (06 -19A) API No: 50- 029 - 20791 -01 -00 08/05/08 LJH/PJC GLV C/O (07/22/08) SEC 2, T1 ON, R14E, 231' FSL & 910' FEL 04/02/10 JR/JMD DRLG DRAFT CORRECTIONS 11/15/11 CJS /PJC ADPERFS (11/08/11) a BP Exploration (Alaska) TE OF ALASKA • ALASKA OIL AND CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ b 208 -1020 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 '' 50- 029 - 20791 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028311 r PBU 06 -19A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11363 feet Plugs (measured) None feet true vertical 9035.05 feet Junk (measured) None feet Effective Depth measured 11279 feet Packer (measured) 4849 8406 8512 feet true vertical 9037.12 feet (true vertical) 4849 8292 8395 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 2485' 13 -3/8" 72# L -80 29 - 2514 29 - 2514 4930 2670 Intermediate 4977' 9 -5/8" 47# L -80 28 - 5005 28 - 5005 6870 4760 Production 8662' 7" 26# L -80 27 - 8689 27 - 8566 7240 5410 Liner 2851' 4 -1/2" 12.6# 13CR80 8512 - 11363 8395 - 9035 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ - tf _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 24 - 8525 24 - 8408 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Top Packer 4849 4849 4 -1/2" Baker S -3 Perm Packer 8406 8292 5" Baker ZXP Top Packer 8512 8395 12. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): \i'l ` '''il Treatment descriptions including volumes used and final pressure: , . miSSion oam � ;�, '0 ".9' C + S 13. Reesentative DaiwiAget44644oduction or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 470 31,624 160 844 Subsequent to operation: 406 13,649 237 842 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development IO -- Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . IO Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE 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: NA Contact Joe Lastufka . Printed Na : . - Lastu l _ Title Petrotechnical Data Technologist Signatu Phone 564 -4091 Date 11/30/2011 pB /L.2. /( .0 /i?l/� Form 10-404 Revised 10 /2DMS DEC 0 1 2011 Submit Original Only 06 -19A 208 -102 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 06 -19A 7/14/08 PER 10,250. 10,380. 9,033.63 9,036.87 06 -19A 7/14/08 PER 10,420. 10,620. 9,037.38 9,039.18 06 -19A 7/14/08 PER 10,780. 10,930. 9,039.69 9,044.47 06 -19A 7/14/08 PER 10,980. 11,270. 9,044.07 9,037.33 06 -19A 11/6/11 APF 11,210. 11,230. 9,038.77 9,038.31 06 -19A 11/6/11 APF 11,230. 11,260. 9,038.31 9,037.57 06 -19A 11/8/11 APF 10,790. 10,820. 9,040.2 9,041.85 06 -19A 11/8/11 APF 11,190. 11,210. 9,039.19 9,038.77 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED • MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • • 06 -19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/6/2011 CTU #8 w/ 1.75" CT (CTV =32.2 bbls) jObjective: Reperforate 120' w/ larger guns (first use of NOVA charges) { POOH w /logging tools, + 1.5' correction. RD logging string, MU & RIH w /1st 30' x 3 =3/8" Nova gun assembly. Perforate on bottom at 11230-260', POH. MU gun #2 (20'). RIH, Perf 20' w/3 3/8" Nova guns from 11210- 11230' 6 -SPF. POOH. « «JOB IN PROGRESS »» 11/7/2011;CTU #8 w/ 1.75" CT (CTV =31.9 bbls) Objective: Reperforate 120' w/ larger guns (first use of NOVA charges) SCMT log for =future side track info. #2 guns fired, RD. Cut 100' of coil, MU new MHA & SWS memory GR/SCMT /CCL 'logging tools. RIH. Log from 11220 - 8400'. POH. LD SCMT. Good data from log, +4.5' correction, MU #3 gun, 20' x 3 3/8 ", RIH. ;Notified AOGCC of upcoming weekly BOPE test @ 0810 hrs 11/7/11. Chuck Scheve responded at -1030 hrs 11/7/11 and waived the States right to witness « «JOB IN PROGRESS »» 11/8/2011 CTU #8 w/ 1.75" CT (CTV =31.9 bbls) ':Objective: Reperforate 120' w/ larger guns (first use of NOVA charges) SCMT log for 'future side track info. RIH w / #3 gun & perf from 11190' - 11210', 6 SPF x 3 3/8" Nova. POOH w /gun assembly -ASF. RIH w/ 3 -3/8" gun #4 (30'). Perforate 10790 - 10820' w/ 3 -3/8" guns © 6 spf. POH. FP wellbore w/ 32 bbls McOH. RD spent guns, prep for WEEKLY =BOP test. » >IN PROGRESS »> 11 /9/2011; CT -8 1 3/4" Scope of work: Ad -Perfs & Log 'Cont. w /BOP test & complete RD. Well FP with 60/40, Informed DSO. MOL ' « <JOB COMPLETED »> FLUIDS PUMPED BBLS 335 60/40 METH 335 TOTAL TREE _ CIW WELLHEAD = BAKER C 6 O SAFETY NOTES: * ** ANGLE> 70° @ 9310 "'* ACTUATOR = A KER ***4 - 1/2" CHROM E* TBG & NIPPLES** *ORIG WELL NOT KB. ELEV = 74' SHOWN BELOW WHIPSTOCK*** BF. ELEV =- ? 1 - 1 KOP= 5000' Max Angle = 95° @ 10000' I 2198' I I4 -1/2" HES X NIP, ID = 3.813" 1 Datum MD = 9051' Datum TV D = 8800' SS 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I—I 2514' I---A ST MD _ GAS LIFT MANDRELS TV D DEV TYPE VLV LATCH PORT DATE 4 3476 3476 0 KBG2 DOME BK 16 07/22/08 3 5686 5677 17 KBG2 SO BK 20 07/22/08 I EST TOC I-I 4300' 2 7222 7134 12 KBG2 DMY BK 0 07/15/08 � • 4 4 1 8297 8185 11 KBG2 DMY BK 0 07/15/08 1 • • 7" LNR, 26 #, L -80 BTC-M, ---I 4847' 1 1 �4 I 4849' I — 9 -5/8" X 7" ZXP LTP w /TIEBACK SLV & BKR 0383 bpf, ID = 6.276" •l• � LNR HGR, ID = 6.21" I9 -5/8" WHIPSTOCK I 5025' 01 1 4 `� of 1 �� MILLOUT WINDOW (06 -19A) 5005' - 5021' H11 Minimum ID = 3.725" @ 8513' 4 -1/2" HES XN NIPPLE 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I 8620' 8375' 1 /2" HES X NIP, ID = 3.813" I PERFORATION SUMMARY 8406' H 7" X 4 -1/2" BKR S -3 PKR, ID = 3.870" I REF LOG: Revision After Sidetrack 14 ANGLE AT TOP PERF: 88° @ 10250' 8440' H 4 -1 /2" HES X NIP, ID = 3.813" I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 8512' — 7" X 5" HR ZXP LTP w /TIEBACK 2 -7/8" 6 10250 - 10380 0 07/15/08 SLV, ID = 4.350" 2 -7/8" 6 10420 - 10620 0 07/15/08 2 -7/8" 6 10780 10930 0 07/15/08 I, 8513' 1- I4 -1/2" HES XN NIP, ID = 3.725" I 3 -3/8" 6 10790 - 10820 0 11/08/11 2 -7/8" 6 10980 - 11270 0 07/15/08 8525' H 4 -1/2" WLEG, ID = 3.958" I 3 -3/8" 6 11190 - 11260 0 11/08/11 8534' — 17" X 5" HMC LNR HGR ID = 4.370" 8544' I-I 5" X 4 -1/2" XO, ID = 3.930" I 4 -1/2" TBG, 12.6 1/, 13 -CR VAMTOP, --I 8525' .0152 bpf, ID = 3.958" 17" CSG, 26 #, L -80 BTC-M .0383 bpf, ID = 6.276" H 8689' PBTD I 11279' q� I4 -1/2" LNR, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" I 11363' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/19/82 ORIGINAL COMPLETION WELL: 06 -19A 05/06/96 LAST WORKOVER PERMIT No: '2081020 07/15/08 N7ES SIDETRACK (06 -19A) AR No: 50- 029 - 20791 -01 -00 08/05/08 LJH/PJC GLV C/O (07/22/08) SEC 2, T10N, R14E, 231' FSL & 910' FEL 04/02/10 JR/JMD DRLG DRAFT CORRECTIONS 11/15/11 CJS /PJC ADPERFS (11/08/11) BP Exploration (Alaska) 18 -NOV -2011 2O' - t 02 SchhnkerSer 2.A 5828 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD fir C -12B BINC -00079 SCMT 3- Nov -11 1 1 P1 -20 BJGT -00071 PPROF WI DEFT & GHOST 21- Oct -11 1 1 12 -06A BX69 -00007 PRIMARY DEPTH CONTROL LOG 31- Oct -11 1 1 U -03 AWJI -00172 IPROF 4- Nov -11 1 1 • 06 -19A BCRC -00146 CEMENT BOND LOG 7- Nov -11 1 1 MPS -28 BJGT -00077 LEAK DETECTION LOG 24- Oct -11 1 1 01 -16 BCRC -00144 LEAK DETECTION LOG 5- Nov -11 1 1 18 -15B BINC -00071 PRIMARY DEPTH CONTROL LOG 17- Oct -11 1 1 14 -27 AWJI -00174 PRIMARY DEPTH CONTROL LOG 7- Nov -11 1 1 C -12B BINC -00079 PRIMARY DEPTH CONTROL LOG 3- Nov -11 1 1 Z -67 BCRJ -00098 USIT 19- Jul -11 1 1 Z -30A BJGT -00055 SBHPS 28-Jul-11 1 1 18 -03B BINC -00043 TEMPERATURE & PRESS SURVEY 26-Jun-11 1 1 13 -26 BBRJ -00018 PRIMARY DEPTH CONTROL LOG 28- Oct -11 1 1 Z -113 BG4H -00090 ISOLATION SCANNER 12- Sep -11 1 1 J -16A BYS4 -00004 PRIMARY DEPTH CONTROL LOG 13- Nov -11 1 1 14 -28A BD88 -00176 MEMORY CEMENT BOND LOG 22- Oct -11 1 1 P2 -10 AVIP -00105 REVISION PPROF W/ DEFT & GHOST 10- Sep -11 1 1 S PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 1I(.,, ' 0 1 ) AU b (6' ! i, i L, 11/01/10 3411 nbepoer NO, 5637 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPG -13 BCRJ -00038 X -FLOW CHECK/tBPSET RECORD 09115110 1 1 MPS -43 AYKP•00104 SCM7 08/26/10 1 1 P1 -09 BCRJ -00036 PRODUCTION PROFILE 09/12/10 1 W -37A BD88 -00048 MEM PRODUCTION PROFILE I c4Q 09/11110 1 W -31A AZ2F -00064 MEM PRODUCTION PROFILE 09/16/10 1 4. 06-19A AWJI -00112 MEM PRODUCTION PROFILE 09/19/10 1 1 12 -05AL1 BAUJ -00050 MEM PRODUCTION PROFILE 09/20/10 1 1 p1.16 BCRJ -00049 INJECTION PROFILE 10/06/10 1 i 04 -03 BCRD -00059 PRODUCTION PROFILE 09127110 1 1 1 P -03A AZ2F -00065 MEM INJECTION PROFILE ! 10/06/10 1 1 G -198 AWJI -00114 MEM PRODUCTION PROFI 10104110 1 1 Y -36 BD88 -00058 MEM GLS 10109110 1 1 3 -03IJ -33 BC22 -00025 PRODUCTION PROFILE 09111/10 1 1 L -214A BAUJ -00043 MEM INJECTION PROFILE — 09/13110 1 1 H -01A AWJI.00118 MEM PRODUCTION PROFILE 10/14/10 1 1 - 16 -06B BBUO -00023 PRODUCTION PROFILE BP CORRECTION 06108/10 1 1 H -38 AZ2F -00068 MEM PRODUCTION PROFILE — 10116110 1 1 P2-44 SCRD -00063 PRODUCTION PROFILE 10/15/10 1 G 1 B-1 3B AYKP -00091 CH EDIT PDC -GR (SCM7) 07/02110 (p 1 02 -228 10AKA0069 OH MWD /LWD EDIT 07107/10 2 1 W1913 BCRJ -00034 CH EDIT PDC -GR (SCM7) 09/07/10 1 1 OWDW -SE APBP03WELL RST REDO•PRINTS 09/23/10 1 OWDW -NW BBSK -00033 RST 09/24/10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 DATA SUBMITTAL COMPLIANCE REPORT 2/11/2010 Permit to Drill 2081020 Well Name/No. PRUDHOE BAY UNIT 06-19A Operator BP EXPLORATION (ALASI(ly INC API No. 50-029-20791-01-00 MD 11363 TVD 9035 Completion Date 7/15/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATAINFORMATgN Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number ~me Scale Media No Start Stop CH Received Comments C Lis -,- 17010 "InductioNResistivity 4800 11362 Open 10/10/2008 LIS Veri, GR, ROP, FET~ RPX, RPS, RPM, RPD og Induction/Resistivity 5 Blu 5021 11363 Open 10/10/2008 TVD Vision Service 12-Ju1- 2008 I~Cog Induction/Resistivity 2 Blu 5021 11363 Open 10/10/2008 MD Vision Service 12-Ju1- 2008 D Asc Directional Survey 0 11363 Open 7/18/2008 j pt Directional Survey 0 11363 Open 7/18/2008 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? / N ' Daily History Received? t Yi Chips Received? "-..-r-dT:-- Formation Tops Y / N Analysis Received? •I Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/11/2010 Permit to Drill 2081020 Well Name/No. PRUDHOE BAY UNIT 06-19A Operator BP EXPLORATION (ALASKIy INC MD 11363 TVD 9035 Completion Date 7/15/2008 Completion Status 1-01L Current Status 1-OIL Compliance Reviewed By: Date: API No. 50-029-20791-01-00 UIC N (JC~Il ~ • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 06 Dear Mr. Maunder, 1__.J ao~-~o~ off- ~q/~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 06 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-06 Date: 12/10/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 06-01 1750490 50029201720000 NA Sealed NA 06-02 1770780 50029202520000 NA Sealed NA o6-o3A 1951520 50029201860100 NA Sealed NA os-oaA 2001020 50029201790100 NA Sealed NA 06-05 1780200 50029202980000 NA Sealed NA o6-o6B 2050980 50029202010200 NA Sealed NA 06-07 1780210 50029202990000 NA Sealed NA os-osA 1951950 5oozszo3oool0o NA Sealed NA os-o9 1790730 50029204000000 NA Sealed NA o6-1oA 1981960 5oo2szoaozoloo NA Sealed NA os-11 1791100 50029204280000 NA Sealed NA 06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009 o6-13A 2061020 50029204570100 NA Sealed NA 06-148 2090120 50029204580200 NA Sealed NA 06-15 1800320 50029204590000 NA Sealed NA 06-16 1800330 50o292oasooooo NA Sealed NA 06-18A 2090630 50029207670100 NA 0.3 NA 1.70 11/5/2009 06-19A 2081020 50029207910100 NA 1.5 NA 6.80 10/4/2009 06-20A 2050790 50029207990100 NA 1 NA 5.10 10/4/2009 06-21B 2080990 50029208020200 NA 6 NA 42.50 12/14/2009 06-22A 1930570 500292oso601o0 NA 1.5 NA 5.10 10/4/2009 06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6/2009 06-24A 2000960 50029208220100 NA Sealed NA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~ u r ~1~8 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoAaczs.>>o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 7/15/2008 12. Permit to Drill Number 208-102 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/2/2008 13. API Number 50-029-20791-01-00 ' 4a. Location of Well (Governmental Section): Surface: 231' FSL 910' FEL SEC 02 T10N R E 7. Date T.D. Reached 7/12/2008 14. Well Name and Number: PBU 06-19A , , . , , 14 , UM Top of Productive Horizon: 1458' FSL, 160' FEL, SEC. 02, T10N, R14E, UM 8. KB (ft above MSL): 65.3' Ground (ft MSL): 36.9' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3046' FSL, 557' FEL, SEC. 02, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 11279' 9037' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 686081 y- 5940833 Zone- ASP4 10. Total Depth (MD+TVD) 11363' 9035' 16. Property Designation: ADL 028311 TPI: x- 686800 y- 5942077 Zone- ASP4 Total Depth: x- 686362 y- 5943655 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 5.071): DIR / GR /RES / PWD, DIR / GR /RES / NEU /DEN i,/i~y4o.S/ ~SGt~S'M~ sOpy4697'Y6 22. CASING, LINER AND CEMENTING RECORD CASING .SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER Fr. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 80' Surface 80' 30" 2150# Poleset 13-3l8" 72# L-80 Surface 2514' Surface 2514' 17-1/2" 2300 sx Fondu 400 sx PF'C' 9-5/8" 47# L-8o / S00-95 Surface 0 ' Surface 5005' 12-1/4" 500 sx Class 'G' 300 sx PF 'C' • 7" 26# L-80 24' 8689' 24' 8566' 8-1/2" 227 sx LiteCrete, 169 sx'G', 218 sx'G' 4-1/2" 12.6# 13Cr80 8512' 11363' 8395' 9035' 6-1/8" 346 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TuelNC RECORD If Yes, (ISt each Interval Open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 8525' 8406' MD TVD MD TVD ~ 0250' - 10380' 9034' - 9037 10420' - ~lb620' 9037' - 9039' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. '10780' - 10930' 9040' - 9044' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10980' - ~ ~ 270' 9044' - 9037' Freeze Protect w/ 75 Bbls of Diesel ~, 26. PRODUCTION TEST Date First Production: July 30, 2008 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date Of Test: 8/12/2008 HOUfS Tested: 6 PRODUCTION FOR TEST PERIOD OIL-BBL: 428 GAS-MCF: 3,471 WATER-BBL: 110 CHOKE SIZE: 75 GAS-OIL RATIO: 8,106 Flow Tubing Press. 332 CaSing PfeSS: 900 CALCULATED Z4-HOUR RATE• OIL-BBL: 1,713 GAS-MCF: 13,884 WATER-BBL: 440 OIL GRAVITY-API (CORR): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~OMt'I.I: f'IOC?~ None pph~ii ®I-6~ ~lj~ ~ ~ Z~~B Form 10-407 Revised 02/2007 r Ot~TINUED ON REVERSE SIDE ~fi~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu 5281' 5280' None Top HRZ 8078' 7970' Base HRZ 8260' 8149' Sag River 8692' 8569' Shublik A 8724' 8600' Shublik B 8750' 8624' Shublik C 8764' 8637' Sadlerochit 8798' 8667 Zone 4A 8950' 8792' Zone 3 /Top CGL 9062' 8872' OWC 9190' 8942' Base CGL /Top Zone 2C 9238' 8962' 23S6 /Zone 2B 9355' 9002' 22TS /Zone 2B 9694' 9033' OWC 2 (Inverted) 9922' 9038' 22N (Revert) 10633' 9039' Zone 2A 10775' 9039' Formation at Total Depth (Name): Zone 2A 10775' 9039' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ng is true and correct to the best of my knowledge. 08~ Si d ~ ~~ 8 gne Title Drilling Technologist Date l ' Terrie Hubble PBU 06-19A 208-102 Prepared By Name/Number. Te-rie Hubble, 564-4628 Well Number Drilling Engineer: Jovy Roach, 564-4352 Permit No. / A royal No. INSTRUCTIONS GeweaA~: 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top. and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 06-19 Common Name: 06-19 __ Test Date Test Type Test Depth (TMD) Test Depth (TVI]) AMW Surface Pressure Leak Off Pressure (BHP) EMW 7/1/2008 LOT 5,021.0 (ft) 5,021.0 (ft) 9.00 (ppg) 701 (psi) 3,048 (psi) 11.69 (ppg) 7/8/2008 FIT 8,689.0 (ft) 8,566.0 (ft) 8.40 (ppg) 935 (psi) 4,673 (psi) 10.50 (ppg) Printed: 8/13/2008 9:26:44 AM BP EXPLORATION Page 1 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABORS 7ES Rig Number: Date ~ From - To Hours Task j Code ~ NPT Phase Description of Operations 6/26/2008 18:00 - 19:00 1.00 MOB P PRE Release rig from 2008 summer maintenence at 18:00 hrs. Hook up trucks to pit module, truck shop, Iliamna camp. 19:00 - 20:00 1.00 MOB N WAIT PRE Wait on security for rig move. 20:00 - 00:00 4.00 MOB P PRE Move pit module, truck shop, and Ilimna camp from B-Pad to DS-06. Spot camp & Truck shop. Stage pit module to side of pad awaiting substructure arrival. 6/27/2008 00:00 - 09:00 9.00 MOB P PRE Move rig substructure from B-Pad to DS-06. Lay rig mats as needed on DS-06 corners and on 06-19 wellsite where gravel was added. 09:00 - 11:00 2.00 MOB P PRE Lay out herculite and spot rig sub unit over wellhead. 11:00 - 13:00 2.00 MOB P PRE Lay mats for pit module. Spot pit module in position. 13:00 - 14:00 1.00 MOB P PRE Remove any unnecessary mats from under rig. 14:00 - 18:00 4.00 MOB P PRE Raise Derrick. Rig down bridle lines. Rig up topdrive. Connect lines in interconnect. 18:00 - 00:00 6.00 MOB P PRE Replace line guide pads on drawworks. Function top drive. Make up saver sub and lower IBOP. Adjust RPM proximity switch. Torque washpipe to 4,500 ft-Ibs. 6/28/2008 00:00 - 04:00 4.00 DHB P DECOMP Continue adjustments on topdrive. MU lines to OA and IA for pressure testing of barriers. Note: Accept rig at 00:00 hrs on 6/28/2008. Adjusted accept time to accomodate topdrive adjustments that were impossible until derrick raised. 04:00 - 07:00 3.00 DHB P DECOMP Pressure test OA to 2000 psi for 30 minutes -Passed. Bled down 110 psi in first 15 minutes and 40 psi in second 15 minutes. Perform CMIT - TxIA to 3,500 psi for 30 minutes - Passed. Bleed down pressure and blow down all lines. 07:00 - 10:30 3.50 WHSUR P DECOMP Nipple down existing 7" tree. 10:30 - 13:30 3.00 BOPSU P DECOMP Nipple up BOPE 13:30 - 14:30 1.00 BOPSU P DECOMP Install test joint. Rig up for testing BOPE. 14:30 - 19:30 5.00 BOPSU P DECOMP Test BOPE to 250 psi low and 3500 psi high pressure using 4" and 4.5" test joints. Lower ram test postponed to after pulling 4.5" tubing -tubing hanger and plugs extend too high to close lower rams without interference. Chuck Scheve waived state witness of test. Test witnessed by NAD TPs L. Toussant, C. Weaver and BP WSLs D. Ferguson, M. Martyn. 19:30 - 20:00 0.50 BOPSU P DECOMP Pull test joint and rig down all BOPE testing equipment. 20:00 - 21:00 1.00 DHB P DECOMP Rig up Drill Site Maintenence with lubricator extensions. Pressure test lubricator to 1000 psi - OK. Bleed off well pressure through IA valve. 21:00 - 22:00 1.00 DHB P DECOMP Attempt to retrieve BPV. First attempt unsuccessful, change out retrieval tool -bent. Successful retreival on second attempt. 22:00 - 22:30 0.50 KILL P DECOMP Rig down DSM lubricator. Line up to circulate out freeze protect. 22:30 - 23:15 0.75 KILL P DECOMP Reverse circulate diesel cap off of tubing ~ up to 5 bpm taking returns to tiger tank. 34 bbls diesel recovered from tubing side before transition to water seen. 23:15 - 00:00 0.75 KILL P DECOMP Swap lines and circulate down tubing with returns out the IA valve to tiger tank. Start 50 bbl safe-surf sweep down hole followed by hot seawater at 5 bpm, 440 psi. Recover 118 bbls diesel from IA to tiger tank before transistion to seawater returns. rnrnea: ne.vcwa ccv:oa rm ~ ~ BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABOBS 7ES Rig Number: Date I From - To I Hours I Task i Code I NPT I Phase Description of Operations 6/29/2008 00:00 - 01:30 1.50 KILL P DECOMP Continue circulating soap sweep and hot seawater surface to surface down tubing and out IA to clean up tubing prior to pulling. 5 bpm, 440 psi. 01:30 - 03:30 2.00 PULL P DECOMP Rig up landing joint and make up into tubing hanger. Back out lock down screws. Pull tubing hanger to rig floor. No overpull to unseat hanger. PU - 80k. 03:30 - 04:30 1.00 PULL P DECOMP Circulate bottoms up with clean seawater ~ 5 bpm while rigging up control line spooling equipment. 04:30 - 10:00 5.50 PULL P DECOMP POH LD 126 joints of 4.5" 12.6 # Buttress tubing, 3 GLMs, 1 SSSV Nipple and 2 stainless steel control lines w/ 56 stainless steel bands recovered. No prior records to indicate number of steel bands installed. 10:00 - 10:30 0.50 PULL P DECOMP Clean & clear rig floor of all tubing pulling equipment. 10:30 - 11:30 1.00 BOPSU P DECOMP RU to test lower BOPE rams. Install test plug on 4" test joint. Fill stack. Fluid leaking by at control line port and lock down screw glands. 11:30 - 12:30 1.00 BOPSU P DECOMP Tighten or replace lock down glands as necessary and replace control line port plugs. 12:30 - 13:30 1.00 BOPSU P DECOMP Test lower rams w/4" test jt. to complete BOP test 250 psi/3500 psi low/high pressure. 13:30 - 14:00 0.50 WHSUR P DECOMP Install wear bushing. 14:00 - 14:30 0.50 CLEAN P DECOMP MU BHA #1 - 8.5" MXL-1 bit, 9-5/8" casing scraper, tea Boot Baskets, Float sub, XO to HWDP. 14:30 - 19:30 5.00 CLEAN P DECOMP PU 4" HWDP and 4" HT40 drill pipe 1X1 and RIH. 19:30 - 20:30 1.00 CLEAN P DECOMP Tag up on 4.5" tubing stub at 5,203' md. PU - 115k, SO - 112k. Circulate 1.5 bottoms up ~ 550 gpm, 1680 psi. No debris seen in returns. 20:30 - 22:30 2.00 CLEAN P DECOMP Shut down, monitor well -static. 8.5ppg in and out. POH standing back DP &HWDP to 20'. 22:30 - 23:30 1.00 CLEAN P DECOMP Lay down bit & scraper BHA #1 -one cup of scale and sand debris recovered from boot baskets. 23:30 - 00:00 0.50 DHB P DECOMP Begin RU E-Line for EZSV run. 6/30/2008 00:00 - 00:30 0.50 DHB P DECOMP Continue RU for E-Line EZSV setting run. 00:30 - 03:15 2.75 DHB P DECOMP RIH on E-Line w/ Gamma Ray, Collar Locator, Casing Packer Setting Tool, HES 9-5/8" EZSV Plug. Tag up softly on top of tubing stump at 5,309' E-Line md. Log up and see collar depth at 5,038' md. Correlate and pull into position. Set EZSV at 5,033' E-Line and ~ center element. POH logging to 200' md. 03:15 - 03:30 0.25 DHB P DECOMP Begin RD E-Line and close blinds. Pressure test Casing to 3,500 psi for 15 minutes -Pass. 03:30 - 04:00 0.50 DHB P DECOMP Rig down E-Line loggers. 04:00 - 04:30 0.50 WHSUR P DECOMP Pull wear bushing. 04:30 - 06:30 2.00 WHSUR P DECOMP Verify zero pressure on OA. OA has been left open to bleed tank without flow. Back out lock down screws. Pull existing 9-5/8" Packoff without any trouble. Install new packoff element - sucessful seat on second attempt. Run in lock down screws. 06:30 - 07:45 1.25 BOPSU P DECOMP Nipple down BOP stack and stand back on stump. 07:45 - 08:15 0.50 WHSUR P DECOMP Nipple down existing tubing spool. 08:15 - 09:15 1.00 WHSUR P DECOMP Nipple up replacement FMC Gen 3 Casing Spool. Remove 2nd annulus valve and replace w/ VR plug & blind flange. 09:15 - 09:30 0.25 WHSUR P DECOMP Pressure test void to 5000 psi for 30 minutes -good test. 09:30 - 11:30 2.00 BOPSU P DECOMP Nipple up BOP stack. 11:30 - 12:30 1.00 BOPSU P DECOMP Install test plug and test broken connection to 250 psi low and Printetl: 7/23/2008 2:24:59 PM BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To ~ Hours ~' Task Code NPT ii Phase Description of Operations 6/30/2008 11:30 - 12:30 1.00 BOPSU P DECOMP 3500 psi high pressure. Pull test plug and install wear ring. 12:30 - 16:45 4.25 STWHIP P WEXIT PJSM w/Baker and PU BHA #2 - 9-5/8" whipstock, Starter mill, String Mill, Orienting sub, 5" HWDP, bumper sub, Sea steel DC. Orient UBHO sub key w/whipstock face. 16:45 - 17:30 0.75 STWHIP P WEXIT RU Gyrodata w/ Sperry E-Line unit. Hang sheave and make up toolstring. 17:30 - 19:30 2.00 STWHIP P WEXIT RIH w/whipstock on 4" HT40 drill pipe at 1 stand/min, f/359'to 3,090'. Fill pipe 19:30 - 20:00 0.50 STWHIP P WEXIT Service topdrive. 20:00 - 21:30 1.50 STWHIP N RREP WEXIT Change out washpipe on topdrive. 21:30 - 22:30 1.00 STWHIP P WEXIT RIH w/ whipstock on 4" DP from 3,090' - 5,003' md. 22:30 - 00:00 1.50 STWHIP P WEXIT Fill pipe and circulate 95 bbls ~ 357 gpm, 820 psi. Prepare for gyro run. 7/1/2008 00:00 - 01:30 1.50 STWHIP P WEXIT RIH w/Gyrodata logging tool and tag up on UBHO profile key. Orient whipstock face. 1st survey 345 deg. Rotate 130 deg right -second survey at 98 deg. Work torque to tools -survey several times ~ 118 deg. deg. Pull out of UBHO sub and POH. 01:30 - 01:45 0.25 STWHIP P WEXIT RIH w/whipstock ~ 118 deg and tag up on EZSV at 5,027' md. PU 125K, SO 125K. Slackoff on tools and see whipstock anchor set w/clear surface indication. Pick up and pull 10K over string wt to verify that anchor is set. SO slowly and w/ 35k Slackoff on tools see the brass bolt shear w/clear indication at surface. Slackoff 50k on tools. PU slowly w/no overpull. Whi stock oriented and set w/mills free from shear bolt. c L Jr 01:45 - 02:30 0.75 STWHIP P WEXIT Displace well f/ 8.5 ppg seawater to 9.0 ppg LSND milling fluid. p __ 02:30 - 06:30 4.00 STWHIP P WEXIT Begin milling w/ top of Whipstock slide at 5,005' md. BOW ~ ~~~ l ~ 11 5021'md. -350 gpm, 720 psi, -100 rpm / 3kWlbsTorque 06:30 - 07:30 1.00 STWHIP P WEXIT Mill extra hole to 5037' for LOT 07:30 - 08:30 1.00 STWHIP P WEXIT Pump High Vis Super Sweep -500 gpm / 1073 psi -Sweep Increase in cuttings 10-15% 08:30 - 09:30 1.00 STWHIP P WEXIT Perform Leak Off Test -5021' and /5021' tvd -Fluid pump 2.2 bbls, volume back 1 bbl 09:30 - 10:00 0.50 STWHIP P WEXIT CBU -500 gpm / 1070 psi -Monitor well, static 9.0 ppg mud wt in/out 10:00 - 13:00 3.00 STWHIP P WEXIT POH to Milling assembly 13:00 - 13:30 0.50 STWHIP P WEXIT Lay Down window mills and equipment -Top stab. Full gauge 13:30 - 14:15 0.75 STWHIP P WEXIT Jet BOP stack with wash tool -Function BOP Rams 14:15 - 17:45 3.50 DRILL P INTi P/U BHA and orient MWD, UBHO and Motor -Surface test MWD Equip ~ 812', -550 gpm / 935 psi, Good Test 17:45 - 21:30 3.75 DRILL P INT1 RIH -Pick up 111 jts. 1x1 -RIH with stands to 4835' rnrnea: nzsrmu° czv:oa rm BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 7/1/2008 21:30 - 22:15 0.75 DRILL P INTi Slip and cut drilling line 22:15 - 23:15 1.00 DRILL P INT1 Perform Tie-in log with MWD from 4860 -5000' and -Log at 330'/hr -435 gpm / 1100 psi 23:15 - 23:30 0.25 DRILL P INT1 Perform baseline ECD readings -498 psi / 1358 psi -Cal ECD = 9.5 ppg PUW = 120k /SOW = 120k / RtWt = 117k Perform SPR's 23:30 - 00:00 0.50 DRILL P INT1 Run Gyro Survey 7/2/2008 00:00 - 12:00 12.00 DRILL P INT1 Directional Drill 8 1/2" Intermediate hole 5033 -5433 (5424 tvd) -Orient with ro surve tool, G ro to 5408' and - WOB = 10-18k -545 gpm / 1630 psi off / 1800 psi on -80 rpm 3k ft/Ibs Torque off btm. / 5k ft/Ibs Torque on btm. PUW = 130k /SOW = 120k / RtWt = 125k CECD = 9.41 /AECD = 9.61 ART = 0.65 hrs / AST = 3.07 hrs Total hrs on bit = 3.72 hrs 12:00 - 00:00 12.00 DRILL P INT1 Directional Drill 8 1/2" Intermediate hole 5433-6080 (6050' tvd) - WOB = 10-15k -550 gpm / 1890 psi off / 2230 psi on -80 rpm 2k ft/Ibs Torque off btm. / 5k ft/Ibs Torque on btm. PUW = 138k /SOW = 130k / RtWt = 132k CECD = 9.47 /AECD = 9.81 ART = 1.07 hrs / AST = 7.50 hrs Total hrs on bit = 12.25 hrs 7/3/2008 00:00 - 12:00 12.00 DRILL P INT1 Directional Drill 8 1/2" Intermediate hole 6080- 7480'md -WOB = 10-15k -550 gpm / 2350 psi off / 2640 psi on -80 rpm 3k ft/Ibs Torque off btm. / 7k fUlbs Torque on btm. PUW = 155k /SOW = 140k / RtWt = 150k CECD = 9.58 /AECD = 10.18 ART = 6.17 hrs / AST = 2.22 hrs Total hrs on bit = 20.65 hrs 12:00 - 15:30 3.50 DRILL P INT1 Directional Drill 8 1/2" Intermediate hole 7480 - 7703' and -WOB = 15-18k -550 gpm / 2430 psi off / 2840 psi on -80 rpm 3k ft/Ibs Torque off btm. / 7k ft/Ibs Torque on btm. NOTE: Sliding and steering was very difficult compared to previous runs with this bit design. The bit seemed to have a very steep torque-to-WOB relationship. Sliding had to be done with roughly a third the normal differential pressure and WOB. The motor and bit stalled and became unable to steer with more than 100psi differential pressure. 15:30 - 16:00 0.50 DRILL P INTi Service Wash pipe and add oil to Top Drive 16:00 - 00:00 8.00 DRILL P INTi Directional Drill 8 1/2" Intermediate hole 7703 - 8200'md (8091' tvd) Weight up to 10.0 ppg ~ 7800' and -WOB = 15-18k -500 gpm / 2230 psi off / 2460 psi on -100 rpm 3k ft/Ibs Torque off btm. / 7k fUlbs Torque on btm. PUW = 170k /SOW = 150k / RtWt = 155k CECD = 10.44 /AECD = 10.78 ART = 2.38 hrs / AST = 5.48 hrs Total hrs on bit = 28.50 hrs Printetl: 7/23/2008 224:59 PM BP EXPLORATION Operations Summary Report Legal Well Name: 06-19 Page 5 of 15 ~ Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABORS 7ES Rig Number: Date !I From - To Hours I! Task Code; NPT Phase Description of Operations 7/3/2008 16:00 - 00:00 8.00 DRILL P INTi NOTE: The "stringer-strategy" was utilized throughout the run to preserve the PCD bit. The rotary was slowed to less than 80rpm and the WOB was maintained above 10k while drilling all hard formations. No very hard stringers were encountered. 7/4/2008 00:00 - 02:00 2.00 DRILL P INT1 Directional Drill 8 1/2" Intermediate hole 8200' - 8295' and -WOB = 15-18k -500 gpm / 2230 psi off / 2460 psi on -100 rpm 3k fUlbs Torque off btm. / 7k fUlbs Torque on btm. Mud Cut coming out to 9.6 ppg and bubbling 10.0 ppg MW in /Out with pressurize scale 02:00 - 03:00 1.00 DRILL P INTi Monitor Well for 10 min, Gas cut but not flowing -Mud wt out with pressure scale = 10.0 ppg -Mud wt with non-pressurize = 9.5 ppg -CBU, gas cut mud decreasing -Mud returns down to 9.7 on non-pressurize scale -10.0 ppg MW in /Out with pressurize scale -Monitor well, static 03:00 - 12:30 9.50 DRILL P INTi Directional Drill 8 1/2" Intermediate hole 8295' - 8690'md (8561 Weight up to 10.2 do to increasing Splintered Shale returns -WOB = 7-15k -500 gpm / 2570 psi off / 2710 psi on -80 rpm 3k fUlbs Torque off btm. / 7k ft/Ibs Torque on btm. -PUW = 185k /SOW = 155k / RtWt = 168k -CECD = 10.50 / AECD = 10.72 -AST =5.98 hrs /ART = 2.05 hrs / ADT = 8.03 hrs -Total time on bit = 36.52 hrs NOTE: Sliding and steering was very difficult compared to previous runs with this bit design. The bit seemed to have a very steep torque-to-WOB relationship. Sliding had to be done with roughly a third the normal differential pressure and WOB. The motor and bit stalled and became unable to steer with more than 100psi differential pressure. 12:30 - 16:30 4.00 DRILL P INT1 Circulate up sample for Geologist and confirm casing point -Increase in splintery Kingak shale was observed with bottoms up, -MW raised to 10.4 ppg -500 gpm / 2630 psi -80 rpm / 5k Torque Circulated Hole clean Monitor well, Static 10.4 In /Out 16:30 - 19:30 3.00 DRILL P INTi Trip out to Shoe without problems 19:30 - 20:00 0.50 DRILL P INT1 Service Top Drive, Draw Works and Crown 20:00 - 22:00 2.00 DRILL P INT1 RIH without problems till 8570' -At 8570 (120' off btm) stack 30k, attempt to work through twice without success -Kelly up and wash through 8570 to 8690 without problems, -No Fill on bottom 22:00 - 00:00 2.00 DRILL P INT1 Pump 30 bbls Hi-Vis sweep and circulate hole clean -500 gpm / 2650 psi / 80 rpm / 5k Torque Printed: 7/23/2008 2:24:59 PM BP EXPLORATION Page 6 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 7/4/2008 22:00 - 00:00 2.00 DRILL P INT1 -50% increase in splintery shale on bottoms up -After sweep cuttings was reduced to 10-20 % of previous amount on shakers -Circulate a total of two circulations, shakers clean 7/5/2008 00:00 - 00:30 0.50 DRILL P INT1 Finish Circulating hole clean -500 gpm / 2650 -Shakers cleaned up with small amount of splintery shale cuttings Monitor Well, Static / 10.4 ppg In /Out 00:30 - 05:30 5.00 DRILL P INT1 POH to 4" HWDP -No Problems Pulling in open hole, -Hole taking proper fill 05:30 - 06:00 0.50 DRILL P INTi Lay Down HWDP & BHA 06:00 - 07:30 1.50 CASE P LNR1 Change top rams to 7" -Pull Wear bushing and set test plug 07:30 - 09:00 1.50 CASE P LNRi Test Rams to 250 low and 3500 si hi h - es wi test joint -Each test held for 5 minutes and chart recorded -Test witness BP WSL Duncan Ferguson and NAD Toolpusher Larry Wurdeman 09:00 - 09:30 0.50 CASE P LNR1 R/U to Run 7" -Rig up Power tongs ,elevators and slips -Make Up Safety valve and crossover -PJSM with NAD casing, NAD Rig Crew, NAD TP and BP WSL 09:30 - 15:30 6.00 CASE P LNR1 Run a total of 94'oints 7" 26# L-80 BTC-M -Baker-lok first 3 joints -Best-O-Life 2000 NM thread dope -Avg Make up = 8500 ft/Ibs -77 Straight bladed 8.25" centrailizers ran 15:30 - 17:30 2.00 CASE P LNR1 Make u Baker HMC Liner han er and ZXP liner top Packer -Pick up 1 stand 4" DP. -Establish circulation and circulate 1 1/2 liner volumes -50 gpm / 243 psi 17:30 - 23:00 5.50 CASE P LNR1 RIH to on 4" Drill pipe to Top of Window -Circulate ~ 247 gpm / 482 psi -RIH liner on 4" drill pipe to TD at 8689' -filling pipe every 5 stands except across HRZ -Precautionary wash to btm ~ 2bpm 8570 -8664' 23:00 - 23:30 0.50 CASE P LNR1 Make Cement Head and wash to bottom ~ 2bpm -Tag Bottom and pull off bottom to 8689' 23:30 - 00:00 0.50 CASE P LNR1 Circulate staging pumps up slowly to 5 BPM -5 bpm / 690 psi -no mud loss observed breaking circulation 7/6/2008 00:00 - 01:30 1.50 CASE P LNR1 Finish circulating bottoms up -Shakers cleaned up, small amount of splinter shale cuttings on bottoms up PJSM with Schlumberger cementers, NAD rig crew, NAD TP and BP WSL 01:30 - 04:00 2.50 CEMT P LNR1 Cement 7" Liner -Pump 5 bbl water to fill lines to "Tee" on floor, -pressure test lines to 4500 psi -30 bbl MudPush II at 11.0 ppg Printed: 7/23/2008 2:24:59 PM • BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code ~ NPT ~; Phase Description of Operations 7/6/2008 01:30 - 04:00 2.50 CEMT P LNRi -Pump Lead slurry 100 bbl (230 sx) LiteCRETE at 12.0 ppg (~ 5 bpm -35 bbl (168 sx) class 'G' tail cement at 15.8 ppg ~ 5 bpm -Drop pipe wiper dart, pump out dart -Clean out pump and lines with 5 bbls of water -Switch to rig pumps, displace with rig pumps using 10.4 ppg LSND mud @ 5 bpm -Latch up on schedule, and bump plug ~ 03:15 hrs with 3235 sks, pressure up to 2800 psi and set Han er - ressured on up to 4350 psi to release from liner ee pressure to zero an c eck floats, O.K. 04:00 - 04:30 0.50 CEMT P LNR1 -Rig Down Cement line and line up to rig pumps -Pressure up to 500 psi and pull out of PBR, -bring pumps up to 500 gpm / 1250 psi and pump 50 bbls -slowed pumps down to 2 bpm and start rotating at 20 rpm and sat down to set Packer, Sat 75k down 04:30 - 05:30 1.00 CEMT P LNR1 Displace Cement and Mud Push from hole -Pump ~ 500 gpm / 1250 psi -Mud containment ~ 211 bbls, Dumo 85 bbls of cement containment mud -Highest ph -reading of 11.0 ph -Cement and mud push blended together with no clean cement break -Cement residue left on shaker screens 05:30 - 07:00 1.50 CASE P LNRi POH with running tool -No cement left on tool 07:00 - 09:30 2.50 CASE P TIE61 Rig Up to Run 7" TCII Tie-back -Change to long bai s, -R/U Power Tongs, elevators and slips PJSM with NAD Casing, NAD rig crew and TP, BP WSL 09:30 - 15:30 6.00 CASE P TIE61 Pick up and run 7" 26#, L 80, TC II tie-back liner - Baker Tie Back Stem, from mule shoe to no-go. -0.92' No-go collar. -7" BTC-M pup joint. -7" BTC-M joint 26# L-80 liner -7" Halliburton Float Collar with 3/8" orifice. -BTC-M pin x TC-II box XO pup with Halliburton float collar on pin end. -119 total joints 7" TC-II liner to surface. - With a 9.79' and 14.76' 7" TC-II space out-pup joints. -Place a centralizer on joints 1 to 41 to cover up to 3200' from surface (TOC). -Baker Lock all connections from Tie Back Seal stem, 1 jt full joint, Float collar and XO pup -Jet Lube Seal Guard on all premium connections. -Avg make-up torque 10,000 tt/Ibs Ran to 4788' shut down to repair Hydraulic Fitting 15:30 - 16:00 0.50 CASE N RREP TIEB1 Repair Hydraulic leak on Laydown Machine 16:00 - 17:00 1.00 CASE P TIEB1 Run casing and tag No-Go ~ 4848'md -R/U Cement head 17:00 - 21:00 4.00 CEMT P TIE61 -Break circulation and hold Pre-Job with Schlumberger cementers, Little Red, Baker Tools, NAD Rig Crew and rnnteo: uzs¢uun cza:oa rm ~ ~ BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABORS 7ES Rig Number: Date From - To Hours ~ Task Code' NPT ~~~ Phase Description of Operations I 7/6/2008 17:00 - 21:00 4.00 CEMT P TIE61 BP-WSL -Pump 40 bbl 12.0 ppg high vis LSND mud spacer treated with red dye with rig pumps -Rig up Schlumberger cementers and pressure test cementing line to 4000 psi with 5 bbl fresh water. -Switch over to Little Red Hot Oil unit to cement line and pump 100 bbls of 65 de re ,Pump at 5 bpm ICP =- 350 psi /FCP = 1100 psi -Switch over to Schlumberger. Release bottom plug on top of the diesel. -Release top plug and pump out 5 bbl water with cementing unit, -Switch over to rig pumps and displace with 180 bbl mud, Bump plug at 3100 strokes increase pressure to 1000 psi 500 psi over FCP) -6.5 bbls of clean diesel back to surface_ Lowered stem assembly into the PBR, -Check for flow. -Seal stem. With 30k down on No-Go 21:00 - 21:30 0.50 CEMT P TIEBi Rig Down Cement and casing running equipment 21:30 - 22:30 1.00 BOPSU P TIEB1 Nipple Down stack and raise BOP's to set emergency slips on 7" casing Install Slips with 75,000 down weight 22:30 - 00:00 1.50 WHSUR P TIE61 Rig Up and cut 7" casing with Wachs Tool 7/7/2008 00:00 - 01:30 1.50 WHSUR P TIEB1 Install new 13 5/8" x 13 5/8" Tubing Spool with 7" secondary pack-off. -Test pack-off to 4,000 psi for 30 minutes 01:30 - 07:30 6.00 BOPSU P TIEB1 Nipple up BOP's -Flush Residual Cement from Stack with Jetting tool -Change top rams to 3.5" X 6" VBR 07:30 - 10:30 3.00 BOPSU P TIEB1 PJSM with Rig Crew on testing BOP's Test BOP's to 250 Low and 3500 si Hi h -Witness of Test waived by AOGCC rep Bob Noble, test witnessed by BP WSL Duncan Ferguson, NAD Toolpusher Larry Wurdeman Test using 4" test joint Test to 250 psi low and 3500 psi high, each test held for 5 minutes and charted #1 Test -Top Pipe 3 1/2" x 6" Var.Rams, Choke Valves 1,2,3,16, HCR Kill valve, Upper IBOP #2 Test -Choke Valves 4,5,6, Manual Kill valve, TIW, Manual IBOP #3 Test -Choke Valves 7,8 & 9 #4 Test -Test Super Choke and Manual Choke to 250 psi low, 3500 high #5 Test -Choke Valves 10, 11 and 15 #6 Test -Choke Valve #14 #7 Test -Manual Valve on BOP stack and Annular #8 Test -Choke Line HCR Valve on Stack #9 Test -Bottom 2 7/8" x 5" Var. Pipe Rams #10 Test -Blind Pipe Rams, Choke Valves 12 &13 Test using 4 1/2" test joint Pflntetl: 7/L3/LUUB 2:24:~y PM ~ ~ BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABORS 7ES Rig Number: Date 'From - To Hours Task Code NPT II, Phase Description of Operations 7/7/2008 107:30 - 10:30 3.001 BOPSUF~ P TIEBi Top Rams and Bottom Rams Accumulator Test No Failures, Good Test Tested 7" Tieback to 3500 psi for 10 min, Good Test _ 10:30 - 11:00 0.50 BOPSU~P 11:00 - 12:30 1.50 DRILL P 12:30 - 15:30 3.00 DRILL P 15:30 - 17:00 1.50 DRILL P 17:00 - 18:30 1.50 DRILL P 18:30 - 20:00 1.50 DRILL P 20:00 - 20:30 0.50 DRILL P 20:30 - 22:30 2.00 DRILL P 22:30 - 00:00 I 1.501 DRILL I P 7/8/2008 00:00 - 00:30 0.50 DRILL P 00:30 - 01:30 1.00 DRILL P 01:30 - 02:30 1.00 DRILL P 02:30 - 04:30 2.00 ~ DRILL ~ P TIEB1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 04:30 - 07:00 2.50 DRILL N SFAL PROD1 07:00 - 12:00 5.00 DRILL P PROD1 12:00 - 18:00 6.001 DRILL I P PROD1 -Install wear bushing Make up BHA 6 1/8" Rock Insert Bit, PDM Set ~ 1.83 bend, NM Stab,Short Flex NMDC, MWD/LWD, X0,3 x NM Flex DC's, CCV, NM Short DC, Jar, HWDP, DP Shallow hole test MWD, O.K. RIH Picking Up DP 1x1 to 3402' RIH to 4785' Drill Tie-back Float Equipment and Wiper Plugs 4785 - 4848' RIH to 8559' Chart record test, Good Test Slip and cut drill line -Service TDS Drill Float Equipment and cement to 8679' -5k WOB -225 gpm / 1693 psi -4k torque ~ 35 rpm -175k PUW / 140k SOW / 150k RtWt Tag Float equipment on depth Displace 10.4 LSND mud with 8.4 ppg Flo-Pro -Pump 150 bbls of fresh water -50 bbl Hi-Vis Pill -Chase with new Flo-Pro -237 gpm / 1230 psi Finish Displacing to 8.4 ppg Flo-Pro Drill Float Shoe and 20' of New Hole Perform Fit to 10.5 ooa EMW -8.4 ppg MW / 8566' tvd / 935 psi -Held Pressure for 10 min with pressure bleeding down from 940 - 905psi -Good Test Directional Drill 6 1/8" Production hole -243 gpm 1450 off btm / 1540 on bottom -15-18k WOB -100% Slide Mad Pass log and Tie-in Log -Anadrill MWD unable to Depth Track -Trouble shoot Issue Directional Drill 6 1/8" Production hole 8750 -9005md -243 gpm 1450 off btm / 1540 on bottom -15-25k WOB -250 gpm / 1730 psi - on / 1520 psi - off PUW = 172k /SOW= 152k / RtWt = 157k ADT=5.3 hrs/AST=3.4 hrs/ART= 1.9 hrs Still having problems MWD Depth Tracking Directional Drill 6 1/8" Production hole 9005 - 9209' Drill Conglomerate in Zone 3 difficult, numerous motor stalls rnntea: irz~izuun zz4:°a rm • A BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABORS 7ES Rig Number: Date From - To Hours ~ Task Code NPT i Phase Description of Operations - 7/8/2008 12:00 - 18:00 6.00 DRILL P -- _- PROD1 - -243 gpm 1570 off btm / 1660 on bottom -12-25k WOB -250 gpm / 1730 psi - on / 1520 psi - off 18:00 - 20:30 2.50 DRILL N SFAL PRODi Trouble Shoot MWD depth tracking problems -MWD surface unit or sensors unable to stay on depth, switch from Anadrill depth recorder to Rig Epoch system for depth tracking until depth tracking unit replaced. Depth Tracking working now. 20:30 - 22:00 1.50 DRILL P PROD1 Directional Drill 6 1/8" Production hole 9209 - 9390'md (9010 tvd) End of Build section -15-25k WOB -250 gpm / 1730 psi - on / 1520 psi - off -30 rpm 3k torque off / 5k torque on -PUW = 180k /SOW= 150k / RtWt = 157k -ADT = 4.92 hrs / AST = 3.92 hrs /ART = 1.0 hrs -Total Time on bit = 8.84 hrs 22:00 - 22:30 0.50 DRILL P PROD1 CBU -monitor well, static 8.4 ppg In/Out 22:30 - 23:30 1.00 DRILL P PROD1 Pump out to shoe -242 gpm 1440 psi -No issues pulling to shoe 23:30 - 00:00 0.50 DRILL P PROD1 Open CCV and Pump Dry Job 7/9/2008 00:00 - 03:00 3.00 DRILL P PROD1 POH to BHA 03:00 - 04:30 1.50 DRILL P PROD1 Set Back Jars & DC's L/D MWD, Motor and Bit 04:30 - 06:30 2.00 DRILL P PROD1 Pick up BHA #5 -6 1/8" PDC, AIM PDM ~ 1.5, NM Stab, NM Short Flex DC, MWD, ADN, 3 x NM Flex Dc's, CCV, NMLC, Jars, 1 x HWDP, DP -PJSM on safe handling of RA source on surface 06:30 - 10:00 3.50 DRILL P PROD1 RIH to 9390 -Shallow Hole Test MWD tools ~ 1203', good test -No Problems RIH -Filling every 30 stands 10:00 - 11:30 1.50 DRILL P PROD1 MAD Pass Log from 9390 - 9065' and 11:30 - 12:00 0.50 DRILL P PRODi RIH To 9390' 12:00 - 00:00 12.00 DRILL P PROD1 Directional Drill 6 1/8" Production hole 9390' - 10,125' and (9025 tvd) Geo-Steer as per Geologist -10k WOB -250 gpm / 1785 psi - on / 1600 psi - off -80 rpm 3k torque off / 5k torque on -PUW = 185k /SOW= 145k / RtWt = 155k -ADT = 7.85 hrs / AST = 3.58 hrs /ART = 4.27 hrs -Total Time on bit = 7.85 hrs 7/10/2008 00:00 - 12:00 12.00 DRILL P PROD1 Directional Drill 6 1/8" Production hole 10,125' - 10,501md (9038 tvd) Geo-Steer as per Geologist -15k WOB -250 gpm / 1860 psi - on / 1620 psi - off -80 rpm 4k torque off / 7.5 k torque on -PUW = 183k /SOW= 145k / RtWt = 155k Printed: I/L;i/LUUtl 'l:'L4:~y YM ~ ~ BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations ~ - -- 7/10/2008 00:00 - 12:00 12.00 DRILL P PROD1 -ADT = 8.95 hrs /AST = 6.55 hrs /ART = 2.40 hrs -Total Time on bit = 16.79 hrs 12:00 - 16:30 4.50 DRILL P PROD1 Directional Drill 6 1/8" Production hole 10,501 - 10,624' and (9038 tvd) Geo-Steer as per Geologist -12k WOB -250 gpm / 1810 psi - on / 1620 psi - off -80 rpm 4k torque off / 7.5 k torque on -PUW = 187k /SOW= 145k / RtWt = 155k -ADT=3.18 hrs/AST=2.08 hrs/ART= 1.10 hrs -Total Time on bit = 19.97 hrs After drilling several chert stringers bit quit drilling. We was able to get weight to bit but there was little reactive torque or differental pressure. 16:30 - 17:30 1.00 DRILL P PRODi Pump nut plug sweep to see if bit was balled up. -No appreciable bit improvement from sweep -Monitor Well, Static 8.4 ppg In /Out 17:30 - 19:00 1.50 DRILL P PROD1 Backream to 10, 200' -250 gpm / 1620 psi -80 rpm 4k torque Pulled 2 stands to 10,004, No problems pulling pipe -Drop Ball to open CCV -CCV open with 2283 psi ~ 2 bpm, increase flow rate to 5 bpm / 610 psi -Pump Dry Job 19:00 - 23:30 4.50 DRILL P PROD1 POH to HWDP 23:30 - 00:00 0.50 DRILL P PROD1 Cycle CCV, 1775 psi to close -CCV not fully closed, leaking out bypass ports -Lay Down CCV 7/11/2008 00:00 - 00:30 0.50 DRILL P PROD1 POH to LWD Collar 00:30 - 01:30 1.00 DRILL P PROD1 Pull RA Source from LWD -PJSM with Anadrill MWD, DD and NAD Rig Crew 01:30 - 02:30 1.00 DRILL P PRODi Lay Down LWD /MWD, Motor and bit -Bit Rung out ,outer 20 % Damaged 02:30 - 04:30 2.00 DRILL P PROD1 Pick up new 6 1/8 Insert Rock Bit, motor and MWD/LWD -Change out LWD tool, unable to communicate with surface equipment -orient Motor &MWD -Load RA Source -Pick up CCV and Ball catcher sub 04:30 - 05:30 1.00 DRILL P PROD1 RIH to 1235' 05:30 - 06:00 0.50 DRILL P PROD1 Shallow Test MWD/LWD and Motor, Good Test 06:00 - 09:00 3.00 DRILL P PROD1 RIH -Fill every 30 stands 09:00 - 12:00 3.00 DRILL P PROD1 Directional Drill 6 1/8" Production hole 10,624'- 10,694' and (9036 tvd) Geo-Steer as per Geologist -22k WOB -250 gpm / 1760 psi - on / 1620 psi - off -80 rpm 4k torque off / 7.5 k torque on -PUW = 183k /SOW= 150k / RtWt = 155k -ADT = 2.55 hrs /AST = 0.0 hrs /ART = 2.55 hrs Pnntetl: //'L:3/2UUtl 'L:"L4:b8 PM BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To ~! Hours Task Code NPT Phase Description of Operations - _ - 7/11/2008 09:00 - 12:00 _ 3.00 DRILL -- P PROD1 -Total Time on bit = 2.55 hrs -Feathered Bit on Bottom to clear junk from previous bit -Slow Drilling; Hard Streak, Pyrite and chert in samples 12:00 - 00:00 12.00 DRILL P PROD1 Directional Drill 6 1/8" Production hole 10,694'- 11,268' and (9036 tvd) Geo-Steer as per Geologist -22k WOB -250 gpm / 1830 psi - on / 1750 psi - off -80 rpm 5k torque off / 9 k torque on -PUW = 192k /SOW= 140k / RtWt = 157k -ADT = 7.96 hrs / AST = 2.93 hrs /ART = 5.03 hrs -Total Time on bit = 10.5 hrs 7/12/2008 00:00 - 01:30 1.50 DRILL P PROD1 Directional Drill 6 1/8" Production hole 11 268' - 11 363md (9035 tvd Geo-Steer as per Geologist -25k WOB -250 gpm / 1830 psi - on / 1750 psi - off -80 rpm 5k torque off / 9 k torque on -PUW = 192k /SOW= 140k / RtWt = 157k -ADT = 1.24 hrs / AST = 0.0 hrs /ART = 1.24 hrs -Total Time on bit = 11.88 hrs 01:30 - 02:00 0.50 DRILL P PROD1 Take Survey and CBU 02:00 - 05:00 3.00 DRILL P PROD1 Mad Pass log from TD to 10624'md (previous bit trip) -250 gpm / 1600 psi -90 rpm / 5k Torque -300'/hr pulling speed 05:00 - 05:30 0.50 DRILL P PROD1 RIH to TD ~ 11,363' 05:30 - 07:00 1.50 DRILL P PROD1 Circulate hole clean and spot liner running pill in open hole -250 gpm / 1690 psi -80 rpm / 5k Torque -Monitor well, static 8.5 ppg In /Out 07:00 - 08:30 1.50 DRILL P PROD1 POH to Shoe -No problems pulling ithrough open hole 08:30 - 09:00 0.50 DRILL P PROD1 CBU ~ Shoe -Drop CCV Ball and shift CCV C~ 2100 psi / 2 bpm -CBU C~ 535 gpm / 1080 psi -Wash between 8715' and 8748' 09:00 - 12:00 3.00 DRILL P PROD1 POH to BHA 12:00 - 14:00 2.00 DRILL P PROD1 L/D BHA -PJSM on removing RA Source, Remove RA source from LWD -Lay down All HWDP, Jar, NM HWDP, Motor MWD /LWD -Break bit and L/D motor and MWD 14:00 - 15:00 1.00 CASE P RUNPRD Rig Power tongs, elevators, slips, Torque turn computer to run 4 1/2" Liner 15:00 - 22:00 7.00 CASE P RUNPRD Run 4.5" liner , 67 jts of 12.6# 13CR80 Vam Top. -Baker- lok all connections Fldat Clloar and below -Used Jet Lube seal guard Thread Compound -avg M/U = 4400 ft/Ibs - Pick up Baker Flex-Lock liner hanger and ZXP liner top packer assembly with 'HRD' running tool. Mud Losses ~ 7 - 9 bph 22:00 - 22:30 0.50 CASE P RUNPRD Pick up 1 std of 4 drill pipe minted: iietieuuts c~a:aa rnn • BP EXPLORATION Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date From - To Hours Task Code NPT 7/12/2008 22:00 - 22:30 0.50 CASE I P 22:30 - 00:00 1.501 CASE P 7/13/2008 00:00 - 02:00 2.001 CASE ~ P 02:00 - 02:30 0.501 CASE ~ P 02:30 - 04:00 I 1.501 CASE I P 04:00 - 04:30 0.501 CASE P 04:30 - 06:00 I 1.501 CEMT I P 06:00 - 07:30 I 1.501 CEMT I P 07:30 - 09:00 1.50 ~ CEMT ~ P 09:00 - 10:30 1.501 CEMT P 10:30 - 15:00 4.501 CEMT I P 15:00 - 16:00 I 1.00 CASE ~ P 16:00 - 18:00 I 2.001 PERFOBI P Start: 6/26/2008 Rig Release: 7/15/2008 Rig Number: Page 13 of15~ Spud Date: 7/23/1982 End: 7/15/2008 Phase ~ Description of Operations RUNPRD -Circ 1.5x liner volume 6 bpm = 350psi -PUW = 62k /SOW = 62 k RUNPRD RIH With 4 1/2" liner -filling every 10 stands -Mud Losses 7-10 bph RUNPRD RIH With 4 1/2" liner -filling every 10 stands -Mud Losses 7-10 bph RUNPRD Circulate 1 1/2 drill pipe and liner volume at 7" shoe prior to going into open hole. -Stage pumps up to 6 BPM / 664 psi RUNPRD RIH With 4 1/2" liner -filling every 10 stands -Mud Losses 7-10 bph RUNPRD Make up Cement Head and Cement hose and valves RIH and Tag Bottom ~ 11363 RUNPRD Break circulating, stage up to 6 bpm, 1240 psi PJSM with Schlumberger Cementers and NAD Rig Crew -Mud Loss ~ 5-7 bph RUNPRD -Pump 5 bbls of fresh water via tee and test lines to 4500 psi. Bleed pressure and pump 20 bbls of 12.0 ppg mud push, followed by 73 bbls 15.8 ppg Class G cement at 5 BPM while reciprocating pipe. Drop wiper dart and displace with 55 bbls perforatrion pill followed by 71.5 bbls 8.5 ppg mud at 5 to 6 BPM while reciprocating pipe. Slowed rate to 3 BPM prior to latch and again 20 bbls prior to bump. Bump plug with 2800 psi to set hanger. 25-30 bbls lost during cement job -CIP ~ 07:15 hrs RUNPRD -Set 50K on hanger to ensure set. - Bleed pressure and check floats -floats held. - Remove tee from cement head and install plug on cement head outlet. Open TIW valve to allow pumping through top drive. - Pressure up to 3500 psi to release HRD setting tool. P/U 3' to ensure released. Bleed off pressure. S/O 75K with rotation and see good indication at surface that packer set. Repeat with rotation. - Pressure up to 1000 psi and pick up string to clear packoff and circulate 20 bbls at 6 BPM 1325 psi. Continue picking up string and increase pump rate to 12 BPM, 2150 psi and circulate out 20 bbls of excess cement. - Swap over and displace well to sea water at 500 gpm / 1825 psi RUNPRD Slip and Cut Drilling Line -Service TDS and Blocks, Draw Works and Crown RUNPRD POH with Baker's Liner Running Tool -L/D Excess Drill Pipe RUNPRD Rig Up to Test 4 1/2" Liner -Confirmed 1000 psi compression from Lab -Pressure Test to 3500 psi for 30 minutes, Good Test OTHCMP ~ Rig up to Run 2 7/8" 6spf 2906PJ Perf Guns rnrnea: nzsizuua rza:oa rnn • BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 7/13/2008 16:00 - 18:00 2.00 PERFO P OTHCMP -PJSM with Schlumberger Perf Crew and NAD Rig Crew -Pick U a total of 1037 feet of uns with 770 feet of erfs 18:00 - 21:00 3.00 PERFO P OTHCMP R/U and Run 2 7/8 "Fox" Drill Pipe -Run 60 jts of Pipe 21:00 - 00:00 3.00 PERFO P OTHCMP RIH with Perf Guns on 4" Drill Pipe 7/14/2008 00:00 - 01:00 1.00 PERFO P OTHCMP RIH and Place Perf Guns On Depth -Bottom Perf ~ 11270' MD 01:00 - 01:30 0.50 PERFO P OTHCMP PJSM with Schlumberger Perf Tech and NAD Rig Crew -Fire the guns by pressuring up on the DP in specific sequence. -Bleed pressure to zero -Monitor guns firing with the sound recorder, -Positive Indication of Guns Firing , -Loss 5 bbls of fluid initially and hole stabilized losing 5-10 bph 10250' to 10380' 130' 10420' to 10620' 200' 10780' to 10930' 150' 10980' to 11270' 290' 01:30 - 02:30 1.00 PERFO P OTHCMP POH until guns up in the 7" casing -Monitor well, well static 8.4 seawater in /out 02:30 - 07:30 5.00 PERFO P OTHCMP POH Laying Down Drill Pipe 07:30 - 09:30 2.00 PERFO P OTHCMP Service Rig -Adjust Rails for TDS -Service TDS, Draw Works and Crown -R/U to UD 2 7/8" DP 09:30 - 12:00 2.50 PERFO P OTHCMP UD 2 7/8" DP 12:00 - 14:30 2.50 PERFO P OTHCMP UD Guns, PJSM with Schlumberger Perf Tech and NAD Rig Crew -All Shots Fired 14:30 - 16:00 1.50 BUNCO RUNCMP Pull Wear Bushing -PJSM on Rigging Up to Run Completion -R/U Double Stack Power Tong, Elevators, Slings, Computer and Compensator 16:00 - 00:00 8.00 BUNCO RUNCMP Run 4.5" 12.6# 13CR80 Vam Top tubi~ as per running tally -WLEG 'XN' nipple, X nipple, Baker S-3 packer, X Nipple, 4 GLM, X nipple -Baker-Loc below Packer -No SSSV -Jet Lube Seal Guard thread compound on pin end connections -Avg Torque on connection = 4400 Wlbs -X' nipple placed at 2200' per tubing detail. -4 GLMs, 4.5" X 1" KBG - 1 R. -The #4 GLM ~ 3480'md installed with DCK shear valve 7/15/2008 00:00 - 01:30 1.50 BUNCO RUNCMP Pick up 4.5" 12.6# 13CR80 Vam Top tubing as per running tally and tag up on bottom of PBR ~ 8529.8 (tubing depth) Repeat Sequence with the same results 01:30 - 02:00 0.50 BUNCO RUNCMP Pull Back to Jt #194 -P/U space out pups 3.83' and 9.82' -P/U Jt #195 -Make up Hanger , Pup jt and rih with Landing Jt. rrintea: iicsieuuu c~n:oy rnn • BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: 06-19 Common Well Name: 06-19 Spud Date: 7/23/1982 Event Name: REENTER+COMPLETE Start: 6/26/2008 End: 7/15/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code ; NPT ' Phase Description of Operations i 7/15/2008 01:30 - 02:00 0.50 BUNCO RUNCMP -PUW = 123k /SOW = 115k -85k sitting on hanger -Set WLEG 7.09' in PBR -WLEG C~ 8525.12' (tubing depth) 02:00 - 02:30 0.50 BUNCO RUNCMP Run in Lock Down Screws and torque to 450 fUlbs of Torque 02:30 - 04:30 2.00 BUNCO RUNCMP Rig Up and Reverse circulate 132 bbl clean seawater followed by 155 bbls of seawater treated with corrosion inhibitor into the annulus. 04:30 - 06:00 1.50 BUNCO RUNCMP Dro ball /rod to RHC lu .Set the acker as er Baker and test the tubing to 4500 psi for 30 minutes. Slowly bleed tubing pressure to 1500 psi. Test the annulus to 3500 si for 30 minutes. Bleed A t en ubing to ressure up IA to 2100 psi and see shear valve shear open. Circ both ways to ensure circulation. 06:00 - 06:30 0.50 WHSUR P RUNCMP -Set TWC -Test from below 1000 psi 5 min 06:30 - 07:30 1.00 BOPSU P RUNCMP -ND BOPE stack 07:30 - 10:30 3.00 WHSUR P RUNCMP -NU Adapter and tree. -Test Packoff to 5000 psi. -Test tree w/diesel to 5000 psi. 10:30 - 14:00 3.50 WHSUR P RUNCMP -Lubricate out TWC. -RU Little Red and Freeze Protect -PT 3500psi -Reverse circulate 75 bbls diesel, 3bpm, 1400 psi. -U-Tube, Blow down lines. 14:00 - 15:00 1.00 WHSUR P RUNCMP -RU DSM -Set BPV and test to 1000 psi -RD & Release Rig at 15:00 hrs. Printetl: 7/23/2008 2:24:Sy PM BP EXPLORATION Leak-Off Test Summary Legal Name: Common Name: Test Date 7/1/2008 LOT 7/8/2008 FIT 06-19 06-19 Page 1 of 1 Test Type j Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW - __ __ 5,021.0 (ft) 5,021.0 (ft) 9.00 (ppg) 701 (psi) 3,048 (psi) 11.69 (ppg) 8,689.0 (ft) 8,566.0 (ft) 8.40 (ppg) 935 (psi) 4,673 (psi) 10.50 (ppg) • • Printed: 7/23/2008 2:24:55 PM by ~~~ _ ~ ~ - ~ Scl rger ~~~~~~~~ DS06-19A Surve y Report Report Date: 12-Jul-08 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 11.910° Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: DS-O6 / 06-19 TVD Reference Datum: Rotary Table Well: 06-19 TVD Reference Elevation: 65.30 ft relative to MSL Borehole: 06-19A Sea Bed /Ground Level Elevation: 36.90 ft relative to MSL UWUAPI#: 500292079101 Magnetic Declination: 23.207° Survey Name /Date: 06.19A /July 12, 2008 Total Field Strength: 57678.958 nT Tort /AHD / DDI / ERD ratio: 267.028° / 3403.95 ft / 6.058 / 0.376 Magnetic Dip: 80.896° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: July 09, 2008 Location LaULong: N 70.24329978, W 148.49697063 Magnetic Declination Model: BGGM 2008 Location Grid NIE Y/X: N 5940832.130 ftUS, E 686081.240 ftUS North Reference: True Norlh Grid Convergence Angle: +1.41459295° Total Corr Mag North -> True North: +23.207° Grid Scale Fodor: 0.99993934 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de OOft ftUS ftUS rrolecteo-up U .UU U.UV V.VU 'b,.3U V.VV V.VV V.VV V.UU V.VV V.VV V.VV J~4V63C.13 080UOI.G~i IV /U.L4JL~~/O VV 140. 4~0~/V03 28 .30 0.00 0.00 -37.00 28. 30 0.00 0.00 0.00 0.00 0.00 0.00 5940832.13 686081.24 N 70.24329978 W 148. 49697063 SPERRY 8/19/82 81 ,30 0.27 246.00 26.00 91. 30 -0.09 0.15 0.15 -0.06 -0.14 0.43 5940832.07 686081.11 N 70.24329962 W 148. 49697172 BOSS-16103 GYRO 191 .30 0.30 230.80 126.00 191. 30 -0.43 0.64 0.64 -0.32 -0.55 0.08 5940831.79 686080.69 N 70.24329890 W 148. 49697510 291 .30 0.47 211.10 226.00 291. 30 -1.02 1.31 1.28 -0.84 -0.97 0.21 5940831.27 686080.29 N 70.24329749 W 148. 49697845 391 .30 0.73 214.39 325.99 391. 29 -2.00 2.36 2.31 -1.72 -1.54 0.26 5940830.38 686079.74 N 70.24329509 W 148. 49698307 491 .30 1.08 229.50 425.98 491. 28 -3.33 3.93 3.87 -2.85 -2.62 0.42 5940829.21 686078.69 N 70.24329199 W 148. 49699176 591 .30 0.68 232.39 525.97 591. 27 -4.53 5.46 5.40 -3.83 -3.80 0.40 5940828.21 686077.53 N 70.24328933 W 148. 49700134 691 .30 0.45 258.89 625.96 691. 26 -5.13 6.43 6.32 -4.26 -4.66 0.34 5940827.75 686076.69 N 70.24328813 W 148. 49700825 791 .30 0.55 223.80 725.96 791. 26 -5.70 7.28 7.13 -4.69 -5.38 0.32 5940827.31 686075.98 N 70.24328698 W 148. 49701405 891 .30 0.25 287.00 825.96 891. 26 -6.08 7.91 7.73 -4.97 -5.92 0.49 5940827.02 686075.45 N 70.24328620 W 148. 49701 991 .30 0.45 11.89 925.95 991 .25 -5.67 8.43 7.55 -4.52 -6.04 0.49 5940827.46 686075.31 N 70.24328743 W 148. 49701 1091 .30 0.05 13.10 1025.95 1091 .25 -5.24 8.87 7.23 -4.09 -5.95 0.40 5940827.89 686075.39 N 70.24328859 W 148. 49701871 1191 .30 0.32 321.61 1125.95 1191 .25 -5.01 9.18 7.22 -3.83 -6.12 0.29 5940828.15 686075.22 N 70.24328931 W 148. 49702003 1291 .30 0.15 349.90 1225.95 1291 .25 -4.71 9.58 7.21 -3.49 -6.31 0.20 5940828.49 686075.01 N 70.24329026 W 148. 49702162 1391 .30 0.05 207.30 1325.95 1391 .25 -4.63 9.68 7.21 -3.40 -6.36 0.19 5940828.58 686074.97 N 70.24329050 W 148. 49702196 1491 .30 0.23 136.81 1425.95 1491 .25 -4.79 9.91 7.19 -3.58 -6.24 0.22 5940828.40 686075.09 N 70.24329000 W 148. 49702102 1591 .30 0.38 89.50 1525.95 1591 .25 -4.83 10.41 6.87 -3.72 -5.77 0.28 5940828.26 686075.56 N 70.24328961 W 148. 49701723 1691 .30 0.48 130.31 1625.95 1691 .25 -4.96 11.13 6.49 -3.99 -5.12 0.31 5940828.01 686076.22 N 70.24328887 W 148. 49701197 1791 .30 0.38 80.89 1725.94 1791 .24 -5.04 11.84 6.14 -4.21 -4.47 0.37 5940827.81 686076.87 N 70.24328828 W 148. 49700675 1891 .30 0.42 176.11 1825.94 1891 .24 -5.28 12.39 6.12 -4.52 -4.12 0.59 5940827.51 686077.23 N 70.24328742 W 148. 49700390 1991 .30 0.40 227.10 1925.94 1991 .24 -5.91 13.06 6.72 -5.13 -4.35 0.35 5940826.90 686077.02 N 70.24328577 W 148. 49700577 2091 .30 0.67 233.39 2025.94 2091 .24 -6.64 13.99 7.64 -5.71 -5.08 0.28 5940826.29 686076.31 N 70.24328417 W 148. 49701162 2191 .30 0.65 290.70 2125.93 2191 .23 -6.99 15.05 8.44 -5.86 -6.08 0.63 5940826.12 686075.31 N 70.24328377 W 148. 49701970 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 06-19\06-19\06-19A\06-19A Generated 8/12/2008 3:29 PM Page 1 of 5 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft H ft ft ft de 00 ft ftUS ftUS 2'Ly1.aU V.5/ Zl)4.CV ZZZb.`J3 ZZ`J I.ZJ -/.VJ IO.IU ~.I I -~./I -/.IU U.Cy Jy4U8CO.LD OOOV/4.L6 IV /U.L4JL041.7 vv 140.4.y/VG/tl0 2391.30 0.28 223.39 2325.92 2391.22 -7.41 16.81 9.77 -5.93 -7.77 0.40 5940826.01 686073.62 N 70.24328357 W 148.49703334 2491.30 0.55 203.39 2425.92 2491.22 -8.09 17.53 10.44 -6.55 -8.12 0.30 5940825.38 686073.28 N 70.24328189 W 148.49703623 2591.30 0.07 204.89 2525.92 2591.22 -8.62 18.07 10.92 -7.05 -8.34 0.48 5940824.88 686073.08 N 70.24328053 W 148.49703798 2691.30 0.55 209.19 2625.92 2691.22 -9.13 18.61 11.42 -7.52 -8.60 0.48 5940824.40 686072.83 N 70.24327923 W 148.49704008 2791.30 0.50 190.30 2725.91 2791.21 -10.03 19.52 12.23 -8.37 -8.91 0.18 5940823.54 686072.54 N 70.24327692 W 148.49704260 2891.30 0.32 216.89 2825.91 2891.21 -10.72 20.22 12.85 -9.02 -9.16 0.26 5940822.89 686072.31 N 70.24327513 W 148.49704458 2991.30 0.37 192.19 2925.91 2991.21 -11.29 20.81 13.40 -9.56 -9.39 0.16 5940822.34 686072.09 N 70.24327366 W 148.49704648 3091.30 0.10 25.80 3025.91 3091.21 -11.53 21.09 13.59 -9.80 -9.42 0.47 5940822.10 686072.06 N 70.24327301 W 148.49704673 .3191.30 0.45 170.50 3125.91 3191.21 -11.81 21.45 13.75 -10.11 -9.32 0.53 5940821.80 686072.17 N 70.24327217 W 148.49704590 3291.30 0.47 148.90 3225.90 3291.20 -12.48 22.24 14.12 -10.84 -9.04 0.17 5940821.07 686072.47 N 70.24327015 W 148.49704366 4 3391.30 0.33 168.70 3325.90 3391.20 -13.04 22.93 14.45 -11.48 -8.78 0.19 5940820.44 686072.75 N 70.24326842 W 148.4970 3491.30 0.52 160.31 3425.90 3491.20 -13.69 23.68 14.90 -12.19 -8.57 0.20 5940819.73 686072.98 N 70.24326648 W 148.49703981 3591.30 0.60 162.70 3525.89 3591.19 -14.54 24.65 15.50 -13.12 -8.26 0.08 5940818.82 686073.31 N 70.24326395 W 148.49703731 3691.30 0.10 148.70 3625.89 3691.19 -15.06 25.26 15.88 -13.69 -8.06 0.50 5940818.25 686073.52 N 70.24326238 W 148.49703569 3791.30 0.47 152.11 3725.89 3791.19 -15.44 25.76 16.15 -14.13 -7.82 0.37 5940817.82 686073.77 N 70.24326119 W 148.49703378 3891.30 0.50 172.70 3825.89 3891.19 -16.16 26.60 16.73 -14.92 -7.57 0.18 5940817.03 686074.04 N 70.24325901 W 148.49703178 3991.30 0.33 143.31 3925.88 3991.18 -16.77 27.31 17.23 -15.59 -7.34 0.27 5940816.37 686074.28 N 70.24325720 W 148.49702994 4091.30 0.90 166.11 4025.88 4091.18 -17.66 28.37 17.99 -16.58 -6.98 0.61 5940815.38 686074.67 N 70.24325449 W 148.49702703 4191.30 1.08 173.50 4125.86 4191.16 -19.26 30.09 19.46 -18.28 -6.69 0.22 5940813.69 686075.00 N 70.24324985 W 148.49702464 4291.30 0.42 141.50 4225.85 4291.15 -20.39 31.37 20.51 -19.50 -6.35 0.76 5940812.48 686075.37 N 70.24324650 W 148.49702194 4391.30 1.00 174.20 4325.85 4391.15 -21.46 32.58 21.52 -20.66 -6.04 0.69 5940811.33 686075.71 N 70.24324335 W 148.49701939 4491.30 1.57 122.50 4425.82 4491.12 -22.77 34.68 22.77 -22.26 -4.79 1.23 5940809.76 686077.00 N 70.24323897 W 148.49700934 4591.30 1.32 79.39 4525.80 4591.10 -22.81 37.09 22.92 -22.78 -2.51 1.09 5940809.29 686079.30 N 70.24323753 W 148.49699087 4691.30 1.40 122.11 4625.77 4691.07 -22.79 39.36 23.22 -23.22 -0.34 0.99 5940808.91 686081.47 N 70.24323634 W 148.49697337 4791.30 1.30 111.90 4725.74 4791.04 -23.41 41.71 24.36 -24.29 1.75 0.26 5940807.89 686083.59 N 70.24323341 W 148.49695651 4891.30 1.25 128.31 4825.72 4891.02 -24.09 43.92 25.66 -25.39 3.66 0.37 5940806.84 686085.52 N 70.24323041 W 148.49694110 Tie-In Survey 4991.30 1.25 125.31 4925.69 4990.99 -25.01 46.10 27.24 -26.70 5.40 0.07 5940805.57 686087.30 N 70.24322684 W 148.49692700 GYD GC SS 5005.00 1.26 126.32 4939.39 5004.69 -25.13 46.40 27.46 -26.88 5.65 0.18 5940805.40 686087.55 N 70.24322636 W 148.496 5021.00 3.00 121.90 4955.38 5020.68 -25.35 46.99 27.89 -27.20 6.14 10.92 5940805.09 686088.05 9 N 70.24322547 W 148.4969 5031.00 2.01 121.90 4965.37 5030.67 -25.50 47.43 28.19 -27.43 6.51 9.90 5940804.87 686088.43 N 70.24322484 W 148.49691803 5124.00 3.06 359.62 5058.32 5123.62 -23.63 50.28 26.99 -25.81 7.88 4.81 5940806.52 686089.76 N 70.24322927 W 148.49690697 5221.00 4.09 332.77 5155.14 5220.44 -18.42 56.22 21.10 -20.15 6.28 2.00 5940812.15 686088.02 N 70.24324474 W 148.49691989 5318.00 6.28 351.31 5251.74 5317.04 -10.76 64.91 12.45 -11.82 3.90 2.81 5940820.41 686085.43 N 70.24326748 W 148.49693915 MWD+IFR+MS 5346.07 6.91 350.49 5279.63 5344.93 -7.76 68.14 9.28 -8.64 3.39 2.27 5940823.58 686084.84 N 70.24327617 W 148.49694328 5439.87 9.75 5.33 5372.44 5437.74 5.39 81.65 5.80 4.84 3.19 3.77 5940837.04 686084.31 N 70.24331299 W 148.49694485 5534.64 13.13 15.15 5465.32 5530.62 24.12 100.40 24.19 23.22 6.75 4.10 5940855.51 686087.42 N 70.24336323 W 148.49691610 5631.25 15.51 24.62 5558.93 5624.23 47.68 124.24 47.97 45.56 15.00 3.45 5940878.05 686095.11 N 70.24342426 W 148.49684946 5726.41 17.42 35.49 5650.21 5715.51 73.15 151.14 74.44 68.74 28.58 3.80 5940901.55 686108.11 N 70.24348756 W 148.49673984 5821.50 18.89 47.32 5740.59 5805.89 98.76 180.67 102.76 90.77 48.17 4.16 5940924.05 686127.15 N 70.24354776 W 148.49658165 5920.52 20.05 57.07 5833.98 5899.28 123.80 213.61 133.41 110.87 74.20 3.48 5940944.79 686152.68 N 70.24360267 W 148.49637137 6014.85 19.78 61.39 5922.67 5987.97 145.57 245.72 162.99 127.30 101.79 1.59 5940961.90 686179.85 N 70.24364756 W 148.49614859 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 06-19\06-19\06-19A\06-19A Generated 8/12/2008 3:29 PM Page 2 of 5 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de tt tt ft ft ft ft ft de OOtt ftUS ftUS b 1 Ui3.:i / 6205.60 6299.44 6395.67 6484.13 6586.60 6682.84 6777.41 6874.03 6969.94 7066.30 7161.36 7256.27 7352.25 GV.Uy bG.Z`J bUl V.b`J bV/b.8`J Ibb.Uy G//.bl I:1G./ I 14G.JJ 19.92 61.93 6101.95 6167.25 187.38 310.87 224.30 157.91 20.55 61.07 6190.00 6255.30 208.43 343.33 255.62 173.40 21.34 60.77 6279.87 6345.17 230.99 377.73 289.17 190.12 20.65 64.03 6362.46 6427.76 251.16 409.41 320.06 204.81 20.18 63.90 6458.49 6523.79 273.14 445.16 354.88 220.50 19.88 63.64 6548.91 6614.21 293.49 478.12 387.17 235.07 18.35 62.70 6638.26 6703.56 312.86 509.09 417.65 249.03 16.59 61.68 6730.42 6795.72 331.39 538.09 446.33 262.55 14.35 63.28 6822.85 6888.15 347.65 12.35 61.28 6916.60 6981.90 361.82 12.01 66.92 7009.53 7074.83 374.11 11.33 67.28 7102.48 7167.78 385.07 12.00 69.33 7196.47 7261.77 395.80 7447.29 11.13 70.19 7543.56 11.29 66.62 7638.97 12.84 60.35 7735.15 13.04 60.45 7830.27 13.08 64.78 7925.87 8022.17 8117.46 8211.86 8308.22 8403.52 8498.93 8594.49 8625.82 8702.20 8734.24 8766.30 8797.88 8829.47 8861.83 8893.15 8925.78 8958.00 8988.87 9020.17 9052.91 9083.64 9116.74 9147.66 14.65 13.17 10.52 10.29 11.22 11.61 13.15 15.09 15.16 15.97 20.93 24.86 28.55 34.02 36.27 36.48 36.00 36.83 43.27 45.56 49.16 51.62 54.39 60.88 65.90 65.60 63.97 65.19 68.23 7289.58 7354.88 405.95 7384.02 7449.32 416.28 7477.32 7542.62 428.71 7571.06 7636.36 442.98 7663.72 7729.02 456.58 7756.53 7821.83 470.22 7850.01 7915.31 483.88 7943.26 8008.56 495.66 8036.11 8101.41 506.00 8130.77 8196.07 516.34 563.67 471.64 274.39 585.92 493.69 284.72 605.96 513.47 293.48 625.16 532.26 300.95 644.56 551.20 308.11 663.61 569.73 314.71 682.32 588.04 321.60 702.24 607.84 330.55 723.78 629.34 341.19 745.27 650.72 351.07 I C.7..7V V.4/ Oy4U`1//.OJ OOOLV/.JO IV /V.G'IJ0000/ YV 1'/0. 'F.7.7.7G 1.70 159.30 0.22 5940993.91 686236.58 N 70.24373117 W 148. 49568413 187.82 0.74 5941010.10 686264.71 N 70.24377349 W 148. 49545380 217.88 0.83 5941027.56 686294.35 N 70.24381916 W 148. 49521101 245.95 1.53 5941042.93 686322.05 N 70.24385929 W 148. 49498432 278.07 0.46 5941059.41 686353.76 N 70.24390215 W 148. 49472494 307.64 0.33 5941074.70 686382.96 N 70.24394195 W 148. 49448614 335.28 1.65 5941089.35 686410.25 N 70.24398010 W 148. 49426293 360.94 1.85 5941103.50 686435.56 N 70.24401704 W 148. 49405570 383.61 2.38 5941115.89 686457.93 N 70.24404938 W 148. 49387259 403.31 2.13 5941126.70 686477.38 N 70.24407758 W 148. 49371345 421.33 1.30 5941135.90 686495.17 N 70.24410152 W 148 .49356 439.01 0.72 5941143.81 686512.66 N 70.24412192 W 148 .49342 457.04 0.82 5941151.41 686530.51 N 70.24414149 W 148 .49327950 474.92 0.93 5941158.45 686548.22 N 70.24415951 W 148 .49313515 492.31 0.74 5941165.76 686565.43 N 70.24417833 W 148 .49299468 510.10 2.13 5941175.15 686582.99 N 70.24420278 W 148 .49285102 528.83 0.21 5941186.25 686601.45 N 70.24423184 W 148 .49269978 547.90 1.03 5941196.59 686620.27 N 70.24425882 W 148 .49254573 768.17 673.42 360.61 568. 72 791.32 696.34 370.12 589. 83 810.88 715.75 378.42 607. 54 827.93 732.70 385.74 622. 93 845.91 750.48 392.83 639. 45 64. 04 8224.19 8289.49 527.37 864.76 769.16 400.47 656. 68 60. 37 8317.38 8382.68 540.46 885.21 789.57 410.04 674. 75 57. 07 8410.05 8475.35 556.44 908.51 812.87 422.17 694. 64 57. 07 8440.29 8505.59 562.21 916.69 821.04 426.62 701. 50 57. 00 8513.87 8579.17 576.67 937.18 841.53 437.77 718. 70 39. 08 8544.28 8609.58 584.88 947.25 851.34 444.62 726. 01 30. 08 8573.82 8639.12 596.39 959.70 862.69 454.91 733. 01 22. 30 8602.03 8667.33 610.13 973.87 874.70 467.64 739. 20 13. 99 8629.03 8694.33 626.40 990.24 887.33 483.22 744. 21 12 :35 8655.49 8720.79 645.02 1008.87 900.85 501.36 748. 44 11. 19 8680.71 8746.01 663.60 1027.45 914.21 519.54 752 .23 5 .55 8707.03 8772.33 682.83 1046.72 927.46 538.61 755 .04 356 .76 8732.98 8798.28 701.58 1065.83 938.97 557.69 755 .41 353 .62 8756.60 8821.90 720.58 1085.68 949.50 577.46 753 .71 353 .55 8778.96 8844.26 741.37 1107.58 960.98 599.23 751 .27 351 .84 8801.13 8866.43 764.10 1131.66 973.68 623.11 748 .19 353 .23 8820.72 8886.02 786.44 1155.33 986.55 646.58 745 .12 352 .90 8840.64 8905.94 811.45 1181.77 1001.57 672.82 741 .93 353 .61 8857.18 8922.48 836.19 1207.87 1016.94 698.74 738 .87 1.67 5941206.65 1.54 5941216.67 2.80 5941225.41 0.34 5941233.11 1.13 5941240.60 0.96 5941248.66 1.81 5941258.67 2.20 5941271.30 0.22 5941275.91 1.06 5941287.48 23.35 5941294.51 16.39 5941304.96 16.08 5941317.85 22.02 5941333.54 7.54 5941351.78 2.30 5941370.05 10.32 5941389.18 16.39 5941408.26 21.86 5941427.98 7.32 5941449.68 686640.85 686661.72 686679.21 686694.42 686710.76 686727.80 686745.62 686765.21 686771.96 686788.87 686796.01 686802.75 686808.63 686813.25 686817.03 686820.37 686822.71 686822.61 686820.42 686817.44 N 70.24428490 W 148.49237756 N 70.24431086 W 148.49220708 N 70.24433354 W 148.49206408 N 70.24435354 W 148.49193973 N 70.24437290 W 148.49180632 N 70.24439376 W 148.49166714 N 70.24441989 W 148.49152122 N 70.24445305 W 148.49136056 N 70.24446519 W 148.49130515 N 70.24449565 W 148.49116627 N 70.24451437 W 148.4911 N 70.24454246 W 148.49105071 N 70.24457725 W 148.49100067 N 70.24461981 W 148.49096022 N 70.24466935 W 148.49092599 N 70.24471903 W 148.49089538 N 70.24477112 W 148.49087266 N 70.24482324 W 148.49086966 N 70.24487727 W 148.49088337 N 70.24493673 W 148.49090312 11.65 5941473.48 686813.78 N 70.24500198 W 148.49092791 8.73 5941496.87 686810.13 N 70.24506610 W 148.49095269 8.41 5941523.02 686806.29 N 70.24513779 W 148.49097846 21.08 5941548.86 686802.59 N 70.24520861 W 148.49100315 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 06-19\06-19\06-19A\06-19A Generated 8/12/2008 3:29 PM Page 3 of 5 Comments Measured Inclination Azimuth SulsSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft tt ft tt ft ft ft de 00 ft ftUS ftUS yli5V.7V bJ.// JOa.oa oaic.co oaar.oo ooo.oc iwo.~a ~voa.yi iu.oa ,ov.ao iv.YO JJYIJ//.YJ VVVI J~A/ ~~ /V.~YJ~VVV/ •. ~YV. YJ iv ~a,.,, 9215.54 65.16 2.45 8887.54 8952.84 895.17 1268.57 1058.40 759.36 737.28 10.34 5941609.41 686799.51 N 70.24537421 W 148. 49101592 9244.85 65.53 3.36 8899.76 8965.06 921.48 1295.20 1078.57 785.96 738.63 3.09 5941636.04 686800.20 N 70.24544689 W 148. 49100500 9276.81 65.18 2.96 8913.09 8978.39 950.19 1324.25 1100.96 814.97 740.24 1.58 5941665.07 686801.09 N 70.24552612 W 148. 49099204 9309.59 71.05 1.46 8925.30 8990.60 980.16 1354.66 1124.41 845.35 741.40 18.40 5941695.47 686801.50 N 70.24560912 W 148. 49098261 9340.70 77.18 1.94 8933.82 8999.12 1009.59 1384.56 1147.63 875.24 742.29 19.76 5941725.38 686801.65 N 70.24569079 W 148. 49097541 9363.87 82.61 2.70 8937.88 9003.18 1032.08 1407.37 1165.68 898.03 743.21 23.66 5941748.17 686802.01 N 70.24575303 W 148. 49096792 9394.47 86.69 0.72 8940.73 9006.03 1062.05 1437.83 1189.86 928.47 744.12 14.81 5941778.63 686802.17 N 70.24583621 W 148. 49096057 9426.47 83.81 2.80 8943.38 9008.68 1093.44 1469.71 1215.49 960.34 745.10 11.09 5941810.51 686802.36 N 70.24592327 W 148. 49095265 9458.77 84.64 3.63 8946.63 9011.93 1125.20 1501.85 1242.08 992.43 746.90 3.62 5941842.63 686803.37 N 70.24601093 W 148. 49093806 9487.77 84.86 1.24 8949.29 9014.59 1153.69 1530.73 1265.98 1021.28 748.13 8.24 5941871.50 686803.88 N 70.24608974 W 148. 49092813 9522.13 84.78 0.28 8952.39 9017.69 1187.26 1564.95 1294.00 1055.49 748.58 2.79 5941905.71 686803.49 N 70.24618322 W 148. 49092 9554.43 84.71 0.20 8955.35 9020.65 1218.76 1597.11 1320.44 1087.66 748.72 0.33 5941937.87 686802.83 N 70.24627109 W 148. 49092332 9586.13 84.99 359.68 8958.19 9023.49 1249.64 1628.68 1346.55 1119.23 748.68 1.86 5941969.43 686802.02 N 70.24635734 W 148. 49092357 9617.53 84.54 0.22 8961.06 9026.36 1280.23 1659.95 1372.64 1150.50 748.66 2.23 5942000.69 686801.22 N 70.24644277 W 148. 49092376 9649.53 84.79 0.33 8964.03 9029.33 1311.44 1691.81 1399.53 1182.36 748.81 0.85 5942032.54 686800.59 N 70.24652981 W 148. 49092250 9681.23 84.99 0.34 8966.86 9032.16 1342.37 1723.39 1426.40 1213.93 748.99 0.63 5942064.11 686799.99 N 70.24661607 W 148. 49092098 9713.13 85.47 0.41 8969.51 9034.81 1373.52 1755.18 1453.66 1245.72 749.20 1.52 5942095.89 686799.41 N 70.24670291 W 148. 49091928 9744.83 86.37 0.64 8971.76 9037.06 1404.52 1786.80 1480.99 1277.34 749.49 2.93 5942127.50 686798.92 N 70.24678929 W 148. 49091691 9776.33 86.61 0.37 8973.69 9038.99 1435.34 1818.24 1508.33 1308.78 749.77 1.15 5942158.94 686798.42 N 70.24687518 W 148. 49091465 9809.63 86.78 0.25 8975.61 9040.91 1467.90 1851.48 1537.35 1342.02 749.95 0.62 5942192.17 686797.78 N 70.24696600 W 148. 49091317 9841.93 88.80 359.75 8976.86 9042.16 1499.48 1883.76 1565.60 1374.30 749.95 6.44 5942224.43 686796.99 N 70.24705417 W 148. 49091314 9873.03 93.27 0.31 8976.30 9041.60 1529.90 1914.84 1592.97 1405.38 749.96 14.48 5942255.51 686796.24 N 70.24713910 W 148. 49091299 9904.23 94.29 0.13 8974.24 9039.54 1560.39 1945.98 1620.56 1436.52 750.08 3.32 5942286.63 686795.59 N 70.24722415 W 148. 49091200 9936.43 94.60 0.43 8971.74 9037.04 1591.83 1978.08 1649.15 1468.62 750.24 1.34 5942318.73 686794.95 N 70.24731185 W 148. 49091070 9967.83 94.40 359.41 8969.28 9034.58 1622.45 2009.38 1677.07 1499.92 750.20 3.30 5942350.02 686794.13 N 70.24739737 W 148. 49091103 9999.83 94.84 359.75 8966.70 9032.00 1653.61 2041.28 1705.55 1531.82 749.96 1.74 5942381.90 686793.11 N 70.24748451 W 148. 49091289 10032.83 93.16 359.62 8964.40 9029.70 1685.79 2074.20 1735.10 1564.73 749.78 5.11 5942414.80 686792.12 N 70.24757444 W 148. 49091433 10063.43 90.48 358.91 8963.43 9028.73 1715.62 2104.78 1762.56 1595.31 749.39 9.06 5942445.35 686790.97 N 70.24765797 W 148. 49091= 10096.63 88.26 357.56 8963.79 9029.09 1747.88 2137.97 1792.22 1628.49 748.37 7.83 5942478.50 686789.13 N 70.24774862 W 148. 4909 10128.63 89.08 359.24 8964.54 9029.84 1778.98 2169.96 1820.95 1660.47 747.47 5.84 5942510.44 686787.45 N 70.24783598 W 148. 49093289 10159.83 88.60 358.78 8965.17 9030.47 1809.39 2201.16 1849.22 1691.66 746.93 2.13 5942541.60 686786.14 N 70.24792119 W 148. 49093722 10191.63 87.71 357.29 8966.19 9031.49 1840.25 2232.94 1877.89 1723.42 745.84 5.46 5942573.33 686784.27 N 70.24800796 W 148. 49094600 10222.63 88.12 356.46 8967.32 9032.62 1870.16 2263.92 1905.66 1754.35 744.16 2.98 5942604.21 686781.82 N 70.24809247 W 148. 49095962 10255.03 87.57 357.59 8968.54 9033.84 1901.45 2296.30 1934.82 1786.69 742.48 3.88 5942636.49 686779.34 N 70.24818080 W 148. 49097316 10287.53 87.29 355.69 8970.00 9035.30 1932.77 2328.77 1964.07 1819.10 740.57 5.90 5942668.84 686776.64 N 70.24826935 W 148. 49098851 10319.83 88.60 354.54 8971.15 9036.45 1963.67 2361.04 1992.87 1851.26 737.82 5.40 5942700.92 686773.09 N 70.24835721 W 148 .49101069 10351.13 90.28 352.91 8971.46 9036.76 1993.41 2392.34 2020.56 1882.37 734.40 7.48 5942731.93 686768.91 N 70.24844220 W 148 .49103829 10382.33 89.21 352.39 8971.60 9036.90 2022.86 2423.54 2047.99 1913.31 730.41 3.81 5942762.77 686764.15 N 70.24852673 W 148 .49107051 10413.93 89.28 349.01 8972.01 9037.31 2052.31 2455.14 2075.36 1944.49 725.31 10.70 5942793.81 686758.28 N 70.24861191 W 148 .49111173 10445.33 89.83 345.79 8972.26 9037.56 2080.88 2486.54 2101.74 1975.13 718.46 10.40 5942824.27 686750.68 N 70.24869561 W 148 .49116702 10478.23 88.76 343.47 8972.66 9037.96 2110.12 2519.43 2128.65 2006.84 709.74 7.76 5942855.76 686741.18 N 70.24878227 W 148.49123743 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 06-19\06-19\06-19A\06-19A Generated 8/12/2008 3:29 PM Page 4 of 5 Comments Measured Inclination Azimuth Subsea ND TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 00 ft ftUS ftUS i VoVa.aa aa.a/ 10541.63 89.48 10573.79 89.34 10605.79 89.68 10639.09 90.13 10671.29 90.16 10702.59 90.20 10734.75 90.92 10766.64 87.61 10799.14 10830.34 10862.34 10894.14 10925.04 10957.64 10989.34 11021.25 11052.64 11084.64 11116.44 11148.21 11180.42 11212.21 11244.01 86.70 87.18 87.87 89.86 89.86 90.68 90.44 91.16 92.39 91.67 34U.OV 336.27 336.78 335.21 336.59 336.71 335.52 336.55 337.31 335.80 336.15 336.65 334.97 334.90 335.17 336.21 335.95 336.36 337.82 O~/3.V4 8973.22 8973.55 8973.83 8973.88 8973.80 8973.70 8973.39 8973.80 8975.41 8977.07 8978.46 8979.09 8979.16 .7VJO.J`4 LIJ/.GO GVJV.IJ GIJJ.VI GvJV.VJ 9038.52 2164.08 2582.83 2178.14 2066.49 9038.85 2190.30 2614.99 2202.18 2095.99 9039.13 2216.21 2646.99 2226.11 2125.22 9039.18 2243.15 2680.29 2251.19 2155.62 9039.10 2269.44 2712.49 2275.91 2185.18 9039.00 2294.83 2743.79 2299.94 2213.80 9038.69 2320.88 2775.95 2324.77 2243.19 9039.10 2347.01 2807.83 2349.88 2272.52 9040.71 2373.48 2840.29 2375.47 9042.37 2398.70 2871.44 2400.01 9043.76 2424.73 2903.41 2425.48 9044.39 2450.42 2935.20 2450.77 9044.46 2475.10 2966.11 2475.21 8979.01 9044.31 8978.70 9044.00 8978.25 9043.55 8977.28 9042.58 8976.15 9041.45 91.29 336.29 8975. 32 9040.62 91 .06 334.98 8974. 67 9039.97 91 .06 334.52 8974. 08 9039.38 91 .30 334.16 8973. 42 9038.72 91 .43 335.20 8972. 67 9037.97 2501.18 2998.70 2501.18 2526.75 3030.40 2526.80 2552.62 3062.31 2552.84 2578.08 3093.68 2578.61 2604.33 3125.66 2605.29 2630.42 3157.45 2631.91 2656.03 3189.22 2658.20 2681.69 3221.42 2684.69 2706.88 3253.20 2710.83 2732.20 3284.99 2737.20 2302.30 2330.75 2360.05 2389.05 2417.04 2446.59 2475.48 2504.65 2533.34 2562.80 2592.07 2621.01 2650.13 2678.78 2707.52 688.40 675.59 662.57 648.97 636.21 623.54 610.47 597.98 585.07 572.38 559.58 546.56 533.47 519.71 506.66 493.72 481.04 468.59 456.20 443.09 429.35 415.59 402.00 14.16 5942914.86 1.64 5942944.03 5.02 5942972.93 4.36 5943002.98 0.38 5943032.21 3.80 5943060.51 3.91 5943089.56 10.65 5943118.57 5.42 5943148.02 1.90 5943176.16 2.66 5943205.13 8.19 5943233.79 0.23 5943261.45 2.65 5943290.65 3.37 5943319.21 2.40 5943348.04 4.13 5943376.42 5.08 5943405.55 4.96 5943434.51 4.19 5943463.11 1.43 5943491.89 1.36 5943520.19 3.30 5943548.58 11275.71 91.33 334.61 8971.90 9037.20 2757.50 3316.69 2763.67 2736.22 388.55 1.89 5943576.93 Last Survey 11308.01 91.43 334.30 8971.12 9036.42 2783.14 3348.98 2790.61 2765.35 374.63 1.01 5943605.71 TD (Projected) 11363.00 91.43 334.30 8969.75 9035.05 2826.68 3403.95 2836.66 2814.89 350.79 0.00 5943654.64 Survey Type: Definitive Survey NOTES: BOSS GYRO - (Sperry-Sun BOSS gyro multishot -- Sperry Sun BOSS multishot surveys ) GYD GC SS - (Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination.) MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Borehole -> Survev Legal Description: Northing (Y) fftUSl Easting (X) fftUSl Surface : 231 FSL 910 FEL S2 T10N R14E UM 5940832.13 686081.24 BHL : 3046 FSL 556 FEL S2 T10N R14E UM 5943654.64 686362.42 686718.37 N 70.24894523 W 148.49140979 686704.84 N 70.24902582 W 148.49151325 686691.10 N 70.24910568 W 148.49161839 686676.76 N 70.24918872 W 148.49172820 686663.27 N 70.24926949 W 148.49183128 686649.90 N 70.24934768 W 148.49193363 686636.12 N 70.24942796 W 148.49203913 686622.90 N 70.24950810 W 148.49214003 686609.26 N 70.24958945 W 148.49224433 686595.88 N 70.24966720 W 148.49234678 686582.36 N 70.24974724 W 148.492 686568.62 N 70.24982646 W 148.492 686554.84 N 70.24990293 W 148.49266111 686540.36 686526.60 686512.95 686499.56 686486.39 686473.28 686459.47 686445.02 686430.55 686416.25 N 70.24998367 W 148.49277224 N 70.25006260 W 148.49287765 N 70.25014228 W 148.49298214 N 70.25022068 W 148.49308459 N 70.25030115 W 148.49318514 N 70.25038113 W 148.49328524 N 70.25046017 W 148.49339108 N 70.25053975 W 148.49350205 N 70.25061802 W 148.49361322 N 70.25069653 W 148.49372304 686402.11 N 70.25077493 W 148.49383161 686387.47 N 70.25085453 W 148.49394409 686362.42 N 70.25098986 W 148.49413666 C~ SurveyEditor Ver SP 2.1 Bld( doc40x_100) 06-19\06-19\06-19A\06-19A Generated 8/12/2008 3:29 PM Page 5 of 5 WELLHEAD =, FMC GEN 3 ACTUATOR= AXELSON KB. EL1=.~l/ = 74' BE. ELEV = KOP = 5000' Max Angle = 95° ~ 90000' Datum MD = 051' 9 Datum TV D = _ _ 8800' SS 06-19* I L ~w~mrnum ~u = 3.7z~.. ~, ~~~~~ -112'" XN Nipple 219$" -~4-1 t2" X Nipple, ID = 3.8'f3" 2514' 13-318" CSG, 72#, L-80, ID = 1 $~,}" --~ Planned 'fUG 484r ~s ............~~ 4847' 7" Tieback, 26# L-80 / ° ___ 4$48' 9-518" x 7" Liner Top Packer ...5000' KOP $1025' 9-518" BK12 Whipstock -....~ 5x30' s-518^ Ezsv GAS ul=-rn~Ar~D~a.s 5302' TOP OF 4-1/2" TBGICut TOC 5319' 8620' 1-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION sL)tfARr Revisan after sidetrack A NGLE AT TOP PERF: 88 ~ 10250' Note' Reter to Production DB for historical perf data SIZE SPF INTERVAL flpntSgz DATE. 2 718" S 10250 - 10380 Open 07115P08 2 718" 8 111420 - 10620 ripen 07/15/08 2 718"' 6 10780 - 10930 open 07!15108 2 718" 6 10980 - 11270 Open 07115108 11363' -°4112" LNR, 12.8# L-$0..0152 bpf, ID = 3.958" DATE REV BY COM1~11ENTS C1ATE REV 08M9/82 ()i~GltilAL GOMPLETIflf~E 05/06196 LAST WORKOVl37 U7l15/08 ME5 RWO PRUDHOE SAY UNIT WELL. 06-19A f'ERMfT` Na: 9 82114€1 API Na: 50-029-20791-01 SEC 2, T10N, R14E, 211.23 FEL 5271 84 FNL ST N1D TYD DEV TYPE VLV LATCH PORT DATE 4 3476 8478 0 KBG2 DCIC BEK 1" '07115108 3 5886 5677' 17 KBG2 DMY BK 1" 0711'5/08 2 7222 7134 12 KBG2 [7M1' BK 1" .07115108 1 8297 8185 11 KBG2 DMY BK' 1" 07f15l08 837" 4112" HES X NIP, ID ° 3.813" 8486• --r7" X 41l2" BKR S-3 PKR 8440` 4112" HES X NIP ID = 3.813" 8513' 4112" HES XN NIP, ID - 3.725" r $526' ~ 1I2', 12.6#, 13CR, ID = 3.958" .,,,^ $;`' " x 7" finer Hanger 8689' 7" GSG, 26# L-80, .0226 bpf, ID = 6.278" ~ ExplaralQn (Alaska) W t ~y t SCHLUMBERGER Survey report Client .................... Field ..................... Well ...................... API number ................ Engineer .................. COUNTY :................... STATE :.................... ----- Survey calculation m Method for positions.....: Method for DLS............ BP Exploration (Alaska) Inc. Prudhoe Bay 06-19A 50-029-20791-01 W. Nicoll NSB Alaska ethods------------- Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Depth GL above permanent.......: 36.90 ft KB above permanent.......: N/A Topdrive DF above permanent.......: 65.30 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft Azimuth from Vsect Origin to target: 11.91 degrees [(c)2008 IDEAL ID13_OC_08] 12-Jul-2008 08:21:19 Page 1 of 7 Spud date ................. 30-Jun-08 Last survey date.........: 12-Jul-08 Total accepted surveys...: 178 MD of first survey.......: 0.00 ft MD of last survey........: 11363.0.0 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2007 Magnetic date ............: 07-Jul-2008 Magnetic field strength..: 57679.64 GAMA Magnetic dec (+E/W-).....: 23.23 degrees Magnetic dip .............: 80.91 degrees ----- MWD survey Reference Criteria --------- Reference G ..............: 1002.67 meal Reference H ..............: 57679.00 GAMA Reference Dip ............: 80.91 degrees Tolerance of G...........: (+/-) 2.50 meal Tolerance of H...........: (+/-)300.00 GAMA Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.24 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.24 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • SCHLUMBERGER Survey Report 12 -Jul-2008 08:21:19 Page 2 of 7 ___ Seq ________ Measured ______ Incl ------- Azimuth ------ Course -------- TVD -------- Vertical -----p Dis 1 Dis 1 p Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 -------- 0.00 --- 0.00 0.00 0.00 0.00 0.00 0.00 BP_ UNKNOWN 2 28.30 0.00 0.00 28.30 28.30 0.00 0.00 0.00 0.00 0.00 0.00 BP_ UNKNOWN 3 91.30 0.27 246.00 63.00 91.30 -0.09 -0.06 -0.14 0.15 246.00 0.43 BP_ BOSS GYRO 4 191.30 0.30 230.80 100.00 191.30 -0.43 -0.32 -0.55 0.64 239.85 0.08 BP_ BOSS GYRO 5 291.30 0.47 211.10 100.00 291.30 -1.02 -0.84 -0.97 1.28 229.12 0.21 BP_ BOSS GYRO 6 391.30 0.73 214.39 100.00 391.29 -2.00 -1.72 -1.54 2.31 221.92 0.26 BP_ BOSS GYRO 7 491.30 1.08 229.50 100.00 491.28 -3.33 -2.85 -2.62 3.87 222.53 0.42 BP_ BOSS GYRO 8 591.30 0.68 232.39 100.00 591.27 -4.53 -3.83 -3.80 5.40 224.82 0.40 BP_ BOSS GYRO 9 691.30 0.45 258.89 100.00 691.26 -5.13 -4.26 -4.66 6.32 227.53 0.34 BP_ BOSS GYRO 10 791.30 0.55 223.80 100.00 791.26 -5.70 -4.69 -5.38 7.13 228.92 0.32 BP_ BOSS GYRO 11 891.30 0.25 287.00 100.00 891.26 -6.08 -4.97 -5.92 7.73 229.97 0.49 BP_ BOSS GYRO 12 991.30 0.45 11.89 100.00 991.25 -5.67 -4.52 -6.04 7.55 233.20 0.49 BP_ BOSS GYRO 13 1091.30 0.05 13.10 100.00 1091.25 -5.24 -4.09 -5.95 7.23 235.48 0.40 BP_ BOSS GYRO 14 1191.30 0.32 321.61 100.00 1191.25 -5.01 -3.83 -6.12 7.22 237.93 0.29 BP_ BOSS GYRO 15 1291.30 0.15 349.90 100.00 1291.25 -4.71 -3.49 -6.31 7.21 241.10 0.20 BP _BOSS GYRO 16 1391.30 0.05 207.30 100.00 1391.25 -4.63 -3.40 -6.36 7.21 241.89 0.19 BP _BOSS GYRO 17 1491.30 0.23 136.81 100.00 1491.25 -4.79 -3.58 -6.24 7.19 240.15 0.22 BP _BOSS GYRO 18 1591.30 0.38 89.50 100.00 1591.25 -4.83 -3.72 -5.77 6.87 237.16 0.28 BP _BOSS GYRO 19 1691.30 0.48 130.31 100.00 1691.25 -4.96 -3.99 -5.12 6.49 232.05 0.31 BP _BOSS GYRO 20 1791.30 0.38 80.89 100.00 1791.24 -5.04 -4.21 -4.47 6.14 226.73 0.37 BP _BOSS GYRO 21 1891.30 0.42 176.11 100.00 1891.24 -5.28 -4.52 -4.12 6.12 222.33 0.59 BP _BOSS GYRO 22 1991.30 0.40 227.10 100.00 1991.24 -5.91 -5.13 -4.35 6.72 220.32 0.35 BP _BOSS GYRO 23 2091.30 0.67 233.39 100.00 2091.24 -6.64 -5.71 -5.08 7.64 221.62 0.28 BP _BOSS GYRO 24 2191.30 0.65 290.70 100.00 2191.23 -6.99 -5.86 -6.08 8.44 226.03 0.63 BP _BOSS GYRO 25 2291.30 0.57 264.60 100.00 2291.23 -7.05 -5.71 -7.10 9.11 231.21 0.29 BP _BOSS GYRO 26 2391.30 0.28 223.39 100.00 2391.22 -7.41 -5.93 -7.77 9.77 232.62 0.40 BP _BOSS GYRO 27 2491.30 0.55 203.39 100.00 2491.22 -8.09 -6.55 -8.12 10.44 231.12 0.30 BP _BOSS GYRO 28 2591.30 0.07 204.89 100.00 2591.22 -8.62 -7.05 -8.34 10.92 229.80 0.48 BP _BOSS GYRO 29 2691.30 0.55 209.19 100.00 2691.22 -9.13 -7.52 -8.60 11.42 228.83 0.48 BP _BOSS GYRO 30 2791.30 0.50 190.30 100.00 2791.21 -10.03 -8.37 -8.91 12.23 226.80 0.18 BP _BOSS GYRO [(c)2008 IDEAL ID13_OC_08] SCHLUMBERGER Survey Report 12 -Jul-2008 08:21:19 Page 3 of 7 --- Seq -------- Measured ------ Incl ------- Azimuth ------ Course -------- TVD -------- Vertical -----p--- Dis 1 - p Dis 1 Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 31 -------- 2891.30 ------ 0.32 ------- 216.89 ------ 100.00 -------- 2891.21 -------- -10.72 ----- -9.02 -9.16 12.85 225.43 0.26 BP_ BOSS GYRO 32 2991.30 0.37 192.19 100.00 2991.21 -11.29 -9.56 -9.39 13.40 224.49 0.16 BP_ BOSS GYRO 33 3091.30 0.10 25.80 100.00 3091.21 -11.53 -9.80 -9.42 13.59 223.88 0.47 BP_ BOSS GYRO 34 3191.30 0.45 170.50 100.00 3191.21 -11.81 -10.11 -9.32 13.75 222.68 0.53 BP_ BOSS GYRO 35 3291.30 0.47 148.90 100.00 3291.20 -12.48 -10.84 -9.04 14.12 219.83 0.17 BP_ BOSS GYRO 36 3391.30 0.33 168.70 100.00 3391.20 -13.04 -11.48 -8.78 14.45 217.40 0.19 BP_ BOSS GYRO 37 3491.30 0.52 160.31 100.00 3491.20 -13.69 -12.19 -8.57 14.90 215.10 0.20 BP_ BOSS GYRO • 38 3591.30 0.60 162.70 100.00 3591.19 -14.54 -13.12 -8.26 15.50 212.19 0.08 BP_ BOSS GYRO 39 3691.30 0.10 148.70 100.00 3691.19 -15.06 -13.69 -8.06 15.88 210.48 0.50 BP_ BOSS GYRO 40 3791.30 0.47 152.11 100.00 3791.19 -15.44 -14.13 -7.82 16.15 208.96 0.37 BP_ BOSS GYRO 41 3891.30 0.50 172.70 100.00 3891.19 -16.16 -14.92 -7.57 16.73 206.90 0.18 BP_ BOSS GYRO 42 3991.30 0.33 143.31 100.00 3991.18 -16.77 -15.59 -7.34 17.23 205.23 0.27 BP_ BOSS GYRO 43 4091.30 0.90 166.11 100.00 4091.18 -17.66 -16.58 -6.98 17.99 202.84 0.61 BP_ BOSS GYRO 44 4191.30 1.08 173.50 100.00 4191.16 -19.26 -18.28 -6.69 19.46 200.10 0.22 BP_ BOSS GYRO 45 4291.30 0.42 141.50 100.00 4291.15 -20.39 -19.50 -6.35 20.51 198.05 0.76 BP_ BOSS GYRO 46 4391.30 1.00 174.20 100.0.0 4391.15 -21.46 -20.66 -6.04 21.52 196.29 0.69 BP _BOSS GYRO 47 4491.30 1.57 122.50 100.00 4491.12 -22.77 -22.26 -4.79 22.77 192.15 1.23 BP _BOSS GYRO 48 4591.30 1.32 79.39 100.00 4591.09 -22.81 -22.78 -2.51 22.92 186.28 1.09 BP _BOSS GYRO 49 4691.30 1.40 122.11 100.00 4691.07 -22.79 -23.22 -0.34 23.22 180.84 0.99 BP _BOSS GYRO 50 4791.30 1.30 111.90 100.00 4791.04 -23.41 -24.29 1.75 24.36 175.89 0.26 BP _BOSS GYRO 51 4891.30 1.25 128.31 100.00 4891.02 -24.09 -25.39 3.66 25.66 171.81 0.37 BP _BOSS GYRO . 52 4991.30 1.25 125.31 100.00 4990.99 -25.01 -26.70 5.40 27.24 168.56 0.07 BP _BOSS GYRO 53 5005.00 1.26 126.32 13.70 5004.69 -25.13 -26.88 5.65 27.46 168.14 0.18 BP _BOSS GYRO 54 5021.00 3.00 121.90 16.00 5020.68 -25.35 -27.20 6.14 27.89 167.27 10.92 BP _BLIN D 55 5031.00 2.01 121.90 10.00 5030.67 -25.50 -27.43 6.51 28.19 166.64 9.90 BP _GYD SS 56 5124.00 3.06 359.62 93.00 5123.62 -23.63 -25.81 7.88 26.99 163.02 4.81 BP _GYD SS 57 5221.00 4.09 332.77 97.00 5220.44 -18.42 -20.15 6.28 21.10 162.68 2.00 BP _GYD SS 58 5318.00 6.28 351.31 97.00 5317.04 -10.76 -11.82 3.90 12.45 161.76 2.81 BP _GYD SS 59 5346.07 6.91 350.49 28.07 5344.92 -7.76 -8.64 3.39 9.28 158.60 2.27 BP _MWD+ IFR+MS 60 5439.87 9.75 5.33 93.80 5437.73 5.39 4.84 3.19 5.80 33.43 3.77 BP _MWD+ IFR+MS [(c)2008 IDEAL ID13_OC_08] SCHLUMBERGER Survey Report 12 -Jul-2008 08:21:19 Page 4 of 7 --- Seq -------- Measured ------ Incl ------- Azimuth ------ Course -------- TVD -------- Vertical -----p-- Dis 1 Dis 1 p Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 61 -------- 5534.64 ------ 13.13 ------- 15.15 ------ 94.77 -------- 5530.62 -------- 24.12 23.22 6.75 24.19 16.21 4.10 BP_ MWD+IFR+MS 62 5631.25 15.51 24.62 96.61 5624.23 47.68 45.56 15.00 47.97 18.23 3.45 BP_ MWD+IFR+MS 63 5726.41 17.42 35.49 95.16 5715.51 73.15 68.74 28.58 74.44 22.58 3.80 BP_ MWD+IFR+MS 64 5821.50 18.89 47.32 95.09 5805.89 98.76 90.77 48.17 102.76 27.95 4.16 BP_ MWD+IFR+MS 65 5920.52 20.05 57.07 99.02 5899.27 123.80 110.87 74.20 133.41 33.79 3.48 BP_ MWD+IFR+MS 66 6014.85 19.78 61.39 94.33 5987.97 145.57 127.30 101.79 162.99 38.65 1.59 BP_ MWD+IFR+MS 67 6108.37 20.09 62.29 93.52 6075.88 166.09 142.35 129.90 192.71 42.38 0.47 BP_ MWD+IFR+MS 68 6205.60 19.92 61.93 97.23 6167.25 187.38 157.91 159.30 224.30 45.25 0.22 BP_ MWD+IFR+MS 69 6299.44 20.55 61.07 93.84 6255.29 208.43 173.40 187.82 255.62 47.29 0.74 BP_ MWD+IFR+MS 70 6395.67 21.34 60.77 96.23 6345.16 230.99 190.12 217.88 289.17 48.89 0.83 BP_ MWD+IFR+MS 71 6484.13 20.65 64.03 88.46 6427.75 251.16 204.81 245.95 320.06 50.22 1.53 BP_ MWD+IFR+MS 72 6586.60 20.18 63.90 102.47 6523.79 273.14 220.50 278.07 354.88 51.59 0.46 BP_ MWD+IFR+MS 73 6682.84 19.88 63.64 96.24 6614.21 293.49 235.07 307.64 387.17 52.62 0.33 BP_ MWD+IFR+MS 74 6777.41 18.35 62.70 94.57 6703.56 312.86 249.03 335.28 417.65 53.40 1.65 BP_ MWD+IFR+MS 75 6874.03 16.59 61.68 96.62 6795.72 331.39 262.55 360.94 446.33 53.97 1.85 BP_ MWD+IFR+M5 76 6969.94 14.35 63.28 95.91 6888.15 347.65 274.39 383.61 471.64 54.42 2.38 BP_ MWD+IFR+MS 77 7066.30 12.35 61.28 96.36 6981.90 361.82 284.72 403.31 493.69 54.78 2.13 BP_ MWD+IFR+MS 78 7161.36 12.01 66.92 95.06 7074.82 374.11 293.48 421.33 513.47 55.14 1.30 BP _MWD+IFR+MS 79 7256.27 11.33 67.28 94.91 7167.77 385.07 300.95 439.01 532.26 55.57 0.72 BP _MWD+IFR+MS 80 7352.25 12.00 69.33 95.98 7261.77 395.80 308.11 457.04 551.20 56.01 0.82 BP _MWD+IFR+MS 81 7447.29 11.13 70.19 95.04 7354.88 405.95 314.71 474.92 569.73 56.47 0.93 BP _MWD+IFR+MS 82 7543.56 11.29 66.62 96.27 7449.31 416.28 321.60 492.31 588.04 56.85 0.74 BP _MWD+IFR+MS 83 7638.97 12.84 60.35 95.41 7542.62 428.71 330.55 510.10 607.84 57.06 2.13 BP _MWD+IFR+MS 84 7735.15 13.04 60.45 96.18 7636.36 442.98 341.19 528.83 629.34 57.17 0.21 BP _MWD+IFR+MS 85 7830.27 13.08 64.78 95.12 7729.02 456.58 351.07 547.90 650.72 57.35 1.03 BP _MWD+IFR+MS 86 7925.87 14.65 65.90 95.60 7821.83 470.22 360.61 568.72 673.41 57.62 1.67 BP _MWD+IFR+MS 87 8022.17 13.17 65.60 96.30 7915.30 483.88 370.12 589.83 696.34 57.89 1.54 BP _MWD+IFR+MS 88 8117.46 10.52 63.97 95.29 8008.56 495.66 378.42 607.54 715.75 58.08 2.80 BP _MWD+IFR+MS 89 8211.86 10.29 65.19 94.40 8101.40 506.00 385.74 622.93 732.70 58.23 0.34 BP _MWD+IFR+MS 90 8308.22 11.22 68.23 96.36 8196.07 516.34 392.83 639.45 750.48 58.44 1.13 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_08] SCHLiIMBERGER Survey Report 12-Jul-2008 08:21:19 Page 5 of 7 --- Seq -------- Measured ------ Incl ------- Azimuth ------ Course -------- TVD ----- Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 91 -------- 8403.52 ------ 11.61 ------- 64.04 ---- 95.30 8289.49 527.37 400.47 656.68 769.16 58.62 0.96 BP _MWD+IFR+MS 92 8498.93 13.15 60.37 95.41 8382.68 540.46 410.04 674.75 789.57 58.71 1.81 BP _MWD+IFR+MS 93 8594.49 15.09 57.07 95.56 8475.35 556.44 422.17 694.64 812.87 58.71 2.20 BP _MWD+IFR+MS 94 8625.82 15.16 57.07 31.33 8505.59 562.21 426.62 701.50 821.04 58.69 0.22 BP _MWD+IFR+MS 95 8702.20 15.97 57.00 76.38 8579.17 576.67 437.77 718.70 841.53 58.65 1.06 BP _INC+TREND 96 8734.24 20.93 39.08 32.04 8609.58 584.88 444.62 726.01 851.34 58.52 23.35 BP _MWD+IFR+MS 97 8766.30 24.86 30.08 32.06 8639.12 596.39 454.91 733.01 862.69 58.18 16.39 BP _MWD+IFR+MS 98 8797.88 28.55 22.30 31.58 8667.33 610.13 467.64 739.20 874.70 57.68 16.08 BP _MWD+IFR+MS 99 8829.47 34.02 13.99 31.59 8694.33 626.40 483.22 744.21 887.33 57.00 22.02 BP _MWD+IFR+MS 100 8861.83 36.27 12.35 32.36 8720.79 645.02 501.36 748.44 900.85 56.18 7.54 BP _MWD+IFR+MS 101 8893.15 36.48 11.19 31.32 8746.01 663.60 519.54 752.23 914.21 55.37 2.30 BP _MWD+IFR+MS 102 8925.78 36.00 5.55 32.63 8772.33 682.83 538.61 755.04 927.46 54.50 10.32 BP _MWD+IFR+MS 103 8958.00 36.83 356.76 32.22 8798.28 701.58 557.69 755.41 938.97 53.56 16.39 BP _MWD+IFR+MS 104 8988.87 43.27 353.62 30.87 8821.90 720.58 577.46 753.71 949.50 52.54 21.86 BP _MWD+IFR+MS 105 9020.17 45.56 353.55 31.30 8844.26 741.37 599.23 751.27 960.97 51.42 7.32 BP _MWD+IFR+MS 106 9052.91 49.16 351.84 32.74 8866.43 764.10 623.11 748.19 973.68 50.21 11.65 BP _MWD+IFR+MS 107 9083.64 51.62 353.23 30.73 8886.02 786.44 646.58 745.12 986.55 49.05 8.73 BP _MWD+IFR+MS 108 9116.74 54.39 352.90 33.10 8905.94 811.45 672.82 741.93 1001.57 47.80 8.41 BP _MWD+IFR+MS 109 9147.66 60.88 353.61 30.92 8922.48 836.19 698.74 738.87 1016.94 46.60 21.08 BP _MWD+IFR+MS 110 9180.10 63.77 358.69 32.44 8937.55 863.82 727.39 736.96 1035.47 45.37 16.48 BP _MWD+IFR+MS 111 9215.54 65.16 2.45 35.44 8952.83 895.17 759.36 737.28 1058.40 44.15 10.34 BP _MWD+IFR+MS • 112 9244.85 65.53 3.36 29.31 8965.06 921.48 785.96 738.63 1078.57 43.22 3.09 BP _MWD+IFR+MS 113 9276.81 65.18 2.96 31.96 8978.39 950.19 814.97 740.23 1100.96 42.25 1.58 BP _MWD+IFR+MS 114 9309.59 71.05 1.46 32.78 8990.60 980.16 845.35 741.40 1124.41 41.25 18.40 BP _MWD+IFR+MS 115 9340.70 77.18 1.94 31.11 8999.11 1009.59 875.24 742.29 1147.63 40.30 19.76 BP _MWD+IFR+MS 116 9363.87 82.61 2.70 23.17 9003.18 1032.08 898.03 743.21 1165.68 39.61 23.66 BP _MWD+IFR+MS 117 9394.47 86.69 0.72 30.60 9006.03 1062.05 928.47 744.12 1189.86 38.71 14.81 BP _MWD+IFR+MS 118 9426.47 83.81 2.80 32.00 9008.68 1093.44 960.34 745.10 1215.49 37.81 11.09 BP _MWD+IFR+MS 119 9458.77 84.64 3.63 32.30 9011.93 1125.20 992.43 746.90 1242.08 36.97 3.62 BP _MWD+IFR+MS 120 9487.77 84.86 1.24 29.00 9014.58 1153.69 1021.28 748.13 1265.98 36.22 8.24 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_08] SCHLUMBERGER Survey Report 12-Jul-2008 08:21:19 Page 6 of 7 --- Seq -------- Measured ------ Incl ------- Azimuth ------ Course -------- TVD -------- Vertical ------ Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 121 -------- 9522.13 ------ 84.78 ------- 0.28 ------ 34.36 ------- 9017.69 1187.26 1055.49 748.58 1294.00 35.35 2.79 BP _MWD+IFR+MS 122 9554.43 84.71 0.20 32.30 9020.64 1218.76 1087.66 748.72 1320.44 34.54 0.33 BP _MWD+IFR+MS 123 9586.13 84.99 359.68 31.70 9023.49 1249.64 1119.23 748.68 1346.55 33.78 1.86 BP _MWD+IFR+MS 124 9617.53 84.54 0.22 31.40 9026.35 1280.23 1150.50 748.66 1372.64 33.05 2.23 BP _MWD+IFR+MS 125 9649.53 84.79 0.33 32.00 9029.33 1311.44 1182.36 748.81 1399.53 32.35 0.85 BP _MWD+IFR+MS 126 9681.23 84.99 0.34 31.70 9032.15 1342.37 1213.93 748.99 1426.40 31.67 0.63 BP _MWD+IFR+MS 127 9713.13 85.47 0.41 31.90 9034.81 1373.52 1245.72 749.20 1453.66 31.02 1.52 BP _MWD+IFR+MS 128 9744.83 86.37 0.64 31.70 9037.06 1404.52 1277.34 749.49 1480.99 30.40 2.93 BP _MWD+IFR+MS 129 9776.33 86.61 0.37 31.50 9038.99 1435.34 1308.78 749.77 1508.33 29.81 1.15 BP _MWD+IFR+MS 130 9809.63 86.78 0.25 33.30 9040.91 1467.90 1342.02 749.95 1537.35 29.20 0.62 BP _MWD+IFR+MS 131 9841.93 88.80 359.75 32.30 9042.16 1499.48 1374.30 749.95 1565.60 28.62 6.44 BP _MWD+IFR+MS 132 9873.03 93.27 0.31 31.10 9041.59 1529.90 1405.38 749.96 1592.97 28.09 14.48 BP _MWD+IFR+MS 133 9904.23 94.29 0.13 31.20 9039.54 1560.39 1436.52 750.08 1620.56 27.57 3.32 BP _MWD+IFR+MS 134 9936.43 94.60 0.43 32.20 9037.04 1591.83 1468.62 750.24 1649.15 27.06 1.34 BP _MWD+IFR+MS 135 9967.83 94.40 359.41 31.40 9034.58 1622.45 1499.92 750.20 1677.07 26.57 3.30 BP _MWD+IFR+MS 136 9999.83 137 10032.83 138 10063.43 139 10096.63 140 10128.63 141 10159.83 142 10191.63 143 10222.63 144 T0255.03 145 10287.53 146 10319.83 147 10351.13 148 10382.33 149 10413.93 150 10445.33 [(c)2008 IDEAL ID13_OC_08] 94.84 359.75 93.16 359.62 90.48 358.91 88.26 357.56 89.08 359.24 88.60 358.78 87.71 357.29 88..12 356.46 87.57 357.59 87.29 355.69 88.60 354.54 90.28 352.91 89.21 352.39 89.28 349.01 89.83 345.79 32.00 9032.00 33.00 9029.70 30.60 9028.73 33.20 9029.09 32.00 9029.84 31.20 9030.47 31.80 9031.49 31.00 9032.62 32.40 9033.84 32.50 9035.29 32.30 9036.45 31.30 9036.76 31.20 9036.90 31.60 9037.31 31.40 9037.56 1653.61 1531.82 1685.79 1564.73 1715.62 1595.31 1747.88 1628.49 1778.98 1660.47 1809.39 1691.66 1840.25 1723.42 1870.16 1754.35 1901.45 1786.69 1932.77 1819.10 1963.67 1851.26 1993.41 1882.37 2022.86 1913.31 2052.31 1944.49 2080.88 1975.13 BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS 749.96 1705.55 749.78 1735.10 749.39 1762.56 748.37 1792.22 747.47 1820.95 746.93 1849.22 745.84 1877.89 744.16 1905.66 742.48 1934.82 740.57 1964.07 737.82 1992.87 734.40 2020.56 730.41 2047.99 725.31 2075.36 718.46 2101.74 26.09 1.74 25.60 5.11 25.16 9.06 24.68 7.83 24.24 5.84 23.82 2.13 23.40 5.46 22.99 2.98 22.57 3.88 22.15 5.90 21.73 5.40 21.31 7.48 20.89 3.81 20.46 10.70 19.99 10.40 C~ • SCHLUMBERGER Survey Report 12-Jul-2008 08:21:19 Page 7 of 7 --- Seq -------- Measured ------ Incl ------- Azimuth ------ Course -------- TVD ------ Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 151 -------- 10478.23 ------ 88.76 ------- 343.47 ------ 32.90 -------- 9037.96 2110.12 2006.84 709.74 2128.65 19.48 7.76 BP_MWD+IFR+MS 152 10509.53 89.87 340.80 31.30 9038.34 2137.28 2036.63 700.14 2153.61 18.97 9.24 BP_MWD+IFR+MS 153 10541.63 89.48 336.27 32.10 9038.52 2164.08 2066.49 688.40 2178.14 18.42 14.16 BP_MWD+IFR+MS 154 10573.79 89.34 336.78 32.16 9038.85 2190.30 2095.99 675.59 2202.18 17.87 1.64 BP_MWD+IFR+MS 155 10605.79 89.68 335.21 32.00 9039.13 2216.21 2125.22 662.57 2226.11 17.32 5.02 BP_MWD+IFR+MS 156 10639.09 157 10671.29 158 10702.59 159 10734.75 160 10766.64 161 10799.14 162 10830.34 163 10862.34 164 10894.14 165 10925.04 166 10957.64 167 109.89.34 168 11021.25 169 11052.64 170 11084.64 171 11116.44 172 11148.21 173 11180.42 174 11212.21 175 11244.01 176 11275.71 177 11308.01 178 11363.00 90.13 336.59 90.16 336.71 90.20 335.52 90.92 336.55 87.61 337.31 86.70 335.80 87.18 336.15 87.87 336.65 89.86 334.97 89.86 334.90 90.68 335.17 90.44 336.21 91.16 335.95 92.39 336.36 91.67 337.82 91.29 336.29 91.06 334.98 91.06 334.52 91.30 334.16 91.43 335.20 91.33 334.61 91.43 334.30 91.43 334.30 33.30 9039.18 2243.15 2155.62 32.20 9039.10 2269.44 2185.18 31.30 9039.00 2294.83 2213.80 32.16 9038.69 2320.88 2243.19 31.89 9039.10 2347.01 2272.52 32.50 9040.71 2373.48 2302.30 31.20 9042.37 2398.70 2330.75 32.00 9043.76 2424.73 2360.05 31.80 9044.39 2450.42 2389.05 30.90 9044.46 2475.10 2417.04 32.60 9044.31 2501.18 2446.59 31.70 9044.00 2526.75 2475.48 31.91 9043.55 2552.62 2504.65 31.39 9042.58 2578.08 2533.34 32.00 9041.45 2604.33 2562.80 31.80 9040.63 2630.42 2592.07 31.77 9039.97 2656.03 2621.01 32.21 9039.38 2681.69 2650.13 31.79 9038.72 2706.88 2678.78 31.80 9037.97 2732.20 2707.52 31.70 9037.20 2757.50 2736.22 32.30 9036.42 2783.14 2765.35 54.99 9035.05 2826.68 2814.89 648.97 2251.19 636.21 2275.91 623.54 2299.94 610.47 2324.77 597.98 2349.88 585.07 2375.47 572.38 2400.01 559.58 2425.48 546.56 2450.77 533.47 2475.21 519.71 2501.18 506.66 2526.80 493.72 2552.84 481.04 2578.61 468.59 2605.28 456.19 2631.91 443.09 2658.20 429.35 2684.69 415.59 2710.83 402.00 2737.20 388.55 2763.67 374.63 2790.61 350.79 2836.66 16.75 16.23 15.73 15.22 14.74 14.26 13.80 13.34 12.89 12.45 11.99 11.57 11.15 10.75 10.36 9.98 9.60 9.20 8.82 8.45 8.08 7.72 7.10 4.36 0.38 3.80 3.91 10.65 5.42 1.90 2.66 8.19 0.23 2.65 3.37 2.40 4.13 5.08 4.96 4.19 1.43 1.36 3.29 1.89 1.01 0.00 BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS Project to TD ~~ [(c)2008 IDEAL ID13_OC_08] L~ Drilling & Measurements MWD/LWD Log Product Delivery Customer Well No Installation/Rig BP Exploration (Alaska) Inc. 06-19A Nabors 7ES Dispatched To: Date Dispatched: Dispatched By: Christine Mahnken (AOGCC) 16-J u I-08 F. Medina Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: James H. Jonnson ReCelved By: BP Exploration (Alaska) Inc. 1 ~ ~ ~ Petrotechnical Data Center (LR2-1) /Z. l1-~ ~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhC~3bp.com LWU LOg UeIIVery VL.I, U3-U6-Ub a~8 - (~~ L~ 6 SARAH PALIN, GOVERNOR CUI~SEB~0 C ~ I~ 333 W. 7th AVENUE, SUITE 100 ii~~ ANCHORAGE, ALASKA 99501-3539 / PHONE (907) 279-1433 Greg Hobbs FAX (so7) z7sas4z Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-19A BP Exploration Alaska Inc. Permit No: 208-102 Surface Location: 231' FSL, 910' FEL, SEC. 02, T10N, R14E, UM Bottomhole Location: 3065' FSL, 298' FEL, SEC. 02, T10N, R14E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill 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 iri 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 speci$cally 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). cerely, Daniel T. Seamount, Jr. c~y~ Chair DATED this! day of June, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~ ~":~ ,_ STATE OF ALASKA 6-I~D~ ~~~~ U ~ ~ ~. 2~~$ ALAS~IL AND GAS CONSERVATION COMMI~N ~ ~`~ PERMIT TO DRILL ,~,~~~~~;~ ~};~ g~ ~~~, C~rrs. Com~h~;~+~n 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 06-19A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11289' TVD 9056' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028311 Pool FEL, SEC. 02, T10N, R14E, UM FSL, 910 231 Top of Productive Horizon: R14E, UM 136' FEL SEC. 02 T10N 1276' FSL 8. Land Use Permit: 13. Approximate Spud Date: June 26, 2008 , , , , Total Depth: 3065' FSL, 298' FEL, SEC. 02, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 37,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-686081 y-5940833 Zone-ASP4 10. KB Elevation (Height above GL): 28.5' feet 15. Distance to Nearest Well Within Pool: 25.6' 16. Deviated Wells: Kickoff Depth: 5000 feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3300 Surface: 2420 18 Casin Pr ram: S ecificatio ns To -Settin De th -Bo ttom uantit of Cement c.f. or sa` ks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 3683' 5000' 5000' 8683' 8574' 227 sx LiteCrete 169 sx Class'G' Tieback 7" 26# L-80 TC-II 5000' Surface Surface 5000' 5000' 232 sx Class'G' 6-1/8" 4-1/2" 12.6# 1 r Vam To 275 ' 8533' 842 ' 112 9056' 17 x Cla 'G' 19. PRESE NT' WELL CONDITION S UMMARY (To be completed for Redrill and Reentry Operations) Total Depth MD (ft): 9322' Total Depth TVD (ft): 9219' Plugs (measured): 8221' Effective Depth MD (ft): 9272' Effective Depth TVD (ft): 9172' Junk (measured): None asing Length' ize Cement Volume MD TVD Conductor /Structural 80' 20" 2150# Poleset 80' 0' Surface 2514' 13-3/8" 2300 sx Fondu 400 sx Permafrost'C' 2514' 2514' Intermediate 8620' 9-5/8" 500 sx Class'G' 300 sx Permafrost'C' 8620' 8554' Producti n Liner 985' 7" 350 sx Class'G' 8330' - 9315' 8276' - 9213' Perforation Depth MD (ft): Below WRP: 8945' - 9144' Perforation Depth TVD (ft): 8862' - 9051' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the fore ing is true and correct. Contact Jovy Roach, 564-4352 Printed Name Gre s Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4191 Date /~ Terrie Hubble, 564-4628 Commission'Use Onl Permit To Drill Number:d?D~'fOa?O API Number: 50-029-20791-01-00 Permit Approv I See cover letter for Da e: ~ otherr uir ments Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed me11thane, gas hydrates, or gas contained shales: Samples Req'd: ~ Yes NJ No Mud Log Req'd: ~ Yes ~ No HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: 7~~®~ y~ * ~'(~~ ~ ~ ~, /~ APPROVED BY THE COMMISSION (O Date ,COMMISSIONER Form 10-401 `Ftev`ise~12/~05 Submit In Duplicate ~~~~'Il~r~'L!1 by • • To: Alaska Oil & Gas Conservation Commission From: Jovy Roach, ODE Date: June 12, 2008 Re: 06-19A Sidetrack Permit to Drill The 06-19A well is scheduled to be drilled by Nabors Rig 7ES which is currently scheduled to move onto the location ~ 07/02/08. The plan is to exit the parent 06-19 wellbore from the 9-5/8" casing at ~ 5000' MD with an 8- 1/2" BHA. The 8-1/2" hole will then be drilled to the top of the Sag River formation where a 7" drilling liner will be run and cemented. A 7" tieback to surface will be run and cemented to 3500'. A 6-1/8" hole will then be drilled building to horizontal in the Ivishak Zone 2B. The planned well then runs horizontally for approximately -- 1923' to a final well TD at 11,323' MD. A solid 4-1/2" production liner will be run and cemented in place. Please reference Sundry number 308-199 for P&A. Waiver Request: 1. If the lower set of rams cannot be tested during the primary BOP test (due to the proximity to the test plug), that set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Please note the following Well Summary as detailed on the next few pages. 06-19A Permit to Drill Application Page 1 Well Name: 06-19A Planned Well Summary Well 06-19A Well Horizontal Target Zone T e Sidetrack Ob'ective 2B API Number: 50-029-20791-01 Current Status 06-19 Shut-In and P&A Procedures commencing Estimated Start Date: 02 Jul 08 Time to Com lete: 25 Da s Surface Northin Eastin Offsets TRS Location 5,940,832 686,081 231' FSL / 910' FEL T10N, R14E, 02, UM Northin Eastin Offsets TRS Target 5,941,896 686,828 1276' FSL / 136' FEL T10N, R14E, 02 Locations 5,942,558 686,821 1938' FSL / 126' FEL T10N, R14E, 02 Bottom Northin Eastin Offsets TRS Location 5,943,680 686,620 3065' FSL / 298' FEL T10N, R14E, 02 Planned KOP: 5000'MD / 5000'TVDss Planned TD: 11,289'MD / 9,056' TVDss Ri Nabors 7ES RT-GL: 28.2' RT-BF: 25.65' Directional - Schlumberger P5 KOP: 5000' MD Maximum Hole Angle: 14.46° sail angle in the 8-1/2" intermediate section 89.94° in the 6-1/8" horizontal section Close Approach Wells: All wells on the pad pass major risk criteria for close approach except for 06-23. See Anti-Collision section on a e 5. Surve Pro ram: MWD Standard + Gyro for orienting whipstock + IIFR + MS Nearest Pro ert Line: 37,000' North to the PBU property line Nearest Well within Pool: 06-23 is the closest well at 25.6' ctr-ctr with 11.8' of allowable deviation at tanned de th of 10880' MD. Contacts Drilling Engineer Geologist Pad Engineer Name Phone # Jovy Roach 564-4352 Doug Stoner 564-5652 James Dean 564-4668 E-mail iow.roach Cc~ bp.com doug.stonerC~bp.com iames.dean@bo.com 06-19A Permit to Drill Application Page 2 Formation Markers 06-19~ased on SOR) Formation Est. Formation To s(TVDss) Estimated Pore Pressure ( si) Base Permafrost -1920 SV2 -3769 SVl -4154 UG4 -4494 UG3 -4662 KOP -4926 UGl -5215 WS2 -5825 W51 -6044 CM3 -6275 CM2 -6797 CM1 -7562 THRZ -7891 BHRZ/TKUP -8070 TJC/LCU -8162 TJB -8318 TJA -8426 TSGR -8515 TSHU -8543 TSAD -8616 TCGL -8814 BCGL -8894 23SB -8950 3265 POWC -8960 HOT -8981 Casina/Tubina Program Hole Size Csg / Tb O.D. WUFt Grade Conn Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb 8-'/z" 7" 26# L-80 BTC-M 7,240 5,410 3683' 5000 / 5000 8683 / 8574 --- 7" 26# L-80 TC-II 7,240 5,410 5000' Surface 5000 / 5000 6-1 /8" 4'/i" 12.6# 13Cr-80 Vam To 8,430 7,500 2756' 8533 / 8428 11289 / 9056 Tubin 4'/z" 12.6# 13Cr-80 Vam To 8,430 7,500 8521' Surface 8521 / 8417 Mud Program Whi stock Millin Mud Pro erties: LSND Whip Stock Window: 9-5/8" 47# casing Densit PV YP API FL MBT PH 9.0 15-30 30-40 6-8 <10 9.0-10 Intermediate Mud Pro erties: LSND 8-1/2" hole section Depth Interva Density (ppg) PV YP API FL MBT PH 5000' - 8046' 9.0 - 9.1 8-14 18-24 <6.0 <15 9.0-10 8046' - 8691' HRZ to Sa 10.0 12-20 12-28 4.0-6.0 <20 9.0-10 Production Mud Pro erties: FLOPRO SF Reservoir Drill-in Fluid 6-1/8" hole section De th Interval Densit PV YP LSVR API FI H MBT 8691 - 11323' 8.4 - 8.5 6-12 22-28 >20,000 6.0-8.0 9.0-9.5 < 4 06-19A Permit to Drill Application Page 3 • Loaaina Proaram 8-1/2" Intermediate: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None Cement Program Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner Slurry Design Basis: Lead slurry: 2691' of 7" x 8-1/2" open hole with 40% excess. Tail slurry: 1000' of 7" x 8-1/2" annulus with 40% excess, lus ~80' of 7", 26#, shoe tract. Mud Push II: 30 bbls at 11 ppg Slurr T e 12.0 Lite Crete slurr ,Yield 2.45 Lead Slurry: Slurr Volume 99 bbls 556 cu ft / 227 sx Slurry Type 15.8 ppg Class 'G' liner slurry, Yield 1.16 Tail Slurry: Slurry Volume 35 bbls (197 cu ft / 169 sx) Temperature BHST = 205° F, BHCT TBD by Schlumberger Casin Strin 7", 26#, L-80, TC II Tieback to Surface Slurr Desi n Basis: Tail slurr :1350' of 7" x 9-5/8" annulus with 40% excess Lead none Slurr T e 15.8 Class `G' slurr ,Yield 1.16 Tail Slurry: Slurr Volume 48 bbls 270 cu ft / 232 sx Temperature BHST = 123° F, BHCT TBD by Schlumberger Casin Strin 4-1/2", 12.6#, 13Cr-80, VamTo Production liner, TOC ~ LNR Han er Slurry Design Basis: Tail slurry: 2,759' of 4-1/2" x 6-1/8" open hole with 40% excess, plus ~80' of 4-1/2 , 26#, shoe tract. Plus 150 of 4-1/2 x 7 annulus. Also 200 on top of liner han er between 4" drill i e and 7"cs . Mud Push II: 20 bbls at 12.0 Slurr T e 15.8 Class `G' liner slur with GasBlok, Yield 1.17 Tail Slurry: Slurr Volume 66 bbls 371 cu ft / 317 sx Tem erature BHST = 210° F, BHCT TBD b Schlumber er 06-19A Permit to Drill Application Page 4 1 Surface and Anti-Collin Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface 06-20 to the north and 06- 18 to the south are nearest at 119' centers. Close Approach Shut-in Wells: The 06-19A WP fails the minor risk AC with the 06-23 wellbore. The closest point of intersection lies in the reservoir section, and there is sufficient mud weight to balance reservoir pressure should 06-19A accidentally intersect. Also 06-23 has a tubing tail plug above the collision depth. See TCR Worksheet for reference. Hydrogen Sulfide DS 06 is an H2S site. Recent H2S data from the pad is as follows: Date of Weall Names H9S 1 evel Reading #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Faults 06-18 10 m 11 /21 /2005 06-21 100 m 4/21 /2007 06-15 10 m 6/7/2006 06-05 10 m 6/26/2007 06-13 250 m 1/9/2004 MD SSTVD Est. Throw Uncertainty Formation Where Encounter Fault Intersect Intersect Throw Direction 100 ft Fault #4 -Zone 2 9720 -8968 10 ft U thrown Fault #5 -Zone 2 10300 -8980 5 FT U thrown 100 ft Comments The proposed 06-19A well lies in a moderate-high risk province of the field for lost circulation at faults as documented by the WURD team. Only 3 loss circulation events were encountered in the Sadlerochit and Kingak sections in 3 of the surrounding 20 wells (15%), as detailed below. The. planned well will pass between two small faults in the Kingak section, staying 130-150 feet away from each. An intermediate target point has been added at the approximate Sag River depth in order to ensure that the proposed well can avoid these faults. After landing, the well will perpendicularly cross two faults in Zone 2 near 9720' MD and 10300' MD. Risk of loss circulation for the proposed 06-19A well is low. Additional faults are located 275 feet north of the planned well at the Shublik level as well as 240 feet east of the well near the proposed TD. The polygon side near this last fault is a hardline. The well can be extended approximately 100 feet to the end of the polygon. Loss Circulation Events Well Type Loss (bbl) MD SSTVD Formation Fault? 06-04 Rig 200 8657 -8334 Kingak Yes (casing) 06-OS Rig 75 9972 -9243 Below Bsad Yes (cementing) 06-20A Rig 469 10187 -8937 Zone 2 No Distance Throw Fault Coordinates for Ma in X Y TVDSS to Ian, ft Fault #1 First Point 686835 5941395 -8350 130' 10' N Fault #1 Second Point 687585 5941585 -8350 865 10' N Fault #2 First Point 686485 5940975 -8405 435' 5' E Fault #2 Second Point 686660 5941195 -8405 150 5' E Fault #3 First Point 686920 5941845 -8~0 275' 5' S Fault #3 Second Point 687035 5941820 -8830 310' 5' S Fault #4 First Point 686645 5942190 -8968 205' 10' S 06-19A Permit to Drill Application Page 5 r Fault # 4 Second Point ~ 686840 5942130 -8968 10' S Fault #4 Third Point 687245 5942050 '8968 410' 5' S Fault #5 First Point 686795 5942710 '8980 0' S' S Fault #5 Second Point 687510 5942850 '8980 320' 10' S Fault #6 First Point 686895 5943460 '8981. 240' S'W Fault #6 Second Point 687260 5942755 -8981 460' 10'W Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. BOP regular test frequency for 06-19A will be 14 days during drilling phase and 7 days during decompletion and surface casing work. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 3300 si C~3 8800' TVDss 7.2 EMW Maximum surface ressure 2420 si .10 si/ft as radient to surface Kick tolerance 51 bbl at 11.7 frac radient assumin 9.0 reservoir and 4" drill i e Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin / 7" Liner Test 3500 si surface ressure Inte rit Test - 8-1/2" hole LOT after drillin 20' from middle of window 7" Drillin Liner The VBRs will be chan ed to 7" rams to accommodate the 7" drillin liner. Production Interval Maximum antici ated BHP 3300 si C~ 8800' TVDss 7.2 EMW Maximum surface ressure 2420 si .10 si/ft as radient to surface Kick tolerance Infinite with a 10.0 FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 7" Casin / 4-1/2" Liner Test 3500 si surface ressure Inte ri Test - 6-1/8" hole 10.0 FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel Disposal No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 06-19A Permit to Drill Application Page 6 Drillirl~ Hazards and Contini POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.2 ppg EMW. This pressure is estimated based on offset well pressures. 3500 psi test pressure is in accordance with the RP for Prudhoe production well casing tests. II. Lost Circulation/Breathing The proposed 06-19A well lies in a moderate-high risk province of the field for lost circulation at faults as documented by the WURD team. Only 3 loss circulation events were encountered in the Sadlerochit and Kingak sections in 3 of the surrounding 20 wells (15%), as detailed below. The planned well will pass between two small faults in the Kingak section, staying 130-150 feet away from each. An intermediate target point has been added at the approximate Sag River depth in order to ensure that the proposed well can avoid these faults. After landing, the well will perpendicularly cross two faults in Zone 2 near 9720' MD and 10300' MD. Risk of loss circulation for the proposed 06-19A well is low. Additional faults are located 275 feet north of the planned well at the Shublik level as well as 240 feet east of the well near the proposed TD. Loss Circulation Events Well Type Loss (bbl) MD SSTVD Formation Fault? 06-04 Rig 200 8657 -8334 Kingak Yes (casing) 06-OS Rig 75 9972 -9243 Below Bsad Yes (cementing) 06-20A Rig 469 10187 -8937 Zone 2 No III. Kick Tolerance/Integrity Testing With the planned mud weights, the kick tolerance for the intermediate section is 51 bbl, and that for the production section is infinite. The LOT and FIT will prove up adequate formation strength for expected ECDs. Integrity Testing Test Point Test De th Test a EMW Ib/ al 9-5/a" window 20-ft minimum from the 9-5/8" window LOT 11.7 minimum 7" shoe 20-ft minimum from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe Significant directional work will be required in the intermediate hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide DS 06 is an H2S site. The highest H2S level recorded on the pad was 250 ppm on 1 /9/2004 on 06-13. Follow procedures for high H2S levels. VII. Faults Some minor faulting is expected along the planned trajectory. See Section II on lost circulation for more details. VIII. Anti-Collision Issues The 06-19A WP fails the minor risk AC with the 06-23 wellbore. The closest point of intersection lies in the reservoir section, and there is sufficient mud weight to balance reservoir pressure should 06-19A accidentally intersect. Also 06-23 has a tubing tail plug above the collision depth. See TCR Worksheet for reference. CONSULT THE DS 06 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 06-19A Permit to Drill Application Page 7 Operations Summary A. Well Status: 1. MIT-T failed 3000 psi 06/25/07 2. CMIT-TxIA failed 3000 psi 06/25/07. WRP at 8221' leaks. Leaking packer(s) and/or corroded tubing likely. 3. OA tracks IA pressure. One-way IA leak confirmed. 4. PPPOT-T passed 5000 psi 10/04/07 5. PPPOT-IC passed 3500 psi 10/04/07 B. Scope Notify the field AOGCC representative with intent to plug and abandon. C. Pre Rig Operations: W 5 PPPOT - IC 9-5/8" 5000 si, PPPOT-T 4-1/2" 5,000 si. Function all lock-down screws. S 1 RU, drift 4-1/2" tubin to the to of tubin tail lu 4-1/2"WRP at 8221' MD. Pull WRP. C 2 P & A the perforations in the 06-19 wellbore (see sundry application form) with ~ 71 bbl + excess 15.8 Class G cement in two sta es. Planned TOC at 5340'. Test to 1500 si. E 3 Jet cut the 4-1/2", 12.6#, L-80 tubing in the middle of is full joint of tubing above the 9-5/8" x 4- 1/2" TIW HBBP-T acker at 5354' MD cut tubin at ~ 5314' MD = 63' above TOC . F 4 Circulate the well to seawater through the tubing cut. Freeze protect the IA and tubing with diesel to 2,200'. F 6 CMIT-TxIA to 3500 psi for 30 min. MIT-OA (13-3/8" surface casing) to 2000 psi for 30 min. Bleed all casin and annulus ressures to zero. W 7 Set BPV in tubin han er. Secure well. O 8 Remove well house. Level the ad. Provide total well re cost on the handover form. r~~` ~~ Rig Operations: 1. MIRU. 2. MIT-OA 2000 psi. If the MIT fails, obtain a LLR. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC and test from below to 1000 psi (also tests TxIA) and from above to 3500 psi. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. c,`~ 4. RU and pull the 4-1/2" tubing from the pre-rig jet cut. Spool up SSSV control lines.. Count bands and clamps retrieved. 5. Pick up 9-5/8" casing scraper. RIH to 5300', ensure casing is clean. POOH. LD scraper assembly. 6. RU E-line. Run GR/CCL from TOC to surface to confirm EZSV setting depth. Set EZSV at 5030' MD (TIW HBBP packer at 5354'). RD E-line. 7. Change out 9-5/8" packoffs (pull packoffs through BOP stack if possible). 8. Pressure test 9-5/8" casing to 3500 psi for 30 min charted. 9. PU 9-5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills). RIH to the top of the EZSV. Orient with gyro and set the whipstock. Swap well over to 9.0 ppg fresh water LSND millina fluid. 10. Mill a window in the 9-5/8" casing from 5000' MD' plus 20' of formation from mid-window. Note: Verify that the mud weight is 9.0 ppg prior to cutting the window. 11. Perform a LOT. POOH for Drilling BHA. 12. MU the 8-1/2" drilling assembly with DIR/GR/RES/PWD and RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the Top of the Sag River (--8683' MD). Monitor ECDs closely for possible cretaceous overpressure, and increase mud weight as necessary. ~~~'-? 13. Increase mud weight to 10.0 ppg before drilling into the THRZ. CBU, short trip to window and back to .~ TD, circulate well clean and POOH. ~,~..~ 14. Change rams to accommodate 7" casing. Test rams. ~`` 15. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing 150' to -- 4850' MD. Set hanger /liner top packer and displace cement with mud. POOH. 16. Test the 9-5/8" x 7" intermediate liner to 3,500 psi for 30 minutes once compressive strength has been achieved. Record the test. H-14B Permit to Drill Application Page 8 17. Run and cement a 7" tiet to surface with 1350' of cement to -- 350 18. Test tieback to 3500 psi for 30 min charted. 19. Split stack. Install 7" casing slips. Cut 7" casing with Wachs cutter. 20. Set back BOP stack. Install new tubing spool and packoffs. Test packoffs to 4300 psi for 30 min. 21. NU BOPs. Change rams to accommodate drillpipe. 22. MU 6-1/8" BHA with DIR/GR/RES/ABI and RIH to the 7" landing collar. 23. Drill out the shoe tract. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform a FIT to 10.0 ppg. 24. Drill ahead building to horizontal landing point 9515' MD. POOH for bit & BHA change. 25. MU 6-1/8" BHA with DIR/GR/RES/DEN/NEU. RIH and MAD pass build section. Drill ahead in the horizontal as per plan to an estimated TD of 11289' MD. 26. CBU, short trip, circulate until clean and spot a liner running pill. POOH. 27. Run and cement a 4-1/2", 12.6#, L-80, IBT-M liner throughout the 6-1/8" wellbore and 150' back into the 7" intermediate casing to 8533' MD. Set liner top packer and displace well to clean seawater above the liner top. Test liner to 3500 for 30 min charted. NOTE: A perf pill will be left in the 4-1/2" liner. 28. RIH with DPC pert guns. Perf intervals to be determined from LWD logs. Plan to perforate overbalance, 800' of perfs. POOH, LD DP and pert guns. 29. Run the 4-1/2", 12.6#, 13Cr, Vam Top completion. Tie into the 4-1/2" liner top. 30. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 31. Set and test TWC. 32. ND BOPE. NU and test tree to 5,000 psi (Change to a 4" tree and use a new adapter flange). 33. Freeze protect the IA and tubing to -2,200' and secure the well. 34. RDMO. Post-Ria Work: 1. Install wellhouse, instrumentation, and flowlines. (S-Riser work required) 2. Slickline pull ball and rod / RHC plug. 3. Install gas lift valves. Estimated Pre-rig Start Date: 06/10/2008 Estimated Spud Date: 07/02/2008 H-14B Permit to Drill Application Page 9 TREE _ FMC GEN 3 WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 74' BF. ELEV = ? KOP = 7100' Max Angle = 19 @ 9000' Datum MD = 8957' Datum TVD = 8800' SS -19 LIMITS: MAX IAP =1 000 PSI, MAX OAP = 000 PSI (12/12105 WAIVER)*** 7" TBG 24' TOP 4-1/2" TBG 24' 24' 7" X 4-112" XO - 2'193' 4-1/2" CAM BAL-O SSSV NIP, ID = 3.812" GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" (~ 2514, Minimum ID = 2.992" @ 8886' 3-1/2" TUBING TAIL 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I~ 8266' I TOP OF 5-1/2" TBG- ~ 8260' 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 8317' TOP OF 4-1/2" TBG-PC~ 8317' TOP OF 7" LNR 8330' 9-5/8" CSG, 47#, L-80, ID = 8.881" 8620' 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" 8843' ~OP OF 3-1/2" TBG-PC ~843~ ~ 3-1/2" TBG-PC, 9.2#, N-80, .00870 bpf, ID = 2.992" ~~ 8886' PERFORATION SUMMARY REF LOG: BRCS ON 08/20/82 ANGLE AT TOP PERF: 18 @ 8945' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 6 8945 - 8970 C 09/16/05 2-1/2" 8 9040 - 9065 C 08/17/05 2-5/8" 4 9080 - 9095 S 03/10/94 2-1/8" 6 9095 - 9122 C 10/16/97 2-1/8" 6 9129 - 9144 C 03/10!94 2-1/8" 6 9144 - 9150 S 03/10/94 9152 - 9154 S 03!10/94 PBTD 9272' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9315' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3002 3002 1 MMG RK 2 4835 4835 2 MMG RK 3 5281 5281 2 MMG RK 5354' ~ 9-5/8" X 4-1 /2" TM! HBBP-T PKR, ID = 3.915" 8202' 9-5/8" X 4-1/2" TMJ HBBP-T PKR, ID = 3.915" 8221' 4-112" WRP (08/24l07~ 8236' 4-1/2" HES XN NIP, ID = 3.725" 8266' 5-1/2" UNIQUE MACHINE OVERSHOT, ID = 4.892" 8309' 9-5/8" X 5-1/2" BKR FHL PKR 8318- 5-1/2" X 4-1/2" XO~ $$43' 4-112" X 3-1 i2" XO $$45' 7" X 3-1/2" BKR MODEL F PKR 8885' 3-1/2" BKR ROUND-NOSE S/O SUB $886' 3-1/2" TBG TAIL, ID = 2.992" 8893' ELMD TT LOGGED 04/27/83 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/19/82 ORIGINAL COMPLETION 08/17/05 WJHrfLH ADPERF 05106/98 LAST WORKOVER 09/22/05 GJBlTLH ADPERF 09/12/01 RN(TP CORRECTIONS 12/21/05 COM/PAG WAVER SAFETY NOTE 09/28/02 BM/TP WAVER SAFETY NOTE 09/24/07 SPF/SV WRP SEl' (06/24/07} 11 /03/02 ?ITP PERF CORRECTIONS 02/11/03 / TLH WAVER SAFETY NOTE PRUDHOE BAY UNIT WELL: 06-19 PERMfI• No: x1821140 API No: 50-029-20791-00 SEC 2, T10N, R14E, 211.23 FEL 5271.84 FNL BP Exploration (Alaska) TREE = FMC GEN 3 WELLHEAD'= FMC ACTUATOR= AXELSON KB. ELEV = 74' BF. ELEV = ? KOP = 7100' ngle = 19 @ 9000' MD = 8957 Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-i 2514' Minimum ID = 2.992" @ 8886' 3-1 /2" TUBING TAIL 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 8266' TOP OF 5-1/2" TBG-PC 8260' 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 8317' TOP OF 4-1 /2" TBG-PC 8317' TOP OF 7" LNR 8330' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8620' 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" 8843' S TOP OF 3-1/2" TBG-PC 8843' 13-1/2" TBG-PC, 9.2#, N-80, .00870 bpf, ID = 2.992" I-i $886' PERFORATION SUMMARY REF LOG: BHCS ON 08/20/82 ANGLE AT TOP PERF: 18 @ 8945' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 8945-8970 C 09/16/05 2-1/2" 6 9040 - 9065 C 08/17/05 2-5/8" 4 9080 - 9095 S 03/10/94 2-1/8" 6 9095 - 9122 C 10/16/97 2-1/8" 6 9129 - 9144 C 03/10/94 2-1/8" 6 9144 - 9150 S 03/10/94 9152 - 9154 S 03/10/94 PBTD 9272' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9315' O ~. 6 ~~ 1 .~ i •.a ,. ~` e •• ~. ' n. w i ' . •. •~ ~ ~• ~ * 4• SA NOTES: ***IAxOA COMM. OPERATING LII MAX IAP =1000 PSI, MAX OAP =1000 PSI (12112/05 WAIVER)*** 24' 7" X 4-1 /2" XO 2193' 4-1/2" CAM BAL-O SSSV NIP, ID = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3002 3002 1 MMG RK 2 4835 4835 2 MMG RK 3 5281 5281 2 MMG RK 5314' Tubing jet cut 5354' 9-5/8" X 4-1/2" TNV HBBP-T PKR, ID = 3.915" 8202' 9-5/8" X 4-1/2" TNV HBBP-T PKR, ID = 3.915" 8221' 4-1/2" WRP(O6/24/07) 8236' 4-1/2" HES XN NIP, ID = 3.725" $266' 5-1/2" UNIQUE MACHINE OVERSHOT, ID = 4.892" 8309' 9-5/8" X 5-1/2" BKR FHL PKR 8318' 5-1/2" X 4-1/2" XO 8843' 1~4-1/2" X 3-112" XO $$45' - -{7" X 3-1/2" BKR MODEL F PKR I 8885' 3-1/2" BKR ROUND-NOSE S/O SUB $$$6' - r-1/2" TBG TAIL, ID = 2.992" 8893' ELMD TT LOGGED 04/27/83 TE REV BY COMMENTS DATE REV BY COMMENTS 9/82 ORIGINAL COMPLETION 08/17/05 WJHITLH ADPERF 05/06/96 LAST WORKOVER 09/22/05 GJB/TLH ADPERF 09/12!01 RNITP CORRECTIONS 12/21/05 COM/PAG WANER SAFETY NOTE 09/28/02 BMITP WANER SAFETY NOTE 09/24/07 SPF/SV WRPSET (06124/07) 11/03/02 ?/TP PERF CORRECTIONS 05/28/08 JER Proposed Pre-rig 02/11/03 / TLH WANER SAFETY NOTE PRUDHOE BAY UNff WELL: 06-19 PERM(f No: 1821140 API No: 50-029-20791-00 SEC 2, T10N, R14E, 211.23 FEL 5271.84 FNL BP Exploration (Alaska) 6x19 Pre-rig 7" TBG -j 24, TOP4-1/2" TBG - TREE = 4" CAMERON WELLHEAD= FMCGEN3 ACTUATOR = AXELSON KB.~ELEV = 74' BF. ELEV = ? KOP = 5000' Max Angle =89.9 ~ 10150' Datum MD = 9092' Datum TV D = 8800' SS ~ 6 ~ 9A DRAFT Minimum ID = 5.725 aG~ 8511 -1/2 XN Nipple 2193' 4-1/2" CAMBAL-OSSSV NIP, ID=3.812" 2514' 13-3/8" CSG, 72#, L-80, ID = 12.34T' 3500' Planned TOC 4844' 7" TBS 4848' 7" Tieback, 26# L-80 4850' 9-518" x 7" Liner Top Packer L 5000' i-iKOP ~ 5025' 9-5/8" BKR Whipstock 5030' 9-518" EZSV GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE ~, 1 3 \ 1 2 5314' TOP OF 4-1/2" TBG ICut Toc 6340' 8401' 4-1/2" HES X NIP, ID = 3.813" 8421' 7" X 4-1 /2" BKR S-3 PKR 8451' 4-1/2" HES X NIP, ID = 3.813" 8511' 41/2" HES XN NIP, ID = 3.725" 8535' 4-1/2" SBR 8541' Hanger/Liner top packer 8691' 7" CSG, 26# L-80, .0226 bpf, ID = 6.276" ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ PERFORATION SUMMARY REF LOG: BRCS ON 08/20/82 A NGLE AT TOP PERF: 18 @8945' Note: Refer to Productbn DB for historical pert data SQE SPF INTERVAL Opn/Sgz DATE ~ XXXXX' ~ 11289' ~4-1/2" LNR, 12.6# L-80, .0152 bpf, ID = 3.95 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/79!82 ORIGINAL COMPLETION OS/17/05 WJH(fLH ADPERF 05/06/96 LAST WORKOV92 09/22/05 GJB/TLH ADPERF 09/12/01 RNJTP CORRECTIONS 12/21/05 COIWPAG WANERSAFETY NOTE 09/28/02 BM/TP WANERSAFETY NOTE 09/24/07 SPF/SV WRPSET(O6/24/07) 11/03/02 ?lfP PERFCORRECTIONS 06/11/08 JER PROPOSED SIDETRACK 02!11 /03 / TLH WA N ER SAFETY NOTE PRUDHOE BAY UNfT WELL: 06-19A P'ERMff No: 1821140 API No: 50-029-20791-01 SEC 2, T10N, R14E, 211.23 FEL 5271.84 FNL BP Exploration (Alaska) ,~ I.OGA'fl/D IN PRO'(RAG'fED L,~G~i. 2~ 11,'(IO1J, R14E', UMIA'( MERIDIAN ~.. 9uRVFY --~E - t2 D.4. G t, ~ e ~ •,.i. VICItJftY IN~-P i"= 4000' ''' - r'.:r".. 1 Et .~ . S N W COR Cl:61.AR LAT= ?i~ vr• tj~, _,? f30X i:L~V=37.05 OF AC ~dt + ~ ~Q.~.c "~.~•.... qs t ~- f r7 ~~ •ti9 i'~; 49th ~ Pe~~I"•~~N~...s .. •....... f (1.7.ur-~ ~ -- - - 1 F c'F~'-•~a. ••' S.i t ~ E ~~~FESSIQKk~ ~G~'"' ~E~.~~..~-'E'er" I HEF:EEY t;El/TIFY THAT I HP1 F>~`t~F- EF:LY i-,E1~ I ~_ TEF~ED AtdC+ L I C:E't~IC:EC1 T+J FF..A~`T I ~=E Li;t~l0 ~:I~F,'~'EY I tiG I Fa THE :STATE ~!F ALAc:F•:A AI-~C~ THtiT 7HIS FLAT F.EF•F:ESEhIT~ RF-1 A:3-E:itILT BUR-_ 4~EY 1•~AC~E Ut-1C+ER t9Y :~UFERti,'I'~ICIt~, AFiC1 THAT ALL C+I MEt•iS I Otia AhaC1 uTH~R ~ETAILa HRE ~:UF,'F:E~=T: AS UF= 6~t4~62 ;;= n_:r'., Ij:_ 1 c~ NW COR G~6LAR LAT= ~'~ ~? c_+i:.L52 KOK i:i.EY=iG.90 L+JI•~i~=14: ::~ 35. ~'_=~1 P1i~TE F•f'c+~ l'=•~:'?~1~_+, '1~'~.'~6 1. Y & ~; i=l:+i!F:G~ t~F:E ALA~t•',A ~inTE :~;= r". : r., +=+5.~ ..3:~ NW GOR Gt't.L~iR FLA[•iE Liif-;E 4 . • LAT= ;~%+ E~? +=+~.+j?5 RsOXt;Lf;V=36.95 ~. ALL C~I;TRt-at::E:, ARE =~i.IRFA~~E. ot:s. 1n/uAtt,l: Y cHK. CRicN9N/aw DATE 6/I~~eZ J08 NO. ' 3. t;LEV. i~ASEv ON MLl.W. SHEET ,. CoN~ucfoR ~15•guir,T •p. s. ~/ ~~-ao ~ }F~ t ~.. Subsidiary at Attontic RieAtield Company NORTH SLOPE ORILLlN~-PRUDHOE BAY C~.ti:. a +=C~til:Ui_:T~JR Li~iHTI~~t~c: ,= r.~_ n , 1 F: , ~ y IVW GOR GEI.I.~R L A T = ~~ +_+ 1 ~ _ . ? ~ 3 BOX ~I.EV= 37.29 LCIi-I~~=1~#:i ::sa ~r .f.53 by DS06-19A (P5) Pro CYelk: BP Exploration Alaska Fiat: Prudtx>e Bay Unit - EOA StnrGure 1 Slot DS-06106-19 Weg:06-,9 ~ pr~Ved t3orahole: Plan 06.19A UNWAPI/: 500292079101 Survey flame 1 Date: 06-19A (P5) I June 3, 2008 ToA 1 AFB 1 DDI 1 hRD ratio: 133.499° 13337.47 ft 15.746 10.369 Grid CoordinaM System: NAD27 Alaska State Planes, Zone 04, US Feet Locatlen Laf0.aq: N 70.24329978, W 148.49697063 Locetlal Grid N1E YIX: N 5940832.130 ftUS, E 686061.240 ftUS GridWrwergenceAlgle: +1.41459295° ~ Schlumberger Slxvey 1 DLS Camptdation Method: Minimum Curvature I Li Vertical Section Azimuth: 11.910° Vertical SecBoe Origin: N 0.000 ft, E 0.000 ft 7VD Refmance DaWm: Rotary Table TVD Reference Elevation: 65.50 ft relative ro MSL Sea Bed 1 Ground Level Elevation: 37.00 ft relative ro MSL Magnetk Declination: 23.214° Total FNId Strengtll: 57679.782 nT Magnetic D~: 80.908° Dedinatla7 Date: July 15, 2008 Magnetic Declination Model: BGGM 2007 North Referenrs: True North Toth Corr Mag North a True North: +23.214° Coaawenle ~ N~7atkrl Azlmldp SuaSaTYD TVD V NS EW ~ f ~ DLS f~ NorWag Eaet4y LatNude Lorlykude S rlcll'al T ool F N N N N N N 100 N Infix n n~ fUIS cnenonc c7 tdlS CCCnG7 4n LI 7n 7A 409Cne w 1An AeCe07M t16-tn aWVey 4M!lI.~IJ I.LJ 7L~.31 4tlLOA77 977`J i. 177 -LV.VI -LV./V J.YV IcV.acm V.v~ Top Whipstock 5000.00 1.26 126.32 4934.19 4999.69 -25.09 -26.81 5.55 114.23M 0.30 2.95 5940805.47 686087.45 N 70.24322654 W 148.49692578 Base Wh~stock 5016.00 3.14 114.23 4950.18 5015.68 -25.25 -27.09 6.09 -- 12.00 3.00 5940805.20 686088.00 N 70.24322576 W 148.49692141 KOP Crv 4!100 5028.00 3.14 114.23 4962.16 5027.66 -25.39 -27.36 6.69 81.24M 0.00 3.00 5940604.94 686088.61 N 70.24322503 W 148.49691658 5100.00 4.95 81.24 5033.99 5099.49 -24.72 -27.70 11.56 65.01 M 4.00 3.10 5940804.73 686093.48 N 70.24322411 W 148.49687726 5200.00 8.51 65.01 5133.29 5198.79 -18.75 -23.91 22.54 20.24E 4.00 3.25 5940808.78 686104.36 N 70.24323445 W 148.49678883 UG1 5283.00 11.68 59.33 5215.00 5280.50 -9.37 -17.03 35.33 14.64E 4.00 3.39 5940815.98 686116.98 N 70.24325325 W 148.49668529 5300.00 12.34 58.53 5231.63 5297.13 x.96 -15.21 38.36 13.86E 4.00 3.42 5940817.88 686119.96 N 70.24325823 W 148.49666083 End Crv 5354.40 14.46 56.44 5284.55 5350.05 1.87 -8.42 48.98 --- 4.00 3.51 5940824.93 686130.41 N 70.24327679 W 148.49657507 WS2 5912.54 14.46 58.44 5825.00 5890.50 101.23 68.63 165.13 -- 0.00 3.91 5940904.82 686244.61 N 70.24348728 W 148.49583709 WS1 6138.71 14.46 56.44 6044.00 6109.50 141.50 99.86 212.19 -- 0.00 4.00 5940937.18 686290.89 N 70.24357257 W 148.49525700 CA43 6377.27 14.46 56.44 6275.00 6340.50 183.97 132.79 261.84 -- 0.00 4.08 5940971.33 686339.70 N 70.24366254 W 148.49485601 CAf2 6916.34 14.46 56.44 6797.00 6862.50 279.94 207.21 374.02 - 0.00 4.22 5941048.50 686450.00 N 70.24386584 W 148.49395009 CM1 7708.38 14.46 56.44 7562.00 7627.50 420.58 316.27 538.42 -- 0.00 4.37 5941161.58 686611.65 N 70.24416377 W 148.49262232 7TiRZ 8046.14 14.46 56.44 7891.00 7956.50 481.07 363.18 609.12 -- 0.00 4.42 5941210.21 686681.17 N 70.24429189 W 148.49205128 BHRZ/TKUP 8231.00 14.46 56.44 8070.00 8135.50 513.98 388.70 647.59 -- 0.00 4.45 5941236.67 686719.00 N7O.2443616O W 148.49174059 TJC /!CU 8326.01 14.46 56.44 8162.00 8227.50 530.89 401.81 667.36 - 0.00 4.46 5941250.27 686738.44 N 70.24439743 W 148.49158090 TJA 8598.64 14.46 56.44 8426.00 8491.50 579.43 439.45 724.10 -- 0.00 4.50 5941289.29 686794.22 N 70.24450024 W 148.49112267 8675.07 14.46 56.44 8500.00 8565.50 593.03 450.00 740.00 - 0.00 4.51 5941300.23 686809.86 N 70.24452905 W 148.49099423 TSAG 8690.56 14.46 56.44 8515.00 8580.50 595.79 452.14 743.22 -- 0.00 4.51 5941302.45 686813.03 N 70.24453490 W f 48.49096819 7" Csg Pt 8890.57 14.46 56.44 8515.01 8580.51 595.79 452.14 743.23 -- 0.00 4.51 5941302.45 686813.03 N 70.24453490 W 148.49096817 Crv 12/100 8715.07 14.46 56.44 8538.73 8604.23 600.15 455.52 748.32 65.21E 0.00 4.51 5941305.96 686818.04 N 70.24454414 W 148.49092700 WeNDesign Ver SP 2.1 Bid( doc4Ox_1OO) 06-19\06-19\Plan 06-19A106-19A (P5) Generated 6/5/2008 1:40 PM Page 1 of 2 Co~ente ~ Ind~aUon Axkndh SuY-SasTVD T1~ NS EW T~od(F~ ~'S D9 EutiD9 LMifudr LonpkudA k k k k k k d 100 k Index fU1S kUS TSIiU C77'J.4tl 74.by 54.55 Cb4.7.UU 230Utl.bU DUU.yO 4J0. 15 /4'J.L4 DJ.JCL 7L.UU 4.QL D`J47 JUO.D7 DQOd76.`J4 n /U.L44Q47Q0 W 790.4`Jtli77'JOT TSAD 8795.99 20.48 30.49 8816.00 8681.50 820.82 473.35 763.96 40.39E 12.00 4.83 5941324.17 686833.24 N 70.24459284 W 148.49080087 8800.00 20.85 29.61 8619.75 8685.25 622.17 474.58 764.67 39.57E 12.00 4.64 5941325.41 686833.92 N 70.24459619 W 148.49079494 8900.00 31.01 14.72 8709.66 8775.16 665.01 515.11 780.07 26.10E 12.00 4.76 5941366.31 686848.30 N 70.24470693 W 148.49067058 9000.00 42.09 6.87 8789.91 8855.41 724.34 573.52 790.66 19.77E 12.00 4.87 5941424.95 686857.45 N 70.24486648 W 148.49058498 TGGL 9033.48 45.89 4.98 8814.00 8879.50 747.46 596.64 793.05 18.41E 12.00 4.90 5941448.13 886859.27 N 70.24492988 W f48.49056568 9100.00 53.50 1.85 8857.00 8922.50 797.57 647.23 795.99 16.38E 12.00 4.97 5941498.78 686860.96 N 70.24506787 W 148.49054187 BCGL 9168.88 61.46 359.21 8894.00 8959.50 854.45 705.26 796.47 14.96E 12.00 5.03 5941556.79 686860.01 N 70.24522840 W 148.49053798 9200.00 65.08 358.15 8907.99 8973.49 881.50 733.04 795.82 14.48E 12.00 5.06 5941584.55 686858.68 N 70.24530230 W 148.49054314 9300.00 76.72 355.09 8940.67 9006.17 972.46 827.19 790.17 13.47E 12.00 5.15 5941678.52 686850.70 N 70.24555951 W 148.49058875 23S8 9352.78 82.89 353.60 8950.00 9015.50 1021.93 878.84 785.04 13.21E 12.00 5.20 5941730.02 686844.30 N 70.24570080 W 148.4906300 End Crv 9386.96 86.88 352.66 8953.05 9018.55 1054.17 912.65 780.97 -- 12.00 5.22 5941763.72 686839.40 N 70.24579297 W 148.49066294 Crv 12/100 9387.99 86.88 352.66 8953.11 9018.61 1055.15 913.67 780.84 82.O6R 0.00 5.22 5941764.74 686839.24 N 70.24579576 W 148.49066400 9400.00 86.98 353.38 8953.75 9019.25 1066.50 925.58 779.38 82.02R 6.00 5.23 5941776.60 686837.49 N 70.24582829 W 148.49067576 9500.00 87.83 359.32 8958.28 9023.78 1162.69 1025.22 773.03 81.75R 6.00 5.29 5941876.06 686828.68 N 70.24610052 W 148.49072699 Target 9519.79 88.00 0.50 8959.00 9024.50 1182.03 1045.00 773.00 77.11 R 6.00 5.30 5941895.83 686828.16 N 70.24615455 W 148.49072722 End Crv 9529.61 88.13 1.07 8959.33 9024.83 1191.66 1054.81 773.13 - 6.00 5.30 5941905.64 686828.05 N 70.24618135 W 148.49072612 Crv 6/100 10101.42 88.13 1.07 8977.98 9043.48 1752.98 1626.22 783.85 79.75E 0.00 5.46 5942477.10 686824.66 N 70.24774239 W 148.49063908 Target 10182.27 89.00 356.30 8980.00 9045.50 1831.64 1707.00 782.00 79.89E 6.00 5.50 5942557.81 686820.81 N 70.24796309 W 148.49065397 10200.00 89.19 355.25 8980.28 9045.78 1848.67 1724.68 780.69 79.87E 6.00 5.51 5942575.45 686819.07 N 70.24801139 W 148.49066450 End Crv 10270.82 89.94 351.07 8980.82 9046.32 1915.71 1794.97 772.26 -- 6.00 5.54 5942645.51 686808.91 N 70.24820343 W 148.49073254 TD / 4-1/2" Lnr 11322.59 89.94 351.07 8982.00 9047.50 2898.67 2834.00 609.00 --- 0.00 5.75 5943680.12 686620.06 N 70.25104203 W 148.49205064 Legal ~asc riutlon: No rthing IYI fftUSl Eastina (XI ff tUSl Surface : 231 FSL 910 FEL S2 T10N R14E UM 5940832.13 686081.24 Target : 1276 FSL 136 FEL S2 T10N R14E UM 5941895.83 686828.16 Target : 1938 FSL 126 FEL S2 T10N R14E UM 5942557.81 686820.81 TO / Btf1: 3065 FSL 298 FEL S2 T10N R14E UM 5943680.12 686620.06 u WeUDesign Ver SP 2.1 Bid( doc40x_700) 06-19\06-19\Pian 06-19A106-19A (P5) Generated 6/5!2008 1:40 PM Page 2 of 2 • by Schlumherger WELL FIELD STRUCNRE DS06-19A (P5) Prudhoe Bay Unit - EOA DS-06 Magnelk Pannrelers ce Lxalion N4D2]glaska Stale Planes. 2ona 04. U0 Feel n MoEel: BGGM 200] Dip'. 00.900' Dale: JuN 15. ]090 La Na N]014 J5.0]9 No9bmB. 59400]2.13 XUS Grp Conv:. 41459295' ~Ob-19 ND Rai. Rotary Tabk ~fi550 a above MS LI ag Dec: •2J.214' S]fi]9B nT 40 29 49 094 Easing: fi88001.2111U0 wb Fact'. O'999939JJ53 Plan. Ob-19q BPS) any Dale: J ne 03, 2008 0 600 1200 1800 2400 4800 5400 6000 6600 x o` 0 m c 7200 O 7800 8400 9000 Tie-In Survey Top Whipstock Base Whipstock KOP Crv 4H 00 _ _ ~ G1 - - ETd CM - - ~ _ _ _ _ _ _ t _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ................ ................................. ~.................................. i...................................i.................................. ~ .................................. _ _ _ _ 2 _ _ _ _ _ 1 _ _ _ _ _ _ F _ _ _ _ _ _ _ _ _ - _ _ _ _ _ Nf3 _ _ _ _ _ _ _ - _ _ _ _ _ _ - _ _ _ - - - - _ gyp' y _ - - - - ' _ _ - - - _ - - - - - - - - - - - - - TN~7' + - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ HF1Z%TKUP _ _ _ _ F _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ J~/LCII _ _ _ _ - - _ _ _ _ _ _ _ _ _ - _ _ _ 7" Csg P[ ' _ _ _ _ _ _ _ ~ A CN 12H00 - _ F _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ G_ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - 8Ad - _ _ _ _ _ _ _ _ _ _ _ _ _ _._ _ _ _ _ _ _ _ _ End Crv Crv 6/700 Tar ~ t :Target ~ End Crv TD / 4-1/2" Lnr CN 61700 _ _ _ _ GL - ~ End crv _ _ _ _ - ~.. ~_.. ~.. ..i. _.. _.. _.. _.. _.. _.. _...:...~.. _...:.. _... _ _ - _ - - - - - _ - • 6-i A os-1 s 4800 5400 6000 6600 7200 7800 8400 9000 (PS) 0 600 1200 1800 2400 Vertical Section (ft) Azim = 11.91 °, Scale = 1(in):600(ft) Origin = 0 N/-S, 0 E/-V • • by Schlumberger WELL DS06-19A (P5) FIELD Prudhoe Bay Unit - EOA 51RUC1LRE DS-06 Magnerw Parameters SuAace Location N5D2] hlasNa 31are Planes. Zone Od. US Feat Miscellaneous Mo0eL. BGGM 200] Olp: 80908' Dale: JuN I5. 2009 a. N>01a 358]9 M1ing. $9MB32. . <ta59295° 3b1' 06-19 ND ReI: Rotary Tab4165.50X above MSLI ag Dec: «23.31 d• FS'. 5]6]9.8 nT Wt<fi 2949.091 Easl'n9. fifiE0fi 1.2<IIU53 Srale Fact: 0.999939JJ53 Plan'. 06-19P IPS) ne 03, 2008 -400 0 400 800 1200 2800 ;......., 2400 ...... 2000 ......... n n n Z 1600 0 0 v c n a~ m ~j 1200 v7 v v v 800 400 0 2800 2400 2000 1600 1200 800 400 0 -400 0 400 800 1200 «< W Scale=l(in):400(ft) E »> • Field: Prudhoe Bay ~ Site: PB DS 06 Well: 06-19 Wellpath: Plan 06-19A 0 1000 ~oo~ 3000 ~.OOo 5000 6000 1000 0000 ~~000 0 ~~o 06-19106-19) Plan 06-19A 06-19/Plan 06-19A ~o o0 0 ~~ °o ~~ Anticollision Companv: BP AmoCO - - Date: 6/3/2008 _ Time: t2;46:28 - Page: 1 field: Prudhoe Bay Reference S ite: PB DS O6 Co-ordinste(NF.) Reference: WeN: 06-19, True North Reference Well: 06-19 Vertical ('['VD) Refere nce: 06-19A Plan 65.5 Reference Wellpath: Plan 06-19A Db: OraCle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/10110 of reference -There are 1[lfQll~aiells in thisHllhilpal Plan 8 PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Ran ge: 5000.00 to 11322.59 ft Scan Method: Trav CyNnder North Maximum Radius: 1329.41 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/7/2007 Validated: No Version: 3 Planned From To Survey Tookode Tool Name ft ft i 91.50 4991.50 06-19 Srvy 1 Boss Gyro (91.50- BOSS-GYRO { .-- I Spent'-Sun BOSS gyro muttishot 4991.50 5300.00 Planned: Plan #5 06-19A V1 GYD-GCBs Gyrodata gyro single shots 5300.00 8630.00 Planned: Plan #5 06-19A V1 MWD+IFR+MS MWD +IFR + Mufti Station 8630.00 11322.59 Planned: Plan #5 06-19A V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points _ MD TVD Diameter Hole Size Name ft ft in in 2505.50 2505.42 13.375 17.500 13 3/8" 5000.00 4999.69 9.625 12.250 9 5/B" 8690.56 11322.59 8580.50 7.000 9047.50 4.500 8.500 7" 6.125 4112" Summary _ . < Offset Wellpath ~ _ Reference T Offset _ _ Ctr-Ctr No-(:o Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS O6 06-01 06-01 V1 _ - ____ Out of range PB DS 06 06-02 06-02 V1 Out of range PB DS O6 06-03 06-03 V1 Out of range PB DS 06 O6-03A 06-03A V1 Out of range PB DS O6 06-04 06-04 V1 5001.08 5025.00 193.70 71.09 122.61 Pass: Major Risk ~, PB DS 06 06-04 06-04A V10 5002.47 5030.00 193.89 71.16 122.72 Pass: Major Risk ~,~ PB DS 06 06-05 06-05 V1 5000.20 5140.00 667.57 87.69 579.88 Pass: Major Risk j PB DS 06 06-06 06-06 V76 Out of range i PB DS 06 06-06 06-O6A V3 Out of range PB DS 06 06-06 06-O6B V4 Out of range PB DS 06 06-06 06-O6BP61 V8 Out of range PB DS 06 06-07 06-07 V1 Out of range PB DS O6 06-08 06-08 V1 5026.57 5410.00 1267.39 103.28 1164.12 Pass: Major Risk PB DS O6 06-08A 06-08A V1 5026.57 5410.00 1267.39 103.28 1164.12 Pass: Major Risk PB DS 06 06-13 06-13 V2 5002.25 5210.00 350.99 130.74 220.24 Pass: Major Risk ~ PB DS O6 06-13 06-13A V3 5001.85 5210.00 387.24 126.44 260.81 Pass: Major Risk ~ PB DS O6 06-13 06-13APB1 V13 5001.85 5210.00 387.24 126.33 260.91 Pass: Major Risk PB DS O6 06-17 06-17 V11 Out of range '; PB DS O6 06-18 06-18 V8 5028.91 5280.00 1275.80 69.99 1205.81 Pass: Mapr Risk PB DS 06 06-19 06-19 V2 5006.50 5015.00 0.04 57.37 -57.33 FAIL: Major Risk PB DS 06 06-20 06-20 V3 5026.43 5250.00 1088.43 77.25 1011.18 Pass: Major Risk PB DS 06 06-20 06-20A V5 5026.16 5240.00 1088.30 77.15 1011.16 Pass: Major Risk '; PB DS 06 06-21 06-21 V5 5001.21 5065.00 351.14 76.36 274.78 Pass: Major Risk PB DS O6 06-21 06-21A V6 5001.21 5065.00 351.14 76.36 274.78 Pass: Maur Risk ~~ PB DS O6 06-21 Plan 06-21B V1 Plan: P 5000.42 5055.00 350.65 76.34 274.31 Pass: Major Risk PB DS 06 06-22 06-22 V1 Out of range PB DS O6 06-22A 06-22A V1 Out of range PB DS O6 06-23 06-23 V1 10843.80 9535.00 378.10 315.03 83.07 Pass: Major Risk PB DS O6 06-23 06-23A V1 10843.80 9535.00 378.10 314.76 63.33 Pass: Major Risk ~ PB DS O6 06-23 06-236 V2 10873.72 9730.00 58.42 278.88 -220.47 FAIL: Major Risk i PB DS O6 06-23 06-23BPB7 V1 10901.58 9730.00 48.23 290.88 -242.65 FAIL: Major Risk PB DS O6 06-23 Plan 4, 06-23C VO Plan 10945.67 9580.00 264.87 295.11 -30.24 FAIL: Major Risk PB DS 13 13-19 Plan 13-19A VO Plan: 1 8600.76 13090.00 409.78 207.94 201.84 Pass: Major Risk Anticollision Company: 8P Amoco Date: 6/3/2008 Time: 13:15:28 Page: I Field: Prudhoe Bay Reference S ite: PB OS 06 Coordinate(NE) Reference: Well: 06-19, True North Reference Weli: 06-19 Vertical ('['VD) Refere nces 06-19A Plan 65.5 Reference Welipath: Plan 06-19A Dh: Oracle NO GLOBAL SCAN: Using user defined selection & scau criteria Reference: Principal Plan i3< PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 5000.00 to 11322.59 ft Scan Method: Trav Cylinder North Maximum Radius: 1329.41 ft Error Surface: Ellipse + Casing i Survey Program for Definitive Welipath Date: 11/7/2007 Validated: No Version: 3 Planned From To Survey Toolcode Tool Name ft ft ~_ -- 91.50 4991.50 06-19 Srvy 1 Boss Gyro (91.50- BOSS-GYRO Sperry-Sun BOSS gyro mumshot j 4991.50 5300.00 Planned: Plan #5 06-19A V1 GYD-GC-SS Gyrodata gyro single shots 5300.00 8630.00 Planned: Plan #5 06-19A V1 MWD+IFR+MS MWD +IFR + Multi Station 8630.00 11322.59 Planned: Plan #5 06-19A V1 MWD+IFR+MS MWD +IFR + Mufti Station ! Casing Points MD '-'VD Diameter Hole Size Name ft ft in in 2505.50 2505.42 13.375 17.500 13 3/8" 5000.00 4999.69 9.625 12.250 9 5/8" 8690.56 8580.50 7.000 8.500 7" ~ 111322.59 =------- 9047.50 4.500 - --------- 6.125 4112" -- Summary < Ofiset Welipath Reference Offset Ctr-Ctr No-Co Allowable Site Weli Welipath MD NiD Distance Area Deviation Warning ft ft ft ft ft PB DS O6 06-01 06-01 V1 Out of range PB DS 06 06-02 06-02 V1 Out of range PB DS 06 06-03 06-03 V1 Out of range PB DS O6 06-03A O6-03A V1 Out of range PB DS 06 06-04 06-04 V1 5001.08 5025.00 193.70 71.09 122.61 Pass: Major Risk PB DS 06 06-04 06-04A V10 5002.47 5030.00 193.89 71.16 122.72 Pass: Major Risk PB DS O6 06-05 06-05 V1 5000.20 5140.00 667.57 87.69 579.88 Pass: Major Risk ~ PB DS 06 06-06 06-06 V16 Out of range ~ PB DS 06 06-06 06-06A V3 Out of range PB DS 06 06-06 06-066 V4 Out of range PB DS O6 06-06 06-066P61 V8 Out of range PB DS 06 06-07 06-07 V1 Out of range PB DS 06 06-08 06-08 V1 5026.57 5410.00 1267.39 103.28 1164.12 Pass: Major Risk PB DS 06 06-08A 06-08A V1 5026.57 5410.00 1267.39 103.28 1164.12 Pass: Major Risk ! PB DS 06 06-13 06-13 V2 5002.25 5210.00 350.99 130.74 220.24 Pass: Major Risk ! PB DS O6 06-13 06-13A V3 5001.85 5210.00 387.24 126.44 260.81 Pass: Major Risk PB DS 06 06-13 06-13AP61 V13 5001.85 5210.00 387.24 126.33 260.91 Pass: Major Risk ! PB DS O6 06-17 06-17 V11 Out of range PB DS 06 06-18 06-18 V8 5028.91 5280.00 1275.80 69.99 1205.81 Pass: Major Risk ~ PB DS O6 06-19 06-19 V2 5011.50 5020.00 0.14 15.20 -15.06 FAIL: Minor 1/200 j PB DS 06 06-20 06-20 V3 5026.43 5250.00 1088.43 77.25 1011.18 Pass: Major Risk ! PB DS O6 06-20 06-20A V5 5026.16 5240.00 1088.30 77.15 1011.16 Pass: Major Risk PB DS O6 06-21 06-21 V5 5001.21 5065.00 351.14 76.36 274.78 Pass: Major Risk ! PB DS O6 06-21 06-21 A V6 5001.21 5065.00 351.14 76.36 274.78 Pass: Major Risk PB DS 06 06-21 Pian 06-21 B V7 Plan: P 5000.42 5055.00 350.65 76.34 274.31 Pass: Major Risk PB DS 06 06-22 06-22 V1 Out of range PB DS O6 06-22A 06-22A V1 Out of range PB DS O6 06-23 06-23 V1 10843.80 9535.00 378.10 315.03 63.07 Pass: Major Risk PB DS 06 06-23 06-23A V1 10843.80 9535.00 378.10 314.76 63.33 Pass: Major Risk ~ PB DS O6 06-23 06-236 V2 10872.94 9675.00 27.31 9.45 17.87 Pass: Minor 1/50 PB DS 06 06-23 06-23BP61 V1 10879.66 9675.00 25.57 13.76 11.81 Pass: Minor 1/50 PB DS 06 06-23 Plan 4, 06-23C VO Plan 10909.83 9530.00 260.50 0.00 260.50 Pass: Minor 1/50 LPB DS 13 13_19 Plan 13-19A VO Plan: 1 8600.76 13090.00 409.78 207.94 201.84 Pass: Major Risk FieldPrudhoe Bay Site PB DS 06 We11:06-19 WellpathPlan 06-19A From KOP to TD Scan interval 50 ft Scale 1:50 157 150 100 50 0 2 50 100 150 157 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre t I Page 1 of 1 • • Maunder, Thomas E (DOA) From: Roach, Jovy [Jovy.Roach@bp.com] Sent: Tuesday, June 17, 2008 2:25 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 06-19A Attachments: TCR 06-19A to 06-23.ppt My apologies for the inconsistency. The text is correct, the TOW/KOP will be at 5000, and the liner top will be at 4850 to include 150' of liner lap. The tieback will be at ~ 4848. We are aware of the close approach, and I have attached the TCR worksheet for reference. Because of the old boss gyro on this well, increasing the center-to-center distance between 06-19A and 06-23 from 25' to 50' does not statistically give us a better chance of avoiding 06-23. The calculated risk is acceptable, and having a shale between the two wells as well as geosteering will reduce the probability of a collision. Thanks, Jovy From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, June 17, 2008 1:40 PM To: Roach, Jovy Cc: Hobbs, Greg S (ANC) Subject: DS 06-19A Jovy, I am reviewing the permit application. It is stated that it is planned to mill out of the casing 5000' md>tvd. In your casing description on the 401, 5000' is also used as the top of your 7" drilling liner and the bottom of the tieback.. In the text (page 8) you do state that the TOL would be ~ 4850'. I am curious regarding the really close approach in the reservoir with 06-23? I don't know that I have seen an approach that close before. Thanks in advance. Tom Maunder, PE AOGCC 6/19/2008 Tolerable CollisiSn Risk Worksheet Use this sheet to justify classifying a well as Minor risk and to establish the Tolerable Collision Risk for use in risk-based well separation rule. Ref. BPA-D-004 (Dir. Svy. H'book) Sections 4.3, 4.4 Prepared by: Jovy Roach Authorised by: YES List all the consequences of collision and the necessary remedial action Name: D-26B to D-26A '~ Here: Close Approach Description: The 06-19A Wp P5 fails the major risk AC with the 06-23 well bore. / Do the \ consequences of collision include a risk to personnel or the environment ? no YES Are tn\ consequences ~ of collision pred? tabl~ no STOP Use Conventional rule -Major ~ risk /r -Collision with the 06-23 well would result in the need for a bit trip and an open hole sidetrack. -The closest point of intersection lies in the reservoir section. There is sufficient MW to balance reservoir pressure should 06-19A accidentally intersect. Also 06-23 will have a tubing tail plug above the collision depth. - The probability of a collision will be reduced by using Geosteering to stay below the shale separating 06-19A and 06-23. Aneutron-density sub will be run, which will improve geological certainty. Key Assumptions (Elements of the drilling pn~gram which are critical to the above analysis) It is assumed that a collision results in a a bit trip and an OH ST. Cost of a collision is set at $500K. How could the probability of collision or the severity of the consequences be reduced ? How might this impact the drilling operation ? Estimate the total cost of substantially V = N/A reducing the risk Tolerable Collision Risk = VF = 0.83 Given the uncertainty in the above estimates, by C how many times must the savings made from not reducing the risk outweigh the risk itself ? VF > 1 close a roach tolerances need not be set (guideline = 20) C pP M = N/A 1 VF Tolerable C F = M = N/A C, ~ 1 ~ Collision Risk = 1 in VF = 1 in 1.2 Estimate the total cost of collision C = $300,000 Is there a YES no practical way to Estimate the value substantially reduce either of the planned well the probability of collision or to the BU the severity of the consequences V = $5,000,000 Accepting a finite risk of collision will reduce the value of the planned well. What reduction, as a fraction of the total value, are you prepared to tolerate ? (guideline = 0.05) F = 0.05 Maunder, Thomas E (DOA) From: Roach, Jovy [Jovy.Roach@bp.com] Sent: Tuesday, June 17, 2008 2:03 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 06-19A -Again Page 1 of 1 Yes we will be pumping a full annulus volume of diesel freeze protect before the cement. Thanks, Jovy From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, June 17, 2008 1:49 PM To: Roach, Jovy Cc: Hobbs, Greg S (ANC) Subject: RE: DS 06-19A -Again Jovy, I presume that you will be pumping freeze protection ahead of the cement for the tieback? That is not stated in the procedure. Regards, Tom Maunder From: Maunder, Thomas E (DOA) Sent: Tuesday, June 17, 2008 1:40 PM To: 'jovy.roach@bp.com' Cc: Greg Hobbs Subject: DS 06-19A Jovy, I am reviewing the permit application. It is stated that it is planned to mill out of the casing 5000' and/tvd. In your casing description on the 401, 5000' is also used as the top of your 7" drilling liner and the bottom of the tieback. In the text (page 8) you do state that the TOL would be ~ 4850'. I am curious regarding the really close approach in the reservoir with 06-23? I don't know that I have seen an approach that close before. Thanks in advance. Tom Maunder, PE AOGCC 6/19/2008 Alaska Department of Natural Resources Land Administration System Page l of~ • __ ~ • ~ is ~~~-r_4~,r's S~~.~=.;~:~ Mate Cabins ~tR1 ~ u S .._.._ Alaska DNR Case Summary File Type. ADS File Number: 28311 ~ Printable Case File_Summary See Township, Range, Section and Acreage? Yes ~' No __~ New Search LA5 t~nca ~ Case A4~stract ~ Cace Detail ~ Land Abstract .~~ I~'ilc': ADL ?831 l ~'~~~~~ Search for 5tatu~ Piat !!~dat~s Customer: 000107377 BP EXPLORATION (ALASKA) INC PO T3OX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tvpe: ~~~ OIL ~ GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Dale: 08/19/1965 Total Acres: ?560.000 Date Initiated OS/?8/1965 Office of Primary Responsibility: DOG D[V OIL AND GAS I ast Transaction Date: (2/04/2006 Case Subtyj~e : ~,t NORTH SLOPE Last transaction: AA-NRB ASSIGNMENT APP ROVED Meridian: U " lowflship: OION R~ur,~r: 014E .~~c°~~lr~~~r.~ O l Section Acres: (~-1U Search' Pats Mcri-irli~in.~ t I L~nrri~l~ij~: O 1(IN I~'urrge: 01 ~I~: ti'ectzon: 02 ti'~~c~liofr _~(~~r~c~~_ 6~(1 l~~T![~l~lil.~ ~,' ~Oll'71 ~'j]l~7: U ~ ~~~~ ~ic7il ~rC: O ~ ~~ ~; ~~~c'C//Ull.~ ~ ~ .ti~('C//UYl .~~Cl'i'~~': ~~-~~) ;11et•rliun.~ l 7'u~t~~~~{~rf~: U I C1N I~~~it,~,~~: 01-11: .C~>~ ~init: I ? .ti~~~clin~t ~Icr~~s: f;-10 Legal Description OS- 28-196 * * ~`SA LF. NOTICE LEGAL DESCRIPTIO,'V * ~` ~` C1-~-132 ION(-lG UM 1, 2,11.12 260.00 U- 3- 7 End s e ~rnm Last updated on 06/17/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28311 &... 6/17/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~~'G~ 06 - »~ PTD# ~o~foa o _ _ Developmeirt~ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: N~-.Cl/D.yDE" ~Ay POOL: ~,~~/,~},~lG~- r~,~y ~ ~ \ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. , API No. 50- - - AP1 number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - _, from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingept 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 throu h tar et zones. Non-Conventional please note the following specia! condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after fComaany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comaanv Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 06.19A Program DEV Well bore see ^ PTD#:2081020 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11650 OnlOff Shon; ~ Annular Disposal ^ Administration 9 Pe[mitfeeattached-------------------------------- ------------ NA-- -------------------- ------------------ - ------------ - ----------------- 2 Lease num4er appropriake- - - - - - - - - - - - - - - - - - - - - Y~ - - - ---------------------------------------------------------- 3 Uniquawettnameandnumbe[------------ - - --- -Yes- ----- -- ----- - - ----- ---- - - -- - - -- ----- 4 Well locatedJna_definedpoQl__________________________ ____________Yes_ ____-_PrudhoeBayFieldlPtudhoeBayfield,-_______________-___.___-_------_-.-___--. 5 -Well(ocatedproperdistancef[omdrillfngt~nit_boundary_______ -__-___Yes ____________________--._________----_--____-,-------------------_-- 6 Well located Proper distance fromQtherwells_______________._ _-__________Yes. .._______-_-____-__-__--_____- ------------------------------------------ 7 Sufficient acrea9e_ayailablein_drillingunit____________________ ____________Yes- ------2569 acres.--_..---_---_---____________._________---_-_--__-____-_-- 8 If deviated,is_wellborePlat-included------ ---- - - - Yes --------- - ------ ------ -- ------ ------------ 9 Operator4n~af[ectedpar4+ -------------- - - - - - - --Yes - -- -- ----- - -- --- ------------------------------------------- 10 Operatorhas-appropriatebopd in fQrce_____________________ ____________Yes_ _-__.SlanketBOnd#61Q4t93.-----__.___________-_- ------------------------------ 11 Pe[miteaDbeissuedwithQUlconserYatien9rder--------------- ------------Yes- ----------------------------------------------------------,-------------- Appr Date 12 Pe[mitcanbeissUedwithoutadminigtrative_app[oval------------ ------------Yes. ----------------------------------------------------------._...------- ACS 611712008 13 Canpermit_beeRRr4vedb8f9re15-daYwait_..---.----------- ---------Yes- -----------------------_---------------------------------,------------- 14 Well_kxetedwithinareaandstratAauth4raQdgYlnlQ~ionO[de[#(putlQ# in_commentsj_(F4r_ NA__ ______-_--____--_-----------------------------------------------_ __ 15 _Ah wells within 1!4_ mid area of [eyiew identified (For- service well only). _ . _ _ - .. .. _ - NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ --------------- 16 Pte•Aroducedinjsctor;duradonofpreproductionlessthan3months(Forserv'lcewellonlY)--~-- -----------------------------__--_.--_--__--_---_----._---_---_---_--_ 17 -NonGOnven, gas-conforms t2 AS31,05.030(1.1.A)~(1.2.A-D) - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Condu-cto[st[i~t9-pl0vlded_._-__---------------------- ------------ NA__ _-_-_-Conduct4rsetinpSOS-19(1821.114)._________._______-__-__,-__--------.__--_--- 19 SudacecasingprotectsallknownU$DWS------------------- -------------PIA__ ______NOaquifers,AIQ4B,_conclusion5,___-_---------------------___--- -- --- 20 CMT-voladequale tocirculate__onconduct9r8,Surf-csg____________ ____________ NA__ __-___Su~facecasingSetin06r19,___._._-_________-----_--__--------_---- 21 CMT-vol adequate t9 Jie•in IQng stung to surf csg _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ ProductiQn_casing set in 06,1$,_ D[illing_lin@r plat~ned_to be fully_cemented. _ - _ - - _ _ _ _ - _ _ _ _ _ - _ _ _ _ _ _ - - 22 CMT_wiilcoyer_ahknown.produotivehorizons_._.------------ ------------Yes- ---------------------------------------------------------------------_-- 23 CasingdesgnsadequateforC,T,B&-pe[mafroSt--------------- ------------Yes- ------.-----.---------------------------------------------------------- ~ 24 Adequate tankage-or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Rig equipped with stefll pits, Nolese[ve pit planned._ All waste_to dppr4ved disposal well(s), - - _ _ _ - _ _ _ _ _ _ _ 25 Ifa-re-d[ill,hasa 90.403#ora4andonmert keen aRprQVed---------- ------------ Yes _-----308.19$------------------------------------,-------------------------- 26 Adequate wellgore separationp[oppsed- - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -Yes - _ - - - _ - Proximity analysis performed, Very close approach in resen!oi[tdentified-likely caused-by suryeYaccuracy, - _ . . 27 If diaertertequited,doesJtmeetre9ulations__________________ _-__--___-- NA__ _-__BQPStsokwillslready-he-in place,-_---_-.-_._-_---__- ------------ Appr Date 28 Drilling fluld_program schematic_& equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - - - _ _ Maximum expected formation presspre 7,2_~MW.- MW planned up ko 19:Oppg in 8-1/2"-hole-and $.5ppg in zone. TEM 6119/2008 29 BOP6s,-do theyrneetregulation------------------------- ------------Yes- --------------------------------------------------------,---------_-- ~~ 30 BOPI:_press rating appropriate; test to_(put prig in comments)- - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ _ - MA$P calculated at 2420psi, 3500_psi_BQP te6t planned. - - _ _ - - - - - - - ---------------- ~ 31 Choke manifoldcomplieswlAPI-RP-53[-MaY$4_)---- -- ------ ------------Yes- -- - - -- --- -- -------- ---- -- - - - -- --- 32 Work will gccurvnthopt_operationshutdown--- -- -- --- -- ------------ Y~- - - - - -- --- --------- - ------- -- -- -- ---- 33 Is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - - _ - - H2$ is reperted_at D$ Oli._ Mud should preclude H~S_ on_rig, Rg has Sensors and alarms._ _ - - - - . - - _ _ 34 MechanicslconditionofwellswithinAQRverified(FO[serviceweflonly)__ ---_______ NA__ __-_.-_________________________________---__-_-__--------_ __ _ Geology 35 Pe[miteant~eissuedwlohYdragen_su~demeasu[es_____________ ____________ No__ ______MaxlevelH2$onPadwas2~pmwell06.13(1!9104).________-__-._-_________-_---_-- 36 Data-Presented on Rotential 9verpressure zones - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 37 Se[smica>talysisofshallowgaszones______________________ ____________NA__ -______-_____________---_---______-__--- _ ACS 6(17!2008 ~ Seaked_conditfon Survey_(ifoff-shore) - - - - - - - - - - - - - - - - - - - - - - - _ _ - - - _ . NA_ _ _-- ------------------- _ _ - ---------------- 39 Contactname/phoneforweekly-proaressrepods[exploratoryony]--_- ______--_--Yes ------,lovyRoach-5C~4-4352•---------------------------------------------------- Geologic Engineering Pu Commissioner: Date Date: Commissioner: Co s ' Daie r ~~~,,~- ~-~s a~ ~~~ p- o~
