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Home My WebLink About193-146)R3)4r✓c Regg, James B (CED) From: Regg, James B (CED) Sent: Monday, January 27, 2020 2:50 PM� j'Z?(ZOZ C To: 'Ketchum, John M' Subject: RE: NGL meter 3017 prover plan Attachments: Postpone PBU NGL Export Meter Proves 11-21-19.pdf, PBU NGL Comparison Jan2019.pdf, PBU_B-35 nov closeout 3-28-18.pdf Thank you for the introduction last week and discussions regarding our B-35 defeated SVS closeout letter and the NGL prover 4 -way valve leak. PBU NGL Prover—attached are the previous approval letter postponing proves and the NGL meter comparison used to track meter performance. AOGCC will accept this same approach while the NGL meter cannot be proved for an estimated 4 months. Contact as soon as you are aware of the delivery date for parts to repair the 4 -way valve and we can discuss the timing for repairs (i.e., BP's question about allowing the repairs to be scheduled to coincide with planned shutdown). -35 Defeated SVS —The closeout letter (3/28/19) for the notice of violation indicates AOGCC is satisfied with the corrective actions plan and quarterly update meetings while corrective action are implemented. Is there a final version of the corrective actions table that shows all actions completed or a summary of the fieldwide SVS performance audit report against the B-35 findings? With that I can prepare an update to the 3/28/18 closeout letter. Jim Regg Supervisor, Inspections AOGCC 333 W.7'^ Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.re¢z@alaska.¢ov. From: Ketchum, John M <John.Ketchum@bp.com> Sent: Friday, January 24, 2020 11:43 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Ketchum, John M <John.Ketchum@bp.com> Subject: NGL meter 3017 prover plan Jim — Thank you for your time yesterday. It's nice to have a face to go with a name. As per our discussion, we are currently unable to prove our NGL meter number 3017 to Kuparuk, due to a packing leak on the four-way valve. We have ordered materials for the repair and have been quoted 110 day lead time. Our supply chain organization is working to expedite delivery. In the interim we will be unable to provide the standard meter proving reports, however, per your guidance, we can provide meter variance data from the Kuparuk meter and our meter, and will do so in the format you provide. To avoid recurrence of the delay in our ability to affect a similar repair in the future, we are identifying critical spares to be stocked in our materials warehouse. Once we have line of site of the arrival of the materials required for the repair, we will review our maintenance execution schedule and I will contact you to agree the best timing for completing the work. Please let me know if you need further information. Regards, John Ketchum Area Operations Manager US Mobile: +1 907 952 7368 THF STATE .z.,-LASKA GOVERNOR BILI. WALKER November 21, 2018 Mr. Glen Pomeroy Pipeline Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number; OTH- 18-056 Delay PBU NGL Export Meter Proves Prudhoe Bay Unit NGL Dear Mr. Pomeroy: Alaska Oil and Gas Conservation con-ImIssion 333 Vvest Seventh Avenue Ancroiage. Alaskr 99' 0 1-35 7 2 .Vain 907.279.1433 Fox: 907.276.7542 vwv✓.aoycr__a"mko.g^.v The Alaska Oil and Gas Conservation Commission (AOGCC) granted approval to BP Exploration (Alaska) Inc. (BPXA) to reinstate and operate the Prudhoe Bay Unit (PBU) natural gas liquids (NGL) export metering system. NGL sales meter reinstatement was conditionally approved on August 30, 2018. Since restart, BPXA has been unable to prove the NGL export meter due to a failed 4 -way valve. By email dated October 31, 2018 BPXA requested a delay for proving the NGL meter. That request was supplemented by additional information provided to AOGCC on November 2-6, 2018, including a comparison of NGL volumes shipped from PBU and received at Kuparuk River Unit Central Processing Facility I (KRU CPF- 1). BPXA notes that for the month of October 2018 the total variation between the two meters was -0.12 percent (volume received greater than sales volume). BPXA also notes that parts to repair the 4 -way valve will not be available until January 2019. AOGCC grants BPXA's request to postpone proving the PBU NGL export meter (to Kuparuk River Unit CPF-1) until repairs can be completed on the 4 -way valve and its functionality confirmed. BPXA is instructed to continue comparing the volumes of NGLs as measured by both the PBU NGL sales meter and the KRU CPF-I receipt meter using a weekly rolling average. BPXA must contact AOGCC if the volume difference exceeds +l-0.50% for any rolling weekly average. A monthly report of the rolling weekly averages shall be provided to AOGCC until the PBU NGL meter can be proved. The report must include the volumes measured at both meters and the volume difference (reported in barrels and a percentage). Please contact Jim Regg of our staff at 793-1236 if you have any questions on this approval. Sincerely, Hollis S. French Chair, Commissioner Regg, James B (CED) From: Pomeroy, Glen <Glen.Pomeroy@bp.com> Sent: Monday, February 18, 2019 7:57 AM To: Regg, James B (DOA) Cc: Fencil, Kollin S; Noble, Jessica M Subject: FW: NGL Meter Comparison for January Revised Jim, I am sending you revised numbers. I did not have the correct timing for the data pull for the placing the date in the table. The excursion that I saw was due to my error. Thanks, Glen R N1 Dally % 7 Day 7 Day var. 7 -Day Daft CPF-2 PRO Sacha (CPF-1) - (PBR) var. Total (bbla) % var FI-CR1007 FI -3017 DHtarenae 1 -Jan -19 10244.00 10221.00 -23 -0.23% 74037.00 -71.00 -0.10% 2 -Jan -19 7768.00 7722.00 -46 -0.60% 71379.00 -146.00 -0.20% 3 -Jan -19 11750.00 11712.00 -38 -0.32% 71749.00 -102.00 -0.14% 4 -Jan -19 12776.00 1I841.00 65 0.51% 73548.00 26.00 0.04% 5 -Jan -19 12960.00 13064.00 104 0.80% 76197.00 148.00 0.19% 6-lan-19 12141.00 12154.00 13 0.11% 78048.00 68.00 0.09% 7 -Jan -19 11455.00 11490.00 35 0.30% 79204.00 110.00 0.14% 8 -Jan -19 11909.00 12000.00 91 0.76% 80983.00 224.00 0.28% 10 -Jan -19 11728.00 11724.00 -4 -0.03% 84985.00 266,00 0.31% 11 -Jan -19 11231.00 11252.00 21 0.19% 84525.00 325.00 0.38% 12 -Jan -19 10593.00 10670.00 77 0.72% 82354.00 337.00 0.41% 13 -Jan -19 11669.00 11633.00 -36 -0.31% 80923.00 197.00 0.24% 14 -Jan -19 10958.00 10937.00 -21 -0.19% 79706.00 153.00 0.20% 15 -Jan -19 9612.00 9684.00 72 0.74% 77900.00 200.00 0.26% 16 -Jan -19 10608.00 10421.00 -187 -1.79% 76321.00 -78.00 -0.10% 17 -Jan -19 10841.00 10801.00 -40 -0.37% 75398.00 -114.00 -0.15% 18 -Jan -19 10032.00 10038.00 6 0.06% 74184.00 -1Z9.00 -0.17% 19 -Jan -19 10334.00 10336.00 2 0.02% 73850.00 -204.00 -0.28% 20 -Jan -19 10446.00 10555.00 109 1.03% 72772.00 -59.00 -0.08% 21 -Jan -19 10250.00 10305.00 55 0.53% 72140.00 17.00 0.02% 22 -Jan -19 10072.00 10032.00 -40 -0.40% 72488.00 -95.00 -0.13% 23 -Jan -19 9241.00 9231.00 -10 -0.11% 71298.00 82.00 0.12% 24 -Jan -19 8583.00 8551.00 -32 -0.37% 69048.00 90.00 0.13% 25 -Jan -19 8644.00 8654.00 10 0.12%� 67664.00 94.00 0.14% 26 -Jan -19 8615.00 8623.00 8 0.09%� 65951.00 100.00 0.15% 27 -Jan -19 8761.00 8752.00 -9 -0.10%� 64148.00 -18.00 -0.03% 28 -Jan -19 8885.00 8807.00 -78 -0.89%r 62650.00 -151.00 -0.24% 29 -Jan -19 8769.00 8836.00 67 0.76%� 61454.00 -44.00 -0.07% 30 -Jan -19 8648.00 8704.00 56 0.64%� 60927.00 22.00 0.04% 31 -Jan -19 8670.00 8745.00 75 0.86%r 61121.00 129.00 0.21% 1 -Feb -19 9046.00 9070.00 24 0.26%' 61537.00 143.00 0.23% 2 -Feb -19 8635.00 8658.00 23 0.27%� 61572.00 158.00 0.26% 3 -Feb -19 8456.00 8373.00 -83 -0.99%� 61193.00 84.00 0.14% 4 -Feb -19 8856.00 8856.00 0 0.00%v 61242.00 152.00 0.26% 5 -Feb -19 8342.00 8328.00 -14 -0.17%F 60734.00 81.00 0.13% 2 From: Pomeroy, Glen Sent: Thursday, February 14, 20191:50 PM To: jim.regg@alaska.gov Cc: Noble, Jessica M <jessica.noble@bp.com>; Fencil, Kollin S <kollin.fencil@bp.com> Subject: NGL Meter Comparison forJanuary Jim, I am providing the NGL meter comparison for January. I have also included the first part of February's data as well due to an excursion that went up to 3.45%. 1 believe the excursion is due to the rapid changes in ambient temperature that affected the volume in the pipeline over its 3.7 day transit time (-13F to+22F and now back to -30F). The variation between the meters appears to be returning to normal and our totals to date are within 0.33%. 1 will continue to monitor and keep you updated. The replacement actuator should arrive by the end of the month. If you have questions or comments, please contact me. Thanks, Glen Dally % 7 Day 7 Day var. 7-Day Date CPF-1 PRB Sales (CPF-1) - (PBR) var. Total (bbis) %var FI-CR1007 FI-3017 Difference 1-Jan-19 10244.00 10221.00 -23 -0.23%r 74037.00 -71.00 -0.10% 2-Jan-19 7768.00 7722.00 -46 -0.60%r 71379.00 -146.00 -0.20% 3-Jan-19 11750.00 11712.00 -38 -0.32%r 71749.00 -102.00 -0.14% 4-Jan-19 12776.00 12841.00 65 0.51%r 73548.00 26.00 0.04% 5-Jan-19 12960.00 13064.00 104 0.80%r 76197.00 148.00 0.19% 6-tan-19 12141.00 12154.00 13 0.11%r 78048.00 68.00 0.09% 7-Jan-19 11455.00 11490.00 35 0.30%r 79204.00 110.00 0.14% 8-Jan-19 11909.00 12000.00 91 0.76%r 80983.00 224.00 0.28% 10-Jan-19 11728.00 11724.00 -4 -0.03%r 84985.00 266.00 0.31% 11-tan-19 11231.00 11252.00 21 0.19%r 84525.00 325.00 0.38% 12-Jan-19 10593.00 10670.00 77 0.72%r 82354.00 337.00 0.41% 13-Jan-19 11669.00 11633.00 -36 -0.31%r 80923.00 197.00 0.24% 14-Jan-19 10958.00 10937.00 -21 -0.19%r 79706.00 163.00 0.20% 15-Jan-19 10958.00 10937.00 -21 -0.19%r 79153.00 107.00 0.14% 16-Jan-19 10608.00 10801.00 193 1.79%r 77954.00 209.00 0.27% 17-Jan-19 10841.00 10801.00 -40 -0.37%r 77031.00 173.00 0.22% 18-Jan-19 10841.00 10801.00 -40 -0.37%r 76580.00 112.00 0.15% 19-Jan-19 10334.00 10555.00 221 2.09%r 76465.00 256.00 0.33% 20-Jan-19 10445.00 10555.00 110 1.04%r 75387.00 402.00 0.53% 21-Jan-19 10445.00 10555.00 110 1.04%r 75005.00 533.00 0.71% 22-Jan-19 10250.00 10305.00 55 0.53%r 74373.00 609.00 0.82% 23-Jan-19 10072.00 10032.00 -40 -0.40%r 73604.00 376.00 0.51% 24-Jan-19 9241.00 9231.00 -10 -0.11%r 72034.00 406.00 0.56% 25-Jan-19 8644.00 8654.00 10 0.12%r 69887.00 456.00 0.65% 26-Jan-19 8644.00 8752.00 108 1.23%r 68084.00 343.00 0.50% 27-Jan-19 8761.00 8807.00 46 0.52%r 66336.00 279.00 0.42% 28-Jan-19 8886.00 8836.00 -50 -0.57%r 64617.00 119.00 0.18% 29-Jan-19 8886.00 8836.00 -50 -0.57%r 63148.00 14.00 0.02% 30-Jan-19 8769.00 8836.00 67 0.76%r 61952.00 121.00 0.20% 31-Jan-19 8669.00 9070.00 401 4.42%r 61791.00 532.00 0.86% 1-Feb-19 9046.00 9070.00 24 0.26%r 62207.00 546.00 0.88% 2-Feb-19 9046.00 9070.00 24 0.26%r 62525.00 462.00 0.74% 3-Feb-19 8636.00 8856.00 220 2.48%' 62574.00 636.00 1.02% 4-Feb-19 8456.00 8856.00 400 4.52%r 62594.00 1086.00 1.73% AnCC nn QQCC nn Ann A CIW r Cn CSA nn icier nn I ACW 4 % Variatlor October Total 254919.00 255222.00 303.00 0.12% November Total 295850.00 295816.00 -34.00 -0.01% December Total V 323295.00 V 323570.00 275.00 0.08% January Total 312476.00 ' 313784.00 285.00 0.09% Running Total Through January Total Through Feb 13th Thanks, Glen Glen Pomeroy 907-564-5921 r 1186540.00 r 1188392.00 1852.00 0.16% r 1298213.00 V 1302458.00 4245.00 0.33% 5 by BP Exploration (Alaska)Inc, Glen Pomeroy 900 E. Benson Boulevard Pipeline Manager Anchorage, Alaska 99508 Tel: (907) 564-5921 Fax: (907) 564-5706 Email: Glen.Pomeroy@bp,corn March 12, 2018 lR31y Cathy P. Foerster Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501-3572 Subject: Update to BPXA Response Docket Number: OTH-18-001 Notice of Violation - Defeated Safety System Unit B-35 Dear Commissioner Foerster: On January 18, 2018, the Alaska Oil and Gas Conservation Commission (AOGCQ issued a Notice of Violation to BP Exploration (Alaska Inc. (BPXA) for a low-pressure pilot that was found defeated at the time of performance testing. On February 5, 2018, BPXA responded and asked for additional time to finish our investigation, which the commission granted until March 12, 2018. BPXA initiated a formal incident investigation to determine if there were systemic issues that needed to be corrected as an acute cause for defeating the B-35 law pressure pilot was not readily apparent and similar incidents have occurred previously at different facilities. The investigation has concluded. The investigation could not find the root cause for closing the root valve and defeating the B-35 low pressure pilot. No specific event or time could be identified when the root valve was closed on the B-35 pilot. This investigation reviewed this and similar historical incidents of defeated SVS systems that have occurred across the field Below is a summary of the investigation findings and the recommended actions that are being undertaken to prevent a future reoccurrence of this type of event. The summary is followed by elements extracted from the investigation report to provide additional context associated with this event and with the findings and recommendations. 1. SUMMARY OF INVESTIGATION FINDINGS AND ACTIONS The investigation team followed necessary lines of inquiry, conducting interviews and performing other assessments and analysis. The team found that the Prudhoe Bay field has experienced several documented SVS events between 2011 and 2017 in which SVS valves were found out of position. These events occurred across the field and each incident's corrective actions only addressed the particular facility involved and were not systematically communicated across field. The event reports focused only on the human error causation and did not highlight the specific barrier requirements within BPXA's Well Update to BPXA Response to NOV AOGCC Docket Number., OTH-18-001 March 12, 2018 Page 3 Finding: The daily TIO inspection procedure in the Operator Tools program does not meet the requirements of BPXA's WIOP procedure, nor is the procedure used field wide. Action. Same as Action 4 above. In addition to the Actions discussed above, BPXA also proposes that we meet quarterly with AOGCC to provide a progress report on the implementation of these Actions. BPXA is also preparing a lessons learned document that will be shared with our personnel across the field. And to help other operators avoid similar issues, BPXA will be sharing the lessons learned with the Prudhoe Bay owners and other North Slope operators. 2. BACKGROUND Event Summary On Thursday January 11, 2018, BPXA was performing "state tests" on all flowing production wells on the Prudhoe Bay Unit B -Pad using an approved well test procedure. An AOGCC representative was present to witness the tests. During the opening of the p - pilot test port valve to pressure the test manifold on B-35, the well inadvertently tripped and the surface safety valve (SSKI immediately began closing. The well trip and closure of the SSV should not have occurred at this stage of the test, highlighting an abnormal condition. BPXA personnel immediately reached down and found the root valve on the pressure pilot blocked in (closed) and notified a supervisor over the radio. A BPXA employee then reached down and opened the root valve. This valve is normally open. The closed root valve would have prevented the SSV from closing under demand. No hydrocarbons or other fluids were released as a result of the event. Shortly after the event BPXA initiated a formal investigation, and that investigation has concluded. Location: B -Pad, Well B-35 B -Pad is a GC -3 production pad south of GC -3 containing 37 wells. The wells flow to the manifold building then to GC -3 via the common lines. Update to BPXA Response to NOV AOGCC Docket Number. OTH-I8-001 March 12, 2018 Page 5 box along with P -Pilots (2), and a small heater to keep the pilots from freezing and a test valve used for maintenance and testing. P -Pilots The term P -Pilot comes from the old Otis type "P" hi -low monitor. These are used on the skid 52/FMX Wells such as B-35. The purpose of the pilot is to shut in the SSV if low pressures are detected on downstream piping. Root Valve The Root Valve is the isolation control needle valve located within the O'Brien box between the well pressure source and the pilot. The root valve is utilized to isolate or supply well line pressure to the pilot and can be manipulated open or closed to allow testing or replacement of the pilot. B-35 Root Valve and P -Pilot located Inside the O'Brien Box (Note: O'Brien Box cover removed to show root valve) RECEI D \a3 -`2k6 ,its • 2,�2.,°► 3 BAKER JUN 15 2017 PRINT DISTRIBUTION LIST HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc BP Exploration(Alaska) Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED /zZ/2 'j WELL NAME B 6 o1 -35 900 E. Benson Blvd. ivl. K. BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska LOG DATE May 10,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares a(�bakerhughes.com TODAYS DATE June 7,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO* LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF F'RIN I S #OF COPIES #OF COPIES #OF COPIES V v J U Baker Hughes,Inc. 0 0 795 E.94th Ave. Anchorage,AK 99515 Attn: Arelys Carolina Martinez Patrick Rider 2 ConocoPhillips Alaska Inc. 1 1 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 1 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 I 1 Attn:Makana Bender JUN W.7th Ave,Suite 100 SCANNED JUN 2 7 201Z Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 1 1 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Gerardo Cedillo TOTALS FOR THIS PAGE: 0 3 4 0 TOTALS FOR ALL PAGES: 0 3 4 0 0 OMEN.) 93- \-V, NMI BAKER JUN D 2 2017 PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANYBF�Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED WELL NAME B-35 900 E. Benson Blvd. G/(3/2017 M.K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE May 10,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(cr�bakerhughes.com TODAYS DATE June 1,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO$ LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF F'RIN I S #OF COPIES #OF COPIES #OF COPIES V v v 4 4 1 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 IJUN 1 5 2Vn1? 700 G Street �NE� Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 (Anchorage,AK 99503 4 State of Alaska -AOGCC I 0 1 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ' Confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 0 0 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David atter TOTALS FOR THIS PAGE: TOTALS FOR ALL PAGES: 9 3 t 0 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 G< ~~~. Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad B Dear Mr. Maunder, DEC 1 6 2009 i~~~~ C-i1 Gas Cons. Commissi~~ An~hQrs~e ~~ 3- «~ ~3-~s Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B 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) nA•e• »/~ una Well Name PTD # API # Initial to 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 B-01 1700080 50029200590000 Sealed Conductor NA NA NA NA NA B-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-O58 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-O6 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-t0A 2082050 50029203210100 Cellar liner welded to Iasi NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 B-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1.70 8/20/2009 B-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 B-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 8-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 B-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 B-23 1970590 50029207790100 12 2.2 BBLS 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 B-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214770100 Sealed Conductor NA NA NA NA NA 8-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 8-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA LJNDER EVALUATION: B-35 ~D #1931460) TxIA Communication n~d during shu... Page 1 of 1 ~ Regg, James B (DOA) From: NSU, ADW Weil Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, July 03, 2009 3:15 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; GPB, Well Pad AB Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer; Schmoyer, AI Subject: UNDER EVALUATION: B-35 (PTD #1931460) TxIA Communication noted during shut-down Attachments: B-35 TIO PIot.ZIP; B-35.pdf All, ~ Well B-35 (PTD #1931460) is exhibiting TxIA communication. it is unclear if the well was stacked out with gas lift in order to freeze protect the well for the GC3 facility shut-down and therefore if the pressure was imposed. Wellhead pressures of tubing/IA/OA equal to SSV/2200/0 were noted on 06/28/09. The IA pressur~ increased 1050 psi overnight after bein bled from 2350 to 1290 si on 06/29/09. The well has been reclassified as Under Eva ua ion. e p an forward includes returning the well to production after the shut-down and attempting to reseat the check valve in the gas lift valve. Plan forward: 1. Downhole Diagnostics: Bleed IA pressure, monitor build-up rate - DONE 2. Operations: POP well 3. Downhole Diagnostics: TIFL the well post POP j 4. WIE: Evaluate if GLV checks seated A TIO plot and wellbore schematic have been included for reference. «B-35 TIO PIot.ZIP» «B-35.pdf» Please let us know if you have any questions. Thank you, Anna ~u6e, ~P. E. w...:~. ~~~~-~.~,~ , ~: ~ ,~ .. ~OD~ Well IntegriLy Coardinator GPB Wells Graup Phone: {90T) 659-5102 Pager: {807) 659-5100 x1154 8/31 /2009 PBU B-35 PTD #1931460 7/3/2009 TIO Pressures __ ._ ~ <.~ II 3,000 ~ 2,0~ ~ ! 1.000 -~- Tbq ^ IA ~ OA OOA • OOQ4 ~ On ~ • TREE = CNV WELLHEAD= FMC ACTUATOR= BAKER C KB. ELEV.-x ~ 68.2' BF. EI~kV = 37J` KOP = 2072' ,_,...~ ~., ~ Max Angle = _~~ 22° @ 5733' Datum MD = 9216' DatumND= 8800' SS I 20" CONDUCTOR, ID = ? 10-314" CSG, 45.5#, NT80 BTRS, ID = 9.950" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 3415 3798 2964 3700 21 19 KBG-2 KBG-2 DOME SO BK BK 16 24 10/20(08 10/20/08 4-1/2" HES X NIP, 1D = 3.813" ~ SAFET E5: "`* 4-112" & 5-1i2 CHROMETBG 8~ B~V~ ~NR~~~ / 2111' 4-1/2" HES X NIP, ID = 3.813" Minimum ID = 3.725" @ 3975' 4-1/2" HES XN NIPPLE 3888~ ~-{ 7-5/8" X 4-1l2" BKR S-3 PKR, ID = 3.875" 3912' ~~ 4-112" HES X NIP, iD = 3.813" 3975~ I-I4-1/2" HES XN NIP, ID = 3.725" ~TOPOF 4-112" SCAB LNR 4-1l2" TBG, 12.6#, 13GR-80 VAM TOP, .0152 bpf, ID = 3.958" 1/2" SCAB LNR, 12.6#, 13CR-80 VAM ACE I--~ 5455' ~ 13CR-80 NSCT 4-1/2" SCAB LNR, 12.6#, ~ 8781~ 13CR-80 NSCT, .0152 bpf, ID = 3.958" TOP OF 5-1l2" LNR $~$$' 7-518" CSG, 29.7#, NT95HS, ID = 6.875" 8936' F'ERFORATION SUMMARY REF LOG: AWS BHCS 12(06(93 ANGLE AT TOP PERF: 4° @ 9172 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAI Opn/Sqz DATE 3-3/8 6 9172-9194 O 12l27193 3-3/8 6 9202-9222 O 12/24l93 ~ PBTD 5-112" LNR, 17#, 13CR-$0 FOX, .0232 bpf, ID = 4.892" 3996, '--17-5/8" X 5-1 /2" BKR 2XP LTP ~ w/ TIEBACK SLV, ID = 4.920" ( 4003` 4-1(2" MULE SHOE, ID = 3.958" 4Q13" 7-518" X 5-1/2" BKR F~IX LOCK HGR, ID - "?,~ 4022' ~ 5-1/2" X 4-1l2" XO, ID = 3.958" 9214' ~-~ FISH - FRSRRIL DEBRIS (RWO 10/15/08) DATE REV BY CQMMENTS DATE REV BY COMMENTS 12/25/93 N18E ORIGINAI COMPLETION 10/17lO8 N4ES RWO 1q/24l08 DAV/TLH G~V GO & CORRECTIONS _ 11I11t08 HBIJMD DRLGDRAFTCORRECTIONS 12t15108 HB/PJC DRLG DRAFT CORRECTIONS f~tUDHOE BAY UNrf W 1.L: B-35 PF_RMIT Na: ~1931460 API Na: 50-029-22406-00 Sec. 31, T11 N, R14E, 1924 FNL & 1607 FEL BP Euploration (Alaska) Page l of 1 Maunder, Thomas E (DOA) From: Baca, Hank [hank.baca@bp.com] Sent: Thursday, November 20, 2008 9:28 AM To: Maunder, Thomas E (DOA) Subject: RE: B-35 (193-146) Tom, the LLR info was just to help determine if we needed LCM and/or fluid loss additives in our cement. The intention was to cement off the damaged casing, and not to squeeze. Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, November 20, 2008 9:04 AM To: Baca, Hank Cc: Reem, David C Subject: B-35 (i93-146) Hank, I am reviewing the 404 for the recent workover on this well. When the scab liner was cemented, it does not appear that any squeeze pressure was applied to force cement out of the damaged casing. A series of injection rates had been determined previously, so it would seem that squeezing was intended. I have seen this when such liners are set in similar cases. Could you comment? Thanks in advance, Tom Maunder, PE AOGCC 11/20/2008 STATE OF ALASKA // A~ OIL AND GAS CONSERVATION CO~SSION REPORT OF SUNDRY WELL OPERATIONS S .. ~ ,_' ~~na 1. Operations Performed: ^ Abandon ®Repair We11 - ^ Piug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development- ^ Exploratory 193-146 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22406-00-00 ' 7. KB Elevation (ft): 67, , 9. Well Name and Number: PBU B-35 - 8. Property Designation: 10. Field /Pool(s): ADL 028310 ' Prudhoe Bay Field !Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9585' ~ feet true vertical 9236' feet Plugs (measured) None Effective depth: measured 9502' feet Junk (measured) None true vertical 9153' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 110' 110' 1490 470 Surface 3165' 10-3/4" 3195' 3132' 5210 2480 Intermediate 8908' 7-5/8" 8936' 8588' 8180 5120 Production Liner 797' 5-1/2" 8788' - 9585' 8441' - 9236' 7740 6280 Scab Liner 4785' 4-1/2" 3996' - 8781' 3889' - 8434' 8430 7500 Perforation Depth MD (ft): 9172' - 9222' Perforation Depth TVD (ft): 8824' - 8873' 4-1/2", 12.6# 13Cr80 4003' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8" x 4-1/2" Baker'S-3' packer 3888' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing. Run 4-1/2", 12.6#, 13Cr80 Scab Liner, cement w/ 147 Bbls Class'G' (825 cu ft / 712 sx). Run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to weN operation: Subsequent to operation: 174 3,063 536 1,260 -0- 14. Attachments: ~] Copies of Logs and Surveys run 15. Well Class after work: - ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 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: Contact Hank Baca, 564-5444 308-281 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: ~` Si nature Phone 564-4628 Date ~ ~ Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 s .~ a ~ it - s , ... ; ~7l~ Submit Original Only ~,i~~ C1 • B-35, Well History (Pre Rig Workover) Date Summary 7/25/2008 T/IA/OA= SSV/150/0 Temp= 40 PPPOT-T (PASS) PPPOT-IC (PASS) PPPOT-T RU 2 HP bleed tools onto THA 100 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment, re-installed Alemite caps. Cycled out 1.0" ran in torqued to 450 ft/Ibs "ET style" all LDS were in good visual and working order. PPPOT-IC RU 2 HP bleed tools onto IC test void 0 psi. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3450/ 30 minutes. Bleed void to 0 psi, RD test equipment, re-installed Alemite caps. Cycled out 1.0" ran in torqued to 450 ft/Ibs "ET style" all LDS were in good visual and working order. 8/9/2008 T/I/0= 1900/120/0 Temp= si MIT-T to 1000 psi FAILED. Pump 3 bbls meth, 100 bbls crude down tbg to fluid pack. pump 11 bbls crude to reach test pressure. Attempt 1--TP lost 80 psi 1st 15 min. TP lost 90 psi 2nd 15 min. Attempt 2--TP lost 70 psi 1st 15 min. TP lost 70 psi 2nd 15 min. Attempt 3--TP lost 70 psi 1st 15 min. TP lost 50 psi 2nd 15 min. Attempt 4--TP lost 50 psi 1st 15 min. TP lost 50 psi 2nd 15 min. TP lost 50 psi 3rd 15 min. Bled tbg pressure down flowline. Pumped 7 bbls crude to reach test pressure. Attempt 5--TP lost 60 psi 1st 15 min. TP lost 60 psi 2nd 15 min. Attempt 6--TP lost 60 psi 1st 15 min. TP lost 50 psi 2nd 15 min. Bled TP to 30 psi. TP lost 20 psi after 30 min. FWHP's=10/140/0 Annulus valves open to gauges. Caution tags hung on master & wing valves, & pad op notified. 8/11/2008 T/I/O = 0/0/0 Temp = SI "'"MITT passed to 1000psi (2nd test)"" Pumped 5bbls meth, 5.5bbls diesel to fluid pack. Pumped 0.9bbls diesel to pressure up. Tubing lost 10psi 1st 15min, Opsi 2nd 15min, for a total of 10psi in 30min. Bled tubing to zero. FWHP's 0!0!0 8/11/2008 WELL SHUT IN ON ARRIVAL. DRIFT TUBING WITH 3.70" CENT, 1.75" SAMPLE BAILER, TO 8725' SLM. TESTED PXN PLUG TEST PASSED. BLED IA AND TUBING TO 0 PSI. RIG DOWN TURN WELL BACK TO DSO. NOTIFY DSO OF DEPARTURE. 8/14/2008 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O:150/100/0. RIG UP E-LINE WITH 3.65" POWER CUTTER. CUT 4.5" TUBING Cam? 8704'. 8/15/2008 CONTINUE TO POOH. RIG DOWN E-LINE. FINAL T/I/O: 0/100/0. GAUGES LEFT AS FOUND: SSV=O, WING=C, MASTER=O, SWAB=C. WELL LEFT SHUT-IN. DSO NOTIFIED. JOB COMPLETE. 8/17/2008 Circ well & freeze protect. (RWO prep) Road to P/U procedure & load neat. Road to location. 8/18/2008 T/I/0=250/100/0 Temp=S/I Circ well & freeze protect. (RWO prep) Pumped a total of 11.7bbls meth down tubing. No communication to IA. Bleed down. Pumped 76bbls 60/40 down IA. Established LLR of 4.8bpm C~ 1450psi. (PC leak), LLR of 2bpm C~ 1050psi, LLR of 1 bpm Q 750psi. Rigged back up to tubing. Pumped 36.5bbls 60/40 down tubing to establish communication. Noticeably pushing something down hole. Established flow path down tubing, through cut, into PC leak. Start Circ-out. Pumped 350bb1s 9.8# Brine down tubing, through cut, up IA, down flowline. Shut flow path to flowline. Pumped additional 30bbls brine down tubing into PC leak ~ 4.6bpm. Followed brine w/ 8bbls diesel (freeze protect.) Rig up to IA. Pumped 198bb1s 9.8# Brine down IA, into PC leak, followed by 15bbls diesel (freeze protect.) FP F/L with 2 bbls neat followed by 61 bbls crude followed by 92 bbls crude and capping w/ 8 bbls diesel. FWHP's=0/0/0 Annulus casing valves open and tagged. DSO notified of following wellhead status upon departure. Swab,Wing, SSV=S/I /Master, IA, OA =Open. 8/20/2008 T/I/O=Vac/0/0. Set 4" CIW H BPV # 146 thru tree, pre rig. 1-2' ext used, tagged C«~ 100". No problems. 9/3/2008 T/I/O/= SSV/vac/0 MIT OA PASSED to 2000 psi (RWO Prep). Pumped 5.2 bbls crude down OA to pressure up to 2000 psi. OA lost 110 psi in 15 min and 40 psi in 2nd 15 min for a total 30 min loss of 150 psi. Bled OAP (2 bbls). Tag hung and IA & OA valves open to gauges upon departure (scaffolding already removed). FWP's=SSV/0/0 10/6/2008 T(I(O=Vac/O/0; Pulled 4-1/16" CIW "H" BPV #146 thru tree for 4ES post move on; 1-2' ext. used, tagged ® 102". Complete. Page 1 of 1 BP EXPLORATION Operations Summary Report Legal Well Name: B-35 Common Well Name: B-35 Event Name` WORKOVER Start: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: Date From - To I Hours ~, Task Code NPT I Phase DECOMP Held PJSM. Tested lines to 250 psi low / 3500 psi high. Displaced well to warm 9.8 ppg brine. Pumped total of 367 bbls brine. Pump pressure varied from 330 psi to 1400 psi at 4-5 bpm. T/I/O 0/0/300 psi. Shut down pumping and monitored well; well dead and stable. DECOMP Installed TWC. Tested TWC from above to 350~i for 10 10/5/2008 18:00 - 00:00 6.00 RIGD P PRE Scoped down and lowered derrick. Prepared rig for move. 10/6/2008 00:00 - 04:00 4.00 MOB P PRE Moved rig F-Pad to B-Pad. 04:00 - 06:00 2.00 MOB P PRE Spotted and bermed rig module and pits. Spotted pipe shed, camp and shop. 06:00 - 09:30 3.50 RIGU P PRE Held crew change and performed pre-tour checks. Raised and scoped up derrick. RU lines to pits, tree and tiger tank. Loaded 9.8 ppg brine. Accepted ria at 08:On brs in/6/2008, 09:30 - 10:30 1.00 WHSUR P DECOMP RU lubricator and tested to 500 psi. Pulled BPV and RD 10:30 - 14:30 I 4.001 KILL I P 14:30 - 16:00 I 1.50 I W HSUR I P 16:00 - 19:30 3.50 WHSUR P 19:30 - 21:30 2.00 WHSUR P 21:30 - 00:00 2.501 WHSUR P 10/7/2008 ~ 00:00 - 04:00 ~ 4.00 ~ W HSUR ~ P 04:00 - 05:00 1.00 PULL P 05:00 - 06:00 1.00 PULL P 06:00 - 08:00 I 2.001 PULL I P 08:00 - 09:00 I 1.001 PULL I P 09:00 - 10:00 I 1.00 I PULL I P 10:00 - 13:00 I 3.001 PULL I P 13:00 - 18:00 I 5.001 PULL I P 18:00 - 19:00 I 1.001 PULL I P 19:00 - 20:30 I 1.501 PULL I P 9/11 /2008 Page 1 of 7 Spud Date: 11 /24/1993 End: 9/16/2008 Description of Operations minutes. Pumped down DECOMP PJSM. ND tree. MU XO, landing joint and TIW valve. LD tree behind rig. DECOMP PJSM. NU BOPE. AOGCC rep Jeff Jones waived witness at 20:15 hrs. DECOMP Test BOPE components 250 psi low / 3500 psi high. Test 3 1/2" x 6" VBR with 3 1/2" and 4 1/2" test joints. Test annular with 3 1/2" test joint. Test witnessed by WSL Vincent Volpe and Toolpusher Paul Yearout. DECOMP Finish ROPE test joint tests, iBOP, TIW valve, Kelly test to 250 psi low / 3500 psi high and accumulator draw down test. IA went on vac during test. IA took 9 bbls to fill following BOP test. DECOMP Conduct weekly safety meeting with crews. DECOMP PJSM. PU DSM_lubricator. Tested lubricator to 500 osi. DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. MU landing joint with XO to 4-1/2" NSCT pin. Held weekly safety meeting with day rig crew. Discussed recent ADW incidents, winter driving, and annular pressure bleed procedures. DECOMP Screwed into tubing hanger and BOLDS. Pulled hanoer freg with 127k Ib PU. PU increased to 185k Ib as tubing hanger cleared floor. Pumped down tubing at 3 bpm and 100 psi; tubing came free. LD landing joint and tubing hanger. DECOMP Circulated bottoms up through tubing cut at 5 bpm and 320 psi. Took 22 bbls to fill well. Had no gas on bottoms up. DECOMP POH and LD 4-1/2" tubin ,spooling control line. Recovered 52 jts tubing, 7 ss bands, 23 clamps. RD control line spooling unit. DECOMP Resumed POH and LD 4-1/2" tubing. 125 of 215 jts LD at 17:00 hrs. DECOMP Held crew change and performed pre-tour checks of PVT equipment and inspected derrick. DECOMP Continue to POH and LD 4-1/2" tubing. Total 213 jts recovered, 1 cut piece (20.35'), 2 X/N nipples, 1 SSSV, and 7 GLMS. The last five stands had sand on them. Printed: 10/20/2008 12:30:26 PM • BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: B-35 Common Well Name: B-35 Spud Date: 11/24/1993 Event Name: WORKOVER Start: 9/11/2008 End: 9/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code I NPT ~ Phase Description of Operations 10/7/2008 120:30 - 22:00 1.50 PULL P 22:00 - 22:30 0.50 PULL P 22:30 - 23:30 1.00 FISH P 23:30 - 00:00 0.50 FISH P 10/8/2008 00:00 - 00:30 0.50 FISH P 00:30 - 04:30 4.00 FISH P 04:30 - 05:00 0.50 FISH P 05:00 - 06:00 ( 1.001 FISH I P 06:00 - 08:00 2.00 FISH P 08:00 - 11:30 3.50 FISH P 11:30 - 18:00 I 6.501 FISH I P 18:00 - 19:00 1.00 FISH P 19:00 - 20:00 1.00 FISH P 20:00 - 20:30 0.50 FISH P 20:30 - 22:00 1.50 FISH P 22:00 - 22:30 0.501 FISH P 22:30 - 00:00 1.501 FISH P 10/9/2008 100:00 - 02:00 I 2.001 FISH I P 02:00 - 03:00 I 1.001 FISH I P 03:00 - 03:30 0.50 FISH P 03:30 - 04:00 0.50 FISH P 04:00 - 06:00 2.00 FISH P 06:00 - 07:30 1.50 FISH P 07:30 - 13:30 I 6.001 FISH I P DECOMP Crew held a PJSM and RD the 4-1/2" tubing handling equipment and RU the 3-1/2" handling equipment. DECOMP Clean and Clear rig floor. DECOMP Crew held a PJSM and installed the wear bushing (ID 8-11!16"). DECOMP Crew held a PJSM for picking up BHA. DECOMP Picked up the RTTS Packer, Circ valve, XO, and 4-3/4 DC (x9). DECOMP RIH with 129 single jts of DP from pipe shed. DECOMP PU 10' pu ands ace out to 4300' (129 jts + BHA + RTTS + 2'). Set RTTS packer; PU 75K, SO 67K, turn to the right and set w/ 20K. DECOMP RU test equipment and test casing from above (backside) to 3500 si for 30 charted minutes. Unset RTTS. DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. Slipped and cut drill line. DECOMP Held PJSM. POH, standing back 3-1/2" DP. LD RTTS. Cleared and cleaned rig floor. DECOMP PU fishin BHA #1: CL guide, HMC, OS bowl, ext, bumper sub, oil jar, 9 x DC. RIH on 43 stands of 3-1/2" DP. Began PU joints of 3-1/2" at 14:30 hrs. DECOMP Crew change. Service rig. Check PVT alarms. Inspect derrick. DECOMP Con't to P/U DP &RIH. Tagged up on tubing stub on it# 270..(. 8697' . DECOMP P/U 10' pup for space out. P/U kelly & break circulation, 3 BPM ~ 500 psi. Slowly go down over tubing stub @ 8697' & swallow 9' to 8706'. P/U &overpull 30K to 175K. Fish engaged, pump pressure increased to 860 psi. Slack off to 10 k overpull & put 15 rounds in DP. Anchor popped free. P/U & had 15k overpull for -5'. Con't to P/U 25' & have 2-3k over pull. P/U Wt = 175K, S/O Wt = 118K. Rot Wt = 133K. DECOMP Circulate well & pump 20 bbl Hi-Vis sweep. Pumped 5 BPM ~ 1130 psi. Pumped total of 433 bbls. Had small amount of gas at surface when bottoms up. Sweep recovered sand, smoo 8~ scale. Lost total of 15 bbls Burin circulation. DECOMP Hold PJSM for POOH & set back kelly. Discuss L/D 10' pup on skate. DECOMP Set back & blow down kelly. L/D 10' pup & 2 jts of DP. POOH & stand back 3 1/2" DP. DECOMP Continue to POH and stand back 3-1/2" DP in derrick, 90 stands total. DECOMP Stand back 3 stands (9 jts) of 4-3/4" Drill collars in derrick and LD BHA and fish. Recovered cut tubino it. 6' pup, and anchor DECOMP ~ Clean and clear rig floor. DECOMP I PU / MU BHA #2,packer milling asst'; Packer mill, boot basket x3, bit sub, bumber sub, oil jar, drill collars x9. TL = 314.5' DECOMP RIH with BHA #2 on DP from derrick to -8730'. DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. Continued RIH with packer mill BHA #2. Tagged soft fill at 8708', washed to packer at 8723'. DECOMP Established parameters: PU/SO/Rot 157k/118k/133k; 70 rpm, 200a, 4500 Ib-ft; 5 bpm, 1200 psi; 2k - 7k WOB. Milled packer with torque varying to 240a, 6800 Ib-ft. Varied rpm to 100, flow Printed: 10/20/2008 12:30:26 PM • BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: B-35 Common Well Name: B-35 Spud Date: 11/24/1993 Event Name: WORKOVER Start: 9/11/2008 End: 9/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: bate I From - To Hours Task ~ Code NPT I~ Phase Description of Operations I I --- 10/9/2008 07:30 - 13:30 6.00 FISH P DECOMP rate to 6 bpm at 1770 psi, WOB to 15k Ib. Milled to 872_ 6~had significant gas in returns; packer released. Circulated until gas subsided; began losing returns. Pushed packer and tailpipe to mill de th of 8731'. 13:30 - 16:30 3.00 FISH P DECOMP PU 10' and circulated once around. Pumped 5 bpm at 1300 psi. After initial fluid loss of 20 bbls, regained full returns. 16:30 - 18:00 1.50 FISH P DECOMP POH with BHA #2, standing back 3-1/2" DP. 18:00 - 19:00 1.00 FISH P DECOMP Crew change. Service rig. Check PVT alarms. Inspect derrick. 19:00 - 20:30 1.50 FISH P DECOMP Continue to POH with BHA #2, standing back 3-1/2" DP in derrick. 20:30 - 22:00 1.50 FISH P DECOMP Hold PJSM and POH and LD BHA #2, packer milling assy. 22:00 - 22:30 0.50 FISH P DECOMP Clean and clear rig. 22:30 - 23:30 1.00 FISH P DECOMP Hold PJSM and PU BHA #3 Packer fishin ass ;Spear, Bumper sub, Oil jar, Drill collars x9, Pump out sub. TL = 302.62. 23:30 - 00:00 0.50 FISH P DECOMP RIH w/ BHA #3 with DP from derrick. 10110/2008 00:00 - 02:30 2.50 FISH P DECOMP Continue to RIH w/ BHA #3 with DP from derrick to _8732'. 02:30 - 03:30 1.00 FISH P DECOMP Establish fishing parameters: PU 168K, SO 117K, 3 BPM ~ 660 psi. Jar on fish 8x. 3 C~3 200K, 4 C~ 225K, and 1 ~235K. Well went on an immediate vac. PU 20' and pumped 100 BBLs at 5 BPM and 1500 psi - no returns. 03:30 - 06:00 2.50 FISH P DECOMP Held PJSM and began POH w/ BHA #3 and fish standing back DP in derrick. Use continuous hole fill while POOH. 06:00 - 08:30 2.50 FISH P DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Continued POH with BHA #3, standing back 3-1/2" DP. OA pressure increased to 860 psi; bled OA to 220 si. Stood back 3 stands DC. 08:30 - 10:30 2.00 FISH P DECOMP LD BHA #3 and packer/tailpipe fish. Punched six holes in tubing to relieve pressure. Tailpipe packed with sand.. 10:30 - 12:30 2.00 FISH P DECOMP Cleared tailpipe of sand. Cleared and cleaned rig floor. 12:30 - 17:00 4.50 FISH P DECOMP PU polish mill BHA #4: polish mill, double pin, 2 boot baskets, 7-5/8" scraper, bit sub, bumper sub, oil jar, 9 x DC. RIH on 3-1/2" DP, adding 15 bbls 9.8 ppg brine each 15 minutes. At 30 stands in hole, pumped 30 bbls 9.8 ppg brine down drill pipe, at 6 bpm and 180 psi. Subsequently added 15 bbls brine down annulus each 15 minutes. Continued to RIH 90 stands total adding 60 bph. 17:00 - 17:30 0.50 FISH P DECOMP Dress the 5-1/2" liner top ~ 8788' (BHA+DP+10' pup+23' on elly ,with 3 BPM and 100 psi. 17:30 - 18:00 0.50 FISH P DECOMP POH standing back DP in derrick. 18:00 - 18:30 0.50 FISH P DECOMP Crew change. Check PVT alarms. Service Rig. 18:30 - 21:00 2.50 FISH P DECOMP Continue to POH standing back DP in derrick. Work the scraper from 3935' to 4028', 4 times. Pumped 60 BPH + pipe dis lacement while POH. 21:00 - 23:00 2.00 FISH P DECOMP LD BHA #4. 23:00 - 00:00 1.00 FISH P DECOMP PU HES FasDrill lu Setting tool, XO, Drill collars x3, XO, Pump sub, Drill collars x9. 10/11/2008 00:00 - 01:00 1.00 FISH P DECOMP Continue to PU FasDrill plug and collars. 01:00 - 05:00 4.00 FISH P DECOMP RIH w/FasDrill plug and 90 stds of 3-1/2" DP from derrick. 05:00 - 05:30 0.50 FISH P DECOMP P/U 2 singles & entered thru top of 5 1/2" liner. P/U 3rd single & space out 14'. Top of FasDrill BP ~ 8850'. Put 20 rt. rounds in string & P/U to 197K & sheared out of plug. P!U & insure free. S/O w/ 15K down wt on plug & verify set. P/U Wt = 157K, Printed: 10/20/2008 12:30:26 PM • BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: B-35 Common W ell Name: B-35 Spud Date: 11/24/1993 Event Nam e: WORKO VER Start : 9/11/2008 End: 9/16/2008 Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: Rig Name: NABOB S 4ES Rig Number: I ' I ~ I Date From - To Hours Task I Code ~ NPT Phase I Description of Operations 10/11/2008 05:00 - 05:30 0.50 FISH P DECOMP S/O Wt = 114K. 05:30 - 06:00 0.50 FISH P DECOMP POOH & L/D 3 singles. R/U circulating head & fill hole. 06:00 - 08:30 2.50 FISH P DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. Filled well with 98 bbls 9.8 ppg brine. Circulated 490 bbls at 5 bpm and 1130 psi. Shut down, filled well. Lost 17 bbls in 10 minutes. Discussed with WO Engr; decided to run 2nd FasDrill lu . 08:30 - 09:30 1.00 FISH P DECOMP Slipped and cut 84' drill line. 09:30 - 12:30 3.00 FISH P DECOMP POH, standing back 3-1/2" DP. LD 3 x 2-718" PAC DC. Continued adding 60 bph 9.8 ppg brine to well. 12:30 - 14:00 1.50 FISH P DECOMP Held PJSM. Redressed FasDrill setting tool and pump out sub. 14:00 - 18:00 4.00 FISH P DECOMP PU 3 jts PAC DC. RIH with 5-1/2" FasDrill #2 on 3 jts PAC DC and 3-1/2" DP. Maintained 60 bph 9.8 pp4 brine additions until 10 stands in, at which point fluid loss decreased to about 20 b h. Continued in hole to 5-1/2" liner top at 8781'. Worked FasDrill plug into liner, tagged fill 7' inside with -3K. Indication of about 50' of fill in 5-112" lin r above FasDrill #1 set at 8850'. PU above liner and discussed with WO Engr. 18:00 - 18:30 0.50 FISH P DECOMP Crew change. Rig service. Check PVT alarms. Inspect derrick. 18:30 - 21:00 2.50 FISH P DECOMP POH standing back 90 stands of 3-1/2" DP and LD 1 single jt. 21:00 - 22:30 1.50 FISH P DECOMP Stand back 1 stand PAC drill collars. LD 5-1/2" FasDrill plug and running tool. 22:30 - 23:30 1.00 FISH P DECOMP PU 7-5/8" RTTS packer and 9 drill collars. 23:30 - 00:00 0.50 FISH P DECOMP TIH with RTTS packer on 3-1/2" DP. 10/12(2008 00:00 - 02:00 2.00 FISH P DECOMP Continue to RIH w/ 5i stands of DP to ~ 5038'. 02:00 - 02:30 0.50 FISH P DECOMP Set RTTS packer ~ 5038' and attempt to test from below to 1000 psi - No test. 02:30 - 03:00 0.50 FISH P DECOMP Unset RTTS packer and RIH 11 more stands (62 stands total) to 6066'. 03:00 - 04:00 1.00 FISH P DECOMP Set RTTS acker @ 6066' and test from below to 1000 si for 10 charted min - ood test. Performed injectivi test down the annulus - C~3 1 BPM 0 - 120 psi at 5 BBLs; ~ 2 BPM 120 - 390 psi at 10 BBLs; ~ 3 BPM 390 - 630 psi at 15 BBLs. 04:00 - 05:00 1.00 FISH P DECOMP Weekly safety meeting with evening tour. 05:00 - 06:00 1.00 FISH P DECOMP Unset RTTS packer and POH standing back DP in derrick. 06:00 - 09:00 3.00 FISH P DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Continued POH, standing back 3-1/2" DP. LD RTTS. 09:00 - 10:30 1.50 FISH P DECOMP Cleared floor. PU clean out BHA #5: shoe, 3 x PAC DC, XO, bumper sub, oil jar, 9 x D ,POS. 10:30 - 13:30 3.00 FISH P DECOMP RIH with clean out BHA #5 on 90 stands 3-1/2" DP. PU single, entered 5-1/2" liner at 8788'. Continued in liner, tagged fill at 8818' 30' in liner . PU/SO 155k/115k. 13:30 - 14:00 0.50 FISH P DECOMP Spotted high-vis sweep around annulus at 3 bpm and 700 psi. Washed fill to 8850', tagged FasDrill with 5k Ib. 14:00 - 15:30 1.50 FISH P DECOMP PU 2', closed annular and RU to reverse circulate. Reversed total of 220 bbls at 3 bpm and 320 psi, until clean returns. RarnvPrad sand. metal cuttings. and sweep. 15:30 - 18:00 2.50 FISH P DECOMP POH with clean out BHA #5, standing back 3-1/2" DP. Initial fluid loss steady at 20 bph. 18:00 - 18:30 0.50 FISH P DECOMP Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 19:00 0.50 FISH P DECOMP Finsh POOH & stand back 90 stands of 3 1/2" DP. 19:00 - 20:30 1.50 FISH P DECOMP Break out & L/D BHA. L/D 3 jts 2 7/8" PAC DP, 9 4 3/4" DCs, Printed: 10/20/2008 12:30:26 PM BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: B-35 Common Well Name: B-35 Spud Date: 11/24/1993 Event Name: WORKOVER Start: 9/11/2008 End: 9/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/12/2008 19:00 - 20:30 1.50 FISH P DECOMP jars, bumper sub, Pump out sub & X-O. 20:30 - 23:00 2.50 CASE P TIEB1 Clear & clean rig floor. R/U liner tools & Torque Turn equip. 23:00 - 23:30 0.50 CASE P TIEB1 Hold PJSM w/ all hands. Review liner running order & assign tasks to specific personnel. 23:30 - 00:00 0.50 CASE P TIE61 P/U & M/U liner assys as follows: Ran Tie-Back stem Assy, 1 Jt 4 1/2" 12.6#, 13Cr-80 tubing X-over, Float Collar Assy & Landing Collar Assy. Baker lok'd all connections. 10/13/2008 00:00 - 06:00 6.00 CASE P TIEB1 Con't to P/U 4 1/2" 12.6#, 13Cr-80 liner &RIH. Fill liner every 5 jts. Torque Turn NSCT connections to 3975 ft-Ibs. Installed 1 free floating Centralizer on each jt. Used Jet Lube seal Guard thread compound on all connections. Keeping hole full while running liner. RIH w/ 70 jts at 0500. 06:00 - 09:30 3.50 CASE P TIEB1 Held crew change and performed pre-tour checks of PVT equipment and derrick. Continued RIH with 4-1/2" 12.6# 13Cr80 NSCT liner. MU NSCT to VAM Ace XO. recalibrated torque turn to 4440 Ib-ft. Resumed RIH with 4-1/2" VAM Ace liner. Continued filling liner each 5 jts with 9.8 ppg brine. Ran total of 79 'ts NSCT + 34 jts VAM Ace + 113 centralizers. MU Flex-Lock liner hanger and ZXP-C2 liner top packer. 09:30 - 10:00 0.50 CASE P TIEB1 Attached head pin, circulated 1 liner volume (75 bbls) at 3-1/2" bpm and 200 psi. 10:00 - 12:00 2.00 CASE P TIEB1 RIH with liner on 3-1/2" DP. Filled DP each 5 stands with 9.8 ppg brine. Tagged 5-1/2" liner top at 8781' and No-Go'd seal 12:00 - 13:30 1.50 CASE P TIE61 RU cementing head. Circulated 9.8 ppg brine to warm well at 3 bpm and 340 psi. 13:30 - 14:30 1.00 CEMT P TIEB1 Held PJSM prior to cementing with all personnel: BP, Nabors, SWS, CH2, Baker. Finished RU cement return line to open-top tank. 14:30 - 17:30 3.00 CEMT P TIEB1 Opened well to SWS cementing unit. Pumped 5 bbls 9.8 ppg brine, tested lines to 5000 psi. Mixed and pumped 147 bbls CI G cement + additives at 15.8 ppg. Dropped wiper dart and cementing unit displaced with 9.8 ppg brine. Displaced at 5 bpm and 250 psi initial pressure. Slowed rate to 3 bpm after 20 bbls displaced, saw dart engage wiper plug and release at 1300 psi. Resumed displacing at 5 bpm with pressure gradually increasing to 1870 psi at 85 bbls displaced. Slowed rate to 2 bpm and bumped plug with 2100 psi at 98 bbls displaced (97 bbls calculated). SO 3', then PU and~ncreased pressure to 3000 psi to set liher hanger. SO to set hanger slips, increased pressure to 4500 psi to set ZXP packer, at ~ 3996'. Bled pressure, returned 2.5 bbls, floats held. Rotated 15 RH turns to release from packer; increased pressure to 1000 psi, PU 7' and observed pressure bleed. Pumped 10 bbls 9.8 ppg brine the long way and PU about 32'. Closed annular and reverse circulated until clean returns, had about 20 bbls cement back. CIP at 16:35 hrs. 17:30 - 18:00 0.50 CEMT P TIE61 R/D Schlumberger cementers 18:00 - 19:00 1.00 CEMT P TIEB1 Crew change, Service Rig, Inspect Derrick, Check PVT Alarms, adjust Draworks oiler 19:00 - 20:00 1.00 CEMT P TIEB1 POOH with 3 1/2" DP L/D 30 jts to pipe shed 20:00 - 20:30 0.50 CEMT P TIEB1 RIH with 8 stands of 3 1/2" DP from derrick 20:30 - 23:00 2.50 CEMT P TIE61 POOH and L/D 120 jts of 3 1/2" DP to pipe shed - R/U bleed Printed: 10/20/2008 12:30:26 PM BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: B-35 Common Well Name: B-35 Spud Date: 11/24/1993 Event Name: WORKOVER Start: 9/11/2008 End: 9/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 4ES Rig Number: Date i From - To I Hours Task ~ Code ~ NPT i Phase ~ Description of Operations 10/13/2008 20:30 - 23:00 2.50 CEMT P TIE61 line from OA to bleed tank 23:00 - 23:30 0.50 CEMT P TIEB1 Make up running tool and pull wear bushing 23:30 - 00:00 0.50 WHSUR P TIEB1 PJSM M/U pack off running tool 10/14/2008 00:00 - 03:30 3.50 WHSUR P TIEB1 Change out Pack off, tested pack-offs to 5000 psi for 30 03:30 - 04:30 1.00 WHSUR P TIEB1 04:30 - 06:00 1.50 BOPSU P TIEB1 06:00 - 13:00 7.00 BOPSU P TIE61 13:00 - 13:30 0.50 CEMT P TIEB1 13:30 - 15:00 1.50 CEMT P TIE61 15:00 - 15:30 0.50 CEMT N WAIT TIEB1 15:30 - 18:00 2.50 CEMT P TIEB1 18:00 - 18:30 I 0.50 I CEMT I P 18:30 - 23:00 I 4.501 CEMT I P 23:00 - 00:00 1.00 CEMT P 10/15/2008 00:00 - 01:30 1.50 CEMT P 01:30 - 02:30 1.00 CEMT P 02:30 - 12:30 I 10.001 DRILL I P 12:30 - 14:00 1.50 DRILL P 14:00 - 16:00 2.00 DRILL P 16:00 - 18:00 I 2.001 DRILL I P 18:00 - 18:30 I 0.501 DRILL I P 18:30 - 20:00 I 1.501 DRILL I P 20:00 - 21:00 1.00 DRILL P 21:00 - 00:00 3.00 DRILL P 10/16/2008 100:00 - 02:00 I 2.001 DRILL I P 02:00 - 02:30 I 0.501 DRILL I P TIE61 TIEB1 TIEB1 TIEB1 TIE61 TIEB1 TIEB1 TIEB1 minutes. Install test plug Change rams to 2 718"x5" VBR RU BOPE test equipment. Held crew change and performed pre-tour checks of PVT equipment and derrick. Tested BOPE,to 250 psi low / 3500 psi high per BP policy and AOGCC regulations. Tested VBR with 2-7/8" and 4-1/2" test joints. Tested annular with 2-7/8" test joint. Test witnessed by S. Bounds. BOPE test witness waived by L. Grimaldi, AOGCC, at 17:30 hrs 10/13/2008. Rig down BOPE test egpt. PJSM - PUMU cleanout BHA. MU cleanout BHA #6 as follows: 3-3/4" PDC bit (used), 2' 3-1/2" boot basket, bit sub, 3-1/8" oil jar, XO, 6' 3-1/8" drill collars, XO. Total length = 193.00'. Wait on 2-7/8" YT elevators to arrive for picking up 2-7/8" HT PAG DP. RIH w/BHA #6 picking up 2-7/8" HT PAC DP 1 x 1 from pipe shed. Crew change, service rig, derrick inspection, check PVT alarms, perform pretour checks Cont. RIH w/ 2 7/8" HT PAC DP 1X1 from pipe shed -Ran 165 jts. No restrictions going into liner R!D 2 7/8" equip, and R/U 3 1/2" DP elevators and slips RIH w/ 3.5" DP from derrick, tagged cement ~ 8684' R/U and test 4.5" scab liner to 3500 psi for 30 min. on chart recorder - 2.5 bbls pumped Pumped 35 bbl Hi-vis pill with 1 drum EP Mud tube spotted ~ bit. Drill cement and float equip. from 8684' 00400 8692') Up wt.=120K Dn wt.=95K Rot wt.=104, RPM=60, Tq.=3k ft. Ibs, 38PM ~ 1780 psi. Drilling on landing collar ~ 06:00-hrs. Drilled out through float collar at 12:30-hrs. Pumped 40-Bbl. Hi-Vis sweep followed by seawater to swap hole over. Washed down to top of FasDril plug ~ 8853'. Circulate and swap hole to seawater at 3.3-bpm ~ -1800-psi. 9214'. TIEB1 Set back and blow down kelly. POH LDDP 1 x 1 through pipe shed. Laid down 30-jts. and stopped and performed flow check. Cont. UD 3 1/2" DP TIEB1 Crew change, service rig, derrick inspection, check PVT alarms, perform pretour checks TIEB1 Cont. POH UD 3 1/2" DP 1x1 to pipe shed. Fill hole ~ 60 BPH + pipe dispalcement. TIEB1 R/D 3 1/2" Handling equip. R/U 2 7/8" Handling equip. TIEB1 UD 2 7/8" HT Pac DP. Monitor well ~ liner top 3996'. Cont. UD 2 7/8" DP. Fill hole ~ 60 BPH + pipe displacement. TIEB1 Cont. UD 2 7/8" Ht Pac DP 1x1 to pipe shed. Fill hole with 60 BPH + pipe displacement. TIEB1 UD BHA #6. Junk basket had 1/2 gallon cement, metal, and Printed: 10/20/2008 12:30:26 PM BP EXPLORATION Operations Summary Report Legal Well Name: B-35 Common Well Name: B-35 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To I Hours Task I; Code I NPT I; 10/16/2008 02:00 - 02:30 0.50 DRILL 02;30 - 03:30 1.00 DRILL P 03:30 - 05:30 2.00 BUNCO 05:30 - 14:00 I 8.50 14:00 - 15:00 I 1.001 RUN 15:00 - 16:00 I 1.00 16:00 - 18:00 I 2.00 Start: 9/11 /2008 Rig Release: Rig Number: Page 7 of 7 Spud Date: 11 /24/1993 End: 9/16/2008 Phase Description of Operations TIEB1 pieces of the composite plug. TIEB1 Clear and clean rig floor. RD 2-7/8" pipe handling egpt. RUNCMP RU to run 4-1/2" VAM To com letion. Maintained 60-bph hole fill while RIH w/completion string. RUNCMP Make up completion BHA: Muleshoe, XN nipple, 1 jt., X nipple, Baker 4-1/2" x 7-5/8" S-3 packer and X nipple. Baker-Lok'd and torque turned all connections below packer. RIH wlcompletion tubing compensating and torque turning all connections to optimum torque of 4,440 ft-Ibs. used Jet Lube Seal Guard thread compound. Tagged liner tie-back receptacle with No-Go at 16' in on joint #91. Spaced out to land completion with No-Go 3' off top of liner tie-back receptacle. Layed down jts. #91, 90 & 89. Picked up and torque turrned 4-1/2" 12.6#, 13Cr80 pups - 9.80', 9.75', 7.82', 3.79' and jt. # 89. RUNCMP Made up 12-1/2" FMC tubing hanger to 3-1/2" DP landing jt. w/closed TIW valve and XO to top of jt. #89. Landed tubing. hanger. RILDS. Broke out and layed down landing joint. Closed blind rams. RUNCMP Reverse circulated 185-bbls. 120E seawater treated with .25 gallons of EC1124A corrosion inhibitor per barrel ~ 3.0-bpm ~ 5-psi with no returns. Opened blind rams. RUNCMP Made up landing joint to top of tubing hanger and dropped ball & rod. Allowed ball & rod to fall on seat. Filled tubing and allowed air to percolate to surface. Closed blind rams. Pressured uo tubing to 3500 psi to set packer and test tubing I for 30-charted minutes. Bleed tubing to 1500 psi & press. up 18:00 - 19:00 1.00 BUNCO RUNCMP Circulate down tubing ~ 3 BPM with 1520 psi. Circulate down annulus C~ 3 BPM with 1580 psi. 19:00 - 20:00 1.00 BUNCO RUNCMP FMC set TWC and tested to 1000 si below & 3500 si fro above for 10 charted minutes each. Blow down lines. 20:00 - 21:30 1.50 RUN 21:30 - 23:00 1.50 RUN 23:00 - 00:00 1.00 RUN 10!17/2008 100:00 - 03:00 3.00 I WHSUR P RUNCMP Change pipe rams to 3 1/2" x 6" VBR"s RUNCMP Nipple down BOPE and set back on stand. RUNCMP Nipple up 13 5/8" x 4 1/2" FMC adapter flange and test to 5000 psi for 15 min. RUNCMP Nipple up Tree and test to 5000 psi for 15 min. Rig up DSM 03:00 - 04:00 1.00 WHSUR P 04:00 - 06:00 2.00 WHSUR P 06:00 - 07:00 1.00 WHSUR P 07:00 - 08:00 1.00 RIGD P RUNCMP Rig up freeze protect lines and valves in cellar. RUNCMP PJSM with all hands. Test lines to 3500 psi. Pump 90 bbls of 90 degree diesel C~? 2 BPM U-tube diesel for 1 hr R/D lines RUNCMP Install BPV and test to 1000 si for 10 min. RUNCMP Secure tree and cellar and prepare to RDMO. Printed: 10/20/2008 12:30:26 PM f WELLHEA.D= 5M FMC ACT~JATOR= BAKER KB'. ELEV = 68.2' BF. ELEV = _ 37.T KOP = 2072' Max Angle = 22 @ 5733' ~ Datum MD = 9216' Datum TV D= 8800' SS 10-3/4" CSG, 45.5#, NT80, ID = 9.953" 3195' 4-1/2" TBG, 12.6#, 13CR80 VAM TOP, I 4003' .0152 bpf, ID = 3.958" Minimum ID = 3.725" @ 3975 4-1 /2" HES XN NIPPLE 4-1/2" SCAB LNR, 12.6#, 13CR, 8781' VAM TOP, ID = 3.958" TOP OF 5-1/2" LNR $7$$' 7-5/8" CSG, 29.7#, NT95HS, ID = 6.875" I-i 8936' PERFORATION SUMMARY REF LOG: AWS BHCS 12/06/93 ANGLEATTOPPERF: 4 @ 9172 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8 6 9172-9194 O 12/27/93 F3-3/8 6 9202-9222 O 12/24/93 PBTD -1 9502, i-1/2" LNR, 17#, 13Cr80, .0232 bpf, ID = 4.892" 9585' SA NOTES: 4-1l2" CHROME TBG&LNR B-35 2111' 4-1/2" OTIS X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 3015 3700 19 KBG-2 DOME BK 16 10/20/08 1 3798 2964 21 KBG-2 SO BK 20 10/20/08 388$' S • 3 P~ ck~ 7-5/8" x ' -1/2" BKR 3975' - 3912' ~4-1/2" HES XN NIP, ID = 3.725" 4-1/2" HES X NIP, ID = 3.813" 3996' 1 7-5/8" x 5-1 /2" BKR ZXP LNR TOP PKR DATE REV BY COMMENTS DATE REV BY COMMENTS 12/25/93 ORIGINAL COM PLEZION 02/05/06 DTR/PJC SET PXN PLUG @ 8777' 02/10!06 COM/PAG WAIV ER SFTY NOTE DELETED 10/17/08 N4ES RWO 10/24/08 DAV/TLH GLV C/O & CORRECTIONS PRUDHOE BAY UNIT WELL: B-35 PERMfT No: 1931460 API No: 50-029-22406-00 Sec. 31, T11 N, R14E BP Exploration (Alaska) • • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 7~~ ~1 ®1~~AdRsA®e` ~® Ly~Y1` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PO Box 196612 / Anchorage, AK 99519-6612 Q~ _ ~ ~ ~p 4-1 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B-35 Sundry Number: 308-281 Dear Reem: ~~~a~~~~ ~~ ~ ~ ~.~ 20~~ David Reem Engineering Team Leader BP Exploration Alaska Inc. Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~; '.~ -_ II /,~ ~,,~ Daniel T. Seamount, Jr. ~// q Chair DATED this ~ day of August, 2008 Encl. STATE OF ALASKA 8 ~ %" ' ,', '' ~ ~ ALA OIL AND GAS CONSERVATION COM~ION ^~ APPLICATION FOR SUNDRY APPROVAL ~~' ~-~~~~m 20 AAC 25280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ®Alter Casing ~ ®Repair Well- ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing , ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 193-146 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22406-00-00` 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU B-35~ Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028310 ~ 67' _ Prudhoe Bay Field / Prudhoe Bay Pool 12, PRESENT WELL CONDITION SUM MARY_ Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9585' ~ 9236' ~ 9502' ~ 9153' ~ 877T - None Casin Len th Size MD TVD Burst Colla se Structural Conductor 80' 2 110' 110' 1490 470 Surface 3165' 10-3/4" 3195' 3132' 5210 2480 Intermediate 8908' 7-5/8" 8936' 8588' 8180 5120 Production Liner 79T 5-1/2" 8788' - 9585' 8441' - 9236' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grad _ ~ Tubing MD (ft): Below Pluq: 9172' - 9222' 8824' - 8873' 4-1/2", 12.6# L~ 8789' Packers and SSSV Type: 7-5/8" Baker'SABL-3' packer Packers and SSSV MD (ft): 8730' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: September 1, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name avid Reem Title Engineering Team Leader _ Prepared By Name/Number: Signature Phone 564-5743 Date T~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ~pZ Conditions of approval: Notify Commission so that a representative may witness ~, ~~5-C?( V ~ ~~~ , } c ^ Plug Integrity ~ ,BOP Test ^ Mechanical Integrity Test ^ Location Clearance " ( ~~ ~~- Other: ~~~ ~~ ~ t ~~ ~ ~~~ Subsequent For quired: ~~~ APPROVED BY ~ ~~ A roved !3 COMMISSIONER THE COMMISSION Date Form 10-403 I~ved~"6/2006 Submit In Duplicate .' - ~ ~~- RUC ~ ~ 2008 V~~~<JI~IY~~ • • by cr,,~,~ B-35 Rig Workover (Restore OA/IA integrity) Scope of Work: Pull 4.5" L-80 completion, run USIT to evaluate 7-5/8" production casing damage, run and cement 4.5" scab liner, replace primary pack-off, and run 4.5" 13 Cr-80 completion. Engineer: Hank Baca MASP: 3241 psi Well Type: Producer Estimated Start Date: September 1St, 2008 F 1 MIT-T to 1000 psi for 10 minutes to verify PXN plug is holding. Attempt to set another PXN lu if test fails, S 2 Drift for 4.5" jet cutter & cut tubing at 8704'. Reference tubing tally from 1/1/04, note this is misdated and should be 12/25/93 F 3 Circulate well with seawater and diesel thru the cut. CMIT TxIA to 3500 psi. Test ex ected to fail, obtain LLR to u date data from 12/2/01 W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. DONE 07/25/08 W 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test ROPE to 250 psi low/ 3500 psi high. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4.5" tubing string to the cut. 3. Mill/fish 7-5/8" x 4.5" packer and 4.5" tail pipe 4. Set 5.5" composite bridge plug C~? 8830' 5. RU wireline and run USIT from plug to surface to determine 7-5/8" production casing condition. 6. Run & cement 4.5" 12.6# 13Cr-80 scab liner from top of 5.5" liner to above bad casing ~ 4700'. 7. Drill out 4.5" shoe track and pressure test casing to 3500 psi for 30 charted minutes. 8. Drill up composite bridge plug, chase to PBTD @ 9502' 9. Run 4-t/z" 13Cr-80 completion with Baker S-3 packer tied into scab liner. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 12. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. E= 4-1/16"CNV WELLHEAD= 5M FMC AC~TLIATOR='- BAKER KB. ~ 68.2' BF. ELEV = 37.7' KOP = 2072' Max Angle = 22 @ 5733' Datum MD = 9216' Datum TV ~ 8800' SS -~ ~ SAF TES: "*" CHROM E LNR *"" 2~ 04' ~ 4-1 /2" OTIS SSSV LAND Nom, ID = 3.813" GAS LIFT MANDRELS 10-3/4" CSG, 45.5#, NT80, ID = 9.953" ~ 3195' Minimum ID = 3.725" @ 8777' 4-1 /2" OTIS XN NIPPLE 4-1/2" TBG, 12.6#, L80, .0152 bpf, ID = 3.958" 8788' TOPOF 5-1/2" LNR $788' 7-5/8" CSG, 29.7#, NT95HS, ID = 6.875" PERFORATION SUMMARY REF LOG: AWS BRCS 12/06/93 ANGLE AT TOP PERF: 4 @ 9172 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8 6 9172-9194 C 12/27/93 ~3-3/8 6 9202-9222 C 12/24/93 PBTD 9502' 5-1/2" LNR 17#, 13Cr80, .0232 bpf, ID = 4.892" 9585' ST MD TVD DEV .TYPE VLV LATCH PORT DATE 7 3079 2886 23 MERLA BK 6 4904 4687 19 MERLA BK 5 6176 5881 21 MERLA BK 4 7148 6789 20 MERLA BK 3 7767 7374 19 MERLA BK 2 8265 7856 12 MERLA BK 1 8646 8232 0 MERLA BK 8672' -14-1/2" OTIS X NIP, ID = 3.813" 8730' 7-5/8" PERM PKR $759' 4-1/2" OTIS X NIP, ID = 3.813" I $777' 4-1/2" OTIS XN NIP, ID = 3.725" $777' 4-1/2" PXN PLUG (02/05/06)1 $7$$' 4-1/2" WLEG, ID = 3.958" $785' ELMD TT LOGGED 12/20/93 DATE REV BY COMMENTS DATE REV BY COMMENTS 12125/93 ORIGINAL COMPLETION 06/06/03 JCP/TLH WANERSAFETY NOTE 02/05/06 DTR/PJC SET PXN PLUG @ 8777' 02/10/06 COM/PAG WANER SFTY NOTE DH.ETED PRUDHOE BAY UNR WELL: B-35 PERMff No: 1931460 API No`. 50-029-22406-00 Sec. 31, T11N, R14E BP Exploration (Alaska) TREE = 4-1 /16" CNV WEILHEAD= 5M FMC ACTUATOR= BAKER KB. F~L.EV ~ 68.2' BF. ELEV = 37.7' KOP = 2072' Max Angle = 22 @ 5733' Datum MD = 9216` Datum TV D= 8800'SS 10-3/4" CSG, 45.5#, NT80, ID = 9.953" ~-~ 3195' 4.5" 12.6# 13 Cr-80 Vam Top tubing & PBR TOP OF 5-1/2" LNR 7-5/8" CSG, 29.7#, NT95HS, ID = 6.875" PERFORATION SUMMARY REF LOG: AWS BHCS 12/06/93 ANGLE AT TOP PERF: 4 @ 9172 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8 6 9172-9194 C 12/27/93 ~3-3/8 6 9202-9222 C 12/24/93 PBTD 9502' 5-1/2" LNR, 17#, 13Cr80, .0232 bpf, ID = 4.892" 9585' B-35 PROPOSED _4-1/2" OTIS X NIP, ID = 3.813" GAS LIFT MANDRELS 2 -4690 1 -3000 ' 4-1/2" OTIS X NIP, ID = 3.813" 4-1/2" OTIS XN NIP, ID = 3.725" ,TOC 4700` 4.5" 12.6# 13 Cr-80 Vam Top ~ 8780` DATE REV BY COMMENTS DATE REV BY COMMENTS 12125/93 ORIGINAL COMPLETION 06/06/03 JCP/TLH WANERSAFETY NOTE 02/05/06 DTR/PJC SET PXN PLUG @ 8777' 02/10/06 COIWPAG WA V ER SFTY NOTE DELETED PRUDHOE BAY UNIT WELL: B-35 PERMff No: 1931460 API No: 50-029-22406-00 Sec. 31, T11N, R14E BP Exploration (Alaska) RE: B-35 Change to Trouble Well (~~ e Pr» #: lq 3- t4~ Suh.iect: RE: B-35 Change to Trouble Well From: "NSlJ, ADW Wclllntcgrity Engincer" <]\;,SlJADWWc1l1ntegrityEngineer@BP.com> Date: Fri, 10 Fcb 2006 05:48:09 -0900 K.?1'1 ¿(\ù\D~ To: "NSLJ, ADW Well Operations Supervisor" <NSLJADWWeIlOpcrationsSupervisor@BP.com>, "Rossbcrg, R Steven" <Steven.Rossberg@BP.com>, "Kurz, John" <john.kllrz@BP.com>, jimJcgg@admin.state.ak.us, winton_..aubert@admin.state.ak.us, "GPB, Wel1s Opt Eng" <GPBWcllsOptEng@BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr@BP.com>, "GPB, Wel1 Pads BAX" <GPBWcI1PadsBAX@ßP.com>, "GPB, GC3 Arca Mgr" <GPBGC3TL@BP.com>. "GPB, GC3 Wellpad Lead" <GPBGC3Wel1padLead@BP.com>, "Subekti, Herry" <Hcrry.SlIbekti@BP.com> CC: "Austin, Paul A" <Palll.A.AlIstin(qJBP.com>, "NSU, ADW Well Jntegrity Engineer" <J\SUADWWcllIntegrityEngincer(q)BP.com>, "MCCOLLUM', CODY 0 (VECO)" <Cody.McCollum(ã.}BP.com>. "Hughes, Andrea (VECO)" <hllgha4@)BP.eom> Hello all. Well 8-35 has been reclassified as a Trouble well. An MITOA failed, so the well is no longer a candidate for a production casing leak waiver. Lead Operator: would you please ensure any waiver related signage is removed from the wellhouse. Please call with any questions Joe 659-5102 /' < r ~o, From: Austin, Paul A Sent: Thursday, February 09, 2006 6:40 PM To: NSU, ADW Well Integrity Engineer Subject: B-35 Change to Trouble Well Joe, 8-35 is currently waivered for a Production Casing leak. On 1/13/06 it failed a MITOA to 3000 psi and no longer meets the requirements for a PC leak waiver. The well has been secured with a TIP. recommend we cancel the waiver on this well and change it to Trouble status. Thanks, Paul Austin Well Integrity Engineer x5766 1 of 1 2/10/20069:41 AM ..... , STATE OF ALASKA .... ALAStO, JIL AND GAS CONSERVATION Ct...,~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Ann - Comm 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1924' SNL, 1607' WEL, Sec 31, T11N, R14E At top of productive interval 2409' SNL, 3733' WEL, Sec 31, T11N, R14E At effective depth (not available) At total depth 2402' SNL, 3768' WEL, Sec 31, T11 N, R14E 5. Type ~f well: Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 66.9 feet 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number B-35 9. Permit Number / Approval No. 93-146 10. APl Number 50- 029-22406 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9585 feet true vertical BKB 9236 feet Effective depth: measured 9500 feet true vertical BKB 9151 feet Casing Plugs (measured) Junk (measured) Length Size Cemented Structural Conductor 110' 20" 260 sx Arcticset (Approx.) Surface 3165' 10-3/4" 1213 sx CS III/375 sx 'G' Intermediate 8908' 7-5/8" 265 sx Class 'G' Production Liner 797' 5-1/2" 91 sx Class 'G' MD TVD BKB 110' 110' 3195' 3132' 8936' 8588' 8788' - 9585' 8441' - 9236' Perforation depth: measured Open Perfs 9172- 9194. 9202- 9222 true vertical Open Perfs 8823 - 8845. 8853 - 8873 Tubing (size. grade, and measured depth) 4-1/2" 13CR80 tubing to 8788' Packers and SSSV (type and measured depth) 7-5/8" Perm Packer @ 8730', 4-1/2" SSSV @ 2104'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge soott L~Voie Title Technical Assistant Prepared By Name/Number: Date ~/..~,) / .~ De Wayne/Schn~rr 564-5174 Form 10-404 Rev. 06/15/88 Submit In Duplicate 04/11/2OO 1 04/14/2001 B-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANN-COMM: EVAL TUBING BEFORE PULLING TTP ANN-COMM: PULL PLUG (ANN COMM) SUMMARY 04/11/01 TUBING MIT PASSED (3000 PSI) 04/14/01 EQUALIZED AND PULLED 4.5" XXN PLUG FROM 8763' SLM, PLUG AND FILL EXT. WAS FULL OF SCALE. WELL WAS RELEASED FOR PRODUCTION ~ Fluids Pumped BBLS. Description 1.5 1.5 BBLS DIESEL DOWN TUBING 1 1 BBL DIESEL FOR P/T 2.5 TOTAL ON OR BEFO W c:LO~M.DOc PERMIT q~3-146 9 ~ - 146 93-146 ~3-146 93-146 5)3-146 93-146 93-146 93-146 93-146 93-146 DATA AOGCC individual well Geological Materials inven'tory T DATA_PLUS 5947 407 DALLY WELL OP ~URVEx BHC/GR CN / GR DiFL/GR PDLS ~~8400-9581, OH-DIFL-LDWG ~OMP DARE' 12/25/93 t~I~!/24/93-12/12/~:3 ' n-~585, MWD & EMS ~936-9552 ~~36-9529 ~w~8%00-9581 ~000-9247 P~'~' ..... ~10 ~/eR/~cL(PERF) 0-9320 PFC/GR/CCL{PERF} ~9!06-9321 PLS(STAT PRES/TE~*L~ 9117=9484 SBT/GR/CCL ~550-9471 SSTVD ~936-9~81 Page - i Date · 10/13/95 RUN DATE_RECVD ,31/05/94 01/21/94 01/21/94 01/21/94 12/20/93 12/20/93 12/20/93 12/02/94 01/18/94 Ol/18/94 01/18/94 01/li/94 12/20/93 Are ery ~icch ~ = .,--' = yes ~.~ .... mpz~- required? nd received? Was the well cored? yes ~Analysis & description r~~ Are wei'i tests requiredg~fes.~ceived? Well is in compliance Initial COHHE NT e LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 28 November 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION v~l~7 , I CN/SR ~INAL B~. + RF %_ ¥ z-14 -(44-18-11-13) % ~ / m)~3 s (2 2 - 3 I - 1 I - I 4 ~S-32 33-26-12-12 1 PDK FINAL BL + RF 1 PLS FINAL BL + RF 1 pDK BORAX FNL BL+RF 1 CN/GR FINAL BL + RF 1 PLS FINAL BL + RF 1 PLS FINAL BL + RF Run # 1 Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 4529.04 4595.07 5833.06 6012.02 6105.02 6107.04 6202.01 Please sign and return to: A~as Wirelin~rvices . Suite~ ~u~n. ~ooney u. ~au±son Or FAX to (907) 563-7803 Received by:. /~..~/~~------~ Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 93-146 3. Address N R I Gi~jAL .8. APINumber P. O. Box 196612, Anchorage, Alaska 99519-6612 5o-029-22406 4. Location of well at surface '"" 9. Unit or Lease Name 1924' SNL, 1607' WEL, SEC. 31, T11N, R14E ~!" ;-:'r.~'';,' -= '- "; Prudhoe Bay Unit At Top Producing Interval i ' ,-~: ~~'.-~-': .:' =" B-35 (22-31-11-14) 2409'SNL, 3733'WEL, SEC. 31, T11N, R14E ..~ 11. Field and Pool At Total Depth ~ ~ ,'~/~-C_~ ~~~ Prudhoe Bay Field/Prudhoe Bay Pool 2402'SNL, 3768' WEL, SEC. 31, T11N, R14E :5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 66.9' I ADL 28310 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 11/24/93 12/5/93 12/25/93I N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~..0. Depth where SSSV set ~21. Thickness of Permalrosl 9585' MD/9236' TVD 9500' MD/9151' TVD YES [] N3 []~ 2103' feet MD! 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/BHCS/CNL/GR/MWD 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 30' 110' 30" 260 sx Arcticset (Approx.) 10-3/4" 45.5# NT-80 30' 3195' 13-1/2" 1213 sx CS 111/375 sx "G" 7-5/8" 29. 7# NT-95HS 28' 8936' 9-7/8" 265 sx Class "G" 5-1/2" 17# 13CR80 8788' 9585' 6-3/4" 91 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) ... SIZE DEPTH SET (MDI PACKER SET (MD) Gun Diameter 3-3/8" 6 spf 4-1/2", 13CR80 8789' 8730' MD TVD 9202'-9222' 8853'-8873' 26. ACID, FRACTURE, CEMENT SQUEF_Z~, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 12/27/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS F~hMATION TESTS NAME .. Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 8940' 8524' Shublik 8967' 8551' Top Sad/erochit 9047' 8631' 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~/t'~lqA. Signed ?'~? ~ TitleOri//ingEnginoorSuoewi'j~2r Date/''~-D'' ~ [~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 .;. :_:::.~ ,,.:il & O0.S O0,q$. '; 'r '"'-". Ar~chor3.~.l': BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: B-35 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 11/23/93 08:00 SPUD: 11/24/93 01:30 RELEASE: OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NABORS 18E 11/24/93 ( 1) TD: 375' ( 375) 11/25/93 ( 2) TD: 1926' (1551) 11/26/93 (3) TD: 3200' (1274) 11/27/93 ( 4) TD: 3200' ( 0) 11/28/93 ( 5) TD: 5030' (1830) 11/29/93 (6) TD: 6309' (1279) 11/30/93 (7) TD: 7716' ( 1407) 12/01/93 (8) TD: 8439' ( 723) DRLG. MW: 8.8 VIS:320 MOVE RIG TO B-35. RIG ACCEPTED @ 20:00 HRS, 11/23/93. N/U DIVERTER. P/U BHA. TEST DIVERTER. SPUD WELL @ 01:30 HRS, 11/24/93. DRLG TO 375'. DRLG. MW: 9.2 VIS:ll2 DRLG F/ 375'-1160'_ SHORT TRIP TO DC. DRLG F/ 1160'-1714' SHORT TRIP 10 STDS. DRLG F/ 1714'-1926'. RUN CSG. MW: 9.5 VIS:130 DRLG F/ 1926'-3200'. SHORT TRIP 20 STDS. REAM TO BTM. CBU. POOH. RIH W/ 10-3/4" CSG. RIH. MW: 9.1 VIS: 34 RIH W/ 10-3/4" CSG. CIRC. PUMP 75 BBLS WATER, 1213 SX LEAD CMT, 375 SX TAIL CMT. BUMP PLUG W/ 2000 PSI. N/D DIVERTER. TOP JOB W/ 144 SX CSII. N/U BOPE. TEST BOPE. RIH W/ BHA, BIT. DRLG. MW: 9.3 VIS: 39 TEST CSG. OK. DRLG FLOAT EQUIP, CMT. LOT (13.6 PPG EMW). DRLG F/ 3210'-3702'. SHORT TRIP TO SHOE. DRLG F/ 3702'-4774'. SHORT TRIP TO 3690'. REAM TO BTM. DRLG F/ 4774'-5030' DRLG. MW: 9.5 VIS: 38 DRLG F/ 5030'-5761' POOH. CHANGE BIT, BHA. RIH. DRLG F/ 5761'-6309'. DRLG. MW: 9.6 VIS: 41 DRLG F/ 6309'-6744'. SHORT TRIP 11 STDS. DRLG F/ 6744'-7716'. DRLG. MW: 9.6 VIS: 38 SHORT TRIP 11 STDS. DRLG F/ 7716'-8439'. 12/02/93 (9) TD: 8942' ( 503) L/D DP. MW: 9.7 VIS: 39 POOH. CHANGE BIT, BHA. RIH. DRLG F/ 8439'-8942' SHORT TRIP 10 STDS. CIRC. POOH, L/D DP. WELL : B-35 OPERATION: RIG : NABORS 18E PAGE: 2 12/03/93 (10) TD: 8942' ( 0) 12/04/93 (11) TD: 9001' ( 59) 12/05/93 (12) TD: 9005' ( 4) 12/06/93 (13) TD: 9585' ( 580) 12/07/93 (14) TD: 9585' ( 0) TEST BOPE. MW: 9.6 VIS: 40 POOH. L/D DP. TEST BOPE. RIH W/ 7-5/8" CSG. CIRC. PUMP 50 BBLS 11 PPG SPACER, 265 SX 'G' CMT. DISP W/ MUD. BUMP PLUG W/ 2000 PSI. SET & TEST PACKOFF. INJECT 100 BBLS MUD DN ANNULUS. TEST BOPE. JARRING ON STUCK PIPE MW: 9.8 VIS: 40 FINISH TESTING KELLY COCKS. #8 MANIFOLD VLAVE LEAKED. HAS BEEN REPAIRED. PU 6 3/4" PACKED BHA AND 260 JTS 3 1/2" DP. TAGGED UP @8800' C.O. CMT STRINGERS F/ 8800' TO F. C. @8814'. CIRC AND COND MUD. TEST 7 5/8" CSG/ DRLG PLUGS, FLOAT COLLAR @8814'. CIRC AND COND MUD. DRLG 6 3/4" HOLE F/ 8952'. WORK AND JAR ON STUCK PIPE @8970'. POH W/ FISH MW: 8.8 VIS: 42 WORK STUCK PIPE @8970' JARRING UP AND DOWN. RU ATLAS W. L. TRUCK. RIH W/ STRING SHOT. CHAINED OUT OF HOLE. FISH LEFT IN HOLE. PU FISHING TOOLS - 3 1/2" SCREW IN SUB. PU KELLY AND BREAK CIRC. SCREW INTO FISH @8913'. ROTATE KELLY DOWN - HOLE TIGHT WHERE PIPE WAS STUCK. HOLE IN GOOD SHAPE. DRLG 6 3/4" F/ 9001' - 9005'. POH WITH FISH. LD DC'S @0600 HRS. LOGGING MW: 8.7 VIS: 42 FINISHED LD 4 3/4" DC'S AND NM DC. PU NEW 6 3/4" BIT, NMDC AND STAB. CUT DRLG LINE. FINISHED RIH TO 9005' HOLE IN GOOD SHAPE. DRLG 6 3/4" HOLE F/ 9005 - 9585' SHORT TRIP TO 7 5/8" SHOE. CIRC AND COND MUD AND HOLE FOR LOGS. POH FOR LOGS - SLM. RU WESTERN ATLAS W. L. RIH W/ LOGGING TOOLS. CIRC AND COND MUD MW: 8.8 VIS: 42 W. ATLAS RAN DIL/BHC/CNL/GR F/ WLTD 9585-8936'_ PU BHA AND RIH SLOW. CIRC AND COND MUD AND HOLE FOR 5 1/2" LINER. DROPPED 2 1/8" RABBIT AND POH - LD BHA. HOLE IN GOOD SHAPE. CHANGED BTM RAMS TO 5 1/2". RU CSG TOOLS. RAN 19 JTS 5 1/2" 17# CR-80 CSG AND BAKER 7 5/8" X 5 1/2" HMC LINER HANGER W/ H- ISOLATION PACKER. RIH W/ 5 1/2" LINER ON 3 1/2" DP. FILL EVERY 10 STDS. CIRC @ 7 5/8" SHOE. CIRC AND COND MUD AND JOLE FOR CMT JOB. WELL : B-35 OPERATION: RIG : NABORS 18E PAGE: 3 12/08/93 (15) TD: 9502 PB: 9152 12/09/93 (16) TD: 9502'( 12/10/93 (17) TD: 9500 PB: 9151 12/11/93 (18) TD: 9500 PB: 9151 12/12/93 (19) TD: 9500 PB: 9151 0) TRIP OUT OF HOLE MW: 0.0 CIRC AND COND MUD AND HOLE FOR CMT JOB. TEST LINES. POH W/ 10 STDS DP. POH W/ SETTING TOOL. LINER WIPER PLUG ON SETTING TOOL W/ DP WIPER PLUG SEATED. INSTALL 3 1/2" RAMS IN BTTM & TEST DOOR SEALS. MAKE UP 6 3/4" BIT. DRILLING CEMENT F/ 8635-8787'. CIRC BTTMS UP. TRIP OUT OF HOLE. INSTALL 2 7/8" RAMS. MAKE UP 4 3/4" MILL, 3 1/2" DC'S, 2 7/8" DP & TRIP IN HOLE @8786'. DRILLING CEMENT FROM 8786-8795'. TRIP IN HOLE TO LND COLLAR @9502'. CIRC 10 MIN & ATTEMPT TO TEST LINER. CIRC BTTMS UP @9502' TRIP OUT OF HOLE WITH 4 3/4" MILL. RUN 5 1/2" RETAINER MW: 8.9 VIS: 40 TRIP OUT OF HOLE WITH 4 3/4" MILL. INSTALL 3 1/2" RAMS IN BTTM & TEST DOOR SEALS @5000 PSI. MAKE UP BAKE POLISH MILL & TRIP IN HOLE @8787' POLISH TIE-BACK WITH 70 RPM, 60 SPM @700 PSI. TRIP OUT OF HOLE WITH POLISH MILL. MAKE UP TIE BACK ASSEMBLY WITH 7 5/8" RET. PACKER & TRIP IN HOLE TO LINER TOP @8787'. BREAK CIRC, STAB IN SEAL ASSEMBLY, PUMP DOWN DP, BROKE DOWN. TRIP OUT OF HOLE WITH SEAL ASSEMBLY/PACKER. INSTALL 2 7/8" RAMS IN BTTM & TEST DOOR SEALS. MAKE UP 5 1/2" RETAINER, RUNNING TOOL, 3 1/2" DC'S, 2 7 7/8" DP, & TRIP IN HOLE. CUT DRILLING LINE & TRIP IN HOLE. RIG UP TO RUN 4 1/2" TUB MW: 8.5 NaC1 TRIP IN HOLE WITH 5 1/2" BAKER K1 CEMENT RETAINER @9502'. SET RETAINER. CIRC, TEST CSG @ 3500 PSI. TRIP OUT OF HOLE WITH RUNNING TOOL. MAKE UP 4 3/4" MILL, BIT SUB, DC'S 2 7/8" DP, TRIP IN HOLE @9500'. CIRC BTTMS UP. P UMP SWEEP, SPACER & REVERSE OUT W.B. MUD WITH 8.5 BRINEEE. CLEAN SHAKERS, MUD THROUGH, ECT. CIRC. "INHIBITOR TREATED" BRINE ON FINAL CIRC. TEST CSG. BREAK KELLY, TRIP OUT OF HOLE LAYING DOWN DP & BHA. INSTALL 4 1/2" RAMS IN BTTM SET & TEST DOOR SEALS. RIG UP TO RUN 4 1/2" TUBING. NU TREE & TEST MW: 0.0 NaC1 RUN 4 1/2" 13 CR TUBING TO BALL VALVE. PICK UP CAMCO EQUIP. INSTAL BALL VALVE & NIPPLE UP CONTROL LINES. CONTINUE TO TRIP IN HOLE WITH TUBING ATTACHING LASALLE CLAMPS EVERY OTHER JT. SPACE OUT, MAKE UP HANGER. INSTALL 2-WAY CHEC. NU CONTROL LINES TO HANGER AND TEST. INSTALL 3 1/2" RAMS & NIPPLE DOWN BOP'S. TEST CONTRL LINES. RELEASE RIG MW: 0.0 NaC1 TEST X-MAS TREE. REMOVE 2-WAY CHECK WITH LUBRICATOR. SET PACKER WITH 4000 PSI & TEST FOR 30 MIN TEST ANN. @3500. SHEAR PR VALVE & DISPLACE ANN. WITH DIESEL, ALLOW TO U-TUBE BACK TO TUBING. RELEASE RIG 12/11/93 @ 1700 HRS. ORIGINAl_ B-35 BAKER HUGHES INTEQ MWD SURVEYS - 0.00' -8,882' EMS SURVEYS - 8,968'- 9,585' · - BP EXPLORATION (Alaska) Inc. Pad B B'35 slot #35 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : EMS <8968 - 9543> Our ref : svy4132 License : Date printed : 20-Dec-93 Date created : 17-Dec-93 Last revised : 20-Dec-93 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on nTO 16 17.459,w148 39 37.719 Slot location is nTO 15 58.535,w148 40 24.491 Slot Grid coordinates are N 5948725.954, E 664050.023 Slot local coordinates are 1924.00 S 1607.00 W Reference North is True North BP EXPLORATION (Alaska) Inc. Pad B,B-35 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : EMS <8968 - 9543> Last revised : 20-Dec-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 131.00 0.10 239.70 131.00 0.06 S 0.10 W 0.08 0.11 222.00 0.40 214.10 222.00 0.36 S 0.34 W 0.34 0.41 314.00 0.50 229.20 314.00 0.89 S 0.83 W 0.17 1.00 408.00 0.70 236.20 407.99 1.48 S 1.62 W 0.23 1.90 500.00 0.70 230.30 499.98 2.15 S 2.52 W 0.08 2.92 592.00 1.20 235.20 591.97 3.06 S 3.74 W 0.55 4.31 683.00 1.70 265.40 682.94 3.71 S 5.87 W 0.98 6.52 776.00 1.90 264.00 775.90 3.98 S 8.78 W 0.22 9.42 869.00 2.00 260.00 868.84 4.42 S 11.91 W 0.18 12.58 962.00 2.10 262.20 961.78 4.94 S 15.19 W 0.14 15.90 1054.00 2.00 257.30 1053.72 5.52 S 18.43 W 0.22 19.18 1147.00 1.90 257.70 1146.67 6.20 $ 21.52 W 0.11 22.35 1240.00 2.20 257.30 1239.61 6.92 S 24.77 W 0.32 25.68 1331.00 2.00 256.30 1330.55 7.68 S 28.01 W 0.22 29.01 1423.00 2.20 258.70 1422.49 8.41 S 31.30 W 0.24 32.38 1516.00 1.80 264.00 1515.43 8.91 S 34.51 W 0.47 35.62 1609.00 1.50 268.60 1608.39 9.10 S 37.18 W 0.35 38.26 1701.00 2.40 265.40 1700.34 9.28 S 40.30 W 0.98 41.35 1793.00 4.00 265.80 1792.19 9.67 S 45.42 W 1.74 46.44 1885.00 5.10 267.90 1883.90 10.05 S 52.71 W 1.21 53.64 1978.00 6.30 264.00 1976.44 10.74 S 61.91 W 1.36 62.78 2072.00 9.90 257.70 2069.49 13.00 S 74.94 W 3.94 75.99 2164.00 12.30 257.30 2159.76 16.84 S 92.23 W 2.61 93.70 2255.00 14.50 257.70 2248.28 21.40 S 112.82 W 2.42 114.79 2347.00 17.00 258.00 2336.82 26.65 S 137.23 W 2.72 139.76 2439.00 19.20 258.40 2424.26 32.49 S 165.21 W 2.40 168.34 2532.00 20.10 259.80 2511.84 38.39 S 195.92 W 1.09 199.60 2625.00 20.50 259.10 2599.07 44.30 S 227.64 W 0.50 231.84 2718.00 20.80 258.70 2686.09 50.62 S 259.82 W 0.36 264.63 2810.00 20.50 259.40 2772.18 56.78 S 291.68 W 0.42 297.07 2902.00 20.80 259.40 2858.27 62.75 S 323.57 W 0.33 329.50 2994.00 21.20 260.50 2944.16 68.50 S 356.03 W 0.61 362.44 3086.00 20.80 260.10 3030.05 74.05 S 388.53 W 0.46 395.37 3140.00 20.60 260.50 3080.56 77.27 S 407.34 W 0.45 414.44 3240.00 20.60 262.60 3174.17 82.44 S 442.14 W 0.74 449.54 3334.00 19.20 261.90 3262.55 86.75 S 473.84 W 1.51 481.43 3428.00 19.60 261.90 3351.22 91.15 S 504.75 W 0.42 512.56 3518.00 19.60 257.30 3436.01 96.59 S 534.43 W 1.71 542.72 3611.00 19.20 254.50 3523.73 104.11 $ 564.38 W 1.09 573.58 3704.00 19.00 253.40 3611.61 112.52 S 593.62 W 0.44 603.95 3795.00 18.70 253.50 3697.73 120.90 S 621.81 W 0.33 633.27 3888.00 18.10 253.80 3785.97 129.16 S 649.97 ~ 0.65 662.56 3980.00 18.00 255.90 3873.45 136.61 S 677.48 W 0.72 691.02 4072.00 17.60 254.90 3961.04 143.70 S 704.70 W 0.55 719.13 4164.00 17.30 254.90 4048.81 150.88 S 7'~1.34 ~ 0.33 746.68 4256.00 17.20 253.80 4136.67 158.24 S 757.61 W 0.37 773.92 4347.00 17.10 255.20 4223.62 165.41 S 783.46 W 0.47 800.71 4439.00 16.70 254.90 4311.65 172.31 S 809.30 ~ 0.44 827.43 4532.00 16.40 253.80 4400.80 179.46 S 834.81 W 0.47 853.87 All data is in feet unless otherwise stated Coordinates from slot #35 and TVD from wellhead (68.20 Ft above mean sea level). Vertical section is from S 0.00 W 0.00 on azimuth 257.64 degrees. Declination is 0.00 degrees~ Convergence is 1.26 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. Pad B,B-35 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : EMS <8968 - 9543> Last revised : 20-Dec-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 4622.00 15.80 257.00 4714.00 18.50 255.90 4808.00 19.20 254.50 4901.00 19.10 254.20 4994.00 18.60 254.90 4487.27 185.76 S 858.95 W 1.19 878.80 4575.17 192.13 S 885.31 W 2.96 905.92 4664.13 199.90 S 914.67 ~ 0.89 936.26 4751.98 208.12 S 944.05 ~ 0.15 966.72 4840.00 216.13 S 973.01 W 0.59 996.72 5088.00 17.80 254.50 5178.00 19.00 255.90 5271.00 20.10 259.80 5363.00 19.60 258.00 5456.00 19.60 258.70 4929.29 223.88 S 1001.33 ~ 0.86 1026.04 5014.69 231.12 S 1028.80 W 1.42 1054.42 5102.33 237.64 S 1059.21 ~ 1.83 1085.53 5188.87 243.65 S 1089.86 ~ 0.86 1116.75 5276.48 249.95 S 1120.42 ~ 0.25 1147.95 5547.00 18.90- 257.30 5639.00 20.10 258.00 5733.00 21.70 257.00 5828.00 21.30 255.60 5922.00 21.60 256.60 5362.39 256.18 S 1149.76 W 0.92 1177.95 5449.11 262.74 S 1179.76 W 1.33 1208.66 5536.92 270.01 S 1212.49 ~ 1.74 1242.19 5625.31 278.25 S 1246.32 ~ 0.68 1276.99 5712.80 286.51 S 1279.69 ~ 0.50 1311.36 6016.00 21.40 255.60 6112.00 21.40 254.20 6207.00 21.40 253.50 6300.00 21.40 252.80 6394.00 21.40 254.90 5800.26 294.78 S 1313.13 W 0.44 1345.79 5889.64 303.91 S 1346.94 W 0.53 1380.78 5978.10 313.55 S 1380.24 ~ 0.27 1415.36 6064.68 323.38 S 1412.72 ~ 0.27 1449.19 6152.20 332.92 S 1445.66 W 0.82 1483.41 6488.00 20.70 257.70 6584.00 20.70 258.00 6679.00 20.70 257.70 6772.00 20.60 256.60 6869.00 20.70 257.70 6961.00 20.50 257.30 7053.00 20.20 256.60 7146.00 19.90 255.60 7243.00 19.80 255.90 7336.00 19.70 255.90 6239.93 340.93 S 1478.45 ~ 1.30 1517.16 6329.74 348.07 S 1511.62 ~ 0.11 1551.09 6418.60 355.14 S 1544.45 ~ 0.11 1584.67 6505.63 362.43 S 1576.42 ~ 0.43 1617.46 6596.40 370.04 S 1609.77 ~ 0.41 1651.67 6682.51 377.04 S 1641.37 W 0.26 1684.04 6768.77 384.27 S 1672.54 W 0.42 1716.03 6856.14 391.92 S 1703.49 W 0.49 1747.90 6947.37 400.03 S 1735.41 W 0.15 1780.82 7034.90 407.69 S 1765.89 W 0.11 1812.23 7430.00 19.60 255.90 7525.00 19.30 254.90 7620.00 19.00 254.50 7714.00 18.60 255.90 7809.00 16.80 255.90 7123.43 415.39 S 1796.55 W 0.11 1843.83 7213.01 423.36 S 1827.16 W 0.47 1875.43 7302.75 431.58 S 1857.22 ~ 0.34 1906.56 7391.73 439.32 S 1886.51 ~ 0.64 1936.82 7482.23 446.36 S 1914.52 W 1.89 1965.69 7903.00 15.10 257.30 7998.00 14.20 258.00 8093.00 13.80 257.30 8187.00 12.60 259.40 8281.00 11.70 258.00 8374.00 10.50 258.40 8467.00 9.50 259.80 8561.00 7.90 260.50 8655.00 7.20 262.90 8748.00 6.20 264.00 7572.61 452.36 S 1939.64 ~ 1.85 1991.51 7664.52 457.50 S 1963.11 W 0.96 2015.54 7756.70 462.42 S 1985.56 W 0.46 2038.52 7848.22 466.77 S 2006.58 ~ 1.37 2059.98 7940.11 470.64 S 2025.98 W 1.01 2079.76 8031.37 474.30 S 2043.50 ~ 1.29 2097.66 8122.95 477.36 S 2059.36 ~ 1.11 2113.81 8215.87 479.80 S 2073.36 ~ 1.70 2128.01 8309.05 481.60 S 2085.58 W 0,82 2140.33 8401.42 482.84 S 2096.36 ~ 1.08 2151.12 8843.00 5.80 Z66.50 8495.90 483.67 S 2106.25 W 0,50 2160.96 8882.00 6.00 267.50 8534.69 483.88 S 2110.26 W 0,58 2164.92 LAST MWD SURVEY 8968.00 5.55 267.17 8620.25 484.28 S 2118.90 ~ 0.52 2173.45 BEGIN EMS SURVEYS 8983.00 5.42 267.34 8635.18 484.35 S 2120.33 ~ 0.87 2174.86 9045.00 4.76 265.45 8696.94 484.69 S 2125.82 ~ 1,10 2180.30 All data is in feet unless otherwise stated Coordinates from slot #35 and TVD from wellhead (68.20 Ft above mean sea level). Vertical section is from S 0.00 ~ 0.00 on azimuth 257.64 degrees. Declination is 0.00 degrees, Convergence is 1.26 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. Pad B,B-35 Prudhoe Bay,North Slope, Alaska Measured Inclin. Azimuth True Vert. R Depth Degrees Degrees Depth C 9138.00 4.45 270.98 8789.64 9230.00 4.32 274.19 8881.37 9322.00 3.77 285.55 8973.14 9415.00 3.65 289.54 9065.95 9506.00 3.21 290.54 9156.78 9543.00 2.95 292.10 9193.73 9585.00 2.96 292.10 9235.68 SURVEY LISTING Page 3 Your ref : EMS <8968 - 9543> Last revised : 20-Dec-93 E C T A N G U L A R Dogleg Vert 0 0 R D I N A T E S Deg/lOOFt Sect 484.94 S 484.62 S 483.56 S 481.75 S 479.89 S 2133.27 W 0.58 2187.63 2140.30 W 0.30 2194.43 2146.67 W 1.05 2200.42 2152.40 W 0.31 2205.64 2157.52 W 0.49 2210.23 479.16 S 2159.37 478.35 S 2161.38 0.74 2211.89 0.02 2213.67 PROJ. SVY TO T.D. All data is in feet unless otherwise stated Coordinates from slot #35 and TVD from wellhead (68.20 Ft above mean sea level). Vertical section is from S 0.00 W 0.00 on azimuth 257.64 degrees. Declination is 0.00 degrees, Convergence is 1.26 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes ]NTEQ BP EXPLORATION (Alaska) Inc. SURVEY LISTING Page 4 Pad B,B-35 Your ref : EMS <8968 - 9543> Prudhoe Bay,North Slope, Alaska Last revised : 20-Dec-93 Comments in wellpath MD TVD Rectangular Coords. Coherent 8882.00 8534.69 483.88 S 2110.26 W LAST MWD SURVEY 8968.00 8620.25 484.28 S 2118.90 W BEGIN EMS SURVEYS 9585.00 9235.68 478.35 S 2161.38 W PROJ. SVY TO T.D. All data is in feet unless otherwise stated Coordinates from slot #35 and TVD from wellhead (68.20 Ft above mean sea level). Bottom hole distance is 2213.68 on azimuth 257.52 degrees from we[lhead. Vertical section is from S 0.00 W 0.00 on azimuth 257.64 degrees. Declination is 0.00 degrees, Convergence is 1.26 degrees. CalcuLation uses the minimum curvature method. Presented by Baker Hughes INTEQ ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 January 1994 RE: Transmittal of Data ECC #: 6107.03 Data: PL Dear Sir/Madam, Reference: BP B-3~ (22-31-11-14) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Sent-by U.S. MAIL PLS FINAL RF SEPIA 1 PFC/PERF FINAL RF Run ~ 1 PLS FINAL BL Run ~ 1 /r_~lc~u"~ ~z[z~lo3' ~ i ~t~oo-q%2o 5 Please sign and return to: Atlas Wireline ServiCes Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson ,.,,. ... .,'" Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 January 1994 RE: Transmittal of Data ECC #: 6107.02 Data: PL Dear Sir/Madam, Reference: BP B-35 (22-31-11-14) i --~ NORTH SLOPE, AK Enclosed, plea~? find the data as described below: Prints/Films: Sent by U.S. MAIL · _ 1 PFC/GR/CCL FINAL BL 1 PFC/GR/CCL FINAL RF Run ~ 1 Run ~ 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 3 January 1994 RE: Transmittal of Data ECC #: 6107.01 Data: SBT/GR Dear Sir/Madam, Reference: BP B-35 (22-3~1-11-14) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL SBT/GR/CCL FINAL BL SBT/GR/CCL FINAL RF Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, ~ 99518 Attn. Rodney D. Paulson Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 28 December 1993 RE: Transmittal of Data ECC #: 6107.00 Data: OH-LDWG Dear Sir/Madam, Reference: BP B-35 (22-31-11-14) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tape s/D iskett e s: Sent by U.S. MAIL DIFL LDWG TAPE+LIST Run # 1 goo - l Received by: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson / Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. -USA Date: 13 December 1993 RE: Transmittal of Data ECC #: 6107.00 Data: OH-LDWG Dear Sir/Madam, Reference: BP B-35 (22-31-11-14) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Sent by U.S. MAIL DIFL/GR FINAL RF BHC/GR FINAL RF CN/GR FINAL RF SSTVD FINAL RF DIFL/GR FINAL BL BHC/GR FINAL BL CN/GR FINAL BL SSTVD FINAL BL Run Run Run ~ 1- ~9~-~5~[ ~/~ Run Run Run Run Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 October 13, 1993 Terry Jordan Drilling Engineer Supervisor BP Exploration, Inc. P O Box 196612 Anchorge, AK 99519-6612 Re: Prudhoe Bay Unit B-35 BP Exploration, Inc. Permit No: 93-146 Sur. Loc. 3384'NSL, 1611'WEL, Sec. 31, TllN, R14E, UM Btmhole Loc. 2887'NSL, 3752'WEL, Sec. 31, TllN, R14E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BO?E) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,, f", STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 66.6 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28310 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 ^^c 25.025) 3384' NSL, 1611'WEL, SEC. 31, T11N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2887' NSL, 3752' WEL, SEC. 31, T11N, R14E B-35 (22-31-11-14) 2S100302630-277 At total depth 9. Approximate spud date Amount 2887' NSL, 3752' WEL, SEC. 31, T11N, R14E 11/15/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 28286-1248' feet B-12-42' @ 1477' MD feet 2560 9452' MD/9057' TVD feet 16. To be completed for deviated wells ~17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2200 feet Maximum hole angle 22 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psi~ 18. Casing program Specifications Setting Depth size Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 30" 20" 91.5tt H-40 Weld 80' 30' 30' 110' 110' 268 sx Arcticset (Approx.) 13-1/2" 10-3/4" 45.511 NT8OLHE Butt 3071' 29' 29' 3100' 3065' ~ 175 sx CS 111/375 sx "G"/250 sx CS II 9'7/8" 7-5/8" 29. 7# NT95HS NSCC 8973' 28' 28' 900 I' 8607' 265 sx Class "G" 6-3/4" 5-1/2" 1711 13CR80 NSCC 601' 8851' 8462' 9452' 9057' 90 sx Class "G" 19. To be completed for Redrill. Re-entry. and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural !'" " '-'~ i ..... i: '~'~ i:"~ Conductor ~,. ,:..:' :.. , Surface ........... : ':" ' ' Intermediate Production :ii: ;~," ;". ;!~ ;:';.;ii;;~: Liner Perforation depth: measured .,,: .... ¢ ..... : L. ,i t::, :.:., ', :',~.',~:',~,ii~''-:;!''''''~ true vertical ~:. ;.-;;~t3;'::!;,', 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l'2] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-'l 20 AAC 25.050 requirementsl-] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge __ Signed /~/~//Z/-/~?,,¢¢._._I:\ -~ Title Drilling Engineer Supervisor Date /'- / ~ Commission Use Only Permit Number APl number IAp/pr/~v¢ d~te Ieee cover letter ~',,_~- //--/'6 50- o,2_'~- .2-.2_ z-/O~I ~, ~, ,_y,/ - ~c;~), Ifor other requirements Conditions of approval Samples required [] Yes .~ No Mud log required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required ~i~ Yes [] No Required working pressure for BOPE 1-12M; F-13M; ~ii[,SM; D10M; l-]15M; Other: by order of Approved by Commissioner tne commission Date · .. Form 10-401 Rev. 12-1-85 Submit in triplicate I Well Name: ]B-35 PBU Well Plan Summary Type of Well (producer or injector): i Producer Surface Location: I 3384' FSL 1611' FEL Sec 31TllN R14E UM Target Location: I 2887' FSL 3752' FEL Sec 31 T11N R14E UM Bottom Hole Location: 2887' FSL 3752' FEL Sec 31 T11N R I4E UM I AFE Number: ]4PXXXX I I Rig: I Nabors 18-E I Estimated Start Date: [Nov 15,1993 ] I Operating days to complete: I 18 [MD: ]9452 ] [TVa: 19057' ] ]KBE: ]66.6 ] Well Design (conventional, slimhole, etc.): ] Slimhole producer Formation Markers: ,. Formation Tops MD TVD (BKB) Ugnu Zone 4A 4489' 4367' , W. Sak Sands Top Seabee 5275' 5097' Kupamk/Put River ' Absent IKRU/LCU 8170' 7790' Top Sag River 9001' 8907' .Top Shublik 9029' 8635' Top Sadlerochit 9104' 8709' Target 9259' 8864' Total Depth 9452' 9057' Casin /Tubin Program: Wt/Ft Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD "30" 20" 91.5# H-40 Weld 80' 301/30, 1107110' 13 1/2" 10 3/4" 45.5# NTDOHI.I~. Butt 3071' 29'/29' 3100'/3065' 9 7/8" 7 5/8" 29.7# NT95HS NSCC 8973' 28728' 9001'/8607' , 6 3/4" 5 1/2" 17# 13Cr-80 NSCC 601' 8851'/8462' 9452'/9057' 4 1/2" 12.6 13Cr-80 NSCT 8774' 27'/27'' 880178407' Well Plan Summary Page 1 Logging Prog i~Open HOle Logs: 13 1/2" Hole 9 7/8" Hole 6 3/4" Hole I Cased Hole Logs: 7 5/8" Casing 5 1/2" Liner ram: None None GR/DIL/BHCS/CNL None SBT. (optional Gyro) Mud Program: I Special design considerations I None Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 100 20 15 20 9 15 ,,. tO tO tO tO tO tO tO · 9.5 300 60 60 80 10 25 Intermediate Mud Properties: l Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 35 10 5 10 9.5 5 tO tO tO tO tO tO tO 10.0 50 15 10 20 10 10 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 30 8 3 7 8 6 tO tO tO tO tO tO tO 9.0 45 13 10 15 9 8 Directional: IKOP: !2200. I Maximum Hole Angle: I 22 degrees Close Approach Well: [ B-Il at surface (66' away), B-12 at 1477' (42' away) The above listed wells will be secured during the close approach. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Well Plan Summary Page 2 PROPOSED DRILLING AND COMPLETION PROGRAM WELL B-35 [ -31-11N-14E] PBU MIRU. NU diverter and function test same. Drill 13-1/2" hole to 3100' MD BKB. Run and cement 10-3/4", 45.5#, L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. A formation leak-off test will be performed 10' below the 10-3/4" shoe. Directionally drill 9-7/8" hole to the 7-5/8" casing point above the top of Sag River. Run a 7- 5/8", 29.7 # NSCC casing string to within 10' of 9-7/8" TD and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected with dead crude oil. Directionally drill the 6-3/4" hole to TD. Run 5-1/2" liner from TD to 1.50' inside 7-5/8" casing shoe and cement using Class G cement. Clean out to 5-1/2" float equipment. Change over to NaC1 completion fluid. Test casing and lap to 3500 psi. Run 7-5/8" production packer on the 4-1/2" tubing. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Freeze protect the tubing and annulus with Diesel from surface to 2100' TVDBKB. Set and test packer. The well will be perforated after the rig has been released. Fluids incidental to the drilling of a well will be injected down CC-2A. Tubing Size: 4-1/2", 12.6 # NT13CR-80 tubing with 6 GLM's. Well Plan Summary Page 3 10-3/4" SURFACE CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 10-3/4" CIRC. TEMP 38°F SPACER: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: ColdSet III ADDITIVES: retarder WEIGHT: 12.2 ppg APPROX #SACKS: 1175 YIELD: 1.92 ft3/sx MIX WATER: 10.5 gps THICKENING TIME: Greater than 4 hrs @ 50°F TAIL CEMENT TYPE: Class G ADDITIVES: 2% A-7 +1 ghs FP-6L. WEIGHT: 15.8 ppg YIELD:I.15 ft3/sx APPROX #SACKS: 375 MIX WATER: 4.95 gps THICKENING TIME: Greater than 3 1/2 hrs @ 50°F TOP JOB CEMENT TYPE: Coldset II ADDITIVES: retarder WEIGHT: 14.5 ppg YIELD:0.96 ft3/sx MIX WATER: 3.89 gps APPROX #SACKS: 250 THICKENING TIME: Greater than 2 hrs @ 50°F CENTRALIZER PLACEMENT: 1. Run one(l) bow type centralizer per joint for the first 20 joints. 2. Place the centralizers in the middle of each joint with a stop collar. CEMENT VOLUME: 1. Lead slurry from shoe to surface w/100% excess (not including tail slurry volume). 2. Tail slurry volume 375 sx 3. Top job volume 250 sx. Well Plan Summary Page 4 7-5/8" INTERMEDIATE CASING CEMENT PROGRAM- BJ SERVICES CIRC. TEMP: 140° F SPACER: 50 bbls ARCO Alpha, weighted to current mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES' 0.4% FL-52+0.5% CD-32+3% A-2+lghs FP-6L WEIGHT: 11.0ppg YIELD: 3.31 ft3/sx MIX WATER: 20.9 gps APPROX #SACKS' NONE THICKENING TIME: Greater than 5 hfs at 140°F FLUID LOSS' 100-150 cc @ 140°F FREE WATER: 0 cc TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.3% FL-52 + 0.5% CD-32 + 0.1% A-2 + lghs FP-6L WEIGHT: 15.8ppg gps APPROX # SX: 265 YIELD: 1.14 cu ft/sk MIX WATER: 4.85 THICKENING TIME: 3 1/2-4 1/2 hfs @ 140°F FLUID LOSS: !00-150 cc @ 140°F FREE WATER: 0 cc CENTRALIZER PLACEMENT: 1 Turbulator centralizer per joint on the bottom 500' of 7-5/8" casing ( 12 required ). One solid body 7-3/4" x 9-1/4" centralizer or turbolator on first 2 joints inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud programand ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not batch mix tail cement. CEMENT VOLUME: 1. Tail slurry to 1000' MD above casing shoe with 30% excess. 2. 120' MD 7-5/8", 29.7# capacity for float joints. Note: There is no other hydrocarbon above Sag River. Well Plan Summary Page 5 5-1/2" PRODUCTION LINER CEMENT PROGRAM - BJ SERVICES CIRC. TEMP 140° F TVDSS. PREFLUSH: 20 bbls fresh water BHST 226 deg F at 8800' SPACER: 70 bbls ARCO Alpha weighted 1.0 ppg above mud weight. CEMENT TYPE: CLASS G ADDITIVES: 150 ghs BA-86L+0.6% CD-32+0.2% FL-33+0.2% A-2+0.5% gel WEIGHT: 15.7 ppg YIELD:I.17 ft3/sx MIX WATER: 3.58 gps APPROX #SACKS: 90 THICKENING TIME: 45 min @ surface + 3-4 hrs @ 140°F FLUID LOSS: < 50 cc @ 140°F FREE WATER: 0 cc at 45° angle. Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: Run 2 right hand turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Report actual fluid loss on morning report. Displace @ 6-8 bpm. LINER CEMENT VOLUME: . Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 5-1/2", 17# casing capacity below landing collar (80'). 150' liner lap (6 3/4" x 5-1/2") 150' of cement on top of the liner in the 7-5/8" casing w/DP. Well Plan Summary Page 6 -~SEP-18-1995 17:34 FROM G~.~EAT LAND DIR DRILLING TO I '- PBUDHOE 'BAY OB I LF I ~i ~o~LO~.~ox~oo ~oo ~oo o o.oo VERTICAL SECTION VIEW c~ ~o o~ ~.~o ~L~ ~o~ ~o~ ~ ~.~ O) KOPOnOP 1.50/100 780~ 7443 1923 2~.B3 .......... E) ENO O~ 2.~0 DROP 9~59 8864 2~97 0.00 Section at: 256.93 F) fAR6ET 925g 8864 2~g7 O.O0 TVD Scale.' I inch = ~200 fee( <KB> ~-T~ 9,5~ 9057 ~]97 0.00 Oep Scale.' ~ inch = ~200 fee( i A" i .' ! ~ Orawn · 09/~8/9B 800 .... ~ ..... ii ii ...... ~ [ great land Directional OrJC]ing ~ ~ ...... 1800 ............... ~ / / 2400__ [ 8 - _ ! i , .,,, ,,,, , .... ,,, " : : --.. .......... ~ ..... , ~ : 4200- -- [ I ' ' I -~ ................ '~ ~ C -~ - ~ ..... r .......... . ~ , I t / i '~' 'I ~ ' ' , ~ ' ~oo .......................... ·X ' ....... i -i ...... 1 ~ I 6000- -- ; I I i ', ' , . . ~- - . , , ; ¢. ,L .i 7200 I , ., ~ / ~..~.[~ .... ~ ~;~ ~'~~~ ..... :___, . seeD-¢~E~:~¢~g,~-~$~= ..... ' ~ = = ............. '- ' ~200 -6oo 0 600 ~200 ~800 2400 ~000 3600 ~300 4800 5400 Section Departure (c)B~'85~ BI.~O 5:03 ~ 'd .................. PRUDHOE BAY-"D-R];L'LTN6- ":-- .... I, larl,.er Ident i f i cat ion .A~ I<B 81 I(OP BUILD ~.50/100 £J EN[) OF 2.50 BUILD DJ KO¢ DIIOP 1.50/ E) EllO~ t.50 F) 1,~RGE r ,; 6) 1D 0 0 , 0 2200 0 . 0 3073 37 560 ~804 435 J873 9259 497 2i,tO 9259 497 21,i0 9,15~ 497 2140 6eeat Land Directional D?illJng ---- -,111 i , , , J 1 B-35 (P2) PLAN V]~E~ CLOSURE .....: OECL INAT ION.: SCALE ....... : DRA~IN ....... : 2197 feet at Azir~ulh 256.93 29.882 E I inch = 300 feet 09/18/93 ................ /~ ........ ~,- ..... -i:~ :~.L,~ -. ................................. I ........... ::~' .. ' /,ReEf t00' x 300 ALONG iZ 230 dig = I :, ................................................................ :i ...... ~ ........... i ~5S~ E'400 ~51} ~lO0 1950 1800 t650 1500 135~ 1200 1050 900 750 600 450 300 150 0 150 ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE D/ATE/ [9 thru [10 & 13] (4) Casg ~ ,, [ 14 thru [23 thru 28] Company ~P ~/~4o%~ > '-- / Lease & Well %~4~/~ NO REMARKS 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4.' Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ YES 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease nLrnber appropriate .......................................... 13. 14. 15. Does well have a unique name & nLrnber ................................ ~ Is conductor string provided ......................................... ~_ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~ Is enough cement used to circulate on conductor & surface ............ ~ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... .~. Will all casing give adequate safety in collapse, tension, and burst. ~ Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 .............. Is adequate wellbore separation proposed ............................. (~ Is a diverter system required ........................................ ~ Is drilling fluid program schematic & list of equipment adequate ..... ~ Are necessary diagrams & descriptions of diverter & BOPE attached .... ~ . Does BOPE have sufficient pressure rating -- test to ~-O~ psig ..... (~ Does choke manifold comply w/API RP-53 (May 84) ...................... ~ Is presence of H2S gas'probable ...................................... 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (6) Other /./~ ~x~j//~z 29. [29 thru 31] 30. ~2. (8) Addl ' 33. geology' engineering: gWd~ MTM -- _RAD~:> RPC/~ B~JDi-L.~m//I [ ~ TAB ~{~/~,['~,,.~ rev 6/93 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL I UNIT ON/OFF POOL CLASS STATUS AREAI ~ SHORE ~'-/ o l s ~ ~ ~c, l-~ , 'lI ? ? c~ /I d~o Additional remarks' ?/ MERIDIAN' UM ~ SM WELL TYPE' Exp~ X Redri 11 Inj Rev Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. B-35 PRUDHOE BAY OCT 1 G 199~ Atast~ Oil & Gas OODS, Gommia6ion ./ ~ . ~ · .r- ..~</~LC' ;,..- , .:.'..,-. -. ~ - .~ . .: : --.' . . ' . /'~'~?_.... ~;..~ '.'~:"'>~-"~ >~. ~~?~'~:~.~¢::.:,:~.:.%..:...',::::~'-'*':"'/:::'U"*-::';:::~'::":':":'":::'-:':* ::;.'.~:.~:~-:-- :.- ...... . '.. . ..' '.. ~'' ~ "* .._~'.'.~ ~''~. ,. . % .... . : ... ./.. ~:: ~,.~i~' ~ ~*x *' ,-:~--:.::.'.-_::.t~'".:~;X'.~ ';'"';:-~-'::c't':": ~ . ~- · ~~ ~ ~ ~- '~ 2 '"* r* '~' "' .... -,':':".: q::':-:: :'->''-' ' -' ' ~ ~ - -":'~ :--~:;'-'2":'- ~ :- :%L:~F:*/-''::' ~: ' '~ ~:~::: F.-' (-~ --' ~:' .~ : - . ." :* '¢% ~':':,,._.;:~_:-,..;:~:.~:!:: :::::.;.;:-::.:::~,<:.::.~: :/?}~/:://~-.:-.'--I 20-August-1996 - /~,:,?:y.~::.e;:..{::._~::?~:::~? '?:-.~/:,.{~?.:~L~:{::"::~;:/-~:~:~S :: ,] Cased Hole ~ --_:~:: .:~?'-:-'~-;t:'--:{_'~%~-_ '"~-_ _F-~-.. ':: ..::.;::')..:7::'i'"t:: _'.-'_t. ~. ' ~ '~l -. c,:':-..-t' :--'-'.- ~ ......... -.- .......~ .... .:-,-: :~:..'~...-.~ fi:'-: .: . _ . .z~:~;~js".~¢ ~5~,: .-- .., -- -,: .: .:..-. ::;., . ~ . . ..:.. .. , .~: ........ -~--,¢, ~4~:-,~ -~ *,..,~.-. ,~, ........... ,.-, ....... .,: ..../---~-:...*. .... - .... .... .. -'~' -* -;**-~:*:-~S ] ~' ~:'~.:Q::~:-:.-L-.~t::-:~t:.-:,i:-:t:-:.'-::t--'-'..:_-. '.:":':::~;--':~. ~":%--::-'h.:: ..;-. ;: ' ,,~ -~.~':':-; -::x:::':;F -~::; -' ..- ~: -:._,.-.,.: :::..:..: ..'., _:;--; -:-. ~;: .~:-~;;".:'. .... '-:/ .... V~-~'~ ~a,~,.-.,¢;~;*<*~: i , ...... ...., ..... ..................... ...._: __. ,.,-_ ...... ~:.~::.Z'_:_./_ /::._. :.._ .~**.. ~***~~¢~- WESTERN ATLAS Logging Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPEP~ATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) B - 35 500292240600 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 23-SEP-96 6107.05 D. BARBA E. KRUMANOCKER 31 liN 14E 1923 1606 68.20 37.70 CAS ING DRILLERS CAS ING SIZE (IN) DEPTH (FT) WEIGHT 7.625 8936.0 29.70 5.500 9585.0 17.00 4.500 8788.0 12.60 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD BASELINE CURVE FOR SHIFTS GRCH 8934.0 8935.5 8941.0 8949.5 8950.0 8951.0 8960.5 8961.0 8961.5 8979.0 8980.0 8980.5 8981.0 BHCS GR 2 1 06-DEC-93 WALS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 8932.5 8934.0 8941.0 8949.5 8950.5 8951.5 8960.5 8961.0 8962.0 8979.5 8980.0 8980.5 8981.5 (MEASURED DEPTH) (LB/FT) EQUIVALENT UNSHIFTED DEPTH 8984.0 8985.0 8985.5 8986.0 9027.0 9028.0 9034.0 9039.5 9075.0 9076.0 9100.5 9101.0 9103.5 9104.5 9105.5 9106.0 9115.5 9131.5 9133.5 9135.0 9146.5 9147.5 9153.0 9177.5 9183.0 9199.0 $ REMARKS: 8983.5 8984.0 8984.5 8985.5 9026.5 9027.0 9033.0 9039.0 9074.5 9075.0 9099.5 9100.5 9103.0 9103.5 9104.5 9105.5 9115.0 9132.0 9134.0 9134.5 9146.0 9146.5 9152.5 9177.0 9183.0 9199.0 CN/GR Cased Hole. TIED INTO BHC ACOUSTILOG DATED 06-DEC-93. PUMPED 100 BBLS OF SEAWATER PRIOR TO LOGGING. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CHISM OFF, CALIPER & CASING CORRECTED, SALINITY = 0.0 PPM. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. /? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. 1 0.5000 PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - START DEPTH STOP DEPTH 8876.0 9201.0 8890.0 9215.0 PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 (MEASURED DEPTH) BASELINE DEPTH NPHI 8941.0 8941.0 8949.5 8949.5 8950.5 8950.0 8951.5 8951.0 8960.5 8960.5 8961.0 8961.0 8962.0 8961.5 8967.5 8967.0 8979.5 8979.0 8980.0 8980.0 8980.5 8980.5 8981.5 8981.0 8984.0 8983.5 8985.0 8984.0 8985.5 8984.5 8986.0 8985.5 9034.0 9033.0 9039.5 9039.0 9047.0 9046.5 9056.0 9055.0 9069.0 9068.0 9079.5 9078.5 9087.0 9085.5 9100.5 9099.5 9101.0 9100.5 9103.5 9103.0 9104.5 9103.5 9105.5 9104.5 9106.0 9105.5 9115.5 9115.0 9131.5 9132.0 9133.5 9134.0 9135.0 9134.5 9146.5 9146.0 9147.5 9146.5 9153.0 9152.5 9177.5 9177.0 9183.0 9183.0 9199.0 9199.0 EQUIVALENT UNSHIFTED DEPTH $ REMARKS: PASS 1. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN STAT / ? ?MATCH1B. OUT $ : BP EXPLORATION (ALASKA) : B - 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 15 Tape File Start Depth = 9230.000000 Tape File End Depth = 8865.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TP~AILER **** LIS representation code decoding summary: Rep Code: 68 3656 datums Tape Subfile: 2 198 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 8876.0 2418 8890.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 8882.5 8883.0 8884.5 8892.5 8894.0 8932.0 8933.0 8932.5 8933.5 8933.5 8934.0 8936.0 8936.5 8936.5 8937.0 8937.0 8937.5 8938.0 8939.0 8939.0 8940.0 8939.5 8940.5 8940.0 8941.0 8941.0 8941.5 8941.5 8942.5 8942.0 8949.0 8950.0 8951.5 8951.0 8953.0 8960.5 8959.5 8964.0 8974.5 8975.0 8980.0 8981.0 8980.0 8981.5 8982.0 8980.5 8982.5 8981.5 8983.5 8982.5 8984.5 8983.0 8985.0 8984.0 8992.5 8991.5 8993.0 8994.0 8994.5 8994.0 for each run in separate files. STOP DEPTH 9201.0 9215.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 8882.5 8936.5 8937.0 8938.0 8949.0 8949.5 8952.5 8963.0 8973.5 8974.5 8979.5 8980.0 8981.0 8992.0 8992.5 8993.0 899 899 899 899 899 9OO 9O0 901 901 902 902 902 902 903 903 903 903 904 9O5 9O5 9O5 9O5 9O5 905 905 9O5 906 906 907 907 9O8 909 909 909 910 910 911 911 912 912 913 913 913 913 913 913 913 913 913 913 914 914 914 914 914 914 915 915 916 916 5.0 5.5 6.0 6.5 7.5 5.0 6.0 7.0 8.0 6.5 7.5 9.0 9.5 0.5 1.0 9.0 9.5 9.5 0.5 4.0 4.5 5.0 6.5 7.0 7.5 8.5 0.0 1.0 5.5 6.5 8.0 1.0 2.0 2.5 1.0 1.5 0.0 0.5 0.0 0.5 0.5 1.0 1.5 2.5 3.5 4.5 5.0 5.5 6.0 7.0 0.0 1.0 1.5 7.0 8.0 9.0 0.0 3.0 0.0 0.5 8996.0 8996.5 9053.5 9054.5 9059.5 9060.0 9074.5 9075.0 9086.5 9090.0 9119.0 9133.5 9134.5 9135.0 9135.5 9136.0 9140.0 9141.0 9146.5 9152.0 9159.0 9160.0 8994.0 8994.5 8995.5 9004.5 9005.0 9016.0 9016.5 9025.0 9025.5 9027.0 9028.0 9029.0 9030.0 9038.0 9039.0 9049.0 9049.5 9053.0 9053.5 9055.0 9056.0 9056.5 9057.0 9089.5 9090.0 9091.0 9099.5 9100.5 9109.0 9110.0 9119.5 9120.5 9130.5 9131.5 9132.0 9132.5 9134.5 9135.0 9135.5 9136.0 9136.5 9139.5 9140.0 9147.0 9147.5 9149.0 9170.0 9182.5 9183.0 9185.0 9189.0 9189.5 9190.0 9191.0 9192.0 9193 .0 9193 .5 9195.0 9195.5 9201.5 9202.5 9203 .0 9204.5 9205.0 9207.5 9209.0 9210.0 9211.5 9212.5 9217.5 9219.5 9220.0 $ REMARKS: 9182.0 9183.0 9189.0 9189.5 9190.0 9191.0 9191.5 9192.5 9193.5 9195.0 9196.0 9205.0 9205.5 9169.0 9185,0 9201.5 9202.0 9203.0 9204.5 9209.0 9210.5 9211.0 9212.5 9213.0 9217.0 9219.0 9219.5 PASS 2. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH2A. OUT / ? ?MATCH2B. OUT $ CN : BP EXPLORATION WN : B - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units GRCH 2418 68 1 GAPI NPHI 2418 68 1 PU-S FUCT 2418 68 1 CPS NUCT 2418 68 1 CPS (ALASKA) Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 15 Tape File Start Depth = 9230.000000 Tape File End Depth = 8865.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3656 datums Tape Subfile: 3 172 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 8876.0 2418 8890.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 8882.5 for each run in separate files. STOP DEPTH 9201.0 9215.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 8883.0 8883.0 8884.5 8891.5 8892.0 8892.5 8894.0 8931.5 8932.5 8932.5 8933.0 8933.5 8933.5 8934.5 8933.5 8935.0 8934.0 8935.5 8935.5 8936.0 8938.5 8939.0 8949.0 8960.0 8960.5 8961.0 8936.0 8936.5 8937.0 8937.5 8939.0 8940.0 8940.5 8941.0 8943.0 8944.0 8945.5 8946.5 8950.0 8953.5 8960.5 8961.0 8962.5 8964.0 8973.5 8974.0 8978.0 8979.0 8980.0 8981.0 8984.0 8984.5 8993.0 8934.5 8935.0 8936.0 8937.0 8940.0 8941.0 8943.0 8943.5 8945.0 8945.5 8952.5 8962.5 8972.0 8973.0 8977.0 8977.5 8978.5 8979.0 8982.0 8983.0 8991.5 8994.0 8995.0 8995.5 9001.5 9002.0 9003 .5 9004.5 9019.5 9020.0 9023.0 9024.0 9025.5 9026.0 9026.5 9027.5 9030.0 9030.5 9059.0 9060.0 9061.0 9062.0 9064.0 9067.0 9074.0 9075.0 9083.0 9084.0 9093.5 9095.5 9096.0 9097.5 9099.0 9102.0 9102.5 9103 .5 9105.5 9115.0 9115.5 9116.5 9118.5 9119.5 9120.0 9120.5 9125.0 9128.5 9130.0 9130.5 9131.0 9132.0 9132.5 9133 .5 9135.5 9136.5 9137.5 9139.0 9140.0 9147.0 9151.5 9152.0 9152.5 9018.0 9019.0 9022.0 9022.5 9072.5 9073.0 9082.0 9092.0 9096.0 9098.0 9104.5 9115.0 9133.0 9133.5 9134.0 9134.5 9135.5 9136.0 9145.5 8992.0 8993.0 8994.0 9000.0 9001.0 9002.5 9003.0 9021.5 9022.0 9023.5 9024.5 9025.0 9025.5 9028.0 9029.0 9057.5 9058.0 9059.0 9059.5 9062.5 9065.0 9081.0 9081.5 9093.0 9094.0 9097.0 9101.0 9101.5 9102.0 9113.5 9114.5 9117.5 9118.0 9118.5 9119.5 9124.0 9128.0 9129.5 9130.5 9131.0 9131.5 9135.0 9135.5 9138.0 9138.5 9150.0 9150.5 9151.0 9159.0 9165.5 9166.5 9170.5 9176.0 9181.5 9186.0 9188.5 9189.5 9193 .5 9194.0 9195.0 9195.5 9200.0 9200.5 9201.0 9204.5 9205.0 9205.5 9207.0 9208.0 9217.5 $ REMARKS: PASS FUCT, 9158.0 9164.5 9165.0 9174.5 9180.5 9192.5 9193.5 9194.5 9196.0 9200.5 9201.0 9201.5 9205.0 9205.5 9169.0 9185.5 9188.0 9188.5 9204.0 9205.0 9206.5 9209.5 9217.0 , NUCT, & TENS WERE SHIFTED WITH NPHI. /? ?MATCH3A. OUT / ? ?MATCH3B. OUT $ CN : BP EXPLORATION WN : B - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: (ALASKA) Name Tool Code 1 GRCH 2418 68 2 NPHI 2418 68 3 FUCT 2418 68 4 NUCT 2418 68 Samples Units Size 1 GAPI 4 1 PU-S 4 1 CPS 4 1 CPS 4 * DATA RECORD (TYPE# Total Data Records: 0) 1006 BYTES * 15 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 Tape File Start Depth = 9230.000000 Tape File End Depth = 8865.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7312 datums Tape Subfile: 4 168 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: CN WN FN COUN STAT 1, 2, 3 1, 2, 3 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES. $ : BP EXPLORATION (ALASKA) : B - 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH CNAV 68 1 GAPI 4 2 NPHI CNAV 68 1 PU-S 4 3 FUCT CNAV 68 1 CPS 4 4 NUCT CNAV 68 1 CPS 4 4 38 995 99 1 4 38 995 99 1 4 38 995 99 1 4 38 995 99 1 16 * DATA RECORD (TYPE~ 0) 1006 BYTES * Total Data Records: 15 Tape File Start Depth = 9230.000000 Tape File End Depth = 8865.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7312 datums Tape Subfile: 5 38 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8874.0 2418 8888.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 9209.0 9223.0 20-AUG-96 FSYS REV. J001 VER. 1.1 1121 20-AUG-96 9502.0 9218.0 8890.0 9215.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SBAR PCM CCL GR CN $ SWIVEL S INKER BAR PULSE CODE MODULATOR CASING COLLAR LOC. GAMMA RAY COMPENSATED NEUTRON TOOL NUMBER 3913NA 8250EA 8248EA 8220XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : 0.000 9585.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : SEAH20/PROD . FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN) : 0.0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : B - 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 4 42 150 01 1 4 42 636 99 1 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 52 Tape File Start Depth = 9226.000000 Tape File End Depth = 8866.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20282 datums Tape Subfile: 6 Minimum record length: Maximum record length: 129 records... 62 bytes 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8874.0 2418 8888.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 9205.0 9219.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SBAR PCM CCL GR CN $ SWIVEL S INKER BAR PULSE CODE MODULATOR CASING COLLAR LOC. GAMMA RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 20-AUG-96 FSYS REV. J001 VER. 1.1 1139 20-AUG-96 9502.0 9218.0 8890.0 9215.0 1500.0 YES TOOL NUMBER 3913NA 8250EA 8248EA 8220XA 2418XA 0.000 9585.0 0.0 SEAH20/PROD. FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : B - 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GR 2418 68 1 CNC 2418 68 1 CN 2418 68 1 LSN 2418 68 1 SSN 2418 68 1 CCL 2418 68 1 SPD 2418 68 1 TEN 2418 68 1 GAPI 4 PU-S 4 PU-L 4 CPS 4 CPS 4 4 F/MN 4 LB 4 4 42 310 01 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 4 42 150 01 1 4 42 636 99 1 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 51 Tape File Start Depth = 9222.000000 Tape File End Depth = 8870.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19994 datums Tape Subfile: 7 Minimum record length: Maximum record length: 128 records... 62 bytes 1014 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8874.0 2418 8888.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 9205.0 9219.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SBAR PCM CCL GR CN $ SWIVEL S INKER BAR PULSE CODE MODULATOR CASING COLLAR LOC. GAMMA RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 20-AUG-96 FSYS REV. J001 VER. 1.1 1159 20-AUG-96 9502.0 9218.0 8890.0 9215.0 1500.0 YES TOOL NUMBER 3913NA 8250EA 8248EA 8220XA 2418XA 0.000 9585.0 0.0 SEAH20/PROD. FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT P~ATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT R3tTE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS) : 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : B - 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 4 42 150 01 1 4 42 636 99 1 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 51 Tape File Start Depth = 9222.000000 Tape File End Depth = 8870.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 32964 datums Tape Subfile: 8 Minimum record length: Maximum record length: 128 records... 62 bytes 1014 bytes Tape Subfile 9 is type: LIS 96/ 9/23 01 **** REEL TRAILER **** 96/ 9/23 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 23 SEP 96 l:18p Elapsed execution time = 2.80 seconds. SYSTEM RETURN CODE = 0 Run 1' 06 - December - 1993 DIFL/ACICNIGR 8400 9581 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6107.00 R. IORIO SEE REMARKS B- 35 (22-31-11-14) 500292240600 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 28-DEC-93 RUN 2 RUN 3 31 liN 14E 3357 1610 67.65 66.15 37.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 6.750 REMARKS: DIFL/AC/CN/GR 7.625 9585.0 8936.0 LOGS WITNESSED BY: M. WHITLEY & H. HAYWOOD. CIRCULATION STOPPED AT 23:30, 05-DEC-93. GR LOGGED TO 8400'. ALL OTHER LOGS GO TO THE CASING SHOE AT 8936. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, 6.75" BOREHOLE CORRECTION, CHISM FILTERING IS ACTIVE, NO CASING OR SALINITY CORRECTIONS APPLIED. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DIL 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA depth shifted and clipped curves; 0.5000 START DEPTH STOP DEPTH 8936.0 9522.0 8936.0 9552.0 8936.0 9581.0 8936.0 9529.0 GR (MEASURED DEPTH) BASELINE DEPTH 8936.0 8945.5 8964.0 8966.5 8971.5 8972.0 8974.5 8978.0 8985.0 8986.0 8993.0 8996.0 9005.5 9010.5 9012.5 9016.5 9019.5 9023.0 9026.0 9028.0 9029.5 9034.5 9038.5 9040.5 9041.0 9041.5 9045.5 9049.0 9055.5 9056.0 9062.5 9068.5 9069.0 9073.0 9078.5 9079.0 9082.5 9087.0 9090.5 9092.5 EQUIVALENT UNSHIFTED DEPTH - LL8 ILM DT 8936.0 8936.0 8936.0 8944.0 8963.5 8966.0 8972.5 8974.5 8978.5 9029.5 9041.0 all runs merged; 8971.5 8978.0 8985.0 8992.5 9011.5 9019.0 9027.5 NPHI 8936.0 8967.0 8971.5 8971.5 8974.5 8974.5 8996.5 8986.0 9005.5 9011.0 9016.5 9023.0 9026.5 9026.5 9034.0 9038.0 9039.0 9041.5 9049.0 9055.0 9041.0 9056.0 9063.0 9069.0 9069.0 9069.0 9073.0 9078.5 9078.0 9081.0 9087.0 9087.0 9089.0 9092.5 9092.0 9045.5 9056.0 9057.0 9069.0 no case 9095.0 9097.0 9104.0 9105.0 9112.5 9115.5 9130.0 9130.5 9140.0 9140.5 9141.5 9158.0 9160.0 9161.0 9170.5 9171.0 9177.0 9182.0 9183.0 9193.5 9198.5 9201.0 9202.5 9203.0 9211.5 9222.5 9229.5 9236.0 9236.5 9256.0 9257.0 9264.0 9266.0 9268.5 9269.0 9269.5 9270.0 9272.5 9279.0 9283.0 9289.0 9289.5 9301.5 9305.5 9320.0 9328.5 9329.5 9332.5 9333.0 9350.5 9351.5 9357.0 9357.5 9363.5 9384.5 9389.0 9392.0 9395.5 9401.0 9403.0 9095.0 9105.0 9115.5 9140.5 9157.5 9160.0 9171.0 9177.0 9201.0 9203.0 9222.5 9229.5 9237.0 9270.0 9289.5 9334.5 9358.5 9389.5 9403.0 9096.5 9103.5 9114.5 9129.0 9139.5 9160.0 9170.0 9176.0 9193.0 9198.0 9202.0 9222.5 9229.0 9235.5 9256.0 9266.0 9269.5 9272.0 9279.0 9288.5 9305.0 9329.0 9333.5 9350.5 9357.5 9384.5 9395.0 9103.5 9141.5 9160.0 9170.0 9176.5 9182.0 9198.0 9202.5 9212.0 9222.5 9229.0 9268.0 9288.5 9333.0 9357.5 9389.5 9402.0 9405.0 9113.0 9129.5 9140.5 9169.5 9182.0 9201.5 9211.5 9256.5 9263.5 9269.0 9283.0 9290.5 9301.5 9320.0 9329.5 9351.0 9363.5 9391.5 9404.0 9405.5 9405.5 9406.0 9405.5 9411.0 9410.0 9411.5 9411.5 9413.5 9414.0 9420.0 9420.5 9432.0 9431.5 9448.5 9450.0 9451.0 9451.0 9451.0 9456.5 9457.0 9468.0 9473.0 9475.0 9475.5 9475.5 9486.5 9487.0 9487.0 9492.5 9493.0 9500.0 9545.5 9545.5 9564.5 9563.5 9600.0 9600.0 9600.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR i 3 BCS I 3 DIL i 3 2435 i 3 $ REMARKS: 9408.0 9411.5 9449.0 9473.0 9486.0 9600.0 9405.5 9450.0 9468.0 9487.0 9499.5 9600.0 MERGE TOP 8936.0 8936.0 8936.0 8936.0 OPEN HOLE portion of MAIN PASS. MTEM, TEND, & TENS WERE SHIFTED WITH LL8. ILD WAS SHIFTED WITH ILM. FUCT & NUCT WERE SHIFTED WITH NPHI. SP WAS LEFT UNSHIFTED WITH GR. MERGE BASE 9522.0 9552.0 9581.0 9529.0 / ? ?MATCH1. OUT / ? ?MATCH2. OUT / ? ?MATCH3. OUT / ??MATCH4. OUT $ CN : BP EXPLORATION WN : B - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: API API API API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 GR BCS 68 1 GAPI 4 4 67 465 06 6 DT BCS 68 1 US/F 4 4 84 653 71 5 TEND BCS 68 1 LB 4 4 20 789 90 0 TENS BCS 68 1 LB 4 4 20 789 90 0 LL8 DIL 68 1 OHMM 4 4 50 746 76 l ILM DIL 68 1 OHMM 4 4 50 746 76 ~ ILD DIL 68 1 OHMM 4 4 50 746 76 1 SP DIL 68 1 MV 4 4 58 070 90 6 MTEM DIL 68 1 DEGF 4 4 50 746 76 1 NPHI 2435 68 1 PU-S 4 4 98 211 23 1 FUCT 2435 68 1 CPS 4 4 98 211 23 1 NUCT 2435 68 1 CPS 4 4 98 211 23 1 48 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 70 Tape File Start Depth = 9600.000000 Tape File End Depth = 8936.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17278 datums Tape Subfile: 2 291 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 3 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH $ BASELINE CURVE FOR SHIFTS: 0.5000 START DEPTH 8401.0 STOP DEPTH 8936.0 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE portion of MAIN PASS. CN : BP EXPLORATION WN : B - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TEND GR 68 1 LB 3 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 12 * DATA RECORD (TYPE# 0) Total Data Records: 18 1014 BYTES * Tape File Start Depth = 8936.000000 Tape File End Depth = 8400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4293 datums Tape Subfile: 3 45 records... Minimum record length: 38 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 0.2500 VENDOR TOOL CODE START DEPTH GR 8400.0 AC 8900.0 DIFL 8913.0 2435 8902.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9531.0 9561.0 9590.0 9538.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP GR CN PCM AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 06-DEC-93 FSYS REV. J001 VER. 1.1 2330 05-DEC-93 658 06-DEC-93 9585.0 9585.0 8400.0 9581.0 2100.0 TOOL NUMBER 3974XA 3967XA 2806XA 1309XA 2435XA 3506XA 1609ER/1603MA 1503XA 6.750 8936.0 8936.0 LSND 8.70 42.0 10.0 6.6 186.0 2.340 56.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN : BP EXPLORATION WN : B - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.762 3.350 0.000 1.460 0.000 THERMAL SANDSTONE 0.00 6.750 1.5 186.0 46.0 0.0 47.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 CHT AC 68 1 LB 4 5 TTEN AC 68 1 LB 4 6 TEN AC 68 1 LB 4 7 SPD AC 68 1 F/MN 4 8 RFOC DIFL 68 1 OHMM 4 9 RILM DIFL 68 1 OHMM 4 10 RILD DIFL 68 1 OHMM 4 11 CILD DIFL 68 1 MEHO 4 12 VILD DIFL 68 1 MV 4 13 VILM DIFL 68 1 MV 4 14 SP DIFL 68 1 MV 4 15 TEMP DIFL 68 1 DEGF 4 16 CNC 2435 68 1 PU-S 4 17 CNCF 2435 68 1 PU-S 4 18 CN 2435 68 1 PU-L 4 19 LSN 2435 68 1 CPS 4 20 SSN 2435 68 1 CPS 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 34 704 23 6 4 04 522 10 6 4 04 522 10 6 4 53 419 67 0 4 40 467 34 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 8O * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 401 Tape File Start Depth = 9600.000000 Tape File End Depth = 8400.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 118100 datums Tape Subfile: 4 480 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 2 0.2500 VENDOR TOOL CODE START DEPTH GR 8906.0 AC 8906.0 DIFL 8906.0 2435 8903.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9530.0 9560.0 9589.0 9536.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP GR CN PCM AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: 06-DEC-93 FSYS REV. J001 VER. 1.1 2330 05-DEC-93 625 06-DEC-93 9585.0 9585.0 8400.0 9581.0 2100.0 TOOL NUMBER 3974XA 3967XA 2806XA 1309XA 2435XA 3506XA 1609EB/1603MA 1503XA 6.750 8936.0 8936.0 LSND 8.70 42.0 10.0 6.6 186.0 2.340 0.762 3.350 56.0 186.0 46.0 MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN : BP EXPLORATION WN : B - 35 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.000 1.460 0.000 THERMAL SANDSTONE 0.00 6.750 1.5 0.0 47.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 CHT AC 68 1 LB 5 TTEN AC 68 1 LB 6 TEN AC 68 1 LB 7 SPD AC 68 1 F/MN 8 RFOC DIFL 68 1 OHMM 9 RILM DIFL 68 1 OHMM 10 RILD DIFL 68 1 OHMM 11 CILD DIFL 68 1 MMHO 12 VILD DIFL 68 1 MV 13 VILM DIFL 68 1 MV 14 SP DIFL 68 1 MV 15 TEMP DIFL 68 1 DEGF 16 CNC 2435 68 1 PU-S 17 CNCF 2435 68 1 PU-S 18 CN 2435 68 1 PU-L 19 LSN 2435 68 1 CPS 20 SSN 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 34 704 23 6 4 4 04 522 10 6 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 80 * DATA RECORD (TYPE# 0) Total Data Records: 233 1014 BYTES * Tape File Start Depth = 9599.000000 Tape File End Depth = 8903.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 62779 datums Tape Subfile: 5 310 records... Minimum record length: Maximum record length: 44 bytes 1014 bytes Tape Subfile 6 is type: LIS 93/12/27 01 **** REEL TRAILER **** 93/12/23 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 23 DEC 93 4:50p Elapsed execution time = 31.58 seconds. SYSTEM RETURN CODE = 0