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Home My WebLink About200-1262025-0304_Surface_Abandon_PBU_02-30B_ksj Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 03/11/2025 P. I. Supervisor FROM: Kam StJohn SUBJECT: Surface Abandonment - Final Petroleum Inspector PBU 02-30B Hilcorp North Slope LLC PTD 2001260; Sundry 324-366 03/11/2025: Today’s witness was for the final surface abandonment after tubing and tubing-casing annulus were topped off with cement. Refer to Inspector Josh Hunt’s report 3/7/2025 for prior inspection. Teven Dubose was the Hilcorp representative today at PBU 02-30B. I re-verified the marker plate information was correct. The well cutoff was clean and flush and the cement was hard in all sections of the tubing and casing spaces – this was verified by hitting with a hammer. Welding went well and marker plate was fit as per regulations. No follow up needed. Attachments: Photos (5) 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.10 12:14:29 -08'00' 2025-0304_Surface_Abandon_PBU_02-30B_ksj Page 2 of 3 Final Surface Abandonment – PBU 02-30B (PTD 2001260) Photos by AOGCC Inspector K. StJohn 3/11/2025 2025-0304_Surface_Abandon_PBU_02-30B_ksj Page 3 of 3 PBU 02-30B Marker plate welded in place 2025-0307_Surface_Abandon_PBU_02-30B_jh Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 3/9/2025 P. I. Supervisor FROM: Josh Hunt SUBJECT: Surface Abandonment Petroleum Inspector Prudhoe Bay Unit 02-30B Hilcorp North Slope LLC PTD 2001260; Sundry 324-366 3/7/2025: I traveled to PBU 02-30B for a surface abandonment Inspection. I met with Steven Dubose representing Hilcorp North Slope. I inspected the marker plate thickness and verified all information was correct. The location was verified by a location map and well sign. I was informed there is a 135-foot column of fluid still in the tubing and a small void at surface in the IA. They plan to displace the fluid with cement and fill in the IA void today and let it cure tomorrow. Surveys show the tundra being roughly 12 feet down from pad grade, confirmed when digging the cellar out before the cut. I was able to measure the cut off piece and came up with tundra depth being 12 feet 5 inches below pad grade and the cut was right at 16 feet from the pad grade according to surveyor marks on the wellhead which puts the cut approximately 3 feet 7 inches below original tundra grade. I took pictures of the cutoff, marker plate, and measurements confirming the cut depth below tundra. 3/9/2025: I received a call from Hilcorp this morning stating that the cement in PBU 02- 30B was not completely set up. I passed this info along to the other inspectors as I depart the North Slope tomorrow morning. Attachments: Pictures (4) 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.10 10:49:58 -08'00' 2025-0307_Surface_Abandon_PBU_02-30B_jh Page 2 of 3 Surface Abandonment – PBU 02-30B (PTD 2001260) Photos by AOGCC Inspector J. Hunt 3/7/2025 Cut prior to filling tubing and IA with cement. Marker plate with correct information 2025-0307_Surface_Abandon_PBU_02-30B_jh Page 3 of 3 . Overall length of the cut off piece Tundra depth above the cut MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 36 Township: 11N Range: 14E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 12,362 ft MD Lease No.: ADL0028308 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 10-3/4" O.D. Shoe@ 2549 Feet Csg Cut@ Feet Intermediate: 7-5/8" O.D. Shoe@ 8063 Feet Csg Cut@ Feet Liner: 5-1/2" O.D. Shoe@ 9618 Feet Csg Cut@ Feet Liner: 3-1/2" O.D. Shoe@ 11983 Feet Csg Cut@ Feet Tubing: 4-1/2" x 3-1/2" O.D. Tail@ 9442 Feet Tbg Cut@ 6777 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Open Hole Bottom 10,038 ft 6239 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Attachments: Jerry Culpepper Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Remarks: I arrived on location and met with Jerry Culpepper. We went over the current schematic and the plan forward. He informed me that they had already done a preliminary tag and attempted a combination tubing/IA MIT. The test looked good at first but started taking fluid and loosing pressure. I asked about this and was informed they believe they have a leak somewhere in the 7-5/8 inch production casing. I was informed that there is fill (sand?) in the hole at a 10,038 ft MD which serves as the base of the cement plug. For the plug tag, they ran a 1-7/8 inch weight bar (13 feet) followed by a set of oil jars, spangs, and mule shoe assembly on the bottom of the drive down bailer utulizing a flapper type valve inside. This BHA was approximatley 35 feet long and roughly 210 LBS. Tagged the top of cement at 6,239 ft MD and hit the top several times to comfirm a solid tag. The first and second cement samples looked about the same -thick and chunky with some small hard pieces mixed in. They did not attempt another MIT on this well while I was there. They plan to talk with the Hilcorp engineers to determine how to finish this abandonment. December 31, 2024 Josh Hunt Well Bore Plug & Abandonment PBU 02-30B Hilcorp North Slope LLC PTD 2001260; Sundry 324-366 Photos (2) Test Data: Casing Removal: rev. 3-24-2022 2024-1231_Plug_Verification_PBU_02-30B_jh 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.08 13:50:11 -09'00' īŪČϙ«ôŘĖƱèÍťĖĺĲϙ– PBU 02-30B (PTD 2001260) Photos by AOGCC Inspector J. Hunt 12/31/2024 Bailer sample 1 Bailer sample 2 Reviewed By: P.I. Suprv Comm ________ :ZϬϭͬϯϭͬϮϬϮϱ /ŶƐƉĞĐƚEŽ͗ƐƵƐ'ϮϰϭϭϭϱϭϲϬϭϱϵ tĞůůWƌĞƐƐƵƌĞƐ;ƉƐŝͿ͗ ĂƚĞ/ŶƐƉĞĐƚĞĚ͗ϭϭͬϭϱͬϮϬϮϰ /ŶƐƉĞĐƚŽƌ͗'ƵǇŽŽŬ /ĨsĞƌŝĨŝĞĚ͕,Žǁ͍KƚŚĞƌ;ƐƉĞĐŝĨǇŝŶĐŽŵŵĞŶƚƐͿ ^ƵƐƉĞŶƐŝŽŶĂƚĞ͗ϳͬϲͬϮϬϬϳ dƵďŝŶŐ͗Ϭ /͗Ϭ K͗Ϭ KƉĞƌĂƚŽƌ͗,ŝůĐŽƌƉEŽƌƚŚ^ůŽƉĞ͕>> KƉĞƌĂƚŽƌZĞƉ͗<ƌŝƐƚŽƉŚĞƌ'ĞŽǌŽƐ ĂƚĞK'EŽƚŝĨŝĞĚ͗ϭϭͬϭϱͬϮϬϮϰ dǇƉĞŽĨ/ŶƐƉĞĐƚŝŽŶ͗^ƵďƐĞƋƵĞŶƚ tĞůůEĂŵĞ͗WZh,KzhE/dϬϮͲϯϬ WĞƌŵŝƚEƵŵďĞƌ͗ϮϬϬϭϮϲϬ tĞůůŚĞĂĚŽŶĚŝƚŝŽŶ tĞůůŚĞĂĚǁĂƐŝŶŐŽŽĚĐŽŶĚŝƚŝŽŶǁŝƚŚŶŽƐŝŐŶƐŽĨůĞĂŬŝŶŐ͘ ^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞŽŶĚŝƚŝŽŶ ŽǀĞƌĞĚŝŶƐŶŽǁͬŝĐĞ͘ƵƌƌĞŶƚůǇĂĚƌŝůůŝŶŐƐĐĂĨĨŽůĚŝŶƉƌŽƚĞĐƚŝŶŐƚŚĞǁĞůů͘KŶĐĞƌĞŵŽǀĞĚĂǁĞůůͲŐƵĂƌĚŽƌĂǁĞůůŚŽƵƐĞƐŚŽƵůĚ ďĞƉƵƚŝŶƉůĂĐĞƚŽƉƌŽƚĞĐƚƚŚĞǁĞůů͘ ŽŶĚŝƚŝŽŶŽĨĞůůĂƌ ŽǀĞƌĞĚŝŶƐŶŽǁͬŝĐĞ͘ ŽŵŵĞŶƚƐ /ŶƐƉĞĐƚĞĚĚƵĞƚŽ,ŝůĐŽƌƉŶŽƚďĞŝŶŐĂďůĞƚŽŐĞƚƚŚĞǁĞůůƉůƵŐŐĞĚĂŶĚĂďĂŶĚŽŶĞĚďĞĨŽƌĞƚŚĞĞŶĚŽĨƚŚĞǇĞĂƌ͘dŚĞǁĞůůĂŶĚ ƐƵƌƌŽƵŶĚŝŶŐĂƌĞĂƐŚŽƵůĚďĞƌĞŝŶƐƉĞĐƚĞĚǁŚĞŶƚŚĞĂƌĞĂŝƐĐůĞĂƌŽĨƐŶŽǁͬŝĐĞ͘dŚĞǁĞůůůŽĐĂƚŝŽŶǁĂƐǀĞƌŝĨŝĞĚďǇƉĂĚŵĂƉ͘ ^ƵƉĞƌǀŝƐŽƌŽŵŵĞŶƚƐ WŚŽƚŽƐ;ϱͿĂƚƚĂĐŚĞĚ ^ƵƐƉĞŶƐŝŽŶƉƉƌŽǀĂů͗ŽŵƉůĞƚŝŽŶZĞƉŽƌƚ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚ͍ KĨĨƐŚŽƌĞ͍ &ůƵŝĚŝŶĞůůĂƌ͍ tĞůůďŽƌĞŝĂŐƌĂŵǀĂŝů͍ WŚŽƚŽƐdĂŬĞŶ͍ sZWůƵŐ;ƐͿ/ŶƐƚĂůůĞĚ͍ Ws/ŶƐƚĂůůĞĚ͍ &ƌŝĚĂǇ͕:ĂŶƵĂƌǇϯϭ͕ϮϬϮϱ 9 9 9 9 9 9 9 9 9 9 9 2024-1115_Suspend_PBU_02-30B_photos_gc Page 1 of 3 Suspended Well Inspection – PBU 02-30B PTD 2001260 AOGCC Inspection Rpt # susGDC241115160159 Photos by AOGCC Inspector G. Cook 11/15/2024 2024-1115_Suspend_PBU_02-30B_photos_gc Page 2 of 3 Tubing pressure gauge IA pressure gauge 2024-1115_Suspend_PBU_02-30B_photos_gc Page 3 of 3 OA pressure gauge 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 02-30B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-126 50-029-22202-02-00 12362 Conductor Surface Intermediate Liner Liner 8910 80 2521 8037 1721 2548 6292 20" 10-3/4" 7-5/8" 5- 1/ 2" 3- 1/ 2" 5310 28 - 108 28- 2549 26 - 8063 7897- 9618 9435- 11983 29 - 109 28- 2354 26 - 6768 6624- 8301 8119- 8905 11416 470 2090 4790 6280 10530 6292 1490 3580 6890 7740 10160 10350 - 11900 4-1/2" 12.6# x 3-1/2" 9. 3# 13-CR x L-80 25 - 6264 , 6777 - 9442 8899 - 8902 Structural 3-1/2" Baker SABL-3 , 9387 , 8071 No SSSV 9387 8071 Bo York Operations Manager Ryan Holt Ryan.Holt@hilcorp.com (907) 564-5102 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028308 25 - 5289 , 5689 - 8126 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.12.17 16:31:58 - 09'00' Bo York (1248) By Grace Christianson at 10:26 am, Dec 18, 2024 RBDMS JSB 122624 WCB 2-6-2025 DSR-12/20/24 ACTIVITYDATE SUMMARY 11/10/2024 ***CONTINUED FROM 11/9/24 WSR*** (Plug and abandonment - In progess) MADE MULTIPLE ATTEMPTS TO DRIFT INTO TUBING STUB @ 6,777' MD ***WELL LEFT S/I ON DEPARTURE*** 11/14/2024 T/I/O = 110/VAC/VAC. Temp = SI. Suspended well inspection (pre-state). Dryhole tree installed. No visable leaks, site clean. Secured well sign around tree. SV = C. MV = O. IA, OA = OTG. 16:30 11/15/2024 T/I/O = 0/0/0. Temp = SI. AOGCC Suspended well insp (Witnessed by Guy Cook). Dry hole tree installed, drill scaffold around well, well house removed. Well has propper identification sign. Daily Report of Well Operations PBU 02-30B RESERVOIR AB SUSPENDED STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 02-30B JBR 11/25/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:3 Tested with 3 1/2" and 2 7/8" test joints, B1 and C-15 Valves were greased and passed retest, B6 valve was changed out and passed. Pre-Charge Bottles = 1@950psi, 1@975psi, 10@1000psi, 2@1025psi, 1@1050psi and 1@1100psi. Control System Response Time: Annular Preventer 9/15. Test Results TEST DATA Rig Rep:R. Coyne / R. FletcherOperator:Hilcorp North Slope, LLC Operator Rep:J. Perl / D. Johnson Rig Owner/Rig No.:Nabors CDR2AC PTD#:2001260 DATE:9/8/2024 Type Operation:WRKOV Annular: 250/3000Type Test:WKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopBDB240909145239 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 23.8 MASP: 2420 Sundry No: 324-366 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 12 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2 3/8"P Annular Preventer 2 7.06"/13 5/8"P #1 Rams 1 2 3/8"P #2 Rams 1 2 3/8"P #3 Rams 1 2 7/8"x5"P #4 Rams 1 Blind/Shear P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 1 2 1/16"FP Kill Line Valves 2 2 1/16"P Check Valve 0 NA BOP Misc 1 2 1/16"FP System Pressure P3000 Pressure After Closure P1300 200 PSI Attained P49 Full Pressure Attained P165 Blind Switch Covers:PYes Bottle precharge P Nitgn Btls# &psi (avg)P10@2025 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 1 P Annular Preventer P9 #1 Rams P2 #2 Rams P2 #3 Rams P7 #4 Rams P12 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9999 9 9 9 9 9 FP FP FP 3 B1 and C-15 Valves were greased and passed retest B6 valve was changed out and passed CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20240709 0947 PTD 200-126 Response to abandonment questions PBU 02-30B Date:Tuesday, July 9, 2024 2:36:29 PM Attachments:image001.png From: David Bjork <david.bjork@hilcorp.com> Sent: Tuesday, July 9, 2024 9:47 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL] PTD 200-123 PBU 02-30B Abandonment Questions Thanks Mel, Responses in red below, happy to discuss in person or give me a call. Thanks, Dave From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, July 5, 2024 3:43 PM To: David Bjork <david.bjork@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: [EXTERNAL] PTD 200-123 PBU 02-30B Abandonment Questions Dave, Please help me clarify steps 7 and 8 under ‘Rig’. 7. RIH and recover coil tubing and milling assembly. With an overshot assembly? That is correct. 8. RIH with packoff overshot and engage fish. What is Hilcorp’s contingency if you cannot drift past the tubing cut at 9360’ MD? If you cannot, will you contact AOGCC to discuss the plan forward? If unable to drift we will further evaluate but more than likely start recovering the tubing to the cut. Absolutely will discuss the plan forward and any substantive changes to the sundried procedure. Many things I must either research myself or Hilcorp can provide to me, to assure this reservoir abandonment has an adequate length of cement across all annuli within the confining zones. Questions follow: 1. How did the cement job go on the 5-1/2” liner? I would characterize the cement job as good, pre-cementing conditioning got up to 6bpm while cement was batched up. a. Good returns? Returns are not noted in the 9/20/2000 summary but 5bbls cement was circulated off the top after the liner job. b. Plug bumped? Plugs bumped on schedule. c. Cement returns to surface? Not noted in the IADC or daily ops reports, but cement was circulated off the top after releasing the liner running tools. d. Is the 5-1/2” shoe set at TSAG? Correct, TSAG is 9612’ 2. Is the 3-1/2” x 5-1/2” liner lap cemented? 10/08/2000- yes a. Is the 5-1/2” shoe set at TSAG? Correct, TSAG is 9612’ 3. There will be no cement between the 3-1/2” liner hanger and thethe 5-1/2” x 3-1/2” production packer. Correct, the dead space between the packer tailpipe and liner top will not be directly cemented, the inside will be fully cemented. Will cement above the production packer at 9387’ MD assure reservoir fluids remain in place? Cement will provide adequate overbalance to the reservoir. 4. The 5-1/2” x 3-1/2” packer set at 9387’ MD will the first place you have cement across all annuli (if 5-1/2” liner cement job went well). Is that 5-1/2” x 3-1/2” packer set in the PB oil pool confining zones and are there significant confining zones above this packer? Above the packer setting depth is the HRZ/Colville mudstone, note attachment below. Hilcorp is laying in cement in the 4-1/2” x 3-1/2” tubing but does not discuss assurance that fluids will U-tube to the 3-1/2” x 5-1/2” annulus. What is that assurace? No assurance other than fluid density differences and the tubing is open on top and cut/punched on bottom, and additional cement volumes. A cement retainer would be optimal, but it will not fit thru the stuck eclipse patch and inflates have been problematic lately. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email ortelephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by thecompany in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 02-30B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-126 50-029-22202-02-00 ADL 0028308 12362 Conductor Surface Intermediate Liner Liner 8910 80 2521 8037 1721 2548 6292 20" 10-3/4" 7-5/8" 5- 1/ 2" 3- 1/ 2" 5310 28 - 108 28- 2549 26 - 8063 7897- 9618 9435- 11983 3300 29 - 109 28- 2354 26 - 6768 6624- 8301 8119- 8905 11416 470 2090 4790 6280 10530 6292 1490 3580 6890 7740 10160 10350 - 11900 4-1/2" 12.6# x 3-1/2" 9. 3# 13-CR x L-80 25 - 6264 , 6777 - 94428899 - 8902 Structural 3-1/2" Baker SABL-3 No SSSV 9387 8071 Date: Bo York Operations Manager Dave Bjork David.Bjork @hilcorp.com 907.564.4672 PRUDHOE BAY June - July 2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:20 pm, Jun 24, 2024 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.06.18 15:08:37 - 08'00' Eric Dickerman (4002) 2420 -mgr Abandon MGR09JUL24 10-407 * BOPE test to 3500 psi. Annular to 3000 psi. * AOGCC to witness reservoir abandonment plugs. Slickline tag TOC ~ 6300' MD, pressure test to 2500 psi. * AOGCC to witness cement in all annuli at surface before grouting. *Photo document cemented annuli. *Photo document welded plate in place. DSR-6/25/24SFD 6/26/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.10 14:43:10 -08'00'07/10/24 RBDMS JSB 071624 Well: PBU 02-30B PTD #200-126 Well Name:PBU 02-30B API Number:50-733-22202-02 Current Status:Shut-In Producer Rig: Estimated Start Date:June - July 2024 Estimated Duration:1month Regulatory Contact:Carrie Janowski 564-5179 Reg.Approval Req’d?Yes - 403 First Call Engineer:Dave Bjork 907 440-0331 (C) Second Call Engineer:Oliver Sternicki 907-564-4891 (O) Current Bottom Hole Pressure (est):3300 psi @ 8800’ ssTVD (est.) Maximum Expected BHP:3300 psi Maximum Potential Surface Pressure:2420 psi Gas Column Gradient (0.1 psi/ft) History Drilled and completed in 1991 as an oil well. The well was rotary sidetracked in 1997 and again in 2000. A rig workover was attempted in 2007 but collapsed 7-5/8” casing was encountered @ 6353’ MD and the well was suspended. Service coil attempted to mill thru the CIBP and drift to the top of the sand plug but left tools in the hole above the tubing stub. A rig will be required to restore continuity before final abandonment. Current Status The tubing is cut and punched just above the production packer. Tubing is also cut at 6777’ MD. A 7-5/8” EZSV is set @ 6292’ MD above the collapsed 7-5/8” casing (6353’ MD). A PC leak exists (most likely at the collapsed casing @ 6353’ MD) with a LLR of 5 bpm/650 psi. A 2.7” pilot hole has been milled thru the CIBP. The milling BHA and 10ft of 1-3/4” coil tubing is at 6,518ft. A sand plug isolates the Ivishak perfs from the cretaceous leak above. Objective Plug and abandon the well to surface. 50-029-22202-02-00 SFD See attached email for description of current status of cement in OH x Liner(s) and liner laps. - mgr Well: PBU 02-30B PTD #200-126 Fullbore 1. Circ out wellbore to 9.8ppg brine and establish loss rate. Well Support 2. Set and test CTS plug to 3,500-psi. 3. Pull wellhouse Rig 1. MIRU CDR2 2. Test BOPE to 3,500-psi and annular to 3,000-psi. 4-1/2” and 3-1/2” test joints. 3. Pull tubing hanger and 3-1/2” kill string. 4. PU DP and fishing BHA to burn over the CIBP at 6292ft. POOH SBDP 5. RIH to recover CIBP. POOH SBDP 6. RIH with taper mill and string mill assembly, open up casing restrictions to 6”. POOH SBDP 7. RIH and recover coil tubing and milling assembly. POOH SBDP 8. RIH with packoff overshot and engage fish, RU SL and drift to top of sand plug with 2” OD assembly. If successful POOH LDDP RIH with 3-1/2” overshot and kill string. 9. RDMO Coiled Tubing 10. MU 2” cementing nozzle and RIH to top of sand @ 10,038’ MD. 11. RU cementers and lay cement in 3-1/2” liner/tubing from top of sand up to ~6300’ MD; take returns from the CT x Tbg backside: ¾104 bbls 12-15.8 ppg Class G cement i. Lay in @ 1:1 for 3-1/2” tubing (1 bpm = 115 fpm pulling speed) to chemical cut @ 9360’ MD ii. Lay in @ 1:1 for 3-1/2” tubing plus 5-1/2” IA volume (1 bpm – 50 fpm pulling speed) to top of 5-1/2” @ 7897’ MD iii. Lay in @ 1:1 for 4-1/2” tubing plus 7-5/8” IA volume (1 bpm = 24 fpm pulling speed) to top of 4-1/2” tubing @ 6777’ MD iv. Lay in @ 1:1 for 7-5/8” casing volume (1 bpm = 22 fpm pulling speed) to ~6300’ MD. v. Park nozzle, SI returns and squeeze ~10 bbls of cement into PC leak ¾POOH @ 80% circulating any excess cement in killstring OOH. ¾FP from 2200’ MD to surface. ¾Verify circulation down tubing and out IA before RDMO. Volumes: ¾3-1/2” Liner & Tubing from 4-1/2” XO @ 7831’ MD to top of sand @ 10,038’ MD: 2207’ x 0.0087 bpf =19 bbls 4-1/2” tubing from top of cut @ 6777’ MD to 3-1/2” XO @ 7831’ MD: 1054’ x 0.0152 bpf =16 bbls ¾IA from top of 5-1/2” liner @ 7897’ MD to production packer @ 9387’ MD: 1390’ x 0.011 bpf =17 bbls ¾IA from 4-1/2” XO @ 7831’ MD to top of 5-1/2” liner @ 7897’ MD: 66’ x 0.034 bpf =2 bbls ¾IA from top of 4-1/2” tubing cut @ 6777’ MD to 4-1/2” XO @ 7831’ MD: 1054’ x 0.026 bpf =28 bbls 24 hour notice for AOGCC opportunity to witness. -mgr 1490' - mgr Well: PBU 02-30B PTD #200-126 ¾7-5/8” casing from 6300’ MD to top of 4-1/2” tubing cut @ 6777: 477’ x 0.0459 bpf =22 bbls Total cement: 104 bbls Cement Design Parameters: ¾SBHT: 179 deg F @ 8800’ TVD ¾Thickening time: 8 hours ¾Fluid Loss: As required for through-CT pumping application Slickline 12. Tag TOC (AOGCC Witnessed) Fullbore 13. CMIT-TxIA to 2500 psi (AOGCC Witnessed) ~ 6300' MD 24 hour notice to AOGCC. - mgr Well: PBU 02-30B PTD #200-126 Fullbore 14. RU cementers and pump TxIA cement plug as follows: ¾5 bbls MeOH ¾5 bbls FW ¾258 bbls 14-15.8 ppg Class G cement (8 bbls excess) ¾2 bbls FW ¾Foam wiper ball ¾16 bbls 9.8 ppg brine Note: Intent is to cement the IA from the bottom of the killstring to surface, and the killstring from 2000’ MD down to the killstring tubing tail. Note if good cement is returned from the IA. Volumes: ¾IA from surface to killstring tail @ 6265’ MD: 6265’ x 0.034 =213 bbls ¾3-1/2” tubing from 2000’ MD to killstring tail @ 6265’ MD: 4265’ x 0.0087 bpf = 37 bbls Total Cement: 250 bbls Displacement: ¾3-1/2” tubing surface to 2000’ MD: 2000’ x .0087 bpf =18 bbls Cement Design Parameters: ¾SBHT: 80 deg F @ 4,400’ MD ¾Thickening time: 4 hours ¾Fluid Loss: No Fluid Loss additives required Wells Support 15. ND tree, install dryhole tree for final cementing. E-line 16. Perforate 3-1/2” tubing, cement, and 7-5/8” casing @ ~1500 – 1510’ MD w/ 2-1/2” BH HMX guns (or similar), 6 spf, 60 deg phase. Fullbore 17. Circulate crude out of OA: ¾5 bbls MeOH ¾73 bbls FW or 9.8 ppg brine (can forgo the brine if going right into cementing – brine is only to FP the TxOA) Well: PBU 02-30B PTD #200-126 Fullbore 18. RU cementers and pump TxOA cement plug surface-to-surface as follows: ¾5 bbls MeOH ¾30 bbls hot FW + surfactant (160 deg F) ¾5 bbls FW ¾78 bbls 14-15.8 ppg Class G or Arctic Set cement (5 bbls excess) Volumes: ¾OA from surface to 1500’ MD: 1500’ x 0.0397 bpf =60 bbls ¾3-1/2” tubing from surface to 1500’ MD: 1500’ x 0.0087 bpf =13 bbls Total cement: 73 bbls Cement Design Parameters: ¾SBHT: 10 deg F @ 800’ MD ¾Thickening time: 3 hours ¾Fluid Loss: No Fluid Loss additives required Wells Support 19. Excavate and install shoring box. 20. Cut off all casings 3’ below original tundra level. 21. AOGCC witness of TOCs before top-jobbing with cement. 22. Top job of cement voids in all annuli. 23. Bead-weld ¼” thick steel marker cap on the 20” conductor. 24. AOGCC witness of installed marker cap before backfilling. 25. Remove shoring box and backfill. Marker cap as follows: Hilcorp North Slope, LLC PTD#: 200-126 PBU 02-30B API#: 50-029-22202-02 Attachments: 1. Current Schematic 2. Proposed Schematic 3. CDR2 BOP stack 4. Sundry Change Form -00 SFD Photo document welded plate install. - mgr Photo document cemented annuli. - mgr Well: PBU 02-30B PTD #200-126 Current Schematic: OA Shoe Cemented by downsqueeze ca. 2003: ~2000’ – 2558’ MD Per Hilcorp email 09-July-2024: 5-1/2" fully cemented. 3-1/2" x 5-1/2" liner lap fully cemented. 5-1/2" shoe set in TSAG. - mgr Well: PBU 02-30B PTD #200-126 Proposed Schematic: TxOA Cement Plug: Surface to perfs @ 1500’ TxIA Cement Plug: IA: Surface to killstring tail @ 6,265’ MD Tbg: ~2000’ MD to killstring tail @ 6,265’ MD Reservoir & TxIA Cement Plug: Laid in with CT from top of sand @ 10,038’ MD to ~6300’ MD CementedHRZ/Coleville Mudstones above 9387' MD - mgr Uncemented Shoe set in TSAG. - mgr Per Hilcorp email 09-July-2024: 5-1/2" annulus fully cemented. 3-1/2" x 5-1/2" liner lap fully cemented. 5-1/2" shoe set in TSAG. - mgr Well: PBU 02-30B PTD #200-126 CDR2 BOP Stack Well: PBU 02-30B PTD #200-126 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20240508 1415 PTD (200-126) PBU 02-30B Suspended Well Inspection Date:Wednesday, May 8, 2024 2:25:26 PM Oliver, No suspended well inspection required on PBU 02-30B if P&A’d in the 2024 calendar year. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Dave Roby From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, May 7, 2024 1:46 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: V-109 (PTD# 202202), 02-30B ( PTD# 200126) SU inspections Mel, Got a couple questions about SU well inspection on wells we are P&Aing this year, V-109 (PTD# 202202) and 02-30B( PTD# 200126). V-109 was suspended last year on 11/29/2023 meaning that we need to get an inspection by 11/29/2024. Can we forego this since we are P&Aing the well by the end of the year? 02-30B was originally suspended on 7/6/2007, the last renewal was 10/28/2015. Under the old regulations the next renewal submission is 8/28/2025. The last inspection on this well was 5/26/2019, a little early on the 5-year cycle due to the 24 month window for inspecting in the old regs. With the change over to the new SU regs this one wouldn’t necessarily need to be inspected until sometime in the summer of 2025, correct? By that point it would be ~6 years since the last inspection, not sure if that matters? Since we are P&Aing the well this year is it necessary to get an inspection this summer or is it really due next summer and it shouldn’t matter? Thanks Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 02-30B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-126 50-029-22202-02-00 ADL 0028308 12362 Conductor Surface Intermediate Liner Liner 8910 80 2521 8037 1721 2548 6292 20" 10-3/4" 7-5/8" 5- 1/ 2" 3- 1/ 2" 5310 28 - 108 28- 2549 26 - 8063 7897- 9618 9435- 11983 2420 29 - 109 28- 2354 26 - 6768 6624- 8301 8119- 8905 11416 470 2090 4790 6280 10530 6292 1490 3580 6890 7740 10160 10350 - 11900 4-1/2" 12.6# x 3-1/2" 9. 3# 13-CR x L-80 25 - 6264 , 6777 - 94428899 - 8902 Structural 3-1/2" Baker SABL-3 Packer No SSSV 9387 , 8071 Date: Bo York Operations Manager Aras Worthington Aras.Worthington@hilcorp.com 907.564.4763 PRUDHOE BAY 2/17/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 12:16 pm, Feb 02, 2023 323-069 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.02 10:47:15 -09'00' SFD 2/6/2023 * AOGCC to confirm TOC in all annuli before welding marker plate. * Photo document TOC in all annuli before welding plate and then with welded plate in place. DSR-2/3/23 10-407 * AOGCC to witness slick line tag (TOC ~6,300' MD and pressure test (to 2500 psi) of reservoir abandonment plug. MGR08FEB23GCW 02/10/23 JLC 2/10/2023 2/10/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.10 12:06:58 -09'00' RBDMS JSB 021423 P&A Sundry Well: PBU 02-30B PTD #200-126 Well Name:PBU 02-30B API Number:50-733-22202-02 Current Status:Shut-In Producer Rig:SL, EL, FB, CT Estimated Start Date:February 2023 Estimated Duration:1month Regulatory Contact:Carrie Janowski 564-5179 Reg.Approval Req’d?Yes - 403 First Call Engineer:Aras Worthington 907-564-4763 (O) Second Call Engineer:Oliver Sternicki 907-564-4891 (O) Current Bottom Hole Pressure (est):3300 psi @ 8800’ ssTVD (est.) Maximum Expected BHP:3300 psi Maximum Potential Surface Pressure:2420 psi Gas Column Gradient (0.1 psi/ft) History Drilled and completed in 1991 as an oil well. The well was rotary sidetracked in 1997 and again in 2000. A rig workover was attempted in 2007 but collapsed 7-5/8” casing was encountered @ 6353’ MD and the well was suspended. Current Status The tubing is cut and punched just above the production packer. Tubing is also cut at 6777’ MD. A 7-5/8” EZSV is set @ 6292’ MD above the collapsed 7-5/8” casing (6353’ MD). A PC leak exists (most likely at the collapsed casing @ 6353’ MD) with a LLR of 5 bpm/650 psi. A sand plug isolates the Ivishak perfs from the cretaceous leak above. A subsidence drift in 2022 encountered hydrates just below the christmas tree. Objective Plug and abandon the well to surface. -00 DLB P&A Sundry Well: PBU 02-30B PTD #200-126 Coiled Tubing 1. Jet ice with MeOH to clear hydrates down to ~2200’ MD. 2. MU 2.70” Mill and mill through EZSV @ 6292’ MD. 3. POOH and LD mill and motor. 4. MU 2” cementing nozzle and RIH to top of sand @ 10,038’ MD. 5. RU cementers and lay cement in 3-1/2” liner/tubing from top of sand up to ~6300’ MD; take returns from the CT x Tbg backside: ¾104 bbls 12-15.8 ppg Class G cement i. Lay in @ 1:1 for 3-1/2” tubing (1 bpm = 115 fpm pulling speed) to chemical cut @ 9360’ MD ii. Lay in @ 1:1 for 3-1/2” tubing plus 5-1/2” IA volume (1 bpm – 50 fpm pulling speed) to top of 5-1/2” @ 7897’ MD iii. Lay in @ 1:1 for 4-1/2” tubing plus 7-5/8” IA volume (1 bpm = 24 fpm pulling speed) to top of 4-1/2” tubing @ 6777’ MD iv. Lay in @ 1:1 for 7-5/8” casing volume (1 bpm = 22 fpm pulling speed) to ~6300’ MD. v. Park nozzle, SI returns and squeeze ~10 bbls of cement into PC leak ¾POOH @ 80% circulating any excess cement in killstring OOH. ¾FP from 2200’ MD to surface. ¾Verify circulation down tubing and out IA before RDMO. Volumes: ¾3-1/2” Liner & Tubing from 4-1/2” XO @ 7831’ MD to top of sand @ 10,038’ MD: 2207’ x 0.0087 bpf =19 bbls 4-1/2” tubing from top of cut @ 6777’ MD to 3-1/2” XO @ 7831’ MD: 1054’ x 0.0152 bpf =16 bbls ¾IA from top of 5-1/2” liner @ 7897’ MD to production packer @ 9387’ MD: 1390’ x 0.011 bpf =17 bbls ¾IA from 4-1/2” XO @ 7831’ MD to top of 5-1/2” liner @ 7897’ MD: 66’ x 0.034 bpf =2 bbls ¾IA from top of 4-1/2” tubing cut @ 6777’ MD to 4-1/2” XO @ 7831’ MD: 1054’ x 0.026 bpf =28 bbls ¾7-5/8” casing from 6300’ MD to top of 4-1/2” tubing cut @ 6777: 477’ x 0.0459 bpf =22 bbls Total cement: 104 bbls Cement Design Parameters: ¾SBHT: 179 deg F @ 8800’ TVD ¾Thickening time: 8 hours ¾Fluid Loss: As required for through-CT pumping application Slickline 6. Tag TOC (AOGCC Witnessed) Fullbore 7. CMIT-TxIA to 2500 psi (AOGCC Witnessed) P&A Sundry Well: PBU 02-30B PTD #200-126 Fullbore 8. RU cementers and pump TxIA cement plug as follows: ¾5 bbls MeOH ¾5 bbls FW ¾258 bbls 14-15.8 ppg Class G cement (8 bbls excess) ¾2 bbls FW ¾Foam wiper ball ¾16 bbls 9.8 ppg brine Note: Intent is to cement the IA from the bottom of the killstring to surface, and the killstring from 2000’ MD down to the killstring tubing tail. Note if good cement is returned from the IA. Volumes: ¾IA from surface to killstring tail @ 6265’ MD: 6265’ x 0.034 =213 bbls ¾3-1/2” tubing from 2000’ MD to killstring tail @ 6265’ MD: 4265’ x 0.0087 bpf = 37 bbls Total Cement: 250 bbls Displacement: ¾3-1/2” tubing surface to 2000’ MD: 2000’ x .0087 bpf =18 bbls Cement Design Parameters: ¾SBHT: 80 deg F @ 4,400’ MD ¾Thickening time: 4 hours ¾Fluid Loss: No Fluid Loss additives required Wells Support 9. ND tree, install dryhole tree for final cementing. E-line 10. Perforate 3-1/2” tubing, cement, and 7-5/8” casing @ ~1500 – 1510’ MD w/ 2-1/2” BH HMX guns (or similar), 6 spf, 60 deg phase. Fullbore 11. Circulate crude out of OA: ¾5 bbls MeOH ¾73 bbls FW or 9.8 ppg brine (can forgo the brine if going right into cementing – brine is only to FP the TxOA) P&A Sundry Well: PBU 02-30B PTD #200-126 Fullbore 12. RU cementers and pump TxOA cement plug surface-to-surface as follows: ¾5 bbls MeOH ¾30 bbls hot FW + surfactant (160 deg F) ¾5 bbls FW ¾78 bbls 14-15.8 ppg Class G or Arctic Set cement (5 bbls excess) Volumes: ¾OA from surface to 1500’ MD: 1500’ x 0.0397 bpf =60 bbls ¾3-1/2” tubing from surface to 1500’ MD: 1500’ x 0.0087 bpf =13 bbls Total cement: 73 bbls Cement Design Parameters: ¾SBHT: 10 deg F @ 800’ MD ¾Thickening time: 3 hours ¾Fluid Loss: No Fluid Loss additives required Wells Support 13. Excavate and install shoring box. 14. Cut off all casings 3’ below original tundra level. 15. AOGCC witness of TOCs before top-jobbing with cement. 16. Top job of cement voids in all annuli. 17. Bead-weld ¼” thick steel marker cap on the 20” conductor. 18. AOGCC witness of installed marker cap before backfilling. 19. Remove shoring box and backfill. Marker cap as follows: Hilcorp North Slope, LLC PBU 02-30B PTD#: 200-126 API#: 50-029-22202-02 Attachments: 1. Current Schematic 2. Proposed Schematic Photo document marker in place. -00 SFD 2/6/2023 Photo document TOC. P&A Sundry Well: PBU 02-30B PTD #200-126 Current Schematic: OA Shoe Cemented by downsqueeze ca. 2003: ~2000’ – 2558’ MD P&A Sundry Well: PBU 02-30B PTD #200-126 Proposed Schematic: TxOA Cement Plug: Surface to perfs @ 1500’ TxIA Cement Plug: IA: Surface to killstring tail @ 6,265’ MD Tbg: ~2000’ MD to killstring tail @ 6,265’ MD Reservoir & TxIA Cement Plug: Laid in with CT from top of sand @ 10,038’ MD to ~6300’ MD STAE OF ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS _ 1. Operations Performed raflJ.b�rulll L 1 Lull andon El ate 0 ng 0 Cps Suspend ❑ Plug Perforations Perforate ❑ Fracture Other Stimulate ❑ After Casing ❑ Ch.4A, p =ref ❑ Plug for Redml ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work 5. Permit to Drill Number 200-126 3. Address: P.O. Box 196612 Anchorage, Development El Exploratory C] AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22202-02-00 7. Property Designation (Lease Number): ADL 0283088. Well Name and Number: PBU 02-3013 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Size: MD'. TVD: Buret: Water -Bbl Collapse: Total Depth: measured 12362 feet Plugs measured 6292, 10038 feet true vertical 8910 feet Junk measured 11416 feet Effective Depth: measured 6292 feet Packer measured 9387 feet true vertical 5310 feet Packer true vertical 8071 feet Casing: Length: Size: MD'. TVD: Buret: Water -Bbl Collapse: Structural Tubing Pressure Prior to well operation: Suspended Conductor 80 20" 28-108 28-108 1490 470 Surface 2521 10-3/4" 28-2549 28-2354 3580 Daily Report of Well Operations a 2090 Intermediate 8037 7-5/8" 26-8063 26-6768 6890 IGSTOR ❑ WINJ ❑ WAG ❑ 4790 Liner 1721 5-1/2" 7897-9618 6624-8301 7740 Authorized Name: Lastufka, Joseph N 6280 Liner 2548 3-1/2" 9435-11983 8119-8905 10160 10530 Perforation Depth: Measured depth: None feet True vertical depth: feet 3-1/7'9.3# L-80 / 24-6264/ 24-52881 Tubing (size, gratle, measured and true vertical depth) 4-112" 12.6# x 3-112" 9.2# 13Cr80 8777-9442 5689-8126 Packers and SSSV (type, measured and 3-112" Baker SABL-3 Packer 9387 8071 true vertical depth) 12. Stimulation or cement squeeze summary Intervals treated (measured): Inducing volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Md Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Suspended Subsequent to operation: 14.Attachments (regW.dpaIMMC25.07025.071,3252e3) 15. Well Class after work: Daily Report of Well Operations a Exploratory ❑ Development ® Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ® SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Lastufka, Joseph N Contact Name: Montgomery, Travis J Authorized Title: SI Special Contact Email: Travis.Montgomery0tio.com Authorized Signature: Date: JL9-/Iq Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 X61, *44Vr1"1rq RBDMS�&JUN 25 2019 Submit Original Only T/I/O = LOTO/280/400. Temp = SI. WHPs (Pre AOGCC SU Well Inspection). Dry hole tree. No scaffolding. Wellhead and cellar are free of any signs of leakage. No trash inside or outside of well house. 5/15/2019 SV = C. MV = LOTO. IA, OA = OTG. 16:45 T/1/0 = MV/250/350. Temp = SI. AOGCC Suspended Well Inspection (Reg Compl). Witnessed by Bob Noble. Site clean, all equipment working. Pictures taken. 5/26/2019 MV= LOTO IA, OA = OTG 12:10 Suspended Well Site Inspection Form 5 year Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 02-30B Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 200-126 API Number: 50029222020200 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 7/6/2007 Surface Location: Section: 36 Twsp: 11N Range: 14E Nearest active pad or road: DS -02. West Dock Road Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good, clean gravel active pad raa or iocatlon surface: Location cleanup needed: Pits condition: Surrounding area condition: Water/fluids on pad: Discoloration, Sheens on pa Samples taken: None Photographs taken (# and snow or water: Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: FMC wellhead with double master valves casing valves open to gau• no leaks or drips, master valve locked out Cellar description, condition, fluids: cellar clean, some Ice Rat Hole: N/A Wellhouse or protective bs Well identification sign: Tubing Pressure (or casing Annulus pressures: Wellhead Photos taken (# Work Required: None Operator Rep (name and signature): Ran Hayes AOGCC Inspector: Bob Noble Othe a rs: Inspection Date: 5/26/2019 AOGCC Notice Date: 5/24/2019 Time of arrival: 12:00 PM Time of Departure: 12:10 PM Site access method: Truck T + xih� Yom'. -• - ... �" ,�. •'�• �v' y`F � �d '{N'�.' �f yam{ S :y V ti� x II ' I IIB 11 111 1 or 49 A 40 / ! A • A �°/� ////� k I� I� 15-258 18-040. .� — 12-13 '•,} 18-11 15-43 - - — _ 18-06A L _ 1612A _ 1 G118-17 24 Ll 15-24 15.23 -.FE" _ �^ 15-11C 23 B ,. 18-298 C 18 04 18-29A — IS 24A 15-12APB1 I 18-04A 18-29BPB1 18-24AL1 15-11CPB1 - 02-38 18-04B - 8-24AL2 F 1S-D3C -_ 1 -148 — (_ 'f- 12 _ I15-1 Oj 1531 B is-0'AC _ — 1°-118 ' 18-04BP& C. 18-03 037 i� ,15- 39A 18.29 18-19PB 1 15-12BPE1 r 15-4 02-176 � -ISC L2-11CUK 18-05A 18 19 1G 2F81 _' 15-H 02 1S 02-1SCP81 FE2 8-05 — 18-028 R- SBP 42 178 18APB3' 02-18AP82 18-02A --`18-40PB_ _E — O•-158 02-33�j 18-02A�IE1 02-18 02-37 02-38L1 0-39 02-38 L: L 0-30B x' 02-18APB1 0 1s j*',� I 1E -a1{., 1"-40A 151EGPE7 —0= '° 1'w428 Si _ 02-17 02-MAPBt�, 02_38A 02-39APBI•:. 'E- APE* — Y1115-42 (12-30 PSI C, _ �1E-15 0 -15 A 020 02-37L1 02r'tAPB2 = 07-1R 5-38A 02-1EGPE1 ^ - 0' 3�� -018 ❑ 02-09F 02-39A L' 07-338 V 02 OS C_ 326' 25 39APB4 Tr 07-3 PBI 02 32A 02-090 02-39A 31 0�-330'-33A- 02- .PB2 ^ M -09C 02-29C d-38AP81 •w 0-33APB2 02-28A 1 �`t12-3 83 02-09EPB1 02-09C 02AP8 11 G az-zaar_ s a2 PB -1 D2 o9APBa 02 $1 — 0'-07 �'-'A. G2-Df—.P81 08 02-08 B1 �$1 Qc 0:1_A 02 09AP61. Dz_24E 02A _ � C 07-D8A — - C _33p 32CP81 C.... D_ „5A 07-07A 02-05 02-01 38PB1 02-09A C 07- 34 r? -7 Og81 A 02-27 i- _ 02MM10A °T-� � �D�1`95AL�05-3 B O 07-17 {/ 07- 3C _ 07-34A C 02-10B i 1fl1P 1 07-07B15A I 02-13B OE -38A 05.315AP7 02-fl2 15 �� t L 02-1 - l-29 - 05-38 07-05 02 15AP83✓ 02-148 1 02-05AXX = 02-13 yr 02-14 i� :u _ 02-13� 02-28APB 1 C 02-08C 7, 02-04Ac 02-20B C -�� 2-23A i1 �� ,.f.. — 02 34AP8 � 0<"-34 — i 02-28C - W-,23PB1 U 02-34B , _02-34F{PB1 34� 35 L 07-02B 35 02-25A 02-0 1.— ''. 22-076 02-34 07-18 [ 02-08A—P`_75 02-07APBj DS3 05-3 L 02-08 021078PE2 Li 02-35A L' 07-208 02 07APSI x-040 02-28 _ 07-02A ,-. 02.12E 02-03� 02-07, 0$-Q7PB1 C 07.02 0� 40PE1 1 02-07A 12ADW U 07-07C O 02-355 02-12APB1��L 07-19A C 02-008- 002-19 02-13C -129 02-12A 05-0 IA — TTtff= 4-1/16 FMCSM =I REP LOG: TCP PERF XR== Nota: Refer to Production DB for historical perf data SIZE I SPF 1 ==e OPNSqz I SQZ 2' 4 = Cr =D= AW/SV DEPTH WRRi3;TDN 2- 4 4-1/2- :R -0152 W. 3.958' 20' COLD, 91.5#, 1-40, D =19.124• D = 2.992' Minimum ID = 2.75" @ 72112' 3-1/2" HES X NIPPLE TOP OF WHFSTOCK —� -5/8• CSG. 29.7#. L-80 MOD. D = 6.875' —� ISI 5-1Q' X 31/2' � � 1 = 2.992' AM 5-12' LNR 17#. L-80. D=4.892• I P9iF0RATDN SUMMARY REP LOG: TCP PERF ANGLEATTOP PERF: 76" @ 10350' Nota: Refer to Production DB for historical perf data SIZE I SPF 1 NTE VAL OPNSqz I SHOT SQZ 2' 4 10350-10834 Cr 10/11/00 AW/SV DEPTH WRRi3;TDN 2- 4 10898 -11000 C 10/11100 RRQ'RIC RILL UPPER PATCH / FSH 2' 4 11120 -11239 C 10/11/00 2' 4 11320 -11751 C 10/11/00 2' 4 11850 -11900 C 10111/00 14-12• X 312• XO. D = 3.958• I 2'HES X W,, D=2.75 2' HES X NP, D = 2.75 2' ALES, D= 2.992- MAS I FTMANDRAS 5T MD I TVD IMVI TYPE VLVLATCH FORE DATE 2 7530 6313 3 9148 7706 32 KBMC 35 KGB -2 -LS "OMY —ow BK 1 002 M 0 122/02 02/22/02 "ORDWIL V%LLBORE 706W M PSE PATCH. D = 2240' .0087 904J�7-5B'XS12'BKR ZXP PKR u=aJ175- 1 870•7-5I8'Xs12'BKRHMGHGRD=4.875' CSG MILLOUT VNPDOW (02-308) 8063' - 8088' DATE REV BY I COMMENTS DATE RB/ BY I COMMENTS 08/25/91 ONGINAL COMPLErM 0626/07 RWYPJC CHEM CUT, TBG PURCH FISH 02AMM EG SIDETRACK (02.30A) 0722/07 ?/ PJC DRLG DRAFT CORRECDONS 10/11100 TOG SIOEfRACK (02 -3DB) 0725/07 AW/SV DEPTH WRRi3;TDN 07A6/07 NOES RWO (02-308 SUSPENDED) 06/18/19 JNL/JMD ADD CKB, REF, BF & COND 0623/07 RRQ'RIC RILL UPPER PATCH / FSH 0625/07 SRBIPJC SP RUSHED BTMV SAND PLUG. 5.12• X 31f2' 11416' IHSH-BKRIBP PUSHED TO BTM PRUDHOE BAY UW WELL: 02-30B Pl30dlf No: 2001260 AR No: 50-029-22202-02 SEC. 36, T11 R R14E 5125' FSL & 4506' FEL BP BWbration (Alaska) Date Inspected. 05/26/19 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Inspector: Bob Noble Well Name: PBU 02-30B PTD No.: 2001260 Location Verified? Yes " If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Operator: BPX Oper. Rep: Ryan Hayes Oper. Phone: 907-659-5297 Oper. Email: Suspension Date: 07/06/07 Date AOGCC Notified: 05/24/19 Sundry No.: Well Completion Report Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing N/A Photos Taken? Yes IA 250 OA 350 Of Of ng Surface Up Actions is in good condition with out any leaks or drips. 2 masters that are locked out. Flow line and Flow cross have been removed. IA and OA gauges on them. map was used to verify well location. Cellar looked clean with snow and gravel. Wellhead was protected with a well house. Pad good clean gravel. Phtolos (4) Supw PLS 10/2011 2019-0526 Suspend PBU_02-308_bn Suspended Well Inspection — PBU 02-30B PTD 2001260 Photos by AOGCC Inspector B. Noble 5/24/2019 Y WELL: 02-308 '"%F OWNER Prudhoe Bay Ihel OPERATOR 9P Ezpotation lAkskal tk, API NUMBER 50-029-22202-02.00 SUR. LOCATION NW 1; 4, Sac 36 TQM Rte .. DRILLING PERMIT 200-126 2019-0526_Suspend_PBU 02-30B_bn.docx Page 1 of 2 s v v' 2019-0526_Suspend_PBU 02-30B_bn.docx Page 1 of 2 •l�/l/f 11 t l♦t i i•!1• f l t�E.ttQ 1j1111111141111g4. lll!!lJJJ,1Jj'., I )111111 344 tlt' l l�J��J�1� IIEl1111��1�� ,1//!► !/�lJ! 11t��1� 1Ei�i� 11 �yl��l��)�11! I�iliM1 2019-0526_ Suspend _PBU_02-30B_bn.docx Page 2 of 2 MEMORANDUM TO: Jim Regg �e q 5/7-9/117 P.I. Supervisor (( FROM: Adam Earl Petroleum Inspector Section: 18 Township: Drilling Rig: NA Rig Elevation: Operator Rep: David Wallingford Casing/Tubing Data: Conductor: 117/8" O.D. Shoe@ Surface: 8 5/8" O.D. Shoe@ Intermediate: Csg O.D. Shoe@ Production: 51/2" O.D. Shoe@ Liner: Feet O.D. Shoe@ Tubing: 2 7/8 O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 24, 2019 SUBJECT: Well Bore Plug & Abandonment Lone Creek Unit #3 Plugging Inlet LLC PTD 205-097; Sundry 318-340 12N Range: 11W Meridian: Seward " NA Total Depth: 3025 ft MD Lease No.: CIRI C-061500 Suspend: P&A: X 80 - Feet 700 Feet Feet 3018 Feet Feet 2860 Feet Type Plug Founded on Casing Removal: Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ Feet Csg Cut@ NA Feet Csg Cut@ Feet Tbg Cut@ NA Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Bridge plug 1300 ft MD' 830 ftMD N/A Initial 15 min 30 min 45 min Result Tubing 2060 - 2020 2000 - 59 IA 32 32 32 P OA P Initial 15 min 30 min 45 min Result Tubing 62 59 59 IA 1800 1700 - 1670 " P OA Remarks: I traveled out to Lone Creek #3 to witness pressure tests of the tubing and I/A. David Wallingford was the company representative on the job. My understanding was a COP was set @ 1300' and sliding sleeve just above(1,265') was opened. 10 bbls of cement was displaced down tubing while taking returns up IIA, total displace was 800' of calculated tubing volume. Cement plugs in tubing and IA were not tagged (revised procedur approved 12/11/18 estimated top of cement in tubing and IA was 830 ft MD. This is what was tested against. Attachments: none rev. 11-28-18 2019-0524_Plug_Verification_LoneCk-3_ae STATE OF ALASKA SLASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS • 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Sus Well Inspection Rpt CZ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 200-126 3. Address: P.O.Box 196612 Anchorage, Development a Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22202-02-00 7. Property Designation(Lease Number): ADL 0028308 8. Well Name and Number: PBU 02-30B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 12362 feet Plugs measured 6292/10038 feet measured NOVL2OU 6 1 true vertical 8910 feet Junk 11416 feet iV Effective Depth: measured 6292 feet Packer measured 9387 feet true vertical 5310 feet Packer true vertical 8070.81 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 26-106 26-106 1490 470 Surface 2520 10-3/4"45.5#J-55 29-2549 29-2354 3580 2090 Intermediate 8037 7-5/8"29.7#L-80 26-8063 26-6768 6890 4790 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10350-10834 feet 10898-11000 feet 11120-11239 feet 11320-11751 feet 11850-11900 feet True vertical depth: 8899-8918 feet feet 8913-8910 feet 8910-8902 feet 8902-8902 feet 8901-8902 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED MAR 3 12017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1166 38771 52 400 738 Subsequent to operation: Well Shut-In 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development m Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP Ed SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature YI - e K/ Phone +1 907 564 4424 Date 11/14/16 Form 10-404 Revised 5/2015 r T L -`a. G ' RDDIYIS L t 9 ��/'/� ��J 1 � ��i� Submit Original Only • • Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Drilsite 02 No 30B Field/Pool: Prudhoe Bay Field I Prudhoe Bay Pool Permit#(PTD) 2001260 API Number: 500292220202 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 7/6/2007 Surface Location: Section: 36 Twsp. 11N Range: 14E Nearest active pad or road: West Dock Rd Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Active Pad, Some trash debris behind well house-pick up during inspection Pad or location surface: Flat Gravel Pad Location cleanup needed: None Pits condition: Good - Frozen water, no hydrocarbon residue visible Surrounding area condition: Good , clean Water/fluids on pad: none Discoloration, Sheens on pad, pits or water: none Samples taken: None Access road condition: Good-Gravel Road Photographs taken (#and description): Well house with sign Condition of Wellhead AOGCC requires: 1)a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: FMC Dry hole Tree, FMC Wellhead, Good Conductor No visible leaks Cellar description, condition, fluids Good -gravel cellar, no fluids, no signs of hydrocarbons Rat Hole: N/A Well house or protective barriers: Yes, good well house Well identification sign Yes Tubing Pressure (or casing if no tubing): 0 Annulus pressures IA=200psi , OA=250psi Wellhead Photos taken (#and description) Wellhead, gauges Work Required: None Operator Rep (name and signature): Joshua Stephens AOGCC Inspector: Jeff Jones Other Observers Inspection Date: 10/10/2016 AOGCC Notice tate 10/9/2016 Time of arrival: 8:50am Time of Depart re. 9:00am Site access method Pickup Truck • • 0.2 0.1 0 0.2 Miles 40 bp ••=1.:: . =.18-29 x:18-03 ;15-42A L2-I I CNX 02-18C ;..18-19581 18-056 1'02-17A i 18-19 :I S-I I '02-18CP81 18-028 ;02-188 );02-18A -'02-306 18-05 :(02-I8AP83 02-178 'D'_-ISBPe t ':1d-026 ;15-42 (02-18A PB2 (18-02A 58 I ;'02-168 /02-30 02-338 _338 02-381_1 Legend ;IS-42BP81�02.308 : IREE= 4-1/16"FMC 5M PJC • 02-30D S LANG EES 70: "4-1/2"X3-1/2"CHROME TBG"" WELLHEAD= FMC-5M R j� @ 10321'.PRE-02-30B SDTRK ACTUATOR= BAKER DRAFT SUSPENDED WELLBORE NOT SHOWN BELOW WHIPSTOCK.02-30A KB.BEV= 58.8' P&A'D W/CMT, DO NOT SET BPV.SEE DRLG REPORT BF. ELEV= NA 4-1/2"TBG,12 6#, - 25' ,_ � 1 1, FOR 10/12100.""7-5/8"CSG IS BUCKLED @--6300'*'* KOP Max Angle= 96° @ 11164' 13-CR, 0152 bpf, 25' 1--14-1/2"X 3-1/7 XO,D 3.958" I Datum MD= 10230' 13=3-958- Datum 3-958"Datum TVD= 8800'SS; 20"COND, 72' A 2112' -13-1/2"HES X NP,D=2.75" 91.5#,H-40, \ 6252' -13-1/2"I-ES X NP,D=2.75" D=19.124" I 6265' H3-112"WLEG,D=2.992" 10-3/4"CSG,45.5#,BTRS,D=9.950" H 2558` - GAS LFT MANDRELS 3-1/2"TBG,9.2#,L-80 NSCT XO TO L-80 TCI -j 3449' / ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 7530 6313 32 KBMG °"DMY BK 0 02/22/02 3-112"TBG,9.2#,L-80 TCI,.0087 bpf,D=2.992" -j 6264' 3 9148 7706 35 KGB-2-LS "DM' INT 0 02/22/02 -ORIGINAL WELLBORE 7-5/8"EZSV(07/04/07) -1 6292' i 7066' -ECLIPSE PATCH,D=2.240" a (BOTTOM SECTION) 4-1/2"TBG STUB(07/01/07) H 6777' 4-1/2"TBG,12.64,13-CR,.0152 bpf,D=3.958" --1 7830' ^ - ` 7831' -4-112"X 3-1/2"TBG XO,D=2.992' 7897' -1 BKR TIEBACK SLEEVE,C)=5.750" Minimum ID =2.75" @ 72112' - 3-1/2" HES X NIPPLE 7904' -17-518"X5-1/2"BKR ZXPPKR,D=4.875" 7910' -17-518"X 5-1/2"BKR HMC HGR D=4.875" TOP OF WHIPSTOCK -1 8062' - CSG MLLOUT WINDOW(02-30B)8063'-8088' 7-5/8"CSG,29.7#,L-80 MOD,D=6.875" -{ -8062' / f ' 9346_9348 -j TBG PUNCH(06/25/07) 7 - 9360' -j 1EM CUT(06/26/07) 7-5/8"EZSV RETAIN - 8102' vfl' 9387' -I5-1/2"X 3-1/2"BKRSABL-3 PKR D=2.750" /i 9421' -13-1/2"HES X M19',D=2.750" Ilk 9435' -j BKR TEBA CK S L V,D=5.750" 3-1/2'TBG,9.3#,13-CR,.0087 bpf,D=2.992' -1 9442' 'W 9442" H3-112"WLEG,D=2.992" iv- 5-1/2"X 3-1/2" BKR CPH PKR D=3.000" -1 9441' 0, + --5-1/2"X 3-1/2"BKR HMC HGR,D=3.000" H 9445' 5-1/2"LNR,17#,L-80,D=4.892" -{ 9618' 11‘ 10038' -TOP OF SAND PLUG PERFORAT ON SUMMARYFIEF LOG: TCP FEF (06/25/07) ANGLE AT TOP PERF: 76°@ 10350' Note:Refer to Production DB for historical perf data 11416' FISH-BKR EP SCE SPF ITE RVAL Opn/Sqz SHOT SOZ PUSHED TO BTM 2" 4 10350-10834 C 10/11/00 ((06/25/07) 2" 4 10898- 11000 C 10/11/00 ` 2" 4 11120-11239 C 10/11/00 2" 4 11320-11751 C 10/11/00 ` 2" 4 11850- 11900 C 10/11/00 P610 H 11910' 3-1/2"LNR 9.3#,L-80,.0087 bpf,D=2.992" -1-11983' ; TO - 12362' 41* DATE REV BY COI/I EfTS DATE REV BY COMuETTS PRUDHOE BAY UNIT 08/25/91 ORIGINAL COMPLETION 06/26/07 RRD/PJC CHEM CUT,TBG FUNCH,FISH WELL: 02-30B 02/04/97 RIG SIDETRACK (02-30A) 07/22/07 7/PJC DRLG DRAFT CORRECTIONS PERMT No:"2001260 10/11/00 RIG SIDETRACK (02-30B) 07/25/07 AW/SV DEPTH CORRECTION API Na: 50-029-22202-02 07/06/07 N4ES RWO(02-308 SUSPENDED) SEC.36,T11 N,R14E,5125'FSL&4506'FB 06/23/07 RRD/PJC FULL UPPER PATCH/FISH 06/25/07 SRB/PJC 6P PUSHED BTM SAM)PLUG BP Exploration(Alaska) • • Q o 0 0 0 0 0 o O (� C) co LU Ln o Ln O I,- N LC) 0 N V 00000 U O O O L 0 0 0 0 O i 0) CO 0) CO CO C) (O 3 V LO CO N m CO CO I" O O O Nr CO A- LO N I- LO C) O O O) CO N O co N- (`) O N L() N co CO CO (() CO CO I 1 1 I 1 1 I I- CO O) CO N CO C3) CO CO N LU 0) CO N N N CO N O LO CO CO LO Q) OCA co COO) ON O V CO O Co co Ln O CO N 00 N CO O CA ✓ Ci I I I I LLJ lar-' CD LO N O M CO 0) CO A- v In CO (1) NN N N CA CV CO CO = p • W Ln O O IL O LC) O O O (b CO a) _ J J J CY) _ LU 4# 1$ Nof N *k • fn N O O N N pM N N N O L Ch th t +-' O I- CO CO c' CO N 0O N CO O Ch C CO LO O I- LO N O CO C) N CO A- N CO A-- J U-1 w' Q C D ' U W w U O u_ E Et Z Z Z Z W w w m m m O D ~ Z Z D J D Z J J H • 0 Packers and SSV's Attachment PBU 02-30B SW Name Type MD TVD Depscription 02-30B PACKER 7904 6630.45 5-1/2" Baker ZXP Hydro Set Packer 02-30B TBG PACKER 9387 8070.81 3-1/2" Baker SABL-3 Packer • 0 _ 0 2 / \ B \ k 0 0_ c coa = o m = \ k 3Tof c co CL / § y O § 2 c < f E a) 1- 2 =0 TO E D % / R 0:1 l % — o • / / CD el £ £/ @ Li 4 $ E@ 00 pm > • ok -tCO ^/ a — o 0- \ % d e COO 2 7 0 c I I I' 0 /< . = o o O CO CI / %p -o - d \ 2d \ pn = 11 E \ 2 % d ƒ 7 /± II $ / f $ g eeo � 0 / % U2 z L < (0 121 _\ 7 ® 0 D 5 2co @ % U < S • • S (�i + Ire) ' . l P , I f 1 1. i .tom 3 .s`" '.. 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"Y , k ' h � !°' L.:„..,,';,,,,,,,,',;;',,,,,,, h ,k„ �' , j d 'k, 0,- " W , o � l' dt` i14.,;',,, b v�rr..sf pk k4:1,! s " :,tik,40,-; f4p .r iCMa" f d S t{ l v' 1 t''?i,t ;� #4 { i, ' C ' " M . ; k' + fY e a , i • W4 47 . Pq r* f T ' a". I zi-f-;. ' ,{i „ 'I7' "!, r w #1.,' ,#+ iFN a', p ' , : '..,;".0t.. ,h„,,,', , r +1f,, ' '''',1. d i ; P ,P",ga y . af 4 i A C fif ° �+ ; , , f a " `y $4 µ Yu , r f r� ! „, 9e4,0�N : x1;`°';;N� fy: « yf ' f -t t.",-;.”, .0:1,,,„„),„,,..1.„,,,,, d 4k } � + Gp, r ' �{ f,! '2';14,i21!.!:;0 ' „x: i 1 Pr e,e# ,'„„,i, t,‘,,,4r,";,;„ r1. ,, aI; ,4,4,,.;44,,,:",l•';, . , ik ",,t;_,#4:fir,. ° ,,$ c 0 s m ry ';'."4i1,4',0'';',,"' v + ti:i!1 ' 40 eft- *Xi 4 mow mop 11100 WOW 0"..yo, 4", 11111r. OW ,WW W MI& Alit ems APO 4444 low iiiingz7ingrp-v "or lip 7, Mir 4 ,4 ,, t It t ,-- ' •,, -_ .„...... ,, ..,..,. , ,,, . .. :. . , - ' - ' i 1 l t „, , .„ . . , , , , , ,.. . , , , - ,.. . .. .::... i ..s.c-. '. , ' ,' ' ., „. 4 i .ge fit, ,. y / ( fir,:. 44 w p • b alioliiiii ; 111 ii` f 11 i,P' y t 9. 1011111 r ri ” 4:;",5 , to 1, a,. 0. <- a11 99 .... ' a - .9944 9'u' #' ''''',10, em* ' 1144114,.60,. Ate ,,,�; ,,gyp d°,400\4;°°;./941P '' ' I°e ' 4 s.. "y. 'may ;,Psy � �i� ...1 c s ' ' * f • • • • , ..„ • WELL NAME 02-30A BP Exploration(Alaska)Inc. Mlet 1 4 A. r414$ Ac.afor,Pf.Pmr 9,6,493 1 - . , w 44 ' •„, ' p 444 . , • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 10/10/16 Inspector: Jeff Jones Operator: BPXA Well Name: PBU 02-30B Oper.Rep: J.Stephens PTD No.: 2001260 Oper.Phone: 659-5766 Location Verified? Yes Oper.Email: joshua.stephens(d)bp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 07/06/07 Date AOGCC Notified: 10/09/16 Sundry No.: Well Completion Report Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 200 OA 250 Condition of Wellhead: FMC wellhead&dry hole tree in good condition,no visible leaks. Condition of Surrounding Surface Frozen level gravel pad with road access. Insulation trash in well house and behind it near reserve pit(picked up).No hydrocarbon , Location: residue visible. Follow Up Actions Needed: None. Comments: Well identified by permanent well identification sign on well house.Mr.Stephens took pictures at my direction and are attached to his report. SCAMS JUN 0 8 2017. Attachments: none - REVIEWED BY: Insp.Supry w192- i//,4(, Comm PLB 12/2015 2016-1010_Suspend_PBU_02-30BJj.xlsx ti0FTy • • � t"\1%%i s� THE STATE Alaska Oil andGas '!::"411"..r, ---,,=1.1.--- of Conservation Commission u i< -t2 z',1, - :_- 333 West Seventh Avenue wh', GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®1 ALAS�Q' VFax: 907.276.7542 OE t� 2015www.aogcc.alaska.gov Ryan Daniel Alaska Wells Integrity& Compliance Team Leader ClQ ,^ ' BP Exploration(Alaska), Inc. a.b P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool,PBU 02-30B Sundry Number: 315-580 Dear Mr. Daniel: 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. Approval is granted contingent on development of a P&A plan for suspended wells with no future utility which brings these wells closer to abandonment prior to pad decommissioning. This plan must be developed and approved through the Commission by 12-31-2016. Failure to comply with this requirement will invalidate this sundry. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Cif-- Chair DATED this ��of October, 2015 Encl. RBDM NOV 0 2 2015 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMIAN APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend p Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 .,Plug for Redrill CI Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other ,..'{nC9 a-I r u • Vv.. rw 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: . 5. Permit to Drill Number: 200-126 . 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22202-02-00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No l PBU 02-30B • EIVED 9. Property Designation(Lease Number): 10. Field/Pools: SEPp 2 1 2015 ADL 0028308 • PRUDHOE BAY,PRUDHOE OIL , 7'5 /C Q3/is 11. PRESENT WELL CONDITION SUMMARY AOGCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12362 ' 8910 • 6292 5310 6292/10038 11416 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 26-106 26-106 1490 470 Surface 2520 10-3/4"45.5#J-55 29-2549 29-2354 3580 2090 Intermediate 8037 7-5/8"29.7#L-80 26-8063 26-6768 6890 4790 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal p 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development ® Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended ® ' 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and cprrect to the best of my knowledge. Contact Daniel,Ryan / Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan Title Alaska Wells Integrity&Compliance Team Leader Signature ' �' Phone +1 907 564 5430 Date , LW-Zen' COMMISSION USE ONLY JC Conditions of approval:Notify Commission so that a representative may witness Sundry Number: -6-0 Plug Plug Integriity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other f7/0/0 ro v ae.I / ,. Gd r-4,-; f'r Gl de h tr ne1 erz f o.--. de ye l o p k.'e If o f a- -,d no tire' r�I-,'Jr l7rch (7r�Yi S fhr5c Pl(.L p1a For Sv5 tv,,ie d r,,1c•115 VvIA., �" _ �?.,r,>7 !� f� limn L✓t1x15 4. 1oStr¢s 0._ b r dmr-,-,rnt' P✓„r to pncL d ct.',-,-,rni55 /✓ t0 be Ell Vfla prd akiot Rpp,,�__,,//yew/ thre✓4h rt-iG Co.-,.i„n f�,S5�/#"on tri cl 1219//14. 5Fa./ 1vrtlnt, e6' p1 yes❑ No.`ti-7 t1- 13 rrq,bsequ`t✓r,)'Form Required.: d.//11 ,kl �%i olA t✓thr3 i?un�r `(. APPROVED BYTHE �p Approved by: COMMISSIONER COMMISSION Date:L/Q'..CCT is T L i0/z(J)5- RBD a 2 2015 ORIGINAL /A.I % ,pry Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,X)j /0,Zlr. 1.c------ • S Cu C)o 0 0 0 0 0 0 0 f6 ti 0) 0O Lo IMC) Ln O I� N LO O NsZrCO 0 0 r•-•- N- (o) O rnrn (00) NI- ° CO • •cr Lo co pp co co ti co c' v co — Lo N N- Cfl CO LO CO O O 0) CO N O N LO N CO CO CO Lo CO CO a I I I I I I I I I— CO 0) M CO C7) CO CO N L!) 0) CO N N O N CO LO CO CO LO CO C w 6) M CO M CA O 00 O CO M LO O O N CO v N CO C)) CO N- O v a • W Q M CO CA (r) Lo C - v COO CO NN N N 0)) V" N N- (00 C p • W Lo O ` a co O LO co 0 0 0 _ J J J c' • d lO 4t M N 4$ N �▪ N 0) CA co N U a7 � 0o -__ _ - O co j r- N N O M M , M L +' O is CO CO 'CrCO N 0O N CO O CO C CO LO O N- LO N CD CO d N (X) ' N J W Ct Q C W W ' U o o Q o C Z Z Z Z W W W m m m 0D1— zz > > D C.) z_ H F- I- • . a) N c0 03 CA N N— CO CA L CO O 0) CO N— p, 1� O N a) ,- 0 0 0 p C7) CA 0 (3) 0) 0 co co co Co co i- 0. 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W U J 00 W n. 0 0 0 0 0 < < CO CO LL LL (n CO d o_ • a� U Cl_ 4) • U) -6- 0 r o Q � d o = J = U N• � � N CO N < m m m N N G) AMM E V < > O mCO O c- N M CO 00 oO • N (n cn m C U) ca • 20) co C.) cD Ct W WW O. �+U 0 Q Q Q d d 0_ w Emmm CO O O O Z M M M O O O TREE= FMC 5M WELLHEAD= 4-1/16"FMC 5M PJC. 02-30 B' GEES:70o"4-1/2"X 3-1/2"CHROME TBG" ACTUATOR= BAKER DRAFT F SUSPENDED S WELLBORE NOT SHOWN BO WHIPSTOCK 0022--30A KB.ELEV= 58.8' P&A'D W/CMT. DO NOT SET BPV.SEE DRLG REPORT BF.ELEV= NA " 11---- I FOR 10/12100."'7-5/8"CSG IS BUCKLED -6300'*`* a-1/2 TBG, 12.6#, — 25• l �' KOP= 79a 13-CR,.0152 bpf, Max Angle= 96" @ 11164' 25' 1 4-1/2"X 3-1/2"XO,D=3.958" 1 Datum MD= 10230' D=3-958" Datum ND= 8800'SS 20"OOND, 72' I 2112' —13-1/2"HES X NP,D=2.75" 91.5#,1.40, \ 6252' —13-1/2"HES X NP,ID=2.75" ID=19.124" ' , 6265' —3-1/2"WLEG,0=2.992" 10-3/4"CSG,45.5#,BTRS,D=9.950" — 2558' GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 3-1/2'TBG,9.2#,L-80 NSCT XO TO L-80 TCI H 3449' 2 7530 6313 32 KBMG ""DMY BK 0 02/22/02 3-1/2"TBG,9.2#,L-80 TCI,.0087 bpf,ID=2.992" —1 6264' 11111116 3 9148 7706 35 KGB 2-LS *'DANNT 0 02122102 *'ORIGINAL WELLBORE 7-5/8"EZSV(07104/07) — 6292' 7066' —ECLIPSE PATCH,D=2.240" 4-1/2"TBG STUB(07/01/07) —1 6777' $ (BOTTOM SECTION) ___.-----\ 7831' --14-1/2"X 3-1/2"TBG XO,D=2.992" 4-1/2"TBG,12.6#,13-CR,.0152 bpf,0=3.958" —1 7830' 7897' —BKR TIEBACK SLEEVE,D=5.750" Minimum ID =215" @ 72112' l 3-1/2" HES X NIPPLE CI 7904' —7-5/8"X 5-1/2"BKR ZXP FKR D=4.875" 7910' —17-5/8"X 5-1r2'BKR HMC HGR,D=4.875" TOP OF VVFIPSTOCK H 8062' CSG MLLOUT WINDOW(02-30B)8063'-8088' 7-5/8"CSG,29.7#,L-80 MOD,D=6.875" —1 —8062' ' 9346-934$IH TBG PUNCH(06/25/07) L 9360' —`CHEM CUT(06/26/07) 7-5/8"EZSV RETAINER — 8102' Vfr 9387' --15-1/2"X 3-112"BKRSABL-3 FKR,D=2.750" �i 9421' H3-112"HES X NI',D=2.750" Ilk 9435' —1 BKR TIB3ACK SLV,0=5.750" 3-1/2"TBG,9.3#,13-CR.0087 bpf,D=2.992" 9442' f 9442' --13-1/2"VVLEG,D=2.992" IIIN 5-1/2"X 3-1/2" BKR CPH FKR,D=3.000" —1 9441' Illika 5-1/2'X 3-1/2"BKR HMC HGR,D=3.000" H 9445' BR 5-1/2"LNR,17#,L-80,D=4.892' —1 9618' — 10038' —TOP OF SA ND PLUG ` 7) PFORATFON SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 76°@ 10350' Note:Refer to Production CO for historical pert data 11416(' —FISH-BKR BP SIZE SPF I4TTRRVAL Opn/Sgz SHOT SOZ PUSH@ TO BTM 2' 4 10350-10834 C 10/11/00 — (06/25/07) 2' 4 10898-11000 C 10/11/00 2" 4 11120-11239 C 10/11/00 2' 4 11320-11751 C 10/11/00 ` 2' 4 11850-11900 C 10/11/00 PBTD —1 11910' \ 3-1/2"LNR,9.3#,L-80,.0087 bpf,ID=2.992" 1 11983' �`; TD — 12362' DATE REV BY COMM$JTS DATE REV BY COMVEJTS PRUDHOE BAY UNIT 08/25/91 ORIGINAL COMPLETION 06/26/07 RRD/PJC a-F M CUT,TBG RJNCH,FISH WELL: 02-30B 02/04/97 RIG SIDETRACK (02-30A) 07/22/07 ?/PJC DRL.G DRAFT CORRECTIONS PERMT ND:82001260 10/11/00 RIG SIDETRACK (02-30B) 07/25/07 AW/SV DEPTH CORRECTION AR ND: 50-029-22202-02 07/06/07 N4ES RWO(02-306 SUSPENDED) SEC.36,T11N,R14E,5125'FSL&4506'FEL 06/23/07 RRD/PJC PULL UFPER PATCH/FISH 06/25/07 SRB/PJC BP PUSHED BTM'SAND PLUG BP Exploration(Alaska) • • bp BP Exploration(Alaska) Inc. Douglas A. Cismoski, P.E., BPXA Wells Intervention Manager Post Office Box 196612 Anchorage,Alaska 99519-6612 August 27, 2015 Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well 02-30B (PTD # 2001260) Application for Renewal of Existing Suspension (10-403) Dear Ms. Foerster, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well 02-30B on 05/31/2014 (20 AAC 25.110 (h). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: • Wellbore diagram illustrating the current configuration of the well • Suspended Well Site Inspection form documenting the pressures and site condition • Pad map and aerial photo showing well location and other wells within one- quarter mile radius of the surface location. Prudhoe Bay Unit well 02-30B was suspended on 07/06/2007. It is located on a pad with active wells and/or service wells. The strata through which the well was drilled is neither abnormally geopressured or depleted. The open perforations are covered with a sand plug, the top of which was confirmed at 312' above the top perforation interval. The well is secured with a 7-5/8" mechanical plug at 6292'. The well is mechanically sound as proven by a pressure test after the plug was set. Based on these conditions and the inspection on 05/31/2014 Prudhoe Bay Unit well 02-30B meets the provisions required in 20 AAC 25.110 (a)(1). Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Prudhoe Bay well 02-30B is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 564-4303 or Whitney Pettus/ Kevin Parks at 659-5102. • ! Sincerely, Douglas A. Cismoski, P.E. BPXA Wells Intervention Manager Attachments Technical Justification 2014 Suspended Well Site Inspection form Wellbore Schematic Well location plat and aerial photo Cc: Doug Cismoski Pettus/ Parks Ryan Daniel • • Prudhoe Bay Well 02-30B (PTD 2001260) Technical Justification for Renewal of Suspended Status August 27, 2015 Well History and Status Prudhoe Bay Unit well 02-30B (PTD 2001260) was suspended effective 07/06/2007 During a rig work over the tubing was not able to be pulled from a cut near the packer so it was subsequently cut higher at 6777'. This tubing was able to be removed, but the rig was unable to get an overshot down to the tubing stub. A caliper was run and it was discovered that the 7-5/8" production casing had collapsed to a 5-1/2" ID. The well was then secured with a 7-5/8" EZSV at 6292 and a kill string was put in place to 6265'. In the current state the well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, is secure, safe and not a threat to public health The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of Wellhead and Surface Location Prudhoe Bay Unit well 02-30B is located on an active, well maintained pad with clean gravel. The surrounding area is in good condition and there is no discoloration and no sheen on the pad, pits or in nearby water. The well pressure readings are T/I/O= 0/90/540 psi recorded on 05/31/2014 and are stable. Request BPXA requests approval for renewal of the existing suspension status for 02-30B. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. • Suspended Well Sit*Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness 10 Year Well Name. Dribete 02 NO 308 Field/Pool: Prudhoe BayField/Prudhoe Bay Pool Permit*(PTD) 2001260 API Number 500292220202 Operator BP EXPLORATION(ALASKA)INC Date Suspended 7/6/2007 Surface Location: Section. 36 Twig): 11N Range: 14E Nearest active pad or road: West Dock Rd Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges.fittings,tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of me condition of the surface location,Including discoloration,fluids or sheens visible on the ground or in any nearby water. 2)photographs showing the condition of the location surrounding the well General location condition. Clean,active pad Pad or location surface: level gravel pad Location cleanup needed none Pits condition snow/ice Surrounding arse condibon clean Wateriffluids on pad: snow melt Discoloration.Sheens on pad,pits or water none Samples taken: none Access road condition: good Photogrepha taken(Sand description). Yes,wellhouse.flowline/pit area Condition of Wellhead AOGCC requires: 1)a description of the condition of the wellhead,2)well pressure readings,where practicable, 3)photographs showing the wellhead condition Wellhead/tree/valve description,condition FMC wellhead,FMC drytiole,annuli valves open Cellar description,condition,fluids snow melt/ice Rat Hole: N/A Wellhouse or protective barriers Yes,house Wet identification sign: Yes Tubing Pressure(or casing if no tubing) 0 psi Annulus pressures. LA-90 psi OA-540 psi(arctic packed OA) Wellhead Photos taken($and description) Yes,wellhead,IA/OA,cellar Work Required none „-• Operator Rep(name and signature) Laurie Clime( AOGCC Inspector. John Crisp Other Obsarvrs Ryan Hayes inspection Date: 5/31/2014 AOGCC Notice Date 5/29/2014 Time of arrival 1.40 PM Time of Departure: 1:50PM Site access method: truck . I • TFFE- 4 1/16"FMC 5i4 PJC 02-30 B SAFETY NOTES. """4-112"X 3.1tr CHROME TOG"- WELLHEAD- FWC-5MWIrli.P.4400,C,70.e 19321'.ME-02-300 tIDTRN ACTUATOR- BAKER DRAFT SUSPENDED WELLBORE NOT SHOWN BELOW WHPSTOC K 02-3M KB REV- 58 8' NIKO VWCIAT. DO NOT SFr WV.SFEDFILG REPORT til IILV. I*" 4 10"BIG,17 61, H 25' 1 --k. 1 FOR 10/12100,***7-61111"CSO ES 181,ICKL 11341)-4300''``` KOP- 790' 13-CR 015241, Mix Anglo r- 96" 12 11164' 2,5* I- 4-11TX 3-112'XO,D=3.958*1 10230,ID.3 95S- Datum MD- Datum TVD..-, 3800,SS 20"COM, '; 77 1 I I , E 2112° 1 -3112 HES X NIP„ID=235' 91 RI,iI440, \ / 6267 —13-112-HEs X Ay.to-,2.75' 0=19 124" i/' I L6j.EE_j—[iiei•intG.e)-2.992"1 -...-- 10-314"CSO 45.54,BTRS,D.9.950' H 2668* 1 ''.- GAS LII MANU1*i S 31 IAD WO DILY TYPE. 1 VLV LA 1W FORT DATE 13-10"THO,9 2*,L-110 WO,X0 TO L-80 1431 H 34149' i ---------. i.... , 2 IMO W13 -.1 tQf443 -una til< 0 02722102i 3 9148 7706 35 KG13-2-LSHOU'Y KT 0 (02122faZ 3-1!2'TUG,9 240.i-80 RM. 0081 hpf,0 r4 2 992' — 6264' I= • i it-518'EZSV(07104,07 1 i 6262- El 1. 1 7066' 1 1 i(3 VISI-TA 64,ID r 7 240" TBG STL.43(07011071 H 677T I BOTTOM SECTION) ____..---s. / I 7891' 1-14-1.12*X 3-117 TB03 X0,D.2992"I H 1/2*MG,1214,13-CK, 6 i 80.1444%irs-s.s68. H 7810- I [Minimum ID=215"@ 72112' J { 789r 113KR TIEBACK SLEEVE,ID 5 150' 1.4 i L 79". '7-518"X 5-112"BKR ZXPPKR 1]-4 875" :3-1/2"HES X NIPPLE 1 7910' I-17-5M'X 5-172"BKR MC/DR,D=4 875" 1 TOP Of V'A4STOCI_LI—L82' CSG MELOUT WINDOW(02-3011)8063' 808" r-sier( Q29 TIR,I-19:1 MOO,0.6 615- H -4106z. ir/ ii. $ 9346-93481 PSG F'UNCH(06254072 j 1 9360' 11 alwarr measoon .., 17-5/8"EZSV RETAP 8102 --,- 4387' '1 (5-112'X 3-112'BKR S81.-3 PKR,ID=2750" 1 4.4 1 3-112"'MG,9.34-13-CR.0087 WO=2,992' H 9442. .111111164. IA 9421* —13-112-HES X rip.I)-2.750" 943S' .1 BKR TIEBACK SLV,ID=5.750" 1 9442' 1,-13 112'WIEG,0-2.942'..1 V IS 15-lir X 3-1,2- BKR CRI RKR,ID-3.000' .--1 9441' J iit ...s 15-1/2"X 3-1/2"EiKR MC NG-1.13=3 000' H 944S' No. I, 10038"J I TOP OF SAND PI UG /s 1/2*LA44,110,L 40,43 4 992- i--.1 9418' (0605/07) PERFORATION SMART REF LOG TCP PERF A 'NOLL A 1 TOP /V@ 1035FY Nuts..Refer to Production CB for historical pert data MIN 11416' —flat-LIKR LIP SIZE- SPF MEM/AL Opn1Sqz SHOT SOZ FISH TO BM 2' 4 10350-10834 C 10/11100 (00125,07) 2" 4 10898 11000 I C 10/11100 Ilik 2' 4 11120-11239 C 10/111010 .4, 2" 4 11320-11751 C 10111100 2' 1 4 11850-11900 C 10111100 =HD 111418' 1 .111iAl4A 1 _ 111111141161, '0911141' 13-1/2"1 NR 9 30,4-80, met bp',10-2662 1 11983' It) 1411144111144414 ID 12362' 16111611' DATE REV 3Y ODMMENTS DATE REV BY COIMENTS I FFICHIDE BAY UHT 08125161' 4DRIGINIAL COMPLETION 06/2810/" 149)PJC CHEM CUT.MG FUNOH FISH VilE_L 02-3013 i 0204/97' RIG SIDETRACK(02-30A) 07/22/07 7)PJC LIFLG CRAFT CORRECTORS Pg1PAT hei:'001260 t I SMUT*i, RIG SIDETRACK 102-308) 0705/07 A1A9SV DEMI CORRECTION MIND-50-029-22207-02 07/06107 NIES ;MVO(02-308 SUSPENDE)) SEC 36,T11N.R14E,5125'FSL 8 4506PE i4 06/2310 r FIRD/PJC PUI.1 MLR PA rai 1 HSI I 06125837;SI /PJC WHISKED BIM)SAND PLUG BP Stploralion(Alas k a) 1 • • • • 6 l 240' f i _ Y `ti 2 i ' c +7.._,A 29*- r t 9 p ri Enter,'Exit +a.-; -A/4/1 1/' '= j3• ca k 37 1 alti 39 J � � i 2 I i 29A 10 it I. r 0 34 I r 5 2s•-_ _ e i Ahh.... ' i -'; 25 1 24 .111111 7s 1.Y :1 t .. _ .. - yell• , L 20 i • "' EnteeEvi 230' 2185' — WELL PRODUCER ■if WELL INJECTOR A DATE :01106,•2009 SCALE: 1°=350' MAP DATE:2007 PBIJ - DS 2 WELL 8L0T W/CONDUCTOR 0 • I • 2 uIy 9.2010 Approximate Scale: 1".400' s. 2010-19c-7-14 .16.111:011n 1 \4" ''' ' \'‘ ''''. ,I,1r,� . ‘1,,, i , Ir., ,,, , 1 k_414 ,, . ,,,.. e -mow, f. i as a t :4„,„, ,4 , a i s' s y � f • 41110 Loepp, Victoria T (DOA) From: Daniel, Ryan <Ryan.Daniel@bp.com> Sent: Thursday, October 22, 2015 9:01 AM To: Loepp,Victoria T(DOA) Cc: Sternicki, Oliver R Subject: FW: PBU Suspension Renewal Wells Good Morning Victoria, Thanks for the conversation this morning. BPXA currently have 59 suspended status wells, of which many would not have *future utility today. My view for the business and from a risk perspective is to leave these wells "as is" until pad level decommissioning.The SU wells on pads with trees are monitored daily and pose minimum risk to our operations. Any wells,that are determined to have a higher risk associated with communication, re-pressurization etc will certainly be given priority for intervention and mitigation. *Additionally, as the business starts to realign from oil to gas over the next 10-15 years we would want to preserve various options(wells and surface locations)for the future. Let me know if you have any other questions Rgds Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, October 21, 2015 3:56 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells Oliver, At what point will these wells with no future utility be brought closer to abandonment?Approximately how many suspended wells are in this category? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepoe.alaska.gov CONFIDENTIALITY NOTICE: his 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • • Loepp, Victoria T (DOA) Subject: From: Daniel, Ryan [mailto:Ryan.Daniel@bp.com] Sent: Tuesday, October 20, 2015 4:25 PM To: Loepp, Victoria T(DOA); Sternicki, Oliver R Cc: Regg, James B (DOA); Julian, Jennifer Y; Bill, Michael L (ASRC) Subject: RE: PBU Suspension Renewal Wells Hello Victoria, Negative. BP and its working Interest owners are developing some longer term options for"decommissioning"work scope which includes some wells and surface kit.These are screening opportunities only(potential future activities)and still in the very early scoping stage. They are not funded or approved yet,and as such it would be premature for BPXA to comment any further. The Observation well P&A program which I discussed recently with Jim, and the Suspended well renewal applications submitted by Oliver are also separate (discrete and unrelated)activity plans for well stock management and as such have different timelines and rational. We are happy to discuss the Suspended wells further id necessary. If you could use Oliver as the single point of contact for this work that would be much appreciated. Thanks Ryan From: Loepp, Victoria T(DOA) [rnailto:victoria.loepp@alaska.gov] Sent: Tuesday, October 20, 2015 2:16 PM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, Do you have any information to share with us on the sustained P&A program and where these suspension renewal wells fit in the program? Thanx, Victoria 1 • From: Sternicki, Oliver R [ ] Sent: Thursday, October 08, 2015 4:03 PM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: PBU Suspension Renewal Wells Victoria, This is the response from Base Management for the 9 suspended wells renewals and if the fall under A or B of 20AAC 25.110(a)(2). 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. WGI-01: no current sidetrack plans 02-30B: no current sidetrack plans G-13A: no current sidetrack plans, but may use surface equipment for another well V-201: no current sidetrack plans 5-14A: no current sidetrack plans W-09A: no current sidetrack plans E-18B: evaluating several sidetrack options NK-14A: evaluating a sidetrack option Y-25A: no current sidetrack plans Let me know if you have any other questions. Regards, Oliver Sternicki W illobsi twat ammo oboe Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternicki(a,bp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, September 28, 2015 3:10 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells So no well listed below,with the exception of 1-100 has future utility as an exploratory, development,or service well and no well listed below is a viable candidate for redrilling? I understand the wells are all located on active pads. Victoria Victoria Loepp Senior Petroleum Engineer 2 • State of Alaska • Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppa aaska.Qov 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 Victoria Loepp at(907)793-1247 or Victoria.Loeeo@alaska.gov From: Sternicki, Oliver R [mailto:Oliver.St hhrnicki@ bp.com] Sent: Monday, September 28, 2015 2:41 PM To: Loepp, Victoria T(DOA) Cc: AK, D&C Well Integrity Coordinator; Daniel, Ryan Subject: RE: PBU Suspension Renewal Wells Victoria, The below wells that you have listed fall under the category; (C) is located on a pad or platform with active producing or service wells. 1-100 which you did not list is the only well that BPXA sent for renewal of suspended status that falls under the category. (A) has future utility as an exploratory, development,or service well; no wells meet the (B) criteria. Regards, Oliver Sternicki global we*w O Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternickibp.com From: Daniel, Ryan Sent: Monday, September 28, 2015 9:26 AM To: Sternicki, Oliver R Cc: AK, D&C Well Integrity Coordinator Subject: FW: PBU Suspension Renewal Wells Oliver, Can you please reply to Victoria on this question, Copy me,or come and discuss if we have an issue. Thanks Ryan 3 • • From: Loepp, Victoria T(DOA) [mailto:victoria.loeDp@alaska.gov] Sent: Monday, September 28, 2015 9:25 AM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, PBU 02-30B 200-126 PBU V-201 201-222 PBU E-18B 204-139 PBU G-13A 200-163 PBU S-14A 204-071 PBU W-09A 204-102 PBU WGI-01 179-031 PBU Y-25A 208-140 PBU NK-14A 206-031 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. Which wells meet the criteria of(A) and/or(B)? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp onalaska.aov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepo@alaska.gov 4 Imam[," '~roject Well History File Cover{' '.ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c~ 00 1 c~_ ~:2 Well History File Identifier RESCAN DIGITAL DATA [] Color items: ~o. ~--.~' [] Maps: OVERSIZED (Scannable) [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~INDY [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL(~WINDY Scanning Preparation BY: BEVERLY ROBIN VINCENT SHERYL~INDY + 7 - TOTAL PAGES Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: '. PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ./;~ YES Sta~e 2 IF NO IN STAGE 1, PAGE(8) DISCREPA~RE FOUND: ~ YES BY: BEVERLY ROBIN VINCENT SHERYL MARI,~ DA~( (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL A~ENTION IS REQUIRED OFAN IINDI~DUAL PAGE ~SIS DUE TO QUALI~, G~YSCALE OR COLOR IMAGES) NO NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /si General NOtes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned,wpd �� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report 09/11/10 Date Inspected: Inspector: Chuck Schev Operator: BPX Well Name: PBU 02-30B • Oper. Rep: Jack Winslow PTD No.: 2001260 ' Oper. Phone: 65*5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 07m6m7 Date AOGCC Notified: Sundry No.: Well Completion Rpt Type of Inspection: Initial ' Wellbore Diagram Avail.? Yes Well Pressures Tubing Vac - nm m Photos Taken? Yes / IA 0 by Operator OA 140 Condition of _ Wellhead: Double Master Valves only. No Well house or barricade on well. No Well sign. Condition of Surrounding Surface OK Location: - Follow Up Actions Install Well house or barricade and Well sign. Needed: Attachments: � None - REVIEWED BY: mep.oupry T / » / 7/k Comm mm ^ �«\� � � «' .' .��Y r` - - PLB 08/2010 2010-09 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 � k 'I U r 41,44. 40 i ?011 Mr. Tom Maunder �I $r �$a Alaska Oil and Gas Conservation Commission 4 v4 V. C 333 West 7 Avenue a 34 2,9 113 / 4 44 1 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -02 a00- 1 c9•6 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 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, Gerald Murphy, at 659-5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 STATE OF ALASKA~~ ALAS • IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~:.ryT~~~ 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ®Suspended 1b. Well Class: 20AAC25.105 soAACZS.~to ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Ab ~ 12. Permit to Drill Number ' BP Exploration (Alaska) Inc. 7/6/2007 ~ 200-126 30 l'~33 3. Address: 6. Date Spudded 13. API Number xi-S` P.O. Box 196612, Anchorage, Alaska 99519-6612 09/17!2000 50-029-22202-02-00 ~ 1~ 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 4' 1 ' 10/06/2000 PBU 02-30B 5 FNL, 774 FWL, SEC. 36, 711N, R14E, UM Top of Productive Horizon: 8. KB (ft above MSL): 58.8' - 15. Field /Pool(s): 3369' FSL, 1370' FEL, SEC. 26, T11 N, R14E, UM Ground (ft MSL); 30.3' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 4189' FSL, 2775' FEL, SEC. 26, T11N, R14E, UM 11910 8902 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 687504 y- 5951044 Zone- ASP4 12362 ~ 8910 r ADL 028308 TPI: x- 685271 y_ 5954514 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 683845 y- 5955299 Zone- ASP4 None 18. Directional Survey ^ Yes ®No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): Submit electronic and rinted information er 20 AAC 25.050 N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, RES, NEU, DEN, Sonic 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD ..HOLE.. AMOUNT WT..PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE.... CEMENTING RECORD PULLED 20" 91.5# H-40 Surfa a 110' Surf ce 110' 30" 11 cu ds Arcticset 10-314" 45.5# J-55 Surface 2558' Surface 2361' 13-1/2" 2563 cu ft Coldset III 405 cu ft'G' 7-5/8" 29.7# L-80 Surface 8063' Surface 6768' 9-7/8" 1369 cu ft Class 'G' 5-1/2" 17# NT-80S 7897' 9618' 6 24' 83 1' 6-3/4" 225 cu ft Clas 'G' 3-1 /2" 9.3# L-80 9435' 11 83' 8119' 8905' 4-3/4" 225 cu ft Class 'G' 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, IISt each I (MD+TVD of Top & Bottom; Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 4 spf Kill String: 4-1/2" x 3-1/2" 6265' MD TVD MD ND A-1/2", 12.6#x3-112°, s.3u, tsc~eo 6777 - 9442' 9387 10350' - 10834' 8899' - 8918' ETC 25, ; ACID FRACTURE CEMENT SQUEEZE 10898' - 11000' 8913' - 8910' , , , . 11120' - 11239' 8910' - $902' DEPTH INTERVAL MD AMOUNT Si KIND OF MATERIAL USED 11320' - 11751' 8902' - 8902' 10038' Set Sand Plug: 7500# of 20/40 River Sand 11850' - 11900' 8901' - 8902 6292' Set EZSV Freeze Protect w/ 20 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OlL RATIO: TEST PERIOD Flow Tubing Casing Press: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Press. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None t~, ~ ~, SEP ~ ~ 7ClQ~ ~;~~ ~ -.----~ .~ ~W (ts Form 10-407 Revised 02/200 ~ ~ ~ ^ ~ ~ t n ~ CONTINUED ON REVERSE .SIDE '28. GEOLOGIC MARKERS (LIST ALL FORMATIONS A KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9612' 8295' None Shublik 9660' 8343' Sadlerochit 9704' 8387' Zone 3 9863' 8545' Zone 2C 9930' 8608' Zone 1 B 10222' 8847' Zone 1A 10318' 8889' Formation at Total Depth (Name): Zone 1A 10318' 8889' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. V Si d V /~~~ ~ gne Title Technical Assistant Date Terrie Hubble PBU 02-306 200-126 Prepared eyName/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Aras Worthington, 564-4102 Permit No. / A royal No. INSTRUCTIONS GeNereA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. 1reM 4b: TPf (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only RE: Well 02-30B RWO/Well su~sion ~ Page I of 2 Hubble, Terrie L From: Worthington, Aras J Sent: Thursday, July 05, 2007 8:44 AM To: Hubble, Terrie L Subject: FW: Well 02-30B RWO/Well suspension Follow Up Flag: Follow up Flag Status: Red Ni Terrie - Copying you on the note below just to let you know of the impending 407 form...we entered this rig workover intending to repair the casing with a scab liner but the current casing string was too collapsed to get the scab liner in, so we suspended the well as noted. Cheers, Aras From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, July 04, 2007 9:11 AM To: Worthington, Aras J Subject: RE: Well 02-30B RWO/Well suspension Aras, As we spoke last night. I spoke with Commissioner Foerster and advised her of the situation with 2-30B. She concurs with the plan forward and by copy of this message you have her oral approval to proceed. Please advise Terrie that since the well will be suspended, the proper form is a 407. Good luck. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: Worthington, Aras J [tnailto:~t•as.ti~'orthingtc~nCa~bp.ct»n] Sent: Tue 7/3/2007 9:09 PM To: Maunder, Thomas E (DOA) Subject: Well 02-30B RWO/Well suspension Tom, As per our conversation on the phone earlier, here are our plans for 02-308. The background is that during the rig-workover we could not pull tbg from the cut near the packer and had to cut higher, above the patch-packer. We retrieved that tbg but could not get an overshot down to the tbg stub. We subsequently ran a caliper and found that the 7 5/8" liner was collapsed to ~5.5" ID in four places above where the overshot hung-up. We plan to suspend the well pending a review of our options per the following procedure: Run SL drift for EZSV plug (6.12" OD). 2. RU E-line, flanged to the top of the bag 7/24/2007 RE: Well 02-30B RWO/Well sus~ion ~ Page 2 of 2 3. Set an EZSV plug set up as a cement retainer (with asting-in valve) as deep as the drift goes, probably 6300' based on the caliper data. 4. PT the 7 5l8" casing against the plug to 1000 psi for 30 minutes. 4. Run a USIT log on E-line to find the cement top behind the 7 5/8" casing (data for the assumed future sidetrack of the well). Log from the EZSV to surface. RD E-line. 5. Prepare to run an L-80/IBTM kill-string completion as follows: a) Wireline Entry Guide b) 1 jt. 3 1/2" tbg c) 2.812" HES X-nipple (10' pups above and below) d) 3 1/2" tbg e) 2.812" HES X-nipple set -2100' MD (10' pups above and below) f) New tbg hanger with competent BPV profile 6. Space-out to have WLEG ~ 60' above the EZSV. 7. Circulate the entire well to corrosion inhibited 9.8ppg brine (tbg and annulus). 8. Land the tbg hanger and RILDS. 9. FMC to set TWC and test to 1000 psi from above below for 10 min (charted). 10. ND BOPE and NU adapter flange and tree. Test the tbg hanger, adapter, and tree to 5000 psi. 11. RU hot oilers to the annulus. PT lines to 3500 psi. Reverse in 90 bbls diesel ino inner annulus. RU jumper between IA and tbg. Allow IA and tbg to U-tube for 1 hour. RD hot oilers. 12. DSM/FMC to install BPV. Secure the tree and cellar. 13. RDMO. 7/24/2007 Digital Wellfile Well: 02-30 Well Events for SurfaceWell - 02-30 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS1 -> 02 -> 02-30 Date Range: 15/May/2007 to 28/Jun/2007 Data Source(s): AWGRS Events Source Well Date Description • Page 1 of 3 AWGRS. 02-30B 06/28/2007 ***TRAVEL FROM 14-33*** PULLED 4 1/2" XX-PLUG FROM 2199' SLM. SET 4 1/2" WRP @ 231' SLM/235' MD. T/IA/OA = 0 psi. ATTEMPT TO TEST PLUG. ***IN PROGRESS/CONT. WSR ON 6-29-07*** AWGRS 02-308 06/27/2007 *** JOB CONTINUED FROM 06-26-07 WSR *** (fish eline tools/pre rig) SET 4 1/2" XX PLUG (HP LOCK, 8- 1/8 EQ PORTS, 25"OAL) IN SSSVN @ 2181' SLM. MIT-T TO 3500# PASSED . NOTE: MAX HOLDING PRESS ON PLUG IS 3740 PSI FROM ABOVE . ***WELL LEFT S/I ON DEPARTURE*** AWGRS 02-30B 06/27/2007 Continued from 6-26-07 MIT-OA to 2700 psi, (RWO Prep) ***PASS**** Pumped 1.2 bbls crude to pressure OA to 2700, PASSED 1st attempt, Loss of 160 1st 15 min loss of 70 psi 2nd 15 min. S-Line set plug in SSSV niple, test plug to 3500 psi, PASS Loss of 160 psi 1st 15 min, loss of 7 psi 2nd 15 min. Freeze protect F.L. W/ 5 bbls meth, 86 bbls crude, 2 bbls meth 20 bbls diesel FWHP=O/0/0 AWGRS 02-30B 06/26/2007 *** WELL SHUT IN ON ARRIVAL *** (fish eline toots) RAN BAITED OVERSHOT TO 7053' SLM (BTTM ANCHOR OF PATCH) , NO MARKS INSIDE OVERSHOT INDICATING E-LINE TOOLS ALREADY FELL DOWN HOLE .FISHED E-LINE TOOLSTRING FROM 9929'SLM .STANDBY FOR LRS TO CIRC-OUT WELL *** JOB CONTINUED ON 06- 7-07 WSR ** AWGRS 02-30B 06/26/2007 *****CONTINUE AWRGS FROM 25-)UN-07***** RIH WITH CHC. CUT TUBING AT 9360' ELMD. CHC ANCHORS BEGAN STICKING IN COLLARS WHILE POOH, ABLE TO JAR OUT OF COLLARS. ANCHORS BECAME STUCK IN PATCH AT 7044'. PULLED OF OF WEAKPOINT AND LEFT TOOL IN THE WELL. TOP OF FISH AT 7028', 1 3/8" FISHING NECK LOOKING UP HOLE. POOH AND RD ELINE. WELL LEFT SHUT IN. FINAL T/I/O: 300/100/0. AWGRS 02-30B 06/26/2007 T/I/0= 350/0/0 CIRC-OUT (RWO-Prep) Pumped 5 bbls meth spear, 300 bbls 9.8 Brine down tbg taking returns up IA to F.L. Shut in IA Jumper while pumping 5 bpm down tbg, IA increased 90 psi instantly then stabilized, TBG increased 60 psi then stabilized, Open jumper to FL continue pumping remainder of 470 bbls total down IA, Rig up to TBG, Bullhead 184 bbls brine down IA Into PC Leak before running out of fluid. Continued on 6-27-06 AWGRS 02-308 06/25/2007 ***02-30 SPINNER/TEMP/GRADIOMANOMETER/CCL -TBG PUNCHjSTRING SHOTJCHEM- CUT*** WELL SI ON ARRIVAL. INITIAL T/I/O = 300/100/0 LOGGED PRESSURE/TEMPERATURE/GRADIO/SPINNERS ACROSS PATCH AREA 7050' AND 9400' AND CONFIRMED NO FLUID MOVEMENT IN TUBING. TUBING PUNCH WITH 1-11/16" 2 FEET @ 4SPF = ,9 HOLES FROM 9346'-9348'. TOP OF FIRST FULL JT ABOVE PACKER. SHOT STRING SHOT ONE STRAND 9350'-9362'. RU CHC AND RIH TO CUTTING DEPTH. JOB IN PROGRESS. ****CONTINUE ON AWRGS 26-JUN-07**** AWGRS_ 02-306 06125/2007 CTU #8, Sand Plug; Cont' from WSR 6/24/07 ... Completed sand plug. POOH. FP weH with 50/50 to 2500'. Final SIWHP = 280 psig. Notified E-Line for tubing cut to follow. RD CTU #8. *** Job Complete *** AWGRS 02-30B 06/24/2007 ****CONTINUED FROM 23-JUN-2007***** OBSERVED LEAK FROM AREA UNDER PULLED PATCH AT 7053 FT. NO FLOW ABOVE LEAK, 100% FLOW INTO PERFORATIONS. FINAL T/I/O/ = 100/150/0 RIG DOWN AND NOTIFY DSO UPON DEPARTURE ****JOB COMPLETE**** AWGRS 02-306 06/24/2007 CTU#8, Sand Plug; Cont' from WSR 6/23/07 ... MIRU CTU #8 with 14593' 1.75" CT. MU and RIH with BHA#1 with 2" Big Hole Nozzle (2.125" Max OD on BHA). Tagged IBP at 11290' ctmd. Pushed IBP to 11416' ci:md. Could not get IBP deeper. PUH to 7145' ctmd. Pump 7500# of 20/40 river sand and bullhead displace slurry to calculated sand top of 10050'. Saw 80 to 90 psi increase in WHP. Wait 1.5 hrs for gel to break. Current SIWHP = 195 psig. RIH and tag top of sand at 10041' ctmd. PUH. Surge/pump down backside. RBIH and tagged sand top at 1 38' ctm . P ON. Ccint' on WSR 6/25/07 ... AWGRS 02-306 06/23/2007 CTU#8, Sand Plug; Road Unit to DS02-30 and waiting for VECO to finish RU. Continue on 06/24/07 ... AWGRS 02-30B 06/23/2007 *** E-LINE RIGGED UP ON WELL ON ARRIVAL*** STANDBY FOR E-LINE TO GET OFF DS2- 30. JOB CANCELLLED FOR DS.Z-30. *** E-LINE STILL RIGGED UP ON WELL ON DEPARTURE *** AWGRS 02-30B 06/23/2007 **** DS02-30 -INFLATABLE BRIDGE PLUG ****** INITIAL T/I/O = 100/150/0 E-LINE ATTEMPTED SET BAKER IBP DIA.: 2.13" (NON-SET) LENGTH: X0.51' CENTER SET @: 9380' CCL TO CENTER OF PLUG: 23.76' TOP OF IBP TO CENTER OF ELEMENT: 7.12' FISHING NECK: 1.375" OD - 5500 LBF TO PULL RELEASE SEALING EL.: 2 x 6", 1x1" STIFFENER RG PIPE ID: 2.992". MIN. RESTRICTION: 2.24" @ 7035' (PATCH) PLUG NOT PROPERLY SET. SUSPECT OF CROSSOR DOWNFLOW FROM LEAK AT 7,053' DOWNHOLE E-LINE TO RIH WITH httpa/digitalwellfile.bpweb.bp.comlWellEventslHome/Default.aspx 712512007 Digital Wellfile ~ ~ Page 2 of 3 SPINNER/TEMP/GRADIOMANOMETER/CCL TO CONFIRM CROSS/DOWNFLOW OBSERVED LEAK FROM AREA UNDER PULLED PATCH AT 7053 FT. *****CONTINUED 24-JUN-2007**** AWGRS 02-30B 06/23/2007 *** JOB CONTINUED FROM 06-22-07 WSR *** (assist ctu #5) FISHED 4 1/2" ECLIPSE PULLING TOOL FROM PATCH @ 7055' SLM DRIFTED TBG W/ 2.150" CENT & 1 1/2" S. BAILER P 0 N RESTRICTIONS FOUND (TARGET = 9347' ELM) SAMPLE BAILER WAS EMPTY *** TURNED WELL OVER TO CTU #5 *** A_W_GR_S 02-30B 06/23/2007 CTU #5. Fish Bait Sub. *** Continued from WSR 06/22/07 *** Standby on slickline to fish bait sub. RDMO CTU. ***Attempt*** AWGRS 02-306 06/22/2007 *** WELL SHUT IN ON ARRIVAL *** (assist ctu #5) RIG UP SLICKLINE, STANDBY FOR N2 BOTTLES *** JOB CONTINUED ON 06-23-07 WSR *** AWGRS 02-30B 06/22/2007 CTU #5. Fish Bait Sub. ***Continued from WSR 06/20/2007 *** RIH with WFD BHA #3 w/ motor and retrievable Pin Tapp. Attempt to engage fish at 7061' ctm with motor spinning. Pull up with 3k overpull. Appeared to pull free. Set down and pickup clean. POOH. No fish recovered. Pin Tapp was not buried in fish. Decision made to rerun tool. RIH with Pin Tapp again. Attempt to latch up rotating by pumping 38 bbls of diesel. Jarred down on fish to engage. POOH. No fish recovered. Standback CTU for slickline to attempt to fish. *** Job continued on WSR 06/23/2007 *** Aln_1GRS 02-30B 06/21/2007 CTU #5. Fish Lower Eclipse Packer *** Continued from WSR 06/20/2007 *** Bullhead 50 bbls of 1% KCI w/0.6% SafeLube. RIH with Weatherford 4.5" GS fishing string. Load CT with 35 bbls of diesel at 6950' ctm. Engage fish at 7055' ctm. Perform 62 jars hit at 25k over string weight. Disengage from fish and POOH for string management. RIH with Weatherford 4.5" GS fishing string. Engage fish at 7054' ctm. Jar 60 times at 28k over string weight. Pump off fish and POOH for pipe management. RD Weatherford BHA. RD. Decision made to re-rig CTU to remove bait sub from lower packer assembly. Re-rig up CTU ***Continued on WSR 06/21/2007 *** AWGRS 02-30B 06/20/2007 CTU #5. Fish Lower Eclipse Packer. *** Continued from WSR 06/19/2007 *** MIRU CTU. Make up WFD 4.5" GS fishing string. RIH. Latch fish at 7053' ctmd. Jar up at 18k over for 53 jar licks. Pump off of fish for pipe management. POOH. Perform pipe management for chrome wells. MU new set of WFD toolstring. Bullhead 50 bbl 1% KCI with 0.6% SafeLube into wellbore. *** Continued on WSR 06/21/2007 *** AV1jGRS 02-30B 06/19/2007 CTU #5. Standby on Rig Up. *** Continued on WSR 06/20/2007 *** AWGRS 02-30B 06/19{2007 ***CONTINUE JOB FROM 06/18/07*** MADE SEVERAL ATTEMPTS TO FISH BOTTOM PATCH @ 7026' SLM.... UNABLE TO PULL W/ BRAIDED LINE. *NOTE: BOTTOM PATCH LEFT IN HOLE @ 7066' MD* ***WELL LEFT A_W__GRS 02-30B 06/18/2007 ***WELL S/I ON ARRIVAL*** RECOVERED TS FROM 6972' BLM IN PROCESS OF PULLING BOTTOM OF ECLIPPE PATCH ***JOB CONTINUED ON 06/19/07 WSR*** AWGRS 02-30B 06/17/2007 *** CONT FROM 06-16-07 WSR *** (pre rwo) MADE SEVERAL ATTEMPTS TO PULL ECLIPSE LWR PKR ASSY. @ 7034' SLM W/ NO SUCCESS *** LEFT WELL S/I *** ****NOTE: 4 1/2" ECLIPSE PULLING TOOL PLANTED IN LWR PKR ASSY. (4 1/2" G-FN, OAL= 14.5", 3.66" OD, 4" DEEP INSIDE FN)**** AWGRS 02-306 06/16/2007 *** WELL SI ON ARRIVAL *** (pre rwo) PULLED UPPER ECLIPSE PKR ASSY. FROM MASTER VLV @ -2' SLM ATTEMPTING TO PULL LOWER PKR ASSY. FROM 7034' SLM... 4 HRS @ 1800# *** JOB IN PROGRESS/ CONT ON 06-17-07 WSR *** A__WGRS 02-30B 06/16/2007 Mill obstruction/ Pull eclipse patch. CTU #9. ***Continued from 6/15/07 WSR*** LD fishing tools. Perform weekly BOP test. Freeze protect coil. Cap well with 20 bbls 50/50 meth. RDMO. Notify DSO of well status. Attach do not operate tag to master valve. ***Job Complete*** ***Fish (upper assembly of 4-1/2" eclipse patch) hung in master valve*** ***Top of fish is ~'~/2' above master valve. 4-1/2 "G" internal fishing neck looking up. Length of fish X32.7'*** ***Lower packer still in hole (requires same eclipse retrieval tool) *** AWGRS 02-30B 06/15/2007 Mill obstruction /Pull Eclipse patch. CTU #9. ***Continued from 6/14/07*** RIH with BHA #2 (3.57" OD mill). pass restriction and dry tag top of patch at 7027' ctmd. Make milling pass thru restriction and backream. No motor work observed. TOOH. MU BHA #3 - 3.70" OD mill and RBIH. Tag and mill out restriction at 6796' ctmd. No other restrictions seen. POOH. MU BHA #4 - 3.80" OD Mill and RBIH. Tag obstruction 6795'. Mill through obstruction, Make multiple passes from 6785' to 6815'. POOH. Gauge mill and 3.784" will no-go. MU and RIH with BHA #5 - WOT fishing tools w/ 4-1/2" Eclipse retrieval tool. Latch patch at 7031' ctmd. ,Pull free after 2nd jar lick. POOH. Hang fish in master. Well secure with 2 swab valves. ***Continued on 6/16/07 WSR*** A~vGRS 02-30B 06/14/2007 CTU # 9, 16125' of 1.5" CT. JOB SCOPE -Mill obtruction seen at 6789' SLM /pull Eclipse patch at 7035'. MU BHA #1 with 2 7/8" motor and 3.80" parabolic diamond mill, TIH. Tag o s ~ruc ion a 6795' ctmd. Start milling at 6793.6' with numerous stalls. Try to jar down and swage open. Between milling and beating, made .3 ft. TOOH, MU BHA #2 - 3.57" OD mill and RIH. ***Continued on 6/15/07 WSR*** AWGRS 02-30B 05/19/2007 *** JOB CONTINUED FROM 05-18-07 WSR *** DRIFTED TBG W/ 3.750" CENT, 3.50" LIB, SD @ 6789' SLM MARKS ON LIB WERE INCONCLUSIVE. DRIFTED TBG W/ 3.25" CENT, 3.25" http://digitalwellfile.bpweb.bp.com/WellEvents/Home/Default.aspx 7/25/2007 Digital Wellfile ~ ~ Page 3 of 3 LIB, SD @ 7024' SLM (PATCH) LIB SHOWED CLEAN IMPRESSION OF PATCH. DRIFTED TBG W/ 3.51" SWEDGE, WORKED PAST TIGHT SPOT @ 6789' SLM TAGGED PATCH @ 7024' SLM DRIFTED TBG W/ 3.625" SWEDGE SD @ 6789' SLM UNABLE TO WORK PAST DRIFTED TBG W/ 3.80 TAPERED LIB, TAGGED RESTRICTION @ 6789' SLM LIB IMPRESSION WAS INCONCLUSIVE *** LEFT WELL SHUT IN *** A~rVGRS 02-30B 05/18/2007 ***WELL S/I ON ARRIVAL*** (pre rwo) DRIFTED TUBING W/ 3.805" GAUGE RING, SD @ 6789' SLM, UNABLE TO WORK PAST *** - - AV~LG€ZS 02-30B 05/15/2007 T/I/O=SSV/150/0. PPPOT-T (PASS), PPPOT-IC (PASS). Pre-rig. PPPOT-T: Stung into the test void to check pressure (0 psi). Pumped through void until clean returns were achieved. Pressured void to 5000 psi for 30 min test, lost 200 psi in first 15 min, lost 50 psi in second 15 min (PASS). Functioned all LDS, all moved freely. PPPOT-IC: Stung into test void to check pressure (psi). Bled pressure to 0 psi. Pumped through void until clean fluid was achieved. Pressured void to 3500 psi for 30 min test, lost 100 psi in first 15 min, lost 0 psi in second 15 min (PASS). Functioned all LDS, all moved freely. Refresh List http://digitalwellfile.bpweb.bp.com/WellEverxts/HomelDefault.aspx 7/25/2007 • • BP EXPLORATION Operations Summary Report Page 1 of 6 Legal Well Name: 02-30 Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: WORKOVER Start: 6/27/2007 End: 7/6/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/6/2007 .Rig Name: NABOBS 4ES Rig Number: Date From - To I Hours ' Task Code - -- - L 6/26/2007 12:00 - 20:00 8.00 MOB P 20:00 - 00:00 4.00 MOB N 6/27/2007 00:00 - 06:00 6.00 MOB N I 06:00 - 22:30 16.50 MOB N 22:30 - 23:30 1.00 MOB P 23:30 - 00:00 0.50 RIGU P 16/28/2007 00:00 - 02:00 2.00 RIGU P 02:00 - 04:30 ( 2.501 RIGU I P 04:30 - 07:00 2.501 RIGU P 07:00 - 09:30 I 2.501 KILL 1 P NPT ' Phase ~ WAIT WAIT WAIT 09:30 - 13:30 4.00 KILL I N WAIT 13:30 - 14:00 0.50 KILL ~ N DFAL 14:00 - 16:30 I 2.501 KILL I N (DFAL 16:30 - 17:30 1.00 KILL N DFAL 17:30 - 18:30 1.00 KILL N DFAL 18:30 - 20:00 1.50 KILL N DFAL 20:00 - 20:30 0.50 KILL N DFAL 20:30 - 23:30 3.00 KILL N DFAL 23:30 - 00:00 0.50 KILL N DFAL 6/29/2007 00:00 - 02:00 2.00 KILL N DFAL 02:00 - 02:30 I 0.501 KILL I N I DFAL Description of Operations PRE Moved rig from G-Pad to DS 02. PRE Waiting on DS 02-30B well prep. Rig on standby charge. PRE After moving rig from G-Pad to DS 02, arrived on location about 20:00 hrs 6/26/2007. Waited on 02-30B slickline I operations, well house removal, flow tine removal, and site ~ preparation. Performed rig cleaning and general rig housekeeping. Reviewed PETEX well control case histories with night rig crew. Left message for AOGCC with 24 hour notice of BOPE test. PRE SW S slickline and LRS completed circulating well with 9.8 ppg brine and setting XX plug in X nipple @ 2199'. LRS P/T'd XX plug to 3500 psi from above for 30 minutes with 180 psi loss in 30 minutes. RDMO SWS and LRS @ 0630-hrs. Waiting on j well support to remove wellhouse and Roads & Pads to prep area around well. Continued light rig maintenance. PRE PJSM. Prepared rig modules for move over well. PRE Spotted rig modules over DS 02-30B. PRE Continued spotting, leveling and berming rig modules over 02-30B. Spotted, bermed and plumbed Tiger tank. PRE PJSM. Raised and scoped derrick. Accepted rig 04:00 hrs 6/28/2007. PRE -PJSM. RU surface lines. RU 2nd inner annulus valve. Taking on 9.8 ppg brine to rig pits. P/T circulating lines to 3500-psi. DECOMP T/IA/OA = 0/0/0. P/T "XX" plug set in "X" nipple from below. Pumped into IA @ 5.0-BPM @ 200-PSI and noted a pressure increase on tubing to 200-PSI as well. Bled off tubing and IA. Connected circ. hose to tubing and pressured up tubing to 3500-PSI for +20 charted minutes. Tubing leaked off 150-PSI ' in 25 minutes. Reconnected circ. lines to IA and pumped into IA @ 5.0-BPM @ 500-PSI while monitoring tubing for flow out bleeder on mud manifold. Tubing blowing gas and then flowing liquid after 50-Bbls. brine pumped down IA. Verified that "XX" plug is leaking from below. DECOMP Wait on SWS slickline unit to arrive. DECOMP SWS slickline arrive on DS-02. PJSM -all crew: Reviewed 'rigging up wirleine procedure/process w/all crew.. DECOMP Rig up slickline with lubricator and full pressure control to top of tree cap. P/T lubricator - 250-PSI Lo, 3500-PSI Hi. DECOMP MU, RIH with retrieving tool. Latched and retrieved XX plug. DECOMP PU MU WRP. DECOMP RIH with WRP. Set @ 235'. DECOMP RU lines and tested to 3500 psi. DECOMP Attempted to test WRP. Pumped 37 bbls down annulus to catch fluid. Pumped 30 bbls down annulus at 6 bpm and 670 psi to test W RP from below. Pressured up on tubing to test WRP from above. WRP would not hold 3500 psi. Made numerous unsuccessful attempts with pressure loss of 100 psi to 300 psi in 10 minutes. DECOMP Waited on 2nd WRP. DECOMP MU WRP retrieving tool on slickline. RU lubricator and tested to 200 psi. RIH and latched WRP. Equalized pressure, pulled and retrieved WRP. DECOMP Held PJSM. Printed: 7/24/2007 4:05:08 PM • • BP EXPLORATION Operations Summary Report Page2of6~ Legal Well Name: 02-30 Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: WORKOVER Start: 6/27/2007 End: 7/6/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/6/2007 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT ' Phase ( Description of Operations __ _ - I - -- -- --- --- _ - -- 6/29/2007 02:30 - 03:30 1.00 KILL N DFAL DECOMP ~' Added 73 bbls 9.8 ppg brine down tubing. Reprogrammed WRP setting tool. MU W RP #2. 03:30 - 06:00 2.50 KILL N DFAL DECOMP I RIH with WRP #2. Set at 115'. POH with WRP setting tool. RD and set aside lubricator. Rig up lines to P/T WRP. 06:00 - 07:00 1.00 KILL N DFAL DECOMP P/T 4-1 /2" WRP set @ 115'. P/T WRP from above to 3500-PSI for 30 charted minutes. PSI leakoff over 30 minutes = 450-PSI. P!T W RP fdrom below for 15 charted minutes by pumping @ 6.0-BPM into IA. Took 38-Bbls. to fill hole. When hole full, pressure increased from 150-PSI to 200-PSI. Increased pump rate to 6.0-BPM and pressure increased to 500-PSI over 10 minutes. Reduced pump rate to 3.0-BPM and could not keep hole filled. S/D pumping and closed in well to 'formulate forward plan. 07:00 - 10:00 3.00 KILL N WAIT DECOMP Collaborate with Anchorage engineering support and slope well operations support to formulate forward plan. 10:00 - 11:00 1.00 KILL N DFAL DECOMP Pressure test 4-1/2" WRP @ 115'. Pressured up tubing to ~ 2500-PSI and noted a 50-PSI decrease in 10 minutes. :Increased pressure to 3000-PSI. leakoff 0 PSI in 10-minutes. Raised pressure to 3500-PSI. Leaked off 500-PSI in 70-minutes. Bled off pressure. FMC wellhead technician pressure tested casing packoff and tubing hanger packoff void to 5000-PSI -tested good. 111:00 - 13:00 2.00 KILL N WAIT DECOMP Wait on PDS leak detection specialist and tools to arrive. 13:00 - 14:30 1.50 EVAL N DFAL DECOMP PUMU PDS leak detection logging tools on wireline tool string. P/T lubricator t0 300-PSl Lo, 3500-PS! Ht. for 5 minutes. RIH to top of 4-1/2 W RP. Pressure up tubing to 3500-PSI and log i up to surface. 14:30 - 15:30 1.00 EVAL N DFAL DECOMP ,Drain down lubricator and disconnect from top of tree. BO/LD -'leak detection log tools. No data recovered from leak detection tools. Reset leak detection tools. 15:30 - 17:30 2.00 EVAL N DFAL DECOMP P/T lubricator to 300-PSI Lo, 3500-PSI Hi. for 5 minutes. RIH to top of 4-1/2 WRP. Pressure up tubing to 3500-PSI and log up to surface. 17:30 - 19:30 2.00 EVAL N DFAL DECOMP Drain down lubricator and disconnect from top of tree. BO/LD leak detection log tools. Log data showed possible leakage past WRP at 3500 psi. Consulted with well operations support, made decision to leave WRP in place and set 2nd WRP @ ~60'. Updated AOGCC re: possible initial BOPE test within 24 ~ hours. 19:30 - 21:00 1.50 EVAL N DFAL DECOMP Held PJSM. MU W RP ass't'. MU and armed WRP setting ass't'. 21:00 - 00:00 3.00 EVAL N DFAL DECOMP ~ RIH, set WRP @ 55'. Let firing head cool. POH with same, set slickline lubricator aside. 6/30/2007 00:00 - 01:30 1.50 DHB N DFAL DECOMP Tested WRP as follows: (1) pressured tubing above plug to 3500 psi, lost 150 psi / 22 minutes; (2) pressured tubing above plug to 3500 psi, lost 50 psi / 15 minutes; (3) pressured tubing above plug to 3500 psi, lost 25 psi / 10 minutes; bled pressure to 2000 psi then (4) repressured to 3500 psi, Post 20 psi / 10 minutes. WSL called test passing. 01:30 - 04:00 2.50 DHB N DFAL DECOMP RD test equipment. RD and offloaded slickline equipment and unit. Cleared rig floor. 04:00 - 05:00 1.00 WHSUR P DECOMP ND tree and adapter flange. FMC wellhead technician (inspected tubing hanger lifting threads and made up 4-1l2" IF x Printed. 7!24/2007 4:05:08 PM • • BP EXPLORATfON Operations Summary Report Page3of6~ Legal Well Name: 02-30 Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: WORKOVER Start: 6/27/2007 End: 7/6/2007 Contractor Name: NABOBS ALASKA DRILLING l Rig Release: 7/6/2007 Rig Name: NABOBS 4ES Rig Number: Date From - To ,Hours Task Code' NPT ~ Phase Description of Operations 6/30/2007 fi04:00 - 05:00 - 1.00 _ I _ - - _ _ _ _ - WHSUR P DECOMP 9" L.H Acme box x box XO to top of hanger. Counted 6.5 turns to makeup XO. 05:00 - 07:30 2.50 BOPSU P DECOMP Nipple up BOPE and rig up 3-112" and 5-1/2" test joints along with other test equipment. AOGCC notified of impending BOPE test. Right to witness ROPE test waived by John Crisp - AOGCC. 07:30 - 13:00 5.50 BOPSU P DECOMP Perform initial BOPE test per BP/AOGCC requirements - 250-PSI Lo, 3500-PSI Hi. Rig down BOPE test equipment. 13:00 - 14:00 1.00 DHB P DECOMP Nipple down flow riser. Nipple up shooting flange. 14:00 - 14:30 0.50 DHB P DECOMP PJSM -All crew -Rigging up and rigging down slickline unit and tools. 14:30 - 18:00 3.50 DHB P DECOMP Rigging up slickline unit, tools and equipment. Held crew change. Performed pre-tour checks. 18:00 - 19:00 1.00 DHB P DECOMP RIH with WRP retrieving tool. Latched WRP @ 55' and pulled free. POH, LD W RP. 19:00 - 19:30 0.50 DHB P DECOMP MU WRP running tool. RU lubricator and tested to 500 psi. RIH, latched WRP C~ 115' and pulled free. POH, LD 2nd WRP. 19:30 - 22:00 2.50 DHB P DECOMP Held PJSM. RD slickline equipment. ND shooting flange. NU drip pan, flow nipple, and riser. Shot fluid level in IA @ 474'. 22:00 - 00:00 2.00 PULL P DECOMP Held PJSM. MU landing joint. BOLDS. Pulled tubing hanger free with 115k Ib. PU to 240k Ib with 8' of stretch. Tubing would not pull free. 7/1/2007 00:00 - 01:30 1.50 PULL P DECOMP CBU. Took 96 bbls 9.8 ppg brine to reach circulation. Circ 5 bpm, 310 psi. 01:30 - 03:00 ~ 1.50 ~ PULL P DECOMP Worked tubing to 250k Ib PU with 8' of pipe stretch. Made no- 03:00 - 03:30 0.50 PULL N DPRB DECOMP RILDS. LD landing joint and circulation equipment. 03:30 - 05:30 2.00 FISH N DPRB DECOMP Held PJSM. Held H2S drill. RD flow riser and nipple. Removed drip pan. NU shooting flange. Cleaned rig floor. Called out SWS E-line to chemical cut tubing. 05:30 - 08:30 3.00 FISH N WAIT DECOMP Waiting on SWS E-line to arrive. 08:30 - 09:00 0.50 FISH N DPRB DECOMP PJSM -All rig crew &SWS E-line crew: Reviewed "Running Wireline Through Tubing" procedure and Rig 4ES "Guiding Principles" along with special precautions to be taken when running string shot and chemical cutter. 09:00 - 11:30 2.50 FISH N DPRB DECOMP MIRU SWS E-line equipment. Prepare to RIH w/2 strand string shot. 11:30 - 12:30 1.00 FISH N DPRB DECOMP RIH w/2 strand string shot on E-line. Correlate and log top of shot into position @ 7025'. Fired shot @ 12:45-hrs. POH w/E-line tool string. 12:30 - 14:30 2.00 FISH N DPRB DECOMP BO/LD string shot tools. PUMU 4-1/2" chemical cutter tool string. 14:30 - 16:00 1.50 FISH N DPRB DECOMP RIH w/chemical cutter tool string. tag up Q 6793' w/cutter head. Work tool string to get through tight spot. No-go. Collaborate w/RWO engineer -Worthington and agree to cut tubing @ middle of joint above tight spot which will put the cut 258' higher than was desired. Correlate cutter depth to tubing collars w/CCL. Fired shot @ 6777'. 16:00 - 18:00 2.00 FISH N DPRB DECOMP POH w/chemical cutter tool string. 18:00 - 20:00 2.00 FISH N DPRB DECOMP Crew change and PJSM. Performed pre-tour checks. RD E-line lubricator and set aside. ND shooting flange, NU drip pan, flow nipple, and riser. Printed: 7/24/2007 4:05:08 PM • • BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: 02-30 Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: WORKOVER Start: 6/27/2007 End: 7/6/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/6/2007 Rig Name: NABOBS 4ES Rig Number: Date I From - To ' Hours Task Code 7/1/2007 20:00 - 21:00 1.00 FISH ~P 21:00 - 21:30 ~ 0.501 FISH ~ P 21:30 - 23:00 I 1.501 FISH ! P 23:00 - 00:00 I 1.001 FISH I P 7/2/2007 100:00 - 06:00 I 6.001 FISH I P 06:00 - 07:30 I 1.501 FISH I P 07:30 - 08:30 1.001 FISH P 08:30 - 11:30 3.00 ~ FISH ~ P 11:30 - 17:00 I 5.501 FISH I P 17:00 - 18:00 {'{ 1.00 FISH P 18:00 - 20:30 I 2.50 FISH I P 20:30 - 21:30 I 1.001 FISH ( P 21:30 - 23:30 I 2.001 FISH I N 23:30 - 00:00 0.50 FISH N 17/3/2007 00:00 - 03:30 3.50. FISH N NPT '; Phase ' Description of Operations DECOMP MU landing joint to tubing hanger. BOLDS. DECOMP Pulled tubing hanger and tubing string free with 88k Ib PU. Pulled 40k Ib additional pulling hanger to floor. LD landing joint and tubing hanger. DECOMP RU to CBU. Filled well bore with 46 bbls, then circ total of 180 bbls. RD E-line service. DECOMP RU to LD tubing. POH, LD 4-1/2" tubing. First jt coated with fine sand. 8 jts LD @ 00:00 hrs. DECOMP Continued LD 4-12/" tubing. Added double displacement + 50 bbls/hr 9.8 ppg brine to well bore. 58 jts LD @ 02:00 hrs. 127 jts LD @ 04:00 hrs. Pulling string through wiper rubber, but many jts partially coated with granular scale. Held D1 drill @ 04:45 hrs. DECOMP 193 jts. POH @ 0630-hrs. 203 jts. POH @ 0715-hrs. Cut jt. (14.47') laid down @ 0730-hrs. Cut is uniform and smooth with no hanging chads and no belling to O.D. of pipe. Remainder of cut jt. left in hole is 17.41' in length. Recovered 203 full jts. of 4-1/2" tubing, 1 x 4-1/2" GLM w/2 x 10' 4-1/2" pups and 1 x 4-1/2" X nipple w/2 x 10' pups, 2 x 4' 4-1/2" pups, 1 x 4-1/2" 6' pup, 1 x 4-1/2" 8' pup, 1 x 4-1/2" 10' pup, 1 x 4-112" 3' XO pup and a 10" x 4-1/2" tubing hanger. All tubing and jewelry is in generally good condition with no visible corrosion on outside surfaces. Avery thin (2-3 mil) coating of what appears to be scale is adhering to outer surface of bottom 25 jts. POH. Breakout torque on bottom 8 connections was 4500-5100 ft-Ibs. on bottom of connections and 6000-7000 ft-Ibs. on top of connections. DECOMP Clear and clean rig floor and prepare to PUMU BHA #1. DECOMP PUMU BHA #1: 5-7/8" Overshot w/packoff, 1 x 4-3/4" lubricated bumper sub, 1 x 4-3/4" fishing jar and 9 x 4-3/4" drill collars. Shoot sonic fluid level. Fluid shot indicates fluid level @ 432 FFS. DECOMP RIH w/BHA #1 on 3-1/2" DP 1 x 1 from pipe shed. 100 jts. DP RIH @ 1330-hrs. Maintaining well control w/70-Bbls./hr. 9.8ppg brine. Tagged up @ 6353' with 192 jts. RIH. Set down 10K. Rigged up circulating hose and broke circulation @ 5.0-BPM @ 1070-PSI. Noted returns @ 26-Bbls away. Worked pipe and tagged up at same spot with 25K downweight. Circulated bottoms up @ 5.0-BPM @ 1080-PSI. DECOMP POH with BHA #1. DECOMP Held crew change and PJSM. Performed pre-tour checks. Continued POH with BHA #1, adding to well twice the tubing displacement + 50 bbl/hr of 9.8 ppg brine. DECOMP LD BHA #1. Stood back DC, broke out and photographed guide shoe (see S-Drive). Shoe was significantly deformed and showed signs of damaged 7-5/8" casing. Consulted with WO Engr Team Lead; determined need for additional information via lead impression blocks on slickline. DPRB DECOMP RD flow nipples. NU shooting flange in preparation for slickline operations. Continued to add 50 bbl/hr 9.8 ppg brine to well. DPRB DECOMP Spotted slickline equipment. DPRB DECOMP Held PJSM with all rig personnel and sllickline crew. Continued spotting and RU slickline equipment with full pressure control, Printed: 7/24/2007 4:05:08 PM • • BP EXPLORATION Operations Summary Report Page5of6~ Legal Well Name: 02-30 Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: WORKOVER Start: 6/27!2007 End: 7!6/2007 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 7/6/2007 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task 'Code NPT j Phase Description of Operations 7/3/2007 00:00 - 03:30 '_ - - -- 3.50 FISH - - -- - - -- - - -- - - - li N DPRB DECOMP including shooting flange, slickline BOPE, and (lubricator. 03:30 - 05:00 1.50 FISH N ~ DPRB DECOMP MU 6" LIB w/5.82" solid centralizer. Tested lubricator to 500 psi. RIH to tag. Tagged tight spot @ 6357' SLM. POH w/6" LIB. Inspected LIB and noted depression approx. 14" deep one one side. Photographed LIB and put pies in RWO we11 file on "S" drive. 05:00 - 06:15 1.25 FISH N DPRB DECOMP PUMU 5.5" LIB with 2 x bowspring centralizers. Makeup lubricator to extension and P/T to 500-PSI. 06:15 - 07:15 1.00 FISH N DPRB DECOMP RIH w/5.5" LIB. Tagged @ 6626' SLM. POH w/5.5" LIB. Inspect LIB and photograph. Indentation on LIB is identical to 6.0" LIB but with a small li cut into one side indication a shar edge looking up. Copied pies to RWO well file on "S" drive. 07:15 - 09:00 1.75 FISH N DPRB DECOMP PUMU 4.5" LIB. makeup lubricator extension top. P/T lubricator to 500-PS1. RIH w/4.5" LIB. POH w/ LIB. tagged @ 6785' SLM. Good picture of chemical cut 4-1/2" tubing. Called for PDS 40 arm caliper logging tools. Will plan to use 4.5" LIB 09:00 - i 1:00 ~I 2.00 FISH run as drift for PDS caliper log. N DPRB DECOMP Wait on PDS caliper logging tools to arrive. 11:00 - 18:00 ~ 7.00 FISH N DPRB DECOMP PUMU PDS 40 Arm caliper logging tools with extended arms. RIH w/same to 6,779' SLM. Log up to 2500' SLM. Examine date from caliper logs. Logs showed considerable damaged 18:00 - 18:30 ! 0.50 TA N DPRB DECOMP Wait on 6.1" wireline drift. 18:30 - 19:30 1.00 TA N DPRB DECOMP PUMU 6.1"drift and RIH to 6,364' WLM. POOH and UD drift. 19:30 - 20:30 1.00 TA N DPRB DECOMP R/D SWS tools and equipment. 20:30 - 21:30 1.00 TA N DPRB DECOMP N/D shooting flange, N!U flow line and bell Hippie on BOPE 21:30 - 22:30 1.00 TA N DPRB DECOMP PU bumper sub and jars. Make service breaks and VD. 22:30 - 23:00 0.50 TA N DPRB DECOMP PUMU HES 7-5/8" EZSVB squeeze packer and running tool. RIH on (3) stands of 4-3/4" drill collars from derrick. Total length of BHA #2- 284.46' 23:00 - 00:00 1.00 TA N DPRB DECOMP RIH with HES 7-5/8" EZSVB on 3-1/2" drill pipe for derrick. 7/4/2007 00:00 - 03:00 3.00 TA N DPRB DECOMP Continue RIH with HES 7-5/8" EZSVB on 63 stands and one single of 3-1/2" drill pipe for derrick to 6,292'. 03:00 - 03:45 0.75 TA N DPRB DECOMP Establish parameters of Up Weight- 108,000 Ibs and Down Weight- 72,000 Ibs. R/U and circuale at 3 BPM w/ 320 psi to clear debris from around EZSV. To set EZSV, rotate 37 right hand turns, get one back. Pull overpull in 10,000 Ibs increments with 2 minutes in between to allow elements to seat. Shear off with 52,000 Ibs overpull (160,000 Ibs). Too of EZSV @ 6,292', bottom of EZSV @ 6,295'. 03:45 - 04:30 0.75 TA N DPRB DECOMP POOH and UD one single 3-1/2" drill pipe. R/U and test EZSV to 1,000 psi for 30 minutes. Charted results. 04:30 - 06:00 1.50 TA N DPRB DECOMP POOH and UD 3-112' Drillpipe 06:00 - 06:30 0.50 TA N DPRB DECOMP Crew change. Inspect derrick & check PVT alarms. 06:30 - 07:30 1.00 TA N DPRB DECOMP Con't to POOH & UD 3 112" DP. 07:30 - 08:30 1.00 TA N DPRB DECOMP Cut & slip 137' of drilling line. 08:30 - 11:00 2.50 TA N DPRB DECOMP Finish POOH & UD 3 1!2" DP. 11:00 - 11:30 0.50 TA N DPRB DECOMP POOH, UD 4 3/4" DCs & running tool. 11:30 - 12:00 0.50 WHSUR N DPRB DECOMP P/U running tool & pull Wear Bushing. 12:00 - 13:00 1.00 ZONISO N DPRB OTHCMP Remove flow nipple & install perforating flange. 13:00 - 15:00 2.00 ZONISO N DPRB OTHCMP Hold PJSM w/ all hands &SWS. R/U e-line equip. 15:00 - 20:00 5.00 ZONISO N DPRB OTHCMP Run CMT USIT log in low resolution mode from 6,250' WLM to surface. Make repeat section pass over top of CMT. Top of Printed: 7/24/2007 4:05:08 PM s • BP EXPLORATION Operations Summary Report Page6of6~ Legal Well Name: 02-30 Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: WORKOVER Start: 6/27/2007 End: 7/6/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/6/2007 Rig Name: NABOBS 4ES Rig Number: Date 'From - To Hours I Task Code NPT I' Phase Description of Operations 7/4/2007 15:00 - 20:00 5.00 ZONISO N DPRB OTHCMP CMT at 2,055' with some ossible strin ers of CMT to 1,700'. 20:00 - 20:30 0.50 ZONISO N DPRB OTHCMP R/D SWS USIT logging equipment. R/D SWS e-line unit. 20:30 - 22:00 1.50 ZONISO N DPRB OTHCMP I R/D shooting flange on top of ROPE. R/U bell nipple and flow line. 22:00 - 22:30 0.50 ZONISO N DPRB OTHCMP R/U floor for running 3-1/2" tubing kill string. R/U power tongs and tubing handling equipment. 22:30 - 00:00 1.50 ZONISO N DPRB OTHCMP PJSM on handling and running tubing. P!U and RIH w/ 3-1/2", ~ ~ 9.2#, L-80, TC-II TBG. 7/5/2007 00:00 - 06:00 6.00 ZONISO N DPRB OTHCMP Continue P/U and RIH w/ 3-1/2", 9.2#, L-80, TC-II and NS-CT TBG. 06:00 - 06:30 0.50 ZONISO N DPRB OTHCMP Crew change. Inspect derrick & Check PVT alarms. 06:30 - 08:30 2.00 ZONISO N DPRB OTHCMP Con't to RIH w/ kill string. Ran total of 199 jts. WLEG @ 6264' , X Nipples @ 2112' & 6252'. 08:30 - 10:30 2.00 ZONISO N DPRB OTHCMP Displace hole w/ 290 bbls of 9.8 ppg Inhibited Brine. Pumped 4 BPM @ 440 psi. 10:30 - 11:30 1.00 ZONISO N DPRB OTHCMP M/U hanger & landing jt. Land hanger. RILDS. P/U Wt = 57K, S/O Wt = 45K. UD landing jt. 11:30 - 12:30 1.00 ZONISO N DPRB OTHCMP Install TWC w/ T-bar. R/U & attempt to test TWC from below. No success. Tested from top w/ 3500 psi, Ok. 12:30 - 14:30 2.00 ZONISO N DPRB OTHCMP P/U lubricator & pull TWC. Inspect same. looked good. Install new TWC. UD lubricator. attempt to test TWC from bottom,.. No good. 14:30 - 15:00 0.50 ZONISO N DPRB OTHCMP ' P/U lubricator & pull TWC. 15:00 - 16:00 1.00 ZONISO N DPRB OTHCMP M!U landing jt into hanger. BOLDS. Pull hanger to floor. 1/2" control line plug missing in hanger. Install & tighten new 1/2' plug. 16:00 - 16:30 0.50 ZONISO N DPRB OTHCMP Re-land hanger. RILDS and torque to 450 ft-Ibs. UD landing jt. ' Install TWC in hanger. 16:30 - 17:00 0.50 ZONISO N DPRB OTHCMP Pressure test TWC from bottom w/ 1000 psi for 10 min. held OK. Pressure up from top w/ 3500 psi for 10 min. Held Ok. Charted same. 17:00 - 20:00 3.00 BOPSU N DPRB OTHCMP N/D BOPE and adapter spool. 20:00 - 21:00 1.00 BOPSU N DPRB OTHCMP Change out damaged lockdown screw on TBG spool. N!U adapter flange and tree. Retorque LDS. 21:00 - 22:30 1.50 BOPSU N DPRB OTHCMP R/U and test adapter flange void to 5000 Ibs. Held test for 30 minutes. Good test. 22:30 - 23:30 1.00 BOPSU N DPRB OTHCMP R/U and test tree to 5000 psi. Held test for 10 minutes. Good test. 23:30 - 00:00 0.50 BOPSU N DPRB OTHCMP . Hold PJSM with rig crew and LRHOS for pumping freeze protection. R/U LRHOS. Test pumping lines to 2500 psi. Pump 20 bbls diesel freeze protection down annulus at 1.5 BPM w/ 500 psi. 7/6/2007 00:00 - 00:30 0.50 BOPSU N DPRB OTHCMP R/D CMT lines. R/U jumper hose and U-Tube well freeze protection. 00:30 - 01:30 1.00 BOPSU N DPRB OTHCMP DSM dry rod BPV in TBG HGR. R/U and test to 1000 psi for 10 minutes w/ LRHOS. R/D LRHOS. 01:30 - 02:00 0.50 BOPSU N DPRB OTHCMP `Secure Cellar and RDMO. Release Rig @ 02:00 hrs 7/6!07. Printed: 7/24/2007 4:05:08 PM T#tEE _ ~ ~ 4-1116" FMC 5M WELLHEAD= FMG5M ACTUATOR = KB. ELEV = BAKER 58.8' BF. ELEV = NA KOP = 790' Max Angle = Datum MD = 96 @ 11164' 10230' Datum TVD = 8800' SS ~ 02-30B ~ll~rg7 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" ~ 25' 10-3/4" CSG, 45.5#, J-55, ID = 9.950" 2558' 3-1/2" TBG, 9.2#, L-80 NSCT XO TO L-80 TCII 3449' 3-112" TBG, 9.2#, L-80 TCiI, .0087 bpf, ID = 2.992" 6264' 7-5/8" EZSV (07/04/07) 6292' 4-1/2" TBG STUB (07/01107) 6777' 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 7830' Minimum ID = 2.75" @ 72112' 3-1/2" HES X NIPPLE TOP OF WHIPSTOCK H 8062' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 7-5/8" EZSV RETAINER ~-~ 8102 3-1/2" TBG, 9.3#, 13-C R, .0087 bpf, ID = 2.992" I--I 9442' ~, 5-1 /2" X 3-1 /2" BKR CPH PKR, {D = 3.000" 9441' 5-1/2" X 3-112" BKR HMC HGR, ID = 3.000" 9445' 5-1/2" LNR, 17#, L-80, ID = 4.892" ~--~ 9618, PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 76 @ 10350' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10350 - 10834 C 10/11/00 2" 4 10898 - 11000 C 10/11/00 2" 4 11120 - 11239 C 10/11/00 2" 4 11320 - 11751 C 10/11/00 2" 4 11850 - 11900 C 10/11/00 0038' ~-i TOP OF SAND PLUG 11416' ~ FISH -BKR IBP PUSHED TO BTM 25, ~--~4-1/2" X 3-1/2" XO, ID = 3.958" 2112' 3-1/2" HES X NIP, ID = 2.75" 6252' 3-1/2" HES X NIP, ID = 2.75" ' 6265` --` 3-1/2" WLEG, tD = 2.992" GAS LIFE MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 3 7530 9148 6313 7706 32 35 KBMG KGB-2-LS "DMY "DMY BK INT 0 0 02/22/02 02/22/02 "'UKIGINAL WELLBUKt 7066' ECLIPSE PATCH, ID = 2.240" (BOTTOM SECTION) 7831' 4-1/2" X 3-112" TBG XO, ID = 2.992" 7897' BKR TIEBACK SLEEVE, ID = 5.750" 7904' 7-5/8" X 5-1/2" BKR ZXP PKR, ID = 4.875" 7910' 7-5/8" X 5-1/2" BKR HMC HGR, ID = 4.875" CSG MILLOUT WINDOW (OZ-30B) 8063' - 8088' 9346 - 9348 TBG PUNCH (06125107) 9360' CHEM CUT (06/26/07) 938T 5-1/2" X 3-1/2" BKR SABL-3 PKR, ID = 2.750" 9421' 3-1/2" HES X NIP, fD = 2.750" 9435' BKR TIEBACK SLV, ID = 5.750" ~ 9(-442' 1 3-112" WLEG, ID = 2.992" PBTD 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 08/25/91 ORIGINAL COMPLETION 06/26/07 RRD/PJC CHEM CUT, TBG PUNCH, FISH 02/04/97 RIG SIDETRACK (02-30A) 07!22!07 ?/ PJC DRLG DRAFT CORRECTIONS 10/11/00 RIG SIDETRACK (02-306) 07/06/07 N4ES RWO (02-306 SUSPENDED) 06!23/07 RRD/PJC PULL UPPER PATCH /FISH 06/25/07 SRB/PJC IBP PUSHED BTM/ SAND PLUG 11910' 119! PRUDHOE BAY UNfT WELL: 02-30B PERMfi No: 2001260 API No: 50-029-22202-02 SEC. 36, T11N, R14E, 5125' FSL & 4506' FEL BP Exploration (Alaska) Scblumbepg8P RECf:JVE[) ¡}CD- ( é)0 07/27/07 NO. 4346 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth JUL 3 0 zom Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 l\Iæta on & Gas. COI1S. CommissiQn rl Anchorage _ '" io..\1\\E.Ð. .. .. . A \j {j 0 1 'LOU ¡~v"- Well Job# og Description ae L o or 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/5-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 ....- 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 S8HP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-308 11626108 LDL 06/25/07 1 H-07 A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 8HP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 C8L & IMAGE LOG 07/21/07 1 01-15A 11849924 USIT 07/20/07 1 02-308 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 L D t B Field: Prudhoe 8ay Endicott C I CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Received by: glP Scblumblrg8r ¿;oO-{t90 . . ·CE···· fVE..·~r) R.E . -,,~ - 07/27/07 NO. 4346 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth JUL 3 0 ZOOl Iilasta Oil & Gas Cons: commi~~~"'Nt.O J\\J tj tJ 1 tWJ? An~ 'S~" Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Well Job# Loa Description Date BL olor CD 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/5-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 US IT 07/20/07 1 02-30B 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 C . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: glP Maunder, Thomas E (DOA) From: Sent: To: Subject: Maunder, Thomas E (DOA) Wednesday, July 04,20079:11 AM Worthington, Aras J RE: Well 02-308 RWOlWell suspension ~oo -. \ ()-<'.o Aras, As we spoke last night. I spoke with Commissioner Foerster and advised her of the situation with 2-30B. She concurs with the plan forward and by copy of this message you have her oral approval to proceed. Please advise Terrie that since the well will be suspended, the proper form is a 407. Good luck. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: Worthington, Aras J [mailto:Aras.Worthington@bp.comJ Sent: Tue 7/3/2007 9:09 PM To: Maunder, Thomas E (DOA) Subject: Well 02-30B RWO/Well suspension SCANNED JUL 0 5 2007 Tom, As per our conversation on the phone earlier, here are our plans for 02-30B. The background is that during the rig-workover we could not pull tbg from the cut near the packer and had to cut higher, above the patch-packer. We retrieved that tbg but could not get an overshot down to the tbg stub. We subsequently ran a caliper and found that the 7 5/8" liner was collapsed to -5.5" ID in four places above where the overshot hung-up. We plan to suspend the well pending a review of our options per the following procedure: 1. Run SL drift for EZSV plug (6.12" OD). 2. RU E-line, flanged to the top of the bag 3. Set an EZSV plug set up as a cement retainer (with a sting-in valve) as deep as the drift goes, probably -6300' based on the caliper data. 4. PT the 7 5/8" casing against the plug to 1000 psi for 30 minutes. 4. Run a USIT log on E-line to find the cement top behind the 7 5/8" casing (data for the assumed future sidetrack of the well). Log from the EZSV to surface. RD E-line. 5. Prepare to run an L-80/IBTM kill-string completion as follows: a) b) c) d) e) below) f) Wireline Entry Guide 1 j t. 3 1/2" tbg 2.812" HES X-nipple (10' pups above and below) 3 1/2" tbg 2.812" HES X-nipple set -2100' MD (10' pups above and New tbg hanger with competent BPV profile 6. Space-out to have WLEG - 60' above the EZSV. 7. Circulate the entire well to corrosion inhibited 9.8ppg brine (tbg and annulus) . 8. Land the tbg hanger and RILDS. 9. FMC to set TWC and test to 1000 psi from above/below for 10 min (charted) . 10. ND BOPE and NU adapter flange and tree. Test the tbg hanger, adapter, and tree to 5000 psi. 11. RU hot oilers to the annulus. PT lines to 3500 psi. Reverse in 90 bbls diesel ino inner annulus. RU jumper between IA and tbg. Allow IA and tbg to U- tube for 1 hour. RD hot oilers. 12. DSM/FMC to install BPV. Secure the tree and cellar. 13. RDMO. 2 06/29/07 Scblumbepgep RECEIVED NO. 4324 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth JUL 0 3 ZOOl Company: State of Alaska Alaska 011 & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ¡\læka Oil & Gas Cons. Commission Anchorage Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD H-13 11676950 GAS ENTRY SURVEY 06/20/07 1 C-41 11801077 LDL 06/19/07 1 A-30A 11661159 MEM PROD PROFILE 06/23/07 1 W-21A 11661140 MEM PROD PROFILE 04/21/07 1 E-21 B 11661157 MEM PROD PROFILE 06/19/07 1 M-23 11626107 PRODUCTION PROFILE 06/23/07 1 01-21 11824330 PRODUCTION PROFILE 06/22107 1 J-25A 11767130 MEM PROD PROFILE 06/18/07 1 Z-08A 11630483 GLS/PROD LOG 06122/07 1 M-34 11824330 PRODUCTION PROFILE 06/22/07 1 02-30B 11594512 LDL 06/23/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 S-38 11801078 LDL 06/20/07 1 H-37 A 11594506 PPROFIIPROF (REVISED) 06/05/07 1 N-15 11637129 PROD PROFILE (REVISED) 06/13/07 1 Z-13A 11649962 MEM PROD PROF (REVISED) 04/21/07 1 P2-15A 11594511 SCMT 06/15/07 1 12-05 11676951 US IT (CEMENT) 06/24/07 1 12-05 11676951 USIT (CORROSION) 06/24/07 1 B-15 11626097 USIT 06/14/07 1 G-24A 11628750 SCMT 02105/07 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2836 ATTN: Beth 5CANNED JUL ( 5 2007 Date Delivered: cJ(j) -t;;ì0 Received by: · . ~V&\VŒ ffi)~ &\~&\~æ&\ / AI/A~1iA. OIL AlQ) GAS / CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-30B. ^ (/) Sundry Number: 307-133 O....I(Jß' SCANNED APR 2 3 2007 ~() Dear Mr. Reem: 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, DATED this 1i day of April, 2007 Encl. or5 ~ 4 ¡q-07 ~ " - STATE OF ALASKA _~/~I?~ RECEIVED A/I ql7 ALASKA Oil AND GAS CONSERVATION COM~ION ~,'t APR 1 6 Z007 ,- I APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate o Time Extensioltnchorage o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 200-126 : 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22202-02-00 - 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 02-30B - Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028308 . 58.8' - Prudhoe Bay Field / Prudhoe Bay Pool , 12. PRESENT WELL t.;L NUIIIUN~I··· .~ .. -. I . ..... ........... .i.. ·.i\c\i Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12362 . 8910 - 11910 8902 None None Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2558' 10-3/4" 2558' 2361' 3580 2090 Intermediate 8063' 7-5/8" 8063' 6768' 6890 4790 Production Liner 1721' 5-112" 7897' - 9618' 6624' - 8301' 7740 6280 Liner 2548' 3-1/2" 9435' - 11983' 8119' - 8905' 10160 10530 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10350' - 11900' 8899' - 8902' 4-112",12.6# x 3-1/2",9.3# 13Cr80 9442' Packers and SSSV Type: 5-112" x 3-1/2" Baker 'SABL-3' packer I Packers and SSSV MD (ft): 9387' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory ~ Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: May 15, 2007 ~Oil DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-4102 Printed N~Vld Reem Title Drilling Engineer Date (oj¡,lð 7 Prepared By Name/Number: Signature ./I1l1-l-- Phone 564-5743 Terrie Hubble, 564-4628 Commission Use Onlv I Sundry Number: ~O 7 .. J ~~~ Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity OO,BOP Test D Mechanical Integrity Test D Location Clearance Other: ~5CO~?--~ -ro,<~"?~ <J...", ~\CÅ~~ 5'CANNED APR 2 3 2007 Subsequent Form Required: '-\G~~¡ 'I ~ ~OMMJSSIONER APPROVED BY Date T -/'7-I)~ Approved Bv: THE COMMISSION Form 10-403 Revised 06/2006 V """ V, Submit In Duplicate ORIGINAl FØJMS 8FL APR 2 0 2007 . . OS 02-308 Rig Workover Scope of Work: Pull 4 W' x 3-W' L-80 completion, Run 51/2" scab liner from -2800' to -7900' md and cement. Run 3-W' x 4 W' 13Cr-80 completion. MASP: 2400 psi Well Type: Ivishak Producer Estimated Start Date: May 15, 2007 P k re-rla DreD wor : 1. 0 Bleed OA, IA & T to zero psi. PPPOT - T & IC. Function all LDS and repair / replace as necessary. 2. S Pull Eclipse patch @ 7035' MD. 3. S Drift 4-1/2" x 3 %" tubing for Fasdrill and chemical cutter down to 9650' md. 4. E Set 3 %" Fasdrill plug in the 3 W' liner @ -9600' md 5. E String shot and punch the tubing near the top of the first full joint above the production packer (-9355'md). Chemical cut the 3-1/2" 13Cr-80 tubing at -9360' md in the middle of the first full joint above the packer. Reference the tubing tally dated 10/9/2000 6. F Circulate the well bore clean with 9.8 ppg brine. Freeze protect as needed (tree/wellhead only). 7. 0 Set a back pressure valve in the tubing hanger. 8. 0 Remove the well house, remove the flow lines and level the pad as needed. Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-1/2" x 5" VBR pipe rams. Pressure test to 3500 psi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circulate well to clean kill weight brine through the cut. 2. Pull and LD 4 %"" x 3-W' tubing string to the cut. 3. Set RBP in 5 %" liner 4. Run and fully cement new 5 1/2" scab liner from -2800' to 7900' md. 5. Drill out shoe-track and PT casing to 3500 psi f/30-minutes~ L->.. _ \') 'Q. \:) _ \ 6. Run 4-W' x 3 W' 13Cr-80 completion with Baker S-3 packer. ~"n 'CL~<è:... \'-.,:::>\ ~Q.C--~\o 7. Displace the IA to packer fluid and set the packer. i gryJ\ 8. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. yrJ- . \.\( 9. Set BPV. ND BOPE. NU and test tree. RDMO.\.~ , . TREE = 4-1/16" FMC5M SAF TES: ***4-1/2" X 3-1/2" CHROME TBG*** WELLHEA 0 = FMC-5M WELL ANGLE> 70' @ 10321' & > 90' @ 10696'. PRE- 02- ACTUATOR = BAKER 02-308 30B SDTRK WELLBORE NOT SHOWN BELOW KB. ELEV = 58.8' WHIPSTOCK 02-30A P&A'D W/CMT. DO NOT SET BPV. BF. ELEV = NA SEE DRLG REPORT FOR 10/12/00. KOP= 790' Max Angle = 96 @ 11164' Datum MD = 10230' Datum TVD = 8800' S5 I I 2199' -14-1/2" HES X NIP, 10 = 3.813" I µ ~ GAS LIFT MANDR8...S 110-3/4" CSG, 45.5#, J-55, 10 = 9.950" I 2558' ST MD TVD DEV TYÆ VLV LATCH PORT DATE L 1 4356 3806 37 KBMG DMY BK 16 09/06/02 2 7530 6313 32 KBMG DMY BK 0 02/22/02 Minimum ID = 2.24" @ 7035' 3 9148 7706 35 KGB-2-LS DMY INT 0 02/22/02 ECLIPSE PATCH ~ t I 7035' -1 ECLIPSE PA TCH, 10 = 2.240" I I 7066' -i BOTTOM PATCH I 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" I 7830' I -4-1/2" X 3-1/2" TBG XO, ID = 2.992" I I 7831' I 7897' -1 BAKER TIEBACK SLEEVE, ID = 5.750" I ~ ) 7904' -17-5/8" x 5-1/2" BKRZXP A<R. 10 = 4.875" I i - 7910' -17-5/8" x 5-1/2" BKR HMC HGR, 10 = 4.875" I TOP OF WHIPSTOCK I 8062' I 7-5/8" CSG MILLOUT WINDOW (02-308) I 8063' - 8088' (OFF WHIPSTOCK) I 7-5/8" CSG, 29.7#, L-80, 10 6.875" J 9387' -15-1/2" x 3-1/2" BKR SABL-3 PKR, 10 - 2.750" , 17-5/8" EZSV RETAINER I 8102' I 9421' H 3-1/2" HES X NIP, 10 - 2.750" I :-I 9435' H BKRTIEBACK SLV, 10- 5.750" I I 3-1/2" TBG, 9.3#, 13-CR, .0087 bpf, 10 = 2.992" I 9442' ~~l 9442' H 3-1/2" WLEG, 10 2.992" I 15-1/2" X 3-1/2" BKR CPH PKR, 10 = 3.000" H 9441' I ~ Y 15-1/2" X 3-1/2" BKR HMC HGR, 10 = 3.000" 1 9445' 15-1/2" LNR. 17#, L-80, 10 = 4.892" I 9618' ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ANGLEATTOPÆRF: 76 @ 10350' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2" 4 10350 - 10834 0 10/11/00 2" 4 10898 - 11 000 0 10/11/00 2" 4 11120 -11239 0 10/11/00 2" 4 11320 - 11751 0 10/11/00 2" 4 11850 - 11900 0 10/11/00 1 PBTDI 11910' I .A' 13-1/2" LNR, 9.3#, L-80, .0087 bpf, 10 = 2.992" 1 '" 11983' µ !"\ ."R ~ >'" 12362' r- DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 08/25/91 ORIGINAL COMPLETION 09/03/06 TWS/PAG SET BKR IBP @ 9405 WELL: 02-308 02/04/97 RIG SIDETRACK (02-30A) 10/17/06 SKBITLH WArI/ER SFTY NOTE DELETED ÆRMIT No: 2001260 10/11/00 RIG SIDETRACK (02-30B) 02/27/07 KSB/TLH IBP FULLED 9/20/06 API No: 50-029-22202-02 08/21/05 WJH/TLH IBP SET SEC. 36, T11N, R14E, 5125' FSL & 4506' FEL 09/14/05 JLIvVTLH GLV C/O (09/06/02) 08/14/06 A LHlPJC IBP @ 9405 PULLED (9/22/05) BP Exploration (Alaska) .. .. TREE = /16" FMC 5M WELLHEAO = FMC-5M SAF TES: -4-1/2" X 3-1/2" CHROME TBG- AClUA TOR = BAKER 02 -3 0 B Proposed WB.L ANGLE> 700 @ 10321' & > 900 @ 10696', PRE- 02- KB. ELEV = 58.8' 30B SDTRK Wa.LBORE NOT SHOWN BB.OW BF. ELEV = NA WHIPSTOCK. 02·30A P&A'DW/CMT, DO NOT SET BPV. KOP= 790' I 1- SEE DRLG REPORT FOR 10/12100. Wax Angle = 16 @ 11164' ..... Datum MO = 10230' --r 2000' 1-14-112" HES X NIP. ID = 3.813" I Datum TVO = 8800' 55 /~ -2700' 1-14-112" X 3-112" TBG XO. ID = 2.992" I 14-112" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" H -2700' yJ ./ ~ 110-314" CSG, 45.5#, J-55, ID = 9.950" I 2558' ~ --+ BAKER ZXP PKR I Minimum ID = 2.24" @ 7035' ~ GAS LIFT MANDRELS ~ ST MD TVO DEV TYPE VLV LATCH PORT DATE ECLIPSE PATCH 1 3799 3350 37 KBG-2-9 DMV BK 2- õ727 5650 32 KBG-2-9 DMV BK 15-112" LNR, 17#, L-80, ID = 4.892" -I 7897' H BAKER TIEBACK SLEEVE, ID = 5.750" I ~ 7904' -1-17-518" X 5-112" BKRZXP PKR, ID = 4.875" I I 7910' H7-5I8" X 5-112" BKR HMC HGR, ID = 4.875" I ~ 7-518" CSG MlLLOUTWlNOOW (02-3OB) 8063' - 8088' (OFF WHIPSTOCK) 1 TOP OF WHIPSTOCK H 8062' 1-- '\ I- 3-112" HES X NIP, 10- 2.813" I 17-518" CSG, 29.7#, L-80, ID = 6.875" I--- H5-112" X 3-112" BKR SABL-3 PKR, 10= 2.790" 3-112" HES X NIP, 10 = 2.750" I 3-112" TBG, 9.3#, 13-CR, .0087 bpf, 10 = 2.992" H ] 5-112" X 3-112" UNIQUE OVERSHOT I 7-5/8" EZSV RETAINER H 8102' I 'l ~ 9387' -15-1/2"X3-112"BKRSABL-3PKR,ID=2.750" I I ~"" 1-1 3-112" HES X NP, ID' 2.750" I 9435' 1-1 BKR TIEBACK SLV, ID = 5.750" 1 1 15-1/2" X 3-112" BKR CPH PKR, ID = 3.000:J-i 9441' I 'I¡ Þ\ 15-112" X 3-112" BKR HMC HGR, ID = 3.000" 9445'-V 15-112" LNR, 17#, L-BO, ID = 4.892" I 9618' PERFORATION SUIVMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 76@ 10350' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERVAL OpnlSqz DAlE 2" 4 10350 - 10834 0 10/11100 2" 4 10898-11000 0 10/11100 2" 4 11120-11239 0 10/11100 2" 4 11320 - 11751 0 10/11100 2" 4 11850 - 11900 0 10/11100 I PBID 11910' .LI' -~r 13-112" LNR, 9.3#, L-80, .0087 bpf, 10 = 2.992" I .. 11983' :Þ r=ï t' I L.:..::..J DAlE REV BY COMMENTS DATE REV BY COMMENTS PRU[H)E BAY UNIT 08/25191 ORIGINAL COM PlETION 09103106 1WSIPAG SET BKR IBP@ 9405 WELL: O2-30B 02104197 AG SIDETRACK (02-3OA) 10/17106 SKB/TLH WAIVER SFTY NOlE DELETED PERMIT No: 2001260 10111/00 AG SIDETRACK (02-308) 02rZl107 KSB/TLH IBP PULLED 9120106 API No: 50-029-22202-02 08121/05 WJI-Vll.H IBP SET SEC. 36. T11 N, R14E, 5125' FSL & 4506' Fe. 09114105 JLNVTLH GL V C/O (09106I02) 08114106 AL~PJC IBP @ 9405 PULLED (9122105) BP Exploration (Alaska) 02-30B (PTD 2001260) Waiver Canceled, Re.ified to Trouble . Helloal!. The production casing leak waiver for well 02-308 (PTD 2001260) has been canceled and the well reclassified to Trouble. The well failed a recent IA no-flow test and a RWO is planned. Lead Operator: would you please ensure any waiver related signage is removed from the well house. Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com i;:il[]¿'1Nt~ên Ct I of I 10/23/2006 4:57 PM Schlurnberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED NO\! 292005 ~D b-- /J-C¡; Well Job# log Description Date Bl 02-30B !}[)() - , ri(r, 10980581 RST 07/17/05 1 PSI-01 10674389 RST 10/27/03 1 PSI-07 10619045 RST 12/26/03 1 l3-02 11072860 RST 06/13/05 1 X-16A 10980531 RST 03/01/05 1 F-30 10987523 RST 06/22/05 1 W-31 10913021 RST 06/30/05 1 Z-15 10980580 RST 07/10/05 1 C-30 10980583 RST 07/13/05 1 W-39A 10928650 MCNl 10/16/05 1 18-31A 10942210 MCNl 04/28/05 1 H-02A 10928622 MCNl 04/05/05 1 05-24A 10928609 MCNl *(PRINT SENT 1/24/05) * 12/22/04 K-06A 11015903 MCNL 07/30/05 1 l-03 10913041 OH lDWG EDIT FOR WIRELlNE DATA 08/01/05 2 B-02A 10889169 SCMT 09/22/04 H-05 10614401 CBl 01/21/04 G-13A 10563115 SCMT 06/17/03 E-06A 11051045 SCMT 05/19/05 W-20 10672389 USIT 06/03/04 MPF-81A 10108043 USIT 01/08/04 MPA-03 11058243 USIT 09/07/05 MPF-89 11051088 USIT 08/17/05 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: \ \r. ...., ",'\' \.....r if v\ \" 0\CO/-.... ~,\ "k \.12\. ~ Û } u . ~-d NO. 3602 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 1th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. Color 1 1 1 1 1 1 1 1 1 CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 3 ?;'1:)- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth /' r' ~ Received by: tUtßJ[ t --.,eJJ0 Q.r l/ (.j 11/17/05 '-""" .~ ") STATE OF ALASKA 'I~ AlAv...:Ä Oil AND GAS CONSERVATION COMIV,.-.JSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 58.8 KB 8. Property Designation: ADl-028308 11. Present Well Condition Summary: Total Depth measured 12362 true vertical 8909.56 Effective Depth measured 11910 true vertical 8902.45 Casing Conductor Surface Production Liner Liner length 80 2529 8035 1708 2538 Size 20" 91.5# H-40 10-3/4" 45.5# J-55 7-5/8" 29.7# l-80 5-1/2" 17# l-80 3-1/2" 9.3# l-80 Perforation depth: Measured depth: 10350 - 10834 True Vertical depth: 8898.61 - 8917.89 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations x Plug Perforations 0 Perforate New Pool D Perforate D 4. Current Well Class: Development I;?' Stratigraphic StimulateD . .Ot~~r D" Waiver D Time Extens·ibnD Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory Service 200-1260 6. API Number: 50-029-22202-02-00 9. Well Name and Number: 02-30B 10. Field/Pool(s): PRUDHOE SAY Field/ PRUDHOE Oil Pool feet feet Plugs (measured) Junk (measured) 9405 None feet S(;ANNe~,) NOV @ 92005 feet MD TVD Burst Collapse 30 - 11 0 30 - 110 1490 470 29 - 2558 29 - 2360.82 3580 2090 28 - 8063 28 - 6768.1 6890 4790 7910 - 9618 6635.62 - 8301.43 7740 6280 9445 - 11983 8128.7 - 8904.91 10160 10530 1 0898 - 11 000 11120 - 11239 11320 -11751 8913.1 - 8910.02 8909.8 - 8901.91 8901.93 - 8901.66 4-1/2" 12.6# 13CR80 25 - 7830 5-1/2" Baker ZXP Hydro Set Packer 7904 3-1/2" Baker SABl-3 Packer 9387 3-1/2" BAKER CPH PACKER 9441 RBDMS BFl SEP 2 6 2005 Representative Daily Average Production or Injection Data Gas-Met I Water-Bbl I Casing Pressure SHUT - IN SHUT - IN 15. Well Class after oroposed work: Exploratory r Development P 16. Well Status after proposed work: Oil P Gas' WAG' GINJ' Tubing pressure Service , WINJ r WDSPL í 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal ~ . / Signat~.7.kU Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 Date 9/21/2005 ¡ '-', ~ ¡ \ -~ \. I', \ '^ II ¡ '/ '\ ;"'i. . ¿ 1" \ '.....,~" Submit Original Only 1" ) ) ". 02-308 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/20/2005 **** WELL SHUT IN PRIOR TO ARRIVAL (PRE-IBP SET) **** DRIFT W/ 2.233" CENT AND SAMPLE BAILER TO 10, 312' STOPPED DUE TO DEVIATION. NO SAMPLE RECOVERED. ***TURN WELL OVER TO DSO - LEFT WELL SHUT IN*** 8/21/2005 2.13" BAKER IBP SET AT 9505'. TOP IBP: 9397.88'. CENTER ELEMENT: 9405'. BOTTOM IBP : 9409.38'. 1.375" EXTERNAL FISHING NECK - 5500 LBS TO PULL RELEASE DRILL SITE OPERATOR NOTIFIED UPON DEPARTURE. *** JOB COMPLETE *** 8/22/2005 Cant. on 8-23-05 T/I/O= 550/240/0 Pumped 10.4 bbls crude for MITx T @ 3000 psi. (PASSED) on 2nd attempt, Loss of 40 psi. 1 st 15 min. Loss os 20 psi. 2nd 15 min. FWHP= 500/250/0 8/23/2005 Continued from 8-22-05 Finish bleeding pressure, Rig down surface lines. FWH P= 500/250/0 8/24/2005 T/I/O = 550/200/vac. Temp = SI. TBG FL @ 160' (2.4 bbls) (for MITT). FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL F:\LaserFiche\CvrPgs _I nserts\M icrofi 1m _Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE .;.,:=~ 1".' ~':Jr- '-"" !i: :0-: ) ) STATE OF ALASKA ALASKA OIL AND, GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ RE-SQZ gA w/CMT Pull tubing _ Alter casing _ Repair well _X Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 154' FNL, 4506' FEL, Sec. 36, T11N, R14E, UM At top of productive interval 1911' FNL, 1370' FEL, Sec. 26, T11N, R14E, UM At effective depth 1518' FNL, 2630' FEL, Sec. 26, T11N, R14E, UM At total depth 1090' FNL, 2776' FEL, Sec. 26, T11N, R14E, UM 5. Type of Well: Development _X Explorato~._ Stratigraphic._ Service_ (asp's 687504, 595104~,~ (asp°s 685272, 5954513) (asp's 684002, 5954875) (asp~ 683845, 5955299) 12. Present well condition summary Total depth: measured true vertical 12362 feet 8910 feet Plugs (measured) 6. Datum elevation (DF or KB feet) RKB 59 feet 7. Unit or,Property name Prudhoe Bay Unit 8. Well number 02-30B 9. Permit number / approval number 'J 200-126 10. APl number 50-029-22202-02 11. Field / Pool Prudhoe Bay Field / Prudhoe Ba~/Oil Pool Tubing Patch @ 7035'-7066', MIN ID = 2.24" Effective depth: measured true vertical 11910 feet Junk (measured) 8902 feet Casing Length Conductor 110' Surface 2527' Intermediate 8032' Liner 1721' Sidetrack Liner 2548' Size Cemented Measured De~t~........ True Vertical Depth 20" 99 cf ArcticSet 141' 141' 10-3/4" 2563 cf Cold Set III, 405 2558' 2361' cf Class,'G' 7-5/8" 1369 cf Class 'G' 8063' 6768' 5-1/2" 225 cf Class 'G' 7897' - 9618' 6624'- 8301' 'G' 3-1/2" 225 cf Class ~~F~~li~tl .~ ""'"-ai~st"~l~'~ 8119'-8905' Perforation depth: measured Open Perfs 10350'-10834', 10898'-11000', 11120'-11239', 11320'-11751 ', 11850'-11900'. true vertical Open Perfs 8899'-8918', 8913'-8910', 8910'-8902', 8902'-8902', 8901 '-8902'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-CR, TBG @ 7830'. 4-1/2" x 3-1/2" XO @ 7830'. 3-1/2", 9.3#, 13-CR, TBG @ 9442'. Packers & SSSV (type & measured depth) 7-5/8" x 5-1/2" BKR ZXP PKR @ 7904'. 5-1/2 x 3-1/2 BKR SAB',~~."~.~:~,7~,,~,,, ~ ~ 5-1/2" x 3-1/2" BKR CPH PKR @ 9441'. 4-1/2" HES X Nipple @ ~i~J~.~?~ .... ~v ~ ........... " 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) ~j~j~ ¥ 0 ~ ~.ij,~, j Treatment description including volumes used and final pressure ,~,t~,,,.~ l'~? ~'; ~':~;~:: ~,:~.~';~ ',i ,~ ~,'?~! ~?t 14. Reoresentative Daily Averaae Production or Iniectior~ 'l~a~;'& ...... ~,.¥.',%~'~L.~'~' ~ '-~ Oi,-Bb, Gas-Mcr Water-Bb, C a s~ n"g' ~:~u~ Tubing Pressure Prior to well operation 04/01/2003 2283 20080 54 204 Subsequent to operation 04/26/2003 2270 24523 77 204 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ 16. Status of well classification as: Oil _X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~e R~.,~~)~ Title: Techica. Assistant DeWayne R. Sc norr RBDM8 BFL NAY 6 2003 Form 10-404 Rev 06/15/88 · ORIGINAL Date April 30. 2003 Prepared by DeWa},ne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 03/14/2003 03/15/2003 03/16/2003 03/16/2003 03/19/2003 03/19/2003 03/20/2003 04/03/2003 04/06/2003 04/11/2003 04/23/2003 03/14/03 03/15/03 03/16/~3 03/16/03 03/19/03 03/19/03 03/20/03 04/03/03 02-30B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND REPAIR): REPAIR): REPAIR): REPAIR): REPAIR): REPAIR): REPAIR): LOAD WELL TO SECURE CEMENT SQUEEZE AC-MONITOR MIT-OA AC-LNFT MIT-OA ,/ NF.D 1 2003 AC-MONITOR ANN-COMM (AC-EVAL AND REPAIR): AC-EVAL; AC-FLUID LEVEL CEMENT SQUEEZE: CEMENT SQUEEZE ANN-COMM (AC-EVAL AND REPAIR): AC-MITOA TESTEVENT --- BOPD: 2,816, BWPD: 68, MCFPD: 25,903, AL Rate: 0 EVENT ~UMMARY LOAD Ia WITH 10 BBLS NEAT, 400 BRINE, AND 10 BBLS NEAT. MIRU DOWELL CEMENTER (JOST): WELL FLOWING ON ARRIVAL @ 500 PSI. SQUEEZED OA WITH 45 BBLS ARCTIC SET 1 CEMENT. LEFT ~25 BBLS CEMENT IN THE OA AND -20 BBLS PAST THE SHOE. DID NOT SEE MUCH SQUEEZE PRESSURE BUILDUP. RDMO, WELL LEFT FLOWING. T/I/O = 500/60/170. TEMP = WARM. MONITOR WHP's. (POST OA SQUEEZE, SECURE WELL). IA AND OA FL's @ SURFACE. MIT OA TO 3000 PSI --- FAILED --- PUMPED A TOTAL OF 5 BBLS DIESEL @ 0.5 BPM. SAW PRESSURE BREAKDOWN. DID NOT ESTABLISH INJECTION RATE. T/I/O = 500/12/97. LNFT-IA PASSED. NA A/L LINE ON WELL. IA AND OA FLs @ SURFACE. BLED OA FROM 97 PSI TO 0 PSI IN 1 MINUTE (6 GALLONS). BLED IA FROM 12 PSI TO 2 PSI IN 1 HOUR 30 MINUTES - 2 BBLS METHANOL. NOT ENOUGH PRESSURE TO PUSH FLUID TO SLOP TRAILER. BEGAN LNFT. BLED 1 GALLON IN 1 MINUTE. BLED AN ADDITIONAL 15 GALLONS TO BUCKET. BEGAN LNFT. BLED 1 GALLON IN 30 MINUTES. FINAL WHPs = 500/0+/5. MIT OA TO 3000 PSI. --- FAILED --- ESTABLISHED INJECTION RATE OF 2 BPM @ 1500 PSI. T/I/O=500/0/20. TEMP - WARM. MONITOR WHP's. POST LNFT - IA (PC LEAK). OAP IS UP 15 PSI, FROM PREVIOUS DAY. TIO= 640/50/190 PREP FOR OA DOWN SQUEEZE. IA & OA FLs @ SURFACE. Page 1 02-30B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/06/03 SQUEEZED OA WITH 47 BBLS OF 15.7 PPG AS-1 CEMENT. LEFT TOC @ 1979' WITH A MINIMUM OF 24 BBP CEMENT. BUILT ~ 350 NET SQUEEZE PRESSURE TO 680 PSI. WELLL WILL BE READY FOR MITOA TO 3000 PSI ON 04-11-03. 04/11/03 MIT OA TO 3000 PSI PASSED WITH 2 BBLS OF DIESEL. 04/26/03 TESTEVENT --- BOPD: 2,270, BWPD: 77, MCFPD: 24,523, AL RATE: 0 FLUIDS PUMPED BBLS 20 NEAT 49 60/40 METHANOL WATER · 7 DIESEL 163 CRUDE 4O0 BRINE 92 ARCTIC SET 1 CEMENT @ 15.7 PPG. 40 CW101 455 FRESH WATER 1226 TOTAL 6CANNED f A¥ 1l 5 20D3 Page 2 Permit to Drill 2001260 MD 12362 TVD DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. PRUDHOE BAY UNIT 02-30B Operator BP EXPLORATION (ALASKA) INC 8910 Completion Dat 10/11/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22202-02-00 UIC N REQUIRED INFORMATION Mud Log No Sample No Directional Survey N__~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name Log Log Scale Media Run No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint OH I CH Dataset Received Number ..Comments 8/9/2001 10238 -~7811-12294 T T R R D_./- D R R D~ D R R D D R R C C L L L L L L L L Lo Le Leak~....~ Lo Le Leak~..,...,~'~''~ ,9~'~'y Report4~.~ ey Report ,-.---- Survey Report ~ Survey Report~ ~ I'~ ~'/urvey Reportd-'/ =~urvey Report---"~ t) -{ · LIS Verificationj 10238 "~ LisVeriflcatior~ 10384~ Access SSTVD 2 .~i~Access Prorsity 5 /:~l~m Access Neutron 2 ' S~i~onicACCeSS Array 2/5 Blu Blu FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL 7811 7810 10447 10447 10447 10447 8034 8034 7810 9536 9620 9620 9620 9620 100 100 12294 Open 11670 Open 12362 12362 12362 12362 11739 11739 11670 OH OH oh oh 10240 OH 10250 CH 10250 CH 10250 CH 10250 CH 8585 Case 8585 Case 8/2/2001 1/9/2001 1/9/2001 1/9/2001 1/9/2001 1/9/2001 1/9/2001 8/2/2001 8/2/2001 8/13/2001 8/13/2001 10/15/2001 10/16/2001 10/16/2001 10/16/2001 10/16/2001 11/8/2002 12/10/2002 10202 ~810-11670 10447-12362 Digital Data 10447-12362 Paper Report 10447-12362 Digital Data 10447-12362 Paper Report 8034-11739 Digital Data //~:)34-11739 Paper Report 10202" 7810-11670 Digital Data LIS Verification, Paper Copy 10238/~Lis Verification Digital Data _ ~Verification Paper Copy 10384 "'9536-10240 Digital Data 9620-10250 BL, Sepia 9620-10250 BL, Sepia 9620-10250 BL, Sepia 9620-10250 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments Permit to Drill 2001260 MD 12362 TVD DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. PRUDHOE BAY UNIT 02-30B Operator BP EXPLORATION (ALASKA) INC 8910 Completion Dat 10/11/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22202-02-00 UIC N ADDITIONAL INFORMATION Well Cored? Y~) Chips Received? ~ Analysis R~.c.~.iv~.d ? Daily History Received? Formation Tops )/N Comments: Compliance Reviewed By: 12/09/02 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2586 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD O.S. 4-04 I "']O-O~/~ PRODUCTION PROFILE 1~i29102 D.S. 4-20 ,~ ,~'c>~ - jz~ ~ LDL 10126102 A-42 ,. ~ ~-//~ PRODUCTION PROFILE J0117102 H-~4A I ~ - ~ LDL 1 ~124102 PSI-06 ~-O~ SaHPSURVEY 14119102 PSI-09 ~O ~- /~ SASE TEMPI JEWELRY LOG 07~29~02 NKk2 ~ ~q' / O ~ PROD PROFIL~DEFT 10123102 R-14 !~,~0~ ~ LDL 10128102 D.S. 2-30B ~ OO- I~ LDL 10125102 D.S. 9-39 ]~/-~]~ INJECTION PROFILE 10130102 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND,RETU. I~NIN,.G ONE COPY EACH TO: BP Exploration(Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. ~_:jV~ Anchorage, Alaska 99508 DEC Date Delivered: 0[{ & Cons. mmlss a Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A3-1'N: Beth 11104102 Schlumberger Alaska Date &' Consulting Services 3940 Arctic Blvd, Suite 300. Anchorage, AK 99503-57tl ATrN: Beth NO. 2530 Corcpany: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wespie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date Blueline Color Sepia Prints CD ,'~ NK-27 ~ INJECTION PROFILE 10/22/02 '1 ~1~ NK-27 --- ----- -' STATIC SURVEY 1i)122/02 1 r' D.S. 2--30B~---~'~'~/~:..<' !~ LEAK DETECTION LOG 10125102 J-27 F<F7--O 5~' LEAK DETECTION LOG 10/17/02 -. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd.' Anchorage, Alaska 99508 Date Delivered: RECEIVED NOV 0 8 2002 A~ch~ge Schlumberger GeoQuest 3940.Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 10/15/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. 1531 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite t00 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD F-4t I c~/~/~¥.. 21410 RST 09/09/01 1 I t H-13 I ~l-01"'7 21390 CNTG 08/01101 I 1 1 D.S. 2-30B 20434 SLIM ACCESS ARRAY SONIC/NEUTRON/POROSITY 10/07100 1 D.S. 2-30B ,, I ,~ 20434 SLIM ACCESS ARRAY SONIC 10107100 I 1 D.S. 2-30B ,~L~:f"*' 20434 SLIM ACCESS NEUTRON 10/07/00 I t D.S. 2-30B ~'~0' 20434 SLIM ACCESS POROSITY 10/07100 1 1 D.S. 2-30B ;~)~' 20434 SLIM ACCESS SSTVD 10107100 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED OCT 1 2001 Date Delivered: Alaska Oil & Gas Cons. Commiasion An~eraae Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie WELL LOG TRANSMITTAL To: State of Alaska August 14, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 02-30B & 0_-_~0B PB 1 AK-MM-00183 02-30B: Digital Log Images: 50-029-22202-02 02-30B PBI' Digital Log Images: 50-029-22202-70 1 CD Rom 1 CD Rorn PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL L'ETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-teclmical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED AU$ 20 ?.001 Alaska 13tl & Gas Cons, Commmior, Anchorage WELL LOG TRANSMITTAL To: State of Alaska August 9, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 2-30B, AK-MM-00183 1 LDWG formatted Disc with verification listing. API#: 50-029-22202-02 pLEASE ACKi~OWLEDGE RECEIPT BY SIGlglSlG ~ RETIJR_NISIG A COPY OF TI~ TIO~ISI~UTrAL LETTER TO ~ ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED AUG 13 2001 Alaska Oil & Gas Cons. Commiadon WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 2-30B PB 1, 1 LDWG formatted Disc with verification listing. API#: 50-029-22202-70 July 20, 2001 AK-MM-00183 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Cemer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED {. STATE OF ALASKA M("~c, SiON ALASKA OIL AND GAS CONSERVATION COM WELL COMPLETION OR RECOMPLETION 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 (Alaska) Inc. 200-126 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6012 50- 029-22202-02 4. Location of well at surface ,-- · - ..... 9. Unit or Lease Name 154' SNL, 774' EWL, SEC. 36, T11 N, R14E, UM ?i;;..'-i..?i ""'i'.~: "i, i LQC"A~~ Prudhoe Bay Unit At top of productive interval i ..... ;': ',.!i~ I~ V~' 3369'NSL, 1370'WEL, SEC. 26, T11N, R14E, UM !-/'~-.//-oo' '".l;,~~r 10. WellNumber At total depth 4189' NSL, 2775' WEE, SEC. 26, T11N, R14E, ua i~..--,/~ ......... i'~i 02-308 .... 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 58.80' ADL 028308 12. Date SpuddedD/17/2000 113' Date T'D' Reached 114' Date C°mp"-Susp'~'°r Aband'l 0/0/2000 10/,J~0~l~ 115' water depth' if °ffsh°reN/A MSL 110' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) ~ 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 12362 8910 ETI 11910 8902 FTI []Yes [] NoI (Nipple) 2199' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, NEU, DEN, Sonic 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE ToP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.05# H-40 Surface 110' 30" 11 cu yds Arcticset 10-3/4" 45.5# J-55 Surface 2558' 13-1/2" 2563 cuft Cold Set III, 405 cu ft 'G' 7-5/8" 29.7# L-80 Surface 8063' 9-7/8" 1369 cu ft Class 'G' 5-1/2" 17# NT-80S 7897' 9618' 6-3/4" 225 cuft Class 'G' 3-1/2" 9.3# L-80 9435' 11983' 4-3/4" 225 cuft Class 'G' 24. Perforations open to Production (M.D+.TVD of Top and 25. TUBING RECORD Bottom and interval, size and numoer) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 7830' MD TVD MD TVD 3-1/2", 9.3#, 13Cr80 7830' - 9442' 9387' 10350' - 10834' 8899' - 8918' 10898' - 11000' 8913' - 8910' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11120'- 11239' 8910'-8902' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11320'. 11751' 8902' - 8902' .. 11850' - 11900' 8901' - 8902' Freeze Protected with 185 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 3, 2000 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS'MCF :WATER-BB~. OIL GRAVITY-APl (CORR) Press. 24-Hour RATE 2,8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Su~mi~c~e~ip~ E D DEC 18 2000 Alaska 0il & Gas Cons. C0mmissi0r Anchorage Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate '29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Sag River 9612' 8295' Shublik 9660' 8343' Sadlerochit 9704' 8387' Zone 3 9863' 8545' Zone 2C 9930' 8608' Zone 1 B 10222' 8847' Zone lA 10318' 8889' RECEIVED DEC 1 8 000 Alaska Oil & Gas Cons. Comr~issior Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble .~~4~ ~ Title TechnicalAssistant Date 02-30B 200-126 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. ,, , ~NSTRUCTIONS 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 , . BP EXPLORATION Page 1 of 7 Operations Summa Report Legal Well Name: 02-30 Common Well Name: 02-30 Spud Date: 9/13/2000 'Event Name: REENTER+COMPLETE Start: 9/13/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: N^BORS 7ES Rig Number: . ' Sub Phase= DesCription of'Operations' ...Date.. From'.~To Hours Task Code ....... ". 9/1312000 08:00 - 18:00 10.00 RIGD PRE Bridle up. RD floor. Set out cuttings tank. PJSM. Lower derrick. Load out shop. PJSM wi Peak. Set out camp & pits. Move & spot sub on DS 2-30B. PJSM. Raise derrick. Move & spot pits & camp. 18:00 - 21:00 3.00 RIGU PRE Berm rig. Hook up lines. Spot shop. Unbridle. Hookup top drive. RU floor. Rig accepted ~ 2100 hrs on 9/13100. 21:00 - 23:00 2.00 RIGU . DECOMP Install 2nd annulus valve. RU hoses to slop tank. Pull BPV w/DSM. 23:00 - 23:30 0.50 WHSUR DECOMP PreSpud meeting w/crew. 23:30 - 00:00 0.50 WHSUR DECOMP RU lines to reverse circ freeze protect fl wellbore. 911412000 00:00 - 02:30 2.50 WHSUR DECOMP Fin RU lines. Reverse & circ diesel f/well bore. Circ well to seawater. Spill Drill: OS; 40 sec. 02:30 - 04:00 1.50 WHSUR DECOMP Set BPV. Test to 1000 psi f/below. ND tree & adapter flange. 04:00 - 06:00 2.00 BOPSUI; DECOMP NU adapter & BOPE. 06:00 - 11:00 5.00 BOPSUl; DECOMP Test BOPE to 25014000 psi; annular to 25013500 psi. Witnessing waived by John Crisp--AOGCC Field Inspector. 11:00 - 12:30 1.50 BOPSUI; DECOMP Pull TTP. RU lubricator. Pull BPV. RD DSM. 12:30- 13:00 0.50 PULL DECOMP PJSM. 13:00 - 14:00 1.00 PULL DECOMP MU landing jr. BOLDS. Work tbg free. Max pull 225k. 14:00 - 15:00 1.00 PULL DECOMP Circ well surface to surface wl seawater. Monitor well-OK. RU csg tools & spooler. 15:00 - 23:00 8.00 PULL DECOMP LD 4.5" tbg to SSSV nipple. Recovered 50 SS bands. LD SSSV. RD spooler. Continue LD total of 191 jts 4.5" tbg & 1-GLM. D1 Drill: OS: 2 min. 23:00 - 00:00 1.00 PULL DECOMP RD 4.5" tools & RU 3.5" tools. 9/15/2000 00:00 - 01:00 1.00 PULL DECOMP Finish LD 3.5"tbg. Total of 15 jts + cutoff. LD tbg tools & clear floor. 01:00 - 01:30 0.50 STWHIP WEXlT Set wear ring. 01:30 - 02:30 1.00 STWHIP WEXlT Cut 102' drlg line. 02:30 - 04:00 1.50 STWHIP .WEXlT MU mills for dummy run-BHA #1. 04:00 - 09:30 5.50 STWHIP .WEXIT Single in 4" HT DP. Tight spots ~ 6228' & 6509'. Worked thru OK. Set down w/25K {~ 6745'. 09:30 - 12:30 3.00 STWHIP CLCG WEXlT POH to BHA. 12:30 - 15:00 2.50 STWHIP CLCG WEXlT Change out BHA. Window mill was pinched down slightly to 5.875". MU MS, 1-HWDP, String mill, BS, DC's, jars, & HWDP. 15:00 - 17:00 2.00 STWHIP CLCG WEXlT RIH. Set down {~ 6264'. 17:00 - 19:00 2.00 STWHIP CLCG WEXIT Milled f/6264'-65' & 6425'-26'. Washed f! 6779'-80'. Upper spot milled the hardest (6k wt wi 8k torque). Lower was the least problem. 19:00 - 20:00 1.00 STWHIP WEXlT !Single in DP to 8275' & set down. 20:00 - 21:00 1.00 STWHIP WEXIT Pump 40 bbl HiVis sweep. Recovered small amounts of fine metal on ditch magnets. 21:00 - 00:00 3.00 STWHIP WEXlT Pump dry job. Start POH. SLM. 9/16/2000 00:00 - 01:00 1.00 STWHIP WEXIT Fin POH to BHA. 01:00 - 01:30 0.50 STWHIP WEXlT LD milling BHA. 01:30 - 02:00 0.50 STWHIP WEXlT PJSM w/SWS. 02:00 - 05:00 3.00 STWHIP WEXlT "RU SWS. RIH wl CIBP.Correlate to Schlumberger CBT/GR dated 8/22/91. Set plug @ 8102' WLM. POH. RD SWS. Fire Drill: OS-1:30 · min. Tr. 05:00 - 05:30 0.50 STWHIP WEXlT Test casing & EZSV to 3500 psi fl 30 min-OK. 05:30 - 09:30 4.00 STWHIP WEXlT MU whipstock & milling BHA. Set Sperry depth encoder. Test MWD. <~ :~ = Blow down lines. ~ 09:30 - 13:00 3.50: STWHIP WEXIT RIH to 8056'. '~~' '? ~ 13:00 - 14:00 1.00 STWHIP WEXIT Orient whipstock to 77? Left of High. Set ~ 8062' DPM. Shear off. ( :) ~ ~ 14:00 - 16:30 2.50 STWHIP WEXlT Displace well to 10.5# milling fluid. ~, ~'- ~. '~. 16:30 - 23:30 7.00 STWHIP. WEXlT Mill window fl 8061' to 8076'. Miled to 8088'. Circ sweep. Rotate & reciprocate through window. Appeared smooth. Printed: 11/28/2000 8:48:37 AM BP EXPLORATION Page 2 of 7 Operations Summa Report Legal Well Name: 02-30 ,Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: REENTER+COMPLETE Start: 9/13/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: .... SUb : . 'Date' From - To Hours Task code l Phase, ,Description of Operations 9/16/2000 23:30 - 00:00 0.50 STWHIP WEXIT Monitor well. Pump dry job. Blow down lines. 911712000 00:00 - 02:00 2.00 STWHIP WEXIT Finish POH to BHA. 02:00 - 04:00 2.00 S'I'WHIP WEXlT LD steel DC's & milling assembly. Mill in gauge. 04:00 - 04:30 0.50 STWHIP WEXIT Flush out stack & clear floor. 04:30 - 06:00 1.50 DRILL INT1 Cut & slip 88' drlg line. Service top drive. 06:00 - 09:00 3.00 DRILL INT1 MU 6.75" drilling BHA. Orient. Plug in & upload MWD. RIH wi BHA. 09:00 - 09:30 0.50 DRILL INT1 Shallow test MWD. Blow down lines. 09:30 - 10:30 1.00 DRILL INT1 PU 45 jts 4" DP. 10:30 - 12:30 2.00 DRILL INT1 RIH to 7863'. D1 Drill: OS-1:45 min. 12:30 - 13:30 1.00 DRILL INT1 Cased hole Mad Pass fl 7863'-8063'. 13:30 - 14:00 0.50 DRILL INT1 Orient BHA 77? Left of High and exit through window. Window in good shape. Wash to 8088'. 14:00 - 14:30 0.50 DRILL INT1 Drill fl 8088'-8097'. AST: 1/2 hr. Spill drill: OS-1 min. 14:30 - 15:30 1.00 DRILL INT1 Perform FIT to 12.5~ EMW. D2 Drill: OS-45 sec. 15:30 - 00:00 8.50 DRILL INT1 Drlg f/8097'-8294'. AST: 7 hrs. 911812000 .00:00 - 00:00 24.00 DRILL INT1 Drld fl 8294'-9127'. Penetration rate 100'-120' fph when rotating. AST: 10 hrs; ART: 9 hrs. Two Fire Drills: OS- 1 min & 45 secs. 9119/2000 00:00 - 07:30 7.50 DRILL INT1 Drld f! 9127'-9618'; top of Sag TD. ART: 6.5 hrs. Spill Drill: OS-2-min. 07:30 - 09:00 1.50 DRILL INT1 = Circ fl samples. 09:00 - 10:30 1.50 DRILL INT1 Short trip to window. No fill. Hole in good shape. 10:30 - 13:00 2.50 DRILL INT1 Circ Hi-Vis sweep. Spot liner running pill. 13:00 - 13:30 0.50 DRILL INT1 Drop ESS. Check shot {~ 9530'. 13:30 - 14:00 0.50 DRILL INT1 Drop rabbit. Pump dry job. Blow down lines. 14:00 - 16:00 2.00 DRILL INT1 POH to BHA. 16:00 - 18:00 2.00 DRILL INT1 Download MWD. LD BHA. 18:00 - 18:30 0.50 DRILL INT1 Service top drive & clear floor. 18:30 - 19:00 0.50 CASE INT1 RU casing tools. 19:00 - 19:30 0.50 .CASE INT1 PJSM on running liner. 19:30 - 21:30 2.00 CASE INT1 Run 39 jts 5.5", 17#, NT80S ST-L liner. MU hanger assembly. LD casing tools. 21:30 - 00:00 2.50 CASE INT1 Run liner on DP to 3900'. D1 Drill: OS-45 sec. 912012000 00:00 - 02:00 2.00 CASE INT1 RIH to window. 02:00 - 03:30 1.50 CASE INT1 Circ ~ window & MU cement head on single. 03:30 - 05:00 1.50 CASE INT1 RIH. MU single & precautionary wash to bottom. r.. 05:00 - 07:00 2.00 CEMT INT1 Circ & cond mud to cement. Staged rate up to 6 bpm. Reciprocated .~-- pipe. PJSM wi Dowell. Batch cement. .~_ 07:00 - 08:00 1.00 CEMT INT1 Cement wi 40 bbls Class 'G' @ 15.8 ppg. Displace wi Dowell. Bumped E plug w/calculated volume. Set hanger w/3000 psi. Increase to 4000 ~ c~ ~si. Check floats-OK. Set & release f/liner top packer. Pressure DP & ~ sting out. CIP 0745. {:30 ~ ,. 08:00 - 09:30 1.50 CEMT INT1 CBU ~ 10 bpm while reciprocating pipe. Recovered -,5 bbls cement on ¢.3 ~ bottom's up. Clean shakers & LD cement head. (.~ ~; ~ 09:30 - 14:00 4.50 CEMT INT1 Pump dry job. Blow down lines. POH. LD liner running tool. 1,,.J ,=~ 14:00 14:30 0.50 WHSUR INT1 Pull wear ring & set test plug. I~ --- 14:30 - 17:00 2.50 ' WHSUR INT1 Test BOPE to 25014000 psi; annular to 250~3500 psi. Witnessing o waived by Jeff Jones-AOGCC Field Inspector. --~ 17:00 - 18:00 1.00 WHSUR INT1 Pull test plug & set wear ring. Blow down surface equipment. .~ 18:00 - 18:30 0.50 DRILL INT1 RU 2 7~8" DP tools. Spill Drill: OS-1:10 min. 18:30 - 00:00 5.50 DRILL INT1 MU BHA #5. Orient. Surface test MWD & motor. 9/21/2000 00:00 - 03:30 3.50 DRILL INT1 . PU 3500' 2 7~8" DP. 03:30 - 04:00 0.50 DRILL INT1 Change out handling tools. 04:00 - 05:30 1.50 DRILL INT1 Cut & slip 70' drlg line. Service top drive. 05:30 - 08:00 2.50 DRILL INT1 RIH to TOL. Take check shot. RIH to landing collar. 1.4.1 Printed: 11128/2000 8:48:37 AM BP EXPLORATION Page 3 of 7 Operations Summa Report Legal Well Name: 02-30 Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: REENTER+COMPLETE Start: 9/13/2000 End: 'Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: . · Sub' ' ' " Date From To ·. Hours Task 'Code Phase Description of OPerations · · o :oo. o:oo .oo RECEIVED 10:00 - 11:00 1.00 DRILL INT1 Test casing to 3500 psi f/30 rain-OK. 11:00 - 12:00 1.00 DRILL INT1 Perform D2 Drill followed by D5 Drill. 12:00- 14:00 2.00 DRILL INT1 Drill shoe track & 2' new hole. ~t[C '~ 8 2000 14:00 - 16:30 2.50 DRILL INT1 Displace well to 8.5 ppg QuickDril. 16:30 - 17:00 0.50 DRILL INT1 Drill fl 9620'-38'. 17:00 - 17:30 0.50 DRILL INT1 Perform FIT to 9.5~ EMW. Alaska 011 & 13~ (~0n~. [;0mmi~s 17:30 - 00:00 6.50 DRILL PROD1 Drld fl 9638'-9881'. Allctlt3ragfl 9/2212000 00:00 - 04:00 4.00 DRILL PROD1 Drld f! 9881'-96'. Bit quit drilling after going into Zone 3. ^ST: 4 hrs. 04:00 - 08:00 4.00 DRILL PROD1 POH to 2 718" DP ~ 3700'. Change out handling tools. 08:00 - 10:00 2.00 DRILL PROD1 POH to BHA. 10:00 - 15:30 5.50 DRILL PROD1 Pull DC's. Down load LWD and PWD. LD motor. Bit was hammered out, but still in gauge. Upload PWD. MU bit & orient. 15:30 - 17:30 2.00 DRILL PROD1 RIH w/2 7/8". Change handling tools. 17:30 - 20:30 3.00 DRILL PROD1 RIH wi 4" DP. Took Jorps check shots @ 9770' & 9890'. 20:30 - 00:00 3.50 DRILL PROD1 Drld f/9896'-9957°. ^ST: 2 hrs. 9~23~2000 00:00 - 18:00 18.00 DRILL PROD1 Drld fl 9957'-10,300'. AST: 9.75 hrs; ART: 3.25 hrs. Drld to max hrs on bit. Gradually slowed down to 5-6 fph. Spill Drill: OS-1:10 min. 18:00 - 20:30 2.50 DRILL PROD1 POH to 10,300'. Observe well-OK. Blow down lines. POH to 3702'-wet. 20:30 - 21:00 0.50 DRILL PROD1 Change out handling tools. 21:00 - 23:00 2.00 DRILL PROD1 POH w/2 7/8" DP to 192'-wet. 23:00 - 00:00 1.00 DRILL PROD1 LD jars. Stand back flex DC's. 9/24/2000 00:00 - 02:00 2.00 DRILL PROD1 Fin pull BHA. Change bit. Check orientation. Download MWD. P-,IH w/ BHA. 02:00 - 04:00 2.00 DRILL PROD1 RIH wi 2 7/8" DP. PU 12 additional jts (4080'-total). 04:00 - 04:30 0.50 DRILL PROD1 Change out handling tools. 04:30 - 06:00 1.50 DRILL PROD1 RIH wi 4" DP to 7812'. 06:00 - 07:30 1.50 DRILL PROD1 Cut & slip 105' drlg line. Service top drive. 07:30 - 08:30 1.00 DRILL PROD1 RIH. Precautionary wash & ream 60' to bottom. 08:30 - 00:00 15.50 DRILL PROD1 Drill f/10,300'-10,626'. ART: 3 hrs; AST: 8 hrs. D2 Drill: OS-45 sec. Spill Drill: OS-1:10 min. 9~25~2000 00:00 - 00:00 24.00 DRILL PROD1 Drld fl 10,626'-11,333'. AST: 11.25 hrs; ART: 2.75 hrs. Spent considerable time nosing up & down, looking f/sweet spot. Fire Drills both crews: OS-1:10 min & 1:30 min. 9/26!2000 00:00 - 13:30 13.50 DRILL PROD1 Drlg 4 3/4" Hole to 11739 13:30 - 15:00 1.50 DRILL PROD1 POH to 10100, RIH to 10470 15:00 - 00:00 9.00 DRILL PROD1 Attempt Open Hole Side Track; F/10470-10490; Time Drlg to 10505 9/27/2000 00:00 - 08:00 8.00 STKOH DIR PROD1 Attempt Open Hole Sidetrack 08:00 - 09:00 1.00 STKOH DIR PROD1 Flow Check Well, POH to 9600', Pump Dry Job 09:00 - 11:30 2.50 STKOH DIR PROD1 POH to 4080 11:30 - 12:00 0.50 STKOH DIR PROD1 PJU 2 7~8" Tools 12:00- 14:00 2.00 STKOH DIR PROD1 POH 2 7!8 DP 14:00- 16:00 2.00 STKOH DIR PROD1 Handle BHA 16:00- 17:00 1.00 STKOH DIR PROD1 =DownLoad MWD 17:00 - 22:30 5.50 BOPSUI:; DIR PROD1 Test BOPE. 250 Iow/4000 psi high. Witness of test waived by ^OGCC J. Crisp. 22:30 - 23:30 1.00 STKOH DIR PROD1 R/U equip to P/U 2-1/16" CS Hydril. M/U muleshoe to firstjt. 23:30 - 00:00 0.50 STKOH DIR PROD1 Serviced top drive. 9~28/2000 00:00 - 02:30 2.50 STKOH DIR PROD1 RIH W/25 Jts 2 1116 CS Hy Tbg, Circ Thru Same 02:30 - 04:00 1.50 STKOH DIR PROD1 RIH W! 2 7/8 DP 04:00 - 04:30 0.50 STKOH DIR PROD1 R/D Power Tongs, Change Out Elevators 04:30 - 06:30 2.00 STKOH DIR PROD1 RIH W/4" DP to 10915 06:30 - 08:00 1.50 STKOH DIR PROD1 CBU, Reciprocate Printed: 11/28/2000 8:48:37 AM BP EXPLORATION Page 4 of 7 Operations Summa Report ,Legal Well Name: 02-30 'Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: REENTER+COMPLETE Start: 9/13/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Sub Code Phase ' ' : Description of Operations . .. 9~28~2000 08:00 - 09:00 1.00 STKOH DIR PROD1 PJSM, Pump 5 BBL Water, Test Lines to 3500, Pump 5 BBL Water, 13 BBl. (73 sx) Batch Mixer CMT {~ 17#/gal, I BBL Water, Balanced Plug, CIP 0900, Calc TOC 10320 09:00 - 09:30 0.50 STKOH DIR PROD1 POH Slow, 10 Stds, Had 105K Overpull 09:30- 10:00 0.50 STKOH DIR PROD1 CBU 10:00- 12:30 2.50 STKOH DIR PROD1 POH 4"DP 12:30-13:00 0.50 STKOH DIR PROD1 R/Ufor27/8 13:00 - 16:00 3.00 STKOH DIR . PROD1 POH w/2 718 & 2 1116 16:00 - 17:00 1.00 STKOH DIR PROD1 Clear Floor, RJU to PIU BHA 17:00 - 18:30 1.50 STKOH DIR PROD1 P/U Motor, Bit, MWD, FS, & Insert Probe 18:30- 19:00 0.50 STKOH DIR PROD1 Load MWD 19:00 - 20:00 1.00 STKOH DIR PROD1 Finish MIU BHA 20:00 - 21:30 1.50 STKOH DIR PROD1 RIH W/2 7/8 DP 21:30 - 22:00 0.50 STKOH DIR PROD1 Clear Floor J~8'$~' 22:00 - 00:00 2.00 STKOH DIR PROD1 RIH 9~29~2000 00:00 - 01:00 1.00 STKOH DIR PROD1 Slip & Cut 85' Drlg Line 01:00 - 02:00 1.00 STKOH DIR PROD1 Continue RIH to 9874, Replaced One Jt 4"DP (Mashed Tube) 02:00 - 02:30 0.50 STKOH DIR PROD1 Make Check Shot WIMWD 02:30 - 03:00 0.50 STKOH DIR PROD1 RIH to 10165, Tag 03:00 - 04:00 1.00 STKOH DIR PROD1 Wash & Ream CMT Stringer FI10165-10350 04:00 - 08:00 4.00 STKOH DIR PROD1 CBU, CMT in Returns; Take Check Shot Survey ~ 10317 08:00 - 08:30 0.50 STKOH DIR PROD1 Wash & Ream CMT Stringers 10391, Drlg Soft CMT to 10450 08:30 - 10:30 2.00 STKOH DIR PROD1 CBU While WOC 10:30 - 00:00 13.50 STKOH DIR PROD1 Low Side Sidetrack Well Holding Tool Face of 180, DRLG to 10833, ART 5.5, AST 2.5 9~30/2000 00:00 - 16:00 16.00 DRILL i DIR PROD1 Drlg to 11052, ART 2, AST 10 Hrs, Increasing Rotary Torque 16:00 - 17:30 1.50 DRILL DIR PROD1 CBU, Pump Sweep 17:30 - 19:00 1.50 DRILL DIR PROD1 POH to 9560, Tight 10325-10367; Wiped Thru OK 19:00 - 21:30 2.50 DRILL DIR PROD1 POH to 4064 21:30 - 22:00 0.50 DRILL DIR PROD1 Change Elevators 22:00 - 00:00 2.00 DRILL DIR PROD1 POH 10/1/2000 00:00 - 01:30 1.50 DRILL DIR PROD1 I_/D BHA 01:30 - 03:00 1.50 DRILL DIR PROD1 P/U BHA, Adjust New Motor 2.12, Orient MWD 03:00 - 03:30 0.50 DRILL DIR PROD1 Service Wear Bushing 03:30 - 05:30 2.00 DRILL DIR PROD1 RIH W/BHA & 2 7/8" DP 05:30 - 06:00 0.50 DRILL DIR PROD1 Change Out Elevators 06:00 - 08:30 2.50 DRILL DIR PROD1 RIH, Check Shot ~ 9874, Took Weight @ 10881 08:30 - 09:00 0.50 DRILL DIR PROD1 Wash & Ream from 10881-11052 09:00 - 00:00 15.00 DRILL DIR PROD1 Drlg to 11139 ART 2.5 AST 8 Hrs 10/2/2000 00:00 - 23:00 23.00 DRILL DIR PROD1 Drlg, AST 13.75, ART 1.25 Hrs '23:00 - 00:00 1.00 DRILL DIR PROD1 .CBU, Check Shot Surveys ~ 11330, 11345 10/3/2000 00:00 - 01:00 1.00 DRILL DIR PROD1 Finish CBU, Flow Check 01:00 - 04:00 3.00 DRILL DIR PROD1 POH F/11395-4064, Wet, Tight Spot @ 10480, 20K overpull 04:00- 04:30 0.50 DRILL DIR PROD1 Change Elevators 04:30 - 06:30 2.00 DRILL DIR PROD1 POH Wet F/4064-180 06:30 - 08:30 2.00 DRILL DIR PROD1 Change Out Motor, Download MWD 08:30- 09:00 0.50 DRILL DIR PROD1 Clean Rig Floor 09:00 - 09:30 0.50 DRILL DIR PROD1 Pull Wear Bushing 09:30 - 10:00 0.50 DRILL DIR PROD1 Set BOP Test Plug 10:00 - 13:30 3.50 DRILL DIR PROD1 Test All Rams, Valves, Lines to 250- 5 min, 4000 Hi-10 min, Annular 250 Iow 5 rain, 3500 Hi 10 Mins, Witnessed By John Crisp AOGCC 13:30 - 14:30 1.00 DRILL DIR PROD1 Pull Test Plug, Set Wear Bushing 14:30 - 16:00 1.50 DRILL DIR PROD1 Slip & Cut 75' Drill Line Printed: 11/28/2000 8:48:37 AM BP EXPLORATION Page 5 of 7 Operations Summa Report Legal Well Name: 02-30 Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: REENTER+COMPLETE Start: 9/13/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: Hours' ' Task' SUb. Phase. · Description of OperatiOns Date Fro._. - To · Code ,.. ,,. ,,., ~.,, % ~ ~,- I'~ · ........ 10/3/2000 16:00-16:30 0.50 DRILL DIR PROD1 'Service Top Drive ~(, E ~ r' H I V IJ 16:30 - 17:00 0.50 DRILL DIR PROD1 R/U 2 7/8" Tools 17:00-19:00 2.00 DRILL DIR PROD1 M/U BHA, MWD DEC ] 8 2000 19:00 - 21:00 2.00 DRILL DIR PROD1 RIH WI BHA & 2 7/8 21:00 - 22:30 1.50 DRILL DIR PROD1 P/U 57 Jts 2 7/8 DP 22:30 - 23:00 0.50 DRILL DIR PROD1 PJD 2 7/8 Tools Alaska 0il & Gas Cons, C0mmissi0~ 23:00 - 00:00 1.00 DRILL DIR PROD1 RIH WI 4" DP Anchorage 10/4/2000 00:00 - 02:00 2.00 DRILL DIR PROD1 RIH WI 4" DP to 9889, Check Shot Survey, Tight @ 9965, 10015 02:00 - 03:00 1.00 DRILL DIR PROD1 RIH to 11170, Took Check Shots ~ 11007, 11030, 11053 03:00 - 04:00 1.00 DRILL DIR PROD1 Wash & Ream FI 11170-11395 04:00 - 19:00 15.00 DRILL DIR PROD1 Drlg to 11659, AST 9, ART 1.25 Hrs 19:00 - 23:00 4.00 DRILL DIR PROD1 Stuck Pipe After Taking Survey, Jar On Stuck Pipe, MaxPul1270K, Full Circ 23:00 - 00:00 1.00 DRILL DIR PROD1 PJSM R/U Hot Oil Truck, PT Lines, Pump 108 BBL 110 F Diesel ~ 2.5 BBL/Min @ 1425-2325 psi, Pipe Chained Down WI 94000~ Pull. Pipe Came Free. DP Cap = 85 BBL 10/5/2000 00:00 - 00:30 0.50 DRILL DIR PROD1 Pumped 108 BBLs Diesel (of 150 Planned), Pipe Came Free, Pull up to 11570 00:30 - 02:30 2.00 DRILL DIR PROD1 Rotate & Reciprocate While Displace Diesel out of Well 02:30 - 04:00 1.50 DRILL DIR PROD1 POH to CSG Shoe, Had One Tight Spot @ 11480; 30K Overpull, Wiped Through, OK 04:00 - 08:00 4.00 DRILL DIR PROD1 Clean Pits, Take On New Mud, Displace Hole to New Mud 08:00 - 09:00 1.00 DRILL DIR PROD1 RIH to 11663 09:00 - 11:00 2.00 DRILL DIR PROD1 Drlg to 11739 11:00 - 00:00 13.00 DRILL PROD1 Drlg to 12131 AST 2.5, ART 6 Hrs 10/6/2000 00:00 - 11:00 11.00 DRILL PROD1 Drlg to 12362. AST 3.75 ART 2 11:00 - 13:00 2.00 DRILL PROD1 Circ Sweep Around 13:00 - 15:30 2.50 DRILL PROD1 POH to Shoe, Tight @ 10625; 30K Over, Wipe Through, OK 15:30 - 16:00 0.50 DRILL PROD1 Service Top Drive & Crown 16:00 - 17:00 1.00 DRILL PROD1 RIH to Bottom, No Problems ! 17:00 - 20:30 3.50 DRILL PROD1 Circ Sweep Around & Spot liner pill 20:30 - 00:00 3.50 DRILL PROD1 POH to Run W/L Logs, No Overpulls 10/7/2000 00:00 - 00:30 0.50 DRILL PROD1 POH 00:30 - 01:00 0.50 DRILL PROD1 R/U 2 7/8 Tools, Recover Rabbit, Drop Rabbit 01:00 - 03:30 2.50 DRILL PROD1 POH w/2 7/8 DP 03:30 - 05:30 2.00 DRILL PROD1 I_/D Excess 2 7/8 DP 05:30 - 08:00 2.50 DRILL PROD1 I_/D BHA Download MWD 08:00 - 08:30 0.50 DRILL PROD1 Clean & Clear Rig Floor 08:30 - 14:00 5.50 DRILL PROD1 R/U Schlumberger, Damaged Induction Tool on Skate, Run Neutron, Sonic, Density from 10250-9618 for GOC 14:00 - 14:30 0.50 DRILL PROD1 PJD Schlumberger 14:30 - 15:30 1.00 DRILL PROD1 R/U Liner Running Equip 15:30 - 23:30 8.00 DRILL PROD1 Run 79 Jts 3 112" 8.8~ L80, STL, R 2 Liner, Unique Machined Right Hand Turbulators Appear to be MisCut 23:30 - 00:00 0.50 DRILL PROD1 MIU Baker Liner HGR, Liner Top PKR, Circ Lier Volume, Liner Wt 25000' 10/812000 00:00 - 01:30 1.50 CASE PROD1 RIH 2 7/8" DP 01:30 - 02:00 0.50 CASE PROD1 R/D 2 7/8 Equip, R/U 4" Equip 02:00 - 05:00 3.00 CASE PROD1 RIH to 9618 (Liner Shoe) 05:00 - 06:00 1.00 CASE PROD1 R/U CMT Head, Circ Liner Contents, Get Up & Down Wts 06:00 - 07:30 1.50 CASE PROD1 RIH to 11983, Took Wt from 11463-11983 07:30 - 08:30 1.00 CASE PROD1 PJSM; CMT OPS While CIRC Prior to CMT Job 08:30 - 11:00 2.50 CASE PROD1 Pump 5 BBL B45 Spacer @ 9.5 ppg, PT Lines to 4500, Pump 20 More Printed: 11/28/2000 8:48:37 AM BP EXPLORATION Page 6 of 7 Operations Summa Report Legal Well Name: 02-30 Common Well Name: 02-30 Spud Date: 9/13/2000 Event Name: REENTER+COMPLETE Start: 9/13/2000 End: Contractor Name: N^BORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: .. . Date. 'From - To HoUrs .Task · Sub Phase DescriptiOn of OperatiOns '" Code · . 10/8/2000 08:30 - 11:00 2.50 CASE PROD1 BBL Spacer, followed By 40 BBL(193 sx) @ 15.8~1gal G+ .4% D167+.13% D800+.28% D65+ .01gps D47, :Launch Dart, Displace w 30 BBL/Perf Pill, Followed by Mud, Bump Plug to 4200, Hang Liner, Confirm Hung, Floats Held, Release From Hgr, Pressure Up to 1000, PlU Observe Pressure Loss, Displace to Seawater, Slack Off 3OK, Observe Liner Top PKR Set, CIP 1045 Hrs 10/8/00, LC 11910, TOL 9435 11:00 - 14:30 3.50 CASE PROD1 Continue Displace to Seawater 14:30- 16:00 1.50 CASE PROD1 POH 16:00 - 16:30 0.50 CASE PROD1 Change Elevators 16:30 - 18:30 2.00 CASE PROD1 POH, L/D 66 Jts 27~8" DP J~ 18:30 - 19:00 0.50 CASE PROD1 Break & L/D Baker Running Tool ~ ~ 19:00 - 20:00 1.00 CASE PROD1 R/U & Pressure Test Liner to 3500 psi, 30 Min. OK ~, ~ 20:00 - 20:30 0.50 CASE PROD1 PJU Schlumberger "'" eX:) 20:30- 21:00 0.50 CASE PROD1 PJSM, DP Conveyed Perf I..I,J ~ ~'~ 21:00 - 23:00 2.00 CASE PROD1 P/U 1585' 2" Guns & Blanks U (_3 23:00 - 00:00 1.00 CASE PROD1 RIH W/Guns on 2 1116 TBG 'l,[,J ~ 1019/2000 00:00 - 01:00 1.00 CASE PROD1 Continue P/U 2 1/16 CS Hydril Tbg i~ 01:00 - 02:00 1.00 CASE PROD1 RIH w/2 7/8 DP ~ ~:~ 02:00 - 05:00 3.00 CASE PROD1 RIH wi 4" DP, Locate on Landing Collar, Space Out 05:00 - 05:30 0.50 CASE PROD1 PJSM, Firing Guns, R/U Sound Monitering Equip 05:30 - 06:30 1.00 CASE PROD1 Close Annular, Pressure Up to 2200 psi, Bleed Off, Detected Shot, Open Bag, Well Taking 1-2 BPH, POH to 10300 06:30 - 07:00 0.50 CASE PROD1 R/D Surface Equip. 07:00 - 08:30 1.50 CASE PROD1 POH, L/D DP to 7897 :08:30 - 10:00 1.50 CASE PROD1 Cut Drlg Line ~10:00 - 13:00 3.00 CASE PROD1 ,POH, IJD 4" DP 13:00 - 14:30 1.50 CASE PROD1 I_/D 2 7~8" DP 14:30 - 16:00 1.50 CASE PROD1 I./D 2 1/16" CS Hydril Tbga 16:00 - 16:30 0.50 CASE PROD1 PJSM, L/D Guns 16:30 - 22:00 5.50 CASE PROD1 L/D Guns, All Shots Fired, Had Some Trapped Pressure In Blanks, See Perf Report 22:00 - 22:30 0.50 CASE PROD1 Clean Rig Floor of Gun Debris 22:30 - 00:00 1.50 CASE PROD1 RIH w/Excess 4" In Derrick, POH L/D Same 110/10/2000 00:00 - 00:30 0.50 CASE PROD1 Finished LD 4" drill pipe. 00:30 - 01:30 1.00 CASE PROD1 Pull wear bushing and clear rig floor. 01:30 - 03:30 2.00 RUNCOI~! COMP Rig up tools and equipment to run chrome tubing completion. PJSM with all personnel. 03:30 - 18:00 14.50 RUNCOI~! COMP RIH with Baker SABL 5 1/2" packer, 3 GLMs, 2 LNs, 3 1/2" & 4 1/2" 13 Cr tubing and pup joints for completion. 18:00 - 22:30 4.50 RUNCOI~ COMP Spaced out tubing, installed pup joints and tubing hanger. Landed tubing and tightened LDS. 22:30 - 00:00 1.50 RUNCOI~ COMP RU and reverse circulated with fltered seawater adding Corexit corrosion inhibitor in last 175 barrels. 10/11/2000 00:00 - 01:00 1.00 RUNCOI~ ~ COMP Finished circulating wellbore with filtered seawater containing Corexit corrosion inhibitor. 01:00 - 02:30 1.50 RUNCOI~ ~ COMP Dropped ball rod and pressured tubing to 4500 psi. Set Baker 5 1/2" Model SABL production packer at 9387 ft. Held pressure on tubing for 30 min. test with no bleed. Bled tubing pressure to 1500 psi and pressured annulus to 3500 psi. Held pressure for 30 min. test with no bleed. Bled tubing pressure to 1000 psi and sheared RP valve in GLM #1. Bled pressure from tubing and annulus. 02:30 - 04:00 1.50 RUNCOI~I COMP Removed landing joint and rigged down handling equipment. Set BPV Printed: 11/28/2000 8:48:37 AM BP EXPLORATION Operations Summary Report Page 7 of 7 al Well Name: 02-30 Common Well Name: 02-30 Event Name: REENTER+COMPLETE Contractor Name: NABORS Rig Name: NABORS 7ES Date. rom - To 1011112000 02:30 - 04:00 04:00 - 06:00 06:00 - 07:00 r:00 - 16:30 - 18:30 18:30 - 20:30 20:30 -. 22:30 22:30 - 23:30 10112/2000 23:30 - 00:00 00:00 - 00:30 00:30 - 00:50 50 - 04:30 - 04:45 45 - 06:45 45 - 08:30 ~8:30 - 12:00 :00 - 13:00 13:00 - 17:00 ,17:00 - 18:00 18:00 - 23:00 23:00 - 00:00 phase. COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Start: Rig Release: Rig Number: 9/13/2000 Spud Date: 9/13/2000 End: Group: RIG Description of oPerations.. .. and tested below to 2500 psi - OK. Nippled down BOP & nipple up tree. Rigged up DSM with lubricator and pulled BPV. Ran and set tree test plug in tubing hanger. Tested tree to 5000 psi. Rigged up DSM lubricator and attempted to pull tree test plug wlo success. Modified pulling tool by increasing shear pin size, but unable to pull test plug w/35K pull, Rigged up HES wireline unit. Latched plug with GR pulling tool and arred up on plug with link jars. Release pin in pulling tool sheared after ar strokes. Waited on modified GS pulling tool and delivery of pattern tree test plug from Kuparuk. Rigged up wireline lubricator and made up baited GS pulling tool string. Caught tree test plug and jarred on same with wireline link jars, Sheared steel pin in pulling tool and brass pin in baited pulling tool. Applied steam to heat wellhead, Redressed pulling tools with steel shear pins in both. Added oil and accelerator jars to tool string. Finished making up oil and accelerator wireline jars. Pinnned GS pulling tool with 114" steel pins. Jarred on tree test plug for 20 rains with jars tripping at 900-1000# pull, 0.108 wireline parted at measuring sheave, Pulled off kinked wire. Sheared pulling tools by hand and spooled parted wireline. Redressed tools after determining that skirt on GS pulling tool beginning to swell and dogs beginning to deform. Rigged ~ up with 0,125D wireline and engaged fish Jarred on plug fish with 4 jar strokes to 1400~ line pull and 0,125D wireline parted at measuring sheave. Unspooled bent wire. Sheared and released pulling tool and recovered tool string, Rigged down wireline unit to change out, Moved in new HES slickline unit and rigged up with 0,125D wire. Jarred on tree test plug fish. Pull strain to 2000# and trip jars at 1700~ for 15 rains., then release tools, check and redress tools. Cut 40 ft. of wireline every third tool redress. Failed to jar plug loose, Rigged down HES slickline. Picked up Baker GS hydraulic pulling tool, hydraulic jars and joint of 2 718" drill pipe. Caught fish and pulled on tree test plug at increasing strains up to 30,000~, Jarred on fish with 4 strokes up to 7000~ and one stroke at 25,000#. GS pulling tool pulled out of fish. Changed out latching collet but could not pull strain on fish above 10,000# without slipping out. Latch profile apparently stripped out of plug. Laid down fishing tools and jars. Rigged up Little Red hot oil unit. Began reverse circulating with diesel at 1/3 bpm at 2800 psi thru bore of tree test plug. Rate gradually increased to 2 bpm at 1800 psi. Freeze protected 7 5/8" x4 1/2" annulus and 4 1/2" tubing to 4385 It. with 185 bbls. diesel. Blew down and broke out circulating lines. Removed secondary valve from casing and secured well, Released rig at 2400 hrs. RECEIVED DEC 1 8 2.000 Alaska 0il & (~as Cons. C0mmissio~ Anchorage Printed: 1112812000 8:48:37 AM 21 -Nov-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 MWD Surveys (Definitive, no MWD+IIFR applied) Re: Distribution of Survey Data for Well 2-30B PB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 8,034.40' MD 80.63' MD 11,739.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) z~- 21 -Nov-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 MWD+IIFR Surveys (Definitive) Re: Distribution of Survey Data for Well 2-30B Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 10,447.72' MD 10,450.00' MD 12,362.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) 21 -Nov-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 MWD Surveys (Not Definitive) Re: Distribution of Survey Data for Well 2-30B mwd Dear Lori Taylor: Enclosed are two survey hard copies. 4- ~ ~-,~~ Tie-on Survey: Window / Kickoff Survey Projected Survey: 10,447.72' MD 10,450.00' MD 12,362.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 02 02-30B mwd Job No. AKMM00183, Surveyed: 6 October, 2000 SURVEY REPORT 21 November, 2000 Your Ref: API-500292220202 Surface Coordinates: 5951044.31 N, 687504.44 E (70° 16' 15.9439"'N, 211° 30' 59.6682" E) Kelly Bushing: 58.80ft above Mean Sea Level A Halliburton Company Survey Ref: svy10561 Sperry-Sun Drilling Services Survey Report for 02-30B mwd Your Ref: AP1-500292220202 Job No. AKMMO0183, Surveyed: 6 October, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10447.72 88.740 259.560 8851.75 8910.55 10450.00 88.780 259.560 8851.80 8910.60 10476.39 84.920 257.010 8853.25 8912.05 10507,40 85.130 256.630 8855.94 8914.74 10539.37 86.400 255.180 8858.30 8917.10 10570.39 87.450 254.660 8859.96 8918.76 10602.12 88.490 254.340 8861.09 8919.89 10633.53 89.080 254.600 8861.75 8920.55 10664.86 89.450 253.260 8862.16 8920.96 10696.33 90.120 252.940 8862.27 8921.07 10726.98 90.180 252,330 8862.19 8920.99 10756.23 90.580 251,790 8862.00 8920.80 10787.70 91.660 251.110 8861.39 8920.19 10818.30 92.890 248.580 8860.17 8918.97 10850.46 94.220 251,390 8858.18 8916.98 10882.52 94.490 253.360 8855.74 8914.54 10913.49 95.020 259.010 8853.17 8911.97 10945.03 92.280 261.370 8851.16 8909.96 10979.63 88.920 263.720 8850.80 8909.60 11009.80 86.980 267.770 8851.88 8910.68 11037.76 87.140 271.680 8853.32 8912.12 11069.21 91.630 275.490 8853.65 8912.45 11100.07 93.140 276.700 8852.37 8911.17 11130.48 93.820 276.820 8850.52 8909.32 11163.53 96.040 276.480 8847.68 8906.48 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3498.90 N 2271.59W 5954485.53 N 685146.38 E 3498.49 N 2273.83W 5954485.06 N 685144.15 E 3493.14 N 2299.63W 5954479,08 N 685118.50 E 3486.10 N 2329.71W 5954471.28 N 685088.61E 3478.33N 2360.63W 5954462.75 N 685057.89 E 3470.27 N 2390.54W 5954453.95 N 685028.19 E 3461.80 N 2421.09W 5954~.72 N 684997.85 E 3453.39 N 2451.35W 5954435.56 N 684967.82 E 3444.72N 2481.45W 5954426.14 N 684937.94 E 3435.57 N 2511.56W 5954416.24N 684908.07E 3426.43 N 2540.81W 5954406.37N 684879.05 E 3417.42N 2568.64W 5954396.67N 684851.46 E 3407.41N 2598.47W 5954385~92N 684821.89 E 3396.87N 2627.17W 5954374.68 N 684793.46 E 3385.89 N 2657.33W 5954362.94 N 684763.58 E 3376.21N 2687.79W 5954352.51N 684733.37E 3368.84 N 2717.75W 5954344.40 N 684703.60 E 3363.48 N 2748.76W 5954338.26 N 684672.74 E 3358.99 N 2783.06W 5954332.92 N 684638.56 E 3356,76N 2813.12W 5954329.94 N 684608.57E 3356.62N 2841.04W 5954329,11N 684580.66 E 3358.59 N 2872.41W 5954330.29 N 684549.25 E 3361.86 N 2903.07W 5954332.80 N 684518.52E 3365.43N 2933.21W 5954335.62N 684488.30E 3369.25 N 2965.91W 5954338.62N 684455.51E Dogleg Rate (°/lOOft) 1.75 17.52 1.40 6.02 . 3.78 3.43 2.05 4.44 2.36 2.00 2.30 4.06 9.19 9.65 6.18 18.26 11.46 11.85 14.88 13.98 18,72 6.27 2.27 6.79 Alaska Drilling & Wells PBU_EOA DS 02 Vertical Section Comment 4o21.70 Tie-on Su~ey 4023.11 Window Point 4038.85 4056.66 4074.63 4091.64 4108.87 4125.91 4142.67 4159.11 4174.91 4189.74 4205.40 4219,87 4235.12 4251.48- 4268.99 4288.62 4311.29 4332.28 4353.07 4377.84 4402.94 4427.85 4454.84 Continued.., 21 November, 2000.11:29 - 2 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 02-30B mwd Your Ref: API-500292220202 Job No. AKMMO0183, Surveyed: 6 October, 2000 . North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11193.57 93.570 278.040 8845.17 8903.97 11225.23 91.880 281.940 8843.66 8902.46 11255.98 90.090 281.620 8843.13 8901.93 11288.11 89.720 286.450 8843.19 8901.99 11317.37 89.780 285.520 8843.31 8902.11 11351.67 89.170 314.720 8843.63 8902.43 11364.91 88.370 315.830 8843.92 8902.72 11400.27 87.790 308.500 8845.11 8903.91 11429.03 89.420 316.300 8845.81 8904.61 11462.05 92.400 317.750 8845.28 8904.08 11491.28 92.890 323.260 8843.93 8902.73 11525.22 90.800 327.000 8842.84 8901.64 11556.09 89.690 328.170 8842.71 8901.51 11587.71 88.890 329.620 8843.10 8901.90 11618.40 89.690 330.540 8843.48 8902.28 11642.58 89.780 334.790 8843.59 8902.39 11680.82 90.830 336.390 8843.39 8902.19 11709.06 90.460 338.160 8843.07 8901.87 11737.32 89.750 340.050 8843.02 8901.82 11767.34 89.910 342.220 8843.11 8901.91 11798.52 90.220 342.880 8843.07 8901.87 11829.99 90.770 342.050 8842.80 8901.60 11859.73 89.050 342.580 8842.85 8901.65 11894.06 88.860 341.540 8843.47 8902.27 11924.82 87.970 343.040 8844.32 8903.12 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3373.03 N 2995.60W 5954341.66 N 684425.73 E 3378.52 N 3026.74W 5954346.37N 684394.47E 3384.79 N 3056.84W 5954351.89 N 684364.22E 3392.58 N 3088.00W 5954358.91N 684332.88 E 3400.64N 3116.13W 5954366.26 N 684304.56 E 3417.66 N 3145.48W 5954382.55 N 684274.79 E 3427.07N 3154.79W 5954391.72 N 684265.25 E 3450.78 N 3180.97W 5954414.77N 684238.49 E 3470.15 N 3202.18W 5954433.60 N 684216.80 E 3494.30 N 3224.68W 5954457.19 N 684193.70 E 3516.82 N 3243.25W 5954479.24 N 684174.58 E 3544.65 N 3262.64W 5954506.58 N 684154.51 E 3570.71N 3279.18W 5954532.21N 684137.32E 3597.78N 3295.52W 5954558.87N 684120.31 E 3624.38 N 3310.82W 5954585.08 N 684104.35 E 3645.85 N 3321.92W 5954606.27N 684092.72E 3680.67N 3337.73W 5954640.68 N 684076.05 E 3706.72 N 3348.63W 5954666.45 N 684064.50 E 3733.12 N 3358.71W 5954692.59 N 684053.76E 3761.52 N 3368.42W 5954720.74N 684043.35 E 3791.27N 3377.77W 5954750.25 N 684033.27 E 3821.27 N 3387.25W 5954780.01 N 684023.04E 3849.61 N 3396.28W 5954808.11 N 684013.30 E 3882.26 N 3406.86W 5954840.49 N 684001.92 E 3911.55 N 3416.21W 5954869.54 N 683991.84 E Dogleg Rate (°/lOOft) 9.72 13.41 5.91 15.08 3.18 85.15 10.33 2O.78 27.70 10.04 18.90 12.62 5.22 ' 5.24 3.97 17.58 5.00 6.40 7.14 7.25 2.34 3.16 6.05 3.08 5.67 Alaska Drilling & Wells PBU_EOA DS 02 Vertical Section Comment 4479.55 4506.48 4533.15 4561.62 4588.01 4621.26 4634.47 4669.78 4698.51 4731.37 4760.21 4793.18 4822.85 4853.04 4882.15 4904.70 4939.64 4965.09 4990.15 5016.27 5043.01 5070.02 5095.59 5125.18 5151.62 Continued... 21 November, 2000- 11:29 -3- DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 02-30B mwd Your Ref: AP1-500292220202 Job No. AKMMO0183, Surveyed: 6 October, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (~t) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11952.28 88.120 341.720 8845.26 8904.06 3937.71 N 3424.52 W 5954895.48 N 683982.88 E 11985.34 87.940 342.300 8846.40 8905.20 3969.13 N 3434.72 W 5954926.64 N 683971.90 E 12008.13 88.030 341.280 8847.20 8906.00 3990.77 N 3441.84 W 5954948.09 N 683964.24 E 12047.53 87.780 341.740 8548.64 8907.44 4028.11 N 3454.33 W 5954985.11 N 683950.83 E 12078.47 88.060 341.420 8849.76 8908.56 4057.44 N 3464.10 W 5955014.19 N 683940.33 E 12115.72 89.140 340.910 8850.67 8909.47 4092.69 N 3476.12 W 5955049.12 N 683927.44 E 12145.09 89.510 340.910 8851.02 8909.82 4120.44 N 3485.72 W 5955076.63 N 683917.14 E 12173.20 89.290 339.650 8851.31 8910.11 4146.90 N 3495.21 W 5955102.84 N 683907.00 E 12207.11 89.850 340.680 8851.57 8910.37 4178.80 N 3506.71 W 5955134.44 N 683894.71 E 12238.38 89.940 340.560 8851.62 8910.42 4208.29 N 3517.09 W 5955163.67 N 683883.60 E 12267.08 90.620 340.730 8851.48 8910.28 4235.37 N 3526.60 W 5955190.51 N 683873.42 E 12297.83 90.250 340.230 8851.25 8910.05 4264.35 N 3536.88 W 5955219.22 N 683862.42 E 12318.57 90.250 340.750 8851.16 8909.96 4283.90 N 3543.80 W 5955238.59 N 683855.01 E 12362.00 90.250 340.750 8850.97 8909.77 .4324.90 N 3558.12 W 5955279.23 N 683839.68 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are' relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 311.600° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12362.00ft., The Bottom Hole Displacement is 5600.45ff., in the Direction of 320.556° (True). Dogleg Rate (°il00ff) 4.84 1.84 4.49 1.33 1.37 3.21 1.26 4.55 3.46 0.48 2.44 2.02 2.51 0.0o Alaska Drilling & Wells PBU_EOA DS 02 Vertical Section Comment 5175.19 5203.69 5223.38 5257.50 5284.29 5316.68 5342.28 5366.94 5396.73 5424.07 5449.16 5476.08 5494.24 5532.17 Projected Survey Continued... 21 November, 2000.11:29 - 4 - DrillQuest ZOO.02 Sperry-Sun Drilling Services Survey Report for 02.30B mwd Your Ref: API-500292220202 Job No. AKMMO0183, Surveyed: 6 October, 2000 North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 02 ~'~-'~ Commen ts Measured Depth (h) Station Coordinates TVD Northlngs Eastlngs (fi) (ti) (fi) 10447.72 8910.65 3498.90 N 2271.59 W 10450.00 8910.60 3498.49 N 2273.83 W 12362.00 8909.77 4324.90 N 3558.12 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From To Measured Vertical Measured Depth Depth Depth (fi) (~t) (/t) o.0o 0.00 12362.00 Vertical Depth (fi) 8909.77 Survey Tool Description MWD Magnetic 21 November, 2000 - 11:29 - 5 - DriilQuest 2.00.02 North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 02 02-30B Job No. AKMMO0183, Surveyed: 6 October, 2000 SURVEY REPORT 21 November, 2000 Your Ref: API-500292220202 Surface Coordinates: 5951044.31 N, 687504.44 E (70° 16' 15.9439" N, 211° 30' 59.6682" E) Kelly Bushing: 58.80ft above Mean Sea Level A Halliburton Company Survey Ref: svy10559 Sperry-Sun Drilling Services Survey Report for 02,30B Your Ref: API-500292220202 Job No. AKMMO0183, Surveyed: 6 October, 2000 North Slope Alaska Measured Depth (It) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10447.72 88.740 259.560 8851.75 8910.55 10450.00 88.780 259.560 8851.80 8910.60 10476.39 84.920 257.710 8853.25 8912.05 10507.40 85.130 256.150 8855.94 8914.74 10539.37 86.400 254.790 8858.30 8917.10 10570.39 87.450 254.050 8859.96 8918.76 10602.12 88.490 253.750 8861.09 8919.89 10633.53 89.080 253.800 8861.75 8920.55 10664.86 89.450 252.740 8862.16 8920.96 10696.33 90.120 252.670 8862.27 8921.07 10726.98 90.180 251.830 8862.19 8920.99 10756.23 90.580 252.010 8862.00 8920.80 10787.70 91.660 251.410 8861.39 8920.19 10818.30 92.890 251.730 8860.17 8918.97 10850.46 94.220 253.730 8858.18 8916.98 10882.52 94.490 253.510 8855.74 8914.54 10913.49 95.020 259.230 8853.17 8911.97 10945.03 92,280 262.100 8851.16 8909.96 10979.63 88.920 264.340 8850.80 8909.60 11009.80 86.980 268.490 8851.88 8910.68 11037.76 87.140 272.300 8853.32 8912.12 11069.21 91.630 274.420 8853.65 8912.45 11100.07 93.140 275.850 8852.37 8911.17 11130.48 93.820 275.110 8850.52 8909.32 11163.53 96.040 278.410 8847.68 8906.48 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (it) (ft) (ft) (ft) 3498.90 N 2271.59W 5954485.53 N 685146.38 E 3498.49 N 2273.83W 5954485.06 N 685144.15 E 3493.30 N 2299.66W 5954479.23 N 685118.46 E 3486.31N 2329.75W 5954471.50 N 685088.55 E 3478.31N 2360.61W 5954462.73N 685057.90 E 3469.99 N 2390.45 W 5954453.67 N 685028.28 E 3461.20 N 2420.92 W 5954~'!.~.12 N 684998.04 E 3452.43 N 2451.07 W 5954434.60 N 684968.12 E 3443.41 N 2481.07 W 5954424.84 N 684938.35 E 3434.05 N 2511.12 W 5954414.74 N 684908.55 E 3424.71 N 2540.31W 5954404.67N 684879.60 E 3415.63N 2568.11W 5954394.90 N 684852.03 E 3405.76N 2597.99W 5954384.29 N 684822.41E 3396.09 N 2626.99W 5954373.90 N 664793.65 E 3386.56 N 2657.64W 5954363.61N 684763.25 E 3377.55 N 2688.31W 5954353.83 N 664732.82 E 3370.28 N 2718.29W 5954345.82 N 684703.03E 3365.17 N 2749.35W 5954339.94 N 684672.11 E 3361.09 N 2783.69W 5954335.01N 684637.87 E 3359.21N 2813.78W 5954332.37N 684607.85 E 3359.40 N 2841.70 W 5954331.87 N 684579.93 E 3361.24 N 2873.08 W 5954332.93 N 684548.51 E 3364.00 N 2903.79 W 5954334.92 N 684517.74 E 3366.90 N 2934.00 W 5954337.07 N 684487.47 E 3370.77 N 2966.69 W 5954340.12 N - 684454.69 E Dogleg Rate (°/lOOft) 1.75 16.21 5.06 5.81 4.14 3.41 1.89 3.58 2.14 2.75 1.50 3.93 4.15 7.46 1.09 18.49 12.57 11.67 15.18 13.62 15.79 6.74 3.30 12.00 Alaska Drilling & Wells PBU_EOA DS 02 Vertical Section Comment 4021.70 Tie-on Survey 4023.11 Window Point AK-6 BP_IFR-AK 4038.97 4056.84 4074.61 4091.39 4108.34 4125.06 4141.51 4157.77 4173.39 4188.16 4203.94 4219.21 4235.81 4252.76 4270.35 4290.18 4313.16 4334.40 4355.41 4380.10 4404.89 4429.41 4456.43 Continued... 21 November, 2000 - 11:29 - 2 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 02,30B Your Ref: API-500292220202 Job No. AKMMO0183, Surveyed: 6 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11193.57 93.570 279.960 8845.17 8903.97 11225.23 91.880 284.790 8843.66 8902.46 11255.98 90.090 287.950 8843.13 8901.93 11288.11 89.720 295.740 8843.18 8901.98 11317.44 89.780 303.400 8843.31 8902.11 11351.67 89.170 306.690 8843.63 8902.43 11364.91 88.370 309.340 8843.91 8902.71 11400.27 87.790 312.170 8845.10 8903.90 11429.03 89.420 315.880 8845.80 8904.60 11462.05 92.400 318.710 8845.27 8904.07 11491.28 92.890 323.340 8843.92 8902.72 11525.22 90.800 327.300 8842.83 8901.63 11556.09 89.690 328.000 8842.70 8901.50 11587.71 88.890 328.800 8843.09 8901.89 11618.40 89.690 330.590 8843.47 8902.27 11642.58 89.780 334.110 8843.58 8902.38 11680.82 90.830 337.900 8843.38 8902.18 11709.06 90.460 338.890 8843.06 8901.86 11737.32 89.750 340.510 8843.01 8901.81 11767.34 89.910 342.000 8843.10 8901.90 11798.52 90.220 342.370 8843.06 8901.86 11829.99 90.770 342.100 8842.79 8901.59 11859.73 89.050 342.750 8842.84 8901.64 11894.06 88.860 341.850 8843.46 8902.26 11924.82 87.970 343.330 8844.31 8903.11 Local Coordinates Global Coordinates Northings Eastings Northings Easting$ (fi) (fi) (ft) (ft) 3375.55 N 2996.24W 5954344.17 N 684425.03 E 3382.33N 3027.12W 5954350.17 N 684393.99 E 3390.99 N 3056.62W 5954358.10 N 684364.29 E 3402.94 N 3086.42W 5954369.30 N 684334.20 E 3417.40 N 3111.91W 5954383.12 N 684308.36 E 3437.05 N 3139.92 W 5954402.07 N 684279.86 E 3445.20 N 3150.35 W 5954409.96 N 684269.23 E 3468.27 N 3177.12 W 5954432.35 N 684241.90 E 3488.25 N 3197.79 W 5954451.81 N 684220.74 E 3512.51 N 3220.18 W 5954475.50 N 684197.75 E 3535.20 N 3238.54W 5954497.73 N 684178.83 E 3563.09 N 3257.83W 5954525.13 N 684158.85 E 3589.17 N 3274.35W 5954550.79 N 684141.69 E 3616.10 N 3290.92W 5954577.29N 684124.45 E 3642.59 N 3306.40W 5954603.39 N 684108.31E 3664.00N 3317.62W 5954624.52N 684096.56 E 3698.93 N 3333.17W 5954659.05 N 684080.15 E 3725.19 N 3343.57W 5954685.04N 684069.10 E 3751.69 N 3353.37W 5954711.29 N 684058.64E 3780.12 N 3363.02W 5954739.47N 684048.29 E 3809.80 N 3372.56W 5954768.91 N 684038.01E 3839.77N 3382.16W 5954798.62N 684027.67E 3868.12 N 3391.14W 5954826.74N 684017.99 E 3900.82 N 3401.57W 5954859.17 N 664006.74 E 3930.16 N 3410.77W 5954888.27 N 683996.81E Dogleg Rate (°/lOOft) 9.70 16.15 11.81 24.27 26.12 9.77 20.90 8.17 14.09 12.44 15.91 13.19 4.25 3.58 6.39 14.56 10.28 3.74 6.26 4.99 1.55 1.95 6.18 2.68 5.61 Alaska Drilling & Wells PBU_EOA DS 02 Vertical Section Comment 4481.7o 4509.29 4537.1o 4567.31 4595.98 4629.98 4643.19 4678.52 4707.24 474o.o9 4768.88 48Ol.83 4831.49 4861.76 4890.93 4913.54 4948.35 4973.56 4998.49 5o24.58 5o51.42 5078.49 51o4.o3 5133.55 5159.9o Continued... 21 November, 2000.11:29 - 3 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 02-30B Your Ref: API-500292220202 Job No. AKMMO0183, Surveyed: 6 October, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (fi) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eestings (ft) (ft) (ft) (ft) 11952.28 88.120 341.980 8845.25 8904.05 3956.35 N 3418.95 W 5954914.26 N 683987.98 E 11985.34 87.940 342.500 8846.39 8905.19 3987.82 N 3429.03 W 5954945.46 N 683977.12 E 12008.13 88.030 341.490 8847.19 8905.99 4009.48 N 3436.07 W 5954966.94 N 683969.54 E 12047.53 87.780 342.060 8848.63 8907.43 4046.88 N 3448.39 W 5955004.02 N 683956.30 E 12078.47 88.060 341.960 8849.75 8908.55 4076.28 N 3457.94 W 5955033.18 N 683946.02 E 12115.72 89.140 341.170 8850.66 8909.46 4111.61 N 3469.71 W 5955068.20 N 683933.37 E 12145.09 89.510 340.980 8851.01 8909.81 4139.39 N 3479.24 W 5955095.74 N 683923.16 E 12173.20 89.290 338.660 8851.30 8910.10 4165.77 N 3488.93 W 5955121.87 N 683912.81 E 12207.11 89.850 340.840 8851.56 8910.36 4197.58 N 3500.67 W 5955153.38 N 683900.28 E 12238.38 89.940 340.450 8851.61 8910.41 4227.09 N 3511.03 W 5955182.61 N 683889.19 E 12267.08 90.620 340.760 8851.47 8910.27 4254.16 N 3520.56W 5955209.44N 683878.98 E 12297.83 90.250 340.480 8851.24 8910.04 4283.16 N 3530.77W 5955238.18 N 683868.06 E 12318.57 90.250 340.830 8851.15 8909.95 4302.73 N 3537.64W 5955257.57N 683860.71 E 12362.00 90.250 340.830 8850.96 8909.76 4343.75N 3551.90W 5955298.23 N 683845.43 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. "----." Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 311.600° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12362.00ft., The Bottom Hole Displacement is 5611.08ft., in the Direction of 320.727° (True). Dogleg Rate (°/lOOft) 4.94 1.66 4.45 1.58 0.96 3.59 1.42 8.29 6.64 1.28 2.60 1.51 1.69 0.00 Alaska Drilling & Wells PBU_EOA DS 02 Vertical Section Comment 5183.41 5211.84 5231.49 5265.52 5292.19 5324.45 5350.02 5374.78 5404.68 5432.02 5457.12 5484.Ol 5502.13 5540.03 Projected Survey Continued... 21 November, 2000 - 11:29 - 4 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 02.30B Your Ref: API-500292220202 Job No. AKMMO0183, Surveyed: 6 October, 2000 North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 02 Comments Measured Depth (ft) Station Coordinates TVD Northings Easflngs (~t) (ft) (~t) Comment 10447.72 8910.55 3498.90 N 2271.59 W Tie-on Survey 10450.00 8910.60 3498.49 N 2273.83 W Window Point 12362.00 8909.76 4343.75 N 3551.90 W Projected Survey Survey tool program From To Measured Vertical Measured Vertical Depth Depth Depth Depth (~) (~t) (ft) (~t) 0.00 0.00 10450.00 8910.60 10450.00 8910.60 12362.00 8909.76 Survey Tool Description MWD Magnetic AK-6 BP_IFR-AK 21 November, 2000.11:29 - 5- DrillQuest 2.00.02 North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 02 02-30B PB1 Job No. AKMMO0185, Surveyed: 26 September, 2000 SURVEY REPORT 21 November, 2000 Your Ref: API.500292220270 Surface Coordinates: 5951044.31 N, 687504.44 E (70° 16' 15.9439" N, 211° 30' 59.6682" E) Kelly Bushing: 58.80ft above Mean Sea Level I;IFIIIL. I_ I NtB SBFIVlCelB A Halliburton Company Survey Reh svy10557 Sperry-Sun Drilling Services Survey Report for 02,30B PB1 Your Ref: API-500292220270 Job No. AKMMO0183, Surveyed: 26 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8034.40 29.800 328.789 6684.65 6743.45 8063.00 29.540 329.090 6709.50 6768.30 8105.00 26.860 329.290 6746.51 6805.31 8132.21 26.580 329.430 6770.81 6829.61 8166.31 23.410 329.630 6801.71 6860.51 8197.99 20.650 329.850 6831.08 6889.88 8226.41 18.250 330.120 6857.87 6916.67 8260.02 15.170 329.940 6890.06 6948.86 8291.01 12.370 333.610 6920.16 6978.96 8320.18 9.440 333.270 6948.80 7007.60 8353.61 6.150 326.000 6981.92 7000.72 8383.40 4.430 319.540 7011.58 7070.38 8414.18 4.170 317.750 7002.27 7101.07 8447.14 3.590 326.230 7075.16 7133.96 8478.33 2.620 340.600 7106.30 7165.10 8505.44 2.130 3.640 7133.39 7192.19 8598.19 3.240 93.340 7226.07 7284.87 8694.00 4.120 99.380 7321.68 7380.48 8787.30 5.810 115.220 7414.63 7473.43 8881.03 5.490 113.250 7507.90 7566.70 8974.39 5.310 110.780 7600.85 7659.65 9068.47 4.990 112.210 7694.55 7753.35 9162.34 4.570 113.340 7788.09 7846.89 9255.65 3.990 110.970 7881.14 7939.94 9348.89 3.690 111.090 7974.17 8032.97 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (~) (~) (~) (~) 3564.31N 1947.00W 5954549.01N 685469.49 E 3566.44N 1954.31W 5954560.95 N 686461.89 E 3583.48 N 1964.47W 5954577.73N 685451.30 E 3594.01N 1970.71W 5954588.10 N 685444.80 E 3606.42N 1978.02W 5954600.33N 685437.19 E · 3616.68 N 1984.00W 5954610.44N 685430.95 E 3624.88 N 1988.74W 5954618.52 N 685426.01E 3633.25 N 1993.56W 5954626.76N 685420.98 E 3639.73N 1997.07W 5954633.16 N 685417.31E 3644.67N 1999.54W 5954638.03 N 685414.72E 3648.60 N 2001.77W 5954641.91N 685412.39 E 3650.80 N 2003.41W 5954644.07N 685410.70E 3652.53 N 2004.93W 5954645.76 N 685409.13 E 3654.28 N 2006.31W 5954647.47N 685407.71E 3655.76 N 2007.09W 5954648.94 N 685406.89 E 3656.85 N 2007.27W 5954650.02N 685406.69 E 3658.42N 2004.54W 5954651.65 N 685409.38 E 3657.70 N 1998.44W 5954651.09 N 685415.49 E 3655.14 N 1990.86W 5954648.72N 685423.13 E 3651.35 N 1982.45W 5954645.14 N 685431.64E 3648.05 N 1974.31W 5954642.05 N 685439.86 E 3644.96 N 1966.45W 5954639.15 N 685447.79 E 3641.94 N 1959.24W 5954636.31N 685455.08 E 3639.30 N 1952.79W 5954633.83 N 685461.59 E 3637.06 N 1946.96W 5954631.74N 685467.47E Dogleg Rate (°/lOOft) 1.05 6.38 1.05 9.30 8.72 8.45 9.17 9.46 10.05 10.25 6.10 0.95 2.47 3.96 3.92 4.17 1.00 2.32 0.40 0.31 0.37 0.46 0.65 0.32 Alaska Drilling & Wells PBU_EOA DS 02 Vertical Section Comment 3815.76 3829.28 3848.20 3859.85 3873.55 3884.85 3893.83 3902.99 3909.92 3915.04 3919.32 3922.Ol 3924.30 3926.49 3928.06 3928.91 3927.91 3922.87 3915.51 3906.70 3898.42 3890.49 3883.09 3876.52 3870.68 Tie-on Survey Window Point Continued... 21 November, 2000 - 12:02 - 2 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 02-30B PB1 Your Ref: API-500292220270 Job No. AKMMO0183, Surveyed: 26 September, 2000 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (fi) 9441.96 3.400 110.440 8067.06 8125.86 9534.08 3.300 106.190 8159.03 8217.83 9559.30 3.090 107.070 8184.21 8243.01 9631.78 2.990 98.190 8256.59 8315.39 9726.28 2.600 83.330 8350.98 8409.78 9819.90 8.650 173.190 8444.21 8503.01 9846.48 13.790 178.320 8470.27 8529.07 9883.11 18.500 175.680 8505.45 8564.25 9910.95 20.370 182.970 8531.70 8590.50 9945.09 20.400 200.220 8563.73 8622.53 9976.16 21.170 215.800 8592.80 8651.60 10003.74 22.020 231.090 8618.47 8677.27 10037.90 23.050 247.410 8650.05 8708.85 10069.00 28.130 250.440 8678.09 8736.89 10095.88 33.140 253.330 8701.22 8760.02 10131.20 39.870 256.670 8729.59 8788.39 10162.54 46.880 260.000 8752.36 8811.16 10186.50 51.790 259.840 8767.97 8826.77 10221.63 58.300 259.520 8788.09 8846.89 10257.03 62.290 260.340 8805.62 8864.42 10289.24 66.160 259.410 8819.63 8878.43 10321.36 70.170 258.550 8831.57 8890.37 10354.31 76.380 258.970 8841.05 8899.85 10382.03 80.270 259.490 8846.66 8905.46 10414.07 86.490 258.900 8850.35 8909.15 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3635.02N 1941.58W 5954629.83 N 685472.90 E 3633.33 N 1936.48W 5954628.27N 685478.04 E 3632.93 N 1935.13W 5954627.90 N 685479.40 E 3632.08 N 1931.39W 5954627.15 N 685483.16 E 3631.98 N 1926.82W 5954627.16 N 685487.73 E 3625.22 N 1923.87W 5954620.48 N 685490.85 E 3620.07N 1923.54W 5954615.33 N 685491.30 E 3609.91N 1922.98W 5954605.19 N 685492.12 E 3600.66 N 1922.90W 5954595.95 N 685492.44 E 3589.13 N 1925.26W 5954554.36 N 685490.36 E 3579.49N 1930.42W 5954574.60 N 685485.44E 3572.20 N 1937.36W 5954567.13 N 685478.68 E 3565.60 N 1948.53W 5954560.26 N 685467.68 E 3560.81N 1961.07W 5954555.15 N 685455.27 E 3556.57N 1974.09W 5954550.60 N 685442.36 E 3551.19 N 1994.38W 5954544.71 N 685422.21 E 3546.88 N 2015.45W 5954539.88 N 685401.26 E 3543.70N 2033.33W 5954536.25 N 685383.45 E 3538.54 N 2061.64W 5954530.39 N 685355.28 E 3533.17 N 2091.91W 5954524.27N 685325.15 E 3528.07N 2120.46W 5954518.45 N 685296.74 E 3522.37N 2149.72W 5954512.03 N 685267.63 E 3516.22 N 2180.65W 5954505.11 N 685236.86 E 3511.15 N 2207.32W 5954499.38 N 685210.33 E 3505.18 N 2238.56W 5954492.64N 685179.24 E Dogleg Rate (°/lOOft) 0.31 0.29 0,86 0.66 0.87 9.64 19.68 13.01 10.99 17.54 17.92 20.58 18.50 16.86 19.42 19.86 23.52 20.50 18.55 11.45 12.29 12.73 18.89 14.15 19.50 Alaska Drilling & Wells PBU_EOA DS 02 Vertical Section Comment 3865.30 3860.36 3859.08 3855.73 3852.24 3845.55 3841.88 3834.71 3828.51 3822.63 3820.08 3820.43 3824.40 3830.60 3837.52 3849.12 3862.01 3873.28 3891.02 3910.09 3928.05 3946.15 3965.2o 3981.77 4001.18 Continued... 21 November, 2000 - 12:02 - 3 - DriilQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 02-30B PB1 Your Ref: API-500292220270 Job No. AKMMO0183, Surveyed: 26 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Vertical Depth (~t) 10447.72 88.740 259.560 8851.75 8910.55 10474.14 89.230 259.570 8852.22 8911.02 10568.82 93.850 261.020 8849.67 8908.47 10662.63 93.970 261.650 8843.28 8902.08 10754.91 91.600 262.060 8838.79 8897.59 10784.04 91.780 261.140 8837.94 8896.74 10814.63 91.480 261.530 8837.07 8895.87 10849.49 92.490 262.230 8835.86 8894.66 10883.91 93.850 262.450 8833.95 8892.75 10915.66 92.490 266.300 8832.20 8891.00 10942.89 92.400 270.500 8831.04 8889.84 10978.18 95.210 275.690 8828.69 8887.49 11009.91 93.020 278.900 8826.42 8885.22 11037.14 89.940 282.430 8825.71 8884.51 11071.74 91.390 288.120 8825.31 8884.11 11102.79 92.800 291.630 8824.17 8882.97 11130.27 90.680 295.810 8823.34 8882.14 11164.78 87.820 301.440 8823.79 8882.59 11195.97 89.170 306.120 8824.61 8883.41 11222.80 90.180 306.870 8824.76 8883.56 11259.50 89.820 312.310 8824.76 8883.56 11290.01 89.540 316.730 8824.93 8883.73 11317.11 90.890 323.010 8824.83 8883.63 11351.80 89.780 328.690 8824.63 8883.43 11382.77 88.680 332.340 8825.05 8883.85 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (~t) (ft) (ft) (fi) 3498.90 N 2271.59 W 5954485.53 N 685146.38 E 3494.12 N 2297.57 W 5954480.10 N 685120.53 E 3478,17 N 2390.83 W 5954461.83 N 685027.70 E 3464.07 N 2483,36 W 5954445.43 N 684935.55 E 3451.01 N 2574,59 W 5954430.11 N 684844.67 E 3446.76 N 2603.40W 5954425.14 N 684815.98 E 3442.15 N 2633.62W 5954419.78N 684785.88 E 3437.23 N 2668,11W 5954414.00 N 684751,52E 3432.65 N 2702.17W 5954408,57N 684717.59 E 3429.54 N 2733.71W 5954404.68 N 684686.13 E 3428.78N 2760.90W 5954403,24N 684658.97E 3430.68 N 2796.05W 5954404.27N 684623.79 E 3434.70 N 2827.43W 5954407.50 N 684592.31 E 3439.74 N 2854.18W 5954411.87N 684565.45 E 3448.85 N 2887.54W 5954420.15 N 684531.87E 3459.39 N 2916.71W 5954429.96 N 684502.44 E 3470.44N 2941.85W 5954440.38 N 684477.04 E 3486.96 N 2972.13W 5954456.14 N 684446.36 E 3504.29 N 2998.04W 5954472.82 N 684420.03 E -3520.25 N 3019.60W 5954488.24N 684398.07E 3543.63N 3047.88W 5954510.91N 684369.23 E 3565.02N 3069.62W 5954531.74N 684346.95 E 3585.73 N. 3087.08W 5954552.01 N 684328.98 E 3614.42N 3106.55W 5954580.21N 684308.81E 3641.37N 3121.78W 5954606.78 N 684292.90 E Dogleg Rate (°/lOOft) 6.97 1.86 5.11 0.68 2.61 3.22 1.61 3,52 4.00 12.84 15.41 16.69 12.22 17.20 16.97 12.18 17.05 18.30 15.61 4.69 14.86 14.52 23.70 16.68 12.31 Alaska Drilling & Wells PBU_EOA DS 02 Vertical Section Comment 4o21.7o 4037.96 4097.11 4156.93 4216.49 4235.21 4254.75 4277.28 4299.7O 4321.23 4341.o6 4368.60 4394.74 4418.08 4449.08 4477.90 4504.03 4537.64 4568.52 4595.24 4631.90 4662.37 4689.17 4722.78 4752.07 Continued,.. 21 November, 2000 - 12:02 - 4 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 02-30B PB1 Your Reft API-500292220270 Job No. AKMMO0183, Surveyed: 26 September, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings (fi) (ft) (ft) (fi) (ft) (ft) Global Coordinates 11410.55 87.750 332.280 8825.91 8884.71 3665.96 N 3134.69 W 5954631.03 N 11447.90 88.400 334.640 8827.17 8885.97 3699.35 N 3151.37 W 5954664.00 N 11478.42 88.890 335.230 8827.89 8886.69 3726.99 N 3164.29 W 5954691.31 N 11506.39 89.910 335.900 8828.18 8886.98 3752.45 N 3175.86 W 5954716.48 N 11538.02 90.270 336.330 8828.13 8886.93 3781.37 N 3188.67 W 5954745.07 N 11572.27 91.450 335.330 8827.62 8886.42 3812.62 N 3202.69 W 5954775.95 N 11599.18 90.060 335.850 8827.26 8886.06 3837.12 N 3213.81 W 5954800.17 N 11631.73 87.170 336.110 8828.05 8886.85 3866.84 N 3227.05 W 5954829.55 N 11693.39 90.000 336.490 8829.57 8888.37 3923.27 N 3251.83 W 5954885.35 N 11739.00 90.000 336.490 8829.57 8888.37 3965.10 N 3270.02 W 5954926.71 N All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Eastings 684279.39 E 684261.89 E 684248.28 E 684236.08 E 684222.55 E 684207.76 E 684196.03E 684182.05 E 684155.88 E 684136.65 E The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 311.600° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11739.00ft., The Bottom Hole Displacement is 5139.56ft., in the Direction of 320.488° (True). Dogleg Rate (°/lOOft) 3.35 6.55 2.51 4.36 1.77 4.52 5.51 8.91 4.63 0.00 Alaska Drilling & Wells PBU_EOA DS 02 Vertical Section Comment 4778.04 4812.68 4840.70 4866.25 4895.o3 4926.26 4950.84 4980.48 5036.47 5077.85 Projected Survey Continued... DriilQuest 2.00.02 21 November, 2000 - 12:02 - 5 - Sperry-Sun Drilling Services Survey Report for 02-30B PB1 Your Ref: API.500292220270 Job No. AKMMO0183, Surveyed: 26 September, 2000 North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 02 Comments Measured Depth (fi) Station Coordinates TVD Northinga Eaetings (fi) (ft) (ft) 8034.40 6743.45 3554.31 N 1947.00 W 8063.00 6768.30 3566.44 N 1954.31 W 11739.00 8888.37 3965.10 N 3270.02 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From To Measured Verily=al Measured Depth Depth Depth (fi) (ft) (fi) 0.00 0,00 11739.00 Vertical Depth 8888.37 Survey Tool Description MWD Magnetic 21 November, 2000 - 12:02 - 6 - DrillQuest 2.00.02 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount ,~) ~ Commissioner DATE: October 3, 2000 THRU: Blair Wondzell P.I. Supervisor FROM: John Crisp'p~ J°[~", C_.. Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nabors 7ES BPX 02-30B 200-126 Prudhoe Bay Field Operator Rep.: John Rail Contractor Rep.: Charles Henley Op. phone: 659-4103 Rig phone: 659-4144 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 4000 MISC. INSPECTIONS: PIF Location Gen.: Good Housekeeping: Good PTD On Location '.~.e.~i'.'..~.. Standing Order: BOP 'STACK: Quantity Size PIF Sign: Yes Rig cond: Good Hazard: ..~es PIF Annular Preventer 1 13 518" P Pipe Rams 1 3112X6" P Lower Pipe Rams 1 2718X5" P Blind Rams 1 13 5/8" P Choke Ln. Valves 1 3" P HCR Valves 2 3" P Kill Line Valves 1 3" P Check Valve Annular: 3500 Choke: 4000 TEST DATA FLOOR VALVES: Quantity PIF Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 2 P CHOKE MANIFOLD: Quantity P/F No. Valves 14 P Man. Chokes 1 functioned Hyd. Chokes 1 functioned MUD sYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector Tested Tested~.. H2S Gas Detector Tested ~ested ACCU M ULATOR SYSTEM: Time/Psi P/F System Pressure 3000 After Closure ..... 4700 200 psi Attained 24 sec. Full Pressure 2 min. 3 sec. Blind Covers (All Stations): X N2 Bottles (avg): 6 ~[~ 2200 psi. Test's Details I traveled to BPX's Prudhoe Bay Field DS 02 to wimess the weekly BOP test on Nabors 7ES. One failure ws witnessed. The choke manifold gauge isolation valve failed to operate. The valve will be replaced & tested before drilling assembly enters open hole on Till. Rig & location are in very good condition. Due to increased Rig activity, there were many new were many new hands on the floor during BOP testing. Good test procedures & great contractor Rig supervisors will assure this Rig's continued excellent maintenance & testing of secondary well control equipment. Total Test Time: $ hrs. Number of failures: cc-' Attatchments: none V0vc7m6r.xls MEMORANDUM TO: Dan Seamount Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 3, 2000 THRU: Blair Wondzell tJ[~~ P.I. Supervisor ! 0[~/<30 FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nabors 7ES BPX 02-30B 200-126 Prudhoe Bay Field Operator Rep.: John Rail Contractor Rep.: Charles Henley Op. phone: 659-4103 Rig phone: 659-4144 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 400.0.. Annular: 3500 Choke: 4000,. TEST DATA MISC. INSPECTIONS: P/F Location Gen.: Good Housekeeping: Good PTD On Location Yes Standing Order: Yes P/F Sign: Yes Rig cond: Good ,! Hazard: Yes BOP STACK: FLOOR VALVES: Quantity PIF Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 2 P Quantity Size PIF Annular Preventer 1 13 518" P CHOKE MANIFOLD: Pipe Rams 1 31/2×6" P Quantity PIF Lower Pipe Rams 1 27/8X5" P No. Valves 14 P Blind Rams 1 13 5/8" P Man. Chokes 1 functioned Choke Ln. Valves 1 3" P Hyd. Chokes 1 functioned HCR Valves 2 3" P Kill Line Valves 1 3" P Check Valve MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector Tested Tested H2S Gas Detector Tested Tested ACCUMULATOR SYSTEM: Time/Psi PIF System PresSure 3000 After Closure 1700 200 psi Attained' 24 sec. Full Pressure 2 min. 3 sec. Blind Covers (All Stations):, X N2 Bottles (avg): 6 ~ 2200 psi. Test's Details I traveled to BPX's Pmdhoc Bay Field DS 02 to witness the weekly BOP test on Nabors 7ES. One failure ws witnessed. The choke manifold gauge isolation valve failed to operate. The valve will be replaced & tested before drilling assembly enters open hole on TIH. Rig & location are in very good condition. Due to increased Rig activity, there were many new wexe many new hands on the floor during BOP testing. Good test procedures & great contractor Rig supervisors will assure this Rig's continued excellent maintenance & testing of secondary well control equipment. Total Test Time: 6 hrs; Number of failures: 1_ cc.' Attatchments: non,e. Vv36b7di.xls ALASKA OIL AND GAS CONSERVATION CO~iSSION ,i TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drillng Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 02-30B BP Exploration (Alaska) Inc. Permit No: 200-126 Sur Loc: 154'SNL, 774'EWL, Sec. 36, T11N, RI4E, UM Btmhole Loc. 5149'NSL,'3126'WEL, Sec. 26, T11N, R14E, UM Dear Mr. Stone: EnClosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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 (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, J'r. Commissioner BY ORDER OF THE COMMISSION DATED this '~ ~ 7~'2' day of August, 2000' dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASK~ IL AND GAS CONSERVATION COM ..~SION ~ ' PERMIT TO DRILL 20 AAC 25.005 [] Drill Ba Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. RKB = 59.5' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028308 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 154' SNL, 774' EWL, SEC. 36, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number ~333'~SL, 1492' WEL, SEC. 26, T11 N, R14E, UM 02-30B Number 2S100302630-277 At t0"t~l depth 9. Approximate spud date 5149' NSL, 3126' WEL, SEC. 26, T11N, R14E, UM 8/29/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028307, 130' MDI 380' from 02-17 at 9899' MD 2560 13269' MD/~D 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8100' MD Maximum Hole Angle 91.6 ° Maximum surface ~,450" psi!~ At total depth (TVD) 8800' / 3330 psig 18. Casing Program Specifications Setting Depth %~'k~..\ ~ Size T~ ~1;) B~tt0m qppntity Of Cern~nt Hole Casincl Wei(~ht Grade CouDlino Lenqth MD TVD MD 'I'VD (include staqe deta) 6-3/4" 5-1/2" 17# L-80 ST-L 1668' 7950' 7750' 9618' 8300' PP3 cu ft Class 'G' 4-3/4' 3-1/2" 9.3# L-80 IBT-M 3801' 9468' 8230' 13269' 8841' 339 cuft Cle$$ 'G' ~'~ ~'~"~ .'~"'~, ~" ~'~ ~!i: ~ ...... ~:'"'~ ~i~=*'=' ~-.'=' ~f ~=:"' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~ ='~ ~'.?.:': ~:~' ~ ..... Present well condition summary Total depth: measured 12300 feet Plugs (measured) .~: ~ ~£' ~ (I ~'"~,.~ :.':~ ~ ~.., true vertical 8793 feet Effective depth: measured 12300 feet Junk (measured)~:¢!~,,~': ~--,"... r-~.~.:.' ,.., ' ..... ;,:~ ,'c~: (:i~ i'"'."~*~.~:~ !' ',:~":,:,'~';r~i:~.~.~¢...r:. true vertical 8793 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 11 yds Arctic Set 110' 110' Surface 2558' 10-3/4" 2563 cu ft COld Set III, 405 cuft 'G' 2558' 2361' Intermediate Production 8475' 7-5/8" 1369 cuft Class 'G' 8475' 7128' Liner 2494' 5-1/2" 257 cuft Class 'G' 8291' - 10785' 6968' - 8896' Liner 1778' 2-7/8" Uncemented Slotted Liner 10522' - 12300' 8822' - 8793' Perforation depth: measured Slotted Liner: 10773' - 12296'ORIGINAL true vertical Slotted Liner:. 8896' - 8793' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Schmitz, 564-5773 J~.~ ~//~/~r~j Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and pprrect to the best of my knowledge Signed DanStone ,~---------"~.~_, ~v"t, ~ Title Senior Drilling Engineer Date ~ / ,?-.~, 50- 029-22202-02(:~'/~,.~ / ~0 for other requirements Conditions of Approval: Samples Required [] Yes ~r'No Mud Lo~ I~equir~d [] Yes ~No Hydrogen Sulfide Measures ~'Yes[] No Directional Survey Required J~ Yes [] No Required Working Pressure for BOPE I"12K; r-I 3K; r-I 4K; [] 5K; r-110K; [] 15K by order of Approved By ORIGINAl. Rl~r::D 9y Commissioner the commission Date Form 10-401 Rev. 12-01-85 D Taylor Seamount 'riplicate 2-30B Permit to Drill DS 2.308 Ri_ site. Strr an/of Drillin Hazards POS7 THIS NOTICE IN THE DOGHOUSE IntenT~iate Section: The 6 ~' intern~iate section will be ddlled with mud ~ight ranging from 10.5 to 10 ppg. I-~gh fonmtion pressures could be present while drilling the Put River Sand. Pore pressure Equivalent Mud VVeight at 9.9 ppg may be encou~. I--lydrocarbo~ could be presaf[ in the int~ate section. Pit volum~ and rrud retums shodd be monitored carefully for signs of insuffident rrud v~ght. Shale imta~lity in the HRZ shale and Kingak shale, after kick-off-point (KOP), varmnt rrud v~gh~ ranging from 10 to 10.5 ppg to prevent shale sloughing. Pipe sticking tenda~ is possible if the HRZ shale gives problaTS. Back rearring at conned, ions and good hole deaning practio~ will contd~ to favorable hole conditions. Production Interval: ~/ ~ Kicks, Lost Returns, Stuck Pipe, and Plugged Rowlinas have been experienced dudng past Drill Site 2 ~ions. IVlud v~ight will be maintained in the 8.3-8.5 ppg range to conl~ fonTation ElV~ at 7.3 ppg. A fault crossing is expected in the resavdr at approximatdy 10950'. Slight risk of lost drculation is possible. LCM additions may be v~rr-ar~ed to restore drculation. ~/ DS-2(Drill Site 2) is not a designated I-ES pad. ~T THE PAD DATA SI-EET AND TIE V~I I PLAN FORADDITI(3NAL INF~TION 2-30B Permit to Drill IWell Name: 102-30B Sidetrack Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location' Target Location: Zn lA 8802 TVDss Bottom Hole Location' 154' SNL & 774' EWL, Sec. 36, T11N, R14E, Umiat X: 687504 Y: 5951044 3333' NSL & 1492' WEL, Sec. 26, T11N, R14E, Umiat X: 685150 Y: 5954475 5149' NSL & 3126' WEL, Sec. 26, T 11 N, R 14E, Umiat X: 683470 Y: 5956250 I AFE Number: 14J0447 I IRig: I Nabors 7ES I I I Operating days to complete: 122.9 I I CBE: 30.2 I I7Es: 29.3 I .KB: 59.5 [Estimated Start Date: 108/29/00 I MD: 13269 I ITVD= 8839 I Well Design (conventional, slimhole, etc.): I Conventional Horizontal Sidetrack Objective: I Development producer targeting distributary and mouth bar sands in Zone lA. I Mud Program: iMillinglCutting Casing Mud Properties: LSND Density (ppg) I Funnel Vis I Yield Point ~0.0 I 45- 55 I 25- 35 I Whipstock Window in 7-5~8" I pHI HTHP FL 9-9.5 <10 Intermediate Mud Properties: LSND I 8-1/2" hole section From sidetrack depth to 8384' MD (8369' TVD). TD Top of Sag River. Density (ppg) I Funnel Vis Yield Point I PV tau0 10.5 to 10.0 I 45 - 55 23 - 28I 10 - 17 3 - 7 APl FL <10 to 6 IProduction Mud Properties: Low Density QUICKDRILn Density (ppg) I Funnel vis I LSRV I PV 8.3-8.5 I 40- 50 I < 12,000 cPI 5-8 6 1/8" hole section I APl FI YP I Ca++ 17 -22 <100 <10 IpH 9.0-9.5I Directional: KOP: 8100' MD - 6 %" 29.2 deg. inclination Maximum Hole Angle: 91.6° @ 112003' (8893' TVD) I 2-30B Permit to Drill Vvell Name: APl Number: Well Type: Current Status: BHP: BHT: Last H2S Sample: Is this well frac'd? LOT Current Well Information 2-30A 50-029-22202-01 Shut-In Producer To be P&A'd as part of Pre-Rig Work & Replaced w/the 2-30B PSI I TVD I PSI/FT PPG 3320 8800 0.377 7.26 188°F @ 8800' TVDss DS 2 Pad Data Sheet: No wells >10ppm H2S No 7 5/8" @9963 F.I.T. on 8/18/91 to 12.5 EMVV 2-30 Wellhead: Tubing: Casing: Mechanical Condition: GL / MSL = 30.2(CBE, cellar box elevation) 4-1/2" & 3 %" L-80 Buttress Set on 5 % x 3 % Packer @9947'MD 10 %" 45.5#, J55@ 2558 7 5~8" 29.7#, L-80 (Pb = 6980 psi) 5 % .... Liner 8277-10785' MD. 2 7~8" 6.2#, L80 Liner 10529-10773 2 7/8", slotted liner 10773-12296' MD TD / PBTD / Fill: Pre-rig expected P&A cement top max 8100', min 10673 Casing Head: 7-5/8" Casing Hanger: Tubing Head Adapter: Tbg. Hanger: BPV Profile: Tree: Arco Prudhoe Bay Slim Hole 20" x 10 % SOW" x 7 5/8" x 4 %" 7 5/8" mandrel w/compression pack-off 11" 5M x 4 1/16 5M TC-IA EMS w/SBMS 4 % Butt. On bottom To be determined. 7 1/16" 5m x 5 1/8" Bore - TClA-EN Hanger, FMC Open Perfs: Tubing Fluids: Annulus Fluids: To be P&A'd as part of pre-rig work Seawater and diesel as per handover Seawater and diesel as per handover Tubing Test: 7-5/8" Test: 10 3/4" Test 7-5/8" Pack-off Test: 4 %" Pack-off Test: Failed Tubing x IA test. Possible leak at 10 % x 5 % liner top Test pending'rig setting ClBP. No record 8/13/91 Tstd to 3500 psi (5M rated) 8/25/91 Tstd t o 5000 psi 2-30B Permit to Drill Formation Markers: Formation ~) (~)~) Co.~e~ : Base Permafrostl SV3/T5 K15 (top 1st coal) . .-'. · .., "= ......... UG4~op Ugnu~ WS2/Top West Sak . ... ,....,r..~, , ~/K1 O/Top Colville Mdstn I CMl/K5 .' ........... "" .. ' ,,' ,' '"',;,..3. K-12 Marker ",".~".....' ...::.".' K-10 Marker 6370 K-5 Marker l 8 ! 00 6805 Sidetrack & KOP K-2 Marker/Top of HRZ 9:250 7856 K-1 Marker 9400 8051 Base HRZ( shale wall)! 9650 8058 Put River 80?3 Kuparuk Ss Not present LCU: 9450 81.20 I~ingak 9498 8120 TJD/Top Kingak D 9498 8120 TJB/'I'op Kinoak B 9498 8120 Sa~l River Ss 9608 8230 Drill 6 3/4" hole into the TSGR & sot 5 1/2" drilling liner. WD-TSHU/Shublik 9648 8270 Eileen 9725 8347 VVD-~/~4B 9725 8347 VVD-TZ3 9885 8506 WD-TZ2C 9946 8567 WD-23SB 10024 8642 VVD-22TS 10100 8708 VVD-21TS 10102 8750 WD-TZ1B 10356 8820 Max TVDss 10900 8841 , , 'ID 13269 8781 WD-'TZlA 8845 BSAD 8875 Logging Program: Intermediate Section Production Hole MWD / GR / Resistivity IDrilling: Open Hole: Cased Hole: Drilling: Open Hole: None None MWD / GR / Resistivity / Neutron / Density/ABI None 2-30B Permit to Drill I CasinglTubin9 ram: Hole Size Csg/Tbl~ #1~ Grade Conn Length Top MD TVD Btm MD TVD ID 6 314 5 112 17 L-80 ST-L 1668 7950 7750 9618 8300 4.892 4 314 3 112 9.3 L-80 IBT-M 3801 9468 8230 13269 8841 2.992 Tubing 4 112 12.6 Cr IBT-M 7950 7950 7750 9468 8230 3.958 Tubing 3 112 9.3 Cr IBT-M 1518 7950 9468 2.992 Drilled Interval 1: KOP 7 518 29.7" I ID 6.875 I KOP: 8100 Bit: 6 3/4 to 9618 Total length to be drilled this interval: ~ 1518 ft. Drilled Interval 2' Drill out: 5 112 17 I ID 4.892 Total length to be drilled this interval: ~ Shoe: 9618 Bit: 4 314 to 13269 Cement Calculations: 3651 ft. Liner: Intermediate 6 314 inch bit 5 112 in liner 4 in. DP Lead: None Tail: Design based on 80' shoe track volume, open hole ~} 30% XS, 150' liner lap, 200' XS. BarrelsI CF ISacksl PPGI CFIsk ]TOC, MD TOL ITopOH Btm, MDI Type 39.8 223 I 193 I 15.8 1.16 7750 7950 I 8100 9618 Dowell Class 'G" Cement Length, feet 200 150 J 1518 80 Barrelslft calc's 0.030 0.017 0.019 0.023 Liner: Production 4 314 inch bit 3 112 inch liner 2 718 in. DP Lead: None Tail' Design based on 80' shoe track volume, open hole ~} 50% XS, 150' liner lap, 200' XS. BarrelsI CF IS.=k=l,,oI .oc.M= iTopOHBtm. MDIType 60.3 339 I 289 I 15.8 1.17 9268 9468 9618 13269 IDowell Cl 'G"+ addsI Cement Length, feet 200 150 ; 3651 80 I Barrelslft calc's 0.015 0.011 0.015 0.009 2-30B Permit to Drill Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Maximum Anticipated Surface Pressure: (based on BHP & full gas column at 0.10 psi/ft). Section Max Sfc Pres. Presv TVD Gas Grad. EMW FM Intermediate 2427 3264 8369 0.1 7.5 Sag R Intermediate 3384 4200 8164 0.1 9.9 Put R. Production 2450 3330 8800 0.1 7.3 Zone 1 Planned BOP test pressure: 4000 psi Intermediate/~ Production Planned completion fluid: 8.6 ppg Seawater / 6.8 ppg Diesel ....... .'.I,;','.? ~'.J.,:i ~.'i'~' ''~'' ~=.',~.','.i :..~ .. ;: '~;'.L.' i'". '"" i~! '-~,, ~i.,, ,,.,..~...~'" ',,., ': ' ' ~', ....... ,, .' Drilling Hazards/Contingencies: .. lC, ~.,,~., ,,,, .,.. ~'~.,, '~: '~;. ,, ...., .". .... :, ...... ...,? HYDROGEN SULFIDE - H2S · DS- 2, {DS-'IS,. & DS-15 BHL Locations) are not designated as H2S drill sites and do not have wells with over 10 ppm, (9128199). Standard Operating Procedures for H2S precautions should be followed at all times. RIG MOVE & SHUT-IN REQUIREMENTS · Adjacent wells 2-17 & 2-18 are 35 & 38' respectively from the 2-30 wellhead. All 7ES & 9ES rig moves which involve well to well spacing greater than 30' have been given dispensation and do not require surface and/or SSSV shut-in of adjacent wells. Establish a minimum distance of 5' from each of the adjacent wellheads or wellhouses. Discuss the move at a pre-job safety meeting and designate a spotter to ensure that there is no danger of collision. DRILLING CLOSE APPROACH: · There are close approach wells associated with the directional plan for this well. The risk of collision is considered to be minor as the trajectory immediately begins diverging away from the offset wellbore(s). The consequences of a collision could include lost circulation or a hydrocarbon influx (kick). Remedial action could include squeeze cementing and sidetracking. Close Approach Well: I 2-17 380' Approach while drilling at 9883' Producing Well I 2-30B Permit to Drill INTERMEDIATE SECTION: ..... " .'.' Hydrocarbons could be present in the intermediate section. Geologist advises that the K2 & K1 Marker could contain gas and the Put River sand could be oil bearing @ 4200 psi. Follow good well control practices at all times. Monitor pit volumes and mud returns for any signs of insufficient mud weight There should not be significant stability problems within the intermediate interval. Kick-off with sufficient mud weight into the K5 marker shale and maintain MW into the short Kingak shale that will be encountered. It would be advisable to minimize pressure surges while drilling, tripping, and running liner. After sidetracking, out of 7 5/8" @ 29 degrees inclination, the intermediate hole will be taken nearly vertical to casing point. On DS 2, tight hole and packing off have been the main problems throughout this interval. Good drilling practices and 10.5 t o10 ppg mud weight will be used to maintain the shales in the intermediate hole section. Also, asphalt shale products such as Baranex and Barotrol in the mud system and the HTHP filtrate values below 10 cc/30 minute will assist with shale stability. Pad data sheet indicates Put R. zone may have a reservoir pressure of 4200 psi. Kingak and Shublik drilling has experienced gas cut mud. KICK TOLERANCE: In 6 314" open hole section is 39 bbls at an ISIP of 16 psi. This assumes an influx from the Sag River formation at -9618' MD (8300' TVD), a 7.5 ppg pore pressure within that interval, a 10.5 ppg mud in the hole, exerting pressure against an 12.5 ppg fracture gradient at the 10 % .... shoe. This assumes that while circulating a gas kick out of the hole, a breach in the 7 5/8" casing exposes the 10 %" surface casing shoe to pressure. PRODUCTION SECTION: Fault crossing expected in the reservoir section @ 10950 x= 683800, y = 595540. Displacement approximately 20' drilling from downthrown to upthrown fault block. Little risk of lost circulation as fault plane likely to have abundant shale smear. Ivichak zones 4,3,2 & 1 have experienced lost returns. KICK TOLERANCE 4 %" production hole, at the 5 1/2" shoe would be an infinite influx (the annular volume) assuming an influx at section TD of 12,590 (9034' TVD). This is a worst case scenario based on a 7.5 ppg pore pressure, a minimum fracture gradient of 9.5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. 2-30B Permit to Drill SUMMARY SIDETRACK PROCEDURES Notify the field AOGCC representative with intent to plug and abandon * Pre-Ria Work: 1. MIRU Slickline. Drift/tag liner top packer tailpipe SN @9971' MD. 2. Load and Kill IA and tubing. Perform injectivity test to verify ability to pump into the well. 3. Plug & abandon w/15.8 ppg Class G cement. Overdisplace to peris with S/W and diesel for freeze protect. Place 5 bbls minimum behind pipe into pert's. Max TOC is 8100' to allow tubing to be cut and sidetrack. 4. Minimum TOC is 100' above top perforation. 5. MIRU S/L. Drift/Tag TOC test, and document top of cement per AOGCC requirements. 6. If TOC is higher than 8100', MIRU coil unit with 4.5" mill to clean up cement stringers. Re-PT cement plug and record on chart. 7. Test the FMC 7 5/8" mandrel pack-off to 5000 psi and service lock down studs by backing out and re- torquing one at a time. Test the tubing hanger pack-off to 5000 psi and service each LDS. 8. Test the 7 5/8" casing to 3500 psi against the packer. Hold 1000 psi on the tubing to prevent from collapsing the tubing. 9. MIRU E/L unit. RIH with jet cutter and sever 3 ~' below anticipated side-track depth. A 7 5/8" CIBP & whipstock will be set after the drilling rig removes the 4 %" & 3 %" tubing. Jet cutter is acceptable as this tubing will not be fished. Note the depths of the GLM's in the 5 %" tbg string. Circulate clean sewater around IA and tubing. 10. Check with the 7ES Rig Supervisor regarding rig timing and determine if freeze protection to diesel will be required. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 3500 psi. Secure well with 0 psi on tubing and annulus 11. Remove the well house and flow lines. Level the pad and dig out the cellar. Please provide total well preparation cost on the hand over form. 2-30B Permit to Drill Rig Operations: Summary 1. MIRU Nabors 7ES. 17. 18. 19. 2. Circulate out freeze protection and displace well to sea water. Ensure BPV is set. Nipple down tree. Nipple up and test BOPE to 4000 psi. 3. Pull and lay down production tubing, X nipple & GLM's from E-line cut. Replace 7-5/8" pack off as required. 4. RU E-line and make 7 5~8" GR/JB run to top of tubing cut. Set 7 5/8" ClBP on E-line at whipstock depth. (set per Baker recommended depth to avoid milling casing collar). Pressure test casing to 4000 psi. 5. PU 4" DP & collars. TIH with 7-5/8" Baker bottom-trip anchor whip-stock/mill assembly. Displace w/ LSND mud. Orient whip-stock, with MWD as required and set. Mill 6.75" window in 7-5/8" casing at -8100' MD. POOH. Note: hole angle - 29 deg...orient whipstock using high side. 6. Run in hole w/directional drilling assembly. Drill 20' & conduct FIT to 12.5 ppg. EMW. Kick-off and drill 6 %" hole from into the top of the Sag River formation. Run MWDIGRIRESIABI LWD. LSND mud @ 10.5 ppg. Drop ESS. 6 %'" Bit#1. POOH. 7. Run and cement a 5 %", 17# L-80 intermediate drilling liner with 150' of lap to TD. POOH. 8. Make up and RIH with a 4 3/4" bit, directional assembly, 3 %" DC's, -5500' of 2 7/8" DP, XO, 4" DP & TIH to the landing collar. 4 %" Bits 2, 3, 4 TBD. ...~ ~tec~ ¥~--;~ ~(3~'~-.~'¥ rv~r~f .. ,-: 9. Test the 7-5/8" casing and 5.5" liner from the landing collar to surface to 4000 psi for 30 minutes. ~ ~1~ 10. Drill out 20' & FIT tp 9.5 ppg EMW. Displace w/Iow density mud. Drill 4 3~4" hole from to TD in Zone lA. Run1 MWDIGRIReslDENINEUIABI real time LWD. Run 2 MWDIGRIReslABI. 11. Spot liner running pill in open hole & POOH w/DP. 12. Run 3 %", 9.2# L-80 IBT-Mod production linerw/150' of lap to TD. Pump cement, drop wiper plug and displace with "perf pill" followed by mud. 13. Test the 3-1/2", 5.5", and 7-5/8" casing from the landing collar to surface to 3500 psi for 30 minutes. Displace well to clean sea water above liner top. POOH. 14. Drill pipe convey, over-balanced, perforate 4spf, -2000', of the production interval as determined by log analysis. POOH w/DP. 15. Run WLEG, Packer, 3 GLM's, 3 % Chrome, & 4-1/2" Chrome tubing, to the 3-1/2" liner' top. Reverse circulate clean seawater w/corrosion inhibitor. 16. Drop ball/rod & set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. Shear the RP. Set BPV & test from below to 3500psi. ND BOPE & Nipple up adapter and test the tree to 5000 psi. Freeze protect the wells tubing & annulus to -2000' and secure well. Rig down and move off. Post-Ria Work: · MIRU slickline. Pull the ball / rod and RHC plug from 'X' nipple below the new production packer. Install gas lift valves. Place well on production. TREE: $-1J2" - 5M L-80 WELLHEAD: FMC - 5M Gen 3 Surface Location: x=687504 y= 5951045 161' FNL & 4606' FEL Sec 36 Tll N R14E 2-30A Existing Completion GL Elevation = 37.1 Nabors 7ES RKB [] 67.1' 4-112" 'X' Landing Nipple with 3.813" profile 2186' MD 10 314" 45.5# #/ft, J55 ~ 2558' Tubing: 4-112" 12.6# L-80, IBT Mod Tubing 0 - 7980' MD XO 2.386" ID 3 112" 9.3#, LB0, 7980- 10528' MD GLM t KBMG 1" ~ 6t88' MD GLM 2 MMG2 1 112" 8180' MD GLM 3 TrimV4 1" I~ 9914' MD 7 6/8", 29.7 #/ft, L80, BTC, 9973 MD' ~ 8475'-8620' Original Window Cut 7 5/8" x 6 112 ZXP LHIPkr 8277' MD ~ 6 112", 17# LB0 8277-10786MD 5 112 x 3 112 SABL Pkr 9947' MD 3 112 XN Nipple, 2.636" ID ~ 997t' MD PXN plug ran 5121199 WLEG 9993' MD 6 112 x 3 112 TIW S6 Pkr ~ 10620' MD 3 112 x 2 718" XO ~ 10528' MD 2 718" 6.2#, LB0 liner 10629-10773' MD, (8896-8794 TVD) PRUDHOE BAY UNIT WELL: 6-24A APl #: $0-029-20822.01 .. .-' ~.:..'.~ ~ ) ,~:. . ~, . ~.~......: .,:~ .. ,... 2 7/8" slotted liner 10773-12296' MD, (8896-8794 TVD) Date Revised by Comments 7/24/00 SHS Existing completion TREE: 5-112" -5M L-80 WELLHEAD: FMC - 5M Gen 3 2-30B Proposed Completion GL Elevation = 37.1 Nabors 7ES RKB = 55.20' 4-112" 'X' Landing Nipple with 3.813" profile 2186' MD 10 314" 45.5~ #1ft, J55 ~ 2558' TOC Calculated 3586 Lead TOC Calculated 8367' Tail III Proposed: Whipstock set on CIBP ~ -8100' MD' Original: 7 5/8", 29.7 #1ft, LB0, BTC, 9973 MD' 8475'-8520' Original Window Cut Tubing: 4-112" Chrome Tubing: -7800' 3 112" Chrome Tubing 7800' to 6 112" Liner Top wi X nipple & WLEG GLM t GLM 2 GLM 3 7 $18" x $112" Liner Hanger/Packer-7950' MD 7 5/8" x 5 tl2 ZXP LHIPkr 8277' MD 5 112", 17# L80 8277-10785MD 6 314" borahole 5 112 x 3 112 SABL Pkr 9947' MD 3 112 XN Nipple, 2.635" ID ~ 9971' MD PXN plug ran 5121199 WLEG 9993' MD 5 112 x 3 112 TIW S6 Pkr ~ 10520' MD 3 112 x 2 718" XO ~ 10528' MD 2 718" 6.2#, LB0 liner 10529-10773' MD, (8896-8794 TVD) P & A Cement: Max TOC I~ 9900' (3 1/2" tubing cut) Min TOC ~ 10663' ( 100' above top perf) PRUDHOE BAY UNIT WELL: 6-24A APl #: 50-029-20822.01 5 112 x 3 112 Liner HangerlPkr Proposed: 6 314" borehole 5 112" 17# LB0 ST-L FJ Drilling Liner set at TSGR TSagR. 9873' MD, 8283'TVD Proposed: 4 3/4" Bit 3 1/'2" Prod. Liner to TD DPC Perforated 2 718" slotted liner 10773-12298' MD, (8895-8794 TVD) Date Revised by Comments 7/24/00 SHS Proposed completion 6800 7200 7600 .-- ~, 8000 8400 (:3 II 0 ~. 8800 Shared Services Drilling 02-30B Wp 01 Exit @ 12.000°1100ft, 270.000° TF · 8100.00ft MD, 6800.54ft TVD Dir @ 10.000°ll00ft· 8140.00ff MD, 6835.42ft TVD Dir' 8451.88ft MD, 7134.37ft TVD J DrillQuest' Proposal Data for 02-308 WP01 Vefllcal Odgifl: Well Horizontal Origin: Wel Measurement Urits: fl Nerlh Reference: True Nollh Dogleg sevefily: Degrees per lOOft VelliCal Sec0on AzrmlJIh: 311.603' Vedlcal Sec~on Decalph~'c Well Vedical Section Odgin: 0.00 N.0.00 E Measured MCI. AzIm. VerticalNorthlngl Enaflngl Vertical DogJeg Depth Depth 8ecfon hie 8100.0029.186 329.39568(30.54 3582.05 N 1963.56 W3S46.M 8140.0029.544 319.6256835.42 3397.96 N 1974.92 W3~6.70 12.OGO 8451.881.751160.8267134.37 3653.40 N 2024.39 W3939.~)I0.(NJO 9~8.19 1.7571~).8268$SO.(X) 3611.52N 2009.83 W3W0.80 O.OGO IQ358.74 87.072 246.2~38880.30 3488.28 N 2268.24 W40J2-2019.ge0 1~55.7487.072 24~2S3 8880.30 3488.21S N2268.24 W4012-20I g.(XJO 10672.8S 87.072 246.2538896.SO 336O.75 N 2.558.12 W 4144.29O.O(]O 10956.32 91.435 280.(]00 F~0.30 3327.36 N 2835.42 W4329.411 12.000 11432-~91.435 337.2088887.27 3612.4ON 3192.44 W4785.7012.060 13268.97 91.435 337.2088841.30 5304.59 N 3903.50 W6440.95O.OO0 7" Casing 9618.06 MD 8300.00 TVD ~4ss. zs ~i 2zas. z4 n' sJ.2zs6 ~.; ~sss.4~ n, I 4000 4400 4800 Single Well Target Data for 02-30B WPS Mnastrement Urits: It Coordinate Target Point Name Type 02-30B BSL F~ Point BomxJary Poinf A D I 02-308 BSL Entry Point 02*308 bt Emy Point TVDrkb TVDnaNorthlflgl ;-stingsASP Y ASP X Target Shape 8880,t0 8820.00 3488.28 N 2268.24 W 5954475.00 N 683150.00 E Polka 888030 8820-00 3701.97,~ 2212.90W 5954600.00,~ 685200.00 £ 8880.30 8820.00 3545.97 N 2776.96 W 5954520.00 N 684640.00 E 8880.30 8820.00 3651.92 N 3014.39 W 5954620.00 N 684400.1)0 E 8880.30 8820.00 5432.55 N 3820.28 W 5956380.00 N 683550.00 E 8880.30 8820.00 5319.32 N 4093.19 W 5956260.00 .~ 683280.00 E 8880.30 8820.00 4447.63 N 3634.76 W 5955400.00 N 683760.00 E 8880.30 8820.00 3399.10 N 3305.78 W 5954360.00 N 684115.00 E 8880.30 8820.00 3160.33 N 2956.62 W 5954130.00 N 684470.00 E 8880-10 8820.00 3378.83 N 2090.91 W 5954370.00 N 685330.00 k 8900.10 8840.00 3327.36 N 2835.42 W 5954300.00 N 684587.00 E Poinl 8841.10 8781.00 5304.59 N 3903.50 W 5956250.00 N 683470.00 E Poinl I Current Well Properties Wdl: 02-308 WPS TJD/Top KingaA B/I.C( i . 818C1.$0 ~ 'D H~lal ~xxdimtos: Ref. Cdobal Cooedimlos: 5951044.31 N, 687504.44 E Ref. SImc;lum Refemm:e: 2247.23 N, 79.84 W Ref. Genital Coerdinatea: 70' t6' t5.9439' N, 148' 29' 00.3318' W 73'GR - ~)9~.$0 TVD .73.WU. 85 ~0_$0 TFD RKB Eleva~on : 60,3~t ax)ve Msan Sea Lavd I Nodh RMBmnce: True Nerlh ~:)~O~cO '~)-- I Units: Foci ...........................................................................................~.~... rz3 - ~66.311 ,t'l 4 1/2' Liner 25.%7~- .~;;02.$, 7';'D ......................... 1'3268.'97 MD' ............. .1~,41..3.0. ~3~) .............. ~2L3' - 376&.~0 7'1,'1) . ~1 '13'. 8n'hl.$o 5200 5600 8000 :02,~OB:WFU:',C::::::: :.,,)~.-..)#t,~ ~)3 ~t: - -' ................. 77.1/t. #80r~.3o 13.'[.) .................. IZ/ ~ · ,';,¥35.$0 TI'l) · ~,~'.-.,~-T,~-J-~- ................... J'~,~;,lO- 1~9.t0.311 T[/D 5.¢0.L.'~9 :\:, -F~fi.L .~,") I I 6400 6800 Scale: linch = 400ff Vertical Section Section Azimuth: 311.603° (True North) 02-$0B Iht 8841.30 Shared Services Drilling 02-30B WD 01 · 5200 Scale: linch = 400ft -4000 -3600 I I 4 1/2' Uner 13268.97 MD Eastings -3200 -2800 -2400 -2000 4800 - 4400 - 4000 - 3600 - c) II ~ 3200 - r Current Well Propariias ng ~m~'lkel CcxVcilKe~: /~ ir t[~ N, 14r ~OJ~lr W ~m Ibo~ Sl,~mJm ndB,m~ : I -4000 -3600 Scale: linch = 400ft I -3200 02-30B BSL 8900.30 TI'Z) 3327.36 N, 2835.42 -2800 Eastings I -2400 Casing 9618.06 MD 8300.00 TVD 02-30B B$~ 8880.30 h'd $488.28 N. 2268.24 W -2000 Reference is True North 5200 4800 4400 4000 36OO II .B 3200 ~ I DrillQuest Sper./-Sun Drilling Se, ¢ices Proposal Data - 02-30B WPS- 02-30B WP01 i 3~2.05N~ 1963.56Wi ~!~ 10.000 :4 :~: 9898. t9 ~6~31 ::1:757 : 1~5.63 3611.52N 2009.~W 10355.74 457,~ 87.072 246.253 8880.30 ~0.30 3488.28 N 2268.24 W 19.000 '85.518 6 ~t0355.74 0.00 87.072 246.253 8880.30 .... 0.00 3488.28'N' 2268.24'W 19.000 338,868 7 10672.85 317.1'1 87.072 '246.253. 8896.50· "16.20 3360:75'N '2558. i2 W 0.000 0.000 .8" 10956.32 283.47 91.435 280.000 8900.30" ""' 3:80 3327.36 N 2835.42 W i2.000.:.'' .". 83.073 ..... . .. . .,i... ,~. ~, ...... ,~ ,~... .. . ..... ...9.. · '!1432.89 476.57....9i;435 '337~208 ' 8887;27 . ..'~-13.03 .. 3612.40 N ".3192;4~4 W' 12.000 .."::. 89.218 · .. :10 :..113268.97....fl836.08 ..:911..435: ..:.337~.208: 8841.30' -45.97 5304.59 N 3903.50 W 0.000 0.000 27 July, 2000- 12:28 - 1 - DriliQuest North Slope Alaska Alaska State Plane 4 PBU EOA DS 02 02-30B W~S- 02-30B W~I~ T 2~ Surface Coordinates: 5951044.31 (70° 16' 15.9439" N, 148° 29' 00.3318" HO above Mean Sea Level Proposal Ref: pro909~ North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (f~) (ft) 8100.00 29.186 329.395 6740.24 8140.00 29.544 319.625 6775.12 8200.00 23.546 319.304 6828.77 8300.00 13.552 318.182 6923.45 8400.00 3.590 311.003 7022.22 8451.88 1.757 160.826 7074.07 8500.00 1.757 160.826 7122.17 8600.00 1.757 160.826 7222.12 8700.00 1.757 160.826 7322.07 8800.00 1.757 160.826 7422.02 8900.00 1.757 160.826 7521.98 9000.00 1.757 160.826 7621.93 9100.00 1.757 160.826 7721.88 9200.00 1.757 160.826 7821.84 9300.00 1.757 160.826 7921.79 9400.00 1.757 160.826 8021.74 9498.30 1.757 160.826 8120.00 9500.00 1.757 160.826 8121.70 9600.00 1.757 160.826 8221.65 9608.36 1.757 160.826 8230.00 9618.06 1.757 160.826 8239.70 9648.37 1.757 160.826 8270.00 9700.00 1.757 160.826 8321.60 9725.41 1.757 160.826 8347.00 9800.00 1.757 160.826 8421.55 Sperry-Sun Drilling Services Proposal Report for 02-30B WPS - 02-30B WP01 Vertical Local Coordinates Global Coordi Depth Northings Eastings Northings (ft) (~t) (ft) 6800.54 3582.05 N 1963.56 W 5954576.: 6835.42 3597.96 N 6889.07 3618.34 N 6983.75 3642.28 N 7082.52 3653.09 N 7134.37 3653.40 N 7182.47 3652.01N 7282.42 3649.11N 7382.37 3646.22 N 7482.32 3643.32 N 7582.28 7682.23 36372 7782.18 7882.14 7982.09 8082.( ~.94 N 81! N N 8281.4 3620.15 N 8290.30 3619.91N 8300.00 3619.63 N 8330.30 3618.75 N 8381.90 3617.26 N 8407.30 3616.52 N 6481.85 3614.36 N 1974.92 W 1992.34W 2013.23W 2023.43~ .89 W W W 2017.86 W 2016.86 W 2015.85 W 2014.84 W 2013.85 W 2013.84 W 2012.83 W 2012.74 W 2012.65 W 2012.34 W 2011.82 W 2011.57 W 2010.82 W (°ll00ft) 5964646.14 N 5954644.76 N 5954641.89 N 5954639.02N 5954636.15 N 5954633.28 N 5954630.41N 5954627.54 N 5954624.67 N 5954621.80 N 5954618.93 N 5954616.11N 5954616.06 N 5954613.19 N 5954612.95 N 5954612.67 N 5954611.80 N 5954610.32 N 5954609.59 N 5954607.45 N Alaska State Plane 4 PBU_EOA DS 02 Vertical Section (ft) 3646.64 E 12.000 3865.70 685422.58 E 10.000 3892.25 685401.10 E 10.000 3923.76 685390.63 E 10.000 3938.57 685389.66 E 10.000 3939.50 685390.18 E 0.000 3938.21 685391.26 E 0.000 3935.64 685392.33 E 0.000 3932.86 685393.41E 0.000 3930.18 685394.49 E 0.000 3927.51 685395.57 E 0.000 3924.83 685396.65 E 0.000 3922.16 685397.73 E 0.000 3919.48 685398.81E 0.000 3916.80 685399.89 E 0.000 3914.13 685400.95 E 0.000 3911.50 685400.97 E 0.000 3911.45 685402.04 E 0.000 3908.78 685402.13 E 0.000 3908.55 685402.24E 0.000 3908.29 685402.57 E 0.000 3907.48 685403.12 E 0.000 3906.10 685403.40 E 0.000 3905.42 685404.20E 0.000 3903.42 Comment ST Exit (~ 12.000°/100ft. 270.000~'1'F: 8100.00ft MD, 6800.54ft TVD Be~in Dir ~. 10.000°ll00ft: 814'0.00ft MD, 6835.42ft TVD End Dir: 8451.88ft MD, 7134.37ft TVD TJD/Top Kingak B/LCU TSG~ "~'Casing TSHU TSAD/TZ4B/Eileen Continued,.. 26 July, 2000- 16:21 - 2- DrillQues! 1.05.05a North Slope Alaska Sperry. Sun Drilling Services Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (~) (~) 9884.49 1.757 160.826 8506.00 8566.30 9898.19 1.757 160.826 8519.70 6580.00 9900.00 1.816 171.691 8521.51 8581.81 9945.72 9.332 235.617 8567.00 8627.30 10000.00 19.556 241.404 8619.50 8679.80 10024.25 24.148 242.431 8642.00 8702.30 10100.00 38.514 244.140 8706.53 8766.83 10101.88 38.871 244.168 8708.00 8768.30 10160.82 50.059 244.875 8750.00 8810.30 10200.00 57.498 245.226 8773.14 8833.44 10300.00 76.487 245.922 8812.04 8872.34 10355.74 87.072 246.253 8820.00 8880.30 10400.00 87.072 246.253 8822.26 8882.56 10500.00 87.072 246.253 8827.37 8887.67 10600.00 87.072 246.253 8832.48 8892.78 10672.85 87.072 246.253 8836.20 8896J 10700.00 87.470 249.490 8837.49 10800.00 88.993 261.399 8840.59 8900.! 10900.00 90.559 273.297 8840.98 8901.28 10956.32 91.435 280.000 8840.00 8900.30 11000.00 91.500 285.243 8838.88 8899.18 11100.00 91.602 297.247 8836.16 8896.46 11200.00 91.634 309.251 8833.33 8893.63 11300.00 91.594 321.256 8830.50 8890.80 11400.00 91.485 333.260 8827.81 8888.11 Proposal Report for 02-30B WPS - 02-30B WP01 Local Coordinates Global Coordi Northings Eastings Northings (ft) (ft) (ft) 3611.91 N 2009.96 W 5954605J 3611.52 N 2009.83 W 5954604 3611.46 N 2009.81W 3608.65 N 2012.77W 3601.79 N 2024.41W 3597.55 N 2032.38 3580.00 N 2067. 3579.49N 3561.78 N 3548.46 N 3510.61N .88W .24W (°ll00ft) E 0.000 E 0.000 E 19.000 685402.39 E 19.000 685390.92 E 19.000 ~ 685383.06 E 19.000 5954571.69 N 685348.37 E 19.000 5954571.15 N 685347.33 E 19.000 5954552.52N 685310.56 E 19.000 5954538.49 N 685282.26 E 19.000 5954498.57 N 685199.79 E 19.000 5954475.00 N 685150.00 E 19.000 .75 N N N 3320.85N 3327.36 N 3336.90 N 3373.06 N 3427.76 N 3498.63 N 3582.55 N 2308.70 W 2400.12 W 2491.53 W 2558.12 W 2583.24 W 2679.81 W 2779.52 W 2835.42 W 2878.02 W 2971.02 W 3054.46 W 3124.70 W 3178.67 W Alaska State Plane 4 PBU_EOA DS 02 Ve~ical Section (fi) 3901.16 3900.80 3900.75 3901.09 3905.25 3908.39 3923.01 3923.46 3939.54 3952.11 3989.37 4012.20 5954456.20 N 685109.99 E 0.000 4030.64 5954413.71N 685019.61E 0.000 4072.29 5954371.23 N 664929.23 E 0.000 4113.95 5954340.28 N 684863.38 E 0.000 4144.29 5954329.45 N 684838.53 E 12.000 4156.29 5954301.98 N 684742.61E 12.000 4211.86 5954294.88 N 684643.05 E 12.000 4283.35 5954300.00 N 684587.00 E 12.000 4329.48 5954308.47 N 684544.18 E 12.000 4367.66 5954342.30 N 684450.31E 12.000 4461.21 5954394.91N 664365.53 E 12.000 4559.93 5954464.00 N 684293.55 E 12.000 4659.50 5954546.56 N 664237.51E 12.000 4755.58 Comment TZ3 Be~in Dir ~. 19.000°/100ft: 9898.19ft IV'ID, 8580.00ft TVD TZ2C 23SB 22TS 21TS End Dir: 10355.74ft MD, 8880.30ft TVD Taraet - 02-30B BSL, Ge01ogical Be~in Dir ~ 12.000°1100ft: 10672.85ftTvID, 8896.50fl TVD Tamet - 02-30B BSL, Gee'logical Continued... 26 July, 2000 - 16:21 - 3 - DrillQues! f. O5.05a Sperry-Sun Drilling Services Proposal Report for 02-30B WPS - 02-30B WP01 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 11432.89 91.435 337.208 8826.97 11500.00 91.435 337.208 8825.29 11600.00 91.435 337.208 8822.78 11700.00 91.435 337.208 8820.28 11800.00 91.435 337.208 8817.78 11900.00 91.435 337.208 8815.27 12000.00 91.435 337.208 8812.77 12100.00 91.435 337.208 8810.27 12200.00 91.435 337.208 8807.76 12300.00 91.435 337.208 8805.26 12400.00 91.435 337.208 8802.75 12500.00 91.435 337.208 8800.25 12600.00 91.435 337.208 8797.75 12700.00 91.435 337.208 8795.24 12800.00 91.435 337.208 8792.74 12900.00 91.435 337.208 8790.24 13000.00 91.435 337.208 8787.73 13100.00 91.435 337.208 8785.23 13200.00 91.435 337.208 8782.73 13268.97 91.435 337.208 8781.00 Vertical Local Coordinates Depth Northings Eastings (ft) (~) (ft) 8887.27 3612.40 N 3192.44 W 8885.59 3674.25 N 3218.43 W 8883.08 3766.42 N 3257.15 W 8880.58 3858.58 N 3295.88 W 8878.08 3950.74 N 3334.61 W 8875.57 4042.90 N 3373.33 8873.07 4135.07 N 3412. 8870.57 4227.23 N 8868.06 4319.39 N 8865.56 4411.55 N 8863.05 4503.72 N .97 W 8860.55 70 W 8858.05 W 8855.54 4780.2~ W 8853.94 3721.88 W 8850.54 3760.60 W 8848.03 3799.33 W 8845/. ,86 N 3838.06 W N 3876.78 W 3903.50 W Global Coordi,~~gleg Northings ~E~s~gs 'Rate (ft) ~-~r_ (o/'~oort) 5954576.~~~0 E 12.000 5954~37.~ ~95.~7~ 0.000 5~ N 6~031.43 E 0.000 5955093.09 N 683990.42 E 0.000 5955184.26 N 683949.41E 0.000 5955275.42 N 683908.40 E 0.000 N 683867.39 E 0.000 5955457.76 N 683826.37 E 0.000 5955548.93 N 683785.36 E 0.000 5955640.10 N 683744.35 E 0.000 5955731.27 N 683703.34E 0.000 5955822.44 N 683662.33 E 0.000 5955913.61N 683621.32 E 0.000 5956004.78 N 683580.31E 0.000 5956095.95 N 683539.30 E 0.000 5956187.12 N 683498.29 E 0.000 5956250.00 N 683470.00 E 0.000 Alaska State Plane 4 PBU_EOA DS O2 Vertical Section Comment (fi) 4785.70 End Dir:11432.89ftMD, 8887.27ffTVD 4646.20 4936.35 5026.50 5116.65 5206.80 5296.96 5387.11 5477.26 5567.41 5657.56 5747.71 5837.86 5928.01 6018.17 6108.32 6198.47 6288.62 6378.77 6440.95 T~al Depth: 13268.97ff MD, ,~,, 8641.30ff TVD ~ Liner Targa - 02-30B Int, Geological Continued... 26 July, 2000.16:21 .4 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for 02-30B WPS - 02-30B WP01 North Slope Alaska All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 311.603° (True). Based upon Minimum Curvature tyPe calculations, at a Measured Depth of The Bottom Hole Displacement is 6586.04ft., in the Direction of 323.652° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (~t) (ft) (ft) (ft) 8100.00 6800.54 3582.05 N 1963.56W 8140.00 6835.42 3597.96 N 1974.92W 8451.88 7134.37 3653.40 N 9898.19 8580.00 3611.52 N 10355.74 8880.30 3488.28 N 10672.85 8896.50 3360.75 N 11432.89 8887.27 3612.40 N 3192. 13268.97 8841.30 5304.59 N 3903.51 Com: 270.000° TF: 8100.00ft MD, 6800.54ft TVD 10.000°ll00ft: 8140.00ft MD, 6835.42ff TVD MD, 7134.37ff TVD 19.000°1100ff: 9898.19ft MD, 8580.00ff TVD 10355.74ft MD, 8880.30ff TVD Begin Dir @ 12.000°/100ft: 10672.85ft MD, 8896.50ft TVD End Dir' 11432.89ft MD, 8887.27ft TVD Total Depth · 13268.97ft MD, 8841.30ft TVD Alaska State Plane 4 PBU_EOA DS 02 Continued... 26 July, 2000-16:21 -5- DrillQues! 1.05.05a Sperry. Sun Drilling Services Proposal Report for 02-30B WPS - 02-30B WP01 North Slope Alaska Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings (~) (ft) (ft) (ft) (~) 9498.30 8180.30 8120.00 3623.10 N 2013.85 W 9608.36 8290.30 8230.00 3619.91 N 2012.74 W 9648.37 8330.30 8270.00 3618.75 N 2012.34 W 9725.41 8407.30 8347.00 3616.52 N 2011.57 W 9884.49 8566.30 8506.00 3611.91 N 2009.96 W 9945.72 8627.30 8567.00 3608.65 N 2012.77 W 10024.25 8702.30 8642.00 3597.55 N 2032.38 W 10101.88 8768.30 8708.00 3579.49 N 2068.58 W 10160.82 8810.30 8750.00 3561.78 N 2105.80 W Formation Name TJD/Top Kingak TSGR TSHU TZ3 Alaska State Plane 4 PBU_EOA DS 02 Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (~t) (~) <Surface> <Surface> 9618.06 <Surface> <Surface> 13268.97 Vertical Depth (~) 8300.00 8641.30 Continued... 26 July, 2000.16:21 - 6 - DrillQues! 1.05,05a Sperry. Sun Drilling Services Proposal Report for 02-30B WPS - 02-30B WP01 North Slope Alaska Targets associated with this wellpath Target Name 02-30B BSL Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Mean Geographical Coordinates #5 #6 #7 #8 #9 #1 #2 #3 fi4 #.5 #6 #7 #8 #9 #1 #2 #3 fi4 #5 #6 #7 #8 #9 Targ ordinates TVD (~) N 0o 8880.30 8880.30 5954475.00 N 16'50.2498"N 8880.30 8880.30 8880.30 8880.30 8820.00 8820.00 8820.00 8820.00 8820.00 8820.00 8820.00 8820.00 8820.00 3701.97 N 3545.97 N 3651.92 N 5432.55 N 5319.32 N 4447.63 N 3399.10 N 3160.33 N 3378.83 N 595469O.OO N 5954520.00 N 5954620.00 N 5956380.00 N 5956260.00 N 5955400.00 N 5954360.00 N 5954130.00 N 5954370.00 N Eastings (ft) 2268.24 W 685150.00 E 148° 30' 06.3993" W 2212.90W 2776.96W 3014.39W 3820.28W 4093.19W 3634.76W 3305.78W 2956.62W 2090.91W 685200.00 E 684640.00 E 684400.00 E 683550.00 E 683280.00 E 683760.00 E 684115.00 E 684470.00 E 685330.00 E 70° 16'52.3517"N 70° 16'50.8156"N 70°16'51.8567"N 70° 17'09.3667"N 70°17'08.2515"N 70° 16'59.6802"N 70°16'49.3689"N 70° 16'47.0219"N 70° 16'49.1738"N 148° 30'04.7892"W 148° 3~ 21.2176"W 148°3~ 28.1347"W 148° 3~ 51.6348"W 148°3~ 59.5840"W 148° 3~ 46.2159"W 148° 3~ 36.6190"W 148' 3~ 26.4463"W 148° 3~ 01.2333"W Alaska State Plane 4 PBU_EOA DS 02 Target Target Shape Type Polygon Geological 26 Juh/, 2000- 16:21 - 7- DrillQuest 1.05.05a Sperry. Sun Drilling Services Proposal Report for 02-30B WPS - 02-30B WPOf North Slope Alaska Target Name 02-30B BSL 02-30B Int Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Alaska State Plane 4 PBU_EOA DS 02 Target Target Shape Type Point Geological Point Geological 26 July, 2000 - t6:22 - 8 - DrillQuest f. O5.05a [ DATE ~_ CHECK NO. VENDOR ALASKASTAT !O DATE INVOICE / CREDIT MEMO DESCRIPTION GROS~ DI~OUNT N~ 0~0200 ~KO~02000 100. O0 100. O0 H~NDLII~G INST: TERR IE X4628 I A~ACHED CHECK = m PAY~ ~ ~ ~AIBED A~. ~ 1 OO. OD 1 OO_ DO ':"i.~iii::i.!",':AN~'.RO~".'A(~g;!i!A~Sl{~?: 99519-0012 :i:'~'~:.i~.ii::i:":~.':/'' :i .. , . ., aAy'.,.' ., ,. '.., ,,,' ,..', ,,:. '..... .. ~E~::/':::::'~:i:i: ~e~"C::!!ii::;': , !:::,i~,''''!;':~:':! '?':::::? 300:,%1~:::' ;:i~ORCUp ' ..,i: :': ":~'~' ':...'"' . .... ,. ,.. ANCHORAGE' AK 99501 :";i! ...': ::'i' ~,~.~'m':~'. :::~U'.::i:.:'.:... * .:,.~.:::.::...:,.... ,~.~,,~.~,~,~..,.,.~, .:: .:~.,,.:~: . "::.:::"::'..:.[~.:}' '. ~[~D, OHIO ...'.: ::..:'.. ::'"'" · '~'.~:.:~.h? ...... ":'"'?:;~:~:~89:";~'::'412 '"" '~'"~:?~?::'{': ...... '"~?:":: '1':'~}''~::::''~'~¥?''''~'~?:~''''''''''~:?'??~?1~ 7~'''r:~: ' ''' ' '.' .' .. , . ,,.,"'.'., ,.'.;/,., ',:.',"':..'.,,~..:'"".': :':..?."'.'. ..,.,~ ,....,? ,.,Fh'.,'.' .' : :." ':?~..'".~ ."..' ' ':.",": .':, ":,: ,, . ...' , ,. ...:..~.:[:~. , , ::?,.. =: ...:i~" .'.~...::..::::::~:..:.. '.,~'.'["~ ~,. ?:'.~ ..... . .... '."..: .... '1" "' '"'"' ,'l,?i?Sr-.h,' ~:Ot, l,i?O3&qS~: OOP. ht, i,q,' ,. STATE OF ALASKA ,. ALASI~( )IL AND GAS CONSERVATION COi~' 3SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown . . Name of Operator BP Exploration (Alaska) Inc. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate [] Perforate [] Other Plug Back for Sidetrack Type of well: Ea Development I-I Exploratory I-I Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 60.30' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 02-30A 9. Permit Number 196-193 10. APl Number 50-029-22202-01 , Location of well at surface 154' SNL, 774' EWL, SEC. 36, T11N, R14E, UM At top of productive interval 3593' NSL, 2023' WEL, SEC. 28, T11N, R14E, UM At effective depth 5277' NSL, 3088' WEL, SEC. 26, T11N, R14E, UM At total depth 5277' NSL, 3088' WEL, SEC. 26, T11N, R14E, UM 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Liner true vertical measured true vertical 12300 feet 8793 feet 12300 feet 8793 feet Length 110' 2558' 8475' 2494' 1778' Size 20" 10-3/4" 7-5/8" 5-1/2" 2-7/8" Plugs (measured) Junk (measured) ORIGINAL Cemented' 11 yds Arctic Set 2563 cu ft Cold Set III, 405 cuft 'G' 1369 cu ft Class 'G' ' 257 cuft Class 'G' Uncemented Slotted Liner MD TVD 110' ' 110' ' 2558' 2361' 8475' 7128' 8291' - 10785' 6968' - 8896' 10522' - 12300' 8822' - 8793' Perforation depth: measured true vertical Slotted Liner: 10773' - 12296' 'Slotted Liner:. 8896' - 8793' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 7981'; 3-1/2", 9.3#, L-80 from 7981' - 10528' Packers and SSSV (type and measured depth) 5-1/2" x 3-1/2 TIW 'S-6' pkr at 10520';'5-1/2" x 3-1/2" Baker 'SABL' pkr at 9947'; 75/8" x 5-1/2" Baker 'ZXP' liner top pkr at 8277'; 4-1/2" Camco 'BAL-O' SSSV Nipple at 2186' 13. Attachments · 4. Estimated date for commencing operation August 22, 2000 16. If proposal .was verbally approved Name of approver [] Description Summary of Proposal Date Approved '115. Contact Engineer Name/Number: Steve Schmitz, 564-5773 ~'/./.5'~' r'l Detailed Operations Program Status of well classifications as: I~ Oil [] Gas [] Suspended Service [] BOP Sketch Prepared By Name/Numbec Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my .knowledge Signed Dan Stone ~"~, ~ Title Senior Drilling Engineer Date ~i'.' "~:~ '~,.'..~;".~;.~=~....~'~ ....... ~ ', .... ~' ,.~..~,~ ~. .~J '~ ',. '~ ~. .... ~. · ..~...~.~. .... · .... ,~ ..., ..., .......... ~ .... .,:~.., ....... ,~ ..... Conditions of Approval: Notify Commission so representative may witness Plug integrity. Mechanical Integrity Test __ ~,13proved by order of the Commission Forr~ 10-403 Rev. 06/15/88 BOP Test Location clearance Subsequent form required 10-' J. Approval No. Z00 '" ~" O (O Commi~_~ioner Date Submit In Triplicate ~ST ADMINISTRATIO~ 1. Permit fee attached ........................ ~ N _ENGINEERING 2. Lease number appropriate ................... 3. Unique well name and'number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation o~'der ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ LDATE 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... ' 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meat'.regulation 26. BOPE press rating appropriate; t;st' t~ '_'' ~:~::~:~ 1 '~~. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28..Work will occur without operation shutdown ........... 29. Is presence of H:,S gas probable ................. 30. Permit can be issued wlo hydrogen sulfide measures ..... Y~'~) 'Y;" 'i. 31. Data presented on potential overpressure zones ....... y"-1~7,,~ 32. Seismic analysis of shallow gas zones .......... '. ~.. , //~ 33. Seabed condition survey (if.off-shore) .......... ~.-/~L t'~ y N 34. Contact name/phone for weekly progress reports '[e'x~l~3~6ry only] Y N _ANNULAR DISPOSAL35. With proper cementing records, this plan APPR DATE (A) will contain waste in a suitable receiving zone; ....... y N .' ~ ...... ~ ' ' (B) ~lls~r~a~?tammate freshwater; or cause dnlhng waste .... Y N. __/ [~-~(3 ~,.-~,¢,,,,_.~,~.,t ¢-. \' ' ~'-(,,,~ ~__~.~~ . !~C! ..w.l!! _no_! ~m_P_a_~[mecha. n,.cal ,.ntegr,!.y of the well used for disposal; Y N tu~ w,, no[ aamage proauang Tormatlon or impair recovery from a Y N pool; and . ' -- / .... , ~~..~. U_ LC _C _c _c _c _c _c couu,ss,o.: ..... ' Z , -i -r- c:~soffice\wordian~iana\checklist (rev. 02117100) Well Histo.ry 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 APPE .N. DIX~ ,. No'special'eflo .rt has been made to chronologically organize this category of .information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Aug 08 15:34:08 2001 Reel Header Service name ............. LISTPE Date ..................... 01/08/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LIST?E Date ..................... 01/08/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: DS 2-30B 500292220202 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Systems 08-AUG-01 MWD RUN 2 MWD RUN 3 MWD RUN 4 AK-MM-00183 AK-MM-00183 AK-MM-00183 R. KRELL R. KRELL R. KRELL T. ANGLEN T. ANGLEN T. ANGLEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MWD RUN 7 MWD RUN 8 AK-MM-00183 AK-MM-00183 AK-MM-00183 R. KRELL M. HANIK M. HANIK T. ANGLEN J. RALL J. RALL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: MWD RUN 9 AK-MM-00183 M. HANIK J. RALL 36 liN 14E 154 FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 774 .00 58.80 30.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 8063.0 4.750 5.500 9618.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. THE KICKOFF POINT/TOP OF WHIPSTOCK IS 8063'MD/6768'TVD IN THE PARENT WELL, DS 2-30. THE FIRST WELL SECTION (DS 2-30B PB1, PRESENTED SEPARATELY) WAS PLUGGED BACK DUE TO POOR ROCK QUALITY. THE FINAL WELL (DS 2-30B, THIS PLOT) WAS KICKED OFF AT 10450'MD/8910.41'TVD, IN DS 2-30B PB1.' 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND DRILL OUT. IT IS NOT PRESENTED. 4. MWD RUNS 2-9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). DGR DATA FROM 7810'MD/6554.65'TVD TO THE KOP WERE RECORDED WHILE RIH FOR MWD RUN 2. RUNS 3-9 INCLUDED PRESSURE WHILE DRILLING GAUGES (PWD), THE DATA FROM WHICH ARE NOT PRESENTED IN THIS PLOT. 5. DIGITAL AND LOG DATA ARE DEPTH-SHIFTED TO A SCHLUMBERGER GAMMA RAY LOG (FROM A CBL) RUN ON 22 AUGUST 1991, IN THE PARENT WELL DS2-30. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 2-9 REPRESENT WELL DS2-30B WITH API%: 50-029-22202-02. THIS WELL SECTION REACHED A TOTAL DEPTH (TD) OF 12362'MD/8909.68'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 (DEEP Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH GR 7811.0 FET 7830.5 RPD 7830.5 RPM 7830.5 RPS 7830.5 RPX 7830.5 ROP 8062.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 7810.0 7809.0 7823.5 7822.5 7830.5 7828.0 7832.0 7830.5 7834.0 7832.5 7844.0 7846.0 7857.5 7855.0 7869.0 7867.5 7872.0 7871.0 7879.0 7875.5 7882.5 7877.5 7886.5 7886.5 7893.0 7892.5 7910.0 7906.5 7915.5 7914.5 7934.0 7932.0 7941.5 7943.0 7946.0 7946.0 7954.0 7954.5 7963.0 7962.0 7971.0 7970.5 7978.0 7978.0 7994.0 7994.0 7999.0 7999.5 8002.5 8003.5 8009.0 8006.5 8014.0 8012.5 8025.0 8026.5 8042.5 8044.0 all bit runs merged. STOP DEPTH 12294.5 12306.0 12306.0 12306.0 12306.0 12306.0 12361.0 EQUIVALENT UNSHIFTED DEPTH 8045.0 8047.5 8052.5 8055.5 8059.0 8060.5 12294.5 12296.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 MWD 5 MWD 7 MWD 8 MWD 9 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 7810.0 9618.5 9897.5 10301.0 10450.0 11053.0 11394.5 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 9618.5 9897.5 10301.0 10450.0 11053.0 11394.5 12362.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 7811 12361 GR MWD API 15.16 474.92 ROP MWD FT/H 0 353.42 RPX MWD OHMM 0.4 1928.25 RPS MWD OHMM 0.4 2000 RPM MWD OHMM 0.1 2000 RPD MWD OHMM 0.12 2000 FET MWD HOUR 0.02 115.55 Mean Nsam 10086 9101 102.539 8968 56.9273 8599 58.1477 8952 94.8726 8952 185.43 8952 443.327 8952 4.4074 8952 First Reading 7811 7811 8062 7830.5 7830.5 7830.5 7830.5 7830.5 Last Reading 12361 12294.5 12361 12306 12306 12306 12306 12306 First Reading For Entire File .......... 7811 Last Reading For Entire File ........... 12361 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7810.0 9575.5 RPX 7828.0 9582.5 FET 7828.0 9582.5 RPS 7828.0 9582.5 RPM 7828.0 9582.5 RPD 7828.0 9582.5 ROP 8063.5 9618.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 19-SEP-00 Insite 4.27 Memory 9618.0 2.1 26.9 TOOL NUMBER ?B01654FGR4 PB01654FGR4 6.750 LSND-HT 10.50 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum SPecification Block sub-type...0 50.0 9.3 1250 2.2 1.120 .620 · 970 1.250 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 R?D MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 67.0 127.0 67.0 67.0 Name Service Unit Min Max DEPT FT 7810 9618.5 GR MWD020 API 39.22 406.57 ROP MWD020 FT/H 0.13 153.56 RPX MWD020 OHMM 0.4 290.51 RPS MWD020 OHMM 0.4 2000 RPM MWD020 OHMM 0.1 2000 RPD MWD020 OHMM 0.12 2000 FET MWD020 HOUR 0.02 3.47 Mean Nsam 8714.25 3618 138.159 3532 69.0553 3111 2.89124 3510 10.8669 3510 257.91 3510 256.781 3510 0.872829 3510 First Reading 7810 7810 8063.5 7828 7828 7828 7828 7828 Last Reading 9618.5 9575.5 9618.5 9582.5 9582.5 9582.5 9582.5 9582.5 First Reading For Entire File .......... 7810 Last Reading For Entire File ........... 9618.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPX RPS RPD FET RPM ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9576 0 9583 0 9583 0 9583 0 9583 0 9583 0 9619 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9829.5 9840.5 9840.5 9840.5 9840.5 9840.5 9897.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: 22-SEP-00 Insite 4.27 Memory 9896.0 2.6 13.8 TOOL NUMBER PB01613RF3 PB01613RF3 4.750 QUIKDRIL-N MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 8.40 45.0 9.3 5O0 12.0 2.600 1.360 3.400 1.800 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 75.0 149.0 75.0 75.0 Name Service Unit Min Max Mean Nsam DEPT FT 9576 9897.5 9736.75 644 GR MWD030 API 22.62 474.92 93.7594 508 ROP MWD030 FT/H 0.6 120.51 57.1557 558 RPX MWD030 OHMM 1.65 1928.25 109.627 516 RPS MWD030 OHMM 2.83 2000 337.403 516 RPM MWD030 OHMM 0.52 2000 204.653 516 RPD MWD030 OHMM 0.27 2000 351.097 516 FET MWD030 HOUR 0.72 58.68 9.73124 516 First Reading 9576 9576 9619 9583 9583 9583 9583 9583 Last Reading 9897 5 9829 5 9897 5 9840 5 9840 5 9840 5 9840 5 9840 5 First Reading For Entire File .......... 9576 Last Reading For Entire File ........... 9897.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9830.0 10232.5 FET 9841.0 10244.0 RPM 9841.0 10244.0 RPS 9841.0 10244.0 RPX 9841.0 10244.0 RPD 9841.0 10244.0 ROP 9898.0 10301.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 23-SEP-00 Insite 4.27 Memory 10300.0 20.4 62.3 TOOL NUMBER PB01613RF3 PB01613RF3 4.750 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM?ERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 QUIKDRIL-N 8.40 44.0 9.2 1100 10.0 1.400 .770 1.500 .950 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MWD040 FT/H 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 80.0 152.0 80.0 80.0 Name Service Unit Min Max Mean Nsam DEPT FT 9830 10301 10065.5 943 GR MWD040 API 15.16 114.72 29.3774 806 ROP MWD040 FT/H 0.41 166.38 39.3699 807 RPX MWD040 OHMM 6.61 671.85 158.363 807 RPS MWD040 OHMM 6.67 1277.37 260.223 807 RPM MWD040 OHMM 6.82 1190.45 246.676 807 RPD MWD040 OHMM 10.3 2000 1283.21 807 FET MWD040 HOUR 1.45 23.62 5.53517 807 First Reading 9830 9830 9898 9841 9841 9841 9841 9841 Last Reading 10301 10232.5 10301 10244 10244 10244 10244 10244 First Reading For Entire File .......... 9830 Last Reading For Entire File ........... 10301 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10233.0 10413.0 FET 10244.5 10413.0 RPD 10244.5 10413.0 RPM 10244.5 10413.0 RPS 10244.5 10413.0 RPX 10244.5 10413.0 ROP 10301.5 10450.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 26-SEP-00 Insite 4.27 Memory 10450.0 70.2 95.2 TOOL NUMBER PB01613RF3 PB01613RF3 4.750 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 QUIKDRIL-N 8.50 45.0 9.6 1100 8.0 1.800 .780 1.700 1.400 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD050 API 4 1 68 ROP MWD050 FT/H 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 68.0 165.0 68.0 68.0 Name Service Unit Min Max DEPT FT 10233 10450 GR MWD050 API 33.22 195.68 ROP MWD050 FT/H 2.23 82.89 RPX MWD050 OHMM 11.78 302.45 RPS MWD050 OHMM 15.44 302.31 RPM MWD050 OHMM 16.9 240.84 RPD MWD050 OHMM 21.54 2000 FET MWD050 HOUR 2.26 21.49 Mean Nsam 10341.5 435 65.1466 361 38.9175 298 106.526 338 122.645 338 121.482 338 673.138 338 8.97595 338 First Reading 10233 10233 10301.5 10244.5 10244.5' 10244.5 10244.5 10244.5 Last Reading 10450 10413 10450 10413 10413 10413 10413 10413 First Reading For Entire File .......... 10233 Last Reading For Entire File ........... 10450 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ........ STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 10350.0 11011.0 RPX 10413.5 11011.0 FET 10413.5 11011.0 RPM 10413.5 11011.0 RPD 10413.5 11011.0 GR 10413.5 11001.5 ROP 10450.5 11053.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 30-SEP-00 Insite 4.27 Memory 11052.0 84.9 95.0 TOOL NUMBER PB01613RF3 PB01613RF3 4.750 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 QUIKDRIL-N 8.50 45.0 9.7 1000 8.0 1.600 .700 1.450 1.200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD070 API 4 1 68 4 2 ROP MWD070 FT/H 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 65.0 156.6 65.0 65.0 Name Service Unit DEPT FT GR MWD070 API ROP MWD070 FT/H RPX MWD070 OHMM RPS MWD070 OHMM RPM MWD070 OHMM RPD MWD070 OHMM FET MWD070 HOUR Min Max Mean Nsam 10350 11053 10701.5 1407 39.56 167.02 74.5281 1177 2.18 156.35 45.5045 1206 9.21 111.44 66.9871 1196 9.75 160.18 77.9668 1323 10.39 390.9 78.7072 1196 14.97 1169.98 160.347 1196 0.71 115.55 9.09353 1196 First Reading 10350 10413.5 10450.5 10413.5 10350 10413.5 10413.5 10413.5 Last Reading 11053 11001.5 11053 11011 11011 11011 11011 11011 First Reading For Entire File .......... 10350 Last Reading For Entire File ........... 11053 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Previous Fi~e Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11002.0 11341.5 RPX 11011.5 11353.0 RPS 11011.5 11353.0 RPD 11011.5 11353.0 FET 11011.5 11353.0 RPM 11011.5 11353.0 ROP 11053.5 11394.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 02-OCT-00 Insite 4.27 Memory 11395.0 88.4 96.0 TOOL NUMBER PB01613RF3 PB01613RF3 4.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 QUIKDRIL-N 8.50 46.0 9.7 1000 8.5 1.900 .860 1.600 1.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD080 API 4 1 68 4 2 ROP MWD080 FT/H 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 70.0 162.7 70.0 70.0 Name Service Unit DEPT FT GR MWD080 API ROP MWD080 FT/H RPX MWD080 OHMM RPS MWD080 OHMM RPM MWD080 OHMM RPD MWD080 OHMM FET MWD080 HOUR Min Max Mean Nsam 11002 11394.5 11198.3 786 27.29 173.57 100.006 680 0 191.03 22.967 683 13.22 186.58 42.3424 684 13.62 217.53 48.7523 684 13.62 196.16 51.327 684 18.26 2000 145.799 684 1.67 27.31 6.87275 684 First Reading 11002 11002 11053.5 11011.5 11011.5 11011.5 11011.5 11011.5 Last Reading 11394.5 11341.5 11394.5 11353 11353 11353 11353 11353 First Reading For Entire File .......... 11002 Last Reading For Entire File ........... 11394.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11330.0 12296.0 RPD 11353.5 12307.5 RPM 11353.5 12307.5 RPS 11353.5 12307.5 RPX 11353.5 12307.5 FET 11353.5 12307.5 ROP 11395.0 12362.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA 06-OCT-00 Insite 4.27 Memory 12362.0 87.8 92.9 TOOL NUMBER PB01613RF3 PB01613RF3 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 6.750 QUIKDRIL-N 8.40 48.0 9.4 900 7.3 2.100 .920 2.200 1.100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD090 API 4 1 68 4 2 ROP MWD090 FT/H 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 70.0 168.9 70.0 70.0 Name Service Unit Min Max DEPT FT 11330 12362.5 GR MWD090 API 22.46 201.91 ROP MWD090 FT/H 0 353.42 RPX MWD090 OHMM 5.48 1738.92 RPS MWD090 OHMM 5.34 2000 RPM MWD090 OHMM 5.35 2000 RPD MWD090 OHMM 6.2 2000 FET MWD090 HOUR 0.84 31.93 Mean Nsam 11846.3 2066 94.7098 1931 66.56 1936 94.8015 1909 138.071 1909 155.105 1909 706.746 1909 4.34307 1909 First Reading 11330 11330 11395 11353.5 11353.5 11353.5 11353.5 11353.5 Last Reading 12362.5 12296 12362.5 12307.5 12307.5 12307.5 12307.5 12307.5 First Reading For Entire File .......... 11330 Last Reading For Entire File ........... 12362.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/08/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/08/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Jul 20 13:59:01 2001 Reel Header Service name ............. LISTPE Date ..................... 01/07/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/07/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: DS 2-30B PB1 500292220270 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 20-JUL-01 MWD RUN 2 MWD RUN 3 MWD RUN 4 AK-MM-00183 AK-MM-00183 AK-MM-00183 R. KRELL R. KRELL R. KRELL T. ANGLEN T. ANGLEN T. ANGLEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 5 AK-MM-00183 R. KRELL T. ANGLEN 36 liN 14E 154 774 .00 58.80 GROUND LEVEL: WELL CASING RECORD 30.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 6.750 7.625 8063.0 2ND STRING 4.750 5.500 9618.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS(MD)UNLESS OTHERWISE NOTED. 2. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND IS NOT PRESENTED. 3. MWD RUNS 2,3,4,AND 5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4). RUNS 3-5 INCLUDED PRESSURE WHILE DRILLING GAUGES (PWD). 4. DIGITAL AND LOG DATA ARE DEPTH-SHIFTED TO A SCHLUMBERGER GAMMA RAY LOG (FROM A CBL) RUN ON 22 AUGUST 1991, IN WELL DS 2-30. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 5. MWD RUNS 1-5 REPRESENT WELL DS2-30B PB1 WITH API#:50-029-22202-70. THIS WELL REACHED A TOTAL DEPTH(TD)OF l1739'MD/8888'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/20 Maximum Physical'Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 7810.0 FET 8058.5 RPD 8058.5 RPM 8058.5 RPS 8058.5 RPX 8058.5 ROP 8062.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 7810.0 7809.0 7823.5 7822.5 7830.5 7828.0 7832.0 7830.5 7834.0 7832.5 7844.0 7846.0 7857.5 7855.0 7869.0 7867.5 7872.0 7871.0 7879.0 7875.5 7882.5 7877.5 7886.5 7886.5 7893.0 7892.5 7910.0 7906.5 7915.5 7914.5 7934.0 7932.0 7941.5 7943.0 7946.0 7946.0 7954.0 7954.5 7963.0 7962.0 7971.0 7970.5 7978.0 7978.0 7994.0 7994.0 7999.0 7999.5 8002.5 8003.5 8009.0 8006.5 8014.0 8012.5 8024.5 8026.5 8042.5 8044.0 8045.0 8047.5 8052.5 8055.5 8059.0 8060.5 11670.5 11672.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 MWD 5 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record STOP DEPTH 11670.5 11681.5 11681.5 11681.5 11681.5 11681.5 11738.5 EQUIVALENT UNSHIFTED DEPTH MERGE TOP MERGE BASE 7809.0 9618.5 9618.5 9897.5 9897.5 10301.0 10301.0 11740.0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT GR ROP RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD API 4 1 68 MWD FT/H 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 7810 11738.5 GR MWD API 15.16 474.92 ROP MWD FT/H 0 1613.85 RPX MWD OHMM 0.4 1928.25 RPS MWD OHMM 0.4 2000 RPM MWD OHMM 0.39 2000 RPD MWD OHMM 0.22 2000 FET MWD HOUR 0.29 58.68 Mean 9774.25 104.756 61.1085 65.8136 97.8325 88.5545 415.002 2.83278 Nsam 7858 7722 7354 7247 7247 7247 7247 7247 First Reading 7810 7810 8062 8058.5 8058.5 8058.5 8058.5 8058.5 Last Reading 11738.5 11670.5 11738.5 11681.5 11681.5 11681.5 11681.5 11681.5 First Reading For Entire File .......... 7810 Last Reading For Entire File ........... 11738.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7809.0 9575.5 RPX 8060.0 9582 5 RPS 8060.0 9582 5 RPM 8060.0 9582 5 RPD 8060.0 9582 5 FET 8060.0 9582 5 ROP 8063.5 9618 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT,SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ 19-SEP-00 Insite 4.27 Memory 9618.0 2.1 26.9 TOOL NUMBER PB01654FGR4 PB01654FGR4 6.750 LSND-HT 10.50 50.0 9.3 1250 2.2 1.120 · 620 .970 1.250 67.0 127.0 67.0 67.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD020 API 4 1 68 ROP MWD020 FT/H 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 7809 9618.5 GR MWD020 API 39.22 406.57 ROP MWD020 FT/H 0.13 153.56 RPX MWD020 OHMM 0.4 290.51 RPS MWD020 OHMM 0.4 1245.25 RPM MWD020 OHMM 0.39 1965.9 RPD MWD020 OHMM 0.22 1937.62 FET MWD020 HOUR 0.29 3.47 Mean 8713.75 138.119 69.056 2.35585 2.89382 6.16647 6.40749 0.973907 Nsam 3620 3534 3111 3046 3046 3046 3046 3046 First Reading 7809 7809 8063.5 8060 8060 8060 8060 8060 Last Reading 9618.5 9575.5 9618.5 9582.5 9582.5 9582.5 9582.5 9582.5 First Reading For Entire File .......... 7809 Last Reading For Entire File ........... 9618.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER iIl FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9576.0 9829.5 RPS 9583.0 9840.5 FET 9583.0 9840.5 RPD 9583.0 9840.5 RPX 9583.0 9840.5 R?M 9583.0 9840.5 ROP 9619.0 9897.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 22-SEP-00 Insite 4.27 Memory 9896.0 2.6 13.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: TOOL NUMBER PB01613RF3 PB01613RF3 4.750 Quikdrill-N 8.40 45.0 9.3 5OO 12.0 2.600 1.360 3.400 1.800 75.0 149.0 75.0 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD030 API 4 1 68 ROP MWD030 FT/H 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 9576 9897.5 GR MWD030 API 22.62 474.92 ROP MWD030 FT/H 0.6 120.51 RPX MWD030 OHMM 1.65 1928.25 RPS MWD030 OHMM 2.83 2000 RPM MWD030 OHMM 0.52 2000 RPD MWD030 OHMM 0.27 2000 FET MWD030 HOUR 0.72 58.68 Mean 9736.75 93.7594 57.1557 109.627 337.403 204.653 351.097 9.73124 Nsam 644 508 558 516 516 516 516 516 First Reading 9576 9576 9619 9583 9583 9583 9583 9583 Last Reading 9897.5 9829.5 9897.5 9840.5 9840.5 9840.5 9840.5 9840.5 First Reading For Entire File .......... 9576 Last Reading For Entire File ........... 9897.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9830.0 10232.5 FET 9841.0 10244.0 RPX 9841.0 10244.0 RPS 9841.0 10244.0 RPD 9841.0 10244.0 RPM 9841.0 10244.0 ROP 9898.0 10301.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 23-SEP-00 Insite 4.27 Memory 10300.0 20.4 62.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PB01613RF3 PB01613RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.750 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCpSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Quikdrill-N 8.40 44.0 9.2 1100 10.0 1.400 .770 1.500 .950 80.0 152.0 80.0 80.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DE?T FT 4 1 68 GR MWD040 API 4 1 68 ROP MWD040 FT/H 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HOUR 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 9830 10301 GR MWD040 API 15.16 114.72 ROP MWD040 FT/H 0.41 166.38 RPX MWD040 OHMM 6.61 671.85 RPS MWD040 OHMM 6.67 1277.37 RPM MWD040 OHMM 6.82 1190.45 RPD MWD040 OHMM 10.3 2000 FET MWD040 HOUR 1.45 23.62 Mean 10065.5 29.3772 39.3699 158.363 260.223 246.676 1283.21 5.53517 Nsam 943 806 807 807 807 807 807 807 First Reading 9830 9830 9898 9841 9841 9841 9841 9841 Last Reading 10301 10232.5 10301 10244 10244 10244 10244 10244 First Reading For Entire File .......... 9830 Last Reading For Entire File ........... 10301 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10233.0 11672.0 RPD 10244.5 11683.0 RPM 10244.5 11683.0 RPS 10244.5 11683.0 RPX 10244.5 11683.0 FET 10244.5 11683.0 ROP 10301.5 11740.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 26-SEP-00 Insite 4.27 Memory 11739.0 70.2 95.2 TOOL NUMBER PB01613RF3 PB01613RF3 4.750 Quikdrill-N 8.50 45.0 9.6 1100 8.0 1.800 .780 1.700 1.400 68.0 165.0 68.0 68.0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD050 API 4 1 68 ROP MWD050 FT/H 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 10233 11740 GR MWD050 API 20.27 233.61 ROP MWD050 FT/H 0 1613.85 RPX MWD050 OHMM 6.52 338.26 RPS MWD050 OHMM 7 359.47 RPM MWD050 OHMM 7.64 1651.28 RPD MWD050 OHMM 13.62 2000 FET MWD050 HOUR 0.8 21.49 Mean 10986.5 86.7391 59.3795 99.169 109.825 110.599 6.15.457 2.80557 First Last Nsam Reading Reading 3015 10233 11740 2879 10233 11672 2878 10301.5 11740 2878 10244.5 11683 2878 10244.5 11683 2878 10244.5 11683 2878 10244.5 11683 2878 10244.5 11683 First Reading For Entire File .......... 10233 Last Reading For Entire File ........... 11740 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/07/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services. Reel Trailer Service name ............. LISTPE Date ..................... 01/07/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File