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183-121
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 4 Township: 11N Range: 14E Meridian: Umiat Drilling Rig:Rig Elevation:Total Depth: 12043 ft MD Lease No.: ADL0028300 Operator Rep:Suspend: X P&A: Conductor: 20"x30" O.D. Shoe@ 120 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2817 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 11259 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 12043 Feet Csg Cut@ Feet Tubing: 4.5" O.D. Tail@ 11019 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Perforation Bottom 11841 ft 11121 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2735 2637 2600 IA 4 4 5 OA 8 8 8 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Pollard Wireline tagged cement at 11097 ft MD and drove down to 11119 ft MD. With the wireline correction of 22 ft that would mean top of cement is at 11121 ft MD. The tool string was approximately 350 pounds with a 2.5-inch by 4 foot drive down bailer fitted with a mule shoe with a flapper valve. The bailer sample was good cured cement. 3 bbls was pumped in the well to pressure up for the MIT-T and 2.8 bbls returned after the MIT was completed. October 16, 2025 Guy Cook Well Bore Plug & Abandonment PBU K-01 Hilcorp North Slope LLC PTD 1831210; Sundry 325-621 None Test Data: P Casing Removal: Jerry Culpepper Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-1015_Plug_Verification_PBU_K-01_gc 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 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 K-01 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 183-121 50-029-20998-00-00 341J ADL 0028300 12043 Conductor Surface Intermediate Production Scab Liner / Liner 9135 80 2780 11224 8074 10992 20" x 30" 13-3/8" 9-5/8" 7" 8233 40 - 120 37 - 2817 35 - 11259 3969 - 12043 2500 40 - 120 37 - 2691 35 - 8455 3446 - 9135 11841, 11901 2670 4760 5410 10992 5380 6870 7240 11362 - 11887 4-1/2" 12.6# 13Cr80 33 - 110198542 - 8998 Structural 4-1/2" Baker S3 Packer No SSSV Installed 10819, 8090 10/8/2025 Jack Lau Date: Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY 10/10/2025 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 2:55 pm, Oct 10, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.10.10 13:39:37 - 08'00' Torin Roschinger (4662) 325-621 A.Dewhurst 10OCT25 10-407 J.Lau 10/14/25 DSR-10/13/25 AOGCC witnessed tag TOC. AOGCC witnessed MITT to 2500 psi.December 31, 2027 X 10/14/25 Page 1 of 5 Well:K-01 Reservoir Abandon 10/08/2025 Well Name:K-01 API Number:50-029-20998-00 Current Status:Offline Not Operable Pad:K PAD Reg. Approval Reqd?10-403 & 10-404 Job Type:Suspend Well Regulatory Contact:Abbie Barker First Call Engineer:Finn Oestgaard Phone:(907) 350-8420 Second Call Engineer:Leif Knatterud Phone:(432) 227-4342 Current Bottom Hole Pressure:3,376 psi (Estimated based on average Ivishak BHP) MPSP:2,500 psi (Estimated from BHP- .1psi/ft gas gradient+ safety factor) KWF:7.4 PPG (BHP @ 8800 TVD) Max Dev:53 deg @ 4,400 MD Min ID:3.48 @ 54 MD tubing restriction Background: K-01 is high angle producer that was drilled in 1983. It is located in the far northern K PAD drainage. It has been predominantly SI for the past 7 years due to HGOR and no value. A shallow tubing restriction was initially noted by Slickline in July 2022 and assumed to be mechanical damage. During a gas lift change out to dummy the top two stations for screening on Oct 7, 2025, SIWHP pressure was introduced to the IA from the open mandrel and was observed communicating to the OA followed by bubbling in the cellar. The confining zone for the Ivishak pool is the Kingak with a bottom marker TSAG @ 11,338 MD & top marker TKNG @ 10,669 MD It is believed the cement behind the original 7 liner to be fully cement from drilling reports. After cementing the liner 208 of cement above the liner hanger was drilled out to the liner hanger, the well passed a Liner lap test to 3,000 psi and on the subsequent run to drill through the liner hanger 20 of cement was drilled directly below the hanger. The volume pumped (396 ft 3 Class G w/ 18% salt) is 52% in excess when assuming 30% washout. The combination of these factors suggest the 7 liner is fully cemented to the liner hanger @ 10,797. Estimated TOC behind 9-5/8 casing based off volumetrics is 10,812 assuming 30% washout, 250 ft3 Class G cement pumped. Justification for suspension includes the well has no future utility however is located on a pad with active wells. It will be mechanically sound after completion of this program with a passing MIT-T. It will not allow migration of fluids, or impair recovery of oil or gas and is not a threat to public health. In accordance with 20 AAC 25.110 Recent Drift History: 7/9/22 3.64 Swage bobbled through restriction 6/9/25 3.59 Swage through restriction 10/4/25 3.48 x 12 Dummy whipstock drift needed to be forced through restriction Page 2 of 5 Well:K-01 Reservoir Abandon 10/08/2025 Objective: Place a cement plug from 11,841 to 11,200 resulting in a 641 cement plug in the production liner and 138 across all strings of pipe in the confining zone resulting in a plug in conformance with 20 AAC 25.112.C.1.C. for suspension. Procedure: FB 1. Maintain hole fill in T & IA while Eline sets HEX Plug EL 1. Set HEX plug in tubing tail @ 10,992 SL 1. Set catcher on HEX plug 2. Set DGLVs in station #4 & #3 3. MIT-T to ~ 500-1,000 psi to confirm valves set 4. Pull catcher Coil 1. MU pulling tool string for HEX plug set in tubing tail @ 10,992, Circulate coil over to hot KCl and begin RIH monitoring the out MM temp while pumping hot fluid until just above HEX plug. When just above HEX plug, circ bottoms up with 9.8ppg brine until density on the out MM reflects the heavier brine. RIH toequalize & pull HEX plug. Flag pipe for depth control on subsequent cementing run. - If unable to pull plug to surface, it is acceptable to push to TD & release 2. MU cementing nozzle, RIH and correct depth to flag. Continue RIH and tag HEX plug in 7 liner @ 11,841 & pull up 5. - If found shallower than previously pushed down by SL (11,841), jet down and push back down to as deep as possible. If unable to get pushed below 11,811 (top of lower perfs interval) contact OE to discuss. 3. Bullhead down coil backside and displace the well to diesel. 4. Perform injectivity test with 1% KCL pumping down the coil. 5. Pump 5 bbl FW spacer 6. Pump cement Lay in cement while POOH Target TOC is 11,200. Once @ 11,300 (62 above top perf) close choke and bump pressure ~ 500 psi & lay in remaining cement. If no pressure bump is observed, open choke and continue laying in cement. - Volume between target TOC (11,200) & last tag of HEX (11,841) = 24.55 bbls,cement volume may be adjusted depending on combination of tag depth of HEX plug & injectivity results. 7. Displace coil volume with 5 bbls FW followed by diesel while POOH. 8. WOC Monitor WHP for signs of pressure build up suggestion gas has compromised squeeze. 9. Once Cement has built 1000 psi UCS, pressure tubing to 500 psi to confirm perfs have been squeezed. If unable to achieve 500 psi, contact OE to discuss plan forward. Potential to reattempt squeeze. 10. If necessary, RIH to 2500tvd and FP well before RDMO. HEX plug set 10/8/2025 SL work completed 10/10/2025 Page 3 of 5 Well:K-01 Reservoir Abandon 10/08/2025 Cement type/weight: Class G 15.8 ppg or similar Bottom hole static temp:180°F Thickening Time 6 hours Fluid Loss 40-200cc (20-100cc/30 min) Slickline 1. WOC 3 days, RIH tag TOC (AOGCC Witnessed) 2. MIT-T to 2,500 psi (AOGCC Witnessed) 3. Pull station 4 and circ FP into IA & OA and reset DGLV. Page 4 of 5 Well:K-01 Reservoir Abandon 10/08/2025 Page 5 of 5 Well:K-01 Reservoir Abandon 10/08/2025 Proposed WBS 11,200 Target TOC 10,979 12,043 Estimated cement behind 7 liner TSAG 11,338 TKNG 10,669 10,812 Estimated TOC behind 9-5/8 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: October 8, 2025Subject: Changes to Approved Sundry Procedure for Well K-01Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) first call engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call 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:Lau, Jack J (OGC) To:Torin Roschinger Cc:Finn Oestgaard - (C) Subject:Re: K-01 (PTD# 183121) - Request for Expedited P&A Approval Date:Wednesday, October 8, 2025 4:03:10 PM Torin, Your plan detailed below is approved. Please ensure a 10-403 is submitted within 3 days. Thanks for the detailed request. Jack From: Torin Roschinger <torin.roschinger@hilcorp.com> Sent: Wednesday, October 8, 2025 2:05 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Subject: K-01 (PTD# 183121) - Request for Expedited P&A Approval Good afternoon Jack, On October 7th, 2025, slickline was performing screening activities on K-01. After slickline pulled the LGLVs, the tubing quickly communicated with the IA which was to be expected. However, the OA was noticed to begin tracking the IA so the operator began bleeding the OA pressure down. Shortly thereafter, bubbling was noticed in the cellar indicating TxIAxOAxsurface casing leak to atmosphere with the GLVs pulled. A pump began pumping KWF down the tubing while taking returns from both the IA and OA to the flowline until a second pump arrived at which time it began pumping KWF down the IA while the first pump continued to kill the well down the tubing. I’ve asked the team to maintain continual hole fill with KWF down both the tubing and IA while taking returns from the OA until we can have eline set a downhole plug to temporarily secure the well. Once the well is temporarily secured, the plan will be for slickline to set DGLVs in the open two pockets and perform an MIT-T to 500-1000psi to ensure tubing integrity. After tubing integrity is confirmed, we would like to pull the downhole plug and immediately P&A the existing perfs with coiled tubing to isolate the reservoir. With historical well test rates on K-01 showing minimal water, 300-400BOPD and ~45MMSCFD and IAxOAxsurface casing communication, Hilcorp would like to request written email approval from the AOGCC to execute the P&A while pursuing the 10-403. I’ve attached a wellbore schematic for your reference. Please note that there is a tubing restriction noted at 58’md. It is assumed from historical data on K-Pad, 70’ well spacing to the nearest well and a caliper indicating no helical buckling throughout the tubing that this restriction was from an ice plug forming in the surface casing x production casing that collapsed the production casing in on the tubing creating the tubing restriction. However, further investigation into this will be postponed until the well can be secured with a cement plug across the existing perforations. Please let me know if we have your blessing to move forward with the P&A of the perforations on K-01 as soon as weather permits. Plan forward: Pumping: Maintain hold fill while eline sets HEX plug Slickline: Set catcher sub, DGLVs in STA # 3 and 4, MIT-T to 500-1000psi. Pull catcher sub Coiled Tubing: Tag HEX plug and circulate KWF bottoms up before pulling plug. Pull plug. RIH and perform P&A from tag depth up to 11,200’TVD. Slickline: WOC 3 days. RIH tag cement top and perform MIT (AOGCC witnessed) Engineering: Continue to progress subsequent P&A program after well is confirmed secure. Thank you, Torin Roschinger Hilcorp Energy Alaska Prudhoe Bay West - Operations Manager c. 406 570 9630 Torin.roschinger@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. 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): 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 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 K-01 Pull HEX Plug Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 183-121 50-029-20998-00-00 12043 Conductor Surface Intermediate Production Liner 9135 80 2780 11224 8074 11841 20" x 30" 13-3/8" 9-5/8" 7" 8958 40 - 120 37 - 2817 35 - 11259 3969 - 12043 40 - 120 37 - 2691 35 - 8455 3446 - 9135 11841 2670 4760 5410 None 5380 6870 7240 11362 - 11887 4-1/2" 12.6# 13Cr80 33 - 11019 8542 - 8998 Structural 4-1/2" Baker S3 Packer 10819, 8090 Stan Golis Sr. Area Operations Manager Noel Nocas Noel.Nocas@hilcorp.com 907.564.5278 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 13.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 0028300 No SSSV Installed 33 - 8255 N/A N/A 84 358 43687 45520 84 0 0 0 1279 1959 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 10819 8090 By Meredith Guhl at 1:49 pm, Jul 18, 2022 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2022.07.18 12:13:00 -08'00' Stan Golis (880) MGR07SEP2022 ACTIVITY DATE SUMMARY 6/20/2022 ***WELL SHUT IN ON ARRIVAL*** (DRIFT/TAG) MIRU E-LINE DRIFT 2.375" DUMMY WRP DRIFT. TAG HEX PLUG AT 11711' ELM ***JOB CONTINUES ON 21JUN22 WSR*** READY TO POP FOR LDL 6/21/2022 ***JOB CONTINUES FROM 20JUN22 WSR*** (LEAK DETECTION) RIH W/ STP TOOLS WHILE FLOWING WELL. PERFORM UP-DOWN PASSES 30/60/90FPM 11000-11700 5 MINUTE STATION SURVEYS AT 11100. 11300. 11420, AND 11690' FOUND 100% OF FLOW COMING FROM UPPER PERF INTERVAL ( 11362' - 11392'), HEX PLUG NOT LEAKING. ***JOB COMPLETE / WELL FLOWING ON DEPARTURE*** 7/8/2022 ***WELL S/I ON ARRIVAL*** (perforating) RAN 10' x 3" PUMP BAILER TO HEX PLUG @ 11,715' MD (Bailer empty, good FN marks). ***WSR CONTINUED ON 7-9-22*** 7/9/2022 ***WSR CONTINUED FROM 7-8-22*** PULLED 363-700 HEX PLUG FROM 11,695' SLM TO 58' SLM WHERE PLUG WOULDN'T PASS (gs sheared & plug fell back downhole) ATTEMPTED TO GET A 3.84" GAUGE RING THROUGH OBSTRUCTION @ 58' SLM (nasty metal gouges on opposing sides of gauge ring) ATTEMPTED TO GET 3.75" SWAGE THROUGH W/ SAME RESULTS ATTEMPTED TO GET 3.70" SWAGE THROUGH, LESS STICKY & CAME BACK W/ LESS GOUGES 3.64" SWAGE BOBBLES THROUGH OBSTRUCTION RE-RUN 3.70" SWAGE FOR 1 HOUR W/ NO LUCK ***(pics in well picture folder)*** CHASED HEX PLUG DOWN TO 11,841' SLM ***UNKNOWN OBSTRUCTION @ -58' SLM. ~3.64" ID - METAL SCARING ON ALL TOOLS LARGER ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** Daily Report of Well Operations PBU K-01 folder)*** CHASED HEX PLUG DOWN TO 11,841' SLM Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes BCU 18RD 50133205840100 222033 6/11/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/18/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/7/2022 Yellowjacket GPT-PLUG + Report BCU 24 50133206390000 214112 6/16/2022 Halliburton PPROF BCU 24 50133206390000 214112 5/23/2022 Yellowjacket GPT-PERF + Report BCU 24 50133206390000 214112 5/26/2022 Yellowjacket GPT-PERF + Report BCU 7A 50133202840100 214060 6/21/2022 Yellowjacket CBL BCU 7A 50133202840100 214060 6/15/2022 Yellowjacket GAMMA RAY + Report BRU 232-26 50283200770000 184138 5/25/2022 Yellowjacket CBL CLU 01RD 50133203230100 203129 5/19/2022 Yellowjacket PERF + Report CLU 01RD 50133203230100 203129 5/24/2022 Yellowjacket PERF + Report CLU 09 50133205440000 204161 5/27/2022 Yellowjacket PERF + Report CLU-1RD 50133203230100 203129 5/28/2022 Halliburton PPROF + Report END 1-17A 50029221000100 196199 5/26/2022 Halliburton LDL END 1-45 50029219910000 189124 5/23/2022 Halliburton LDL + Report END 3-17F 50029219460600 203216 6/15/2022 AK E-Line PLUG CUT FALLS CREEK 3 50133205240000 203102 6/4/2022 Yellowjacket PERF + Report HVB B-16 50231200400000 212133 6/14/2022 AK E-Line CIBP KALOTSA 1 50133206570000 216132 7/7/2022 Yellowjacket PERF + Report KBU 11-07 50133205560000 205165 6/16/2022 Yellowjacket GPT-PERF + Report KBU 11-07 50133205560000 205165 6/20/2022 Yellowjacket GPT-PERF + Report KBU 33-06X 50133205290000 203183 6/22/2022 Yellowjacket CBL MPU B-28 50029235660000 216027 5/27/2022 Halliburton LDL MPU B-28 50029235660000 216027 5/27/2022 Halliburton MFC + Report MPU B-30 50029235710000 216153 5/18/2022 Halliburton PERF MPU E-06 50029221540000 191048 5/28/2022 Halliburton MFC + Report Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: MPU E-35 50029236150000 218152 6/15/2022 Halliburton MFC + Report MPU L-50 50029235550000 215132 6/24/2022 Read COIL FLAG PAXTON 10 50133206910000 220064 5/27/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton RBT PBU GNI-03 50029228200000 197189 6/25/2022 Read CALIPER PBU GNI-03 50029228200000 197189 6/25/2022 Read TEMP-PRESS PBU K-01 50029209980000 183121 6/21/2022 Halliburton PPROF + Report PBU M-13A 50029205220100 201165 5/27/2022 Halliburton TMD3D-WFL + Report PBU NGI-05 50029201960000 176014 6/7/2022 Halliburton CAST PBU W-01A 50029218660100 203176 6/8/2022 Halliburton RBT SRU 241-33 50133206630000 217047 6/13/2022 Yellowjacket PERF SRU 241-33B 50133206960000 221053 5/25/2022 Halliburton TEMP-PRESS SRU 32A-33 50133101640100 191014 6/11/2022 AK E-Line PPROF Please include current contact information if different from above. BCU 18RD PTD:222-033 T36747 BCU 24 PTD:214-112 T36748 BCU 7A PTD:214-060 T36749 BRU 232-26 PTD:184-138 T36750 CLU 01RD PTD:203-129 T36751 CLU 09 PTD: 204-161 T36752 CLU1RD PTD:203-129 T36751 END 1-17A PTD:196-199 T36753 END 1-45 PTD:189-124 T36754 END 3-17F PTD:203-216 T36755 Falls Creek 3 PTD:203-102 T36756 HVB B-16 PTD:212-133 T36757 Kalosta 1 PTD:216-132 T36758 KBU 11-7 PTD:205-165 T36759 KBU 33-06X PTD:203-183 T36760 MPU B-28 PTD:216-027 T36761 MPU B-30 PTD:216-153 T36762 MPU E-06 PTD: 191-048 T36763 MPU E-35 PTD:218-152 T36764 MPU L-50 PTD:215-132 T36765 Paxton 10 PTD:220-064 T36766 PBU C-24B PTD:212-063 T36767 PBU GNI-03 PTD:197-189 T36768 PBU K-01 PTD:183-121 T36769 PBU M-13A PTD:201-165 T36770 PBU NGI-05 PTD:176-014 T36771 PBU W-01A PTD:203-176 T36772 SRU 241-33 PTD:217-047 T36773 SRU 241-33B PTD:221-053 T36774 SRU 32A-33 PTD: 191-014 T36775 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.12 12:56:51 -08'00' ' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: ,5j Cf if&Xply ' air 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number. 183-121 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20998-00-00 7. Property Designation(Lease Number): ADL 0028300 8. Well Name and Number: PBU K-01 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: Total Depth: measured 12043 feet Plugs measured 11715 feet SEP ��� true vertical 9135 feet Junk measured 11901 feet G Effective Depth: measured 11715 feet Packer measured 10819 feet true vertical 8848 feet Packer true vertical 8089.98 feet !G1 CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 40-120 40-120 Surface 2777 13-3/8"72#L-80 37-2814 37-2691 4930 2670 Intermediate 11224 9-5/8"47#L-80 36-11259 36-8455 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11362-11392 feet 11811-11812 feet 11812-11851 feet 11851-11887 feet True vertical depth: 8542-8568 feet feet 8931-8932 feet 8932-8966 feet 8966-8998 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 33-11018 33-8254 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 NOV 0 8 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 363 47411 0 800 1157 Subsequent to operation: 1147 49843 424 100 958 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development fid Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Derrick,Laurie R Contact Name: Derrick,Laurie R Authorized Title: Petro eum Engineer Contact Email: Laurie.Derrick@bp.com / Authorized Signature: V Date: Ci a)7 A-- Contact Phone: +1 907 564 5952 Form 10-404 Revised 04/2017 ///-1-7. L O 1 Lo I L 7/0,7 RE3DMS I l/LS' _ 1 2 9 2017 Submit Original Only • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED SEP 2 8 2017 RE: BP Exploration (Alaska), Inc. AOG C Report of Sundry Well Operations Summary September 25, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug and Addition of Perforations for Well K-01, PTD # 183-121. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Ca a 0 0 0 0 0 0 C8 C� I2 ;- ;7COI O CN10LON- I- V M O� COO M 7 co 0o N N • m Nt CO Ns N- 00 00 to N. 00 to .cr CA to N M to NCO "Zr NN N CO 00 0) 0) CO 1 1 1 1 1 1 1 F- 0 N 00 OtoNNM 'crM M M M 0M O) CO A- M 00 O tO N- N N cN O) O) 0 0 N 0 I- N C.)s CIS 2 6 1 1 1 1 1 1 < O0�o N O 1� CfD O O) NI- MMM On a F_— 00 L o � _1a�o000000 � M N *k J J J u N X *k 4t CO y N -00 CV N C.) N (I)I � N CO 0 0 r- N N c co N- N O N O) J N e- Co 0) O W � Q C W W U C) 0 u_ � D a Z Z c W W W W m O 0 H Z Z Z D • 0 Packers and SSV's Attachment PBU K-01 SW Name Type MD TVD Depscription K-01 PACKER 2729.49 2627 9-5/8" DV Packer K-01 PACKER 3981.44 3453.28 7" Baker ZXP Top Packer K-01 TBG PACKER 10819 8089.98 4-1/2" Baker S-3 Perm Packer • • • a_ a) 2 O c c / ± a 0 x | \ = § m/ % 0 A / 0 % 2 = / 0 I- / 0_ a LU E z CNI --IU w / / A 0.5 = / Cl_ W q c = 2 § >- u_ 0 b ƒ - w 0 .... f E •co < 0 a- Il I 2 E @ 02 Z0W . kb � \ 2 / � O _• k W W � � \ k / a / / k ms x « c - < ® o Ti 9 �e 2 � R / �_c0 % � / Ain \ -I22 L.T. % Ca R $ / L & � O n2 � WG - 0 / r � 7 / m CC > U) U w < z / / L2 < o :U ƒ Rca2DwL1J 1_ : F- (9 � � - - « , W 2 W 1‘..- CN >,Et Li ("3- 22k $ E > wS7 - � 2 2 - ,. o n re > . w ¥ \ § 0_ o - IL g o s & < q ■ C) ƒ / / § CD CO ti < w R : \ 2 6 2 b ED 0 ,-2-5 Z b o_ * w ,. « & W W o 2 ƒk o ? ctkc) m � O _1ak / Cq2 -0 .0 % U § ¥ 0 R n - 0 ƒ w O m O § q £ _1Hom ¥ � 6m = Io0o : = = " a) wW � � � w / _, k0ka_ q � � C2a Io2 � Ek29 � L = ISI ® -1kUEff a) | 0 i R E i CC 2 Ce ƒ < | ; ƒ & U- .6 \ 8 u < ¥ ¥ N- * _� / CD ® o C / N. S \ q \ = Co = @ < T}2EE= 6"MCEVOY WELLHEAD= MCEVOY K-01 -O1 SAFETY NOTES: '4-1/2"CHROME TBG*** ACTUATOR= OTIS OKB ELEV= 61.10' I - - i Li BF.BEV= 25.87 KOP= 1500' , ' I 2218' H4-1/2"FES X NP,D=3.813" Max Angle= 53 @ 4400' Datum MD= 11730' Datum TVD= 8800'SS GAS LFT MANDRELS 13-3/8'CSG,72#,N-80,D=12.347" -{ 2816' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3705 3259 51 MNG DOME RK 16 04/26/17 Minimum ID =3.725" @ 10957' 3 7161 5503 50 KGB2 DOME BK 16 04/26/17 4-1/2" HES XN NIPPLE [ 2 9408 6698 44 KGB2 DMY BK 0 0924/06 1 10715 8002 35 KGB2 DMY BK 0 0924/06 TOP OF 7'LNR H 3969' I 3969' H9-5/8"X 7"BKR ZXP LIP w/6'TEBK.ID=_" ► 3986' H 9-5/8"X 7"BKR FLEX LOCK HGR,D= ' 4 ' ' 10791' H4-1/2"FES X NP,D=3.813" ►1 r 10812' H7"X 4-1/2'BKR S-3 PKR,D=3.870' f 1 ,--14 10846' -14-1/2"HES X ice,D=3.813" ►1 ►4 4 ► 4 ' , 4 10957' H4-1/2"FES XN( D=3.725" 4 4 7"SCAB LNR,26#,L-80 BTC-M, -J 10966' 4 .0383 bpf,ID=6.276' 4-1/2'TBG,12.6#,13CR VAM TOP, H 11010' / \ 11012' H4-1/2"WLEG,D=3.958' .0152 bpf,ID=3.958' 9-5/8'CSG,47#,L-80,ID=8.681" JH 11259' 1132FORATION SUMMARY 9 REP LOG:BHCS ON 09/02/83 ANGLE AT TOP PERF:310 @ 11362' 0 11544' H7'MARKER JONT Note:Refer to Production DB for historical perf data SIZE SR= INTERVAL Opn/Sqz SHOT SQZ '.011111 11715' --I NTERWELL 363-700 FDC PLUG(08/27/17) 3-3/8" 6 11362-11392 0 08/27/17 2-7/8" 6 11811-11851 C 08/27/07 08/27/07 3-3/8" 4 11812-11887 C 01/29/85 0129/85 4111 11901' HFISH-EZSV DEBRIS(9/23/06) PBTD H 12000' 4 44 4 •.s.,.,....s.$$ 7"LNR,26#,L-80,.0383 bpf,D=6.276" --i 12043' 4.11111.11, DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 09/07183 ORIGINAL COMPLETION 09/01/07 TEUSV RE-PERFS(08/27/07) WELL: K-01 09/25/06 NORDIC 2 RWO 07/31/14 PJC SCAB LNR CORRECTION FERMI Na: 1831210 10/12/06pMcUPJC DRLG DRAFT CORRECTIONS 05/03/17 DG/JMD GLV CIO(04/26/17) AR No: 50-029-20998-00 10/20/06 JRFYPAG GLV C/O(10/18/06) 08/29/17 MS/JM) SET HEX PLUG/ADFEFFS(08/27/17) SEC4,T11N,R14E,1626'FAL&1091'FWL 07/06/07 BSE/SV GLV C/O(07/061107) 08/17/07 KSB/PJC GLV C/O BP Exploration(Alaska) AI RECEIVED • /" JUN 152�17 �'�2q $ ®'`�� BAKER PRINT DISTRIBUTION LIST HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc BP Exploration(Alaska)Inc. DATA LOGGED Petrotechnical Data Center,LR2-1 Cs /27-12011 WELL NAME K-01 900 E. Benson Blvd. M K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska LOG DATE April 27,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(a�bakerhughes.com TODAYS DATE June 7,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO$ LOGS CGM, Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #UI-PRIN lb n#OF COPIES #OF COPIES #OF COPIES t1 V V V V V 1 Baker Hughes,Inc. 0 0 795 E.94th Ave. JUN Anchorage,AK 99515 SCANNk0 ,i „ Attn: Arelys Carolina Martinez Patrick Rider 2 ConocoPhillips Alaska Inc. I 1 I 1 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 0 1 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 41State of Alaska -AOGCC 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 1 1 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn: Nancy Landi TOTALS FOR THIS PAGE: 0 3 4 0 0 TOTALS FOR ALL PAGES: 0 3 4 0 0 • LX25� .� Date:5/11/2017 Transmittal Number:0151 P e;.t=cs, Wp"fPorw Pxirt-keen RIGHT PLACE FIRST TIME GYRODATA SURVEY TRANSMITTAL DATA LOGGED Co/8/2011 M.K.BENDER State of Alaska - AOGCC Attn: Makana Bender RECEIVED 333 W 7th Avenue, Suite 100 MAY 3 0 97 Anchorage, AK 99501 AOGCC Enclosed are the materials listed below. If you have any questions,please contact Steve Thompson: 907-250-1200; Stevetfc4gyrodata.com or Jamie McCrimmon: 403-640-7755;Jamiem evrodata.com. Drill Site SW Name Date Description K PAD K-01 4/28/2017 SURVEY REPORT: 1 Hard Copy; 1 Disk P1e e Si and Return on opy of this transmittal to: g ane cPh b p.com aksurve ys'd odata_ � � p a y gyr com Thank You, scpatiEa JUN 1 61°17 Steve Thompson Gyrodata Inc. Gyrodata Incorporated 23000 Northwest Lake Drive Houston, TX 77095 r�S� -t2t • * i t7 RECEIVED MAY 302017 AOGCC I BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 North Slope Borough /Prudhoe Bay Unit 1 OF 13 AK04176CM111 S gwm/data A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, N. Slope Borough/ Prudhoe Bay Unit Job Number: AK0417GCM111 Run Date: 28 Apr 2017 Surveyor: Jeff Patrick Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.339197 deg. N Longitude: 148.609491 deg. Azimuth Correction: None Gyro: Bearings are Relative to True North Depth Reference: Rotary Table Air Gap ( RKB to MSL) 61.12 ft. Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference 2 OF 13 AK0417GCM111 • • • gym/data A Gy rod ata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.0 0.0 0.00 0-11620 FT. CONTINUOUS GYROSCOPIC MULTISHOT SURVEY RAN INSIDE 4.5"TUBING. ALL MEASURED DEPTHS AND COORDINATES ARE REFERENCED TO RKB ELEVATION OF 61.12 FT. ABOVE MSL. BF TO MSL: 25.47 FT. / BF TO SWAB: 9.58 FT. / SWAB TO GYRO SENSOR: 8.5 FT. / ZERO TOOL ON SWAB: +17.57 FT. 100.00 0.26 242.63 100.00 0.10 S 0.20 W 0.2 242.6 0.26 200.00 0.13 197.30 200.00 0.32 5 0.44 W 0.5 234.1 0.19 300.00 0.43 206.87 300.00 0.76 5 0.64 W 1.0 220.1 0.30 400.00 0.54 225.09 399.99 1.43 S 1.15 W 1.8 218.7 0.19 500.00 0.65 217.94 499.99 2.21 S 1.83 W 2.9 219.6 0.13 600.00 0.73 215.50 599.98 3.18 5 2.55 W 4.1 218.7 0.08 700.00 0.72 214.43 699.97 4.21 S 3.27 W 5.3 217.8 0.01 800.00 0.62 218.09 799.97 5.16 5 3.97 W 6.5 217.5 0.11 900.00 0.21 212.64 899.96 5.75 S 4.40 W 7.2 217.4 0.41 1000.00 0.07 183.38 999.96 5.96 S 4.51 W 7.5 217.1 0.16 1100.00 0.08 57.95 1099.96 5.99 S 4.45 W 7.5 216.6 0.13 1200.00 0.70 18.05 1199.96 5.37 S 4.20 W 6.8 218.0 0.64 1300.00 2.86 19.67 1299.91 2.44 5 3.17 W 4.0 232.4 2.16 1400.00 5.44 20.21 1399.64 4.35 N 0.70 W 4.4 350.9 2.58 1500.00 8.03 23.99 1498.94 15.18 N 3.78 E 15.6 14.0 2.63 1600.00 10.96 19.65 1597.56 30.52 N 9.82 E 32.1 17.8 3.01 1625.00 11.26 19.05 1622.09 35.07 N 11.42 E 36.9 18.0 1.29 1650.00 11.79 17.81 1646.59 39.80 N 12.99 E 41.9 18.1 2.34 1675.00 12.08 16.26 1671.05 44.75 N 14.51 E 47.0 18.0 1.73 1700.00 12.34 15.92 1695.48 49.83 N 15.97 E 52.3 17.8 1.08 1725.00 12.79 14.72 1719.88 55.07 N 17.41 E 57.8 17.5 2.08 1750.00 13.04 14.62 1744.25 60.48 N 18.82 E 63.3 17.3 1.00 1775.00 13.64 13.97 1768.57 66.07 N 20.25 E 69.1 17.0 2.47 1800.00 14.05 13.62 1792.85 71.88 N 21.67 E 75.1 16.8 1.67 1825.00 14.25 13.10 1817.09 77.82 N 23.09 E 81.2 16.5 0.95 1850.00 14.37 13.28 1841.31 83.84 N 24.50 E 87.3 16.3 0.51 1875.00 14.58 13.22 1865.52 89.92 N 25.93 E 93.6 16.1 0.84 1900.00 15.16 13.11 1889.68 96.17 N 27.39 E 100.0 15.9 2.32 1925.00 15.96 13.00 1913.77 102.70 N 28.90 E 106.7 15.7 3.20 1950.00 16.61 13.03 1937.76 109.53 N 30.48 E 113.7 15.6 2.60 1975.00 17.67 12.58 1961.65 116.72 N 32.12 E 121.1 15.4 4.27 2000.00 18.46 12.58 1985.42 124.28 N 33.80 E 128.8 15.2 3.16 2025.00 19.00 12.17 2009.10 132.13 N 35.52 E 136.8 15.0 2.22 2050.00 20.08 12.06 2032.66 140.30 N 37.28 E 145.2 14.9 4.32 3 OF 13 AK0417GCM111 • • greidata A Gy rod ata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 2075.00 20.87 11.82 2056.08 148.86 N 39.09 E 153.9 14.7 3.18 2100.00 21.68 11.59 2079.37 157.74 N 40.93 E 163.0 14.5 3.26 2125.00 22.49 11.54 2102.54 166.95 N 42.81 E 172.3 14.4 3.24 2150.00 23.18 11.85 2125.58 176.45 N 44.78 E 182.0 14.2 2.80 2175.00 23.90 11.80 2148.50 186.22 N 46.82 E 192.0 14.1 2.88 2200.00 24.38 12.08 2171.31 196.22 N 48.94 E 202.2 14.0 1.97 2225.00 24.82 12.10 2194.04 206.40 N 51.12 E 212.6 13.9 1.76 2250.00 25.27 12.86 2216.69 216.73 N 53.41 E 223.2 13.8 2.21 2275.00 25.50 13.68 2239.28 227.16 N 55.87 E 233.9 13.8 1.68 2300.00 25.86 14.63 2261.81 237.67 N 58.52 E 244.8 13.8 2.19 2325.00 26.02 14.65 2284.29 248.25 N 61.28 E 255.7 13.9 0.64 2350.00 26.31 15.59 2306.73 258.89 N 64.16 E 266.7 13.9 2.02 2375.00 26.61 15.99 2329.11 269.61 N 67.19 E 277.9 14.0 1.40 2400.00 27.03 16.61 2351.42 280.43 N 70.35 E 289.1 14.1 2.02 2425.00 27.67 17.12 2373.63 291.43 N 73.69 E 300.6 14.2 2.73 2450.00 28.16 17.19 2395.72 302.61 N 77.14 E 312.3 14.3 1.96 2475.00 29.28 17.70 2417.64 314.07 N 80.74 E 324.3 14.4 4.59 2500.00 30.17 18.04 2439.35 325.87 N 84.55 E 336.7 14.5 3.62 2525.00 31.14 18.03 2460.86 337.99 N 88.49 E 349.4 14.7 3.88 2550.00 32.29 18.28 2482.12 350.48 N 92.59 E 362.5 14.8 4.63 2575.00 33.30 18.09 2503.14 363.34 N 96.81 E 376.0 14.9 4.06 2600.00 34.51 18.06 2523.89 376.60 N 101.14 E 389.9 15.0 4.84 2625.00 35.61 17.94 2544.35 390.25 N 105.58 E 404.3 15.1 4.41 2650.00 36.63 17.80 2564.54 404.28 N 110.10 E 419.0 15.2 4.09 2675.00 37.78 17.75 2584.46 418.68 N 114.71 E 434.1 15.3 4.60 2700.00 38.58 17.69 2604.11 433.40 N 119.42 E 449.5 15.4 3.20 2725.00 39.45 17.72 2623.53 448.39 N 124.20 E 465.3 15.5 3.48 2750.00 40.30 17.61 2642.72 463.66 N 129.07 E 481.3 15.6 3.41 2775.00 40.92 17.92 2661.70 479.16 N 134.03 E 497.5 15.6 2.61 2800.00 41.43 18.06 2680.51 494.81 N 139.12 E 514.0 15.7 2.07 2825.00 41.70 18.14 2699.22 510.58 N 144.27 E 530.6 15.8 1.10 2850.00 42.10 18.61 2717.83 526.42 N 149.53 E 547.2 15.9 2.03 2875.00 42.52 18.99 2736.32 542.35 N 154.96 E 564.1 15.9 1.97 2900.00 43.16 19.49 2754.65 558.40 N 160.56 E 581.0 16.0 2.90 2925.00 44.06 20.09 2772.75 574.63 N 166.40 E 598.2 16.1 3.96 2950.00 44.77 20.38 2790.61 591.04 N 172.45 E 615.7 16.3 2.95 2975.00 45.93 20.51 2808.17 607.71 N 178.66 E 633.4 16.4 4.65 3000.00 46.68 20.66 2825.44 624.63 N 185.02 E 651.5 16.5 3.03 3025.00 47.51 20.97 2842.46 641.74 N 191.52 E 669.7 16.6 3.44 3050.00 48.26 21.31 2859.23 659.04 N 198.21 E 688.2 16.7 3.17 4 OF 13 AK0417GCM111 • • gre*Iiata A Gyrodata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 3075.00 48.90 21.37 2875.77 676.50 N 205.03 E 706.9 16.9 2.57 3100.00 49.31 21.72 2892.14 694.08 N 211.97 E 725.7 17.0 1.95 3125.00 49.56 21.68 2908.39 711.73 N 219.00 E 744.7 17.1 1.01 3150.00 49.78 21.74 2924.57 729.43 N 226.05 E 763.7 17.2 0.90 3175.00 49.76 21.77 2940.72 747.16 N 233.12 E 782.7 17.3 0.12 3200.00 49.86 21.77 2956.85 764.89 N 240.20 E 801.7 17.4 0.40 3225.00 49.98 21.84 2972.95 782.65 N 247.31 E 820.8 17.5 0.53 3250.00 50.27 21.91 2988.98 800.46 N 254.46 E 839.9 17.6 1.18 3275.00 50.35 21.84 3004.94 818.31 N 261.62 E 859.1 17.7 0.39 3300.00 50.29 21.78 3020.91 836.18 N 268.77 E 878.3 17.8 0.30 3325.00 49.90 21.86 3036.94 853.98 N 275.90 E 897.4 17.9 1.58 3350.00 49.64 22.05 3053.09 871.68 N 283.04 E 916.5 18.0 1.19 3375.00 49.67 22.13 3069.27 889.34 N 290.20 E 935.5 18.1 0.27 3400.00 49.44 22.41 3085.49 906.94 N 297.41 E 954.5 18.2 1.25 3425.00 49.50 22.43 3101.74 924.51 N 304.66 E 973.4 18.2 0.25 3450.00 49.63 22.46 3117.95 942.10 N 311.92 E 992.4 18.3 0.53 3475.00 49.82 22.49 3134.11 959.72 N 319.22 E 1011.4 18.4 0.77 3500.00 50.05 22.48 3150.21 977.40 N 326.53 E 1030.5 18.5 0.92 3525.00 50.03 22.40 3166.26 995.11 N 333.85 E 1049.6 18.5 0.26 3550.00 50.02 22.36 3182.32 1012.83 N 341.14 E 1068.7 18.6 0.13 3575.00 50.10 22.41 3198.37 1030.55 N 348.44 E 1087.9 18.7 0.35 3600.00 50.03 22.27 3214.42 1048.28 N 355.73 E 1107.0 18.7 0.51 3625.00 50.19 22.24 3230.45 1066.03 N 362.99 E 1126.1 18.8 0.65 3650.00 50.12 22.11 3246.47 1083.81 N 370.24 E 1145.3 18.9 0.49 3675.00 50.35 22.09 3262.46 1101.61 N 377.47 E 1164.5 18.9 0.92 3700.00 50.67 22.08 3278.36 1119.49 N 384.72 E 1183.8 19.0 1.28 3725.00 50.82 22.24 3294.18 1137.42 N 392.02 E 1203.1 19.0 0.78 3750.00 50.94 22.03 3309.95 1155.38 N 399.33 E 1222.4 19.1 0.81 3775.00 51.12 22.02 3325.68 1173.40 N 406.62 E 1241.9 19.1 0.72 3800.00 51.40 22.09 3341.32 1191.48 N 413.94 E 1261.3 19.2 1.14 3825.00 51.61 22.04 3356.88 1209.61 N 421.29 E 1280.9 19.2 0.85 3850.00 51.83 22.01 3372.37 1227.80 N 428.65 E 1300.5 19.2 0.89 3875.00 52.12 22.03 3387.77 1246.06 N 436.04 E 1320.1 19.3 1.16 3900.00 52.25 22.08 3403.10 1264.36 N 443.45 E 1339.9 19.3 0.54 3925.00 51.97 22.10 3418.45 1282.64 N 450.87 E 1359.6 19.4 1.12 3950.00 51.85 22.14 3433.87 1300.87 N 458.28 E 1379.2 19.4 0.50 3975.00 51.92 22.22 3449.31 1319.09 N 465.71 E 1398.9 19.4 0.38 4000.00 51.85 22.66 3464.74 1337.27 N 473.21 E 1418.5 19.5 1.41 4025.00 52.00 22.80 3480.15 1355.42 N 480.82 E 1438.2 19.5 0.74 4050.00 52.25 22.89 3495.50 1373.60 N 488.48 E 1457.9 19.6 1.04 5 OF 13 AK0417GCM111 • • gyroidata A Gy rod ata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 4075.00 52.44 22.95 3510.78 1391.83 N 496.19 E 1477.6 19.6 0.78 4100.00 52.69 22.97 3525.97 1410.11 N 503.93 E 1497.5 19.7 1.00 4125.00 52.78 23.00 3541.11 1428.43 N 511.70 E 1517.3 19.7 0.37 4150.00 52.87 22.98 3556.22 1446.77 N 519.48 E 1537.2 19.8 0.37 4175.00 52.85 23.00 3571.31 1465.11 N 527.27 E 1557.1 19.8 0.10 4200.00 52.98 23.02 3586.38 1483.47 N 535.06 E 1577.0 19.8 0.52 4225.00 53.21 22.96 3601.40 1501.87 N 542.87 E 1597.0 19.9 0.94 4250.00 53.12 22.96 3616.38 1520.30 N 550.67 E 1617.0 19.9 0.36 4275.00 53.16 22.99 3631.38 1538.71 N 558.48 E 1636.9 19.9 0.19 4300.00 53.23 22.79 3646.36 1557.15 N 566.27 E 1656.9 20.0 0.70 4325.00 53.20 22.90 3661.33 1575.60 N 574.04 E 1676.9 20.0 0.37 4350.00 53.19 22.93 3676.31 1594.04 N 581.83 E 1696.9 20.1 0.10 4375.00 53.20 22.92 3691.28 1612.48 N 589.63 E 1716.9 20.1 0.05 4400.00 53.39 22.92 3706.23 1630.94 N 597.44 E 1736.9 20.1 0.76 4425.00 53.32 22.95 3721.15 1649.41 N 605.25 E 1757.0 20.2 0.30 4450.00 53.32 22.86 3736.08 1667.88 N 613.06 E 1777.0 20.2 0.29 4475.00 53.51 23.00 3750.98 1686.37 N 620.88 E 1797.0 20.2 0.88 4500.00 53.39 23.06 3765.87 1704.85 N 628.74 E 1817.1 20.2 0.52 4525.00 53.12 23.20 3780.83 1723.27 N 636.60 E 1837.1 20.3 1.17 4550.00 52.39 23.57 3795.96 1741.54 N 644.50 E 1857.0 20.3 3.15 4575.00 51.98 23.82 3811.28 1759.62 N 652.44 E 1876.7 20.3 1.82 4600.00 51.69 23.99 3826.73 1777.59 N 660.40 E 1896.3 20.4 1.28 4625.00 51.40 24.14 3842.28 1795.47 N 668.39 E 1915.8 20.4 1.25 4650.00 51.42 24.15 3857.87 1813.30 N 676.38 E 1935.3 20.5 0.09 4675.00 51.19 24.23 3873.50 1831.10 N 684.38 E 1954.8 20.5 0.95 4700.00 51.09 24.22 3889.19 1848.85 N 692.36 E 1974.2 20.5 0.40 4725.00 51.12 24.24 3904.89 1866.60 N 700.35 E 1993.7 20.6 0.14 4750.00 51.00 24.26 3920.60 1884.33 N 708.34 E 2013.1 20.6 0.48 4775.00 50.89 24.49 3936.35 1902.01 N 716.35 E 2032.4 20.6 0.84 4800.00 50.82 24.73 3952.13 1919.64 N 724.42 E 2051.8 20.7 0.80 4825.00 50.59 25.09 3967.96 1937.18 N 732.57 E 2071.1 20.7 1.45 4850.00 50.28 25.42 3983.89 1954.61 N 740.79 E 2090.3 20.8 1.60 4875.00 49.92 25.97 3999.93 1971.90 N 749.11 E 2109.4 20.8 2.22 4900.00 49.62 26.46 4016.07 1989.02 N 757.54 E 2128.4 20.8 1.92 4925.00 49.28 27.10 4032.32 2005.98 N 766.10 E 2147.3 20.9 2.37 4950.00 49.08 27.34 4048.67 2022.80 N 774.75 E 2166.1 21.0 1.08 4975.00 48.96 27.52 4065.06 2039.55 N 783.45 E 2184.9 21.0 0.73 5000.00 48.81 27.63 4081.50 2056.25 N 792.17 E 2203.6 21.1 0.69 5025.00 48.88 27.72 4097.95 2072.92 N 800.91 E 2222.3 21.1 0.39 5050.00 48.88 27.89 4114.39 2089.58 N 809.69 E 2241.0 21.2 0.51 6 OF 13 AK0417GCM111 • • gr*Ciatia A Gyrodata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 5075.00 48.79 28.01 4130.85 2106.20 N 818.51 E 2259.7 21.2 0.51 5100.00 48.78 28.14 4147.32 2122.80 N 827.36 E 2278.3 21.3 0.39 5125.00 48.72 28.31 4163.81 2139.36 N 836.25 E 2297.0 21.4 0.56 5150.00 48.78 28.41 4180.29 2155.90 N 845.18 E 2315.6 21.4 0.38 5175.00 48.71 28.40 4196.77 2172.43 N 854.12 E 2334.3 21.5 0.28 5200.00 48.81 28.37 4213.26 2188.97 N 863.06 E 2353.0 21.5 0.41 5225.00 48.69 28.37 4229.74 2205.51 N 871.99 E 2371.6 21.6 0.48 5250.00 48.27 28.32 4246.31 2221.98 N 880.88 E 2390.2 21.6 1.69 5275.00 48.43 28.20 4262.93 2238.43 N 889.72 E 2408.8 21.7 0.73 5300.00 48.66 28.20 4279.48 2254.95 N 898.58 E 2427.4 21.7 0.92 5325.00 48.99 28.27 4295.93 2271.53 N 907.48 E 2446.1 21.8 1.34 5350.00 49.02 28.32 4312.33 2288.14 N 916.42 E 2464.8 21.8 0.19 5375.00 48.93 28.30 4328.74 2304.75 N 925.37 E 2483.6 21.9 0.37 5400.00 48.75 28.51 4345.20 2321.30 N 934.32 E 2502.3 21.9 0.96 5425.00 48.59 28.68 4361.71 2337.78 N 943.31 E 2520.9 22.0 0.82 5450.00 48.79 28.61 4378.21 2354.26 N 952.31 E 2539.6 22.0 0.83 5475.00 48.67 28.55 4394.70 2370.77 N 961.30 E 2558.2 22.1 0.51 5500.00 48.57 28.49 4411.23 2387.25 N 970.25 E 2576.9 22.1 0.44 5525.00 48.33 28.34 4427.81 2403.70 N 979.16 E 2595.5 22.2 1.06 5550.00 48.20 28.12 4444.45 2420.14 N 987.98 E 2614.0 22.2 0.84 5575.00 48.32 28.13 4461.10 2436.59 N 996.78 E 2632.6 22.2 0.48 5600.00 48.31 27.96 4477.72 2453.07 N 1005.55 E 2651.2 22.3 0.51 5625.00 48.48 27.93 4494.32 2469.58 N 1014.31 E 2669.8 22.3 0.69 5650.00 48.45 27.87 4510.90 2486.12 N 1023.07 E 2688.4 22.4 0.22 5675.00 48.21 27.88 4527.52 2502.63 N 1031.80 E 2707.0 22.4 0.96 5700.00 48.24 27.81 4544.17 2519.11 N 1040.51 E 2725.5 22.4 0.24 5725.00 48.12 27.70 4560.84 2535.60 N 1049.19 E 2744.1 22.5 0.58 5750.00 48.02 27.76 4577.55 2552.07 N 1057.84 E 2762.6 22.5 0.44 5775.00 48.07 27.74 4594.26 2568.52 N 1066.50 E 2781.1 22.5 0.21 5800.00 47.84 27.64 4611.01 2584.96 N 1075.12 E 2799.6 22.6 0.97 5825.00 47.99 27.65 4627.76 2601.39 N 1083.73 E 2818.1 22.6 0.60 5850.00 47.82 27.69 4644.52 2617.82 N 1092.35 E 2836.6 22.6 0.69 5875.00 47.73 27.79 4661.32 2634.21 N 1100.96 E 2855.0 22.7 0.47 5900.00 47.53 27.90 4678.17 2650.54 N 1109.59 E 2873.4 22.7 0.86 5925.00 47.41 28.13 4695.07 2666.80 N 1118.24 E 2891.8 22.7 0.83 5950.00 47.59 28.28 4711.96 2683.05 N 1126.96 E 2910.1 22.8 0.85 5975.00 47.56 28.15 4728.83 2699.31 N 1135.68 E 2928.5 22.8 0.40 6000.00 47.31 28.09 4745.74 2715.55 N 1144.36 E 2946.8 22.9 1.02 6025.00 47.17 28.05 4762.71 2731.74 N 1153.00 E 2965.1 22.9 0.57 6050.00 47.02 27.97 4779.73 2747.91 N 1161.60 E 2983.3 22.9 0.64 7 OF 13 AK0417GCM111 • • /day A Gyrodata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 6075.00 47.24 27.96 4796.74 2764.09 N 1170.19 E 3001.6 22.9 0.88 6100.00 47.34 28.07 4813.69 2780.31 N 1178.82 E 3019.9 23.0 0.51 6125.00 47.33 28.16 4830.64 2796.53 N 1187.48 E 3038.2 23.0 0.27 6150.00 47.24 28.35 4847.60 2812.71 N 1196.18 E 3056.5 23.0 0.66 6175.00 47.14 28.46 4864.59 2828.84 N 1204.90 E 3074.8 23.1 0.51 6200.00 47.31 28.55 4881.56 2844.96 N 1213.66 E 3093.0 23.1 0.73 6225.00 47.36 28.77 4898.51 2861.09 N 1222.47 E 3111.3 23.1 0.68 6250.00 47.34 29.20 4915.44 2877.18 N 1231.38 E 3129.6 23.2 1.27 6275.00 47.70 29.45 4932.33 2893.25 N 1240.41 E 3147.9 23.2 1.62 6300.00 47.75 29.83 4949.14 2909.33 N 1249.56 E 3166.3 23.2 1.14 6325.00 47.96 29.96 4965.92 2925.40 N 1258.80 E 3184.7 23.3 0.92 6350.00 47.94 30.13 4982.66 2941.47 N 1268.10 E 3203.2 23.3 0.51 6375.00 47.73 30.13 4999.45 2957.50 N 1277.40 E 3221.6 23.4 0.84 6400.00 47.77 30.09 5016.26 2973.51 N 1286.68 E 3240.0 23.4 0.20 6425.00 47.74 30.07 5033.06 2989.52 N 1295.96 E 3258.3 23.4 0.13 6450.00 47.90 30.07 5049.85 3005.55 N 1305.24 E 3276.7 23.5 0.64 6475.00 47.85 30.03 5066.62 3021.60 N 1314.52 E 3295.2 23.5 0.23 6500.00 47.87 29.99 5083.39 3037.66 N 1323.80 E 3313.6 23.5 0.14 6525.00 47.83 29.91 5100.17 3053.72 N 1333.05 E 3332.0 23.6 0.29 6550.00 47.78 29.87 5116.96 3069.77 N 1342.28 E 3350.4 23.6 0.23 6575.00 47.88 30.00 5133.74 3085.83 N 1351.53 E 3368.8 23.7 0.56 6600.00 48.08 30.30 5150.48 3101.89 N 1360.85 E 3387.3 23.7 1.20 6625.00 48.27 30.75 5167.15 3117.94 N 1370.32 E 3405.8 23.7 1.54 6650.00 48.36 31.18 5183.78 3133.95 N 1379.92 E 3424.3 23.8 1.33 6675.00 48.49 31.33 5200.37 3149.94 N 1389.63 E 3442.8 23.8 0.69 6700.00 48.67 31.59 5216.90 3165.93 N 1399.41 E 3461.4 23.8 1.06 6725.00 48.66 31.84 5233.42 3181.89 N 1409.28 E 3480.0 23.9 0.75 6750.00 48.69 32.03 5249.92 3197.83 N 1419.21 E 3498.6 23.9 0.58 6775.00 48.61 32.07 5266.44 3213.73 N 1429.17 E 3517.2 24.0 0.34 6800.00 48.55 32.19 5282.98 3229.61 N 1439.14 E 3535.7 24.0 0.43 6825.00 48.56 32.39 5299.53 3245.45 N 1449.15 E 3554.3 24.1 0.60 6850.00 48.63 32.61 5316.06 3261.27 N 1459.22 E 3572.8 24.1 0.72 6875.00 48.78 32.68 5332.56 3277.08 N 1469.36 E 3591.4 24.2 0.64 6900.00 48.60 32.77 5349.06 3292.88 N 1479.51 E 3610.0 24.2 0.77 6925.00 48.53 32.87 5365.61 3308.63 N 1489.67 E 3628.5 24.2 0.41 6950.00 48.73 32.89 5382.13 3324.39 N 1499.85 E 3647.1 24.3 0.80 6975.00 48.78 33.06 5398.61 3340.16 N 1510.08 E 3665.7 24.3 0.55 7000.00 48.98 33.03 5415.05 3355.94 N 1520.35 E 3684.3 24.4 0.81 7025.00 49.06 32.97 5431.45 3371.77 N 1530.63 E 3702.9 24.4 0.37 7050.00 49.08 32.93 5447.83 3387.62 N 1540.91 E 3721.6 24.5 0.14 8 OF 13 AK0417GCM111 i • gyrqdata A Gyrodata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 7075.00 49.23 32.93 5464.18 3403.50 N 1551.19 E 3740.3 24.5 0.60 7100.00 49.18 32.90 5480.51 3419.38 N 1561.47 E 3759.0 24.5 0.22 7125.00 49.43 33.06 5496.81 3435.28 N 1571.79 E 3777.8 24.6 1.11 7150.00 49.51 33.24 5513.06 3451.19 N 1582.18 E 3796.6 24.6 0.63 7175.00 49.73 33.45 5529.25 3467.10 N 1592.65 E 3815.4 24.7 1.09 7200.00 49.91 34.20 5545.38 3482.97 N 1603.28 E 3834.3 24.7 2.40 7225.00 50.03 34.29 5561.46 3498.79 N 1614.05 E 3853.1 24.8 0.55 7250.00 50.04 34.58 5577.52 3514.60 N 1624.89 E 3872.0 24.8 0.89 7275.00 50.11 34.73 5593.57 3530.37 N 1635.79 E 3890.9 24.9 0.54 7300.00 50.17 35.04 5609.59 3546.11 N 1646.76 E 3909.8 24.9 0.98 7325.00 50.42 35.18 5625.56 3561.84 N 1657.83 E 3928.8 25.0 1.09 7350.00 50.49 35.34 5641.48 3577.58 N 1668.96 E 3947.7 25.0 0.57 7375.00 50.42 35.51 5657.40 3593.29 N 1680.13 E 3966.7 25.1 0.59 7400.00 50.31 35.69 5673.34 3608.95 N 1691.34 E 3985.6 25.1 0.71 7425.00 50.35 35.69 5689.30 3624.58 N 1702.56 E 4004.5 25.2 0.16 7450.00 50.48 35.61 5705.23 3640.23 N 1713.79 E 4023.5 25.2 0.58 7475.00 50.31 35.61 5721.17 3655.89 N 1725.01 E 4042.4 25.3 0.68 7500.00 50.26 35.64 5737.14 3671.53 N 1736.21 E 4061.3 25.3 0.22 7525.00 50.11 35.63 5753.15 3687.13 N 1747.40 E 4080.2 25.4 0.60 7550.00 50.00 35.76 5769.20 3702.70 N 1758.58 E 4099.1 25.4 0.59 7575.00 50.07 35.76 5785.26 3718.25 N 1769.78 E 4117.9 25.5 0.28 7600.00 50.21 35.89 5801.28 3733.81 N 1781.01 E 4136.8 25.5 0.69 7625.00 50.22 35.97 5817.28 3749.36 N 1792.28 E 4155.7 25.5 0.25 7650.00 50.19 36.01 5833.28 3764.90 N 1803.57 E 4174.6 25.6 0.17 7675.00 50.17 36.03 5849.29 3780.43 N 1814.86 E 4193.5 25.6 0.10 7700.00 50.25 36.03 5865.29 3795.97 N 1826.16 E 4212.4 25.7 0.32 7725.00 50.11 36.06 5881.30 3811.50 N 1837.46 E 4231.3 25.7 0.57 7750.00 50.09 36.16 5897.34 3826.99 N 1848.77 E 4250.2 25.8 0.32 7775.00 50.13 36.17 5913.37 3842.48 N 1860.08 E 4269.0 25.8 0.16 7800.00 49.99 36.24 5929.42 3857.94 N 1871.41 E 4287.9 25.9 0.60 7825.00 50.04 36.21 5945.48 3873.40 N 1882.73 E 4306.7 25.9 0.22 7850.00 50.11 36.20 5961.53 3888.87 N 1894.05 E 4325.6 26.0 0.28 7875.00 49.91 36.20 5977.59 3904.32 N 1905.36 E 4344.4 26.0 0.80 7900.00 49.88 36.21 5993.70 3919.75 N 1916.66 E 4363.3 26.1 0.12 7925.00 49.94 36.23 6009.80 3935.18 N 1927.96 E 4382.1 26.1 0.25 7950.00 49.96 36.31 6025.89 3950.61 N 1939.28 E 4400.9 26.1 0.26 7975.00 49.86 36.23 6041.99 3966.03 N 1950.60 E 4419.8 26.2 0.47 8000.00 49.82 36.23 6058.11 3981.44 N 1961.89 E 4438.6 26.2 0.16 8025.00 50.02 36.15 6074.21 3996.88 N 1973.18 E 4457.4 26.3 0.84 8050.00 49.87 36.12 6090.29 4012.33 N 1984.47 E 4476.3 26.3 0.61 9 OF 13 AK0417GCM111 • . .. gyroidata A Gyrodata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 8075.00 50.02 36.12 6106.38 4027.79 N 1995.75 E 4495.1 26.4 0.60 8100.00 50.04 36.20 6122.44 4043.26 N 2007.05 E 4514.0 26.4 0.26 8125.00 49.63 36.23 6138.57 4058.67 N 2018.34 E 4532.8 26.4 1.64 8150.00 49.53 36.19 6154.78 4074.03 N 2029.58 E 4551.6 26.5 0.42 8175.00 49.63 36.19 6170.98 4089.39 N 2040.82 E 4570.3 26.5 0.40 8200.00 49.65 36.23 6187.17 4104.76 N 2052.07 E 4589.1 26.6 0.15 8225.00 49.17 36.16 6203.44 4120.08 N 2063.29 E 4607.8 26.6 1.93 8250.00 49.17 36.17 6219.79 4135.35 N 2074.45 E 4626.5 26.6 0.03 8275.00 49.19 36.11 6236.13 4150.63 N 2085.61 E 4645.2 26.7 0.20 8300.00 49.22 36.15 6252.46 4165.92 N 2096.77 E 4663.8 26.7 0.17 8325.00 49.21 36.16 6268.79 4181.20 N 2107.93 E 4682.5 26.8 0.05 8350.00 49.18 36.19 6285.13 4196.48 N 2119.10 E 4701.2 26.8 0.15 8375.00 49.18 36.19 6301.47 4211.75 N 2130.27 E 4719.8 26.8 0.00 8400.00 49.00 36.12 6317.84 4227.00 N 2141.42 E 4738.5 26.9 0.75 8425.00 48.79 36.04 6334.28 4242.23 N 2152.51 E 4757.1 26.9 0.87 8450.00 48.92 36.14 6350.73 4257.44 N 2163.60 E 4775.7 26.9 0.60 8475.00 48.98 36.05 6367.15 4272.68 N 2174.71 E 4794.3 27.0 0.36 8500.00 49.11 36.09 6383.53 4287.94 N 2185.83 E 4812.9 27.0 0.53 8525.00 49.05 36.09 6399.91 4303.20 N 2196.95 E 4831.6 27.0 0.24 8550.00 48.86 36.11 6416.32 4318.44 N 2208.06 E 4850.2 27.1 0.76 8575.00 48.69 36.07 6432.80 4333.63 N 2219.14 E 4868.8 27.1 0.69 8600.00 48.61 36.11 6449.32 4348.80 N 2230.20 E 4887.3 27.2 0.34 8625.00 48.56 36.11 6465.85 4363.94 N 2241.24 E 4905.8 27.2 0.20 8650.00 48.31 36.04 6482.44 4379.06 N 2252.26 E 4924.3 27.2 1.02 8675.00 48.21 36.02 6499.08 4394.15 N 2263.23 E 4942.7 27.3 0.40 8700.00 48.26 36.08 6515.74 4409.22 N 2274.20 E 4961.2 27.3 0.27 8725.00 48.06 35.99 6532.41 4424.29 N 2285.16 E 4979.6 27.3 0.84 8750.00 48.01 36.01 6549.13 4439.32 N 2296.09 E 4998.0 27.3 0.21 8775.00 47.64 35.92 6565.91 4454.32 N 2306.97 E 5016.3 27.4 1.50 8800.00 47.56 35.92 6582.77 4469.27 N 2317.80 E 5034.5 27.4 0.32 8825.00 47.46 35.89 6599.66 4484.20 N 2328.61 E 5052.8 27.4 0.41 8850.00 47.30 35.66 6616.59 4499.13 N 2339.37 E 5071.0 27.5 0.93 8875.00 47.27 35.59 6633.55 4514.06 N 2350.06 E 5089.2 27.5 0.24 8900.00 47.09 35.62 6650.54 4528.97 N 2360.74 E 5107.3 27.5 0.73 8925.00 46.91 35.61 6667.59 4543.83 N 2371.39 E 5125.4 27.6 0.72 8950.00 46.92 35.61 6684.67 4558.68 N 2382.02 E 5143.5 27.6 0.04 8975.00 46.53 35.49 6701.80 4573.48 N 2392.60 E 5161.5 27.6 1.60 9000.00 46.41 35.60 6719.02 4588.23 N 2403.14 E 5179.5 27.6 0.58 9025.00 46.19 35.37 6736.29 4602.95 N 2413.63 E 5197.4 27.7 1.10 9050.00 46.07 35.31 6753.62 4617.65 N 2424.06 E 5215.2 27.7 0.51 10 OF 13 AK0417GCM111 • • A Gyrodata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 9075.00 46.09 35.27 6770.96 4632.35 N 2434.46 E 5233.1 27.7 0.14 9100.00 45.68 35.31 6788.36 4647.00 N 2444.83 E 5250.9 27.7 1.64 9125.00 45.65 35.16 6805.83 4661.61 N 2455.14 E 5268.6 27.8 0.45 9150.00 45.74 35.16 6823.30 4676.23 N 2465.45 E 5286.4 27.8 0.36 9175.00 45.45 35.16 6840.79 4690.83 N 2475.73 E 5304.1 27.8 1.16 9200.00 45.45 35.06 6858.33 4705.41 N 2485.98 E 5321.7 27.8 0.29 9225.00 45.24 34.89 6875.90 4719.98 N 2496.17 E 5339.4 27.9 0.97 9250.00 45.18 34.89 6893.51 4734.53 N 2506.32 E 5357.0 27.9 0.24 9275.00 44.94 34.77 6911.17 4749.06 N 2516.43 E 5374.6 27.9 1.02 9300.00 44.72 34.71 6928.90 4763.54 N 2526.47 E 5392.1 27.9 0.90 9325.00 44.72 34.63 6946.66 4778.01 N 2536.48 E 5409.5 28.0 0.23 9350.00 44.41 34.50 6964.48 4792.46 N 2546.43 E 5427.0 28.0 1.29 9375.00 44.30 34.44 6982.35 4806.87 N 2556.32 E 5444.3 28.0 0.47 9400.00 44.16 34.39 7000.26 4821.25 N 2566.18 E 5461.7 28.0 0.58 9425.00 43.93 34.41 7018.23 4835.59 N 2576.00 E 5478.9 28.0 0.92 9450.00 43.56 34.27 7036.30 4849.87 N 2585.75 E 5496.1 28.1 1.53 9475.00 43.74 34.13 7054.38 4864.14 N 2595.45 E 5513.3 28.1 0.82 9500.00 43.34 34.25 7072.51 4878.38 N 2605.13 E 5530.4 28.1 1.63 9525.00 43.22 34.24 7090.71 4892.55 N 2614.77 E 5547.4 28.1 0.48 9550.00 43.02 34.22 7108.96 4906.68 N 2624.38 E 5564.4 28.1 0.80 9575.00 42.75 34.22 7127.27 4920.75 N 2633.95 E 5581.3 28.2 1.08 9600.00 42.68 34.15 7145.64 4934.78 N 2643.48 E 5598.2 28.2 0.34 9625.00 42.35 34.01 7164.07 4948.77 N 2652.95 E 5615.0 28.2 1.37 9650.00 42.51 33.81 7182.52 4962.77 N 2662.36 E 5631.8 28.2 0.84 9675.00 42.20 33.79 7201.00 4976.76 N 2671.73 E 5648.6 28.2 1.24 9700.00 42.14 33.74 7219.53 4990.72 N 2681.06 E 5665.3 28.2 0.28 9725.00 42.22 33.79 7238.05 5004.67 N 2690.39 E 5682.0 28.3 0.35 9750.00 41.71 34.04 7256.64 5018.54 N 2699.71 E 5698.6 28.3 2.15 9775.00 41.69 34.16 7275.31 5032.32 N 2709.04 E 5715.2 28.3 0.33 9800.00 41.67 34.22 7293.98 5046.07 N 2718.38 E 5731.7 28.3 0.18 9825.00 41.49 34.22 7312.68 5059.79 N 2727.71 E 5748.2 28.3 0.72 9850.00 41.36 34.28 7331.42 5073.46 N 2737.02 E 5764.7 28.3 0.54 9875.00 41.38 34.28 7350.19 5087.11 N 2746.32 E 5781.1 28.4 0.08 9900.00 41.33 34.29 7368.95 5100.76 N 2755.63 E 5797.5 28.4 0.20 9925.00 41.18 34.32 7387.75 5114.38 N 2764.92 E 5813.9 28.4 0.61 9950.00 41.17 34.38 7406.56 5127.97 N 2774.21 E 5830.3 28.4 0.16 9975.00 41.18 34.34 7425.38 5141.55 N 2783.50 E 5846.7 28.4 0.11 10000.00 40.97 34.52 7444.23 5155.10 N 2792.78 E 5863.0 28.4 0.96 10025.00 40.74 34.69 7463.14 5168.56 N 2802.07 E 5879.3 28.5 1.02 10050.00 40.64 34.60 7482.09 5181.97 N 2811.34 E 5895.5 28.5 0.46 11 OF 13 AK0417GCM111 0 0 _. gyr4data A Gyrodata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 10075.00 40.33 34.80 7501.11 5195.32 N 2820.58 E 5911.6 28.5 1.34 10100.00 40.37 34.91 7520.16 5208.60 N 2829.83 E 5927.7 28.5 0.33 10125.00 40.30 35.09 7539.22 5221.85 N 2839.11 E 5943.8 28.5 0.54 10150.00 40.05 35.05 7558.32 5235.05 N 2848.38 E 5959.8 28.6 1.01 10175.00 39.95 35.10 7577.47 5248.20 N 2857.61 E 5975.8 28.6 0.42 10200.00 39.91 34.95 7596.64 5261.35 N 2866.82 E 5991.7 28.6 0.42 10225.00 39.68 34.96 7615.85 5274.46 N 2875.99 E 6007.6 28.6 0.92 10250.00 39.26 35.11 7635.15 5287.47 N 2885.11 E 6023.4 28.6 1.72 10275.00 39.06 35.19 7654.53 5300.38 N 2894.20 E 6039.1 28.6 0.83 10300.00 38.89 35.32 7673.97 5313.22 N 2903.28 E 6054.7 28.7 0.75 10325.00 38.57 35.51 7693.47 5325.97 N 2912.34 E 6070.2 28.7 1.37 10350.00 38.55 35.60 7713.02 5338.65 N 2921.40 E 6085.7 28.7 0.24 10375.00 38.34 35.75 7732.60 5351.27 N 2930.47 E 6101.1 28.7 0.92 10400.00 37.92 35.87 7752.26 5363.79 N 2939.50 E 6116.4 28.7 1.71 10425.00 37.67 36.11 7772.02 5376.19 N 2948.50 E 6131.6 28.7 1.16 10450.00 37.56 36.23 7791.82 5388.51 N 2957.51 E 6146.8 28.8 0.53 10475.00 37.54 36.35 7811.64 5400.79 N 2966.52 E 6161.9 28.8 0.30 10500.00 37.20 36.78 7831.51 5412.97 N 2975.56 E 6176.9 28.8 1.71 10525.00 36.82 36.95 7851.47 5425.01 N 2984.59 E 6191.8 28.8 1.57 10550.00 36.64 37.09 7871.51 5436.95 N 2993.59 E 6206.6 28.8 0.79 10575.00 36.49 37.24 7891.59 5448.82 N 3002.59 E 6221.3 28.9 0.70 10600.00 36.34 37.20 7911.71 5460.64 N 3011.57 E 6236.0 28.9 0.61 10625.00 36.08 37.28 7931.88 5472.40 N 3020.51 E 6250.6 28.9 1.06 10650.00 35.79 37.28 7952.12 5484.07 N 3029.39 E 6265.2 28.9 1.16 10675.00 35.53 37.37 7972.44 5495.66 N 3038.23 E 6279.6 28.9 1.06 10700.00 35.37 37.59 7992.80 5507.17 N 3047.05 E 6293.9 29.0 0.82 10725.00 35.61 37.52 8013.16 5518.67 N 3055.90 E 6308.3 29.0 0.97 10750.00 35.11 38.09 8033.54 5530.10 N 3064.77 E 6322.6 29.0 2.40 10775.00 35.18 38.42 8053.99 5541.40 N 3073.68 E 6336.8 29.0 0.81 10800.00 35.09 38.61 8074.43 5552.66 N 3082.64 E 6351.0 29.0 0.57 10825.00 35.06 38.73 8094.89 5563.88 N 3091.61 E 6365.1 29.1 0.30 10850.00 34.51 38.86 8115.42 5574.99 N 3100.55 E 6379.2 29.1 2.22 10875.00 34.64 38.99 8136.01 5586.03 N 3109.46 E 6393.2 29.1 0.60 10900.00 34.54 39.08 8156.59 5597.06 N 3118.40 E 6407.1 29.1 0.45 10925.00 34.36 39.16 8177.21 5608.03 N 3127.32 E 6421.1 29.1 0.74 10950.00 34.44 39.16 8197.83 5618.98 N 3136.24 E 6435.0 29.2 0.32 10975.00 34.39 39.33 8218.46 5629.92 N 3145.18 E 6448.9 29.2 0.43 11000.00 34.12 39.55 8239.12 5640.79 N 3154.12 E 6462.7 29.2 1.19 11025.00 34.37 39.72 8259.79 5651.62 N 3163.10 E 6476.6 29.2 1.07 11050.00 34.12 40.20 8280.45 5662.41 N 3172.13 E 6490.4 29.3 1.47 12 OF 13 AK0417GCM111 • 0 gifro/data A Gyrodata Directional Survey BP EXPLORATION (ALASKA) INC. Lease: K Pad Well: K-01 Location: Wellhead, North Slope Borough, Prudhoe Bay Unit Job Number: AK0417GCM111 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 11075.00 33.69 40.29 8301.20 5673.05 N 3181.14 E 6504.1 29.3 1.73 11100.00 33.58 40.45 8322.02 5683.60 N 3190.11 E 6517.7 29.3 0.57 11125.00 33.40 40.73 8342.87 5694.08 N 3199.08 E 6531.2 29.3 0.95 11150.00 33.47 40.51 8363.73 5704.53 N 3208.05 E 6544.7 29.4 0.56 11175.00 33.22 40.68 8384.61 5714.97 N 3216.99 E 6558.2 29.4 1.07 11200.00 33.14 41.10 8405.54 5725.31 N 3225.95 E 6571.6 29.4 0.97 11225.00 32.80 41.28 8426.51 5735.55 N 3234.91 E 6584.9 29.4 1.42 11250.00 32.49 41.37 8447.56 5745.68 N 3243.82 E 6598.1 29.4 1.26 11275.00 32.43 42.21 8468.66 5755.68 N 3252.76 E 6611.2 29.5 1.82 11300.00 32.49 43.70 8489.75 5765.50 N 3261.90 E 6624.3 29.5 3.21 11325.00 31.88 46.19 8510.91 5774.92 N 3271.30 E 6637.1 29.5 5.84 11350.00 31.29 47.66 8532.21 5783.87 N 3280.87 E 6649.6 29.6 3.88 11375.00 31.31 47.39 8553.57 5792.64 N 3290.45 E 6662.0 29.6 0.57 11400.00 31.45 47.04 8574.91 5801.48 N 3300.00 E 6674.4 29.6 0.92 11425.00 31.17 46.84 8596.27 5810.35 N 3309.49 E 6686.8 29.7 1.19 11450.00 30.67 46.74 8617.72 5819.15 N 3318.85 E 6699.0 29.7 2.01 11475.00 30.42 46.38 8639.25 5827.88 N 3328.08 E 6711.2 29.7 1.24 11500.00 30.35 46.34 8660.81 5836.61 N 3337.23 E 6723.3 29.8 0.29 11525.00 30.19 46.00 8682.41 5845.34 N 3346.32 E 6735.4 29.8 0.94 11550.00 30.03 45.11 8704.03 5854.12 N 3355.28 E 6747.5 29.8 1.90 11575.00 29.80 44.74 8725.70 5862.94 N 3364.08 E 6759.5 29.8 1.18 11600.00 29.66 44.25 8747.41 5871.79 N 3372.77 E 6771.5 29.9 1.12 11620.00 29.51 43.81 8764.80 5878.89 N 3379.63 E 6781.1 29.9 1.32 Final Station Closure: Distance: 6781.09 ft Az: 29.89 deg. 13 OF 13 AK0417GCM111 Schlumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well F-48 G-19A NGI-13 MPE-30A F-11B W-12A 11-27 02-22A 01-16 01-14 L5-05 D-21 14-15 D-18A 14-05A 1-23/0-15 5-03 1-09A1L-21 P2-19A OWDW-NW K-01 11-32 3-25B/L-27 Job# 11846815 11890315 11890313 11855817 11649954 11418301 11637127 11216214 11630486 11801086 11767129 11626119 11221550 11695074 11813055 11846802 11223120 11849930 11649963 11211370 11695073 11630498 11630490 5~NED OCT 312007 Log Description USIT lCì 1- ()H~ USIT 1'-1'1- t/)"?, USIT I )It' _ t -:r-X- -cA. I USIT :)Ó/ - 0 ( MCNL ~ (f-/ - It L(" /5"s-:f3 MCNL )'ì1r -/'5f'd .. ~Ç-::¡Lf RST j~ £0 - 147r t1: ¡ ,<:,-S"":}Co MCNL ::Jtv..... - f-\ ~o. "It J "''' ,J--+ RST 1--=1-"'ír-OD<x"'1 5S-+-?r RST ..-¡ ~ _ r-."¡.? . I ~-~ +'-1 MCNL / ~ '":} -(')~c.. *, <:":~ 0 RST /71";:) - I"\~..::) <It- I ";":<;--s,- I RST /11'1 - ó"lJL( ~ ,~.')'Xn RST C)/') I - Jf'}"'"A .... I S ~ "7f RST I D¡;) - (10' .. 1 ~1f [¿, RST ¡}-,.'" ,,,,,-fi- :)'$,- 'II: 1~~155 RST /1rl - 1<1.(') 'Êt,¡,):'\"6L( RST Io,~ -t,,qq 11: I~S-+~ MCNL ~1()+- ()jd .... 1~5?d RST (J'1:¡\ ,_, -V/^ 1=I-15:')~1 RST 1~3- 1;::)/ ..../007-ù RST tD, '--I - I~ I *" 15'"5L.,c:¡ RST ,Qt"lQ - "~I ..., .ç<:7_ ";( - 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: '. >'.,~ .,,_.,..;'._,...;i;;I;"~ t ".f':; Date 10/12/07 09/30/07 09/30/07 10/01/07 03/22/07 09/10/06 06/05/07 1 0/02/06 06/28/07 07/07/07 06/17/07 09/12/07 03/07/06 08/28/07 06/11/07 08/11/07 06/13/06 08/04/07 04/22/07 02/28/06 08/27/07 09/03/07 07/26/07 NO. 4459 Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milm! Pt.,LisburnE BL Color 1 1 1 1 CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 , AT" eo," ¡¿L Received by: Cd 10/23/07 . . K-01 (PTD #1831210) Class. as Under Evaluation . Page 1 of 1 Maunder, Thomas E (DOA) NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Monday, July 02,200712:44 PM Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; Rossberg, R Steven; NSU, ADWWell Operations Supervisor; Randall, Jaclyn S; NSU, ADW WL & Completion Supervisor; GPB, GC1 Wellpad Lead Cc: NSU, ADWWelllntegrity Engineer; Roschinger, Torin T. Subject: K-01 (PTD #1831210) Classified as Under Evaluation Attachments: K-01.pdf From: Sent: To: All, Well K-01 (PTO #1831210) has been found to have sustained casing pressure on the IA. The TIO pressures were 2100/2100/870 psi on 06/30/07 and the well failed a subsequent TIFL ~n 07/01/07. The well has been classified as Under Evaluation. The plan forward for this well is as follows: 1. D: TIFL - FAILED 2. S: DGL Vs 3. D: Re-TIFL SCANNED JUL 1 ß 2007 A wellbore schematic has been included for reference. «K-01.pdf» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 7/16/2007 STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION T 2, 3 2006 REPORT OF SUNDRY WELL OPERA"!JgQM$Gas Gons. Commission , IVED 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. Repair WellŒ Plug PerforationsD Pull TubingŒ! Perforate New PoolO Operation ShutdownD Perforate 0 4. Current Well Class: Development ŒI Stimulate 0 WaiverD t\f\i"l::(Jf?gP. ,n,'.m. OtherD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: II 18~1210 6. API Number 50-029-20998-00-00 1. Operations Performed: AbandonD Alter CasingD Change Approved ProgramD ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicO 9. Well Name and Number: K-01 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ServiceD 61.10 8. Property Designation: ADL-028300 11. Present Well Condition Summary: Total Depth Effective Depth measured 12043 feet true vertical 9135.0 feet Plugs (measured) measured 12000 feet Junk (measured) Fish - EZSV Debris @ 11901' (09/23/2006) true vertical 9098.0 feet Casing CONDUCTOR SURFACE PRODUCTON SCAB LINER LINER Length Size MD TVD Burst Collapse 110 20" x 30" 40 - 150 40.0 - 150.0 2777 13-3/8" 72# N-80 39 - 2816 39.0 - 2611.0 4930 2610 11221 9-5/8" 41# L-80 38 - 11259 38.0 - 8454.0 6810 4160 6991 1" 26# L-80 3969 - 10966 3422.0 - 8208.0 1240 5410 1063 1" 26# L-80 10980 - 12043 8220.0 - 9136.0 1240 5410 ~CANNED C 2 6 2005 Perforation depth: Measured depth: 11812-11881 True vertical depth: 8933-8999 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 VAN TOP @' 35 .--- 11012 - Packers & SSSV (type & measured depth): 9-5/8" ZXP LNR TOP PKR 7" Baker S-3 Packer 4-1/2" HES X Nipple @ 3969 @ 10115 @ 2218 R8DMS 8Ft 0 CT 2 :-f 2006 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RWO work completed - run and cemented Scab 7" Liner and replaced tubing with 4-1/2" Chrome tubing. Prior to well operation: Subsequent to operation: Oil-Bbl SI SI Representative Daily Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 13 o o o o --- Tubina Pressure o o --- 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 15. Well Class after proposed work~ ExploratoryD 16. Well Status after proposed work: OilŒ] GasD DevelopmentŒ ServiceD Contact Printed Name Signature DeWayne R. Schnorr DeWayne R. Schnorr " ~ '2L _. _ ¿;?' .xc fL WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: I 306-324 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Phone Petroleum Engineer 564-5114 Date 10/20/06 Form 10-404 Revised 4/2004 U Rl (J I N A I '. TRæ= WELLHEAD = ACTUATOR::: KB. ELEV = BF. ELEV = KOp::: Max Angle = Datum MD = DatumTVD= 6" MCEVOY MCEVOY OTIS 61.10' 25.82' 1500' 53 @ 4400' 11730' 8800' SS K-01 TES: ***4-1/2" CHROME TBG*** 113-3/8" CSG, 72#, N--80, ID::: 12.347" Minimum ID = 3.725" @ 10957' 4-1/2" HES XN NIPPLE PERFORA TION SUMMARY REF LOG: BHCS ON 09/02/83 ANGLE AT TOP PERF: 29 @ 11812' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 4 11812-11887 C 01/29/85 7" SCAB LNR, 26#, L-80, .0383 bpf, ID =6.276" 4-1/2" TBG, 12.6#, 13CR V AM TOP, .0152 bpf, ID = 3.958" 11010' 19-5/8" CSG. 47#, L-80, ID::: 8.681" I 11259' I PBID I 12043' 12000' I 7" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" I DATE 09/01/83 09/25/06 10/12/06 REV BY COMMENTS ORIGINAL COMPLETION NORDIC RWO BMcLlPJ DRLG DRAFT CORRECTIONS DATE REV BY . ST MD 4 3705 3 7161 2 9408 1 10715 -14-1/2" HES X NIP, ID = 3.813" I GAS LIFT MANDRELS TVO DEV TYÆ VLV LATCH 3259 51 MMG OCR RKP 5503 50 KGB2 DMY BK 6698 44 KGB2 DMY BK 8002 35 KGB2 DMY BK PORT DATE o 09/24/06 o 09/24/06 o 09/24/06 o 09/24/06 7" X 9-5/8" ZXP LNR TOP PKR, ID::: 6.30" (6' TIEBACK) -14-1/2" HES X NIP, ID = 3.813" I 10812' -17" X 4-1/2" BKR S-3 PKR, 10 = 3.870" I 10846' -14-1/2" HES X NIP, 10 = 3.813" I 10957' -14-1/2" HES XN NIP, ID = 3.725" I -14-1/2" WLEG I -1MARKERJOINT I 11901' -I FISH-EZSV DEBRIS (9/23/06) I COMMENTS PRUDHOE BA Y UNIT WELL: K-01 PERMIT No: '1831210 API No: 50·029-20998-00 SEC4, T11N, R14E, 1626.16' FNL & 1090.94' FWL BP Exploration (Alaska) . . K-01 DESCRIPTION OF WORK COMPLETED EVENT SUMMARY AWGRS 06/15/2006 T/I/O= 400/51010 Temp= SII CIRC-OUT (PRE RWO). AWGRS 06/15/2006 TIIIO = 400/500Nac. SI. OA FL (pre-rig MITOA). OA FL @ 60'. AWGRS 06/16/2006 CIRC- OUT (PRE RWO) Pumped 5 bbls neat, 1090 bbls 5% kcl down tubing, up the IA through the jumper line taking returns down the flowline. Freeze protect IA with 110 bbls diesel and freeze protected Tubing with 81 bbls diesel....MIT OA ( PASS) with 1.1 bbls diesel to 2000 psi... Gained 70 psi in 1st 15 mins, Gained 70 psi in 2nd 15 minns for a total gain of 140 psi in 30 minns...bled back 1.2 bbls from OA, Bled back 3 bbls from IA, Bled back minimal from Tubing FWHP = 01010 AWGRS 06/17/2006 T/IAlOA = SI/5010 -PPPOT-T = Passed I PPPOT-IC = PASSED Bleed Tubing void to 0 psi. Casing hanger void on VAC. Functioned lockdown screws. Rigged up test equipment, pumped until clean returns achieved. Pressured tested tubing hanger to 5,000 psi. for 30 mins. Plastic PaklTested casing hanger to 3,800 psi. for 30 mins. DIMS 08/17/2006 G-21 - NU Tree and test. RDMO G-21 DIMS 08/18/2006 MIRU, Kell well wi 8.5# SW, Set and test TWC, ND tree, NU BOPE and test AWGRS 08/18/2006 Pull 6" ciw TWC for rig work over.No problems DIMS 08/19/2006 Initial BOPE test. RIH w/BHA #1. Latch upper Packer. POH LD fish. AWGRS 08/19/2006 Pull 6" ciw TWC for bop test on rig.No problems DIMS 08/20/2006 POH wi BHa #1, did not retrieve upper packer/tubing), Re-run AWGRS 08/2012006 Pull 6" bpv J-plug for rig AWGRS 08/20/2006 PuIl6"TWC ciw for rig after bop test, DIMS 08/21/2006 Fishing Tubing patch. DIMS 08/22/2006 POH LD BHA #4. RIH w/BHA #5. Cut 5-1/2" Tbg. POH LD BHA #5. Set and attempt PIT TWC. DIMS 08/23/2006 Set TWC. Pull TWC. Change & PIT upr. & Iwr. pipe rams. POH LD 7' x 5-1/2" completion to cut. DIMS 08124/2006 POH UD 7" and 5-1/2" Tubing. RIH w/BHA #5. Set HES 9-5/8" RTTS. Test BOPE. DIMS 08/25/2006 Weekly BOPE test. External cut 5-1/2" Tubing. POH UD external cutter, fish and 3-1/2" STL Tubing. RIH w/BHA #6. AWGRS 08/26/2006 ***NORDIC 2 RIG JOB*** DRIFTED WI 4.5" CENT x 4.605" CENT BAR-BELL WI 4.5" LIB TO 7292' SLM, IMPRESSION OF TOP OF 5 1/2" TBG CUT DRIFTED WI 4.50 CENT & 3.25 LIB TO 8982' SLM, NO IMPRESSION ON LIB ( CLEAN), RIH WI 3.70 CENT & 3.25 LIB SID @ 10,995' SLM STANDBY FOR RIG CREW TO DO CHANGE OUT. *** JOB IN PROGRESS *** Page 1 DIMS 08/26/2006 DIMS 08/27/2006 AWGRS 08/27/2006 . . K-01 DESCRIPTION OF WORK COMPLETED Fish lower Packer. N/U shooting flange. MIRU S/L unit. Tag IBP @ 10995'. Drift tubing for e-line. E-line set EZSV and Jet Cut 5-1/2" Tubing. RIH w/OS. Latch fish. POH w/fish. (drift for chem cut) DRIFTED W/ 3.70 CENT & 3,25" LIB TO 10,995' SLM (IMPRESSION OF IBP). DRIFTED W/ 4.25 CENT TO 10,850' SLM (TARGET DEPTH +/. 10,750' MD). RDMO. *** DSO NOTIFIED ON DEPARTURE *** DIMS 08/28/2006 POH LID 5-1/2" Tubing. RIH/POH LID 2-7/8" DP and 3-1/8" DC's. DIMS 08/29/2006 RIH w/BHA #8, Set RTTS, C/O Packoffs, Mill GLM, SS & cement. DIMS 08/30/2006 Mill GLM, SS & cement, POH BHA#8, C/O Mill, RIH BHA #8 and Mill DIMS 08/31/2006 Mill GLM, SS & cement, POH BHA#8, C/O Mill, RIH BHA #8 and Mill DIMS 09/01/2006 Mill to 10,809', BOP Test, Circulate in new vis. seawater DIMS 09/02/2006 POH w/ Mill, C/O Mills, RIH w/ new Mill, Mill from 10818' - 10827' DIMS 09/03/2006 Milling 5-1/2" Tubing and Cement, C/O Mills DIMS 09/04/2006 C/O Mills, Mill from 10,856'-10,879', Circulate DIMS 09/05/2006 POH w/ BHA, C/O BHA, RIH to mill Seal Assem and packer, DIMS 09/06/2006 RIH w/ BHA #12, Milled from 10,879' MD to 10,896' MD, POH W/ BHA #12 DIMS 09/07/2006 C/O Mill, BOP Test, Mill Seal Assembly DIMS 09/08/2006 Milled from 10898' MD to 10918' POH and C/O WS DIMS 09/09/2006 POH w/ BHA 13, C/O WS, RIH w/ BHA 14, Mill packer and push to bottom DIMS 09/10/2006 POH w/ WS, Circ, RIH w/ OS and grapple DIMS 09/11/2006 Attempt to fish PKR. 2 runs w/ different sized grapples. DIMS 09/12/2006 Mill over TOF @ 10934'. Mill down to 10955'. Circ. hi-vis sweep. POH. DIMS 09/13/2006 Mill over TOF. POH LID BHA#17. RIH w/BHA#18 - Double basket O/S. Latch fish. POH w/BHA#18 & fish. DIMS 09/14/2006 DIMS 09/15/2006 DIMS 09/16/2006 POH LID BHA #18 and fish. RIH w/9-5/8" scraper BHA to TOL. POH LID scraper BHA. PUMU RIH w/RCJB. Hang off on RTTS. Test BOPE. Weekly BOPE test. RIH w/BHA #20. POH LID BHA #20. RIH w/BHA #21. Slip & cut drlg. line. FCO to 11900'. POH LID BHA #21. RIH w9-5/8" RTTS. PIT casing to 3500 psi. Page 2 DIMS 09/17/2006 AWGRS 09/17/2006 DIMS 09/18/2006 DIMS 09/19/2006 DIMS 09/20/2006 DIMS 09/21/2006 DIMS 09/22/2006 DIMS 09/23/2006 DIMS 09/24/2006 AWGRS 09/25/2006 DIMS . . K-01 DESCRIPTION OF WORK COMPLETE~D ~~ Isolate 9 5/8" Csg leak, POOH RTTS, RIH 7" FasDril BP, POH, RIH w/?" scab Liner. IBP MONTHLY RENTAL FOR 07/01/06 - 09/01/06. MOs 2,3 & 4. NOTE IBP SET 06/01/06. NORDIC 3 PULLED IBP 9/15/06 Set FasDril plug. RIH wi?"~ scab Liner. Failed attempt to cement 7" scab Liner. Wait on Schlumberger to return with different eqpt. lineup. Cement?" scab Liner. POH LID Liner hanger setting tool. RIH w/6-1/8" mill BHA. PIT Liner. Drill out shoe track from 10777' to 10895'. POH to P/U mud motor and RBIH and resume drilling Shoe Track. Weekly BOPE test. RIH w/6-1/8" cement milling BHA. Mill 22'. POH w/6-1/8" cement milling BHA. Drill out Shoe Track and EZSV plug. Swap fluid to seawater system from viscosified brine system. POH LDDP and drilling BHA. RIH w/4-1/2" 13CR completion. RIH w/completion and land same. Reverse circulate inhibited seawater into IA. ***RIG JOB NORDIC 3*** CHASED BALL & ROD TO X-NIPPLE @ 10861' SLM W/ 3.55" B-GUIDE & 2.75" BLIND BOX. RDMO *** DSO NOTIFIED ON DEPARTURE *** 09/25/2006 Land completion. Set Pkr. PIT Tubing and IA. Set and PIT TWC. DIMS 09/26/2006 Freeze protected K-01 and released rig at 1300-hours. AWGRS 10/17/2006 ***WELL S/I ON ARRIVAL **** (post-rig) RIG-UP SLlCKLlNE. AWGRS 10/18/2006 PULL BALL & ROD FROM 10848' SLM, PULL 1" DUMMY FROM STA #3, MAKE SEVERAL ATTEMPTS GET 1.5" DCR PULLED FROM STA#4...SET 1.5" DOME 1/4" PORT, TRO 1500, RK LATCH) STA # 4..SET ( 1" ORIFICE 5/16" PORT, BK LATCH) STA #3.. PULL RHC PLUG FROM 10852' SLM. *** WELL LEFT SII ON DEPARTURE, NOTIFY DSO *** Page 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 8/17/2006 13:00 - 20:30 7.50 RIGU P PRE Moye from WOA G-21 to K-01. Jeff Jones w/ AOGCC notified yesterday afternoon for upcoming BOPE test. Jeff Jones - AOGCC called at 1800-hrs. and waived witness BOPE test. 20:30 - 21 :30 1.00 RIGU P PRE Spot rig over well. Accept rig @ 2130-hrs. 21 :30 - 00:00 2.50 RIGU P PRE Level rig and prep for RWO. 8/18/2006 00:00 - 02:30 2.50 RIGU P PRE Finish rigging up hardlines to tiger tank and prepare rig for RWO. Call grease crew. Master and swab valves leaking on tree. Pump open SSV, install fuseable cap, bleed pressure from actuator. 02:30 - 05:00 2.50 RIGU P PRE PUMU Veco lubricator and pull BPV. Tbg / IA / OA = 800/0/ o psi. Master and swab valves leaking on tree. Grease crew service valves. Rig up pump in tree cap and lines to circulate to kill well. 05:00 - 06:00 1.00 KILL P DECOMP Pressure test all lines to closed choke to 3000 psi. Test hardline from choke to tiger tank (downstream of choke) to 300 psi. 06:00 - 06:30 0.50 KILL P DECOMP PJSM w/ crew to discuss well kill and circ out procedure. Notify BP radio of venting on pad, and open tubing to choke and bleed to tiger tank. Bleeding gas. 06:30 - 07:30 1.00 KILL P DECOMP Pump seawater down annulus taking returns from tubing @ 6 BPM, 310 psi annulus, 50 psi tubing. Pump 290 Bbls with 55 Bbls of returns (diesel). 07:30 - 12:00 4.50 KILL P DECOMP Continue pumping seawater down annulus w/ returns for tubing @ 8 BPM, 850 psi annulus, 150 psi tubing. With 580 Bbls away, 130 Bbls of diesel retuns to tiger tank. With 840 Bbls away, 240 Bbls returns, diesel and KCL. Haul off returns while roundtripping trucks with seawater. With 1120 Bbls away, 400 Bbls returns and 8.5 # seawater in and out. Tubing and IA on vacuum. Flow check well for 30 minutes. Well on vacuum on tubing and annulus. 12:00 - 12:30 0.50 KILL P DECOMP Rig camp on High Line Power. Flow check well and tubing and annulus on vacuum. 12:30 - 13:30 1.00 KILL P DECOMP Cameron service hand dry rod in TWC. Test to 3500 psi from above, hold and chart for 10 minutes. Swap to pump in IA to test TWC from below. Pump @ 7 BPM, 150 bbls seawater to see increase in pressure to 850 psi on annulus, TWC holding from below. 13:30 - 14:30 1.00 WHSUR P DECOMP Rig on High Line power. Bleed packoffs and ND tree. Remove tree and adaptor flange. Screw XO for 7" IJ4S hanger threads into hanger with 5 1/2 turns. 14:30 - 00:00 9.50 BOPSU P DECOMP NU 13 5/8" BOPE. BOPE configuration from top down: Annular preventer, 7" fixed rams, Blind rams, Flow cross, and 2 7/8" - 5 1/2" VBR on bottom. 8/19/2006 00:00 - 06:00 6.00 BOPSU P DECOMP PIT BOPE per BP and AOGCC requirements - 250 psi Low/3500 psi High. Test all BOPE components excepting upper and lower pipe rams. Lower VBR failed test on 2 7/8" test joint with accumulator pressure increased to 2200 psi. Upper rams tested successfully w/ 7" test joint. 06:00 - 13:00 7.00 BOPSU P DECOMP Change out ram configuration to 2 7/8" fixed rams on bottom, 3 1/2" fixed rams on top. Test both to 250 psi low, 3500 psi high. Attempt to test annular preventer. Leaking flange bolts below bag. Attempt to re-tighten with hammer wrenches and test. Get Sweeney torque wrench from Veco Wells Support and Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: torque all bolts/nuts. Test annular to 250 low 13500 psi high and pass. Complete BOPE testing. 13:00 - 15:00 2.00 FISH P DECOMP DHD shoot fluid level in IA. Level @ 1350'. Pull TWC w/ lubricator. 0 psi on lA, Tbg on strong vacuum. Load hole wI 120 Bbls of Seawater. Clean and clear floor. Load Baker tools and equipment to rig floor PJSM. 15:00 - 00:00 9.00 FISH P DECOMP PUMU 4" Hydraulic GS. 3 1/8" PO Sub, BS, Jars, 9 joints of 3 1/2" DC's. RIH on 150 jts. (4627') 2 7/8" PAC DP picking up singles from pipe shed. 22:00 . 23:00 1.00 FISH P DECOMP PUMU 3-1/2" IF x 2-7/8 PAC BxP XO. 23:00 - 23:30 0.50 FISH P DECOMP Swap pipe handling tools to run 3-1/2" DP. 23:30 - 00:00 0.50 FISH P DECOMP RIH w/3-1/2" DP. 8/2012006 00:00 - 04:30 4.50 FISH P DECOMP Crew change. RIH w170 jts. 3-1/2" DP. POH and stand back 21 jts. 3-1/2" DP in derrick. PU & RIH wI 23 jts. 3-1/2" DP. Establish fishing parameters. PUW - 11 OK -- SOW - 83K. Tag top of upper packer @ 29' in on jt. #73 or 7238' DPMD. Overpull110K PUW -8K-10K to shear release packer. PU string 30' and RIH to tag lower seal assembly. 04:30 - 05:00 0.50 FISH P DECOMP PU 30' and monitor hole and allow packer element to relax. Fill hole with 45 Bbls. seawater. 05:00 - 06:00 1.00 FISH P DECOMP POH w/ upper packer, 3-1/2" DP/2-7/8" DP, DC's and BHA #1 standing DP and DC's back in derrick. 06:00 - 07:00 1.00 FISH P DECOMP Drop ball to open PO sub, let fall for 45 minutes. Open circ sub and continue to POOH slowly. Load the hole every hour w/ 50 Bbls seawater. Dragging as POOH. 07:00 - 08:30 1.50 FISH P DECOMP Continue POOH wI patch assy. With BHA @ 5000', DP pulling wet. Loaded hole with 50 Bbls of SW down backside. Pressured DP to 800 psi and bled off rapidly to surge PO sub. Pressured DP to 1200 psi, unable to circulate DP. Well still taking fluid down backside. 08:30 - 14:30 6.00 FISH P DECOMP POOH wI wet workstring. Double displacing DP with SW down backside every 5 stands, and pumping additional 50 Bbls every hour. Dragging as POOH until into 7" tubing. 14:30 - 15:00 0.50 FISH P DECOMP Break out lay down BHA. Clrc sub not opened, sub packed off with pipe dope and ball on dope. Shear screws not sheared to open circ sub. Dress circ sub and hydraulic GS. 15:00 - 16:00 1.00 FISH P DECOMP Slip and cut drill line. 16:00 - 21 :45 5.75 FISH P DECOMP RIH w/ BHA to fish top section of patch - 51/2" Eclipse packer and 20 joints of 3 1/2" STL tubing. 21 :45 - 23:00 1.25 FISH P DECOMP Establish fishing parameters. While attempting to establish fishing parameters and obtain SOW, stacked out on TOF with entire string weight. Tagged TOF 30' high at 7208'. PUW- 110K, SOW = 80K. Set 5K down weight on TOF and pump 30 Bbls. seawater down DP to clear DP of any obstructions. DP is Clear. Drop ball and wait for 30 minutes for ball to get on seat. Pressure up DP to 1700 psi and shear open Pump Out Sub. 23:00 - 00:00 1.00 FISH P DECOMP POH wlfish filling hole with double steel displacement every 5 stds. and 50 Bbls. every hour. 8/21/2006 00:00 - 06:00 6.00 FISH P DECOMP POH wI fish filling hole with double steel displacement every 5 stds. and 50 Bbls. every hour. 06:00 - 07:30 1.50 FISH P DECOMP Stand back DC's, POOH w/ hydraulic GS, PO sub, jars, BS. Retrieving tool (spear) from Weatherford Eclipse packer on GS. Packer and 3 1/2" tubing with seal mandrel still in hole. Printed: 101212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 8/21/2006 06:00 - 07:30 1.50 FISH P DECOMP Pump 50 Bbls SW in hole. 07:30 - 10:00 2.50 FISH P DECOMP Discuss options with town, Weatherford, and Baker Fishing. Wait on Baker Fishing to set up spear and deliver to rig. Take Weatherford 5 1/2" Eclipse packer to Baker fishing to measure and size proper spear. Dry run with spear in shop. 10:00 - 11 :00 1.00 FISH P DECOMP MU Baker Bull nose releaseable spear w/4.10" O.D. Grapple to re-dressed PO circ sub, Jars, BS, DC's 11 :00 - 16:00 5.00 FISH P DECOMP RIH wI Baker fishing BHA #3 on 2 7/8"AC DP. Pump 50 Bbls seawater in hole every hour. 16:00 - 17:30 1.50 FISH P DECOMP Tag fish @ 7208'. Work left hand torque into spear to set grapple. Set spear and pull 20K overpull. Trip jars. Re-set and work over pull gradual/ly up to 40K overpull. Spear pull free. Re-set spear and work over pull gradual/ly to 55K overpull. Spear pull free, able to re-set but releases with 15K overpull. Load hole wI 50 Bbls seawater. 17:30 - 22:45 5.25 FISH P DECOMP POOH wI spear. Call and confer with Weatherford and Baker. No fish attached to spear grapples. Visible slip marks on grapple where grapple slipped inside TOF. 22:45 - 23:30 0.75 FISH P DECOMP PUMU BHA. Dress spear with 4.20" O.D. grapple and add upldown jars to BHA. 23:30 - 00:00 0.50 FISH P DECOMP RIH w/Baker fishing BHA #4 on 2-7/8" AC DP and 3-1/2" DP. Pump 50 Bbls. seawater in hole every hour for well control. 8/22/2006 00:00 - 02:45 2.75 FISH P DECOMP RIH w/Baker fishing BHA #4 on 2-7/8" AC DP and 3-1/2" DP. Pump 50 Bbls. seawater in hole every hour for well control. 02:45 - 03:30 0.75 FISH P DECOMP Kick while tripping drill. 03:30 - 04:30 1.00 FISH P DECOMP RIH w/Baker fishing BHA #4 on 2-7/8" AC DP and 3-1/2" DP. Pump 50 Bbls. seawater in hole every hour for well control. Double check DP tally and note 30' difference. 04:30 - 05:00 0.50 FISH P DECOMP RIH to 7244'. Stab TD and pump 30 Bbls. seawater @ 2.0 BPM @ 380 psi down DP to clear of any obstructions. 05:00 - 06:00 1.00 FISH P DECOMP Establish fishing parameters - 110K PUW - 80K SOW. Tag TOF @ 7233' DP MD while pumping 2.0 BPM @ 380 psi. No returns obtained. SO to 70K and stroke jars at 130K for three licks. SO to 70K and stroke jars @ 140K for eight licks. SO to 70K and stroke jars @ 150K 45 times @ 0600. Stroking jars once per minute. No measureable movement in TOF. 06:00 - 07:00 1.00 FISH P DECOMP Jarring on fish with 40K overpull for first jar lick, followed by 55K oyerpull for second lick. After 2 hours of jarring on fish, spear pulled free. SO 10K down, no down lick. Repeat picking back up with no additional weight aboye string weight. Pump 50 Bbls in hole. 07:00 - 12:00 5.00 FISH P DECOMP POOH wI BHA #4. Strap 31/2" DP in Derrick. Double DP displacement every 5 stands and 50 Bbls added every hour as POOH. 12:00 - 12:30 0.50 FISH P DECOMP UD BHA #4. Noted that spear grapple was broken and one segment missing. 12:30 - 13:00 0.50 FISH P DECOMP PUMU BHA#5 - inside cutter assy. - No-Go, "DB" underreamer, Mud Motor, Float Sub, PO sub, DC's. 13:00 - 17:30 4.50 FISH P DECOMP RIH BHA #5 on 2-7/8" PAC DP and 3-1/2" DP. 17:30 - 17:45 0.25 FISH P DECOMP Tag TOF @ 7236' DPMD. Bring on Pump to .5 BPM - 250 psi for 1 minute. Increase to 1.5 BPM @ 1600 psi. PSI increase to 3600# @ 1.5 BPM for 1.5 minutes. Pressure fell off to 1200 psi and increased rate to 2.5 BPM @ 1200 psi for 3 minutes. Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 8/22/2006 17:30 - 17:45 0.25 FISH P DECOMP SID pump. 17:45 - 22:30 4.75 FISH P DECOMP POH wlDP and BHA #5. 22:30 - 23:30 1.00 FISH P DECOMP PJSM. Slip and cut drilling line. 23:30 - 00:00 0.50 FISH P DECOMP Set and PIT TWC to 1000 psi from top and bottom for 5 charted minutes to prep for change pipe rams and PIT BOPE. Unable to obtain successful PIT on TWC. 8/23/2006 00:00 - 01 :00 1.00 BOPSU P DECOMP Troubleshoot problem with TWC and make decision to pull and replace TWC. 01 :00 - 02:30 1.50 BOPSU P DECOMP Wait on Valve Shop technicians to arrive. 02:30 - 05:00 2.50 BOPSU P DECOMP PU and lower 7" lubricator extension into BOP. Close annular preventer around extension. PUMU lubricator and attempt to pull TWC. Unable to pull TWC. LD lubricator. Pull and lay down lubricator extension. 05:00 - 07:30 2.50 BOPSU DECOMP Wait on 3-1/2" IF x 1-3/8" BxP XO to arrive from Nordic Rig #2 to break TWC free. 07:30 - 08:30 1.00 BOPSU DECOMP Hold PJSM to discuss all aspects of pulling TWC with DP and XO. P/U and M/U the 3-1/2" IF box by 1-5/8" XO to i-joint of 3-1/2" DP and RIH and engage the TWC. Install Load Cell on Pull-back line, install slips, check for pressures (IA and tubing = O-psi) put 300-psi on Hydrill. Install rig tongs and the TWC backed out with -750-lb-ft of torque. Lower Top Drive and M/U to DP (recommendation of Floorhand during the PJSM) and continue backing out the TWC. Stop and check for flow and well is on yacuum. Open Hydril and POH with TWC. 08:30 - 09:30 1.00 BOPSU P DECOMP P/U Floor Safety Valve and XO and M/U to 7"-IJ4S Landing Joint. Fill hole with 48-Bbls seawater, after being S/I for i-hour. RIH and engage Hanger and test to 1,OOO-psi. 09:30 - 15:00 5.50 BOPSU P DECOMP PJSM for changing rams. Change-out Top Rams to 7" and Bottom Rams to 2-7/8" x 5-1/2" VBRs. Install 4" x 3" single-studded adaptor spool and 3", 5K valve on BOP spacer spool to facilitate pressure testing the changed-out rams. Conduct PJSM to change out the Bails to handle the longer requirement to pull the 7"-Hanger to the Rig Floor. Change-out the Bails. 15:00 - 18:00 3.00 BOPSU P DECOMP Pressure test 7" Fixed Rams and test the VBRs with 3-1/2" and 5-1/2" Test Joints to 250-psi low and 3,500-psi high, and record same on chart. Find leak in flange between 3" wing yalve and bottom Spacer Spool. Call DSM to send Wellhead crew and their Sweeney-style wrench to torque the nuts. 18:00 - 19:00 1.00 BOPSU DECOMP Wait on DSM to send Wellhead crew with Sweeney-style torque wrench to torque valve flange. 19:00 - 19:30 0.50 BOPSU DECOMP Located hammer wrench and continued with tightening flange bolts since an additional hour of waiting time would be consumed. Obtained successful pressure test to 2-7/8" x 5-1/2" VBR's w/5-1/2" testjoint. 19:30 - 20:00 0.50 PULL P DECOMP LD 5-1/2" test joint. PU 7" landing joint and prep to unland Tubing Hanger. Rig up floor with 7" pipe handling equipment. 20:00 - 20:15 0.25 PULL P DECOMP PJSM. Laying down 7" and 5-1/2" tubing. 20: 15 - 22:00 1.75 PULL P DECOMP Unland Tubing Hanger w/PUW @ 185K. String weight - 180K. UD two joints 7" Tubing. 22:00 - 00:00 2.00 PULL P DECOMP POH LD 7" Tubing through pipe shed. 23 joints layed down at OO:OO-hrs. 8/24/2006 00:00 - 04:00 4.00 PULL P DECOMP POH LD 7" Tubing through pipe shed. 76 joints layed down at Printed: 10/212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: DECOMP 04:00-hrs. DECOMP Rig down 7" pipe handling equipment. Rig up 5-12" pipe handling equipment. DECOMP POH LD 5-1/2", 17#/ft. tubing 1x1 through pipe shed. Filling hole w/double steel displacement every 5 jts. and an additional 50 Bbls.lhr. Load out Schlumberger Copntrol Line Spooler. Recoyered 37-clamps and 3-SS bands versus 38-clamps and 4-SS bands shown in original completion tally. Continue POH and UD 5-1/2", 17# Tubing thru Pipe Shed. Recover 100 full joints and a 15.59'-long cut-joint of 5-1/2", 17# tubing, 1-SSSV, and 3-GLMs. Clear and clean Rig Floor and RlU to P/U and M/U Baker external cutter for 5-1/2" tubing. Bring Baker equipment to Rig floor. Install Wear Ring with 12-1/4" bore. Hold PJSM to discuss P/U and M/U the Baker equipment and the 6-joints of 6' DCs from the Pipe Shed. P/U and M/U the Baker External Cutter BHA: Cut Lip Guide on 8-7/16" Outside Cutter, 1-jt 8-1/8" Wash Pipe, Triple Connection, 6-ea 6" Drill Collars. Continue RIH with 31-stands of DP from Derrick. Continue RIH with DP singles from the Pipe Shed. 100 Jts, RIH @ 06:00-hrs. AOGCC - Chuck Sheve waived witness BOPE test. RIH to 180 its. DP (6004') @ 19:00-hrs. PUMU Halco 9-5/8" RTTS Packer w/Storm Valve. RIH w/3 jts. DP and set Packer @ 95'. POH LD Packer retrieving tool and stand back 3 its. DP. Close blind rams. PIT Packer to 1000 psi from above. Pull wear ring. PUMU and set test Plug. RI4LDS. Change upper pipe rams from 7" to 2-7/8" x 5-1/2" VBR's. Change lower rams from 2-7/8" x 5-1/2" VBR's to 3-1/2" fixed bore rams. Weekly BOPE test. Chuck Scheve, AOGCC, waived witnessing the tests. PIT BOPE per AOGCC/BP guidelines - 250 psi Lo/3500 psi High. Unable to get initial body test. Pressure leaking off past test plug. Run in alllockdown screws. Choke and Kill Manifold valves leaking and had to call DSM Grease Crew to bring their greasing equipment to lube all valyes--took 4-gallons of Lubchem's Valve SaverNalve Penetrant to get valves to hold pressure. All tests okay and recorded on charts for 5-minutes. DECOMP RID BOPE test euipment. P/U Storm Valve/RTTS running tool and RIH to release and retrieve Storm Valve/ RTTS Packer. Break off and UD Halliburton equipment. Install wear ring w/12-1/4" bore. DECOMP Continue RIH with Baker Extemal Cutter BHA and stop with joint #217. P/U #218 and #219 and slowly RIH and soft tag @ 7,210'. Check parameters: P/U wt 145K, S/O wt 93K. DECOMP M/U to Top Drive and slowly rotate (10-RPM) down to get Cut Lip to swallow stub and see indication that stub is swallowed. Stop rotating and continue on in and stack out softly @ 7,246'. P/U to check Extemal Cutter dogs against collar of 5-1/2" cut stub, see grab at 8' out. S/O 3' and start rotating at 10-RPM, 5K Ib-ft torque, Rotating wt 117K to 123K. Stop cutting after 8/24/2006 00:00 - 04:00 04:00 - 05:30 4.00 PULL P 1.50 PULL P 05:30 - 06:30 1.00 PULL P 06:30 - 12:00 5.50 PULL P DECOMP 12:00 - 13:45 1.75 PULL P DECOMP 13:45 - 14:15 0.50 PULL P DECOMP 14:15 - 15:30 1.25 PULL P DECOMP 15:30 - 16:45 1.25 PULL P DECOMP 16:45 - 19:00 2.25 PULL P DECOMP 19:00 - 20:00 1.00 PULL P DECOMP 20:00 - 21 :30 1.50 PULL P DECOMP 21 :30 - 00:00 2.50 BOPSU P DECOMP 8/25/2006 00:00 - 09:30 9.50 BOPSU P DECOMP 09:30 - 11 :30 2.00 DHB P 11 :30 - 12:30 1.00 FISH P 12:30 - 13:30 1.00 FISH P Printed: 10/212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 8/25/2006 12:30 - 13:30 1.00 FISH P DECOMP 10-minutes and P/U to check weight. See additional5-6K Ibs as constant pull on full joint of #219 and #218. (575' of 3-1/2", 8.8# STL = 5,060-lbs) Calculate new cut @ +1- 7,236' Nordic 3 RKB. Stop and circulate in 78-Bbls of seawater before returns come to surface--all seawater in returns. 13:30 - 19:30 6.00 FISH P DECOMP POH with fish and additional weight keeps coming. Small amount of methane emanating from DP w/500' DP & BHA to pull. Possible trapped gas under packer. Fill hole and DP. 19:30 - 20:45 1.25 FISH P DECOMP UD BHA #5 - Baker External Cutter and cut joint of 5-1/2" Tubing. Length of cut joint below collar- 3.04'. Length of cut joint above collar - 24.50'. Note: Grapple section of 4.20" O.D. spear lost during BHA #4 run was recovered in top of Eclipse packer bore. Top of Eclipse packer corroded completely away down 20:45 - 22:00 1.25 FISH P DECOMP POH UD 20 jts. of 3-1/2" STL Tubing 1x1 through pipe shed. 22:00 - 23:00 1.00 FISH P DECOMP Clear and clean rig floor. Rig up handling tools to PUMU BHA #6. Rig up handling tools to RIH w/3-1/8" DC's and 2-7/8" PAC DP. 23:00 - 00:00 1.00 FISH P DECOMP PUMU BHA #6. 8/26/2006 00:00 - 04:45 4.75 FISH P DECOMP RIH w/BHA #6 on 3-1/2" DP to TOF @ 7831. BHA RIH to top of 5-1/2" Tubing cut @ 7236' @ 04:00-hrs. No resistance to entry of 5-1/2" Tubing with BHA was noted. Continue RIH w/BHA #6. Stop RIH @ 7729'. Pump 35 Bbls. seawater @ 2.0 BPM @ 510 psi down DP to clear of possible obstructions. 04:45 - 05:30 0.75 FISH P DECOMP RIH to 7792'. Establish fishing parameters. PUW = 142K- SOW = 90K. P/U joint 220. Circulate @ 1.0 BPM @ 110psi. RIH and tag TOF @ 7795'. Pick up to PUW. Overpull9K to 151K. No shearing action noted. Pick up to 40K overpull. Jars tripped at 40K overpull. Pick up to 48K after jars tripped. No joy. S/O to 90K. Pick up to 33K overpull. Jars tripped at 33K overpull. Pick up to 48K oyerpull. No packer release. Slacking off to recock jars and noted that Packer had released. Stop pipe movement for 15 minutes to allow packer element to relax. Slacked off 30' past original tag to 7825' to verify packer release. 05:30 - 11 :00 5.50 FISH P DECOMP POH with 3-1/2" DP and BHA #6. Bottom 5-1/2" Eclipse Packer to Floor at 11 OO-hours. 11 :00 - 11 :30 0.50 FISH P DECOMP Clear and clean Rig Floor and load Baker BHA equipment out of Pipe Shed. 11 :30 - 13:00 1.50 FISH P DECOMP Slip and Cut Drilling Line. 13:00 - 15:00 2.00 FISH P DECOMP N/D Drilling Riser and Flowline. N/U Shooting Flange. 15:00 - 18:30 3.50 FISH P DECOMP R/U SLB Slickline equipment. 18:30 - 20:00 1.50 FISH P DECOMP RIH w/4.5" O.D. drift and 4.5" LIB. Stacked out on top of 5-1/2" stump at 7275' WLM. Wireline jumped lower sheaye wheel. Fixed jumped sheave. POH w/tools string. Picture of 5-1/2" stump top on LIB. 20:00 - 22:00 2.00 FISH P DECOMP Reorient sheave wheels to prevent wireline jumping sheave wheels. Changeout tool string. RIH w/4.5" O.D. drift, knuckle joint and 3.25" O.D. LIB. Hard tagged tight spot at 8982' WLM. POH w/tool string. No picture on LIB. 22:00 - 23:30 1.50 FISH P DECOMP Changeout tool string. RIH w/3.695" O.D. drift and 3.25" O.D. LIB for EZSV plug. EZSV plug O.D. = 3.66". Tag up at 10995' WLM. IBP is setting on TIP @ +1-11010. Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 8/26/2006 23:30 - 00:00 0.50 FISH P DECOMP POH w/tool string. 8/27/2006 00:00 - 00:30 0.50 FISH P DECOMP POH wltool string, 00:30 - 01 :00 0.50 FISH P DECOMP Changeout tool string. RIH w/4.25" O.D. drift and 3.25" LIB for Jet Cutter. Jet Cutter 0.0. = 4.17". Drifted tubing to 10850'. 01 :00 - 02:00 1.00 FISH P DECOMP POH wltool string. RDMO slickline unit. 02:00 - 03:30 1.50 FISH P DECOMP Wait on Schlumberger E-line unit to arrive due to field road conditions and road construction. 03:30 - 07:00 3.50 FISH P DECOMP PJSM. Rig up e-line to set EZSV plug and Jet Cut 5-1/2" tubing. 07:00 - 09:15 2.25 FISH P DECOMP RIH with EZSV, setting tool and sinker bars and correlate setting depth using CCL. Did not see any obstruction while running through the TOF @ 7,275' WLM or further on into the cement sheath. Went all the way to 10,980' ELM, and came back up to resume correlation with earlier CCL (2003). Stopped with EZSV parked @ 10,945' and fired setting tool. Saw and felt good indication at surface. 09:15 - 10:00 0.75 FISH P DECOMP POOH and park tool in lubricator to perform casing pressure test. 10:00 - 11 :00 1.00 FISH P DECOMP Pressure test EZSV to 1,OOO-psi but pressure drops to 500-psi within 3-4 minutes for each of 3-attempts, but fluid level holds constant with pressure bled off. 11 :00 - 12:00 1.00 FISH P DECOMP Rig down the EZSV running tools and prepare to P/U Jet Cutter. Clear and clean Rig Floor. 12:00 - 13:00 1.00 FISH P DECOMP Tour Change-out. PJSM with Day Tour to cover all aspects of P/U M/U and RIH with Jet Cutter. Clear all Rig Crew from Rig Floor and Pipe Shed. P/U Jet Cutter and bring into Pipe Shed. 13:00 - 13:15 0.25 FISH P DECOMP RlU Jet Cutter to E-Line and arm it. PIU and insert into SLB BOP stack and lower the Lubricator onto BOP stack and M/U. RIH 200' and allow Rig Crew to resume normal activities. 13:15 - 15:00 1.75 FISH P DECOMP RIH Schlumberger Jet Cutter to 10,700' @ 1430-hrs to correlate depth of cut with SCMT log dated 6-1-2006. Correlate Jet Cutter depth to 10,727' and fire at 1500-hrs and see good indication at surface. 15:00 - 16:00 1.00 FISH P DECOMP POH with Jet Cutter. 16:00 - 17:00 1.00 FISH P DECOMP Stop with Jet Cutter 200' below Rig Floor, hold PJSM to UD Jet Cutter and RID SLB equipment and haye Rig Crew leave the Floor until tool removed. 17:00 - 19:00 2.00 FISH P DECOMP PJSM. N/D Shooting flange. N/U riser and flowline. 19:00 - 20:15 1.25 FISH P DECOMP PUMU BHA #7. 20:15 - 22:30 2.25 FISH P DECOMP RIH on 3-1/2" DP to 7236'. Establish fishing parameters. PUW = 145K - SOW = 90K 22:30 - 22:45 0.25 FISH P DECOMP Tag TOF @ 7265'. S/O and set 10K downweight on TOF to latch O/S. P/U to 145K PUW with no bite. Engage TD and rotate @ 10 RPMI1000 ftIlbs. torque. S/O and set 10K downweight on TOF. Disengage TD. P/U to 175K. Fish engaged in O/S. S/O and set 20K downweight on TOF. P/U to 175K allow jars to bleed off. P/U to 220K w/fish. 22:45 - 00:00 1.25 FISH P DECOMP CBU @ 9 BPM @ 1560 psi. 8/28/2006 00:00 - 01 :30 1.50 FISH P DECOMP Continue CBU. Gas units @ 350 during CBU. Continue circulate additional 150 Bbls. SID pumps. Monitor well. 01:30 - 05:15 3.75 FISH P DECOMP POH w/3-1/2" DP & BHA #7. Filling hole every 5 stds. wldouble steel displacement. 05:15·07:00 1.75 FISH P DECOMP UD BHA #7. Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 8/28/2006 07:00 - 07:30 0.50 FISH P DECOMP PJSM to POH and UD 5-1/2" tubing. RIU 5-1/2" handling eqipment. 07:30 - 12:30 5.00 FISH P DECOMP POH and UD 5-1/2" tubing. Stop and load out each layer of tubing from Pipe Shed. Recover a 38.77' cutoff joint, 79 full joints, a 15.25' cutoff joint of 5-1/2" tubing and 6-GLMs. Tubing will be normed and junked. 12:30 - 13:30 1.00 FISH P DECOMP RIU to RIH with 3-1/8" DCs and 2-7/8" DP to be able to POH and UD same through the Pipe Shed. Clear and clean Rig Floor. 13:30 - 17:45 4.25 PULL P DECOMP RIH with 3-1/8" DCs and 2-718" DP from Derrick. Hold Long-tour change-out Safety Meeting, then resume RIH. 17:45 - 19:30 1.75 PULL P DECOMP Shut down operation to wait for rig crew arrival. 19:30 - 20:00 0.50 PULL P DECOMP Pre-tour HSE meeting with new crew. 20:00 - 20:30 0.50 PULL P DECOMP Maintenance on top drive. 20:30 - 00:00 3.50 PULL P DECOMP POH UD 150 jts. ea. of 2-7/8" PAC DP and 9 ea. of 3-1/8" DC's through pipe shed 1 x1 . 8/29/2006 00:00 - 02:45 2.75 PULL P DECOMP Continue POH UD 2-7/8" PAC DP and 3-1/8" DC's through Pipe Shed. 02:45 - 04:45 2.00 PULL P DECOMP Rig up floor to PUMU BHA #8 and Load Baker fishing tools into Pipe Shed and prep to PUMU. 04:45 - 07:00 2.25 PULL P DECOMP PUMU BHA #8 - Milling assembly. 07:00 - 09:00 2.00 PULL P DECOMP RIH with Milling BHA on DP from Derrick 09:00 - 10:30 1.50 PULL P DECOMP PJSM. PIU and MIU Halliburton SSCV Valve and RTTS Packer and RIH. Set Packer and pressure test to 1,OOO-psi. Pressure bled to 350-psi in 10-minutes, but the hole has been standing full and we didn't lose any fluid to the formation during trip in and out with spaghetti string. 10:30 - 11 :30 1.00 PULL P DECOMP Bleed off tubing, release from Storm Valve and POH. Break-off and UD SSCV/RTTS Running and Pulling Tool. 11 :30 - 14:00 2.50 PULL P DECOMP PIU landing joint and MIU to Wear ring Pulling Toll, RIH and remove Wear Ring. RIH with Pack-off running and pulling tool and pull pack-offs with 15K. POH and PIU new packoffs and RBIH, install, and test to 3,800-psi for 30-minutes. Good test. 14:00 - 17:30 3.50 PULL P DECOMP NID IA valve and replace with valve delivered by DSM and test to 1,OOO-psi. Reinstall Wear Ring. 17:30 - 18:30 1.00 PULL P DECOMP Unseat Storm Valve and RTTS. Opened 1502 Valve on Head Pin. Well dead. Let Elements relax. POH w/ Storm Valve and RTTS. 19:00 - 22:30 3.50 CLEAN P CLEAN RIH wI 3-1/2" DP and BHA # 8 to 10,700' MD. 22:30 - 00:00 1.50 CLEAN P CLEAN Circulate in viscosified seawater. LRSV = 7000. 8/30/2006 00:00 - 02:30 2.50 CLEAN P CLEAN Circulate in viscosified seawater. LRSV = 70000. 02:30 - 03:00 0.50 CLEAN P CLEAN PJSM wI Baker and Rig Crew. RIH wI BHA #8 and tag Stub @ 10,726' MD. 03:00 - 03:15 0.25 CLEAN P CLEAN Begin to Mill on 5-1/2" Tubing Stub. Stalled out to due to high torque before reaching top of Stub. 03:15 - 04:15 1.00 CLEAN P CLEAN C/O Screens in Shaker and change maximum torgue setting on Top Drive from 11 k #s to 15k #s. 04:15 - 00:00 19.75 CLEAN P CLEAN Mill 5-1/2" Tubing Stub while circulating at 7 BPM and 1150 psi. Only able to set 2k #s on stub due to high torque. Average ROP as of 0600 hrs = 1 ftIhr. 0700-hrs--7-BPM, 1130-psi, WOB 2-3K, 80-RPM, 4' cum penetration Torque loss decreased after entire system achieved 70,000 Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 8/30/2006 04:15 - 00:00 19.75 CLEAN P CLEAN LSRV. 0900-hrs--8-BPM, 1300-psi, WOB 4-5K, 8O-RPM, 7' cumulative penetration 1000-hrs--8-BPM, 1300-psi, WOB 4-5K, 80-RPM, 13' cum 1100-hrs--8-BPM, 1380-psi, WOB 8K, 80-RPM, 16' cum Cuttings across Shakers are pulverized, but contain fine, metal shavings. 1430-hrs--8-BPM, 1380-psi, WOB 12-13K, 80-RPM, 28' cum 1630-hrs--8-BPM, 1380-psi, WOB 12-13K, 80-RPM, 37' cum 1830-hrs--8-BPM, 1380-psi, WOB 12-13K, 80- RPM, 40' cum 1930-hrs--8-BPM, 1480-psi, WOB 11-13K, 80- RPM, 43' cum 2030-hrs--8 BPM, 1380-psi, WOB 11-13K, 80-RPM, 43' cum (Milling through bottom section of GLM) Pump Sweep 2130-hrs--7 BPM, 1280-psi, WOB 11-13K, 70-RPM, 44' cum 2230-hrs--7 BPM, 1280-psi, WOB 11-13K, 70- RPM, 44' cum Sweep back at surface. Cuttings across Shakers are fine metal. Considering replacing mill. 2330-hrs--7 BPM, 1280-psi, WOB 11-13K, 70 RPM, 44' cum Progress has halted. Decision made to POOH and replace Mill. 8/31/2006 00:00 - 07:30 7.50 CLEAN P CLEAN PJSM. POOH wI BHA #8 in order to replace Mill. 07:30 - 10:00 2.50 CLEAN P CLEAN Break-out Bit, Bit Sub, Stabilizer and Junk Baskets. The bit was worn down evenly 1/2" to 3/4", leaving a relatively unscathed diameter of -1-1/2" in the center of the mill. Empty Junk Baskets and find the top Junk Basket filled with heavy metal cuttings and a 10" long by 4" wide metal shaving from what appears to be the upset nose of the GLM. The skirt weld on the top JIB had also broken. We will re-use the other two JIBs. Replace spent 8-1/2" Mill wI new 8-1/2" Mill. 10:00 - 10:30 0.50 CLEAN P CLEAN RIH with Junk Mill #2 on 3-stands of DP to resume Milling operations @ -10,771', then park to Slip and Cut Drilling Line. 10:30 - 15:00 4.50 CLEAN P CLEAN Slip and Cut Drilling Line. Service Top Drive. Changeout a Top Drive link tilt bearing. 15:00 - 16:30 1.50 CLEAN P CLEAN Continue RIH with Mill #2 on DP from Derrick. Stop at 6,100' to CBU to condition the viscosified fluid before continuing in the hole. 16:30 - 17:15 0.75 CLEAN P CLEAN Circulate Bottoms Up to condition fluid system. The yiscosified fluid has thixotropic properties. 17:15 - 18:00 0.75 CLEAN P CLEAN Continue RIH with Mill #2 on DP from Derrick. 18:00 - 18:30 0.50 CLEAN P CLEAN RIH and Tag top of Tubing and Cement @ 10,771' MD. Begin rotating and milling. 18:30 - 00:00 5.50 CLEAN P CLEAN Mill 5-1/2" Tubing Stub and Cement while circulating at 7 BPM and 1180 psi. Average Rap as of 1930 hrs = 2.5 ftIhr. 1930-hrs--7-BPM, 1180-psi, WOB 5-7K, 75-RPM, 46' cum penetration 2030-hrs--7-BPM, 1400-psi, WOB 10K, 70-RPM, 50' cum penetration 2130-hrs--8-BPM, 1400-psi, WOB 10K, 80 RPM, 53' cum pen 2230-hrs--7-BPM, 1280-psi, WOB 10K, 80 RPM, 56' cum pen 2330-hrs--7-BPM, 1300-psi, WOB 10K, 80 RPM, 59' cum pen 9/1/2006 00:00 - 10:30 10.50 CLEAN P CLEAN Mill 5-1/2" Tubing Stub and Cement while circulating at 7 BPM and 1180 psi. Average Rap as of 0030 hrs = 2.5 ftIhr. 0030-hrs--7-BPM, 1260-psi, WOB 10K, 75-RPM, 61' cum Printed: 101212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/112006 00:00 - 10:30 10.50 CLEAN P CLEAN penetration Shut down to C/O screens on Shaker 0130-hrs Resume Milling--7-BPM, 1250 psi, WOB 10K, 75 RPM, 61' cum penetration 0230-hrs--7 BPM, 1250 psi, WOB 10K, 75 RPM, 65' cum pen 0330-hrs--7 BPM, 1211 psi, WOB 10K, 75 RPM, 70' cum pen (Mill @ 10,796' MD) C/O Screens on Shaker 0430-hrs C/O Screens 0530-hrs--7 BPM, 1200 psi, WOB 12K, 73 RPM, 75' cum pen 0730-hrs--7-BPM, 1180-psi, WOB 12-15K, 70-RPM, 80' cum pen 1030-hrs--7-BPM, 1100-psi, WOB 12K-15K, 70-RPM, 83' cum 10:30 - 13:00 2.50 CLEAN P CLEAN Change out screens. Call engineer and confer with MI, decide to swap out the fluid system due to possible contamination from MI Lo-Torq mud lube. Rotate and reciprocate while changing screens and transferring 3%KCI water to Pits. 13:00 - 15:00 2.00 CLEAN P CLEAN Circulate Bottoms Up to clean hole before setting SSCV/RTTS Storm valve for weekly BOP test. John Chrisp waiyed State's witness of the BOP test. 15:00 - 17:30 2.50 CLEAN P CLEAN PJSM. POH with 3-stands of DP and PIU Halliburton SSCV Valve and RTTS. RIH i-stand below the Rig Floor (top of SSCV @ 98') and set and test to 1,OOO-psi. Disengage from SSCV, POH 1-stand and SIB in Derrick. 17:30 - 17:45 0.25 BOPSU P CLEAN Pull Wear Ring, install Test Plug, and cleanout BOP Stack 17:45 - 22:00 4.25 BOPSU P CLEAN Pressure Test BOPE to 250 psi low 13500 psi high 22:00 - 23:00 1.00 CLEAN P CLEAN RIH w/1 stand of DP and tag SSCV/RTTS. POH and UD SSCV/RTTS. 23:00 - 23:15 0.25 CLEAN P CLEAN RIH w/2 stands to 10,807' MD. 23:15 - 00:00 0.75 CLEAN P CLEAN Clean out pits in preparation for fluid swap. Line up vac trucks. PJSM. Circulate and check out pumps. 9/2/2006 00:00 - 04:00 4.00 CLEAN P CLEAN PJSM. Check new viscosified seawater. Circulate new viscosified seawater @ 6 BPM while taking returns to Pit #1 and #2 and then offloading to a dirty vac truck. Tiger Tank lined up if needed. 04:00 - 06:00 2.00 CLEAN P CLEAN Full circulation complete. New viscosified seawater at surface and is in desired condition. Continue to circulate and wait for another load of viscosified seawater from Hot Water Plant before continuing to mill. 06:00 - 11 :30 5.50 CLEAN P CLEAN Resume milling operations at 10,809'. 0700-hrs--7-BPM, 900-psi, 18-20K WOB, 78-RPM, 87' cum, TD-10,813' 0800-hrs--7-BPM, 1000-psi, 18-20K WOB, 78-RPM, 89' cum, TD-10,815' 1100-hrs--7-BPM, 1070-psi, 18-20K WOB, 78-RPM, 92' cum, TD-10,818' 11 :30 - 13:30 2.00 CLEAN P CLEAN Circulate Bottoms Up before POH to change out Mills. 13:30 - 19:00 5.50 CLEAN P CLEAN POH and SIB DP in Derrick. DP pulling wet, so a Mud Bucket is being used for each connection break. 19:00 - 21 :00 2,00 CLEAN P CLEAN C/O Mill. Empty Junk Baskets. Used Mill was flattened and worn through to the inside metal of the Mill. Junk in Junk Basket contained large pieces of what appears to be 5-1/2" Tubing and lots of smaller metal shavings. Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/2/2006 9/3/2006 3.00 CLEAN P 1.00 CLEAN P 1.50 CLEAN P 20.50 CLEAN P 21 :00 - 00:00 00:00 - 01 :00 01 :00 - 02:30 02:30 - 23:00 CLEAN CLEAN CLEAN CLEAN 23:00 - 00:00 1.00 CLEAN P CLEAN 9/4/2006 00:00 - 07:30 7.50 CLEAN P CLEAN 07:30 - 09:00 1.50 CLEAN P CLEAN 09:00 - 11 :00 2.00 CLEAN P CLEAN 11 :00 - 14:30 3.50 CLEAN P CLEAN 14:30 - 00:00 9.50 CLEAN P CLEAN RIH w/ Mill #3 to 10,818' MD. RIH wI Mill #3 to 10,819' MD. Slip and Cut Drill Line. Resume milling operations at 10,819'. 0330-hrs--7-BPM, 1180-psi, 6K WOB, 100-RPM, 98' cum, TD-10,824' 0430-hrs--7-BPM, 1180-psi, 6K WOB, 100-RPM, 100' cum, TD-10,826' 0530-hrs--7-BPM, 1180-psi, 6K WOB, 100-RPM, 101' cum, TD-10,827' 0800-hrs--7-BPM, 1150-psi, 6.5K WOB, 100-RPM, 105' cum, TD-10,831' 1600-hrs--7-BPM, 1250-psi, 11-13K WOB, 70-RPM, 115' cum, TD-10,841' Running Hi-Vis sweeps every 10'. 1800-hrs--7BPM, 1250 psi, 11-13K WOB, 70-RPM, 121' cum, TD-10,847' 1900-hrs--7 BPM, 1200 psi, 15K WOB, 70-RPM, 122' cum, TD-10,848' 2000-hrs--7 BPM, 1200 psi, 12K WOB, 70-RPM, 124' cum, TD-10,850' 2100-hrs--7 BPM, 1200 psi, 15K WOB, 70-RPM, 126' cum, TD-10852' (Pump Hi-Vis Sweep) 2200-hrs--7 BPM, 1280 psi, 18K WOB, 70-RPM, 130' cum, TD-10856' 2300-hrs--7 BPM, 1200 psi, 18K WOB, 70-RPM, 130' cum, TD-10856' POH to 10,853' MD and circulate bottoms up. POH and SIB DP in Derrick. DP pulling wet, so a Mud Bucket is being used for each connection break. Break out and UD BHA with Mill #3. Clean out Junk Baskets and get -4-gallons of metal cuttings and chunks. Clear and clean Rig Floor. Service Top Drive. RIH BHA with Mill #4 to resume milling @ -10,856'. Mill 5-1/2" tubing starting at 10,856'. 1530-hrs--7.5 BPM, 1300-psi, 3-5K WOB, 6-9K Ib-ft, 100-RPM, 131' cum, TD-10,858' 1630-hrs--Add 1-drum of MI Safe-Lube and Myacide (biocide) 1830-hrs-- 7.5 BPM, 1200-psi, 5K WOB,6-9K Ib-ft, 100-RPM, 134' cum, TD-10,861' Add more MI Safe-Lube to raise system to 0.6% 1930-hrs--7.5 BPM, 1380 psi, 6K WOB, 70 RPM, 137' cum, TD-10,864' 2030-hrs--7 BPM, 1220 psi, 5K WOB, 40 RPM, 138' cum, TD-10,865' Order Sodium Bicarbonate, Safe-Lube, and EP Mud Lube. 2130-hrs--7.5 BPM, 1328 psi, 6K WOB, 80 RPM, 139' cum, TD-10,866' Added 1 drum of EP Mud Lube to system 0000-hrs--7 BPM, 1280 psi, 6K WOB, 75 RPM, 140' cum, TD-10,867' Printed: 10/212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/512006 00:00 - 04:00 4.00 CLEAN P CLEAN Mill 5-1/2" tubing and cement: 0000-hrs--7 BPM, 1280 psi, 6K WOB, 75 RPM, 140' cum, TD-10,867' 0100-hrs--7.5 BPM, 1280 psi, 8K WOB, 75 RPM, 141' cum, TD-10,868' 0200-hrs--7.5 BPM, 1280 psi, 8K WOB, 75 RPM, 143' cum, TD-10,870' 0300-hrs--7.5 BPM, 1280 psi, 15K WOB, 50-80 RPM, 149' cum, TD-10,876' o400-hrs--7.5 BPM, 1280 psi, 15K WOB, 60 RPM, 152' cum, TD-10,879' 04:00 - 06:00 2.00 CLEAN P CLEAN Circulate in new viscosified seawater. Lubricants not effective in current mud system due to elevated calcium leyels from the cement being milled. Rotary torque is excessive and lubricants are needed. 06:00 - 10:30 4.50 CLEAN P CLEAN Swap out mud system and build new with Bíozan viscosifier and 0.6% Myacide (biocide). Circulate and condition to ensure Myacide is throughout the wellbore and Pits. 10:30 - 17:00 6.50 CLEAN P CLEAN POH and SIB DP and DCs in Derrick. Pull heavy off bottom. Suspect cuttings falling down around BHA during fluid swap of mud system. Rotate and circulate to loosen up. continue to POOH 17:00 - 18:30 1.50 CLEAN P CLEAN Break out and lay down Milling BHA. 18:30 - 22:00 3.50 CLEAN P CLEAN Empty Junk Baskets and clean. Clean Stack. Very little amount of cuttings in Stack. P/U amd M/U BHA #12 wI 8-1/2" x 6-3/4" ID Washover Shoe and RIH wI Drill Collars. 22:00 - 23:15 1.25 CLEAN P CLEAN Cut and Slip Drill Line. 23:15 - 00:00 0.75 CLEAN P CLEAN RIH wI BHA #12 wI 8-1/2" x 6-3/4" ID Washover Shoe and Drill Collars on 3-1/2" DP from Derrick. 9/6/2006 00:00 - 04:30 4.50 CLEAN P CLEAN RIH wI BHA #12 wI 8-1/2" x 6-3/4" ID Washover Shoe and Drill Collars on 3-1/2" DP from Derrick. 04:30 - 06:30 2.00 CLEAN P CLEAN Tag fill @ 10,865' MD. Begin circulating at 3 BPM and 500 psi. Cleanout to top of 5-1/2" Tubing and cement @ 10,879' MD. Circulate High Vis sweep surface to surface @ 8 BPM and 1200 psi. 06:30 - 09:30 3.00 CLEAN P CLEAN Mill wI WS and wash pipe from 10879' to 10885', 15K WOB, 9K RT, 50 -70 RPM, 8 BPM, 1200 PSI. Pump 30 Bbl Biozan sweep from surface to surface as continue milling 09:30 - 13:00 3.50 CLEAN P CLEAN Mill wI WS and wash pipe from 10885' to 10888', 15K WOB, 9K RT, 50 -70 RPM, 8 BPM, 1200 PSI. 13:00 - 15:00 2.00 CLEAN P CLEAN Circulate High Vis sweep with no effect on excessive torque. 15:00 - 17:00 2.00 CLEAN P CLEAN Milling progress has haulted at 10,888' MD due to excessive torque. Decision made to pump Super sweep and keep circulating rates at 10 BPM while reciprocating. 17:00 - 18:00 1.00 CLEAN P CLEAN Pump 30 Bbls of Super Sweep preceeded by 10 Bbls of water at 10 BPM. Reciprocating and rotating while waiting for full surface to surface circulation. Extremely large quantites of metal coming across Shaker. 18:00 - 19:00 1.00 CLEAN P CLEAN Begin Milling at 10,888' MD to 10891' MD. Top Drive Torque at 9,000 ft-Ibs, RPM-8o, 10 BPM, 1700 psi. ROP=3ft1hr. 19:00 - 20:00 1.00 CLEAN P CLEAN Milling from 10,891' MD to 10,894' MD. Top Drive Torque at 9,000 ft-Ibs, RPM-75, 10 BPM, 1900 psi. Pumping High Vis sweeps every hour once previous sweep has reached surface. Printed: 10/212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/612006 19:00 - 20:00 1.00 CLEAN P CLEAN Getting large quantities of metal across Shakers. ROP=3ft1hr. 20:00 - 21 :00 1.00 CLEAN P CLEAN Milling from 10,894' MD to 10,895' MD. Top Drive Torque at 9,000 ft-Ibs, RPM-75, 10 BPM, 1900 psi. ROP=1ft1hr. Amount of metal coming across Shaker has decreased. 21 :00 - 22:00 1.00 CLEAN P CLEAN Milling from 10,895' MD to 10,895' MD. Top Drive Torque at 9,000 ft-Ibs, RPM-90, 10 BPM, 1900 psi. 22:00 - 00:00 2.00 CLEAN P CLEAN Milling from 10,895' MD to 10,895' MD. Top Drive Torque at 9,000 ft-Ibs, RPM-90, 10 BPM, 1900 psi. Pump High Vis Sweep. Keep stalling out due to excessive torque. 9/7/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN Milling from 10,895' MD to 10,896' MD. Top Drive Torque at 7,500 ft-Ibs, RPM-47, 10 BPM, 1900 psi. Pump High Vis Sweep. 01 :00 - 02:30 1 .50 CLEAN P CLEAN Milling from 10,896' MD to 10,896' MD. Top Drive Torque at 7,500 ft-Ibs, RPM-47, 10 BPM, 1900 psi. Unable to make any progress. Mill is most likely spent. 02:30 - 03:30 1.00 CLEAN P CLEAN Pull up off bottom and pump High Vis sweep with Super Sweep Surface to Surface at 10 BPM, 2000 psi. Reciprocate pipe 60' down slowly then up quickly. Rotate pipe at 100 RPM. Super Sweep bringing back large quantities of of fine metal (similar to the size of sand grains) 03:30 - 04:30 1.00 CLEAN P CLEAN Milling from 10,896' MD to 10,896.5' MD. Top Drive Torque at 7,500 ft-Ibs, RPM-47, 10 BPM, 1900 psi. Torque remains low while on top of Seal Assembly and Cement but in order to Mill deeper additional WOB is needed. When WOB is added to 15K in order to make hole, RPM drop to zero and Top Drive stalls out. Unable to progress. 04:30 - 10:00 5.50 CLEAN P CLEAN POH wI BHA #12 SIB DP in Derrick. Watching drag carefully due to the amounts of metal seen across Shaker during High Vis sweeps. Will inspect Wash Pipe for abrasions, Shoe for wear, and Junk Baskets for content. 10:00 - 14:00 4.00 CLEAN P CLEAN Break and UD BHA #12. Two Metal Muncher Teeth have broken off. One Tooth apparently gouged the inner part of Muncher. Wash pipe has several deep gouges near the Metal Muncher. Upper portion of Wash Pipe is bowed. A slice of 5-1/2" Tubing approximately 3' long is lodged in the Wash Pipe and cannot be removed. MIU BHA #13. 14:00 - 18:00 4.00 CLEAN P CLEAN RIH to 3130' MD and set RTTS/Storm Valve. Prepare for BOPE Test. 18:00 - 22:30 4.50 BOPSU P CLEAN Pressure Test BOP to 250 low and 3500 high. 22:30 - 00:00 1.50 BOPSU P CLEAN RIH wI 1 stand of DP, engage RTTS/Storm valve. POH wI RTTS/Storm Valve and UD Same. 9/8/2006 00:00 - 03:00 3.00 CLEAN P CLEAN RIH wI BHA #13 wI 8-1/2" x 6-3/4" ID Washover Shoe and Drill Collars on 3-1/2" DP from Derrick. 03:00 - 05:00 2.00 CLEAN P CLEAN Tag @ 10896' MD. Begin to circulate @ 10 BPM. Send High Vis Super Sweep Surface to Surface followed by Low Torque (system @ 0.6%). Super Sweep bringing back fine metal shavings. Not as much across Shaker as preYious sweeps. 0500 hrs -- 100 RPM -- Torque 8,000 ft-Ibs -- 10 BPM -- 1800 psi-- 5K WOB -- 10,898' MD 05:00 - 14:00 9.00 CLEAN P CLEAN Mill from 10,898' MD to 10,916' MD. Torque at 8-10K #s·- 10 BPM -- 2000 psi -- 10 K WOB 14:00 - 16:00 2.00 CLEAN P CLEAN Pull off bottom and circulate High Vis Super Sweep Surface to Surface prior to milling through Packer. Large quantities of Printed: 10/212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/812006 14:00 - 16:00 2.00 CLEAN P CLEAN metal flakes coming across Shakers. Super Sweep is caking the metal together in wallet size clumps. Circulate until metal returns reduce to virtually nothing. 16:00 - 18:30 2.50 CLEAN P CLEAN Mill from 10,916' MD to 10,918.5' MD. Torque at 8-10K #s -- 10 BPM --1200 psi -- 20 K WOB. Begin replacing mud system in pits with seawater. 18:30 - 00:00 5.50 CLEAN P CLEAN Mill @ 10918.5' with yarying WOB, RPM, BPM. Appears that mill is worn, spinning on top of packer, or both. Mix "super sweep" and circulate surface to surface @ 10 BPM, 2100 psi while continuing to work mill @ 10918.5'. Super Sweep still caking metal together in clumps. 9/9/2006 00:00 - 04:30 4.50 CLEAN P CLEAN Pump salt pill so DP will be pulled dry. POH wI BHA #13, SIB DP in Derrick. Repair Pump #2, replacing 4-1/2" Liners and Swabs. 04:30 - 06:00 1.50 CLEAN P CLEAN Break and UD BHA #13. Washover Shoe is in good overall condition. The interior mill wall has been worn down and become smooth. One gouge on the exterior was found. Washover pipe is in very good condition. No gouges or abrasions were seen. 06:00 - 07:30 1.50 CLEAN P CLEAN M/U and RIH BHA #14 07:30 - 09:00 1.50 CLEAN P CLEAN Slip and cut Drill Line. 09:00 - 14:00 5.00 CLEAN P CLEAN Continue RIH wi BHA #14 14:00 - 17:00 3.00 CLEAN P CLEAN Tag fish @ 10917.4'. Dry mill then work WS/MiII on fish wI 75 RPM, 5-8K WOB, varying pump rates when pumping while milling. Mill to 10918.5' 17:00 - 19:30 2.50 CLEAN P CLEAN Continue milling to 10921' MD. Pump pressure dropped. Packer has fallen. RIH to tag packer @ -10,955' MD. Sit down 20K # on Packer, no further movement. Pull off bottom 10'. Were experiencing losses (-20 Bbls/hr) but losses have now stopped. Empty viscosified seawater out of pits and replace with seawater. 19:30 - 23:00 3.50 CLEAN P CLEAN Circulate High Vis Sweep followed by seawater displacement @ 6 BPM and 1100 psi. 23:00 - 00:00 1.00 CLEAN P CLEAN Begin POH wI BHA #14. Experiencing overpull and swabbing. Appear to have packer on BHA. Line up to circulate @ 10 BPM to free any potential obstructions between washpipe and casing or to dislodge packer. 9/10/2006 00:00 - 00:30 0.50 CLEAN P CLEAN Pump @ 10 BPM and 2100 psi in order to try to free packer from BHA andlor free junk from between wash pipe and casing. No results. 00:30 - 04:00 3.50 CLEAN P CLEAN POH wI BHA while circulating @ 6 BPM and 800 psi in order to prevent overpull/drag. P/U weight without pumping = 250k #s. P/U weight while pumping = 170k #s. 04:00 - 06:00 2.00 CLEAN P CLEAN POH to 7713' MD. Pumps pressure up to 3500 psi while circulating. Pumps shut off. Loss of 50 Bbls in 3 minutes. Lost all returns. Can't pump down DP. Unable to POH or RIH. Pulling 40k #s over. No moyement. Sitting down 120k #s. No movement. Attempt to pump down backside. Pressure IA to 1500 psi. Slow bleed off. Attempt to pressure up on DP. Pressure DP to 1500 psi. Slow bleed off. Able to pump at 1 BPM at 1000 psi down DP. Rotate and sit down multiple times. Finally break free. 06:00 - 07:30 1.50 CLEAN P CLEAN Circulate 40 Bbl Duo Vis sweep @ 10 BPM and 1850 psi Printed: 101212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/10/2006 06:00 - 07:30 1 .50 CLEAN P CLEAN attempt to clear restriction causing overpullldrag of DP. Small metal flakes, dope, and little pieces of rubber in returns. 07:30 - 14:00 6.50 CLEAN P CLEAN POH from 7713'. Unable to pull without oyerpull when not pumping or rotating. POOH puming 4 BPM, rotating 50 RPM. Pulling slow, steady, and smoothly with no overpull. 14:00 - 15:00 1.00 CLEAN P CLEAN BHA @ 3500'. Circulate 20 Bbls of Hi-Vis sweep @ 10 BPM, 800 PSI as rotate and reciprocate pipe. circulate surface to surface. Returns of small metal flakes, pipe dope, and occasional very small rubber particles. Attempt to POOH with out pumping, unsuccessful as BHA sticking. 15:00 - 18:00 3.00 CLEAN P CLEAN Continue POOH rotating the BHA @ 55 RPM, pumping 4 BPM, and pulling slowly and steadily with no overpull. 18:00 - 22:00 4.00 CLEAN P CLEAN Break and UD BHA. Inspect Washshoe. Only damages is a partially missing tooth. Washshoe is not worn. Wash pipe is in good condition. Some abrasions but nothing major. Pulled a ruler sized metal piece from wash pipe. 22:00 - 00:00 2.00 CLEAN P CLEAN M/U and RIH wI BHA #15. 9/11/2006 00:00 - 01 :30 1.50 CLEAN P CLEAN Service Top Drive. CIO Saver Sub. Empty Trip Tank. Repair Crown light. PJSM. 01 :00 - 05:00 4.00 CLEAN P CLEAN RIH wI Overshot and Grapple on 3-1/2" Tubing and DCs to 7700' MD. 05:00 - 06:00 1.00 CLEAN P CLEAN Circulate High Vis Sweep @ 10 BPM and 1650 psi. 06:00 - 08:00 2.00 CLEAN P CLEAN RIH wI Overshot and Grapple, 8 1/2" washpipe, 3 ea boot baskets, bumper sub, jars, on 3-1/2" Tubing and DCs. 08:00 - 10:00 2.00 CLEAN P CLEAN RIH to 10915', PU wt of 175K, SO wt of 130K. Pump Hi-Vis sweep @ 10 BPM, 1800 psi while rotating and reciprocating the pipe from 10870' - 10930'. Pump sweep surface to surface. Circulate out small gas bubble. No noticeable amount of cuttings or materials in returns wI sweep. 10:00 - 11 :00 1.00 CLEAN P CLEAN RIH and tag fish @ 10938'. PU wI 50K overpull, trip jars and pull uphole wI slight drag. Repeat setting 30K weight on fish, overpull wI 50K, and pull free wI out jars. Repeat and POOH to 10880'. Pump down DP @ 1 BPM, 80 psi. No indication of having packer. Suspect latched onto milled seal mandrel. 11 :00 - 15:30 4.50 CLEAN P CLEAN POOH filling wI double DP displacement every 5 stands, keeping trip sheet to monitor losses. Pulling clean off bottom. Lossses to formation of 3 Bbls/Hr. No problems POOH, hole clean. 15:30 - 16:30 1.00 CLEAN P CLEAN At surface wI BHA. Inspect BHA and 6 3/4" spiral grapple missing from overshot. Grapple control still in overshot but grapple missing. Empty boot baskets, recover -2 gals of metal-rubber cuttings from lowermost basket. 16:30 - 17:30 1.00 CLEAN P CLEAN Reconfigure BHA. Lay down 2 boot baskets, MU 6 5/8" spiral grapple and control in new overshot wI cut lip guide. 17:30 - 19:30 2.00 CLEAN P CLEAN RIH wI BHA on 8 ea 6" DC's, 1 stand of 3 1/2" DP. Secure well and slip and cut Drill Line. 19:30 - 00:00 4.50 CLEAN P CLEAN RIH wI BHA #16. 9/12/2006 00:00 - 01 :00 1.00 FISH DECOMP Tag fish @ 10938'. Pump 1 BPM @ 60 PSI, PU weight of 175K #'s, SO of 135K #'s. Set 15K #'s on fish. Pull25K #'s overpull and trip jars, then pull to 50K over. Repeat 6 times. Pull 35K #'s overpull and trip jars, then pull 60K over. Repeat 6 times. Pull 50K #'s overpull and trip jars. Pull 75K #'s over and pull free. Fluid drop 100' in wellbore. RIH tag @ 10938', Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/12/2006 00:00 - 01 :00 1.00 FISH DECOMP POOH wI 5K #'s weight dragging. Pump 1 BPM 60 PSI. Shut down pumping and POOH. 01 :00 - 06:30 5.50 FISH DECOMP Continue POOH wI BHA # 16. Losses to formation of 15 Bbls/Hr. 06:30 - 09:30 3.00 FISH DECOMP At surface wI BHA. No fish in OS and 6 5/8" spiral grapple missing. Grapple control still in oyershot. No material in boot basket. Break out and lay down oyershot. PUMU 15' of additional 8 1/8" WP wI 8 1/8" OD x 7" ID bumshoe. MU additonal2 boot baskets. RIH wI BHA # 17 on 6" DC's and 3 1/2" DP to clean around top of fish. 09:30 - 15:00 5.50 FISH DECOMP RIH wI BHA # 17. 15:00 - 17:00 2.00 FISH DECOMP Tag fish @ 10934'. Establish milling parameters of 6 BPM, 300 PSI, 4100 ftllbs torque @ 60 RPM. Begin milling. With 500 Bbls circulated, gas bubble to surface, POH above fish and circulate out gas then resume milling. Vary pump rate, RPM. No WOB but stalling with torque. 17:00 - 00:00 7.00 FISH DECOMP Mill from 10936' to 10943'. Varying pump rate from 4 BPM to 10 BPM. WOB - 3K-5K but stalling with torque. Pumped 20 Bbl. sweep around while continuing to mill. Stopped milling and spudded mill onto TOF. Pushed mill shoe down -2'. Continue milling. Mill depth @ 10944' at OO:OO-hrs. Bled OA from 200 psi to 0 psi. 9/13/2006 00:00 - 01 :30 1.50 FISH P DECOMP Mill from 10944' to 10955' while circulating @ 10.0 BPM at -2100 psi. Unable to mill deeper as it appears that fish is spinning on liner top. 01:30 - 03:15 1.75 FISH P DECOMP Pump 20 Bbl. hi-vis sweep @ 10 BPM @ 2100 psi. taking sweep returns to cuttings tank. 03:15 - 04:00 0.75 FISH P DECOMP POH wI BHA #17. Fluid losses = 15 BPH. 04:00 - 05:00 1.00 FISH P DECOMP PJSM. Slip and cut drilling line. 05:00 - 09:00 4.00 FISH P DECOMP Continue POH wI BHA #17. 09:00 - 12:00 3.00 FISH P DECOMP Break out and lay down milling BHA # 17. Burn shoe worn to a nub. Most if not all of cut-rite on mill face gone, worn smooth. Big chunks of grapple in all 3 boot baskets, with - 4 gal of metal-rubber cuttings. MU double bowl oyershot with 6 3/4" spiral grapple on bottom, wI 6 5/8" grapple +1- 4 feet above. 31' of 8 1/8" wash pipe wI drive sub boot basket. OAL to swallow fish of 48'. RIH wI BS, Jars and 8 ea 6" DC's. OAL of BHA 320.53' 12:00 - 12:30 0.50 FISH P DECOMP Fluid losses to formation while MU BHA of 20 Bls/Hr. RIH wI double OS BHA #18. 12:30 - 13:30 1.00 FISH P DECOMP DC's buried, service Top Drive, Block Shieves, Crown. 13:30 - 17:30 4.00 FISH P DECOMP RIH wI BHA # 18 to fish packer from TOL. Losses @ - 15 Bbls/Hr. Notified Chuck Scheve wI AOGCC @ 17:00 of upcoming BOPE test. 17:30 - 19:00 1.50 FISH P DECOMP BHA @ 10914', establish fishing parameters of 185K PU wt, 125K SO wt, 3 BPM, 260 PSI. RIH tag and engage fish @ 10946'. Work pipe, jarring 25K and 35K overpull, and swallowing fish to 10954'. Pull to 65K overpull and fish come free wI no jar action. Work pipe and RBIH to 10958', PU to 10875' wI 8K #'s additional weight. 19:00 - 21:30 2.50 FISH P DECOMP Drop ball to open circ sub and circulate bottoms up to circulate out any gas. Circ. sub sheared at 2100 psi. CBU pumping @ 6-7 BPM, 1000-1100 PSI. Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/13/2006 21 :30 - 00:00 2.50 FISH P DECOMP POH wlfish and BHA #18. Pulling slowly to prevent swabbing and maintaining 100% hole fill through trip tank. Fluid losses to well = 18-20 BPH. 9/14/2006 00:00 - 03:00 3.00 FISH P DECOMP Continue POH w/fish. OOH @ 0200-hrs. UD jars, bumper sub and boot basket. 03:00 - 05:00 2.00 FISH P DECOMP PJSM - Rig up HES hot tap equipment. Drill hole 5' above "X" nipple in tailpipe. Small amount of pressure relieved. Rig down hot tap equipment. 05:00 - 07:30 2.50 FISH P DECOMP UD fish and BHA#18. Swallowed fish wi double overshot to center of the packer where the rubbers had been. PJSM, sniff for hot work permit, break out and cut apart BHA. TP assembly below packer had IBP across perf holes in tail pipe above XN nipple wI stuck TTP. 07:30 - 09:00 1.50 FISH P DECOMP Clean and clear rig floor and pipe shed. PU "Swizzle Stick" and wash/clean the stack. 09:00 - 13:30 4.50 CLEAN P DECOMP PUMU BHA # 19. 81/2" RCJB, 2 ea 7" Boot Baskets, 95/8" casing scraper, string magnet, 6 1/4" Bowen BS and Jars, on 8 ea 6" spiral DC, 3 1/2" pump out sub on 3 1/2" DP. RIH wI ball on seat of RCJB. 13:30 - 16:00 2.50 CLEAN P DECOMP Work scraper reciprocating pipe from 10700' to Tag TOL @ 10966' pumping 3 BPM, 260 psi. PUH to 10955' and pump 20 Bbl Hi-Vis sweep @ 8 BPM, 2000 psi, surface to surface. Circulate out small gas bubble. 16:00 - 20:00 4.00 CLEAN P DECOMP POOH wI double DP displacement. Losses to formation of - 20 Bbls/Hr. 20:00 - 20:15 0.25 CLEAN P DECOMP PJSM - UD BHA #19. 20:15 - 23:30 3.25 CLEAN P DECOMP UD BHA #19. Inspect RCJB, Boot Baskets and String Magnet. No debris recovered in RCJB or Boot Baskets. String Magnet retrieyed -1/2 pint of fine iron particles. 23:30 - 00:00 0.50 CLEAN P DECOMP PJSM. PUMU BHA #20 - 6-1/8" RCJB, 2 x 4-3/4" Boot Baskets, BS, Jars and POS. Notified AOOCC - of BOPE test at -0300-hrs. 9/15/2006. Chuck Sheve waiyed witness test. 9/15/2006 00:00 - 00:15 0.25 CLEAN P DECOMP PUMU BHA #20 - 6-1/8" RCJB, 2 x 4-3/4" Boot Baskets, BS, Jars and POS. 00:15 - 02:00 1.75 CLEAN P DECOMP RIH wI BHA #20 on DP to depth of 4300'. PUMU 9-5/8" RTTS wI storm yalve and set -78' below BOPE. 02:00 - 02:30 0.50 BOPSU DECOMP Pull wear ring. Set test plug. Run in 8 lockdowns. 02:30 - 04:45 2.25 BOPSU DECOMP Commence BOPE testing. Unable to get test plug to seat and hold pressure. Pull and inspect test plug. Packoff element has vertical split approx. 3/4 through element. 04:45 - 05:30 0.75 BOPSU WAIT DECOMP Order replacement test plug from Tool Services and wait for arrival. 05:30 - 06:00 0.50 BOPSU DECOMP PU and set new test plug. 06:00 - 12:00 6.00 BOPSU DECOMP Test BOPE wi 3 1/2" and 4 1/2" test joints. Pull test plug, install wear ring. Both IA valves leaking. Troubleshoot and grease IA valves. Close blind rams and test to 1500 psi, OK. 12:00 - 14:30 2.50 CLEAN P DECOMP PUMU HES retrieving stinger for storm valve. RIH and engage RTTS-storm valye. Unseat RTTS, lose 45 Bbls fluid, gas bubbling @ surface. MU circulating hose, pump 3 BPM, 400 psi and bullhead 60 Bbls. Open choke and circulate 100 Bbls. Flow check well, losing fluid gradually and no signs of gas @ surface. Break out and lay down HES tools. 14:30 - 17:30 3.00 CLEAN P DECOMP RIH wi 6 1/8" RCJB BHA on 3 1/2" DP. PU singles 1 x 1 from Printed: 10/212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/15/2006 14:30 - 17:30 3.00 CLEAN P DECOMP 10640'. 17:30 - 20:30 3.00 CLEAN P DECOMP Tag fill @ 11840'. (47' of fill). PU and circulate @ 6 BPM, 1400 psi. Pump 25 Bbl. sweep surface to surface and recover sweep to cuttings tank. No cuttings or other debris recovered in sweep. Fluid losses to formation during circulation = 53 Bbls. 20:30 - 22:00 1.50 CLEAN P DECOMP POH w/BHA #20. At liner top @ 10960' overpulled PUW by 24K. Screwed in with TD and rotated @ 60 RPM while pumping @ 6 BPM and working pipe. SD rotation and pulled past liner top. Pulling free. 22:00 - 00:00 2.00 CLEAN P DECOMP POH w/BHA #20. 9/16/2006 00:00 - 02:30 2.50 CLEAN P DECOMP POH w/BHA #20. Maintaining 100% hole fill with continuous feed from trip tank. 02:30 - 03:30 1.00 CLEAN P DECOMP B/O UD BHA #20. Approximately 1/2 gallon fine metal and cement cuttings and 3 pieces metal approx. 1" square by 3/8" thick recovered from boot baskets. Recovered one piece of metal from RCJB approx 1.5"L x 1 "W x 1/4" thick. Noted circular junk cut marks on jars in an area l' long. Mill indicated small amount of wear on outer circumference as well as bottom cutting surface. No visible drag marks present on major diameter of RCJB. 03:30 - 04:45 1.25 CLEAN P DECOMP PUMU BHA #21 . 6" Concave Junk Mill, 3 x 4-3/4" Boot Subs, 1 x 4-3/4" Bumper Sub, 1 x 4-3/4" Oil Jar, 1 x 4-3/4" Pump Out Sub and 12 x 4-3/4" DC's and 1 std. DP. 04:45 - 06:00 1.25 CLEAN P DECOMP Slip and cut drilling line, service rig. 06:00 - 08:30 2.50 CLEAN P DECOMP RIH wI BHA #21 for FCO. 08:30 - 09:30 1.00 CLEAN P DECOMP BHA @ 10900', establish PU of 180K and SO of 125K. RIH slowly and tag TOL @ 10966'. PU and rotate pipe slowly and RIH thru TOL. RIH to 11208' and hang up. SO of 20 K and 20K overpull. Rotate pipe slowly and try to free up BHA. Work repeatedly. Able to work free not rotating. Continue RIH slowly. 09:30 - 10:30 1.00 CLEAN P DECOMP Pull bushing to pull stripper rubber and discover rubber down in stack above annular preventer. Secure well, remove pitcher nipple and work stripper rubber out of stack. NU pitcher nipple, air boot etc., test. 70 Bbls losses to formation since midnight. (-8 Bbls/Hr) 10:30 - 13:30 3.00 CLEAN P DECOMP RIH and dry tag @ 11840', pump Hi-Vis sweeps and mill to 11900'. Also appears we are pushing something ahead of Mill. From 11900', pump 40 Bbls Hi-Vis sweep and reciprocate DP from 11800' - 11900' while displacing sweep wI seawater @ 10 BPM, 3300 psi DP pressure. 13:30 - 15:00 1.50 CLEAN P DECOMP POOH wI Junk Mill BHA from 11900'. Pull 20K overpull. POOH rotating @ 25 RPM. pumping 5 BPM, 640 psi. Occasionally attempt to POOH wI out rotating or pumping, and pulling 20K overpull. Backream out of 7" TOL @ 10968'. Acted like we had a piece of junk around our mill as pull up OOH and out of liner. Pull cleanly in 9 5/8" Csg. 15:00 - 18:45 3.75 CLEAN P DECOMP POOH standing back 31/2" DP in Derrick. Keeping hole full wI continuous pumping from trip tank. 18:45 - 19:00 0.25 CLEAN P DECOMP PJSM - UD DC's and milling assembly. 19:00 - 19:15 0.25 CLEAN P DECOMP Rig up floor to UD DC's and milling assembly. 19:15 - 20:15 1.00 CLEAN P DECOMP B/O UD 12 x 4-3/4" DC's and BHA #21 - Milling assembly. Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/16/2006 19:15 - 20:15 1.00 CLEAN P DECOMP Recovered approximately 2 gallons mill cuttings and metal chunks from Boot Baskets. 20:15 - 20:45 0.50 CLEAN P DECOMP Clear and clean rig floor. 20:45 - 21 :30 0.75 CASE P DECOMP PUMU Halco 9-5/8" RTTS packer to RIH and pressure test casing. 21 :30 - 00:00 2.50 CASE P DECOMP RIH/w/Halco 9-5/8" RTTS packer to 10950' on 3-1/2" DP. 9/17/2006 00:00 - 02:45 2.75 CASE P DECOMP RIH w/Halco 9-5/8" RTTS packer to 10950' on 3-1/2" DP. 02:45 - 06:00 3.25 EV AL P DECOMP Set packer @ 10940'. PIT casing. No test. Pumped 81 bbls. away @ 3-4 BPM and pressured up to 3500 psi. Leaked off to 1000 psi in 12 minutes. Bled off IA. Release packer and pulled uphole and set packer @ 10650'. Pressured up and injecting into leak @ 830 psi @ 1.0 BPM. Released packer and pulled uphole and set packer @ 9680'. Pressured up and injecting into leak @ 830 psi @ 1.0 BPM. 06:00 - 09:00 3.00 EV AL P DECOMP POOH to 8720', test csg, 1 BPM, 650 psi injection. POOH to 7750', test csg to 3500 psi - Good Test RIH to 8235', test csg, 1 BPM, 650 psi injection POOH to 7950', test csg to 3500 psi, Good Test RIH to 8045', test csg, 1 BPM, 650 psi injection POH to 8021', test csg to 3500 psi, Good test 09:00 - 09:30 0.50 EVAL P DECOMP RTTS set @ 8021'. Test 9 5/8" Csg to 3500 psi and chart for 30 minutes. Good Test. 09:30 - 10:00 0.50 EVAL P DECOMP RTTS set @ 8045', Injection test to confirm leak. 1 BPM 875 psi. Pump 15 Bbls injection test. Unseat RTTS, Flowcheck well. 10:00 - 12:00 2.00 EVAL P DECOMP POOH wI RTTS, keeping hole full wI continuous fill from trip tank. 12:00 - 13:00 1.00 EVAL C TIEB1 Discuss change of scope to casing repair w/ Chuck Scheve w/ AOGCC. He instructed that we need approval from town enginer Wynton Aubert to proceed. Called Wynton and left message for him to call to discuss situation. Continue POOH wI RTTS. 13:00 - 15:00 2.00 EVAL C TIEB1 Discussed change of scope w/ Wynton Aubert - AOGCC. He approved changes. Requested e-mail from BPX town engineer of necessary changes in scope be sent to him to add to package AOGCC has for this RWO. Continue POOH w/ RTTS 15:00 - 16:00 1.00 CASE C TIEB1 B/O UD RTTS. Clean and clear rig floor. PUMU HES 7" FasDril composite bridge plug with mechanical running tool on 31/2" DP. Pull Stripper rubber from inside of pitcher nipple above BOPE. 16:00 - 21 :30 5.50 CASE C TIEB1 RIH wI 7" HES FasDril composite bridge plug to TOL @ 10966'. Encountered no resistance at liner top when running plug into liner. Establish setting parameters - PUW = 185K, SOW = 110K. RIH through TOL to 11010'. Pull up to 11000 and set FasDril plug. Apply 30 clockwise turns in DP. Overpull 15K to establish that plug slips are set. Oyerpull 30K and shear out of plug. SO to 15K downweight on plug. Top of plug @ 11000'. 21 :30 - 00:00 2.50 CASE C TIEB1 Pull DP above liner top wIno drag. POH w/DP and FasDril plug mechanical setting tool. 9/18/2006 00:00 - 01 :30 1.50 CASE C TIEB1 POH wlDP and FasDril plug mechanical setting tool. UD setting tool. Printed: 10/212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: Rig Release: Rig Number: 6/28/2006 9/26/2006 3 Spud Date: 8/12/1983 End: 9/18/2006 01 :30 - 04:30 3.00 CASE C TIEB1 Load pipe shed with 7" liner and liner hanger assembly. Rig up floor to run 7" liner. 04:30 - 04:45 0.25 CASE C TIEB1 PJSM - Running casing. 04:45 - 06:00 1.25 CASE C TIEB1 PUMU 7" liner BHA. RIH w/ 7" liner assembly. 06:00 - 10:00 4.00 CASE C TIEB1 RIH wI 7" shoe joint. (7" float shoe wI insert and ball on 20' joint. 4 ea 1" OD holes drilled 6' above float shoe, 8 1/4" straight vane centralizer tack welded above float shoe). 7" float collar, 1 full joint 7", landing collar 7", and 100 joints of 7",26#, L-80 BTC-MOD. 7 1/8" ID x 8 1/4" OD x 8" Length free floating straight vane centralizers run on every other joint above the shoe track. Fill liner wI seawater every 5 joints. 10:00 - 10:30 0.50 CASE C TIEB1 Secure well with safety valve in 7" Csg. Load centralizers to rig floor. Wait on 70 additional joints of 7",26# Csg. 10:30 - 13:30 3.00 CASE C TIEB1 Load 70 joints of 7",26# Csg in pipe shed. Strap and drift. 13:30 - 16:00 2.50 CASE C TIEB1 RIH wI 69 joints of 7", 26# Csg from pipe shed. Straight blade centralizer on every other joint, filling every 5 joints. Total of 169 joints of 7" scab liner. 16:00 - 16:30 0.50 CASE C TIEB1 PUMU Baker Liner Hanger and LinerTop Pkr wI 6' Tieback. BHA OAL -7013' 16:30 - 17:00 0.50 CASE C TIEB1 Work on top drive. RIH wI Liner BHA on 1 stand of 3 1/2" DP. MU circulation head. Circulate wlrig @ 5 BPM, 2100 psi, 20 Bbls total. 17:00 - 20:00 3.00 CASE C TIEB1 RIH wn" Liner on 3-1/2" DP. 20:00 - 20:30 0.50 CASE C TIEB1 Soft tag existing 7" liner top. PUW = 260K, SOW = 130K. Circulate 25 Bbls. @ 5.0 BPM @ 440 psi. 20:30 - 21 :00 0.50 CASE C TIEB1 PUMU Bakercement head and rig up cement lines to cement head. 21:00 - 21:15 0.25 CASE C TIEB1 Tag top of existing liner at 10968' w/2K downweight. Hanging weight = 258K. P/U liner to neutral. Line up cemeting manifold lines to pump cement and pressure test. 21 :15 - 21 :30 0.25 CASE C TIEB1 PJSM - Cement job. All rig crew, Schlumberger, VECO, MI and Baker personnel. 21 :30 - 22:00 0.50 CASE C TIEB1 PfT Schlumberger and rig lines to 4500 psi. OK. 22:00 - 22:45 0.75 CASE C TIEB1 Schlumberger pump 10 Bbls. FW to prime up pump and load lines. Batch mix 15.8#/gal. cement and start pumping @ 4.0 BPM @ 420 psi. Cement slurry density yarying from 15.8#/gal down to 13.04#/gal. Unable to maintain consistent slurry density at or close to 15.8#/gal. Shut job down w/59 Bbls. cement slurry of varying density away and circulate out to cuttings tank. 22:45 - 00:00 1.25 CASE C TIEB1 Circulate cement out to cuttings tank 9 BPM @ 1050 psi to 2000 psi. Wash up and RD Schlumberger cementers. 9/19/2006 00:00 - 00:30 0.50 CASE C TIEB1 Circulate cement out to cuttings tank 9 BPM @ 1050 psi to 2000 psi. 00:30 - 06:30 6.00 CASE X WAIT TIEB1 Wait on Schlumberger to load out bulk truck and return to well to rig up and pump liner cement job. Circulating @ 5.0 BPM @ 480 psi. while waiting. 06:30 - 08:00 1.50 CASE X TIEB1 MIRU SLB cement crew. PJSM. 10 hours NPT time due to SLB cement problems. 08:00 - 09:30 1.50 CASE C TIEB1 SLB pump 5 Bbl H20, Test cmt line to 3000 psi. pump 5 Bbl H20, followed by 190 Bbls of Class G cmt mixed @ 14.5 #/gal - 15.9 #/gal for first 50 Bbls. Problems with bulk delivery system. 1 ea 3 minute shutdown. Rate reduced to mixing and pumping Ponted: 10/212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/19/2006 08:00 - 09:30 1.50 CASE C TIEB1 @ 1.1 BPM. When SLB started having problems, close annular, take retums thru choke and trap 150 psi back pressure to keep cement in place. Last 140 Bls of cement mixed and pumped @ 3 - 5 BPM, density varying from 14.5 to 16.0 #/gal. 09:30 - 10:30 1.00 CASE C TIEB1 Shut down pumping wI SLB, drop DP dart, pump 10 Bbls FW. Swap to displace wI Rig using seawater @ 6 BPM, trapping 150 psi back pressure. When circulating pressure reached 600 psi on DP, open choke and displace cement @ 6 BPM, pressure increasing as lifting cement to 2100 psi. With 5933 strokes away (100 strokes early), bump plug and pressure to 2500 psi. Open bag. 10:30 - 11 :00 0.50 CASE C TIEB1 Slack off and put 15K down. pressure DP to 4200 psi to set hanger and packer. Bleed DP to 0 psi. Rotate 15 turns to release liner hanger setting tool. Pressure DP to 1000 psi, unsting from TOL, PU 3 ft and circulate 10 Bbls. 11 :00 - 11 :30 0.50 CASE C TIEB1 Reverse circulate @ 5 BPM, 855 psi. +1- 15 Bbls contaminated cement returns. 11 :30 - 12:00 0.50 CASE C TIEB1 BO/LD Baker TD plug head, clean and clear floor. 12:00 - 16:00 4.00 CASE C TIEB1 POOH wI liner hanger setting tool. BOLD liner hanger setting BHA. 16:00 - 17:00 1.00 CASE C TIEB1 PUMU 6 1/8" mill BHA w/12 4 3/4" DC's. RIH on 1 stand of DP. 17:00 - 19:30 2.50 CASE C TIEB1 Slip and cut Drill Line. Service Top Drive. 19:30 - 20:30 1.00 CASE C TIEB1 RIH wI milling BHA on 3 1/2" DP out of Derrick. RIH to 3900' and break circulation @ 4.0 BPM. Enter liner top @ 3979' and set BHA @ 3989'. CBU @ 4.0 BPM @ 300 psi. 20:30 - 00:00 3.50 CASE C TIEB1 RIH to 10750'. 9/20/2006 00:00 - 00:45 0.75 CASE C TIEB1 PIT 7" scab Liner to 3500 psi. and chart for 15 min. Good test. 00:45 - 02:00 1.25 DRILL C TIEB1 RIH wlmilling BHA to 10750'. establish milling parameters, PUW = 190K, SOW = 11 OK. RIH and tag TOC @ 10777'. Cement consistency is soft. Break circulation @ 4.0 BPM @ 600psi. RPM = 65, free torque = 7000 ftllbs. Drill to 10866'. WOB = 4-5K. Torque = 8K. Increase circualtion rate to 6-7 BPM @ 1350 psi. 02:00 - 03:00 1.00 DRILL C TIEB1 RPM = 80, WOB = 4-5K, pump = 7 BPM @ TD stalling out - torque exceeding 10K. Stop drilling. Circulate 30 Bbl. Hi-Vis sweep and work Pipe while circ. out sweep. 03:00 - 03:30 0.50 DRILL C TIEB1 Resume drilling cement @ 10866'. Pump = 7 BPM @ 1650 psi. RPM = 80, Torque = 9500-10000 ft.llbs., WOB = 4-5K. Top drive failed @ 0330-hrs. Mill depth - 10870'. 03:30 - 05:00 1.50 DRILL X TIEB1 Repair top drive. Circulating @ 7.0 BPM @ 1410 psi. Working pipe from 10842' to 10870'. 05:00 - 10:00 5.00 DRILL C TIEB1 Resume drilling cement. Pump Rate -7.0 BPM @ 1600 psi. WOB = 4-5K, Torque - 9-10K ft.llbs., RPM - 66. Drill to 10895'. 10:00 - 11 :00 1.00 DRILL C TIEB1 Discuss with town to change-out Drilling Fluid. Wait on dirty Vacs to clean out Pits and Cuttings Tank. 11 :00 - 14:00 3.00 DRILL C TIEB1 Circulate while cleaning Pits and Cuttings Tank. Wait on new Drilling Fluid: 2%-KCI mixed with Biozan. LoTorq lubrication wil be added after the new fluid has been circulated throughout the wellbore. Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/20/2006 14:00 - 16:00 2.00 DRILL C TIEB1 Displace drilling fluid from well bore and replace with new drilling fluid. 16:00 - 18:00 2.00 DRILL C TIEB1 Resume Milling Shoe Track @ 10895'. Circulate 40-Bbl MI Super Sweep and get nothing back but the Super Sweep material and very little small fines entrained in the Super Sweep. 18:00 - 23:45 5.75 DRILL TIEB1 POH SIB DP. BO/LD 6-1/8" Mill and 7" Scraper. 23:45 - 00:00 0.25 BOPSU TIEB1 Prep for weekly BOPE test. 9/21/2006 00:00 - 02:00 2.00 BOPSU TIEB1 Rig up pressure test equipment for weekly BOPE test per AOGCC requirements. John Crisp - AOGCC on hand to witness test. PUMU 4-1/2" BTC test joint to test plug. Set test plug, RILDS and fill BOP stack and test joint with water. 02:00 - 06:30 4.50 BOPSU C TIEB1 Commence testing. Unable to obtain low pressure test on 2-7/8" x 5-1/2" variable bore rams. BOLDS, POH UD test joint and plug. Call out grease crew to grease choke manifold and manual and HCR valves in cellar. PUMU 3-1/2" DP test joint to Test Plug. Set test plug and back out and lay down 3-1/2" DP test jQint. Close blind rams. Pressure test blind rams and choke manifold. Low pressure test to 250 psi successful. Increasing pressure towards target of 3500 psi and at 3100 psi a sudden pressure loss to 1300 psi occurred. Screwed lockdown screws in to try to ascertain what happened. Were able to makeup lockdown screws past their normal depth. BOLDS and pull test plug with 3-1/2" DP test joint. Found that test plug was improperly seated and top ring on test plug had been displaced and all 12 top ring hold-down bolts sheared off when test plug fully seated. Recovered 11 of the sheared bolts to rig floor. Left one top ring hold-down bolt in hole. The 4-1/2" IF pin on bottom of test plug also cracked more than 3/4 around circumference of pin. Called Tool Service for another test plug and also called Cameron wellhead specialist to location for consult. 06:30 - 09:30 3.00 BOPSU C TIEB1 Drain BOP stack. Close Blind Rams and open VBR door and find seal on top of VBR block had severe cut. Replaced upper seal. Removed all LDS and did not find any damage to the LDSs. Opened Lower Ram Door and found the missing Test Plug Seal Backup Ring bolt. P/U BOP Stack wash tool and wash all cement and debris out of Stack. 09:30 - 11 :00 1.50 BOPSU C TIEB1 P/U replacement Test Plug and M/U on DP and RIH to set in Tubing Head. Wouldn't set properly, so POH to examine Test Plug, but find no indication of damage. RIH with Test Plug; pull 2-LDSs and watch Test Plug being landed in Tubing Head with no problem. RILDS to resume BOP testing. 11 :00 - 15:30 4.50 BOPSU C TIEB1 Resume BOP tests, 250-psi low and 3,500-psi high. All tests eventually passed, and observed by John Crisp, AOGCC and M. Rooney. Replace studs in 4" x 3" adaptor spool that connects the double annulus valves to the 13-5/8" Spacer Spool. Load Mud Motor with Stabilizer into Pipe Shed, and tally same for new ement cleanout BHA. While performing BOPE test, swap out and viscosity brine system to 70-90,000 LSRV. 15:30 - 16:00 0.50 BOPSU C TIEB1 Rig down BOP test equipment, clear and clean Rig Floor. 16:00 - 17:00 1.00 CASE C TIEB1 PJSM. M/U cement cleanout BHA: 6-1/8" Baker Junk Mill, SIS Mud Motor, lubricated Bumper Sub, Jars and 12 x 4-314" DC's. Printed: 10/2/2006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/21/2006 17:00 - 18:00 1.00 CASE X RREP TIEB1 Top Drive would not rotate to reposition elevators for RIH with DCs and DP from the Derrick. Troubleshoot and repair. 18:00 - 18:30 0.50 CASE C TIEB1 RIH wlBHA and 1 std. DP. Break circulation to test mud motor. O.K. 18:30-21:30 3.00 CASE C TIEB1 RIH wlcement cleanout BHA on DP from Derrick to TOC @ 10910' 21 :30 - 00:00 2.50 DRILL C TIEB1 Establish milling parameters - PUW = 220K, SOW = 100K. Break circulation at 4.0 BPM and increase pump rate to 6.0 BPM @ 1550 psi. after returns were establised. Commence milling cement @ 10910'. Mill to 10932' in 1.5 hrs. Pump super sweep after reaching 10930'. Continue milling 1 ft. to 10933' in one hour. Super sweep recovered to surface and moderate amount of metal cuttings continuously being recovered. Stop milling and call engineer Dave Reem for consult. Agreed plan is to POH and UD 6-1/8" junk mill and RBIH wlmedium tooth rock bit. 9/22/2006 00:00 - 00:45 0.75 DRILL C TIEB1 Circulate and condition hole @ 6.0 BPM @ 1550 psi. 00:45 - 09:00 8.25 DRILL C TIEB1 POH with 6-1/8" cement milling BHA standing DP in derrick. DP pulling wet. Drop Ball & Rod @ 0430-hrs and let fall while POH. Pull 5 stands DP and rig up circulating hose. Shear Pump Out Sub @ 2100 psi. Rig down circulating hose. POH with DP and DCs and break-off Baker 6-1/8", 6-bladed mill. 09:00 - 13:30 4.50 DRILL C TIEB1 P/U 6-1/8" Roller Cone Bit and install in Bit Breaker Box and M/U to Mud Motor. RIH on DCs from Derrick. Redress Pump-out Sub. Continue RIH on DP from Derrick to resume drilling out Shoe Track TOC @ 10,932'. 13:30 - 16:00 2.50 DRILL C TIEB1 Tag cement @ 10,934'. Parameters: P/U wt 215K, S/O wt 100K, 8-10K WOB, 6-BPM @ 1500-psi. Make slow headway 1500-hrs when bit gets through Float Collar @ +/- 10, 943'. P/U stand #110 and continue drilling cement. Break through Float shoe at 1530-hrs at 10,966'. Continue slowly (stopping @ 1600-hrs) to 10,980' losing no weight. 16:00 - 18:00 2.00 DRILL C TIEB1 Mix and circulate 40-Bbl MI Super Sweep and get -1 to 1-1/2 Bbls of cement and some chunks of rubber, phenolic, and plastic across Shakers. Decide to mix and circulate additional 40-Bbl MI Super Sweep. 18:00 - 22:00 4.00 DRILL C TIEB1 Wait on 4-truckloads of seawater to displace the KCl/Biozan drilling fluid. Swap well bore and pits to seawater system from viscosified brine system. 0900-hrs: Spilled 2 Bbls. viscosified brine out of Tiger Tank into bermed secondary containment. Cleaned up spill and disposed of spilled fluids. Notified all required individuals and organizations. 22:00 - 00:00 2.00 DRILL C TIEB1 RIH to tag and drill out EZSV plug @ 11,000'. No tag @ 11,000'. RIH w/DP and tag EZSV plug @ 11,843'. Wait for crew change to commence drilling plug. 9/23/2006 00:00 - 02:30 2.50 DRILL C TIEB1 Break circulation @ 6.0 BPM @ 1350 psi. Establish drilling parameters - PUW = 215K, SOW = 100K. Begin drilling and pushing plug remnants into rathole. Bottom last tagged @ 11,900'. Drilled out and pushed plug to 11,901' DPM. POH wlbit to 11,850' while circulating. SID circulation and monitor well for fluid losses. No apparent fluid losses at present. Pipe dragging to PUW - 275K while POH @ 11,850 to 11, 750'. Screw in TD, rotate and circulate while POH. Pipe pulling free Printed: 10/212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 9/23/2006 00:00 - 02:30 2.50 DRILL C TIEB1 from 11,750'. 02:30 - 06:00 3.50 CLEAN P DECOMP POH LDDP 1 x 1 through pipe shed. Maintaining hole fill with DP displacement from Trip Tank. SID POH to unload Pipe Shed and monitor well for fluid losses. Fluid losses = 5 BPH @ 0430-hrs. Drop ball & rod and shear out Pump Out Sub. 06:00 - 08:15 2.25 CLEAN P DECOMP Continue POH. While unloading pipe, monitor losses and find 3.5 BPH @ 0700-hrs. 08:15 - 09:15 1.00 CLEAN P DECOMP Hold Safety Moment in Doghouse for Night Tour Crew to discuss current operations, use of PJSMs and Drills and Cuttings Tank cleanout. 09:15 - 15:30 6.25 CLEAN P DECOMP Continue POH and UD DP and DCs through Pipe Shed. Break-out and UD Baker Jars and Bumper Sub, Sperry Sun Mud Motor, Baker Junk Basket, and 6-1/8" Roller Cone Bit. Empty Junk Basket and find several small pieces of steel, one of which appeared to be a 1" x 3" x 1/4" thick piece of a threaded pin connection that had been flattened by milling, drilling, or spearing operations. 15:30 - 16:00 0.50 CLEAN P DECOMP Hold Safety Moment in Doghouse for Day Crew to discuss current operations. PJSMs and Drills were discussed in Pre-Tour meeting. 16:00 - 17:00 1.00 BOPSU DECOMP Pull Wear Ring. P/U BOP Stack washing tool and wash stack. 17:00 - 19:15 2.25 RUNCO RUNCMP Clear and Clean Rig Floor. Change out Elevators. P/U Doyon Casing Crew tubing handling equipment. 19:15 - 19:30 RUNCMP PJSM - Review chrome Tubing running procedure and identify hazards associated with employing torque turn and compensator equipment. 19:30 - 00:00 RUNCMP RIH w/4-1/2", 12.6# 13CR Tubing completion per running order and using torque turn and compensator equipment with oversight from Baker Completions expert. Making up connections to optimum torque of 4440 ft./lbs per direction from Doyon Casing crew. Baker-Lok'd all Tubing connections below Packer, including removing Tubing couplings from 2 full Joints below Packer and applying Baker-Lok to those connections as well. 9/24/2006 00:00 - 00:45 0.75 RUNCO RUNCMP Extended PJSM wlall crew to discuss current operations and reyiew safety drill procedures and fluid transfer procedures. 00:45 - 14:00 13.25 RUNCO RUNCMP Resume RIH w/4-1/2", 12.6# 13CR Tubing completion per running order and using torque turn and compensator equipment with oversight from Baker Completions expert. Making up connections to optimum torque of 4440 ft.llbs per direction from Doyon Casing crew. 54 Joints RIH @ tour change. 105 Joints RIH @ 0400-hrs. Avg. Joints/hr. = 15. Fluid losses = 3-4 Bbls.lhr. 169-jts plus all GLMs RIH @ 0830-hrs. Losses at 0900-hrs, 4-BPH with displacement while RIH. 14:00 - 15:00 RUNCMP P/U XO and Tubing Hanger and M/U to Landing Joint. M/U to string and RIH to Tubing Head Bowl. P/U wt 170K, S/O wt 95K. RILDS. RID Doyon Casing Crew equipment. C&C rig floor. 15:00 - 20:00 WAIT RUNCMP Wait on 4-truckloads of hot Seawater (2-trucks with Corrosion Inhibitor) to displace wellbore fluids, set packer and test tubing and IA. One truckload of 290 Bbls. 130F seawatewr arrived. Switched rig off onboard power @ 2000-hrs. 20:00 - 22:00 RUNCMP PJSM - Reverse circulate 290 bbls. seawater @ 3.0 BPM @ Printed: 10/212006 10:55:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-01 K-01 WORKOVER NORDIC CALISTA NORDIC Start: 6/28/2006 Rig Release: 9/26/2006 Rig Number: 3 Spud Date: 8/12/1983 End: 250 psi into well bore taking returns to rig pits and cuttings box. Still waiting on two vac trucks with 580 Bbls. corrosion inhibited seawater. 22:00 - 00:00 WAIT RUNCMP Continue waiting on 2 x 290 Bbl. vac trucks to arrive. 9/25/2006 00:00 - 00:30 RUNCMP PJSM - Review ConQor 303A corrosion inhibitor MSDS wlcrew and discuss reverse circulation job. 00:30 - 01 :00 RUNCMP PIT rig lines to 3500 psi in preparation to PIT IA and Tubing. 01 :00 - 01 :45 RREP RUNCMP Rig electrical problem. Crew troubleshoot and repair. 01 :45 - 02:00 RUNCMP PIT rig lines to 3500 psi in preparation to PIT IA and Tubing. 02:00 - 05:30 RUNCMP Reverse circulate 580 Bbls. corrosion inhibited 120F seawater into IA @ 3.0 BPM @ 270 psi taking returns to rig pits. 05:30 - 07:30 RUNCMP Drop ball & rod and allow to fall for 30 minutes. Ball would not go on seat; suspect it's hanging up in a GLM. Call Slickline for a unit and Tool Services for a Shooting Flange. 07:30 - 11 :00 RUNCMP Close Blind Rams, check pressure in tubing and IA--O-psi. NID Riser and Flowline and Riser Extension. N/U Shooting Flange. Spot SLB slickline unit. 11 :00 - 13:00 RUNCMP PJSM. P/U and M/U 2-ea by 5-foot long SLB 7" Otis extensions and M/U to the Shooting Flange. P/U SLB BOP and Line Wiper and M/U to extensions. Lift off Line Wiper, run slick line through stripper and M/U 3" Bell Guide with Blind Box, Jars, and Roller Stem. Run string into well, M/U Line Wiper to BOP and pressure test SLB "stack" to 1,OOO-psi. 13:00 - 14:00 1.00 RUNCO RUNCMP RIH with Bell Guide, slow down for each of the 4-GLMs, and do not see stack-out until just above the X-nipple at 10,845'. Pull up 50' and start pump to see if Ball and Rod are onseat. Pressure starts building as soon as Stroke Counter registers first stroke. Builds to 390-psi within 5-strokes (1-Bbl = 20.1-Strokes). Shut down and bleed off pressure. 14:00 - 15:30 RUNCMP POH with slickline, close Blind Rams. Hold PJSM to discuss breaking out and laying down the SLB equipment. Break out and lay down SLB equipment. 15:30 - 16:30 1.00 RUNCMP NID Shooting Flange. 16:30 - 18:00 1.50 RUNCMP Nipple up Riser, Flowline, Riser Extension and Air Boot. Crew change PJSM for returning Day Crew. 18:00 - 22:00 RUNCMP Set Packer. PIT and chart record Tubing and IA to 3,500-psi for 30-minutes each. Shear DCR-1 valve. 22:00 - 23:30 1.50 RUNCMP Cameron representative dry rod set and PIT TWC for 10 charted minutes from below and above to 1000 psi. 23:30 - 00:00 0.50 RUNCO RUNCMP Rig down pressure test equipment and clear and clean rig floor. 9/26/2006 00:00 - 04:00 4.00 BOPSU P RUNCMP Nipple down BOPE. 04:00 - 07:30 3.50 WHSUR P RUNCMP Nipple up Tree and test to 5000 psi. 07:30 - 10:30 3.00 WHSUR P RUNCMP P/U Lubricator, install on Tree and pull TWC. Pull Lubricator. R/U Lil Red Hot Oilers, PT lines to 3,500-psi. 10:30 - 13:00 2.50 WHSUR P RUNCMP Freeze Protect with 155-Bbls of dieseLlnstall BPV and test to 1,000-psi. Allow to U-tube to equalize diesel to -2,200-psi. Secure Tree and Cellar. Release rig @ 1300-hrs. 13:00 - 15:30 2.50 RIGD P POST RDMO to K-11. Printed: 1012/2006 10:55:53 AM . . FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" 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 $CANNED SEP 2 82006 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU K-01 Sundry Number: 306-324 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set Qut 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, ~~ Cathy P. Foerster Commissioner I jf DATED thislJ day of September, 2006 Encl. j~3 -td I ~~\~dvV . STATE OF ALASKA 11'~ l/1t/Ob Al~ Oil AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVAL W4A- '1JUIz..o(J(,p 20 MC 25.280 ~¡:p 1 q ?nnh 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing ~ Repair Well o Plug Perforations o Stimulate ft!!~JmeM~k~~mmissÎol1 o Change Approved Program ~ Pull Tubing o Perforate New Pool o Waiver o Other Anchorage 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 183-121 / 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20998-00-00 /' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU K-01 / Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field 1 Pool(s): ADL 028300 61.1' Prudhoe Bay Field 1 Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUMMARY , ',.", , "" Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): Junk (measured): 12043 9136 12000 9098 None None Casino Lenoth Size MD / TVD Burst CollaDse Structural Conductor 110' 20" x 30" 110' 110' Surface 2816' 13-3/8" 2816' 2677' 4930 2670 Intermediate 11259' 9-5/8" 11259' 8454' 6870 4760 Production Liner 1063' 7" 10980' - 12043' 8220' - 9136' 7240 5410 Perforation ~D (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): None - Removed this RWO Packers and SSSV Type: None I Packers and SSSV MD (ft): None 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 SePtemb~7, )006 16. Well Status after proposed work: CommencinQ Operations: ~Oil DGas D Plugged D Abandoned 17. Verbal Approval: Da~9/17/2006 DWAG DGINJ DWINJ D WDSPL Commission Representative: Winton Aubert 18. I hereby ce~~hat the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Nam avid Reem Title Drilling Engineer Bryan McLellan, 564-5516 Signature ) If1 -!<..t..c..;.-- Phone 564-5743 ,/1'/1>' Prepared By Name/Number: Date Terrie Hubble, 564-4628 , Commission Use Onlv 1 Sundry Number: . :;>0 ~ -. ":?Q<L Conditions of approval: Notify Commission so that a representative may witness f D Plug Integrity 5ÍBOP Test D Mechanical Integrity Test D Location Clearance Other: T -e-ç t- ~DPf to ~ÇOO f fú . RBDMS 8Ft SEP 2 5 2006 Subsequent Form Required: lD - 404- Approved BV:f1æ. &2_~ ~L APPROVED BY Date c¡ ..?J - fJ ~ COMMISSIONER THE COMMISSION Form 10-403 Revisec(06/2006 ^ t Submit In Duplicate ORIGINAL . . K-01 Rig Workover Original ScoDe of Work: Pull 7" x 5-%" completion, replace 9-5/8" casing packoffs, mill and remove production packer, run new 4-1/2" 13Cr completion. No Sundry application was submitted for the /' original scope of the RWO because no casing repairs were planned. ChanQe of ScoDe: The 9-5/8" casing failed a pressure test during the RWO and a leak was isolated below 8021' md. As a result, a 7" 26# L-80 scab liner will be run and fully cemented from the top of the existing 7" liner, from 10980' md to 4000' md. MASP: 2370 Well Type: Producer Estimated Start Date: Liner Running is in progress as of 9/18/06. Pro Dosed Procedure: 1. Pressure test 9-5/8" casing and isolate leak below 8021' md (this step has been completed). 2. Set a composite bridge plug in the existing 7" liner at 11000' md (this step has also been completed). 3. Run and cement 7" 26# L-80 scab liner from the top of the existing liner at 10980' md to -4000' / md (currently in progress as of 9/18/06). e 4. Mill out float equipment and pressure test 9-5/8" casing and 7" scab liner to 500 si. 5. Mill up composite plug and push remnants to bottom. 6. Run 4-1/2" 13Cr tubing with production packer set at -10825' md. Packer fluid will be seawater with corrosion inhibitor and diesel freeze protection. 7. Pressure test Inner Annulus to 3500 psi. I 8. ND BOP's, NU adaptor flange and tree. Test same to 5000 psi. ' 9. RDMO. . ElEV = 25.82' ) P= 1500' ~ 2979' -i 7" X 5-1/2" XO I x Angle - 53 @ 4400' tum MD = 11730' V / 2991' -15-1/2" CAM SSSV LAND. NIP, ID = 4.562" I tum ND = 8800'SS / V . GAS LIFT MANDRElS 17" TBG, 26#, .0383 bpf. ID = 6.276" I 2979' r/ ST MD ND DEV TYÆ VLV LATCH PORT DATE 10 3401 3003 50 OTIS DMY RA 0 05/17/05 TOPOF 5-1/2" TBG I 2979' r 9 5209 4133 48 OTIS DMY RA 0 05/17/05 113-3/8" CSG, 72#, N-80,ID= 12.347" I ~ ~ 8 6875 5271 49 OTIS DMY RA 0 2816' 7 8191 6111 49 OTIS DMY RA 0 12" Sl ADAPTER-USE 4-1/2" GS TO PULL (06/06/06 I 7243' r ........ L 6 8956 6647 46 OTIS DMY RA 0 I.., 7243' I - 5 9586 7076 42 OTIS DMY RA 0 5-1/2" ECLIPSE PKR, ID = 2.992" (20 JTS) 4 10069 7452 40 OTIS DMY RA 0 3-1/2" LNR PATCH, 8.8#, ID = 2.992" 3 10220 7529 39 OTIS DMY RA 0 (BETWEEN PKRS) 2 10607 7846 36 OTIS DMY RA 0 ITBG PUNCH, 4 SPF (06/01/06) I 10666' TO l 1 10764 8010 35 OTIS DMY RA 0 110668' ELM I '\. ,// 7831' 1-15-1/2" ECLlPSEPKR,ID=2.992" I Minimum ID = 3.725" @ 10991' '\ ~ I)C ~--t 7832' J-13-1/2" XN NIP,ID=2.75" I 4-1/2" OTIS XN NIPPLE (SEE SAFETY NOTE) '1) .i-' 7834' H3-1/2" WlEG ITOC IN \A (06/01/06) 10730' ELM 10790' 1-1 TOP OF CEMENT SHEA TH, ID - 3.8" I I TOP OF CEMENT SHEATH (06/01/06) 1 110834' ELM I 10835' Jî 5-1/2" BKR l SLDNG SLY, ID = 4.313" I ~ II I 12.5" BKR IBP SET (06/01/06 I 10806' ELM ~ CEMENTED & MILLED OUT TO 3.8" ~ 10894' Jî TBG SEAL ASSY, ID = 3.813" I CEMENTED & MillED OUT TO 3.8" 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 10918' I ....I 10918' J-19 5/8" BOT PKR, ID = 3.958" I I2S ~- 10918' 1-15-1/2" x 4-112" XO I ï ITOPOF 7" lNR I 10980' I . I . I 10952' 1-i4-1/2"OTISXNIP,ID=3.813" I ~ 10991' H 4-1/2" OTIS XN NIP, ID - 3.725", W/STUCKTTP I 1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 11033' I r1 1 11033' 1-14-1/2" TBG TAil, ID = 3.958" I , 19-5/8" CSG, 47#, l-80, ID = 8.681" I ,oj .. I 11051' H ElMDTTlOGUNAVAllABlE 11259' ÆRFORA TION SUMMARY REF LOG: BHCS ON 09/02/83 ANGLEAT TOP ÆRF: 34@ 10972' Note: Refer to Production DB for historical perf data I 11544' H MARKER JOINT I SIZE I SPF INTERV AL Opn/Sqz DATE TBG PUNCH 10972 - 10975 C 06/28/99 TBG PUNCH 10980 - 10984 C 03/01/01 ~ 3- 3/8" 4 11812-11887 C 01/29/85 I PBTD I 12000' I / 17" lNR, 26#, L-80, .0383 bpf, ID = 6.276" I 12043' I TREE = ElLHEAE> = ACTUA TOR = KB. ElEV = BF KO Ma Da Da 15-1 14- DATE 09/07183 07/25/03 07/31/03 08/14/03 05/17105 09/25/05 6" MCEVOY MCEVOY OTIS 61.10' ~-R\. ~~S K-01 S OTES: T X IA LEAK IN SEAL ASSY ABOVE PKR. PKR HAS BEEN CEMENTED IN PLACE. TTP STUCK IN XN NIPPLE@ 10991' REV BY COMMENTS ORIGINAL COM PLETION BJM'KK SET ECLIPSE PKR @ 7831' JGM'TLP SET ECLIPSE PKR @ 7243' JCM'TlH GL V C/O DTRlPJC GL V C/O 1WS/TLH XN PlUG SET (05/17105) DA TE REV BY COMMENTS 05118/06 RRD/PJC PULL XN PlUG @ 7804' 06/09/06 RLM'PAG CORRECTIONS-MUL TI- 6/1 INF 06/09/06 JCM'PAG ECLIPSE PULL TOOL (06/07/06) PRUDHOE BA Y UNIT WElL: K-01 PERMIT No: "1831210 API No: 50-029-20998-00 SEC4, T11N, R14E, 1626.16' FNl & 1090.94' FWl BP Exploration (Alas ka) TREE = ELLHEAÐ = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumlVD= 6" MCEVOY MCEVOY OTIS 61.10' 25.82' 1500' 53 @ 4400' 11730' 8800' SS 113-3/8" CSG, 72#, N-80, ID = 12.347" I I HOLE IN 9-5/8" CASING BELOW 8021' MD I TOP OF 7" LNR I I 9-5/8" CSG, 47#, L-80, ID = 8.681" I . >8021' 10980' 11259' ÆRFORA TION SUMMARY REF LOG: BHCS ON 09/02/83 ANGLE AT TOP ÆRF: 34 @ 10972' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 11812 - 11887 C 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I PBTD I DATE 09/07/83 07/25/03 07/31/03 08/14/03 05/17/05 09/25/05 REV BY COMMENTS ORIGINAL COMPLETION BJMlKK SET ECLIPSE A<R@ 7831' JGM/TLP SET ECLIPSE A<R @ 7243' JCM/TLH GL V C/O DTRlPJC GL V C/O 1WS/TLH XN PLUG SET (05/17/05) 01/29/85 12000' 12043' DATE 05/18/06 06/09/06 06/09/06 09/18/06 K-01 Existing Completion OTES: 11544' HMARKERJOINT I REV BY COMMENTS RRD/PJC PULL XN PLUG @ 7804' RLMlPAG CORRECTIONS-MUL TI- 6/1 INF JCMlPAG ECLIPSE PULL TOOL (06/07/06) BJM EXISTING WELL BORE PRUDHOE BA Y UNfT WELL: K-01 ÆRMfT No: "1831210 API No: 50-029-20998-00 SEC4, T11N, R14E, 1626.16' FNL & 1090.94' FWL BP Exploration (Alaska) TREE = 6" MCEVOY . K-01 ~OTES: WELLHËAé> = MCEVOY ACTUATOR - OTIS KB. ELBI = 61.10' Proposed Completion /. BF. ELBI = 25.82' KOP= 1500' Max Angle - 53 @ 4400' Datum MO = 11730' I . I 2200' 1-14-1/2" HES X NIP, ID = 3.813" I Datum TVO = 8800' SS - GAS LIFT MANORELS ST MO TVO DBI TYÆ VLV LATCH PORT DATE 4 3691 1.5" 3 7157 1.0" 113-3/8" CSG, 72#, N-80, 10 = 12.347" I ~ ~ 2 9412 1.0" 2816' 1 10725 1.0" L / BAKER ZXP LINER TOP PACKER I 4000' ~ I TOP OF CEMENT 1 4000' Minimum ID = 3.725" @ 11005' 4-1/2" HES XN NIPPLE I I ~I 10800' H4-1/2" HES X NIP, 10 = 3.813" I . ~ 10836' H 7" x 4-1/2" BAKER S3 A<R, 10 = ??? I 17" SCAB LNR, 26#, L-80, .0383 bpf, ID = 6.276"1 10980' ~ I I ~I 10867' H4-1/2" HES X NIP, 10 - 3.813" I TOPOF7" LNR I 10980' I I I I 10977' H 4-1/2" HES XN NIP, 10 - 3.725" I 14-112" TBG, 12.6#, 13Cr80, .0152 bpf, ID = 3.958H 11030' I I I 11030' H4-1/2" WLEG I 19-5/8" CSG, 47#, L-80, 10 = 8.681" I 11259' I ~ ÆRFORA TION SUMMARY REF LOG: BHCS ON 09/02/83 ANGLEAT TOP ÆRF: 34 @ 10972' Note: Refer to A"oduction OB for historical perf data I H MARKER JOINT I SIZE SPF INTERV AL Opn/Sqz OATE 11544' 3-3/8" 4 11812 - 11887 C 01/29/85 [) [) I PBTD I 12000' 1 7" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" I 12043' DATE RBI BY COMMENTS DATE REV BY COMMENTS PRUOHOE BAY UNIT 09/07/83 ORIGINAL COM PLETION 05/18/06 RRD/PJC PULL XN PLUG @ 7804' WELL: K-01 07/25/03 BJMlKK SET ECLIPSE A<R @ 7831' 06/09/06 RLMlPAG CORRECTIONS-MULTI - 6/1 INFC ÆRMIT No: '1831210 07/31/03 JGM/TLP SET ECLIPSE A<R @ 7243' 06/09/06 JCMlPAG ECLIPSE PULL TOOL (06/07/06) API No: 50-029-20998-00 08/14/03 JCM/TLH GL V C/O 06/13/06 BJM PROPOSED RNO SEC4, T11N, R14E, 1626.16' FNL & 1090.94' FWL 05/17/05 OTRIPJC GL V C/O 09/25/05 lWSITLH XN PLUG SET (05/17105) BP Exploration (Alaska) Scblum~erger RECEiVED 06/05-06/06 JUN 0 8 Z006 NO. 3835 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ;\Í""~(C: Ci¡' ~ {~__... (""OS c.crr.!11isScn Anchorage AK 99503-2838 ' '"...~..~ ~. ç¡ ,-".......1.1 . '. . .. ..~ , A ,..¡"... ' 'j("" iJl."h"J· n ATTN: Beth ,~n"'II\,~.e ~\ot;;~I,;!~t:.;..;. 1 2: Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 \ Anchorage, AK 99501\0-"1...... ( )/ Field: Prudhoe Bay ~ ..J Well Job# Loa DescriDtion Date BL Color CD 17-13A R6.C) - ,")":¡(\ 11001218 US IT 04/04/05 1 NK-65A AD,"'1 -(J r:-:< 11084270 SCMT 07/05/05 1 02~10B :Jtx.'-- ("', &, '- 10964140 LDL 04/06/05 1 01-11 j'~i -('1< + 11051039 INJECTION PROFILE (i.,:;)" - (".,,, "~'~ C./~"I":" 1,'0"7. 04/29/05 1 01-09A I~( - ()3~ 10559825 INJECTION PROFILE ' , 07/31/03 1 01-11 .:¡.."+ - ,.--,~ .-:¡. 10662950 INJECTI~~ PROFILE QOP~I - (-<.c.e\V~ 5¡t)3IQ~ 09/16/03 1 11-34 I o.,i..( - ¡,-=?~'< 10687720 LDL 12/31/04 1 A-07 Î ~.~ -O~I 9153241 PRODUCTION' PROFILE (ì ~ C\; - r ¿C' ... .;.) ¡;' {~l., 02104/03 1 B-36 ¡ q r,~ - 00,5"' 10563182 LDL (\ ,. ,~ i - r 0 (-' ; .,,: . "'. ') Î I .::J ~ I t" 7,' 07/09/03 1 01:20 Î7i,::).-}4C 10687694 PRODUCTIÒN (PROFILE 07/16/04 1 K-01 I -sr-:%' - 1.:::J 11211415 SCMT 06/01/06 1 H-31) L ~7r - i'\~~:'" 11217253 USIT 06/01/06 1 D.S:09-06 )"'+(~- r4l"X- 11258699 US IT 04/13/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. , Anchorage, Alaska 99508 .' (U'. \) ....' C\ ' J / 1"-- .......... Alaska Data & Consulting Services 2525 Gambell Street. Su~e 400 Anchorage, AK 99503-2838 ATTN: Beth e e 5/10/2005 10:51 AM 1 of 1 Content-Description: K-01.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 «K-01.ZIP» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-51 00, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom Attached is a wellbore schematic. Please call if you have any questions. SCAN~\jED JUL 072005 The plan forward for this well is as follows: Obj: Restore Tubing integrity 1. DHD: TIFL - FAILED 2. WIE: Eval way forward, options: - Set TTP @ 7832' MD for MITIA - Pull patch, caliper, re-patch or TTP All, Well K-01 (PTD #1831210) has sustained casing pressure on the IA and is classified as a Problem well. TIO's on 05/09/05 were 1250/1370/260. ) ) Subject: K-01 (PTD#1831210) Classified as Problem Well From: "Anders, Joe L" <anders22@BP.com> Date: Mon, 09 May 2005 20: 19:40 -0800 T~.:· SchmoyAL@BP.com, uGPB,' GCIW ellpadLeadu <GPBGC lWellpadI;ead@BP . com>, .' "Rbssberg;'R Steven:' <RossbeRS@BP .com>,. "NSlJ, 'ADWWell Operations Sup~rvisÇ>r" " <NSUADWWellOperationsSupervisor@BP.com>, "GPB,WellsOptEng" . . . <qPBWellsO~tf1}g@)I3:P.ç'Orn>,. "A()~~,~im .F;e~g~~rrt~jl)'\ <Cjiri1__r¢~g@adin~~~t~te.al<:.t1:S>" '1 '''APGCCWitltQp. Aubert (E-mail)..<winton_aubert@a(1min.·statë.ak.uS> ,: "NSU~ ,ADW¡WL' &. Completion· Supervisor".<NSUADWWL&CompletionSupervisor@BP.com>,. "OPB;·Ops.Mgr..··. <ÇìP:sc>psMgr@BPpom>-, ."gPB~ (jC 1. An~a'Mgr" ~q~~GC 1 TL@BP ;coI11>,"(}PB~Well.,Pa4s . . CÈK-N2"<GPBWéllPadsCEK-N2@Bp.com> ':.' -, .. .... . , C¢:' "NSU,ADW' Wen Integrity Engineer" <NSUADWWellIntegtìtýEngineer@BP.co111>,"Reeves, Donald F"'<Reeves[)f@BP.com>; ..' .'.,'" ....,. ..... '.' ... ......,'. . ...., K-01 (PTD #1831210) Classified as Problem Well ) TREE = WELLHEA D = AëtUA TOR ''';' KB. äï~v = BF. ELEV = k6ï:l";;;,······ M~ixÄiigie ,,; 'Datum MD = Datum TV D = 6" MCEVOY MCEVOY OTIS ........... "61 ~ 1 b' 25.82' , '15"66; .,. 53@ 44ÖO' 11730' 8800' SS 17" TBG, 26#, .0383 bpf, JD = 6.276" 1--1 2979' I TOP OF 5-1/2" TBG 1--1 2979' 113-3/8" CSG, 72#, N-80, ID = 12.347" 1--1 2816' 5-1/2" ECLIPSE PKR, ID = 2.992" (20 JTS) --1 3-1/2" LNR PATCH, 8.8#, ID = 2.992" (BETWEEN PKRS) 15-1/2" ECLIPSE PKR, ID = 2.992" 1--1 13-1/2" XN NIP, ID = 2.750" l-i 13-1/2" WLEG l-i 7243' 7831' 7832' 7834' Minimum ID = 3.725" @ 10991' TTP STUCK IN XN NIPPLE 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" l-i 10918' ITOPOF7" LNR l-i 10980' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 11033' 1 19-5/8" CSG, 47#, L-80, ID = 8.681" 1--1 11259' 1 PERFORA TION SUMMARY REF LOG: BHCS ON 09/02/83 ANGLEATTOPÆRF: 34 @ 10972' Note: Refer to Production DB for historical perf data SIZE I SPF INTERVAL Opn/Sqz DATE TBG PUNCH 10972 - 10975 0 06/28/99 TBG PUNCH 10980 - 10984 0 03/01/01 3-3/8 4 11812-11887 0 01/29/85 I PBTD 1-1 12000' 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 12043' DATE 09/07/83 03/03/01 1 0/06/0 1 04/05/03 04/11/03 4/28-5/2/03 07/18/03 REV BY COMMENTS ORIGINAL COM PLETION SIS-MD FINA L RNlTLP CORRECTIONS BJMlKK CORRECTIONS PJVElKK SET 3" BKR IBP BJMlKK PULL & SET IBP JCM'TLH GL V C/O DATE 07/17/03 07/25/03 07/31/03 08/04/03 08/14/03 ) K-01 ) SAFETY NOTES: T X IA LEAK IN SEAL ASSY ABOVE PKR. PKR HAS BEEN CEMENTED IN PLACE. - 2979' 1-11" X 5-1/2" XO 1 2991' 1-15-1/2" CAM SSSV LAND. NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 10 3401 3003 50 OTIS DOME RA 16 08/12/03 ~ 9 5209 4133 48 OTIS SO RA 20 08/12/03 8 6875 5271 49 OTIS DMY RA 0 7 8191 6111 49 OTIS DMY RA 0 6 8956 6647 46 OTIS DMY RA 0 5 9586 7076 42 OTIS DMY RA 0 4 10069 7452 40 OTIS DMY RA 0 3 10220 7529 39 OTIS DMY RA 0 2 10607 7846 36 OTIS DMY RA 0 1 10764 8010 35 OTIS DMY RA 0 ~ L X ~ g " " tl 10790' 1-1 TOP OF CEMENT SHEA TH, ID = 3.8" 1 10835' 1- 5-1/2" BKR L SLDNG SLV, ID = 4.313" CEMENTED & MILLED OUT TO 3.8" 10894' 1- TBG SEAL ASSY, ID = 3.813" CEMENTED & MILLED OUT TO 3.8" " 1--195/8" BOT PKR, ID = 3.958" 1 ~\~ r~ 10918' 10918' 1-15-1/2" X 4-1/2" XO 1 11 , ~ I I 10952' 1-14-1/2" OTIS X NIP, ID = 3.813" 1 M ~ 10991 ' 1- 4-1/2" OTIS XN NIP, ID = 3.725" W/ STUCK TIP 11033' 1--14-1/2" TBG TAIL, ID = 3.958" 1 I 11051' 1-1 ELMDTI LOG UNAVAILABLE 1 ~ .. ~ I 11544' 1-1 MA RKER JOINT 1 -. REV BY COMMENTS JBMlKK PULL IBP BJMlKK SET ECLIPSE PKR @ 7831' JGMlTLP SET ECLIPSE PKR @ 7243' CMOITLP KB ELEVATION CORRECTION JCMlTLH GL V C/O PRUDHOE BA Y UNIT WELL: K-01 PERMIT No: 1831210 API No: 50-029-20998-00 SEC 4, T11 N, R14E, 1626.16' FNL & 1090.94' FWL BP Exploration (Alaska) .. ~,. (STATE OF ALASKA ~. ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 SuspendD Operation ShutdownD Perforate 0 WaiverD OtherD Alter CasingD Repair WellŒJ Plug PerforationsO Stimulate D Time ExtensionO Change Approved ProgramD Pull TubingD Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 183-1210 Development ŒJ Exploratory D 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-20998-00-00 7. KB Elevation (ft): 9. Well Name and Number: 61.10 K-01 8. Property Designation: 10. Field/Pool(s): ADL-0028300 Prudhoe Bay Field 1 Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 12043 feet true vertical 9136.1 feet Plugs (measured) 10991 Effective Depth measured 10991 feet Junk (measured) None true vertical 8229.1 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 38 - 118 38.0 - 118.0 1490 470 Liner 1063 7" 26# L-80 10980 - 12043 8220.0 - 9136.1 7240 5410 Production 11223 9-5/8" 47# L-80 36 - 11259 36;0 - 8453.7 6870 4760 Surface 2779 13-3/8" 72# N-80 37 - 2816 37.0 - 2677.2 4930 2670 Perforation depth: Measured depth: 11812 -11887 True vertical depth: 8933.09 - 8998.91 Tubing ( size, grade, and measured depth): 7" 26# L-80 @ 35 - 2979 5-1/2"17#L-80 @ 2979 - 10918 RECEIVED 3-1/2" 9.3# L-80 @ 7243 - 7834 4-1/2" 12.6# L-80 @ 10918 - 11033 Packers & SSSV (type & measured depth): 9-5/8" DV Packer @ 2729 JAN 0 8 2004 5-1/2" Eclipse Packer @ 7243 5-1/2" Eclipse Packer @ 7831 Alaska Oil & Gas Cons. Commission 5-1/2" Baker 3-H BOT Packer @ 10918 A chorage No SSV n 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1060 28.1 27 0 1158 Subsequent to operation: 962 24.2 39 0 947 14. Attachments: 15. Well Class after proposed work: Exploratory D Development ŒJ Service D Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D OilŒJ GasD WAG D GINJD WINJD WDSPLD Daily Report of Well Operations. ~ Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Garry Catron Printed Name Garry Catron Title Production Technical Assistant ~ "'Ií'~~ 1 5 'J!OO.ii1 Signature ~- (~. [ r~,). '.' t.. ~ Phone 564-4657 "" Form 1 0-404 Revised 12/2003 ,<t J ,~ II~~ - . ." , '\ +' ,I, K-O1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/17/03 PulllBP from 109121 SLM w/elements. 07/17/03 Run SBHP. 07/17/03 Pull DGLV.s from Station 9,10. 07/19/03 Well Kill. Load unit road to location. AWGRS continued to 7-20-03 07/19/03 T/I/O = 290/vac/vac. Tubing and IA FLs (patch). Tubing FL @ 1440' (53 BBLs)..IA FL @ 10021 (26 BBLs). 07/20/03 ATTEMPT TO SET WFD LOWER PATCH AND UNABLE TO GET PAST UPPER MOST GLM @3401 PACKER SETTING DOWN IN TOP OF MANDREL. WFD PACKER OD 4.53in. 07/20/03 AWGRS continued from 7-19-03 TIO= 375/0/0 Pump well kill fluids. Pumped 5 bbls neat meth 240 bbls 1 % KCL 100 BBls 50/50 meth down tubing to kill well. Rigged up to LA. & pumped 30 bbls crude. Final pressures TIO=O/O/O. 07/20/03 T/I/O = 170/vac/vac. Tubing and IA FLs post-load. Tubing FL @ 11801 (44 BBLs). IA FL near surface. 07/20/03 (SSV CLOSED ON ARRIVAL) RIGGING UP SLlCKLINE UNIT *****CONT ON 7-21-03 WSR 07/21/03 ATTEMPT TO SET LOWER PACKER FOR ECLIPSE TUBING PATCH. UNABLE TO GET BELOW GLM @34011. WILL CHANGE TAIL PIPE ASSEMBLY AND ATTEMPT FOLLOWING DAY 07/21/03 DRIFT W/ WEATHERFORD DUMMY PATCH 4.53 00 X 73in OAL (SET DOWN @ 29691 - 68501 - 9570' - 10050' - 105881) TAGGED TD @ 108151 SLM DRIFT W/ 4.50in CENT 5-1/2in BL BRUSH 4.54in GR THRU TIGHT SPOTS. Ran weatherford drift thru tight area @ Sta # 7 & SVLN -- worked tools until falling freely. Left well SI. 07/22/03 ATTEMPT TO RUN LOWER PACKER FOR EXTENDED TUBING PATCH (PUP JOINT BELOW PACKER SHORTENED BY 81 TO MIMIC DRIFT RUN). UNABLE TO GET BELOW GLM @34011TO SET WFD PATCH. 07/23/03 DRIFTED TBG. W/ 131 OF 3.625 AND 51 OF 4.535 DRIFT ON BOTTOM DOWN TO 86001 SLM ( BOBBLES THROUGH ST A # 10 @ 60' PER MIN BUT DOES NOT SIT DOWN / ALSO SLIGHT BOBBLE THROUGH ST A # 9). RDMO / LEFT WELL SHUT IN 07/26/03 Set 2.81" XXN plug in eclipse packer @ 78021 slm 07/28/03 Tbg. Patch; MIRU CTU #9 with WWP. Perform BOP test. *** Job in Progress *** 07/29/03 Tubing Patch/ RIH w/ Weatherford Model R snap latch seal assy 3 1/2in STL spacer tubing and a 5 1/2in PB Eclipse packer. Sting in and latch seal assy in to lower packer at 78311 DPM(7825 ctm) set upper packer at 7247'. Pressure up tubing to 1000 psi. Lost 70 psi in 10 minI no increas in lAP. Relase from packer and POOH. Patch in place. RIH w/3 1/2" G spear to fish 3 1/2" TTP. Perform MIT-IA to 3000 psi, Failed. Lost 100 psi in 2 min /3 attempts. Tubing tracked IA. MIT-T, same result. POOH, did not fish plug. MU seal assy to test top packer, patch and lower seal latch. RIH w/seal assy. Test patch. Determined top packer is set and holding and the production tubing is free of leaks above the patch. Communication is rapid and 1 for 1. Most likely the lower seal assemble in the bottom packer is the source of communication. Call out for and MU fishing tools to pull patch. Page 1 it ( ( , " " K-O1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/30/03 Pull Tubing patch; Continued from 7/29/03 WSR... RIH w/ WFD 5 1/2in Eclipse retrieval adapter baited to 4 1/2 GS. Set down and latched upper packer of patch at 72341 ctm. Pull free with 1 overpull and 1 jar lick. POOH patch is intact seals are missing 07/31/03 Continued from WSR of 7/30/03. Venturi 7800 to 7828. POH. Recover 1/2 cup plastic coating and two more pieces of packing. RBIH with 3in Venturi. Hover from 3350 to 7828 CTMD. POH. Recover 1 cup plastic coating no rubber. Monitor well RU tbg running tools. PJSM w/all crews. Tally pipe, MU/RIH with 20 jts 3.5" L80 tbg. MU/WOT Liner Ptch running tools. RIH stab into lower pkr at 78401, pull19k to verify latched in. Lauch ball, set upper pkr at 72431 ctm. Test pkr to 2000 psi. MIT tbg and IA to 2000 psi. JFT. POH. Tools look good. MU and RIH with 2.7511 GS. Latch and pull 3 1/211 XXN plug from 7828 CTMD. Job in progress. 08/01/03 Continued from WSR of 7/31/03. Freeze protect well with 80 bbls MEOH. Blow down coil for reel swap. RDMO. 08/02/03 MIT IA- to 3000 psi/ Could Not Do Job/ BPV in Hole 08/05/03 T/I/O=O/O/O. MIT IA PASSED to 3000 psi. (Post Long Patch set). Pressured IA to 3000 psi with 6.7 bbls of crude. IA Lost 90 psi first 15 min & 30 psi second 15 min for a total of 120 psi in 30 minutes. Bled IA back to 0 psi. Final WHpls= 0/0/0 08/12/03 T/I/O = 210/0+/0. Tubing FL for slickline. Tubing FL @ 15961. 08/12/03 Set LGL V in Station 10 and S/O GL V in Station 9 08/12/03 T/I/0=300/0/0 assist wireline Pump 40 bbls 60/40 30 bbls neat and 10 bbls crude Final WHP=100/0/0 08/12/03 Run SBHP. FLUIDS PUMPED BBLS 5 Neat Methonal 845 1 % KCL 37 Crude 298 50/50 Methonal/H20 1185 TOTAL Page 2 .~ ( ( ,. ..,'" .' TREE = 6" MCEVOY WELLHEAD = MCEVOY K 0 1 SAFETY NOTES: T X IA LEAK IN SEAL ASSY ABOVE ACTUA TOR = OTIS - PKR. PKR HAS BEEN CEMENTED IN PLACE. KB. ELEV = 61.10' BF. ELEV = 25.82' KOP= 1500' 2979' -i7" X 5-1/2" XO I Max Angle = 53 @ 4400' Datum MD = 11730' 2991' -i5-1/2" CAM SSSV LAND. NIP, ID = 4.562" I Datum TVD = 8800' SS 8 " - " I ' GAS LIFT MANDRELS 17 TBG, 26#, .0383 bpf, ID - 6.276 2979 ST MD TV D DEV TYÆ VL V LA TCH PORT DA TE 1 TOP OF 5-1/2" TBG I 2979' 10 3401 3003 50 OTIS DOME RA 16 08/12/03 9 5209 4133 48 OTIS SO RA 20 08/12/03 113-3/8" CSG, 72#, N-80, ID = 12.347" I 2816' 8 6875 5271 49 OTIS DMY RA 0 7 8191 6111 49 OTIS DMY RA 0 6 8956 6647 46 OTIS DMY RA 0 5-112" ECLIPSE PKR, ID = 2.992" (20 JTS) 7243' 5 9586 7076 42 OTIS DMY RA 0 3-1/2" LNR PATCH, 8.8#, ID = 2.992" 4 10069 7452 40 OTIS DMY RA 0 (BETWEEN PKRS) 3 10220 7529 39 OTIS DMY RA 0 2 10607 7846 36 OTIS DMY RA 0 15-1/2" ECLIPSE PKR, ID = 2.992" I 7831' 1 10764 8010 35 OTIS DMY RA 0 13-1/2" XN NIP, ID = 2.750" I 7832' 3-1/2"WLEG 7834' 10790' -iTOPOFCEMENTSHEATH,ID=3.8" I II 10835' 5-1/2"BKRLSLDNGSLV,ID=4.313" Minimum ID = 3.725" @ 10991' CEMENTED & MILLED OUT TO 3.8" TTP STUCK IN XN NIPPLE 10894' TBG SEAL ASSY, ID= 3.813" CEMENTED & MILLED OUT TO 3.8" 10918' -i9 5/8" BOT PKR, ID = 3.958" I 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" l-i 10918' I 10918' -15-1/2" X 4-1/2" XO I TOP OF 7" LNR I 10980' 10952' -14-1/2" OTIS X NIP, ID = 3.813" I 10991' 4-1/2" OTIS XN NIP, ID = 3.725" W/ STUCK TIP 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 11033' 11033' -i4-1/2" TBG TAIL, ID = 3.958" I 1 11051' l-i ELMDTI LOG UNAVAILABLE I 19-5/8" CSG, 47#, L-80, ID = 8.681" I 11259' PERFORA TION SUMMARY REF LOG: BHCS ON 09/02/83 ANGLEAT TOP ÆRF: 34 @ 10972' Note: Refer to Produetion DB for historieal perf data l-i I SIZE SPF INTERVAL Opn/Sqz DATE 11544' MARKER JOINT TBG PUNCH 10972 - 10975 0 06/28/99 TBG PUNCH 10980 - 10984 0 03/01/01 3-3/8 4 11812-11887 0 01/29/85 I PBTD I 12000' 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 12043' DA TE REV BY COMMENTS DA TE REV BY COMMENTS PRUDHOE BA Y UNIT 09/07/83 ORIGINAL COMPLETION 07/17/03 JBMlKK PULL IBP WELL: K-01 03/03/01 SIS-MD FINAL 07/25/03 BJMlKK SETECLIPSEPKR@ 7831' PERMIT No: 1831210 10/06/01 RN/TLP CORRECTIONS 07/31/03 JGMlTLP SET ECLIPSE PKR@ 7243' API No: 50-029-20998-00 04/05/03 BJM/KK CORRECTIONS 08/04/03 CMO/TLP KB ELEVATION CORRECTION SEC 4, T11 N, R14E, 1626.16' FNL & 1090.94' FWL 04/11/03 PvVElKK SET 3" BKR IBP 08/14/03 JCMlTLH GLV C/O 4/28-5/2/03 BJM/KK PULL & SET IBP 07/18/03 JCMlTLH GLV C/O BP Exploration (Alaska) 06/05/03 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2800 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 Prints CD W-19AL1 ~ 23099 TIE-IN MGR/CCL 03~06~03 P2-57A '"...5 23272 MCNL 03/15/03 D.S. 12-20 "'~J LDL 06103/03 D.S. 15-21A--J PRODUCTION PROFILE 05115/03 B-04 "-J PRODUCTION PROFILE/GHOST 05/17/03 F-10A "'-J LDL 05118103 D-30A '"~"J MEM PRODUCTION PROFILE 05/20/03 D-22B --..~ MEM PRODUCTION PROFILE 05122/03 K-01 '--~ LDL 05116103 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: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 5GANNF-..B JUN [ 3 ?_DD3 STATE OF ALASKA ALAS "L AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other Add-Perfs Tubing Puncher 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1626' FNL, 1090' FWL, SEC. 04, T11N, R14E, UM At top of productive interval 1151' FNL, 865' FEL, SEC. 33, T12N, R14E, UM At effective depth 1278' FNL, 976' FEL, SEC. 33, T12N, R14E. UM At total depth 905' FNL, 603' FEL, SEC. 33, T12N, R14E, UM 5. Type of well: IX] Development [] Exploratory [] Stratigraphic [] Service (asp's 671351, 5975592) (asp's n/a) (asp's 674419, 5981292) (asp's 674782, 5981672) 6. Datum Elevation (DF or KB) KBE = 61.12' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number K-01 9. Permit Number / Approval No. 183-121 10. APl Number 50- 029-20998 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 12043 feet 9136 feet 11001 feet 8237 feet Length Structural Conductor 110' Surface 2781' Intermediate 11224' Production Liner 1063' Plugs (measured) Junk (measured) Tag TD @ 11001' SLM (01/12/2001). Fish in 4-1/2" tubing @ 11001'. Size Cemented MD TVD 20" x 30" 72 c.f. concrete 145' 145' 13-3/8" 3900 c.f. Amticset II 2816' 2677' 9-5/8" 133 c.f. Arctticset I; 250 c.f. Class 'G' 11259' 8447' 7" 396 c.f. Class 'G' w/18% salt 10980'-12043' 8220'-9136' Perforation depth: measured Tubing Puncher holes 10972' - 10975', 10980' - 10984', 10985' - 10988' Open Perfs 11812' - 11887' true vertical Tubing Pucher holes 8213' - 8216', 8220' - 8223', 8224' - 8226' Open Perfs 8933'- 8999' Tubing (size, grade, and measured depth) 7" x 5-1/2" crossover @ 2979'. 5-1/2" 17#, L-80 tubing to 10918'. 4-1/2" 12.6# L-80 tubing tail @ 11033'. Cement Sheath from 10790' to 10957' --- ID - 3.8". Packers and SSSV (type and measured depth) 9-5/8" Packer (B.O.T.)(3.958" ID) @ 10918'. 5-1/2" Camco (flapper)(4.562" ID) SSSVLN @ 2991'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certj,fv th.at the foreg~s true and correct to the best of my knowledge Signed ~ ~ ~w""~ Title Technical Assistant Date Prepared By Name/Number: De Wayne Schnorr 564-5174 Form 10-404 Rev. 06/15/88 ,~il. ~''''' i~_~ "-'~ ~, :. Submit In Duplicate 02/08/2001 02/09/2001 02/12/2001 03/01/2001 K-01 Description of Work Completed NRWO OPERATIONS PERF(ADD-PERF): DFF W/2.5" DMY GUN (PRE-TBG PUNCH)- IN PROGRESS PERF(ADD-PERF): D/I' W/DMY GUN PERF(ADD-PERF): DFF W/2.5" DMY GUN - PRE TBG PUNCH PERF(ADD-PERF): ADD PERF SUMMARY 02/08/01 SPOT WIRELINE EQUIPMENT. HAVE TGSM. GET EQUIPMENT READY TO PICK UP IN THE MORNING. SDFN. ****TALK W/PAD OPERATOR. WELL LEFT SHUT IN.**** 02/09/01 CALL OUT GREASE CREW TO SERVICE VALVES. SWAB NOT HOLDING. MASTER FROZE UP. HEATER UNAVAILABLE UNTIL AT LEAST NOON. RDMO. ****TALK W/PAD OPERATOR. WELL LEFT SHUT IN.**** 02/12/01 DRIFT TBG W/2.5" DG. TAG @ 11,001' SLM (TOP OF FISH). NO PROBLEMS. RDMO. ****TALK W/PAD OPERATOR. OK TO POP **** 03/01/01 PERFORATED TUBING TAIL 10980-10984 WITH TUBING PUNCHER 4 SPF, 16 HOLES. *** WELL RETURNED TO POP*** Fluids Pumped BBLS. Description 2 PRESSURE TESTS OF LUBRICATOR TO 3000 PSI W/DIESEL. 2 TOTAL ADD PERFS 03/01/2001 SUMMARY The following interval was perforated using 1-11/16" TUBING PUNCHER GUN, 4 SPF 0 degree phased, Iow-side orientation. 10980' - 10984' MD MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT' Petroleum Inspector DATE: April 20, 2001 Safety Valve Tests Prudhoe Bay Unit K Pad Friday, A. pril 20, 200t: I traveled to BPXs K Pad and witnessed the 30-day retest of the safety valve systems.. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 11 Wells-and 22 components with 3 failures. The pilots on wells K-06, K- 07 and K-09 tripped below the required set point. The pilot on well K-09 was retested and operated properly. Wells K-06 and K-07 normally flow into the Iow~ pressure, system (at 200 to 300 psi) but were recently switched into the high- pressure system. The PilOtS on these two wells were left in the Iow pressure setting (125 psi) and tdpped :near:this set point but were failed on this test due to the higher flowing tubing pressure required to produce into the high pressure system. These two pilots were adjusted to the higher set pressure (550 psi) and retested at this time. Merv Liddelow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the Well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in fair conditions. Summary: I witnessed the 30-day retest of the safety valve systems at BPXs K- Pad in the Prudhoe Bay Field. PBU K Pad, 11 wells, 22 components, 3 failure 13.6% failure rate 16 wellhouse inspections Attachment: SVS PBU K Pad 4-20-01 CS X Unclassified Confidential (Unclassified if doc. removed ) SVS PBU K Pad 4-20-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Prudhoe / PBU / K Pad Separator psi: LPS 154 Date: 4/20/01 HPS 670 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE K-01 1831210 670 550 525 P P OIL K-02B 1941350 670 550 525 P P OIL K-03A 1990030 154: 125 100 P P OIL K-04A [1970210 K-05A 1931560 K-06A 1981360 670 550 100 3 P 4/20/01 OIL: K-07C 1991090: 670 550 100 3 P 4/20/01 OIL K-08 1851790 670 550 525 P P OIL ~-09B 1970860 670 550 100 3 P 4/20/01 OIL ~-10 1871140 K-11 1871170 K-12 1871040 154 125 110 P P OIL K-13 1871010 K- 14 1870950 K-16A 1981800 154 125 120 P P OIL K-17A 1980610 K-19A 1981680 154 125 125 P P OIL K-20A 1981500 154 125 150 P P OIL Wells: 11 Components: 22 Failures: 3 Failure Rate: 13.64°A~] 9o var Remarks: The pilot on well K-09 tripped below the set point it was retested and worked properly Wells K-06 & K-07 were recently switched from the low pressure to high pressure oi train but the pilots were left at the low pressure setting. These pilots were adjusted an retested. RJF 1/16/01 Page 1 of 1 SVS PBU K Pad 4-20-01 CS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 October 1995 RE: Transmittal of Data Sent by: HAND CARRY -t Dear Sir/Madam, Enclosed, please find the data as described below: K-12 ~~ K-03 K-O1 DESCRIPTION (23-33-12-14) ~ LDWG TAPE+LIS (31-04-11-14).~' v 1 5DWG TAPE+LIS ~%~V~[i~LDWG TAPE+LIS Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 3770.03' 3789.01 6183.01 6492.00 Received by: Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 _ AX to (907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK,. 99501. Date: 6 October 1995 Transmittal of Data Sent bv: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION ~~% K-07 (23-33-12-14) ~_~\~ K-11 (32-33-12-14) %~\~\ K-O1 1 CN/GR FINAL BL+RF ' 1 PDK FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 CN/GR FINAL BL+RF 1 CN/GR FINAL BL+RF ECC No. Run ~ 1 3770.03 Run # 1 3789.01 Run # 1 5832.04 Run # 1 5967.04 Run # 1 6189.01 Run # 1 6492.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: ./~/~~~~---~te: R CE VED OCT Alaska Oil & Gas Cons. Oommissio~ Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PLS FINAL BL + RF 1 PLS FINAL BL + RF 1 CN/GR FINAL BL + RF 1 PLS FINAL BL + RF 1 PFC/PERF FINAL BL+RF 1 CN/GR FINAL BL +RF 1 PLS FINAL BL + RF Date: 1 December 1994 Transmittal of Data Sent by: MAIL Run # 1 .. Run # 1 ECC No. 4952.03 5089.04 Run # 1 · 5770.02 Run # 1 ~ 5788.06 Run # 1 5803.07 Run # 1 5811.05 Run # 1 -. 5867.06 Please sign and return to:" A~~as Wireline S vi~~ces 56.0~_ Street / Anchorag _~kK 99518_ Attn ~~D. P~lson ~~o (~o~-78o~ Reoeived by: Date: BP F_XPLORA~90N ' TO: HOUSTON ARCO C~EVRON E.~C~ON TET. AC0 MOBIL PH~LLZP S STA~ OF ALASKA ARCH1-VES INDEXED BP Exl31oration (Alaska) 900 East Benson Boulevard MO. Box 196612 Anchorage, Alaska 99519-6612 (9O7) 561-5111 Date: 05-05-89 80036 REFERENCE: BP F~AL DATA - PP. ESSURE S%'R~Y DATA The following material Is being submi~rt'ed herewith. Please acknowledge receipt by signing a copy of ,';'h;is .lel-I'er and returning It to this office: A-33 BHP--Static Gradient 04-27-89 Camco C-04 B~P--Static Gradient 04-30-89 Camco K-O1 BHP--Static Gradient 04-26-89 Camco M-05 BH~--Static Gradient 04-26-89 Camco N-09 BHP--Static Gradient 04-27-89 Camco S-07 BHP--Static Gradient 04-30-89 Camco S-15 BHP--Static Gradient 04-25-89 Camco U-06 BHP--Static Gradient 04-25-89 Camco W-22 : BHP--Static Gradient 04-26-89 Camco X-09 BHP--Static Gradient 04-29-89 Camco X-15 BHP--Static Gradient. 04-27-89 Camco W-20 BHP--Static Gradient 04-28-89 Camco Gas Cons. Commission Anchorage- Rece I ved Date Shirley R. McCurry I NFORMAT I ON CONqqROL Wei I Records LR2-1 S~o.da~d Alaska ~rocluclion Companl 900 Eo~ 8e..son 8ouk P.O. Anchorage. (~7~ 564-5 1 i I INO£XED TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA ARCHIVES REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA STANDARD ALASKA PRODLJC TION 07/13/88 D~te: 79086 ¥1: The following material Is being submitted herewith. Please acknowledge recelpt by signing a copy of this letter and returning if fo this office: · E-18 E-26 E-27 G-04 G-24 ~-K-01 K-12 N-06 R-07I W-39 Y-05I Z-06 Flowing Gradient 06/23/88 Camco Static Gradient 06/26/88 Otis Static Gradient 06/24/88 Otis Static Gradient 07/02/88 Camco Static Gradient 06/24/88 Otis Static Gradient 06/26/88 Otis Static Gradient 07/02/88 Camco Static Gradient 06/23/88 Otis Static Gradient 06/20/88 Otis Static Gradient 07/01/88 Camco Static Gradient 06/21/88 Otis Static Gradient 07/01/88 Camco Alaska 0il & O, ss Ce. nc. C0mm[ssi0~ Race ! veal Date A u-;~ of Ihe o,;9;,~ol S,ondo,d O~1 Co,'npon!, Fou~:led ;n Cle-elond. O~;o. h.~ 1870 Jennifer Dietz I NFORMAT I ON CONTROt Wel I Records hR2-1 Standard Alaska ~' Production Company~ 900 East Benson Boule,ora PO Bo. 196612 Anchorage AIo~,l~o 99519.6612 1907/ 564.511 I TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA INDEXED STANDARD ALASKA PRODLJCTION Date: 09/21/87 TI: 78183 REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: ~B-27 Flowing/Gradient 09/07/87 ~ B-27 " " 09/13/87 ~B-28 Static Gradient 09/06/87 ~-B-29 Flowing Gradient 09/10/87 "'J-21 Static Gradient 09/12/87 ~"J-23 " " 09/10/87 -- K-1 " " 08/21/87 '"Y-20 " " 09/03/87 ~"Yv20 " " 09/06/87 "Y-21 " " 09/08/87 -~ Kuparuk State 22-11-12 Static Gradient Camco 1! Camco Camco Camco Camco Camco Camco Camco Camco 08/26/87 Camco Rece I ved Date · Alaska Oi! & G~s Cons. commisslozl Fou,~dtd ,- (h".elo.d O,,n ,n ILRTO Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 Standard Alaska Production Compar' 900 lost Benson Boule.~d P.O Box 196612 Anchoroge, Alosko 99519-66 I (9071 564-511 I . DALLAS ARCO cHEVRON EXXON TEXACO -TO: MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES INDEXED STANDARD ALASKA PRODUCTION 'Dote: 05/21/87 TI: 77919 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signlng a copy of thls letter and returnlng it to this offlce: K-1 CH/CNL 05/18/87 #1 11250-11934 Sch 5" D-18 Work-Over Pump-in Temp 05/07/87 #- 10800-11200 Otis 5" Rece i ved Da te A un,! ot lhe or,cj,nol $)o~dord ~.~1 [o,.p.n7 Founded ,n Clev~.lond C~,r, ,,~ IHT~ Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TEXACO TO~ SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS STATE BPAE (Transmittal Only) ]1 1 ~ "¢:" STIIEET ANCltOflAGE. ALASKA fELEPI[ONE (9071 265.0000 MAll_ POUCH 6-612 ANCHORAGE. ALASKA 99502 Date' 3/27/85 T#: 76080 REFERENCE: .. .SO .~.O FINAL DATA- PRESSURE SURVEY DATA .~/~-~ll%~g material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- K-1 K-6 X-24 X-26 Static Gradient & BHPD Flowing Gradient & BHPD Static Gradient Static Gradient 3/1-2/85 Camco 3/6-8/85 Camco 2/27/85 Otis 2/28/85 Otis RECEIVED DATE Alaska 0ii & Gas Co,Is. Commission Anchorage : Cathy Perkins LR 2-1 Development Geology ,9 Well Records SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CIIEVRON EXXON To: SFO/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS STATE OF AK BPAE 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-6 ! 2 ANCHORAGE, ALASKA 99502 Date: 3/18/85 T#- 76062 REFERENCE: ~HIO CASED HOLE FINAL LOGS . /The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: Spinner 3/1/85 11600-11920 ~1 Camco 5" Alaska 0il & Gas Cons, Commi~.~or~ Anchorage l')^ Ii Development Geology INDEXED SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON TO: SFO/UNIT/STATE: TEXACO (-Mar a thon) MOB IL PHILLIPS .STATE ' BPAE (Transmittal Only) 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: T#: 3/5/85 76035 REFERENCE: SOHI~NAL DATA- PRESSURE SURVEY DATA llowing material is being submitted herewith. Please acknowledge receipt by signing a f this letter and returning it to this office:-- H_8~/ H-17 L. H-18 H-19 H-20'~ K-3~ K_6~- K-2A M-17 M-17~ N-18 Q-3 ~' R-9~ R-10 S-8~ PBU & BHPD 1/31-2/2/85 Go Flowing Gradient & BHPD 1/30-2/1/85 Camco PBU & BHPD 2/3/85 & 2/4/85 Go PBU & BHPD 2/5/85 & 2/6/85 Go Flowing Gradient & BHPD 2/2-2/3/85 Camco Static Gradient 2/6/85 Camco Static Gradient 2/8/85 Camco Static Gradient 2/10/85 Camco Static Gradient 2/12/85 Camco Static Gradient 1/4/85 Otis Gradient & BHPD 1/17 & 1/19/85 Camco Flowing Gradient 1/17-1/18/85 Camco PBU & BHPD 2/7 & 2/8/85 Go Static Survey 12/2/84 Go Static Gradient 2/18/85 Otis PBU & BHPD 2/14 & 2/17/85 Go PBU & BHPD 2/9 & 2/11/85 Go RECEIVED DATE _:~:C.:~ ~Q~:athy PerKins ....... , -.~ . .~- _ . '" ' ~ ~ evelopment Geology " ,9 Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 February 8, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well K-1 (41-33-12-14) PBU Enclosed, in duplicate, are the following forms for the above-named well. . e , Form 10-407, Completion Report; Form 10-403, Sundry Notice and Reports on Wells; Form 10-404, Monthly Report of Drilling and Workovers. JAB/J~/~jmw Enclosures cc: A. E. Leske Well Records Drilling Well File #17 Yours very truly, ~iS tA~ 1Bc~apgge ~ r o~l~m En~~ginee~~(A~ct ing) R CEIV£D A!aska Oil & Gas Cons. Commis~.~on Anch~ra?a ~. ALASK IL AND GAS CONSERVATION , IMISSION 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 SOHIO ALASKA PETROLEUM COMPANY 83-121 3. Address 8· APl Number P. O. Box 6612, Anchorage, Alaska 99502 50-029-20998 4. Location of well at surface 9. Unit or Lease Name 1626' SNL, 1091' EWL, Sec. 04, TllN, R14E, UPM (corrected) Prudhoe Bay Unit At Top Producing Interval Top of Sag. R. Sst. 10. Well Number 1151' SNL, 865' WEL, Sec. 33, T12N, R14E, UPM K-1 (41-33-12-14) PBU At Total Depth 11. Field and Pool 906' SNL, 620' WEL, Sec. 33, T12N, R14E, OPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 61.12' AMSL] ADL 28300 1-2. Date Spudded8_12_83 13. Date I.D. Reached8_31_83 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns9--6--83 feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 12043 'MD-9135 ' TVD 12000'MD-9098 'TVD YES [] NO [] 2991 feet MDI 1964 ' 22. Type Electric or Other Logs Run DIL/SFL/BI-iCS/GR/SP, FDC/ClXrL/GR/CAL, LDT/ClxlL/CAL/GR, Gyroscopic survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20x30 Insulated Conduct(,r Surfac~ 110 36 18 cu. yds. concrete 13-3/8 72# L-80 Surface 2816 17-1/2 :3900 cu. ft. ArcticsE:t II 9-5/8 47# L-80 Surface 11259 12-1/4 133 cu. ft. Arcticse~ I; *250 cu. ft. Class G squeezed 7 26# L-80 .10980 12043 8-1/2 396 cu. ft. Class G ~'/18% salt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) MD TVDSS SIZE DEPTH SET (MD) PACKER SET (MD) · , Prudhoe Oil Pool Top: 11812' 8871' 7"/5-.1/2" 10918' 10918' Bottom: 11887' 8937' w/4-1/2" tailpipe 11034' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11,812 '-11,887 ' (8871 ' -8937 ' TVDSS) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11119' *250 cu. ft. Class G squeezed through EZ Drill at 9-5/8" s -. 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) January 29, 1985J Flowing ,. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD I~ Ii:low Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24~HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips· R.F_C '/VF.D Alaska 0ii & Gas Cons. C0mmJssi0n ,Anr:h0ra.~e loc Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. 29 '.. . GEOLOGIC MARKERS ' ' FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB SUBSEA Sag. R. Sst. 11335' 8457' Shublik 11398 ' 8511 ' Ivishak 11441 ' 8548 ' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ /~B~~ Acting District ~~/~ ~ Signed Title Petroleum EngineeDate INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ALASKA01L AND GAS CONSERVATION COwiMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator SOHIO ALASKA PETROLEUM COMPANY 3. Address P. O. Box 6612, Anchorage, Alaska 99502 4. Location of Well COMPLETED WELL At Surface: 1626' SNL, 1091' EWL, Sec. 4, TllN, R14E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 61.12' AMSL 6. Lease Designation and Serial No. ADL 28300 OTHER [] 7. Permit No. 83-121 8. APl Number 50- 029-20998 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number K-1 (41-33-12-14) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were perforated January 29, 1985 using Gearhart 3-3/8 Tru-Jet guns at 4 s.p.f. A lubricator was installed and tested to 3500 psi on all well work. 11,812'-11,887' BKB (Ref. BHCS/GR, 9T2-83) An SSSV was set and tested in the ball valve nipple at 2991'. vt,~o, C0rrlmjSsi0, 14. il hererp~certify Cond~t/o~ of Approval, if any: that the foregoing is true and correct to the best of my knowledge. Acting TideDistrict Petroleum Engineer Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PERFORATING DATA - WELL K-1 (41-33-12-14) PBU January 27, 1985: Pressure tested tubing and inner annulus. January 29, 1985: Rigged up Gearhart and perforated the following intervals using 3-3/8" Tru-Jet guns at 4 spf: 11,812'-11,887' BKB (Ref. BHCS/GR, 9-2-83) Put well on production. February 4, 1985: Shut well in to prepare for static pressure survey. February 6, 1985: Ran static pressure/temperature survey at 8800' TVDss. February 7, 1985: Set and tested SSSV in ball valve nipple at 2991'. Well on production. STATE OF ALASKA ALASK~'~-~']L AND GAS CONSERVATION C'-'-IMISSION ,- ~' MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~] Workover operation [] 2. Name of operator 7. Permit No. SOHIO ALASKA PETROLEUM COMPANY 83-121 3. Address 8. APl Number P. O. Box 6612, , Anchorage, Alaska 99502 50-029-20998 !4. Location of Well 9. Unit or Lease Name at surface Prudhoe Bay Unit 10. Well No. 1626' SNL, 1091' EWL, Sec. 04, TllN, R14E, UPM K-1 (41-33-12-14) PBU 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe :Bay KBE = 61.12' AMSL ADL 28300 Prudhoe 0il Pool For the Month of February , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data Aia~ka 0il & (4as '" See Attached. -17.~hereby certify that the foregoing is true and correct to the best of my knowledge. '~/~' (~~//~('~Av/~, Acting District SI~j.~JED \, TITLE Petroleum Engineer DATE NOTE--R~)/pl)rt on this form is required~oll;/each calendar month, regardless of the status of operations, and must be fi[led ~- duplicate with the Alaska Oil and G :onservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 1 4 Submit in duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 December 17, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Wells K-l, K-2A, K-3, and K-6 Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perforate these wells. James A. Bragg District Petroleum Engineer (Acting) Enclosures cc: A. E. Leske Geology Well File 917 RECEIVED DEC 1 Alaska 0i~ & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA ~'~-'"- AND GAS CONSERVATION CC dlSSlON SUNDRy NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Sohio Alaska Petroleum Comply 3. Address P.O. BOX 6612, Anchorage, Alaska 99502 4. Location of Well At S~fac~: 1626' SNL, 1091' EWL, Sec. 04, TllN, R14E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBV. = 61.12' AMSL 6. Lease Designation and Serial No. ADZ, 28300 7. Permit No. 83-121 8. APl Number 50-029-20998 9. Unit or Lease Name P~dh~ Bay Unit 10. Well Number K-1 (41-33-12-14) PBU 11. Field and Pool Prudhoe Bay P~dhc~ Oil Pul 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimu late [] Abandon [] Stim u lat ion Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be perforated in December, 1984 wing 3 3/8" Sc~llops at 6 spf. A lubricator will be ir~talled and tested to 3500 psi for all well work. 11,812'-11,887' BKB (Ref. BHCS/GR, 9-2-83) An SSSV will be set ~d tested in the ball valve nipple at 2991'. RECEIVED DEC 1 919 tm Form ~o.l S igT h ~:~w~f o r C/om~i~~ to the best of my knowledge. Title Dis~crigt ?etroleum Enginee. r Conditions of Approval, if any: Approved by ~pp rovc~ Cop~. By Order of COMMISSIONER the Commission Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 October 8, 19 84 Alaska Oil & Gas Conservation Con~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: WRT,T, K-1 (41-33-12-14) peri, it No. .83-121 Reference is made to your request dated October 4, 1984 for well cuttings samples on the above-namsd well. Although this was the' first well drilled on K Pad, well K-1 was not cored. Therefore no core chips, drill cuttings or mud logs are available for this well. Yours very truly · R. H. Reiley District Drilling Engineer cc: Well File #17 RECEIVED OCT 1 1 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND 8AS ~,ONSERVATION.COMMISSION Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA gg501.1-31 g 2 TELEPHONE (907) 279,-1433 --.. DATE: ~ ....... TO: ~oc. ~ed, ~ ' ' We ~ ~o b~ ~o ~ou~ a~e~on ~ha~ ~e go~%s~on ~as no~'~ which our records indicated was completed_ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. C. V. Chatter Chairman lc:C.024 Bill Sheffield Governor ALASKA OIL AHD GAS CO#$EftVATIO# CO,M, A~iS$10Y 300! PORCUPINE DRIVE ANCHORAGE,ALASKA 99501';'3~19 2 TEL EPHONE (907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed ~?-Z~_~-g,~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Chairman Bill Sheffield Governor ALASKA OIL A#D GAS CO#S££VATIO# 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501;-3'192 TELEPHONE (907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed ~?-O~-J~3 . Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, C. V. Chat~ Chairman INDEXED SOHIO ALASKA PETROLEUM COMPANY SFO ARCO · CHEVRON EXXON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO: Date: 12/21/83 GETTY MARATHON MOBIL CC#:.. 74908 PHILLIPS STATE OF AK BPAE (Transmittal Only) .E~E~ENTRAL FILES (CC#' s-Transmittal On. ly) /q~IO F!NAL DATA- Open Hole Finals /The material is being submitted herewith. Please acknowledge receipt by signing a following U/ copy of this letter and returning it to this office:-- · ~. K-1 Mudlog 8/12-31/83 EXLOG depth: 117-12,043 '4/82) RECEIVED DATE Vicboria Aldridge Development Geology Well Records TP1-5 SOHIO ALASKA PETROLEUM COMPANY TO: State of Alaska · · REFERENCE: 3111"C°'STREET ANCHORAGE. ALASKA TELEPHONE 19071 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 11-17-83 CC#: 074826 SOHIO MAGNETIC LIS TAPES AND LISTINGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- : · ACC# _. 68669/- 10-2-83 '.Run i i ~3 / ]-83 ~ 7~'/- ? ~ TDT ' 686 TDT 6867]' DeveloF~_nt Geology An-hn~nnn DATE RECEIVED K-l? O.H. 68536 z//~. 9-2-83 Run 1,2,3-~/~37 ~5.'- - Om'. '- 68662~-/' 10-16283 - ~ 1,2 10-12-83- Run 1 - Run - 10-7-83 Run 1 . '",~ 10-11-83 ~ SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET , ANCHORAGE, ALAS~A'-"~ TELEPHONE (907) 276-~111 MAIL: POUCH 6-612 ANCHORAGE ALASKA ~9~ October ?, Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton ?~T'.T'. 'K-1 ' (41-33-12-14) PBU Kindly ch .ange your copies' of Form 10-407, Well Completion Report, for the aboVe-named well to sh°w the correct bottom hole location (total depth) to' be 906 ' SNL, 620 ' WEL, Sec..33, T12N, R14E, UPM. Very truly yours, District Drilling Engineer \ mc~ cc: Well File %17 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 September 30, 1983 Alaska Oil & Gas Conservation Conmt~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton -W~',T. 'K't ' (.41-33-12'14)' 'PBU Enclosed, in duplicate, is Form l0-407, Well Completion Report, for the above-namedwell together withthe Well History, Well Logs and Directional Surveys. This well has been completed as a non-perforated oil well. Very truly yours, encs cc: Well File ~r17 Geology R. H. Reiley District Drilling Engineer INDEXED SOHIO ALASKA PETROLEUM COMPANY .... SFO ARCO CHEVRON EXXON '- 311'1 "C" STREET' ............... ANCHORAGE, ALASKA ~ .. TELEPHON£'igo~) 265L0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 TO: SFO/UNIT/ GETTY Date: 10/3/83 STATE: MARATHON MOBIL CC#.:. 74744 .. PHILLIPS * STATE OF AK BPAE (Transmittal Only) R6FEREN~:ENTRAL FILES (CCI!' s-Transmittal Only) _ /~HIO OPEN HOLE FINAL LOGS ' /The following material is being submitted herewith. Please acknowledge receipt by signing a {.,,/ copy of this letter and returning it to this office:-- * Date to State Via Drilling: 10/3/83 SFO/UNIT/STATE: K-1 DIL/SFL K- 1 BHC S K-1 LDT/FD'C/CNL K-1 LDT/FDC 8/14/83& #la 8/24/83 #2 9/2/83 #3 8/14/83& #1& 8/24/83 #2 9/2/83 #3 8/24/83& #2& 9/2/83 #3 8/24/83& #2& 9/2/83 #3 120-2820 2814-11239 11248-12021 120-2786 2814-11208 11248-11987 2814-11241 11248-11991 2814-11241 11248-11991 Sch 5" & 2" Sch Sch Sch 5" & 2" Sch Sch Sch 5" & 2" Sch 5" & 2" STATE ONLY: DIRECTIONAL SURVEYS: Magnetic Single Shot Directional Survey Gyroscopic Directional Survey Date: 8/12/83- Jobl/:AL883D17 8/24/83 Date: 9/9/83 3ob#:AK-BO-30099 RECEIVED DATE E LVEr ~/~~~- ~.~l, Victoria Aldridge TP1-5 ,~C, -9 :~,~., Development Geology 19 ......................... , . ~ell Records AlasKa Oil & Gas Cons. Gommmmo. Anchorage STATE OF ALASKA ' ALASK;~,~'L AND GAS CONSERVATION;-.~..,~_.'A MISSlON 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 Sohio Alaska Petroleum Company 83-121 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20998 4. Location of well at surface 9. Unit or Lease Name 1626' SNL, 1091' EWL, Sec. 04, TllN, R14E, UPM (coxr_e~4~d~ Prudhoe Bay Unit At Top Producing Interval ~::)p of Sag. R. Sst. LOCATIONS 10. Well Number VERIFIED K-1 (41-33-12-14) PBU 1151' SNL, 865' WEL, Sec. 33, T12N, R14E, UPM At Total Depth Surf.. _?~ 11. Field and Pool 1-3Ug~SNL, 620' WEL, Sec. 33, T12N, R14E, UPM B.H...~- Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial ~0. P~oe Oil Pool KBE = 61.12 ' AMSLI ADL 28300 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Cusp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 8-12-83 8-31-83 9-6-83I feet MSLI One 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost !12043'MD-9135 'TVD 12000'MD-9098 'TV[ YES ~ NO []I 2991 feet MD 1964' 22. Type Electric or Other Logs Run DIL/SFL/BHCS/GR/SP, FDC/CNL/GR/CAL, LDT/CNL/CAL/GR, Gyros~pic survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20x30 Insulated Conduct )r Surfa¢~e 110 36 8 cu. yds. concrete 13 3/8 72# L-80 Surface 2816 17 1/2 39'00 cu. ft. Arctics~t II 9 5/8 47# L-80 Surface 11259 12 1/4 133 cu. ft. A~-cticset I; *250 'cu. ft. Class G. squeezed.. 7 26# L-80 10980 12043 8 1/2 396 cu. ft. Clas~ G ~/18% salt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7"/5 1/2" 10918 ' 10918' ~/4 1/2" tail.pipe 11034' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 11119' *250 cu. ft. Class G squeezed ~Trough EZ Drill at 9 5/8" st 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED~, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr.) Press. 24-HOUR RATE ~I~ . 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29'. , . 30. ' ' ~ GEOLOGIc MARKERs. - FORMATION TESTS , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB SUBSEA Sag. R. Sst. 11335 ' 8457 ' Shublik 11398 ' 8511 ' Ivishak 11441 ' 8548 ' 31. LIST OF ATTACHMENTS Well History, Well Logs and Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge J ~+.~j R. H. Reiley ~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". WELL K-1 (41-33-12-14) PBU WELL HISTCRY Spudded well at 2245 hours August 12, 1983. Vertically drilled 17 1/2" hole to 1200', kicked off and directionally drilled 17 1/2" hole to 2830'. Ran surface open hole logs. Ran 68 jts. 13 3/8" 72~ L-80 Buttress casing to 2816'. Cemented with 3900 cu. ft. Arcticset II cement. Installed and tested BOPE. Cleaned out to 2772', tested casing to 3000 psi, okay. Drilled out to 2846', ran leak-off test to 0.65 psi/ft, gradient. Directionally drilled 12 1/4" hole to 11274' .' Ran intermediate open hole logs. Ran 276 jts. 9 5/8" 47~ L-80 Buttress casing to 11259'. Started pumping first stage cement -- returns came to surface through open ~D. V~i- packer collar at 2728'. Displaced all cement out of hole. pumped l_~cu, f~t. Arcticset I cement preceded by 212 bbls. Arctic Pack thorough D. V.; D. V. would not close. Installed 9 5/8" packoff; tested BOPE. RIH with R~ p~Ck~r, 'se-~- in' D. V. and closed D. V. ports. Tested casing to 3000 psi, ok. RIH and set EZ Drill at 11119'. Established injection rate. Sting into EZ Drill and squeezed away 250_ c~. ft. class G cement. Drilled out EZ _ Drill and cement to 11184'; drilled out shoe. Directionally drilled ~ 1/2" hole to 12043'. Ran open hole logs. Ran 26 jts. 7" '~26~' L-80 IJ4S liner to 12043'. Cemented with 396 cu. ft. Cla~-~ G cement with 18% salt. Cleaned out to 12000', tested liner to 3000__psi, ok. Changed well over to NaCl Ran CBL. Ran 260 jts. 7" 26# '~ I~4~/5---1/2" 17~ A/B Mod Buttress ~PC tubing with 4 1/2" tailpipe assembly to 11034'. Landed tubing with ball valve at 2991'. Installed and tested tree. Displaced tubing to diesel, set packer at 10918'. Tested tubing to 3500 psi, okay. Released rig at 2200 hours on September 6, 1983. Ran gyroscopic survey, tested and secured well September 11, 1983. GR AT D;RECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY SOH_!O COMPANY K- I WELL NAME PRUDEIOE BAY. ALASKA. LOCATION AL883D17 SINGLE SHOT 8-25-83 JOB NUMBER LYNN HENSLEY TYPE SURVEY ENGINEER DATE NAME TITLE SIGNATURE 1200 11088 DEPTH INTERNAL FROM TO DATE SURVEY TAKEN 8-12-83 8-24-83 FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confi- dence. Additional copies of your survey report can be made from the orlginal by any blueprint company. GREATLAND D i RECT I FINAL DR I LC i NiB C:0FiPLET l ON REPORT' 200. UUBSEA :SEt::'~ l ON D i RE.F: '1-i i"3N DEPTH Fi l :':;'( ANGLE --e, 1. i '..-' iL}. UU (j. (-)i:~ i:kEL. A"[ .[ VE: L:LnL, t:~i't ','. i"qA'l-E.:-:; F RUi"I Wb. LL--Hb. AL O. (3U (J. (3U F:LOSURE Li j.'.=;'TANC:E DG: MN S (]. 00 0 0 (':~ LiUG,..b' -"t'. ,2 e _~ / i 0 (. 0. (30 ( .~_ 2:00 O C) i ..-~:C:,U. 0U l 13:'::. 88 U. UO ~'). OA ~..~,.'-"-"-_.,,. .... .5 l::: i :3:i:5. '-~2. ...'~ ',"74. :~:O ::: .... 7:3 N i i z t,:z0 'J~ 6 i 5 i :::. 7'7 i 45'J./:,5 Z:2:. 14 N Z4. 10 ~,/:::f/ .Ld ~Z .~/:'30. i7 i'/19.05 /e,. !U N 12. L-/.}:; i/ .::t) '! ':/ ~, '=:' 2¥ i, ........ i7 ].Z~ 07 N i2 50 .... : i :;:,~* 2:3:3e, 21:3i . ~:0_ 207o. :2',:3 i':'~,,_,._ . 6('). N i i . !0 .,:::.:~ '" o '.-2~, C, ~270. :32 Z',-.20'~.~. 20 247. 16 N i 4. :30 ;,dX, ...... .;. ¢-~ ..:; i /:', 2459 ,, ":).. 1 '::"="::)P~._, .. _,. 79. :34 / . ~:,2 N ). / . 40 ]:Z::,t:&~: :36:30 2562.9 i 2:50 i. '""'""/:¢ ~ ~ 5. 1 5 N 18 . '.::L::J'?8 ~:3 (..~ i:'/50. 'i 6 26:~:9. O~ 57 i. 50 N 20. :30 · .:',049 ~.~3 .::(:, 2:356.79 27'~:5.e, 7 6'?"~.';~6 N 21.7'0 :::4~ 7 '¢ :,0 ~::,. :3 :L :3C, . '90. :'::(')'7_ _ F;_ .7°,_, 1003 . '96. N .='":":'._,. :::c~_ _ :3';)4 i 5>2 o :3~Z/. :32 :3:366.20 i :l:/i, z. :3E: N · ~+ :3'7 ? ?, 3 ' '"" :'369:3 . z,:, .04 36:3i ?22 t707.84 N 24. i0 484i 5~') ........... :36 ::-:'.977 7[:, ~::'~)1~* (~ Z(')ZO ~'~} tNI ~/~.""C~.) t,".,249_:Z 4~:: ~2 4:d50. .... .:,"-"o ~ ..... ~ b":~ .2~i 2:3'P i . ZZ N 2'9.. .00 62:3'~ ~'/ z:, ~S)O0. ()~ ~ .... :,,:,.. :3 ! i N 67 ("~ 7 mB ..... ' ~2 i w. i 5 =, ' ~7'" '-'"" ,. ~ z .... 1 .. ,:,. 0:3 :3 ~ e,:3.0:3 N .:,~. 60 C,':~'2 i 49 0 5~06.0:3 5'.3~. 91 :3e, 7,5. :39 N :3~. 00 .... · _ ~ ~,:,. 0 D .:, ~; ._,. N 60 / t z~,,:? 4'~ :4( ) F,~i()9 1 '7 ~ ' '-' .... ""'"?=' 7:3 ':'":' , .- ..... . ._~-_,. 7496 50 24 ~yz"::.:) ............ 44 ~167t ':'":'= 4059' 97 N .--,Zoo. 8('J 79C)/-, 50 0 5994. F:'g, Dio-~-:, . ...... ,/- ,-,(' ............. 77 4372 ~:7 N .:, .... :,J 8221 4'9 12 61'99... 04 61:37. '92 46 t 0.27 N :36. UO' ..... O. UO O. OU O. O0 :=:. :34 N (~. 7 :=: F: :3. ":.'~2 ':."2. '? 1 N 6,. :i:4 ~ 2:3.72 :3:3.2:3 N i :3. :3:3 E ~0.49 /:3. 78 ~ 2~.zi ~ 77.66 122.56 N :=:=,.2:6 E Z27.53 it:5./5 N 48.46 E 1'~1.727 248. ~'7 N /:,2.60 E 256.23' :34 7. u9 N 'yO. :~:2 E :35'F/. 55 4i:3.56 N !1:L.85 E 428.42 q:¢ i. :35 N i 33.55 E ~'9'~. 54 564.77 N 16Z.02 E 587.55 667.].3 N ~01.:32 E 696.84 'Pc, 7.96 N :327.47 E 1021.85 12'9'7. i ';~ r'4 ~'7 i. :30 E 1:380.15 i 6 i 5 o,,.., o o / o . oo N 6 i i. ~ '-" E i 727. ~'~' 1':~¢65. i5 N 766. 12 E 20'90.59 '2':Z2'9 ~+5 N 9 i 4 75 E 24(')9. ,. I 245'7.08 N 1040.15 E 2~!,68. i7 26~,i. 9'2 N i i52.. 30 E 2900.62 2859.00 N i26i.76 E Gi25.05 :3i61.68 m i443.63 E 3475.67 3:}40.41 N 156i.04 E :3687. I7 343'9.88 N 1627.62 E 3805.51 :3656.90 N ~7:30.72 E 4067.42 3909.13 N I96'9.41 E 4377.20 410t.21 N 2~i:3.10 E 4613.58 0 0 0 N 11 30 (:) N 16 45 4:3 E N 19 1':' · _, :3 i E N i6 :3 ":' N 14 37 21 E N 14 8 z.._,'-'=' E N 14 37 54 E N 15 7 60 E N 15 30 N 16 027 E N 16 47 31 E N 18 4i 27 E N i9 ..,o'-'~ .:,'":' E N 20 43 45 E N 21 --.~°'"' 5i m ...... N 22 Ic ..... ' ,-, .:, 1E N 22 56 39 F: N "?-'~.o 24 .-'._,"= E N 23 48 48 E N'24 32 o.] -N-'-.-,'"~'- 2 51 E N z..:,'-'~-~ 1:=; ;L,:,'"'" E N 25 57 49 E N 26 44 "-'( N 27 15 ":'=' ..g, ._'i E o. Z. 42~ .::. 2. :3 i 'i, i. ~2'.. ~.-., :3. 0. ~5: 0.4it 0.3i~ 0. 0 i' O. 0. t5~ 0. O. 30( 0. :34': 0.09:: 0.25, RECORD OF SURVEY · ;~EA~.J~ DR i FT TRUVERT .c2;UBF~EA SECT i Or~ 0 i RECT i O~'~ REUAT i VE COORD i NATES OEP-i"H DG f~N DEPTH DEPTH DIS"( ANOLE F'ROP'~ WELL-HEAD ~,-,,o.:38 N 10 E .... " 8~3 N 2272.~0 E .......... u'::'¢ /:::;40 4 Z ¢2, 70 i. 7 :i: 6 ~,40. 6 i t'; i '72. i ~ N :3 ~,. 10 E ~ 557.4'? ¢4 Z 64 '7. :~: :5 E · ->'.:'w i..~.. ~. ~2 b'920.32 685'~. 20 5:39~. 7'9 N ._,._':'~;. 40 i 47:'::9_.. 2:::: N 2578.72 E '~;';::~? i z~ ], i :::: 7:2,~,9, b6 /Z?>:~:. 54 5:~:() i. :36 N :34.70 ~ 5073.90 N Z:b~ i :3.0:3 E i0:2;(:,4 :3',3 Z4 7722. '76 /c,~,l 6~ /;,iQ2 ]. ():-::~ ............. ~:, .i~ t-, :~:0 7/",, 0~, F:(] 14 '~)4 6:~:8,:1:7 .:. ~. ():3U.:J:.::: 4:3 8:30'::~ ,42 ::;Z4:~:, "'.:,0'" 6521 CLOSURE D i STANCE '¥:~:78.45 N 27 45 5t7:3.27 N 28 .... ":~=' '-'P 33 .~ o; .J. .... ¢-,-: 71 N Z:=: 45:37 i 58U i. .... ~ ....... 6521 40 8-25-8:3 DOG L~i O. O. U, '.52~ 0.6'.:".' (~. 7 '? SOH IA K- 1 DATA iN"I'ERPOLATED FOR EVEN I00 FEEl- OF SUB:_.;EA I'~EF'TH 8-25-83 MF_AS. 62 :362 562 c, 62 , , .- i C, ~ J. ": 2 .L 'Y O M :d 00 2. 6 4 27' 7 7 29 i2 2:056 :'3'.Z 10 3677 :3997 TRU VER"F D E F' -I" H :36,2 46,2 %i- ':' i 06, 2 ~ :[62 -i ~,i i :2: &, i i4ai If c,]. 17i~1 i86, i 2: i C, ]. 226 i 2:36, i 246i ,,-:~ ~ . 276 ! 286,1 2961 :3061 :3 t 6 i :336 i · _,4 :,1 SUB SEA ' MD-"i'VD VER'T l _.AL DEF"F H D i F'F. CORRECT (3 i 00 0 0 200 0 300 0 400 o 0 500 0 0 600 o 0 7uO 0 0 %:00 0 i 000 0 0 1 1 O0 0 0 i 200 1 1 i :300 i i ~ 00 i 0 ]. 500 :3 2 16o0 5 .... . 1700 / '2 i :BOO :l. :L 4 i 900 i 4 3 2000 :Z i 7 :2 i 0("3 29 2 200 :39 i 0 ' 2 :q (') () ~" ....... ,.:. i 4 24o0 ' ''¥ t:,~ i 4 2500 8. / 20 . 2600 i i 6 29 2700 151 '"'= .... :~._,' 44 ~ yo0 2.49 o4 ....o(3' ~ (.){.) .~,'"" :':: 1 (')(") ""~' _ . . .~, 3200 ~ 16 =;"'._:Y 3300 475 ="-._,~ :3400 536 6 i Rt~LA-i" i VE COORO i NATES FRFiM WELL-HEAD 0. O0 O. O0 0. O0 0. O0 0. C) O (:). 0 C) 0. (:) 0 0. 0. (:}0 t':). 00 0.00 0. O0 0.00 0.00 0.0 0 0.00 0. O0 O. O0 0. O0 0. O0 0. O0 0.00 o. 00 0.00 o. 79 N 0.07 E 5.43 ~'~ l.l:3 E i4. ':~':, N :3.94 E 29.2S) N 'f~,70 E ' ~7 7'":' .o3 E . ~ N 16 c,,Y "~"~ N '>'R 1,~ E ,{) ~. -:, ..... o N ~,_,'""n' i ":'":' ~._,. 14 N :3:5 '""- 157.7:3 N 42.79 t'98.70 N 5i .),:, E ~,:: N 74 :3~8.6 i N 91 ~i'-"' 34 N 11i.~5 E m:,:~..07 N Z.:,._,, ~o [ ..... ,: 5'7~.8.7 N Z6.5.78 E. ' ' 671.7 6 N .-:,~ (,..._,c,. ~ ~ E 77° 9? N ""' ..... ~ ~,. 69 E 886.:i:7 N 2'~1.98 E ':995.04 N 33'F)..40 'E 107. ~'""._,o N o,;,~'-":":'. ,.,0~" E 22i.29 N 438.38 E 1._,o7.52 N 4,~,~.7~ E SOH i 0 K-1 DATA 'iN'TERF'OLAYED FOR EVEN 100 FEET ;-dF SUB:SEA DEP'FH 8-25-83 4327 ....?c:: '/9 ?'23L~ /5~ t 7698 / 854 8 t 6:3 8918 9064 'i'RU VERf SUB SEA MD-TVD VERTICAL i.] ~..P "1 Pt DEF:"I'M D l FI:-- CORRECT .:,._, '-, t :':: 75 (') (') 6 f) 1 :,._, :'36, ,':, 1 9:600 d, 66 65 :37 z:, i 2:70~') 729 d,:3 ::::-3 d, i :2:800 791 62 35; ~, i ..:, x 0 .) ,=,'-" ._,=""'.o 6, 2 4 i ~i, i 4 i 00 ~ ;2__~-. i 420 () i 018 ._~.%" 4:2: t:, 1 4300 i 06, 9 51 446 i 44()0 1120 ti i ' "= t ._,61 4500 1' ' "" 4 · ~,~.,/-,_ _ I 4600 i 2 i ,_,c' 4-9 4 761 4- 700 i iZ66 4:3 4:'::6. i 4::::(~0 1:313 47 49 z.:, t 4-'.{, 0 ~/) "" z: '"' 506 i 50o0 i 4 i I 49 · _,'=' 16. i ._,=' 1 (')0 1460 49 526 i 5200 ~ =; - i.. i0 50 5 :':: 61 5:3 ~,:~ ~-) 1 ._, 546 i 5400 i · .~..., :, 1 5500 i 669 54 .56b i 5600 1 '725 56 576 t 5700 17 :::: ('~ "' =' 5861 5:300 1 ,=,,:, 7 ._7=; - ._, Y6,1 .5'.:}00 1 ,:, :...:~ /:.,A/-, i 6A 00 . - - ::' '~r ,.T., ._ ._! 6 i 6 i 6 i O0 ::'dQ02 62/-, 1 /-,2¢)¢) .... '"] = = F, ":' =,.:,.61 6300 '":' C "'" · ' 1 .),ri ~,.~ 646i 6400_ :,._~61 6.=;AO 22(i)8 49 6.66 i 66()0 .... ..' ,:. ..., /' "' = -' 49 6'76 i o/0 3 46 6861 /-,:::(")('; '-' '"'' .... · .' ._',46 43 6":~6 t 6'7700 '"'""'~' - - ., .~,~ RELA'I"i VE CI30RD i NA'TES FROM W[ELL-MEAO 1457. i'.:.) N ~]--.-;, i ._ t, . 40 N 1696.2:3 ;'4 i:i:i'"/,'. 42 N 15)2e,. 40 N 2033,72 N 2138.09 N 22~(]. i4 N 2:3:'::9. 22 N 24::::i:. i 6 N 25:2:.5.78 N 2632.52 N 2727.88 N 2822. :37 N 2'~i7. i1 N · :,312. i0 N 3106.83 N 3202.00 N 3297.65 N 3393.3t) N :3490.87 N 3588.20 N 3684.53 N 3780.75 N 3876.76 N 397i. 69 N 4065.70 N 4i58.66 N 4251.34 N 4343.49 N 4433.24 N 4=;'-' ~. 84 4607.33 N 4690.50 N 4771.66 N .541. 13 E 57~4.35 E 647.90 E '7(52. O1 E 756.91 E :=:i0.53 E :~65.03 E ?)20.68 E '~;75.42 E i02S'. 78 E i083.24 E i i 36.20 E :L i88.58 E i241. i8 E 1 ~':~4. ?}2 E i350.90 E - i408.97 E i469.57 E t 532.38 E i 596.63 E 16,':,i. 99 E 1730.28 E i80i. :'3<2 E i873.37 E 1945. l'~ E 20i6.21 E 2086.54 E 2155.93 E 2224.42 E ' 229I. 80 E 235'7,25- E' 2421.86 E 2484.07 E 2543. 260i. 70 a S O H i CI K- 1 DATA INTERPOLATED FOR EVEN 1OO FEET OF SUB'.E;EA DEPTH 8-2.5-83 ;'flEAS. DEPTH 9487 ':) t- -5, '~' 9'758 '~:~ 89:3 0024 015 ~ 02E:4 0537 0062 0'787 0'/~ 09 l O :30 i'RU VERT SUB F;EA MD-i'VD VEtA]'ICAL DEF'TH £ EF TH D i F F · f':F~RRECT 7061 7o00 2426 2:9 7 i e, i 7100 2462 :36 7261 7200 2497 :35 7:2:6 i 7:::00 25:32 :35 '.7461 '7400 256,3 31 7561 7500 25S):3 '.30 7e, 61 7600 2623 30 776 ~ 7700 2651 28 7861 7800 2676 25 7'761 '7900 2701 25 806 i 8000 2726 25 8161 8100 2748 22 826 i 8200 2769 2 i RELAT i VE COORD Ii~iA'i'ES FROM WELL-HEAD 4850.30 N 4926.68 N 5001.28 N 5074.93 N =i" ' '" · · . 14~ _ N 5'..:'i3. ':-:'1 N 5280.04 N · _,.:,44.27 5405.03 N 5463.94 N "-"---,o 97 N 5574. '97 1'4 5627.29 N 2657. i:3 E 271(i). 65 E 2762.64 E 2:313.75 E 2862.59 E 2911.20 E 2959..~' · _L-, E 3006.86 E 3052.70 E :3098.30 E 314.'3.62 E -:3i8'7.70 E 3231.79 E :SOHIO K-1 DATA INTERF'OLATED FOR EVEN 1000 FEET OF MEASURED DEF'TH FiEAS. DEPTH : o0o :3000 4000 6000 '70(.)(-) 8000 0000 ! TRU VERT SUB SEA RELATIVE COORDINATE::_; 'F~EPTH DEP]"H FRFJM WELL-HEAD 10(}0 ?):37, 0.00 0.00 i '~)85 1924 28:24 2'76:3 6:33.39 N 3464 340:3 1:33?2.8'}~ N 48~/. 82 40 7'~? 4018 2054. :32 N 82 i. 10 54 i 2 5:351 :3:346.05 N :t 564.84 6055 57':~4 :3'966.69 N 2012.47 /!,7 i 7 6656 45'70.41 N 2457. ~ 7 7442 7:381 .... ~t N = ........ 1 82:36 :~J 175 5614.73 N :3221.08 . Notes t SOHIO : All v~lu~ In fe~t. DQpth~ shown or~ TVD. CIo~ure: B521 ft at N 29 d~g 55 .lin E Bottom holQ~ TVD 830§ TMD 11088 MQ§n~ic de¢]lnobion: 31 de~ 30 m~n E FlOR I ZONTAL V I EW SOHIO K-! RADIUS OF CURVATURE SINGLE SHOT SURVEY SCALE: 1 inch: 1000 DRAWN: 8-25-83 A X VERTICAL SECTION SOHIO SOHIO K-1 RADIUS OF CURVATURE SINGLE SHOT SURVEY SCALE: 1 inch = 1500 Feet DRAWN: 8-25-83 ' ql. 75 0 L 0.75 1,50 7,58 CUSTOMER : SOHIO LOCATION : PRUDHOE BAY, ALASKA WELL PAD : K WELL NO. : 1 DRILLING CO. : AK UNITED CUSTOMER JOB NO. : 114625 RIG NO. : 3 TELECO JOB NO. : 309-AK MAGNETIC DECLINATION : 31.30 E PLANE OF PROPOSED DIRECTION IS : N 29.26 E SURVEY REPORT PAGE TELECO OILFIELD SERVICES OF ALASKA, INC. 6116 NIELSON WY., ANCHORAGE, ALASKA, 99502 TEL : <907) 562-2646 DATA REDUCED BY RADIUS OF CURVATURE METHOD TYPE OF SURVEY : MAGNETIC START DATE : 08/12/83 FINISH DATE : 08/24/83 REPORT PREPARED BY : PAT HAVARD MEASURED DRIFT TRUE VERTICAL. DRIFT DEPTH ANGLE VERTICAL SECTION DIRECTION DEG MIN DEPTH DEG MIN TOTAL COORDINATES CLOSURES DISTANCE ANGLE DD MM SS DOG - LEG SEVERITY DEG/100 FT. 1200 0.00 1200.00 0.00 1336 3.18 1335.94 3.72 1427 6.00 1426.64 10.87 1520 9.06 1518.84 22.98 1615 11.18 1612.34 39.69 ].787 13.42 1'780.26 76.08 1880 14.54 1870.38 98.16 1973 17.30 1959.69 123.08 2065 20.42 2046.62 151.82 2157 23.42 2131.80 184.89 2310 26.06 2270.58 246.64 2526 31.06 2460.22 347.22 2650 36.30 2563.26 414.81 2674 40.48 2582.01 429.50 2896 43.00 2747.25 575.32 3049 48.36 2853.91 683.87 3172 50.12 2933.96 776.55 3479 50.06 3130.68 10].0.94 3941 52.00 3421.11 1368.49 4379 53.18 3686.84 1'714.98 N 11.00 E N 11.30 E N 18.30 E N 24.06 E N 21. 18 E N 12.54 E N 13.36 E N 12.30 E N 11.30 E N 11.06 E N 14. 18 E N 1'7.24 E N 18.06 E N 17.24 E N 20.18 E N 21.42 E N 22.42 E N 23.48 E N 23.24 E N 23.48 E 4631 51.36 3840.42 1914.02 N 24.48 E 4851 50.36 3978.57 2084.86 N 26.12 E 5262 48.42 4244.67 2397.96 N 29.00 E 5609 48.].8 4474.60 2657.84 N 28.42 E 5924 47.24 4685.99 2891.36 N 28.42 E 0.00 N 3.84 N 10.97 N 22.35 N 37.87 N 73.45 N 95.81 N 12]..09 N 150.53 N 184.62 N 247.46 N 346.93 N 412.63 N 426.90 N 567.21 N 669.61 N 756.08 N 972.63 N 1301.88 N 1620.94 N 1803.03 N 1957.57 N 2235.15 N 2462.78 N 2667.63 N 0.00 E 0.76 E 2.67 E 7.11 E 13.60 E '24. 29. 35. 41. 48. 62. 91. 112. 116. 164. 203. 239. 332. 476. 615. 697. 771. 916. 1041. 1154. 55 E 82 E 67 E 93 E 74 E 91 E 15 E 18 E 75 E 65 E 96 E 24 E 28 E 12 E 52 E 74 E 45 E 56 E 96 E liE 0.00 3.92 N 11 14 59 E 11.29 N 13 41 59 E 23.46 N 17 39 02 E 40.24 N 19 45 33 E 77.45 N 18 28 53 E 100.34 N 17 17 07 E 126.23 N 16 24 56 E 156.27 N 15 33 56 E 190.95 N 14 47 23 E 255.34 N 14 15 45 E 358.70 N 14 43 12 E 427.60 N 15 12 31 E 442.58 N 15 17 41 E 590.62 N 16 11 12 E 699.99 N 16 56 24 E 793.03 N 17 33 31 E 1027.82 N 18 51 42 E 1386.21 N 20 05 18 E 1733.87 N 20 47 35 E 1933.33 N 21 09 19 E 2104.09 N 21 30 31 E 2415.77 N 22 17 49 E 2674.13 N 22 55 56 E 2906.58 N 23 23 42 E 2.426 3.026 3.422 2.373 1.747 1.304 2.815 3.496 3.265 1.798 2.414 4.366 18.009 1.320 3.718 1.440 0.277 0.417 0.306 0.744 0.672 0.695 0.132 0.286 JOB NUMBER : 309-AK CUSTOMER : SOHIO PAD : K WELL NO. D R ILL I NG : 1 REPORT PAGE MEASURED ~RIFT TRUE VERTICAL DRIFT DEPTH ANGLE VERTICAL SECTION DIRECTION DEG MIN DEPTH DEG MIN 6238 47.06 6707 48.42 6991 49.00 7149 49.30 7496 50.24 7653 50.12 7906 50.00 8221 49.12 8567 48.54 8820 47.30 8978 46.42 9291 44.42 9544 43.06 9891 41.18 10138 40.18 10364 38.24 10460 37.30 10805 35.06 11088 33.48 11189 33.12 BOTTOM HOLE CLOSURE: PRINTED : 4 SEP, 1983 8:30:08 PM 4899.13 3121.94 5213.56 3469.77 5400.45 3683.08 5503.58 3802.40 5726.86 4066.60 5827.15 4186.31 5989.43 4378.66 6193.59 4616.47 6420.36 4875.74 6588.99 5063.00 6696.55 5177.83 6915.15 5400.25 7097.45 5574.74 7354.51 5806.72 7541.49 5967.19 7716.25 6109.42 7791.95 6167.93 8070.00 6369.69 8303.36 6527.00 8387.59 6581.51 6582.14 FEET AT N 29.24 E N 32.36 E N 34.00 E N 33.36 E N 36.48 E N 37.06 E N 36.48 E N 36.48 E N 36.06 E N 36.06 E N 36.48 E N 35.24 E N 35.00 E N 34.42 E N 36.06 E N 36.24 E N 37.30 E N 38.54 E N 41.00 E N 41.42 E N 30 3 16 TOTAL COORDINATES 2869.20 N 1266.07 E 3167.48 N 1445.30 E 3346.21N 1562.71E 3445.68 N 1629.29 E 3662.73 N 1782.41E 3759.27 N 1855.02 E 3914.38 N 1971.69 E 4106.46 N 2115.39 E 4316.67 N 2270.65 E 4469.06 N 2381.78 E 4562.16 N 2450.54 E 4743.16 N 2582.53 E 4886.51N 2683.65 E 5077.79 N 2816.84 E 5209.35 N 2910.34 E 5324.91 N 2995.07 E 5372.09 N 3030.56 E 5532.60 N 3156.86 E 5655.32 N 3259.66 E ~5697.17 N 3296.49 E CLOSURES D I STANCE ANGLE DD MM SS 3136.12 N 23 48 36 E 3481.64 N 24 31 36 E 3693.13 N 25 01 58 E 3811.47 N 25 18 25 E 4073.40 N 25 56 56 E 4192.04 N 26 15 50 E 4382.91 N 26 44 04 E 4619.30 N 27 15 16 E 4877.44 N 27 44 42 E 5064.12 N 28 03 19 E 5178.65 N 28 14 32 E 5400.65 N 28 34 01 E 5574.94 N 28 46 31E 5806.77 N 29 01 07 E 5967.19 N 29 11 27 E 6109.43 N 29 21 22 E 6167.95 N 29 25 43 E 6369.89 N 29 42 31E 6527.49 N 29 57 31E 6582.14 N 30 03 16 E COPYRIGHT (C) 1983 ABACUS COMPUTER SERVICE 820 W. 71st AVENUE ANCHORAGE, AK. 99502 ( 907 ) 344-0761 DOG - LEG SEVERITY DEG/100 FT. 0.190 0.610 0.386 0.370 0.752 0. 195 0. 121 0. 254 0. 176 0. 553 0.601 0.715 0.642 0.522 0.549 0. 845 1. 173 0. 736 0. 622 0. 707 September 20, 1983 Mr. Gary PlisqFa Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Re: Our Boss Gyroscopic Survey Job No. A/<-BO-30099 Well: K-1 (SEC04 TllN R14E) Prudhoe Bay Field North Slope, Alaska Survey Date: September 9, 1983 Operator: E. Sellers Mr. Plisga: Please find enclosed the "Original" and sixteen(16) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity robe of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures OHIO ALASKA PETROLEUM -1 (SEC04 TllN R14E) RUDHOE BAY LASKA ......... : .................... SF'ERRY%$UN. WELLSURVEYINGCOMF'ANM ANCHORAGE ALASKA ERT ICAL SECTION CALCULATED' · ALONG CLOSURE P_AGF___i INC DATE OF oJRVEY SEPTEMBER 09, 1983 · ~YRu.:,CL P.I SURVEY~ .... ,, _C:.OMPUTATION DATE ................. BOSS -' '- .... -i F't AK-Bo-oO0 ~ SEPTEMBER 12, 1"'"~' ~.,:.,:, ,.lOB NUMBER .....' e- KELLY BUSHING ELEV. = 61.12 FT. ............................ OPERATOR-... E. SELLERS "' ' ~"" "'F : ]'RUE :-';UB-SEA L. UUR,:,E L. JUR.:,E · . EASUREI] VERT I CAL VERT I CAL I N ..L I NAT I ON D I RECT I ON IEPTH DEPTH DEPTH DEG M I N DEGREES DOG-LEG TOTAL SEVERITY RECTANGULAR COORDINATES VERTICAL' ) DEG/100 NORTH/SOUTH EAST/WEST SECT I ON 0 0.00 100 100.00 200 199.99 300 299199 400 399.98 '500 499.97 600 59~.95 700 699.93 800 799193 900 899.92 1000 999.92 1100 1099192 1200 1199.91 1300 1299.76 1350 1349.58 1400 1399.30 1450 1448.85 1500 1498.21 ... 1550 1547.38 1600 1596.39 1650 1645.26 1700 1694.01 i750 1742.61 38.88 138.87 < .... >:37 338.86 438.85 538.83 638.81 738.81 838.80 938.80 1038.80 1138.7~ 1238.64 1288.46 1338.18 1~o7.73 C) ...... (} ............... N ..... 0" .... O"E 1437, 0 "~' S ~:6 1, ~() W C) o~ S 12.89 W 0 37 S 15.30 N 0 52 S 20.19 W 1 4 . S_26.'~'~ ~ .. ...... i~.,.. W 1 4 S 35.10 W 0 ~-.M'~' S~,~"-"~'. 5£) W 0 27 S 27.89 W '0 10 S 35.30 W 0 4 S 79.30 W 0 6 S 40.50 E 1 34 N 21.30 E 4 21 N 21. 0 E 5 I .25............ N ....19. 50 E 6 41 N,:"'1,60 E 8 29 N 22, 0 E .................. ~ o E ............ 10 ~M,.,':' N 18 .39 E 11 48 N 1:'...,. 60 E ....... 12..... ~[ 5 ....... N _.1.3. ,39_ E ......... 1486.26 1535.27 15:34.14 1632.89 1681.49 1729,.95 1778.26 1826.30 1~00 1791.07 1850 1 ,:,o.'. 38 1900 1887.42 ...... 19.50 . .1935.05 ....... 1873:. 93 ............ 18 ..... 33 . ."4 2000 1982.18 1921 06 20 '~ 2050 2028.78 1967.66 ~o-., 3 2100 2074 87 '-" ........................................ ~ 01.3..~7.5-- ..... 2_8.~.3_1 ..... 13 10 N .12.30 E 13 54 N 10.50 E 14___36__ N !_l,.B9 E 15 18 N 9.89 E 16 50 N 10.89 E 0.00 C). 00 0.44 0.38 S 0.14 1123 o'-' 0~ Z. 21 0.27 o.'" 45 S ~ t~ I 5.01 .... 0.16 6.62 S 0.20 8.03 S 0.42 9,03 S 0.28 9.51 S O. 14 9.65 S 0.16 ~.74 S ...... 1.62 8.53 2.78 3.72 S 2.16 0 '~ - .~ N 2.60 5.22 N · :: ~° 11.35 N 0 ' 00 ........ 0 . 00 0.01 W -0.34 0.13 W -1.12 O. 37 W -2.09 O. 78 W -3.37 1.47.. W ........................ --5 ' 06 2.44 W -6.93 ~. 09 W -8.63 4.26 W -10.36 4.42 W -10.55 4.41 W -10.62 '"'l. · l o 85 W -'.~ 30 2. O0 W -4.21 1.33 E 5.17 3.79 E 11.69 · 2..78 ............. 18._.78 N ..... 6.67_E ............ 19.55 ............ '~ 36 27 31N 9 67 E 28.42 ~m m · 1.98 06.75 N 12 55 E '-"-' 1,:33 ............... 46,98 N .......... 15,.19_..E ..... 48.,14 ........ 1.28 57185 N 17.67 E ...... 5:3..7-$ 1.69 69.33 N 19.98 E 1...54 ..... 81._40_N _22..3Z__E 1.75 94.07 N 24.81 E 3.11 107.69 N 27.31 E N.. 1_0, 80_.E .......... 3, 44 N 10.39 E 3171 N 10.19 E 3.30 I~_Z_(}_~_.3 (}I._E.__ ............ --':' l._92 ..... -.. :~. 62. N ...... 30.17l.l,g 139.01 N 33.24 E 156l 82 N 36.47 E . 175.88 mw N ................ ;..qg_.Z2_E_ 69.80. 93.53 106.51 120.80 ............ 136.46 153.42 ....... oPERRY-..,LN WELL SURVEYING COMPANY ..........................' ............................................................ PAGE ....2 ANCHORAGE ALASKA iHIO ALASKA PETROLEUM INC. DATE OF SURVEY SEPTEMBER 09. 1983 -1 (SIEC04 Tl lN IR14E), I]:C~MPLITATION DATE ........ BOSS. GYROSCOPIC SURVEY .................................................. ~UI]HuE BAY :=;EPTEMBER 12, 1;w:~;3 .lOB NUMBER AK-BU-o00~9 .A~ KA KELLY B.IoHING ELEV = 61 12 FT. OPERATOR. E..SELLERS .................................... :RT'I CAL 'SECT I ON bALL:L~ - ILATED' '; ALONG CLOSURE ............................................................................. 'i TRLIE :=:UB-SEA.. ' '-' I VERTICAL :AoL RED VERT i CAL :P]'H DEPTH DEPTH 2150 21'-"' '" = 39 ~0.51 ~0~,9. 22A0 2165.82 2104.70 · " ~.' ,.. 0 '-~'-' 10. cy - .~. ~ O 2149.78 2300 '-'~'~5 ~ ~., ~. 80 ~'? 1.94. 68 ~.:,. 0 2300 42 '2239.30 2400 '-'~' ~44.63 --,--,,:,o 51 2450 o.-,o,-, ~o,_,~. 18 2327.06 '2500 2430.77 236~. 65 ~, ~ ~ ,-, ,~, ~.._,v 2472. '-'~ ~Y ~411 · 17 2600 251~.° 7.9 ~-~1'~' A 5 . 67 '765A 2552 '"'- - - .oZ 2491 20 2700 2590.81 ~'"5°c~... 69 · -i ~ ' i i ~7.0 2628 4~ 2567 37 ~c, uC ~d, 6~,. 75 2604.63 · ~,,~r~ 2702 39 "'. . ~41 27 2~00 ~7,,=,. 17 2G77 0~ 2950 2772.89 2711.77 3000 2806.45 2745 . ~,~'-"~ .:,~._ 0 2839 16 2778.04 3100 2871 46 '~'~ . ~o10.34 3200 ~,o.-,M. ~.. ~. 54 2874.42 3300 2~.9~. 72 2938.60 3400 3064.2~ 3003.17 3500 .... 3128.67 3600 3192.68 3700 3256.03 3800 3318.26 3900 337~. 95 4000 3441.46 41 O0 .-,= - o · ~0~. 35 L. UURoE .......COl IR::;E DOG-LEG I NCL I NAT I ON., D I REI':T I AN SEVER I TY DEG M I N DEGREES DEG/100 ....... TOTAL ........ ' ~ I'~ ' _ .......................................... ')\ REL;.TAN_ULAR COORDINATES . VERTICAL ,. NORTH/SOUTH EAST/WEST SECTION ~4 40 N 10.60 E 25 22 N 1'; ~.39 I-- ='"=~,?,~1 N 13.60 E 26 21 N 14.8.9 E 27 15 N 16.10 E Mc.: 26 Iq 16.3.9 E 30 ..'::,c . . .,...Z N 16 89 E 32 46 Iq 17. 0 E 34 54 ...... N...1.7. F) E 36 ~-'-' -,~ N 16.8.9 E ~,=, 3:=: N 16.80 E 40 40 N ...17 ..... 0. E. 41 29 N 17. 0 E 42 10 Iq 17.89 E 4:3 .::'q N 1'-?. r) E 45 3 N 1.9.89 E 46 · _ o N 19.80 E ..48 4-1 _ N 20.89 E 49 34 N '-' ' .-.0.89 E 4'2 ~ . ~6 N 20.89 E 50 21 .... N 20.89 E ...... 0.40 49 48 N '71 19 E 0 60 .~ . . 49 45 N 21.:ac . ,_J E 0 46 2.08 1.41 1.52 2.08 2.40 3.89 4.82 4.26 3.92 3.54 ...... 4.09 1.62 1.81 .3.16 3.23 3.84 ......... 3.82 1.76 O. 74 ~-..-',1 1,o...,.., N 4o.6.~ E 190.71 ~1d,.68 N 47.84 E ~°10.67 237.74 N 52.71 ~5. 07 N 58 13 ._'],,~ o0o.'--"1~. Iq 70. 692 0z6.73 N 77.73 351.7~ N 85.36 378.39 N 93.5(3 406.42 N 102.04 435.72 N 110.91 ..... 466.25 . Iq 120.19 497.67 N 129.8(3 52~. 49 N 13.9.80 561.74 N 150.57 594.67 N 162.20 628. ~' . ~o N 174 41 66o. N 187.30 698.56 N 200.79 734.22 N 214.41 .. _805..94 N 241.79 877.51 N 269.34 i 74,:,. 56 N 297.32 E 231.26 E 252.36 E 274.11 E 2~6.72 E 320.53 E 345.95 E 372.9~ E 401.45 E 431.17 E . 462.15 S 494.06 E 526.51 E . 559.74 Z 593.99 E 62'2.31 E ........... 66~..Z5 .... E 703.01 E 740.62 E .........816.26 E 891.85 E 967.21' .... 0067 .... 50 ...... = _ · ~.. ~.1 ...... ~.1 __ 3131.56 50 18 0--1 ol.94.91 51 5 3257.14. ..... 51 .... 56. ..... 3o 18.83 ~ 1 52 ooo0.34 52 11 3441.z¢'*'-' N_ 21..50_E__ 0 . 40 N 21.39 E 0.22 N 21.39 E 0.79 N..21.10. E .......... 0.88 N 21.60 E 0.40 N 21.60 E 0.31 52 _ 47 ............ N_22.3'2 E .......... 0.87 1019.68 N ........... 325.55_E ........ 1042..77 ............ 1091.18 N 353.65 E 1118.58 1163.22 N 381.88 E 11.94.93 1236.18 N 410.25 E 1272.13. 1309.48 N 438.~0 E 1349.77 1382.78 N 467.~2 E 1427.61 1456.32_N. 497.64 E ......... 1506..0~ ......... L.]HIO ALASKA PETROLEUM INC. -1 (SE..C. O4.]'llN..R1.4E) ......................... RUDHOE BAY LASKA .............. S..P,,.E_R.~.X._-SI_IN WE.LL_S.L!RVEY I NG__.COM_P_.ANY PAGE 3 AI~CHORAGE ALASKA DATE OF SURVEY SEPTEMBER 0,O, 1,o83 I-':L,!!9 F_'!-_!T.!~T. I_0 .N.._..F-!A_T E ......................... BOSS. _G Y R O.S.C.O P_,!!::.... S_U R._V_.EY.. SEPTEMBER 12, 1,O83 dOB NUMBER AK-BO-300,O'.-] KELLY BLi~HING ELEV. =' ~1.'12 FT. .. ........... .O..P..ER ..A .T.O_R-__.E_,_.._S_E L L E_R S ERTIL. AL ~ .... :,EL.T'~ '~ .... I ON cALcULATED':' '~ ........................... ALuNuZ -:'-~:bLcg':~_~L'I-RE" EASURED EPTH DEPTH i ......... 4 .."U(.'-' ' ] .... 3562. TRLIE ~LIB-:,EA VERT I CAL VERT I CAL COLIRSE L. UUR.:,E DOG-LEG TOTAL INCLINATION ..... DIRECTION SEVERITY ...... REcTANGLILAR cOoR£[iNA]:Es ~-'~-i-i:]'~'I~- DEG MIN DEGREES DEG/iO0 NORTH/SOUTH EAST/WEST SECTION DEF'TH 6:3 .......... 350'i.. ~ ................ 1 53 3621.36 53 3681.88 52 3743.84 51 3806.62 51 386,O.~6 50 4400 3682.48 4500 3743.00 4600 3804.~6 4700 3867.74 4800 3,O31.08 4~00 3995.83 5000 4061.62 5100 4127.57 5200 4193.88 5300 4260.04 5400 4325.~8 5500 43~2.47 5600 445,O.20 5700 4525.?8 5800 4593.11 5?00 4660.52 6000 4728.31 6100 47~6.37 6200 4864.28 6300 4,O31.74 64.00 49,O8.,O3 6500 5066.17 6600 5133.05 6700 51,O,O.50 6800 5265.77 6?00 5331.89 7000 53,O7.74 7100 5463.01 7200 5527.62 3734.71 4000.50 4066.45 4132.76 41,O8.71 4264.86 4331.35 43?8.08 4464.86 4531.~8 4667.1,O 4735.25 4803.16 4870.62 4~37.81 5005.05 N ==. L4U E 0 .-'.-.'e_..1~,.:,0.~¢" 1 ~,84..94 4 '--'"-' ~'' 12 N ~,~='"~. ~,o 18 N '~" 50 E 0 14 1678.15 N .... ~.00 E 1743 36 12 ............... N_ ~'"' 30 E 1 26 1751 48 N 61~.~7 E 1822 21 1'*' ~ 24." ..... ou E 1 27 1~2~.29 N 651. 0 N 24.1~ E 0.21 lo94.26 N 683.60 E 1977.45 ~3 N 60_.E .................. 1 ~5 1~64 44 N 716 18 E 2054 48 46: 5:3 N 27.30 E 1.97 48 4,O N 27.8,O E 0.46 4.6: '::,3 N 28 1,O E 0 4,'-=:16 N~'~'~'o. 60 E 0 .48 48 52 N c..8.60 E 0.60 48 36 N '~'-' '-" .... ,. .......... .sc,. or) E 0. L~'.." 48 3 N '2:3.1'2 E 0.7A 48 13 N '-'-' ~c,. 10 E 0.18 47 ~'-' . · _o N 27.89 E 0.28 47 41 N 27.8~ E 0.2'2 47 ~ - ' ol N Z~:.30 E 0.o4 47 6 '"'=' . ......... .......... N._~,.,. :39 E 0.43 47 6 N 28.89 E 0.37 47 20 N 29.80 E 0.70 47. 4::: .....N._ 30.3'2 E. O. 65 47 45 N 30.50 E 0.09 47 44 N 30.30 E 0.15 2032.67 N 20,O,O.40 N 2165.74 N 2231.5,O N 22?7.43 N 2363.36 N 242,O.01N 24,O4.67 N 2560.39 N 2625.~0 N 26,O1.05 N 2755.75 N . 2820.04 N 2884.02 N ~2,O47.88 N 3011.73 N 3075.57 N 5071.93 .......... 48 _18 ...... 5138.37 48 24 N 32.30 E 5204.64 48 34 N 33.10 E 5270.77 ........ 48 .37 .........N .33.50 E 5336.62 49 0 N 33.1,O E 5401.87 4,O 30 N 34.10 E 5466.50 ...... 49 5~ ......... N....35.BO.E_ N _'31.60....E ........ 1.12 ......... 313,O.32 N 0.53 3202.73 N 0.62 3265.75 N 0.30 3328.45 N 0.43 33,Ol.32 N 0.85 3454.38 N 1.03 3517.12 N 750.10 E 2130.40 784.,O,O E ~05.60 ozv ..34. E .................. 2280 855.,O4 E 2355.47 8,Ol.84 E 2430.40 ,O27.,O3 E 2505.53 ._ ,O63.58 E 2580.17 ~,O8.72 E 2654.57 1033.66 E 2728.,Ol 1068.34 E 2802.,O4 1103.13 E 2876.72 1138.04_.. E .............. 2950.17 1173.17 E 1209.14 E 1246.16 E 1283.70 E 1321.15 E 1359.3,O_E ...... 13,O8.74 E 143,O.3,O E 1480.58 E ...... 1521.,O5 E 1563.93 E 3023.39 30,O6.76 ......... 3170.57 ............ 3244.64 3318.66 33,O2..,O~ ........... 3467.71 3542.55 3617.50 36,O2.68 3768.34 1607 38 E .... ~44..4~ ........................... SPERR,¥.-...SUN..~ WELL_, SURVEY_ING, COMPANY ANCHORAGE ALAoKA OHIO ALASKA PETROLEUM INC. DATE OF SURVEY SEPTEMBER 09, 1983 -1 . ( SEC04 T 1 I.N ..R 14E). i--.COHF_'UTAT_IC~N DA. TE ................................. BOSS... GYROSCOP._.IC_ SURVEY. .... RLIDHOE BAY SEPTEMBER 12, 1983 ..lOB NUMBER AK-BO-30099 LASKA . KELLY BUSHING ELEV. = 61.12 FT. OP. ERA....T.OR,._ E ...... SELLER_S __ i i% i--. -- I~l I~I - --, IIi - 1Ii, I RAGF____4 TRUE SUB-SEA ....... COURSE ..... COLIRSE........ DOG-LEG ............................. TOTAL ............... IEASLIRED VERTICAL ...... VERTICAL INCLINATION _DIRECTION SEVERITY REC:TANGULAR COORDINATES ~EPTH DEPTH DEPTH DEG MIN DEGREES DEG/100 NORTH/SOUTH EAST/WEST VERTICAL SECTION ..........7 c:"c.) 0 .......................................................................................................... ==~,., ,.. :.~ 1.71 5530.5"-,' 50 1 :--] N ,:.o'" = . ~-.'-:/ E 7400 5655. ~,oP4 ~1 50 7500 5719.87 5658.75 49 7600 5784. '-'= =~'~ ~, ~,/~c,. 1o 5(]) 7700 ='~ ~ '- 49 ~,~4,.,. 5~ 5787.41 7800 5912.86 5851.74 49 7900 ~, ~77.30 5916.18 49 :::000 6041 81 ~,:~,ar, 69 4~ 810C) 6106.68 6045.56 8200 6172.12 · 6111.00 8300 6237.76 6176.64 8400 6303.52 6242 ,-, ~ _ ~, - ,%, o~,00 6569,55 8600 64~6 07 6374 :3700 6503.17 6442 i~i-i ' ' I ,_,:,0o 657C) 86 A509 8900 6639.04 9000 6707.87 9100 6777.64 9200 6848.10 9300 6919.23 9400 6991.14 9500 7063.90 9600 7137.46 9700 7211.71 9800 7286.49 9900 7361.62 10000 7437.21 10100 7513.42 10200 7590.50 (.).44 o57~.62 N 1651.96 E 3920.98 13 N 06'~ .30 E 0.47 ~641~ .83 N 1697.16 E 3997.56 ......... ~ ~ ........... N ..._3.6 ,z30....E ..................... ~] ,.4C) ................. 3703 ....60... N ........... 1.742.~3_E ....... ~QZ~.,.S3 .............. 0 N o6.6,9 E 0.35 ~76~,.10 N 1788.05 E 4149.96 59 N .,6.,:,0 E 0.08 '":'~A '-"~'-'. · ~,.,~..48 N lo~ 88 E 4226 15 ...... .... , ..... N_37.._19_E ................... 0.31 388~..63....N ........... 1879 95 E 4302 25 49 N 36.89 E O.~=~, 3948.66 N 192~.03 E 4378.26 49 N 37. 0 E 0.08 4009.72 N 1971.96 E 4454.22 ......... 4.9 ....... 17 ........ N_36.89_._ 4:-] 58 N 36.60 48 58 N 36.89 .40 .........48 __46 .... N_36_. .43 48 34 N 36.80 .95 48 2 N 36.89 .05 .. 47 ...... .40 ........ N_$7. O_ .74 47 7 I',1 37.19 ......... ..'017..70._.E ......... 45.'9. ~_8_ ........... E ................... 0 .54 .......... ..4070.54 N '-' ' '-' '~- E O. 39 E O. 23 E ................ 0.20 ....... E O. 22 E 0.53 E ..... 0.38 ...... E 0.56 4131.13 N 2062.~5 E 4605.09 4191.58 N 2108.09 E 4680.11 4251.82. N ....... 2153.32_E ......... 4755.01 .............. 4311.91 N 2198.36 E 4829.69 \ 4371. 66 N ~.'~'~. 14 E 4903.93 ) 4430.9'.2_N ......... 2287.~_1_F 4977..6~ __ 448~.63 N 2332.11E ..... 5050.80 6577.92 6646.75 6716.52 6786.~8 6858.11 6930.02 7002.78 7076.34 7150.59 7225.37 7300.50 7376.09 7452.30 752~.38 46 53 ............ _46 ....... 6_ 45 23 45 1 44 _17. ...... 4.3 45 42 52 .... _42 23 _ 41 43 41 41 40 40 39 N 36.69 E 0.43 N._36 .... 89_E ....... _0..80 _. N 36.69 E N 36.30 E N_36. iO_...E ..... N 36. C) E N 35.8A' N_ 35.50_ N 35.89 28 N 36.10 7 ........N._35.89 39 N 36.19 1 N 36.80 6 N. 36.89 0.73 4663.53 N 0.47 4720.57 N 0.74 ..... 4777.29 N 0.54 E 0.88 E ...... 0.52. E O. 73 E O. 28 E O. 36 E 0.51 E 0.74 E O. 92 4833.47 N 486:9.04 N .. 4944.08 N 4998.48 N 5052.19 N 5105,57 N 5158.52 N 5210.55 N 5261.53 N 4548.09 N 2376.08 E .4606.18_N ........ 2412..53_.E_. 2462.44 E 2504.65 E ._ 2546.16 E 2587.06 E 2627.28 E 2666.76 E 2705.85 E 2744.87 E 2783.67 E 2822.19 E 2860.70 E 2898.90 E. 5123.53 _5.195..66 5266.89 5337.50 5407.46 ........ 5476."66 5544.98 5612.47. 5679.21 5745.32 5811.04 5876.23 5940.64 6003.98 SPERRY.SUN WELL .GL RVEYING ...COMPANY_ .................. P_ AG E.__5. __ ,. ANCHORAGE ALASKA 0 H I 0 '=< '" ALA..KA PETROLEUM INC. DATE OF SURVEY SEPTEMBER 09, 1983 -1 . (GEL;U4 T11N. R14E) ............... COMP..UTATION DATE .............................. BOSS L~YROolZ. UPIt; ~.LRVEY. RUDHOE BAY . . SEPTEMBER. 12, 1983 LAoKA ERTICAL SECTION CALCULATEr-~ ALONG t;LO.:,URE , ............ TRUE ....... SLID.SEA .............. COURSE ...... --..._COURSE ........... DOG.LEG ..... EASURED VERTICAL VERTICAL INC:LINATION ..... DIREC:TION SEVERITY EPTH DEPTH DEPTH dOB NUMBER AK-BO-30099 KELLY BUSHING ELEV. = 61.12 FT. .ORERA.T..OR_-___E. _SEI. I .ERS_ .... DEG .,MIN ................. DEGREES ..................... _TO.T.AL ........... RECTANGULAR COORDINATES VERTICAL DEG/iO0 NORTH/SOUTH EAST/WEST .......... SECT. ION 10400 7747.16 10500 ........ 7826. 10600 7907. i 0._, t~ O' '--' ' 76/=,;,'='. 41 7607. .~... c? 2~ ,.4'- 7686.04 37 10700 7988. 10800 ..... 8070. 10900 8153.30 11000 8236.06 11100 8319.22 · ].I200 84-03.17 11300 8488.13 11400 8573.88 11500 8660.21 11600 8747.14 11700 8834.47 11800 8921.98 11900 9009.74 12000 9097.67 12043 9135.48 ~,'- N 3 E 0.60 ~,~11.56 N 2936.67 E 6066.2~ ¢o. 0 E 1.12 5860.38 N 2974.27 E 6127.46 - '-"-' '"~ ' 'J~' 5 ] '-' ] ........ :=:5 7765.73 36 47 ~.__¢o.~ ri. E ............ ~_ .... ~.o ....... ~4~ 7,_70_N ....... c,t 1_! 83 E 6187.33 .... ,4~L4.62 N 3049.08 ,E .......... 6245.85· 49 7846.37 '-'M ~ 43 N 39 19 E 1 08. = ='- 89 7927 77 35 18 N 39 80 E 0.== 5498.44 N 3086.02 E 6303 25 ~3-. ...... :=:A¢~. 7~ ~- __?-'~ N 41.3"FC_E ............ 1_._12. 55~1_._~6_N ..... ¢'*'~ m'~ ~ 6359~3 ...... ~ ............ ;':~_ ~ ~ ,_,(.)9.~. 18 8174.94 c,-* ..,o... 10 ....... ~ ~,4~. 05 ~:2 26 N 43.60 E 1.04 ..,707.30 N 8427.01 31 16 N 4.9 '~' ' .~2 E 3.47 5743.49 N ~--~ ~ .--¢ .............. -- -- ............................................ c,~, 1~. 76 30 ~8: N 49.. 0 E 0.74 5776.97 N '='='-"-' 09 ~ 58 N 47 30 E I0'~y 5810 63 N 8686. ' '-' 0~ 2~ 16 N 46. 0 E 0.95 5844.55 N 8773.¢'~ ?e 2 N._43 69 E 1 14 5879.08 N · ~ ~ .... ~ ,- ..................... m m .................. 8860.86 28 51 N 43.10 E 0.35 5914.24 N qO~,-, - _ ~..~o.62 2E: ~6 N 42.60 E 0.48 5949.39 N '~036 MM '-':~ '-'~ N 42.60 E ........... 0._00..~_ 5984_..44_N · ~ ~ ~ ........... ~ _.__~ .' ................ ~074.3~ 28 26 N 42,60 E 0,00 599~,52 N 34 13 N 40.80 E 0.54 5584.58 N 3160.50 E 6415.36 34 4 N 42. 0 E 0.69 5626.69 N ~' ~ 197.62 E 6470.53 · -i ,--I i~?_1 ........ ~c,. _. _23 ....... N._42 ,.80_ E ................0. o 1 .........5667_, 69_.N ......... 3235., 06 E ...... 652_4_._.~_1 3272.25 E 6577.97. 3310.58 E 6628.67 3349.~;_.E_ .... ~677.~.1 ........... 3387.23 E 6725.56 3423.17 E 6773.09 .3457.53_.E ......... 6820.._33 .... 3490.78 E. 6867.55 3523.38 E 6914.42 3555.._62_E_ 6~._0_3 3569.48 E 6981.07 ~ DEG .... 45.._MIN. EAST_AT MD = HORIZONTAL DISPLACEMENT? ..... 6981..0Z ..... EEE%_A%__NOR~H..O .... 120~3_ ,, THE C:ALC:ULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ....... SPERRY=SLIN WELL, SURVEYING_, COMPANY ................................................................ ~AGE_,_,6 ................. ANCHORAGE ALASKA OHIO ALASKA PETROLELIM INC. DATE OF SURVEY SEPTEMBER 0.9, 1.983 -1 (SEC04 T11N R14E) COMRUTAT. ION DATE RUDFIOE BAY SEPTEMBER 12, 1.983 dOB NUMBER AK-BO-300.9.9 LASKA KELLY BUSHINO ELEV. = ,61.12 FT. : .......... OPERATOR.."_. E .... SELLER.S. ........................................ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH EASURED EP_._TH ...... TRLIE .... :=;LIB-SEA ................................. ]:C;TAi].- ................................................................................................................ VERT I CAL VERT I CAE RECTANGULAR COORD I NATES MD-TVD VERT I CAE .......... BERTH ............................ DEP_T_H_ ......... ~.OR_~H/_ $_OLITH EA_..S.T..__/W ES.T__..D_ I E..F E R E N C:E ....... CORRECTION_ O 0.00 -61.12 0. OO 1000 9.9.9.92 .938.80 ........................ ?,_65__ S __ 2000 1982, 1E] 1921.06 13.9, 01 N 3000 2806.45 2745.33 663.24 N 4000 3441 46 '"""-' ' ................. . ...... ,..-,:,ot~..34 .............. 1382._7.8 N ...... 5000 406I. 62 4000.50 2099.40 N 6000 4728.31 4667.1.9 2755· 75 N 7000 53.97. 8000 6041. ?.)O00 6707. 10000 ........7437. 11000 8236. O. O0 0. O0 4 ..,4.2.._W ....................... 0,..0 8 ........................... 0 .. 08 ..................................................... 33.24 E 17.82 17.75 187.30 E 1.93.55 175.72 .... ~67_,,.72 ....E ................. 558,54 _364 ,_9..9. 784..9.9 E 938.38 37.9.85 1138.04 E 1271 . 6.9 333.30 .26 ....... ooo_. o,~ ................... l.,..o,~__j~ ...... ~_....,.,.. l .......... ~- ......... 1.602 ...................... 330_..57 ,=, 1 5980.6'.-? 400.9 · 72 N 1971 96 E 1.958.1 :37 6646.75 4606.18 N 241.9.53 E =='~"°°..=. 13 21 7376.09 ._,=~o.'~ '~ 52 N __2822.._1>~.E .256.2.._7.~? .......... 06 12000 90.97.67 ¢~,~,~ 62 E 2~02.33 .....1~''=04L4~ .. ............... ~:.~.=~.~ ....... ~_~Z.._52 355,93 _27Q,¢6 201.15 138.3.9 ........... 5~.~9. · , , THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL .RADIUS OF CURVATURE..METHOD. iOHIO ALASKA PETROLEUM i-1 (SEC04 T11N R14E) 'RLIDHOE BAY ~LASKA ~EASURED ~EPTH SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA INC. COMPUTATION DATE SEPTEMBER 12, 1.983 .......................................... ~AGE ...... DATE OF SURVEY SEPTEMBER 09, 1.983 JOB NLIMBER ' AK-B,DZ300'~.9 KELLY BUSHING ELEV. = 61.12 FT. .... OPERATOR~ E SELLERS INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRLiE ,-. _,:. · ..",LIB ..,EA TOTAL . VERTICAL VERTICAL RECTANGLILAR COORDINATES MD-TVD VERTICAL DEPTH ................ DE..P~ _H .......... _.N_O _R.'_T.H / ~.~! u T H EAST__/...WE~_T_ ..... DIFFERENCE .............. .C.O.RRECT_!_ON 0 O. 00 61 61.1'2 . . 161 161.12 261 261. i2 361 361.12 461 461.12 561 561.1 '.'.. ' ............ 661 ....661.12 ........ 761 761.12 700.00 ~1 861 12 800 00 .961 . .961.12 ...... .900_,_0_0 1061 1061.12 1000.00 1161 1161 1'" 1100.00 ......... l ........ -'"il '~ ........... 1261.. 1261 12 1..'-0¢.00 ~ . ,.,0 ~. O0 1361 1,.61 12 1o F 1462 14.61.12 1400. O0 .... 1_563 .......... 1.5~1 ,_12 ........ 150~.],_00 1666 1661 . 12 1600 . O0 1769 1761 . 12 1700. O0 -/:, 1.12 0. O0 0. O0 0.00 O. 00 ....................... 0..0.9_S .................. O, C!O.._.W ............................. O. 00 ...................................... 0.00 100.00 0. :::7 S 0.04 W 0.00 0.00 200.00 1.80 S 0.26 W 0.01 0.00 300 ._00 2,._8~_$ 0.._58. W ....................... 0.01 0.._0.1 400.00 4.36 S 1.14 W 0.03 0.01 500.00 6.02 S 2.02 W 0.04 0.02 600..00 .................................. 7,_52__S_._ .. _~'_.3..07_.W ...................... O. 06 ....................... O, 02 8,75 8 ....... .3,84 W 0,07 0,01 9.41 S 4.19 W 0.08 0.00 9,._64___S _4_,_3.7__W ....... 0.._.08__ 0..._00_. 9.68 S 4.46 W 0.08 0.00 ~.52 S 4.24 W 0.08 0.00 ...... _6 ,..1 l_S_ _ 2,_F~2._W 0.... 15 ........................ 0 1.32 N 0.16 W 0.48 0.32 13.06 N 4.4.8 E 1.2.9 0.81 .. 27...86__N 1.0_,_5LE 2,_88 1_..._5.'?-~ 50.44 N 16.01 E 5.13 2.25 73.86 N 20.83 E 7.95 2.82 OHIO ALASKA PETROLEUM INC. -1 (SEC04 T11N R14E) RUDHOE BAY " LASKA IEASURED ~EPTH SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE SEPTEMBER 12, 1983 PAGE_.8 DATE OF SURVEY SEPTEMBER 09, 1983 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH i SUB-SEA .TOTAL. _ ]'RUE VERTICAL VERTICAL RECTANGULAR COORDINATES IdD-TVD .DEPTH.' ....... DER.TH ................. NO.~TH/$OU~ ............ EAST/WEST ...... DIFFERENCE .. dOB NUMBER AK-BU-~Oc~. KELLY BUSHING ELEV. = OPERATOR- E. SELLERS 61.12 FT. VERTICAL CORRECTION o/= 1861.12 1977 1961.12 ~c,~, 2061.1'~' lY4 2161.12 z.~ 0 ~, 2261.12 ....... 2418 , <"~'~ . =~.~1 12 · -! ~ ~m · ~.o6 246.1 12 ~6=.1 '2561 12 · . . 2793 2661.12 2932 2761.12 3083 2861.12 ~40 2961 12 3395 3061.12 3550 '-' o161.1';' 3708 3261.12 3869 3361.12 1800 O0 100 02 N '-'= '-' . . .'-~,. o6 E 11.45 3.49 1900,. 00 ............ 131,36 .,. N ....................... 31,,~;....:-'" E . 16 43 4 99 2oo0 00 169 99 N ~:=: 85 E ~.~o 7.45 2100.00 214 .50 N 47. ~:6- E jc.:j. 68 ¢.o0'-' ' 2200.00 261.61 N ~'=' 80 E 44.82 11.14 2300 00 311 78 N 73. '~' - . . ~1 E 57.63 ~' 1~.81 2400. O0 370.97 N o~r)r, 00 442.47_N 2600. O0 525.49 N 2700.00 616.71 N ~,=,00,. 00 ................. 722..73_N ..... 2900.00 834, 78 N 3000 O0 . .. ~,. 08 N 3100.. 00 ~,z00.00 1~69.10 N 3300.00 1287.17 N ....... 4C)32 ........... 3461., o .1,= ............ 34C)0,._00 .... 1_406 .... 33_N_ 4197 3561.12 3500.00 1528.26 N 4364 3661.12 3600.00 1651.68 N 91.2-3 E 75.28 17.65 ..... 11.1"' ¢"5 ,E ............ 100, 15 ~4.88 138.51 E 132.63 32.48 170.16 E 171.69 3.9.05 _.210 o2 E ...... 222.81 51_._1~' .-., ~.....-, ~,-' · 81 E 278.97 56.16 295 93 E '-~'-":' ~'"' . ~¢. ~ 55.01 ___339., 78 __E .................. 389, 49 ......................... 55, 51 .... 384.18 E 446.99 57.50 430.07 E 508.36: 61.39 4ZZ.~5_E_ __.570~94_ 62._56,_ 527.22 E 636.36 65.42 578.03 E 703.14 66.78 OHIO ALASKA PETROLEUM -1 (SEC04 T11N R14E) RUDHOE BAY ': LASKA INC. ~PERRY-~LIN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPLITATION DATE SEPTEMBER 12, 1983 INTERPOLATED VALUES FOR EVEN .. PAGE 9. DATE OF SURVEY SEPTEMBER 09, 1983 dOB NUMBER AK-BO-30099 KELLY BUSHING ELEV. = OPERATOR- E. SELLERS 100 FEET OF SUB-SEA DEPTH 61.12 FT. IEASURED iEPTH TRLIE VERT I C:AL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR cOORDINATES MD-TVD DEPTH NORTHZSOUTH .............. EAST/WEST .DIFFERENCE VERTICAL ,') CORRECTION 4529 4689 4847 4999 5150 5301 5453 5602 5752 5900 6048 6195 6343 6492 6642 6792 6944 7097 7252 3761.i2 3861.12 3961.12 4061.12 4161.12 4261.12 4361.12 4461.12 4561.12 4661.12 4761.12 4861.12 4961.12 5061.12 5161.12 5261.12 5361._12 54.61.12 5561.12 3700.00 1772.95 N 629.21E 768.45 65.31 3800. O0 1886.80 N 680.25 E 828.35 59.90 3900.00 1997.02 N 731.87 E A'~= · .. ~o..,.89 57 54 4000.00 2098.90 N 784.73 E 938.13 ~,~=°. 24 4100 00 219'~ 28 N ~"~- '- . · o~,~.~5 E .... 989.62 .......................51.50 4200.00 2298.52 N 892.43 E 1040.53 50.91 4300.00 2398.~3~-' N 947.04 E 1091.94 51.41 4400.00 .... ..... ~496.5~._N ................. 999.73 E.. 1141 .77 49.'-'~z 4500. O0 z~=~'~;-~. 82 N 1051 .89. E 1191 .34 49.57 4600.00 2691.62 N 1103.44 E 1239.77 48.43 4700. O0 2786.80 N 11~ '"/- ~ ~ · . ',. c. :~ r- * 2:37..OS"' .................. 47 '~'" · . -'1 47.13 4,.,00.00 ~'-'q'-'~ c, · ~ 04 N 1207 44 E 1334. '~ 4900. 5000. 5100· 5200. 5300..0~ ................ 3356..15_N~. 5400.00 3452.55 N 5500.00 3549.72 N O0 2975.83 N 1262.57 E 1382.62 48.41 O0 ..........3070.77...N ............ 1318.3~.._E .............. 1431.37 ................... 48.75 . .n~ 49 71 00 3166.16 N 1375 91E 1481 ~_, . O0 3261.34 N 1436.52 E 1531.86 50.78 1_498~0_..F__ 1583.12 ............. 51...26 1562.70 E 1635.97 52.85 1630.50 E 1691.02 55.05 ;OHIO ALASKA PETROLEUM ]:NC. i-1 (SEC04 T11N R14E) 'RUDHOE BAY ,LASKA .... ~ ERRY-~UN ..WELL. SUR~E~I NG~ ...COMPANY PAGE_.i£~ ............. ANCHORAGE ALASKA DATE OF SURVEY SEPTEMBER 09, 1983 ............................... COMF'L;TAT I ON. DATE SEPTEMBER 12,1~.~.~'- dOB NUMBER AK-BD-oo09~ KELLY BUSHING ELEV. = 61.12 FT. OPERATOR- E. SELLERS INTERPOLATED VALUES FOR EVEN 1.00 FEET OF SUB-SEA DEPTH IEASURED iEPTH TRUE VERT I CAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH ......... EAST/WEST DIFFERENCE VERTICAL CORRECTION -) 7408 7564 7719 7874 8029 8183 5:335 :3487 8637 8785 8932 9076 9218 9358 9496 9632 9766 .9899 10031 5661.12 5761.12 ~,~61.12 5961.12 6061.12 6161.12 6z61.1~' 6361.12 6461.12 6561.12 6661.12 6761.12 6861.12 6961.12 7061.1'2 7161.1~'~ 7261.12 7361.12 7461.12 5600.00 3647.15 N 1701.07 E 1747.46 5700.00 074.-. 99 N 1771.56 E 1 ""-' ~U ..'-. 8.9 .... ,_-, .-., ,_-~ 5800. O0 :::~:3:::. 4.9 N 1 ,..4-.. ~..6 E 1858.46 5900. O0 '-"" ~ ~',::3. '"" 79 ,:.:.;-: N 1914.52 E 191'" 600A.O0 4027.98 N .............. 1985.72 E 1" ':' . .~6,... 80 6100.00 4120.98 N 2055.42 E 2022.13 6200.00 4213.05 N '2124.21 E 2074.48 '-' ] '" ":' 92 63 6,:,0¢ 00 4304 ,~6 N 1 E ~.126 1:3 . . a~. · m /:.400.00 '4393 .94 N 2259 .o:)'"/. E 2176' .34 6500.00 4481.27 N 2325.76 E 2224.56 6600. O0 _.4567.0_.1_ N ............... 2390..18 E ......... 2271.20 6700. O0 4/:.50.10 N 245'.'..'. 43 E 2315.35 6800.00 4731.07 N 2512.37 E 2357.30 6900.00 . 4810.21~N 2570.16 E 23.97.31 7000, 00 4,_,,_-,6, ..*5 N 2625 77 E 24~5, 08 7100.00 4961.67 N 2679. o'~1 E 2470.91 7200.00 ~,0._.4. c 7_ N. 2731 66_.~ 2505.02 ................. 34.11 7300.00 5105.23 N 27:33.41 E 2538.22 '33.20 7400.00 5175.0.9 N 2834.32 E 2570.40 32.18 56.44 55.42 55.57 55.33 55.01 53.32 52.35 51.66 50.21 48.22 46.63 ......................................................... 44.16 41..95 40. O1 ................- 37,77 35.83 :OHIO ALASKA PETROLEUM i-1 (SEC04 TllN R14E) 'RUDHOE BAY' ~LASKA .................. SPERRY.=SUN. WELL SURVEYING..COMPANY ................................ P_AGE_.'L1 ANCHORAGE ALASKA INC, ......................................... COMPUTATION._.Z~ATE _. SEPTEMBER 12, 1 ,, DATE OF SURVEY SEPTEMBER 09, 1983 dOB NUMBER AK-BO-30099 KELLY BUSHING ELEV. = 61.12 FT. OPERATOR. E. SELLERS ..................................................... INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 1EASLIRED IEPTH 10162 10290 10417 10542 10665 10788 10909 11030 11150 11268 113:35 ].1501 11616 11730 11844 11956: 12043 ] R JE ~LIB-~EA TOTAL ,! VERT I CAL VERT I CAL REE:TANGIJLAR COORD I NATES MD-TVD VERT I CAL DEPTH ............ D E F-'_'T'H .............. NORTH / SC!LL'[H ..... EAST/~.WEST ........ P I FFERENCE ................... CORRECT ION 7561 12 7500.00 ~' '~' · ~24..". 43 N 28:34.56 7661 12 7600.00 ..,c, tJ6~'-' ' . 94 N c,, .':,.:, · ~ ............... ~.~ ..... 16 7761 12 7700, O0 ~"-' '" ,~...~ N ~ ~o0.87 7861.12 7800.00 5427.61 N 3027.~0 7961.12 7~00.00 5483.34 N 3073.44 8061 12 :~000.00 ~]="" ~ - .... ,~... c, N 3118.88 8161.12 :~100_ .00 M~':'A._ ~ ._,,.. 61 N3163.97 8261.12 8200.00 ,563~. 29 ,N .......... 3208. ~6 8361 12 8300 00 =~' .... ,~ o7.86 N '-"-'='-' · :,~,.:,. 78 8461.12 8400.00 5732.~M~- N 32~8.17 8561.12 8500.00 5772..01_ N ........ 3343. ~3 8661.12 '~ ''. - . -- . ,.6UO 00 M~'10 9~ N 3~:~7 62 8761.12 8700.00 5850.00 N 3428.81 8861.12 8800.00 588~.78 N. 3467.75 8961.12 8~00.00 ~9'-~c~. ~._ · 98 N c,'-'='~, 0 ~ = . 49 9061.12 '~000. .00 5~6~. 88 N ~,~ ~4.'~'-' ~2'- ~135.48 9074.36 59~9.52.N .~ 356~.48 E 2601 01 ~¢' . ~ ). 61 E 2629.56 28.55 zc ...,o. 48 26.92 E ~o-'"/' '-'". 65 25.17 : 2704. q' 23.21 E 2727.08 22.22 E 2748.34 21.26 E 2769.14 20.80 -- 2789.00 19. :37 E 2807.22 18.22 = '"":'-")~ 05 16:32 . . E 26::39.93 15.89 '-~:~ . . . E ..~54 91 14 :-78 E 2869.36 .14.45 ,~o.,~.~. 5/:, 14.20 E 2897.32 13 · 75 E 29(.')7.52 10.20 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM. RADIUS OE....CURVATURE). POINTS T~UE NOBTH 0.00 // 000.00 I -1000. O0 3000.00 000. 0/' / O0 Sohio Alaska Petroleum Company Our Boss Gyroscopic Survey Job No. AK-BO-30099 Well: K-1 (SF£04 TllN R14E) Prudhoe Bay Field North Slope, Alaska Survey Date: September 9, 1983 Operator: E. Sellers Scale: 1" = 1000' Surface Location (1626SNL 1091EWL) 1000.00 I 2000. O0 3000. O0 -]000.00 HORIZONTAL PRO JECTION ., Suggested fo~.~ to be i~L~rte,] in eadT "Active" well folder to d~.eck for .tin~zly compliance wit~] our. regulations. : - O[~2~r~tor , "ell IQa;~ and N~nkcr and Haterials to be received by: /~- Reports Date Rcqui red Date Received RGnarks Ccmp letion Report Yes /~ Core ~scription , ,, .' ~ ~ .' _ Registered Su~ey Plat ~~ Drill Stm Test RemUs . ..~~ ~ _ , ,,- ......... ,~,~.~,.,~.~ Pr~u~ion T~t Re~rts ._- .- ____~'~/ ~s Run Yes SOHIO ALASKA PETROLEUM COMPANY SFO TO: ARCO CHEVRON EXXON GETTY MOBIL PHILLIPS STATE OF ALAS~ BPAE (Transmittal Only) CENTRAL FILES (CC#'S Transmittal onlyk 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE 1907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 .., Date: 9/26/83 CC#: 74736 REFERENCE: TELECO MAGNETIC DIRECTIONAL SURVEY (S) / /, /T~e following material is being submitted herewith. Please acknowledge receipt by signing a / copy of this letter and returning it to this office:-- K-1 Teleco Survey 8/12/83 to 8/24/83 Job # 114625 RECEIVED - . _ DA T E _ Victoria Aldridge TP1-5 Wells Records Dept. Development Geology TP1-5 MEMORANDUM State of Alaska TELEPHONE NO: Ch 9 - ~ ~ FILE NO: Thru: ~onnie C. Smith ;''/;'!~;'~ 108B:F2 Commissioner · -~'?~- ~ SUBJECT: FROM: Bobbw_¢ Foster-."; - Petroleum Inspector 1983 Witness BOPE .Test on SOHIO's Sec. 4, TllN,R14E, UM, Permit No. 83-121. ~nday,_ Aug~..t.: 15, I983: concluded at 10:30 pm. there were no failures. The BOPE test began at 9:30 pm and was As the attached BOPE test report shows In summary, I witnessed the BOPE test on SOHIO's E-1. Attach~nt 02-00IA(Rev. 10!79) STATE 0[: AkAS bP% ALASKA Or & -CAS CDNSERVATION CQv~SI~N B ~r:.~ P .E. Inspection Report Representative # ') · ~tion: Sec ~ T//WR/~ ~1 ~_ '; ' /~~as~g~et 8~/~ ,~t. ~il ling ~n~a~or~/~ Q-~/y~/~ig ~Repre~ntative ~/~/(~ · ~.~~~ Location, Genera~ · / Well Sign / Ceneral Housekeeping / Peserve pit / / ACCU~UIATOR SYSTEM BOPE Stack "" ':~'i'.... ".. ' ./ I Test Pressure Annular Preventer: . .~' Blind Rams / Ch°ke Line Valves /.. Ful 1 Charge Pressure . ~ } ~ © psig Pressure After Closure../~00' psig Pump incr. clos. pres 200 psig. ~- ~Osec. Full Charge Pressure Attained: : ~ min --' sec. 3 Controls: Master ~.~ Remote ~ Blinds switch cover Kelly and Floor Safety valves · Upper Kelly ,., / ,. Test Pressure ~r Kelly /. Test Pressure Ball Type .././5 H.C.R. Valve Kill Line Valves Check Valve Test Pressure Inside BOP / . Test Pressure Choke Manifol, ~_~_~est Pressure ~o. valves //, NO. flanges ~ ~ffj ustable Chokes }~fdrauically operated choke / Test Results: Failures_ Test Tim' / . hfs Repair or Replac~nent of failed equipment to he made within -~ days and Inspector/Ccmmission office notified. Remarks: ~oOc/ .~.& ,~2~t / - Distribution orig. - AO&QCC cc - Operator cc - Supervisor August 8, 1983 Mr. R. }i. Reiley District Drilling Engineer Sohio Alaska Petroleum C~pany Pouch 6-612 Anchorage, Alaska 99502 Re: Prudhoe Bay Unit K-1 Sohio Alaska Petroleum Company Permit Mo. 83-121 Sur. Loc. 1626'SN~L, 1090'~vWL, Sec. 4, TllN, R14E, UPM. Btmhole Loc. 693'SNL, 683'WEL, Sec. 33, T12N, Ri4E, UPM. Dear F~. Reiley: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each. foot of. recovered co~e is required. Samples of well cuttings and a mud log are required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter survey8. Many rivers in Alaska and their drainage systems have been classified as important for the spa¥~ing or migration of ar~adro~ous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commenc~nK operations you may be contacted by the Habitat Coordinator~ Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article-7 and the regulations promulgated thereunder (Title 18, Alaska Administrative'Code, Chapter 70) and by the Federal '~ater Pollution Control Act, as amended. Prior to co~enclng operations you may be contacted by a representative of the Depart~-~ent of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to com~encing installation of the blowout Mr. R. H. Relley Prudhoe Bay Unit K-1 -2- August 8, 1983 prevention equipment so that a representative of the Commission may be present .to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandor~nent, please give this office adequate advance notification so that we may have a ~tness present. Ver~M trul~foUr s, C. V. C/satterto~ ..... ~ O~ ~;~ ~'~O~ Alaska Oil and Gas ~nServation Co~ission be:6:H/A Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. DePartment of Environmental Conservation w/o encl. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907)276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 August 4, 1983 Alaska Oil & Gas Conservation Con~nission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: WELL K-1 (41-33-12-14) PBU m..~...REViSED Enclosed are the following revised documents, in triplicate, for the above named well. 1. Application for Permit to Dr ill; 2. Proposed drilling program outline; 3. Proposed Blowout Prevention Diagram and Diverter System Detail; 4. Surveyor's plat showing well location; 5. Directional map. If you have any questions, please call Ted Stagg at 263-5173. Yours very truly, R. H. Reiley District Drilling Engineer RHR: MCM:pw cc: Well File #17 Alaska 0il & Gas Cons. /trlcl~orsge ALASKA STATE OF ALASKA AND GAS CONSERVATION CC..,MISSION PERMIT TO DRILL 2O AAC 25.OO5 1 a. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum ~y 3. Address Pouch 6-.6]2, Anchor_.age, Alaska 99502 4. Location of well at surface 1626' SNL, 1090' EWL, Sec. 04, TllN, R14E, UPM At top of proposed producing interval ~target) 900' SNL, 800' WEL, Sec. 33, T12N, R14E, UPM At total depth 693' SNL, 683' WEL, Sec. 33, T12N, R14E, UPM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Est. KBE = 60' AMSL ADL 28300 12. Bond information (see 20 AAC 25.025) -Type ]~-]!alqket Surety and/or number Safeco Ins, 2975387 13. Distance and direction from nearest town 14. Distance to nearest property or lease line NW of Dead_horse - 10 miles North of ADL 28303 - 4380 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 120G6" MD - 9031' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures o KICK OFF POINT 12GQ feet. MAXIMUM HOLE ANGLE 46 (see 20 AAC 25.035 (c) (2) 21 SIZE Hole ! Casing 36 20x30 17½ 13 3/8 725 12¼ 9 5/8 475 8½ 7 265 22. Describe proposed program: Weight Insulat~ Proposed Casing, Liner and Cementing Program CASING AND LINER Grade / Coupling ~d Condgctor L-80! Butt. l_r-80/ Butt. L-80/ Butt. SETTING DEPTH Length MD TOP TVD 80 2779 10973 Surface ~el followed b, 1223 Surface Surface ~ 8240 10783, 9. Unit or lease name Prudhoe Bay Unit 10. Well number K-1 (41-33~12~14 11. Field and pool Prudhoe Bay l:'rudtr~ Oil Pool Amount $20Q,QQO.Q0 15. Distance to nearest drilling or completed well 18. Approximate spud date A~3~t 8, 1983 ' psig@ Surface 4390 psig@ ~[q0~J ft./x~D (TVD) MD BOTTOM TVD 110 110 28091 2680 110331 8414 ' 575 c4u.ft. C1 120061 9091 QUANTITY OF CEMENT (include stage data) 3720 cu.ft.Arcticset 2050 cu.ft. Class G ~ss G;130 cu. ft. Perm. C 335 cu.ft. Class G 18% salt See. attached proposed drilling and completion program. As shown on the attached directional plat, we are aware of the potential intersection problems which can result frQm the drilling of th_is well. If during actual drilling operations, one of these 'intersections is approached w~thin hazardous proximity, ~he well %o be intersected will be shut-in. ~ F ',C E IV F~ ~ Alaska 0il & Gas Cons. Commission 23. I hereby certify that the foregoing is true and correct to the best of my knowledge i ~~~.~~ District Drilling Engineer SIGNED ~'~:;~ TITLE The space be ow or Co~mi'ssion u~f R. H. Reiley DATE CONDITIONS OF APPROVAL Samples required ~YES I--INO Permit number Form 10-401 Rev. 7-1-80 Mud log required ~-YES [] NO 8~ ~ z'/- Directional Survey required [~YES []NO IAPl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission August 8, 1983 Submit in triplicate ~ t~ ~ TITLE 9 IC-! COL~c;~' LII~ UOULD ~ LTr..E R FLrr. L RF_t'ORT SErf? TO ~ Pll~IherE~ ? Uf_i~lO~t LOL*'~T IO~ = U-E .'S-H TU'D(SB.q) TOP 90TT0tt 67479~.56 5981~,74 i40TE - ~I.L IEPTH6 IH I:EIi'T BEU)g KE'LLV gUSflX~ (gtCg) C~ ~R~ OI~ - 43.7 CL~ ~ F~ ? ~ ~ UERTIC,~. ~'PROPOSED% /1~_~1~¥ % UERT ICRL Alaska Oil &. (:as Cons, Commission Anchora~e ~ - td.L DEPT~S XH FEET 9ELOU F. ELL¥ UERTI¢~ ~Pt~OPOgF_D~ ~'IEAIt ~V"~. DEP~'T TU~ DF_PP~T DX Alaska Oii& Gas Cons. Uommts:aion Anchorage Proposed Drilling and Completion Program Well K-1 (41-33-12-14) PBU Install and cement 80' of 20" x 30" insulated conductor to surface. Install 20" diverter. Drill 17 1/2' hole to 2700' TVD and cement 13 3/8" 72# L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas colunn to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1~4" hole to + 100' TVD above the Sag River Sandstone. Run 9 5/8" 47~ L-80 ButtreSs casing to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9 5/8" shoe and a second stage using Arctic Pack followed by 130 cu. ft. permafrost cement displaced through a DV packer collar set 80' above 13 3/8" shoe. Directionally drill 8 1/2" hole to TD. Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G Cement with 18% salt. Clean out to 7" floa~ equipment. Change over to~9.6 ppg NaC1 completion fluid. Test casing and lap to 3000 psi. Run CBL. Run 9 5/8" production packer on internal plastic coated tubing with gas lift mandrels and a sliding sleeve. Set packer +50' above top of liner. A subsurface safety valve with dual control lin-es will be placed +50' below base of permafrost. Install and test Xmas tree. Displace tu~ing to diesel. Set and test packer. Suspend well for perforation subsequent to rig release. Tubing Size 5 1/2"/ 7" Tapered Tubing B.O.P.~,S TACK CONFIGURATION. 5/8" TRIPLE RAM STACK _ 5000 PSI WP DRILLING ANNULAR PREVENTER ! I ! t PIPE RAMS BLIND RAMS CHECK 2" KILL LINE HAND GATE GATE DRILLING SPOOL PIPE RAMS t t CHOKE LINE GATE ,J 10 3/4" Hydraulic operated__% Butterfly ~_~lve automatically~ opens when Annular Preventer closes. ~' ' C' 10 "' ~ROUND. LEVEL DRILLING RISER 20" 2000 PSI WP ANNULAR PREVENTOR DRILLING SPOOL 20" CONDUCTOK PIPE DIVERTER SYSTEM DETAIL DRILL. DEPT. April 1982 ~0~: DI~RTER LI~ ~S ~0 DI~CTIO~ CAPABILITY -AFTER LEAVING RIG SUB-BASES. SURFACE HOLE DIVERTER SYSTEM Two lines venting 90° apart ' - 10 3/4" manual butterfly valves 1. All pipe connections 150~ ANSI Flanges or welded connections. 2. Manual 10 3/4" butterfly valves, safety wired in open ppsitlon at diverter line tee. ~ 10 3/4" 55~ Buttress 10-3/4" Hydraulic operated penButterfly valve automatically s when. Annular Preventer closes. 20 Diverter SFool w/lO 3/4 Side Outlet:. ii I I 04 I I ~ ~0 20 30 4O ~0 20 30 40 ! lO I 4o I- - ,~---~ ~ -I- I I [ .... ~ - (Pro,posed) I ' ITI2 I '.-" ' : '--' ' OI I - STAKED) ' ~ ',,~o'1~ , ~ ~T. : ~o. ~o'~,.,, ',', ~t ~ X= 671,350 __~ ~_~ + ~ ....... ~ , ..... , I PAD DETAIL SCALE = I"= 500' PORT ION Of T. II ~ 12 N.,R. 14 E.,U.M SCALE: I" = I/2 MILE SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A LOCATION SURVEY OF THE WELLPAD SHOWN AND THE WELLS THEREON. THIS SURVEY WAS MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. BOTTOM HOLE LOCATIONS ARE FURNISHED BY OTHERS. DATE "--~'"~['~'~. ~L,L~J~r-- --- REGISTRATION NO.. REGISTERED LAND SURVEY~)R AUG - 5 :..~,,, 0ii & Gas Cons. Anchorage REVISE K- I SURFACE LOC. FROM PROPOSED TO AS-STAKED. REVISE K- I BHL, 8/ 3/83 7/26/85 {AS - STAKED) n~i~i0. PAD "K" Loc(~ted In NWl/4 PROTRACTED SEC. 4~T. I IN,IR.14E.~uM,IAT MER,.~,A, LA.S. KA Surveyed for SOHIO ALASKA PETROLEUM CO. Surveyed by OCEAN TECHNOLOGY LTD. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights.Boulevard Anchorage, Alaska A-12847- 8:5 i i i SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 August 1, 1983 Alaska Oil & Gas Conservation Ccamission 3001 Porcupine Drive Anchorage,' Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: 'WELT, K-1 '(41'33-12'14) PBU Enclosed are the following documents, in triplicate, along with our check for $100 to cover the permit filing fee. 1. Application for Permit to Drill; 2. Proposed drilling program outline; 3. Proposed Blowout Prevention Diagram and Diverter System Detail; 4. Surveyor's plat showing well location; 5. Directional map. If you have any questions, please contact Ted Stagg at 263-5173. enCS CC: Yours very truly, R. H. Reiley District Drilling Engineer Well File %17 STATE OF ALASKA '-" ALASKA ulL AND GAS CONSERVATION CL, MMISSION ERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL [~, REDRILL [] DEEPEN [] I b. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum ~y 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface ~' 1611' SNL, 1084' A~L, Sec. 04, TllN, R13E, UPM At top of proposed producing interval (target) 900' SNL, 800' WEL, Sec. 33, T12N, R14E, UPM At total depth 691' SNL, 790' ~L, Sec. 33, T12N, R14E, UPM 5. Elevation in feet (indicate KB, DF etc.) Est. KBE = 60' AMSL 6. Lease designation and serial no. ADL 28300 9. Unit or lease name Prudhoe Bay Unit 10. Well number K-1 (41-33-12-14) PBU 11. Field and pool 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number Safeco Ins. 2975387 Amount $200,000.00 · 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed NW of Deadhorse - 10 miles North of ADL 28303 - 4380feet well E-3 - 5600 feet ! 16. Proposed depth (MD & TVD) 111369' ~) - 9096' TVD feet 17. Number of acres in lease 2560 18. Approximate spud date August 8, 1983 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1200 fee~. MAXIMUM HOLE ANGLE 41© (see 20 AAC 25.035 (c) (2) 4390 psig@~ Surface .psig@ 8800 ft. 'I}O((TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight 20x30 Lnsulat( 136 ii? i12 1/4 8 1/2 13 3/8 9 5/8 72# 47# 26# 22. Describe proposed program: CASING AND LINER Cona, ctor L-80~ Butt. L-80/ BUtt' L-80 / BUtt. Length 80 2779 10428 1161 SETTING DEPTH MD TOP TVD Surface Surface Sur ace 10208 I 8227. M D BOTTOM TV D 110I 110 '28091 2680 104581 8414 575 cu. ft.~ i1369 i 9096 QUANTITY OFCEMENT (include stage data) 8 cu. yds. concrete 4000 cu. ft.Arcticset 1870 cu. ft. Class G w/: ;lass G; 130 cu. ft. P~ 325 cu.ft.Class G win 18% salt See attached proposed drilling and completion program. As shown on the attached directional plat, we are aware Of the potential intersection problems which can result from the drilling of this well. If during actual drilling operations, one of these intersections is approached within hazardous proximity, the well to be intersected will be shut-in. ?'t: .~.. !.,,,~-' ~ ~ i':~'~ 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED t~__~/~-~ The space below for C(of~missipt~se Distr~E Drilling Engineer R. H. Reiley DATE Samples required J~YES I-]NO Permit number Mud log required ~.YES []NO Approval date CONDITIONS OF APPROVAL .. ' / Directional Survey required,\ ~/ ] APl number ~YES FqNO ~ 50- O ?-'~ - 7~ o ? ~ ~ SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE by order of the Commission ~S I % m.C Form 10-401 Submit in triplicate Proposed Drilling and Completion Program Well K-1 (41-33-12-14) PBU Install and cement 80' of 20" x 30" insulated conductor to surface. Install 20" diverter. Drill 17 1/2" hole to 2700' TVD and cement 13 3/8" 72# L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas colunn to surface from 8600' TVDss and an oil colunn to 8800' TVDss. Directionally drill 12 1./.4" hole to + 100' TVD above the Sag River Sandstone. Run 9 5/8" 47~ L-80 ButtreSs casing to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9 5/8" shoe and a second stage using Arctic Pack followed by 130 cu. ft. permafrost cement displaced through a DV packer collar set 80' above 13 3/8" shoe. Directionally drill 8 1/2" hole to TD. Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G Cement with 18% salt. Clean out to 7" float equipment. Change over to 9.6 ppg NaC1 completion fluid. Test casing and lap to 3000 psi. Run CBL. Run 9 5/8" production packer on internal plastic coated tubing with gas lift mandrels and a sliding sleeve. Set packer +_50' above top of liner. A subsurface safety valve with dual control lines will be placed +50' below base of permafrost. Install and test Xmas tree. Displace tu~ing to diesel. Set and test packer. Suspend well for perforation subsequent to rig release. Tubing Size 5 1/2"/ 7" Tapered Tubing i ! B.O.R~.,S TACK ..CO N FIGU F~--~-T ION 1:5 5/8" TRIPLE RAM STACK 5000 PSi WP DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS 2" KILL LINE CHECK GATE GATE DRILLING SPOOL PIPE RAMS I ! CHOKE LINE GATE HYDR. AS:ST. GATE DRILLING RISER 20" 2000 PSI WP ANNULAR PREVENTOR DIVERTER SYSTEM DETAIL DRILL. DEPT. April 1982 ,? 10 3/4" Hydraulic Butterfly ~.~lve automatics/ opens when Annular Preventer closes. 10 ,t DIVERTER GROUND. LEVEL 12" MAX. DRILLING SPOOL 20" CONDUCTOR PIPE NOTE: DIVERTER LINE HAS TWO DIRECTION DISCHARGE CAPABILITY ~-TER LEAVING RIG SUB-BASES. SURFACE HOLE DIVERTER SYSTEM Two lines venting 90© apart 4 10 3/4" manual butterfly valves 10 3/4" 55~ Buttress 10-3/4" Hydraulic operated Butterfly valve automa~ly opens when. Annular Preventer closes. ~ 20" Diverter Spool w/10 3/4" ~ Side Out,let. 1. All pipe connections 150~ ANSI Flanges or welded corm ect ions. 2. Manual 10 3/4" butterfly valves, safety wired in open posit~on at diverter line tee. - ! . ' i I ~ 40 I0 20 )1 I I ,2 J I I I I I I I I o~ I I 02 I I. I I I 04 I I I I 8 20 3O 4O -t- { Propo~d) ITI2N I ~m. I -- I - I 1-~ ~._ WELL K 1 (PROPOS'EoT)lIN: ~ L~NG,= 148~36'34.37" ~ ~ X= 671,344 I ~'~ Y = 5,975,607 I I : I PAD DETAIL SCALE: I": 500' PORTION OF T. II A 12 N.,R. 14 E.,U.M SCALE : I" : I/2 MILE I I I I SURVEYQR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STA~rE OF ALASKA, THAT THIS PLAT REPRESENTS A LOCATION SURVEY OF THE WELLPAD SHOWN AND THE WELLS THEREON. THIS SURVEY WAS MADE BY ME OR UNDER :MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. BOTTOM HOLE LOCATIONS ARE FURNISHED BY OTHERS. DATE ..5~.~ /..L,/'_?$__[~= REGISTRATION NO .... REGISTERED LAND SURVEYOR REVISE K- I BHL, _ . I I I (PROPOSED) PAD "K" Located In N.N.N.N~W I/4,,PR, OT,RACTED SE.C, 4~m, I!N,~R.14E,tUMIAT MER,~ALASKA Surveyed for SOHIO ALASKA PETROLEUM CO. -- Surveyed by OCEAN TECHNOLOOY LTD. LAND & HYDROGRAPHIC SURVEYORS 2502 We~t Norfhern Llght=.Boulevord Anchoroge, Alasko A- 12847 - 83 II .o 9 oo ITEM APPROVEi~ :~ DATE ~2 thru 8) · ............. 3. '"'~ ' ' - - - * --"-'-*"'~ ........ ' 4 · 51 ' ' ' ' ~(~thru 11)' / 10. / ~ 11. (12 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. (21 thru 24) 21. 22. 23. 24. 25. , ~,~,. ,. ,. !,:?.::,. :: ,... :, ,r:,,, v', ," 2, .'~,~,,,~.,:.,,,' .~' '.'. ,, .,,.' ,,,.,~,,,': ~,,,,,,~%~ ~, ~-~,,,o~.~ ~.f!,, . ,,. Lease & Well N°, · " : yEs NO REMARKS Is .the permit fee attached ..... ,. .......... · ....... ' ........ · Is well to be located in a defined pool ............... '... ' · Is well located proper distance from property line .' ..... 'i ' Is 'well located proper distance from other wells · ......... :: Is sufficient undedicated acreage, available in this pool .. Is well to be deviated and is well bore plat included ..... Is operator the only affected party ..; ................. ; · · Can permit be approved before ten-daY wait * .............. Does operator have a bond in force ...... ..... . ..... Is a conservation 9rder needed. ............. ii iii !iii iiiiii i Is administrative approval needed ........ ' ............ condUctor string provided ~ " Is Is enough., cement used to circulate on conductor and surface · .- Will cement tie in surface and intermediate or production st~igg~ ~1 ,, Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing 'give adequate safety in collapse, tension and burst,. I's this well to be kicked off from an existing welibore ..' ........... /~. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... ~-f , diverter syst quired ' Is a em re ..... ................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to J-~-~Z> psig .. . Does the choke.manifold comply w/API RP-53 (Feb.78) .................. __ #bT Additional requirements ~3ELL. /~ " ~ z o~ z Geology: Engi ,n~.er ing: H'WK _~ L~S~/~ BEw / WVA / rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. 'SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. .o K-OI %~ PRUDHOE BAY OCT 2 4 199§ Alaska 0il & Gas Co'ns. Commission Anchorage :::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::-- :. ::.._:....~..~:::::..::;..::._?-:.~.:.~.~.;;;:::::::....;::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :, :::::: ::::::;::: ::::::::::::,,:.~.'.?.:!!~ii~_'-_:! E E~ !!!!':~E E Y.-~."!!!: ::::::::::::::::::::::::::: .a. ...... , ..... :::-~:::::~::: ................................ Run 1: 01 - October - 1995 CNIGR Cased Hole 11290 11874 WESTERN ATLAS 'Logging Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: - JOB NUMBER: ~ LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD K - 01 500292099800 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 10-OCT-95 6492.00 L. KOENN E. RANDALL 4 liN 14E 1626 1091 61.10 59.60 20.20 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 11259.0 47.00 7.000 12043.0 26.00 5.500 10918.0 17.00 4.500 11033.0 12.60 BASELINE DEPTH GRCH 11306.0 11305.0 11307.0 11306.0 11308.0 11306.5 11324.0 11322.5 11327.5 11325.5 11329.5 11327.5 11330.0 11329.0 11330.5 11330.0 11331.0 11330.5 11332.0 11331.0 11338.5 11337.5 11339.5 11338.0 11353.0 11351.5 EQUIVALENT UNSHIFTED DEPTH PBU TOOL CODE: BHCS PBU CURVE CODE: GR RUN NUMBER: 2 PASS NUMBER: 1 DATE LOGGED: 12-AUG-83 LOGGING COMPANY: SWS 11354.0 11354.5 11356.5 11390.0 11391.5 11393.0 11402.0 11403.5 11405.0 11427.5 11428.5 11429.5 11431.0 11431.5 11432.5 11434.5 11437.5 11438.5 11440.0 11442.0 11444.5 11447.0 11461.5 11479.0 11481.5 11506.5 11509.5 11510.0 11512.5 11513.5 11532.5 11533.0 11534.5 11553.0 11556.0 11580.0 11608.0 11608 ..5 11610.0 11619.0 11619.5 11625.0 11626.0 11626.5 11628.0 11630.5 11632.0 11641.5 11643.0 11643.5 11667.0 11699.0 11707.5 11709.0 11711.0 11711.5 11717.5 11718.0 11719.0 11720.0 11352 11353 11355 11389 11391 11391 11400 11402 11404 11426 11427 11427 11429 11430 11431 11433 11437 11438 11439 11441 11443 11445 11460 11478 11480 11505 11508 11509 11511 11512 11531 11532 11533 11551 11554 11579 11606 11607 11607 11616 11617 11623 11623 11624 11626 11629 11629 11639 11641 11642 11665 11698 11705 11706 11708 11709 11715 11716 11717 11717 .0 .5 .5 .5 .0 .5 .5 .0 .0 .5 .0 .5 .0 .0 .5 .5 .0 .0 .5 .5 .0 .5 .0 .0 .5 .0 .0 .0 .5 .0 .0 .0 .5 .0 .0 .0 .5 .0 .5 .5 .5 .0 .5 .5 .5 .0 .5 .0 .0 .0 .0 .5 .5 .0 .0 .0 .0 .0 .0 .5 11720.5 11721.5 11723.0 11733.5 11734.0 11735.0 11746.5 11747.0 11777.0 11788.5 11813.0 11813.5 11815.0 11821.0 11827.0 11829.5 11830.0 11831.0 11859.0 11859.5 $ REMARKS: 11718.0 11718.5 11721.0 11731.5 11732.0 11732.5 11744.0 11745.0 11775.0 11787.5 11812.0 11813.0 11814.5 11820.0 11826.0 11829.0 11829.5 11830.0 11858.0 11858.5 CN/GR Cased Hole. LOG TIED INTO, BHC SONIC LOG DATED 14-AUG-83. WELL LOGGED SHUT-IN. FOUND GAS IN THE BOREHOLE ON PASS NO. 2 AT 11363'. FOUND GAS IN THE BOREHOLE ON PASS NO. 3 AT 11390'. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CHISM OFF, CALIPER & CASING CORRECTED, SALINITY = 0.0 PPM. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES - Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 11290.0 11864.0 11300.0 11874.0 BASELINE DEPTH 11306.0 11307.0 11308.0 11324.0 11327.5 11329.5 11330.0 11330.5 11331.0 11332.0 11338.5 11339.5 11353.0 11354.0 11354.5 11356.5 11390.0 11391.5 11393.0 11396.5 11402.0 11403.5 11405.0 11427.5 11428.5 11429.5 11434.0 11436.0 11438.5 11440.0 11442.0 11444.5 11447.0 11461.5 11479.0 11481.5 11506.5 11509.5 11510.0 NPHI 11305.0 11306.0 11306.5 11322.5 11325.5 11327.5 11329.0 11330.0 11330.5 11331.0 11337.5 11338.0 11351.5 11352.0 11353.5 11355.5 11389.5 11391.0 11391.5 11396.0 11400.5 11402.0 11404.0 11426.5 11427.0 11427.5 11432.5 11434.0 11438.0 11439.5 11441.5 11443.0 11445.5 11460.0 11478.0 11480.5 11505.0 11508.0 11509.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH -- 11512.5 11513.5 11530.5 11534.5 11553.0 11556.0 11580.0 11608.0 11608.5 11610.0 11619.0 11619.5 11625.0 11626.0 11626.5 11628.0 11630.5 11632.0 11641.5 11643.0 11643.5 11667.0 11699.0 11707.5 11709.0 11711.0 11711.5 11717.5 11718.0 11719.0 11720.0 11720.5 11721.5 11723.0 11733.5 11734.0 11735.0 11747.0 11777.0 11788.5 11814.0 11822.5 11829.5 11835.5 11859.0 11859.5 $ REMARKS: ±1511.5 11512.0 11529.5 11533.5- 11551.0 11554.0 11579.0 11606.5 11607.0 11607.5 11616.5 11617.5 11623.0 11623.5 11624.5 11626.5 11629.0 11629.5 11639.0 11641.0 11642.0 11665.0 11698.5 11705.5 11706.0 11708.0 11709.0 11715.0 11716.0 11717.0 11717.5 11718.0 11718.5 11721.0 11731.5 11732.0 11732.5 11744.0 11775.0 11787.5 11811.0 11820.5 11826.5 11833.5 11858.0 11858.5 PASS 1. FUCT & NUCT WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN FN COUN / ? ?MATCH1B . OUT $ : BP EXPLORATION : K - 01 : PRUDHOE BAY : NORTH SLOPE (ALASKA) STAT : ALASKA * 'pORMAT RECORD (TYPE# 64) -- ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 25 Tape File Start Depth = 11895.000000 Tape File End Depth = 11275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6206 datums Tape Subfile: 2 Minimum record length: Maximum record length: 308 records... 62bytes 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 ~START DEPTH STOP DEPTH 11290.0 11864.0 11300.0 11874.0 BASELINE DEPTH GRCH 11295.0 11294.0 11305.0 11309.0 11306.5 11315.5 11316.0 11319.0 11316.5 11319.5 11317.5 11321.5 11326.5 11324.5 11327.0 11325.5 11328.0 11328.5 11329.5 11327.5 11330.0 11328.5 11333.0 11333.5 11343.0 11345.5 11346.0 11348.0 11352.0 11350.5 11353.5 11354.0 11352.5 11354.5 11353.0 11361.5 11362.5 11389.0 11391.0 11390.5 11391.5 11391.0 11392.5 11393.0 11391.5 11395.0 11396.5 11397.5 11399.5 11398.0 11400.0 11399.0 11402.0 11401.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 11304.0 11315.5 11316.0 11319.0 11324.5 11325.0 11327.0 11331.5 11332.5 11342.0 11344.0 11345.0 11347.0 11350.5 11361.0 11362.0 11386.5 11394.5 11396.0 11396.5 11389.0 11389.5 11404.0 11406.5 11407.0 11424.0 11427.0 11430.0 11430.5 11432.0 11433.0 11435.5 11441.5 11446.0 11447.0 11448.5 11449.5 11450.0 11462.0 11470.5 11471.0 11471.5 11472.0 11476.5 11496.0 11500.0 11501.0 11502.0 11507.0 11510.5 11511.0 11515.5 11520.0 11523.0 11523.5 11524.5 11525.5 11526.5 11536.5 11543.0 11551.0 11552.0 11555.5 11556.5 11557.0 11594.0 11601.0 11602.0 11602.5 11609.0 11610.5 11614.5 11615.5 11621.0 11622.0 11624.5 11625.5 11627.5 11631.0 11638.0 11639.0 11641.0 11403.5 11405.5 11406.5 11429.5 11430.5 11432.5 11433.0 11435.0 11445.5 11446.0 11447.5 11448.0 11460.5 11469.5 11470.0 11476.0 11495.5 11506.0 11509.5 11519.0 11523.0 11525.0 11607.0 11622.5 11623.0 11638.5 11423.0 11425.5 11440.5 11449.0 11470.5 11471.5 11499.5 11500.0 11500.5 11509.5 11514.5 11522.0 11523.0 11525.0 11525.5 11535.5 11541.0 11549.0 11549.5 11553.0 11553.5 11554.0 11593.0 11600.0 11600.5 11601.0 11608.0 11612.0 11613.5 11619.0 11619.5 11623.0 11625.5 11629.0 11635.5 11636.0 1164 1164 1165 1166 1169 1169 1169 1169 1169 1170 1170 1170 1170 1170 1171 1171 1172 1172 1173 1173 1173 1173 1173 1174 1174 1175 1175 1175 1175 1177 1177 1178 1178 1178 1178 1178 1178 1179 1179 1179 1179 1179 1180 1180 1180 1181 1181 1181 1181 1181 1181 1181 1182 1182 1183 1184 1184 1184 1184 1184 1.5 3.5 1.0 8.5 0.0 2.5 5.0 8.5 9.5 1.0 3.5 4.0 7.0 8.5 8.0 8.5 1.5 5.0 4.5 5.0 6.0 8.5 9.5 8.5 9.5 1.0 2.0 7.0 7.5 6.0 6.5 1.5 3.0 4.5 7.5 8.5 9.5 2.5 3.0 3.5 4.0 6.5 3.5 4.5 9.0 0.0 1.0 3.0 4.0 5.0 7.0 8.5 6.5 7.5 2.0 3.5 4.0 5.0 5.5 6.5 11639.5 11666.5 11692.0 11700.5 11703.0 11704.5 11715.5 11716.5 11719.5 11733.0 11733.5 11746.0 11754.0 11754.5 11775.5 11776.0 11780.0 11791.5 11792.0 11793.0 11803.0 11803.5 11812.0 11813.0 11817.5 11831.0 11843.5 11641.0 11649.5 11689.0 11694.0 11697.5 11698.0 11702.5 11705.5 11722.0 11732.0 11736.0 11736.5 11746.5 11748.5 11749.5 11781.0 11784.0 11786.5 11787.5 11788.0 11792.5 11794.0 11806.5 11807.0 11807.5 11810.5 11815.0 11824.5 11825.0 11829.5 11842.5 11843.0 11844.0 11844.5 11849.0 11852.5 11853.5 11855.5 11858.5 11859.0 11859.5 11869.5 $ REMARKS: 11851.0 11851.5 11854.0 11857.5 11859.0 11847.0 11854.5 11858.0 11870.0 PASS 2. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH2A. OUT /??MATCH2B.OUT $ : BP EXPLORATION (ALASKA) :K-01 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 25 Tape File Start Depth = 11895.000000 Tape File End Depth = 11275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6206 datums Tape Subfile: 3 224 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER - FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 11290.0 2418 11300.0 $ CURVE SHIFT'DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 11295.0 11305.0 11308.5 11309.0 11313.5 11318.5 11319.5 11320.0 11320.5 11321.0 11326.5 11328.0 11328.5 11330.0 11330.5 11334.0 11334.5 11335.0 11337.5 11338.5 11339.0 11342.0 11343.5 11349.5 11352.0 11352.5 11353.5 11356.0 11388.5 11389.0 11390.5 11396.0 11402.0 11403.0 11403.5 11407.5 11408.0 GRCH 11294.0 11305.5 11306.5 11311.0 11318.0 11319.0 11326.5 11328.0 11329.0 11333.0 11336.0 11336.5 11350.0 11351.0 11352.5 11355.0 11389.0 11401.5 11402.5 11406.5 11407.5 for each run in separate files. STOP DEPTH 11864.0 11874.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 11304.0 11317.0 11318.0 11318.5 11326.5 11328.5 11332.5 11333.5 11337.0 11340.0 11343.0 11349.0 11350.5 11388.5 11389.0 11395.0 11401.5 11409.0 11412.5 1142~. 0 11429.5 11430.5 11431.0 11432.0 11433.0 11436.0 11436.5 11441.5 11442.0 11442.5 11444.0 11445.0 11446.5 11447.5 11450.5 11460.0 11460.5 11474.5 11475.0 11476.0 11477.5 11478.0 11479.0 11480.0 11480.5 11481.0 11481.5 11482.0 11499.5 11500.0 11500.5 11501.0 11508.5 11510.5 11511.5 11515.5 11516.0 11523.0 11523.5 11529.5 11535.0 11536.0 11538.0 11542.5 11551.0 11551.5 11552.5 11554.5 11555.0 11566.0 11566.5 11583.0 11592.5 11599.5 11600.0 11602.5 11608.5 - 11429.0 11429.5 11431.5 11432.0 11432.5 11436.5 11441.5 11442.0 11446.0 11446.5 11459.0 11460.0 11481.0 11499.0 11507.5 11509.5 11528.5 11582.0 11606.5 11407.0 11411.5 11423.0 11435.0 11441.0 11442.0 11443.5 11444.0 11449.5 11474.0 11474.5 11475.0 11476.5 11477.5 11478.5 11479.0 11479.5 11480.5 11481.5 11498.0 11499.0 11500.0 11509.5 11510.0 11514.0 11515.0 11522.0 11523.0 11534.5 11535.0 11537.5 11540.5 11549.0 11550.0 11551.0 11554.5 11555.0 11564.5 11565.0 11591.5 11598.5 11599.5 11602.0 11611.5 11612.0 11615.5 116-18.5 11620.0 11621.5 11625.5 11629.0 11630.0 11631.0 11632.0 11633.0 11634.5 11635.0 11642.0 11642.5 11644.0 11646.0 11648.5 11652.5 11659.0 11683.5 11689.0 11691.5 11692.0 11694.0 11698.0 11699.0 11703.5 11708.5 11710.0 11710.5 11711.0 11711.5 11718.5- 11719.0 11719.5 11722.0 11724.0 11733.5 11734.0 11734.5 11735.5 11736.0 11737.0 11737.5 11738.5 11744.0 11745.0 11748.5 11774.0 11775.5 11776.0 11778.5 11780.0 11787.5 11793.0 11794.0 11794.5 11795.5 11629.0 11629.5 11632.0 11633.0 11640.0 11642.0 11708.5 11716.5 11717.5 11720.5 11732.0 11734.0 11734.5 11746.0 11776.5 11778.5 11793.0 11608.5 11609.0 11613.0 11616.0 11619.5 11621.0 11623.5 11627.0 11627.5 11629.5 11630.0 11641.0 11644.5 11647.0 11650.5 11657.0 11683.5 11689.0 11691.0 11691.5 11693.5 11697.5 11698.0 11702.5 11706.0 11707.5 11708.0 11709.0 11716.5 11717.5 11720.0 11721.5 11732.0 11733.0 11733.5 11735.5 11736.0 11741.5 11742.0 11771.0 11773.5 11774.0 11786.5 11792.0 11792.5 11794.0 11803.5 11805.5 11809.5 11812.5 11813.5 11814.5 11823.0 11829.5 11839.5 11840.0 11841.5 11843.5 11846.0 11847.0 11848.0 11851.0 11851.5 11855.5 11856.0- 11858.0 11860.5 11869.5 $ REMARKS: 11802.5 11811.5 11812.0 11849.5 11850.5 11854.5 11855.5 11803.0 11806.0 11811.0 11820.0 11826.5 11836.0 11837.0 1183~.0 11840.0 11843.5 11844.5 11845.0 11849.0 11857.5 11859.5 11869.0 PASS 3. FUCT & NUCT WERE SHIFTED WITH NPHI. / ? ?MATCH3 A. OUT /??MATCH3B.OUT $ CN : BP EXPLORATION WN : K - 01 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: (ALASKA) Name Tool Code Samples Units 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS Size * DATA RECORD (TYPE# 0) Total Data Records: 25 1006 BYTES * API API API API Log Crv Crv Length Typ Typ Cls Mod 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 Tape File Start Depth = 11895.000000 Tape File End Depth = 11275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep COde: 68 12412 datums Tape Subfile: 4 238 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 pASSEs INCLUDED AVERACE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: CN WN FN COUN STAT 1, 2, 3 1, 2, 3 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES. $ : BP EXPLORATION (ALASKA) : K - 01 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH CNAV 68 1 GAPI 4 2 NPHI CNAV 68 1 PU-S 4 3 FUCT CNAV 68 1 CPS 4 4 NUCT CNAV 68 1 CPS 4 4 38 995 99 1 4 38 995 99 1 4 38 995 99 1 4 38 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 25 Tape File Start Depth = 11895.000000 Tape File End Depth = 11275.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12412 datums Tape Subfile: 5 48 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER - FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11289.0 2418 11299.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : STOP DEPTH 11884.0 11894.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 01-OCT-95 FSYS REV. J001 VER. 1.1 1927 01-OCT-95 12043.0 11876.0 11300.0 11874.0 1500.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA 0.000 12043.0 0.0 PROD FLUID/SEAWATER 0.00 0.0 0.0 0 0.0 0.OOO 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS) : 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) :K-01 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 4 42 150 01 1 4 42 636 99 1 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 89 Tape File Start Depth = 11895.000000 Tape File End Depth = 11279.000000 TaPe File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 34598 datums Tape Subfile: 6 164 records... Minimum record length: Maximum record length: -- 42 bytes 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMML~RY VENDOR TOOL CODE START DEPTH GR 11290.0 2418 11300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11882.0 11892.0 01-0CT-95 FSYS REV. J001 VER. 1.1 1956 01-OCT-95 12043.0 11876.0 11300.0 11874.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 12043.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PROD FLUID/SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): REMARKS: PASS 2. $ 0.0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : K - 01 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 4 42 150 01 1 4 42 636 99 1 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 89 Tape File Start Depth = 11895.000000 Tape File End Depth = 11279.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 34598 datums Tape Subfile: 7 164 records... Minimum record length: Maximum record length: 42 bytes 1014 bytes Tape Subfile 8 is type: LIS pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0. 2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11290.0 2418 11300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO) : STOP DEPTH 11882.0 11892.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 01-OCT-95 FSYS REV. J001 VER. 1.1 2142 01-OCT-95 12043.0 11876.0 11300.0 11874.0 1500.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA 0.000 12043.0 0.0 PROD FLUID/SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE FILE HEADER - FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW~(FT) : 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) :K-01 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 4 42 150 01 1 4 42 636 99 1 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 89 Tape File Start Depth = 11895.000000 Tape File End Depth = 11279.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 56784 datums Tape Subfile: 8 164 records... Minimum record length: Maximum record length: 42 bytes 1014 bytes Tape~Subfile 9 is type: LIS 95/10/10 01 **** REEL TRAILER **** 95/10/11 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 11 OCT 95 10:07a Elapsed execution time = 2.42 seconds. SYSTEM RETURN CODE = 0 **** ~ ~************************ * ALASKA COMPUTING CENTER * .-- . . .............................. r~ ,~ .............................. ~ ............................ COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : K-O1 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292099800 REFERENCE NO : 98259 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/06/ 1 ORIGIN : FLIC REEL NAM~ : 98259 CONTINUATION # : PREVIOUS REEL : COf4~IE2VT : BP EXPLORATION, PRUDHOE BAY, K-O1, API #50-029-20998-00 **** TAPE HEADER **** SERVICE NAFiE : EDIT DATE : 98/06/ 1 ORIGIN : FLIC TAPE NAFIE : 98259 CONTINUATION # : 1 PREVIOUS TAPE : COf~4ENT : BP EXPLORATION, PRUDHOE BAY, K-O1, API #50-029-20998-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: K-O1 API NUMBER: 500292099800 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 1-JUN-98 JOB NUMBER: 98259 LOGGING ENGINEER: H. KIRKBY OPERATOR WITNESS: C. HOFFMAN SURFACE LOCATION SECTION: 4 TOWNSHIP: 1 iN RANGE: 14 E FNL : 1626 FSL: FEL: FWL: 1091 ELEVATION(FT FROM MSL O) KELLY BUSHING: 61.10 DERRICK FLOOR: 59.60 GROUND LEVEL: 20. 20 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT)WEIGHT (LB/FT) 1ST STRING 8. 000 7. 000 12000.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUI4BER : PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. 88888.0 11845.5 11840.5 11836.0 11833.5 11831.5 11830.0 11827.0 11821.5 11818 5 11818 0 11812 0 11808 0 11804 5 11803 0 11801 0 11788 5 11786.0 11785.5 11783.5 11783.0 11776.5 11775.5 11772.0 11771.5 11767.0 11760.0 11744.0 11743.5 11741.5 11740.5 11740.0 11739.0 11738.5 11738.0 11726.0 11719.5 11718.5 11712.0 11711.5 11709.0 11704.5 11701.0 11698.0 11694.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNL 88887.0 88887.0 11844.5 11844.5 11839.5 11839.5 11837.0 11837.0 11835.0 11835.0 11833.0 11833.0 11831.0 11831.0 11828.0 11828.0 11823.0 11823.0 11820.0 11820.0 11813.5 11813.5 11809.0 11809.0 11805.5 11805.5 11803.5 11803.5 11800.5 11800.5 11790.0 11790.0 11787.5 11785.0 11776.0 11770.5 11766.5 11759.5 11746.5 11743.5 11743.0 11740.5 11729.0 11722.0 11715.0 11711.5 11708.5 11701.5 11698.5 11787.5 11785.0 11776.0 11770.5 11759.5 11746.5 11743.5 11743.0 11740.5 11729.0 11722.0 11715.0 11711.5 11708.5 11701.5 11698.5 11694.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Compu ting 11693.5 11685.5 11685.0 11680.0 11667.0 11665.0 11660.5 11658.5 11655.5 11653.5 11649.0 11645.5 11635.0 11629.0 11624.0 11620.0 11615.5 11613.0 11610.0 11609.5 11596.0 11595.5 11588.0 11587.0 11580.0 11579.0 11571.5 11566.0 11565.5 11561.5 11557.5 11557.0 11552.0 11551.5 11548.5 11541.0 11540.5 11537.0 11536.5 11529.0 11528.5 11525.0 11524.5 11521.0 11517.0 11512.5 11507.5 11507.0 11505.0 11501.0 11494.0 11493.5 11492.0 11482.5 11476.0 11472.5 11694. 11686.0 11679.5 11668.5 11666.5 11661.0 11658.5 11656.0 11654.5 11646.5 11644.5 11637.0 11630.5 11625.5 11621.5 11618.0 11615.0 11611.5 11596.5 11589.0 11587.0 11579.5 11572.5 11567.0 11563.5 11559.0 11552.0 11550.0 11542.0 11538.0 11529.5 11525.5 11523.0 11517.5 11515.0 11508.0 11506.0 11502.0 11496.5 11495.0 11483.5 11477.0 11473.5 Center 1-JUN-1998 11:39 11686.0 11679.5 11668.5 11666.5 11661.0 11658.5 11656.0 11654.5 11646.5 11644.5 11637.0 11630.5 11625.5 11621.5 11618.0 11615.0 11611.5 11597.0 11589.0 11587.0 11580.0 11572.5 11567.0 11563.5 11559.0 11552.0 11550.0 11542.0 11538.0 11529.5 11526.0 11523.0 11517.5 11515.0 11508.0 11506.0 11502.0 11497.0 11495.0 11483.5 11477.5 11473.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11470.5 11471.5 11471.5 11468.0 11470.0 11470.0 11464.0 11466.0 11466.0 11459.0 11459.5 11459.5 11455.5 11456.0 11456.0 11450.5 11452.0 11452.0 11445.5 11447.0 11447.0 11442.0 11442.5 11441.5 11442.5 11440.5 11440.0 11439.5 11440.0 11438.0 11437.5 11436.5 11437.5 11433.0 11433.5 11433.5 11422.0 11423.0 11423.0 11416.0 11416.0 11415.5 11416.0 11408.5 11408.0 11408.0 11405.0 11405.5 11405.5 11400.5 11401.5 11402.0 11399.0 11399.5 11400.0 11397.0 11397.5 11396.5 11398.0 11389.5 11390.0 11389.0 11389.5 11387.0 11388.0 11386.0 11388.0 11384.0 11386.0 11386.0 11379.0 11380.5 11380.5 11373.5 11374.5 11373.0 11374.5 11369.0 11370.5 11370.5 11366.0 11367.0 11367.0 11364.0 11363.5 11363.5 11361.0 11360.5 11360.5 11357.5 11358.0 11358.0 11355.0 11355.0 11355.0 11351.5 11351.5 11351.0 11351.5 11346.5 11348.0 11345.0 11346.0 11347.0 11340.0 11341.0 11339.0 11341.0 11334.5 11334.5 11334.5 11330.0 11331.0 11331.5 11325.5 11327.0 11325.0 11327.0 11318.0 11319.5 11317.0 11319.5 11315.0 11317.0 11314.0 11317.0 11310.0 11311.5 11311.5 11306.5 11309.0 11309.0 11297.5 11297.0 11297.0 11297.0 11291.0 11292.0 11292.0 1-JUN-1998 11:39 PAGE: 4 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11286.5 11287.0 11286.0 11287.0 11283.0 11283.0 11283.0 11277.0 11278.0 11276.5 11278.0 11272.5 11273.5 11271.5 11273.5 11267.5 11267.5 11267.5 11264.0 11263.5 11263.5 11263.5 11261.5 11262.0 11260.5 11262.0 11259.0 11258.5 11258.5 11259.0 11252.5 11254.5 11254.5 11248.5 11251.0 11251.0 11214.0 11211.5 11211.5 11211.0 11210.5 11210.5 11208.5 11207.5 11207.5 11202.0 11200.0 11200.0 11198.5 11198.0 11198.0 11198.0 100.0 99.5 100.0 $ REM_ARKS: 1-JUN-1998 11:39 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNL DATA AQUIRED ON BP EXPLORATION'S K-O1 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GAM~A RAY, ALSO PASS #1NPHI AND THE BCS GAMMA RAY, CARRYING ALL CArLCURVES WITH THE NPHI SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUf4BER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 1 DEPTH INCREMenT: 0.5000 FILE SUM~zARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: GRCH 11847.0 11193.5 CArL 11852.0 11194.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CArL REMARKS: THIS FILE CONTAINS CASED HOLE CNL PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CArL PU-S 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CArL 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-199~ 11:39 PAGE: 7 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) CRAT CAUL 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNL CPS 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNL CPS 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNL CPS 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNL CPS 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNL GAPI 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNL LB 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CArL V 1102987 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11852.000 NPHI.CNL 34.489 NRAT. CNL NCNT. CNL 3219.917 FCNT. CNL 611.570 CFTC. CNL GRCH. CNL -999.250 TENS. CNL 1502.000 CCL. CNL 5.265 CRAT. CNL 5.575 587.360 CNTC. CNL 3062.393 0.000 DEPT. 11193.500 NPHI.CNL -999.250 NRAT. CNL -999.250 CRAT. CNL -999.250 NCNT. CNL -999.250 FCNT. CNL -999.250 CFTC. CNL -999.250 CNTC. CNL -999.250 GRCH. CNL 55.562 TENS. CNL -999.250 CCL. CNL -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-199~ ~1:39 PAGE: Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INC~: 0.5000 FILE SUMFLARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11846.5 11210.5 CNL 11852.5 11207.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 BASELINE DEPTH .............. 88888.0 11850.0 11846.0 11845.5 11839.5 11835.5 11831.5 11826.5 11823.5 11821.0 11819.0 11816.0 11814.0 11813.0 11809.0 11808.0 11806.0 11805.0 11804.0 11803.5 11801.5 11800.0 11798.5 11797.0 11796.0 11794.5 11791.0 11789.0 11786.5 11784.5 11782.5 11781.0 11779.0 11778.5 11776.5 11775.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNL .............. 88886.5 88887.5 11849.5 11844.5 11845.5 11838.5 11842.0 11837.0 11832.5 11833.0 11828.0 11824.5 11823.0 11820.5 11817.5 11815.0 11813.5 11810.0 11809.0 11806.5 11806.0 11804.0 11805.5 11803.0 11800.5 11800.5 11797.5 11796.5 11794.0 11790.0 11790.5 11788.0 11787.0 11782.0 11781.0 11779.5 11779.0 11776.0 11776.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 11769.0 11768.0 11768.0 11767.0 11766.0 11764.5 11765.5 11764.5 11759.5 11761.5 11757.0 11758.5 11754.5 11754.5 11753.5 11754.5 11750.5 11752.0 11747.5 11749.5 11745.0 11746.5 11743.5 11746.5 11740.0 11743.0 11743.5 11738.5 11740.5 11735.0 11737.5 11730.0 11732.5 11727.0 11729.5 11722.5 11725.0 11721.5 11724.5 11720.0 11722.0 11719.5 11722.0 11712.5 11715.0 11711.0 11715.0 11709.0 11711.5 11706.5 11708.5 11710.0 11703.5 11703.5 11700.0 11699.5 11699.5 11700.5 11698.0 11698.5 11695.5 11696.0 11693.5 11693.0 11686.0 11686.0 11683.5 11684.0 11673.5 11673.5 11668.0 11670.0 11667.5 11669.0 11662.0 11661.5 11664.0 11660.0 11661.0 11655.5 11656.0 11651.5 11652.5 11650.0 11649.0 11646.5 11646.5 11645.5 11644.5 11639.5 11640.0 11634.5 11636.5 11633.5 11635.0 11630.0 11631.0 11629.0 11630.5 11627.5 11627.5 11626.0 11626.0 11623.5 11625.0 11621.5 11622.5 11620.0 11621 . 5 11619.5 11621.0 11615.0 11617.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 10 11614.0 11613.5 11610.5 11609.5 11602.0 11599.5 11595.5 11593.5 11593.0 11589.5 11586.5 11586.0 11579.5 11578.5 11568.5 11562.0 11556.0 11555.5 11550.0 11544.0 11542.5 11537.0 11536.0 11534.0 11532.5 11531.0 11529.0 11528.5 11526.5 11526.0 11525.0 11522.0 11521.0 11519.0 11516.5 11515.0 11514.0 11510.0 11507.5 11507.0 11505.0 11504.5 11501.5 11500.0 11496.0 11495.0 11486.0 11485.5 11477.5 11476.5 11475.0 11473.5 11473.0 11471.0 11465.0 11615.0 11611.5 11601.5 11596.5 11595.0 11589.0 11586.5 11579.5 11563.5 11559.0 11552.5 11540.5 11538.0 11533.5 11532.0 11529.5 11527 0 11525 5 11523 0 11517 5 11515 0 11507 5 11506.0 11502.0 11495.0 11485.5 11477.0 11473.5 11472.0 11613.5 11611.5 11603.5 11600.5 11597.5 11594.0 11591.0 11585.0 11579.0 11567.0 11556.0 11545.5 11543.0 11538.0 11531.5 11529.5 11527.5 11523.0 11520.0 11516.5 11512.5 11507.5 11505.5 11502.0 11497.0 11487.5 11479.0 11476.0 11473.5 11467.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 11 11463.0 11465.0 11461.5 11463.0 11459.5 11459.5 11455.5 11456.0 11453.0 11452.5 11449.5 11450.0 11443.5 11445.0 11442.0 11442.5 11440.5 11440.0 11439.5 11440.0 11437.5 11437.5 11437.5 11434.0 11434.0 11433.0 11433.5 11431.0 11432.5 11430.5 11431.5 11428.5 11429.0 11425.5 11427.0 11423.5 11424.5 11422.0 11423.0 11417.5 11419.5 11416.0 11416.0 11416.0 11413.5 11413.5 11412.5 11412.0 11410.5 11408.5 11409.0 11406.5 11407.0 11407.5 11403.5 11403.0 11399.0 11399.5 11398.5 11399.5 11397.0 11397.5 11392.5 11392.5 11392.0 11392.0 11389.0 11388.0 11386.5 11386.0 11386.0 11388.0 11384.0 11383.0 11382.5 11383.5 11379.0 11379.0 11376.5 11377.5 11374.0 11375.0 11369.0 11370.5 11368.5 11370.5 11365.0 11367.0 11363.0 11363.5 11359.0 11360.5 11357.5 11359.0 11354.5 11355.0 11351.0 11352.0 11349.0 11351.5 11346.5 11347.5 11345.0 11347.0 11340.0 11341.0 11338.0 11341.0 11334.0 11334.0 11334.0 11331.0 11332.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 12 11329.5 11328.5 11327.0 11324.5 11321.0 11318.5 11318.0 11314.0 11313.5 11310.5 11307.5 11305.5 11302.5 11300.5 11299.0 11294.5 11292.0 11291.0 11288.5 11286.5 11285.0 11283.0 11281.0 11276.5 11273.0 11268.0 11265.0 11264.5 11261.0 11260.5 11257.0 11251.5 11250.0 11246.0 11242.0 11240.0 11236.0 11233.0 11231.0 11228.5 11227.0 11223.5 11218.0 11217.5 11215.5 100.0 $ 11331.0 11327.0 11326.0 11320.0 11316.5 11311.5 11309.0 11304.0 11298.5 11295.0 11292.5 11288.0 11283.0 11276.0 11268.0 11263.5 11262.5 11259.0 11251.5 11248 5 11244 0 11241 0 11235 5 11233 0 11230 5 11228.0 11223.5 11219.5 11216.0 100.5 11327.5 11323.5 11321.0 11315.0 11306.5 11300.5 11293.0 11290.5 11287.5 11283.0 11273.5 11263.0 11258.5 11250.0 11243.0 11234.5 11226.5 11215.0 97.5 RE~IAPJfS: THIS FILE CONTAINS CASED HOLE CNL PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CArLCURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1102987 00 000 O0 0 2 1 1 4 68 0000000000 NPHI CNL PU-S 1102987 O0 000 O0 0 2 1 1 4 68 0000000000 ArRAT CNL 1102987 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNL 1102987 O0 000 O0 0 2 1 1 4 68 0000000000 NCNTCNL CPS 1102987 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNL CPS 1102987 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNL CPS 1102987 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNL CPS 1102987 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNL GAPI 1102987 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNL LB 1102987 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CArL V 1102987 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11852.500 NPHI. CNL 29.888 NRAT. CNL 4.730 CRAT. CNL NCNT. CNL 3153.527 FCNT. CNL 666.667 CFTC. CNL 640.275 CNTC. CNL GRCH. CNL -999.250 TENS. CArL 1502.000 CCL.CNL 0.000 DEPT. 11207.500 NPHI. CNL 59.143 NRAT. CNL 8.030 CRAT. CNL NCNT. CNL 1958.506 FCNT. CNL 243.902 CFTC. CNL 234.247 CNTC. CNL GRCH. CNL -999.250 TENS. CArL 1415.000 CCL.CNL 0.000 5.031 3176.646 8. 371 1972. 164 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 14 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUAIBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMFIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11849.5 11208.5 CNL 11852.5 11209.0 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CArL ............................ 88888.0 88889.5 88887.5 11847.5 11847.0 11844.5 11846.0 11843.0 11841.5 11842.5 11844.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 15 11839.0 11838.5 11836.0 11837.0 11833.5 11835.0 11833.0 11833.0 11831.5 11833.0 11830.5 11831.0 11829.5 11829.5 11826.5 11827.5 11825.5 11828.0 11824.0 11824.5 11822.0 11822.5 11820.5 11823.0 11819.0 11821.5 11818.0 11819.5 11816.0 11816.0 11812.0 11814.0 11809.0 11809.5 11808.5 11809.0 11799.5 11800.5 11797.0 11796.5 11789.5 11790.0 11789.0 11790.5 11786.0 11787.5 11782.0 11783.5 11778.5 11779.0 11779.5 11763.5 11767.0 11761.5 11761.5 11758.5 11762.0 11754.0 11755.0 11750.5 11752.0 11747.0 11749.5 11744.0 11746.5 11743.5 11746.5 11740.5 11743.0 11740.0 11743.5 11735.5 11737.5 11734.0 11736.5 11730.5 11733.0 11730.0 11733.0 11727.0 11730.5 11726.5 11729.5 11720.0 11722.0 11719.5 11721 . 5 11711.5 11715.0 11709.5 11712.0 11707.0 11710.5 11705.5 11709.0 11700.0 11700.5 11698.0 11698.5 11694.0 11696.5 11691.5 11691.0 11686.5 11689.0 11686.0 11685.0 11686.0 11682.5 11682.0 11680.5 11678.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 16 11679.0 11678.0 11671.5 11670.5 11669.0 11666.5 11665.0 11662.0 11660.5 11658.0 11653.5 11652.0 11646.5 11642 5 11639 5 11634 5 11633 5 11630 5 11628 5 11625 0 11622 5 11622 0 11620.5 11620.0 11614.0 11613.0 11612.5 11609.5 11603.5 11599.5 11595.5 11592.5 11591.5 11586.5 11584.5 11579.0 11578.5 11571.5 11561.5 11559.0 11558.0 11553.5 11547.5 11544.5 11539.0 11534.5 11532.0 11531.0 11529.0 11526.0 11525.0 11521.5 11520.0 11519.0 11517.0 11680.0 11670.0 11667.5 11661.0 11659.0 11656.0 11646.5 11642.0 11636.5 11631.5 11625.5 11623.0 11621.5 11614.5 11598.0 11595.0 11593.5 11587.0 11579.5 11563.5 11559.0 11552.5 11547.5 11541.5 11535.5 11533.0 11532.0 11529.5 11525.5 11519.5 11517.5 11673.0 11668.5 11667.0 11664.5 11660.5 11651.5 11640.0 11635.0 11629.0 11624.5 11621.0 11617.5 11613.0 11611.5 11603.5 11600.5 11593.5 11585.0 11577.5 11570.0 11559.0 11545.5 11527.0 11523.5 11520.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-199U 11:39 PAGE: 17 11516.5 11513.5 11509.5 11505.5 11504.5 11500.0 11494.0 11491.5 11490.0 11486.0 11484.5 11480.5 11478.0 11476.5 11475.0 11468.5 11465.5 11463.5 11459 5 11456 0 11455 5 11453 5 11453 0 11448 0 11445 5 11443 5 11441 0 11440 0 11437 5 11434 5 11433 0 11432 5 11430.0 11427.5 11426.0 11422.0 11416.0 11415.5 11412.5 11408.5 11403.0 11401.0 11399.0 11398.0 11397.0 11394.0 11393.0 11391.0 11387.5 11386.0 11381.0 11373.5 11368.0 11367.5 11365.5 11515.0 11506.0 11502.5 11495.0 11483.5 11477.0 11469.5 11465.0 11462.5 11460.0 11455.5 11454.0 11447.5 11445.0 11440.5 11433.5 11428.5 11423.0 11416.0 11408.0 11405.5 11401.5 11399.5 11397.5 11392.5 11388.0 11386.0 11374.5 11370.5 11366.5 11516.5 11510.5 11505.5 11494.5 11492.5 11488.0 11482.0 11479.0 11475.5 11456.5 11452.5 11451.0 11445.5 11440.0 11438.0 11434.5 11433.0 11429.0 11426.5 11416.0 11412.0 11403.0 11399.5 11395.0 11387.5 11383.5 11370.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 18 11364.0 11363.0 11359.5 11357.0 11350 0 11349 0 11346 5 11344 5 11338 0 11334 0 11331 5 11330 0 11324 0 11321 5 11314 5 11314 0 11313 5 11310 5 11307 5 11298 5 11296.0 11294.5 11293.0 11291.0 11287.0 11285.5 11284.5 11283.0 11272.5 11272.0 11266.5 11265.0 11261.0 11257.5 11254.0 11249.0 11245.5 11243.5 11242.5 11241.5 11237.5 11234.0 11228.0 11221.5 11217.0 11216.0 11214.0 100.0 $ 11363.5 11360.5 11355.5 11350.5 11347.5 11334.5 11331.0 11326.0 11323.0 11316.5 11311.5 11309.0 11299.0 11295.0 11292.5 11291.0 11287.5 11285.0 11283.0 11273.5 11264.0 11262.0 11251.0 11247.0 11244.5 11243.0 11239.0 11233.5 11227.5 11221.0 11218.0 11212.5 98.5 11366.0 11351.5 11347.0 11340.5 11332.5 11323.5 11315.0 11313.0 11297.0 11287.5 11273.5 11266.5 11258.0 11255.0 11243.0 11215.0 99.0 THIS FILE CONTAINS CASED HOLE CNL PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNL CURVES WITH THE NPHI SHIFTS. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 19 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1102987 00 000 O0 0 3 1 1 4 68 0000000000 NPHI CNL PU-S 1102987 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNL 1102987 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNL 1102987 O0 000 O0 0 3 1 1 4 68 0000000000 NCNTCNL CPS 1102987 O0 000 O0 0 3 1 1 4 68 0000000000 FCNTCNL CPS 1102987 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNL CPS 1102987 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNL CPS 1102987 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CArL GAPI 1102987 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNL LB 1102987 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNL V 1102987 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11852.500 NPHI.CNL 30.590 NRAT. CNL 4.800 CRAT. CNL NCNT. CNL 3148.595 FCNT. CNL 656.000 CFTC. CNL 630.031 CNTC. CNL GRCH. CNL -999.250 TENS.CArL 1508.000 CCL. CNL 0.000 5.116 3166.907 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 2O DEPT. 11208.500 NPHI.CNL NCNT. CNL -999.250 FCNT. CNL GRCH. CNL 57.247 TENS.CArL -999.250 NRAT. CNL -999.250 CFTC. CNL -999.250 CCL.CNL -999.250 -999.250 -999.25O CRA T . CNL CNTC. CNL -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE · 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASSNUI~ER: 4 DEPTH INCRE~4ENT: 0.5000 FILE SOI~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11850.5 11207.0 CNL 11851.5 11209.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFiBER: 1 BASELINE DEPTH 88888.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CArL 88890.5 88886.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 21 11848.5 11843.0 11842.0 11839.5 11837.5 11835.5 11835.0 11834.0 11832.0 11827.0 11826.5 11824.5 11822.0 11820.5 11819.5 11817.5 11816.0 11809.0 11808.5 11805.0 11804.0 11803 5 11800 5 11797 0 11789 0 11784 0 11783 5 11779 5 11778 5 11776.0 11768.5 11766.0 11764.5 11762.0 11754.5 11749.0 11744.5 11743.5 11740.5 11739.0 11738.5 11738.0 11735.5 11734.5 11730.0 11727.5 11727.0 11725.5 11723.0 11720.0 11719.0 11712.5 11712.0 11707.0 11700.0 11844.5 11837.0 11835.0 11833.0 11828.0 11825.5 11823.0 11820.0 11809.0 11805.0 11800.5 11785.0 11779.0 11776.0 11766.5 11761.5 11746.5 11743.0 11740.5 11738.0 11729.0 11727.5 11722.0 11715.0 11701.0 11847.0 11842.0 11837.0 11836.0 11833.0 11831.0 11828.0 11824.5 11821.0 11814.5 11810.0 11806.5 11805.5 11797.5 11790.0 11782.5 11779.5 11767.0 11764.5 11762.0 11755.0 11749.5 11746.5 11743.5 11742.5 11740.5 11737.0 11732.5 11730.5 11724.5 11722.0 11715.0 11710.5 11700.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 22 11698.0 11698.5 11695.5 11695.5 11692.5 11691.0 11692.0 11691.0 11686.0 11686.0 11681.0 11680.5 11679.0 11678.0 11675.5 11675.5 11669.0 11670.0 11668.0 11669.0 11667.5 11668.5 11663 . 0 11664.5 11661 . 0 11660.0 11658.5 11658.5 11653.5 11653.0 11651.0 11650.0 11644.5 11644.5 11643.0 11642.5 11639.0 11640.0 11635.0 11636.5 11633.5 11635.0 11629.5 11630.0 11626.5 11627.5 11628.0 11625.0 11625.5 11623.5 11625.0 11621.5 11621.5 11617.5 11619.0 11614.0 11618.0 11613.5 11615.5 11610.0 11611.5 11608.5 11611.5 11602.5 11603.5 11602.0 11603.5 11599.5 11600.5 11595.5 11596.5 11592.0 11593.0 11590.5 11591.0 11586.0 11586.0 11579.5 11579.5 11579.0 11573.0 11572.0 11566.5 11564.0 11565.5 11567.5 11558.0 11559.0 11554.0 11555.0 11542.0 11543.0 11541.5 11542.5 11537.0 11538.5 11534.5 11536.0 11531.5 11532.0 11531.5 11529.5 11529.5 11529.0 11529.5 11527.0 11528.0 11522.0 11523.0 11517.0 11517.5 11514.0 11516.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 23 11507.0 11508.0 11504.5 11505.0 11501.5 11502.5 11500.0 11500.0 11492.0 11495.0 11487.0 11488.5 11479.0 11481.5 11478.0 11479.0 11476.5 11477.0 11475.5 11476.0 11472.5 11473.5 11471.0 11472.0 11469.0 11470.0 11466.5 11467.0 11466.0 11465.5 11462.5 11463.5 11461.0 11461.5 11460.0 11460.0 11458.5 11458.0 11456.0 11456.5 11455.5 11456.0 11452.5 11453.0 11448.5 11449.5 11448.0 11449.5 11446.0 11447.5 11444.0 11445.0 11442.0 11443.0 11443.0 11440.5 11440.0 11440.0 11440.0 11438.0 11438.0 11437.5 11438.0 11435.0 11435.5 11434.5 11433.0 11433.5 11431.5 11433.0 11430.5 11430.5 11427.0 11427.5 11426.0 11427.0 11422.0 11423.0 11420.5 11420.5 11418.5 11419.5 11416.0 11416.0 11416.0 11411.0 11410.5 11409.0 11408.5 11408.0 11401.0 11402.0 11399.5 11399.5 11398.5 11399.5 11397.0 11397.5 11395.5 11397.5 11394.0 11394.0 11391.5 11391.5 11389.5 11389.5 11385.5 11387.5 11384.0 11386.5 11382.0 11384.0 11379.5 11380.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 24 11375 0 11374 0 11369 5 11368 5 11364 5 11358 5 11351 5 11351 0 11346.5 11345.0 11340.0 11338.5 11334.5 11332.0 11328.0 11327.0 11325.5 11324.0 11321.5 11315.0 11313.0 11307.5 11306.0 11304.5 11302.0 11299.0 11298.5 11298.0 11294.5 11292.0 11288.0 11283.0 11281.5 11280.0 11279.5 11271.0 11266.5 11266.0 11261.0 11258.5 11256.0 11250.0 11249.5 11246.0 11242.0 11240.5 11239.0 11229.0 11228.0 11225.5 11222.5 11215.0 11214.5 100.0 $ 11374.5 11370.5 11364.0 11358.0 11351.5 11347.5 11341.0 11334.5 11327.0 11317.0 11309.0 11307.0 11304.0 11299.0 11295.5 11283.0 11281.0 11278.0 11273.0 11268.0 11262.0 11251.0 11243.5 11241.0 11227.5 11224.0 11212.0 97.0 11375.0 11370.5 11351.5 11347.0 11341.0 11335.0 11333.0 11330.0 11327.0 11326.0 11323.5 11317.0 11314.5 11306.5 11303.5 11299.0 11297.0 11293.0 11287.5 11282.0 11280.5 11266.0 11258.5 11255.0 11250.0 11246.5 11240.5 11230.0 11227.0 11214.0 99.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 25 REM3LRKS: THIS FILE CONTAINS CASED HOLE CAUL PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #4 AND GRCH PASS #1, ALSO NPHI PASS #4 AND NPHI PASS #1, CARRYING ALL CNL CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA_M~ SERV UNIT SERVICE APIAPI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 4 1 1 4 68 0000000000 DEPT FT 1102987 NPHI CArL PU-S 1102987 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CArL 1102987 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNL 1102987 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CArL CPS 1102987 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNL CPS 1102987 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CArL CPS 1102987 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNL CPS 1102987 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNL GAPI 1102987 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CArL LB 1102987 O0 000 O0 0 4 1 1 4 68 0000000000 CCL CNL V 1102987 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 26 ** DATA ** DEPT. 11851.500 NPH~.CNL NCNT. CNL 3170.909 FCNT. CNL GRCH. CNL -999.250 TENS. CArL DEPT. 11207.000 NPHI. CNL NCNT. CNL -999.250 FCNT. CNL GRCH. CNL 57.604 TENS. CArL 31.655 NRAT. CNL 613.139 CFTC. CNL 1520.000 CCL. CNL -999.250 NRAT. CNL -999.250 CFTC. CNL -999.250 CCL.CNL 5.172 CRAT. CNL 588. 866 CNTC. CNL O. 000 -999.250 CRAT. CNL -999.250 CNTC. CNL -999.250 5.243 3198.071 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION · O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INC~ 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUM~ERS 1, 2, 3, 4, CNL THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1, 2, 3 &4. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 27 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 FT 1102987 PU-S 1102987 O0 000 O0 0 5 1 1 4 68 0000000000 1102987 O0 000 O0 0 5 1 1 4 68 0000000000 1102987 O0 000 O0 0 5 1 1 4 68 0000000000 CPS 1102987 O0 000 O0 0 5 1 1 4 68 0000000000 CPS 1102987 O0 000 O0 0 5 1 1 4 68 0000000000 CPS 1102987 O0 000 O0 0 5 1 1 4 68 0000000000 CPS 1102987 O0 000 O0 0 5 1 1 4 68 0000000000 GAPI 1102987 O0 000 O0 0 5 1 1 4 68 0000000000 LB 1102987 DEPT NPHI CNAV NRA T CNA V CRAT CNAV NCNT CNAV FCNT CNAV CFTC CNAV CNTC CNAV GRCH CNL TENS CNL O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11852.000 NPHI. CNAV -999.250 NRAT. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNL -999.250 TENS. CNL 1502.000 DEPT. 11193. 500 NPHI. CNAV -999. 250 NRAT. CNAV -999. 250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNL 55. 562 TENS. CNL -999. 250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 28 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASSNUFiBER: 1 DEPTH INCRzS~4F2FT: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11887.5 11192.5 CNL LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 11-0CT-97 8B1-129 1946 11-0CT-97 11868.0 11868.0 11194.0 11853.0 1800.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 29 GR CNL $ GAM~A RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TE~JPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CGRS -A CNT- D 8. 000 12000.0 SEAWATER 8.40 180.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 5600 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 25000 TOOL STANDOFF (IN): REMARKS: SEAWATER WAS PUMPED INTO WELL FOR LOGGING ONE PERF INTERVAL FROM 11812 - 11887 FEET LOGGED FROM TD TO 11200 FEET FOUR PASSES AT 1800 FPH cArL run to analyze fluid movements including GOC, gas underruns and oil lens drainage. Data needed to plan wellwork and new penetrations to effectively deplete K-Pad reserves. INITIAL PUMPING OF 240 BBLS INSUFFICIENT. AN ADDITIONAL 300 BBLS WAS PUMPED TO COMPLETE LOG. TIED INTO SWS BHC LOG DATED AUG. 14/83 THIS FILE CONTAINS THE RAW DATA FROM PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 30 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS1 PU 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS1 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 TNRAPS1 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS1 CPS 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS1 CPS 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS1 CPS 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS1 CPS 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 CCLDPS1 V 1102987 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11887.500 NPHI.PS1 66881.453 RTNR.PS1 -999.250 TNRA.PS1 RCNT. PS1 4000.000 RCFT.PS1 0.000 CNTC. PS1 3916.387 CFTC.PSi GR.PS1 55.938 TENS.PSi 830.000 CCLD. PS1 0.000 DEPT. 11192.500 NPHI.PS1 53.847 RTNR.PS1 7.596 TNRA.PS1 RCNT. PS1 2187.755 RCFT. PS1 288.000 CNTC. PSl 2098.049 CFTC. PSI GR.PS1 48.561 TENS.PSi 1433.000 CCLD. PS1 -999.250 -1056.501 0.000 7.765 276.599 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 31 ** END OF DATA ** **** FILE TRAILER **** FILE NA~IE : EDIT .006 SERVICE ·FLIC VERSION ·O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .007 SERVICE : FLIC VERSION ' O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11897.0 11207.0 CNL LOG HEADER DATA DATE LOGGED: 11~0CT-97 SOFTWARE VERSION: 8B1-129 TIFiE LOGGER ON BOTTOM: 1946 11-0CT-97 TD DRILLER (FT) : 11868.0 TD LOGGER (FT) : 11868.0 TOP LOG INTERVAL (FT) : 11194.0 BOTTOM LOG INTERVAL (FT) : 11853.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 32 GR CNL $ GAM~A RAY COMPENSATED NEUTRON CGRS-A CNT- D BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.000 12000.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TRMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEAWATER 8.40 180.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5600 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 25000 TOOL STANDOFF (IN): REMARKS: SEAWATER WAS PUMPED INTO WELL FOR LOGGING O1VE PERF INTERVAL FROM 11812 - 11887 FEET LOGGED FROM TI) TO 11200 FEET FOUR PASSES AT 1800 FPH CArL run to analyze fluid movements including GOC, gas underruns and oil lens drainage. Data needed to plan wellwork and new penetrations to effectively deplete K-Pad reserves. INITIAL PUMPING OF 240 BBLS INSUFFICIENT. AN ADDITIONAL 300 BBLS WAS PUMPED TO COMPLETE LOG. TIED INTO SWS BHC LOG DATED AUG. 14/83 THIS FILE CONTAINS THE RAW DATA FROM PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 33 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS2 PU 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS2 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS2 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS2 CPS 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS2 CPS 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS2 CPS 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS2 CPS 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 CCLD PS2 V 1102987 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11897.000 NPHI.PS2 23.554 RTNR.PS2 4.000 TNRA.PS2 RCNT. PS2 4000.000 RCFT. PS2 1000.000 CNTC. PS2 3916.387 CFTC. PS2 GR.PS2 55.938 TENS.PS2 1187.000 CCLD. PS2 0.000 DEPT. 11207.000 NPHI.PS2 56.522 RTNR.PS2 7.147 TNRA.PS2 RCNT. PS2 2016.529 RCFT. PS2 282.158 CNTC. PS2 2048.023 CFTC. PS2 GR.PS2 61.495 TENS.PS2 1419.000 CCLD. PS2 -999.250 4.229 960.413 8. 071 270.988 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 34 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SOWi~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11888.0 11208.5 CArL LOG HEADER DATA DATE LOGGED: 11-0CT-97 SOFTWARE VERSION: 8B1-129 TIME LOGGER ON BOTTOM: 1946 11-0CT-97 TD DRILLER (FT) : 11868.0 TD LOGGER (FT): 11868.0 TOP LOG INTERVAL (FT) : 11194.0 BOTTOM LOG INTERVAL (FT) : 11853.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH coNTRoL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ........... LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 35 GR CNL $ GAF~CA RAY COMPENSATED NEUTRON CGRS-A CNT- D BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8.000 12000.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEAWATER 8.40 180.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5600 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 25000 TOOL STANDOFF (IN): REMARKS: SEAWATER WAS PUMPED INTO WELL FOR LOGGING ONE PERF INTERVAL FROM 11812 - 11887 FEET LOGGED FROM TD TO 11200 FEET FOUR PASSES AT 1800 FPH CNL run to analyze fluid movements including GOC, gas underruns and oil lens drainage. Data needed to plan wellwork and new penetrations to effectively deplete K-Pad reserves. INITIAL PUMPING OF 240 BBLS INSUFFICIENT. AN ADDITIONAL 300 BBLS WAS PUMPED TO COMPLETE LOG. TIED INTO SWS BHC LOG DATED AUG. 14/83 THIS FILE CONTAINS THE RAW DATA FROM PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 36 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1102987 O0 000 O0 0 8 1 1 4 68 0000000000 NPHI PS3 PU 1102987 O0 000 00 0 8 1 1 4 68 0000000000 RTNR PS3 1102987 O0 000 O0 0 8 1 1 4 68 0000000000 TNRA PS3 1102987 O0 000 O0 0 8 1 1 4 68 0000000000 RCNTPS3 CPS 1102987 O0 000 O0 0 8 1 1 4 68 0000000000 RCFT PS3 CPS 1102987 O0 000 O0 0 8 1 1 4 68 0000000000 CNTC PS3 CPS 1102987 O0 000 O0 0 8 1 1 4 68 0000000000 CFTC PS3 CPS 1102987 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1102987 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1102987 O0 000 O0 0 8 1 1 4 68 0000000000 CCLDPS3 V 1102987 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11888.000 NPHI.PS3 23.554 RTNR.PS3 4.000 TNRA.PS3 RCNT. PS3 4000.000 RCFT. PS3 1000.000 CNTC. PS3 3916.387 CFTC. PS3 GR.PS3 55.938 TENS.PS3 990.000 CCLD.PS3 0.000 DEPT. 11208.500 NPHI.PS3 58.301 RTNR.PS3 8.602 TNRA.PS3 RCNT. PS3 2176.000 RCFT. PS3 252.964 CNTC. PS3 2014.181 CFTC. PS3 GR.PS3 52.300 TENS.PS3 1410.000 CCLD.PS3 -999.250 4.229 960.413 8.275 242.950 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 37 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11894.5 11209.5 CArL LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VEalrDOR TOOL CODE TOOL TYPE 11-0CT-97 8B1-129 1946 11-0CT-97 11868.0 11868.0 11194.0 11853.0 1800.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 38 GR CNL $ GAM~A RAY COMPENSATED NEUTRON CGRS-A CNT-D BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8.000 12000.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) '. GAS/OIL RATIO: CHOKE (DEG) : SEAWATER 8.40 180.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5600 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 25000 TOOL STANDOFF (IN): REMARKS: SEAWATER WAS PUMPED INTO WELL FOR LOGGING ONE PERF INTERVAL FROM 11812 - 11887 FEET LOGGED FROM TD TO 11200 FEET FOUR PASSES AT 1800 FPH CNL run to analyze fluid movements including GOC, gas underruns and oil lens drainage. Data needed to plan wellwork and new penetrations to effectively deplete K-Pad reserves. INITIAL PUMPING OF 240 BBLS INSUFFICIENT. AN ADDITIONAL 300 BBLS WAS PUMPED TO COMPLETE LOG. TIED INTO SWS BHC LOG DATED AUG. 14/83 THIS FILE CONTAINS THE RAW DATA FROM PASS #4. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 39 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ND~B SAMP ELEM CODE (HEX) DEPT FT 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 NPHI PS4 PU 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 RTNR PS4 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 TNRA PS4 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 RCNTPS4 CPS 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 RCFT PS4 CPS 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 CNTC PS4 CPS 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 CFTC PS4 CPS 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS4 LB 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 CCLD PS4 V 1102987 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 11894.500 NPHI.PS4 41.388 RTNR.PS4 6.000 TNRA.PS4 RCNT. PS4. 6000.000 RCFT. PS4 1000.000 CNTC. PS4 5874.580 CFTC. PS4 GR.PS4 0.000 TENS.PS4 810.000 CCLD. PS4 0.010 DEPT. 11209.500 NPHI.PS4 54.537 RTNR.PS4 7.285 TNRA.PS4 RCNT. PS4 2105.263 RCFT. PS4 288.973 CNTC. PS4 2005.339 CFTC.PS4 GR.PS4 57.604 TENS.PS4 1410.000 CCLD. PS4 -999.250 6.344 960.413 7.844 277.534 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-JUN-1998 11:39 PAGE: 4O ** END OF DATA ** **** FILE TRAILER **** FILE NANiE : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/06/ 1 ORIGIN : FLIC TAPE NAME : 98259 CONTINUATION # : 1 PREVIOUS TAPE : COMM_F2VT : BP EXPLORATION, PRUDHOE BAY, K-O1, API #50-029-20998-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/06/ 1 ORIGIN ' FLIC REEL NAME : 98259 CONTINUATION # : PREVIOUS REEL : COMFiENT : BP EXPLORATION, PRUDHOE BAY, K-O1, API #50-029-20998-00 bVP O10.H02 VERIFICATION LISTING PAGE 1 ** REEL HEADER DATE :~3/10/25 ORIGIN : REEL NA~E :REEL ID CONTINUATION # PREVIOUS REEL : COMMENTS :REEL COMMENTS ** TAPE HEADER ** SERVICE NAME :EDIT DATE :83/10/25 ORIG~N :0000 TAP~ NAM~ :8536 CONTINUATION # PRMVIOUS TAPE : CO~' 'NT$ :TAPE COMMENTS ********** EOF ********** ** FILE }{FADER ** FILE NAME :EDIT ,001 SERVICE NAME : VERSION # : ~AXIMU~ LEN~TM : 1024 FILE TYPE PREVIOUS FILE : ** INFORMATION RECORDS MNMM CONTENTS CN ~ SOHIO ALASKA PETROLEUM COMPANY N : K-1 : PRUDHO~ BAY TOWN: tln SECT: 4 COON: N. SLO E STAT: CTRY: USA ** C,O~ENTS ** UNIT TYPE CATE SIZE CODE 000 000 o3o O65 000 000 01'0 065 000000 000000 §~ 0650~5 000 000 004 065 000 000 002 065 000 000 008 000 000 006 065 000 000 004 065 ~¥P 010.N02 YERIFICATIDN LISTING PAGE ~ SCHLUPBER~ER * ~ ALASKA COMPUTIMg C£MTER * ************************************************************************************ THIS LISTING REPRESENTS A MERGED PRODUCT OF RUN! RUN~ AND RUN3. *********************************************************~.************************* ~OMPANY = SOHIO ALASKA PETROLEUM COMPANY ~ELL = FIELD = PRUDHO~ BAY COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACC: 68536 bDP: MGM TY FLUID -XC625" ~ - POLYMER DE TY = g 6 LB/G VISCOSITY : 3~,0 S FbU~D LOss = 6,0 C] MATRIX SANDSTONE 11248' - BIT SIZE = 8 1/2" Tf] 1204]' RM RMF RMC RM AT BHT 3.040 ~ 79,0 DF 3,010 ~ 61,0 DF 3.100 ,~ 64 0 DF 1.520 ~ 16~.0 DF DVP 010,M02 VEPIFICATION L~STIB~G PAGE JOB NUMBER AT ACC: 68519 RUN. #2, DATE LOGGED: LDP: TYPE FLUID DENSITY VISCOSITY FLUID LOSS 13,375" 0 2814' - BIT SIZE = 12 1/4" GEL, POLYP!ER 9 8 bB/G RM 3~.o s R~F 9.5 ~MC 6,4 C3 RM AT BHT 2.500 0 63,0 DF 2.400 0 63,0 DF 3.080 0 63 0 DF 1,017 a 16~,0 DF MATRIX SANDSTONE JOB ~4U~BER AT. ACC: 6865] RUI" "1 D~TF, LOGGED: 8-14',,83 CASING TYPE FLUID DENSITY VISCOSITY FbUIO t, Oss = 20,0" 0 1.20' ' BIT SIZE = 17.5" = LIGNOSULFONATE = 9,3 LB/G RM = 33.0 S RMF = 9 = 14,4 C3 RM AT BHT 080 ~ 62,0 DF 3~190 0 62,0 DF 2,260 ~ 62 0 DF 897 O ,10~'0 DF ,( '.,VP 010,~02 V~IFICATI(1N [,ISTI~IG PAGE 4 ~ DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE RgPR CODE ENTRY 4 1 66 ~ 4 73 6O 9 4 65 ,lI~ 0 ~ 66 0 DATUM SPECIFICATLON BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE PROCESS SAMPLE REPR DE/.{ ID ORDER # bO~ TYPE CLASS MOD NO, FT 0 0 0 0 0 4 SFLU DIL OHMM 7 0 0 0 0 4 ILL DIL OHM~ 7 12 46 0 0 4 IbM DIL OHMM 7 0 0 0 0 4 SP DIL ~V 7 ]. 0 0 0 4 GR DIL GAP! 7 3! 32 0 0 4 ~ ~.c ~,~ ~o ~ ~ o o 4 NPHI LDT PO 0 68 2 0 0 4 ~..0 ~ ~;ca 0 44 0 0 0 4 CAbI ~,OT T. 0 ~8 3 0 0 4 ~.~A t,~o? o o o o o 4 p~ ~,~? o o o o o 4 GR CNL GAP! 42 31 32 0 0 4, LEVEL CODE 0 1 68 0 i 68 0 1 68 0 1. 60 0 1 68 0 1 68 0 1 6~ 0 I 68 0 1 68 0 1 68 0 1 6~ 0 I 68 0 1 68 0 I 68 0 ! 68 0 I 68 0 I 6~ 0 I 68 0 1 68 SP '1! 5469 NP~I -999 2500 DR. HO FC'NL -999 9500 CALI PEF -999 2500 GR 2,9805 I'bD 93,6250 DT '999.,.2500 RHOB '999~2500 NRAT '999,2500 GR 9 , 62 GR -999,2500 NCNL -999,2500 RNRA -999,~500 2 3398 -099,2500 -999.~500 2ooo.oooo sr~,,,~, 3.4v~ -o~, .~,~? c,. .~.~soo 3,0039 92.0625 3 ;~ 52 ' ~0~ 5VP OlO,tt02 VERIFICATION I_,ISTI~G PAGE 5 ~PH! 36.9629 DEMO ?CNb -1307.0000 CALl ~EF ].9512 DEPT 11900.0000 SFbU SP '33,0625 NPHI 35.8398 DRHO FCNI, 1058.0000 CALI PEF 3.0469 GE D£PT llgO0.O000 SFLU SP -92.4375 GR NPHI 28,7109 DEMO FCNL 1049.0000 CAbI PEF 2.6934 1170O 0000 -55 5OD0 22 7539 1694 0000 2 4141 DEPT 11600,0000 SFbU SP -78.6875 GR ~PHI 24.41,4! DEMO 1[500 0000 -50 4063 2~ 0215 1.49 00o0 ] 2363 O~PT 11400,0000 8P -4,5742 NPHI 24,2676 DEMO FC. 1o7 oooo [ 0..oo0o NPHI 51'7578 DRHO FCN[, 345,0000 CAbI PEF 3.6836 GR OEPT 11~00,0000 8FbU SP 51.,6563 GR NPHI 39,~1602 DEMO FCN[,, 559.0000 CA.[,[ PEF 2~8633 GE OEP? lliO0"O000 Sr[,u SP 19,9375 D£PT SP ~P DEPT SP NPHI ?CN [, PEF GR DEMO CALI SFhU 5,9883 8,0156 -206,7500 22,0000 69 3750 1045 ~ 5547 65,2500 33.0000 20.0781 0.0337 8.5000 3.9687 20.5938 22.5625 -0.0103 8,3359 29.8906 58'6250 15,117.2 -0.0303 8.4063 18.5313 57 4375 26 609.4 -0 0264 8 5859 26 9~44 10.7969 124.3125 2 1074 95 50OO 0 1.4 I0,4 ~6 1875 8750 -0.~ 05 12, 107,81~5 2,9746 NEAT GR ILD DT RHO8 NEAT DT RHOB NEAT GR DT RHOB NEAT DT RHOB NEAT GE ILO DT RHOB NEAT GR ILD DT RHOB NEAT ILO DT RHOB NRAT GR DT. NEAT D T 14,8906 3,1211. -999,2500 10.6094 ~3.5000 2.3008 3,0254 -999.2500 24.1406 102.1875 2.2734 2.6563 -999.2500 25 1094 80:6875 3633 -999.2500 56.6250 go,o000 2,2578 ,99~ '3594 .2500 81 100 2 2 -999 8 '999, -999' 2 3 69 2 100 0625 2500 2480 2168 2500 9844 3750 61gl 4297 2500 7764 5OO 480 383 2500 .9531 .4375 ,5508 .4980 .3750 ,6992 ,9375 NCNb RNR A IbM GR NCNb RNRA IbM GR NCNb R NRA IbM GR NCNb RNEA IbM GR NCNb RNRA GE NCNL RNRA IbM R N C N [, RNRA GR NCNb RNRA GR NCNb -4356 0000 3:3320 11.3906 69.3750 3278,0000 3.0977 20.7031 20.0781 2.0000 3092.9473 21.9o62 22.5625 4086.0000 2.4102 43,3750 1,5.1172 3752,0000 2,531.3 48 3750 26:6094 3564,0000 2,3809 9,0547 96,0000 264].~000 . 590 8623 :sooo 155.~,0000 ,4961 825 .0742 ., 8750 1846.0000 3.3008 2.~895 102. 125 5VP 010.H02 VERIFICATION LISTING PAGE 6 ~PgI 43 2617 DRHO ~CNb 463i5000 CALI ~EF 2 7676 GR DEPT llO00.O000 SFLU 5P -11 0156 ~R ~PHI 39!0137 DRHO rCNL 495 0000 CAb! ~£F 2 8008 GR O. 12, 1.06, 2 O. 12. 108, DRPT 10900,0000 SFLU 4 SP -I0.9922 GR 78 NPHI 32.0313 DRHO 0 ?CNI., 605.0000 CA£,I 13 PEF 2.1719 OR 83 DF. PT 10800. O000 SFI,,,U 2 SP -34.9375 GR 109 35.3027 DR.O 0 FC% 464,0000 PEF 2.3027 GR '97 DEPT 10700 NPHI 42 FCNL 393 PEF 2 O000 SFLU 0156 GR 8223 DRHO 2500 CALl 53~3 GR DEPT 1060.0 0000 8FhU 8P -27i5469 GR NPHI 48 1934 DRHO FCNb 333,2500 CALI P~F 2,8027 GR DEPT 10500 SP NpHI 48 FCNL 438 PEF 3 0000 SFLU ~469 GR 8770 DRHO 5000 CALI 7227 ~R j ~T 10400 -41 NPH! 41 FCNb 455 PE'F 3 0 GR 922 DRHO .500 CAbl 0996 ~R SP NPHI 38. FCNL, 52 ! PEF ] 0000 SFbU 8125 GR 3301 DRHO 0000 CAbI 6230 GR 2 105 0 13 96 6. 232, 12. 237. 190, 174' 0 13 129 O, 13. 1'15, DEPT 1.0200,o000 SFLU 13, SP -29,~594 GR 118. 0474 9062 0000 7480 6875 O2OO 6172 8750 7031 2500 0767 3047 6250 4922 1250 0039 4688 0000 4473 5625 0249 1406 8750 4531 8750 0122 5OOO 8750 1758 0366 0781 5000 7656 7500 0537 2578 8750 1484 3750 .40146 375 7500 RHOB NRAT GR DT RHOR NRAT DT RHOB NRAT ILD DT RHOB NRAT GR RHOB NRAT GR DT RHOB NRAT ~R ILO DT RHOB NRAT DT RHOB NRAT ILD DT RHOB NRAT DT 2.4043 3 7246 47:3750 2.4219 100.6875 2.4102 3.4824 52.4063 3.7188 92.0000 2.4512 3,~230 50,9687 2.1914 90,0000 2.4082 3 2969 62:3750 2.1406 1.06.3125 2.3594 3,7090 67.3125 3,8848 115,7500 2,1348 3.9883 140'2500 5,9961 106.6250 2,3477 4,0391 132,1250 4,8594 107,1875 2.. 3,49 6 3,6641 93,5625 8,4219 106,5ooo .3 74,3750 9,8594 I04.0000 NCNb RNRA GR NCNb RNRA I LI~ GR NCNb RNRA IL~ GR NCN[~ RNRA IbM OR NCNb RNRA ! bM NCNb RNRA GR NCNb RNRA ! LM GR NCNb RNRA GR NCNb RN~A I bM GR 1790.0000 3.8613 2.4922 ~13.6875 1886.0000 3.8086 3.8027 78.2500 2011,0000 3.3223 2,2383 1.09,1250 1738,0000 3,7441 2,1387 105,5625 173~,0000 .4180 4,2930 ~3~,8750 .0000 1484.4609 3 190, 1794,000~ 4,089 4,~258 132. 500 184~,0000 ,0508 8,1953 132,3750 203~.00~.0 ,91 1 9,4'922 118,5625 JVP 010.H02 VERIFICATION LISTING PAGE 7 IPH! 44 1406 DRHO ~CNL 431i$000 CALl ~EF 3 6406 ~R )EPT 10100.0000 SFLU ;P -23.3125 GR CPHI 35.9375 DRHO ~CNL 560 5000 CALI ;£F 321680 GR )EPT 10000.0000 SFLU SP -0.3716 GR qPHI 37.7441 DRHO ?CNL 535.0000 CALI PEF 2.8184 ~R 9EPT 9900.0000 SFLU 5P -23.3125 GR 31.~g18 ~RHO ooo PEF" . ~9961 GR 9800 0000 -27 ~594 36 4746 576 5000 2 ~867 DEPT 9Z00..~000 ~FLU bP 25, 500 GR NPH! 2~..2969 DRHO FCNL 72 ,0000 CALI SP 10,2 GR NPHI 27.0508 DEHO 0000 PEF 5664 GE , oooo PEF 5645 ~R DEPT 9~00.0000 SFLU 8P 38.~125 GR NPH! 29.2969 DRHO FCNL 80],0'000 CALl PEF 3.0000 GR DEPT 9100,0000 gFb~ SP 29.3438 G~ DEPT SP NPHI FCNL PEF DRHO CALl -0 O4O5 12!9766 6.2891 145 7500 0.0664 13.8281 122.3750 :1914 15 1250 0.0396 14.2734 146,1250 5 6953 114 5000 0 0635 13 4219 107 0750 3.5645 16, 1250 .0.0000 98. 0 4 9062 92 ~875 0 322 86 8750 6 5352 70 7500 .o t4 34 78 2500 5078 75O0 17 8125 3 .6426 89 5625 14 5984 87 8125 3.500O 95.8125 RHOB NRAT RHOB NRAT GR DT RHOB NEAT GR ILO DT RHOB NRAT DT NR&T DT RHOB NEAT I LD DT RHOB N. RAT DT NEAT GR ILD DT NRAT DT ?.3496 3.7754 76.3750 5.9062 92.2500 2.5215 3.3438 78.8750 5.0352 97,8750 2.4551 3,4551 54.1875 5.9414 9~.3750 ,4355 3.0957 66.3750 4. 5703 88. 4375 2.5156 3 3730 6920000 5 1484 90 3750 2 4863 2 98.05 56 31.25 6,~219 1. 250 2,3 77 2 4941 3 0840 51.21.87 4,0898 80.3125 2,4922 2.9824 51.3750 , 9004 9 .O625 NCNb RNRA GR NCNb RNRA GR NCNb RNRA IbM NCNb RNRA NCNb RNRA ILM GR NCNb RNRA ! LM GR NCNb R NRA IbM NCNb RNRA IbM GR NCNb RNRA GR 1854.0000 4.2930 5,7031 145.7500 1804,0000 3.2168 5,0742 157.1250 1846.0000 3.4492 5.7266 114,5000 1894,0000 3,1074 4.2383 11.6,1250 2136,0000 3,705t 6.~789 70, 500 265~,0000 ,8301 3,8184 83.7500 2471.0000 .2031 76 26283,~000 715 , 8809 9 .8125 bVP 010.M02 VEPlFICATIOW LISTING PAGE {P~I 32,O313 DRMO ?CNL ~03,0000 C~LI PEF 2,7969 GR 0 14 92 DEPT 9200. 0000 SFLU SP -31 3125 GR NPHI 29:7363 DRHO FCNL 771.5000 CAb! PEF 2. 3945 GR 3 95 14 86 DEPT glO0 SP -28 NPH! 32 FCNL ~42 PEF 2 0000 1875 OR 2754 DRHO o000 CALl 6465 GR 3 93 0 15 87 DEPT go00,0000 SFLU SP '1.9,8437 GR ~,,' 29.0039 DRHO :oooo PEF 4492 GR 3 -0 15 83 DEPT 8900,0000 SFLU ~Np -41,8125 GR PHI 30. 3223 DRHO FCN[, 792, oooo cat,~ PEF 3 :0430GR 6 81. ',0 15 81' O£P? 8800 SP -42 NPHI 27 PEr 3 0000 SFLU 2813 GR 0996 DRHO 0000 CALI 2305 GR 5 82 0 15 8~1 DEPT 8700 SP r C N b 7 PEr 2 000 SFt, U 0 0 CAbI 4 -0 15 80 NPH l rCNb PEF 8600 °47 29 771 2 0000 SrLU 562 363 DRHO 5000 CAY.si 7129 UR 4 66 7~ DEPT SP NPH! FCNh PE.F' ,,58 0000 SFI, U 9062 GR 7109 DRHO 5000 CALI 3555 GR -0 17 DEPT sp .4375 GR 6 49 ,0010 .6953 .7500 .0293 5625 :0181 .4453 .3125 .8008 .3750 ,0352 ,2500 ,5000 3555 9375 0078 1797 5625 4336 50OO 0137 6563 6875 ,8672 ,1875 :7500 3125 187 750 4.54 313 5000 .1719 7500 5O156 938 .0625 ,~836 , 188 RHOB NRAT GR ZLD DT RHOB NRAT GR RHOB NRAT GR DT RHOB ILD DT NRAT GR ILO DT. RHOB NRAT DT RHOB NRAT DT RHOB GR DT RHOB NRAT GR DT 3. 50. , 93. 2, 3. 54. 92. 2. 3. 49. 2, 2. 46. 0 91. 2, 3, 60, 5 93 6O 5 5 87 2 3 55 2 8O 4668 1602 7500 2617 3750 4082 0020 7813 3477 8125 4414 1895 0938 0391 0000 4160 9727 5938 1406 1250 4375 0723 oo0o 4570 5000 0625 3086 9375 4238 8184 3125 4570 1250 4609 0293 9375 ,1992 ,0000 ,4395 ,0137 ,6250 ,8945 .6875 NCNb RNRA IbM GR NCNb RNRA GR NCNb RNRA IbM GR NCNb RNRA IbM NCNb R NRA IbM GR NCNb RNRA NCNb RNRA .I b M NCNb RNRA NCNb R N R A IbM GR 2598,0000 3,2344 3 2402 95}5625 2472 0000 3 2031 4 2109 93:3750 2308,0000 3.5938 85 93 5 247] 00 7 0;.34 81!5000 2576 0000 3 2520 i, 4258 8 ,18'/5 ,0000 2462,7988 8~' 1680 ,1875 247~'0000 ,1992 0000 2520 5,1406 83. 7500 22662,0000 3,1445 3 ,. _42 7 7 49,7188 ijvP 010,H02 VERIFICAT.[ON LIS?lNG PAGE 9 qPH! ?CN I, 5t:' PEF SP NPMI FCNL PEF DEPT SP FC DEPT SP NPHI rCNb PEF DEPT SP NPH! FCNL PEF DEPT SP NPHI rCNL PEr N:PHI FCNL DEPT NPHI FCN[, PEF DEPT SP 30.9082 712 0000 2:9687 oo}oooo 26 6250 31 0547 654 5000 2 5996 8200.0000 -42.3438 29.7363 · 3770 8100 0000 -43 0313 26 2695 1056 0000 2 0273 8000 0000 26 648 1~ 14 7900 0000 -38 5313 27 9297 914 O00O I 9619 7800 0000 -36 5000 3~. 9102 66 0000 2 0410 7700 0000 -44 5938 32 4219 730 0000 2 4570 7600 0000 -40 0625 29 8828 694 00~ I 88 ~ DRHO CALl G~ SFLU DRHO CALI SFL[! GR DRHO SFLU G~ DRHO CALl GR SFLU GR DRHO CA[,I SFLU GR DRHO CALl GR SFLU DRHO CALI GR SFLU GR DRHO CALI 8FLU GR DRH[] 7~00,0000 5FLU 69,2500 ~R 0,0415 13.7344 48.8750 4.4492 84.1250 0.0117 18.6719 72.8750 4 3125 2i8437 ~0 0O34 14,5703 53.3750 5,8477 49,9062 0,0181 14.0938 49.7500 41.,06 5 4 4961 56 2500 0 0376 t3 6406 51 4063 13 8047 51 8750 4 ,7188 ,0073 i3,6641 42.7500 5 328i 56 2187 -0 0264 15 ~000 60 562 4~.2910 .0313 RHOB ~RAT GR DT NRAT GR ILO DT RHOB NRAT IbD DT RHOB NRAT GR DT RHOB NRAT GR I bO DT RHOB NR~.T GR DT RHOB NRAT [)T RHOB NRAT DT RHOB NRAT 2.4961 3.0625 35,2187 5.2969 81.9375 2.4355 3.2012 53.8437 3.2637 85.4375 2.4375 3.0030 38.5000 3.4219 91 7500 2,7598 48,3125 2.2266 .%02.5000 2,2090 2.7617 44.2813 2.1426 94,1875 2,~.578 2. 574 29.0.%56 . 750 2,2:266 3.1973 42,3125 2,2402 95,2500 2207 10~ 7402 3750 2 2715 3 0391 39 5625 0~,2803 ~ .7500 NCNL RNRA Ib~ GR NCNL RNRA GR NCNL RNRA ILM GR NCNb RNRA IbM GR. NCNb RNRA IbM GR NCNb RNRA GR NCNb RNRA IbM NCNb RNRA GR NCNL RNRA I .L M GR 2272 0000 5.3398 84.1250 2098.0000 3,2051 3.8828 52,8437 3660,0000 3,0723 4,1484 49,9062 2880,0000 2,7266 2:6563 3 8750 2792,0000 .3,1289 2,5977 56,2500 2766,0000 3,0254 4~,. 5684 2813 .2 o :oooo 3730 2 797 , 980 , ~)187 .3~ O0 65 1,~645 42, 313 5VP 01,0,~02 VERIFICATION I, ISTtNG PAGf: 10 ~PNI ~CNL )EPT ~P ~PHI rCNb ~EPT SP ~IPHI PEF DEPT SP DEPT NPH! FCNL DEPT SP NPH! FCNL OEPT SP rCNb PEF PHI FCNb PEF OEP? SP NPH.! FC N L :PEr DEPT SP 32,3730 833.5000 1,7266 7400.0000 10.7500 39.3066 473.5000 2.5449 7300.0000 -16 6406 535,0000 2,3223 7200 0000 -57 3750 31 2988 725 0000 ! 9395 7100 0000 -16 2344 0000 ~ 40~3 700~,0000 '3 ,3125 3~,0625 ,5000 483,1738 6900,0000 -27.2500 65,5762 251,8750 6~001'0000 .34,4063 37,2070 598,0000 2,0840 .7oo:,oooo -'42,8750 35,3027 '0000 75~,4746 6~00,.~000 88, 500 DRHO CA[,I GR SFLU DRHO DRHO CALl ~R SFLU GR DRNO CALl GR SFLU DRHO CALl GR SFI, U GR DRMO CALI GR C A t., I GR SFbU GR DR}{O CAI.,! ~R SFI, U 8rLU °0. 0356 EHOB 2.1348 NCNb 13:1719 NEAT 3.3426 33; 4063 GR 32.9375 3.1699 ILO 3.7793 q9 6250 DT 105.4375 GR ~020015 RHOB 2.330! NCNb 16,4531 NRAT 3.5996 RNRA 91.0000 GR 48.2187 2.2187 ILD 2,5059 Z3.3125 DT ~0.6875 GR 0.0093 RHOB 2,2793 NCNb 7.2813 NEAT 3.4336 RN~A 0.3125 GR 37.5625 3.2285 ILD 2.1152 IbM 54,6250 DT ~1.8750 GR -0.0396 RHOB 2 1875 NCNb 16,0625 NR~T 3:~4~4 RNRA 49.3125 GR 37'4688 2 76~7 lbD 3 1465 IbM o i, oo o i ooo .o oo, 7 O0 DT 1.1X,5625 GR -0',0068 RHOB 2,2695 NCNb 16,1250 NRAT 3,5762 RNRA 69,6875 GR 35.,0313 5,I680 56,1562 DT 146,%250 GR -0'0869 RHOB 1'4766 NCN~ 14,3984 NR~.T 5,0039 RNRA 39,1875GR 44~3~25 63,4063 DT. ~.13.~8750 GR -01.,O205 RHOB NCNb I5,5625 NEAT 3,4590 RN'RA ~5,:8750 34'8750 77,%250 .... 8.1875 RHOB 2,,37~0 NCNb 15'0234 NRAT 3,3379 RNRA .3~2 52,87'5 DT GR 2820 0000 3:3828 3.5254 99,6250 1925,0000 4.0625 2,5234 73,3125 1885.0000 3,5215 2 3535 54:6250 2434,0000 3.3555 95 SO0 2118. 0000 3 6895 5801 4,5898 56~156~ t320,00o0 5,2303 :2 ' 5566 63,4063 2228,'0000 3,7246 :2,6563 77,125'0 2768'0000 3,6563 2,3027 52,8750 jYP OlO,lt02 VERIFI¢tTION !,ISTING PIGE )EPT ~P ~PHI ,rCNL ~EPT NPHI PEF DEPT SP PEF OEPT SP NPHI FCNL PEF DEPT SP NPH! FCN L PEF DEPT SP NPHI FC~L PEF CNL OEPT NPH! FCND PEF DEPT 26.5625 DRHO 864 5ooo c t,z 212s5.,) cr 6~00.0000 SFLU 44.2500 GR 38 4766 DRHO 606:5000 CALl 2.2871 Or 6400,0000 8FI.,U -44.7813 GR 37.5488 DRHO 559.5000 CALI 2.5781 GR 62.00, 0000 SFLU 53,8125 GR 36,8652 DRHO 5000 CAL! 6100 0000 -78 3750 36 4746 664 5000 1 7295 SFLU GR DRHO CALl 34 745 2 0000 7188 4727 000 547 SFLU OR DRHO CALl 5900 -8 40 496 2 0000 2 422 1855 $ F L GR CAI., 5800 ~00 -7 44 42 2852 472 2500 2 7695 SFLU GR DRHO CALI 5!00,0000 SFLU 22.7969 GR -0 OO]4 13'.1016 4,i.6875 4.2578 90 1250 '0:0186 15.7188 72,4375 3 5078 84:5000 6 7813 84 5000 2;9336 6563 7969 8750 7,2031 58 4375 -0i0371 184 6563 4 . 6563 3 OO78 33 50OO -0 0352 1.3 1719 34 8750 4 2500 60 8437 0 0029 84 5 2.8828 75.6250 7~ 7012 6250 -0 0083 14 9687 76 .7500 7383 :0000 RHOB DT NRAT GR DT RHOB NRAT DT RHOB GR XLD DT RHOB NRAT GR ILD DT NRAT GR DT RHOB NRAT XLD DT RHOB NR~T Gr ILD DT RHOB NRAT GR ILO DT 2.2754 2.7520 31.6563 4.5117 113,5000 2,2051 3.5332 50.0938 4.9180 113.1250 2.2930 3.5098 42,4688 1.4287 118.0625 2 1367 3~2676 21,1250 4.0039 121,4375 2,1289 3.4141 37,2500 12 ,7500 ,0820 .3555 25.0938 2,7246 112.8125 1 7 3, 34.1562 3-3770 ,,,,]:oooo 3047 3.60!6 43,0625 4 4570 121 0000 84 .4,6 5000 3,82'2] 110.8750 NCNb IbM GR NCNb RNRA IbM GR NCNI~ RNRA IbM GR NCNI, RNRA GR NCNb RNRA GR NCNb RNRA .NC'Nb RNRA GR NCNL RNRA NCNL RNRA IbM 2610.0000 3,0176 4. 3594 g0 1250 2254:0000 3,7148 4.3867 84.5000 2056.0000 3,6738 1,5264 37,6563 2426,0000 3,5371 4,5664 58,4375 209~,0000 ,6445 ,3633 3 .5000 2391,0000 ..6016 60. 3'7 2451,0000 ,29i0 3,3418 79.3750 1857,0000 3,7402 4,2266 78,6250 1953,0000 4.1328 73, O0 bYP OlO.H02 VER1FICA?ION LIS?lNG PAGE 12 NPHI 39 2324 DRHO FCNL 608:5000 CALl PEF 2.5957 GR DEPT 5~00i0000 SFLU SP 24 3125 GR NPHI 33 0078 DRHO ~CNL 592.5000 CALl PEF 2.9453 GR DEPT 5500.0000 SFLU SP -30,67i9 GR NPH! 38.8672 DRHO FCNL 617 5000 CALl PEF 2:4902 GR DEPT 5400,0000 SF£,U SP '77.6875 GR NP~' 36,1816 DRHO FC. ~ 640.5000 CAI,! PEF 1,8828 GR DEPT 5300'.0000 SFLU SP -21,1406 OR NPHI 37.1582 DRH0 FCNL 52~,0000 CALl P£F '5859 OR OEPT 5200 0000 SFLU SP -27 6094 HR NPHI 40 3 320 DRHO rCNL 560 5000 CRb! PKF 2 6387 GR OEPT 5~00.~000 Sr[,U 8P 62, 500 HR , NPH! 37.~070 OReO p ~ 5000'0000 $FLU ' '41,7813 H! 37..8906 DRH,(] FCNL 559,0000 CALl PEF 2,6426 GR DEPT 4~00,0000 SFLU P 70,3750 GR PHI 40'9668 DRH0 FCNb 599.0000 CALI P:EF 2,0605 GR DEPT 4~00,0000 SFLU 8P 69.4375 GR ~0.0107 4.1406 69.6250 3,6621 78,1.250 ~ 6563 81.1250 3.1484 65.9375 -0,0283 13.9219. 66.2500 3 5137 48 7188 -0 0342 12 5234 39 1562 3,8496 89.9375 0.,0020 17.9687 88,8125 4,7070 74,0000 74.4375 4,2500 49,6250 -0'0 7 5.,4063 41,2930 60.5313 .0,0088 13,3281 68.1250 3,7344 52,2813 -0,0112 12,9766 46'1250 2,9746 i)9.1.875 RHOB NRAT GR DT RHOB NRAT GR ILD DT RHOB NRAT DT RHOB DT RHOB NRAT IbP DT RHOB NRAT GR DT RMOB NRAT GR ILD DT RHOB NRAT GR DT RHOB NRAT lbD DT 2 3 45 3 108 2 3 49 !1 3 J2 2 .3223 .4785 .3125 .1602 .8125 .3926 .3008 .9375 3 5332 3:8750 2.2637 3.5078 6.0313 1.4561 1.1250 2,0938 3,3223 7.5469 !14,2227 1.3125 2,3418 3.~195 57. 813 4 1.15 2 3 4 11 3 1523 0625 3047 5870 2 2500 2,2598 9.8125 2,164,1 3,3906 3,4063 3,3770 J16.1875 3 . 95 42.0625 1 127 2 3 34 1 126 6309 0625 ~27o 996 6250 .6729 .8750 NCNL RNRA NCNb RNRA IbM OR NCNb RMRA I[,M NCNb R NRA GR NCNb RNRA GR NCNb RNRA IbM GR NCNb RNRA IbM NCNL RNRA GR NCNL RNRA 2114 0000 3:4727 3,3809 78.1250 2138.0000 3.6074 3 9043 65:9375 2186,0000 3.5391 1,6787 48,7188 2234.0000 3,4863 3 9941 89;;9375 1918 0000 3 6309 4.3281 74,0000 203~,0000 ' , 6270 2 30 , 0 3,7031 60,531,3 211~,0000 .7871 215 , 000 , 679 1,9053 39,1875 6VP 010.H02 VERIFICATION {,ISTING PAGE 13 ~PWI 37.4512 DRHO FCNL 614,0000 CALI PEF 2.0859 GR DEPT 4700.0000 SFLU SP -31.7344 GR NPHI 32.8613 DRHO FCNL 592,0000 CALl PEF 2.7285 GR 4600 0000 -60 2187 37 7441 606 0000 2 1836 DEPT 4500 0000 SFLU PEF 2 9922 GR SFLU GR DRHO CALI GR OEPT SP NpHI FCNL PEF DEPT $P NPHI FCNL PEF DEPT NPH! FCNL PEF DEPT ?CNb NPHI FCNL PEF NPHI FCNL PEF DEPT SP 4400.0000 SFLU -16,6250 GR 41.4551 DRHO 47~,2500 CALl .3066 G~ 4300.0000 ~FI,,U ,,160~ DR~O 62,5000 CALl .173~ ~R 35,1562 DRHO 5OO0 CALl 4~0~ 0000 - 3594 ~2 6270 512 5000 ~ 2539 4000..~000 SFLU -68, 250 GR 40.0391 DRHO -50,7188 GR SF:LO GR ORHO CAt,][ GR -0.01~6 13.0547 42.6250 4 3477 69 0000 -0 0151 15 8125 73 1875 3.8633 7,0938 0,0327 14,5547 52,~,.875 3.9375 ~5,5625 '0,0137 15,8594 85.9375 3,0215 77.7500 -0,0166 15,g844 79,8750 70 75O -0 . 25 'i 1367 7 bO00 0000 7g. 3750 3 3379 0~.4~ 13 5391 67 7500 -0 0669 42 6875 2,8379 65.6875 RHOB NRAT GR I bO DT RHOB NRAT GR DT RHOB NRAT GR ILD DT RHOB NRAT DT RHOB NRAT DT RHOB NRAT GR ILD DT RHOB NRAT ~R RHOB GR DT RHOB NRAT GR I L,D DT 2.0859 3 4063 23:4531 4.0430 118.4375 2.3203 3,2441 43.1875 2.3320 126,2500 2.1523 3.4629 35,2187 4.2266 131.8750 7246 57.5000 2.9785 135.0000 .1777 ],7051 44,31~5 2.5547 138,5000 2,1328 3,5801 46.3750 3 0801 125 3125 2 ]148 :3 477 48 6875 2.6387 127,8.125 23,~719 , 051 51,7500 I ~045 140: 50O 2,0176 3.'5352 28.3594 1,8613 131.6250 NCNb RNRA GR NCNb RNRA IbM GR NCNb IbM GR NCNb RNRA IbM GR NCNb RNRA GR NCNb RNRA tlr NCNb RNRA GR NCNb GR NCNL RNRA GR 2188 0000 3:5625 4.0156 69 0000 2104:0000 3.5527 2.5938 57.0938 2370,0000 3,9102 5:1094 8 5625 , 4 :oooo 0469 2,9785 77,7500 201~,.0000 ,2656 2,5039 214 . 0000 8105 71'0000 177 ,3516 2 7988: 75 6875 196~ 0000 8262 ,2637 4~,3438 221,42,0000 ,0703 3¸2 bVP 010,H02 VERIFICATION I.!]STING PAGE 1.4 ~PHI 40,6738 DRHO FCNb 535.0000 CALI PEF 2.1074 GR DEPT 3800 0000 SFLU SP -60;1562 GR NPH! 44,t895 FCNL 574. BO00 CALI ~EF 2.0449 GR DEPT 3700.0000 SFLU SP -]0.7188 OR NPHI 27.5879 DRHO FCNL 795.0000 CaLl ~EF 2.5625 GR 3600 0000 -~3 O234 40 ~855 416 0000 2 6113 DEPT 3500. 0000 SFLU SP '31,5625 NPHI 40,2344 DRHO tONI, 527..0000 CAbI PEF 2.0879 GR OEPT 3~00,0000 8.P 71,1875 GR NPHI ~5293 rCNL 5 0000 CA[.I PEF 9434 , DEPT 3300. 0000 SFt. U 'P 19,~500 ~R NPHI ' 1, 477 FCNb T20, 000 CALl PEF 2,0352 GR (~T 3~00.0000 8FLU 29,2344 NPHI 46,7285 DRHO FCNL 385,7500 CALI per 3.09~8 - u DEPT 3100. 0000 S~ L ~p ~38,6563 GR NPMI 4~.6270 DRMO FC.NL 480.0000 CALl PEF 3.0645 DEPT 3000..0000 SFbU SP '46,8125 GR DEPT SP SFLU DRHO CALl GR .0.0420 12.7969 57.1875 2.9687 45.1562 .1875 .9062 4.4336 55.3750 0.0225 17.0469 56.7500 2 1211 82.9375 -0,0015 17.0938 79.8750 2 3906 64 13 4297 68 6250 :~ 2598 3125 5i 0566 ~ 7031 44 4688 6914 2187 9375 ~781 O25O 4 84 9375 I 7852 40 6250 -0 ~566 13 594 38 9375 5~.0o2o .6250 NRAT GR ILD DT RHOB NRAT ILD DT RHOB NRAT DT RHOB NRAT DT RHOB NRAT ILD DT NRAT ~R ILD DT RHOB NRAT DT RHOB NRAT GR DT RHOB NRAT I LD DT 2.1328 3.5~01 44.2813 1.7246 138.2500 0918 38,1562 5.2969 ]14.3125 2.4375 2.9258 36.7813 2.6855 140.3750 2.2148 3,6641 39.3750 2 0469 !~9:6250 2,1484 3,57~3 4{.,4375 0 8696 1 4~ 6250 27 9062 2,1934 131,0000 ,.2559 3,1445 40.9062 887 25O ~187 58.~187 3125 I5 2,~ 2 8906 1,2480 137.5000 NCNL RNRA Ib~ GR NCNb RNRA GR NCNb RNRA IbM GR NCNb RNRA IbM NCNb RNRA IbN GR NCNb RNRA ILM GR NCNb RNRA IbM GR NCNb RNRA ! bM GR NCNb RNRA 2023 0000 3:7813 1,8994 45 1562 2086:0000 3,6309 4.6875 55.3750 2392.0000 3.0078 2 4355 82.9375 1648,0000 3.9609 2.0664 64.9375 195~.,0000 .7148 0 99'76 50:3125 0 2,2520 62,2187 2491,0000 .4648 2,~187 167 , 000 , 438 4 , 50 19844,0000 ,1328 1,3545 52,6250 ~¥P 010,H02 VERIFICATION LISTING PAGE 15 CPHI 41,6504 DRHO -0 ~CNL 558.5000 CALI 14 PEF 2.2285 GR 43 )EPT 2900.0000 SFLU 2 ~P -56.7500 OR 39 ~PMI 41,6016 DRHO '0 ~CNL 479.7500 CALI 13 ?£F 2.4746 GR 41 3EPT 2800 0000 SFLU 2 5P -91:0625 GR 48 ~PHI 59,2773 DRHO -0 ?CNI., 239,7500 CALI 12 P£F 64,6875 GE 31 DEPT 2700,0000 SFLU 2 SP -148.2500 GR 48 NP~ -999,~500 DRHO -999 FCN~ -999,2500 CAb! -999 PEF -999.'2500 GR -999 D£PT SP NPHI FCNb PEF D£PT NPH! FCNL D£PT SP NPH! FCN'L P£ F NP H I rCNb DEPT SP NPH! FCNL PEF DEPT SP 2600 0000 · ,180 6250 -999 2500 -999 2500 ,,999 2500 :0493 7656 .2500 ;2793 4688 .0635 ,6719 ,7853 3652 1875 9751. 6172 4531 0684 0313 2500 2500 2500 SFLU 1,9795 R 48,8750 ~RHO '999.~500 CALT. '999, 500 GR '999,~500 2500,. ~000 SFLU -185, 750 ~R "999.. O0 CAbI "999'2500 GR 2 57 "'999 =999 '999 '9999 - 99 -999 '999 999 -999 -999 2 25 ~400,~000 SFLU 184, 250 ~r -999,2500 DRHO -999,2500 CAbI "999,2500 GR ~300...0000 SFLU 189,0000 GR -999,2500 DRHO -999,2500 CA£,! ~999,2500 GE 2200.0000 SF[,U -204,8750 GE -999,2500 DRHO .-999,~500 CALl 999,2500 GR ~100.0000 SF[,U 207. 2500 GR 496 313 2500 2500 2500 4863 8437 O0 2500 941 875 2.50.0 2'500 2500 5820 7500 2500 2500 2500 RHOB NRAT GR DT RHOB NR~T GR DT RHOB NRAT GR DT RHOB NRAT DT RHOB NRAT GR ILO DT RHOB NRAT GR ILD DT RHOB NRAT ILD DT RHOB NRAT GR IbD DT RHOB NRAT GR DT 2,1113 NCNL 3,6S36 RNRA 32.8437 1.0850 IbM 136,8750 GR 2.0762 NCNb 3,6543 RNRA 26.4688 1,9824 Ib~ 142.5000 GR 1,8936 NCNb 4,6055 RNRA 13,9375 t,9570 IbM 138,6250 GR '999.2500 NCNb '999 2500 RNRA -999:2500 2 0195 .!45 6250 999 0 O0 -999 2500 GR NCNb RNRA 2,941.4 IbM ~34,3750 GR -g ,2500 RNRA -999'2500 2.2520 IbM 14:3.5000 GR -99~.~9 ,2,500 NCNb: ,2500 ~NRA -999.25OO .999,2500 NCNb ,.999,2500 RNRA 999.2500 .15[ (~145000 .999 ~,500 999 2'500 -999 2500 4,83ol. 16 .3750 GR NCNb RNRA GR 0000 1.2129 39,4688 1935.0000 4,0313 2,1211 48,1875 1270,0000 5.2969 2,0664 48.0313 -999,2500 -999. 2500 2,0938 48,8750 ,"999,2500 -999.2500 -9~ ,2500 -999,2500 -999, 5 0 -999, 500 1.8115 47,1875 -999,~500 -999.2500 ~,8232 3 ,7500 -999,2500 '999,~500 O4 1'~59~ 25, VERIFICATION LISTING PAGE 16 ~CNL 3EPT ~P qPHI ~CNb ~P ~PNI }EPT SP PEF DEPT NPHI ?CNL DEPT SP NPHI rCNb P£F OEPT SIP NPH! FCNb NPH! FCNb PEF D£PT SP FCNL PEF D£PT -999.2500 -999.2500 -999.2500 2000.0000 =198.5000 -999.2500 -999.2500 '999,2500 1900 0000 -196 3750 =999 2500 -999 2500 -999 2500 1800 0000 -189 7500 -999 2500 -999 2500 -999 2500 1700,0000 '222,2500 -999,2500 -999,2500 -999,2500 ~600.0000 .217,0000 ~999,.2500 999'~500 -999,2500 1500'0000 -214.7500 -999,2500 -999,2500 ."999,2500 1400"0000 216..8750 -99~,:2500 -999,~500 -999,2500 ! oo' 999, O0 -999..~00 -999,~500 ! oo,oooo 234,0000 DR~O GR SFLU DRHO CALl GR SFLU GR DRHO CAt, I SFLU GR DRHO CALI GR 8FLU GR DRHO CALI SFLU DRHO GR FLU R DRNO CA.L! gR DRHO CAb! GR SFbU GE DRHO CAbI GR -999.2500 -999 2500 -999:2500 4 7891 28 7188 -999 2500 -999 2500 -999 2500 8 2891 36,0625 '999,2500 '999.2500 '999.2500 29 5000 29~2500 '999,.2500 '999.2500 -999,2500 71.7500 . 25,6563 .999.~500 .999.2500 .999.2500 44 8 -999. 0 "999,2500 44,4688 . 49~2500 999,2500 '999,.2500 "999'2500 536.0000 31,9531. "999,2500 ~999'2500 '999'2500 348,2500 . 26,3906 :999,2500 ~999,2500 TM RHOB NRAT ILD DT RHOB NRAT GR DT RHOB NRAT GR ILD DT RHOB NRAT DT RHOB NRAT GR ~0~ NRAT GR DT RHOB NRAT GR DT RHOB NRAT RHOB NRAT GR, -999.2500 NCNb -999,2500 RNRA -999.2500 3.8906 IbM 180.3750 GR -999.2500 NCNb -999.2500 RNRA -999,2500 6.7305 147.5000 GR -999.2500 NCNb -999,2500 RNRA -999.2500 28.4844 IbM 90.7500 GR -999.2500 NCNb · .999.2500 RNRA -999.2500 142,6250 IbM 75,8750 GR -999.2500 NCNb -999,2500 RNRA -999,2500 47,8750 IbM 107,6250 GR ~ ~IO0 NCNb :99 '2 O0 R RA 99 , N "999,2,500 43,5625 ! b M .150'3750 G.R .999,2500 NCNb 999,21500 RNRA -999" 2500 795.0000 IbM ,,104'0000 GR 999 2500 NCNb -999,2500 RNEA -999 '2500 85'125 GR -999,2500 NCNb -999,2500 RN~A -999,2500 ooo: ooo 76 500 GR '999,2500 -999,2500 4,1094 28,7188 '999,2500 '999,2500 7,0742 36,0625 -999,2500 -999,2500 5,4063 ]9,2500 '999,2500 -999,2500 126,5625 25,6563 -999,~500 -999, 500 ,999, 999, .4500 500 -999,, O0 '999. lbO0 7,9687 ~1,953! '999'2500 -999,2500 39,3438 26,3906 -99~:,2500 -99 ,2500 168,.7500 32,4063 ]VP OIO,H02 VERIFICATION LISTING PAGE 17 ~PH! FCNL DEPT SP NPH! FCNL PEF FCNL PEF 8P DEPT SP NPHI FCNL PEF DEPT SP NPH! FCNL DEPT NP H ! FCNL DEPT SP NPHX DE'PT -999.2500 DRHO -999.2500 CALl -999.2500 GR 1100.0000 SFLU -245 500O GR -999~2500 DRHO -999.2500 CALl -999.2500 GR 1000,0000 SFLU -247.3750 GR -99~.2500 DRHO -999,2500 CALI -999,2500 OR 900 0000 SFLU -239 7500 OR ,999 2500 DRHO -999 2500 CALI -999 2500 GR 800 0000 SFLU -231!8750 GR -999 2500 DRHO :999,2500 CAI.! 999.2500 GE 700 0000 SFLU '249 1.250 GE '999 2500 DRHO -999 2500 CAbI -999 2500 GR 600,0000 SFLU -293,0000 GE -999,2500 DRHO -999,2500 ~ALI -999,2500 R .500,0000 $:FLU 25.4,5000 ~R -999,2500 DRHO .9~9,,2500 CALl -999.2500 ~R .400,0000 8FLU 315~0000 GR -999,2500 DRHO :999;2500 CAL! 999,2500 ~R .300 0000 SFLU 308 5000 G~ -999.2500 RHOB -999.2500 N~AT -999.2500 GR 48.4375 ILD 49.8750 DT '999.2500 RHOB -999,2500 NRAT -999.2500 GE 121 5000 IbD 41i531] DT -999 2500' RHOB -999.2500 NRAT -999.2500 GR 160.6250 ILD 37.4688 DT -999.2500 RHOB -999 2500 NRAT -999:2500 GR 44 8i25 ILD 54i7813 DT '999 2500 RHOB :999.2500 NRAT 999,2500 ~R 282 50OO IbD 36 -999 -999 -999 185 38 -999 -999 -999 75 DT O0 RHOB 2500 NRAT 2:500 GR ,2500 RHOB 2500 NRAT 2500 OR 42 ~625 23 281 DT -999 2500 RHOB -999 2500 NRAT -999 2500 GE, 422 -99? -999 .,999 5000 IbD 7031 DT 2500 RHOB 2500 ~RAT 2500 GR 454,5000 XbD 24,0469 DT -999.2500 NCNb :9999 2500 RNRA 99:2500 58.5938 ~09,~500 -999 2500 NCNb -999:2500 -999.2500 143.8750 97.2500 GR -999,2500 NCN[. -999.2500 RNRA -999.2500 215.1250 IbM 93 2500 GE -999:2500 NCNb -999,2500 RNR.A -999.2500 55,2187 ]LM 110.5000 GE -999,2500 NCNb '999,2500 RNRA -999,2500 i76 1250 IbM 94 2500 GR -999 ~500 NCNL -999 500 RNRA. -999 2500 8 . GR '999,2500 NCNb -999,2500 RNRA -999.2500 49 6875 ~M 69 0000 -999 2500 NCNb -999 2500 RNRA -999 2500 6,00'00 IbM 4~7.8750 GR '999,2500 NCNb '999.2500 RNRA '999.~500 564,5000 X.LM 68,7500 GR -gg9 2500 -ggg:2500 35,7188 49.8750 -999.2500 -999,2500 54,6875 41,5313 -999,2500 .999,2500 65,4375 37,4688 -999,2500 -999.2500 25,6875 54,781'3 -999.2500 -999.2500 65,~375 36, 375 -999,~500 ~999. 500 42.9687 38,0938 ~ggg,2500 ~ggg.2500 ],000'0 ,8281 -9 9.]50:0 -999. 500 t28,~000 26, 031. -999,~500 · '999, 500 . 469 ~VP O!O,H02 VERIFICATION LISTING P~GE 18 4PHI ,,999,2500 DRHO -999, rCNt, 999,2500 C~LI -999, .~ZF ~999, ~500 GR -999, )EPT 200,0000 SFLU 191, ~P 343 5000 GR . 22, qPHI ] ' g99, · 999,2500 DRHO PCNL -999 2500 CAI, I -999, }EF -999:2500 GR -999, DEPT 100,0000 SFI, U 0 ~P 169.6250 GR 16 ~PHI ~ ~ 999 999,2500 DRHO ?CNL -999,2500 CA[.I -999 PEF -999,2500 GR -999 DEPT 86 SP -164 N~ -999 F .~ -999 PEF -999 0000 SFLU O, 1250 OR 15, 500 DRHO -999, ~500 CALl -999, 2500 GR -999, ** FILE TRAILER FILE NAME :EDIT SERVICE NAME : VERSION # : DATE I MAXI~EIM,E,,ENGTH : FIbE TYPE : ** ,001 1024 *****~***~ EOF 2500 RHOB 2500 NRAT 2500 GR 6250 ILD 1406 DT 2500 RHOB 2500 NRAT 2500 G~ 7168 I!,D ]906 DT 2500 R~OB 2500 NmAT ~500 GR 6309 IL~ 4453 DT 2500 RMOB 2500 NRAT 2500 GR -999 -999 -999 2000 69 -999 -999 -999 2OOO 62 -999 -999 -999 94 56 -999 -999 -999 .2500 ,2500 .2500 .0000 .1250 ,2500 ,2500 ,2500 ,0000 .9375 ,2500 ,2500 ,2500 ,6875 ,5000 ,2500 2500 ~2500 'NCNb RNRA NCNb RNRA IbM GR NCNb RNRA GR NCNb RNRA ~999 2500 999:2500 65,4375 . 22,1406 999,2500 -999,2500 7,406) 16,3906 -999,2500 -999,2500 i00,0000 1~,4453 999.,2500 999,2500 ** TAPE TRAILER ** SERVICE NA~E :EDIT DATE 8~ 5 O, ooo ~ NAgE 18536 COMMENTS ;TAPE COMMENTS ** RE,.,,L TR SERVICE NAME ~EDIT DATE ORIGIN CONTYNIJA~ION # :01 NEXT .REEL COMMENTS · *~******** EOF ********** EOF
