The URL can be used to link to this page

Home My WebLink About181-1037. 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 13-05 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 181-103 50-029-20626-00-00 ADL 0028315 11055 Conductor Surface Intermediate Production Liner 9530 80 2628 9818 1503 7937 20" 13-3/8" 9-5/8" 7" 7222 34 - 114 33 - 2661 31 - 9850 9547 - 11050 2470 34 - 114 33 - 2661 31 - 9849 8439 - 9527 10977 520 2670 4760 7020 7937, 9230, 10010 1530 5380 6870 8160 10001 - 10310 5-1/2" 17# x 4-1/2" 12.6# N-80 29 - 95718788 - 9018 Structural 5-1/2" BOT 3-H Packer No SSSV Installed 9498, 8401 Date: Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY 8/1/2025 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 3:06 pm, Jun 12, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.06.12 13:25:08 - 08'00' Bo York (1248) 325-359 10-407 DSR-6/18/25A.Dewhurst 22JUL25 X JJL 6/16/25 AOGCC witness tag TOC and MIT AOGCC witness casing cuts before any top job commences. AOGCC witness marker cap install before backfilling. Photo evidence of cement tops post-cut X JLC 7/22/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.07.22 11:59:38 -08'00'07/22/25 RBDMS JSB 072225 P&A Sundry Well: 13-05 PTD: 181-103 API: 50-029-20626-00 Well Name:13-05 Permit to Drill Number:181-103 Well Type Suspended API Number:50-029-20626-00-00 Job Scope:P&A Reg.Approval Req’d?Yes Current Status:Not Operable, Offline Date Reg. Approval Rec’vd: Estimated Start Date:8/1/2025 Estimated Duration:15 days Regulatory Contact:Abbie Barker First Call Engineer:Oliver Sternicki Second Call Engineer:Jerry Lau Current Bottom Hole Pressure:3350 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2470 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:112 psi Min ID:2.34” POGLM @ 5053’ MD Max Angle:39 deg @ 7800’ MD Top of Sag:9993’ MD Well History: Prudhoe well 13-05 (PTD #181103) was drilled and completed as a producer in August 1981. TxIA communication was found in 1995 with a leak detect log and was later repaired in 1996 with a POGLM (patch over gas lift mandrel) over station #2. In late 1997, the well was no longer competitive and was secured with an IBP and the subsurface location was replaced with well 13-06 in 1998. 13-05 remained as a long-term shut-in well until it was suspended on 06/04/2004 with the 7” liner cement top tagged at 9710’ MD and successfully pressure tested to 2500 psi on 06/08/2004. In 2012, under sundry 312-245, work was executed to progress the well towards full abandonment. During the abandonment work multiple leaks were found in the 5.5” tubing at 5060’, 6475’ and 7035’ MD. The full abandonment to surface was deferred due to initial injectivity problems into the control and balance lines, but eventually slickline was able to pump into both lines on 8/31/2012, indicating thatthe problem was resolved. Work was completed where the tubing and IA were cemented to 7887’ SLMD on 10/2/2012 and a CMIT-TxIA passed to 2500 psi on 11/24/2012. The sundry was closed at that point with no further work was completed. Current Status: 13-05 is currently not operable and offline. Objectives: The intent of this program is to fully abandon the 13-05 as part of the 2025 PBU P&A program. P&A Sundry Well: 13-05 PTD: 181-103 API: 50-029-20626-00 P&A Sundry Well: 13-05 PTD: 181-103 API: 50-029-20626-00 Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. 1. EL a. Punch tubing w/ 10’ of punches positioning mid punch across collar closest to 7500’ MD. b. Tie into 5.5” Tubing Summary (8/15/1981) c. Use 0° phase, decentralized, oriented to low side, rated for 5.5”, 17#, L-80 tubing. 2. Fullbore: a. Circ out IA with 505 bbls 9.8 ppg brine, pumping down tubing, taking returns from IA. Volume based on circulation through tubing punch holes ~7500’ MD (IA= 330 bbls, T= 175 bbls). 150’ meth cap u-tubed if done during low ambient temps. 3. DHD a. Cement control and balance lines with microfine cement. 4. Coiled Tubing: Cement IA to surface, cement tubing to 3000’ MD. Note:tubing punch from ~7500-7510’ MD, tubing holes at 5060’, 6475’, 7035’ MD. POGLM at 5053- 5078’ MD, ID= 2.34”. a. RIH to tubing punch holes at ~7500-7510’ MD (1) Taking returns from tubing and IA, pump 20 bbls inhibited surfactant wash. (2) Taking returns from tubing and IA, pump 20 bbls FW spacer. (3) Lay in 302 bbls (IA= 197 bbls, T= 105 bbls) of cement taking returns from tubing and IA to bring cement to 3000’ MD. Once volume is pumped, shut-in coil backside and pump remaining 152 bbls (132+20 bbls excess) through tubing holes, up IA and to surface. (4) Displace with 5 bbls FW spacer followed by (coil volume) 9.8 brine and 9 bbls diesel pipe displacement while POOH for FP. Max circ pressure= 3000 psi. Hold ~937 PSI (based on 15.8 ppg cement) on coil backside when pulling out of hole after cementing. Once diesel is in place hold ~996 psi on tubing to keep cement in place. Cement Volumes: x 5.5” x 9.625” annulus from 0’-7500’ MD: 7500’ x 0.0438= 329 bbls x 5.5” tubing from 3000’-7500’ MD: 4500 ’ x 0.0232= 105 bbls P&A Sundry Well: 13-05 PTD: 181-103 API: 50-029-20626-00 Total cement: 434 bbls + 20 bbls excess Cement Type/weight:Class G permafrost cement 14-16 ppg or similar Bottom hole static temp:~145°F at base of cement (7500’ MD) 10°F surface in IA. Fluid Loss:20-200 cc/30 min Thickening Time:Minimum 8 hours P&A Sundry Well: 13-05 PTD: 181-103 API: 50-029-20626-00 Proposed Schematic- post IA cement to surface P&A Sundry Well: 13-05 PTD: 181-103 API: 50-029-20626-00 5. Fullbore WOC 5 days, MIT-T, CMIT-TxIA to 2500 psi max applied pressure, 2250 psi target pressure –AOGCC Witnessed 6. Slickline WOC 5 days, Drift and tag TOC –AOGCC Witnessed 7. Well Support: Nipple down tree, install dry hole tree for cementing if required. 8. Eline: Perforate 5.5” tubing and 9.625” casing at 2000’ MD. 3.125” MaxForce- FLOW or similar. Calculated TOC from rig OA downsqueeze= 2248’ MD. a. Perforate 5.5” tubing and 9.625” casing at 2000-2010’ MD to establish circulation point for cementing. b. Apply 500 psi to 5.5” prior to perforating, record before/after pressures. c. Note any pressure changes. 9. Fullbore : ***Arctic Pack in OA*** Circulate the following down the tubing and up the 9.625”x 13.375” annulus to prep for cement. a. 5 bbls MeOH b. 25 bbls hot diesel (min 120 degF) c. 80 bbls hot (160degF) fresh water + surfactant. d. 189 bbls (25 bbls over calculated volume) of 9.8 brine (80-100 degF) Ensure reasonably clean returns. (can skip freeze protecting step if immediately going to cementing) e. Max pressure 2500 psi. Contingent Coiled Tubing: ***If unable to circulate up OA, rig up coil for contingent thaw and flush of OA. 10. Fullbore Cement: Circulate the following down the tubing to cement the tubing and 9.625”x 13.375” annulus from surface to 2010' MD. a. 5 bbls MeOH b. 10 bbls fresh water c. 184 bbls (20 bbls over calculated volume) 14- 16 ppg Class G permafrost cement (or similar) cement or until uncontaminated cement is seen at surface. d. Max pressure while pumping 2500 psi. e. Top of cement will be at surface in the tubing and 9.625”x 13.375” annulus. Confirm cement at surface in OA. Cement Type/weight:Class G permafrost cement 14-16 ppg or similar Bottom Hole Temp:10°F Fluid Loss:20-200cc/30 min Thickening Time:Minimum 8 hours P&A Sundry Well: 13-05 PTD: 181-103 API: 50-029-20626-00 Cement Volumes: x 5.5” tubing from surface to 2010’ MD: 2010’ x 0.0232 bpf= 47 bbls x 9.625”x 13.375” annulus from surface to 2010’ MD: 2010’ x 0.0581 bpf= 117 bbls Total cement: 164 bbls +20 bbls excess Displacement: x No displacement P&A Sundry Well: 13-05 PTD: 181-103 API: 50-029-20626-00 Proposed Schematic- post surface cement plug P&A Sundry Well: 13-05 PTD: 181-103 API: 50-029-20626-00 11 DHD: a. Bleed all wellhead pressures to 0 psi. b. Monitor wellhead pressures 24 hours after pressures were bled to 0 psi. 12 Special Projects: a. Excavate and cut off all casings and wellhead 3’ below original tundra level. b.AOGCC witness of cut-off casings before any top job commences. c.AOGCC witness cement tops in all annuli. Top off with cement as needed. d. Bead weld ¼” thick steel marker cap on outermost casing string. Photo document all steps and AOGCC witness of installed cap. Marker cap to read as follows: Hilcorp North Slope, LLC PTD # 181-103 Well: PBU 13-05 API # 50-029-20626-00 e. Remove shoring box, backfill excavation. P&A Sundry Well: 13-05 PTD: 181-103 API: 50-029-20626-00 5.5” Tubing Summary Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: June 11, 2025Subject: Changes to Approved Sundry Procedure for Well 13-05Sundry #: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.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date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y Anne Prysunka at 8:36 am, Sep 14, 2022 'LJLWDOO\VLJQHGE\%R<RUN '1FQ %R<RUNRX 8VHUV 'DWH 0*56(3'65'/% ; $SSURYHGIRU\HDUVXVSHQVLRQ1H[WZHOOLQVSHFWLRQWREHSHUIRUPHGZLWKLQPRQWKVRIQH[WVXVSHQVLRQ UHQHZDO GWV -/& Jeremy Price Digitally signed by Jeremy Price Date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x 6XVSHQGHG:HOO6LWH,QVSHFWLRQIRUPGRFXPHQWLQJWKHSUHVVXUHVDQGVLWHFRQGLWLRQ x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´OLQHU FHPHQWWRSWDJJHGDW¶0'DQGVXFFHVVIXOO\SUHVVXUHWHVWHGWRSVLRQ,Q XQGHUVXQGU\ZRUNZDVH[HFXWHGWRSURJUHVVWKHZHOOWRZDUGVIXOO DEDQGRQPHQW7KLVZRUNZDVVWRSSHGDIWHUWKHWXELQJDQG,$ZHUHFHPHQWHGWR¶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his 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:Oliver Sternicki To:Rixse, Melvin G (OGC) Cc:PB Wells Integrity Subject:RE: [EXTERNAL] RE: LGI-08 (PTD# 186057), 13-05 (PTD# 181103). Suspended wells with slow IA repressurization. Attachments:image001.png image002.png image003.png image004.png image005.png image006.png Mel, The tests were not witnessed. On LGI-08 the renewal application is due 7/5/2022, the last inspection was on 6/28/2020. If I turn the renewal in a week early we are going to be just within the 24 month window, but due to what is going on with the well I have a new inspection scheduled in the next few weeks. On 13-05 the renewal application is due by 09/24/2022, the last inspection was on 7/6/2019. We are planning on getting another inspection on this well in the next few weeks. Any idea when the new SU regs are going to come out? Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, June 3, 2022 10:25 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: [EXTERNAL] RE: LGI-08 (PTD# 186057), 13-05 (PTD# 181103). Suspended wells with slow IA repressurization. Oliver, A couple of questions: 1. Did anyone from the state witness the MITs on Wednesday? 2. I believe these wells fall into the old regs, i.e., inspections every 5 years and a renewal of suspension before 10 years. So do we have well inspections within the last 24 months? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, June 2, 2022 10:28 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: LGI-08 (PTD# 186057), 13-05 (PTD# 181103). Suspended wells with slow IA repressurization. Mel, Passing CMIT-TxIA pressure tests were conducted on both LGI-08 and 13-05 yesterday: LGI-08: 13-05: Attached are the 10-426 forms for these tests due to the unique nature of them. Next step on this is to bleed the tubing and IA down to ~100psi and monitor. We are currently reviewing the future utility of these 2 wells for the potential suspension renewals. Regarding my question to you about the 20AAC25.110(k) requirement for a report within 5 working days of notification. I did some digging and found that there is historic precedent from MPL-35A back in 2015 for the email communication to the AOGCC sufficing as the required “report”. Let me know your thoughts on this. Being how these wells have been inactive for so long and all previous work to convert to suspended status was under sundry, any pertinent historic info would be in AOGCC’s Data Miner. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Oliver Sternicki Sent: Tuesday, May 31, 2022 1:55 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: LGI-08 (PTD# 186057), 13-05 (PTD# 181103). Suspended wells with slow IA repressurization. Mel, Suspended wells LGI-08 (PTD# 186057) and 13-05 (PTD# 181103) are coming up for renewal over the course of the next couple months. While reviewing these wells for the renewal application, I found that both wells show very slow IA repressurization since they were suspended back in 2012. Both wells have reservoir plugs in them, no surface lines or blinded surface lines, and IA fluid levels at surface. LGI-08 previously passed a CMIT-TxIA to 2500 psi on 9/5/2012. 13-05 passed a CMIT-TxIA to 2500 psi on 11/24/2012. Per 20AAC25.110(j) we are immediately notifying you that there is potential fluid migration occurring into the IA of these wells. Our plan forward is to CMIT-TxIA these wells to 2500 psi max applied pressure to verify the production casing and cement top integrity. I will relay the results to you when the tests are completed and we can discuss further steps if necessary. Let me know if you have any questions Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com LGI-08: 13-05: The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you arehereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly andpermanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. Noresponsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Oliver Sternicki To:Roby, David S (OGC) Cc:Rixse, Melvin G (OGC); Davies, Stephen F (OGC); Boyer, David L (OGC); Regg, James B (OGC) Subject:RE: [EXTERNAL] Suspension renewal request for PBU 13-05 (PTD 181.103) Date:Thursday, September 15, 2022 12:31:41 PM Attachments:RE EXTERNAL RE LGI-08 (PTD# 186057) 13-05 (PTD# 181103). Suspended wells with slow IA repressurization..msg Dave, There is a location to the south of 13-04, where a fault has likely trapped oil. This leaves a target for an injector or producer. Additionally, with change in operator, reduced costs to drill (relative to 2012) make this target more economically viable. 13-05 is in a location that should be able to access the described target. See the attached email regarding the pressure test earlier this year on the well. Let me know if you have any questions. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Wednesday, September 14, 2022 4:07 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: [EXTERNAL] Suspension renewal request for PBU 13-05 (PTD 181.103) Hi Oliver, Looking at this request I saw that in 2012 the plans were to permanently P&A the well and work was begun to do this. That work failed and BPXA said they were going to reevaluate how to proceed with the P&A. Hilcorp’s plan now is to keep the well as a potential sidetrack candidate. What has changed that now makes this a viable candidate for redrill instead of a well that should be P&A’d? Also, why did you pressure test the well ahead of the suspended well inspection earlier this year? Thanks, Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1811030 Type Inj N Tubing 780 2515 2475 2447 Type Test P Packer TVD 8401 BBL Pump 4.0 IA 760 2500 2453 2425 Interval O Test psi 2100 BBL Return 4.0 OA 480 697 697 698 Result F Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1811030 Type Inj N Tubing 2447 2518 2490 2475 Type Test P Packer TVD 8401 BBL Pump 0.1 IA 2425 2500 2469 2453 Interval O Test psi 2100 BBL Return 0.1 OA 698 698 698 710 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec hanicall Integrityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Non Witnessed Suspended well CMIT-TxIA to demonstrate casing / plug integrity Notes: Notes: Hilcorp Alaska LLC Prudhoe Bay / PBU / DS13 Ryan Holt 06/01/22 Notes: Non Witnessed Suspended well CMIT-TxIA to demonstrate casing / plug integrity Notes: Notes: Notes: 13-05 13-05 Form 10-426 (Revised 01/2017)2022-0601_MITP_PBU_13-05_2tests +LOFRUS1RUWK6ORSH//& 9 9 9 9 9 9 9 9 9 6XVSHQGHGRLOSURGXFHU 6XVSHQGHGRLOSURGXFHU 9 9 9 -5HJJ CMIT-TxIA t CMIT-TxIA casing / plug integrity casing / plug integrity Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 06/21/2022 InspectNo:susMFH220606124538 Well Pressures (psi): Date Inspected:6/5/2022 Inspector:Matt Herrera If Verified, How?LAT / LONG Suspension Date:9/1/2012 #312-245 Tubing:112 IA:109 OA:337 Operator:Hilcorp North Slope, LLC Operator Rep:Ryan Holt Date AOGCC Notified:6/4/2022 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT 13-05 Permit Number:1811030 Wellhead Condition Good, fairly clean, all valves and gauges operational and SSV in place in the closed position. Wing Valve closed and LO/TO Surrounding Surface Condition Good, no apparent stains or subsidence. Flowlines still connected Condition of Cellar Good, clean with no stains or debris Comments Well house on well out of inclement weather. Supervisor Comments Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, June 21, 2022 9 9 9 9 9 9 3KRWRV$WWDFKHG 2022-0605_Suspend_PBU_13-05_photos_mh Page 1 of 2 Suspended Well Inspection – PBU 13-05 PTD 1811030 AOGCC Inspection Rpt # susMFH220606124538 Photos by AOGCC Inspector M. Herrera 6/5/2022 2022-0605_Suspend_PBU_13-05_photos_mhPage 2 of 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUL 2 3 I . Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations hdtll wn .❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work 5. Permit to Dnll Number: 161-103 3. Address: P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service 11 1 6. API Number: 50-029-20626-00-00 7. Property Designation (Lease Number): ADL 028315 8. Well Name and Number: PBU 13-05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Suspended Subsequent to operation: Total Depth: measured 11055 feet Plugs measured 7937, 9230, 10010 feet 15. Well Class after work: true vertical 9530 feet Junk measured 10977 feet Copies of Logs and Surveys Run ❑ Effective Depth. measured 7937 feet Packer measured W98 feet true vertical 7222 feet Packer true vertical 8401 feet Contact Email. Travis.Montgomery0bp.com Casing: Length: Size: Authorized Signature: MD: TVD: Buret: Collapse: Structural Conductor 80 20" 34-114 34-114 1530 520 Surface 2628 13-3/8" 33-2661 33-2661 5380 2670 Intermediate 9818 9-5/8" 31 -9849 31-8672 6870/8150 4760 / 5080 Production Liner 1503 7" 9547 - 11050 8439-9527 8160 7020 Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 x 4-1/2"12.6411 N-80 29-9571 29-8457 Packers and SSSV (type, measured and 5-1/2' BOT 3-H Packer 9498 8401 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descnptions including volumes used and final pressure 3. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Suspended Subsequent to operation: 14. Attachments mt,, ed per20 rine 25 070.25.071, a 25 2831 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C, O. Exempt: WA Authorized Name: Lastufka, Joseph N Contact Name. Montgomery, Travis J Authorized Titie: IM ialist Contact Email. Travis.Montgomery0bp.com Authorized Signature: Data: ZJ'�� Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 Al /�t5-n¢.�+�s'+►�+9 RgDMSIMUL 2 4 2019 Submit Original Only Daily Report of Well Operations 13-05 ACTIVITYDATE SUMMARY T/I/O = 450/450/170. Temp = SI. Pre AOGCC SU well inspection. AL disconnected. Wellhouse, wellhead and cellar are clean and dry. Surface area around well is clean, dry and clear of debris. Well ID sign on wellhouse. 6/30/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 03:00 T/I/O = SSV/450/180. Temp = SI. AOGCC SU well inspection (Witnessed by Bob Noble). No AL. 7/6/2019 ISV, WV, SSV = C. MV = O. IA, OA = OTG. 11:45 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 13-05 Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1811030 API Number: 50-029-20626-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 9N+"4 Surface Location: Section: 13 Twsp: 10N Range: 14E Nearest active pad or road DS -09 Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: C`Pgn Pad or location surface: Location cleanup needed: Pits condition: Surrounding area condition: Water/fluids on pad: A/ n Discoloration, Sheens on pad, pits or water: A/0 Samples taken: None Access road condition: Photographs taken (# and Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: G�Xj^ Cellar description, condition, fluids: Rat Hole: Wellhouse or protective 6ar Well identification sign: Tubing Pressure (or casing Annulus pressures: Wellhead Photos taken (# a i� f't/ Operator Rep (name and signature): Josh Prowant AOGCC Inspector: 1`Other Observers: Inspection Date: tit" /tq AOGCC Notice Date: Time of arrival: Zr7h Time of Departure: Site access method: Access Road "Ol 11 114*= GW1Y GEN2 VVLLFEAD= GRAY ACTUATOR= AXE -SON KB. ELEV = 78' BF. H.EV = _? KOP= 3100' Max Angle = 51"Q 11055' Datum MD= 10122' Datum TVD= 880(Y SSI L-80 BTC, D = 12.347" 1-1 2661' ESTMATEDTOC N TBG (XX/XX/XX) 7937' ESTMATE TOC N b (XX/XX/XX) 7838' G, 47#, L-80 BTC XO TO SOO-09 BTC 6900' Minimum ID =4.562" @ 5057' 5-112" OTIS SSSV TSG PUNCH (07/30/12) 13-05 SAFETY NOTES: GRAPHITE PUMPED. LDON'T MITOA; PASSED NFT 04111195. POCLM LEAK id 5057' O 2156' 5-12' OTIS ROM SSSV NP, D = 4.562' GAS LFT AANDRAS ST MD TVD DEV I TYPE VLV LATCH PORT DATE 1 2922 2921 6 OTIS DOME RO-5 16 0927/96 2 5060 4833 32 OTIS *DOME BK 16 09!29/96 3 6594 6134 35 OTIS DOME RO-5 16 09/29/96 4 7733 7063 37 OTIS SO RO-5 20 09/27/96 5 8451 7609 43 OTB DAM 80.5 0 0927196 6 8530 7667 43 OTIS DAM RO-5 0 08A)5181 7 8951 7982 41 OTIS OMY RD -5 0 08/10/96 8 9029 8042 41 OTIS DMY RO-5 0 08!05/81 9 9323 8267 40 OTIS OM1' RO-5 0 08!05/81 11019401183271 40 1 OTIS I DW I RO-5 1 0 01105/81 STA'S #5 TFRU #9 BEFBPD CBMHJI'- # 9 9230' ceANT REfAN62(XXOO T��s -19-58•X7-12" BOT3-HPKR D=5.625' 5-12" TBGPC, 17#, L-80,.0232 bpf, D= 4.892" 9506' 7-12" muouT IX rENsK { D = 5.625' 7-1/2" X 4-112" XO, D = 3.958" TOPOF 7" LNR BTC, D = 8.681" H 9850' PERFORATION SUMMARY REF LOG: BHS ON 08/09/81 ANGLE AT TOP PERF: 41' Q 10001' Note: Refer to Production OB for historical pert data SIZE SPF NI RVAL OprdSgz DATE 3-3/8" 2 10001 - 10021 S? / C 03/18/91 3-3/8' 4 10128 - 10148 C 08107/95 3-318" 4 10158 -10178 C 06115190 3-3/8" 4 10191-10201 C 06/15/90 3-3/8' 4 10211- 10221 C 06/15190 3-3/8" 4 10228- 10238 C 06/15190 3.3/8' 4 10246 - 10266 C 06/15/90 3-118" 10274 - 10280 S 01/16/86 31/8' 10290-10310 S 01/16/86 am 1 9568• 1 j 9571' —j4-12"VVLEG,D=3.958" 9568' E -W TT LOGO 0820/81 9790' EST TOP OF CMT PLUG (06/0 I 10010' I 1 10977' 1 DATE REV BY CORAN305 DATE REV BY COMYBJTS 08116/81 OR GINAL COMPLETION 08/01/12 JCMJM) TBG PUNCH (07/30112) 0920/12 R~JMD SET BKR BP(09/18/12) 0926112 M&JM1D PULLED BKR 13P(09/25M2) 10/15/12 -?/PJC CMTRETANDYTOP(XX/XX/XX I BP RUSHED DOWN FROM 9485't 10131103) 1 17' DOUBLE SHORT MARKER JOINT I r r 711 WELL 1305 PERW N0: 9811030 AR No: 50-029-20626-00 SEC 13, T10R R14E, 13 8775 FEL 8 4330' FPL BP 6tplora0on (Alaska) TREE= GRAYGEN2 WELLHEAD= GRAY ACTUATOR= AXELSON KB. ELEV = _ 78' BF. ELEV= 45AV KOP= 3100' Max Angie = 51' 11055' Dalian MD= 10122' DabanTVD = 8800' SS SUSPENDED 13-3/8' CSG, 72#, L-80 BTC, D =12.347' 2661' I ESTIMATE TOC N A (XX/XX/XX) - 783$' G, 47#, L-80 BTC XO TO SOO-09 BTC$900' Minimum ID = 4.562" @ 5057' 5-112" OTIS SSSV TBG Pl1NCH (07/30/12) 9438' - 944$' r LO -Mr -217M T ST MD I ND I DEV I TYPE VLV I LATCH PORT DATE 1 2922 2921 6 OTIS DOME 80.5 16 09/27/96 2 5060 4833 32 OTIS *DONE BK 16 09/29/96 3 6594 6134 35 OTIS DONE 80.5 16 09/29/96 4 7733 7063 37 OTIS SO RO-5 20 09/27/96 5 8451 7609 43 OTIS DW RO-5 0 09/27/96 6 8530 7667 43 OTIS DAM RO-5 0 08/05/81 7 8951 7982 41 OTIS DAM RO-5 0 08/10/96 8 9029 8042 41 OTB D4Y RO-5 0 08/05/81 9 9323 8267 40 OTS DW RD -5 0 08/05/81 10 9401 8327 40 OTIS DNN RD -5 0 08105/81 I CBoSJr RETANEt(XX/XX/XX) I 9508' SIZE SPF 949$' -I9 -51W X 7-1/2' BOT 3-H PKR, D = 5.625' 9503' 7-1/2" MLLOUr IXTBJSDN, D = 5.625' 9508' 7-12' X 4-1/2" XO, D= 3.958" OF 7" LNR H 9547' 9-5/8' CSG, 47#, Soo -95 BTC, D = 8.681" 9850• FERFORATM SUMMARY REF LOG: BHCS ON 08/09/81 ANGLEATTOPPERF: 41' @ 10001' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz DOTE 3-31W 2 10001 -10021 S? / C 03/18/91 3-31W 4 10128 - 10148 C 08/07/95 3-3/8" 4 10158 - 10178 C 06/15/90 3-31W 4 10191-10201 C 06/15/90 3-3/8" 4 10211-10221 C 06/15/90 3-3/8" 4 10228 - 10238 C 06/15/90 3-3/8" 4 10246 - 10266 C 06/15/90 3-1/8" 10274 - 10280 S 01/16/86 3-11W 10290 - 10310 S 01/16/86 PBTD H 1101V 17- LNR, 29#, L-80..0371 bpf, D = 6.184' I EbiisEl I4-1/2' OTIS XN NP, D = 3.725' �Gllll7alal•� ••• • �. � I BP PUSHED DOWN FROM 9485'(10/31/03) 1 10977' H FSH - 2" DATE REV BY COMMENTS DATE REV BY COMMENTS 0&18191 ORIMNAL COMPLETION 0801/12 JCM/JMD TBG PUNCH 07rM12 09/20/12 R4W,YJMD SET BKRIBP 8/12 09126/12 MSS/JMD PULED BKR BP 2 10/15/12 ?/PJC CMTRETANERRDP 0723/19 JNJJMD ADDED BFE & SUSPENDED PRUDHOE BAY UNIT WELL IaZ5 PERMITNo: 1811030 API No: 50429-20626-00 10N R14E.13 8775FEL & 43 BP Ezpkxabon YUaska) Suspended Well Inspection Review Report InspectNo: susRCN190707170933 Date Inspected: 7/6/2019 Inspector: Bob Noble Type of Inspection: Subsequent ' Well Name: PRUDHOE BAY UNIT 13-05 Date AOGCC Notified: 7/5/2019 Permit Number: 1811030 Operator: BP Exploration (Alaska) Inc. Suspension Approval: Sundry # 304-025 Operator Rep: Josh Prowant Suspension Date: 6/4/2004 Wellbore Diagram Avail? ❑� Location Verified? © Photos Taken? If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: 450 BPV Installed? ❑ OA: 180 VR Plug(s) Installed? ❑ Wellhead Condition Wellhead looked good. Flowline is attachec but locked out. SSV is closed. AL line is removed and blinded. Wellhouse protecting wellhead. Condition of Cellar Good clean dry gravel ' Surrounding Surface Condition Good clean gravel. Comments Location verified with a pad map. Supervisor Comments Photos (2) attached. ,91` �IIWIl9 Friday, August 16, 2019 Suspended Well Inspection — PBU 13-05 PTD 1811030 AOGCC Inspection Rpt # susRCN 190707170933 Photos by AOGCC Inspector B. Noble 7/6/2019 BP Exploration (Alaska) Inc. Prudhoe Bay Unit -Well# 13-5 SL 1761' FSL & 56' FWL Sec.13- T10N-R14E-UM BHL 1427' FSL & 893' FEL Sec.13-T10N-R14E- UM State Lse.# ADL 28315 Drilling Permit u 81-103 APL 50-029-20626 I 2019-0706_Suspend_PBU_13-05_photos_bn.doex Page 1 of 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM ON 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:Suspend Well IZI. 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 181-103 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20626-00-00 7. Property Designation(Lease Number): ADL 0028315 8. Well Name and Number: PBU 13-05 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL (4' 1 ,§ p' 11.Present Well Condition Summary: Total Depth: measured 11055 feet Plugs measured 7937/9230 feet A U!6 4 201! true vertical 9530 feet Junk measured 10010/10977 feet Effective Depth: measured 7937 feet Packer measured 9497 feet ;(,\ Li true vertical 7222 feet Packer true vertical 8400 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 35-115 35-115 1530 520 Surface 2628 13-3/8"72#L-80 33-2661 33-2661 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1503 7"29#L-80 9547-11049 8438-9526 8160 7020 Perforation Depth: Measured depth: 10001-10021 feet 10128-10148 feet 10158-10178 feet 10191-10201 feet 10211-10221 feet 10228-10238 10246-10266 feet 10274-10280 feet 10290-10310 feet True vertical depth: 8788-8803 feet 8883-8897 feet 8905-8920 feet 8929-8937 feet 8944-8952 feet 8957-8964 8970-8985 feet 8991-8996 feet 9003-9018 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 4-1/2"BOT 3H Perm Packer 9497 8400 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: EM1{ N 0V 1 LL 2015 SCMO 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 210 3685 1865 -11 -16 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.2831 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development [,3 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 IZI. 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: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature A 4,tni, CGS_. Phone +1 907 564 4424 Date 8/4/15 Form 10-404 Revised 5/2015 vri- R/Z/ ` 4ly1,--- RBDM5-A AUG 1 4 201bmit Original Only • • Q o 0 0 0 0 0 0 I� CO CO N 00 O u, CO n O O N N- O N VLUN- (DN- 0 7) 0 0 0 0 0 0 0 L CO M I- if) CO NY CO') M 10 0) (0 N d m c- szt CO 00 co 00 V co co co co CO h N 00 1.0 CO O CO Cf) CO N I- co O) co co 1 1 1 H OO Ln 1n co CO 0) CO CO CO CO CA NY N CO I� 00 CO I. G) CO O CO O In 0 N- N- CO 0) CO t 10 N CO O O) O) C I I I I I I I Q 11 I) CO O TY 0) N- Q}M M co co O) 1f) N V ▪ M� CO 0) 0) W I- a0 O OO O CO C) pI ccO o• co z. Ooo _1 _C N *tcn , * co (I) Nom - • � � N (� p) 00 d N CV U O M 00 F 04 cm co I O L �O co CO O O N 00 (0 CO10 'Cr 0) G) N CO O CA J W W Q Q _OH w 0 0 •NUUww U u a _Z Z_ z 0 W W W m m O 0 Z Q W C H H • • 0 0 0 a) -o C a) a) m T (0 0) 2 T O >- o 475 LL i a) Q O Q a) m ~ O _ - M r -c O - ;, m L a o °a a) m Q .( Q N -o a) -o -0 CNi 0 0 I d in O_ (/)O ~ (� L 0 OQ c 0 z w I- < u) 0 >- O co N .o 5 ` I U • • Suspended Well Site Inspection Form 5 Year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT 13-05 Field/Pool: PRUDHOE BAY/PRUDHOE OIL Permit#(PTD): 181-103 API Number: 50029206260000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 11/24/2012 Surface Location: Section: 13 Twsp: 10N Range: 14E Nearest active pad or road: DS 13 Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean, active pad Pad or location surface: graded gravel Location cleanup needed: none Pits condition: good, rain water Surrounding area condition: clean Water/fluids on pad: none Discoloration, Sheens on pad, pits or water: none Samples taken: none Access road condition: good Photographs taken(#and description): (2) flowline and wellhouse Condition of Wellhead AOGCC requires: 1)a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition Gray Gen 2 wellhead, gray tree. Clean, functional Cellar description, condition, fluids: back filled w/gravel, clean Rat Hole: N/A Wellhouse or protective barriers: yes, wellhouse Well identification sign: yes, correct Tubing Pressure (or casing if no tubing) n/a SSV closed Annulus pressures: IA/OA=210/20 psi Wellhead Photos taken (#and description): (3)wellhead, tree, S riser Work Required: none 041, Operator Rep(name and signature): Whitney Pettus AOGCC Inspector: Matt Herrera Other O'• -_ Ryan Hayes Inspection Date: 7/12/2015 AOGCC Notice Date: 7/8/2015 Time of arrival: 8:00 AM Time of Departure: 8:05 AM Site access method: truck '.. A . ., ,.... - . .. „, . „. ,, -.. 1,,,,', it, „ ..........-- ..--'. -•:,..'i., ,..-.,,,k.„ ,,,,,,.-:: . ...,4?4,,,,,,,.,..,..„,,,,, ....,,..., .., wiffigni-"'''"\ ,.. ,. t... ..-.....„,. ....-..,....t.i,,,, - ', ,.,`..*4•%-, . -,..%...:Az.-,..,-. ..,..1. .-.,-.,........,., ..--.,,,,,,..4. , ,. , . - ,..,.. '''''' •I‘kN I :,,,,,l',.. ... ',,,ig4 r' * ,..., ... .. ,.. ..,..., „„.. .,.:,....,,,,,... :. . . ,.... . :.. ....., ...„..„ ..... ... ... ,...,_:,,, .,, \ :„, „, -„J.,-.4.-,*,,,I•7,,,)!,,,'„,-,-,- , .i,', ,....7„7,0t ',..i4g44...;: 4.. .„.„, „i..,...,,,, ,.,.. :44- :,.„-'-:'!•!,' .,' ,.., . , . . . ...... .. .. .. .. . ... , _ . . ... . ,..,.._,..,.._ .., ., ,.. ... ,.. ,, ------ ,............, ,,,,..... . li..,„--... ........ ....... , ,, ..... , _ ., . . , ,...,.......„ ., . ... .. ,, „.....,..‘,. . - ...... ..., ,... ... . . . „. - - .„. 1:-.= 1' .,,,,,,..#;' .,.. ,.„,„ ,.., „. 14--.'z'r -,:':,''',„,, t - ,,,,,:' :„ ... '„,t;.:, „ 4' iii„. i ..,.:Itoo). „. ., ,'; , „:',,:. '.,',;.,,-„' ' .,,,,,', -,.,. --.1t.-4. - ,,,., - ' „;',,,'/,',-.'in:',:'7.t, ' ,;,. 1 ' , 1 '11 4 0,, ,, .. ', . ,.., :' ” I , ' , , ' i",,4 ,:',,,,?:, :1,"''" 1 t ,. ''' ' . . . ..... A , 1 , ,,.....,, _le ' ,,,,,,,,.: , = , , ,,,, -=.„. Itillittitir r pit . ,...,-..: , . ..,-,.. - ..„._ A ,.. 4 ..., _,.................„ .._ ~„......,.......„Ati.,,,i,....................„,_,..._ f . t ' J. ,{ :h nw x � . 4 ':,,,,'.,".:;4'''''''''4:*:f.4..'-4'.,,.:''"'":44'. ' Q. \ \ ,.vlk- ; ,r4.,,, •, , \ ET \ , . \ - y tat- c ` ax tttr 1 : - ...au �r ..". � „OPP' 4 µ-- ri �`d. - �a � mx 'te .' 9:x gillillP y t a Jt C ..w. y .s '1. m a.Yy�b ty 4,...... 4,Pc,yp.e„ _.•.w �-tea. } ��a ”-�-i►. _-�... .�'$"..�. ..�l,a. ,- �ww�w iY.,._ �s"" { { ; f ,_ :,k..7,,'`.:`'' 1 it 1l4 • 1 i :„,:i. ',''•:';':.•-.5*-...*'...:,... 1, t l ,•:". " li t f. s•iy k .'....',':,....' .'',..-,...... •' . A .1,,?,-,... , • • • 8 ,......,,,....,,,:„.1.:„.:5,,.1, } i • • ,•�y•a ..',i''' � • f'''''•-• •,1 t ti' ,, • , (. 1 fi_ p'f ..10,e0,4,,,,,,,,,,''''. \ s i L611ILP,LI ! FJ£Al{�i. V i=vy z in^ 4 y�W�L t . oi'° 0 1 ,i 't . , • at. , tillih‘ J ,,,,...„,,..-,.'' 0 1 --ikv„ t t i ;. �' tete,., :, • . r 1! ! jj1hkY Vii; . • ,. . ir,7 r ..,. . \ . , , .e. , , . * ' .. ., , . . .. . . ommorAdminn"":, , . 1 i .. . . v....------- Milli urnimisommill go uNIMIF AIIIIIIII, v,„,, i I. • ' 4111110Millir All ,allumillaw,''' --- . '' ' . .. ., ,..,...,. . : . ,../.., .. ---;------- -- rA a..artitarall___). , .4 II , .1 , ' • ' . ‘ ii, \ - - A lirarifall gillir---Allir---1111111-- ir - ---- ----;' —- •' 1:. : / AI v 4.mroma , / / ' ,....- /., .' . • /714--•i•Ai ''•/• ,, .E.-::-:' i7.---- A r'''''"• . ' i ____ .,.._•-, -.7. .... 1. •:••.... .:-,.:.„ . .... g g / a TY w 1-- - - , 4.,,,, a • ------- , — ..,„.... --- - Gal 2 sib,NOTES: L REQUIRES A SSSV. GRAY WELLHEAD EAD= GRAY 1 3-05 GRAPHITE P M PED.LDON'T MITOA;PASSED NFT ACTUATOR= AXELSON 04/11195.POGLM LEAK tb 5057' KB.ELEV= 78' BF.B.EV= KOP= 3100' 2156' H 5.1/2"OILS ROM SSSV It D=4.562" Max Angle= 51"@ 11055' GAS LFT MANS Datum M)= 10122' ST M) TVD DEV TYPE VLV LATCH FORT DATE Datum TVD= 8800 SS 1 2922 2921 6 OTIS DOME RO-5 16 09(27/96 13-3/8"CSG,72#,L-80 BTC,N3=12.347" H 2661' 2 5060 4833 32 OTIS 'DONE BK 16 09/29/96 3 6594 6134 35 OTIS DOME RO-5 16 09/29/96 4 7733 7063 37 OTIS SO RO-5 20 09/27/96 ESTMA 1 Ei)TOC N TBG(XX/XX/XX) H7937' 5 8451 7609 43 OTIS DMY RO 5 0 09/27/96 T 6 8530 7667 43 OTIS DMY RO-5 0 08/05/81 ESTIMATE TOC N IA(XX/XX/XX) —I 7838' i } - 7 8951 7982 41 OTIS DMY RO-5 0 08/10(96 9-5/8"CSG,47#,L-80 BTC XO TO S00-09 BTC 8900' ' ♦ 8 9029 8042 41 OTIS OW RO-5 0 08105181 v"' 9 9323 8267 40 OTIS DMY RO-5 0 08/05/81 .. 41 i 10 9401 8327 40 OTIS DW RO-5 0 08/05/81 Minimum ID =4.562 @5057 = ' STA,S#5T-I J#9BB-11BM)(ae4T-#9 5-112" OTIS SSSV ifirefirie;Cie 9230' —ICE ENT RETAI 2(XX/XX/XX) TBG PUNCH(07/30/12) — 9435' -9445' .a • 'rll�rr ,�% *--� 9478' H5-1/2"BOT PBR,ID=4.875' litivI�f �f 9498' _--I9-5/8"X 7-112"BOT 3-H PKR,ID=5.625" 72 PiAlliy,,I ,11 5-1/2"1BG-FC,17#,L-80,.0232 bpf,13=4.892" --r 9508' }--2'i 9503' H7-1/2"ILLOUT EXTENSION,D=5.625" P 9508' —7-1/2'X4-1/T XO,ID=3.958" TOP OF 7"LNR -I 9547' •Vii 9568' --H4-1/2"OTIS XN NP,D=3.725" Al 4-1/2"TBG-PC,12.6#,N-80,.0152 bpf,D=3.958" —{ 9571' = • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 07/12/15 Inspector: Matt Herrera Operator: BP EXPLORATION AK Well Name: PBU 13-05 Oper. Rep: Ryan Hayes PTD No.: 1811030 • Oper.Phone: 907-659-5766 Location Verified? Yes - Oper.Email: rvan.haves(rDba.com If Verified, How? LAT/LONG • Onshore/Offshore: Onshore Suspension Date: 06/04/04 - Date AOGCC Notified: 07/08/15 Sundry No.: 304-025 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing N/A Photos Taken? Yes IA 210 OA 20 AUG 1 9 2015 S Condition of SOME Wellhead: Good,Gauges operable Condition of Surrounding Surface Location: Good no standing water or oil sheen discoloration around well house or in cellar area Follow Up Actions Needed: Monitor IA and OA pressure and visually inspection by Operator Comments: SSV was closed. Attachments: Photos(5) REVIEWED BY: Insp.Supry Sr— 7/745 Comm PLB 12/2014 2015-0712_Suspend_PBU_13-05_mh.xlsx : f x • w t litIN waif r' t _ .- • � z a "Irk • 'ion _, , t. N _ u,�,ti a j; in O �. i J Ji iii/11)1i/its J v �� li J11t ,,!111111111 b ': ;;".,717111iiiiii11 ' 1 lJJ 0. , � -1: 11111) cil V ` 111 :; {fit � ]: M fit NI ,CI) rn '` s, , :7j '... � � ' ��'41i�� ,�1 � 0.1 'll�r. a ''llijjj 4 0 ill ail] ji G., M w imA CAA) s 1 O >, * • jI 4 j II t '! NSM Z q } / 4 O fV J�, �' i iljj j O v) a. a N ff � a , li,t/' ; i ' ivy ,t. 1 r, 1 • 1 11 ilrilPt- - i , ; ot ''') • 7 i .a !#1, ' ,....1. .." . A illi.r1 II4, ;111C ' 11111111110M , . ,.., , - - 0,-4, 4 r , s / i i tia a 2015-0712_Suspend_PBU_13-05j,hotos_mh.docx Page 2 of 3 0 k Ir.pi"ii Jul-,k .4 910 , r , , II i I ' 4 I 1 ,, P I ' ti A II 1 . rill' 1, *-1 • -'. —ism ' I ' f Zir.".• , i 11421 I T I° .... . leN\ 111111. ..,....:...trl, . , , i pa I• N • -: ,• .. 1 . , 1 . . . 1 ; i ' \ . a II 0'' a Fiii p. 1 ni \ 1 :„ 1 1 ,.\ \ i 1 tilt, \ ..... ....., 1 -.._..._ 1 _ \ _ ,,,,\ -0-61.--..r.:;,-4.-t-. ,„:,-.--.:,.,,, '1",,,:7,'7'4,47i''';',.• ... •,usint A- t.7-,'"';!:',;"4 ,Vt.,,,f.",,:`,4: I • .07*.f...i'?.:,..:...,..,-;,;';-.1,,::,:,.4 ,:.,:t.:',:te,,t`,,,,r...,':i'..'-'*,!:i;..1 ;4.'.4t.1 6,44..f'4.-;14c*,...44';'",'''..;''-,.' ' . , , --. '..,,',.,..,,i...PP7-:'''f.,,,.4 c 2, L'z,4j,yV..."4,*(:,::',. .4.4r4":* '''''';'141160,' '''..1 r..-.4',,,7M-....i.°*,". - • - ' -...,. ' '''- .,1 1 . ''':,;„ ,,,it.:'''',........1. ,,24.-...4.44.g.v.als KAA.A. ..,,, AV-4.•:.;:ti,.:.-•-- -,•. , - - • -'•...-•',-1-- -: '•-,,,.'0".:r.-:•1•:t''.7;-•• '„--.74-`-,-, •47:71.4:4-'''• " 'V.,—.,•'' - . -7-•*- . -.• - - - - - 2015-0712_Suspend_PBU_13-05photos_mh.docx Page 3 of 3 1 RECEIVED • STATE OF ALASKA • DEC 13 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOd\ la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® Suspended' 1b. Well Class 20AAC 25 105 20AAC 25.110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero • ® Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 11/24/2012 181 - 103• 312 - 245 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 7/21/1981 50 029 - 20626 00 - 00• 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 8/12/1981 PBU 13 -05 1761' FSL, 56' FWL, Sec. 13, T1ON, R14E, UM 8. KB (ft above MSL): 78 00 , 15. Field / Pool(s) Top of Productive Horizon: 1453' FSL, 3855' FWL, Sec, 13, T1ON, R14E, UM GL (ft above MSL): Prudhoe Bay / Prudhoe Bay. Total Depth: 9. Plug Back Depth (MD +TVD) 948' FSL, 4405' FWL, Sec. 13, T1ON, R14E, UM 7937' 7222' • 4b. Location of Well (State Base Plane Coordinates, NAD : 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x - 687277 y 5931829 Zone ASP4 11055' 9530' • ADL 028315 - TPI: x - 691083 y - 5931617 Zone ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x - 691645 y - 5931126 Zone ASP4 None 18. Directional Survey: 0 Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): • (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIL / BHCS / SP / GR, FDC / CNL / Cal, CBL / CCL / GR, GR / JB / CCL N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM ToP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H -40 Surface 115' Surface 115' 32" 300 sx Permafrost 13 -3/8" 72# L -80 33' 2661' 33' 2661' 17 -1/2" 400 sx Permafrost, 2351 sx Fondu 9 -5/8" 47# _ S00- 95/L -80 31' 9849' 31' 8672' 12 -1/4" 500 sx Class 'G' 7" 29# L -80 9547' 11050' 8439' 9527' 8 -1/2" 531 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open .SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 5-1/2", 17 #, L -80 x 9571' 9498' / 8401' 4 -1/2 ", 12.6#, N -80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes ❑ No 7 2 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED H,� NI t 2 b 9230' 7937' 2 -1/8" Baker Inflatable Cement Retainer 101 Bbls Class 'G' 27. PRODUCTION TEST Date First Production a,, :-• �"° ,,, Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested: Production For OIL-BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RRr.MS DEC 14 2012 4 Form 10-407 Revised 10/2012 CONTINUED ON R EVERS a ub It Iginal Only / CO U O S / � g�� Q 1 b 29. GEOLOGIC MARKERS (List all formations an arkers encounter 30. FORMATION TESTS NAME D TVD Well Tester Yes No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 4727' 4549' None HRZ 9109' 8103' Sag River 9992' 8781' Shublik 10024' 8805' Sadlerochit 10124' 8880' Ivishak 10179' 8920' Zone 2C 10527' 9177' Zone 2B 10578' 9213' Zone 2A 10750' 9335' Zone 1B 10877' 9417' Zone 1A 10969' 9475' Formation at Total Depth: 31. List of Attachment: Summary of Work History, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Aras Worthingt 4-4102 Email: Aras.Worthington @bp.com Title: Drilling Technologist Printed ::: oe tfk *�,� i Pho ne 564 - 4091 Date: j! �"'` • INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50 - 029 - 20123 00 - 00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 10/2012 Submit Original Only • • 13 -05, Well History Date Summary 07/26/12 Drift Tubing [DTB] - ***WELL SHUT -IN ON ARRIVAL* ** (PRE - FULLBORE P &A). DRIFTED TBG W/ 2.30" CENT. & S. BAILER TO 9,688' SLM (RECOVERED CEMENT & SCALE). 07/27/12 DRIFTED TBG W/ 10' OF 2 -1/8" STEM, TEL, S. BAILER & LOC. TT AT 9,539' SLM (9,568' ELMD, +29' CORR.) & TAG HARD BTM AT 9,688' SLM 9,717' ELMD (recovered cement). 07/30/12 INITIAL T/I/0 = 200/200/200. RAN 2" HSD 6 SPF 60 DEGREE PHASED 2006 POWER FLOW GUN AND PERFORATED TBG @ 9436- 9445'. WELL LEFT SHUT IN - NOTIFIED DSO OF WELL STATUS. FINAL T /I /O 200/200/200. 08/06/12 Sssv And K -Valve [SSV] - ** *WELL SHUT IN ON ARRIVAL * * *. ATTEMPTED PURGE DOWN CONTROL LINE. CONTROL LINE PRESSURED UP.. PURGE 3 GALLONS OF HYDRAULIC DOWN BALANCE LINE. 08/21/12 SET 5 -1/2" RQY DUMMY SSSV @ 2130' SLM (unable to gain balance or control line integrity). 08/22/12 PULLED 5 -1/2" RQY DUMMY SSSV @ 2130' SLM . SET 5 -1/2" RQY DUMMY SSSV W/ SWELL FIX O- RING @ 2130' SLM. NOTE:UNABLE TO GAIN INTEGRITY ON CONTROL OR BALANCE LINE. 08/30/12 Sssv And K -Valve [SSV] - ** *WELL S/I ON ARRIVAL * ** (TROUBLE SHOOT SSSV). PUMPED 2 GALS HYD FLUID DOWN BALANCE LINE (NO RESISTANCE, PRESSURE MATCHING IA).. PUMPED 1 CUP HYD FLUID DOWN CONTROL LINE (PRESSURED RIGHT UP).. PULLED 5 1/2" RQY DUMMY SSSV (BOTH SETS OF PACKING AND O -RINGS LOOKED GOOD). 08/31/12 pump 235 bbls hot dsl down IA to assist slickline. Pumped an additional 8 bbls dsl into IA pressure up TxIA to 2500 psi. SSL working on control line. Pumped 164 bbls of 180* dsl down IA taking returns up tbg to hardline to 13 -03 flowline to production. Pumped 6.62 bbls dsl into IA to pressure T xIA up to 2500 psi. SSL working on control line. Total dsl pumped on 08- 31 -12= 413 bbls. Bled TxIA back 294/328. SSL still on well at LRS departure. FWHP= 294/328/53. 08/31/12 Sssv And K -Valve [SSV] - (TROUBLE SHOOT CONTROL LINE). TROUBLESHOOT CONTROL LINE WHILE LRS PERFORMED HOT DOWN IA & UP TBG. PUMPED 2 GALLONS OF HYDRAULIC DOWN CONTROL LINE AT 5000PSI.. PUMPED 1 GALLON METHANOL DOWN CONTROL LINE AT 5000PSI.. ROCKED LINE BACK AND FORTH WITH & W /OUT PRRESSURE ON IA/TBG.. —1/2 GALLON METHANOL AND —1 -1/2 GALLONS HYDRAULIC LEFT IN CONTROL LINE. 08/31/12 T/I/0 = 430/520/50. TEMP = SI. PRE AOGCC SUSPENDED WELL INSPECTION (AOGCC INSPECTION). REPLACED IA & OA GAUGES. TBG & IC HANGERS WILL NEED LIGHT CLEANING. SL & LRS CURRENTLY ON WELL.. SL IN CONTROL OF VALVES. 09/01/12 T/I/0 = 146/153/21. TEMP =SI. ASSIST WI PROJECTS (STATE INSPECTION - WITNEESED BY BOB NOBLE). NO AL. INTEGRAL INSTALLED ON CROSS FLOW =NOT CURRENT.. SV,WV= CLOSED. SSV,MV =OPEN. IA,OA =OTG. NOVP. (0900 HRS). 09/18/12 Leak Detect Log [LDL] - ** *WELL SHUT IN ON ARRIVAL * ** (E LINE SET IBP /LDL). INITIAL T/I/0 = 60/120/50 PSI. SSV AND SWAB OPEN. RIH W/ HEAD[6X3] /ERS /IBP TOOL. LENGTH: 32'. WEIGHT: 220 #. MAX OD: 2.13 ". SET DEPTH (MID ELEMENT): 9425'. TOP OF PLUG = 9418'. CCL TO PLUG: 23.67'. CCL STOP DEPTH: 9401.3'. LOG CORRELATED TO TUBING TALLEY DATED 8/15/81. GOOD PLUG SETTING INDICATION - POOH.. FINAL T /I /O = 60/120/50 PSI. Page 1 of 2 • • 13 -05, Well History Date Summary 09/19/12 T /I /O 0/90/26 Temp =SI MIT -T FAILED to 2000 psi (assist E- line). Pumped 2 bbls meth, IA tracking.Job postponed due to wind direction & poor placement of return tank. FWHP's= 543/577/29 DSO notified upon departure E -line still on well & in control of all VLV's. 09/19/12 INITIAL T /1 /O = 590/600/30 PSI. PJSM. TOOL CHECKS GOOD. CONCERNS ABOUT WIND DIRECTION CHANGE VS BLEEDING TO OPEN TOP POSITIONING (WINDS GOING RIGHT ACROSS ALL EQUIPMENT). PLAN IS TO HAVE OPEN TOP TANK REMOVED AND HARDLINE RIGGED UP TAKING RETURNS DOWN 13 -03 TO ELIMINATE THE POSSIBILITY OF HYDROCARBONS BLOWING INTO THE EQUIPMENT FROM THE OPEN TOP TANK. RIGGED DOWN EQUIPMENT AND LEAVE LOCATION. WILL RETURN AT LATER DATE TO PERFORM LDL. * ** FINAL T /I /O = 540/570/50 PSI. 09/23/12 Leak Detect Log [LDL] - ** *WELL SHUT -IN ON ARRIVAL * ** E -LINE LEAK DETECT LOG. INITIAL T /I /O = 550/500/0, SSV CLOSED. RAN LEAK DETECTION LOG DOWN TO 9400', JUST ABOVE IBP (DID NOT TAG). BASELINE TEMP DOWN PASS AT 120 FPM, PUMPED 30 BBLS CRUDE DOWN TUBING, RETURNS UP IA TO WELL 13 -03 FLOWLINE. LOGGED UP DYNAMIC PASS TO SURFACE AT 120 FPM. ABSORB DEBRIS IN WELL KEPT CLOGGING SPINNERS, FOUND IT WRAPPED AROUND SPINNER AND BEARING SHAFT ON RIG DOWN. LOWEST LEAK WAS FOUND AT 7035'. NEXT LEAK FOUND WAS AT POGLM AT 5060'. FOUND THIRD LEAK AT 6475'. LEFT WELL SHUT -IN, SSV CLOSED AS ON ARRIVAL. CLOSED IN JUMPER LINE TO WELL 13 -03. JUMPER SECURED. NEW ORING ON TREE CAP, CAP TESTED. HAND OVER WITH DSO PRIOR TO DEPARTURE, WELL SECURE.. FINAL T /I /O = 550/500/0. 09/23/12 T /I /O = 633/627/151 Temp = SI ( Assist E -Line with LDL.) Rig to TBG. Pump 3 bbis 60/40 meth followed by 286 bbls dead crude down TBG and up IA taking returns down 13 -03 FL while E -Leine makes logging passes. Shut Down / Standby for E -Line to POOH. E -Line in control of well notified DSO upon departure. FWHP = 885/662/158. M/W /SSV /M/ = E -Line. IA/OA = OTG. 09/25/12 PULLED BAKER IBP FROM 9,385' SLM (9418' ELMD) (all elements recovered). 10/01/12 CTU #9 w/ 1.75" CT. Scope: P &A Stage 1. RU. BOP test (pass). RIH w/ 2 -1/8" BKR Inflatable cement o e retainer. Launch 1/2" steel ball. Set cement retainer at 9230'CTM. Verify good set by applying 9K down weight. Perform injectivity test through retainer out IA — 1.5 bpm at 3300 psi. Prep for cement. 10/02/12 CTU #9 w/ 1.75" CT. Scope: P &A Stage 1. Pumped 71 bbis of 15.8 ppg class G cement through retainer placing 5 bbis in tubing (below retainer) and 66 bbls into IA through tubing punches at 9435- 9445'MD. Unsting from cement retainer. Lay in 30 bbls of 15.8 ppg class G cement in tubing. Contaminate w/ biozan to 7900'CTM. Chase OOH. FP tubing w/ 60 bbis of diesel. Final estimated TOC in IA — 7938'CTM, Tbg — 7937'CTM. RDMO. 11/17/12 DRIFT TO TOP OF CEMENT O 7887'S W/2.15" CENT & SAMPLE BAILER - SAMPLE RECOVERED, STATE WITNE - D. 11/24/12 T /I /0= 84/21/0 (AOGCC state witness CMIT TxIA to 2500 Psi Passed) (PLUG AND ABANDONMENT) First 2 CMIT Tx IA Failed. See Pumping log for details. Pump 12 bbls diesel down IA to achieve a test pressure of 2500 Psi. ( CMIT Tx IA) T /I /O lost 18/17/0 in 1st 15 min. and lost 13/14/0 in 2nd 15 min. for a total loss of 31/31/0 in 30 min. test. (CMIT Tx IA Passed) Bleed back Tx IA pressure. RDMO. FWHP 82/7/0 wing =shut / swab =shut / ssv= shut / Master= open / IA and OA open to gauges. Operator notified of departure. Page 2 of 2 TREE = WELLFEAD = GRAY GRAY 13 5 - ITE PUMPED. DON'T MITOA; PASSE[} NFT ACTUATOR = AXE3_SON 04111/95. POGLM LEAK t) 5057' KB. E3_EV = 78'' BF. EEEV = ? KOP = 3100 2156" H5 01ls ROM SSSV Ni? ID =4.562' Mix Angle = 51° @ 11055' s GAS tFTMANDRELS Datum MD ° 10122' ST MD E)El/ TYPE VLV LATt I ]PORT DATE Da um WD 880p' Ss ' MD TV /� 1 2922 2921 6 0115 DOME RO-5 16 09/27/ 13 -318" CSG, 72#, L -80 BTC, ID = 12.347' I-1 2661' �� 2 5060 4833 32 OTIS 'DOME BK 16 09/29/96 3 6594 6134 35 OTIS DOME RO-5 16 09/29/96 4 7733 7063 37 OTIS SO RO-5 20 09127/96 5 8451 7609 43 OTIS DMY FBI) -5 0 09/27/96 ESTIMATE) TOC 04 TBG (XX/XX/XX) 7937' 6 8530 7667 43 0115 OW RO-5 0 08105/81 ESTIMATE TOC IN IA (XX/XX/XX) 1 7838' ► 1 € + 7 8951 7982 41 OTIS EXvfl' RO-5 0 08110196 Y. I" il 1► - - 8 9029 8042 41 OTIS DMY RO-5 0 08/05/81 9 -5/8" CSG, 47 #, L -80 BTC X0 TO 500 -09 BTC I— 8900' I l 4P 4i!' 4P flfr 40 9 9323 8267 40 OTIS DMY RO-5 0 08/05/81 $ f 4 ' 110 9401 8327 40 0115 D RO-5 0 08/05/81 Min 'minimum !D = 4,56 "" 5057' ► � _ STA'S #5TFRU#9BE BM)CGBdr - #9 5 -112" OTIS SSSV i P 9230' - CE N X ENT RETAIN K/XX /XX) ITBG PUNCH (07 /30/12) 9435' '► 9445' +- ,� y b lb. # I t 9478' H5 BQT PBR, ID = 4.875" I O ► I►l 1 3 ►mot 9498' H9-5/8" X 7-1/2" BOT 3-H PKR, ID = 5.625" 5-1/2" TBG-F C, 17 #, L -80, .0232 bpf, 93 = 4.892" 9508' ' Z4� I 9503' H7 -1/2" MILLQl.1T F7CTEN5KDN, ID = 5.625" P 9508' H7-1/2" X 4-1/2' XO,. ID = 3.958" gik. Ai p TOP OF 7" LNR 9547' ♦ P P Ii 9568' --H4 -1/2" O T I S xN NIP ID= 3.725" ,411 4 -1/2" TBG -PC, 12.6#, 14.80, .0152 bpf, ID = 3.958" H 9571 95 71' — i4 -1/2 WLEG, ID = 3.958 9568' IH F] fufl TT LOGGED 08120181 �� 9790' H EST TOP OF Civil FLUE (06/04/04) fe ere 9-5/8" CSG, 47 #, S00-95 BTC, ID = 8.681' 9850' fee" 4 e 41 ire 4 PE32FORATION SUMMARY 10010' — IBP PUSHED DOWN FROM 9485' (10/31/03) REF LOG: BHCS ON 08/09/81 I ANGLEAT TOP PERF: 41" © 10001' Note: Refer to Production C43 for historical pert data 10090' —17" DOUBLE SHORT MARKER JOINT I SIZE SPF INTERVAL Opn/Sqz DATE I 3 -3/8' 2 10001 -10021 3? / C 03/18/91 3 -318" 4 10128 - 10148 C 08/07/95 I 3 -3/8' 4 10158 - 10178 C 06/15/90 I 3 -318" 4 10191 - 10201 C 06/15/90 3-3/8" 4 10211 - 10221 C 06/15/90 I 3-3/8" 4 10228 - 10238 C 06/15/90 3 -3 /8" 4 10246 - 10266 C 06/15/90 3 -1/8' 10274 - 10280 S 01/16/86 3-1/8" 10290 - 10310 S 01/16/86 10977' H FISH - 2" JDS RUNNING TOOL (01/08/89) PBTD 11019' P111111 •••••••1 7" LNR, 29#, L - 80, .0371 bpf, ID = 6.184 11050' •4•4•4•.4•4•*• 'TD --I 11055' a•♦■♦aa DALE REV BY COtvI\D TS DATE REV BY COI tQ ffS PRIX7HOE BAY UNIT 08/16/81 ORIGINAL COMPLETION WELL 13-05 08/01 /12 JCM(JMD TBG PUNCH (07/30/12) PED2MT No: ° 1811030 09/20/12 RWM/JMD' SET BKR OP (09/18/12) AA No: 50- 029 - 20626 -00 r 09/26/12 1/ISS/JMD PULLED BKR BP (09/25/12) SEC 13, T10N, R14E, 13 8775' FE_ & 4330' FN_ 10/15/12 ?/ PJC CMT RETAnJER/TOP (XX/XX/XX) BP Exploration (Alaska) III STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/01/12 Inspector: Bob Noble Operator: BPX Well Name: PBU 13 -5 Oper. Rep: Jon Arend PTD No.: 1811030 • Oper. Phone. Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 06/04/04 / Date AOGCC Notified: 08/30/12 " Sundry No.: Well Completion Rpt - Type of Inspection: Initial ' Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 146 Photos Taken? Yes IA 153 ° OA 21 ' Condition of Wellhead: Weelhead looked to be in good condition. FL, IA and OA were all blinded with gauges. SSV was opened to get pressures and then closed. AL , line had been removed. Cellar looked to be dry gravel. Wellhead procted with wellhouse. Location verfied with plot plan. Condition of Surrounding Surface Location: The location looked to be good clean gravel. Follow Up Actions a Needed: None Comments: Well Completion Report dated 7/10/2012 • SCANNED APR 1 7 2013 d Attachments: Photos (3) REVIEWED BY: Insp. Supry ---.f- 1° / .4 11Z- Comm PLB 10/2011 2012- 0901_Suspend_PBU_13 -05_bn Suspended Well Inspection — PBU 13 -05 PTD 1811030 Photos by AOGCC Inspector B. Noble „ / r P C f . l , i ,,,,, _ , / .,- ' , , • d 0 , ., . , , • • i y I , ` gyp ) , + by <:. 41 ^',' ). t .A. , A. ""' G i t . ,�� at PBU 13 -05 Suspended Well Inspection — page 2 of 2 Pr .1..sop,..... '1111 110 WP— K411111P ,.j I .....„. 'cso III i hi 1 1 111 1 II d li - - `",° !I ill I;" IA 4 111 E • v 1 1 DATE: 5-Nov-12 Stephanie Pacillo TRANS#: 6192 akana Data Delivery Services Technician K Bender Schlumberger Oilfield Services - I N Vi atural Resources Technician II . ) WIREUNE 2 ii 2.(113 ---- ..zklaska Oil & Gas Conservation Commission 2525 Gambell St, Ste. 400 \FEB , 4, ,::.',3C W -:::, ,.:,N,:, SUI'tc: ICC .1 .-..,. ,.',‘, I Anchorage, AK 99503 SCO '454. _ it: Office: (907) 273-1770 SERVICE OH RESERV •CNI IVIECH LOG DESCRIPTION' NAME ORDER it MST DS t DtsT otsT ., - LOGGE,O PRINTS PMTS ' 15-3013 BCRC-00208 X MEMORY PPROF 05-SEP-202 1 1 CD ---- A s k S-102 C5XI-00029 X - MEMORY IPROF 18-Aug-12 1 1 CD II/ MPE-23 C600-00055 X MEMORY !PROF 7-Oct-12 1 1 CD MPL-15 C600-00035 X MEMORY IPROF 9-Aug-12 1 1 CD MPC-05A AMPSURVEEL X SCMT 1-Oct-12 1 1 CD ...... . . 01-02 CBTY-00004 X LEAK DETECTION LOG 5-Oct-12 1 1 CD G-08A CBAF-00009 X LEAK DETECTION LOG 27-Sep-12 1 1 CD . - . . _ 09-05A APBNRWOSEL X FLOSCAN IMAGER 16-Oct-12 1 1 CD _ - --- W-15A BZ2J-00023 X MEMORY GAS LIFT SURVEY ' 10-Aug-12 - - 1 - — 1 CD - MPI-18 BCRC-00204 X _ _ _ MEMORY !PROF 30-Auk12 'I 1 CD 13-05 CBAF-00008 X LEAK DETECTION LOG 23 Se • -12 1 1 CD - 13-08A BBSK-00139 X LEAK DETECTION LOG 26-Sep-12 1 _ _ 1 CD V-225 BSM4-00035 X IPROF RST W/ WFL 26-Aug-12 1 1 CD , . — _ - • . - . - , 41) LL ....... . __:.• Please return a signdd copy to: Please return a signed copy to: BP PDC LR2-1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 8 O c.) cp RECEIVED STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMM ON SE p 1 9 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon • Repair Well • Plug Perforations • Perforate • 0 = ICI Susp Well Insp Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wee 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ - 181 -103 -0 3. Address: P.O. Box 196612 Stratigraphie Service ❑ IS. API Number: Anchorage, AK 99519 -6612 50- 029 - 20626 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028315 PBU 13 -05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11055 feet Plugs measured None feet true vertical 9530.1 feet Junk measured 10010 feet Effective Depth measured 9720 feet Packer measured 9498 feet true vertical 8572.85 feet true vertical 8400.89 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 20" 94# H -40 34 - 115 34 - 115 1530 520 Surface 2628 13 -3/8" 72# L -80 33 - 2661 33 - 2660.81 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 1503 7" 29# L -80 9547 - 11050 8438.57 - 9526.92 8160 7020 Perforation depth Measured depth 10001 - 10021 feet 10128 - 10148 feet 10158 - 10178 feet 10191 - 10201 feet 10211 - 10221 feet 10228 -10238 feet 10246 - 10266 feet 10274 - 10280 feet 10290 - 10310 feet True Vertical depth 8787.63 - 8802.7 feet 8882.59 - 8897.45 feet 8904.89 - 8919.75 feet 8929.41 - 8936.84 feet 8944.28 - 8951.72 feet 8956.93 - 8964.38 feet 8970.35 - 8985.28 feet 8991.26 - 8995.75 feet 9003.23 - 9018.19 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 4 -1/2" BOT 3H Perm Pac 9498 8400.89 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ScANNED JAN 2 8 Z0 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 210 3685 1865 -11 -16 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratonJ Development ❑✓ - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ W6$PL J GSTOR ❑ WINJ ❑ WAG GINJ ❑ SUSP a SPLUGJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature id c Phone 564 -4424 Date 9/19/2012 RE3DMS SEP 2 9 20124 M 7t 7- /401/2.'*-- Form 10-404 Revised 11/2011 A Submit Original Only Casing / Tubing Attachment ADL0028315 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 20" 94# H -40 34 - 115 34 - 115 1530 520 LINER 1503 7" 29# L -80 9547 - 11050 8438.57 - 9526.92 8160 7020 PRODUCTION 8869 9 -5/8" 47# L -80 31 - 8900 31 - 7944.02 6870 4760 PRODUCTION 949 9 -5/8" 47# S00-95 8900 - 9849 7944.02 - 8672 8150 5080 SURFACE 2628 13 -3/8" 72# L -80 33 - 2661 33 - 2660.81 4930 2670 TUBING 9449 5 -1/2" 17# L -80 29 - 9478 29 - 8385.57 7740 6280 TUBING 93 4 -1/2" 12.6# N -80 9478 - 9571 8385.57 - 8457.11 8430 7500 • • Daily Report of Well Operations ADL0028315 ACTIVITYDATE SUMMARY • = - • . emp= . ssis "" •rojec s a e nspec ion - ►vi neese• •y :o• lo• e No AL. Integral installed on cross flow =not current. SV,W 9/1/2012 V= Closed. SSV,MV =Open. IA,OA =OTG. NOVP. (0900 hrs) • • • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 13 -05 Field /Pool: Prudhoe Bay /Prudhoe Oil Permit # (PTD): 1811030 API Number: 50 -029- 20626 -00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 7/16/2012 Surface Location: Section: 13 Twsp: 10N Range: 14E Nearest active pad or road: Drillsite 13 Take to Location Digital camera Map showing well location /Aerial photos Brief well history Welibore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good, clean Pad or location surface: Level gravel pad Location cleanup needed: None Pits condition: Water, no sheen Surrounding area condition: Good Water /fluids on pad: Rainwater Discoloration, Sheens on pad, pits or water: None Samples taken: N/A Access road condition: Spine - good Photographs taken (# and description): (2) Front wellhouse, Back wellhouse Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: Gray tree, Gray wellhead and annular valves Cellar description, condition, fluids: Clean gravel, 24" deep Rat Hole: None Wellhouse or protective barriers: Wellhouse, good condition Well identification sign: Yes Tubing Pressure (or casing if no tubing): 146 psi Annulus pressures: IA= 153 psi, OA= 21 psi Wellhead Photos taken (# and description): (2) Tree, Wellhead and annular valves Work Required: None Operator Rep (name and signature): Gerald Murphy AOGCC Inspector: Bob Noble Other Observers: Jon Arend Inspection Date: 9/1/2012 AOGCC Notice Date: 8/31/2012 Time of arrival: 9:00 AM Time of Departure: 9:20 AM Site access method: Pickup TREE = GRAY GEN 2 • S NOTES: WELL REQU9?ES A SSSV. WELLHEAD = GRAY GRAPHTE PUMPED. DON'T MFTOA; PASSED NFT ACTUATOR = AXELSON 1 3-05 04/11/95. POGLM LEAK ® 5057' 'KB. ELEV = 78' BF. ELEV= Max Angle = 51 ° (4 11055' • I 2156' H5-1 /2' OTIS RQM SSSV MP, ID = 4.562" 1 Datum MD = 10122' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2922 2921 6 OTIS DOME RO-5 16 0927/96 13 -3/8" CSG, 724, L -80 BTC, 10= 12.347' 26 61' 2 5060 4833 32 OTIS 'DOME BK 16 09/29/96 H 3 6594 6134 35 OTIS DOME R0-5 16 09/29/96 4 7733 7063 37 OTIS SO RD-5 20 09/27/96 5 8451 7609 43 OTIS DMY RO-5 0 0927/96 1 9.58" CSG, 471, L -80 BTC X0 TO SO0-09 BTC H 8900' t — I 6 8530 7667 43 OTIS DMY RO-5 0 08/05/81 L 7 8951 7982 41 OTIS DMY FtD-5 0 08/10/96 8 9029 8042 41 OTIS DMY RO-5 0 08/05/81 Minimum ID = 2.340" @ 5057' 9 9323 8267 40 OTIS DMY RO-5 0 08/05/81 5.1/2" AVA DWP POGLM 09/29/96 10 9401 8327 40 oTis DAY RO-5 0 08/05/31 " STA 12 = 5-1 R AVA DWP POGLM TBG PUNCH (07/30/12) I--I 9435' - 9445' I • • I 9478' H5 -1/2" BOT PBR, D = 4.875" I ■-:',A �� 9498' H9 -5/8" X 7 -1 /2" BOT 3 -H POI, ID = 5.625" I 5-112" TBG-M, 171, L-80, .0232 bpf, 0= 4.89? H 9508' in L 9503' H7-1/2" MLLOUT EXTENSION, O = 5.625" I 1 9508' H7 -1/2" X 4-1/2" X0, ID = 3.958" I I TOP OF 7" LNR H 9547' 9568' H4 -117 OTIS XN NIP, O = 3.725" 4-112" TBG- PC, 12.6#, N-80_0152 bpf, D = 3.958" 9571' 9571 4-111" WIEG, ID - 3.958" 1 9568' H ELM) TT LOGGED 08/20/81 I 1VAVAv1 9790' HEST TOP OF CMT PLUG (06/04/04) I 1 9-5/8" CSG, 471, S00-95 BTC, 0 = 8.681" H 9850' 1�1�1�1�1 .4 1•••••11 1 1 `1. 1 `1. 1 ' 1 ' 1 'x PERFORATION SUMMARY , 1001 H IBP PUSHED DOW'1 FROM 9485' (10/31/03) REF LOG: BHCS ON 08/09/81 ANGLE AT TOP PERF: 41° 0 10001' I Note: Refer to Production DB for historical perf data I 10090' H7" DOUBLE SHORT MARKER JOINT SIZE SPF INTERVAL Opn/Sqz DATE ' 3-3/8" 2 10001 -10021 S? / C 03/18/91 3-3/8" 4 10128 - 10148 C 08/07/95 ' 3-3/8" 4 10158 - 10178 C 06/15/90 ' 3-38" 4 10191 -10201 C 06/15/90 3-3/8" 4 10211 -10221 C 06/15/90 ' 3-38" 4 10228 -10238 C 06/15/90 ' 3-3/8" 4 10246 - 10266 C 06/15/90 3-1/8" 10274 - 10280 S 01/16/86 3-18" 10290 -10310 S 01/16/86 L 10977' H FSH - 2" JOS RUNNING TOOL (01/08/89) 1 PBTD 11019' ••••••• 17" LNR , 298, 1 bpf, 10 1040.4 = 6.184" H 11050' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 TD 11055' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MT 08/18/81 ORGINAL COMPLETION 0426/10 PJC DRAWNG CORRECTIONS WELL 13-05 01106102 RNFTP CORRECTIONS 12/20/10 MB/JMD ADDED SSSV SAFETY NOTE PEWIT No: v 1811030 02/08t03 AT(YTP DELETE WAIVER SAFETY NOTE 08/01/12 JCMJMD TBG PUNCH (07/30/12) AA No: 50-029-20626-00 10/31103 JJ/TLP BP FUSI-ED DOININNARD SEC 13, T1 ON, R14E,13 8775' FEL & 4330' FNL 03/15/08 JWYTLH CMT PLUG (06/04/04) 11/08/09 PJC DRAWING CORRECTIONS BP E&ploration (Alaska) DS -13 , f July 11, 2012 Approximate Scale: 1' =400' V 2012- DMC0157 -9 -16 C 1 aerometric L .! a.< t E „ .. ,.......„. 1 t - •� „. ._ \ . . ., f ., 1 ,...‘ \ , : s ' ‘, . ' . :0 't. i :. _., t.. t `y.. • ,._., � ' € . 1 j �' , t - r > ! - . 1 f - . 1 J • • IIIIIIIIIIIIIIIIIIIIIIIIIINIMIIIPPF 183W '' I ■1111111111111! •10 ■•... i 240' 14iiihMt: (i Ented Exit L t • ' 1 175 1 it i , ,0,-...,• i I- . 236 I ' i '1•4 , .1 k - - ' 1 7 b. 1 11 '111110.;:`,A. I (II 41 ■ . '--,- . , .; ' , 04 ...... _ I l'... , -1--z$ • vl.' ' , ( _ . 1/.. ,,. . ' • ! . I. 1 1 ..-!-•_ a -- , 1 Ii 1 Is a . , le ......■& I II3 g . 1 1 - ' • a 4 I ..---0. 172' 1 1 z I .-,' -- - ' • • ' 1 — i °•,- . 1 , , 1 1 11"; - • (. t ' -1 ii I t• 1 I se , 14 ss, i I 1 ---..: 4 - • 9 . I ' it i .1 i , , , Ci fl '' ,.... 1 Errteri --;.....-- 1 1 I '-, Ent 40"1"r ,,f, .1. I • 1 3 • , I-I - ' ' i t — 6 29 It 1 2 • it I I ii II li i 1110 0 1 n '' f a , A ,, : • .... ...'". \ .-Sik ' 't 1 / I ......." -..- t ‘-' -^ ••■• — — — 1 1' --. •••• ' ',:t...,' • - WELL PRODUCER III or 0 WELL INJECTOR • DATE : 5/30/2012 SCALE . 1" = 300' MAP DATE . 2011 PBU - DS 13 WELL SLOT W/CONDUCTOR 03 bs , 449 5 fn./ • • ,, Al I DAN GEF ii . z a AP • • ilui 1 I■1 lialliN i iiii .. 4 qp.. - ----- Maki :411e! P P - i A ........... i, ri I OOP' /*is ! 0 0 . , f 1, 0 yir . ..F�_ , ` RIi I,1 001E itli. r,d or • • A it , . ,..,.-, -' , v- -T� ., A � '� • ' .., , , ..v...., , , it , L I P , it , 7,4 : , { A illItf. ' ..., '0'' .. ,..... i . . . - -...... 10 • ill III . r 1 111/ 111111 { I ' I ' ' r eft iris " . ; ,,G ~ ' �- , _. , t , ,.. . : . . , 1 i . / N , . . . . .., Ilk' ififirip -tri - ''',....4 . 4...- . . - I ., ,,, a. 1 . t . .... , . . ;,--, ' i 111111M I ...Dili '"... . 1! 7 -- -.' - -:. ‘ ' .; . i • 8 • • Tra 0[Fn[LnsEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMM'IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Josiah Igwe Wells Engineer c° BP Exploration (Alaska), Inc. t P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13 -05 Sundry Number: 312 -245 51„AiD JUL 8 2014, Dear Mr. Igwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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 reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this gi day of July, 2012. Encl. . STATE OF ALASKA Cliiittt V ALASKA OIL AND GAS CONSERVATION COMMISSION (� APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ® Suspend , ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 181 - 103 . 3. Address: 6. API Nu P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 - 0 - ' - r r • . 1 V re 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: JJ , 4. property line where ownership or landownership changes: PBU 13.4WL Q Spacing Exception Required? ❑ Yes ► .T1 No 3 2012 9. Property Designation: 10. Field / Pool(s): GCC ADL 028315 . Prudhoe Bay / Prudhoe Bay • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11055' " 9530' ' 9790' 8627' 9790' , 10010' 10977' Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2661' 13 -3/8" 2661' 2661' 4930 2670 Intermediate 9850' 9 -5/8" 9850' 8673' 6870 4760 Production Liner 1503' 7" 9547' - 11050' 8439' - 9527' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 10001' - 10266' 8788' - 8985' 5 -1/2 ", 17# x 4 -1/2" 12.6# L -80 / N -80 9571' Packers and SSSV Type: BOT 3H Permanent Packer Packers and SSSV 9498' / 8401 MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 15, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah Igwe Printed Name Josiah Igwe Title Wells Engineer -. Prepared By Name /Number: Signature \4-Ji � .- 4 .J f Phone 564 - 4753 Date _ /54/2,_ Joe Lastufka, 564 - 4091 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 3 /. Li Sudry Number: [Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: "T / 6.1-: 47 "t"'sa-ye„G c,,.,t- .----.1 4. # At -tersi,d ? 11 f Ace-y.4. yroj i i "--* * Subsequent Form Required: l6 -- '/D 7 i APPROVED BY / / Approved By: .. 1 � ' ti— COMMISSIONER THE COMMISSION Date 7- f - ! Z Form 10 -40 `.� -vised 0 2010 / Submit In Duplicate N DM JUL U 17 4+ . ' � 6/1-- 0 R 1 G I NA L. ,�T�� • • bp To: J. Bixby / R. Liddelow - Wireline Team Lead Date: April 24, 2012 C. Olsen / T. Norene - Well Services Team Lead From: Josiah Igwe, Well Engineer AFE: 0000004021 Subject: 13 -05 Full P & A Est. Cost: $400M IOR: N/A Sundry approval required prior to performing this work. Operation Sequence: 1 S Drift and tag top of cement plug (WSL to pump SqueezeCRETE to P&A each of the 2 control lines) 2 E Perforate tubing 3 C Set Inflatable Cement Retainer /P &A #1(9445' to 7945') 4 S Drift and Tag top of cement/ CMIT - TxIA to 2500 psi(AOGCC must witness). 5 E Perforate tubing and casing 6 F P &A #2 into all annuli and tubing (2661' to surface) 7 F MIT -T and MIT -IA to 2500 psi after 3 days WOC ( AOGCC must witness). 8 0 ND Tree and weld plate on casing. (AOGCC must witness). Well Status: • Current Status: LTSI since November 1997 Max Deviation: 51 degrees @ 11055' Minimum ID: 2.340" @ 5057' (POGLM) Last Downhole Op: 02/07/06 CT field test unit Last TD Tag 06/08/04 Slick Line drift to TT at 9710 slm Latest H Value: 06/29/2002 200 ppm Last SBHPs 11/24/89 Formation Pressure is estim. at - 3300 psi /214 BHST 1 • • OBJECTIVE: As part of BP's risk mitigation program to minimize the number of unsecured non - operable wells across its area of operation, well 13 -05 has been targeted for permanent abandonment. As per AOGCC definitions, the proposed work will be for full abandonment. The abandonment will require cement to be pumped in two stages. For the • first stage E -Line will shoot holes at the interval 9435' - 9445'. Coil will set Baker Inflatable Retainer at 9430' and pump cement slurry to set a lateral cement plug between the 5 -1/2" tubing and the annulus to bring top of cement to -7,945'. This will provide a -1,500' column of lateral cement plug above Sag River in the tubing and all annuli. A second plug will be pumped across to abandon the surface casing, IA and the tubing. Well History: Well 13 -05 was drilled 8/81 as a Z4 Ivishak producer and has cum'd 7.78 MMBO to date. Initial production was nearly -3000 BOPD at low WC. Early wellwork helped sustain high oil production including a 1/86 adperf ( +4000 BOPD), 5/87 crude backflush ( +1000 BOPD), and a 7/97 EDTA matrix stim ( +650 BOPD). IA/OA pressure tracking was seen in 1/89 and well was waivered for IAxOA comm the following month. WC began to steadily rise in 1988 and a 5/90 PPROF identified a down channel to the OWC; a squeeze was performed without notable benefit. Oil rates plummeted following the squeeze /reperf, so a Z4 frac was completed in 8/90 bringing the oil rates back to competitive. Sag perfs were added in 3/91. TxIA comm was verified with a 1/95 LDL and later mitigated with a POGLM in 9/96. Well 13 -05 reached MGOR in late 1997 and was SI /secured with an IBP in 12/97. The subsurface location was replaced by 13 -06i in 2/98 as part of the pattern reconfiguration project. The Weill 3-05 location was not used due to a fault in the NWB area and the 240M frac job. Well 13 -05 was suspended with a cement plug in 6/04., Secured by CT P&A 06/04/04 > 08/11/96: Run TTP; CMIT Passed to 3000 psi. > 08/18/96: LDL: #2 GLM still leaking; no others. > 09/27/96: WL set POGLM across GLM #2. > 10/01/96: TIFL Passed > 11/11/97: TIFL Failed: Well Capable to FTS! > 11/12/97: Well loaded > 11/14/97: WHP (1500/1300) Need to place TTP. > 12/02/97: WL set IBP in TT at -9,485'. > 02/05/98: CMIT TBG X IA Failed 2 • • > 08/09/98: Per DSO Shut -in Well Report "FTS- unknown leak pt, PWS" > 03/06/99: T /I /O = 1380/1360/1360 TBG FL NS. IA FL at surface. OA FL at surface. Monitor IBP > 03/08/99: CMIT -TxIA Passed to 3000 psi > 11/08/99: Monitor 1320/1320/1320 psi. IA FL NS, OA FL NS. > 09/20/02: MIT OA to 3000 psi Passed - CMIT T x IA to 1800 psi Passed to test integrity of IBP > 01/31/03: TxIAxOA comm waiver cancelled > 05/07/03: Drift for IBP - still in place > 10/08/03: IA and OA FL's rose to surface during bleeds. > 10/12/03: CMIT TxIA to 2000 psi PASSED. > 10/31/03: Beat IBP downhole > 03/26/04: Drift TBG - asphaltines @ 9300' 5u/ > 06/04/04: P&A © v > 06/08/04: MIT -T Passed to 2500 psi ✓ Cµ ,- s �� 3 > 02/04/12: MIT -T Failed, .CMIL -TxIA Passed to 2500 psi > 02/14/12: PPPOT -T & IC Passed > 02/20/12: MIT -OA Passed to 2000 psi Attachment Summary: 1. Pilot Cement Design pages 10 & 11 2. Penetration Report pages 12 & 13 3. Welibore Schematic page 14 4. Proposed Welibore Schematic page 15 5. Tubing Tall pages 16 & 17 6. Baker Inflatable Cmt Retainer page 18 Contacts: Josiah Igwe Wells Engineer Office / Cell: 564-4753/590-0610 Garry Garry Catron Petroleum Engineer Office / Cell: 564 - 4424/227 -7349 VOLUMES Tubing OD ID bbl /ft 4-1/2", 12.6# 4-1/2" 3.985" 0.0152 5-1/2", 17# 5-1/2" 4.892" 0.0232 7 ", 29# 7" 6.184 0.0371 Casing OD ID bbl /ft Annular Cap 9 -5/8 "x 4 -1/2" 0.0535 Annular Capacity 9 -5/8" x 7" 0.0256 3 • • Cement Design BHST: 214 degF BHCT: 184 degF SBHP: 3300 psi Slurry density: 15.8 ppg unislurry Class G cement Thickening time: 6 -7 hours Fluid loss: 80 -120 cc /30 min Perform a UCA test and a thickening time test on the field blend prior to rigging up. Estimated zone tops: Top Sag River (TSGR) = 9992.5 MD Top Shublik (TSHU) = 10024 MD Top Sadlerochit (TSAD) = 10124 MD Offline opportunities: o Grease all tree valve cavities, including SSV o Lock wing closed o PT all iron per SOP: Well Entry Procedures o Ensure SLB has transducers to monitor IAP o Special project PE to pump -1.2 gals of SqueezeCRETE cement down each of the control lines to plug and seal the control line to surface. There are 2 control lines. Pressure up line to 5,000 psi to ensure good squeeze. 1. Slick Line: 1. MIRU Slick Line 2. MU tool string and drift with dummy 2 -1/8" inflatable cement retainer. 3. Drift and tag top of cement then correct depths to tubing tail. 4. Dummy LGLVs stations 1,2,3 and 4t 5. RDMO 4 • • 2. E -Line Perforation: 1. MIRU E -Line 2. Ensure well is fluid packed. If fluid is not to surface, load well with 1% KCL and freeze protect with diesel prior to perforating tubing. 3. MU 2.0" 10ft of guns • Ensure the gun is centralized. • Gun spec will be HSD PF 2006, HMX at 6 SPF, 60 degrees phasing 4. RIH and tie in to the tubing tally dated 08/15/1981 and perforate the interval 9435' - 9445' 5. At surface confirm holes in the gun. 6. RDMO ✓ 3. Coil Tubing - P & A #1. 1. MIRU 1.75" CT 2. MU tool string with 2 -1/8" Baker Inflatable Cement Retainer. o Note the Differential Pressure for the cement retainer is 2600 psi. 7. RIH and set retainer at 9230', confirm retainer set as Baker Representative and POOH. o Coil flag is not required since there is a big window for setting between the retainer and the perforated interval. 3. Perform injectivity test with - 50 bbls. 4. RU cementers. o Test lines to 4500 psi o Line up cement lines and ready cementing equipment for mixing on the fly 5. Begin mix on the fly 15.8 ppg Class G cement . Collect cement sample for UCA test. o Please send cement test result to Josiah.lgwe(d bp.com 6. Pump cement slurry as per sequence below: 5 • • • 5 bbl fresh water spacer • 71 bbls 15.8 ppg class G cement. • Ensure to set CT weight on the retainer so as not to pump out of the retainer 7. Un -sting from the cement retainer and lay in the remaining cement slurry on top of the cement retainer with 1:1 returns as per below. o 30 bbls of cement o -30 bbls of fresh water (CT volume) behind. o This will put TOC both in the 5 -1/2" x 9 -5/8" casing annulus and 5 -1/2" tubing -7,945' 8. Quickly PUH to 7,500' and swap to 20 bbls of biozan to contaminate any trace of green cement in the coil or above TOC. 9. Swap back to 1% KcI and continue to circulate as POOH. 10. Freeze protect tubing with 60 bbls of diesel. 11. RDMO CT. Wait on Cement for at least 3 days. 4. Slick Line: Drift and tag cement / CMIT -TxIA to 2500 psi (AOGCC must witness): 1. MIRU Slick Line o Notify AOGCC 24 hrs ahead before testing. 2. Drift to top of cement with centralizer and sample bailer at - 7,945' md, note sample and depth in the AWGRS. 3. CMIT -TxIA to 2,500 psi as per MIT SOP. 4. Send test chart to Josiah.IgweAbp.com and retain hardcopy. 5. RDMO 6 • • 5. E -Line perforation: 1. MIRU E -Line and LRS 2. MU 2.5" 20ft of guns to perforate through 5 -1/2" tubing and 9 -5/8" casing • Ensure the gun is centralized. • Gun spec will be HSD PJ 2506, HMX at 6 SPF, 60 degrees phasing • Tie -in to tubing tally 08 -15 -1981 3. RIH and perforate from 2550' - 2530' md. Monitor OA pressure, should see change on OA if communication is established. 4. Establish communication with LRS down Tubing and up OA with 50 bbls of hot (120 150 deg F) diesel at 2.0 bpm not exceeding 2000 psi. • Note that graphite was pumped down OA and it passed MIT -OA to 2000 psi. • If unable to establish circulation circulate down tubing and up IA rock back and forth. • If still unable to establish circulation POOH and load guns. S hoot 500' above the current shot interval. 5. RDMO 6. Fullbore P &A #2: ✓ 1. MIRU SLB cementers. 2. Pump down Tbg and up IA with 20 bbl Chemical Wash pill at 2.0 bpm followed with 130 bbls of 120 °F KCL. This will clean out 9 -5/8" x 5 -1/2" casing annulus and make ready for cement. 3. Pump down Tbg and up OLat 2 bpm with 20 bbl Safe Surf 0 pill mixed in fresh water followed by 180 bbls of 120 °F KCL. This will clean out all the crude in the 13 -3/8" x 9 -5/8" annulus and make ready for cement. 4. Line up cement equipment, test lines to 3,500 psi and ready to mix on the fly. 5. Line up to pump down Tbg at 2 bpm taking returns up OA. Pump 5 bbls fresh water followed with 227 bbls Class G Cement. (OA Volume = 155 bbls, Tbg Volume = 62 bbls, plus 10 bbls to get good cement at surface) 7 • • 6. After 10 bbls of cement returns to surface open IA and gradually close OA '" valves. 7. Continue pumping down Tbg and take returns up IA. .. 8. Pump 127 bbls of Class G Cement down tubing and up IA. (IA Volume = 117 bbls plus 10 bbls good cement at surface) ✓ e> 14. 9. With 10 bbls of cement slurry at surface, shut down pump. 10. Pump across the IA and OA and the tree valves with 1 -bbls of biozan and diesel to wash out cement and freeze protect. 11. Close tree, IA and OA valves. 12. Wash Up cementers and RDMO. 13. WOC 3 days. . 7. Fulibore MIT -T and MIT -IA: 1. AOGCC Inspectors will need 24 hour notification of pressure testing cement. 2. Rig up Little Red to pressure test Tbg and IA. MIT -T and MIT -IA each to 2500 psi. • As per the current version of CRT- AK- 10 -60. Pressure test is acceptable where pressure drop is <10% over 15 minutes. 8. Other AOGCC Inspectors will need 24 hour notification to witness surface cement plug before marker plate is welded on casing. 1. Pull well house. 2. Excavate around wellhead so casing can be cut off just below pad level. Special Projects WSL to determine amount of excavating needed for saw and permitting required. 3. Flush IA with hot fresh water to remove diesel. Suck out as much fluid from Tree and IA as possible prior to removal. 8 • • 4. N/D Tree and Adapter Flange. 5. Move in crane and install lifting slings on wellhead. Rig up Wach's saw to make cut -1 ft below pad level. Make a clean cut across the Conductor, 13 -3/8" casing, 9 -5/8" casing, and 5 -1/2" tubing. 6. Remove and lay down wellhead. Verify that cement is across all annuli and inside tubing to surface. Perform top job as needed. AOGCC will need to verify cement height. 7. After approval by AOGCC of cement condition at surface install steel subsurface marker plate. • Marker Plate needs to be 1/4" thick and covering the entire area of the well. • Tack weld Marker Plate to outer most casing string (conductor pipe). Do not fully weld Marker Plate to casing to allow venting. • Bead weld the following information on the surface of the Marker Plate with the following information. BP Exploration Alaska, Inc 13 -05 API No. 50- 029 - 20626 -00 PTD No. 1811030 Note: These specifications come from the state of Alaska's regulations 20 AAC 25.120(b) and (d), (1), (2), and (4). 1.0171 8. At this point, the well is considered Suspended as per AOGCC definitions. f Full AbandonmentQf the well will happen at pad remediation, casing will be cut off greater than 3 feet below tundra level and a marker plate will be fully welded in place. / 1.4 C„ 9 • • 1 1 Schlumberger Laboratory Cement Test Report Plug Si. natures Fluid No : PAK 10pIg3065 Client : BP Exploration Location / Rig : Date Well Name Field : Prudhoe Bay EIME=1101 Job Type Plug & Abandon Depth TVD BHST 205 degF BHCT 191 degF BHP Starting Temp. 80 degF Time to Temp. 00:35 hr:mn Heating Rate 3.17 degF /min Starting Pressure 500 psi Time to Pressure 00:35 hr:mn Schedule ( ) Composition Slurry Density 15.80 lb/gal Yield 1.16 ft3/sk Mix Fluid 5.104 gal/sk Solid Vol. Fraction 41.3 % Porosity 58.7 % Slurry type Conventional Code Concentration Sack Reference Component B'.end Density Lot Number G 94 lb of CEMENT Blend 199.77 IbIft3 Fresh water 5.074 gal/sk Base Fluid 0046 0.200 %BWOC Antifoam TU9K1007A0 0065 0.300 %BWOC Dispersant 0A56781687P5 D167 0.350 %BWOC Fluid loss DALA074630 D153 0.200 %BWOC Antisettling 101508 -01 D177 0.030 galisk Retarder 2010133AC Rheolo Avera a read s 300 140.0 127.0 200 104.0 97.6 100 64.5 59.0 60 48.0 39.5 30 35.0 22.5 6 21.1 5.5 3 18.2 2.4 10 sec Gel 26 4 10 min Gel 107 27 Temperature f 80 degF 1 180 degF P.: 117.034 cP P.: 116.041 cP Tr : 24.49 Ibf /100ft2 Tr : 15.98 Ibf /10052 Th ic ken in Tim 30 Bc 05:41 hr:mn 70 Bc 06:10 hr:mn 100 Bc 06:18 hr:mn Free Fluid Trace mL/250mL in 2 hrs At 80 degF and 45 deg incl. Sedimentation None Fluid Loss API Fluid Loss 95 mL 45 mL in 27 min at 180 degF and 1000 psi Page 1 10 • S chill mberger L aboratory Cement Test Report Plug Si. Fluid No : PAK 10pI Client : BP Exploration Location / Rig - Date Well Name Field : Prudhoe Bay Job Type Plug & Abandon Depth TVD BHST 205 degF BHCT 191 degF BHP Starting Temp. 80 degF Time to Temp. 00:35 hr:mn Heating Rate 3.17 degF /min Starting Pressure 500 psi Ti to Pressure 00 :35 hr:mn Schedule 0 ) Composition Slurry Density 15.80 lb/gal Yield 1.16 ft3/sk Mix Fl uid 5.104 gaUsk Solid Vol. Fraction 41.3 % Porosity 58.7 % Slu rry type Conventional Code Concen!raiion Sack P.e£erence Component Blend Density Lct NUM : er G 94 lb of CEMENT Blend 199.77 Ib/ft3 Fresh water 5.074 gallak B ase Fluid 0046 0.200 % BWOC Antifoam TU9K1007A0 0065 0.300 %BWOC Dispersant 0A56781687P5 D167 0.350 %BWOC Fluid loss DALA074630 D153 0.200 %BWOC Antisettling 101508 -01 13177 0.030 gaUsk Retarder 2010133AC Rheolo Avera a readin s 300 140.0 127.0 200 104.0 97.5 100 64.5 59.0 60 48.0 39.5 30 35.0 22.5 6 21.1 6.5 3 18.2 2.4 10 sec Gel 26 4 10 min Gel 107 27 Temperature 80 degF 180 degF Pr: 117.034 cP P•: 116.041 cP Tr: 24.49 Ibf /100ft2 Tr: 15.98 Ibf /100ft2 Thickenin Time 30 Bc 05:41 hr:mn 70 Bc 06:10 hr:mn 100 Bc 06:18 hr:mn Free Fluid Trace m1/250m1 in 2 hrs At 80 degF and 45 deg incl. Sedimentation None Fluid Loss APt Fluid Loss 95 mL 45 mL in 27 min at 180 deqF and 1000 psi Page 1 11 • • Company: BP Exploration Alaska Well: DS13 -05 Penetration Report Completion Borehole Diameter: 16 in Wellbore Fluid: Production Fluid Perforated Depth: 2550.0 11 Fluid Density: 7312 ppg Tubular(s) rising , ■ ., Weight Grade Inner Tubing Stand -off - Am .. , Diamcler Diametef Position Maurii I)ensit', Remjr'. (in) (lhmft) (8i) (pp) ( ° r.' 1 5.5 17.00 L80 4.892 Centralized Gas 1.933 96/96 2 9.625 47.00 L80 8.681 Centralized. Diesel 6.807 100/99 3 13.38 72.00 L80 12.35 Centralized Cement 15.86 100 /100 Formation Rock Type: Sandstone Rock Strength (UCS): 6403 psi Porosity: 20.0 % Vertical Stress: 2550 psi Bulk Density: 2.30 glcm3 Pore Pressure: 1 139 psi Formation Fluid: Oil Wellbore Damage: 8 in Perforating System(s) Pert' Phasing Shot PURE Ciun Stand Total Pen Fonn Pen Form Dia EH Dia AOF \i;ilc 1) 0....t I) Position ( Itl Average Average A)crage .ixcragc (in) (in) lin) (in1 Iin tint ft) ® 60 6.00 0.00 Centered 1.227 1.89 ^ 0.00 ^ 0.00 0.00 0 60 6.00 0.00 Eccentered 0 2,81 ^ 0.00 ^ 0.00 0.00 0 ^ Concrete -based Model: Based on traditional API Section 1 results convened to downhole conditions Gun System(s) (l : Kt Gun OD API Pen API EII i r_m (g) (in) (in) (in) ® 2 -1/2" HSD, PowerFlow 2506, HMX 11.2 2.438 5.20 0.64 19B 1st Ed 2 -1/2" HSD, PowerFlow 2506, HMX 11.2 2.438 5.20 0.64 19B 1st Ed ' Charge performance has been extrapolated from test data Results are based on API and other test data of Schlumberger perforating systems as well as computer modeling of perforated completions. Results are provided in good faith without warranty. SPAN Rock Version 9.1.1 File: C:\Schlumberger\SPAN -R... 9.O\DS13 -05 SPAN 2550ft.sp9 ® Copyright 2012 Schlumberger 12 • • Company: BP Exploration Alaska Well: DS13 -05 Penetration Report Completion Borehole Diameter: 12.25 in Wellbore Fluid: Production Fluid Perforated Depth: 8300.0 ft Fluid Density: 7.312 ppg Tubular(s) Caine Uu0.r ',.. (;rack Inner "tubing Stand -otl Ann dn. ,Annulu- C,g tit: 1)I.: nrL Diameter Position \t.a.rial F)_n,ir, Rcm.mi (In) (pill) 1 5.5 17.00 L80 4.892 Centralized Gas 1.933 98197 2 9.625 47.00 L80 8.68( Centralized - Cement 15.86 100!100 Formation Rock Type: Sandstone Rock Strength (UCS): 6403 psi Porosity: 20.0 % Vertical Stress: 8300 psi Bulk Density: 2.30 g/cm3 Pore Pressure: 3708 psi Formation Fluid: Oil Wellbore Damage: 8 in Perforating System(s) Pert Phasutg Shot Gun Stand Total Pen Form Pen Form Dia EH Dia AOF Angle 1)cn<ity Pn.itinn Off Aeerage Average Avenge Atcragc td,y1 , -',l (in) (uu (0:) (MI (in) ) - ® 60 60 6.00 Centered 1.446 1.89 ^ 0.00 ^ 0.00 0.00 0 6.00 Eccentered 0 1.89 ^ 0.00 ^ 0.00 0.00 0 ^ Concrete -based Model: Based on traditional API Section 1 results convened to downhole conditions Gun System(s) (iu VA ■ Gun O I ) . A P I Pen 1 1 1 ) 1 ) I ( Uni (in) inn ® 2" HSD, PowerFlow 2006, HMX 6.4 2 4.50 0.45 19B 1st Ed 2" HSD, PowerFlow 2006, HMX 6.4 2 4.50 0.45 19B 1st Ed " Charge performance has been extrapolated from test data Results are based on API and other test data of Schlumberger perforating systems as well as computer modeling of perforated completions. Results are provided to good faith without warranty. SPAN Rock Version 9.1.1 File: C: \Schlumberger \SPAN -R... 9.0 \DS13 -05 SPAN 947712.sp9 © Copyright 2012 Schlumberger 13 S • TREE - GRAY GEN 2 SAFETY NOTES: WELL REQUIRES A SSSV. Af E.A - c, CRAPHITTEPIAAPEO. DON'T PIT PASS MR A CTJATOR - AXE_SON 1 3 -0 5 04/11/95. POCIAll LEAK it 50ST KOP - 3 100' 141a... Aige - 51 a 11055.- n I 2156 H5 Irruit, RCAI-SSSV N.P. 0 - 4.562' I Dett-r AU - 10127 Datum - ND - 9430 SS GAS -51 1.441.0R.E..5 ST AID Ni; . DEV T'r lirLV ,ATO4 POW DATE 1 29fl 292 6 OTS DONE 140- 5 113 09,27.1% .r. 2 5060 4933 32 OTS "DCAAE EA 95 0929.98 40 BT. 0- 12 347 I - 1 2 3 6694 6134 35 OM DONE 90- 5 99 092993 4 7713 7983 37 OTS K1 RO5 20 0927/96 • 5 8451 7.309 43 OT IS EMT r1/3 -6 0 0927196 19 5 ..sc xrc. .4. o - ro sccon a 7. H asca I- 6 as xi 7667 43 OTS DAEY r10- 5 0 08/05831 7 99 7912 41 OTS DM'Y RO5 0 oartodge 8 9029 9042 41 OTS DAIY RD- 5 0 08/95831 9 9329 9267 43 Jr S DilY RD- 5 0 0805161 Minimum ID a... 2.340" @ 5057' 10 94 11M7 40 OTS WY RO-5 0 0905.81 5-112" AVA DWP POGLJA mrtwm I • STA 12 - 5 1.'2 AVA DIPOP RE/3_14 3475 H5 3or Pask ta -41°5 1 10.1 orz 941N• Fis.s.Ir x 7 112" BOT IN RM. ta - 5825' I I 5 1.2* TB Dr- 178 :. 9 0232130. E - 4992" H 2938. El ,,, 1 9!5417 7-112"IF A.IIDITE4SOCIl.0 I 9508 I--V1I7 X .412- Ao, ID- 3 35if I I TCPOr 7" ...14/R H f l IN. I 930, H, 1,2" OM 104 yr . C- 3 .725' I 4 1)2' TiOG- PC, 12.90 1 089. 9152=1 £ - 1358' 9571' 9571" 4. 1. M, C, • 19519" I 9588' HELM Tr .JX.iC4:30118211.16 1 I FfR 979W EST 11131 or arr PL LIG .10 :- CO. SC.0 M 95 B. El - a.ao t- H 983W orer 141 4 9 IRATC84 4ARY - .14.a0attatC 1 0010' BP Ptisfi X4 fICIII 3485 .;t0I3 ma: 51..811. --■...-- R:ff _CG. 84 O04 3909,191 A NG...EAT TOP PEW 41 -83,. 1 0001' Noia War io " De 'ar .evar.-21 3.11e, data I MOP H7' DOUBLE SHORT lall.RPIR JONI I Srej.: 9= 1141E5,A- OciraSqx DATE I 9 3.6' 2 93001 101721 S? 3 3,e- A 10128 - 10 149 ce.cu,s5 I . _ I 3.19 4 10158- 10179 C 06.15.90 4 113 191 112011 C 06/15.90 4 1021 1 113Z:1 -2 3a5.s0 .... - 1 3.16" 4 10%29 113.M.8 09/1 I ME 4 10248 1 C fle.' I 10274 • te28e3 S 31116.198 9 1. 10290 1 5 3116.95 Aili I 1097T H 2' JOS RIPPOC 10CA. :01.081691- I Ian 1 1019' Wirei I 7' ..kiR. 290, L-90, .a:371 Te, tor - ts .tair H 11090' %%AM Wind in 1 1055' DATE REV BY XAIMENTS DATE REV BY ODIALENTS FR=JOHOE BAY I.P1T 08/11/8/1 OR1G8NAL CCOPPLET ION 94'28110 P..0 DRAWING COI:1€C.710W WELL_ 13-05 0 1. RNOTP CORFECTIONS 12120/10 kee A 13 A MED SSSV SAFETY NOTE P094T %LE 81 10 30 02108.03 ATD17 DEL ETFINAWER SAM. "Y NOTE A Pi Nu. 50.029 -2062 1 0/31.03 -LIMP OP RISOED DOM/IMAM SEC 13. T1,344, R14.E 13 977 4 rE... 8 4 330 PC. 0 3/15.08 ..,111/11,4 CUT PUG 0,0034: 1 1;0903 RIC 'D.PAWING CORIEC.TONS OP Eiploraffon iAlasika) 14 • • 1 TREE = GRAY GEN 2 SAFETY NOTES; WELL REQUIRES A SSSV. WELLHEAD = GRAY Proposed ACTUUATOROR = AXELSON 1 A 3-05 GRAP►4TEPUMPED. DON'T MITOA; PASSED NFT KB ELEV = 78 04111!95. P(7GLM LEAKIM 5057' BF.ELEV= _ ? NEW CMT •�1 >s'�►��1 *�1 .i KOP= 3100' ® / t 4 irI K •=� , � = 2158' — 15- 12 " OTIS ROM SSSV NIP, ID =4,567' 1 Max Angle 51° @11055' OLD CMT ® ∎46 * � * 1 � � Datum IVD= 10122' ,4t4r4Vtle414 � 5057' 5-12" TBG LEAK 1 Datum TVD= 8B00'SS • A 1 • t . Ise • ST MD TVD DEV GAS LFT TYPE PORT DATE t1 44 . ra �/ 1 2922 2921 6 OTIS DOME RO-5 16 0927196 �. L� 113 -3✓8" CSG, 728,1-80 BTC, ID = 12.347" 2881' 4 ' 4 ' � d►i -i 1 � • 2 5060 4833 32 OTIS 'DOME BK 16 X129196 a 3 8594 6134 35 OTIS DOME RO -5 16 0829/96 ITOCI 7637' 4 7733 7063 37 OTIS SO RO -5 20 09/27/96 • ITOCJ 7945' t 1 44 *4 4 1-' 5 8451 7609 43 OTIS MY RO-5 0 09/27/96 A . � k ►t 7 8951 0 7982 41 OTIS DMY RO-5 0 08/10/96 81 81r 019G 1 9 -518" CSG, 478, 1 -80 BTC XO TO SOO-09 BTC 8800' �j 10 ° ► om' ►C : 8 9029 8042 41 OTIS WY RO -5 0 08/05/81 ► * 1 � � 4:1 i , 1 9 9323 8267 40 OTIS OW RO -5 0 08/75181 Minimum ID = 2.340" X13057' 4 t� ;, ,, {; � *1 10 9401 8327 40 OTIS OMY RO -5 0 08/05/81 5 -1/2" AVA DWP POGLM 09/29/98 , ,4i P - ' ' STA M2 =5.12AVA DWPPOGLM 1 9478' H5-1/7 BOT PBR, ID = 4.875" 1 ■ tit 9498' H9 -5/8 X 7 -1 /Y' BOT 3 -H PKR 0 = 5.625" 1 15-1/2' TBG -PC, 17$, L -80, 0232 bpf, ID = 4.897 I—[ 9508' ' II 9503' 7 -1/2" MILLOUT D(TENSION, ID = 5.62F I 9508' H7 -1/7' X 41/2' X0,10= 3.958' I ITOP OF 7 LNR 1—f 9547' I f 1.. 9588' H4 -1 OTIS XN NIP, ID = 3.725" 1 1 4-1/2" T80 -FC, 12.88, N-80, .0152 bpi', 0=3 358" H 9571' ' 9571' H412" WLEG, ID = 3.958" 1 I gam' H ELFO LOGGED 08/20181 1 •��a� 9790' — EST TOP OF CMT PLUG (08/04/04) 1 ►i411N4 1 9-5/8" CSG, 47#, SOO -95 BTC, ID = 8.681" 9850 . 141441414441414. 11444404 / // /41 4141141. PERFORATION SUMMARY --1 -- 10010' IBP FUSHED DOWN FROM 9485' (10/31/03) 1 REF LOG: BHCS ON 08109/81 ANGLE AT TOP FP1iF'. 41'42110001' Note: Refer to Production DB for historical pert data 1 10090' 1 DOUBLE SHORT MARKER JOINT i SIZE SPF INTERVAL OpVSgz DATE 9435 -9445 3 -3/8" 2 10001 -10021 3? I C 03/18191 3-3/8" 4 10128 - 10148 C 06107/95 3 -3/8" 4 10158 -10178 C 06/15/80 3.3/8" 4 10191 - 10201 C 08/15180 3-3/8" 4 10211 - 10221 C 08/15/90 3-3/8" 4 10228 - 10238 C 06/15/90 3 -3/8" 4 10246 - 10266 C 06/15/90 3 -1/8" 10274 -10280 S 01/18/86 3-1/8" 10290 -10310 S 01/16/88 'ma 1 10877' 1 - 1 FISH - 2' JDS RUNNING TOOL (01/08189) 1 MID St ft 1 7' LNR 29$, L -80, .0371 bpf, ID = 6.184" 11050' 1 411 1 11111 1 / To 11055' �au♦ DATE REV BY COMMENTS DATE REV BY COMMENTS PRl1DFI0E BAY liNT 08/18/81 ORIGINAL COMPLETION 0426/10 PJC DRAWING CORRECTIONS WELL: 13.05 01/06/02 RNITP CORRECTIONS 1220/10 M8/JMD ADDED SSSV SAFETY NOTE PERMT 1811030 02/08/03 ATD/TP DELETE WAIVER SAFETY NOTE AR No: 50- 029 - 20626 -00 10731/03 JJITLP IBP PUSHED DGWIWVARD SEC 13, T1ON, R14E, 13 8775' FEL & 4330 FM. 03/15/08 JIMTLH CMT PLUG (06/04/04) 11 /0809 PJC DRAWING CORRECTIONS BP Exploration (Alaska) 1 5 • • . 5-1/2" COMPLETrON STRIN!". • DRILL SIT P /3 . • DATE_ ...e.zs...4.... , PREPARED BY A ... . . . ........4.1. so .2 ... ...... -- - - -- - - • I ell AO As ,---...-. I . ....... . _I 414 _ . • - • I I 1!/ 9 a.e.* V A(6,4 -.....---- .9 :: - 1 . I 46,..* I ae42.41/4.. . A" " /00 44-616. 4.15.4A A 84 SR .4 I s..6 _ _ ! .€'3&4' I I. I. . _ ...JR: sY„. . 01'.:4 741 mod A„...a _ L .. ,...2 . _ _ t „07.5g, , ta_s_.4 OA g.* 0_44_64ropfensit ' ..../ _ J J S.4.0 ...4..20M_Ahtsge4t..4.!.mat.i.c.s4.4 lb .444r_ .. sear glum'. I - ./-. - I .. J.:1.V... ...407 06.‘ 44E,0„. 7 .. , e 4651 7A+ _. Loa "/...7.e04.-ig 4ititteArs1.1.04.7. nft "0 4 L t ... I.- .47.2 ,...4 b../_7t.r.es2vo_..............,.. 1 -/... _ I. , .Vit.... ..S1 1 .741.00.4343/0444AV.441.0 1.6966..of _ -1.4-• --4t10•.0„...-441161/.24LA War. At..... 1.--ViZia 441.9. .. _ _ -4..&09..S_ ... Sta - r _I 2...--1___13..2.......-SAL420-zatt_aal - _. _ Sa MCI". , _ .t.7 A KS "Ns 4j44 s 4 0.h...t.t.7.44.=.404,1,1714M9i. -5.d et.. I / -7 .1.04 lraceto.r.00 7..a -SO444 _ •__447 ism 7 I f cre_oe 4144,.0% Rot 72ib. $44/..AS i 45;1,44 i • 1,1....atztALait2-.„ . ....A.61A...4.2--4A9S-112 i A vo -663t.fi4t161avazzare44.0 I ':s W Tir sic Pop 46640 7,7( ."14.• - 1---- I J •41/0 . r .X.e - - - - - - - I .. _!.. . . _ Af./..f.____012.5.6401.161641 Z.s...7zA A% .4/Akdoem v Sr9r 4 / ,.7,725:41_ . I -.. .. '4i I •14. .... ..... 11 . 27004 Jee.aille-FLALe044404.X4t:-22 di -Mee-. I l' t t4'SS7 i I 1 .J. - - i. ' 0.4,04 AA 4W3'% 37 . .89sh 37 r i . --. r ..,..fej. ,. . 1.6.q 40...0.514.44. XX I./ b41.1,0•4* ...imr.j... "vs.'. 37 1. F . _.!.. ....1 ...I.X.,41-.. 6.:42#„,ar.-41 a... . 1..6 " 14 j . e973.2? J. / .73 i VS. I 9 3:/294^1044%.90 4r.&.„..akcels.2716-._ . • e 4' flt.47.... , S'S I6. S4 1 1 I /.1. SA _ 'fir .rae a 1 f5/. 44 "I nude I 1 5 'q ..„... 0 7 49.09. 4.4t7.1bv:+44/hummy ;,4I 5 ; 5 5 $4 le i 153P47 i / ! • '33' ! i sr iv,..or....a.a._...._ .. .. _ .. . . . !Ps* . 1 8 Ate16 .1 44p.ocitO aim . -05. ...R. ' rid-. . t 7C. I 193709.1 • I. /3. •ep 147,0 Ale l'eS ./.4 . __ „ . . __ IStet.44/ I 810.51,1 I 1 I 5.50 1 477S $4 •1:04 at 441/A4bw.tty SPAN r tto t / 1 9, gt 1 i . / i 42. ei IXi.) /2ittsZ -. ... . ----.. .. . . . ! ' 1 8 fo _ if 1.1 !. 1 I / s.fr - :st* el*.rit :AA. _ ' ; 94/S. /.2 I goatioi I ' . / . ..1 . . j, 44 . 1417$ 54.1.4 7'..44 OA 4 -Vt - 0.:Ae .5 rar . .. 6 i 4oto a 9. /9 . 9osi 54 i F.: . L..4 _Also. to_ .15* 96 . lye '-1 470.4 AIM .he ,tt',r 7224. I 9 0 5.0 /P. I t-Vo .24.1 /4 6107# • .t../e7. o i 9 .7/0..o6 1363..24 ! I I, ., I .S. . Arts 54.4 *045•0 4,4 4 xle 41/44,...o.y ,..itiz• 1 ; 9 W. '26 I - 9.9.7.4 7.3 7 .1 1 i 16 410 • . . . . . 5-1/2" COMPLETION STRING 1 . DRILL SI TF /3 1.15 . . • . .. DATE eli.J.4 PREPARED B Y ce-W4r.e .4s.4-4 r .. ________..._ • .._._‘ ..........= -.....-7---- . -- hini! I .. —......---- . _ ..._... .9 .93 WA_ ._ ./..47 _ YX 04. __ istilNiakar4.0_011./strac.434in .4_ _141..74/ . _I__ . __/.44 ...._0V.D ilt.7.‘4.1_. .. __ _-___Alt__-417[4444_4.1.t T.s.k.rdcw10 - 4i14,4,23--T17.1:44... 1 /..7 So _L.-FL' __ttiff______.$4 "Pay 4-rovree it&v-Beara.nat- f 2 . 2. _ ...._ ../...._ ... btzy.____zktzag..i.,tid9_t_f — I.-- ) .C.* aor 24(..Fsste.A.e Lea-Atuf-SLALS.9 g. Let_ _esst.12_ / 1.60 Wtr 0 0# 7 'XII .41,44, —4.1.4r_II___1141.1.9_ , a Ma :Avis if.4"/J.4 Al-42 4 9fl4 / /410 Ong %iv MP41.1 sar..u.ra sjois Ow , jeiaX0r t£41$4.- .17 .73or 211,44/./ess Seisha tho• ae I* 'zee 9Sifts4 9g- S3 t . 7 • a.,..t.$ a frio. f3 r ..._ _ —I _rms.4.41. 7- . .._. . ... 1 .......____ [ _... _ .. - ..i _. — • .. __ — /- _ __ ._ • - . ----1- --• •----• ------•-- - --- • ----- - - -- . . - - - • -- • •• ...._._ ..._ _... __ .. . . .. .. . _ . _ ....._ • • 17 • • BAKER Baker Oil Tools HUGHES Well: DS13 -5 Date: 04 -11 -12 Draft O.D. I.D. Length Coil Tubing Connector 2.13" 1.0" .38' J • a 44 Hydraulic Disconnect 2.13" 69" 1.53' 3/4" ball to disconnect Spotting Valve In Release Position 2.13" .56" 5.04' 4600# up Release 1 f ji., 5.0' I 1 Inflatable Cement Retainer 1 " 1/2 Ball seat 5 Pins 2200 PSI 2.13" .63" 9.45' ■ 1 pin DOV =450 psi 1 (( t 4.45' �II I�C(ijli i H Total Tool String Length = 16.40' 18 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® Suspended 1b. Well Class: 20AAC 25.105 20AAC 25110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 06/04/2004 181 - 103 304 - 025 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 7/21/1981 50 029 - 20626 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 8/12/1981 PBU 13 -05 1761' FSL, 56' FWL, Sec. 13, T1ON, R14E, UM Top of Productive Horizon: 8. KB (ft above MSL): 78 15. Field / Pool(s): 1453' FSL, 3855' FWL, Sec, 13, T1ON, R14E, UM GL (ft above MSL): Prudhoe Bay / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): 948' FSL, 4405' FWL, Sec. 13, T1ON, R14E, UM 9720' 8573' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 687277 y- 5931829 Zone- ASP4 11055' 9530' ADL 028315 TPI: x- 691083 y- 5931617 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 691645 y - 5931126 Zone ASP4 None 18. Directional Survey: 0 Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) _ N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill /Lateral Top Window MD/TVD: DIL / BHCS / SP / GR, FDC / CNL / Cal, CBL / CCL / GR, GR / JB / CCL N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H -40 Surface 115' Surface 115' 32" 300 sx Permafrost 13 -3/8" 72# L -80 33' 2661' 33' 2661' 17 -1/2" 400 sx Permafrost, 2351 sx Fondu 9 -5/8" 47# S00 -95 / L -80 31' 9849' 31' 8672' 12-1/4" 500 sx Class 'G' 7" 29# L -80 9547' 11050' 8439' 9527' 8-1/2" 531 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open S D SET (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE (MD) PACKER SET ( MD / TVD) 5-1/2", 17 #, L -80 x 9571' 9498' / 8401' MD TVD MD TVD 4 -1/2 ", 12.6 #, N -80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10010' IBP Pushed down from 9480' 4 .JUL t 3 1 9720' 46 Bbls Class 'G' RECEIVED 27. PRODUCTION TEST JUL 10 2012 Date First Production: Method of Operation (Flowing, Gas Lift, etc.): AOGCC Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS-MCF: WATER -BBL: OIL GRAVITY-API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS JUL 11101"1 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 7 �,1 1 L Submit Original Only 29: GEOLOGIC MARKERS (List all formations a arkers encountered): 30. FORMATION TESTS NAME TVD Well Tested. Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 4727' 4549' None HRZ 9109' 8103' Sag River 9992' 8781' Shublik 10024' 8805' Sadlerochit 10124' 8880' Ivishak 10179' 8920' Zone 2C 10527' 9177' Zone 2B 10578' 9213' Zone 2A 10750' 9335' Zone 1B 10877' 9417' Zone 1A 10969' 9475' Formation at Total Depth (Name): 31. List of Attachments: Summary of Work History, Well Schematic Diagram 32. I hereby certify that th - . , going ' rue , d orrect to the best of my knowledge. [16119-- Signed: Joe Lastufk I 1 Title: Drilling Technologist Date:1 " PBU 13 - 181 - 103 304 - 025 Prepared By Name/Number: Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Josiah Igwe INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Submit Original Only • • 13 - 05, Well History Date Summary 12/02/97 Set IBP @ 9480. 10/31/03 (PRE LOAD & KILL W/ CaCO3). ATTEMPTED TO FISH IBP. ENCOUNTERED ASPHALTENES AND UNABLE TO LATCH IBP. BEAT IBP DOWN TO 10,010' SLM IN THE 7" LINER. 03/25/04 (PRE CEMENT PLUG). DRIFT & TAG. 03/26/04 DRIFT TBG W/ 2.25" DRIVE DOWN BAILER TO 9300' SLM, UNABLE TO WORK PASS DUE TO ASPHALTINES, OBTAIN SAMPLE, RIG DOWN. -- NOTIFY DSO OF WELL STATUS -- (PRE- CEMENT PLUG). 06/01/04 MIRU unit #9. Perform weekly BOP test. Job in progress. 06/02/04 CTU #9: FCO Cement Squeeze. Complete BOP test. RIH with 2" BDN. Tag at 9372' ctm. Unable to inject into well to fluid pack. Attempt to bleed gas from IA to determine where gas is coming from. POOH to modify BHA for FCO. RU jumper to offset well. 06/03/04 CTU #9: FCO Cement Squeeze. RIH w 2" DJN and tag at 9384' ctm. Clean out to 10045' ctm w /hot diesel. Jet across interval from 10045' to 9650' ctm. Circulated bottoms up and POOH. Attempted to bullhead kill well down IA and tubing. Unable to effectively bullhead, poor injectivity. RIH with 2" BDSJN to 10000'. Circulate kill well with 717 bbls KCL. Pumped 46 bbls 15.8 ppg Class G cement while reciprocating above top perf. Placed 32 bbls in liner and behind pipe. Layed in remaining cement and started hesitation squeeze. 06/04/04 CTU #9: FCO Cement squeeze, Plug & Abandon Perfs. Continue to ramp up to squeeze pressure. Final squeeze pressure 730 psi over initial injection pressure, +/- 1200 psi over SIWHP. Dropped ball and cleaned out to 9720' ctm. w/1.5# bio and chased OOH at 50% in liner and 80% in tubing. Washed all jewlery on way OOH. Freeze protected tubing from 2500' to surface w50/50 methanol water. Jetted out tree and stack. Trapped 1440 psi on well and SI. Tagged tree w /freeze protect tag. Contacted DSO and EOC with current well status. Well left shut -in waiting on cement. 06/08/04 ( TAG TOC POST SQUEEZE). DRIFT W/ 2.25 CENT,TEL,SAMPLE BAILER. LOC TT @ 9546 SLM, ELMD= 9568) +22 CORR. = 9710 CORRECTED SLMD. PRESSURE TEST CEMENT PLUG TO 2500 PSI. GOOD TEST. NOTIFY DSO OF DEPARTURE, LEFT WELL S /I. Page 1 of 1 TREE = GRAY GEN 2 • S NOTES: WELL REQUIRES A SSSV. WELLHEAD = GRAY 13-05 GRAP HITE PUMPED. DON'T MITOA; PASSED NFT = AXELSON 04/11 /95 PO L EAK @ 5057' KB. ELEV = 78' BF. ELEV = ? KOP = 3100' Max Angle = 51 @ 11055' ® I 2156' H5 -1/2" OTIS RQM SSSV NIP, ID = 4.562" I Datum MD = 10122' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2922 2921 6 OTIS DOME RO-5 16 09/27/96 113 -3/8" CSG, 72 #, L -80 BTC, ID = 12.347" I-I 2661' I 2 5060 4833 32 OTIS *DOME BK 16 09/29/96 3 6594 6134 35 OTIS DOME RO-5 16 09/29/96 4 7733 7063 37 OTIS SO RO-5 20 09/27/96 5 8451 7609 43 OTIS DMY R0 -5 0 09/27/96 19 -5/8" CSG, 47 #, L -80 BTC X0 TO SOO-09 BTC H 8900' I.. 6 8530 7667 43 OTIS DMY RO-5 0 08/05/81 7 8951 7982 41 OTIS DMY RO-5 0 08/10/96 8 9029 8042 41 OTIS DMY RO-5 0 08/05/81 9 9323 8267 40 OTIS DMY RO-5 0 08/05/81 Minimum ID = 2.340" @ 5057' 10 9401 8327 40 OTIS DMY RO-5 0 08/05/81 5 -1/2" AVA DWP POGLM 09/29/96 * STA #2 = 5 -1/2 AVA DWP POGLM 9478' H 5-1/2" BOT PBR, ID = 4.875" I l■- 9498' H9-5/8" x7-1/2" BOT 3 -H PKR, ID = 5.625" I 15 -1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" 1-1 9508' 9503' J I 7 -1/2" MILLOUT EXTENSION, ID = 5.625" I I 9508' H 7-1/2" X 4-1/2" XO, ID = 3.958" I TOP OF 7" LNR I 9547' I 9568' 1-14-1/2" OTIS XN NIP, ID = 3.725" I 14 -1/2" TBG -PC, 12.6 #, N-80, .0152 bpf, ID = 3.958" H 9571' 9571' H4 -1/2" WLEG, ID = 3.958" I 9568' H ELMD TT LOGGED 08/20/81 I ♦�� 9790' H EST TOP OF CMT PLUG (06/04/04) 1 9 -5/8" CSG, 47 #, SOO -95 BTC, ID= 8.681" H 9850' 40040 WO*** ■ 101.01 0•.......Att, 10010'] -I IBP PUSHED DOWN FROM 9485' (10/31 /03) I PERFORATION SUMMARY REF LOG: BHCS ON 08/09/81 ANGLE AT TOP PERF: 41 @ 10001' Note: Refer to Production DB for historical perf data I 10090' H 7" DOUBLE SHORT MARKER JOINT I SIZE SPF INTERVAL Opn /Sqz DATE ' 3 -3/8" 2 10001 - 10021 S? / C 03/18/91 3 -3/8" 4 10128 - 10148 C 08/07/95 1 3 -3/8" 4 10158 - 10178 C 06/15/90 ' 3 -3/8" 4 10191 - 10201 C 06/15/90 3 -3/8" 4 10211 - 10221 C 06/15/90 1 3 -3/8" 4 10228 - 10238 C 06/15/90 ' 3 -3/8" 4 10246 - 10266 C 06/15/90 3 -1/8" 10274 - 10280 S 01/16/86 3 -1/8" 10290- 10310 S 01/16/86 I 10977' I-I FISH - 2" JDS RUNNING TOOL (01/08/89) I I PBTD I 11019' t'fft rrft 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" I 11050' ►�1��1�1..0 TD 1-1 11055' .�•�•�•�•�•�••• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/81 ORIGINAL COMPLETION 04/26/10 PJC DRAWING CORRECTIONS WELL: 13 -05 01/06/02 RN/TP CORRECTIONS 12/20/10 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: "1811030 02/08/03 ATD/TP DELETE WAIVER SAFETY NOTE API No: 50- 029 - 20626 -00 10/31/03 JJ/TLP IBP PUSHED DOWNWARD SEC 13, T10N, R14E, 13 8775' FEL & 4330' FNL 03/15/08 JIM/TLH CMT PLUG (06 /04/04) 11/08/09 PJC DRAWING CORRECTIONS BP Exploration (Alaska) (¡JGA \ltq/~OOLf 'l STATE OF ALASKA ,?I1:5 r!GC¡ 11- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon 0 Suspend I!] Operation Shutdown D PerforateD WaiverD Annular DisposalD Alter CasinQ 0 Repair Well 0 PluQ Perforations D StimulateD Time ExtensionD OtherD Change Approved Program 0 Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name' BP Exploration (Alaska), Inc. 181-1030 /' . Development Œ] Exploratory D 3. Address: P.O. Box 196612 6. API Number /' Anchorage, Ak 99519-6612 StratigraphicD Service D 50-029-20626-00-00 7. KB Elevation (ft): 9. Well Name and Number: 78.00 KB 13-05 /' 8. Property Designation: 10. Field/Pool(s): ADL-0028315 Prudhoe Ba Field / Prudhoe Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (md): Junk (md): 11055 9530.1 11019 9429.2 None None Casing Length Size MD TVD Burst Collapse to bottom to bottom Conductor 81 20" 94# H-40 34 - 115 34.0 - 115.0 1530 520 Liner 1503 7" 29# L-80 9547 - 11050 8438.6 - 9526.9 8160 7020 Production 8869 9-5/8" 47# L-80 31 - 8900 31.0 - 7944.0 6870 4760 Production 949 9-5/8" 47# SOO-95 8900 - 9849 7944.0 - 8672.0 8150 5080 Surface 2628 13-3/8" 72# L-80 33 - 2661 33.0 - 2660.8 4930 2670 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10001 - 10021 8788 - 8802.7 4.5 " 12.6 # N-80 9478 - 9571 5.5 " 17 # L-80 29 - 9478 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/2" BOT 3H Perm Packer 9498 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 DevelopmentŒ ServiceD 14. Estimated Date for 15. Well Status after proposed work: Commencin 0 eration: Oil D GasO Plugged I!) AbandonedD 16. Verbal Approval: Date: WAG D GINJD WINJD WDSPLD Commission Representative: Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Bartel Printed Name Paul Bartel Title Production Engineer Signature i=',.. . . Q ~ Phone 564-5402 1/23/04 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Mechanciallntegrity Test D Location Clearance R E eEl VE 0 Other: JAN 2 8 2004 Subsequ Approve ORIGINAL .. ~'BfL FEB o~ aM :'({'l¡. \jlr.\~l.{;;:t:' ¡¡-n-!ì') fit, ~ Q)no¡¡ ~~?¿r-~NJe'ì~a...iL t t U \Þ 6.3 ILU ,is!' Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE ",I ~I ~I III . ;0 ? P~/lAÀ;~" t./:. 29-J an-04 ,0 L/ ' U"t, ç 13-05 Suspend Proposal: 13-05 is a long term SI well, which last tested at approximately 300 BOPD, 7100 BWPD, 7.0 MMSCFPD in November, 1997. It was SI due to tubing x inner annulus communication, and the bottom-hole location was later replaced by 13-06A. An inflatable bridge plug was used to secure the well, but it has failed and subsequent attempts to reset another one have been ul)Successful. The well also has high shut-in wellhead pressure due to proximity to the 13-06A injector. A cement plug is .- the preferred method to secure the well. The wellbore should be retained for a possible future rig sidetrack. ..,/' The well has an inflatable bridge plug fish that was pushed to 10010',just below the top perf at 10001'. The proposed program includes: // . Set a cement plug with coiled tubing from the fish to approximately 9700'. f'" . WOC 48 hours. . Tag and pressure test the plug to 2500 psi. /' Prepared By: Paul Bartel Phone#: 564-5402(w), 696-1682(h), 240-8036(c) 1/29/2004 1 - r mŒ= GRAY GEN2 SAFETY NOTES: GRAPHITE PUMPED. WELLH6A.D= GRAY AClUATOR= AXB...SON 13 05 DON'TMITOA;PASSEDNFT04/11/95. KB. ELEV = 78' - POGLM LEAK@ 5057' BF. ELEV = --- ? KOP= 3100' Max Angle = 51 @ 11 055' ~ Datum~= 10122' .. 5-1/2" AVA DNPPOGLM Datum 1V D = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VL V LATCH FQRT DATE 13-318" CSG, 72#, L-80, ID = 12.347" ;tI 2922 2921 6 011S RO-5 *" I 2 5060 4833 32 POGLM BK 3 6594 6134 35 011S RO-5 4 7733 7063 37 011S RO-5 I 5 8451 7609 43 011S RQ-5 * Minimum ID = 2.340" @ 5057 6 8530 7667 43 011S RO-5 5-1/2" AVA DWP POGLM 09/29/96 7 8950 7982 41 011S RO-5 8 9029 8042 41 011S RO-5 9 9323 8267 40 011S RO-5 10 9401 8327 40 011S RO-5 9-5/8" X 5-1 (2" BOT 3-H PKR 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I 5-1/2" X 4-1(2" XO TOP OF 4-1(2" lBG-PC I ITOPOF7" LNR I I -1 4-1/2" 011S XN NIP, ID = 3.725" 1 14-1/2" TBG-FC, 12.6#, N-80, .0152 bpf, ID=3.958" 1 -I 4-1/2"TLBING TAIL I . H ELMDTTLOGGffi 08/20/81 1 19-518" CSG, 47#, L-80, D = 8.681" I PERFORATION SUMMA RY -1IBPAJSHED DOWN FROM 9485' 10/31~0~ 1 REF LOG: BHCS ON 08/09/81 A NGLE AT TOP PERF: 41 @ 10001' I\bte: Refer to A"oductbn œ for historical perf data SIZE SPF INTERV AL OpnlSQZ I)ð. TE 3-3/8" 2 10001 - 10021 0 03/18/91 3-3/8" 4 10128-10148 0 08/07/95 3-318" 4 10158 - 10178 0 06/15/90 3-3/8" 4 10191 - 10201 0 06/15/90 3-318" 4 10211 -10221 0 06/15/90 3-3/8" 4 10228 - 10238 0 06/15/90 3-3/8" 4 10246 - 10266 0 06/15/90 3-1/8" 10274 - 10280 S 01/16/86 3-1/8" 10290-10310 S 01/16/86 10977' 2" JDS RUNNING TOOL - LOST 01/08/89 I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I DATE REV BY COMMENTS I)ð. TE REV BY COMMENTS PRUDHOEBA Y UNIT 08/16/81 ORIGINAL COMPLETION WELL: 13-05 01/06/02 RN'TP CORRECTIONS PERMIT No: 1811030 02/08/03 A TD/TP DELETEWAIVffi SAFETY NOTE AR No: 50-029-20626-00 10/31/03 JJ/TLP BPPUSHEDDOWNWARD SEC 13, T10N, R14E, 13874.59' FEL& 4330.03'FNL BP Exploration (Alaska) I STATE OF ALASKA ~l ALASKA ~' . AND GAS CONSERVATION CO~t,.,.IISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1761' FSL, 56' FWL, Sec 13, T10N, R14E, UM. At top of productive interval 1407' FSL, 1355' FEL, Sec 13, T10N, R14E, UM. At effective depth At total depth 951' FSL, 876' FEL, Sec 13, T10N, R14E, UM. 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2597' Production 9772' Liner 1503' 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 78' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-5 9. Permit number/approval number 81-103 10. APl number 50 - 029-20626 11. Field/Pool Prudhoe Bay Oil Pool feet 11055 feet 9530 feet Plugs(measured) PBTD Tagged @ 10256' M D (6/1/96). 10256 feet 8979 feet Junk(measured) ORIGINAL Size Cemented Measured depth True vertical depth 20" 300 Sx PF 110' 110' 13-3/8" 400 Sx F & 2351 Sx Fondu 2675' 2675' 9-5/8" 500 Sx G 9850' 8673' 7" 531 Sx G 11050' 9526' Perforation depth: measured 10001 - 10021'; 10128 - 10148'; 10158- 10178'; 10191 - 10201'; 10211 - 10221'; 10228 - 10238'; 10246 - 10266' true vertical 8787 - 8802'; 8882 - 8898'; 89O5 - 892O'; 8929 - 8937'; 8944 - 8952'; 8957 - 8965'; 8971 - 8986' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9508' MD; 4-1/2", 12.6#, N-80, PCT @ 9571' MD. Packers and SSSV (type and measured depth)BOT 3-H Packer @ 9498' MD; 5-1/2" Otis RQYE3S~ ~_ I~ ~~. L 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached 0CT 2 4 1996 14. Treatment description including volumes used and final pressure Alaska 0il & 62s Cons. Commission Ancho.m~e Reore~efltative Daily Averaae Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 112 735 5250 - 331 Subsequent to operation 231 1397 9113 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Fleport of Well Operations . X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 352 Signed ¢.~ .,~. Form 10-404 Rev 06/15/88 Title Engineering Supervisor Date SUBMIT IN DUPLICATE~. 13-05 DESCRIPTION OF WORK COMPLETED PACKOFF GAS LIFT MANDREL INSTALLATION 9/29/96 · RIH & installed a 25' POGLM in the 5-1/2" tubing across leaking GLM #2 located at 5060' MD. Set the POGLM at 5057 - 5072' MD (seal to seal), POOH. Rigged down. Placed the well on production & obtained a valid welltest. RECEIVED OCT 2. 4, ]~8 A]~sk.'.], 0]] & G~s Cons. Commiss[o~ STATE Of ALASKA ALASKA{ .AND GAS CONSERVATION C{"'' ~IISSION REPORT OF SUNDRY WELL OPI:I'IATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1761' FSL, 56' FWL, Sec 13, T10N, R14E, UM. At top of productive interval 1407' FSL, 1355' FEL, Sec 13, T10N, R14E, UM. At effective depth At total depth 951' FSL, 876' FEL, Sec 13, T10N, R14E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DE ?r I;(B), 78' RKB '" ~.:..~"~" ," [eet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-5 9. Permit number/approval number 81-103 10. APl number 50 - 029-20626 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Sudace 2597' Production 9772' Liner 1503' 11055 feet 9530 feet 10255 feet 8978 feet Junk(measured) Size Cemented 20" 300 Sx PF 13-3/8" 400 Sx F & 2351 Sx Fondu 9-5/8" 500 Sx G 7" 531 Sx G Plugs(measured) PBTD Tagged @ 10255' MD (8/5/95). Measured depth True ve~lcalde~h 110' 110' 2675' 2675' 9850' 8673' 11050' 9526' Perforation depth: measured 10001 - 10021'; 10128 - 10148'; 10158- 10178'; 10191 - 10201'; 10211 - 10221'; 10228 - 10238'; 10246 - 10266' true vertical 8787 - 8802'; 8882 - 8898'; 8905 - 8920'; 8929 - 8937'; 8944 - 8952'; 8957 - 8965'; 8971 - 8986' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9508' MD; 4-1/2", 12.64t, N-80, PCT @ 9571' MD. Packers and SSSV (type and measured depth) BOT 3-H Packer @ 9498' MD; 5-1/2" Otis RQY SSSV (~ 2156' MD. ~,. , 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) see Attached .J~ Treatment description including volumes used and final pressure /~ O~t & G~ C~s. Commission Reoresentative Daily Average Production or Injection OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 69 543 2936 - 397 Subsequent to operation 118 1205 6129 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and corr,,eet~to the best of my knowledge. rm 10-4' ' Rev 06/15/88 Service 337 SUBMIT IN DUPLICATE 13-5 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 8/5/95: MIRU & PT equipment. RIH & tagged PBTD at 10255' MD, then RIH w/perforating guns & shot 20' of reperforations as follows: Reperforated: 10128 - 10148' MD (Z4) Ref. Log: BHCS 8/9/81. Used a 3-3/8" carrier & shot 4 spf at 180 degree phasing at underbalanced pressure. POOH w/perfgun. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. 9~8~95 NO. 97O9 GeoQuest 500 w. International Airport Road Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99518-1199 A'I-FN: Sherrie Well j~ob~ Log Description Field: Date BL Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay RF Sepia DIR MWD Floppy Disk D.S. dO22A-- [--'7.-~-~ DUAL BURST TDT-P 95 0 8 23 1 1 D.S. 4-7 ST1 ~--/,,.-"' ~ ~7 RST 950808 I 1 D.S. 4-7 ST1 /~) _ (.~ l [ CNTD 950809 I 1 D.S. 7-3A¢~)'~ ~ (,"~ PERFRECORD 950807 I 1 D.S. 11-18 ~' L~ t '~--'~--~ PROD PROFILE 95 0 8 0 7 I 1 D.S. 11-31 ¢~ L.-~ t'~-.--'~ PROD PROFILE 950809 I 1 ~.s. ~-0~ ~ ~ ~ ~% .~.~.~co.~ ~0~0~ ~ ~ . O.S. 15-35 ~q 0~_[~"' DUAL BURSTTDT-P 950806 1 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED / ALASKA OIL AND GAS 'CONSERVATION COM~HSSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 14, 1995 David Smith/Richard Ortiz ~unnular Communication Engineer ARCO Alaska Inc P O Box 100360 PRB 24 Anchorage, AK 99510-0360 Re: No-Flow Verification ~,]~,J Well DS 13-5 Dear Messrs. Smith/Ortiz: On April 11, 1995, our Inspector Lou Grimaldi witnessed a no-flow test on ARCO PBU Well DS 13-5. The well had been flowed down to atmospheric pressure and had been routed into an open top tank. The well had not produced any fluid for at least two hours when Mr. Grimaldi 'arrived; he monitored it for a another two hours with no fluid produced. The well was then shut in for twenty minutes with an 18 psig build-up - the pressure bled off quickly and a sustained gas rate of 150 SCF/HR was observed flowing from the tubing. The Inspector recommended that subject well be approved for no-flow status. The above well meets the criteria of a no-flow performance test and as such is considered incapable of flow to the surface. Under the authority of Conservation Order 341, Rule 5, it is not required to have a fail safe automatic SSSV; however, the pilot and surface safety valve must be maintained in good condition, and if for any reason the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be reinstalled and maintained in good working condition. Sincerely, Blair E. PI Supervisor cc: Lou Grimaldi bew/n f 13-Spb MEMORANDUM TO: THRU: David Johns~ Chairman' Blair Wondzell, ~ P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission · DATE: April 11, 1995 FILE NO: 1G9JCKCD.DOC FROM: Lou Grimaldi,~J/~- SUBJECT: Petroleum Inspector No Flow Verification Arco well #DS13-5 Prudhoe Bay Field PTD # 81-103 Tuesday, April 11, 1995:. I verified the No Flow status of Arco's well #DS13-5 in the Prudhoe Bay Field. When I arrived the well had already been flowed down to atmospheric pressure and been routed into a open top tank. The well had not produced any fluid for at least two hours prior and I observed it in this state for two more hours with no fluid produced. The well was then shut in for twenty minutes with a b~u!l~dup of eighteen pounds. This pressure bled off quickly and a sustained rate of 150 SCF~was ~T3'~erved flowing from the tubing. I recommend the approval of No Flow status for this well. SUMMARY: I verified the No Flow status of Arco's well #DS13-5 in the Prudhoe Bay Field. Attachments: NONE 0rill Sits: 13 Well: E-VALVE DEMI GN Sat Jan 22 14:22:16 1] 11 DOME SET PRESSURE: 320 PMIG 11 Wall will havre to bm run in ~nmmonlinm 13D in ordmr to kmmp tho K-valvm open. It should bm dumpsd by putting it into CC: ENGINEERING FILE / COORDINATOR PRB 2 & J.C. SMART / M.G. SHOEMAKE PRB 20 (WITNOUT3kT~A~J~MRNTE) J.E. FAUEETT / S. PIGGOTT PRB 13 (cov~m~Y) WILSON J~TO 1507 (WITHOUT ]kTTa%~MEN~S ) STJkTE OF AI.~MKA (COVER ONLY) DEMI GNED BY: K. E. LAWLER Drill S~ ~ · ~e: 13 Well. K-VALVE DESIGN Dec n~ vd 22:30:23 1992 DOgiE SET PRESSURE: 265 PSIG ~.. 60 DEG F FTP ~. CLOSE (PSIG): 200 PSIG K-VALVE CLASS (A, B ,C 1: B tl CO~NTS: VALVE PULLED FOR RE-DESIGN. LAST DESIGN SET TO DUMP AT FTP=300, DOME=385. NEW DEEI~ WILL ..ALLOW WELL .TO BE SWAPPED INTO LOWER PRESSURE CO~-24ONLINE CC: ENGIneERING FILE ~ COORDINATOR PRB 24 (WITH ATTAC~NTS) J.C. SMART /, M.G. SHOEMAKE PRB 20 (WITHOUT ATTACm~NTS) J.E. FAUSETT !. C.W. SHUt,AY PRB 13 .... -(COVER ONLY) ,.. R.J. REINTS ATO 1560 (WITHOUT ATTACHMENTS ~ STATE OF ALASKA (COVER ONLY) DESIGNED BY: B.T. SEITZ · 'SU°O s~9 ~ !!0 ~s~m ARCO AL.A~KA: INC. P.O. BOX i00368 ANCHORAGE, ALASKA DATE' i 0-25-9i REFERENCE' ARCO CASED HOLE FINALS PROD PROFILE GR/CCL GR/CCL F'ERF BREAK DOWN GR/CCL LEAK DETECT PROD F'RUP'i LI~ LEAK t)ETECT F'ROD F'ROF'ILE RUN i, RUN RUN t, 5' RUN RUN RUN ~, 2"&5" RUN ~, 5' RUN RUN i, 5' CAMCO CAMCO CAMCO -'CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO _ CHEVRON D ~ EXTENSION EXPLORATION E X X 0 N PiARATHON MOB IL I::'B WEL..i... F'IL_E~; R & D $ BF'X $'i" A'i 1:£ O I::' A L A 3' i< A 'TEXACO F'LEA£E SIGN AND RETURN THE-ATTACHED COPY A~' RECEIPT 01-- DATA . RECEIVED B ' ........... "NAVE ....... ". ....... '""F~r~ -,..:... :.. '.~.':: -,.,.:: ATO-i 5.~9..-':,-.~::.'.:.'.:',~..,:~.,-0.-.'..'.:..:...:~..~:"- ...... · ', ' , .~,..'t/" ,-~.,~', ,. ',7,.':~) ':~:.'.,,",, '::."', ..... ............................. ])'~',S'~ ': F':"."."'.T ........................ ...... % ........................ :.:.':.. ~-..L, ........ :':...' ..................... :...2,~;-.i_,,'.,,,,..". ].-.:..L..Z% ..... : ...... .:,.,:...: ........... '.' ........................................... : .......... 2.:,:.,'.T .......... 'Z~,:,Z_....'...:...,:,,",:,.... :....:,~,,':J.:. '.,:'::. ,;,~::T", ..... '... ............ ~.'":2..:.:::'.~'_.2'. .... '...'.. "....2~..L:2".:'..2 '....'~."_L.' :'.'_.~' ..... nT ~=,~.~ ,~, ,~.'"~:" ]. '. -. .. :~ ]. . .. - ' . .............. :...:.' '.':'~ .... '?..'"' . : __ .....,___...__..-~.-~-.~,,,--,,,-, ........................................ ~.......::..,.~ ........... .., ...................... . ..................... Drill Site: 13 Well: 5 SaY. Sep 07 08:~0:50 1991 K-VAlVE DESIGN DOME SET PRESSURE: 385 PSIG @ 60 DEG F FTP @ CLO~E (PSIG): 300 PSIG K-VALVE CLASS (A,B,C): C COMMENTS: K-valve should dump by flowing well to a depressured CC: C.P. FARMER / W.D. COOPER K.M. KENNEDY / L.D. LASH J.E. FAUSETT / C.W. SHUMWAY ENGINEERING WELL FILE PRB 24 PRB 20 PRB 13 K.L. MARTIN ATO 1551 STATE OF ALASKA (COVER) DESIGNED BY: W. H. Smals~ig Drill Site: 13 Well: 5 Sat Sep 07 08:18:44 1991 K-VALVE DESIGN SSSV DEPTH (MEAS): 2156 FTP @ CLOSE (PSIG): 300 PRESS ADJUSTMENT: 102 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: CK LGR FTP OIL %WTR GOR 81 0 416 1547 83.8 5918 CONDITIONS AT CLOSURE: 81 0 300 1664 83.8 5918 WELL TEST TEMPERATURE @ SSSV: 185 PRESSURE @ SSSV: 740 SEP COML GLR LIQ PWF PI TEMP PRES DATE SEL 956 9576 2098 6.05 174 0 09/07/91 Y 956 10300 1980 6.05 174 0 @CLOSE 185 638 DOME SET PRESSURE: 385 PRIOR DESIGNS: DATE: 03/25/91 Ol/Ol/81 01101181 SET PRESSURE: 365 FTP @ CLOSURE: 365 TEMP: LINEAR 0 0 NA 0 0 NA ESC=EXIT; Fi=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVIT¥ TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; STATE OF ALASKA ALASK~ LAND GAS CONSERVATION Cqt MISSION REPORT uF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM At top of productive interval 1407' FSL, 1355' FEL, Sec. 13, T10N, R14E, UM At effective depth At total depth 951' FSL, 876' FEL, Sec. 13, T10N, R14E, UM 5. Type of Well Development Exploratory Stradgraphic 6. Datum of elevation(DF or KB) 78 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-5 9. Permit number/approval number 81-103 10. APl number 50 - 029-20626 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Sudace 2597' Production 9772' Liner 1503' 11055 feet Plugs(measured) 9530 feet 11019 feet 9513 feet Junk(measured) Size Cemented 20" 300 sx PF 13-3/8" 400 sx F & 2351 sx Fondu 9-5/8" 500 sx 'G' 7" 531 sx 'G' Measured depth 110' 2675' 9850' 11050' Trueverticaldepth 110' 2675' 8673' 9526' Perforation depth: measured 10001 '-10021 ';10158'-10178';10191 '-10201 ';10211 '-10221';10228'-10238'; 10246'-10266' true vertical 8787'-8802°;8905'-8920';8929'-8937' ;8944'-8952';8957'-8965' ;8971 '-8986' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9508' MD;4-1/2",12.6~,N-80,PCT tail @ 9571' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 9498' MD; 5-1/2" Otis RQY SSSV @ 2156' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 904 2935 6976 896 3434 7046 Tubing Pressure 414 38O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~')/'- ~' ~ Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 535 RAC c: J. Gruber, ATO-1478 SH SUBMIT IN DUPLICATE~;~ DS 13-5 ADD PERF PROCEDURE REPORT OF WELL OPERATIONS PROCEDURE Performed 3/18/91 1. RIG UP E/L AND TEST LUBRICATOR. 2. RIH WITH PERFORATING GUNS AND TIE IN TO REFERENCE LOGS. . PERFORATE INTERVAL 10001'-10021' MD (BHCS 8/9/81) TO ATTAIN 2 SPF. POOH. 4. RD AND RELEASE E/L. 5. RETURN WELL TO PRODUCTION. d U L ,~, 0 t991 ,Ataska 0il & Gas Cons. L;om~.~issio,q ^nchorage Dri. ll Site: 15 Well: 5 K-VALVE DESIGN ~on Ma~ 25 08:25:57 DOME SET PRESSURE: 365 PSIG @ 60 DEG F FTP ~ CLOSE (F'SIG): 300 F'SIG K-VALVE CLASS (A,B~C): B Borderl:ine cta=_s B,C K-valve. Due to high rate the ~;'alve cannot, he dumped to depressured se~,arator. "~ , .... "" ' ' ' F'RB 24 !:'-:: (:::: .... F' I- ,.~F, M E R /' K,M, KEI'..INEDY / W,S, WIL. DER PRf'"~ 20 J.l"-". WINTERS / C.W. SHLJMWAY F'RB E:NGINEERING WELL F!t_E K.L. MARTIN A-FO !55.l STATE OF ALASKA (COVER) DESIGNED BY: whs I:;.: Ii-" !::' !ii: R F N C Iii; · A R C 0 C A,i;' Ii:' D H i:] I... E I:" I N A L.. S' i ... i ~ ;.!: ..... i -'.:3 ..... :i.." i C 0 L.. I... A R /F:' Iii: I::,' F R U J'.! i , i .- © '~' '2- '~'''' """ ': ........ ,;:. I "" ~' J F' F:-'. 0 D U C"'f' I 0 N F' I::,' 0 F:' I I... I'.".: R U r'! i .... 3 (i:' :"!:--''7 .... 9 i F:' I:;,' 0 D LJ C'T' I 0 N I::' R 0 I:: I L. I_:'~ ~ R LJ f".~. i , S .... i 3 .... i '7 '"' ? i C 0 I... I.. A I'~'. /F' Iii: R F' R U r'.! i , q ...... 'J 9 2-2 8 "" 9 i I N J I::' F:.: 0 F:' I I... E F:.'. U N i , I::' I:: ..... ..,, .... ..,, ..'~ .... i 6 '"' 91 C 0 I... I... A R / I::' Iii: F;.'. F: R U N i .. '.ii: .... i 2 .]~ ..... :5; ..... 9 i F:' R 0 D LJ (": T I 0 N F:' I:;,' 0 i::' I I...I-:i: I:;.'. U i:'.! i , '7 .... 'i 6 S-iii ..... :2 'i '¥' Iii I'i F:' Ii"' R A T U R Iii R. ~ rJ i .. ,.; .... . ....... ... I:;.:.. i....I i :: · 9 ..:':, .-.. ,. ..... 9 i I... E A I< D E '¥' E C T I FIN . , "i 2 .... '2 :'.'; ..-. 6..-- © i I N..J F:' R 0 F:' I I... F." 1:;: U ~'..~ i . i 2 .... i t :;i!; ..... i .... 9 i F:' R 0 D U C T ]: 0 N F:' F;: 0 F:' I I... Iii: I:;: I..J N i , i ''').'- © i '5 .... A ..... ":? i ][ b,I .J F:' F;.'. 0 F:' i I... E I";,' U N i ...'.. ;; .... · ! i',.:. .... .... 2 Pi ...,"z ..... i ":'~.., .... '::), i I... E A l< I) E 'T' E C "J' I 0 N I::.: L.IN. i .j ~'~ .... I::' ... .' .. . . ..? ..~ S ..... 'i ~::~"- o i C 0 L_ L.. A R /F:' li:.;I;: I:: R I N i .... -...., , "'"""1 RUN i , i4 .... 4 '"~: i ":~"" ::.) i I" I", U D .J C T I 0 N F:' R 0 F: I I... E t4 .... i 2 :i.~ ...... i ~.) "- 9 i ..J E W I:[ I... I:;.'. "f' R U N i: i4 .... i 2 :.iS ..... 'J (:) -9 i F:' R 0 D U C T I 0 i"4 F:'I:;.: 0 F:' I I... E R I..! i".! i , i4'"' 2 S ,'~"- :3 .... :2 i F' R 0 D [J C T I 0 N F:' R 0 F:' I I... E R U N i , i'.!!; ..... 4 '2 ..... I 9 "" 9 i F:' R I ,S' M A N A L..'T' :'~' I ,S' I::: U N i , i6 .... i 5 S"' 8- 9 t I...1!.". A K D E"' T r...: c T I 0 N R U N t , i(:5--- 2 4 ;.iS .... 9 ..... 9 i. I... E A K D E T E C T I 0 N I:;: U N i , ..y "l J i!it .... i 6 ..:~-8"" 91 F' R 01~> U C T I 0 tl F:' R 0 i::' I I...1:'~ I", U N 'i .. I" I.. I::. ~.,,S' E: i.~ I (i; N R Ii"' C Iii: I V Iii; D B Y HAtI:. A NIClii: ,S' i'.1A R 0 N W :[ L..,S' A 'f' 0.. '-' t '5 ,..'.'"' 9 A N I) DAY! 0 N ........ i ': ..... i '" I, E:. f LJ Ik N T H E A "f' 1' A C I'.1E D C t.J I" N A,S' R E C: Iii; I I::' T 0 F:' D A L i' A I::I F:' R 0 V Ii!: I) ............ l"l:;:AN't;":JJ: 9i (')82 ., ....... D I ;S' T I:.~ I B U T I 0 N · '"' CENTI:,'AI.. F'ILE$ '11' "" C: H E V .,,. RON D & H · ,~"'- E X T E: N ,~' I 0 N E X F' L. 0 R A 'f' I 0 N .,,-"" Iii; ,.",¢ X Cl. N f't A R A l' H 0 N :~: Pi 0 B I I_ F' H :1: L. L. I I::' ~' PB W E L. L I::' I L E,S' I:;~ & D '"' B F:'X .,- .:~ T A '1' F- 0 F A L A,S' I< A T E X A C 0 i"' STATE OF ALASKA ~' ' .~' ALASK,e.._,L AND GAS CONSERVATION C~,v,MISS~i~ ! G J J~ A ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing , Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM At top of productive interval 1407' FSL, 1355' FEL, Sec. 13, T10N, R14E, UM At effective depth At total depth 951' FSL, 876' FEL, Sec. 13, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Stratigraphic Service X RECEIVED FEB 1 9 1991 Alaska 0il & Gas Cons. Commission Anchorage 11055 feet Plugs(measured) 9530 feet 6. Datum of elevation(DF or KB) 78 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-5 9. Permit number/approval number 81-103/90-559 10. APl number 50 - 029-20626 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 11019 feet true vertical 9513 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 300 sx PF 110' 110' Surface 2597' 13-3/8" 400 sx F & 2351 sx Fondu 2675' 2675' Production 9772' 9-5/8" 500 sx G 9850' 8673' Liner 1503' 7" 531 sx G 11050' 9526' Perforation depth: measured 10158-10178'; 10191-10201'; 10211-10221'; 10228-10238'; 10246-10266' true vertical 8905-8920'; 8929-8937'; 8944-8952'; 8957-8965'; 8971-8986' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9508' MD; 4-1/2", 12.6#, N-80, PCT tail @ 9571' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 9498' MD; 5-1/2" Otis RQY SSSV @ 2156' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 56 72 171 -- 1004 2676 6921 Tubing Pressure 225 424 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 614 LBL c: J. Gruber, ATO-1478 SUBMIT IN DUPLICATE DS 13-05 FRACTURE TREATMENT OF ZONE 4 DESCRIPTION OF WORK COMPLETED 8/6/90: Replaced LGLV's w/DGLV's. 8/1 1/90 : MIRU & PT equipment to 8000 psi. Pumped a Propped Fracture Treatment using gelled water & Carbolite proppant through open perforations at: 10158 - 10178' MD 10191 10201' MD 10211 - 10221' MD 10228 - 10238' MD 10246 - 10266' MD Ref. Log: BHCS 8/9/81. Pumped: a) b) 300 bbls Pre Pad, @ 45 bpm, followed by Shutdown. ISIP @ 2700. Resumed c) d) e) f) pumping: 650 bbls Linear Pad, @ 45 bpm & 3200 psi, followed by 2000 bbls Slurry w/proppant concentrations of 1 to 12 ppg, followed by 230 bbls Flush, followed by Shutdown. ISIP @ 1842. Placed a total of 239,000 lbs of proppant into the formation. Rigged down. 8/1 2/90: MIRU & tagged bottom at 10372' MD. Replaced DGLV's w/LGLV's. POOH. Rigged down. 9/12/90: RIH & performed a fill cleanout from 9259' to 10700' MD. 9/13/90: RIH & tagged bottom at 9956' MD. Flowed well. I/21/91: Pumped ESL treatment. Returned well to production, and obtained a valid production test. RECEIVED FEB 1 9 t99J Alaska 0il & Gas,Cons'i Anchorage PRUDHOE BAY FIELD K-VALVE DOME-PRESSURE-SEI'rlNG DATA SHEET Drlllslte-Well:I D$13-5 I D.te:l 10/19/90 Comments:I- This is the first k-valve design for the well since frac'ing the well. I' This well is flowing at a 82°H coke with 500-1500 IdCFD A/L gas injection. I .............. = .......... I~ "'7 ........ ~1 ,,,~, ~ ~,~,,~oOUil4.~., Previous Settings: Dome Pres. (PSIG) Closure FTP (PSIG) Date 190 200 Pre-frac 3/6/90 Production Data: ROR= 11 00 BOPD CFR - BOPD Swing Well (very high or Iow GOR): No Design Rates for Hydraulics Program PH2: Test Date 1 0/1 1 / 9 0 Oil Rate 1 093 STBO/D Watercut 9 0 % @ 82 H Deg choke I:)eg choke Choke Priority Well: No RECEIV[D OCT b 0 1990 'Alaska Oil & Gas Cons. Commission At~chorage Formation GOR 2444 SCF/STB Gas Lift Gas Rate 91 4 MSCF/D Total GLR 337 SCF/STB ;lowing Tbg. Pressure 314 PSIG =low. Wellhead Temp. 181 De~ F Choke Setting 82°H Deg Conditions at Valve: Temp. ~1) SSSV 1 91 Deg F Pres. @ SSSV 709 PSIG Pres. Adjustment @ SSSV 20 PSIG Notice: This adjustment is at the valver not surface. Calc. Dome Set Pres. 416.0 PSIG ~) 60 Deg F JActual Dome Set Pres. FTP at K-valve Closure K-valve Type 41 5 PSIG ~ 60 Deg F 25 0 PSIG ~ Surface C (A~ B~ or C) cc: Alternate / Farme ~-"~' Wilder / Kennedy (2 copies) cc: D.S. Eng: K. Martin D.S. Supv: Winters/Shumway Prep. by: W. H. Smalstig ATO-1551 PRB-13 PRB-24 ~ ii~ ~ TOTM.. LIFT F'OIBI TOTM. TEST FIJ T T tELL IMTE TIlE C/gleE SEP FTP ~ OIL ilTIt 61~ ~ 7. G81 ~ LEIIgIN OIL Jl Z 1~1. ~ PBS ~ TEST ~ S18~ BIR) ~ ~ tlTI! SCR/B SCJ:'/B ~ STBD S:CIr,,'D tiTI! T P L G IIIDES 13-65 10-11 2/19 82 181 314 221 1093- 954& 356~ 914 90 244~ 337 8.0 1445 ~ 8~ £ I~ Y G 2.50 13-'05 10"10 6~25 82 181 330 199 437- 10897*. 4785+ lb"ld 96 7482+ 424 8.0 1479 18~ 13-05 10"65 0055 70 179 402 267 1378 8185 3701+ U31 ~ 18t5 387 8.0 1300 1&87 13-05 10-02 1035 70 178 399' 2/2 1312+ 7967t 3337* 1124 8~ 1,gl~+ 3~2 7.') 8&t 904 87 [ il Y G 2.~ ' 13-05 0~-28 1500 &5 1&5 463 207 747 4550 1~8~ ~ 8& 1244, 370 2.0 691 904 87 £ I! 13-05 09,-2~ 0310 65 165 495 296 72i)~ 4#1+ ~ 1199 ~? 969. 341 ii. 0 13-05 09-17 2145 55 151 480 225 435+ 37U+ 1529+ ~9~, ~ 732 3~1 8.1 13-05 08-31 0220 45 11,5 ?73 19~ 53+ 143~ 1591+ 1489 9~ 790 10~) 12.0 13-05 08-27 1739 41 ~ 261+ 182 6.- 0 O... 0 0 O... 0 5.2 13-05 08-03 1814 82 79 228 1~ 19 229 3594~ ~97 92 1956~ 14464 12.1 13-.05 08-02 0400 82 92 223 193 10- 245~ ~31- 9515 96 1577 138,~ 8.0 13-0'3 0?-22 1410 82 89 212 180 ~- 199+ 4014+ 3944 ~& 8&95~ 1r'J89 8.0 IlliL SfllWE-OUT I~1'i~ qt? 73~ MEIlli G 2.50 ~5 799 96£i111G 2.~0 12 8&4 99£1111; 2.50 19 1310 79£11NB 2.50 22 12~ 7~EIIIIG 2.50 22 ~? 7~Ei~Ii(; 2.50 23 Z2~ 7~£111iB 2.50 ~LL £HI'IW PEB:BIT ~ H2S PSI LOC SltlIPLE HO. HO. IMTE TI[ I~TL:'R SOLIDS IIILLION EI(TBED 81' TitlEi( F1811 13--0512 10'-10-900400 84. O0 O. O0 11 10-05-90 0200 85. O0 O. 02 10 10-'02-901700 75. O0 O. O0 9 10-01-90 0130 64.00 O. O? 8 09-:30-900345 73. O0 O. 01 7 09-2~-90 2130 8&. O0 O. O0 & 09-17-90 22~ 94. O0 0.00 5 08-~1-~)00300 90.00 4 08-03-90 6400 98.00 O. O0 3 07-21-70 2330 98. O0 ?.0 PImOqJCTIIm SEPiiI~TIJ 3.0 Pm]DIN:TIm( SEPMMTOI! O. 0 PIIIIDtlCTIflH IEAM]! 1.0 PRfli)UCTIIB ~ 7.0 Plml)OCTIiB IEimBl PImi)UCTIfll( IEhl)t'll PImDUCTIiB HF. qi)81 PIml)UCTIOH S~PNMTIJ O. O PlmlXJCTlflllS~PMi~TOlt 2 07-20.-90 2200 96. O0 PRlX~TION IEitl~. I 07-18-90 0009 85.00 O. O0 10.0 P~I~CTII~ ~ Df. ill :--:it~: 13 Hell: ~' 'i 'r-i LIFT GAS IHJERTiCIH F'L~]T Oct 17 17:5.$:2& 1 Pii-iDL i..GR F'TF" t"l i L :..;:HTR i'$AF; GLR L ]' i;! F'HF F' i TEMF' C:'.=;UF' DATE '._--;EL I I::'i-.JTI~'I::;, DEF'TH '. 'ALI ir-- · ~--, , , ~.., , ..: , _.~_ 1 T',.,'B 2 I f'IEC~'.E;~'~_ EF"rH I I { T U.'E:E F.'F',E'.'-':'.--; ~ iC:R:E;E. F'F:E:F}'.~i; i 4 i 2 t "l" E H.,F'E F:~ T L~F: E t IN,.I DEF'TH I I I'"'l ICT.,I-,I:TI- IT L_'-'''r' I L :3 F: '..;' ! "$ ':':' -{ ! rzi I !... 1 ~-.-~'F'.'3, I PHF 3033 i I. I P'; L.. F: '~-.'"':'. l i { I { I ! I t q, , ": { L GF: :;:." 4 ..................................... 1 i.. Ge: · · .................. . { L_ G R 0 Bt. ill Site: 1~ Hell: 'i' ' ~" 'r.i LiFT GAS INJECTION F'LOT Oct 1~ I7:'4t ,;',iOTiL L..i~Fi FTF" i'-i i L ,".-;:i.,.i]'R Gl-iF: GLR L l Q F'i.o.iF F'i TEMF' C'.:;GF' ]"iRTE .¢, SEL , . TEMF' CF~RREL' LINEAR · EHTER 'FiEF'TH ',.,'ALUE' T',.,' 1] '21 ._ 6 MEAS I]EF'TH 2156 T I_1 l:: E F' F', E S'.;; C A'.E; E F' R E S S i 4 i 2 TEi',iF:EF:ATURE i '3'i L G R 914 0 E, ! L 1 1 'F,.'5 0 F'I.,.IF 2'.'.-,' ,.-'. 2 0 G L R 3 2 '.-.-,' 0 L GR '> L GR '':" L_GR 0 0 01 L 0 0 F' 14 F:' 0 0 ~ ~ ,t { ~ ................... t"-- '-'~. ~ ' ....... ....t-- ,.:.. ;:. ,._...:. ' ;J . ..... "i.".~ ~..':"~ ,.~ F ..I-- r, H F E .':., '4 F ._..-... ~.,.tl '? ...... ~" '" ...... ~ ...................... P'"" .............. ' ----I ..... :.,.,:., .,....,.....,...-, .... ' ........... ""':; .... ~ t:::..::, , .:: F:'L.!.-JH ]"!FMF' C¢¢E;E PRES ........ "r'uT::E F'F',ES ..... Dr.i 11 Site: 13 Hel 1: L. i F T G R S i i'-4d P_ L: I i ~zif..i F'L 0 T 17: 44:2~ I'9' i"iCi.'[iL L~3F: FTP Ci I L ,"-':i.,JTF: '30R GLF; L i t.-:! F'~,,.iF F' I TEI"IF' C:::;GF: DATE :_:;EL F'F-t2 A 1 AA 1 ~A-=, :{:'F' 7 ...'e44 ""= I 12,.- · .'._, A2 2'F'OEI I = :--:4 . _ ............ 1:_::I 15.5,.-m' IE1 ..... 1 1 ...... ;'A 'y' I ! : i .: I I1 - ! I I i 1 I TEMP '-'OF:REL',_. L I NEAF: E?--iTEF', T!EF'TH 'JALUE' 'r. ' v ' T_~ _'.-." 1 .=;, ,'", HERS DEF"FH 215,E, ' TIJ]~:E F' F: E ::; L:; ~ C: A'._:; E ~-' h: v__ ::; ::; i 4 i 2 'i'Ei',iF'EF:ATIjF;E ! 5'i I N J I,~-_ F ~' ' I'"l ~...k.II 'il ici 11 L G F: I,') I I.. L:3F: I · ~:3 0 1.'5,05 ~.~ F'!.,JF 2900 0 13!.... F: 251 ~D EGG: 2 I._.~3F;~ 5 L. GF: 0 ~:j r ......... H ....'T E ?_';-T".ii Drill Site: 15 Well: Current C= .505445e-5 N= Trial C= .505445e-5 N= CHK LGR FTP OIL DEG MSCFD PSIG STBPD Fri Oct 19 17:47:24 1990 I PR TRIAL WELL TEST DATA 1.0981 Entered N= 0.8000 Well Hydraulics Model 1. 8981 Used is: PH2-MONA FORM TOT T E I A S WTR GOR GLR LIQ PWF PROD TEST Y D P L Y CUT SCF/B SCF/B STBPD PSIG INDX DATE P T R L M 82 914 514 1095 89.7 2444 70 1151 402 1578 85.5 18&5 70 1124 599 1512 85.7 l&8& &5 1029 485 85 1195 495 55 1211 480 45 1489 775 82 5497 228 82 5515 225 747 85.8 1245 728 86.6 903 435 89.6 731 557 18659 5827 15.76 18/11/90 R Y A 587 9565 5051 14.68 10/85/90 R Y B 5&l 9219 5107 15.49 10/02/90 R Y C 5&9 5297 5207 18.67 89/28/90 R D 541 5401 5565 15.97 09/26/90 R E 564 4196 5529 11.21 09/17/90 R F 55 96.4 789 1050 1486 5502 5.69 08/51/90 R 8 19 92.2 1957 14484 244 1695 8.12 08/05/90 R H 10 96.0 1577 15846 255 1852 0.15 08/82/90 R I Base Reservoir Pressure: 5770 Current Declined Reservoir Pressure: 5701 Date of Measurement: 01/01/88 Rate of Decline: 2.0 Printing contents of current screen - wait for message to clear ARF:O AL.A~'K A, F'.O. Bi-X ANCHORAGE, ALASKA DATE' 8-28-90 REFERENC.'.E ' ARCO CASED HOLE FINAL~ ,/';.-'7 8-2-9C:, LEAK DETECTION/F'ROD PROFILE ,/i -9 8-i -"7'.¢.) F'RODUC'¥ION PROFILE ,/t-i6, 8-5-9A PRODUCTION PROFILE vi-i2 8.-4-9"3' LEAK DETECTION V-i .-- 2C) 8-4-9;3' F'RODLJCT I(]N F'ROFILE . "':, .-".~ o ,~ 8'- 5- 9"3' F'RODUCT.T. ON F'ROF" I LE .' -: "l ~k 'l .' · /7-33 8-i -4-o(') t.,L. L.L,=,R/' PERF ~/'7-34 8-26;-?':) COLLAF..'/PERF ¢?-.S 4 8-i 7 - 9"::) COL_LAR/F'E:RF ¢9-4i 8.-i'7'-':2¢;' F' E t:;.'. F F:ECORD ,¢9-42 8--i :.:.i -- 9 ,:.b GI:;:-C'CL JEWELRY ,/9 .... 42 8-i 8-9~ I:'ERF' RECORD ¢ i i '-- 7 8 - 'i 6 - '7 ¢) C 0 L L A R / P F R F ~ .-'l · ~/i :$.-- i ,3-.~ 1 --9~,) COLLAR ,¢ 3-t q-"~i -o,:~ VERTIL. OG ¢'i 3-5'. 8-3-9,:) F'RODtJCTION PROFILE Vi 4.-i 5 8-25-9,9 COLLAR/F'ERF ¢q~5.-i i 8-2-'7(:.;, DATAFRAC SURVEY 5-i3 8-3-9~ TEMP DECAY ¢'i 6-i i 8-t .-9¢ DIAC, NO$'i"IC FM F'LEA$;E SIGN RECEIVED BY AND RETURN THE ATTACI"IED COF'Y HAVE A NICE DAY! ;~TAL_I_Y HOFFECKEAAs~ RUN i, RUN i, RUN i , RUN i, R. UN i, RIJN i, RUi'.!i , RUN i, RUN i, RUN i , RLIN i, i:;:UN'1, RUN i , RUN i, RUN i , RUN i , RUN i, RUN i, RUN i, RUN i, AS RECEIPT OF DATA. i 5" 5" 5" 5" 5" 5" ... ~-i c:.:- ..., ,:::: · APPROVED ~" 'I'F:A N,S,' ¢ CAf~UO CAMCO CAMCO CA~'dCO CAMCO CAMCO A'i" L. A ~.' A 'TI_A '~ A i"L A ~' ~CH ~CH ~'CH C~MCO ATLAS C A M C 0 CAHCO D I $1'R I BUT I ON CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL F'HILLIF'$ F'B WELL FILE£' R & D ~ BF'X · ~ STATE OF ALAS'KA i'" TEXACO .. STATE OF ALASKA ~ ~'~ i'~ j' ,;:," ALASK.A(" '_ AND GAS CONSERVATION C(~ ,vllSSlON .-~ REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM At top of productive interval 1407' FSL, 1355' FEL, Sec. 13, T10N, R14E, UM At effective depth At total depth 951' FSL, 876' FEL, Sec. 13, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Strafigraphic 11055 feet Plugs(measured) 9540 feet 6. Datum of elevation(DF or KB) 78 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-5 9. Permit number/approval number 81-103/90-376 10. APl number 50 - 029-20626 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured 11019 feet true vertical 9513 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 110' 20" 300 sx PF 110' Surface 2597' 13-3/8" 400 sx PF & 2351 sx Fondu 2675' Production 9772' 9-5/8" 500 sx G 9850' Liner 1503' 7" 531 sx G 11050' True vertical depth 110' 2675' 8673' 9526' Perforation depth: measured 10158-10178'; 10191-10201'; 10211-10221'; 10228-10238'~ 10246-10266' true vertical 8905-8920'; 8929-8937'; 8944-8952'; 8957-8965'; 8971-8986' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tubing @ 9508' MD; 4-1/2", 12.6~, N-80, PC tubing @ 9571' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 9498' MD; 5-1/2", Otis RQY SS_.S.V_ @ 2156' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attached AUI3 ?- 9 1990 Treatment description including volumes used and final pressure ~Jask."a 0il & Gas Cons. Reoresentative Daily Averaae Production or In!ection OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 298 233 1109 -- 238 Subsequent to operation 32 2 225 -- 197 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations . 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 513 DCR c: J. Gruber, ATO-1478 SH DS 13-05 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER SHUT-OFF 5/26/90: MIRU CTU & Stimulation Equipment. PT Equipment to 4000 psi. RIH w/CT and washed perforations at: 10128 - 10148' MD Ref. Log: BHCS 8/9/81. 10158 - 10178' MD 10191 10201' MD 10211 10221' MD 10228 - 10238' MD 10246 - 10266' MD 10274 - 10280' MD 10290 - 10310' MD Pumped the following treatment: 59 bbls 12% HCI w/10% Xylene, followed by, 58 bbls 12-3% HCI-HF, followed by, 59 bbls 3% NH4CI. Displaced w/MethWater. POOH. RD. 5/27/90: RIH, & changed out LGLV's w/DGLV's. POOH. RD. 5/30/90: The Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 60 bbls cement, squeezing perforations: 10128 - 10148' MD Ref. Log: BHCS 8/9/81. 10158 - 10178' MD 10191 10201' MD 10211 10221' MD 10228 - 10238' MD 10246 - 10266' MD 10274 - 10280' MD 10290 - 10310' MD Placed 10 bbls of cement behind pipe at 3500 psi maximum squeeze pressure. Contaminated cement with Biozan, & cleaned cement out of wellbore. POOH. RD. 6/8/90: RIH, & changed out DGLV's w/LGLV's. POOH. RD. I I/27/89: Reperforated: 10158 - 10178' MD 10191 - 10201' MD 10211 - 10221' MD 10228 - 10238' MD 10246 - 10266' MD Ref. Log: BHCS 8/9/81. E ,¢EIVED AUG 2 9 1990 Nas~a.0il & Gas Cons, CommiSsio[~ Anchorage Returned well to production and obtained valid production test. A Fracture Treatment was performed in August 1990 (Apprvl # 90-559), and is reported on a separate Report Sundry. ARCO ALA%'KA, INC. P.O. BOX i,~"'5S6() ANCHORA(;E, ALA~'KA 99~i ¢~ DATE· 8--8-90 REF:ERENCE' ARCO CAS'ED HOLE F'INAL~: i-.,-':~ 6-n'....- 9¢;. . GR RUN. i i--..,.~': -';' -- .,~ ..¢'" '-- -- o .:~ ...... DI IAL P, IJRE.']' 'I'D'i---F' RUN S- S 8.- i - 9 0 F'E R F R E _'; 0 R O F;.: U N i · "~--.'3 7-23-90 F'ERF' RI.-ZCOF:D RUN i 4-7 7-'23-90 F'E:RF RE:CORD RLJN i 4-i 2 7.-'2S---':J,"'G PERF RECORD RUN i 4 - i ':.'.-.8 - :.:'¢ -- '!? ':) C 0 I... L A R / F:' I-'i: F;.'. F R LJ iH. 5'.-5 '7-2-9,:.~, F't--RF RECOI;.:D F,,'UN i I:-"' .. .. · .;.- t 4 '7- '2'7 -- 9 (9 i' lei: H F'/N 012' E R I IN i 6-;5 8- i -90 CC'L RUN ';"-.Z,S 6--2.4-9,:--) F'ERF RtECOF;:D RUN i i '5-5 6-i 6:.-9,::_) PERF RF'CC.~F(D F:UN i3--26 '?--28-90 TBr.; [;U'i"TEF;~ F;.'.I_:!ECORD RUN i 5-i 9 '7-i 8 .... 9() BRK-DOWN Tli.EMF' RI. JN PWDWi--2 '7 .... 2i--90 LEAl< i)E:Tr_-.;.CTION/I='I'f'~.: RUN i .... ~"~ · (3 ,- F'WDWi-2 ;-,..,:..-9 LEAK DETEC'f'ION./F'IT~7 F,'UN F'I...EAS'E .~'IGNAND I:~:I::']"LJF:.'.N ]"HE ATTACHI-ZD COPY A,S' RECFIPT (:iF DATA, REEE..IVEO HAVE A NICE DAY! /.~UG 10 1990ts'-~~. ~.__.,~,~/ I.-t 0 F F:' F' r': I<' F:' P Alaska Oil & Gas Cons. (.;o~¢t_t DZS'TRIBUTION -"- CIENTRAL FILES ~: I:'H ;[ I.-L l I:'~ 11' ,,'" CHEVRON F'B WELL D & M R & D ..~ ' '' I" "" " EXTENSION EXF'L JR~..,T I ON ~ BF'X '"' F-XXON :~- ~"¥A'T E OF" MARAI'HON 'FEXACO ~ MOBIL FILES ALASKA CAMCO ,?CH £..' C; H ;".; C H .~i: C i-.I $CI--i A T L. A t"ILS' ;S' C 1-.I ATL. A:";; HL.? ,E,' C H CAMCO C A M C 0 CAMCO STATE OF ALASKA ALASI~ .... ')ILAND GAS CONSERVATION ( MMISSION APPLIC I'ION FOR SUNDRY AluPROV Suspend Operation shutdown Re-enter S~l~n~led ~eli .... 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. Abandon Alter casing Repair well Time extension Stimulate X Change approved program Plugging Pull tubing Variance 5. Type of Well Development X.~ Exploratory Stratigraphic Service · 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM At top of productive interval 1407' FSL, 1355' FEL, Sec. 13, T10N, R14E, UM At effective depth At total depth 951' FSL, 876' FEL, Sec. 13, T10N, R14E, UM Perforate Other 6. Datum of elevation(DF or KB) 78 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-5 9. Permit number 81-103 10. APl number 50 - 029-20626 11. Field/Pool ,P~tl~e Bay Oil Pool 12. Present well condition summary z.,~r.,i["""~' ~ ~,,,U .... Total depth: measured 11055 feet Plugs(measur,~E ~_,v true vertical 9530 feet Effective depth: measured 11019 feet ~L ~ j~ ~-~; .~,~,~"~ trueve~ical 9513 feet Junk(measured) v,- ~;~O~t[~ Casing Length Size Cemented ~'" . '. ~""~Sured depth True ve,ical depth Conductor 110' 20" 300 sx PF 110' 110' Sudace 2597' 13-3/8" 400 sx F & 2351 sx Fondu 2675' 2675' Production 9772' 9-5/8" 500 sx G 9850' 8673' Liner 1503' 7" 531 sx G 11050' 9526' Perforation depth: measured 10158-10178'; 10191-10201'; 10211-10221'; 10228-10238'; 10246-10266' true vertical 8905-8920'; 8929-8937'; 8944-8952'; 8957-8965'; 8971-8986' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 9508' MD; 4-1/2", 12.6#, N-80, PCT tail @9571' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 9498' MD; 5-1/2" Otis RQY SSSV @ 2156' MD Description summary of proposal x Detailed operations program BOP sketch x 13. Attachments Date approved 14. Estimated date for commencing operation July1990 15. Status of well classification as: Oil ~ Gas __ Suspended 16. If proposal was verbally approved Sr. Area Operations Engineer Date Name of al)prover Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title FOR (;OMMI.~,~ION URI:: ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Original Sig~ed By David W. dohn§tor~ Approved Copy .L RetL~rned Approved by order of the Commissioner I Approval No.~ ~ Date SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 309 LBL cc: J. Gruber, ATO-1478 ~-~/vv i -o Drill Site 13-5 Zone 4 Fracture Treatment Preliminary Procedure Fracture treat DS13-5 as follows: I , . . , . . . MIRU fracturing service company. Pressure annulus to 3000 psig. Pump the propped fracture treatment in intervals: MD referenced to the BHCS log dated 8/9/81, using gelled water and Carbolite or LWP proppant at 45 bpm. Preliminary pump schedule is listed below. a. 300 bbls Pre-Pad 2350 bbl Pad. 1370 bbl Slurry at 1-12 PPG with 230,000 lbs Proppant. Flush to perfs. RDMO fracturing service company. Cleanout excess proppant to PBTD with CTU if needed. MIRU slickline to tag fill and replace gas lift valves. Place well on production. 6 5 4 2 ! 1 COILED 1UBINi3 UNIT BOP Ei)U l PHENi' 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYD~UL~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~ PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 RECEIVED ~UL 2,~ lg~ ~ ~.~,~ .Oij .& Gas C~ N]REL]NE BOP EOU]PHENT 1. 5000 PSI 7" WELLHEAD CONNECIOR IrLANG! 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) .1. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF AF;::]:3 AL. A3'KA, ];NC.,. ' F' ,. 0 ,. BOX t ..'D .:} ;~ 6 ;:,,' ANCHORAGE: ALASKA '~':;'~'i,, _, (".,_ DATE' 5i25190 REFE:RE:NCE' ARCO CASED HOLE F'INAL..2 4 '7 i :~ ~ -- "'" 0 ('0 .,' .~' ~ · . ~ .-:? 5- 7-9 ~.-'.~ _;'~' -" ';.~ =~',. _, i,:.°- i ;5-~ic''_ , 5=25 i '->-i,:. ;5- e ;:,...~ .... · .-.,- ,-i t ~-q";":" 6-i 8 5--6-9~.D 7-4 i 'z 5 - i c~ .. 9 ,'-~ :=! .. . ,.: 9-.- i..~8 5-4-9(-} i S'~.'- 6 5-7-9A i S-'.S i '~,-- c, :~- S.- 9(:.~ :.. · ....' ,, i S,-i~ '~ 5-3-°-- ~'',.. ... i 5-29 5- 5- 9 c?.' i 4--6 4-'-29-9~D i' 7-- i,.. ~ 5--'",:.- c.(~,. i 8'-7 5-4-96, RECEIVED ];N,JECTION F:'R(]F']: L.E TEMF' ,. G/R TVI) BFIC A(.','CJLJ., G/P.. TVD COidF',. NEUTRON G/F.: i"VD DUAl...I:NDUCT;rON G,/R F'RODUCTiON F'F;:OF' l LE F' ['"' F,' f-" F~'.ECORD STATIC TEifiF' F'tJHP- 1;N TEHF' F' F.: 0 D tJ C T I (] N F' R 0 F :[ I_ F: l N ..I E C 'f' I 0 N P F;.'. 0 F ]: L E F' I';..' 3 D, F' F;.: 0 F: I I_ E F' I T 2." F' R 0 I) U C T I 0 N. F" F;.'. 0 F:' Z L E:' F' F;: 0 D U C '? I (3 N F' I;..' 0 F:' I L E L. EAI< DE:'TIECTI ON F'l. JIdl:"- Z N TEMF' RUN t, RUN RUN i, F;,' U N i, R U i",~ i , RUN i , 5' RUN i , 5" F;,'UN t , 5" RUN 1, ':',.' F;:UN i , 5' RUN i, IS" RUN' t, 5' RLIN RUN i: S ' RUN i, 2"&5:" RUN i, 5' CAMCO C A H C (] A 'f' L.A ,':.;.' A'f'LA~ A r L. A37 CAMCO SCH C A i"-'i C 0 CAMCO CAMCO CAMCO (]AMC(] CAMCO CAMCO C A M C O CAMCO F'I...EASE..~IGN AND RETURN THE ATTACHEI) C. OF'Y AS RECFIPT OF DATA,, RECEIVED BY HAVE: A NICE DAY! SALLY HOFFECKER A'¥O- i 529 · " '" ""C' I~' ~-~FF RuVE '¥1;,'AN S:~ 9 ¢2 (-.)(D !)ISTRIBUTION ~ CENTRAL FILES ~"~ CHEVRON D&M ~: EXTENSION EXF'LORATION = EXXON MARATHON ~ MOBIL ,.-""F' H ! I_ L :[ F' $ F:'B WE:L.L_ F:'IL.E:,S' R & D ~ BF:'X -" " V'T'A'T'E OF ALASKA TE-'.XACO STATE Of ALASKA ALAS.'~'' ,)ILAND GAS CONSERVATION( MMISSION APPLICATION FOR SUNDRY Ar'PROVALS Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance Perforate X Other 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM At top of productive interval 1407' FSL, 1355' FEL, Sec. 13, T10N, R14E, UM At effective depth At total depth 951' FSL, 876' FEL, Sec. 13, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 78 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-5 9. Permit number 81-103 10. APl number 50 - 029-20626 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11055 feet Plugs(measured) 9540 feet RECEIVED Effective depth: measured 11019 feet MAY 1 8 1990 true vertical 9513 feet Junk(measured)~,,~,,~., & Cons. Uommlssl ll Casing Length Size Cemented , , r.~l~J, li~{~~ depth True vertical depth Conductor 110' 20" 300 sx PF 110' 1'10' Sudace 2597' 13-3/8" 400 sx PF & 2351 sx Fondu 2675' 2675' Production 9772' 9-5/8" 500 sx G 9850' 8673' Liner 1503' 7" 531 sx G 11050' 9526' Perforation depth: measured 10128-10148'; 10158-10178'; 10191-10201'; 10211-10221'; 10228-10238'; 10246-10266'; 10274-10280'; 10290-10310' true vertical 8883-8898'; 8905-8920'; 8929-8937'; 8944-8952'; 8957-8965'; 8971-8986'; 8992-8996'; 9004-9018' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tubing @ 9508' MD; 4-1/2", 12.6#, N-80, PC tubing @ 9571' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 9498' MD; 5-1/2", Otis RQY SSSV @ 2156' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation June 1990 16. If proposal was verbally approved Oil X Name of approver Date approved Service 17. I hereby certify that the for_..egoing is true and correct to the best of my knowledge. Sic]ned Title Sr. Area Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test.. Subsequent form required 10- 15. Status of well classification as: Gas __ Suspended Date . Approved by order of the Commissioner Form 10-403 Rev 06/15/88 382 DCR cc: J. Gruber, ATO-1478 ORIGINAL SIGNED BY P1(13-S)W1-3 Commissioner Date :~".-~.l .-¢:::~0 Approved Copy Returned SUBMIT IN TRIPLICATE DS 13-5 Non Rig Workover Water Shut Off Work Scope Workover Obiective · Repair a confirmed channel down to the aquifer. I · · Make a slickline tag to verify PBTD. Obtain production test. Acid wash the perfs and channel. Obtain second well test. · · Perform a high pressure (3000 psi) squeeze with 60 bbls of cement to isolate the perforations from 10128 - 10310 (BHCS). Reverse out the contaminated cement. · Spot TEA accelerator across perforations. Reperforate after 4 days as follows: Zone Perforations (BHCS) 4 10158 10178 4 10191 10201 4 10211 10221 4 10228 - 10238 4 10246 - 10266 Other Well Information Current status: Producing. Expected static bottomhole pressure: 3800 psi. @ 8800' SS Expected fluid in wellbore at reperforation: seawater. REQ'EIVED MAY 1 8 1990 Alaska 011 & Gas Cons. Commission AnchOrage ,5 4 2 COILED TUBINg UNIT BOP Ei)U 1 PHEN~ 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3, 5000 PSI 4 1/6" HYD~UL~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX H]RELINE BOP EOUIPHENT 1. 5000 PSI ?" W[LLHEA~ CONNECTOR FLANGE 2. 5000 PSI WIRELIN£ RAKIS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF F' .: 0: .,7..-: (.)X i ,.'-},:.'-'.., 3,5,'3 A N C i-! 0 i'-'.: A G IE, A i_ :'::~ 5,'K A c'c:CC'ENCE' ARCO PRESSURE DATA i '- t A i i _.,_".7 ~,=' _ ,.,.q c,,, B t'4 ,i:' .--~ -- ! : ..--~ ~ ~-~0-8o ~I.-IF" 3--'7 i 2 - 4 -- 89 B H F:' Y--fO i i-25-89 BHF' 4-2i i i --24-89 BHP 7 .-5 ~ 27 - 89 B 14 F' · i 2: - _5: i i - 2 '4 - 6-,' 9 B I..i P i 3-9 i 2--i 6-89 BI-IF' · -.. ,--! ,--~ __ i ,~--.,:... i.o i ~,-:=~9_ . BHF' i 4-i S i .~.:-,.--:.,, i 4-2','" i,~"'"-i 7-89 i4"-...'5i i 2-4-89 i a, -. 36 i ,._'-"-- i 6--89 --.";']'ATiI"::GRAD ..... S'T A'i' I C': f'-RA D --- 5' T A 'i' ]; C C i"4 A D --:":.' TAT I CGRAD ...... STA'T]-'C GRAD .... 5"T A 'r :[ C.. C-R A D .... 5.' ]"A '1" :1: C g F,' A D · --2*TAT !C C-RAD -.- S 'I" A "I" :r C GF;:AD B H F .... 5' "1' A T I C C; R A D BHF ....S'TATIC GRAD BI-IF: ..... STA'T.[C GRAD BHF: ..... STATIC'. GRAD lENT .[: E N T Z E N 'f' I E N'T I ENT I E N"I- ]: E: N T :[EN i' ZEN]' I EN'f' I EN'T i' E N T ]: E N T CAMCO CAMCO CAMCO CAMCO CAMCO C A ['! C 0 C: A H C O C A i''i C 0 CAMCO C A ~ C (] CAMCO C A M C 0 C A M C 0 PLEASE SIGN AND I:;,'ETUF,:N THE ATTACHED Rt!:':CE I VED BY ~~ HAVIF.. A NICE DAY, RECE~X~.20 :'=..' A L. l. Y HOFFECK r..!:R A",'O-t 52? FEB 1 ~ 1990 AlaSka Oil & 6as ConS, AnchOrage ~ ~ ZTR ~ BU~' COF'Y AS I';~ECEIF'T OF APF'ROVED .~. .... ]'RANS.'.~ 90(~'6S D A 'i" A., CENTRAL FILES CHEVRON D&M . EXTENSION EXF'LORATION EXXON,, MARATHON' " MOBIL F'I4 lt_LZ F'S F'B WELL R & D BF'X STATE OF T I!:' X A C 0 F:' ]: LES AI_A,S'I< A STATE OF ALASKA ALASKA _~ AND GAS CONSERVATION C_q" fISSION 0 ~ I G I APPLICA' ,ON FOR SUNDRY APPROVALS I. Tyke of Request: Abandon Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM At top of productive interval 1407' FSL, 1355' FEL Sec. 13, T10N, R14E, UM At effective depth At total depth 951' FSL, 876' FEL, Sec. 13, T10N, R14E, UM Operation shutdown Plugging Pull tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) 78' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-5 9. Permit number 81-103 10. APl number 50 - 029-20626 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary i'(' ('" F Total depth: measured 11055 feet Plugs(measured) ,, . ~i~ :. true vertical 9530 feet u Effective depth: measured 11019 feet .... ';-: ..... · true ve~ical 9513 feet Junk(measured) :'..~,':.,....~',~'.~ .... C~ ~:~" GaS Cv~S,.""~ Casing Length Size Cemented Measured depth~l~~rtical depth Conductor 110' 20" 300 Sx PF 110' 110' Sudace 2675' 13-3/8" 400 Sx PF & 2351 SX Fondu 2675' 2675' Production 9850' 9-5/8" 500 Sx G 9850' 8673" Liner 1503' 7" 531 Sx G 11050' 9526' Perforation depth: measured 10128'-10148'; 10158-10178'; 10191'-10201'; 10211'-10221'; 10228'-10238'; 10246'-10266'; 10274'-10280'; 10290'-10310' true vertical 8883'-8898'; 8905'-8920'; 8929'-8937'; 8944'-8952'; 8957'-8965'; 8971'-8986'; 8992'-8996'; 9004'-9018' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tbg @ 9508'; 4-1/2", 12.6N, N-80, PC tbg @ 9571' MD Packers and SSSV (type and measured depth) BOT 3-H pkr @ 9498' MD; Otis RQY SSSV @ 2156' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X Date 14. Estimated date for commencing operation December, 1989 16. If proposal was verbally approved Oil X Gas Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~~,,.o-~ ~ ~-~--'.,~,¢~ Title Operations Engineering Manager FOR COMMISSION U~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- /~ ORIGINAL SIGNED BY LONNtE C, SMITH 15. Status of well classification as: Suspended Approved by order of the Commissioner ,[_A,,p proval No. , .,,.,~.o,~ea ~"-' Commissioner Date //¢:~" '~"--~)/~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL 13-5 SAG RIVER PERFORATING PROCEDURE 1. MIRU ELU and test lubricator. 2. Flow well on artificial lift to achieve drawdown. , Perforate the Sag River interval 9992'--10024' MD (Ref. B HCS 8/9/81) at 4 SPF. 4. RD ELU. 5. Test well. 2. 5000 ~,~ ~k~ ~ (v.,~r~.[ S~,[) 4. SO00 PSi 4 l/e,- ri. Ow T~I[ P~C-~r ARC:: ~I_~$KA, INC F'.O. BOX i (30.S6() ANCHORAGE, ALASKA DATE' 2-i5-89 REFERENCE' ARCO PRESSURE DATA '~-'~ i - i i -89 ~-i 7i i '~-i 8-88 4-i 8 i 2-t 'S'-88 4 '-' '-~ '~'i -88 · -'4 i --.' 7-3~, i '-'-' ~.; i 7-88 9-i "i i-24-88 9-i i-iS-89 9-4 i 2-S,:'}-88 9-4 i -i =~-8c~_; , 9-'S i i..'~"-S'~-88 9-712 i i-24-88 t i -i 5 i -!'-89 i2-9 i -'7-89 t 2- i i i '2- i '?-88 iS-S 2-i-89 i 4--S'7 t -Si -89 i4-S8 i-Si -89 i 4-4~ i -271--89 i 8-i S i..'~- '3-88 i 8-i 5 i 2-i -88 F'WDW2-i i-i 9-89 BHF'--FLOWi BHF'--FLOWI BHF'--$TATI BHF'--$TATI BHF'--FLOWI NG GRADIENT NG GRADIENT C GRADIENT C GRADIENT NG GRADIEN'T BHF'--FLOWING GRADIENT BHF'--SI'AT IC GRADIENT BHF'--FLOWI NC- GRADIENT BHF'--STAi' I C GRADIENi BHF'--F'LOW I BHF'--STAI' I BHP--STATI BHF .... FLOW I NG GRADIENT C GRADIENT C GRADIEN¥ NG GRADIENT BHF'--FI_OW I NG GRADIENT BHF'--STATIC GRADIENT BHP--$TATIC GRAD IEN'IF BHF'--STATIC GRADIENT BHP--$TATIC GRADIENT BHF'--STATIC GRADIENT BHP--$'I'AT I C GRADIENT BHP--STA'r IC GRADIENT PI_EASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT CAMCO CAMCO 0 T I $ OTIS CAMCO CAMCO CAMCO CAMCO OTIS C ,.':~ M C 0 C~:~MCO CAMCO CAMCO OTIS OTIS 01'l$ ~ 'l' I S CAMCO CAMCO CAMCO OF DATA~ RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 'fRANS ~8907~ AF'F'ROVED __ _, FEB 1 6 i.589 Cons. Ccmmissioa Anohorag~ ¥~TRIBUTION CENTRAL FI'LE~.f~. CHEVRON' D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL '"' F' H l L L I F' S 'Ir F'B WELL FILES ¢ R & D ~ SAF'C ~ STATE OF ALASKA ~ TEXACO THE CORRFC'f'EI) AF:'I:~: FOR THIS BHF' RE:PORT IS 5.¢~-()29-2t5(-)8. ARCO Alaska, Inc. ~, Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 17, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-5 Approval No. 8-387 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 13-5)W1-3 Naska 011 & Gas Cons. Commission ,,-~ Rnch0rage WELLS/106 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C '~ STATE OF ALASKA I~ ALAS ,-, OIL AND GAS CONSERVATION COM ,,oSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown - Stimulate i( Plugging -' Perforate -- Pull tubing ' Alter Casing i2 Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage~ AK 99510 4. Location of wellatsurface 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM 5. Datum elevation(DF or KB) 78' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 13-5 Feet At top. ofproductive interval 1407' FSL, 1355' FEL, Sec. At effective depth At total depth 951' FSL, 876' FEL, Sec. 11. Present well condition summary Total depth: measured true vertical 13, T10N, R14E, UM 13~ T10N~ R14E~ UM 11055 feet 9530 feet Plugs (measured) 8. Approval number 8-387 9. APl number 50-- 029-20626 10. Pool Prudhoe Bay Oil Pool Effective depth: measured 11019 feet true vertical 9507 feet Casing Length Size Junk (measured) Cemented Measured depth True Vertical depth Surface 110' 20'' 300 Sx PF 110' 110' Intermediate 2597' 13-3/8" 400 sx PF & 2675' 2675' Production 9772' 9-5/8" ~lsxSX'~gndu 9850' 8673' Liner 1503' 7" 531 Sx 'G' 11050' 9526' Perforation depth: measured true vertical 10128-10148'; 10158-10178'; 10191-10201'; 10211-10221'; 10228-10238'; 10246-10266'; 10274-10280'; 10290-10310' Tubing (size, grade and measured depth) 5½", 17#, L-80, PC tubing @ 9508'; 4~", 12.6#, N-80, PC tail @ 9571' MD Packers and SSSV (type and measured depth) BOT 3H Packer @ 9498' MD; Otis RQY SSSV @ 2156' MD 12. Stimulation or cement squeeze summary R 8883-8898'; 8905-8920'; 8930-8937'; 8945-8952'; 8957-8965' 8971-8986'; 8992'8996'; 9003-9018' Intervals treated (measured) See attached Treatment description including Volumes used and final pressure Alaska Oil & Gas Cons. Commission ., ~..n.~hnrn@e 13. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1704 831 901 -- Tubing Pressure 300 Subsequent to operation 2075 1501 1077 280 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~'~//J~..'~~~.~. Title Operations Engineering Manager Form 10-404 Rev. 12.1-85 WELLS/106 T. P. Allen, 263-4837 Date . Submit in Duplicate¢ Drill Site 13-5 Description of Work Performed TREATMENT: OBJECTIVE: TREATMENT DATE: 1. 10. 11. Amine Phosphonate Scale inhibitor Treatment To Scale Inhibit Zone 4 and the Top of Zone 3 May 23, 1988 Obtained capacity of well prior to this treatment. 2. Obtained a produced water sample from this well and analyzed for PH and the ions present. 3. Performed a fluid level survey on the 5-1/2" x 9-5/8" annulus and loaded the annulus with 70 bbls of dead crude and 4 bbls of diesel. 4. Loaded 50 bbls of filtered fresh water for blending the EDTA. Loaded 105 bbls of filtered 2% NaCI water for blending the amine phosphonate scale inhibitor. 5. Mixed 2000 gals. (48 bbls) of filtered fresh water adding: -1550 lbs of Na2EDTA -4 gals of surfactant -2 gals of corrosion inhibitor Checked pH, iron content, and EDTA content. 6. MIRU pump trucks and transports. 7. Pumped the following fluids down the production tubing: A. 4 4 bbls EDTA w/additives B. 105 bbls Amine Phosphonate Blend C. 600 bbls Diesel D. 2 3 0 bbls Dead Crude E. 5 bbls Diesel 8. Shut in well for 12 hrs. RD and released equipment. 9. Returned the well to production following the 12 hour shut-in period. Obtained the capacity of the well. Following the treatment, a second sample of produced water sample was taken and analyzed for PH and the ions present. '"' I::'1..I T! I T I::' ~'' I::' T:~ I.,.I I:EI ! 1::' T 1 I::' ;':.' I:~.' ~., T~ :II: $~ f~ I::' f': ':: '~ .~'..' 'T' -P., 'T' !::' f'l I:' ~ I (.'~ S: I(' ~..', .:Ii: 'T' I? ':.':.' r:~ (': f'l T) T 5: 'i" t:;: T I':.:1 t'T' T ARCO Alaska, Inc. ~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager Hay 12, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-5 Permit No. 81-103 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp At ta chment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 13-5)W1-3 WELLS/A~0c~ Alaska, Inc. is a Subsidiary of AflanticRichfieldCompany AR3B--6132-C I~' STATE OF ALASKA ~lll~ ALAS A OIL AND GAS CONSERVATION COM 'oSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program [] Plugging [] Stimulate ~ Pull tubing ~ Amend order ~ Perforate rq, Other 2. A~e 2s , a,t o n c. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM ¢Z[(¢~1~ ofproductive interval FSL, 1355' FEL, Sec. 13, T10N, R14E, UM At effective depth At total depth 951' FSL, 876' FEL, Sec. 13, T10N, R14E, UM 11. Present well condition summary Total depth: measured true vertical 11055 feet Plugs (measured) 9529.7 feet 5. Datum elevation (DF or KB) 78' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 13-5 feet 8. Permit number 81-103 9. APInumber 50-- 029-20626 10. Pool ;'i~: PrudhQe ,Ba~'~Oil Pool Effective depth: measured 11019 feet true vertical 9507 feet Casing Length Size Cemented Measured depth True Vertical depth Surface 110' 20" 300 Sx PF 110' 110' Intermediate 2597' 13-3/8" 400 sx PF & 2675' 2674.9' Liner 1503' 7" 531 Sx 'G' 11050' 9526' Perforation depth: measured 10128-10148'; 10158-10178'; 10191-10201'; 10211-10221'; 10228-10238'; 10246-10266'; 10274-10280'; 10290-10310' true vertical 8883-8898'; 8905-8920'; 8930-8937'; 8945-8952'; 8957-8965' 8971-8986'; 8992-8996'; 9003-9018' Tubing (size, grade and measured depth) 5~", 17#, L-80, PC tubing @ 9508'; 4½", 12.6#, N-80, PC tubing @ 9571' MD Packers and SSSV (type and measured depth) BOT 3H Packer @ 9498' MD; Otis RQY SSSV @ 2156' MD 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation May 1988 14. If proposal was verbally'approved, Name of approver Date approved 15. I hereb~,-~ertify ~/a,~the~re~ng is true and correct to the best of my knowledge Signed ~¢-~~// ~/'~,~~.~--~ Title Operations Engineering Manager Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance A, pproved Copy ~-, ,. .,--'-h ~ / ,¢' Returned Approved bye/~, (. /¢~ Commissioner Form 10-403 Rev 12-1-85 w'g~rc'~/l'06 rT. ?/. Allen, 263-4837 I Approval No. ~ .~.,%"'2f ¢ the commission Date ~,~ SuJCmit ir¢ triplicate~ Drill Site 13-5 Stimulation Treatment ARCO Alaska, Inc. proposes to perform the following scale inhibition treatment: 1. Obtain a valid well test. 2. Obtain a produced fluid sample. The sample should be taken to central lab and the water phase should be analyzed for PH and the ions present. 1 Perform a fluid level survey on the 5-1/2" x 9-5/8" annulus and ensure that the annulus is fluid packed. 1 Load 50 bbls of filtered fresh water for blending the EDTA. Load 105 bbls of filtered 2% NaCI water for blending the amine phosphonate scale inhibitor. 5. Mix 2000 gals. (48 bbls) of filtered fresh water adding: -1550 lbs of Na2EDTA -4 gals of F75N, NE-18 or Losurf 300 -2 gals of A186, CI-9 or MSA Check pH, iron content, and EDTA content. 6. MIRU pump trucks and transports. 7. Pump the following fluids: A. 4 8 bbls EDTA w/additives B. 109 bbls Amine Phosphonate Blend C. 600 bbls Diesel D. 2 3 0 bbls Dead Crude E. 5 bbls Diesel 8. Shut in well for 12 hrs. RD and release equipment. 9. Return the well to production following 12 hour shut-in period. 1 0. Obtain the capacity of the well. 11. Following the treatment, produced the well for approximately a week and obtain a second produced fluid sample. The sample should be taken to central lab and the water phase should be analyzed for PH and the ions present. ~~ ~-22-B~ PR.PRFL..E/FM/TP/FD/U ~UN ~, ~ '~ v AAMCO ~~t-2t-~8 PRD.PRFLE/FH/TP/FD/M RI.IN ~~-DG-88 PR'D., PRFL D/HPFM/TFHF'/DFN RIIN ~~ ~-2e-88 PRD.PRFL. E/HPFM/TEMP/DEN/WHIIT RUN ~, 5' ~AM:D ~/2-4-88 PIT,~/GR/TEMP RLIN ~, 5' ~AM~D ~~ t -24-BB PRO. PRFLE/HPF,/UHL~T, Oil & Gas Cons. Oommis:'.CRUN t, 5' CAMCO t -23-BR F'RD, PRFL. E/HPFM/WH[[f~R ~chorage RLIN ~~i-22-B8 PRD,PRF[.[/HPFM RUN ~, 5' CAMCO -27-88 PRD.PRFLE/$PIN/TEMP/~HLIT RUN ~, 5' CAMCO .-25-8~ INJ.PRFL~/FM/TP RLIN ~ , 5' CAMCO ~ o-~ -/, ~,.8-88 INJ PRFLE/HPFM/T~MF' RLIN ~ , 5 CAMCO ~ ~-~9~-~-B8 PIT~/TEMF' RUN ~, 5' CAMCO F'R~. PRFL. E/SP I N/'" ~"', ~., ,,. ,~ ¢ ""' u U T ,..,.,, ~ ~, RUN PEGGY BENNET ::~:&ui,~':'~-- ' ' ~To-~ S~, / ~~ f~ ~/4~ APPROVED 1~ ............. Z-- ~/ ~ ~ ~ '- - '~' -- ' ....... _'_ _ C F~LE~ CENTRAL . "~" . . "':"' . EXTENEION EXPLORATION . EAFC ~ ~ / ~ EXXON ~ .~TATE OF AL. ASFA ' / MARATHON ~ TEXACO ~ / ARCO AI_A~KA, INC, '~ii'' P,Oo BOX tOe~60 ANCHORAGE, ALASKA 995t0 DATE: 2-t 6-88 REFERENCE: ARCO CA.TED HOLE FINAl. t -4 t -22-88 t -t 3 t -22-RR t-~ 6 t-2~-88 i -t 9 t -2G-88 t -23 t -2G-88 i -23 i -24-88 4-7 2-4-88 4- t 8 2-3-88 4-22 i -29-88 ?- ~ ~ 2-5-88 9-34 ~ -23-88 t t-t 8 i-~0-88 t 3-i t-24-88 i -2~-88 t3-i7 i-23-88 i 3-28 i -22-88 t4-22 t -27-88 t 6-2 i -25-88 t 6-5 t -28-88 t 6-t 9 2-t -88 t 6-i 9 t-28-88 t 6-20 t -29-88 i 7-2 t -3t -88 t 7-8 t -25-88 i 7-i G t-25-88 PI. EAS'E ,~ RECEIVED HAVE A N PR ,, PRFI...E/FM/TP/FD/W Fl. OWMETER PRD ,, PRFLE/FM / TP/FD IW PRO., PRFL F/HPFM/TFMF'/DEN PRD~PRFI_E/HPFM/TEMP/DEN/WHI.IT P .l' T..~/TEMP P .'[ T,.~/GR/TEMP PIT,~ P .T. T,~/TEMF' PIT,~ FI_OWMETER. PIT~.~/TEMP PRD ,, PRFI..E/HPFM/WHI.IT PRO, PRFL. E/HF'FM/WHIlT /GE' GAMMA RAY PRD. F'RFL. E/HPFM PRD ~, PRFI..E/$P .I N/TEMF'/WHUT INJ ,, F'RFLE./FM/TP I NJ , PRFLE/HPFM/TEMP PITE/TEMF' PR. ODUCTI. ON PROFILE PRO , PRFI..E/,.~F'IN/TEMP/GR/WHUT F'RD ,, PRFL. E/HF'FM/GR/WHUT I N,..I., PRFI.. E/HPFM T_NJ, PRFLE/HPFM RI.IN RI IN RI.IN RI. IN RI.IN RI. IN RI.IN RlIN RI.IN RI. IN RI.IN RUN RI.IN El. IN RI.IN RUN RUN RUN RIlN RUN R. tJN El.IN RUN RUN RECEIPT OF DATA.. OAMCO OAMCO CAMCn CAMCO CAMCO CAMCO CAMCO CAMCO CAMCfl CAMCO CAHCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO PEGGY BENNETT ATO-tS,.9 TRAN~ ~88t85 APPROVED DISTRIBUTION "' CENTRAl_. FII_E,~ ~ . · ,.""CHEVRON D & M ~. EXTEN,~I ON EXPLORATION ~'~. EXXON MARATHON ~' MOBIl_ "'.,,-PH I1..I.. IP,~ PR WELL F.T.I.E,~ R & D ~ ,~AF'C ~, ,.~TATE OF AI..AS'KA ,,~ TEXACO ARCO Alaska, In( Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 24, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-5 Approval No. 7-424 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/jp Attachment cc: Standard Alaska Production Company P1 (DS 13-5)W1-3 detailing work RECEIVED SEP 2 8 1987 Alaska Oil & Gas Cons. Commission Anchorage WELLS/~ Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ~ STATE OF ALASKA " AL~, ,<A OIL AND GAS CONSERVATION cOt~...AISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other ,~1 2. Name of Operator ARCO Alaska, Inc. 3. Address P_ ~. gn~ ]~60~ Anchora~e~ AK 99510 4. Location of wellatsurface 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM 5. Datum elevation(DF or KB) 78' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 13-5 Feet At top of productive interval 1407' FSL, 1355' FEL, Sec. At effective depth 13, T10N, R14E, UM At total depth qB1' FSL= g76' FEL: Sec. 13, T10N? R14E, UM 11. Present well condition summary Total depth: measured 11055 feet true vertical 9529.7 feet Plugs (measured) 8. Approval number 7-424 9. APInumber 50-- ~2q-2~626 lO. Pool Prudhoe Bay Oil Pool Effective depth: measured 11019 feet true vertical feet 9513 Casing Length Size Structural Conductor 110 ' Surface 2675' Intermediate Production 9850 ' Liner 1503' Perforation depth: measured Junk (measured) Cemented Measured depth True Vertical depth 20" 300 Sx PF 110' 110' 13-3/8" 400 + 235 Sx 2675' 2674.9' 9-5/8" 500 Sx 'G' 9850' 8672.6' 7" 531 Sx 'G' 11050' 9526' 10128-10310' (8 .intery~l~) true verzlca~ 8883-9018' (8 intervals) ~bing (size, grade and measured depth) 5~", 17#, L-80, PC tubing @ 9508'; 4½", 12.6#, N-80, PC tubing @ 9571' MD Packers and SSSV (type and measured depth) BOT 3H Packer @ 9498' MD; Otis RQY SSSV @ 2156' MD EECFIVED 12. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure SEP 2 8 1987 Alaska 0ii & Gas Cons, C0mmissi0ri Anchorage 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 2940 1764 60 3020 1812 211 600 600 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 2¢/¢p.~--~~~--~ Title Operations Engineering Manager Date y.,., .~z//~ ~, Form 10-404 Rev. 12-1-85 WELLS/106 P. V. Lantero, 263-4312 Submit in Duplicate~ DRILL SITE 13-5 EDTA MATRIX TREATMENT On 7/11/87, the following treatment was performed on DS 13-5: 275 bbls Na2EDTA w/additives 10 bbls diesel with 5% EGMBE 235 bbls dead crude The well was shut in well for 12 hours following the treatment. RECEIVED Anchorage WELLS/106 ARCO Alaska, Inc( Prudhoe Bay ,-'ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 25, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-5 Permit No. 81-103 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/jp Attachment cc: Standard Alaska Production Company Pi(DS 13-5)W1-3 WELLS/106 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALA ..,-~ OIL AND GAS CONSERVATION CO ...,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing F~ Time extension [] Change approved program [] Plugging [] Stimulate ~' Pull tubing [] Amend order [] Perforate © Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of wellatsurface 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM 5. Datum elevation(DF or KB) 78' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 13-5 feet At top of productive interval 1407' FSL, 1355' FEL, Sec. At effective depth 13, T10N, R14E, UM Attotaldepth 951' FSL, 876' FEL, Sec. 13, T10N, R14E, UM 8. Permitnumber 81-103 9. APInumber 50-- 029-20626 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 110 ' Surface 2675 ' Intermediate Production 9850 ' Liner 1503' Perforation depth: measured 10128-10310' (8 intervals) true vertical 8883-9018' (8 intervals) Tubing (size, grade and measured depth) 11055 feet Plugs (measured) 9529.7 feet 11019 feet Junk (measured) 9513 feet Size Cemented Measured depth 20" 300 Sx PF 110' 13-3/8" 400 + 235 Sx 2675' True Vertical depth 110' 2674.9' 9-5/8" 500 Sx 'G' 9850' 8672.6' 7" 531 Sx 'G' 11050' p52.6..' i;: i; 'ii I) 5½", 17#, L-80, PC tubing @ 9508'; 4~"~ , 12.6#, N-80, PC tubing @ 9571' MD Packers andSSSV (typ_e_a. nd measur.edRQydeOth)sssv BOT 3H Packer @ 9498' MD; Otis @ 2156' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation July 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that, the foregoing is true and correct to the best of my knowledge Signed ,(~~~~ Title Operations Engineering Manager Date Conditions of approval Approved by Commission Use Only Notify commission so representative may witness I,~provaINo. ......... ..~.~~9~/:, [] Plug integrity [] BOP Test [] Location clearancel~.~i.~;~u,~.~~ ,~,,~.' :,.:., .:,:.!. ::,,,. ,,..,~,: ,- !¢;.: ~:~"-.~0 ,~/~ by order of Commissioner. the commission Date Form 10-403 Rev 12-1-85 WELLS/106 P. V. Lantero, 263-4312 Submit in triplicate DRILL SITE 13-5 EDTAMATRIX TREATMENT JUSTIFICATION AFE #699012 PROPERTY CODE #2120658-13 · e . Obtain a valid well test. Pump the following: 11,600 gals of Na?EDTA w/additives 10 bbls of diesel-with 5% EGMBE 235 bbls of dead crude Shut in well for 12 hours. Return well to production and obtain well test at same FTP as the pre-treatment test. WELLS/106 ARCO Ataska, Inc, F',O. Box i0(~360 -.'~ Anchorage, A[as.ka" 995 t ~) DATE: June t2, t787 REFERENCE: ARCO F'ressure Data ~t3-2A 5-t9-87 Static BHP Otis ~t3-5 5-t&-87' Static BHP Otis ~t3-8 5-t7-87 Static BHP Otis ~t6-7 5-t-87 Ftowing/PBU/$tatic Gradient Camco I:'[ease sign and return the attached copy as receipt of data, Recei red By. HAVE A NICE DAY! ~osan n~ Peek ATO-'. t 529 TRAN$ ~87304 Approved_ DISTRIBUTION Cen't'~" .., I. Fi les' Chevron ~ D & M Extension Exploration '"" E x x Ol'l '1~' Marathon ...'"' Mob i L Phi llips PB Well,Fi les R& D 3oh io State of Alaska Tex~SCO AR(:;(.'). A I.a.~ka, Inc F:' ,. 0 _. Box Anchorage, A L a.~'k a D A T E · I::'e b ~" u. a 'c ¥ '1 '7, 't 9 8'7 R E-" F I::: R E N C E:: A R C 0 M a ..el n e 't' i c '¥ a p e.~ w / I. i .s' '{' i n g · .',~-)(. ':~ ..~.- 5; 7- 2 (.).... 8 ~: M a g -I: a p e ~: E C C 2 2 (.)7 F' D I< .... -i (.> c:'~ i> ~'- e_?.s' C e n 't' ~" a I. F:' i I.e.~ o n I. y ........ t' h i .'.~' 't' a I:~ e i s' 't' h e ~.~' a m e a s' F' D K .... i (-) ~ d a 't' (-'-, cl 8.-- t 5-.- 85: · 1:.., TM "" 5 'l 2 .... 'i o, .... ,.,° ~.,'~' Pi a cj -I.. a p e I.':' ....... f': ~'": :II: 258 'i F:' D K .... '1 e, 0 R I:!i D 0 N E D 'c' e :;' ~.~' F' I. e a .'..~ e ? i g n @ n d r e 't' u'r n -I: h e a 't' 't a c h e d c o p ¥ ~':~ .'..;' r' e c e i p '1: o 'f' d ,':~ 't' a., I:;,:eceivecl By .............................................................................. I.-IAVE A NIC'.E DAY! A'TO- ~ 529 'T'F::Ai'-J.S' ""8'7C?~c'~... A I::' i:~' ¥' 0 v e d ............................................................................................ C e ~'~ .1: ~-- @ I. F:' i I.e.'..~' C h e v r o 'n D & H F'., M c F' h e e 't' e ~" .'..~' Iii: x x o'n M a 'c a 't' h o n Mol:) i I. .110 · .. I::'h i I. Lip ~' F:'B WeLl. F:'i I. es' F.'. & D ,11. '.:.~ ',,' ,.:. 0 h i o .,..". ,.,..'." .t: a .I.. e c)'f' A L a ~' k a Te x a c o i"! ¢., V E ~'.":'~ J'..! ;t; (:.': IT i) ~'.":'~ Y ! /~: t=EErl O' ' i:,? ,'", .-~: .:'..-, .,.-, .,.., ,.,:.:, !::, ,:.:.:, ,:.:.:, !.:: ~ 9 8 7-) r:':'~ ';", ,...""~ .... i '::' :2 '7' F...:. ~"Alaska Oil & Gas Cons, Commisskxl Anchorage '~" i:;; ~'::'~ N,'i.;.' '"-'::' · :.., 7 (.)6 (.) A ~"~ c: h o r ;..'~ g e, A I. a :~ I-: a I)A'T'E' ,.Jar~u. ary SO , '1987 F;,' E F:' E R E N C: E ' A 17 C 0 C a .s' e d H o I. e F:' i ¥; a I. ~ .... t '5~ ~ ''~. .... ~ 9 -8'? I::' D K - 'i 00 ~ ;~ .... 5 ~ 2~"~ 9'"'87 PI)I<-"~ O0 F:' I. e a s' e .'..;' i r..j 'r'~ a 'nd ~" e 't' u r ~"~ 't' I", e a 't' 't' a c: h e el (: o p y a '.:...' ¥' e c e i p 't' o 'f' d a -I: ,-.., ,. I.-IAVI!i; A NICIE DAY! A TO .... t 5 2.9 Oil Gas on. o.~rnfssi T I:;: A N,I':.' :Il: Ii.", '70':;' ..: C; I) '1: 5' "1" 17 ]: B U T ]; 0 i"-! '"' C e n 't' r a I. F:' i I. e s · '" C h e v 'r o 'n '11' I) & M F:'hi I. !. iP s' F:'B Wel. I. F:'i I.e R & D S'oh i o 5'ta'~'e of A I.m.~ka Texaco ARCO Alaska, Inc Prudhoe ( Engineering Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 13, 1986 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-30 DS 13-26 DS 13-14 DS 13-13 DS 13-8 DS 13-5 Permit No. 81-101 Permit No. 82-74 Permit No. 82-171 Permit No. 82-178 Permit No. 81-148 Permit No. 81-103 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/SKAD/jj Enclosures cc: SOHIO Alaska Petroleum Co. File PI(DS 13-30)W1-3 PI(DS 13-26)W1-3 PI(DS 13-14)W1-3 PI(DS 13-13)W1-3 PI(DS 13-8)W1-3 PI(DS 13-5)W1-3 ARCO Alaska, Inc. ts a Subsidiary of AtlanticRIchfieldCompany . ,,.. STATE OF ALASKA [ ALASKa. ,L AND GAS CONSERVATION C .AMISSION 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 ARCO Alaska, Inc. 81-103 3. Address 8. APl Number Post Office Box 100360, Anchorage, AK 99510 50- 029-20626 4. Location of well at surface 9. Unit or Lease Name 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM Prudho~ Bay Unit At Top Producing Interval 10. Well Number 1407' FSL, 1355' FEL, Sec. 13, T10N, R14E, UM 13-5 At Total Depth 11. Field and Pool 951' FSL~ 876' FEL~ Sec. 13~ T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 78' RKB APL 28315 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 07/23_/81 08/3_2/81 08/3_6/83_I __ feet MSL 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost l1055'MD~9540'TVD llO19'MD,9513'TVD YES ~X NO [] 2~.62 feet MD lq~' 22. Type Electric or Other Logs Run DIL/BHCS/SP/GR_ ]:iT)~/~I~T./~I (2.~.T /(~T /~P ~P /TI~.//~T 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE'WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 0' 110' 32" 300 sx Permafrost 13-3/8" 72.0# L-80 0' 2675' 17~" 400 sx Permafrost 2351 .~x Fondu 9-5/8" 47.0# L-80 0' 9850' 12~" 500 sx Class G S00-95 7" 29.0# L-80 9547' 11050' 8%" 531 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SI~E DEPTH SET (MD) PACKER SET (MD) 10128-10148 'MD 10228-10238 'MD 5~" 9576 ' 9498' 10158-10178 ' MD 10246-10266 'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10191-10201'MD 10274-10280'MD 4 spf 10211-10221'MD 10290-10310,MD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8883- 9018 ' TVD Ref: BHCS 08/09/81 N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) iO/O~/R?I 1~1 .... Date of Test Hours Tested PROD0(~i'~J~FOR PI L-BBL GAS-MCF WATER-BBL CHOKE SiZE GAS-PI L RATIO A I TEST PERIOD I~, ~18 GAS-~gF WAOFER-BBL OIL ~AVITY-API ~'~) , FIo~,~-b-i~- Casir~-Pressure CALCULATED.~ OIL-BBL Press. 24-HOUR RATE !!00 ~/~ ~'~'~ ~'~ 0 25.9 28. ~ ........ CDR E DATA""" Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .. i:: ~" '"' ',.;.; Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit O/W Contact Base Sadlerochit GEOLOG C MARKERS .. MEAS DEPTH 10122' ]_0397/].0424 ' 10968 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge .............. :-.---.-...-- ~" Title 0per.F,n_g_~. M r.L~_~,~____ Date ~'~U/_L".,~'/~__.t~,~ fO'~/ __ Signed INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing 'tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10..407 ARCO Alaska, Inc. (' Prudhoe Bay~ jineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 13, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re' DS 13-30 DS 13-26 DS 13-14 DS 13-13 DS 13-8 DS 13-5 Permit No. 82-101 Permit No. 82-74 Permit No. 82-171 Permit No. 82-178 Permit No. 81-148 Permit No. 81-103 Enclosed are the "Subsequent" Sundry Notices detailing work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/SKAD/jj Enclosures CC' SOHIO Alaska Petroleum Co. File PI(DS 13-30)W1-3 PI(DS 13-26)W1-3 Pi(DS 13-14)W1-3 PI(DS 13-13)W1-3 PI(DSl3-B)WI-3 P1(DS13-B)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfleldCompany ( STATE OF ALASKA ('~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [~X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM At Top Producing Interva]: 1407 FSL, 1355' FEL, Sec. 13, TION, R14E, UN At Total Depth: 951' FSL, 876' FEL, Sec. 13, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 78' RKB 6. Lease Designation and Serial No. ADL 28315 7. Permit No. 81-103 8. APl Number 50- 029-20626 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-5 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il 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 F'~X 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). Began perforating operation on 01-16-86. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 10290-10310'MD (4 spf), flowed well to clean up. Shut-in well, POOH, all shots fired. RIH w/gun #2A and w/gun #2B, shot interval 10274-10280'MD (4 spf) and shot interval 10158-10178'MD (4 spf), flowed well to clean up. Shut-in well, POOH, gun #2A did not fire and gun #2B did not fire. RIH w/gun #3, shot interval 10128-10148'MD, (4 spf), flowed well to cleanup. Shut-in well, POOH, gun did not fire. RIH w/gun #4A and gun #4B, shot interval 10274-10280'MD (4 spf), and shot interval 10158-10178'MD (4 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #5, shot interval 10128-10148'MD (4 spf), fl owed to clean up. Shut-in well, POOH. Ran SSSV, secured well, RD. Ref' BHCS 08/09/81 14. I hereby~certify that the foregoing~ true and correct to the best of my knowledge. ~_r~'/¢._ zZ,¢-~'.' -'~/.!~~J- ' /~//) ~'/~/~'"'~ Operations Engineering Mgr. Signed " Title The space below for Commission use Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay }eering Post Office Box ]00360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 13, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-1 Permit No. 78-60 DS 13-2A Permit No. 83-21 DS 13-3 Permit No. 78-62 DS 13-4 Permit No. 78-63 DS 13-5' Permit No. 81-103 DS 13-8 Permit NO. 81-148 DS 13-12 Permit No. 80-142 DS 13-13 Permit No. 82-178 DS 13-14 Permit No. 82-171 DS 13-26 Permit No. 82-74 DS 13-29 Permit No. 83-43 DS 13-30 Permit No. 82-101 DS 13-33 Permit No. 82-106 DS 13-34 Permit No. 82-136 Enclosed are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS:BSM:vh Enclosure RECEIVED JAN 1 1986 Naska 011 & (las Cens. Commission Anchorage cc: SOHIO Alaska Petroleum Co. File PI(DS 13-1)Wl-3 P1 (DS 13-2A)W1-3 Pi(DS 13-3)Wl-3 P1 (DS 13-4)Wl-3 Pi(DS 13-5)W1-3 Pi(DS 13-8)W1-3 Pi(DS 13-12) W1-3 ARCO Alaska, Inc. Is Il Subsidiary of AflanflcRIchfieldCompany PI(DS 13-13) W1-3 P1 (DS 13-14)W1-3 Pi(DS 13-26)Wl-3 PI(DS 13-29)W1-3 Pi(DS 13-30)Wl-3 PI(DS 13-33)Wl-3 Pi(DS 13-34)W1-3 ( STATE OF ALASKA i' ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 1761'FSL & 56'FWL, Sec. 13 T10N, R14E, UM At Top Producing Interval: 1407'FSL & 1355'FEL, Sec.13, T10N, R14E, UM At Total Depth: 951'FSL & 876'FEL, Sec. 13, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 78' RKB I 6. Lease Designation and Serial No. ADL 28315 12. 7. Permit No. 81-103 8. APl Number 50- 029-20626 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-5 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 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 [~[X 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). ARCO Alaska, Inc. proposes to perforate well 13-5 at selected intervals within the Sadlerochit sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and cleanup operation. Proposed Perforation Intervals: 13-5: 10128-].0148' MD 10158-10178' MD 10274-10280' MD 10290-10310' MD Ref: BHCS 8-9-81 RECEIVED JAN 1 ] !986 011 '& Ga~ C~nJ. t:Jommi~lon An~tle 14. I hereby ce, r,l;ify that the foj~going,is true and correct to the best of my knowledge. Signed ,~j~'Y/'~'//~~ Title Operations Engineering Mgr. The space below for Commission use Conditions of APproval, if any: Approved by. Approved Co~¥ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO ALaska, Inc· F'·O~ Box Anchorage, ALaska DATE' December '2, i985 REFERENCE' ARCO Magnetic Tape Data ""DS 16-7 ii .... i7-85 OH tape w/Listing -,~,.,~ 1),5' J 6-..J 7 J (-)-~ 2..-.85 OH ¢spe w/I. J s-'l; J l~g ~3(.)4871 DA * l'his Lis'['lng goes wi'['h 4J-he 'rape .~'en'~ ou't note~ prey i ou.s' I.y ~ See m¢'tached of data.,. TRAN$~ ~:483 D I S 'f' I:;,' I B U T I 0 N Ch evr' C)I'I I) & H I.:.': x p I. o r a t' i o n 5' e r v i c ',~._t':.'e~ i on ~E,x,p L ora,t, Phi, L L ip.s' F:'B WeLL F:'i Le.s R & D ~!$Oh-i~.'o .... '$'t'a'fe of A Texaco DRESSER INDUSTRIES, INC. 5600 'B' STREET, SUITE 201, ANCHORAGE, ALASKA 99502 November 26, 1985 Arco Alaska, Inc. Attn: Kelly McFarland ATO - 1429D P. O. Box 100360 Anchorage, AK 99510 Dear Kelly: Enclosed you will find five (5) copies of the lister for D. S. 13-5. The six tapes and specifications sheets were already sent to your office August 26, 1985. Due to problems in our Computer center we were unable to deliver the listers at that time. Mr. John Boyle of the'Alaska Oil & Gas Commission has notified us and we have sent him a lister directly. We are sorry for any inconvenience this has caused your department. Regards, DRESSER ATLAS , JACKIE BAGLE¥ Secretary /enclosures as stated ARCO Alaska, Inc. {'~ Post Office Box 100360 Anchorage. AlasKa 99510 Telephone 907 276 1215 Date: September 3, 1985 Reference: ARCO CH Finals ~1-4 ~'' CET 127 U' Temp -5 Epilog x,ji~_~ c/o ~ ~13-5 PDK 100 5-25-85 Run 1 5" Sch 8-4-85 1 5" DA 7-22-85 1 5" DA 7-22-85 1 5" DA 7-21-85 1 5" DA Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 292 '~ '~' .~ t:onS. C0~mlSsjorl d.$. C 0 Chevron D&M Expl. Services Ext. Exploration Exxon Marathon Mobil I-U4 Ce-P_.LOC,.}_.,. PB Well Files R&D Sohio State of Alaska Texaco ARCO Alaska, Inc.'j Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: September 3, 1985 Reference: ARCO CH Tapes -"""1-9 CH CNL 8-15-85 # 70747 8-i9-85 ~ECC 220 ~~CH 8-15-85 13-98 CH DIL 8-14-85 970746 Please sign as receipt of data. . REceived by Alaska 0il & Gas Cons. Commission Anchorage Pam Lambert ATO 1429C Trans 301 Chevron Phillips D & M PB Well Files Expl. Services R & D Ext. Exploration Sohio Exxon State of Alaska Marathon Texaco Mobil ARCO Allski. Inc. is DRESSER INDUSTRIES, INC. 5600 'B' STREET, SUITE 201, ANCHORAGE, ALASKA 99502 August 26~ 2'985 Arco Alaska~ Inc, Attn: Kelly McFarland ATO -.2479D P. O. Box~100360 Anchorage, Alas~ka 99510 Dear Kelly; Enclosed you will find six (~) tapes, and s.pecifi.cation sheets, on well' 13-5. Due to Problems with our computer we are unable to send you'the listers which would usually, accompany the tapes, We. will, however~ s. end yo~ the listers . , a~'soon as' pos'sible. we hope this hasn',t caused any inconvenience, If you have any questions please contact myself or .Mr. Jim Thornb. erry. Our office number is .563-3233. Thank. you Re.gards~ DRESSER ATLAS JACKIE WILSON Secretary /enclosUres as: stated ALASKA OIL AND CAS CONSERVATION COMMISSION / 3ool PORCUPINE DRIVE / ANCHORAGE,ALASKA 99501-!-33'92 ,June 5, 1984 , TELEPHONE(907) 279-1433 Ms. Kelly McFarland ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Transmittal #196. Transmitted via Mail are the following: 0uantity Description of Item DS 1-9, 05/10/84, CPL/TDT-M listing DS 1-10, 05/8/84, CPL/TDT-M listing DS 12-9, 04/22/84, CPL/TDT-M listing DS 12-16, 04/22/84, CPL/TDT-M listing DS 13-5, 04/21/84, CPL/TDT-M listing. Kelly, re~ These listings that accompanied the CPL's sent with the captioned transmittal are neither required nor of value and a accordingly returned herewith. William Van Alen Please acknowledge receipt by signing and returning one copy of this letter. ~ SIGNED: DATED: Yo~r s~v~. tru~ Alaska Oil and Gas Conservation Commi s s ion ARCO Alaska, Inc.i' Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Reference: Arco Cas -~.S. 1-9 '~ 1-8-84 /' ~ J 5-10-84 ,- D.S. 1-10 J'" 5-8-84 CPL/TDT-M ~listing jD.S. 12-9-~ 4-22-84 TDT. '~' 5-9-84 CPL/TDT-M w~listing D.S, 12-16J'5-11-84 CPL/TDT-M w~listing ,-D.S. 12-17,? 4-22-84 TDT / ,, D.S. 13-5 / 4-21-84 TDT / · ~,' 5-8-84 \ CPL/TDT-M/w/listing/ --D.S. 13-34~t 4-21-84 kTDT / 5" Sch 5" Sch 5" Sch Run 2 5" Sch 5" Sch Run 1 Run 2 5" Sch 5" Sch 5" Sch 5" Sch 5" Sch ign and return the attached copy as receipt of data. HAVE A NICE MEMORIAL DAY WEEKEND! Kelly McFar!and ATO-1429F Trans. 9 196 DISTRIBUTION Chevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty ~ Mara'th0n Mobil M6bil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office B~ ~0 Anchorage, Alaska 99510 Telephone 907 277 5637 June 20, 1983 Reference: A.~Co Pressure Data D.$. 3-11 ~ 5-18-83 D.S. 7-9 ~ 4-3-83 / 4-3-83 D.S. 13-1 -' 5-29-83 D' S. '13-5 / 5-29-83 D.S. 15-4 j 4-8-83 ~ 4-8-83 D.S. 16-10/ 5-18-83 D.S. 16-11 / 5-18-83 D.S. 16-14j 5-18-83 Static Survey Pressure Build-up Pressure Build-up Survey Report Static Survey Static Survey Pressure Build-up Pressure Build-up Survey Report Static Survey Static Survey Static Survey GO Ca~co Ca~co Ca~%co Camco Camco Camco GO se sign and return the attached copy as receipt of 'data Kelly McFarland ATO-1429D , Trans. 9 367 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOB I L sTATE.OF DALLAS CAROLINE SMITH ARCO Alaskal Inc. tA' Prudhoe Bay Ehy,neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 22, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas -3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 2-19 DS 2-21 DS 2-23 DS 2-26 DS 13-5 DS 14-30 Permit No. 81-186 Permit No. 82-45 Permit No. 82-120 Permit No. 82-107 Permit No..81-103 Permit No. 81-166 Enclosed are Completion Reports for work done on the above- mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/TKKW/lmi Enclosures cc: Sohio Petroleum Co. ARCO Alaaka, Inc, la a SublHdlary of AII.nllcRh hfleldCompany ~ " , ' STATE OF ALASKA ,: ~ ALASK~ IL AND GAS CONSERVATIONd~ AMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ,. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-103 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50-029-20626 4. Location of well at surface 9. Unit or Lease Name 1761' FSL, 56' FWL, Sec. 13, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1407' FSL, 1355' FEL, Sec. 13, T10N, R14E, UM DS 13-5 At Total Depth 11. Field and Pool 951' FSL, 876' FEL, Sec. 13, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 78' RKB ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 7/21/81 8/12/81 8/16/81I -- feet MSLt 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost l1055'MD, 9540'TVD llO19'MD, 9513'TVD YES [] NO [] 2162 feet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/BHCS/SP/GR, FDC/CNL/Cal, CBL/CCL/OR, CR/3B/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 94.0f~ H~40 0' 110' 32" 300 sx Permafrost 13-3/8" 72.0# L-80 0' 2675' 17~" 400 sx Permafrost 2351 sx Fondu 9-5/8" 47.0# L-80 & 0' 9850' 12~" 500 sx Class G S00_95 7" 29.05~ L-80 9547' 11050' 8~" 531 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Ref: CNL 8/20/81 4 spf 5-~" 9576' 9498' 10189-10199' MD 8928-8984' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10209-10219' MD DEPTH INTERVAL(MD) AMOUNT& KIND OF. MATERIAL USED 10226-10236 ' MD N/A 10244-10264 ' MD : 27. PRoDuCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 10/2/82 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE GAS-OIL RATIO 3/26/83 12.5 TEST PERIOD, ~ . 1409 621 53 34 57.6 Flow Tubing Casing Pressure CALCULATED~1~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 639 N/A .24-HOUR RATE ~1~ 2602 1498 109 25.9 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A .,..¢,. ~ ,;!,. *~:; ?. ?,, i~;:_; !'?,;;: ,'",,.-., - Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS' ~ · . .. . FORMATiONTE.STS: ... . NAME _ Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10122' · O/W Contact 10397/10424' .. Base Sadlerochit 10968 ' · . ,. .. , . .. · ,. . 31. LIST OF ATTACHMENTS , . .. 32. I hereby certify that the foregoing is true and,correc~ tO ~he best of mY,knoWledge " '" .... , Signed '' Title · , , INSTRUCTIONS 'Genera:l: This' f.orm is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. - I.tem 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 ot'herwise shown) fo'r depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this. well is completed for separate p.roduction'~.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., inter'val 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 2'3: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". , . Form 10-407 ARCO Alaska, Inc. ~'" Post Office B~,~ 360 Anchorage. Alasxa 99,510 Telephone ~C7 277 5637 April 20, 1983 Reference: Arco Cased Hole Finals D.S. 2-22 4-3-83 CFS D.S. 13-5 4-12-83 CPL/TDT-M w/Listing D.S. 13-6 3-16-83 Diff Temp 3-16-8'3 CFS D. S. 13-34 D.S. 14-11 D.S. 15-6 ,. 4-14-83 ..- CPL/TDT-M w/Listing 2-12-83 X-Y Caliper 3-27-83 CFS Run 1 5" GO 5" Sch Run 1 5" GO Run 1 5" GO 5" Sch Run 1 5" GO Run 1 5" GO ease sign and return the attached copy as receipt of data. Kelly McF. arland AFA-4 03 Trnas. # 297 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOB I L GETTY' D&M STAT.E OF ALASKA DALLAS CAROLINE SM I TH~ ~.~.~ ~!~ ARCO Alaska, Inc.~' Post Office 5', 350 Anchorage, AlasKa 99510 Telephone 907 277 5637 March 17, 1983 Reference: Arco Cased Hole Finals D.S. 6-12 2-17-83 TDT Run 1 5" Sch D.S. 13-5 2-16-83 TDT Run 1 5" Sch D.S. 13-30 2~2-83 Completion Record Run 1 5" S ch D.S. 16-11 3-11-83 ~CPL/TDT-M w/Listing 5" Sch "yP1//Please sign and re~urn ~he attached copy as receipt of data. Kelly McFarland AFA-403 Trans. ~ 226 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY STATE OF .... ' ~i.-'-. ~': ~' ,,,:_., DALLAS ~ ,vu- R CAROLI:NE SMITH ARCO Alaska, Inc. ' 360 Post Office~,1~ ,,,ska Anchorage. 99510 Telephone 907 277 5637 January 25, 1983 Refer. ence: Arco Cased Hole Finals D.S. 13-5 D. S. 14-18 D.S. 17-9 9-29-82 PLS-Temp/F. Density 9-14-82 PLS/Temperature 10-10-82 PLS/Spinner Run 4 5" DA Run 11 5" DA Run 2 5" DA Pl'ease sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 084 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ARCO Alaska. Inc. is a Subsicliary of AtlanticRichfieldCompany EXXON MOBILE GETTY D&M DALLAS~ ', ARCO Alaska, Inc. Post Office ~' 360 Anchorage. ,ka 99510 Telephone 907 277 5637 December 30, 1982 RE: ARCO Cased Hole Finals D.S. 13-5 10-29/30/31-82 Spinner Camco D.S. 14-13 "10-6-82 Spinner Camco D.S. 17-8 10-28/29-82 Spinner Camco D.S. 18-7 Initial run Perf. and Collar Log Camco sign and return the attached copy as receipt of data. Becky Benedict AFA- 403 Transo #685 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M ~ Alaska Oil & Gas Cons. Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompanv Post Office Box 360 Anchorage,~" 'ska 99510 Telephone ~ 277 5637 December 16, 1982 RE: ARCO Pressure Surveys D.S. 3-8 11-20-82 D.S. 3-13 12-3-82 D.S. 3-15 11-21-82 D.S. 6-4 12-2-82 D.S. 6-11 11-11-82 D.S. 6-12 11-11-82 D]S. 11-6 11-7-82 D.S. 11-7 11-7-82 D.S. 13-1 10-22-82 D.S. 13-3 10-23-82 D.S. 13-5 10-29/31-82 D.S. 13-22 11-22-82 D.So 13-23A 10-12-82 D.S. 13-24 11-19-82 Static Survey Pressure Bui ld-up Static Survey Pressure Bui 1 d-up Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Pressure Bui ld-up Static Survey Static Survey Static Survey Camco Gearhart Camco Otis Camco Dresser Camco Camco Camco Camco .Camco Camco Camco Camco D.S. 17-5. 11-18-82 Static Survey Camco "17-6 11 18-82 Static~ Survey Camco · Please sign and return the attached copy as receipt of data. Becky Benedict AFA- 403 Trans. #662 DISTRIBUTION NORTH GEOLOGY R & D DRILLING, PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF' ALASKA DALLAS ARCO Alaska. Inc. is a Subslcliary of AllanticRichfieldComp in,., ARCO Alaska, Inc. Post Office E~~! 360 Anchorage. Ai~ska 99510 Telephone 907 277 5637 November 23, 1982 RE' ARCO Cased' Hole Finals D.S. 1-8 10-24-82 CH CNL D.S. 1-22~ 11-6-82 CBL/VD D.S. 4-1~ 10-30-82 CH CNL D.S. 5-7f 10-26/5-14/10-22-82 CNL Gas Monitor Log D.S. 5-7~ 10-22/5-14-82 CNL Gas Monitor Log D.S. 5-7-- 10-22-82 13.S. 5-14~/' 10-30-82 D.S. 5-12~-~' 10-23-82 D.S. 6-23 ~ 10-21-82 D.S. 6-24~ 11-4-82 D.S. 13-5-~ 8-20/11-1-82 D.S. 13-15~ 10-21-82 -'~ 10-3-82 7-22-82 D.SC- 18-10 ~ 10-21-82 Run 5 SCH Run 1 SCH Run 6 SCH Run 3, 10, & 11 SCH Run l0 & l l SCH CH CNL Run ll SCH CH CNL Run 3 SCH CH CNL Run 7 SCH ACBL Run 1 D/A CBL/VD Run 1 SCH CH CNL (CNL Monitor Overlay) Run I & 2 SCH CBL/VD Run 1 SCH ACBL Run 1 D/A Spinner Camco ACBL Run 1 D/A Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA 403 Trans. #625 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ~PHILLIPS SOHIO MARATHON · CHEVRON EXXON MOBIL GETTY D&M STATE OF ALAS~':'~ DALLAS . ARCO Alaska, Inc. Post Office~ '< 360 Anchorage,l.. .ska 99510 Telephone 907 277 5637 November 8, 1982 RE: ARCO Magnetic Tapes with Listings D.S. 5-14 10-30-82 /D.S. 4-1 10-30-82 ~ D.S. 9-15 10-31-82 D.S. 13-5 11-1-82 ~- D.S. 3-10 ~, D.S. 13-3 ~'~' D.S. 4-13 ~ .... D.S. 1-21 '-~ D.S. 13-4 10-29-82 10-22-82 10-31-82 10-15-82 10-23-82 Cased Hole CNL SCH Tape #ACC 66015 Cased Hole CNL SCH Tape #ACC 66013 Cased Hole CNL SCH Tape #ACC 66014 Cased Hole CNL SCH Tape #ACC 66016 CNL (6 passes) D/A Tape #ECC 1507 CNL/Multispace (2 passes)' D/A Tape #ECC 1503 CNL T~rpe #ECC 1508 D/A Open Hole D/A Tape #ECC 1489 CNL & CNL Repeat. D/A Tape '#ECC 1504 Please sign and return the a.ttached copy as receipt of data°' Becky Benedi ct AFA-403 ~ Trans. #608 DiSTRiBUTiON NORTH GEOLOGY R& D DRILLING PHILLIPS SOHIO MARATHON CHEVRON Run 3 Run 6 Run 1 Run 3 EXXON MOBIL GETTY · D&M STATE' OF ALASKA'~ DALLAS ~,.,, ') ARCO Alaska, inc. Post Office Box 360 Anchorage. A~' a 99510 Telephone 90', 7 5637 October 15, Reference: ,, 1982 ARCO Pressure Data 9-26-82 13-5 9-3-82 Pr~sure Build-Up Survey Pressure Gradient Survey GO D/A Please sign and return the attached copy Becky Benedict AFA- 403 Trans. #554 as receipt of data. -- NORTH. GEOLOGY CHEVRON DALLAS ,,. ARCO Alaska, Inc. Post Offi(~' ox 360 Anchorag%. Alaska 99510 Telephone 907 277 5637 October 15, Reference: 1982 ARCO Pressure Data D.S. 13-20 9-26-82 D.S. 13-5 9-3-82 Pressure Build-Up Survey ¥.~, ~ ! ~ la .,. , - Pressure Gradient Survey GO D/A Please sign and return the attached copy as Becky Benedict AFA - 403 Trans. 9554 receipt of data. DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON GETTY A!aska Oil & Gas (;on:~. (;°~"'~is~ion D&M Anchot'a,qo GEO'i',OG¥ STAT~'. O~ A~S~ DALES ARCO Alaska, Inc. i' Post Office E~., 360 Anchorage, Alaska 99510 Telephone '.'~07' 277 5637 October 19, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Re' D.S. 13-5 - Permit No. 81-103 D.S. 13-19 - Permit No. 81-180 D.S. 13-23A - Permit No. 82-23 Attached are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D .~F~~. $ c~e~ Regional Engineer DFS'TKKW'skh Attachments cc' Sohio Petroleum Co. OCT 2 2 I9 2 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany A( · STATE OF ALASKA "L ALASK ',...,IL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Thc. 81-]03 3. Address P.O. Box 360; Anchorage, AK 99510 4. Location of Well 1761' FSL, 56' FWL, Sec 13, TION, R14E, UN (.surf) 1407' FSL, 1355' FEL, Sec. 13, TION, R14E, UM (Top prod) 951' FSL, 876' FEL, Sec 13, TION, R14E,'UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. _ 7g' RKB ADL 28315 8. APl Number 50- 029-20626 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-5 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation 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.) SUBSEQUENT REPORT OF: (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). Began perforating operation 9/23/82. RU perforating unit, pressure tested surface equipment. RIH with gun #1, shot 10244-10264' MD 4 spf (20' ref. CNL 8/20/81), flowed to tank for cleanuD, monitored rate and took shakeouts. POH - all shots fired. Bottom hole sampling continued until 9/29/82 when perforating commenced again. RIH with gun #2 shot 10226-10236' MD and 10209-10219' MD 4 spf (20' ref. CNL 8/20/81), flowed to L.P. ',.. line. POH - all shots fired. RIH with gun #3, shot 10189-10199' MD 4 spf (10' ref CNL 8/20/81), flowed to L.P. lf, ne. POH - all shots fired. Recorded BHP. RD. Ran SSSV Secured well 10/2/82. 14. I hereby.~ertify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~~ Title Reclional Operations Enaineer The space below for Commission use Date 1 0/18/82 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date ........................................ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Boy 360 Anchorage. A{i a 99510 Telephone 907 277 5637 August 25, 1982 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Re: D.S. 12-4A- Permit No. 81-187 D.S. 13-5 - Permit No. 81-103 D.S. 13-6 - Permit No. 81-121 D.S. 14-18 - Permit No. 81-06 Enclosed are the "Notice of Intention" Sundry Notices for work proposed on the above mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS'TKKW'skh Enclosures cc' Sohio Petroleum Company A('~I STATE OF ALASKA Ct ALASK L AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-103 3. Address 8. APl Number P. O. Box 360; Anchoraqe, AK 99510 5o-029-20626 4. Location of Well 1761'FSL, 56'FWL, Sec 13, TION, R14E, UM (surf) 1407'FSL, 1355'FEL, Sec 13, TION, R14E, UM (top prod) 951'FSL, 876'FEL, Sec 13, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 78' RKB 12. I 6 . Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-5 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 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). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subseqUent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed intervals: 10191'-10201' MD 10211'-10221' MD 10228'-10238' MD 10246'-10266' MD Subsequent Work Reported Xo.Z¢,¢O3 mt a/o_/ /llm 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed_ _ _ ,~~~ Title Regional E,nqineer The space below for Commission use Date Conditions of Approval, if any: Approved by. COMMISSIONER Approved :,opy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc,, North SloFI{ Post Office U~'~x 3G0 Telephono 907 277 Jerry A. District Oper;~tions En~n~er March 16, 1982 Mr. C. D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Subject' D.S. 4-11 Permit No. 78-6 D.S. D.S. 4-14 Permit No. 78-36 D.S. D.S. 11-1 Permit No. 81-123 D.S. D.S. 11-2 Permit No. 81-128 D.S. D.S. 11-3 Permit No. 81-147 D.S. D.S. 11-5 Permit No. 81-155 D.S. D.S. 11-6 Permit No. 81-161 D.S. D.S. 12-4A Permit No. 81-187 D.S. D.S. 12-7A Permit No. 81-175 D.S. D.S. 12-8B permit No. 81-167 D.S. D.S. 12-13 Permit No. 81-87 13-5 Permit No. 81-103 13-7 Permit No. 81-129 13-8 Permit No. 81-148 13-9 Permit No. 81-158 13-10 Permit No. 81-165 13-12 Permit No. 81-142 13-19 Permit No. 81-180 14-12 Permit No. 81-109 14-13 Permit No. 81-101 14-26 Permit No. 81-110 D.S. 12-14 Permit No. 81-138 Enclosed are our' Sundry Notices detailing the work to be done on the above mentioned well. Very_truly yours, . J. ^. P, ochon JAR'TKKW :ml c Enclosure ARCO Alaska, Inc. is ,~ subsidiary of AllanlicRichfieldCornp;~r~y STATE OF ALASKA , ALASKA("' _~L AND GAS CONSERVATION CtMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL:~ OTHER [] 2. Name of Operator ARCO Alaska, 3. Address Inc. P.O. Box 360 Anchorage, AK 99510 4. Location of Well 1761'FSL,56'FWL,Sec 13,T10N,R14E,UM (surface) 1407'FSL,1355'FEL,Sec 13,T10N,R14E,UM (Top-interval 951'FSL,876'FEL,Sec 13,T10N,R14E,UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) RKB 78 ' 12. I 6. Lease Designation and Serial No. ADL 28315 7. Permit No. 81-103 8. APl Number 50-029-20626 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-5 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 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 J~] 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). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. 14. I hereby certify that the foregoing i,%,true and correct to the best of my knowledge. Signed ,?.. '( ,, ~ ";"~. ~ Title n5 ~e_. Opr~. The space b~.. for Commission use Conditions of Approval, if any: Date Approved by__ COMMISSIONER ~',,,Form 10-403 7-1-80 Apprc~ved Returned the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Officc~~' ,< 3(_;[_3 Anchorage ..... ~ska 99510 Telephone 907 277 5537 January.20, 1982 ~.~. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Updated ~11 Completion Reports Dear Sir' Enclosed please find the updated 1.611 Completion Reports for the following wells' DS 11-2 DS 14-16 DS. 12-13 DS A-4 .DS 13-5 DS A-5 DS 13-7 DS A-6 DS14-15 DS B-7 Sincere ly, G. L. Alvord Associate Engineer Enclosures GLA'ss ARCO Alaska, Inc ~s ,'-i qtl[):, rlj I ¥' f'~l ~ll,wHic~qicl,,fleldComp;~rW JAN2o 1982 Gas Cons. Coimnissior~ ~-tnchora,qe, STATE OF ALASKA ALASKA ,~_ AND GAS CONSERVATION C vllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG . 1. Status of Well Classification of Service Well OIL~i[ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-103 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50- 029-20626 4. Location of well at surface 9. Unit or Lease Name 1761' FSL, 56' FWd, Sec. 15, T10N, R14F.,UM -- ~0C~[8~1~T ~Oe .Bay Unit At Top Producing Interval VEPJFtED I 10. Well Number 1407' FSL, 1355 FEL, Sec. 13, T10N, R14E, UM ,is,ff.-~ DS 13-5 At Total Depth lB. lq._~' 11. Field and Pool 951' FSL, 876' FF, L, Sec. 13, T10N, R14E, UM P~udhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil Pool 78' RKB ADL 28315 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116-No. of Completions 7/21/81 8/12/81 8/16/81 -- feet MSLI 1 17. Total Oepth~(~o+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafro-~t l1055tMD ,~'TVD ll019IMD 9513lT~I YES~ NO[] 2162' feetMD 1900' (approx.) 22. Type Electric or Other Logs Run DIL/BHCS/SP/GR, FDC/CNL/C~, CBL/CCL/GR, GR/JB/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , , 20" 94# H-40 0' 110' 32" 300 sx Permafrost 13 3/8" 72# L-80 0' 2675' 17TM 400 sx Permafrost 2531 sx Fondu 9 '5/8" 47# L-80/ 0' .9850' 12~" 500 sX Class G S00-95 7,, 29# L-80 3547' 11050' Q~,, o~. 531 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING.RECORD interval, size and number) siZE . DEPTH 'SET (MD) PACKER SET (MD) 5½" 9576' 9498' N/A , ,,: 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED : · N/A , . , .. 27. PRODUCTION TEsT " Date First Production .- I Method of. Operation (Flowing, gas lift, etc.) N/A , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER[BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ .... Flow,Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A , ...... · .. " ,J A ;",,~ o i !'-t i'~') . Form 10-407 ~Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30~ GEOLOGIC MARKERS NAME Top Sadlerochit Oii/%'~ater MEAS. DEPTH 10122' 10397/10424 TRUE VERT. DEPTF Base Sadlerochit 10968' 31. LIST OF ATTACHMENTS FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 32. I hereby certify that the foregoing is tru~and correct to the best of my knowledge Signed ' Title]i~/t~. Drlg. Engr. INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on 'all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference. (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Comically North Alaska District ,, Post Office ~' 3,.30 Anchoraae ....'~ ka :99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 13, 1981 Reference: ARCO Cased Hole Finals D.S.i-18 10/12/81 · D.S.2-6 d 9/25/81 D.S.13-5 / 10/1/81 D.S.13-5~ 10/1/81 D.S.13-$ ''/ 10/1/81 Perforation & Collar Log Run 1 5" Spinner Log 5" Perforation & Collar Log Run 2 5" Perforation & Collar'Log Run 2 2" 'Perforation &Collar Log Run 1 2" Please sign and .return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal ~738 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO OII and (.;,1~ Company ,$ a Df'./t$,0. n ol AIh.l!ltlcR~chlieldCompany ARCO Oil and Gas Compar~y Nor!h A,las.!, ~ District Post O flick{ Anchorame. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 4, 1981 Reference: ARCO DIRECTIONAL SURVEY DATA D. S. 13-7 10/23/'81 P.s.13-5 10/23/81 Gyroscopic Job No. 5283 Gyroscopic Job No. 5281 Please sign and return the attached copy as receipt of data Mary F. Kellis North Engineering Transmittal #716 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON A!qCO C~I aqd (.ia~, C,'~mpany ,s ,i Oiv~Gn of Atlant~cR,chf,eldC~mDany ARCO Alaska, Inc. Post Office B{ Anchorage, Alaska 99510 Telephone 907 277 5637 September 23, 1981 · Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 11-1 DS 15-10 DS 12-11 DS 16-14 DS 12-13 DS 17-8 DS 13-5 DS 14-19 DS 13-6 A-2 DS 14-11 B-4 Dear Sir' Enclosed please find the following' 1) The Well Completion Reports for DS 11-1, DS 12-13, DS 13-5, and DS 17-10. 2) The Monthly Report for DS 13-6. 3) The Sundry Notice of Intent for DS 15 10. 4) The Gyroscopic Survey for DS 12-11, DS 14-11, DS 14-19, DS 16-14, A-2, and B-4. Sincerely, P. A. VanDusen District Drilling Engineer PAV'GLA'cm Enclosures RECEIVED SEP 3 0 1981 rNaska 0il & Gas Cons. CommJssJor~ ~chorage ARCO Alaska, Inc. is ,'~ suh!~h:liary of AtlanticRichfieldCornpar~y ORIGINAL 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. Per~ N~er ARCO Alaska, Inc. - 3. Address 8. APL~umb"~--2-029--2066 P.O. Box 360 Anchorage, AK 99510 5o- 4. Location of well at surface 9. Unit or Lease Name 1761' FSL, 56' FWL, Sec 13, TION, R14E, UM Prudhoe Bay Unit To be Submitted L1515-b At Total Depth 11. Field and Pool To be Submitted ~S/'£:~L /'?TS'tF~ ,Se~ /3, ~/O~Y//¢/qE /Yfri. Prudhoe Bay Field ' r ' ' Prudhoe Oil Pool 5. Elevation in feet (indicate KB, DF, etc.)78, RKB 16'Lea,~DDLesij~n~.n5and Serial N°' 12. Date Sp.udded7/21/81 13. Date8/12/81T.D. Reached 14. Date8/6/81C°'mAP" ~;us-p' or Aband. 15. Water__Depth, iffeet MSL°ffsh°re 16. ND,of1 Completions 17. Total Depth(MD+TeD)18.PlugBackDepth(MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set [ 21.ThickoessofPerrqafrost i11055'MD 9540'TVD 11019'MD 9513'TV[: YES~x NOr-I 21~?.' feetMD 1900' (appr0x) 22. Type Electric or Other Logs ~.un . ~., DIU/BHCSTSP/GR, FDC/CNL/CAL, CBL'/CCL/GR, GR/JB/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H-40 O' IlO' 32" 300 sx Permafrost 13 3/8" 72# L-80 O' 2675' 17 1/2" 400 sx Permafrost'i~5~l 9 5/8" 47# L-80/ O' 9850' 12 1/4" 500 sx Class G - , S00-95 7" 29# L-80 9547' 11050' 8.1/2" b31 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE. DEPTH SET (MD) PACKER SET (MD) N/A 5 1/Z" 9570' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ' N/A , ,, 27. PRO'DUCTION TEsT Date. First Production . I Method of.Operation (Flowing, gas lift, etc.) N/A ' . .I .., 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-B.BL GAS-'MCF W'ATER-BBL DirE 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. · N/A " ~aska 0i1~~p 'y 0 138] Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit 0 i 1/Water Base Sadlerochi GEOLOGIC MARKERS / MEAS. DEPTH L TRUE VERT. DEPTH To bJ Submitted 31. LIST OF ATTACHMENTS 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Dist. Drlg Engr. Date 9/22/81 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 o'f the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 DS 13-5 DRILLING HISTORY NU 20" riser. Spudded well @ 1130 hrs 7/21/81. Drld 17 1/2" hole to 2675'. Ran 67 jts 13 3/8" 72#/ft L-80 csg w/shoe @ 2661' Cmtd 13 3/8" csg w/2531 sx Fondu & 400 sx Permafrost. ND 20" riser. Instl'd 13 3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 15' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12 1/4" hole to 9870'. Ran 242jts 9 5/8" 47#/ft S00-95 & 218 jts 9 5/8" 47#/ft L-80 csg w/shoe @ 9850'. Cmtd 9 5/8" csg w/500 sx Class G. Instld 9 5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8 1/2" hole to 11,055'. Ran DIL/BHCS/ SP/GR and FDC/CNL/CAL. Arctic packed 9 5/8" x 13 3/8" annulus w/300 bbls H O, 300 sx Permafrost "C" & 131 bbls Arctic Pak. Ran 52 jts 7" 29#/ft L-80 l~r fr/9547' to 11,050'. Cmtd 7" lnr w/531 sx Class G. Drld cmt to 11,019' PBTD. Displaced well to NaC1. Tstd liner lap to 3000 psi - ok. Ran CBL/CCL/ GR and GR/JB/CCL. Ran 5 1/2" completion assy w/tail @ 9570' & pkr @ 9498'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ball and set pkr. Tstd tbg to 3000 psi & ann to 200 psi - ok. Tstd tbg to 200 psi & ann to 3500 psi - ok. Closed SSSV. Instld 'tree cap & tstd to 5000 psi - ok. Secured well and released rig @ 0900 hrs 8/16/81. RECEIVED SEP 0 198I ~laska Oil & Gas Cons. Commission Anchorage COMPLETION REPORT ARCO ALASKA, INC, GYROSCOPIC 5URVFY RADIUS OF CURVATURE METHOD OF COb~PUTATION COHPUTED FOR SDC BY FM LINDSFY 6, ASSOC 23 OCT, 81 WELL DS 13-5 KB £L£V 78. FT. JOB NO 5281 RECORD OF SURVEY TRUE SEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH SUB DRIFT SEA DIREC DE'G, 0 0 0 100 0 0 200 0 0 3 O0 0 0 4 O0 0 0 500 0 0 600 0 0 700 0 0 P,,O0 0 0 90 b 0 0 O,O0 IO0.00 200,00 300,O0 400.00 500,00 -78.00 N O,0OE 22.00 N O.OOE 122,00 N 0,OOE 222,00 N 0,OOE 322.00 N O,O'OE 422.00 N O.OOE 600,00 ~ 522,00 .N O,OOE 700,00 622,01) N 0,OOE 800.00 722,00 N O,OUE 900,00 822,00 N O,OOE 1000 0 0 10OO.00 922.00 N 0,OOE 1100 0 0 1100.00 1022,OO N 0,OOE 1.200 0 30 1199,99 1121,99 Nf13,53E 1300 0 45 1299,99 1221,99 N27,70E 1/400 0 0 1399,98 1321,98 N O,00E 1500 1 0 1499'98 14.21-98. 573,95E 1600 1 0 ]599,96 1521~96 568,7BE 1700 1 0 1699,95 1621,95 $61,61E 1800 1 0 1799,93 1721,93 $45,45E 1900 1 0 1899,92 1821,92 S43,28E 2000 1 0 1999,90 1921,90 $58. llE 2100 0 45 2099.89 2021.89 529,11E 2200 0 15 2199.89 2121,89 SI~.06W 2300 1 0 2299,88 222!1,88 $19,78E 2400 1 0 2399,87 2321.87 .% 4,61E TOTAl. COORDINATES 0,00 5 0,00 W 0.oo s o.oo w 0.00 $ 0.00 w O,,OO.$ 0,00 W o. . .' i :']:: :i o' 0.o0 'ii[:, ,,,0 ,,0,0 w :'0 o 0,00 5 0,00 W 0.00 $ 0,00 W 0.00 S 0,()0 W 0,00 $ 0.00 W 0.39 N 0,15 E 1.27 N 0,79 E 1.90 N 0,94 E 2,36 N 1.54 E 1,BO N 3.20 E 1,07 N 6,78 E 0,03 N 6,18 E 1,20 S 7.4,0 E 2,31 S 8.75 E 3,40 S 9.79 [ 4,24 S 9,90 E 5.~2 5 9,95 f 7.02 S 10,32 E CLOSURES DI STANCE ANGLE O M S DOG LEG SEVER I TY DEG/iO(;FT 0,00 $ 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 O 0 W O,00 $ O 0 0 W O,OO $ O O 0 W 0.00 S 0 0 0 0,00 S 0 0 0 W 0.00 $ 0 0 0 W 0,00 ,S 0 0 0 W 0.00 5 0 0 0 W 0.00 S 0 0 0 W 0,00 5 0 0 0 0,42 N 21 1,50 N 31 43 ~9 2.13 N 26 22 2.82 N 33 1~+ 36 E 3,67 N 60 35 30 4,90 N 77 6.18 N 7,50 5 80 43 45 9.05 S 75 12 25 E 10.36 S 70 /+9 44 E 10.77 $ 66 /+6 41 E' 11,29 S 61 52 22 E 12,48 S 55 46 29 0 · 000 0.000 O,OOO 0 · 0 O 0 0.000 0,000 0 · 000 0,000 O,000 0 · (1 O 0 · 00 0 0.500 . 0.250 0.750 1,001 0.090 0.125 0,281 0 · 0 3~i 0.258 0 · 250 O. 500 0.750 0.264 SECrlO(,, O 1 STANCE 0 · OO 0,00 0.00 O,O0 0.00 0,O0 O.OO 0,00 ii), O0 0.00 (,) · 0/ 0.54 0.58 1,08 2,81 ~-§0 6,07 7.~.9 9.02 lJ.Zb 10.51 10,76 11.43 ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 23 OCT. RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DR IFT SEA DIREC DEG, 2500 1 0 2499.85 2421.85 S 0,43E 2600 0 0 2599.85 2521,85 N O.OGE 270f~ 0 30 2699,84 2621,84 514.90W 2800 3 0 ~799.79 2721.79 $52,95E 2900 6 0 2899.47 2821,47 558,81E 3000 7 30 2998,77 2'920,77 562,63[ 9~0.0 10 30 3097,53 3019.53 S65.46E 3200 1~ 0 3195,43 3117,43 $67,26E 3300 15 0 ~292,~5 92~,45 $68.06E 3400 lB 45 ~88~13 '3SlO,lS $71.66E 3500 21 ~() 3482.02 3~0~,02 S69~55E '3600 25 0 3573,8.8 9495,88 566.5~f 3700 28 0 ~66~,36 ~ 3585,~6 $70.OOE 3~00 30 0 3750,82 3672,82 S75,85E 3900 31 0 3836.98 3758.98 584. OOE 4000 31 0 3922,70 9844,70 N89.00E 4200 30 90 4C;9&.36 4016,36 N84,00E 4300 30 15 4180.63 ~102,63 N84,08E 4400 ~0 45 4266,'79 ~188,79 NB5.75E 4500 30 30 4352,84 4274.84 NBG.13E 46.00 30 0 4439.23 4361,23 ~,700 31 0 4525,39 4447.39 4800 31 0 4611,11 A533.11 4900 31 0 4696,82 4618,82 S89,95E 5000 32 0 4782.09 4704.09 S88.65E 5100 31 0 4867.35 4789,35 S88,30E 5200 31 45 4952,73 4874.73 586.18E 5300 31 15 5037,99 4959.99 TOTAL COORDINATES 8,76 S 10.40 E 8.76 S 10-95 E 8'72 S 10.66 E 11,44 $ ll-59 E 15,8/+ $ 18e09 E 2'1,59 S 28,34 E 28,43 S 42.~0 E 36,59 .5 61.05 E 112.66 S 267,50 E 121.54 S 317.43 E 123.78 S 368-85 E 121.13 S 420,28 E 116.28 $ 471,17 E t11,03 S 521.47 E 106.53 S 5'12,02 E 102,92 $ 622,83 E 99.72 S 673,11 E 96,85 $ 723.78 E 94.45 $ 775,23 E 93,fl5 S 826,72 E 94.09 S 878.96 E 95.48 S 931.19 E 97,98 S 983,19 E 101.6] $ 1035,31 E CLOSURES DISTANCE ANGLE D M S 13,60 S 49 52 34 E 14.03 $ 51 20 53 E 13,,77 $ 50 4,2 4 E 16,29 ,5 45 22 4,7 E 24.04 S 46 47 14 E 35.62 $ 52 41 57 E 51.05 S 56 9 20 E 71.18 $ 59 3 43 E 95.t7 S 61 14 29 12.3,94 S 63 15 13 El 158,12 S 64 50 58 19'7.53 S 65 29 31 E 242.10 S 66 0 27 290,26 S 339.90 S 69 2 bb E 389.07 S 71 26 54 E 437.39 S 73 55 17 E 485.31 $ 76 8 13 E 533.16 S 77 58 48 E 581.85 S 79 27 0 E 631,28 $ 80 36 58 680.4.6 $ 81 34 20 F. 730.23 S 82 22 39 E 780.96 S ~3 3 Il E 831.98 S 883.98 S 83 53 23 E 936,07 S 84 8 44 E 98B.06 S 84 1040.29 S 84 23 35 E DOG LEG SEVERITY DEG/1OOf:T 0,073 1.~00 0-5~0 2.507 3.001 1.501 3.001 2.502 2 .O01 3 · 768 2,765 3,5/40 3.093 2.4~8 2,382 3.604 2.008 0,575 0.251 0.663 0.269 0,512 1 · O04 0.403 1.202 1.065 1.004 0.952 0.511 SECT I0:t D i S lANCE 12.~, 12.07 13.49 20.68 31.81 46.89 66.72 90 119.02 153,01 191, '?0 235.46 283.61 334.32 385,28 435, 494.5. 532.98 581.85 679.99 729.28 779.42 829.85 881.33 932,93 984.51 1036.42 ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 23 OCT, 81 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D N SUB DR ! FT SEA DIREC DEG, TOTAL COORDINAIE$ CLOSURES DI STANCE ANGLE D M 5 DOG LEG 'SEVERITY DEG/IOOFT 5400 31 0 5123,59 5045°59 $86.73E 105.00 S 1086,89 E 5500 30 30 5209,53 5131.53 $66,41E 108.05 $ 1137.93 E 5600 31 0 5295,47 5217,47 S84.38E 112,15 S 1188.89 E 5700 31 0 5381.19 5303.19 584.95E :.116.94 S 1240,17 E 5800 32 0 5466.45 5388.45 5~4.63E 121,68 S 1292.21 E 5900 31 0 5551.72 5473,72 $84.36E 126.69 $ 134~.22 E 6000 32 0 5636.08 5558,98 S84.05E 131,96 S 1396,20 E 6100 32 0 5721.79 5643.7g S83.76E 137.59 $ 1448,89 E 6200 32 0 5806.59 5728.59 S87.73E 14t.51 S 1501.73 E 1091,95 S 84 28 54 E 1143,05 S 84 34 31 E 1194.1.7 S 84 36 38 E 1245.69 S 84 36 47 E 1297.92 $ 84 37 12 E 1350.17 S 84 36 56 E 1402.42 S 84 36 1 E 1455.41S 84 34 BO E ~508.38 $ 84 36 59 E 6300 34 0 5890,45 5812.45 NOS.73E 6400 34 0 5973,36 5895.36 NBS.18E 6500 34 15 6056.I4 5978,14 N85.51E 6600 34 30 61~8,07 6060,67 N83.26E 6700 34 0 6221.33 6143.33 N84.33E 6800 34 30 6303.99 6225.99 N83.85E 6900 35 0 6386.16 6308.16 N83.38E 7000 35 30 6467,82 6389~82 NB2.83E 7100 36 0 6548.98 6470.98 N83.03E 7200 35 15 6630,26 6552.26 N82.95E 7300 36 0 6711.54 6633.54 N85.76E 7400 35 15 6792.83 6714.~3 N86.56E 7500 35 15 6874.49 6'796.49 b186.65E 7600 36 0 6955,78 6877,78 N86.g0E 7700 37 0 7036.16 6958.I6 N87.lSE 7800 38 30 7115.23 7037.23 N88,SDE 7900 39 30 7192.94 711~.94 NSg.15E 8000 39 30 7270.10 7192,10 NOg.23E BI0{) 40 30 7346.71 7268.71 $89,66E 8200 41 0 7422,46 7344.46 S~9.48E 140.56 .5 ~ 1'556,15 E: 1562,49 .5 84 DO 18 E 1611.~9'..E 1617.63 5 85 10 20 E , 131,595 ,1667.81 E 1672,99 S 85 29 I8 E 126.07 5 1728.60 S ~5 49 2 E 119-99 $ 1779.95 E 114.20 S 1835.93 E 107.86 .5 1892.57 E 100.9~ $ 1949.87 E 93.75 $ 2007,85' E 86.64 S 2065.66 E 80.92 S 2123.62 E 77,02 S 2181.74 E 73.61 $ 2239,35 E 70,33 S 2297,51 E 67.26 $ 2356.91 E 65.14 .S 2418.09 E 64.05 S 2481.0! E 63.15 S 2544.61 'E 62.90 $ 2608.B9 E 63.39 S 2674.16 E 1783.99 S 86 8 ~5 E 1839.48 $ 86 26 25 E 1895.64 S 86 44 16 E 1952,48 S 87 2 11 E 2010.04 S 87 19 35 E 2067.48 S 87 35 52 E 2125.16 $ 87 49 3 E 2183.10 S 87 58 40 E 2240,56 S 88 7 1 E 2298.58 S 88 14 ~7 E 2357.87 S 88 21 54 E 2418.97 S 88 27 24 E 2481.84 S 88 31 t6 E 2545.40 S 8~ 34 ~,1 E 2609.65 S 88 37 7 E 2674.92 S 88 3~ 31 E 0.352 0.507 0.735 0.292 1.004 1 1.004 O. 150 2.102 2 0.308 0.2'71 0, '/64. 0.601 0,b23 0.523 0,533 0.505 0.751 1.22~ 0.796 0.048 0,755 1.005 1.633 1.007 0 · 053 1.102 0.506 ': ~" C T I 0 N i) I,STANCL l13B.4a 1169.33 1240.62 1292.~4 1344.69 1396.76 1449.59 1502.25 1609.57 1663.71 1717.93 1771,82 ~82b,80 1~80,33 1991~ 2102.53 2158.96 2214.97 2271.54 2329.38 2389.14 2450.79 2513,15 2576.30 Z6~0.5~ ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 23 OCT. 81 RECORD OF SURVEY TRUE ~4EAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D ~4 SUB DR IFT SEA DIREC DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D h', S DOG LEG SEVERITY DEG/iOOFT 8300 42 0 7497.36 7419,36 S89.18E 6q,16 $ 2740.42 8/+00 42 0 7571.67 7493.67 N89,BSE 64,26 .S 2807.33 8500 43 0 7645,40 75)67,40 588,40E 64.82 S 2874.88 8600 42 0 7719.13 '1641.1B $87.71E :. 67.11 $ 2942.40 8700 42 15 7793.30 7715,30 586,00E 8800 41 0 7868,04 7790,0a 584,56E 8900 40 15 7943,9z~ 7865,94 $83.01E 9000 4.1 0 8019,84 7941,~4 SB2,00[{ 9100 40 0 8095,88 8017,88 Sf:~2,86E 9200 40 0 8172,49 809~,49 S80,38E 9300 ~+0 0 829,9,09 8171,09 S73.46E 70.78 S 3009.37 E 7,6.24 $ 3075.57 E 83.28 5 3140.30 E 91.77 S 3204.85 E 100.33 S 3269,23 E 109.69 $' 124,22;:S i 3395,39 E 2741.17 S 88 39 31 E 2808.07 $ 88 41 19 E 2875,,61 S 88 42 2.9 E 2943.17 S 88 41 36 E 3010.21 S 88 39 9 E 3076,52 S 88 34 47 E 3141,40 .5 88 2~ 50 E 3206.17 S ~8 21 34 E 3270,77 $ 88 14 3t E 3334,6Z S 88 6 53 E 3397.66 S 87 54 16 E 9qO0 40 0 8325,69 82,47,69 571,80E 9500 40- 0 8402,30 8324,30 S70,13E 9600 39 0 8479,46 8401,46 $65.43E 9700 39 0 8557,17 8479,17 $64,55E 9800 40 0 8634,34 8556,34. S62,05E 9900 40 15 8710,80 8632,80 $61,15E lO000 41 0 8786,70 8708,70 S56.I. OE 10100 42 0 8861.,59 8783,59 S55.26E 10200 42 0 8935,91 8857,91 S52,93E 10300 41 30 9010,51 8932,51 $49,83E 10400 43 0 9084,53 9006,53 $50.50E 10500 44 0 9157,07 9079,07 $50,33E 10600 44 30 9228,70 9150,70 S50.88E 107'00 45 0 9299~72 9221,72 54.9,96E 10800 50 0 9367~25 9289.25 $39,10E 10900 50 30 9431,20 9353,20 S38,56E 1.0975 50 30 9~78,90 9400,90 $36~61E 11012 50 30 9502,44 9424,44 537,00E 143.~1 $ 3456,74'E 3q. 59,71 S 87 37 27 [ 164.37'S 3517,50'::f:'::::' 3521.34 $ 87 19 28 E 188.41 S 3576.37 215.02 S '.3633,40 243,59 S 3690,22 27/-+,24 S 3746.91 308,13 $ 3802', 48 34.5,49 S 3857.21 384,72 $ 3911,41 426,27 S 3963,43 469,34 .5 4015,06 513,20 .5 4068,11 ~5~,49 $ 4122,04 602,34. S 4176,30 65.4.80 S 4227,91 714,69 5 ~276.12 760,54 S 4311,4B 783,~+0 S 4328.53 3581.33 S 86 59 3 E 3639.76 S 86 36 47 E 3698.25 S 86 13 23 E 3756.93 $ 85 43 49 E 381t+.gb $ 85 22 1 E 38'12,65 $ 84 52 53 E 3930,2.8 $ ~4 22 56 E 3986,29 S 83 51. qO E 4042,40 S 83 19 57 E 4100.35 S 82 48 3~ E 41.59,56 $ 62 17 51 E ~219,~1 S 81 ~7 3~ E 4278.32 $ 81 1~ 46 E 4335,~ S 80 30'q. 1 E 4377,99 S 79 59 44 E G398,35 S 79 ~4 28 E 1.009 0.981 1.447 1.04.6 0.815 0.991 0.868 1.062 1,596 1,071 1.071 2,113 0.556 1,438 0.451 2,299 1.067 1,561 1,450 1.532 1,003 0,568 0.~7~ 8-103 0,592 2,006 0 · '! 9<2 SECT ION D I STANCE 2705.~ 2771,63 2838.15 2904,94 2971,45 3037,53 3102,45 3167,47 3232.33 3360~73 3424,55 3550.40 3611.34 ~672.4~ 3'194, ~855.26 3915,72 3974,4'1 4033,12 ~154.42 4215,98 4276.33 4~4.69 4~77,79 EXTRAPOLATED TO TO ARCO DS 13-5 GYROSCOPIC SURVEY ,JOB NC) 52'31 23 OCT, RECORD OF SURVEY TRUE HEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DR IFT SEA DIREC DEG. TOTAL COORDINATES 11055 50 30 9529.79 9451,79 S37.00E B09.90 S 4348.50 E BOTTOM HOLE CLOSURE '~423,28 FEET AT S 79 26 58 E CLOSURES DISTANCE ANGLE D M S 4423,28 S..79 26 58 E DOG LEG SEVER I TY DEG/IOOFf S~CTION DIS'FANCL 4423.]' ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 23 OCT. · INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOP, GIVEN DEPTHS T P, U E CODE I~EASURED VERTICAL TOTAL COORDINATES C L O S U R E SUB NANE DEPTH D~:L PT H D I STANCE ANGLE SEA D M TOP ,SA[;)L_ER 10122 8877,94 354.00 S 3869.22 OIL/WATER 103-'-37 ~0~2.34 468.62 S 4012.99 OIL/WATER 10~2~ 9102.05 479.89 S A027.62 ~ASE SADLE 10~68 9474,45 756.5~ S 4307~77 PBTD 11019 9506,89 787.71 S 4331.78 TD 11055 9529.79 809.90 S 4348~50 38B5.38 S 84 46 20 E 8799,94 4040,26 S 83 20 21 [ 9004.34 4,056,11 $ 83 12 18 E 9024,05 4373.70 S 80 2 20 E 9396,45 4402,82 S 79 41 36 E 9428.89 q. 423,28 5 79 26 98 E 9451,79 ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUb SEA DEPTH. 23 OCT, 81 TRUE MEASURED VERTICAL SUB ND-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 178 178- 100 0 278 278. 200 0 378 378, 300 O 475 478, 400 0 57B 578. 500 0 678 678. 600 0 778 778, 700 0 878 878. 800 0 978 978, 900 0 1078 107B, 1000 O 1178 1178. 1100 0 1278 i278, 1200 0 1378 1378- 1300 0 '1478 1478, 1400 0 1578 1578. 1500 0 1678 I678. 1600 0 1778 1778, 1700 0 1878 1878, 1800 0 1978 1978. 1900 0 2078 2078, 2000 0 2178 2178. 2100 0 2278 2278. 2200 0 2378 2378. 2300 0 2478 2478, 2400 O 2578 2578, 2500 0 2678 2678. 2600 0 2778 2778. 2700 0 2878 2878, 2800 0 2979 2978, 2900 1 3080 3078. 3000 2 3182 3178. 3100 4 3285 3278, 3200' 7 3389 3378. 3300 i1 3496 3478, 3400 17 3604 3578. 3500 26 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 4 6 9 0.00 O,00 O,00 0,00 0,,O0 OD O0 0.00 0.00 0,00 0,00 0,25 1,04 1,8'7 2,27 1,91 1,23 0,28 0,93 2, 10 3.14 4,13 4,98 .6,64 8.38 8.98 8,67 10,62 14,7~ 20,43 27,04 35,14 44,40 54.79 66.98 82,62 0,00 W 0,00 W 0,00 W 0.00 W 0,00 W 0.00 W O.CO W 0.00 W O,00 W 0.07 E 0,64 E 1.26 Et 2.83 E 4.43 E', 5,89 E 7,13 E 8,42 E 9,63 E 9,95 E 9.89 E 10,26 E 10.38 E 9~80 E 11,15 E 11,C5 E 16,21 E 25,91 E 39,14 E 57,35 E 79,84 E 107,32 E 141.53 E 181,28 E ARCO DS 13-5' GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 JOb NO 52.81 FEET OF SUB SEA DEPTH. 23 OCT. 81 TRUE MEASURED VERTICAL SUB ~ID-.T VD DEPTH DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 3717 3678, 3600 38 3831 3778, 3700 53 39fl8 3878. 3800 70 4064 3978 · 3900 86 4181 4078. 4000 103 4297 4178, 4100 1].9 4413 4278. 4200 ], 35 4529 4378. 4300 151 4645 4478. 4400 166 4761 4578, 4500 1.83 4878 4678. 4600 200 4995 4778, 4700 2 17 51'12 4878. 4800 234 5347 5078, 5000 269 54.63 5178. 5100 285 5580 5278, 5200 301 5696 5378, 5300 318 5814 54?8, 5400 336 5931 5578. 5500 352 6048 5678, 5600 370 6166 5778, 5700 388 62B5 5878, 5800 407 6405 5978. 5900 427 6526 6078, 6000 448 6648 6178, 6100 470 6768 6278, 6200 490 6890 6378, 6300 512 7012 6478, 6400 534 7136 6578, 6500 558 7258 66?8, 6600 580 7382 6778. 6700 604 7504 6878. 6800 626 7627 6978. 6900 649 775~ 7078. 7000 674. 12 15 17 16 17 16 15 16 15 17 17 17 · , , 16 16 17 18 16 18 18 19 · 20 21 22 2O 22 22 24 22 24 22 23 25 101.06 116,32 123.39 122,46 117.22 111.15 105,96 101.90 94,83 93.44 94.72 95'.'/'1 99.11 103.65 '107,25 111.45 1 1'/,32 12.2.44 128,35 134.73 141,05 141.19 135.89 130.24 122,90 115.77 10'7,95 99 · 97 91.13 82.47 77.I0 73.~+5 69,26 6.5.74 228,56 282.64 342.00 401,78 461,56 519.93 578.64 637.~8 755,13 815,38 876.30 937.38 998,74 1059,45 1119.11 1178.4z~ 12B8.07 1299.36 1360,02 1421,~8 ]483~69 1547,81 1614o68 1682.39 1750.71 1817,91 18~6,81 1956.78 2028,67 2099,06 2171,21 2241-66 2~13-39 2388,86 E E E E E E E E E EE E E E E E E E E E E E E E E E E E E E E E ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 ~4EASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 F ETET OF SUB SEA DEPTH. 23 OCT, 81 TRUE MEASURED VERTICAL SUg MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 7R9l 7178, BO10 7278, 8141 737~, 8274 7478, 8408 7578. 8544 7678 8679 7778, 8813 7878 8945 7978, 90'76 8078 , 9207 8]78. 9338 8278. 9468 8378. 9598 8478. 9727 9857 8678, 9988 8778 1012 2 88 102~6 89'?~ · 103',71 9078. 10529 9178. 10669 9278, 10816 9378. 10973 9478. 7100 702 7200 732 7300 763 7400 795 7500 830 7600 866 7700 901 7800 935 7900 966 8000 998 8100 1029 8200 8300 1090 8400 t120 8500 1148 8600 1179 8'700 1210 8800 1244 8900 1278 9000 1313 9100 1351 9200 1391 9300 1438 9400 1495 28 53.73 S 2468.73 30 63.05 S 2550.98 31 6~.37 S 2635,57 32 64,24 S 2723.07 35 6~.18 $ 2612,69 36 65.98 $ 2904.75 35 70.24 5 2995,27 34 '77,14 S 3084.04 31 86,93 S 3169,07 32 98,66 5 3253,85 31 110.49 5 3387,25 31 131,46 $ 3~18,D4 ~O 157e88 S, 3497,9~ 30 : "~:~ 188.17 $ 3575,10 222,51S 3648,59 :'' ~1 ' 260,98 S 3722.53 " 31 i:i.:::303,90 $ 3795.86 3869.22 3940,5! ~009.B6 4083,56 4159,01 4235,62 4310,04 34 34 35 38 40 47 57 354.00 408.16 465,99 526.1'1 58fl.~9 664,,34 759.66 ARCO DS 13-5 GYROSCOPIC SURVEY JO~, NO 5281 INTERPOLATE[) VALUES FOR EVEN TRUE MEASURED VERT I CAL DEP TH DE P T H 1000 1000, 2000 1999. 3000 2998, 4000 3922. 5000 6000 56 36 7000 6467, 8000 7270, 9000 [~019, 10000 8786 11000 94,94° ,,.,,:.A,SU R E D DEPTH. 1000 FEET OF. ,,r-- SUB SEA TOTAl. COORDINATES 922, 0.00 S 0,00 W 1921, 2,31 S 8,74 E 2920, 21.72 S 28.26 E 3844, 123.78 S 368,85 E 4704, 94,81 S B78.95 E 5558. 132.15 S ]396,18 E 6389. 100,33 $ 1949,79 E 7192. '62.93 S 2544.,61 E 7941, 91,78 S 370fl,85 E 8708, 3(.)8,25 S 3802,41 E 94].6, 776,,.08 $ 4322,86 E · · . HORIZONTAL' VI 5, RdO-'~LAS KA, INC: .[~-'~',_.'r~ WELL DS-15.5 --:----~.' , GYROSCOPIC OCT;:~6, 198 SURV I ' CLo : ...... 8-79°' ''~' .... :~: :~- ' '-:=~'~ ~ *-:-~-;-~-~:: ~': '-~ '.;~',','t'~-='-'?:~: _!.._..i_~-'~:VERTiCAL- ~ISEC ~1 ,I1 ~ ~' ' -- - - - - ',~ ........: .~.' ,;;~-~''~"-"-' ...... :.-.; ...... :'.._~{.._: .......... .: .... : _~.:~ -*L4-.4--~--: ;-'~-t' ~' -~"~ --_ ~..;~', .... ~ .... ~...:'~I ARCO I ALASKA,' ~NCt' ~ ': [ ~---' ' : SURFACE:~ LOCATION IS' ~---~-~-.--/.----:.'~'~- ~- '~ ~ : . : · ~ WELL~DS_I ,~ - . ~ , ' ~, ' ' .-~-~-+-, : RADIUS OF CURVATURE'-; ...... ~" ~' ' ' =,1000 ~'~*~-~- "~x ......... ...... ~oo~, .'i~ '. ' ' , , , .- ...... 9' .~4-~: ~o°:.~~ '-= .... ; = ~-~-: + ~ ~ ~-~-~'Nx-+- ~T!-]~q:TZzN&~7~T ~ U+ .-t-, ..... t-- ~~.~ .... ~~.~ . : ! ~ ~; ~ :- _~_~_~_, .... :_~3__.~ .................................. ~ ~ ..... ~_~ , :~ t { - : I ' ~ ' ' H' ' ~ ' ~ ' ' ~-','~ ~~~- ~ '~ * : ~ -' ' ~ ~ .... --~--t-- ~800- , : .... 1--tm--~ ..... ~- ' , - : ~ ! i I ~ .... ~ ' ! { ~m-~ ; ~-~---+-~ ' ~ · ' ' 'f ~: ' ;': ~ i i i ! J T-- I ' I ~ , ' ' ~ ' ' - - · - ~T~ - I ' - ' - ' ~ '' ~ ' ' : ' ' ~ · -'- ~' ' ~ - I ~ - · · ~ - : · : ...... ?= ~0~o~-~: ........ ~' :.:t':-F: :'7-:~' ~ =7-. - -- , :-: ...... ~':: .... i- ' - . ~ ~ , I ~ ' - ''"' ' ...... ~-~ .... l~-t~ - ~i ............ / · ' ~_ ....... : ..... ~-~-~-~; ......... l--~t ...... : ..................... i - . - ~ ......... ~.' . ; l~ -~~ ........... ~- ~-'-~ ' ~ : ......... ~ ' ~ , - - .... r: t~ ....... :_~_'..l--:--:-'X ,' .1,- ,.. i , ,. ,,. I ~ : .... ; ; .... - ....... [- ..... ~ ; -= -~--4 ---~ i ...... ~ ~ ' ~ ' 'l' ' ~ : ~-~-~ ........... ~ ........ r ........... ~ ..... ~ ' ' ' .... i~'-, ?~ ....... i= .... = -'t-- ~--:::i:-~'=-- w-=:'¢~-'= :':='~ ~'=;:=' ':-:-~, =:~-~ ~. '~__i: _:,!..:L _ : ............. +-.- ......... , ...... 6400~ ......... ~ ~ ~ ~ ...... - -~ ~~-~. ~,'~~- - i ' - ~ ' ~ ' ~ ' ~ . ~ ....... i ........... ..... ~-~_~_--..L__.~ .......... IL ...... ~--. ee~ ..... ~ ......... ......... N--~ .... ~-- .... ~ .... ~ ......... 7" r~L~_L~--;-.-I ....... ~ ...... ~ _ _~ . ; · -- t ' ' ' - '-~ ' ' ' } , J ~~_ :_:._:_4::'._~.4 ..... 4--'-t-'-:-N-~- ..... : ...... ~~ ...... ~ ............ :-'~:, .... ,~___; ...... :.~,~._i ........ ~ ..... ! ............. !---~--~?~--~- ', : ~-t-~-~ - ' ~- . t ; ; . ; ............. ~ ...... ; · 1-, : .... : ,--~, ....... !-~ - : : - : : { ~ ...... :._~_,_~ ....... ~-~ .... :4.--: .... 84~-* ..... '- ~1-~ ~ ..................... I : ......... ...... ~ .......... = .... 'T ...... ! ' . _ i = . ~ ... [ ;----~ _ - ..,~' - : - ': ' - :~' ' 4 - ' ~ ' ~ ~ ~.. - ~.~----.- .~.4 ~ --' ~ II '''~--' ~'--, ' ~ ; . .... ~-; .............. ~': ..... ::::::::::::::::::::::-=~'i-:-:-:=-'-~ ~-'~. '- :_~X..~UD_=: t,,oss i ~ ~ ~ L' "~ :~ ~=" ~~-~ ~ ' 1 ..... ~_: .... ~:~..--~ .... ~-:-:--~ ~: :.-t ......... ~-~-~' t .... : "]~'T~-- .-:': .... ~'~': ,':~'.:' ~.~RCO 'AL. AS?.~A, INC~ ....................................................................................................................................................................................... DS; 1S, 'WELL NO~ 5 Z~SS JOB NO~ A)."'81~04S4 F'RtJBHCEE BAY, NORTH SLOPE, ALASKA I) ~ ~ 01 . * .... ..... , 0-11 2 'MD,-DRII_LER; F'RiSCO'fT/FANCHER RIG Nr): ROWAN..~6 DEC';i...INATION,t 30 1/2 1TiErS EAS'i',' ............................ Ir,: E:.' C 0 t:;.: J] C.) F:' . S L ll';: V E' Y 1.3, WELL JI:~H 0~: BAY', NORTH ~LOPE ALASKA COHI::'U ]" a l' ION PAGE · · ' ............ JO[; NO: A781D0434 ......................................... T'iPiD: .................. DATE ..................................... 09108~45 1S-AUG-81 4SURED DRIFT E F:' ]" I' '1 ,-, *:,',1 L5 ~ I.. E :r Er E T I) H DRIFT D i RECT t ON "5 M -'TRUE ....... r'l U ~''' '"'' ~' kI F'- C<~.r~:,c. -_F:,:TICAL VERTI'-'AL,_. L_ENG Fid DEF'TH SEC]" I GN ~'~" FEET ' r' ~.ET ....F -.~, '"' SU.E-:SEA R F_' C 'T A N G LJ L A R C L O S U R E DOGLEG TVB C 0 O R D ]: N A T E S DiS'FANCE i"~IRE'CTiON SEVERIT"; FEE'I" ..... FEET - ..................... FEF. T - ....... D'"h .... t-it~/'ZO0¢'"i' . 510, 151~:"'. 2675, 0 0 C, ,..."" 0 1.5 S ].5 0 W 0 ;30 i"4 ,q5 0 E 1 0 S 20 0 E 3 0 S 63 SO E: O. 0,:} 0. O0 -78,00 O, O0 ":'~ ..... '"5 ........ 0 .... , ' :..,.,.u,, u,, · 20 4,z.:z 00 1 07 S . 1511.9"- ..... 455 ..... ;~ ~ +/' "'2 .~. ,, ¥ U 2,,.:'":" I ,..'::' 2674,,90 12,76 259,';,,90 11,";;'0 S · ';c:,11..S '''~" '16 '?S 2733.82 ..... 14,62' S .... 0.00 0+00 ...~'- W ' i.'~J.· -- 3,50 E: 4,49 12 ' .03 E lo. 9'2 t ~ , 6 ~ -.. E ............. 2.,. '~ -o.4 .- 'a .... 0,00 0,0."". O, 09 :1., 7.¥ 352° .3 6 J. ;3, S707 ~ ,:. <:)00 4067, ( 6 :L 9 8. 64304, 6669, 71 .. '~ 748S, 6 0 9 45 1'2 15 14 0 '; ]. 0 24 45 · ":, c:, 0 "7'. 0, r.-' ,_, 4 1 5 3 J. 0 Sl 45 31 0 3() 45 '32" 15 S 57 0 I-:: '-:;' 5, S .65 0 E · .17:S, S 7 n~, 30 ,..r':':1. S 4, <:", 6c'0 i::: °1, S ' 74 0 E: 1 '~ 4 S 70 0 E S 72':0 ~::' ~.~ L.. '::: ...... "".'E: ,...' e'" .J' ~. c:.$7 0 t:": 2906,51 '-' '':' ' ':"'-' "-" =i -' ' ~ ........... · -' ,-,, 4,5 2,.~ ,' ~., 4, ,.. ;3077.Ft6' ............. 45.17 2°99, . ,.:. 4.-~ 90'-E ........... ,..2~ t0. 32,'; ?,, ., ,'3:'.:.' ,<:. c;,, :::i 5 3131, '::':/',_ 39,10 ,_.e 66,=;9~. E: 77 · ~.'":'.. ,..,= .,.,:"' '-'::, c:,'-' .,. '01 b', ";" ,, 4 ::.:, ,'~ 22 ,"h.....,. '"',,, 1 4 o., ,.-.: ," t~ ~ b. ':>' 7 E ':,' ...': · 672; ;3.417~0S .......... i"~";:.-,.., :1.5 3339,03 57,07 "q '._. tlS+90"'E ...... 1;3.1-.8~-, Sc>"' ~, O E S 85 C., E S 84 ..-3.0 E ,<::.., 84 30 E · S '84 ' 'O"E -. ~ ;.' i ,:...-, ,::..-,, ,-., -, q,c'::" ' .... :~ o · · ;' ; i: ..' ~.- ' "'.. ':'. ,.: ,. ~' }'i'.::: "',. '-- c ....... ',."* '" ',' .,. . :.:.' : '. ,: ',:, ,.., o c, 0,.:.,,, . .:,o8.'01 ..~,,J,O'.3~ :,: ~b,:iu o~'¢ '18~+25 E 198~0 c., -/, z 7, .> : ,,, ~.-..,-::,' .,~ x ..... -x ,::1 o 4 .... z, ,.'~ c: o ,": 'x q "" '~'-*"'~ 5:3 E 239. o S / 4 +,;:,<: .r., ,,, ,.0 / .,.:. ~. o U "' :'. ::: ,~s. .,,,, : . ~.%'.~ * 't,,'t't,' :,:, ~..~'- / ~7 ,l' ',. '../ r~/ ~ %.,.._, ,.~. C~ .-?'7, ':,',.;::':~: ..... =..: a "] ::' "'~ ...... ' ' ............ ' "' ': ' "'"" ' :"'' 0 ' ;, ,:, '.,: .. . ..,. ? 0 / ,, ~ .,.,,.~ z. 60.~ 7°..-. ~ L-'"S;3 ~ 7'2; .... ""%f~;:::' '~ ........ '~'-:'"~'":I '"' :' ,.,: ..<I. : .... ' "..' ...... ,.." <,' ,' :., :. : o.,..:. .... ,.3.80./:.;... Z~:~i.:::,:. ,::, ............. ,.,-,.,~, .~ w,<:.,~,, +:>' ~a' :,,~,,,: z..,'.,-t,.,'~ ,".,:, .~,/.'.<'.+59 E 3:L"Z~76._. ,~ / ,." / · , ,, , ,, ,, , '¥' ., !,:, 2 C. ':: .... 9 ' 4 ....... "' ("" 4 '" ,..., + ,:~ 8.4+ i (5 0 ";,', 0:3 3 '? 06 ,, 16 10 '"i., ':'?, -.'"' t.~ ,..,., .,. + 87 E: 1 ::. + S 4 "':" '":" '::: ' ..... 122 ' .~.., ,, ,.,. ':~.aO,. ,_ .08 605+ -;.' r.,.. ,, .-4S274' 0~::: 4, ,...o7 .S ~57 + 89 ..E 669 + 2,:5. 1:.'" r"t .r", "' : ...... '~ ,=.. :.,, ,4 ~:~ 5 c:. + 7':? 9 :; 1. J. 0 4 ," ," U. '7'2 i 48+ 0 !5 S 932 + 1.4 iE 94 ;3,8 '? 491. 5.."" -'/84, 14 1. 193., 04 :::; ';..'i 0 O, ]. 4 1 '"; .::"", 20 S :1. ! 82 · 95 E 11 "'";, "-" ,,.., 4 ,~'"' ..... 50 ;3, .... ' 5 ";', 07 '40 t ............ J. 4. 5,.,'::' ~ O0 ..... Jo...y'::'" '''~ -', 0 J. .......... 198 ,56 ' S ...... t. 444 ', 43-E ........... 14:58. O:l. c- 5O .5 -S =' 26' S ~:' ,'-, --/ ~., ',' o,5 S 61 47_5 S 65 48 g S 66 47 E: S 68 12 [::. S 70 :I E ......... S -71 .... ;31 E. S 79 25 E S 80 59 E S 81 43 E ........ S.-62 t0 .E ,..,17 72 S I J. 19 /:' J. 15, ,..,'¢" c.'-' 03., 8 '.;3 J. '::" , ....,'::' ""/"".~: ,..,':: ..... , :::: ~S2 C, 2 ,04._,u"-:' ........ o , ,..:'""u E:' '=,.-, ..... ~:32 =' "'" '" . 7;'3 E: .... 1.646..27. "' ~ ,., ;- 96. t.46 .... :1. .S 45. J. 4 :5218, g C .....t 94. .... '":' c.'" S 1634, '" · . '2S9, 61',?;3+8.4 1778,16 6115+8.4 :LS0..'I~7 S 1.,."'67+;34 E 1778,52 · 48..'f,,858,':_3,,87 .,.:.'" 0 5 "". .,:: + I 0 .::,,' '::' :I.._. 0+ 8-'/ 15,.4,2:[ S .~'-'046 ,18 E .,.? 052. ','-=,., , ,", ='"', -','", i ....... ?-:'-' '-""' S. "2 ¥ 9,02 £. ":' ''~ '=' 3. ~ 1, o c., ;':, / ~ 51 ,::.,-.:.~ o , 14 .<, ,' / ~4, 51 141.,. oo. .... 43 , ,.~ t ,% ...... 1- 20 . , (}2 + :5;' ,6 +30 "3 + } 5 4 +2o ;5,64 . 3,32 0 + ,:'. 0 0 + 1'"'~ 0+05' 'J+ 'S"'3 2., 66 I.,:';'I O, 47 0,26 7960, S8 45 oo68 + 4 ]: '-' 45 .;-) (' ,,:6, 40 30 9S0'7, 79 1.5 95294' ........ 38"'"45 S 8'? 30 E: .47:7., '"'"' ...... ., '" 2 "' ':: ...... '" ":' ........... ,.,:,..,,..~.,.0,. 715';,'."'""'" 1,:,4 ..">7S ""527 / ..'.e,/,..: ~..:.¢: . ~ , q9c."" 2531. , 0S .[4. .......... 88 S0 ki: 408,, .7548.,58 ...... '-',..... '7 '=' x .~. , ,.. :I.i ~ '7470+58 ......... iS';;;', 3::;. ...... 279:1. 003....E ....... 2.7'.7'4,.,_,'::'1 ......... S 84 '"" 0 E 4 '"" 8, '"'"' "'-" 4 ...... '::i':' E S 0'.7' 5 + 58 ..:., ,.., / .=, ~, ,., 4' 6 ._'3, 09.4024 /' 8 .i. b., 64 157',, 60 S ;30910 ._, ,... ........ ...~ ~,.,. _... S 7:8 7.'.';, 0 E: 4 '"' I, t:: 26 '4 c,, 1 3401., 5 S ;.--; 184 + 91 "' 0"'" 9,,::S S,..t,';,'o '-" <:: · -: .~, ,~.,., E 3-40':-~ ::¢4 ~.... 72. ;30E ..".'72 ~. ..... " ~4;354, 50 ......... 3'::'"'9,~,~ + 05 ..8357+50 .':!37+83 S' ....... ,.,~:I. +..4.:L'""::; ..... r:~" ........ S5~9.,41 S S6 5?; E .,,~,. ,.~ . S 87 5 ,':': S 86 ,.,_:.=; ,-:."" S...8~ 9 E t ,. ,::.r ..... NO: 5 I)b:d J. 3,, W'-~'' .... i ' '~' ] ..... t.,DHLi,'- B'AY, iqOF(TH SLOF'E, "' . COMF'LJTATiON PAGE NO~ · .......... JOB NO: 'ATS1D0434 ................... TIME ....................DATE ........................... 0'?~C:8~45 13--AUG-Si ........................ TRUE ~'"' .... A':" E EI-i."T CAL VER ICAL SU.BC:'F:]A F.: E C T A N G U I.. A F,: E: i.. O ~ U ~.: E DI3GLE6 ,'-;leu; U F( _F:][I .[:F( I FT I: ,.,, .[ FT u .~.. ,,.< c-.... ,,, I 7' ...... ,... EF'I'H Aiqg..iL.i..'.'_' DIF~:ECTiO!'.~ I..Ei',IGTH I:IEF'i-I"t SEC'[,'IOi',~ TVZI C CJ [) F,' [l I N A T [:- S £iiSI'Ai"!CE ]'IIi:;:ECi'ION SEVERii'~" F'"'- .......... " ""~ ..... ¥' ~L r.: I Il ~"i [1 i'i FEE]' FEET' ..... FEE:']" F' ~.E'T ................... FEE, .................... · -;'"' ? 0 E 276.,. b6.q. 8,8/ 2;.'.,'0S,,. 4:..3 (), ~,.' 2?5 ........... ':'<;.',0..-., 40 0 c: ,.fi9 ........ S:"";7 '-'=' ...... ,.>O S ..:,,::,'~,'c.., 63 E 370'8 ,, 43 S o...,, 2.'". E 0027. 41 ,"5 S Al 0 E]' '" .... ,, .~:'qJ. 7 7'.'?~ .."'"' " 3 ,, 34 "" ...... .- " -. ,-~c,,~ o73?,7'}' 35;,",, ,, 52 - S 3;327.,,"5'z E 3843,,00 S ;,..~4 41 E ._. ..,2; ,:Z ~.':. -,'. ....... '-. ,..--' 0..:'.,'" ,.., ='' o ......., .'-I. 3 3 ......... 0 S ,..:, .:.:: ,"5I_-E a ...... ,.:, ~. · c;, ::-, 6 .,...:"",. ? o '4 ,C'.', 4 <5 ,, ,v 2 :5; '-;;' O 4,7 '.'.;' ,i, ,....":: .,...'5. c:,' c" .... ,,.?, 44 .-"'" ,::."" ,, e:, ............. ]. r.- --,. ',..'-, ';.':' .,, 1 ,:, ................ :::, LJ .:, ." ¢:. c." J. 01"", 50 O c :,.56 30 ':" ,,,:.N.,:'l5';'51','~ E?,4 447.2;,,,57 ?432 84 706.,,c:'::' ....... .,:-..., ,.. .... ,.. ,, .... .,. :.'.-, W 4.'"..30.8.':t., g 4436 ,05' S 80 50 g ........................................................ O,F'2 0:.7:3 1.17 tS, WEL. L. NO: 5 DSS ..... 1..: - d O 5 i'-i 0 ;:' Fi 7,.'3. I D 0 4 3 .,.,~ RVEY FILE NUHBE;:;; :l.'J. 7 Ii l:-' F'T FI 2675, O0 :'::5c'c' O0 · ~ :--~ .....~ ,:., :' 7,:: ~;4~ O0 3 ]. 5 ili~ ()':.3 -', ,23~. 00 ,:::, c,',3.. · C'O ?~YO. 00 O0 O0 ,"",,, 0 ;..: 0 0 0,:} O0 0 C; D E i':' T H :I 2 E~ 7: J.'O 16 :L 7 20 1512,00 :[512 · O0 2675, O0 2675, ,:"~ 0 2907. O0 3707. ()0 4 067,00 '" <" 0 ..::, ,.)..:~ 3, . + ,,,, ,,... Y ! 52.00 7960 ,, 00 ,m ,-...-, _, 0/; C:' ,,5 ~'£ ,,..' + ? 307, C: 0 ?529 ~ O0 c, r'..-, r. () ,' c. '..,' ,:'., ~ 0 S.' 8 ,-,' 0 ~ O0 '.'i;' 87 ,.}.~ 0 0 10 0 2.7, ()0 'l. J.v"' 1 2 .~ 0 () I) E: F:' T H W E: t G I..t T · .. 26 TM "'- ' /.~ ,, O0 ................... :>0 359i:') o 00 :I. 5 3 S;'3 '2,0 0 6 0 5084,00 ....... 60 6J. 58,00 15 6334, O0 70 8423,+ O0 .................. 65 8881, O0 60 · .. ,.,, , , , , O0 ~00 , O0 ., C, C , O0 , 0 (; , 00 , .-~ ,, ') ''- R.P.M.. · WEIG~tT X '1000 - DRILLING DRYS RSSEMBLY I '. ! ,. Fi .. :. !i RRCO_, ILRSKR, ~ DS '13; ! :NEIJE "ND:! '5 ~ STATION: DEP, TH--11012"HD SOUTH' '/08.95; EAST 4430. 841 SCIENTIFIC DRILLING INTERNATIONAL 1111 East 80th Street, Anchorage. Alaska 99502 · 907~ 349-3541 · Telex: 09025364 (SDC AHG) Subsidiary of AMF INCORPORATED October 1, 1981 Job #5281 North Slope Drilling' Enclosed please find our Gyro Survey on DS 13-5 along with our Horizontal View maps. If any other information is needed please call 349-3541. Thank you for using Scientific Drilling international and. please call again. o~_ncerely Manager COMPLETION REPORT ARCO ALASKA~ INC. GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY G ASSOC 23 OCT. 81 WELL DS I3-5 KB ELEV 78. FT. JOB NO 528 1 RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 0 0 0 0.00 100 0 0 100.00 200 0 0 200.00 300 0 0 300.00 400 0 0 400.00 500 0 0 500,00 600 0 0 600,00 700 0 0 700.00 800 0 0 800,00 900 0 0 900.00 1000 0 0 1000.00 -78.00 N O.OOE 22.00 N O.OOE 122.00 N O.OOE 222.00 N O.OOE 322.00 N O.OOE 422.00 N O.OOE 522.00 N O.OOE 622.00 N O.OOE 722.00 N O.OOE 822,00 N O.OOE 922.00 N O.OOE 1100 O' 0 1100.00 1022.00 N O.OOE 1200 0 30 1199.99 1121,99 N43.53E 1300 0 45 1299.99 1221.99 N27.70E 1400 0 0 1399.98 1321.98 N O.OOE 1500 1 0 1499.98 1421.98 $73.95E 1600 1 0 1599.96 1521.96 $68.7fle 1700 1 0 1699.95 1621e95 S61.61E 1800 1 0 1799.93 1721.93 S45.45E 1900 1 0 1899e92 1821e92 S43e28E 2000 1 0 1999.90 1921.90 S58.11E 2100 0 45 2099.89 2021.89 S29.11E 2200 0 15 2199.89 2121.89 $14.06W 2300 1 0 2299.88 2221.88 S19.78E 2400 1 0 2399.87 2321.87 S 4.615 TOTAL COORDINATES 0.00 S 0.00 W 0.00 S 0.00 W 0.00 S 0.00 W O.OOS 0.00 W 0.005 :'O.O0..W o,O0:s':i:i:~ : ,!0.00 W 0.00 '"""0.00 W 0.00 S 0.00 W 0.00 $ 0.00 W 0.00 S 0.00 W 0.00 S 0.00 W 0.39 N OelS]'E 1.27 N 0.79 E 1.90 N 0.94 E 2.35 N 1.54 E 1.80 N 3,20 E 1.07 N 4.78 E 0.03 N 6.18 E 1.20 S 7.40 E 2,31S 8.75 E 3.40 S 9.79 E 4.24 S 9e90 E 5,32 S 9.95 E 7.02 S 10,32 E CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/iOOFT 0.00 S 0 0 0 W 0.00 S 0 0 0 W .0.00 S O' 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S O' 0 0 W 0.00 S 0 0 0 W 0.00 5 0 0 0 W 0.00 5 0 0 0 W 0.00 $ 0 0 0 W 0o00 $ 0 0 0 W 0.00 S 0 0 0 W 0.42 N 21 4a 0 E 1,50 N 31 43 49 E 2.13 N 26 22 15 E 2,82 N 33 1~+ 36 E 3,67 N 60 :35 30 E 4,90 N 77 21 .40 E 6.18 N 89 38 17 E 7.50 $ 80 4,3 45 E 9,05 5 75 12 25 E 10.36 S 70 ~+9 44 E 10.77 $ 66 46 41 E 11,29 S 61 52 22 E 12,48 S 55 45 29 E 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0.500 0.250 0.750 1.001 0.090 0.125 0,281 0.038 0.258 0.250 0.500 0.7~0 0.264 SECTION DISTANCE 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0 ~ 0.54 0,58 1.08 2.81 4,50 6.07 7.49 9.02 10.25 10.51 10.76 11.43 ARCO DS 13-5 ~YROSCOPIC SURVi~Y JOB NO 5281 23 OCT. 81 RECORD OF SURVEY TRUE NEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 2500 1 0 2499.85 2421.85 S 0.43E 2600 0 0 2599.85 2521.85 N O.OOE 2700 0 30 2699.84 2621.84 S14.90W 2800 3 0 2799.79 2721.79 S52.95E 2900 6 0 2899.47 2821.47 S58.81E 3000 7 30 2998.77 2920.77 $62.63E 3100 10 30 3097.53 3019.53 S65,46E 3200 13 0 3195.43 3117e43 567.26E 3300 15 0 3292.45 3214.45 $68.06E 3400 18 45 3388.13 3310.13 571.66E 3500 21 30 3482.02 3404.02 569.55E 3600 25 0 3573.88 3495.88 566.58E 3700 28 0 3663.36 3585.36 S70,OOE 3800 30 0 3750.82 3672,82 $75.85E 3900 31 0 3836.98 3758,98 S84.00E 4000 31 0 3922.70 3844.70 N89.OOE 4100 31' 0 4008.42 3930.42 N85.1QE' 4200 30 30 4094.36 4016.36 N84.00E 4300 30 15 4180.63 4102.63 N84.08E 4400 30 45 4266.79 4188.79 N85.75E 4500 30 30 4352.84 4274,84 N86,13E 4600 30 0 4439J23 4361'23 N86.58E 4700 31 0 4525.39 4447.39 N86.93E 4800 31 0 4611.11 4533,11 N87.71E 4900 31 0 4696,82 4618,82 S89,95E 5000 32 0 4782,09 4704,09 $88.65E '5100 31 0 4867'35 4789'35 $88'30E 5200 31 45 4952'73 4874'73 S86elSE 5300 31 15 5037.99 4959.99 S85,80E TOTAL COORDINATES 8,76 S 10,40 E 8,76 S 10.95 E 8,7'2 S 10,66 E 11.44 S 11.59 E 15.8/+ $ 18.09 E 21.59 $ 28.34 E 28.43 S 42.40 E 36,59 S 61.05 E 45.79 S 83.43 E 55.77 $ ,110.68 E 67e20 S ':,: .143,13 E 81.,941S ' 1179.73 E 98,44 S 221.18 E 112,66 S 267.50 E 121.54 S 317.43 E 123,78 S 368.85 E 121.13 S 420.28 E 116,28 S 471,17 E 111,03 S 521,47 E 106.53 S 572.02 E 102,92 S 622.83 E 99.72 S 673'11 E 96.85 S 723.78 E 94.45 S 775.23 E 93.4~ $ 826.72 E 94.09 S 878e96 E 95,48 S 931e19 E 97.98 S 983,19 E 101.63 S 1035,31 E CLOSURES DISTANCE ANGLE D M S · DOG LEG SEVERITY DEG/iOOFT 13.60 S 49 52 34 E 14.03 S 51 20 53 E 13.77 S 50 42 4 E 16.29 S 45 22 47 E 24.04 S 48 47 14 E 35.62 S 52 41 57 E 51.05 S 56 9 20 E 71.18 S 59 3 '43 E 95,17 S 61 14 29 E 123.94 S 63 15 13 E 158.12 S 64 50 58 E 197.53 5 65 29 31 E 242.10 S 66 0 27 E 290.26 S 67 9 34 E 339e90 $ 69 2 55 E 389.07 S 71 26 54 E 437,39 S 73 55 17 E 485,31 S 76 8 13 E 533.16 S 77 58 48 E 581e85 S 79 27 0 E 631e28 S BO 36 58 E 680.46 S 81 34 20 E 730.23 S 82 22 39 E 780.96 $ 83 3 11 E 831.98 $ 83 33 2 E 883.98 S 83 53'23 E 936,07 S 84 8 44 £ 988.06 S 84 18 31 E 1040.29 $ 84 23 35 E 0,073 1,000 0,500 2.507 3,001 1.501 3,001 2.502 2.001 3.768 2.765 3,540 3.093 2.478 2.382 3,604 2,008 0,575 0.251 0.663 0.269 0,512 1.004 0e403 1,202 1,065 1,004 0,952 0.511 SECTION DISTANCE 12'~ 12,07 13.49 20,68 31.81 46,89 66.72 90,40 119,02 153.01 191e70 235.46 283,61 334,32 385.28 484.[ 532.98 581.85 631.15 679,99 729,28 779,42 932.93 984,51 1036.42 ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 23 OCT. 81 RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIRE¢ DEG. 5400 31 0 5123,59 5045,59 S86.73E 5500 30 30 5209,53 5131,53 S86.41E 5600 31 0 5295.47 5217.47 S84.38E 5700 31 0' 5381.19 5303.19 S84.95E 5800 32 0 5466.45 5388.45 $84.63E 5900 31 O 5551.72 5473.72 S84.36E 6000 32 0 5636.98 5558.98 S84.05E 6100 32 0 5721.79 5643.79 $83.76E 6200 32 0 5806.59 5728.59 $87.73E 6300 34 0 5890.45 5812.45 N85.73E 6400 34 0 5973.36 5895.36 N85.18E 6500 34 15 6056.14 5978.14 N85.51E 6600 34 30 6138.67 6060.67 N83.26E 6700 34 0 6221.33 6143,33 N84.33E 6800 34 30 6303,99 6225.99 N83,85E 6900 35 0 6386,16 6308.16 N83,38E 7000 35'30 6467.82 6389.82 N82.83E 7100 36 0 6548.98 6470.98 N83.03E 7200 35 15 6630.26 6552.26 N82.95E 7300 36 0 6711.54 6633.54 N85.76E 7400 35 15 6792.83 6714.83 NS6.56E 7500 35 15 6874.49 6796.49 N86.65E 7600 36 0 6955.78 6877.78 N86.90E 7700 37 0 7036.16 6958.16 N87.18E 7800 38 30 7115.23 7037.23 N88.SEE 7900 39 30 7192.94 7114.94 N89.15E 8000 39 30 7270.10 7192.10 N89e23E 8100 40 30 7346.71 7268.71 S89,66E 8200 41 0 7422.46 7344.46 S89.48E TOTAL COORDINATES 105.00 S 1086.89 E 108.05 S 1137.93 E 112.15 S 1188.89 E 116.94 S 1240.17 E 121,68 S 1292.21 E 126.69 S 1344.22 E 131,96 S 1396.20 E 137.59 S 1448.89 E 141.51 S. 1501.73 E 140,56 $ 1556,15 E 136,14:S ~: 1611,89 E 131,59/S 1667.81 E 126,07 S 1724'00 E 119.99 S 1779e95 E 114,20 S 1835e93 E 107,86 S 1892.57 E 100.94 $ 1949,87 E 93.75 S 2007.85 'E 86,64 S 2065.66 E 80.92 S 2123,62 E 77.02 S 2181,74 E 73.61 $ 2239,35 E 70.33 S 2297.51 E 67,26 S 2356,91 E 65.14 $ 2418,09 E 64.05 S 2481,01E 63,15 S 2544,61 E 62.90 S 2608,89 E 63.39 S 2674,16 E CLOSURES DISTANCE ANGLE D M S 1091.95 S 84 28 54 E 1143.05 S 8/+ 34 31 E 1194,17 S 84 36 38 E 1245.68 S 84 36 47 E 1297e92 S 84 37 12 E 1350.17 $ 84 36 56 E 1402.42 S 84 36 1 E 1455.41 S 84 34 30 E 1508,38 S 84 36 59 5 1562~9 S 8~ 50 18 ~ 1617,63 S 85 10 20 5 1672,99 S 85 29 18 5 1728,60 S 85 49 2 5 1783,99 S 86 8 35 [ 1839,~8 S 86 ~6 25 5 1895~64 S 86 44 16 5 1952e~8 S 87 2 11 ~ 2010,0~ S 87 19 35 ~ 2067,48 S 87 35 52 5 2125,16 S 87 ~9 3 E 2183,10 S 87 58 ~0 5 22~0,56 S 88 7 1 5 2298,58 S 88 1~ ~7 ~ 2357,87 S 88 21 54 [ 2418,97 S 88 27 2~ ~ 2~81,84 S 88 ~1 16 5 2609,65 S 88 37 7 ~ 2674,92 S 88 ~8 31 5 DOG LEG SEVERITY DEG/iOOFT 0,352 0.507 0,735 0.292 1,004 1.002 1.004 0,150 2.102 2e859 0,308 0.271 0,764 0.601 0.523 0.523 0,533 0,505 .0.751 1.229 0,796 0.048 0.755 1.005 1,633 1,007 0,0~3 1.102 0.506 SECTION DISTANCE 1087~ 1138 1189,33 1240.62 1292.64 13~4,69 1396.76 1449.59 1502.25 1555,5~ 1609.57 1663.71 1717.93 1771.82 1825.80 1880,33 1991.~ 2046.60 2102.53 2158,96 2214.97 2271.54 2329,38 2389,14 2450.79 2513.15 2576.30 2~40.56 ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 23 OCT. 81 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 8300 42 0 7497,36 7419,36 S89.18E 8400 42 0 7571.67 7493.67 N89,35E 8500 43 0 7645,40 7567,40 8600 42 0 7719.13 7641,13 S87.71E 8700 42 15 7793.30 7715,30 $86,00E 8800 41 0 7868.04 7790,04 $84.56E 8900 40 15 7943.94 7865,94 S83.01E 9000 41 0 8019,84 7941.84 9100 40 0 8095,88 8017,88 S82,86E 9200 40 0 8172.49 8094,49 S80.38E 9300 40 0 8249,09 8171,09 $73.465 9400 40 0 8325.69 8247,69 S71,805 9500 40 0 8402,30 8324,30 S70,135 9600 39 0 8479,46 8401,46 $65,43E 9700 39 0 8557,17 8479,17 S64,55E 9800 40 0 8634,34 8556,34 S62,05E 9900 40'15 8710,80 8632,80 $61,15E 10000 41 0 8786.70 8708,70 S56,10E 10100 42 0 8861,59 8783,59 $55,26E 10200 42 0 8935,91 8857,91 552,935 10300 41 30 9010.51 8932,51 10400 43 0 9084.53 9006.53 $50.50E 10500 44 0 9157,07 9079,07 $50.335 10600 44 30 9228.70 9150,70 S50.88E 10700 45 0 9299,72 9221,72 S49,96E 10800 50 0 9367,25 9289.25 S39.10E 10.900 50 30 9431.20 9353,20 S38.56E 10975 50 30 9478.90 9400.90 $36,61E 11012 50 30 9502.44 9424,44 $37.00E EXTRAPOLATED TO TD TOTAL COORDINATE5 CLOSURES DISTANCE ANGLE D M 5 DOG LEG SEVERITY DEG/IOOFT 64,16 S 2740,42 E 64,26 5 2807.33 E 64,82 S 2874,88 E 67,11' 5 2942,40 E 70,78 5 3009,37 E 76,24 S 3075.57 E 83,28 $ 3140.30 E 91.77 S 3204.85 E 100,33 S 3269.23 E 109,69 $ 3332,82 E 124,22:5 :~: 3395,39~E 2741.17 5 88 39 31 E 2808,07 $ 88 41 19 E 2875.61 $ 88 42 29 E 2943,17 $ 88 41 36 E 3010,21 $ 88 39 9 E 3076.52 5 88 34 47 E 3141.40 5 88 28 50 E 3206,17 5 88 21 34 E 3270.77 5 88 14 31 E 3334.62 5 88 6 53 E 3397.66 5 87 54 16 E 143.41'S 3456,74 E 3459,71 5 87 37 27 E 164.37 5 3517,50 E'I 3521.34 5 87 19 28 E 188,41 5 3576,37 E 215,02 S 3633,40 E 243,59 5 3690,22 E 274,24 S 3746,91 E 308,13 S 3802.48 E 345,49 $ 3857.21 E 384,72 S 3911.41 E 426,27 S 3963,43 E 469.34 S 4015,06 5 513,20 S 4068.11 E 557,49 $ 4122,04 E 602,34 S 4'176,30 E 654,80 5 4227,91 E 714.69 5 4276.12 E 760,54 $ 4311,43 E 783.40 S 4328,53 E 3581.33 5 86 59 3 E 3639,76 5 86 36 47 E 3698,25 5 86 13 23 E 3756.93 5 85 ~8 49 E 3814,95 5 85 22 1E 3872.65 5 84 52 53 E 3930,28 $ 84 22 56 E 3986,29 S 83 51 40 E 4042.40 S 83 19 57 E ~100.35 $ 82 48 35 E 4159.56 S 82 17 51 E 4219,51 S @1 47 34 E 4278.32 S 81 11 46 E 4335,~4 S 80 30 41 E ~377,99 S 79 59 44 E 4398.85 $ 79 44 28 E 1.009 0,981 1.447 1.046 0.815 1,394 0.991 0,868 1.062 1.596 1.071 1.071 2,113 0,556 le438 0,451 2.299 1,067 1.561 1,450 1,532 1,003 0,568 0.678 8.103 0.592 2.006 0,799 SECTION DISTANCE 2705.( 2771.63 2838.15 2904.94 2971.45 3037.53 3102.45 3157,47 3232,33 3296.55 3360,73 3424.55 3488.13 3550,40 3611,34 3~72,43 3733.. 3794.6~ 3855,26 3915e72 3974,47 4033.12 '4093,30 4154.42 4215.98 4276.33 43~4.69 4377,79 4398.80 ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 23 OCT. 81 RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES 11055 50 30 9529.79 9451,79 S37.00E 809.90 S 4348.50 E BOTTOM HOLE CLOSURE 4423.28 FEET AT S 79 26 58 E CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/iOOFT 4423.28 S 79 26 58 E 0.000 SECTION DISTANCE 4423 '{ ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 23 OCT, 81 INTERPOLATED TRUE VERTICAL DEPTHS~ COORDINATES AND CLOSURES FOR GIVEN DEPTHS CODE NAME TRUE MEASURED VERTICAL DEPTH DEPTH TOTAL COORDINATES CLOSURE DISTANCE ANGLE D iq S SUB SEA TOP SADLER 10122 8877,94 354,00 S 3869,22 E OIL/WATER 10397 9082,34 468,62 S 4012,99 E OIL/WATER 10424 9102,05 4?9,89 S 4027,62 E BASE SADLE 10968 94?4,45 ?56,54 S 4307,7? E PBTD 11019 9506,89 787,71S 4331,78 E TD 11055 9529,79 809,90 S 4348,50 E 3885.38 S 84 46 20 E 8799.94 4040.26 $ 8~ 20 21 E 9004.34 4056.11 S 83 12 ~8 E 9024,05 4373.70 $ 80 2 20 E 9396,~5 4~02.82 S 79 41 36 E 9428,89 4423.28 S 79 26 58 E 945~.79 ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 NEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 23 OCT. 81 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 178 178. 100 0 0 278 278. 200 0 0 378 378. 300 0 0 478 478. 400 0 0 578 578. 500 0 0 678 678. 600 0 0 778 778. 700 0 0 878 878. 800 0 0 978 978. 900 0 0 1078 1078. 1000 0 0 1178 1178. 1100 0 0 1278 1278. 1200 0 0 1378 1378. 1300 0 0 1478 1478. 1400 0 0 1578 1578. 1500 0 0 1678 1678. 1600 0 0 1778 1778. 1700 0 0 1878 1878. 1800 0 0 1978 1978. 1900 0 0 2078 2078. 2000 0 0 2178 2178. 2100 0 0 2278 2278. 2200 0 0 2378 2378. 2300 0 0 2478 2478. 2400 0 0 2578 2578, 2500 0 0 2678 2678. 2600 0 0 2778 2778, 2700 0 0 2878 2878. 2800 0 0 2979 2978. 2900 1 1 3080 3078, 3000 2 1 3182 3178. 3100 4 2 3285 3278. 3200 7 3 3389 3B78. 3300 11 4 3496 3478. 3400 17 6 3604 3578~ 3500 26 9 0.00 0.00 0.00 0.00 0,00 0.00 0,00 0.00 0,00 0.00 0.25 leO4 1.87 2.27 1.91 1.23 0,28 0.93 2.10 3.14 4.13 4.98 6.64 8.38 8.98 8.67 10,62 1~.75 20.43 27.04 35,14 44e40 54,79 66e98 82.62 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.07 E 0,64 E 0.96 E 1.26 E 2,83 E 4.43 E 5.89 E 7.13 E 8,42 E 9,63 E 9.95 E 9.89 E 10e26 E 10.38 E 9.80 E 11.15 E 11.05 E 16.21 E 25.91 E 39.14 E 57,35 E 79.84 E 107.32 E 141.53 E 181,28 E ARCO DS 13-5 GYROSCOPIC SURVEY JOB NO 5281 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 23 OCT. 81 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3717 3831 3948 4064 4181 4297 4413 4529 4645 4761 4878 4995 5112 5230 5347 5463 5580 5696 5814 5931 6048 6166 6285 6405 6526 6648 6768 6890 7012 7136 7258 7382 . 7504 7627 7753 3678, 3600 38 3778, 3700 53 3878. 3800 70 3978, 3900 86 4078. 4000 103 4178, 4100 119 4278, 4200 135 4378. 4300 151 4478. 4400 166 4578, 4500 183 4678. 4600 200 4778. 4700 217 4878, 4800 234 4978. 4900 252 5078. 5000 269 5178. 5100 285 5278. 5200 301 5378, 5300 318 5478. 5400 336 5578. 5500 352 5678' 5600 370 5778, 5700 388 5878, 5800 407 5978. 5900 427 6078, 6000 448 6178, 6100 470 6278, 6200 490 6378. 6300 512 6478, 6400 534 6578, 6500 558 6678, 6600 580 6778. 6700 604 6878. 6800 626 6978, 6900 649 7078, 7000 674 12 15 17 16 17 16 16 16 15 17 17 17 17 18 :' 17 16 16 17 18 16 18 18 19 2O 21 22 20 22 22 22 22 25 101.06 S 228.56 E 116.32 S 282.64 E 123.39 S 342,00 E 122,46 S 401.78 E 117.22 S 461,56 E 111.15 S 519.93 E 105,96 S 578,64 E 101,90 $ 637,48 E 98,15 S 695,64 E 94,83 $ 755.13 E 93.44 S 815.38 E 94.72 S 876,30 E 95,71 $ 937,38 E 99.11 $ 998,74 E 103.65 S 1059,45 E 107.25 S 1119,11 E 111,45 S 1178.44 E 117.32 S, 1238,07 E 122.44 128,35 134,73 141,05 141.19 135.89 130.24 122,90 115,77 107.95 99.97 91,13 82,47 77,10 73.45 69.26 65,74 1299,36 E 1360,02 E 1421,48 E 1483,69 E 1547,81 E 1614,68 E 1682,39 E 1750.71 E 1817,91 E 1886,81 E 1956,78 E 2028,67 E 2099e06 E 2171,21 E 2241.&6 E 2313,39 E 2388,86 E ARCO DS 13-5 NEASURED DEPTH AND OTHER DATA GYROSCOPIC' SURVEY FOR EVERY EVEN 100 JOB NO 5281 FEET OF SUB SEA DEPTH. 23 OCT. 81 TRUE NEASURED VERTICAL SUB DEPTH DEPTH SEA MD=TVD DIFFERENCE VERT I CAL CORRECTION TOTAL COORDINATES 7881 7178. 7100 8010 7278. 7200 8141 7378. 7300 8274 7A78. 7400 8408 7578. 7500 8544 7678. 7600 8679 7778. 7700 8813 7878. 7800 8945 7978. 7900 9076 8078. 8000 9207 8178. 8100 9338 8278. 8200 9468 8378. 8300 9598 8478. 8400 9727 8578. 8500 9857 8678. 8600 9988 8778, 8700 10122 8878. 8800 10256 8978. 8900 10391 9078. 9000 10529 9178. 9100 10669 9278. 9200 10816 9378, 9300 10973 9478, 9400 702 732 763 795 830 866 901 935 966 998 1029 1060 1090 1120 1148 1179 1210 1244 1278 1313 1351 1391 1438 1495 28 3O 31 32 35 36 35 34 31 32 31 31 3O 3O 31 31 34 34 35 38 40 47 57 63.73 63.05 63.37 64.24 64.18 65.98 70.24 77.14 86.93 98.66 110.49 131.46 157.88 188.17 222.51 260.98 303.90 354,00 408.16 465.99 526.17 588.89 664,34 759.66 2468,73 E 2550.98 E 2635.57 E 2723,07 E 2812,69 E 2904.75 E 2995.27 E 3084.04 E 3169.07 E 3253.85 E 3337.25 E 3418.54 E 3497.98 E 3575.10 E 3648.59 E 3722.53 E 3795.86 E 3869.22 E 3940.51 E 4009.86 E 4083.56 E 4159.01 E 4235.62 E 4310,04 E ARCO DS 13-5 GYROSCOPIC SURVEY gOB NO 5281 23 OCT. 81 INTERPOLATED VALUES FOR TRUE MEASURED VERTICA DEPTH DEPTH 1000 1000 2000 1999 3000 2998 4000 3922 5000 4782 6000 5636 7000 6467 8000 7270 9000 8019 10000 8786 11000 9494 EVEN 1000 L SUB SEA 922. 1921. 2920. 3844, 4704, 5558, 6389. 7192. 7941. 8708, 9416. FEET OF MEASURED DEPTH. TOTAL COORDINATES 0,00 S 0.00 W 2.31 S 8.74 E 21,72 S 28,26 E 123.78 S 368,85 E 94,81 S 878.95 E 1~2,15 S 1396.18 E 100.33 S 1949,79 E 62.95 $ 2544.61 E 91,78 S 3204.85 E 308,25 S 3802,41 E 776.08 S 4322,86 E HORIZONTAL VIEW ARCO ALASKA, INC. WELL DS 1::5 -5 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE~ I" = !000' OCT. 26~ 1981 14 25 24 T I0 N, R 14 E, U.M. ALL DEPTHS SHOWN ARE TVD . .. 400' 800' IgO0, 1600- 2000- 2400- 2800- SURFACE LOCATION IS 1761' NSL ~ 56' EWL~ SEC. T I0 N~R 14 E~ U.M. VERTICAL SECTION ARCO ALASKA, INC. WELL DS !.3-5 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE: I" = I000' OCT. 26, 1981 AIL DEPTHS SHOWN ARE TVD 4400'~ 48005~ 5600 '~ ......... 6ooo~x~ . ' ' _. i ........ ~. i." _~: P_'i _ ......... .._-. .... i ..... \ 6400-~ . .. 6800 ~7600 ~ 8ooo~N,,,, 8400 '~ . r"... C", ~, ' .,. Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. PS J-S Well NaITe and N~r RePorts and Materials to be received by: '1- IS-/! I Date RaJuired Date Received Remarks I Canpletion Re¡;ort Yes r - 4 e. Well History Yes_gl "¿(,f~., _Samples ~ () f ~~ ~ ð . Core, Chips - ð l Core Description ~~e.,' - -' ð 1)$ ;I , Registered Survey Plat 13 - ) 1'\.Lø~, ',. ð. Inclination Survey 1 Directional Survey \ ~ - pJ Drill Stan Test Reports ~ e..--. - ð Proouction Test Re¡;orts ß, 0 Logs Run . Yes .~h Digitized Data - 8 -'" g, ,,0; LOCATED IN THE APPENDIX WFL IPR LOG CALIPER SURVEY VOLAN CURVE DATA ~ STRATIGRAPHI.C HIGH RESOLUTION DIPMETER OTHER:--7-~w- u,~~-~~ ARCO Oil and Ga~i,.."ompany North Alas[/ .~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer September 17, 1981 Reference: ARCO CASED HOLE FINALS D.S.13-5 8/20/81 CNL/GR Run 1 2"/5" D~S.14-11 8/9/81 CNL/GR Run 1 5" D.S.13-5 8/15/81 ACBL/VDL Run 1 5" D.S.17-10 8/12/81 ACBL/VDL Run 1 5" D.S.7-9 8/12/81 CNL/GR Run 1 5" se sign and return the attached ~op¥ as receipt of data. Mayr F. Kellis North Engineering Transmittal f~605 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL /-~ PHILLIPS ,~,.~~COOs. SOH I 0 ~s~ Oil & ~as Co~n~aio~ MARATHON Ancho~ge CHEVRON ARCO Oil and Gas Company is a Division of AtlanticRichfieidCompany ARCO Oil and Gas C-,mpany North Alask~ .strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer September 11, 1981 Reference: ARCO Open Hole Finals D.S.13-5 9/9/81 FDC Run 1 5" D.S.13-5 9/9/81 FDC/CNL Run 1 5" D.S.13-5 9/9/81 BHCS Run 1 2" & 5" D.S.~3-5 9/9/81 DIL/SFL Run 1 2" & 5" D.S.13-5 8/9/81 CPL(Cyberlook) Run 1 5" ~/~lease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #591 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY MARATHO~Iaska 0il & Gas Cons. CHEVRON A~chora~9: ARCO O11 and Gas Company is a Division of AtlanticRichtielclCompany ARCO Oil and Gas r"3mpany North Alasl{ ,istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer September 3, 1981 Reference: ARCO MAGNETIC TAPE & LISTING D.S.13-5 8/9/81 Tape #62123 Schlumberger Run 1 Please sign and return the attached copy as receipt of data. Mary' F. Kellis North Engineering Transmittal #568 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG, MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil ancl Gas Company ~s a Division of AtlanticRichtieldCompany EXXON MOBIL GETTY PHILLIPS A T H 01~"~/~, ~,. ~1.~,~/~ CHEVRON Alaska Oi~ & Gas Cons. Commissior~ .Armhorage ARCO Oil and Gas,.r"~mpany North Alask( istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer September 1, 1981 Reference: ARCO Magnetic Tapes & Listings D.S.13-5 8/26/81 Tape #CN/Multi-Spaced 9300-11050 Dresser sign and return the attached copy as receipt of data. Mary ~. Kellis North Engineering Transmittal #558 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG ~ MANAGER D&M GEOLOGY STATE OF ALASKA EXXON PHILLIPS SOHIO Alaska 0il & Gas Cons. Commissi0. MA RAT H O N Anchorage CHEVRON ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ARCO Oil and Gas.,r"~mpany North Alask( istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 25, 1981 Reference: ARCO DIRECTIONAL SURVEYS D.S.13-5 8/13/81 Single Shot D.S.14-11 7/22'/81 Single Shot D.S.16-4 4/12/81 Gyroscopic D.S.16-5 4/13/8i Gyroscopic P~~lease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal#544 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Division o! AtlanticRichfieldCompany ARCO .~laska, Inc. ~..' Post Office B~ Anchorage, Alaska 99510 Telephone 907 277 5637 August 27, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-11 DS 12-12 .DS 13-5 DS 14-11 DS 1 6-14 DS 17-9 DS 17-10 DS A-3 DS A-4 ,DS B-4 DS B-5 Dear Sir' Enclosed please find' 1. The Monthly Drilling Reports for DS 14-11, DS 13-5, DS 17-10, DS A-4. e The subsequent Sundry Notice for DS 16-12. ... The Well Completion Reports for DS 12-11, DS 12-12, DS 16-14, DS 17-9, DS A-3, DS B-4, DS B-5. Sincerely, P. A. VanDusen District Drilling Engineer PAV/GLA:sp Enclosures 0il & 6as Cons. Camm~ssi~ ARCO Ahlska. Inc is a su[]sidiary of AtlanlicRi('htieldComparw STATE OF ALASKA ALASKA (- . AND GAS CONSERVATION Cd' ,vllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-103 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 50-029-20626 4. Location of Well at surface 1761' FSL, 56' FWL, Sec 13, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 7R' RKR 6. Lease Designation and Serial No. ADL 2831 5 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. DS 13-5 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool For the Month of. July ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1130 hrs, 7/21/81. Ran 13-3/8" cst. Drld 12¼" hole to 2690', as of 8/1/81. See attached Drilling History. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 94#, H-40 conductor to 110'. Cmtd w/300 sx Permafrost. 13-3/8", 72#, L-80 cst w/shoe @ 2661'. Cmtd w/2531 sx Fondu & 400 sx Permafrost. See attached Drilling History. 14. Coring resume and brief description n/a 15. Logs run and depth where run None to date. ,~16. DST data, perforating data, shows of H2S, miscellaneous data n/a 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TITLE Dist. Drilling Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate DS 13-5 Drilling Hi story NU 20" Riser. Spudded well @ ll30 hrs, 7/21/81. Drld 17½" hole to 2675'. Ran 67 jts 13-3/8" 72#/ft L-80 csg w/shoe @ 2661 '. Cmtd 13-3/8" csg w/2531 sx Fondu & 400 sx Permafrost. ND 20" riser. Instld"13~3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 15' new form. Tstd form to 12.5 ppg EMW - ok, as of 8/3/81. ALASKA OiL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton ~~ July 27, 1981 Chairman THRU: Lonnie C. Smith~ Commissioner Bobby Foster ....... , · Petroleum Inspector Witness BOPE Test on ARCO's D.S. 13-5 Sec. 13 T10N, R14E UM. Permit # 81-103 F_riday.~ July 24, 1981 I traveled this date to Prudhoe Bay to witness the upcoming BOPE test on ARCO' S" ' D.'S. 13-51 ..... s_aturday, .J. uly 25, 1981 The Bop'E test began at 7:30 AM, and was concluded at 9:30 AM. As the .,a~tached BoPE 'test report'shows there were no failures. In summary, I witnessed the BoPE' test on ARCO's D.S. 13-5. BF~vl O&G #4 r"""" '. ('. .' 4/80 \ STATE OF ALASKA ". ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date ---7- d.,s - 8 / vlell D,s,. IJ-S Operator Representative '0/:97 ¡.::;~./ Well --D.~. /$ -S Permit #~'I- 103 Location: Sec 1.3 T~R/qEI1 um " ~CaSing Set @ ,Z66 I ft. Drilling Contractor I!b. ~;J ~ig #~t. ~epresentative ¿. De.//}v1/ieA!f Location, General ACCUHULATOR SYSTEM \tlell Sign Full Charge pressure.....:::S)([JO psig General Housekeeping Pressure After Closure /500 psig Reserve pit 400 psig Above Precharge Attained~min~se( Rig Full Charge Pressure Attained: It.-i:) min& se< N ¿ICO/ ~.:<OO/ ~i.}() o;¡;(~'" 0 . 2 / f3ÐO/ ti<8tJf) /~eS 6),2. 19" C ps ~g Controls: Master yæ.,.:5 Remote Blinds switch cover BOPE Stack Test' Pressure Kelly and Floor Safety Valves Annular P~eventer J 300.0 Upper Kelly I Test Pressure S()()() Pipe Rams' 2 &ô 0 Lower Kelly I Tes t Pres sure S()()O Blind Rams / Ball Type I Test Pressure ItJJ"Í' Choke Line Valves / Ins ide BOP J Tes t Pres sure /Ýj 1- H .C.R. Valve I Choke ManifoldLjf'::> Test Pressure SJ")ð D Kill Line Valves No. Valves. J~ Check Valve No. flanges .31 Adj ustable Chokes ¡ I - po cS . Hydrauically operated choke J Test Results: Failures Test Time Z hrs. Repair or Replacement of failedequiprnent to be made within - days and Inspector/Commission office notified. Remarks: Distribution orig: - AO&GCC cc - Operator cc - Supervisor Inspector, July 13, 1981 Mr. P. Ao VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 13-5 ARCO Alaska, Inc. Permit No. 81-103 Sur. Loc.: 1761'FSL, 56'F~'~L, Sec 13, T10N, R14E, U~. Bottomhole Loc..: 1427'FSL, 893'FEL, Sec 13, TiON, Ri4E, Dear ~r. VanDusen: Enclosed is the approved application for permit to drill the abow.~ referenced, well. Well samples and a mud log are not required. A directional survey is required. If available, a tat~ containing the digitized log .information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys o Many riverz in Alaska an~ their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the ~abitat Coordinator's office, Department of Fish an~ Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and. the regulations promulgated thereund~er (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Prudhoe Bay Unit DS 13-5 -2- July 13, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dri 1 led. In the event of suspension or abandonment, please give this office adequate advance notification so that we. may have a witness present. Very truly' yours, Chairman of Alaska Oil & Gas Conservation Commission Enclosure cc: Department o.f Fish & ~ame, H. abitat Section w/o encl. Department of Environmental Conservation %~/o/encl.. ARCO Alaska, Inc. ~i ?est Office ~-3c~ .... 350 _,:U~chorage, Alaska 99510 -~1 ~ ~:07 277 5~37 :: ,.. Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS13-5 Permit to Drill Dear Sir: Enclosed please find the Application for Permit to Drill the subject well and the required $100.00 filing fee. Attached to the application are: a drawing of the proposed well path, a proximity plat showing the location of DS 13-11 to DS 13-12, and a draWing and description of the BOP equipment including anticipated surface and bottom-hole pressures. In addition, pursuant to Rule 4 (b) of Conservation Order No. 145, we have examined the logs and drilli.ng data collected while drilli.ng the surface hole (0-2700' TVD) of DS 13-12, and we do hereby request that the requirement for a surface hole diverter system be waived for DS 13-5 and all subsequent wells to be drilled from Drill Site 13. Very truly yours, P. A. VanDusen Di stri ct Dri 11 i.ng Engineer PAV/JBK'sr Enc1 osures .ARC:© AIasP, c, ];~c. is m subsidiar~¢ o,[ A~ian~,icRichfieldCompany JUL 1 3 1981 A~aska O# & ~as Cons. AnChorage C°mmis$io~7 · '[ STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENTOII_~ SINGLEZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] -- 2. Name of operator ARCO ALASKA, INC. i crclu: 3. Address ~ L_ ~ ~_ ! ~ I,, " P.O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of well at surfaceJ U L1 3 l B : it or,ease name 1761' FSL, 56' FWL, Sec 13, T10N, R14E, U.M. Prudhoe Bay Unit At top of proposed producing interval Alaska 011 & Gas C01 1447' FSL, 1372' FEL, Sec 13, T10N, R14E U.M. Anch°r~ge DS 13-5 _ At total depth 11. Field and pool 1427' FSL, 893' FEL, Sec 13, T10N, R14E, U.M. Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Prudhoe 0i l Pool 78' RK8 ADL 28315 12. Bond information (see ~20 AAC 25.025) Type Statewide Suretyand/°rnumbe~'ed Ins Co #8080-26-27 Amount $500,000 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 ~v ll-miles __ ,~,~_-'4 974 feet wen (@ tOD zone~ 2675 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. ApprOximate sp~d date 10885 TM:D 9572 TVD feet 2560 __July 15. 1981 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~UU~ - psig@__ Surface KICK OFF POINT3000feet. MAXIMUM HOLE ANGLE37°I (see 20 AAC 25.035 (c) (2) 4669 psig@ 9572 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BoTToM TVD (include stage data) 30 2~ 94# H-40 Welde~ R-3 0 I 0 110 110 250 sx PFII to surf. 17½ 13 3~8 72# L-80 Butt R-3 0 ~ 0 2700 ~2700 2300 sx FONDU + 400 PF 12¼ 9 5/E 47# L-80 ~ Butt R-3 0 . 0 9818 8701 500 sx "G" 1st Stage S00-9 ; Butt R-3 ~ I 300 sx PF II 2nd Stac. 8½ 7 29# L-80 Butt R-3 i_9520 I 8458 10885 9572 750 sx Class "G" CMT. 22. Describe proposed program: ARCO Alaska, Inc. proposes to directionally drill this well to 10885'MD (9572'TVD) to product the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested to 5000 psi. The BOP Equipment will be pressure tested each week therefore. ' A string of 4½" 12.6 L-80 tubing, packer and necessary provisions for subsurface safety equipment will be run.. A non-freezing fluid will be left in all uncemented annuli whthin the permafrost interval. The packer will be set above the Sadlerochit. The downhole safety valve will be tested and in- stalled upon conclusion of job. *Bottom hole pressure based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. 23. I hereby certify that the fo~go'~t to the best of my knowledge SIGNED · TITLE District Drilling Enginee~rE 7~- lO-ECl The space below for Commission use CONDITIONS OF APPROVAL --_ Samples required Mud Icg required Directional Survey required APl number []YES [~NO []YES f~NO .~YES []NO 50- ~::2Z¢- ~.O/~,~=~ Permit number Approval date .... ~/- /O~ 1')?/14/R1 SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY... ,COMMISSIONER DATE by order of the Commission ~-...y Form 10401 Rev. 7-1-80 Submit in triplicate 13-5/8" ~ STACK DIAGRAM Accumulator CaDacit>, Tes.t. RNNULRR PREVENTER BL I ND" RRHS PIPE RRHS ILLING SPOOL · e e e · · 1, Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of-the regulator. Observe time, then close all units simultan- eously and record the time and pressure re- maining after all units are closed wi th charging pump off. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi ; remaining, pressure.) 13-5/8" BOP Stack Test Fill BOP stack and manifold with a non- freezing liquid. Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. · Close annular preventer and chokes and bypass valves on mani fold. PIPE RRMS · In each of the following tests, first hold a .250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. q66~l - Maximum Anticipated Bottom Hole Pressure, psi. Z/O0?_ - Maximum Pressure to which BOP's could be subjected. Calculated by allowing a gas bubble at reservoir pressure to rise w/o expa~nding but cooling to 80VF, psi. RECEIVED JUL 1 ] 1981 Alaska Oil & Gas Cons. Commission Anchorage 5. Increase pressure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe -'rams. Increase pressure to 5000 psi & hold for 'at least 3 minutes. Bleed pressure to zero. 7. Cl'ose valves directly upstream of chokes & open chokes. Increase press, to 5000 psi & hold for at least 3 min. Bleed pressure to zero. 8. Open top 'set of pipe rams then close bottom set of-pipe rams. Increase press, to 5000 psi below the bottom set of pipe rams & hold for at least 3 mi nutes. .9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. ll. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold & lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of De Gasser. 1.6. Record test information on Blowout preventer test form. Sign and send to Drilling Super. 17. Perform complete BOPE test once a week and functional operate BOPE daily. 900 200 100 500 . ~ ~ NORTH 0 I I00 200 I 300 I 400 - 300 - 200 - 100 - O _ 100 - 200 _ 300 _ 400 _ 500 _ RRCO RLRSKR, INC, DS 19, WELL NO-' 5 PROPOSED PRUDHOE BR¥, NORTH SLOPE, RLRSKR ERSTMRN WHIPSTOCK, INC, 367'7 4091 0 · ~/-~l~;Of¢,/,~_] ,a EREBY ~ERTIFY THAT-I AM '-'--' I~'~OPERLY REGISTERED AND LICENSED \ THE STATE OF ALASKA AND THAT Z I~'~ . _ x = 687,27~.57 x = 687,359.h~ _ LAT = 7oo]3'o7.o~5'' LAT = 7°o~3'o3.5o~'' LONG = ]~8°29'20.8~7'' LONG = ]q8°29']~.592'' 6. Y = 5,931,712.29 9. Y = 5,931,36] .37 x = 687,304.04 x = 687,387.57 LAm = 70°13'O5.910'' LAT = 70°13'02.439'' LONG = 148°29'20. ]33" LONG = 149°29' 17.961" 7. Y = 5,931,595.51 10. Y : 5,931,245.26 X = 687,331.97 X = 687,415.71 LAT : 70°13'04.755" LAT = 70°13'01.290" LONG - 148°29'19.407'' LONG = 148o29' 17.228" AtlanticRichfieldC0mpany ~ DATE' DRAWING No: NORTH AMERICAN PRODUCING DIVISION I~-¢-~o ALASKA DISTRICT- PRUDHOE BAY ! CHECK LIST FOR NEW WELL PER.MITS Company Lease & Well No. ITEM APPROVE DATE YES NO (1) Fee (2) hoc (2 thru 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... (3) Admin ~/w.O/~ ~-/J-2/ 9. (9 thru 11) 10. 11. Does operator have a bond in force .................................. .~63~ Is a conservation order needed ...................................... · ~ Is administrative approval needed ................................... /~ (4) Casg 12. 13. 14. 15. 16. 17. ~18. 19. 20. Is conductor string provided ................... ~ ..................... ~ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... ~ 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.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... ~ (5) BOPE ~ 7-~ 5-gl [21 thru 24) 21. 22. 23. 24. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~D~ psig .. ~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. (6) Add: 25. Additional requirements ............................................. Additional Remarks: REMARKS Geology: E ng in~eF ij~g: HWK ___~ \ LCs ~~ BEW ~ W¥~A~ RAD rev: 03/10/81 ' INITI'~L 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 '~ie. 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 APPEbI. DlXl ,, No special'effort has been made to chronologically organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS PAGE 1 OF 2 Company_ ARCO ALASKA INC. Well D.S. 13-5 ~C[?,~~''' - ~.%/, ,,--~ ECC# ~42 Field PRUDHOE BAY , , ""' ,,~ ......... 4/20/88 County, State NORTH SLOPE, ~ASKA ~ k 'm~E~w D~E 5/25/88 ~.'~',., .,',' ,. Curve Name Abbrev ) Standard Curve Name Logs Used Scale FILES 1-3 CCL Casing Collar Locator ~DK-100 ~00-600 LS Long Space " -2700 SS Short Space " ~6000-54.000 __ G1 Gate 1 I ,, ]-72000 GLES G2 Gate 2 " b-12000 GR Gamma Ray " ]-100 BKL IBackground Lonq Space' " )-300 BKS Background Short S~ace " -300 MON Monitor " CSS Capture Short Space " 1 ISS Inelastic Short Space " MSD Mean Std. Dev. " t8-0 SGMA Sigma " 60- O - RATO Ratio of CaptureCounts " 33-3 RICS I Ratio or Inelastic to Capt~" 43-0 RIN IRatio of Inelastics " 14-4 RBOR Borehole Ratio " 3 to-1 Page 2 of 2 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska~ Inc. D.S. 13-5 Well ECC# 3342 Field Prudhoe Bay County, State North Slope, Alaska Date DELIVERY DATE 4/20/88 5/25/88 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale SGAV RNAV RCAV RTAV GR FILE 4 Average Sigma Average RIN Average RICS Average Ratio Gamma Ray Pass 1 PDK-100 60-0 14-4 43-0 33-3 i 0-100 ** REEL HEADER ** REEL NAME : DATE : ...... ORIGIN : FSYS SERVICE NAME: BI'LIS REEL CONTINUATIOk NUMBER: 01 PREVIOUS REEL NA~E :. COMMENTS: DRESSER ATLAS LIS CUSTCMER TAPE --- CRE~TE£ BY SDS PROGRAM LENGTH: 132 BYTES ** TAPE HEADER ** TAPE NAME : DATE : ORIGIN : FSYS SmRVICE NAME: BAS;GR TAPE CONTINU~T!Ok NUMBER: C1 PREVIOUS TAPE NA~E : COMMENTS: LENGTH: 132 BYTES R 2.0 ** PILE PEAOER # I ** FILE N&ME: BASEGR.O01 '. SERVICE kAME: VERSION ,~ : 1 BATE: 85/11/2C MAX RECORD Lr'RGT~': lgZ4 BYTES FILE Typr-: LO PREVIOUS PILE N~:E: , ** INFORMATIC~ ~]ECOR~S MNEM CONTENTS APIN : 5002~2~26 CN : ARCC ALASKA, INC. WN : DS 13-S FN : PRU~OE BAY COUN : NORTH SLOPE STAT : ALASKA LCC : 15~.~0 FORMAT ** UNITS ENTRY BLOCKS TYPE ¢ 8 9 11 0 ENTRY DESCRIPTION 1 DE~T~, S DECREASE 60.0 F R~,~E SF~CING .lIN FR~E SPACING UNITS 12 MAXIMUM FRAMES/.~ECORD TErMINaTOR -0.500 LEVEL SDACiNG DATUM SPECIFICATION BLOCKS CURVE NAME ~EPR CODE SIZE SAMPLE UNITS CU~V= REFR NAME CCCE SIZE --ii-- Iii-- SAMPLE UNITS LS ~ ~ 1 CPS G1 68 Z, I CPS G2 68 4 I CPS MON 68 4 1 CPS 5KS 68 4 1 CPS ISS 6.8 4 1 CPS MSD 65 4 1 SU RgOR ~ 4 I ~I~ RiDS 6~ 4 I SS GElS G~ ~KL DSS SGM.5 RATO RiN ~8 ~8 6~ d8 68 68 r/MN CPS CPS CPS API SU ** FORMAT ** ENTRY BLCCKS TYPE ENTRY DESCRIPTION /-* 1 C:PT~S C-~CRE~SE "0 FRAME SP~CING 9 .liN F~AF"-= S:~C'NS UNITS C T -'_ RI,."Z NAT C q -S..,'::CO L=V=L_ _ ,.,,mA,., EATUM SPEC!Fi~TICN 3LCCKS CURVE REOR CURVE N,&~I: CODE S'Z= SAMPLE LNITS mlII IIIi i--iii! CCL 6~, 4 1 2iH SP3 LS 68 4 1 C ,~ SS G1 ~;: 4 1 ~PS GElS .~,~, G2 .5~ ~ 1 CPS ~,ION 6~, 4 1 C~S BKL BKS 6~, 4 1 C~S DSS ISS 68 4 1 CPS SGM~ MSC 68 4 1 SU R&TO RBOR 68 4 1 DIM RIN RIDS 6~ 4 1 DiM REP~. Ce"2. E 68 ~8 S4~PLE 1 1 1 1 1 1 1 1 1 UNITS IIIim F/MN CPS CmS C~$ SU DIM DIM DEPTH 10975 .COO FT 3345 . 1 87C IImIImiI.iIimillllIlimmlilIIii CCL O.CCO SPD 27.C97 LS G1 29,997 GElS 655284,4C0 G2 MON 0,~00 BKL ~9.993 ~KS ISS 49,995 SGM~ -13,953 R~OR O,CGO RIN O,C~O ~ICS 7~,992 4,224 2.5CC SS GR DSS RATC 19,99~ 56,629 19,998 t,008 DEPTH IOQCO.CC~ FT 3322.327C M IlmmmIImIIImmmiiImImmmmmiimimm CCL G,CCO SPD 32,165 LS G1 21,242 GElS 1~7115,~CC G2 MON 0.000 8KL ~9.046 BKS /SS 19,670 SGMA 5.742 MSD RBOR 0.759 RIN O.COC, RIDS DEPTH lOgOO.COO FT 3291.847C M CCL O,CCO SPD 32,997 LS G1 31,851 G$IS 377E58.100 G2 MON C.CCO BKL 20.317 BKS ISS 23.382 SGMA -5,980 HSD RBOR 1,606 RIN 0.001 RIDS , 11 .99E 15,074 31.6C1 9.102 1,2~4 25.344 11 .9~6 46,/.76 7,112 I ,348 SS GR DSS RATC SS GR CSS RATC 29,657 2~,98~ 15.556 2.~36 10.362 20.638 17,347 0,425 OEPTH 10700.£00 FI 3261.3670 CCL 0.000 SPD 32.997 G1 3.705 GE1S 439523.900 MON 0.000 BKL 33.118 ISS 18.116 SGM~ -230.492 RBOR I .607 RIN O.OOO OEPTM 10600.000 FT 3230.8860 H liIIIii--III----IIIi~IIIiI--I~.--III CCL 0.000 SPD 32.997 G1 11.330 GElS 314371.800 MON O.CO0 BKL 23.103 ISS 13.570 SG~A -216.875 RBOR 1.484 RIN O.CCO CEPTH 10500.CCC FT 3200.4060 M CCL O.CO0 SPO 33.573 G1 19.3~3 GElS 257~81.100 MON O.CCO BKL 8.493 ISS 2.381 SGMA -303.254 RSOR 1,270 RiN O,CO0 OEPTM 10400.C00 FT 3109.9270 M CCL '0.060 SPO 33.276 G1 18.793 GElS 460763.500 MON O,CO0 8KL 105.615 ISS 2.458 SG~A -19.C, 38 RSOR 1.706 RIN 0.000 OEPTP 103OO.CCG FT 3139.446C M CCL' O,O00 SmD 33.346 G1 9,332 G~lS 369550,100 MON O.O00 BKL 37,]78 ISS 13.752 SG~ -62.252 RSOR 1.207 RZN O.CO0 DEPTH 10200.CC0 FT 3138.96~C N CCL O. CC'3 SPO 33.80:9 G1 2;'.551 GElS 183262.100 M, ON O.C,CO 6KL 36.60~ ISS 4.149 SGM, A -15.226 RBOR 0.820 RIN 0,000 DEPTh 19100,C30 FT 307a.480C M CCL O.COO SPD 33.9~7 G1 6.~17 GElS 3~7317.~0~ MON O.CO0 BKL 72.603 ISS 10.967 SG~A -24.125 R~OR 1.372 RiN O.COO DEPTH IOCO0.CCO FT 3048,006C M CCL O,CO0 SPD 33,887 G1 49,3~9 GElS 187041,300 MON 0.060 BKL 239.73~ ISS 30.864 SGMA -11.570 RBOR 0.516 RiN O.CCO DEPTH 9919.50G FT 3023.470C M LS G2 BKS MSD RICS LS G2 EKS MSD RICS LS 62 BKS MSD ~ICS LS G2 BKS MSD RICS LS G2 BKS ~!SO RICS LS G2 5KS MSD RICS LS G2 BKS MSD RICS LS G2 BKS MSD RICS 7.082 9.609 35.578 5.2~ 2.921 3.057 13.635 27.7C2 13.093 1.452 1~,149 18,245 18.470 24,208 C,la2 12.27~ 19.259 215.984 11.571 C.158 17,332 51,934 C.¢22 15,66.¢ 18,0~.5 32,061 ~ .981 0,207 17.2~5 8.990 77,904 27.834 1,0~8 3~.698 46.46~ 240.351 5.684 C.782 SS GR CSS RATO SS GR CSS RATC SS GR CSS R~TO SS GR CSS RATC SS G~ CSS R~TO SS GR CSS R~TC SS GR CSS D, ATO SS GR CSS RATC 5.823 19,~73 6.201 e.815 7.511 12.970 9.348 2.459 6.854 20.$15 14.68~ C.406 17.173 103.123 15.59e 1.337 2~ . 3.S1 27.166 14.¢16 1.234 20,810 29.629 20,OOC 1.324 16.2~0 44.240 10.56'7 0.906 41.309 143.411 39.493 1.097 mmmm CCL O.CO0 SPD 01 0.000 GElS MON O.CgO BKL ISS O.CCO SGM~ RBOR 1.COO RIN 33.997 6551E4.600 99.990 1.822 0.008 STARTING DEPTh =10975.000 FT ENDING D~FTH = 9~19.500 FT LS 02 BKS MSC RZCS 3345.1870 M 3C23.4700 M C.OCC C.OCC 2C9.979 C .6C,~ C.OCC SS GR CSS RATC G.O00 78.136 0.000 O.O00 '* FILE TRAILER ** FILE NAME: B~SESR.OOl SERVICE NAME: VERSION # : 1 DATE: ~5/11/ MAXIMUM LENGTH: 1024 FILE TYPE: LC NEXT FILE N~E: ** FILE HEADER # 2 *~ FILE NAME: PASS 1.002 SERVICE NA~E: VERSION # : 1 OATE: 85/11/?C MAX RECORD LENGTh: 1024 5YTES FILE TYPE: LC PREVIOUS FILE NA~E: . ** INF~RMATiCk RECORDS ** MNEM CONTE~TS mmmm aPIN : 50029206'26 CN : ARCC ~L~.SKa, INC. WN : DS 13-5 FN : mRUE~OE BAY COUN : NORT~ SLOPE STaT : ~LASKA LCC : 150.00 ** FORMAT ** U~ZTS ENTRY BLOCKS TYPE ENTRY ~ESCRIPTION Z, 1 DEPTHS DECREES=. 8 60,0 FR~E SPACING 9 .lIN FR~E SP~CZNG UNITS 11 12 M~XIMUM FR~MES/RECORC 0 TERmINaTOR -~.500 LEVEL SP~CING DATUM SPECImIC~TION BLOCKS CURVE REPR NAME CODE SIZE CCL LS 01 02 68 4 68 4 68 4 68 4 · , . , SAMPLE UNITS 1 DZM 1 CPS I CPS 1 CPS ', . ,. · . CURVE N~ME SS GElS GR REPR COCE SIZE 4 , S~MPLE 1 1 1 1 UNITS F/MN CPS CPS BKS 68 4 1 CPS ISS 68 4 1 CPS MSD 68 4 1 SU RBOR 68 4 1 DIM RICS 68 4 I ** FORMAT ** .. :~KL Ob 4 '1 ess 6S 4 I APl SGM~ 68 4 I SU RATO 6~ 4 1 RIN 68 4 I DiM ENTRY BLOCKS TY,~E ENTRY CESCRiPTION 4 I CEPlHS DECrEaSE 8 6C.0 FRAFE SPACING 9 .lIN FRAFE SP~CiNG UNITS 11 12 FAXZMUM =RAMES/~ECORg 0 TE~FINATC~ -C.500 LEVEL SPaCiNG CATUM SPr-CIFIC&TION BLOCKS CURVE REmR NAME CCDE SIZE SAMPLE LNZTS ilil !ill CCL 5~ 4 1 .3it','I LS 6,~ ~ 1 CPS ~1 ~ ~ 1 CPS G2 68 ~ I CPS MON 6E' 4 1 CmS BKS 6~ 4 1 CPS ISS 68 4 1 MS3 6~ 4 1 SU RSOR 68 ~ 1 RiCS 68 4 1 CURVE N~r~E CO'E SIZE SAMPLE UNITS mill !il-- !!1111 mi/I-- SP~ ~ 4 1 F/MN S,S ~S 4 1 CPS G~IS ~ 4 1 CPS GR 5KL 68 4 1 CoS CSS SGM,a ~ a I SU R~TO RIN 6,~ 4 1 C,!M DATA DEPTm 10974.C00 FT .., 3344.e~2C M CCL O.CCO S°D lC.C~9 G1 2319.76~ GElS 9556C.13C, MCN '45.995 BKL 129,9~7 ISS 315798.4~ SGM~ 27,0~3 RBOR 2.C6~ RIN 12.63~ DEPTH 10900.C0C FT 3322.327C M LS G2 BKS MSg RICS CCL O.CC~ S2O 1~.999 G1 7352.906 GEI,S 106~30.2:30 MON 55.C~1 BKL 39.340 ISS 325946.300 SGMA 1~.632 RBOR 1.88~ RIN 12.176 . , ', " ".,DEPTH 10800.CC0 FT ,. ', CCL ' ',:. G1 '..!:'.,::. M 0 N ISS RBOR 3291.8~7C, M LS BKS MSO RICS O.COO SmC 6645.773 GElS 47.711 BKL 298341.300: 1.87~ RIN 14.999 LS 95369.9~0 G2 61.157 BKS 18.780 12.184 RICS OEPTM 10700.C00 FT 3261.367C M CCL · . , 499.95C SS 13518.650 519,947 GR 4~,069 399.96C CSS 12078.800 0.9,4C RATC 27.053 26.145 121g.148 SS 23383.630 2111,366 GR 28.345 167.0~2 CSS 17438.240 ~.221 RATC 19,191 16.691 1053.4~1 SS 20995.200 1912.464 GR 29.809 184.921 CSS 15644.940 C.271 RATO 19.37~ 19.070 MON 44.355 BKL 3 ISS 302417.300 SGM~ 1 R~OR 1.930 RIN I ¢.'1¥U 7.337 9.80£ Z,C'~4 9r'PTH 106DC.CCC FT 3230.886C M CCL 0.000 $P9 1 G1 7412.418 GElS 9475 MON 42.571 BKL 2 I$S 293470.103 SGM~ 1 RSCR 1.8£4 RIN I 4.999 5.750 3.C10 8.125 2.059 DEPTP.: 10500.C00 FT 3200.406C M iii CCL O.COO SPO 1 G1 8083.703 GElS 10083 NON 53.511 BKL 3 ISS 311530.800 SGM4 1 RSOR 1.912 R!N 1 4.999 6.700 8.9C4 6.923 2.63~ DEPTH 10400.0CC FT 3169,927C M CCL O.O00 SPD 1 G1 7837.5C4 GElS 10351 MON 47.427 BKL 4 ISS 309950.100 SGM~ 1 RSCR 1.916 R~N I 4.9~9 4,7C0 ~,394 2.047 OEPTH 103C0.CC0 FT ~139.446C N ii CCL O.CCO SP3 14.999 51 ~803.7~3 GElS 97550.31C MON 57.~C8 BKL 198.773 ISS 264C60.9C0 SGM.~ 20,891 RSOR 1,462 RIN 11,180 BKS MSD RICS LS 62 BKS MSD RICS LS G2 BKS MSD RICS LS G2 BKS RICS LS G2 HSD RZCS D$FTH_ 102C0.~C0 FT 3108.'~66C M IIlIilllIIiIiiiiilIIiIi CCL 0.000 SPC 15,C72 LS G1 1C903.570 GElS 94~3~.56~ G2 NON &7.372 BKL 215.153 8KS IS$ 263854.100 SGMA 17.3~5 MSD R80~ 1.451 RIN 1C.~15 RIDS DEPTH 10100.C, CC FT 3078.486C M IIlIlIIlIIIiIiIIIllI CCL O.O00 SP3 14.999 LS G1 9953.CC~ SE1S 113~61.5CC G2 MON 52.2C2 5KL 293.053 ~KS ISS 2.~3739.~00 SG~$ 18,2c7 MSD RSOR 1 .561 RIN 11 ,C92 RICS DEPTH 10C30,CC0 IFT 3048,0066 M mmImmmmmmmmmmliimimmmmmIlmmmiI CCL O.CCO SPD 15.242 G1 ~718.527 GElS 97264,690 MON 47.311 EKL 391 .C75 ISS 26~483.100 SGMA 24.480 RBOR 1.538 RIN 11.298 DEPTH 9918,5CC FT 3023.165C M ImmIIm/mmliiimmmIIiImIm__ CCL O.u~O0 SPD 15.998 G1 79.992 GElS 11~91883 MON 1.600 BKL 209.979 LS 62 BKS MSD RICS LS G2 BK$ 17~.£99 C.20~ 18.815 11~7.799 2277.6z, 3 143.27~ 0.37~ 17.78C 1-292.493 2613.24~ 141.949 0.252 18.084 1255.22C 25~8.9CC 211.18C C.555 17 :q8 I'~ 1543.0.55 320.0~1 13,19d 178~,118 3488,94C 394.301 C.322 12.58C 1972,717 4C3.633 0.355 12,817 12d7'.097 14C~ .591 5a4.1C1 C.43a 14.982 49,995 9.999 299.97C CSS RATO SS GR CSS RATC SS GR CSS RATC SS GR CSS RATC SS GR CSS R/~TC SS GR CSS RATC SS GR C S S RATO SS GR CSS RATO SS GR CSS 1~07~.460 20.067 22914.4~0 15.809 1~505.340 19.611 23081.090 18.245 17226.810 17.871. 2320~.920 87.~47 17375.500 18.565 32349,430 28.910 20011.140 2C.923 32994,390 44.725 2C974.140 18.401 33720.590 74.816 2~_137.140 17.176 28333,380 184.993 1792C.950 22.291 2~9.971 103,577 199.980 -- . ,~.~ RBOR I .560 RIN STARTING DEPTH =10974.000 FT ENDING DEPTH : 9918.500 FT 6.865 RICS 3344.8820 M 3023.1650 M ~.U~> 17.$5C 'N~ I'U ** FILE TRAILER ** FILE NAME: PASS 1.002 SERVICE NAME: VERSION # : 1 DATE: 85/11/ MAXIMUM LENGTH: 1024 '. FILE TYPE: LC NEXT FILE NAME: ** FILE HEADER ~ 3 ** FILE N4ME: P~SS 2.003 SERVICE NAME: VERSION # : 1 DATE: 85/11/2C MAX RECORD LENGTF: 1024 FILE TYP~: LC PREVIOUS FILE NAFE: ** INFORMATION RECORDS ** MNEM CONTENTS ~PIN : 5g02920~,26 CN : ARCC ALASKA, WN : ~S 13-S FN : PRUC~O,E BAY COUN : NORTk SLOPE STAT : ALASKA LCC : 150.00 INC · FORMAT ** BYTES UNITS ENTRY BLOCKS TYPE ENTRY ~m---- 4 1 8 6C.0 9 .1~N- 11 12 -0.500 DATUM SPECIFI CESCR:PTION DEPTHS DECREASE FRAME SPACING FRANE SPACING UKITS MAXIMUM F~AMES/F,.ECORS TE.~MINATOR LEVEL SPACING CATION BLOCKS CURVE REPR NAME CODE SIZE SAMPLE UNITS mmmmml emil mmml mmmmm CCL 68 4 1 DIM LS 68 4 1 CPS G1 6~ 4 I CPS G2 68 4 1 CPS MON 68 4 I CPS BKS 68 4 1 CPS ISS 68 ~ 1 CPS MSD 68 4 1 , . . ,. .. . CURVE NAME SPD SS GElS GR BKL CSS SGGM RAT REPR COCE ~8 SIZE 4 4 4 4 4 SAMPLE 1 1 1 1 1 1 1 1 UNITS F/MN CPS CPS CPS RICS 68 4 1 DIM FORMAT KiN ENTRY ELOCKS TYPE ENTRY BESCRIPTION 4 1 EEPTHS DECREASE 8 6C.O FRAME SPACING 9 .lIN FRAME SPACING UNITS 11 12 MAXIMUM FRAM$S/RECC~O 0 TERMINATOR -0.500 LEVEL SP~CING G4TUM SPEC!F!C&TICN BLOCKS CURVE REDR CURVE REaR N4ME CODE SIZE SAMDLE UNITS N~ME CC2E SIZE iIIIII IIIi IiiI iIiII! iIlli iilI CCL 68 4 I DIM SPD ~8 4 LS 68 4 1 CPS SS 68 4 01 68 4 I CPS G~IS ~ 4 02 6~ 4 1 CPS GR MON 68 4 1 C~S 5KL ~ 4 ~KS 68 4 1 CPS CSS 6~ 4 ISS 68 4 1 CPS SGGM dS 4 MSD 68 4 1 R,&T ~ 4 RBOR 6~ 4 I DIM RICS 6,8 & 1 C'IM S~MPLE 1 1 1 1 1 1 1 OEPT~ 10970.CS0 FT ~343.~63C M IIIlliiimImmliiIiii! 4C2.63~ SS 314.2S7 GR 41C.82~ CSS C.OCC RAT 27.063 DEPTH 1C900.CC0 FT '3322.327C M IIIlliIIlIlIIIlllilllIlIIilI!i CCL O.CO0 SPD 15,998 LS 01 74~4.9~2 G~IS 105729.1~0 02 MON 52,732 BKL 48,160 EKS ISS 325539,400 SGGM O.CCO MSO RBOR 1.§43 RIN 12.3C5 RICS 1243.2E5 SS 2274.131 GR 155.765 CSS C .OCC RAT DEPTH 10800.COG FT 3291.847C M lIIIIiIlIIIiIIimIIIllllIIliiIi CCL C.CCO SPD 15,99~ LS 01 7637,426 GElS 103505.600 02 '.',>".)iMON 56,4&8 BKL 32 502 8KS . . m ISS 315283.4C0 SGGM O,COC MSD RBOR 1.912 RIN 12.295 ~ICS ,,. .... ~EPTH 107C0,C00 FT 3261.3~7C M CCL C.CCO SPD 01 7862.691 GElS " MON 54.584 BKL ISS 297413,300 SGGM RBOR 1.910 RIN .' 1229.C21 SS 236C.162 GR 157.QC4 CSS C.OCC RAT 18.2~3 15.998 LS 12C2.488 SS 977C4,56~ G2 2449,139 GR ~.~ BKS ~.~ css o.coo ~so c.ooc ,., ..'.<:. '.. :...'.!':.'..':i~: ":"< .:' '<.'.': ". '.'' .:' <" ":. ::, '. :..':':'. i': L'.. }' '..., i"*;. '.. ':'' ', ,'" , ,, UNITS F/P~N CPS CPS CPS APl 1 I CZ M 11274.420 73.090 10164,740 O.O00 23043.460 2~.644 17275.150 0.000 23278.300 2C.994 17263.190 0,000 22587.360 23.158 16728.040 O.O00 Dr-PTH 10600.C00 FT 3230.8860 H CCL O.CO0 SPD 15.995 G1 7/,63.102 GElS 99247.750 MON 55.077 BKL 36.672 ISS 302461 .400 SGGM 0.000 RBOR I .889 ~IN 12.115 LS G2 BKS MSD RICS DEPTH 10500.C00 FT 3200.4060 M CCL O.CO0 SPg 15.998 G1 8153.207 GElS 101945.C00 "',':i MON 50.977 BKL 36.737 ISS 312909.500 SGGM O.CO0 RBOR I .883 RIN 12.040 LS G2 BKS HSD RICS DEPTH 10400.CC0 FT 3169.927C M CCL O.CO0 SPO 15.993 G1 1579.332 GElS 106731 MON 50.892 5KL 139.589 ISS 318159.600 SGGM 0.000 RSOR 2.1~4 RIN 12.336 LS G2 ~!CS DEPTH 103C0.CCC FT 3139.4460 M LS GZ BKS RICS 2EPTH, 10200.00'0 FT 310E.~6~,C M CCL O.CCO s:r3 14.71,5 G1 I ,2660., NON 51 .C,~1 BKL 222.975 iSS 27351 2.300 SGGM RBOR 1 .452 RIN 10.~43 LS G2 BKS MSO RICS DEPT~ 10100.CC0 FT 3078.4860 M CCL O.CO0 SPD 14.405 G1 7953.~16 GElS 10929S,70S MON 56.570 BKL 258.490 ISS 292036.400 SGGM 0.000 RBOR 1.548 RIN 11.254 LS G2 BKS HSD R!CS DEPTH IOCO0.CCS ~T 3048.0060 M CCL 0.000 SPD 1~,793 G1 8658.684 GElS 98521.810 MON 47.616 BKL 328.671 ISS 272118.400 SGSM 0.000 RBOR I .493 RIN 10.718 LS G2 BKS MSD RICS DEPTH 9930.500 FT 3026.8230 M iIIIIIlIlII CCL O.C'CO SPD 14.999 G1 304.698 GElS 12109.998 MON 6.339 BKL 33~.724 ISS 34869.230 SGGM O.CCO RBOR 0.044 RIN C.430 LS G2 BKS MSD RICS 3343.6630 M 1192.30~ 224C.64~ 163.041 C.OOC 17.976 1288.140 25~6.013 167.243 C.OCC 17.902 499.717 152.711 255.3C8 C .OCC 1902.260 3214.110 297.6~2 0.0C0 12.8~C 1800.714 3143.01.5 420.531 C.OOO 12.828 1570.44 ,c, 1812.1~4 3;3.045 C 14.393 1589.084 2154.629 408.5~6 C.OCC 13.751 221 .709 ':- 8.57~ ,,.,, 3~, ~, .724 0.0CC 20.151 SS GR CSS R~T SS GR CSS R4T SS GR CSS RAT SS GR CSS SS CSS R ~ T SS GR CSS RAT SS GR CSS RAT SS GR CSS R4T 23199.820 23.600 16826.120 C.O00 23524.000 18.998 17478,300 0.000 13781.140 71,071 12307.130 C.OOC 35881.860 38.127 22375.240 34023.770 53.539 21322.160 ¢.eoo 31685.500 102.o35 2029G.820 0.000 31642.060 90.477 19774.310 0.000 2464.513 105.568 1730.400 0.000 STARTING DEPTH :10970.000 FT . ** FILE TRAILER ** FILE NAME: PASS 2.003 SERVICE NAME: VERSION # : 1 DATE: 85/11/ MAXIMUM LENGTh: 1024 FILE TYPE: LO NEXT FILE NAME: 10 ** FILE HEADER ~ 4 ** FILE NAME: PASS 3.004 SERVICE NAME: VERSION # : 1 gATE: 85/11/2C MAX RECO~D LENGTE: 1024 BYTES FILE TYPE: LC PREVIOUS FILE NAME: · ** INFORMATION RECORDS ** MNEM CONTENTS ami-- APIN : 5002920~26 CN : ARCO ALASKA, INC, WN : DS 13-5 FN : PRU~MOE COUN : NORTH SLOPE ST~T : AL~SK~ LOC : ** FORMAT ** U~ITS ENTRY BLOCKS TYPE ENTRY ~ESCRIPTION 4 1 DEPTHS EECRE~SE 8 60.0 FRAME SPACING 9 .lIN F~A~E SPACING UNITS 11 12 ~AXIN~M FRAMES/RECORO 0 TERMINATOR -0,5~0 LEVEL SPACING CATUM SPECIFICATION 5LOCKS CURVE ~AME CURVE NAME CCL 68 4 ~ DIM SPD ~8 4 1 F/MN LS 68 4 1 CPS SS 6~ 4 1 CPS G1 68 4 1 CPS GElS ~8 4 1 CPS G2 68 4 1 CPS GR ~ 4 1 ~PI MON 6~ 4 1 CPS BKL ~8 4 I CPS BKS 6B 4 1 CPS CSS ISS 68 4 1 CPS SGMA 68 4 1 HSD 68 4 1 SU RATO ~ 4 I DIM RBCR 68 4 I EIM RIN 6~ 4 I DIM RIOS 68 4 1 REPR COEE SIZE SAMPLE LNITS REFR COCE SIZE S~MPLE UNITS ** FORMAT ** ' ' ' : '" ' ' ' '''","' "' ' ' ' , ' 'i"" , '."" ' ' '~'' ': "'; ': ' "" '" "~''!'' ..... ' ' , . ,, :NTRY BLCCKS 11: TYPE 4 8 11 0 ~TUM ENTRY --I.la 1 60.0 .lIN 12 -0.500 SPECIF ~cSCRIPTION~_ CEPTHS CECREASE FRAME SPACING FRA~,E SPACING UNITS MAXIMUM FRAMES/RECORD TER~,INATOR LEVEL SPACING ICATICN BLOCKS URVE AME ~ L ..S '1 '2 ~ON KS SS SD BOR ICS REPR CODE 68 68 68 68 68 6.8 68 68 68 * DATA ** CURVE SIZE SAMPLE UNITS N~ME 4 1 CI~ SPD 4 1 CPS SS 4 1 C~S GElS 4 1 C~S G~ 4 1 CPS BKL 4 I CPS CSS 4 I CPS SGMA 4 1 SU RATO 4 I DIM RIN 4 1 DIM RE,~R CCC, E ,~, 68 68 ~8 68, 68 SIZE 4 4 4 SAMPLE 1 1 1 1 1 1 1 1 1 UNITS mImII F/MN CPS CFS ~P~ SU DIM EPTH' 10967.CCCi FT 3342.7480 N i m I m m m I i i -- i-- . I iiii CL O.CCO SPD 13.C, 99 LS 1 1719.828 GElS ~c696C,33G G2 'ON 461995 8KL 139,986 BKS SS 307899,200 SGMA 33,459 MSD 50R 2,309 ~IN 12.917 ~iCS EPTH 10900,CC0 FT 3322.3270 M CL O,COO S. PD 14,999 LS I 7540,672 GElS 101132,600 82 ON 50.494 BKL 65.351 BKS SS 319~23.1~0 SGMA 17.904 MS~ 50R 1.923 RIN 12.220 RICS EPTH 10800.C. C0 FT 3291.847C M mlIlI--ImmmmIImI! CL 0.C00 SPD 14.999 LS 1 5958.348 GElS 96~14.190 G2 ON 50.133 BKL ~0.615 BKS ,SS 311588.~S0 SGMA 18.~42 MSD 50R 1.918 RIN 12.452 RICS 2-PTH 10700.CC0 FT 3261.3670 M ~4C,.~55 169.963 429.957 1.11~, 2~.019 1217.445 2310.9C4 19,-~. ~,45 C .2~7 19.0~? 1159.374 2021.977 1G7.093 0.405 19.572 SS GR CSS RATO SS GR CSS RATC SS GR CSS RATC 1187~.810 52.678 1C988.900 26.302 22088.590 30.109 16731.700 18.194 21302.930 20.972 15919.~00 18.395 O.CO0 SPD 14.999 LS 7327.598 GElS 91735.380 G2 48.392 BKL 55.893 6KS 287200,300 SGMA 17,219 1.909 RIN 11.77~ RICS =PTH 10600.CC0 FT ~230.886C M mIl--iIi--mImIlliImli CL O.CO0 SPD 14;755 . ~^?,,...~?~. ...... ~ ...... .".,' ,., ,., LS 1190.342 2375.682 1~7.905 0.445 18.246 SS GR CSS RATO 1156.978 SS 21329.190 24.600 15740.020 17.937 224'47.210 ,. MON 51.580 BKL ISS 302486.800 SGMA RBOR 1.9S9 60.685 EKS 19.027 HSD 11.852 RICS 219.981 C.2~C 18.450 CSS R~TO 16394.550 19.417 12 C'EPTH 10500.CCG FT 3200.406C N CCL 0.G00 SFD 14.999 · 3-1 8483.195 GElS 101648.600 MON 53.7C9 BKL 47.130 ISS 314901.600 SGMA 16.e67 RBOR 1 .870 RZN 11 .903 LS G2 BKS HSD RICS 1355.3C8 2~3E.641 182.571 C.210 17.7~6 SS GR CSS R~TC 23773.210 19.960 17725.020 17.119 DEPTH 104C0.C00 FT 3169.927C M -- I mm I ii i __ m ii m i i m --iii m Ill CCL O.CC.O SPO 14.999 G1 1641.46~ GElS 97135.440 MON 42.567 BKL 155.315 ISS 295752.900 SGMA 38.617 RBOR 2.112 RiN 12.331 LS G2 MSD RiCS 46C.$11 1~1 .2~.9 25~.'~57 C .6C1 25.862 SS GR CSS R~TG 12971.710 6C.456 11435.790 25.041 DEPTH 10300.C00 FT 31'39.446C M CCL O.CC.O SPD 14.999 01 9789.~13 GElS 94639.000 MON 52.6'_,0 BKL 202.~05 ISS 263727.500 SGMA 18.879 R~OR 1.497 RIN 10.795 LS BKS MSD RICS 17C2.893 2869.0CC 475.269 0.3~,0 13.152 SS GR CSS RATC $17~1.220 33.035 20052.$50 1~.557 DEPTH 10200.CC0 FT 3108.966C M CCL 1285.350 SPD 14.999 G1 9514.C51 GElS 95948.630 MON 54.372 BKL 254.646 ISS 273190.900 SGMA 19.C84 RBOR 1.4~7 RiN 10.9~7 LS G2 BK S MSD RICS 1713.551 ~7~2.54C 35~ .662 C .29C 13.397 SS GR CSS R~TC 31893.030 55.195 2CC91.86C 16.655 DEPTH 10100.000 FT 307~.~6C M CCL O.CO0 SPD 14.999 S1 7978.996 GElS 104464.6C0 MON 52.352 BKL 325.625 ISS 282519.500 SGM~ 20.~94 RBOR 1,554 RIN 11.162 LS G2 BKS MSD RICS 1591.454 2058.547 47C.93~ C.513 14.373 SS GR CSS R~TC 3C46~ .610 101.165 19656.400 19.104 BEPTH IOCO0.CCO FT 3C~8.0C, 6C M mmmmmmmmmm Imm CCL O.CO0 SPB 14.999 01 8107.609 GElS 953~0.500 MON 48.158 BKL 276.91,6 ISS 26C86~.900 SGMA 21 ,961 RBOR 1 .499 RIN 10.~96 CEPTH 9911.500 FT 3021.0310,M CCL O.CO0 SPD 14.999 01 149.985 GElS 6389.355 MON 5.000 BKL 349.965 ISS 18938.110 SGMA 51.450 RBOR 1.673 RIN 9.194 LS G2 BKS MSD RICS LS G2 5KS MSD RICS STARTING DEPTH =10967.000 FT ENDING DEPTH : 9911.500 FT 3342.7480 M 3021.0310 M 1514.799 460.129 C .206 13.777 C .OCC C .0C£ 4C9.959 5.383 20.366 SS GR CSS R~TC SS GR CSS R~TO 3C39G.190 78.89~ 1 8934. 830 20.081 1469.853 87.577 929.907 O.O00 ** FILE TRAILER ** '--, '?.., ", t"'~ ~ ," .'." ~,...'~ .."~,¢'~,..: . ',,,, ,.i ",;.,', ,',,: . .. SERVICE NAME: VERSION ~ : 1 DATE: ~5/11/ ~AXIMUM LENGTk: 1024 FILE TYPE: LO NEXT FILE NAFE: 13 ~* TAPE TRAILER ~* TAPE NAME: SERVICE KAME: ~SS 3 SATE. OSIGIN OF DATA: FSYS TAPE CONTINU~T~Ok # : 01 NEXT T~PE N~E: COMMENTS: ** REEL TRAILER ** REEL NAME: SERVICE NAHE: ~ITLIS DATE : ORIGIN OF DATA:. FSYS REEL CONTINUATION # : ~1 NEXT REEL NANE: COMMENTS: DR;SS R ATLAS LIS CUSTCNER TAPE --- CREATEC, BY SDS PROGRAM R 2.0 REEL HEADER - 1 TAPE. HEADER - 1 FILE FEABER - ~ iNFORNATICN - 4 FORMAT - 6 DATA - ? 2 TABLE DUMP - 4 ~ILE TRAILER - ~ TAPE T~iLE~ - 1 REEL TR~ILER - 1 TOTAL RECOPD$: LIBRA-MY T.kPE CURVE SPECIFICATIONS Company ARCO AT,ASKA INC. PAGE ] OF 2 Well D.S. 13,5 Field PRUDHOE BAY County, State NORTH SLOPE, ALASKA Date 12/19/86 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale I FILES 1-3 ~ "" __ CCL Casing Collar ' Locator DK-100 400-600 ... SS Short ....Space " 60.00- 540.00 G1 Gate 1 " -72000 GR Gamma Ra~! " '~~ ~ Lon~ace' " ~ BKS ~Back~round Short Space " ~-$0Q - MON Monitor " ~ CSS .... Capture Short Space " ISS ~Inelastic Short SPace ~" ~ MSD Mean Std. Dev. ~ SG~ ~ma " ~. 60-~ ~TO ~Ratio of CaDtureCounts " ~ RICS ~Ratio or Inelastic to Ca~~~ ~ RBOR Borehole Ratio ,, 3 to -1 Page 2 of 2 LIBRARY TAPE CURVE SPECIFICATIONS ECC# 2581 Company ARCO Alaska~ Inc. . Well D.S. 13.5 , Field Prudhoe Bay County, State North Slope, Alaska Date 12/19/86 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale RNAV Average RIN ' . " 14-4 RCAV Average RICS " 43-0 RIA¥ 'Average Ratio " 3.3-3 GR Gamma Ray Pass 1 " 0-100 , , i. _ ~ISIN : FSYS ERVZCE NAME: ~iTLIS E=L CONTINUATION NUMS:R: 121 ~bVIUUS k~cL N~M~ : OMHENTS: DRESSER ATLAS LIS CUSTOM=R ENGTH: 132 5YTES ,..rRE~1TE9 '~Y SDS PROSRAM ';,, ~,0 AT~_ : ...... :~i~iN : ~-~,YS E~vZCr. NAME: E~G~NO APE CONTINUATION NU'M'aER: 01 ReviOuS i.~P~ NA~: : 0M~NFS: * riLE ILE NAME: BKGRNB.O01 ERvicE 'NAME: "ERS!ON # : I : 'C"O"U'N ': N.SLOPE STAT '- ALASKA LC, C : I $ 0.0 0 ENTRY BLOCKS ¥'PE E~TRY O;SCRiPT~ON 4 '] DEPTHS DECREASE ,5 i'E,~.O FRAME SPACING 9 ,iiN FRAME .SPACING UNITS i i 25 MA. XiMUM FRAMES/R ECORD 0 iER~iN~fOk; "-i..000 LEVEL SPACING'" AFUM 3FECi~iCA~,:iON ~.LOCR3 ~NT~Y ~LOCR$ YPE ENTRY DESCRiPTiON ~!I IiIi! Ii -4 1 BEmTHS CECRE.&S~ 8 i26,0 FRAFE SPACING -9 .lin FRAME SPACING UNITS 11 25 M~XiMUM FRAMES/R,'~C, ORD u TERi~iNATOR -1,000 LEVEL SPACING ATUM ,SPECiFiCATiON 5LOC'KS URVE REF'R IIIII C U R. v E REAR K L 49 ' SS 49 G M ~ 49 ,~ T 0 4 '9 'i N 49 '1 CPS ..................................................... 1® C P $ 2 1 2 1 C. iM , , CL. 0,000 L5 ,.= i S 32752, CO0 'G2 GM~ -5,.668 MSO :i N O, O 0 0 k .i C S 0. OOO GR ii 9.93a CSS 8.609 RATO O.CO0 ' ' fi. OCt i7.328 -99'92.000 ISS O.'''~ ~..I I,.,I 0 RSOR 1 ,000 EPTH 11,300.C:,3C FT 3352.~,37C UL 560. cO0.,, LS ElS 32752.C00 Gl KL ' 1 ~8.5 O0 B'K S GM.~ -i 5,1 33 MSD I'"'N '0, Ouu RiCS 26 41 100 i ,0,~4 ,125 .125 ,313 SS GR CSS RATO 9.984 50.906 '25.609" 0.375 .... GE -g992.00'3 MON C.OO, O ISS 47.00,5 R:BOR 1.907 EPTH 10'""'"'.O00,"uu FT s3~.~=7'~ .EiS 32752,600 G2 3 K-L 45.686 ~K S 56 G R ...... CSS " 24 4 · ~ c M 0 N 7 .~m8 iSS f'" ,~, '") ,/ r",~ ~,~, F9 ~ 9.,~'~00. RICS _~ · 420_ E~TH 1.q. 30'"'. ...·CC.O FT 32':'1. .8'.c7~. _ M .500 .62~.., SS ~R C~ R~TO 19,4~4 -I~.oC~ iC.~2~ t.111 GE ~ON 0.0'i~ iS~ i~,~7 RBOR 1.E4U EPTH 10FCD.CCO FT 3ZCl · 3OTC M CL U.UOU La ~'i~ 32752,CG0 G2 __ __ ~MA -77.938 MbO IN O.CO0 RIC~ C, .9o 'i · ,~7 :" ,985 SS CSS I 5,289 i'4,~33 2,.~C C C '"' 0 , ,,.,, · '~, * ' ~0 FT 3230 8,860 M ZPTH iOoCO.C,~ . CL 0.00'3 L.S i2, ElS 327..52.000 G2 i0 "k,'L 2 ~ · 4 3 r5 tS K, S i 6 G ,~ ~ - 2,5.5. ,5 25 r~ S o 55 .7ii .062 SS G~ CSS RATO ~.547 0.3q3 MON iS~ ,3.854 RS, OR 0.844 KL "b M A I II I II I I I I !IIl I! I II I U · 0 C 0 L S 32752.0Ct0 G2 0.7j, 5 SS 9"50a, mR ii.07C SE - ,-7, ;,~ 92, O 00 M 0 N 0. O 0 0 CL 0. COO LS iN 3'730 MSD O.C00 ' RICS .... '3i39.446~ '27 :' 000 S S 9,172 RATO 0.601 M RBOR 1.267 CL O.C00 LS :ei,'$ 32752.0,00 K'E ~5.06'3 "B'K SMA -9:4.500 MS iN O.CO0 Ri i S 2 O i CS 9.53 i G ,~ U.~44 "eSS 2 .i 56 RAT0, 0'. 6 ,~ .4 ~FfH 'iO2G0.CC, 0 Fi 3i08.956C M Ct 64.6~5 LS -i2.26a, S$ ElS 32752.000, G2 5.,i~$ GR K'"L 44.a~6 5KS 52.375 C,SS GM~ -'i0.~69 MSD 9,273 RATU iN 0.C00 RiC'S ' 0.891 22.0C, 0 MON 6.795 iS,S 'i.405 RBO~ -9992. 6. 055 0.619 E~TW i0i00.000 FT 3078.~8,5C tq i 5.565 44.8i3 ~ON O.OOC ,::, · ,',,' l S S ..... 1'5.6, 64 G.999 R bu~.: 0.0,01 EPTt'-: !0000.6.'0~ FT _~',']4,~.[]05C M CL 0.00G, LS 20. ,...~1S 327'52_. . £ r, r-',,.., ~ Gq,._ 12,. 9:$.4 KL ~!~.., 7~3 BKS '~6x, GifiA -45.063 MSn ~7.625 z ~,~ O · ',....' O ~ I C S ',.. C _ SS CSS R'~TO 2~.S94 7.73~ 1 3 · 07C' ,SE I S ,S 0.C':03 0.!72 EPT~ ~c4'o.C-O ~f 5,329.7'i~ M CL O.C~- .,. ,~ C~ ~2.6S~ ,SM~ -2.9~9 MSD 6.7E1 ~iq C.CCO ~i.CS 2.433 S~ ,'SSS ,8.7SC '7.25C MCN REOR O.T4E T~,RTiNG DEPT~ :ii04z.003 F7 ~65.9i30 NDiNG DEPT~ = 9~40.000 FT 3329.7i80 ~ :iLE TRAILER ** iLE N~M:; 5KGRND.O01 ERViCE NAME: ERSZON # : I AT~; :5111/ AXZMUM LENGTH,: 1024 %LE TYPE: LO EXT FiLE N~NE: =_RViCE NAME:' -ERSiON #' : 1 'iLE TYP": LO * iNFOrMATiON - FN - PRUDHOE 5, AY CGUN : N.SLCP,: - STAT : ,ALASKA L C .C : i :5 C,. ,3, O * FORM;~T ENTRY BLOCKS -i. oc, o ' D E$C R I PT i ON :D EPT,mS DECREA,SE F ~ ~i,i E SP ~C"ZN G FR&kiE SPACING UNITS NAXZM ...... . u,-, ~- R A~4~ES/R'ECORD T E R i~$ Z N A T 0 R LEVEL SP.~CZNG ......... .&TUM SP:e,-~ ~CATTONz . BLOCKS URVE ~EPR AME COJE SAMPLE LNZTS ~1S 49 2 1 C°S __ R 47 ~ 1 ,~ SS 49 £ I APl __ GMS 49 2 1 SU __ ~TO 49 Z 1 DiM __ ~ N 49 2 i D i ~ CURVE N,~E LS G2 MCN ISS MSD R~OR RiGS CCi, E 4~ S~N~LE i UNITS bPS * ForMAT ** SNTRY ELOCKS YPE :NTRY CESCRiPTiON Z~ll lllli IIIIIl/llIiIiiJlili ....... 4 i U~TH$ D~C~EAS~ 8 i 2O.O FRAPE SPACING --~ .lin FRAME SPACING UNITS ff'i 25 ~AxiMO.M FRAMES/RECO~D 0 I~RN'IN~t'OR -i.O00 L~V~L SPACING URV~ R[PR: -C L 49 ,S 49 ,EiS 49 2 1 CPS G2 -- ~'~, , ',," '~', ','~',~, ~,r,,'~"~,,' ',' ~', '~ ~ ' ',"", ~,,, ~, ', ',,, ',%~,'?,, ~: , R Z, 9 ~ ~'~'' .... ' ........... '"'t~'~""~ .......... "a'P~ ......... ,~ t' ~ "~'~' ~'~, ',', ~,' "' ~' ~, ......... ~ ',~", ' ,, ',x~ , ,,,~'"' ~' ',~ ~,' "~I~" ~' .... ~ ~ %~ ~',9," a ,,,,~l~s', ,', <',~,,W,<~q~¢, ~','~A~,~C~?~ .... ~' " ...... ........ SS 49 2 1 AP1 ISS G'M A 49 2 I S U M S D ,ATO 49 2 1 DIM iN ~9 ~ i ~ZM RiGS 49 2 1 CPS 2 1" 2 I SS C S S RATO i5518.0£C 4~.469: MON 9iii.GCC 5i.i4i -9992.00§ 404.750 37752,000 1.678 ':PTH i i,OOO.COC FT 3552.807C. M I i i i I I i I i I i I I i CL 114.563 ' ' LS 37i.$.SOO "SS -.: i S :32 752. ,3 '0 O G l 7 '2,. 625 G ~t KL 'i2i .56S ' '~;K S 215.875 'C'S S, GF~A 43.063 MSD 0.297 RATO 'iN i i. 359 RI",: $ 30.422 10504.000 GE 45.344 MON .B52~.u~,... iS:S 27.469 REOR 9'992,000 390.7'50 i.9.44 E?TH qOsO'''., u. CO0 "F'T' 3'32~,_.,,,~270. M GL 0 · 000 L S i i 25 ' gOO ,$ S 'i 7,596 · GCC GE -9 ~. 92.0,00 ~L 0.424 22.18~ ~- ~ ISS CSS 127xr.OO,. R~T,~ 15 ~2~ R°~R , .~ I ,~¢ 0 1.7,$? :~TH 102C0.CC0 FT 3291.~47C M CL C.CCO LS KL 't &, ;.7).. .~, c..,~ iN i0.~92 xi C$ iC:2.CCC, la38.C00 6.2C0 2 i. 2~ i SS i772~.JCC G: bR '16.52~ MON CSa i2392.0CC Lbb RATO i6.08~ R50~ 1.811 ?'PT~ iC7CO.CCn FT =26i.367C M O.~,"00 LS =i S 52752.C00 G2 KL 4x .935 £K GMA i 7. 875 MS ~ N 1 0.391 ~: ii22.0C0 i~dS.OOO i55.625 2,3.933 SS i~72.0CC u: GR i6.i25 MON CSS i275~.0CC ZSS R~TO i6.03i RBO~ -gg92.O3© 393.750 3~7'2.00'5 i.756 23-S.886C M ii05.000 1914 '~ S 123.750 D 0.543 CS 2i.009 GR I~ ~X7 MON CSS 1248,_. O, OC ~S S RATC, 16.391 R, BOR -~992.000 sas.s00 52752.000 1.775 ~PTH i 0500 CL ,G M A -i N 200. 406C 99'9'2', 403.7 50 EPTH'Iu4u C~uu e .. u . , T 31 69.9270 M uL ,EiS 327,52.C00 62 241,875 KL i9i','600 ' BKS 326.250 :GMA 35.156 MSD iN i0.438 RiCS 31.'20., GR M ON C,SS 8592 iSS R AT 0 7. 6 O 9 R B, 0 R 383.750 32752,000 ,,~0,¢2 1 39. 4466 185 ;5 · '3 U '0 2976.000 i33,375 i 3 · 42'2 GR 25.0~4 MON CSS i8560'0C6 lSS ' ~ATO i6.2i9 RSOR 44,~ 250 32752.'000 1.374 :PTH I ~00 uuu FT 310;3 ~o60 M O.CO0 LS ElS 32752.00C, KL '57.344 BKS GNA 18.078 MSD IN 9,'009 RiCS 2C01' '~C.~ 31 24. CO0 140.375 0. 262 13.2,~7 ,Sa 30160.0,SC GE GR 25.344 MON ,..oS 1n64'0.~ RATO 1.5.430 R~OR -99'9'Z.00,3 457,750 327~,2. OuO 1.414 EPTH i ,,.,,i C" .,~.. , ',-,' uu FT u.rS,4c, 6C M i3,01.000, G~ 2~9.000 CSrS 59. ,21 9 M 0 N i4960.000 iSS -~9'~ O 424. 750 327q'E.O, O0 9.1 ~8 RZCS 16.375 F-"PTH 10CC0 F'.,~C FT ~34¢-, ,"' ,., ..... . .... ,..,' O/, £ CL 0.C30 LS 3M~ 21 .95~ MSD __ IN W.'jq 5 RIC$ 1453.33C, i~i8.Cu0 0.484 SS GN ~SS RATO ~ 5x~" OCr iOS .OcS i ~c4E. C.,CC 1~.~3~ fi, UN RBOP - 9992. '2;]0 ~*2i. }27S2.000 EPTH 993~.~"'~0 PT 5d~9.1C, vg M gL o.cOu Lb ElS 32752.000 G2 __ -- _ bMA '7.0~3 MSt IN 9.~,~ RIC$ 2 i,5. C, O0 ,'70.7~0 L.,~ 0.7~3 86.873 9~.0CC MON 379.500 ~275Z.C,3u 1.6'1! TARTiNa 3EPTH =11C, 41.000 FT 336.~.30~0 M NL',2N6 L;EPTH = 9938.000 Fi 302~.'10~0 M * ~iLE 7RAiLER TLE NAME: PASS ERViCE NAME: ~c: 85111/ AXiMUM L~NG]':H: i02~+ LLr- ]'yHE: L'3 ',EXT PILE NAME: ~TE ~ X R ~'V * iC~ NAMe: iON ~ : 1 , ~,,,',?,%%' ~UU$ PiLE N~'~: . :'M IN E ,M C 0 N T E N T S .... U N I"T S ........ ' APIN : 50-0'29-Z'Od>26 CN : ARCO ~,L6SKA ii,JC. '-WN : :~.S. 'i3-5 COUN : N". SLOP;= - S, iA i : ALAS~,A LCC : i $ 0.00 -" ENTRY BLOCKS LEVEL SP~C!NG &,TUM SP-'C .i$IC~TiON BLOCKS URVE REPR ,~ME CO~; S-ZE S~nPLE EL 49 2 1 -- ~ 4~ 2 L N iTS CURVE uC~E uNIts IM .T.M B~5 ~W 2 ~ CPS i~3 ~ ~ 1 CPb MS~ 4c 2 1 gU ~£ub 4~ 2 '1 DIN ~ ~ORMAT ** ENTRY ~LC, CKS %PE ENTRY B. ESC ........ 4 i DEPT $ 12¢ ~.G F~ 9 .~iN FRAM ii 25 MAxi ~0 TERM ,U,,:RVE .REPR ,C L 49 2 I DIM LS 49 1 ................. C~S '' APl MON 2 1 CP,,S C P S B K S 4 2 1 C ~:. S APl lSS 4:9 2 I CPS S u 'H :$. ,,3 4 '~' 2 ..... 1 ' .... S U O ,l i'~ R 50 R 49 2 1 D l H .............. DIM RICS 4'9 ...... ~ I ...... ,91M E'"T ' """"'"'"" "'""'"' "'" "'3~'''''' "07r' _ r 'I I I I LJ ~J LJ., L, '~; ',-,' ! ~ ..;' .2 ,r,g i, C:;, ,..., CL 37.938 tS' 373.250 -Ei$ 32752.000 G2 i<L 111.375 8KS 233.~2.5 ~iA 44.2i 9 M£D O. 807 .,,,p ~ ! · .;, ~.,, u ,"~'~, ~0'.'10 ,~ EmT'H i,3~C,O.COn FT 3.~'2i.327C, H .pr, p, .656 ,3 ~ 22 ;7,. O ¢ 4 CS~ t276" r,"C ~, , ~AT'3 1 ~. 21 g NON !SS -ggcE. ,_,JO 41q. OOO 327~2.$33 1 .7~,' ~PT~ i0=0C.060 FT S19-i.847C M .375 .~38 CSb I~I~.UUC R~TO !~.~C~ M ON iSb RBO~ ~.750 ~Pr~ iO700.CCC ~-T 32~i.3~?C M 0. L: C U L ?is 32752.000 ~L 54 .C63 5KS i 51 GMA i7.0q, 7 MSu 0 ~N i0.2z, 2 ~iCS 20 i CO0 .COO .185 .719 GR CSS 12048,.00C NON ISS -9992.030 'i.755 EPTri 13600.000 PT 3230.?,.,8¢C: M O.OOO LS i i45 E'i S 32752.C00 G2 i9i 2 ~ m A i 7.953 M $ ,D '3: iN -i 0. 297 RiC,S ZO .000 .O00 .375 .209 .3i3 SS 18096.0CC gR 1';.672 CSS i R"TO.., i6 .078 GE MON iS; 32752.C!00 1.768 GMS, i ia 'i O. 328 RICS 20.750 CL O.OOO" ' L,$ 437 ~-'i,~ 32:752.000 62 :t16 K'L' 240.873 BKS 3i8 G, M: ~, ~ 0.5 3 i M S ~ i .... ~ N i 0.6 ,,39' R Z C"S "'32 .750 .875 .3 O0 .242 .9"06 SS 9240 ] GR 75.500 CS.S '" 776C.00C R,~TO 22,'i4i GE :MON iSS ~6OR -9992.000 378.000 3,2752.000 2.0S7 'E'iS 5275 KL 6 i 0.000 L~ i787 2.C00 G2 2694 8'.500 b,~S i60 8.797 MSU 0 9.6~3 RiCS 13 . .O, O0 .2i6 .453 SS 282a,$.0CC GR 27.547 eSS 'i~Ca. OCO RATO i3.775 MON iSS R60~ -999.2.000 43i.0j0 32752.0J0 1.392 EPTh i0200.C00 FT 3'108.9,0~0 M .,~00 .750 .4i .6. .2'73 S.S 28,92'8.0C0 GR 27,266 CSS i7744.C, 30 aaTO i.5.3i'3 H ON - 9~9"2. 000 ,32.000 3,27=2., .00'0, I. '3¢3 -LL U.C'OU i_, '~,8'i.UO0 ,,S ,~ 2:3 'i 20.00 O ~" J, '"Z ,". / GE¸ / "~ ¢'~ "2 ~,. /"I 1 ~,& 5KS 255.625 MSD ,3.41 9 ~ ]:C, S 16.172 -'C. 6C,. FT 304S.,,,., ~,C M C0,3 LS 137, P__.~.~;~'O C 00 ,o ,' ! ~, ~ 5. C ",.: 0 75,~ RiCS i5.35z, CSS q &TO 1454q.00C I 7 '474 SS R ,1 T C, i7.009 i.42i ~PT. 9s38.C:00 FT CL 0.C00 LS ~iS 37752.000 G2 ~L i63.625 5KS OMA 37.344 MS~ ~N 9.344 RICS 2i5.500 GR ~i.750 CSS i.093 ~ATO ~3.047 i 3~i 2_ .OCC 73.575 ~21~.00C 24.438 GE -9992.300 MOiN 374.500 ZSS $2752.000 REOR 1.C17 ?4RTiNG 0=PTH =1104'1.000 FT NDiNG DEPTH = 9936.000 FT 65.3~4n M 3029.1090 M -*' FiLE TR~,ILER ,~,~ iLE N.~M;: P/~SS 2.003 ERViCE N4M, E: =,,.,.:R.SiON # : 1 -~T E: ,~; 5 / 11 / ' ~XiMUM LENG'T,r~- 10'24 * iNFOR,~i~TiCN R'ECO~8S *~ APiN : 50-1529-2062~3 CN : ARCO ALA, SKA iNC. 'wi,,i : D.S· 13-.5 FN - PRUDHOE C,OUN : N.SLOPE STAT ; ALASK4 LOC.- 15 O. uO"" ~ F,SRMAT ~. ' E N T R Y B L ~,., r.~. K $ ENTRY DESCRiPTiOi'~ 4 i 'DEPTHS, O E C :R:,. = A ,S E .S P 4 C i iq G ~ I l,.I "T '"f" ATU.M SPEC MAXIMUM ;RA,~'!ES IR ECORB TERIVlN'~TOR LEVEL SP.~CiNG !=!C~TION BLOCKS u~vF- AM= COC=,_ Si~E: S~MPLE UNITS N~M,: CO~F-_ Si?E SAMPLE UN;TS kg 2 1 CPS 49 2 1 CmS ~ 2 '1 CPS 4° ~ I ~I~ El) R ATO __ IN ,CPS CP.5 Su D I M C Z M ,,sNfN¥ ~:LOC~S YPE ENTRY C:SCRiPTiON I AME CO'Z,'E S l Z E S AMPLE UNI TS 2 .... 1 2 1 t' NAM:.~. CO0:~. SI 1 CPS GE 1 CPS G2 1 AP1 MON i CP~ oK, S I APl iSS "SU MSD DIM RICh 2 4 2 49 :2 49 2 49 2 '4..0 ........2 49 F. ~9 2 ,~ M PL 1 I CmS '1 C PS i C P S I ............ I O l M 1 'OIM O~TA ~ EPirt 'ii04i.00'3 Fi' 3365.504C CL O. COO L.~ 449 EiS 32752.000 G2 i~P r< L 5 ,$ ;' · 75 C; B r< S 4 i 9 =5 M A 36. '~ © .6 iq S O O -iN ' ' '11.336 RICS ' ' '21 .750 .875 ,750 .424 ,406 SS CSS -i3592.000 53.i:8,8 MON ~ii2.0CC 29,.57~ 378.750 1.614 EPTH iiCOO.CC0 FT 33~2.,5C7£ M E i $ 'K L -I N 60.4 ~18 LS 340 752. C O 0 G 2 7 1'39.250 '5KS 2'23 43. 375 MbO I = ,5 b R 54.0'3 i MON ' C, SS ...... 7'81'2. OOO .... I'SS X ,~ i-O 2 ,a. 29 '7 R :50 ~, - ~ g r,'¢' 2 .000 3 $ c. 000 32"75 '2.9'0 O 1 EPTN 10~'00.007 ~T S327.327C M SS G R SSS 162 ,.'f ~. C' C C S 5 2~.672 MON 11392.0CC ZSS i 5.75C Rr~©R :~7i~ i8~£.0.CC'2 r-T xZf'i.~4?C M ~I~I~I~IIIIIiI~-- i ii--i~ii~IIi ~ CC C'. C'-C. L~ ElS 327~Z.C00 G2 -i630.CC0 XL 45 · x i 3 .SKS i 53.5CC GMA 17.300 MSO 0.373 iN i0.C, 05 RiCS 21 .0.~4 i~672.0CC. i~.OCC MON i-i~,00.3C:C 15.6.~3 RDOR ~PTH iOTCO.CCC FT 3261.367C M EL O. COO LS 9..58. SCO 415 37752.C00 82 i659.CC0 ~L 53.504 BKS 155.Z50 GMA 17.781 MSO 0.523 iN i0.C55 RiCS 21 .469 .SS G R CSS R~TO I 52.8C. CC'O GE 2i .96c. MON IC. 712.00C ISS 15 '4~ R60R 9~92.000 32752.000 1,760 CL 0.~"0~u LS El S 32752.000 G2 KL 56. Z,']8 BK'S GM~ 17.730 iqSO .7. N ii25.000 SS i~0i~.0CC GE 1927.C00 GR 19,453 MON 167.625 CSS '124~6.0CC iSS C.i74 ~ATO 16.047 RBOR 2C.'.70~ - ~? 992.0 O0 4.27,750 r; 2 · CO0 1. 7 i:,,,~, 7 CL :GM A Z N 77,C00 BKS EF'TH i04GO.CCC FT' 3 C L O. C O 0 L S .ElS 32752.C. 00 G2 KL 264".~5"0' BK GMA 30.2~7 MS ~'N 1U,'219' ' .... RI 188.375 C,S S 1 362,4 · OOC ¢~7~.000 169,927C M EPTH 10l~0{']'.',$0,,,,q Fi' ..7..113.c;,",4.450 M CL O. 000 LS i707, COC' SS ElS 327'.52,6~00 G2 2414.C00 GR KL ,5:0,6~.$ BKS i4i .SCO C .S OMA I 9.438 MSD O, 292 R~TO iN 8.a83 RZCS ' 13,648 Z7536.0CC GE 27.54,7 MON 4.58,750 i684~,0CC iSS "527~'2'.., .000 I 5,859 R80R 1 . ,":: '-- T H i 0 1u'u.'"" ,. u u FT :) 07 ,.".:,. 4,56'"0 ....... M CL C;. (303 LS --1 ¢ '~ 7.., ._, _ KL 1~2.750 5KS GM~ 21 .2~1 MSD IN 8..513 R!CS 1,4~'7. CC C 151 7.00,3 0. 15.80! SS CSS 2ATO ~"~7; CCC ~.~ · 66.. Bl'~ 1~'~72,0Cr' M 0 N :F-TH i3C0-',.CC3 F--T ~048.005C ~,t ~L O · C":O L5 ~'i $ 32752, CO0 ~2 %L 408.Z50 ~KS GM~ 23.516 MSD IN ~.)'i9 RIC$ 'i22e.COO 411 .bCu 0,264 GR CSb .&TO -i28.00C 16.7G$ ~ON RBOR 37E.250 EPIH 9~38.60,J PT 3029.i0~0 M CL O.CUO LS ,Ei$ 52752,00FJ G2 XL i~9.375 5KS GM~ .~7,875 M~U i98.250 G~ 252.~73 CSS 23.09~ lJJC~.0C"C 5556.$CC 24,7&i G ,"" MON ZSS -9~S2.Ud0 586.000 32~52.000 T~RiZNb UtP"iH ='ii04i.000 Fi ~365 =040 M 3029.i090 m TR.~LL~R ** PASS 3.004 1 i~TE' 85i'iii :iLE TYP~: LC >A 'I'E. -- .... ~I~IN OF UAI~: PSYS ,~P'~ CONTiNufiTi0N # : t~X~ rAPE N'ANE: ,UMM= N J S: -~ R:E~L TRAi'L~R '** E~L 'iiAME: ,ERViC~Z NAME: BZiLi3 LA I': : ...... ~'RIG!N OF DATA':' PSYS ~tL C,JN~ZNu~'i-iON # : 0i i~X/' W~EL NAY:: ::OMMENT5: DRESSER ATLAS LiS ,C.U.STOMER TAPE --- CREATED BY SDS PROGRAM R 2.0 ~cL M~AO~K - 1 'AP~ .EAOER - 1 =ZLE HEADER - 4 ' ~FORM,ATiON - 4 'ORMAi - g ~T~ - 1.80' ~6LE DUMP ' 4 APE TRAILER"- 1 i,~L I~A, ILE~, '- 1 LIBRARY TAPE CURVE SPECIFICATIONS PAGE 1 OF Gas Cons. Oommissi.on Anchorage Company ARCO ALASKA INC. Well DS 13-5 ECC# 2581 Field PRUDHOE BAY County, State NORTH SLOPE, ALASKA Date 12z19-86 Curve Name (Abbrev.) Standard Curve Name FILES 1-4(! ' CCL~Casing Collar Locat DK'100 RIN L__S Lon__~g Spac____~e L~ Sh°rt Space " Gate 2 ~ " GR ____~Gan~na Raz BKL' Bac__~round Lon S ace' " BK__~S________~ound Short Soace_______ " MON Monitor CSS C_~ture Short Space' ISS Inelastic Short S~ " !! MSD Mean Std. Dev. _______ SGMA S i_~ma RATO Ratio.of C~aotureC_____~ounts~ " RICS Ratio or Inelastic~" Ratio of Inelastics " Logs Used Scale 4:~0- 600 - 700 )-72000__ RBOR Borehole Ratio " 3 to-1 Page 2 of 2 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska I Inc. Well D'~' 13- 5- gCC# 2581 Field Prudhoe Bay County, State North Slope, Alaska Date 12-19-86 " Curve Name (Abbrev.) SGAV RIqAV RCAV RTAV ~R Standard Curve Name FILE ' 5 Average Sigma Average RIN Average RICS Average Ratio Gamma Ray Pass 1 Logs Used PDK-100 I! Scale 60-0 14-4 43-0 33-3 0-100 PPPPPPPP UBBB~'~ __ PPPPPPP 55BBBBB PP ~ ~D - P~ cD ~B · AAA~A~ CCCCCC AA AA CC Cb AA AA CC CC AAAAAAAA CC AA~AAAAA CC AA ~A ,CC CC AA ~A CC CC AA ~ O0 O0 00000 CO00G O0 0000 O0 wOO O0 OOCOOCO.O0 0,3 ,CO OCCO00CO0 OOGOGO0-C O0 OOC, O0 C30 CO O0~C '00 O0'~ O0 GOO00 O0 30000 OOCCO OO OCOO0 O0 OOCO OS OCO0 O0 000 OO OCO OO O00OO000g OOgOCO600 O000CO O0 00000 UUUUU:UU .. OOOO CO 000, O0 000000000 O00OOO00O O0 99999 :::: 9'9, 99 99~99999 9999999,-: .......... 99 99 ::':': ;999999 99999 :::: 88 88 22 888888 .222 888888 222 28 S 222 · $~, 3~. 2222222'2 888888 ' O0 30 O000O "00000 O0 OOCO CO 000 ~C 3OOC, GOOCO OOCOOCOCO // 222222 /// 2222222Z /// O0 O0 0 222 22 222 222 222 222 222 111 111 !11 III III 22222222 /// · ~2222222 III // 111 1iii 11 11 11 11 1t 11 11111111 11111111 O0 // OEO000000 /1I OOCCOOOO0 /// 03 O0a~ /// O0 COOC /// O0 COQOO tll OOCOO C3 Itl 0060 OO //7 gCC OC III O00CO000C iii COCOCCCO0 /// O0 I1 --EL N,~i,iE ; ;ATE : ...... EkviCE N~M~: ~ZYLiS '--EL COi,~Ti'NU~T~'Oix, NOM:'ER:.~ 0i "REViOUS REEL NAME · 'OMMENTS: DRESSER ATLAS LiS CUSTCF!ER TAP-.= --- CREAT-F.. BY SDS .F_NGTH; 13,2 E'fT ES -.~, TAPE HEADER SATE ; ...... )RiGIN ~ FSYS .. SZRViCE N~ME; ~dSEGR Td~= CONTiNUEYiOK NUMBER; 31 ., =REViOUS TAPE NAMZ , ~ ~,-,,., NTS. ,., _ENGTH: I~Z 5YTES ..~ ',~, :ILE NAME; BASEGR.OOl VERSION ~' ; q MNEM CONTENT.S . APIN : 50-07.9-20626 CN ; ARCO ALASKA .ZNC, WN : B.S. 13-5 UNITS FN : PRUE. hOE BAY COUF~ : N.SLOPE STAT : ALASKA LCC ; I 50 FORMAT ENTRY SLOCKS -TYPE --NTRY F, ESCRI?TION 4 - C - 9 ~ 11 O I DEPTHS DECREASE 6C,0 FRAFE SP:CiNG · lin FRAME SPACING UNITS 13 MAXIMUM FRAMES/RECORD TERi<iNATOR -S, :CO. L~"?L-, S~QC~N'G DATUm S?ECiFiCATION ~LOCKS .. . CURVE P, EOR CURVE R.EPR N~ME CODE SIZE SAMPLE bNITS NAME CCDE SiZ: SAMPLE= UNITS .SCL 68 4 1 CIM LS 68 4 1 CPS SS 68 4 1 CPS G1 68 4 I CPS ,55iS 68 4 i CPS G2 68 4 1 CPS ~R 68 4 i APi MON ~6 4 I CPS SGMA 68 4 1 SO MSD C& 4 1 SU ~ ~o 68 4 I ulM RSOR 68 4 i g:lM FORMAT :i~TRY ffYP- ENTRY g-SCRiPTION 4 i DEPTHS DECREASE 8, 6C.0 FRANE SPACING 9 .lin FRAME S~ACZNG omiTS il i3 ~XZMUFi FRAMESiRECOR~ 0 TERMINATOR -G.SGO LEVEL SPACING ~ATUM SPECiFiCATiON 5LOCKS CuRVe,. REPR NAME COD~ SiZE SS 68 GR 68 CSS 68 SGM~ 68 RATO 68 Rii'q 68 DATA CURVE REPR h . · , U N l T S N ;, M E C ¢:iD'?iE CPS BKS 68 DIM RBOR DIM RICS 6 SAMFLE UNITS DIM Ci M ,~ ;. I S ,, x, 5.; 2 n .. 3KL 5 SGMA - CC~ 7T 3365.~'ISC O.OO0 kS 4.4C0 G2 O.OOO GR 9. 994 BKS i i~.~8 CSS 5.665 MSD 8.6i5 ~TO O. ~C,O ~iCS O.COO C.OCC 54.3'5 £.CCC 17.330 M 0 N iSS RBOR O.O00 C.003 u:FTH 11CC0. CC'""~ FT 3351. 8070 Fi CCL 560.530 L$ 26.107 GElS 415814.300 Gl 41.154 5%L 138.554 BKS 100.185 S-G i,i A -13.135 HSD 15.322 ~iN 8.,300 RiCS I · 871 SS GR CSS RATO 9.992 50 9-' 25.620 C.375 M ON ISS REOR 29.666 O.0O0 47.927 I Cn~ 9"EPTH I"'900.CC0 FT 3322.3276: C%L O.CO0 LS 1 5.730 G-~iS 520206.700 62 0.430 ~-~KL 45.695 BKS 56.973 SS GR CSS n. · ~37 24.44C 7.419 G1 MON iSS 14.441 0.000 17.9'57 RIN O.CO0 RICS 2.420 DEPTH 10800.600 FT 3291.8470 M SCL O.CO0 LS 31.510 $~IS 246740,S00 G2 5KL 22.C?S BKS 51.643 S.SM~ -ii.034 MSO 7.C~i RiN 0.C03 ~iCS i.65Z SS GR CSS 19.497 01 17.0ii ~iON IC.323 ISS -i.-iiZ RbU~ 11.092 0.312 17.050 -1.2~'i 'ZE~TH i3700.CCC FT 3261.3070 iq ~imlmliiIlmmllmllIIIII CCL G.CGO LS 7.875 G~qs 7157~.513 Gl 6.9,52 SKL 2~.525 5K$ i5.960 SGMA -77.¢75 MSD 56,~01 lin O.CO0 ~iC$ ~.~6 SS GR CSS RATO i5.2~6 0i 14.6S4 MON 10.639 ZSS 2.6~1 RBOR i4.24i 8.300 10.654 3.463 Cr~.,, Ic$00 r'~C ~'i ~£30 COL O.OOO LS 12.708 GEIS 261837. 7DO G~ I0. 712 -BKL 24.449 5KS 16,108 ' ¢~SO Sc 904 ~St:,A -255.633 · -. , R!N O.OOO RICS 1 SS GR CSS RATO 6.549 16.7Z8 MON 3.63~ ISS C.343 RBOR 3.299 3.~54 0.g45 DEPTH 10;00.0'30 FT 3200.4060 M CCL O.SCO ];GELS i71072.C00 LS 0,735 SS 11.071 Gl 9..~ii. GR i6 292 MON 02 ' 15.224 0. 000 ! CCL O.CCO LS · ,27.003 SS i GElS 539686.800, ~ 5KL 12i.331 " SGMA .3.732 · RiN O.COO PT .... 4'" M 'gE H q""O".CCCu.~ .,~ =~ ,,~3;,·4 ~ .............................. 24.151 R!CS 0.601 ' CCL 0.000 LS 1.369 GEiS 2i0i38.i00 G1 i9.535 ' 5, r,,L 63.'~90 ~,x~ 20.352 'i RiN O.CO0 RiCS 0.684 12.105 8.436 1.267 SS 2~.336 G1 GR i6.764 MON CSS cO.TSi z$S RATO ';.?~3 RBOR O.O00 i~.202 1.631 t DEPTH 1020,3 C~O FT 310~,. 6au M .]CCL 64.6.50 LS 12.270 '}OEIS 262321.800 G2 ' 3KL 44.675 3K5 52.395 ~SGMA -10 476 . oD 9.279 ,-21N O.CO0 RICS 0.892 SS ;.833 01 GR 2'.016 MON CSS 6.795 ~2TO 1.40~ RBOR I 5 0.012 6.0.5~ 8.619 t DEPT~ 10100.000 FT 307g..:;'°60 M ~CCL 0 COO L5 I ' 'GEiS 150725,300 02 i =~KL 71 .~99 BKS :.i 'SGHA -I 4.224 MSD 'RIN 0,C00 ' RiCS 25.3,39 19.S49 7~ 460 35.473 0.827 cS 1~ ~ o.57C 01 GR 44.843 MON ¢~¢ I~ 95~ i$S R&TO 0.999 R202, 18,':58 C. GOO 1~.671 C.&Ot 3EPTH 10000,000 FT 3048.0060 H 3CL 0.000 LS 20.379 SS 25.598 G1 7.425 'ElS 417669.700 G2 19.993 Gq 138.633 HON 0.000 ~KL 315.326 BKS 366.318 CSS 7.737 ISS 0.177 SGM~ -45.075 r~S.D i7.640 R~TO 1~.07Z RSOR C.9~7 ~iN O.CCO R~CS O.CZ3 Fi- ~C29.566C ~ L$ oo.o19 b~b i~3.~8i ~zC~ C5~ ~6.032 zSS i3.6~I RATO i.i20 RBOR C.813 ENDimG 3~FTn : 9~59,500 ;T 5029.566~ M FiLE TRAILER ** .~LE NAMe: 5~-EGR 001 SERViC~ NAME: VE~SiON MAXiFiUM LENGTm: FiLE l-¥PE: kO i024, NEXT FiLZ NA'NE: . . · SERVICE NAME: VERSION #:1 FiLE TYPE: LC PREVIOUS ~ZLE NANE: ~¢i~~~:~'~¢m~;,~;~~~;~,?- ~ iNFORM.'ATiCN RECORDS MNEFi CONTENTS UNi TS APZN : 50 C29-20626 CN : ~RCC, ALASKA ' FN ; PRUBHOE COUN : N.SLOPE STAT : ALASK~ B~Y cCC : ~. F-- 0 R F.; fiT ENTRY E'LOCK S T~r-E ENTRY CESCRiPTiON EEFT~iS P~ECRE&S: FRAFE SP:~CiNG FRAiV:E SPACING UNITS MAXIMUM PRAt, lES/RECORD i ERP;iN~TOR LEVEL SP~CiN~ DATUM SPECIFICATION BLOCKS CURVE D~PR CURV$ NAME CODE SiZE SAMPLE UNITS NAME ~CL 68 4 1 DIM LS +s ge 4 1 -Ps GElS 68 4 i CPS SR 68 4 i ~PZ MON ~KL 65 4 I CPS BKS -SS 6& 4 ] AP~ SGMA 65 4 1 SU MSD RATO 68 4 ] L, iFi R:OR ~IN 68 4 I DIM RIgS REPR CCDE ~3 6& 68 68 68 SIZ = 4 S A~. I,,1 P L E, UNITS 1 C~S I CPS 4 -1 C? S 4 I CPS 4 1 "P~ A I S u 4 1 4 1 D It-', FORMAT ** :;,'TRY SL$CKS TYPZ -NTRY CESCRiPTZON 4 I DEPT 8 6 C · 0 F R A M I I I 3 MAXi C T = RM -0. 500 LEVE HS DECREASE E SPACING E SPACING UNITS MUM FRAMES/RECORE iNATOR L $?ACTNG DATUM SPECiFiCATiON CURVE REFR 5LOCKS ,SC L 5 =_ I S 6 ,B S-R . 68 BKL 68 ',,SS 68 SGMA 68 ~ 68 RATO : ~i N 68 4 4 4 4 4 4 1 CPS G2 68 1 API ISS I SU MSD ,,, ................... 1 ................ CIM ................... R,BOR ................................. 6.8 ............. · I DIH RICS 6g 4 1 4 1 4 I CPS CPS CPS SU Di M D~'~. M OE?Tn 11341.000 FT 3565.3046 M 3'CL O.CSO LS 429 ~'E1S 64723.520 G2 6; ~KL 229.977 BKS 559 SGMA 42.3C9 HSD O ~iN II.~$~ RiCS 23 .957 .993 .944 .C76 .395 SS GR ,~sS RATO 13328.65C 46.493, HON 931~.076 iSS 31.156 RSOR , 1649.835 21CC13.300 1,675 i~CL 11,.-.'.. ,..,",00 LS ..., $E1S 69747.060 . G2 72 ~KL I 21 . 531 3KS 21 5 S~GMA 43.080 M,SD ~iN 11 .361 RICS .7C1 .64Z i ,' .437 SS GR CSS RATO 10510.31~' G1 45.3 62 M O N 8624.164 ISS 27 ~ · ,+~ £ RBOR 1191.002 3~0.346 -=~L O.SOC LS 1125 ,9g7 SS 6850.2.70 5KL 63.597 BKS SGMA 17.941 MSD RIN 11.009 RIC$ 155.066 0.424 22.190 CSS RATO 12760.590 ISS 253152.S00 1 5.833 RBOR 1 .767 ]EPTH 10800.CC0 FT 3291.847C M ~L 0.300 LS iC72.029 ~RL 3a.87~ 5RS i2~.346 S-GM~ i8.i35 mSD G.2CC SS 17753.900 31 6073.770 'lo.~C ~UN ~iC.CoO -i2392.360 ZSS 26376~.80~ ~.702 RBOR )~Pim 107OO.CCG Fi q~6i.3670 M [lllllIliaIIiIiIIIiIIliIIiliiI ~"~iS ~79i7.750 02 i963.a77 ~G~A 17.887 ~Su 0.544 ~N 10.391 RiCS 20.941 'i827~.2qC 61 o43~.162 i6.i28 MON 393.~24 'i277~.25C ~55 26740;.-3~ io.044 RSOR 1.757 ~PTH i06CO.CCO FT 3238.8860 M ......... ZCL 0.CC3 LS ii05.075 SS ~iS 67~$.130 02 i9i4,755 G~ ~L 28,CC3 ~KS 12S.779 CSS ~MA i7.94~ 'MSD 0.544 RATO ~N iC.5&5 RiCS 2i.304 17701.70C Gl 6i47.0i7 15.367 NON 383.535 124~i.6¢C ZSS 262168.100 i6.395 RBOR 1.776 3EPTm i0500.C00 FT 3~00.4060 M .~CL $ G iq A i 6.862 MS'D-; ;EPTH iO4OO.CCO FT 3169.9270 M :CL O.CO0 E~~ -ElS 65729,030 02 241.988 GR ;NL i9i.COi mKS 326.264 CSS iGMA ~' 35,i84 MSD 0.964 R~TO iiN i0.439 RiCS 3i.205 6736.902 40'3.79i MON .585.844 8598 3 ISS 26,[3i 6.000 21.610 RBOR 2.037 ;EPTH I030C.COC FT 3137.446C . ! i ! i I i ! ~ !I ! t i i i -- /i !,i Ii ! ,CL O. GO0 L~ i656. ,EIS 73846..380 02 2~77.121 KL 62.224 EKS 133.447 ,GMA i 8..380 MSD :iN 9.7:i5 RiCS i3.4E3 a~ ~03)8.640 Gi 980i.9i8 GR 2S.ICZ XON 448.44¢' CSS 1E. 574.~70 lSS 249322.400 RATO 16,227 RBOR 1.374 iEPTH i0'200.000 F--T 3105.9660 M CL C.CC3 LS 20.0i,2i3 ,~10 7939i.060 02 3125.331 KL 57.~2-2 ~KS 140.387 Gm,i~ I 8.084 MSD O. 262_ ~ 9.004 RiCS 13.301 SS S3i68.64C Gl 18111 .ruO~Z GR. 25.355 NON 437.7~9 ~3c~ Ia6~4.$9~ ~a~ ~47~.100 RATO 15.454 RBOR 1.415 ECTH 10100 COO FT 3073 486C ~' · · ! ! III I ! i i i ....... I I I i i i i ! i I I i I 5% C.~CO LS 15~';. 34'= SS -~iS 76579.690 G2 1301.D01 GR ~L i82.4~,9 BK~ 2fig. Z06 CSS , , ,, 24"""'"' 11C 01 6~' . 6 u,,,,., · ,.., ,; 47 6 :.59.2~C NON 424.. 915 i4~6E.470 iSS 24~i47.500 'IN 9.189 RIOS 16.384 EPTH 10000.C00 FT 3C45.006C M 'CL 0.000 LS 1455.291 ~-215 74995.38.3 GZ 1418.305 'KL 360.C35 ERS 40~.313 ;GNA 2i .9~ i MSO 0.~5 ~iN g.025 ~iC$ i 5.1C5 SS GR CSS ~AIU 256o4.23C G1 iC5.095 MON 15655.04C 6933.691 42i.2i0 ::,PTH 9c37.5C0 FT 302~.~56C M I Imim I I i I IIII m III IIIiIIII IIII ! SCi_ 424.803 L'S 557.905 )-F. 1S 6311~.706 G2 7.18.355 ::-i,:, L i96.368 BKS 25i ,353 1OMA 37. i 84 MSD O. 640 :l~ 9.5i4 RiOS 23.00~ S~ GR CSS RATO i47d~.9CC Gl ,,-...,,, ,-,, xO..~,- 5 M N 97~].i45 lES ;d.186 REOR 2092.3i5 3G4.522 ZZ~gO~.10G 1.61! STARTING DEPTI; :11¢'41.'~' u UuO FT ENDING DEPTH - 9937.S00 FI 3363.3C40 M 3C, 28.9560 M FILE TRAILER -ILS NAME: PASS 1.002 SERVICE NAME. V;RSiON # : I :,ATE: 85/1i/ MAXIMUM LENGTH: 1324 ;!LE TYP=: LC NEXT FiLE NAME: VERSION. # ; I PReViOUS FiLE NAME: ** iNFu~MATiON M N F.. ",., C 0" "" "' N T S,,,, UNITS aPiN : 50-C29-2002~ CN : ARCO ALASKA INC. WN ; D.S. 13-5 FN : PRUCkOE 5Al' COUN : N.SLOPE STAT : ALASKA - LCC ; 15O.O0 *.;, FO: ?'?.MAT '*~, ENTRY [LOCKS TYFE ENTRY EESCRiPTI,SN 4 i DEPTHS DECREASE 8,. 60.0 FR~,:'-'~'- SPACING i ~ .lIN FRAYE S?ACZNG UkiTS ' 11 13 MAXIMUM FRAMES/RECORD -0.5C0 LEV-_-L SP.~CZNG ATUM SPSCIFIC~T!ON BLOCKS URVE REaR CURV5 REPR i~mm CuD= Szz: S~iPLm uNItS N~mE CC3~ SiZE CL ~ ~ 1 D~M LS ~ ~ ,~iS 6~ ~ i CP~ 82 66 ~ i CPS ,KL 6~ ~ 1 CPS ~KS ~ ~ 1 CPS ,S~ 08 4 1 AvI i~ o8 4 1 'GMA 68 4 1 ~O HSD 6~ 4 1 SU ~iN oo 4 1 Ol~ kiCS 6b 4 .,~ · ENTRY BLOCKS 'YPE ;ixiTRY DESCRiPTiON 4 i ~r--PTHS D~-CREAS- 8 60.0 FRAKE SPACING ~..:,: ~ .'JiN ~RAM~ SPACING O~iTS .~ i i i3 ' MAXIMUM .FRAMES/RECORD 0 i ~R~iNATOR , -0. 500 LEvSL SPACZNG,, ,,~ 'URVE REPR UNITS 4 I ElM LS 68 1 CPS ,~¢,,,,,, ',,,~, 1 A PI MON 4 I C PS 1 CPS BKS 4 I CPS 1,' .. API ISS 4 I · CPS 1 SU MSD 4 I SU i ~ i i,'i RBOR 4 1 DIM I D I I"~ RICS 4 1 DIM 68 68 IEPTH 11,34t.CCC, FT 33,65.304C M ~F. iS 65393.460 G2 119.988 GR ~NL i89.981 5KS 8i9.9i8 CSS SGMA ~9,54~ HSD i, ?~S RATO ~li~ i i .C62 RiCS 2Z .657 145i8.55C G1 1599.8, i0 52 095 MON 421 9,58 :~' 9769.023 iSS 221 337. 830 ~: 29.182 R30R 1.622 SEPTH 11COO.CCO TT 3351.S$7C M ~CL 37.950 L3 .73.412 SS :-~i S 0806'4.750 G2 79.989 GR 5KL ~11 .419 BKS :33.131 ess SG i.,iA 44..234 MSD 0.507 RATO q~N 11. ~'04 RICS 30.12~ 10037.33C Gl 1084.$62 51.972 kiON 390.474 8318.453 ISS 250~7C.600 26.943 RSOR 1.966 5~L O.CO0 LS 1108.408 SS 2-515 70056.380 G2 1873.134 GR ~.KL 57.131 BKS 212.297 SGMA 18.433 M$D 0.366 RATO ~!N 10.320 RiCS 21 .669 18066.66C G1 6157.015 28.1C6 MON 418.057 12764.36C !SS 276595.400 16.224 RBOR 1 .78.4 SGHA 17.96,3 MSD 0.210 ' RATO t6.G~,7 ~EGR 1.765 -.~', ~. :-~-' ! ' ,. ~ -. ~ CCL BKL SGMA 16.41'S ,' ~IN ~0.352 CCL O.CGG ' : . o ~ ,~ S 65 844. : · BKL 240.895 :, SGMA 40. 556 'RIN 10.610 : I .758 LS 437.890 SS 92~1 G1 G2 ................................. ] ...... 116.930 ........ GR ........................ 75.549 MON 376.099 5KS 31~.725 MSD I .242 R~TO 2~.143 R5OR 2.037 RfC S 32..721 ~DEPTH iO300.CCO FT 3139.44o0 i CCL O.COO L3 1787.526 i GEIS 74815.250 G2 2694.062 l''it BKL 68.5C7 BKS 160.995 SGMA I 8.798 MSD 0.21 6 'i1~ R'IN 9.C27" RICS IS.459' SS GR CSS RATO 28295· 470 61 9Z7~-.~98 27.559 MON 431.114 17421.i5C iSS 234469.800 I ~ 776 RBOR 1 392 GR CSS R ~TO 2~93C 9~ 81 9355 ~'' j ~ m ~ ZT. 277 M3N ~3£. 153 . ~ ~ ~ m 1774~.~G0 iSS £3>6~4 200 15.316 RBOR 1.393 '? SL ' O.OOO LS I381 ..534 SS :~L 158.299 BKS 255.7C5 CSS 14546.16C GMA 23.247 MSD 0.420 RATO 17.074 'IN 8.908 RiCS 16.178 'r--.PTH 10000.000 FT 3045. 0'360. 1',4 RBOR ~.'70 ~' 235320.600 1 .474 -CL O.CCO LS i362.6,41 SS -,Nc 348.399 ~NS ~1 .7i3 CSS 'GMA 2Z.~77 ~SD 0.027 RATO %N 8.761 ~ZCS '15.385 24Z£S.aSC -1-1~.-188 i469i.08C i7.oi8 Gl ZSS 6370.S20 407.755 22d053.~00 1.422 __~mmmm--mmmmmmm--mmmm-- ..... m .... l%L ~i3.;50 LS 537.q~; ]-1S 607$2.990 02 218.245 SOMA 36.768 ~SD 0.S&i 2ZN 9.433 RtCS 22.865 SS i39ii.iCC 7C.5E2 Gl H ON RSOR 202i.69~ 2i2209.700 i.CSZ STaRTiNG DEPTH 11041.C, 00 FT :NDiNG DEPTH - 9937.500 FT 3365.30C0 3028.9560 FILE TRAILER '=ZLE NAME; ~ASS SER'v'iCE NAM_=: VERSION # : .i -~TE: ~5/iii MAXIMUM LENGTm: NAME: .i02~ SERVICE NAME V'_=~S20 MAX R~CORD LENGTh: 1024 BYTES FiLE TY<E: PREY'ZOOS FiLE NAME: ...... · ** iNPOR~ATiON RECORDS ~* ' , MNEM CONi' NI'~ A~iN : 50-C29-20626 CN : ~CO ALASKA iNC. WN : D.S. i3-5 - ~N : PRUDnOE BAY COON : N.SLCr: STAT ; ALASKA LCC : iSO.O0 ,¢. FO .... T .' ¢, ENTRY BLOCKS TYPE ENTRY DESCRiPTiON "4 i F-. =PTHS · ' 8 6C. O FRANE ,' ,I '~ ~, ,,',-' "~ DECREASE SPACING il 13 M&X!MUM FRAMES/RECORD 0 T:RNINATOR -O.SO0 LEVEL SPACING 'ATUM SPECIFICATION BLOCKS ;URV[ qEPR CURVE REPR ~L 68 4 J DiM LS 66 4 1 CPS 68 4 i CPS ~1 6~ 4 1 C~S ~iS 65 4 i CP~ G~ 6& ~ i 12 68 4 1 APl MON 68 4 1 CPS 6G 4 1 CPS ~KS 68 4 I CPS 'SS 58 4 I AFl iSS d~ 4 1 CPS ~Giq~ 68 4 1 SU MS D 65 4 1 SU ~TO 68. 4 i ~iFi ~SOR d ~ ~ 1 ~ N 68 4 I g i M R I C S 6 $ 4 1 D l ~'~ FORMAT ENTRY 'BLOCKS 'YDZ ENTRY D-SCRI~TION= i DEPTHS DECRE~mz 6C.D FRAME SPACING .lin FRAh',E SP~,CiNG UkiTS ~3 MAXIMUM FRAMES/RECORD T~R CODE Si~.~ _~ ;CL ;S ;R' ',KL ;SS iATO SAMPLE UNITS NAME CCBE S SAM LE UNITS 68 4 68 4 1 CPS 01 4 1 CPS 68 4 1 CPS 02 6 4 I CPS 68 4 .. 1. API ......................... MON.: ................... 68 ...... 4.L ...... 1., ' CPS 68 4 1 CPS ~K5 6'9 4 1 C~ 68 4 I A.P! ISS 68 4 1 CPS 68 4 1 sU MSD 68 "' 4 1 Su 6.8 4 1 DIM RBOR 68 4 I DIM 68 4 i DiM Rlu~ 68 4 1 ~IM '., ',EPTH 11041.CCC FT 3365.3040 M ,C~ 0.000 LS 449.955 SS I]59~.640 01 2049.795 ';1S 59474.850 02 199.980 8R 53.21S MCN 378.962 i.:, , ,~L ~89.9~1 BKS '419.95E~ CSS 9119.09C ISS 195260.400 ~S~4A 36.917 MSD 0.424 RATO 2c 582 RBOR 1 615 .'> L~~l * m ,, 11 .]40 RT;S 21 .412 ~DPT',I 11000.OCC FT 3152.8070 M >CL ~ ~'' ~.,., 4:,8 L$ ~40 4~'' ~ '' · ~ · ~-~ SS C'07~. ~-?]3 62079.378 G2 73.916 GR 54.840 F',CN 386.058 .... I~m, · ~v2_,, o,,~,,~c 22Z .r2~. .,.,rSS 7°I = ~GMA 43.395 MSD 1 .357 RATO 2~.301 REOR 1 .$70 :iN ' I'I.C84 RZC3 30.16C, DEPTH 10900.000 FT 3322.327C M SCL O.CO0 LS 1C13.650 GElS 61768.380 02 1(:67.C66 BKL 72.790 BKS 189.811 ~ Gi~/~ i 6,364 I~SFO 0.622 ~ i i',i i O.F..,75 ~lCS 22.003 SS 16Z94.96C 01 5522.734 SR 26.686 MON 401.712 CSS 11396.330 ISS 250756.600 RATO i5.753 REOR 1.764 -DEPTH 13~00.000 FT 52~i.847C M _ l--i------I~--IIi__i .... i--iiilI .... ~ KL 45.522 BK$ i53.597 %GMA 17.5ii MSD 0.373 ~ iN 10.C09 Ri0S SS ]6666.75C G1 5825.008 C55 ii6Gi.6CC 2~S 244826.700 ~4TO 15.690 R~CR 1.802 '%-PTH i0700.C35 ~T 32C. i.307C M ~CL C.COC LS 960.721 GF-iS 572gl .860 G2 i659.403 =KL 53.614 5KS 1~5.173 %GMA 17.795 MSD 0.523 ~iN lO.Cdi RiCS 21 .483 SS 152~C.120 01 5Z41,090 GR 21.97i MON 369,479 CS£ i0718.66C ZSS 23, C269.700 RATO 15.46C REOR 1.760 ~EPTH I0630.CC0 FT 3230.8863 M --i ...... i ................... ,! i COL O.C'O'O L5 ii£8.li7 G~iS 0704i'.440 02 i927.]i4 ~KL 56.457 'BKS 167.695 SuMn i7.755 SS i$02i.05C 6i 6i48.536 GR 19.456 MON , 427,934 CSS 12503.390 ISS 25,3963.100 ~ATO i6.05i ~EPTH IOSOC.CCO FT CCL O.CO0 ~ GElS 71480.500 02 5KL 77.054 BKS SGMA 17.3i4 ~iN 10.116 188.396 CSS 13625.4C0 278362.400 DEPTH i04OO.CCC CCL O.COO LS GElS 59217.540 ~2 SKL 2&4,403 BKS $GMA 30.308 MSO ~IN i0.223 ~ICS FT 3169.9270 M 523.403 SS 498.463 GR 307.369 CSS 1069Z 100 Gl ~ 6 · ~:06.62 8'i· ~4~, MON 3*~ou. 083 8216.363 ISS 248057.200 20.~i8 RBOR i .990 DEPTH 13300.CC. 0 FT 313-~.446C m lIil i IIm Iii i ! ml__i iii ImiiiIii I JCL O.C.O0 LS i707.592 gElS 73476.690 02 2414,726 r~K'L 80.7i0 5KS 14~ .~34 S'GMA I -~,4,50 MSD 0,292 ~ZiN SS GR eSS R&TO 2755i.24C Gl 8726.i91 27.559 MON .458.848 16556.45C ISS 23CC76.830 I5.861 DE?TH i0200.0C0 FT 3108.9660 M SCL O. CC,3 LS i E:i $. 5~4 ~EiS 70073.580 02 2897.252 5~KL 87.234 BKS 152.164 ~A i 7,5,39 ~,i 5 b O. 1 ~ 5 ~i N 8.54= - ,' RICS I Z. SS G~ CS3 RATO 2742C,05C 01 ¢Ic,_~'', u'8~ 3C. 78C MON 431 , 412 16,7;7.130 ISS 2224:32.100 15.246 RSOR I .3~9 ~TH iOiCO.CO$ FT 3073.486C M C'CL 0.000 LS 1447.120 GElS 69066.810 G2 1517.524 BKL 162.-~62 BKS 2~5.508 SOMA 21.296 MSD 0.9CS RiN 8.634 RICS 15.892 SS 22274.78C G1 EO6g.180 GR 66.869 MON 393.438 CSS 13878.9C0 ZSS 220557.100 RATO 16.13~ RBOR 1.497 w~'~ ~240.93i SS 209~].22C G~ 567i.965 1226.142 GR 123.CC6 ~O~ 378.387 S 411.i~ C$5 i25;2.750 i$$ 2CZ3i3.i00 0 0.264 R~TO i6.7~4 ~0~ ~.450 C$ 15.692 C%L 843.300 L$ 534.C22 D-1S 57200.960 G2 230.340 GR 67.36[ MON 383.~22 .~%L 204.163 3KS 2Z8.6~0 Cc~ ~011~ · .42~ ~$S. 20~.=~.Oon. SgMA 37.60.3 MSD 0.577 ~&TO 24.g77 RBOR 1 .634 ~:N ~.0~¢ RICS 22.618 ~TARTiNG DEPTE =11041.000 FT 336;.3C40 M _,~3~N8 DEPTI, = yg~7.:,OO FT 302~.9260 H FiLE TR&iLER ** ' -iLE NAME~ PASS 3.004 ' ~£RViCE NAME; ~RSiON # ; ~REViOUS FiLE NAi,;E: . iNFORMATiON RECORDS MNF_.M CONT E;ATS UNITS 50-029-20626 CN : .ARCO ALASKA INC. WN ; D.S. 13-5 FN ' PRUChO- nAY COUN ; N.SLCPE ..: STAT ; ALASKA LCC - 15~,~ . OO .. ~ FORt.'," ,' ,., .. -NTRY ~LOCKS 'Y-~ E ENTRY 2ESCRIPTION ~ .lin 11 50 0 -0.500 FRAME SP&CING FRANE SPACING UNITS M~IXIMUM FRAMES/RECORD T ERIVTN/1TOR LEVEL SPACTNG D&TUM SF:Ci:iC/~TTC, N 5LOCKq ~i- . COD SLZE S~NPLE uNL]S ~GAV ~ 4 1 R~v 68 ~ 1 RiAv 68 4 1 Ru~v o~ 4 '1 FORMAT ** ENTRY ELOCK~ ~YPE ENTRY OESCRiFTiON IlIi iiIilI! 4 i DEPT '" 9 .lin FRAi< -ii 50 "',0 -0.500 L~VE DECREASE SPACiN$ SPACING UNITS ~uM FR,~MES/R-CORU iNATOR SPACZNG ~ATUM SPECi~iCATiON ICURVE REPR NAME CODE SiZE SGAV ~AAV 68 EEPTH 11C41.C~0 FT 3355.3040 M IlllIlI ........ lliil .......... 3G~V 39 5~ . . ~9 RACY 29 974 RIAV 11.431 RCAV 22.498. 3EPTH iiCO0.OCO F1 ~552.80'7C M S'GAV 43.570 R&AV 27.572 2i~V 11.316 RC~V DEPTH iOgOu. CCC FT 3322.3270 M ~AV i 8.i46 RAAV i 5. 937 RiAV i0.468 RCAV 21.954 TH iOSGC..£CO FT 329i.$47C M IIlIIIIilI,IliiIlllIIiltilll V 17.346 RAAV 16.269 RIAV 10.326 RCAV 21 23* S-E PTH 10700.C0¢,..., :'T, 3261.3670 M I ! / I I ! ! i I I i i i I I ! 17.577 RAAV 15.605 RiAV I g. 234 R CAV 21 R,iAV i C..354 RC$,V 20.679 5;PT~ 10500.CCC FT ~200.4060 M SG&V 16.865 DEPTH 10400.0h0~ RfiAV 15.290 RlfiV FT 31 69.9Z7~ M 10.326 RCAV 20.710 IC.424 qCAV 31.45~ ~EPTH iCSCC.CCC FT 313~.&46C M 3GA V ~ 8.8. 76 i5.~=~ R-A'v' i3.5i0 ~[PTH 10200.CC0 FT 3105.956C M ~AV i?.~63 R~AV E.5i2 RC.~V 13.27z, .,',-EPTH i CiOO.u~'~'~C FT ~075.4F~6C !,I t 6 ~9C R~'~V E.?lC RCAV 15.1:31 3G~V 22.~33 17.52,, R~V ~.775' RCAV 15.427 $GAV 3m.184 RAAV 2~.3~6. RI~V ~.345 RCAV STARTING CEPTh =11041.300 =T 3165.~043 ;4 :mDZNG DEPTH - 9.~r ,.5,00 PT 5028.9~60 M :iLE NAME; ;ERViCE NAME: iERSiCN ~ : q "ATE: S.S/q I / 4~iXiKUM LENGTh :iLE TYPE: LC ~EXT FiLE :,,lAME TAPE TR~!LER ^* ~ 'APE NAME; '" ...... N ~ ~. ~, ~ ~-~, ~. AM[: AVZRAG ~ATE: ...... ),RiGiN OF D&TA: 'APE CONTINU~TiOk ¢ : 01 ~EXT TAPE NAME. .;-; ' OMME NTS. .:. .~ REEL TRAILER .Ax '~ -, ',EL~ NAHE. ..,, 'ERViCE NAME: ~ZTLZS :kTE . , ~GIN 07 DATA- FSYS :", · EEL CONTiNUATiON ~ ; 01 :EXT REEL NA;,~E; ..: ,OMMENTS: DR=SSER ATLAS LiS CUSTCi,iER TAPE --- CREATED EY 3D$ FROGRAM R Z.C -':L HE~DER - I .. A~PE HEADER - 1 ~,..E MEA2-'~'~,, - 5 TT~ 0 R f,; A T T 0 N S ~'"~.~ M A T - I 0 ,:~: TABL~ DUMP - 4lL5 TRAILER - TAPE TRAILER - REEL TRAILER - T~OTAL ~ECG~DE~ 1 1 ?59 LIBRARY TAPE CL,-RVE SPECIFICATIONS Company Arco Alaska, Inc. Well DS 13-5 Fie!f ?rudhoe Bay Count}', State North Slope, Alaska Date 8/26/81 Curve Name (Abbrev.) Standard Curve Name CN Compensated Neutron LS Long Spaced SS Short ,~paced GR i. Ga~na Ray ICas CL t lng Collar Locator Logs Used CN/Mu!tispaced CN/Multispaced CN/Multispaced CN/Mu!tispaced Scale 60-0 0-1000 0-i000 0-i00 100-200 CN/Mul t..i_s~aced 0-10 PAGE 1 ARCO ALASKA INC, D.S. 13-5 PRUDHOE BAY NORTH SLOPE DATA EVERy 1 SAMPLES GR CCL ......... SS ............ L-$ .... CN 9290.00 0.00 0.00 0~00" 0"00 0.00 9290'50 0.00 0.'00 0'0'0 0'00 0'.00 ..................... 9291.00 0'00 '0',00 0',"0'0 0"~0'0 0~00 9291,50 0.'00 0"00 0','00 0,00 0'0'0 9292'"00 0,'00 0,00 0"00 0,00 0,'00 9292',50 0,"00 0"0'0 92'9'3,'00 0,00 0,'0'0 929'3"50 0"00 0,00 0;0'0 0';'00 0','0'0 ................ 92'9'~',"0'00',00 0;'"0'0 ................... g'2'~"4""5'0 50 80. 7. .SG ~82.32 2q PAGE 2 ARCO ALASKA INC, D,S, 13-5 PRUDHOE BAY NORTH SLOPE DATA EVERY 1 sAMPLES GR CCL SS LS CN 9315.50 70.98 7.93 264,72 227'35 38.7~ 9316,00 72.~7 7'92 p61.'59 22'8'59 3'8'57 9516'50 ' 71'06 7',92 "~5-~"~'~6 9"317',0'0 7~.7'i 7,'92 2'57','2"i 95i7'"50 7'5"8~ 7,9'2 ~'5'&,'~ 2~'~,'G'5 $~""2~ 9318.50 76"1'5 ?,~"~ ........ 93i9',0'0 7~",'28 7','9i P'5'~';2'0 2'~"0';'0~ 35,'0'9 9320.00 8~.61 7.91 256.02 23~.58 55.19 .......................... 93..~.i..;..~1.0 .............. ....~1~:~..0...;...9..g ~:.1:.9.11 .......................... 9~'A"'~"','"'O'b ........................ ?.%.3.1i ............................. .00 .............................. ................................ 9'3' , 0 0 9 1 .59 2~ .02 7.9~ ~69,35 2~ .96 32.67 9341'.00 64'55 93~1.50 61.65 '- 9342.00 60.59 9'5~2'5'0 59,5q 9343,00 59.28 ...... 93~'3,50 58,52 PAGE 3 ARCO ALASKA INC, D,S, 13-5 PRUDHOE BAY NORTH SLOPE .... DATA' EVERY 1 SAMPLES .................................... CCL SS .................... L$ CN 7.85 951.93' '250.99 37,-0'3 7.65 253'5'1 '23'0'.'91 37.10 ................................. 7'84 P55','95 230,82 7,83 ~5'8,'66 2'3'2.7'0 3'6,76 7'83" P6'0"'i8 2'34,65 3~','26 ........................................................................................ 7"'83 ~'G'1",'~5 ...... ~"3'6'~'~'5 $'G,52 ........................................................ 9"3"57 .............................. 9"3'~'0"'";50 40. 9~6~,~0 ~. 7.69 P8 .42 25 7.6 0 7.8 ~2.80 2~* .71 35.62 PAGE ~ ARCO ALASKA INC, D.$o 13-5 PRUDHOE BAY NORTH SLOPE .......... DATA EV"ERY 1 S'Ai~pL'ES · .......... GR .... cC'L ...... SE ........... L'~ .......... ~ 9366,50 qq,~5 '?.8q ~79,-9'~ ~36-,6'~ 38.'~0 93G7,00 ~5,29 7,83 27'9",~'G .... 2'3'6,55 3'8,92 93G7°50' 45','6'0 '?,S2 DSZ'"'O~ ..... 2'3'5'~'0'~ ........ ~ .............................................................................. , ...................................................................................................................................................................................................................................... 9309.00 ~9.03 7.85 P82.72 236.21 39.06 ......................... 9,,3,,?,~,,,.:1,0,.1,6 ~l,g,:,,.~,g ................................... ~,..:,..6.,,9 .................... ~"?"~'"'~5~ .................. ~'3'5"'~"'?"0 ............................. 3"~":;'"~"i 7.8 PG~,07 23 .79 GR CCL SS LS CN :,, FROPq 9290.00 TO 11060.00 LEVEL SPACING 0,5000 125. SAMPLES PER EECORD :i':~:' : ...................................... ~'::'" ":'?"'":"'? ............... T"'""'" ............... :"'": ............... LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO ALASKA~ INC. Well D.S. 13-5 ECC 2207 Field PRUDHOE BAY County, State NORTH SLOPE, ALASKA Date AUGUST 15, 1985 Curve Name (Abbrev.) S~andard Curve Name Logs Used Scale SGM1 SIGMA PASS 1 SIGMA PDK-100 60 - 0 Anchora,~e ...... RAT3 i J PASS 4 SGM4 SIGMA " " RAT4 RATIO " " PASS 5 ISGM5 SIGMA . " " RAT5 ! RATIO " " RIC5 RICS " " SGAV SIGMA 5 PASS AVERAGE " " RIAV GR1 t GAMMA RAY -~ ~ " 0 - 100 RAT1 RATIO " ,, RIC1 RICS " ,, PASS 2 SGM2 SIGMA " ,, l~.T2 RAT I0 " " RIC2 RICS " " PASS 3 SGM3 " ,, ,PRUDHO[ 8AY NORTH SLOPE AL/~SKA ~ ~ ' ~ ~ ~ ,,,, ::DA,TE LOGGE,'E **/**/** TIME LOGGSD **:**:** ,.~ - ~ ..~ . ~ ~ ........ , ......... . ~ ..... ~ .~'~ - ..... . ~ .~'~ ..... ~. . ...... ~ ~ .'~?'~ ....... ~ ~ ;~?~,~'~>~..~" . .~.~ ....." "¥~ '~.~.~'~'"~.~ .~..~z~. '~ ':':~.~.~::~.~:~:~.~ ~].~ ~ ~(~ ~[ cf e m .... ~ ~ ..... ~ . ~. , ~ ~ , .' ~.ICl:U,UOOtb ~;C :0 OQI~ RZC;..O,O0010 ~I04:0,00010 RIC):O.OOO!Q "' ~ "~'""~ .... '"~, .......... ~ .... ¢¢ ...... '" " '~ .......... ~' '~' ~'~'" .... '-'~*?'i~"~ ....... ~'~ ' ~t."";~'"' ~'~'~¢~4¢"~r~¢' ~ ,. ¢,,,, PRUDHOE 5AY NORTH SLOPE ALASKA ..... . .. DATE LO~SGED **/**/** TZ,fqE LOGGED ~?¢~.z~:~'~.~:`~.~..~.:.:~.~:~`.~.~.~:~v`~. -~ ~..~.~.~,.~,..~.¢~., .... ~ ............. ** ~N~NONZC ~ND UNZT OF HS~SU~E ** ...~.,/, ..................................... , ................................. ,,.., ...................... , ................... ~ ...... . .................... Sg~V mmm~mmm~mmmm~m~m~m~ .... fiT :2'-~89,C, 0 FT· ---- tt TOTC, L RECORDS DATA '~OE~ FRO¢,I 99~9,,30 TO 10608,50 DSFZNZTZON O~ CURVE HNENONZC ............ ~,, Corr~ti~n Gamma~ Raw B~T~J: 11/26t,~5 TIME': 14:19: ARCO ~L~S~ 13-5 9995. 21.720 15.54~ 13.257 22.93214.815 14..5i~0-61.35a 13.030 1~..557 .: 210015:~ Z3.683 19.236 15.~66 24.101 18.630 14.315 2~3.404 18.321 1~.385 ~3035~ 23.362 17.~03 13.86~. 23.706 17.a24 14.E55 ~23.684 16~6~7 15.42~ 20.8}6 ~0~.~26.979 19.788 13.91127.112 18-~92 15-0}'~ 2~.8,~3~ 1~.437 15-290 29.203 ~]~U55. ~.~25 ~0.23% 13.01)~ 27.~81 19~ 14.~74 27.982 19.7~~-66~ 29.086 ~!~65. ~2.031 16.064 12.55~ 22.6~5 15.~12 1~_6~.~]..~..~0.9 .... 13 ~:::~0073 ~17.710 14 047 11-710__1:~..,:Z3~ :1~,0:57 :12.:656~ 1::8.2~ 13.~69 12.960~7.a6~ 1/0085, 1 1~'3: 0135 :':'10145, t6.111 13.:075 1!,0.36 16.020 12.8'".9~ !1.9~3:16.017 12.0~..,3 12.422 15.21B1 .... 10'15]~ !~,8~597 14~63 11-~Z~ 18'394 ~3'~,~,?Jl 12,0~ 1.8.55~48~2.557 21.546 ~.]:~.S~:.:.!8 ~- 15 9 ~ 13~8~3 15.3~'2 14~27 17.~422 :::::'::1:0175, 18:.008 17.6:55 t3'~350 17 34 t8 314 ~4 17~ ~7P ~4 64 ~]7 737 ~~~~;~;~ ..,....~.~.:~'. :...:].0~05. 20.509 ]6.771 12 333 20.8~0 16.619 13.6.42 21'007 16.632 13.948 19.300 lu~15. 1~.~40 1,~.~17 1~.u~7 1~.)~:~, ~o.3yo 1,.;.0_~~~~60 19.508 ~]0225. 18.3~1 16.213 11.805 tS~A~93 15.684 12.767 !8.921 15%~7 1~327 18.t38 ~d~ ~ ..~ .. ~ ........ ~.~:~ .~; .... ~:; ...... ..... t:~..~: ..... ~ ........ ~: .......... ~;~ ......... ~... ~ ........ ~ ..~ ..... ~ ,~ ...... ~ .,~ .... ~~ .... ~: ..... DATE: 11/26/:~5 Ti~,:.. 14:t~: ~ ~RCO AL~SK~ 13-5 PRUDHOE ~:~Y biO'TH SLOPE ~L~SK~ 496 12.7~3 19.053 lf~'926 13.077~18.3~6 ~26 18.393 16.600 12.720 1~-082 /,.~ 026~- ~19. 79 17 4 · 4, !6 9 ~' t7 1'2 6 ~6 t .~7g, J~"~25 16.063 18.99~ 15-20~ 1~.005 16.150 15"821 13.359 17.893 15.592 ~4.747 17.45~ 20.419 , 16,73=8 15-609 18.38~ 17,774 5-659 19,~83 1 17"638 17.9~=5 1.6,'=~5~ ~18.927 18~' 1,6,~55 1~:,,~)? 1 .... 465 16,989 , 18. 2 375 1 9 16.0.,3 1,,.9~ 18,31:)15.4~2 15.292 20.300 15.128 15.309 19.405 r?:~,~.~'¢'.~a~' ~ ,~'" '~' ~=~'¢~ ~.~'~. ~'~'"' .?'~ ~'~ ~'F~'~,~ .., ~. ~a ~$ .~' ~ ~ ~,~ 24"L15::6 30.1:4 9'9 2.9'5, 22 04,2 12;Z 7 0,4 5.,: 15,219 !4:.27;0 17.~.637 15. 18, :14.08:,2 19'673 1 '::07 ,;._1:~:~::b:5. 1~38 .15. ~,6 17.892 :!: 88 19.8~ 16.776 . 3 , :: :: :, D~TE: 11/25/85 ~RCO PRUDHO~ E~Y Ti~,~E: 1~:!9: 8 13-S NO~T~ SLOP~ ~L~'$K~ 10~75. 16.776 15.420 18.029 1~-29t 14.781 ~0.530 16.32~ 14.771 1~'.948 17.053 10~85. 16.562 15.221 17.284 !6.391 14.522 19.577 1~,.312 15.200 19.199 16.789 ..... ~ · , · - - ~ ..... , .-~ ' . ..~ ~ '~ ,- - -~ .... ~',~~ "~x~, -- '.~,- ' ~'.~,::~ '~. - '.--.~: :~,~ ,,.~.~ ~. :~..,~ .... ~ ..... .: 10495. 16.~ 1~40 18.2~1 17.138 14,Z8~ 20.709 17.0~2 14~8~ 20.233 17.~601 10505. 15.408 14.175 t7.66~, 15.474 13.~g9 20 417 15.496 13.780 19.945 15.964 ,:10515. 17.482 15.960 ~8.281 17.557 15.712 20~6~2 !Z.867 1~6,117 20.045~1~.693 18'228 17,~,3 19,405,17-990 ~6,13~ 22.626~,8.~805 16,.84~2~ · e~', . . · .~:~ . .~..~.:~ ~:~ x~ ~, ..~ .~..~E~ ,x. ~xf~ ..' , ..~:~.~.~ ~Z::q.~ 5 ~ ~1 ~ ,' 863 1~ 6 ~ 876 ~ ~8- 635 ~ ~7 3 ! ~ ~ 1:99~ 2~1~ E~3 18~"~71 5 I ~ ~,~ ~,1~ ! ~ ~.~! 7 ~: :::'10545" 18"369 16.704 18,534 18,355 16.523 21.~7Z 18,7~0 16.558 9 t9 F'~ .. 05. PTH SGMA RATO RiCS SSMA RaTr~,., ~I"S.. RAAV ~.T./~V C-R1 p 9')95. 23.455 17.949 14.435 21.638 17.115 15.715 15.6)1 14.975107.853 lO00S. 22.928 17.905 13.930 22.837 17.213 14.0~4 17.916 13.713 45.~2 ." --,.. ,~,~.~*~-~?,- ..~,~ .... - ..... ' ..... ~ · --~ '~' .x '~ '~-~' '~-~ ~'""~. ~~~ ;10015, 24,04t 17,894 14.406 23,909 17,780 14,560 18,$84 14,187 432~75 10025. 2!,752 15.477 14.718 21.4e4 15,172 14.552 !5.5~ 1~,248 ~.7,781 luw. · =,.244 1~.872 15.¢16 .3, 08 lu. 1 , 4.6 lu~.o 1~,~3. ~, 3 ,~:",I:004S. 28.0e5' 19,627 15.588 26.5~ 19,213 15,~Oa,19,151 J[a,~ 6~,a94~ :~::.=~0055, 27'378 18"981 1S,009 27.820 18:,6~3 1j~062 19.536 1~-88~ 17:-832 1~.562 1~¢0 13.7.~4 12.60~ :~'5.:~ ~5 1 7 · 17'937' 18:~194 !4 t7 :43 1~433 14' 654 17,810 15,26S. 12,49! .... ~.Z,320 !5,~ ...... ~_%~4%_12,3~27~2 ' _ .......... 19,793 1.5,094 13,358 20,033 15,~8 13, 59 18.524 15.948 18.75~ I5.609 13.417 15.9!:6 12,904 32.890 ., PAGE 2 : .... , ~': ~'~ ' .... T ....... : :' :~ '' .... ?' "' '; .......... : : : , , , ~ , , 10235. 18.0~0 t~.i602 !2-7~ 17.732 15.?£4 13.34'2 16.376. 12.496 26.18e' ,, , , ~ . .... , ....... . ~ ~.~.~... ~?.~ ~ ~...~ ~..~. ~.~..:.~' 'lOE4~. 19.285 15.7~2 t3.1C1 19.051 15.504 13.090 16.189 13.067 26.9~5 .... -- -~. .... . .:~. ..... .~ ~ ~ .... ~ . ~ · - ~ .,~ ~. ~ ,.. ~%.~-. , ~. .... ~ ~.~. ~ ~" ~.. ~.,.~ .~'~ .~ .-~ ~ ...~?.' .- ~.~.-~.~. ~'~.~., ~ m.-~~¢~~~ ~'~.~ ~ ' ~ ~ ~ ~ C,~ Q ~ A ~ ~ 7 ~ , ~ ' c ~ 1~26:. l~.~l 17.~7~ 17.7u9 1,.li ~ 1,~.~,1o 17. ~7 ~7,1o~ 16.~3~ 31.6~6 1027~. I~ 412 13 ~35 1~.3~4 15,~:786 1~:956 1~.,393 J, 3~940 1~747~ 21.387 ~. , ~ ~.-..~ ~' '. ~ · · ' " .' ~ .... ~'~ '~,~'. ~ "~.~.' '.'-.~.~'~ '.~' .~e?'~>~' ?~:.' .,,~.~"'?~¢ .~.' ~'~'~'~,~'~' ."~ ~;~'~'"~"'~i~"""'~ "'.~"~'~~:~:~;~*: ?~'10285. 17.733 15.70~ ~0.136 17.030 15.548 1~.936 !5.692 19.592 ~.2~2~ ~ :: ~295- 1~ 979 1~.530 19.617 17.736 15.400 19.710 16.201 19.062 ~5.3~? ~ ~'1~305~ !7.~,41 15-396 1'9.4~9 17~}~5.~27 19~.367 1~~ ~.7~3 20,12~ ........ 315' 17'~08 15 ~ .20,.~6 17 679 l'~.&Ol 20.09~ 15.~39 1~,83~.~3~ 15 787 ~t0385. 17.029 1,,5.455 t8.701 17.2z, 1 t5.7'75 18.355 15.7'90 t8-128 26,450 395 · 1 4.899 1 5 .:0 t 6 18" 894 I 5 ' 88 } I 4.61 4 1 ~¢ ! 5 · ~ 35 1 9.2 S ~37.1 80 23.993 40.575 ~.. 10.~. t4. ...... 1~~..5.~.~ ........ ~_..~:.,.,.7.~ .... ~..~_...798 18.762 25.52~ 10445. 15.4Z9 t3'990 20'074 15.755 13.6:8! ~9.~_ I:~.O:Q_Z 19'-29_7 Z3.9~Z :10455. 15.657 14.129 20'295 1~~1.~_.~__~2 ...... 13~65. 1~.04¢ 1~%6 2~.._.~.~.? .... 1.._~ .... 19, 1~~~5~.618 23.71.7 PAGE ~ ~ ,!4 4 ~,4 9, 79 16 DO~ 1~.93C 19".18~ 14,~ ~ 18.966 24 ~71 ~O~9~. 17 047 14.830 20.3~2 17.0~ 1~.503 19.950 15.:060 19.905 24.124 , ~. ~ ... ...... ~ ~ ~, ., ~ ~= D-~, ..... ., ~ .............. . .......... ~.~, ~ ~ ..... ~ ,~ ...~ ,.. .~ .... ,-~,., ~.~.~2. · . 15.~65 1S 9~3 19 ~84 1 523 1 .474 19'7~ .]~,~77~!9~$ l~,a ~051~. 17.3~3 t5,7~6 1~,969 17'339 1~:.,096 ]9,672 !5'930 1~.72~.~4.2~7 , TDT DATA LISTING COMPANY t ATLANTIC RICHFIELD CO. COUNTRY : U~A Cf]~P~:Y : ATLANTIC RICHWIF, br~ Cg. WF, LL : D,S. 13,,5 P~G~i I $I~A SIGMA SIGMA GR CU CU CU GAPI GR GR GR G~ GAP! ~AP! GAPI AVE'. CU CU inGOO [0599 [n59~ [0597 Io5~6 1o595 1~594 10593 l. osg~ 10591 10500 [058q 105~R 105~7 105~6 i0585 105R4 105~ 10581 {ns~O 1.0579 10578 10577 t0576 1. n575 10~74 1,0573 10572 10571 1,0570 10569 10568 ~0567 ~0566 105~5 10564 10563 10562 10561 10560 10559 10558 10557 1.0556 1.0555 1.0554 18,75 19,09 18 lR,88 18 1.9,75 !9 19,08 10 17,00 16 15 11. 14 1.4:72 14, 15,~7 15.99 15 16.86 1.7.64 17 ~.7..28 1,7 1,6.83 15.95 15 16.11 16 16.88 17 !,~.~5 1,8 19,30 19 1.9,~3 19 19,48 0 ~0,19 1.9,~4 !9 1. o. ]4 18 19 70 1 9 19 89 19 17 67 1:8 19.36 19 ~.~,59 1. R 1~.Y5 ~.45 1.9 19,41 21, .84 21 1 9' 9 1,9 45 17 19 1~ 30 lo ~70 1,8 67 1~ . 10 ,31 !6 ,69 15 .64 1.5 25 15 ~0 .88 1,7 ,06 1.7 .44:17 ,59 ,65 1.5 ,00 1.5 ,23 17 .~4 18 O5 ~ , 2 20 12 20 86 19 71 1~ 47 54 1.9 98 In ~4 1,8 78 17 71 18 56 19 O! 15 20 78 ~0 ,53 19.28 10.13 89 18 49 18,63 ,42 18.74 18,72 1R,~6 ,73 18.58 J9,84 ,02 1~.91 18,72 ,91 16,7~ 16,80 ,35 15,42 J4,94 ,5~ {~.l, 1 15.33 .88 17 36 17.88 14.90 1.4 .~.5 17, q5 17.97 14.93 1,4 ,66 17,08 ~6,97 14,23 13 ,35 15,62 15,7!. 13,48 13 ,~5 15,~2 1.5,60 13,35 13 ,14 15 99 16,44 14 53 14 ,61 1.~:00 18,45 15..69 15 ,05 9..02 18,~72 77 16 6 ~i03 19,78 ~9~45 t6 83 1.6 14 1.9,l~ 19,09 16 ql !.6 ~6 70 20.J1 19 84 1,7 58 19.83 19.,47 17 3,,3 J8.95 79, 06 16 06 7610.~3 07 ~:8'28 ~:9 05 1~ 09 1,5, 61: 1:0' , ,06:~ 5, 59 1,9~ 80 21 16,59 16,39 16,00 15,82 16.30 16.02 16,58 16 50 16,45 16 97 16,77 17 28 17,00 17 11 16 36 16 3q 14~36 13 ~8 12.81, 12,76 12,64 12,93 97 16,86 16, 16,82 15, 16.35 16.. 16,57 16 17,01 17 16,~1 17 17,0~ 17 16,70 16 14.22 14, O0 13, 12,80 1.2, 12.77 1.3, 1.4,10 15 15 60 14 29 13 41 13 57 16 16,1.3 16 74 16 15.93 16 ?' '?? 68 16 5~ 16 17,25 t. 7 73 t7 17,33 16 ,05 16 I .?o 24 16 50 16 7:1. 16 30 16 ~1 1,6 J6 ~5 16,50 16 ~5 17,27 17 45 1~ 4887 I~ 81, 1.6 14~ 3.4 15 45 25 O0 17 36 17.,8 1,7 44 1.7 30.. 1R 82 18'43 19 88 18 34 1,7.64 17.76 19,33 8.9 t6.70 17.31 17,70 77 16.94 17.34 17.09 1,,7 84 16~94 17.29 17..~3 17 50 17 36 17 84 16 39 16 50 1,6 70 16 75 16 16.70 16,36 16.50 1.6.34 16.91 17.11 17,27 16.~4 14.58 1.2,85 13,05 13 25 60 13:46 76 .59 14.68 14.55 1,5.02 13.95 1.4,40 13 26 13.74 13 45 12,82 55 99 19 58 9 94 06 67 18 42 1,8 72 21,23 17, 19 t. 9'55 16., OO 10.27 1.6 'o0 i76',41 16 56 92 25 ~9 45 16 19 45 13 70 80 32 30 .!.5 3,.l 40 46 O0 46 25 91 31 7 (1 14 42 47 28 1 ~8 97 149,5 149. 148.6 148 145.9 145: 142,9 142 1~8.3 148: 151.0 151. 154.6 154. 155.5 !55. 148 9 148. 142i5 1,42 142 0 1,42: 1,41.6 1.41, 14~.0 142. 1.44 O 144 1~4,9 144, 41,,0 141, 1 ,3. 141.6 14,1. 140.1 140.. J44 47, 14, 14 . 144 14~.1 145 14 o6 1.4] 14~.8 144 14 .1 ~4~ 1,48.8 14 49,9 1.49 47ol I: 146.~ !46. i 43, 143, ~..4 143, ,.3 143, I40,4 140, 146,4 146, 144.5 144. 5 6 9 9 3 0 6 5 9 5 0 6 0 9 0 6 1 I 1 1 8 1 8 1, 6 5 ! 4:6., 8 143, 4 14,3 3 1.43 4 1,4.0 4 1,45 4 !.46 5 144 149,5 149.5 1.49.5 19. 1.~8.6 14~.6 14~.~ 1a5.9 14,5.9 14.5, . 142.9 142.9 14,2 148,3 1.48.3 148:~ol 151.0 151.0 1.51.0 154.6 154.6 154.6 19 155.5 1.55,5 155.5 1.~ 148.9 1.48,9 148.9 1.6. 1.42.5 1.42.5 1.42.5 1.5, 142.0 142.0 142.0 15.. 141,6 1,41 6 14!.6 15. !4,2.0 1.4'2:0 142.0 15, 1.44.9 1.44 9 144,9 ~, 145.8 14518 145.8 ,-. 144.9 J44 9 144.9 17 141.o 14,:o 14,..o 1.6 I. .:0 143.0 14.3, '" I ,,,'"" 1 '"'" '" 'I 1 ,47, 148 , 48 1 144.8 '14 . 144. 1 1,45 1.43,.6 ~46 1, 146. 146. 145 1.45 149 ,? 149 148 48. 1.48, .5 1~6,5 1.46.5 18 '8 14:,3,8 143,8 18 4 1~],4 ,.43,~ 1,9 3 14 ,3 143.,, 21 I 140,~ 14,0 I 21. 145, I 44'~ 1~, , 44,- ~SS~ P~S~ P~SS3 P~SS4 P~SS5 P~SS1 PASS2 P~SS3 P~SS4 PASS5 P~SS! P~SS2 ~SS3 P~SS4 P~SS5 ~VE. AVE, NEAR ~FAR ~AR NFAP N~A~ FAR F~R FAR PAR P~R L~AR CU CH CII CU CU Cl! CU CU CU CU ~API GAPI GAPI GAPI GAPI t0553 19.41 19,39 PO,08 19,42 19 17 16,39 16.85 17,06 17,59 17.~ 143.4 143,4 143,4 143,4 143.4 19,41 17,06 " . : 02 144 , 144 , ,~4.8 144.~ 14.4 8 19,42 ,7,0~ 10552 JO.30 ~9,79 19,45 1.9 ~ 19 ,~ 17,05 17,25 16 70 17,23 17, · .. . 105F~ 18.95 1.9.~2 ]q.4R 19.55 1. S.88 1.6,55 16.81 16:58 16.73 17,59 144.4 144.4 144.4 144.4 144.4 19,21 16,7 1055(3 1~.95 ~ ~7 ~,97 P~,O8 1Q,]6 16,86 16 76 16,51 16,8~ 17 56 142.0 142.0 14~,0 !42,0 142,0 1~,38 16,~ ~0548 1Q 64 ~9.14 ~9.~7 I~.~R ~.48 16.86 17 09 17,40 1~,9~ 16.50 ~43.8 ~43,8 143.~ %43.8 143.~ ~9,~1 16, 10547 ~6:7R 20,2~ ~9,~9 19.59 19.~0 }7,39 16 86 17,56 16,95 1~,44 145.4 145·4 145.4 145,4 145.4 19,54 17, ~0546 ~ 95 20.0~ 1~,18 20,03 19 78 16,7~ 17 ~1 ~7,65 16,78 17,~5 147.0 la7 0 %47.0 ~47,0 147.0 ~9.90 17 10545 19:]9 la,42 19,~5 1~,67 19:70 1.7.08 17 09 17,,] 17,05 17,00 {46.0 146:0 146,0 146,0 146.~ 19,47 17 17 ]0 17,16 17,58 16 94 141.9 14~9 141,9 ~4~.,9 141,~ ~.9,]] 17 1.0543 ~9.05 19.54 20,19 t9.33 ' 07 ~7,51 17,58 16:80 0 i4~,0 142, 19,54 17 10544. 19,17 19,Ra 10,33 J. 9.23 1.~,41 17 06 1054~ 1.9,39 1.9,55 19,60 ~q,~4 20.00 1.7,25 16 10541. 19.06 18,72 }..9,{.~ 19.45 {.~.09 ~6,55 16 10540 1~ 42 1q,]4 1~,~0 18,60 ~8.67 15,~4 16 10539 ]~:66 19,35 18,63 1~,70 10'06 16,06 16 ~0538 10 55 10,54 1.9,03 10 49 19,84 16,69 17 0537 19:59 19,48 19,45 19:16 10,9] 17,34 16 10536 10 31 20,13 19 05 18..,54 10,45 17'20 16 10535 ~.9'36 19,92 19~30 19.,~1419.91 17,16 17 1,0533 19,~9 19,0219,,~9 18.88 19'16 16 36 16 10532 18,78 18,67 1~,48 17,92 1.8,80 ].6 31 15 1.0531. 19,22 19,48 10530 20,13 }.9'91 }.9m~6 }9,59 ~9,56 16.91 1.7 10529 19 7~ ~9'25 ' ~ .3116 10528 {.8..,45 18;66 18~33 65 I0527 18.'45 18,95 .99 I6 10525 19.~05 i7;02 .7 10524 18,,63 1.9;70 1.9,72 19,63 1.9, ~9 16 ~0523 ~8,0~ 50 0522 17,52 ~7.$6 17 18'02 18 105~ ~7,70 17 105~9 17.,83 17. 10~18 1.8,89 ~7 ~38 19, 10516 ~9,05 19 10512 {,6.88 10511 16.56 16 17 16 10 09 I ,63 1.6 3 lo50 6 ?3 16 65 3 17,54 16,95 16 ]0 16,Y0 16,85 16 84' 16,2~ 16,6] 16 33 17 67 16,60 },7 71 17:23 16,76 17 68 17,20 16 88 17 01 17,}.6 17 05 17 17 17 }4: 17 28 16 31 16,97 16 70 16 76 1652 !6 08 15 16 53 16 ~5 17 36 16 22 15 09 15 47 16 lg 15 52:15 82 15,25 }5~ 06 15 63 1.~,31 17,80 15 05 14 96 1.5 91 i7,92:: t6,98 14 41. 14 65 14 ~6 16,51 16,39 ~4 67 14 30 1~ 61 i6"38 16109 14 3:6 14 06 14: ~7 16,~2 1.6,64 {4 55 14 03 14 58 1.6'77 16,89 14 ~6 1~ 16.9'8 16.67 14 09 13 .96 142,0 142 ld2.0 !9 02 1.7,88 16 94 148.0 148 0 14.~,0 148,0 148 0 !.9,70 {.7 143:6 1.43 6 143,6 143 , 1,44 6 1 ,,.86 16 36 143,6 50 16 36 144.0 144 0 144,0 144,0 9'52 17 17 144,6 ~44 6 144,6 1.44.6 14'4, 17 144.6 144 6 144.6 I,~.~ ~44,6 19,3i }~ 0 1.46.0 14..,U 146.0 {.9.5 6 14:3,6 143,6 143,6 19,42 17 3 141,3 141,] 14i,3 19'10 16 6 144,6 144,6 144,6 18,63 16 8 147'8 {.47,8 147'8 19'05 16 9 150,9 !50,9 150.9 19,84 17 6147,8 16 4 145,4 145'4 1145;4. 9 23 16 0 142,0 14~,0 14~,0 9 67 I6 5 8. 44 15 04 15 34 14 .10 15 82 15. 71 },5 93 16 63 16 .58 16 64 16 .42 16 !6 06 16 52 1.6,4~ 1.6,3~ 16 :15 93 15 55 16.16 16.~16 t5 7955 }5,34 4'50 I~ 44 43 ~ 43 51 14 ~. 44 , .. 44 30 1 i l 1 ,30 1.. 43 24 I4,49 13 88 143 3 la{ 142,4 1.42,4 14'2,4 !.7 140,5 i4'0,5 140'5 i7' 14025 !40,5 140.5 17 1.45.5 145,5 145,5 1..7 146,8 146,8 t46.~ 146,9 1~6,9 146,9 144,5 144,5 144,5 17 143'3 143'3 143,3 17 144,3 144.3 144,3 6 3 143,3 ~43'3 143,3 6 144,9 144,9 144,9 144,3 t44;3 144,3 6 143.6 143.6 143.6 16 143.3 1.4,., 14].3 16 25 O0 1.46.0 146 88 143,6 1.43 41 141.3 141 75 144,6 144 70 147.8 147 17 2R 17 8 150 9 150 62 ,06 145,8 145. 31!~ 61 16,~ 143 143. 6,3 16 23 tT.O 96 15'20 16.20 142'6 1~2 78 15,04 15'99 141,5 141 .60 1.42 4 t42 ,27 {.40 .5 14'0 ,77 1.40 5 140 ,52 14:5 5 145 ~9 146 8 146, ~1. 147 8 147' 45 146.'9 146, 48 t43 · ~, 82 15' 4,5 ~5, 60 1.5, 79 16, 16 16, 95 t5 10 14 63 14 63 1.4 58 14 61 14 5 . ~ AVE, )FPTH P~SS1P~,.,S2 PASS3 PhSS4 PASS5 P~SS1 P~SS? PASS3 PASS4 PASS5 P~SS~ PASS2 PASS] PASS4 PASS5 FT ~I! CII CII CI~ ~II ~11 CU CU ~[I CI! GAPZ GAPI ~AP! GAPI GAPI CU [050~ 1~.45 1.6.~4 ~6,59 16.34 16,53 14,03 13,73 14.3~ 14.20 13.~9 143.4 143.4 143.4 14.3,4 143.4 16,53 14 1.0505 16.25 1.6,70 16,04 16,00 16,36 13 al 13 67 14,04 !3,~5 14,00 144.3 144,3 1~4.3 144,3 1~4.3 16,25 13 [0504 16.27 16,12 16,46 16.3R 1~.38 14~03 14 28 13.97 14.07 14.55 143.8 143.8 143,8 143.8 143.8 16o32 14 [0503 16..~6 16.75 16,95 17.ll 16.U8 14.34 14 14 10502 17.14 17,47 17,36 17.1.7 17.31 15.41 15 15 [050! 17,95 1R,28 17,~8 17,32 17.39 15 52 15 15 [0500 17,97 18,53 1~,36 17.9R 17 80 15:21 15 15 [0499 17.~g 17.52 1~,00 17.51 !7:o4 14 ~2 14 14 94 144 9 ~7 BO 15 [0498. 17.73 17,92 17,5," 17 52 1.7..81 15:05 15 09 15.00 15.05 15:09 145. ,. 145.1 145,1 145,1 145:1 17,72' 15 ,04o7 1.".08 1~.4~ ~7.47 17:67 17.88 15.37 15 '5 78 1~6:9 1. a6.9 ]4.6.9 1.46.9 ~46.~ ~Z,88 15 Ts is is:s: [0495 1~,{~ 17 98 17,96 l~.~] 18 03 15,48 10494 17,89 17:72 17,86 18.26 1R:25 1.5,38 15 R6 53 [0491 13.63 1.7 17,53 17 96 15,0~ 14 {0490 17.38 1~ ~?.~5 ~7 80 14.79 14 t0489 1.6,921 06 17,~ i~,O0 17 ~ Il 74. 1.4 1.04~8 17,17 17 11 17, . ..28 17 , 58 15 i0486 17,~2 17 06 17,38 I n~ 1~ 6 72 1~ I0~4 17 55 {.~ 17 50 7,20 17 16 15 63 . . ~0482 17 1.04fll 1.7,28 17 1.0480 1.6,34 17 1047© 16,69 1.7 10478 16~81 1.7 I.~475 17,61 17 10473 I 64 17 30 17 58 17 02 17 ~1 16 78 16 66 16 77 10471. 1,7,41 1:0470 1.7.63 10460 '7,~ 17 10468 ]7, 17 1.0467 1~.06 10466 Ii,~1 1 1046~ I .08 17 1046 {.6. ~7 17 17,0o 1.7 17..19 17 51. 17 48 1.7 ~0 6 ~7..61 17 5:18~30:17 .27 1.7,72 17 .11 17.14 17 78 1.7,~8 17 64 16,95 17:: gg 1.7,17 ~7 9~ 17.16:17 ~9 ~7,39 17 36 17,3417 31 17:,25 .17 05 1.7,05 17 30 17,5017 41, 1~,,41 1.7 89 17',66:17 95 17,06 1,7 5217,4417 25 1.4 ~ 1. 14:,~ 1.6 t. 4, 16 1.5 21 1. 5: 81.5 06 1,4 15 15 14 2,,6 94. 15 lo I:4 55 15 37 14: 10 1~ 73 !.7,44 1.7,34 14,83 15 08 1! 1.0 1.7;:28 17,3:8 14,80 1.5 79 14 39 14,40 1~.51 144.3 144,3 144.3 144,3 144.3 16,t~7 55 14:~1 14.47 14.64 143.6 143 6 !43.6 14.3,6 143.6 17.30 97 14 90 15,34 15,38 1a3 8 143:8 143.8 1.43,8 :!43.~8 ~Z 80 53 15:63 15,33 15,74 142:4 142.4 142.4 142.4 142,~ ..~:16 83 ~5,48 15,1~ 144.9 144.9 144,9 144.9 05 91 16 45 O! 43 O0 05 31 40 1.7 14,94 15 31 48 15,28 14~96 62 15,51 15.08 80 1.5.11 15,68 04 15 32 15 64 94 15..:79 15:00 74 1.5 46 14.go 14,96 144 3 144.3 144 3 144,3 144,~ 64 15.~20 14,84 1.4,77 14.6:1 146.1 146:1. 146,1 146, 19 14.88 14.80 I ..09 14 ..3 143:3 1&3.3 1.43.3 143. 80 1~, 96 15,13 14,91 146.1 146 1 {46,1 1~6 I 146. 96 1.~ 76 Ia.82 14.52 143.3 143 3 143.3 143:3 143.~ 1 145.1 145.1 145 02 15 0 {48,0 {48,0 64 14 0 1.47,0 147,0 147,0 76 !4 4 143,4 143 4 14.3.4 69 14 3 1.43'3 ~,43 3 1.43;3 i3 14 91 14! 17 14 146.1 15 15,37 144.3. 144, ...,3 144 3 144 :99 1.5,46 67 15 79 ..' , .. , 10 1,4 89 14 61. 48.0 148 84 1.4'64' 1,4 32 ~47 0 147 0 14,76 14 08 143 14 2 i. 4,71. 14 37 14] i !4] ~ I~.48 14' 66 143 ~ 14] · ..46 14, 7'3 142 la 46 II,~3 1.5 95 ~.7! 15 ~.43.5 14] t, 43.6 14 1.4'5,~ 1.45 148. 148 !48, 1.46,~ 148 146 143,3 14.3 t45:,3 1:45 ..47'0 14 115,] 145 ~44,3144 14~.0 48 ~43 43 14~ ~47. 1.4 .48 ~ 17 17 lO 43 ~ 14 43 14 21 14 ~I 15,19 ];~ 14 145 6 67 1.5 I4.93 ,. i6 148 0 38 1~ 41 15,2~ 1~ 2~ 14. ~ 146 33 14 98 15,78 1.~ .I. 1.4~ 1.48 15 , 15: 19 3 ~ 1.5 0 14,3 ~4,~ ~ 45 7~ 15:5 I~,.5 14,9:5 143 64 15,~8 14,.~! 14,74, 14~ I 145 70 14..'~4 1,4. 14,57 14 46 13 1.4,3~ ~4 1 14,75 145.3 145, 30 14,55 14 ~ 15,0'7 144,3 1.:44. 35 1,5,06 15 1.4,52 14'6 146, SIGMA. SI~"A $~A S'IG,A SIGMA STOMA SI~A SIGMA SIGMA $~G~A G~ GR GR ~R ' GR STG~A SIGMA FEA~ NgAR ~F:A~ N~AR ~,~EA~ ~AR FAR WA~ ~AR FAR NEAR FAR FT Pi! CI) CU CI) CU CU CU CU Cl.) CU GAPI GAP~ GAPI GAP! GAPI Ct1 CU t0459 ~7,]316.63 ~6.9916.8616.7514.3314,98 ]4,24 ]4.2~ 14.58145.1 145.1 1~5.! 145.] 145.3 [045§ 16.~! 16.4416.83 !6.70 ~6.24 !4,1614.36 !4,47 ~4,1234.34145.1 ~45.~ 145.~ 145.1 3,45.~ !6.5314 9 104~7 ~.~.~ 1&,7~ 16,4816.~ 16.20 ~4.4514,20 ~.9914,38 !~.96145.3145.3145.3 ].45.~ 145.] 16,40 ~4 [04~3 ~6.~i 16.36 ig.O~ {&.~{ i6.7514.~014.~314.0314,48 l~.i! i~0.9150..9150.9 {SO.9150.9161652341414 L045216.64 ~6,71, 16,5516.541~,5613,~ 14,.~5 ~4.3913.8514,18148.014~"0148.0145.0148,0 i4~..0148'0 ~ 6014 5 [045016,4416,~416,7q 16.8! 16.7014.333.4.0014,7~ ~4.~ 14.~3 !49.81A9.8 ~49.8149,8 ~49.81 7514 [0~9 ~6,59 ~7,0016.K9 ~.g.9616,!914.48 !4,~ 14,271~.19 !4.53147.0147.0147.0 ~47.0147.0 7 1].4 l .ol 47.0 47.0 47.0 16 13 [044516,6616.41 ~,~,05 ~6.7516.~013.90 !4.3~ 13.7414.~413,8! 145.5145.5145,5 ~45.5 ~45.5 {64~ 3,] 1044417,0616,51, 16.8'6 ~6.86 ~6.733,4.16 ~3,q213.95 ~,,3,771~.68148.9148.93,48.9 ~,48,93,4~.91679 13 [04~3 ~6.6,9 lg.22 lg,~8 {5,9~ 16,~614,8014;0913,95 !4,]8 ~3.7§ ~47.1147.11~7..1 ]47,1147.116 1 4 6 15,g6 ~4 [044~ 16.97 1,6,88 ~6,52 16.92 16,53 ~4.09 ~4,55 !4,63' ~.4,23 14,24 X45.5 145.~ 145.5 ~45,5 14.5.5 t0440 ]6,88 ~6,~ ~6,42 1~,36 ~,6,03 ~4,67 !4,52 ~,4.34 14,03 13,95 14,6,1 ~46.1 ~.46.1 146.~ !46.1 45 ~4 1.0439 ~16,5a !6.091.5.9~ 15.~ 16.4,8 !4,1713,9514.04 ~,3.~8 ,).3,84:~.45.3145.3 ~45.3 !45.3145.3 19 [0438 ~5,9615,73 ~,5,80 ~5.99 ~6,56 ~3,67 ~,~,6 ~3,9513,07 ~3.,73147.0 ~.47.0 !47.0 ~47,0 ~47,0 96 tf')4~6 !5,7)~.6,~515.9515.8~ ~.5,731],4,8 ta,~$ !a ~ ~,a.t~ la.SO 145.5145.5145,5145,5145.5 84 104~4 ~6,05 ~;9216,5215.31 )6.OB ~3,5333,~713, 7514.0~ 1~,84 ~4~.8 ~4~.8 ~4~,814~,~ ~,4~.B O0 !3 ~043~ ~,50 ~6,0~ 16~ ~6,B9 ~6,4B 34.0314;36343813,92 !4.~0 ~44,.] !44.3 ~,4,4.~ ~,44,3 ~44.] 1643{ ~'~6.45 {6,6116~5 :~1:6'3~: ~452 ~3'95 ~3.80 ~44'3 ~4.3 ~44.3144,] !44,.3 5114 104~6 ~,3436~63 ~64416,3616,20 ~4,0414,00 ~38813,5514,]0 ~43.3 ~4~.33.43~3 ~43.3 !4].3 {04~91'~.~.416,3~ 1398~,4613.95~43,3143..3143!,,3 ~43.'3 ~43.3 25 13 {'04~ )5.6016,~3 ~6, 34 ~5,5916.0613.83 !~,0413,g0 ~3,5513.70 ~44,.3144.3144,,3 ~44.3 ~44.3 97 ~04~? {~,44 [4.54 ~,~ ~613.6914.15 ~49.9149.9 ~49,,9149.9 ~49.:9 44 104~6 ~7,8~ ~8,3418, lO ~7.53 ~,7, 7~ 149~ 165915 ~32 ~545 ~4,94 ~61.3 ~6~.3 ],6~ 3 ~61.3 !6~..3 10424 27.55 ~9.~7 ~,, 49 ~9.53 2~170 2~ ~ 27 23 ~5,91 ~4 ~7 ~5 05 1~1,4 1~: 4 ~11,4 1~1,.4 181.4 ~7 25 1fi4~3 ~:.~8 34i90 3~i 64':34'69: 3:~,~ 78:':30 :58:3~, 5:8 3~i,:11 30 ~8 31 30 X80~,3 1~0,, 3 :1~0,~3 ~,80;3 18:0.3 i'0499 36.56 37.4,4 36, ~8 37.56 37, 16 39 06 33,5~ 34~7 33 84 33 84, 187,9 187, 9 187,9 187.9 3.87~9 ~.6 33 ~":04~1 ~,0,0337.67 53 ~53509186,,~. 186: 1, ~.86,,1186,! t86.:1 7534 i04~03~.~536,293606 .]7.5336, 66342833, 593~ 5435283~ 50181,41814 ~.8~. ,4 ~81.418J.4 t04{,9 '35.~1435~5035 44 .:3409311853~,9633003138180,31803 ~,80,,3 X80.3180.3 64 1,04!8 ~5.~935~32357836,56352~ 3~ 193! 26 ]3303~ 633288 ~,74,6 X746174,6 ~.74,6 !74o6 52 ~04~7 ~.0936.~43774:36"!811:363.4,:::3:334 ,3150:3~ 633~ 663306 ~.76,517:65176,,5176~5176.5 42 104~6 ~7,9138,9838 ~7038~53 ~9033453356434593403339! ~,841 J84,]. ~,84 ! ~84,1184.1 7034 104354,0,3,3 88 '363.83586:3534365,336031840184,01840184,.0 !84.0 4~ 36 ~04~44~0,2839.4.439,~ 40.~6401636883656378835133634 ~8! 3181,3381318~,,318~,3 0336 !0,4~,~ 4!.~ 40,88:39 ~9~. 4~7439343775370:~ 37 ~63:704 :~6 ~418041~0,4 ~,,804180.~ !80,4 5537 ( CO, W~I.L : D,S, 1.3..5 PAGE 5 FT CU C{} CU CU CU CU CU CU CU CU GAPI GAPI GAPl GADI GAPI CU CU I04J2 4J,31 39.98 40.36 4~.~ 39,66 ~B.09 37.22 36.72 3~,64 36,44 le~.1 1R2.]. 1~2.~ J. R2,1 ]~,1 40,65 37,41 L04~1 ~,~q 39,96 40,53 4~.70 40.~8 37,59 36,0] 36,g6 37,86 37,97 176.5 176,5 ].76,5 ~76,5 7 .5 40,8~ 37,4! LO4JO 46,g~ 40,70 40.~ 41.76 40.69 36,91 37,43 38,56 3~,92 37,94 178.5 178,5 178,5 178,5 178,5 ~0,69 37,94 l. Oa09 41,2~ 41,08 4~,3~ ~,44 41,B~ 36,~6 40,~2 3~,09 ]~,66 3~,53 }B2.~ 152,! ~82,1 1R~,I 18~.1 4~.55 38,66 [Q40~ 4~.~ 41.94 4{,6'6 4~.98 a~,03 ~6,41 40,14 ]B,5~ 39.6] ]8,BB ~77.5 177,B 177,5 177,5 ~77,5 4~,08 ]8'88 [0407 aS,6Q ~3,~} 4~,]9 4.3,56 43,56 ~D,~6 3~,93 37,94 40,94 ]9,&] 180,4 1~0,4 ~80,4 180.4 180.4 43,45 38,93 [0406 49.47 4~,4A 4~.19 4~.~3 4~.B4 ~7,~ §8,41 ]B.se ]8,97 39,~0 17~.4 178,4 178,4 178.4 178o4 4~.15 ]8,66 [0405 4~,~6 ]9,6! 4~,~ 40.5~ 39.7~ 36.47 3&,65 ~7,89 3~,1~ ~6,44 ~.~O.~ 1~0,] ~0.] ~80,3 ~80.~ 40,~5 104~4 3~,~.6 38,~4 3~.79 ~7.34 3~,06 33.97 34,78 35'~8 34,~8 34,4~ 181.3 ~8~:.3 18~,3 181,3 181.3 38,45 34, [0403 38,88 3q,53 36~60 37.R0 39,06 34,16 34,50 34,19 34,75 33,84 178.5 178,5 178.5 ~78.5 !78.5 38,28 34. 10402 3~,78 39,19 38,3~ 38.~4 38.69 35,34 34,~5 3~.63 35.97 33,~! 183.1 183,1 183.1 183.! 183.1 38.69 34, [0401 3~.~4 39.00 30,4.1 39.34 40.44 37,31 35,59 35,34 36.59 35,44 1~3.1 1~3,1 1~3.1 183,! 1,~3.1 ~9.34 t0400 4j.91 4~..1] 4i,g~ ~l.S9 4~..84 40.56 36,72 36.56 36.66 36,59 187.0 187,0 157,0 187,0 187.0 4~.02 36, t0]09 4~,00 3~,56 ]7.5~ 37,5] ~.09 ~2.~8 2~,67 3~.7~ 30,89 ]0,48 218.1 ~18,1 218,~. 218.1 218,1. 37,53 30. 1.0~98 ~],Sg 2~.]9 ~5.~0 2~.~1 2~.56 21~39 19,~] 20~5~ 19.80 10,98 224.9 224,9 224.9 2~4.9 224.9 2].1] 201 10397 {7,08 17.,~4 ~7,13 16,4~ J. 6,~9 1~,27 15,!4 15,30 {.4,35 15,34 {.~7,0 1~7,0 ]87,0 187,0 ~.87,0 17,01 10396 ~5,60 {6,{~ ~,80 15,58 i5,59 13'77 14,7{ {3,71 ~]~65 13,92 164,1 164.! 164,1 {64,1 1.64.] 15,70 10395 ~6,16 ~7,g3 ~g,8o {g.]~ lg,~0 {'4,85 15,29 ~4,30 1~,98 14,~$ 153.6 ~53,6 1.53,6 153,6 {5]'6 16,~9 14 10~94 ~71,8~ ~8,47 ~9,;g9 ~'s,,8~ I~,58 15,47 15,§7 ~6.,88 ~51,8 ~51..8 15~,8 {.51'8 151.8 17,95 16 ~Q393 ~7,05 {8,~8 18,06 {7,98 ~8"5g {5,89 16,09 {5,70 15,5~ 16,39 148.0 1AS.0 1..4B=,0 148,0 148.0 18,J. 3 15 392 {~,6] {5'54 !5"5~ ~5'~0 145'9 145,9 145.'9 i49'9 145'9 {.7,45 15 IU 10391 i7,55 ~7,81 17,1] ~7,00 ~7,55 15,~£) 15,08 15,14 {5,~1 ~,~9 144.9 144,9 {~4,9 !44,9 144,9 17,4! ~5 10~90 145.3 145'3 I7.,0~ 14 10389 ~6, O~ 1~,~8 ~'6;5~ ~g,72 14,{5 9.~,80 14,87 ~46-1 146,{ 146,1 {.46,1 146,{ 16,85 1.4 10~87 i8 S~ 1~,69 {01 6~ ~g.98 16. 44 16,70 !5'95 15~73 142.0 142,0 142,0 142,0 142,0 19,05 10385 16. 86 ]6,58 ~61~ ~6,~3 ~6 09 14 26 14,69 i4,98 {.4,i~0 ~49 9 ~49,9 9.49,9 ~49. 9 149 80 1.4 1.01384 ~6. 66 {6'69:63 ;:~0:!3,95 1.48 .9 148:'9 ~148,9 1:418,,:9 148 10383 ~7 ~1 i~,§~ 17 ~2 14 77 ~;97 ~4,~ ~4,~2 147.8 147,8 147'8 147. 8 ~47 ~ 14 1038 ]'~ l~ {o ']~ )0 25 {~-~:~ {'& 1] 16 66 16- i6 73 i44 3 144 ,3 144 3 .. ...... .,. .... ~.,,. .., , .. ...... ~ 16 10379 16 70 J..6, I0 14 144,4 1.44. 4 144,4 J, 44 91 14 4 Ii 14.vv 10377 ~6 5~ 16 ~5 {6 27 1~i.()1 14 ~0 1..2..3 1,.,2 3 1,4~3 14~ ] i ..... ~ j'l ~4,23 {10376 :15::::1:.4::I:0~. Ii14 :I~1 'I:41:,0 141 0:14:1:':0:14::1.:!I 0:~I4:1 46 1.4,4t 18 13 80 14 05 14 b3 140,5 t40 5 1.40,5 1,40 5 1.40 50 1.4,09 10037574, i!56'. 50 !6,4 :>316:., O01400 I42 983~88 10373 1,5 88 !6 14 15';4 16,25 16, 52 14 0914,40 1.3 78 140,9 140. 9 140,9 140,9 140,9 16.: 05 13,94 i. 0372 ]i 4 I6 ~ i4i3 i4;.::20 i4i. O i ~ '0 !41:'0 16.44 14,20 10371 m.e~ 47 1.6 91. 1.6,73 16,~1 j6,77 14 .41. 14,~8 14,71.1.4 05 143~.3 1.43.3 14,3,3 I43,3 143.3 16.77 14,4! {]0370 i7 ~017'117 I7i:: 97:1 igi 14:501.4, g 1.44'9144:~9144::i~:9:1144:, I4::4'9107 I46 10369 i6'4716,6616,~61.4143,8143,8 ~438143.,81.6;7, II,60 {o~6~ 6.5 ! ;41.: :03 :I :! I0 ! ! 0 I49::.,0~1,49.0 0 14:9.0 ! ,5 10367 17,72 16,66 ~6,94 17,10 1.6,78 1.4 124 14,~0 14,46 151.~5 151,5 151.,5 !51. 5 151,5 16,98 14,6~ {0366 1 i7; 3 ~ i,:~:i6:9 i:: 5:i::9:2 15,;59155 155':3 1551'3 155 3 !.55 3 1 S4 15,59 13-5 PAGE 6 )FPTH P~SS1 P~SS~ P~$$3 m~SS4 PASS5 PAS,,ql P~SS~ P~Sg3 P~S,~4 P~SS5 PhSS1 P~SS~ P~SS3 P,ISS4 P~SS5 ~VE ~VE, SI~A SIGV. A SIG~ SI~A SIGMA SI~M~ SIGMA, SIG~ SIGMA SIGMA [0365 1~.75 18.44 1~,58 18.77 1~.55 16.44 16.23 16.08 16,20 16,20 1~8.0 148.0 148.0 148.0 148.0 1~.60 {6,~ [0364 1~.~9 1~.53 18 3.4 17,73 18.33 15,54 15,~5 1~,~0 15,73 16,02 14~,0 1~2.0 14~.0 L0363 !~.a4 18.09 {a:36 1~.16 18.14 15,38 15,52 15,80 16,03 16.31 ld4.3 144.3 144,3 144:3 144.3 ! .25 15,8 L0367 17,05 17.~5 17,50 J. 7.98 ~7,~1 14,73 15,a5 15,06 15,65 15.56 148.6 14B.6 148,6 14~.6 14B,6 17.73 15 L0361 16.64 16,]4 17,11 16.~0 {~,~ 14,~B 14,30 13,98 ]4,35 14 71 149.6 149.6 la9.6 149.6 1~9.6 16.69 14 1.035B l~;4R 16,25 1~,~5 16,30 16,91 1.4,80 14 ~7 14.,79 1.4,0~ 14,73 !44,3 144.3 144.3 144,3 144, 10357 17 ~7 17,39 17,33 16,98 17,38 15 85 15:30 15 54 14,89 15,37 144o9 144.9 144,~ 144,9 144. :37 14 i0356 17 73 17,~9 17,~1 1~,23 ~7 5~ 1.5 99 t0355 1R~28 17,39 17,67 1~.17 17~63 .63 15,~6 ~8 15,63 14,94 15,g~ 145 3 145.3 145 3 15 63 15 15,59 16,1.3 14~ 4 142,4 142:4 10353 17.64 17~89 17,5 ~89 17,92 14 98 14,82 14,~9 1.5,37 I ~55 149 9 149 9 149,9 10352 16,67 1~42 16,22 1.6.7~ 1.~,70 14,14 14 09 1.3,95 14,46 14,65 14.8 0 148 1,0350 15,77 16,03 15,91 15.92 15,65 14,09 14 10349 ]g,58 ~.6,56 1~,0'6 {6,07 {~'72 14,30 {,4 10348 i6,89 i7,2.3 16,~8 16.57 16,95 !4,23 14 i0347 17,39 {:7;89 iT,i~ 1.5 1.0346 17,73 17,4.4 i7,~5 ]7,03 ~7,56 ~5'34 1.4 10345 ~7,4~ i7'9~ {7,01 {?,44 ~15.,0~ 14 10344 16,61 16.28 i7,20 16'91 16,50 14,52 ~4 1034.3 1034~ m6,5~ 16 38 {5,9~ {6,31 16'31 13 81 13 10340 1~,53 1,7 89 18 ' 31 1,7,98 16 i0339 04 15 94 15 8915 53 14 0013 8O 14 23 I5 37 15 91:1,4 10338 17,19 16 10337 17,0~ 1.7 10336 16 95 16 70 16 O333 6 50 15, I 30 1 10332 16 7R 15 ~.03§t 3,5 96 ~0330 16 28 15 ~:~ ~5 09 14 04~4 10329 10~ 28 1.03 16 59 16 64 16 22:16 4:5 13 35 , . 27 , ~0~2t ~7 ~0 56 ~7;t4~ 17"48 1:7: 1~]19 17 61 17,:01 ~8,~4 16 91 15 34 2g . . ,16 15 62 142.9 142 43 145.3 145 13 43.8 143 48,0 64 150,6 150 .88 i49.6 149 03 14"64 25 14,30 13. 5215,35 14. ,83 1.4.,72:14 3 48,. 148. ,71 1..4,52 !5 41 149.,0 149 ~45 14,47 1.4 70 147.8 1.47 02 14,1.8 14.. 49 14 90 ~4.7,1 147 84 14'89 15 07 ~.4 73 148.9 1.48 86 15 10 152,5 15 02 14 06 151:,,9 15I, 77 1,4 30 !,45 6 14 5 1,8 14 30 146.6146 05 148 0 1,48 07 t44g 144, 09 13 n9 13 ~0 13,95 ~44 g 144. 09 141 i~3 {..~ 95 13. 83 ~47 6 147~ 80 14 9..4 I6 05 i5 55 1470 147 70 16,06 15,74 1.5,84 t4.3,9 143 . 1 42.Z4 142 52 15.,~2 15.44 15.;29 1 .... ., 5, 5 1.42 142,4 142, 1.49,9 49, 0 1.48 0 148,0 14.8,~ 1 1~6 1 146,1. 146 16 3 144.3 14~,3 144 3 9 141,9 141,9 141 9 7' 9 1~2,9 142,9 142 9 7. 8 1,43,8 143,8 143 8 0 148.0 148'0 148 0 6 150,6 150,6 150 6 6 1.49'6 1:49,6 149 6 17 14'6,1 ~46,! 146,~ 18. 149,0 {49 0 ~49.0 17 147;81478 1 ]..47,1. 147 1. 1'47,1 ~6. 9148'9 5 !52,5 ~5~ 5 152.5 17 9 151::19 t51 9 1:51"9 6 145 6 145'6 6::t46: 148,0 !48 0 148,0 ~1 15 84 15 27 15 77 15 56 14 70 13 58 14 90 1.4 39 15 45 71 1,4 04. 13 15 t6 ~5 t9 14 08 14 99 14 70 1.4 37 14 21 14 30 14 95 14 96 ~14 08 14 ~0 4,4 .!,3, 4t 1,3, 23 13 :14 13 15 56 15 60 15 72 15 CO.~'P~!y : A'rr..~NTIC PIC!.tFIF~LD CO, t~[<.l.:L : D.$, 13-5 PAGe: 7 S..5 PASS1 PASS2 PASS3 PASS4 PASS5 AVE AVE )EPTH P~.SS1 PASS2 PASS3 PASS4 PASS5 F'RSS1 PASS2 PAS..~3 P~SS4 PA g' SIGMA S.T(~A ST(..;~A SIGMA SIGMA SIGMA S~UA SIGMA SIGMA SIGMA gP GR ~R GR G~ SI~A SIG~ F~ CU Ctl C[I CU CU CU CII CU CU CB ~API ~PI GAPI (;AP1 GAPI CU CU [~31~ ~7 86 17,57 , L0317 18:34 18,11 18,48 17,89 17 86 15,48 15 [03!6 17.94 17.95 ~.8,00 1~.16 1~:08 15.14 15 L0315 17.27 17 41 17.06 17.73 17,41 15,10 15 [0314 17.36 17~33 17.53 17.77 ~7.80 15.11 15 i0313 17.14 17'19 16 64 17,72 17.59 15.19 14 10312 ~7.09 17,09 17:!4 ~7.~{ 17.11 14,69 tO311 16 70 16,75 {.5,95 16.gl 16 ]6 14 12 10310 15~52 16.10 15,B4 16.1.6 1.5~67 13:33 13 t0309 15 80 1.5 n8 15,34 15.74 15'9~ 13,61 10308 17~03 17 ~7 16 50 1.7.06 17,23 14,89 14 04 72 18.48 1~.58 17 ~1 16~00 18 1.3 1~.06 ~8.34 15,~4 15 26 15,88 15.41 15.45 143.9 143.9 143,9 143.9 14].9 17.99 15,~ RO 15.46 !4:8~ 15.21 1.42.3 142.3 3.42.3 142,3 142. . .05 15,~ 1.7 15.65 15,17 15.02 144.1 144.1 144.1 144.1 144.~ I~:40 15. 30 15.10 15.,6 15.34 147..8 147.8 147.8 147.~ i47. 56 15.2 50 ld.67 14 50 3.4 82 146.8 146.~ 146.8 m~6.8 1.46.8 1~{ ~9 14 56 14.R9 14:31 1.4:76 147.0 147..0 147.0 147,0 147.0 1 ~2 14 17 la.16 14,06 13,~6 150 6 i50.6 150.6 150,6 150 ~ ]6.55 14 55 14.]5 13161 15Z21 152 8 152.8 152.8 152Z8 152Z .:06 14 70 ~5,39 15,29 15.!6 1.52.8 152.8 152,8 152 1! 15.70 16,06 15.~8 153,6 1.53.6 153,6 78 15,43 15,23 14,59 148,8 148 8 148.8 ~48,8 80 14,50 14.~4 14.07 146.1 146~1 146.1 146.1 05 14 02 , 9 144. 9 144 9 82 16 06 16,34 ]5,35 3 144,3 144 83 15 4{, 35,62 14.74 6 1.49.6 41, 17 ~8 15 71 1.5 O9 15 10307 .1~ 34 1~ 10306 17~72 18 10305 17.31 17 10304 16.55 16 10303 1.6 47 16 10302 17 23 17 10301 I.B 06 18 10300 17 88 17 10209 18 20 18 1.0~8 19 04 19 10297 1.9,41 ~ 10206 1~.30 10205 17,oR 17 10204 20.94 21 10293 21,61 22 10292 19,06 20 10291. 18.45 1~ 10200 17,50 17 10289 1.6 80 17 10288 16 ~8 1.6 10287 17 67 1.~ 102~6 ~7 7~ 17 67 17.~2 17.66 16 52 16,1.6 16.a8 16 50 16.~4 16 53 1.~ 11 17.On 17~67 1.~ 52 17 98 18,67 19 86 16:99 16,97 17 58 ~9,92 ~0,~4. lO 62 17,72 1.7,50 17 ~ 17,65 1.7 ~ 1.~ 71 15 16 92 14,~2 14 1.3 13.96 13 44 14,fl3 14 17 15,15 15 · ,67 14 52 1,5~ 15 14 25 14 41 144,9 144 146.1. 146 144, ~ Oa 15 91 150.9 1.50 21 17.03. ~6.75 3.47, ~ 46 15.21 15.43 150.~ I~ 0 38 15,~ ]~ ',3 '.4~.0 148 18,... 146..1 152. 144 o 1. o: 4o2o 14s. t o.o so.o 3,46 1~6.1 21,96 2J.,78 21 10.77 1.9'71. 19 9 23 1.7 95 17 70 1~ 77 !.:7 ~4 18,00 1.9 1118.54 17 54 17 ~ ,59 1 4717.361 43 18,~6 17, 06 :.17,7'9' t7~ .17 17.95 ~8 5219;:4621: 62 1',50 18 5817,88 17 1028~ 17,94 17.95 1.9 7~ !~,~6 t8 10~8 19.41 .19,77 ~0 94 2~, 3:~0 0279 3.7 78 18,36 1~,54 18,33 17 0278 15 gO 16,4~ 16-~'6 16,42:16 10277 35 91 1.6,17 ~,9.4 ~5,69 16 10276 16 69 16,50 ,34 6'20 :!6 10275 1R,~7 17,95 I.~,1:1~,73 {8 I073 ~n,39 20,36 ~,0~ ~,]0 19 .027~ ~0,~5 t8,88 10,72 1~,~5 ~1.8. 44 18 77 16 09 15 O~. 15 61 14 5:t~ 1:5 1 16 25 15 38 17 53 17 95 45 146 ,~ 3,~ 52 1~ ~4 1~,~ ~ 98 3.45.8 145 66 17 52 17 1.8 16... ,- 20 14~.3 1.44 69 1.6 16 ~7 16 50 144 8 1~4 5,39 15.85 1.5,69 15 58 141.9 141 I .o, . t 1,46 ~ 145.~ ,.4~.8 145 3 144, ,4 .3 144 ~ 144,8 14.4.8 144. 41,9 lal.9 1.41. ~.4~ 142 .... . 142 7O 1~ i. 5 1 67 16 O0 17 72,, :1, 6 16 92 18 ~o 16 34z-:,'1~.62 15.77 15 1'9 '4~ 15,45: i~ 17.00 16.29 16 15,52 1.4 5. 4~ 1~,49 11,77 l~ 63: l,,no' ,o7 , 02 15,86 15,1~ 17 81 17,98 17,5 9 03 143.~ 14.3 t46 46 1~6. 20 164,~ 164 34, 168. 168: ~ 1~,04 18,97 17.94 !63.~ 16~ : ;',1.2 16.75 ~6.95 164. 16 38 50 1.42.4 1 57:3 l~'9 154 31,57 1 6 143 9 1,46 68: 52,I 52, 1~4. 1.54.~ 157, i57. 1.51,8 1.51 ~ 18 1.53,6 153~ 17 16,4 · 14 .9 146.9 ~64,0 164,~ 18 22 15 42 14 34 14 47 14 39 15 52 15 42 1.5 28 1.6 94 1.7 75 1.6 62 1,5 7. 71 .1.5 O' 90 17 1,78 18 9, 74 17 10 1.5 7.17 7,95 1.5 9, 63 3.6 74 1.5 58 15 76 16 35 17 14 1,5 26 13 12 1,5 85 18 )MPTH PASS1 PASS2 P~SS3 PASS4 P~.SS5 PASS1 P~SS2 PASS3 PASS4 PASS5 PASS1 PASS2 PASS3 PASS4 PASS5 AVE, AVE. FD' CU CU CU CU CU ell CU CU CU CU GAPI GAPI CAPI GAPI GADI CU CU !02a9 17,89 17 36 17,72 1.7,30 18,41 15,29 15,20 15,'2.7 1..4.,87 1.5,50 150.9 150.9 ~150,9 150,9 150,9 1 ,72 15, 10268 20.31 18,70 20,36 .1.0,67 .9..2 n5 17,00 1,6 13 16,02 1~,a7 17,23 1.64.4 164.4 1.64.4 !64,4 164,4 20,31 16,8 [0267 22 30 2~,61 ~4,t, 0 23.00 10264 19.31 1.0,34 19,31 lO.67 lq,O0 16.23 16,19 16 34 16,45 16,06 155,6 155.6 155,6 155.6 155.6 1~,33 16 ~0262 1,,55 1~,53 18 91 1. o 08 1~,91 ~026S. 18.~6 1~,83 10:02 1. O:1.3 10260 19,64 2r),03 lq,34 19,20 20 13 10259 21,,02 2!,44 21,~? ~1.,05 1.0258 21;00 21~37 21,88 21,36 21 48 10257 20.~2 20.27 20'91 20.70 20 5B 17.08 ~6,76 17 47 17.80 17 .45 145.1 145.1 1.45.J 145.1 145.1 20.56 17 [0~56 ~.05 [9.03 ~9.52 le.~ 1~ 77 ~6.09 16~0 16 17 ~6,1,~ 16 50 ~45.1 145.~ 145.1. 1,,45.[ ~45.[ le.04 ~6 10255 IR.]3 ~8.59 18.70 1R.58 18 53 ~5.60 ~5,97 16 16 15.85 15.98 ]46.1 146,.~ 146.1 ~,46.1 ~46.1 18,.56 15 ~0~54 ~8.95 ~8.~7 ~8.55 18.52 ~,8.7~ ~5.58 ~6,05 15 ~5 {6,PO 15.9~ ~49.5 149.5 149.5 ~49.5 ~49.5 55 1.5 10253 1q.~7 1.8.~ 18~45 I~..~7 ~9;05 15.75 .16,03 ~5 ~7 16.~6 1~.1.1, ~,4,9.4 149.4 ~.49.4 149.4 149.4 ],~:84 15 10252 19.1,3 !~,84 19.05 !~.81 18.98 15.99 ~025~, )9.17 1,9,,51 19,73 1Q,40 19'36 16,~1 ~6,44 ~7 26 16.66 16.~, 144.9 144.9 144.9 ),44.9 144.9 4,3 ~6 10250 19.88 19, ~5 ~0,~2 2().~, 1,9,78 10247 18,75 1.9...43 ~8;7V :1.9.40 10 45 .1,~,4.4 18; ~3 i7.77 I8.60 1.0)~F 30 21 24 67 38 25;'3:8 25'14 22; ~ 17 ~5.45 ]0240 25.52 ~5 59 ~6 ~2 ~6'00 0239 28,36 ~8 85 ~5 .~38 ~5.03 25 3~. 26 ~7 27.1,3 24,75 2:~, J, 3 21,55 22 ~0 22.55 2'1,.~2 165.0 165.0 1,65.0 165.0 165.0 60 21, ',37 ~.80 ~,9 ,08 ~9 16~, 8:3 ~7~,, 83 ~ 17.82 ]~7~25:156,~4 ~56.4 ].56.4::~56:,4 ~,56.4 .34 ]7 10236 17,27 ]7 90 ]7 58 ~7.~6 ~.7,75 ].0~35 ~7,83 J~7 9~ 0'6:93 ~,5 47 15:'3~ ]5.66 146.~ 146'.~ :14:6.1 ~,46;~ ~46,.~ 18.06 ~5 ~0234 ~,8,17 ~8 68 1~ ~0 18.63 10233 ~7,70 i8 40 '~7 90 1~:..45: i~'30::1,5, 02 15. 77 15 59 15'77 15,:35 ~47.8 147.8 147.8 ~,47,8 ~47.8 J~8.15 15: 1o232 ~.7.59 17 55 17 54 ~7.42 10231 !7.~. ~7 51 ~7 ~9 :~7.64::t5.,00 15 04 14,84 14.56 ~,4.84 146.0 146 0 146.0 146.0:146.0 ~,7..55 14, 10230 17.47 17 73 18 03 ~7,q7 ~7.81 14,48 14 95 14 40 14~66 !4 57 1.44.3 144 3 !44.3 144,3 ~,4,,4.3 1,7~.81 14..., t0229 ~7.45 ~7 54 1:7.73 t7,57 ~:7.52 1,4~ 78 1:5 1.~ J50~ 1:4~4 14 70 145..3 1,45 3 1,,45.3 145;3 145,:.3 17,54:14.89 1~0~ .~ 18 86 ,6 04 16 05 15.87 5 ~0 ,49.8 1,49 t 149.8 149'8 t49-8 '74 15, ~0~ ~8. 18 78 !9 ~7 ~,~.90 I,R.73 i5, g2 15 95 1,6 ~0 ~.6.,06 5 8~ 155.6 155 6 155.6 ~55.6 155.6 ~8,,.82 15,94 ( N~A~ N~AR N~AR N~AP FT Ol.I C[! Cll CU CU CU PASS3 P~S$4 PASS5 PASS1 CU Ct{ CU ~API P~S$~ PASS3 PASS4 PASS5 ~iPI GAD! ¢;lPI GADI AVE NEAR 10224 t0223 10222 tO2?J 10220 t02~9 10217 t02~6 1021,5 {0214 10213 10212 1O211 ~0210 1.0209 102n~ 0207 0206 1 2o5 204 102~] 102~2 1O2O1 102OO 10199 10J97 01~6 0!95 1.0194 1,0193 t0192 1O19! t01~0 i01~8 101.~7 101~6 101~5 I018~ lola3 1.01~2 10190 · 17 18.63 19,52 19:30 10,06 20,!7 20,11 20,1a 21.41 21,38 21.56 21..11 21.14 21.4~ 92 20,13 19,64 19,~5 20.11 19.98 19. l.a,~R 1R,45 15,59 19.34 10,66 1.6,50 20,30 20,75 17,52 ?,!,~6 21,42 l~,On 21,78 20.42 17,20 1~,92 10.47 16 67 19.a5 19.58 16~77 15.67 16 22 17 ll !8 1.8 1.7 90 16 73 16 64 16.04 15,74 15.69 16.64 15,05 16.4~ 17.36 17.28 18.23 1~.17 18,0~ 17,67 18,~4 17,77 16.91 16,69 1~..91 16,53 ~6,47 16,44 16,20 152.5 152 5 148.9 14~m 151.6 151 6 147.1 147~1 148.9 14B.9 146.1 146.1 151.6 151.6 154.6 1,57 5 ~48~q 151.6 147,1 14.8,9 146 1 151:6 154,6 152.5 148.9 151.6 147.1 1.4B.9 146.1 151.6 154,6 148., 1.9 36 151.6 20 23 147.1 21.48 148.9 21.14 146.1 19.80 151.6 19.78 ~54.6 ~0.38 1q,~5 1.0,73 lg,~6 ~9,53 16,66 17 16 16,51 1.6,25 16,09 1.54 6 ~,$3 10,55 20,07 19.79 19.13 19,80 16.~6 1.7 25 16.76 116,70 16.98 153:6 153 6 153.6 153.6 153.6~,67 20.06 20 71 19,97 20.29 20,.55 16,67 16 77 17,37 16,97 17.42 152.8 152 8 ~52.8 152.~ 152.~ 20.30 ~9.27 lg R7 20,04 1q.~7 19,77 !6~50 16 80 16,~4 16,63 16.~2 148.6 148 6 148.6 148.6 148.6 19.65 18,75 1~ 69 lO,ll 1~,7~ 1~,63 16.00 15 94 1.6,46 16,00 ~5,~7 149.5 149 5 1~9.5 149.5 149,9 1,8,75 20.1.4 19 40 19,37 20,17 19,95 17,00 16,13 16.63 16,64 16,47 147.6 147 6 147.6 147,6 147,6 19.77 20.03 19 58 20,48 19,69 20,34 17,08 16,51 16,96 16,76 16.78 149.6 1,49,6 149.6 149.6 149.6 20.03 19.02 18 89 1.8,61 19,1] 10.48 16.66 16.16 16.~9 16,00 16.48 147.1 147.1 i47.1 147,~ 147.1 19.02 20,17 19,65 10,22 20.46 20,55 1,7'14 17.15 !6.30 16,35 17.09 15i.6 151.6 151.6 15t.., 151.6 20,.06 1.9,4,5 19;66 20.~3 1,9,93 20.52 16.97 1,7,05 17.00 17.09 17,59 151.6 1~1.6 151.6 151.6 151.6 20,,,04 20,44 20'~,0 19,,8,7 20,41 20,70 16,73 17.27 17,04 i, 7,62 i, 7,41 1,55.4 155.4 155,4 155.4 155.4 20.29 ~1.36 20,)P 20,,~6 21'28 20.36 17,56 17,44 17.53 18,04 17,53 162.3 162.3 162.3 162,3 162.3 20.82 19,80 1.9,90 19,.78 20,24 1.9,67 17,77 1.7,29 1.7,07 17,45 1~.7~ 1.54,3 1.54.3 154,3 154.3 1.54,3 19.84 19,23 18,97 19,~17 ~,9.5~,. 19.19 16,47 16.44 17.15 16,84 16.56 150.6 1.50.6 150.6 150'6 150,6 10·;20 19,05 18,99 t8,~95 19.22 18,95 161 36 16,36 1.6,4~ 16,70 16,47 149.,9 149,9 149,9 14,9,9 149,9 19,00 1.,~.95 19.98 t, 0,,~219.]019,02 1,6,6616,55 1,6,6616.7~17,08147,6 147.6 1,.47,6 147,6 147'6 19,63 {.9.05 10.27 19,52 1R.72 18,36 16 50 16,63 16'~5 16,17 16.47 147.0 147.0 147.0 !47.0 147.0 18.99 tR,25 18~55 18,,~0 {,'8:,04 1~,~91 15,58 1,5,67 15;95 15,76 1,5.56 148..0 148~0 148.0 1~8'0 148.,0 18.14 17,39 ~7,8~ 17 6! 17.49 ~7,R9 1,,4,98 14,89 1,5,34 14,96 ~4.90 145,9 145,9 145,9 ;~:5,9 145,9 4 1~'64 17.15 17,~9117~05 17.47: 14, 18 1,4,74 I4,56 14,,12 14,.48 {,4:7,1, 147.t 147,1 147,1 147.1 ]1~:615 ~6,4.1 16,97 16,57 t6,70 16,97 1.4. 34 13,g0 13,88 1.4,17 14,31. 148,0 1.48.0 148,0 148,0 148,¢) 6,70 i7;34 ~,7,11 1.6,~2 !7~112 17.64 15,04 14.44 I~,'13 1,4::'32 15.41 149.6 149.6 149,6 1,49,6 ~49~6 17.23 19,95 18,98 1.9,29 19.,,~0 20,05 !6. 75 16,23 {.7,17 15,92 17,31 1.4~...6 1.49 6 1.49.6 149.6 149'6 ~9,51 ~.3~ 2~,40 ~0.83 17,50 18,03 152,.6 152 6 152.6 152.;6 152,6 1.~2 22,25 22,03 21 ~7 21. 73, 21,q2 19 33 1~ 31 10,,25 18,52 10.45 143,8 !,43 8 143,8 143,8 143.~ ~1,,97 19,,16 19,46 18.,:9.! 1'43.3 1~3 3 143,3 ~43'3 ~.43:.3 21'95 2 ~'30 20,98 22,06 2~ 16 ~2,00 21,27 17,81 18 29 18,33 1~,60 1,8.64 !,45.3 1,45 3 145,3 345,3 145,3 ¢1,54 {9;94 20,63 1~ 57 t:0,91 16;66 148.0 148 0 148.0 148,0 148,0~9.84 {8,50 18,00 18 50 I~,34 1~,25 15 19 1,5 29 15,43 15,62 15,52 ~51,,8 151 8 151,8 151,8 1,51,.8 1,8.34 17,~7 i18;~8 18 44 15i. 11 14;~6 15,27 162,1 162 1 162.1 162.m 1.6~,1 18-28 17,94 18,55 18 53 18 27 18,44 15 7~ 1.5 35 15 37 15,~7 15,~9 161,1 161. 1 161,1 lb1,1 161.1 18.,40 !~.Z~o ~.0;08 a~ §2:~i8 [1 i8,~4 I5 691.5 7715 51:15.93 15,;8 160,1 1601 160,1160.1 160.1 1.8,82 19 67 20,17 19,55 1~,1319,05 16,28 17 ~0 16 44. 16,~5 15.75 157,5 157 5 157.5 157.5 157,5 19,55 ' 81.7.0~ 158.4 158 4, 158.4 1~8,4 i58.4 20.95 ~1 13 21:,83 20.88 ~0,,06 20.8:6 ~I8.00:18 27 67 16. 22 14 21,50 2ri,P2 56 21. 66 18,34 17 73 1. ,93 .~.,5~ 1.8,08 1.65,1 165 1 165,1 165,1 165,1 21,56 1, q 89 19.61 19.25 3617,20t. 7 41 1,7,1,1 } ,0 17,56 159.~ 159 4 159,4159.4i5~'4 1'9.63 lq 73 21.30 20,4,0 ~7 20 22 17.39 I~ 48 1,7,68 16'~9 18.36 155,6 1.55 6 155,6 1,55,6 155.6 20,22 ~! ~0 19'99 18 61 20 27 165.0 165 0 165:.0 165,0 165.0 23, 0 44 21.,39 1' ' AVF, SI~A PAR CU 15, 16,!. 17, 1.8, 17,75 16. 16,4 , ,87 1.7.05 16,62 16,02 16,56 16,79 16,33 1,6,75 17,05 17,55 1.7,1.8 16 :{.6 15 14 14 4 '] 4 ~6 17 18 19 CO~PINY : ~TI.,.~NTIC RICNWIELD CO, WRI.,L : h.S, 13-S PiCK 10 2fPTM PSSS1 PASS2 PASS3 P~884 P~$85 FT CU CU CU CI~ C!.! L0177 [0176 17,42 1.0175 }.0174 ~7,88 [0173 17,61 L0172 ~7,55 1.017~ ~7,38 t0170 ~7,~0 !0169 t0168 18,4! 10167 17,7~ t0166 1~,~0 [0165 10164 17,25 L0163 Ifi,69 17,56 1~,39 18.13 17 50 ~7 27 1.7 45 17 94 19 29 1~ 72 1~ 31 18 75 1.8 32 1~ 25 16 50 17,7a 17.54 17.59 1~.5~ 18.25 18.30 l~.75 1,7,41 17.~9 17,52 1~.!7 ~7,29 17.~8 17,P5 17.66 1~,67 ~.94 18,69 18,73 1~,~9 ].7,79 1.7,60 18.38 17.43 17,47 1.6.6.2 PAS81 SIGMA FAR CU $?~.A 8TGMA STG~A el] CII CU PASS5 P~SS1 SIG~ GR rAP CU GAP! PASS2 PASS3 PASS4 PASS5 AVE. ~VE, GAPI UAPI GAPI GAPI CU CU 13.80 15.90 17.61 15.10 15 18.5] 15.52 15 1R.25 15.66 15 1.7.61 15.08 15 17 92 15.19 15 17~fl4 14,95 14 1~,25 15,1.4 15 1g,19 15.63 16 1~ 42 15 85 15 15:50 15:4t 15 17.92 15 27 15 1,.,.4 is 1,6,. 3,95 13 15.84 43 96 ~6 30 12 9~ 53 10 62 54 83 1.5,79 l&,31 15.77 145.3 !4 n~ 15.29 15 31 ld6.1 15~64 15,29 15~80 149,5 ].5,70 !.4,95 15,d8 144,0 15,26 1.5,0~ 14,~0 144.~ 14.81 15 17 15.~5 147,0 14,83 14:g8 15,~7 146 8 15,28 15,41 16,14 147~8 15.3] 15,80 1~.36 '150.9 15,66 1.5,24 15 52 146,1 15,50 15.~7 15:~] 148.1 15.70 15,33 15,13 147,8 15,]0 14,~5 148~.0 15.17 14,71 14.55 14 60 1.44 9 1.4,23 14.04 14 07 145.~9 145.3 1.45.3 1.45.] 145.3 17,89 146.1 146.1 1.46.1 146.1 17.56 149,5 149,5 149.5 149.5 18,39 146:8 146,8 146,8 ~46.P ~7 41 ~47,8 Ia7.8 147.8 147.~ 17:80 150.9 150.9 ~50.9 150.9 146 1. 146.!. 146.1. 146.1 1a,57 147 8 147.8 147,8 147, 148 0 148,0 14~.0 1.48. 8,14 144 9 144 9 145:9 145:9 1.45 ~) 44 3 1.0162 16.58 16 59 1~6~46 16,45 16.33 1.4,13 1.4 10 14 1.1 !.3,~3 1.3 02 148,0 1.48 9 1. d$.9 118,9 148.9 !6 .46 10161 17,92 18 03 1. 32 17,~0 17~47 15,25 15 17 14 61 14,71 14 77 149,9 149 9 149.9 1~9.9 149.9 17 70 10160 1~..'03 1~ 75 1.~ 20 1~,84 18.06 14,96 15 ..., 4.7 !.5 O0 15.56 15 13 1~9.9 149 9 149,9 1. d. 9,9 149.9 1.~ 4t 10159 1.8,27 17 78 17,8~ !7,94 18,I4 1514~ 15 17 i5 22 15,~11 15 60 1,'~5.1 145 1 145.1 145.1 1.45.1 17 98 101.58 1~,78 1~ 25 18,20 1~'1.3 18.34 16,06 15 .80 15 81 15,42 15 75 149,9 !49 9 149.9 149.9 149.9 1.8 ~7 10157 1.8,8:1 18.25 I0.63 15'98 16 25 15 49 15,~8 15 65 14~,6 147 6 14~.6 147,6 147,6 1:8 48 10156 20.,53 19 55 19,27 19.95 20 22 !7,23 1~ 13 16 88 16.61 !6 73 155.6 155 6 155.6 155'6 155.6 19,90 1.0155 22,39 21.58 18 57 18174 1~ I4 165.9 !65 9 165.9 165.9 165'9 2~196 1.015~ 25,61 23.94 ~3,55 26,21.. 33 21;67 20 61 20 36 21,47 21 64 172.6 172 6 172,6 172,6 172,6 10153 25,94 25.~1 03 20 64 20'98 21 17 181'3 .18I 1015~ ~0,47 21 06 2],44 20118 O~ 17 94 !,8 73 1.8,36 17 56 155:., 5 155.,5 155,5 155,5 155,5 20.77 !0151 1 1 06: I~ 00~ i5 7:3 0:5 02 16 52 145:, 14 145'~1 145,1~ :45 1.8:'47 10150 18,95 !.~ 92 ~8 20 18 53 56 15 45 15~99 16 .30 148 8 148..,8 148,8 148,8 148.8 18.47 10149 18.,44 03 30 15:, ~0 I5,73 15 8 1475,8 ~1.47,:8 18'08 10148 16,72 16:88 17 35 16 02 14 46 14,64 14 91 14,48 14~30 144 3 144,] 144'3 144,3 !44.3 16,97 I0147 16,50 16 22 1::fi:: : ::52 I3 ::1:<:4. 0:2 1 24 13':~1 146~. 8 146'.,. t4 i46':8 I46'8 16"52 10146 16 .42 16 57 13 59 13,80 ~3,6~ 152~. 5 !52,5 152,5 152'9 152'5 1'014.5 .::5:4:16 1~ : :1 ,02 153. 153,5:1:5 :::i53:;5 1.6::~0 10144 14. 77 ~2 ~6 1.~96 1~,~3 148. 0 14~,0 148,0 148,0 148,0 15,07 101~3 s: 151:~ 6 1 51 151 65 1 .35 13 35 13,5~ 1~,58 154 8 154,8 !54,8 154.8 154.8 16, t4 1014~ 16 44 1.6,08 1~ t0141. 18:1:9~::160 160, 160'~ ~60'3 60:,3 58 10140 19. 86 19,48 19,19 19, 70 16~.4~ 16 41 16,20 16'70 165.9 165..9 1.65.9 ~65.9 165.9 19,63 10139 1~ 41 1..1 16 7 .:3 16:4,:3: i 1 49 10138 !8 72 18,95 10,13 18,94 10, ;64 16 50 16,3] 17,19 159.5 1.59,5 159.,5 159,5 !59,5 1,9:,03 10137 2:0 I 4:4 i 1262, i {6" ::! 1 20'99 10136 21'22 2!,55 21,50 4521 08 17 80 17 80 18'30 18~4.1 158 1 158,1 158.! !58.1 158.1 21,,39 I0135 }0't3 9::5::::i:9 .~8:::I5 16,:45 150.,5 150;5:I505i5::1:50.9 150':5 10134 !7,7~ 17 .89 17,18 11 15 .!5 1.4 57 15'58 1.4,57 1.47.8 147,8 147.8 147'8 1.47.8 17.,50 133 I 02 16::.7 55 :I3:1.4 ~;46 14:, 30:149..:6 9"6:14 6 1149,6 14:9'6 16'88 1013~ 1.6,69 16 67 16,73 31 14., 33 1.4.05 14,1.6 11,23 1...4,20 1.53. 5 153,5 !53,5 1.53,5 153.5 16,69 10131 53 81 14 ~03~I4'06 13~;'~ 4 I ~'3 1.53 5 153,5 !:53:15 153' 5 i53.5 ~: · 15,89 15. ' 15:10 15,15 14,95 15 41 ~5 84 15 59 15 34 ~5 40 15 17 1.4 63 1,4 04 14 14 15 15 16 18 21. 18 14 ~ 14 I] 13 ~ 6 08 O0 t0 CO~Pll~¥ : ~Tt~lV. TIC P.ICHF'IFiT,.,D CC]. WELL : D.S, 13..5 PAGF )EPTB P~,SS1 PASS2 PASS] PASSa PASS5 P~aSSl PASS2 PASS3 P~SS4 P~SS5 PASS1 PASS~ PASS3 PASS4 PASS5 A. VE. AvE. FT CU Cfi Cfi CU CII CII CU CU CU CU GIPI GAPI GAPI CAPI GAPI CU CU 10130 16,95 16,50 16,q8 16,77 16.75 14, 10129 19,72 18,78 19.35 lP.08 3.9.00 16, 10128 24.36 25.23 25,30 23.27 24,13 10127 26.14 26,34 25.33 2~,95 25,P{ 21. ~0126 24,02 25.20 24,38 24.~ 24.86 21. 10~5 24,75 ~5,06 25,3n ~4,88 ~4.~3 21. ~01~4 25.~5 ~5.53 25,~4 25.14 25.31 2~. ~01.22 24.03 24.3l 24.86 25.54 24.25 22. 10121 2~,63 28,75 30,nO 30.75 30,09 26, 101~0 30.97 ~2.97 31,33 30,43 31.03 J. 0119 74.73 27,11 25,76 24.~1 25,~3 101~8 23.23 23,16 2~,98 23.69 23,20 20, 101~.7 26,59 25,25 26,~3 26,63 26.73 22, ~0116 28.30 26,72 27,16 26'94 ~7.36 23. 10115 26.5~ ~5,~B 25,!4 25.~{ ~6.05 22, 101}4 26.02 25,63 25,25 25.76 25.55 ]0113 27,~0 26,67 2~,63 2~,36 27,91 !01}.2 30,,4,8 30,70 3~,04 31,57 ~0,94 ~6, 10~10 22,78 22.63 2~'93 21.73 2~.98 19, 10107 D3.64 24.2~ 2~ 90 2~.09 23 6~ 20, 10'107 2~,.59 22.54 2~, 90 22.64 2~, 48 1,0106 2'1,tl, 21.49 21 6~ 20.9B 201 8t 17, 10105 21.44 2~.1,4 2~ 35 ~9,.4~ 2J 17 lOl04 21.20 ~i.02 2j,.:22 19.54 20,'00 I?, 101,0220.4,520.§8206220.~11212317~ 1010123.2822 ~623 4022.61, 238020 lOlO0 24.§9 24 55 24 67 24.47 2~ 66:2Ii 1, oo97 5) 05 14 1,0094 41 116 06 16,53.~5. , .00 16 42 1.7 19,19 20,93 19.95 20.72 15 150 24 36 26 44 · . 150 , 2~ 63 21 36 91C83321.2321.R821.31 21.6221'"821'2521.4022.32 21.9421.0220'832,.172_17]~'53~'8280 325 232.191.0.'~a 28232'~32~!i19 ~ 280232'~325 ~"57'~191'..~~2~2!!~0~ 25. 2424'o525.13.~855 2,21222,. 29606716 25 26,64 27.02 28.18 25,69 217 2~ 217. ! 8 29,69 26 64 13 29.'6 26,22 26.93 26.72 224.5 224 5 224.5 224.5 224..~ 31.15 27 42 3~ 23.61 22,20 22.10 21.64 210 5 210 5 210,5 210.5 210.5 25.34 22 1720.0620,2620,6520,03 !80:518051R0,5180.5180.523.2020 5221.4821~9722o~822.'721B541854 ~85,4 ~85,4 23 23,67 23..59 23,i0 24,55 191:9 1.91 9 1.91,9 {,gl,9 191.~. 27.1626'432322 7022,2522,6222,2423,]9184.31843184,31~4.3 ~84, 2 2322.0222'2922.46 ~2.591823 le2:31~2.3 ]~2.{ 1B2.] 25.P825.63222 48 20,47 19,62 20,06 19,64:173 6 1.73.6 3,73.6 173,6 173.~ 22.25 lg X7 20,~5 19,35 19,70 20,13 180 4 180.4 1RO,4 !80,4 180.~ 23,66 19 13 19,9~ 19,06 I9.50 19.~28 187 0 187.0 1~7,0 J87,0 .187,~ 2~,98 {.~ 48 ~9,~2 IR,62 ~8,55 18. 38 179 3 179,3 179,3 J79.3 179.~ 22,59 18 4~ 17~30 17,45 1.7,61 ~..7. 30 {,81.4 ~1,.4 181'4 ]91:'4 181,~ 21e21 17 27 ~7,36 18,05 17,63 17 ~5 173.6 ~73,6 ~7].6 {.7].6 21,J7 1.7 ~6 17.00 17,46 16~37 16.03 192 O 173'6 0] 16 36 16 97 15,73 15 84 192. 192.0 192,0 192.0 !92.. i9,17 16 57 19 27 19 77 19,72 20 38 193,8 193 8 {93,8 J93,8 ~93,8 23.,20 1.9 6 4 1844 184,4 184,4 184~4 24,61 20 9,00 ,7s. o ,!:78 .78.s 78. o ,. . 17, 73 I,,. 62 1 17 13.09 t.3.. 10095 1.7,94 1~,87 1.6 10003 ,.4,35 14,57 1,0002 ~5.6014 9, 6 16 100~I. 17,O4 16.98 10090 18.~3 17.1.4 7 1008910,13 18.72 10088 ~8,86 10087 16.80 17,1.7 1.00~6 15.65 15.~5 l n0~5 15.9~ t5 ~4 . 1,00~4 ~5'69 ~6.~.6~6 I3 :t4"14:1 1,6 1..6,741~ ~5~ ~:3 1~,90 18 4:1,8.5818 54 16.95 31. I~,37 15 82 11 71, 13 62 14 O0 69 94 1~ 41 ~614, 08 9613 ~ 172.6 172 1.89,3 189 98 190 9 190 19o:8 67 175,5 175 93 181,~ 181 53 1,82. 1~2 20 ~72.6 172 ,97 172.~ ,66 167,9 167 6172 3.90.9 ] i.'75,5 175 182,4 1~2 172.6 ]72 ~72,8 ~72 91.67.9 1.72. 167. )~PTH PASS% P~$52 P~SS3 PaSSa PASS5 PASS1 PnS52 PASS3 PAS$~ PASS5 PASS1 P~SS~ PASS3 D~SS4 P~SS5 ~¥E. FY CU CI.I CI! Cfi Cf! CI! CU Ct} CU CU GAP! GAPI aAPI ~API GAD! Cl.! CU [0082 ~8 ,.9 100~1 IO0~O 1~,58 1R 41 1~ 4.3 iu 05 1~ 45 15,10 15 52 {4.~6 15,75 14,~0 1~1,4 1.81.4 1~1.4 181,4 18J,4 1~ 51 1.5 IO0~O 16.58 17:23 16:~6 l~:O0 16:~6 ~4.34 13 66 14.~ ~].~6 13.41 177,6 177.6 177.6 ,77.6 177.6 16:91 1] }0076 ~7 11 ,.6.97 1~.58 ~6.q7 ~7'28 13.~9 13 75 13 60 ,~,~3 1]:g~ ~0~,3 209 3 209 3 ~09.] 209.3 16.97 13 {0075 17:59 17.70 17,8] 1~.67 19:06 14.76 14 45 14:2~ 14.40 15.02 207.5 207:5 207:5 ~07 5 207.5 17.75 {.4 ~0074 lq 67 1g.42 1q,23 20 6~ 1o ~8 16 ~0 ,.6 05 16.04 15,82 16.]4 230,0 2~0 0 ~30,0 930:0 2~0,~ ~O 67 16 1.0073 90180 20.27 19,58 20:42 1~:~2 16141 15 96 16.62 16,3R 1,6.63 237,8 237:8 237.8 ~37.8 237.. 0:1.9 16 10072 19 92 20,44 10,1! 20.06 1.~,63 16 11 15 69 16,~8 16,]0 15,59 261 0 261,0 36!.0 ]61.0 261.0 1.9.87 1.5 ,0071 ,~130 9! 18 48 18.50 15 29 15259 15 19 ,,5,66 15 70 24213 242.3 242.3 242,3 242.3 1.8 6, ,5 10070 1.9. ' 16 22 16, 16208. 16 75 203.4 203 4 203 4 203.i ~ 74 1.6 .~7 16 .28 16 33 16 .0 19olo ~,9o:o 19o, o2 16 ,. 1.~9.1 1~ , 1.~9.1 lo 2, ,.7 9 199,9 1.9 19 199.9 2 91 19 19 06 18, 56 10~92 19,9.2 lo 27 2n. O0 10069 20 20.09 20,06 lO:B9 19.77 10068 ~0 53 1.9 10067 2,:78 ~2 48 23.t2 22:91 ~2.70 19 10065 28,95 10064 ~9,16 ~0063 30,66 30 12 30.15 29,~8 30 100~2 30,2~ 3~ 16 30.08 30,48 30 IOOA1 31,41 31 14 31.01 31,20 30 1.0060 30,70 30 10059 29,00 29 1, o058 ~fl,55 28 1.0057 2:8,55 28 100~6 ~8,97 10055 '0.86 29 1.0054 31,1~ 30 '0053 34., 10052 3~ 75 35 100'1 3 10050 34 ~6 33 10049 3115 lOOd8 29,73 30 1004.7 ~7.07 ~7 10046 ~7,14 26 10045 30.50 ~9 ~0044 I004~ ]3,13 32 10041 31,59 31 0039 ,80 26 100138 ~6,92 26 10037 ~5,77 ~5 06 13 44 13.51 13.~6 13,26 167.0 1~7.0 {.67.0 167.0 167,0 19,~3 20,58 19,64 ~0,34 16,59 16,75 1~,}6 15,35 16.06 169. ,8 169,8 ~6~,8 169.8 20.~1 16, 37 30.28 30, 77 ~9.01, 29, 29 2~.96 49 28.84 28, 6 1, 3 29.:94 ~4 31.4! 071 33'72 33 7734.33 34 97 33,.92::34 72 3,3,65 33 3~.' 2:7:;7:9127 58 27, ] ~ 26 9830.1:8 .29 ,.. ..... 'g733 1.6 27, O0 27, 05 27 84 28 61 27 47 26 9:726 75 2~ 73 26: 4~ 29 30 15.91 22 16 16.56 97 17 03 17 24 17.09 17 56 19 44 22 70 26 66 26 23 26 Ro 2~ 86 26 50 26 97 28 97 3~ 34 35 38 34 11 24 36 27 ~2 30 I 2:3 5 22 6.42 66 27 69 19 77 2~ ~9 2 07 29 03 2~ 37 27 67 ~6 29 26 74 25 95 26 7~ 25 33 56 34.~ 0 33 o 30 69 2~ 3~ 24 17 27 41 30 75 31 50 33 58 21, 30 19,55 18 ~4 ~,95 22 75 215 ,97 26 42 224 43 27,42 27 61 238 1,4 27.61, 23 228 41 5223 259 45 252 33 287 66 324 03 203 22 189 56 1.83 O0 194 .9 ~ 1.93,9 1 46 2~ 05 l~l.i I 02 2 lB8 56 .~3 30 4,2 190 0 ~9 .24 32 13 190 75 33 O0 1.83 I . 24 03 175 75 203.4 19020 190 i. 89.1 189 53 1.99 9 199 4 228 4 228.4 22 .4 228. 8 ~37 8 237 3 0 259 0 259 0 259.~ 25]: 3 233 3 233 3 233, 23 4 224 4 224 4 224,~ 224 ~ 252 4 252 4 252.4 3 324,3 324,3 3~4 ~ 32. 5 360,5 360,5 360 5 360 3 292,3 ~g2, 3 292 3 292 4 203.4 89,. ..... g 1 183 ! 3 4 183 8 194, 194 194,~ 194 0 190,0 190,0 9 199:;9 lgO,9 190.9 183 6 175,6 175.6 1,75. 6 175,6 ,,7~.6 1'/5 ~ ~ g2 1~3.0 163.0 163;',. 163.0 163. 23 22 94 26 ~9 27 12 27 70 29 73 26 ~2 ~6 92 27 36 29 97 32 71 34 92 3.4 08 27 ~2 25 93 33 95 3~ 92 2.. 90 23 ~8 22 6~ 2~ 5O 30 56 33 59 33,03 34,02 34 03 33 9,5 3'2. 78 32-29 31 38 29 5 "a. 29, , z,..,4,6 18 .66 25, I 25.60 25 3:1 21, [00~6 25.02 2~ 03 24,q~ 25.05 24,66 20.98 20,88 21.1J 21.14 21.23 167.8 167.8 J. 67.8 ].67.8 167.8 24.97 t0035 23.64 24. i14 24,20 24.47 23.34 19.50 20.2~ ~.08 20,39 ,,,q! 162.0 162 0 ,62.0 ,6,.0 162 0 ~.92 20 [0034 22.23 22 92 22,39 2~.75 22,14 18,98 18,g .~8 1g,84 18.84 160.9 ].60~9 160.9 160.9 1.60~g ...4g 18 9 10032 22.36 27 97 21,90 23.03 23.47 1.8.94 I 80 18 g2 19,36 19.64 ].62.0 162 0 162.0 162.0 ]62°0 70 19 4 . . ' 92 tg 83 14 20 159:3 159'3 159.3 ].59°3 159: 1.0030 22,31 22.91 22,74 23 12 22 ~3 18.56 lq,OR 18. . . . t0029 22.39 23 no 22,26 23.52 22.ol 19.13 ~9.16 18.79 19,91 19.70 !65.9 165.9 165.9 165.9 ~65.g 22 8g 1.0027 22,55 23 13 ~3,70 ~3.0] ~.34 17,70 1.9,94 19,05 1~,31 19;30 170.8 170,8 170,8 ~70.8 170;8 23 34 19 t00~6 ~1,23 ~2 06 ~0.95 ~l,gg ~.67 ~.7.20 18.42 ~7,88 18.62 ~.8.~4 ~88.g 188.9 ~88.9 ~88.9 188,9 t0025 21,30 23 11 ~0.93 2~.31 22,05 19'06 18,R8 17,77 20,11 1~,64 199.9 1~9.9 199.g 199,0 199.9 21 92 ~9 [00~4 ~6,0~ 25 ~6 23.80 2~.95 2~,91 21.86 21,42 19,70 22.94 22.83 225.1 225,~ 225,1 225,~ 225.1 25 90 21. 1.0023 3].1~ 30 28 ~,0] ~1,75 ~2,1g 28.86 28,72 24,55 28,30 30.~3 279.0 279.0 279,0 27g.0 279,0 3~. 02 28 !.0022 3~,91 3~ 81 ~.9~ ~..02 ~4.88 31.27 32'59 29.2l 31,58 32.75 270.8 270.8 270.8 270.8 270.8 33 96 31 1002~ 29,47 3!. 42 '~ : [00~9 26.59 27 47 ~7,03 ~6..68 ~&.94 23,50 24,39 24,67 24,~2 24,31 ~7J..$ 1gO.~! ~80,~. ]80.1 1.80.1 28'~9 26 . 17~,8 171,~ !7~,8 171.8 26.~94 24 t0018 25,3~ 25 97 ~5'5g ~5;6025,47 2~.~2 23.63 23.38 22'95 23.30 173.6 173,6 1.73.6 ~.7~.6 173,6 25.59 23 10017 2~,91 ~491 24.92 ~,67 94;?5 22.!~ 22,~3 2~,39 22,~2 22,58 !69.8 169,~ 169,8 169,8 169..8 tOOl& 24.67 24 ~9 ~4.'54 9{'91. 22.12 2~,58 168.8 168,8 168.8 ~.68.8 168'8 ~ 40 72 21 22 }~0],5 ~4,78 24. 77 ~4,~g 24,68 94.~5 ~.16 21,95 21.~ 2].89 21,78 166.9 i66;9 ~66.9 ~66.9 166.9 7 21 19 22 100~3 25.()e 25 09 24,95 ~,43 25,06 22 09 22,56 22.05 21,76 2~,39 170.6 !70,6 170.6 1.70,6 170.6 2 2 100].~ 25 .22 ~5 ~3 24~4 .::1. 4 22, 7 22'07:22.1~ ~68.9 168,9 168.9 168'9 i68.~9 ~ ~ ~2 1001~ 25 ].7 ~5 20 25,12 ~5.20 2..~.~,0~ ~ ~8 2~.73 27. ~ 2~.58 ~2,42 164,0 ~64.,0 164,0 1.64.0 1000~ 24 91 25 ~2 ~5.~ 25m~6 ~,2' 92 ~2,~6 ~1.. 96 ~,].4 ~., 02 164.9 ~64~9 164.9 ~,64.9 164.9 10008 24, .48 24. 85 166,9 166.9 ],66:'9 166.9 ~~! 69 ~0007 24 ~.~ 24 47 ~4,~0 ~.~..28 24. 51 3'! ~.,31 21 05 2].,88 2~. ~.6 166.8 ~66~8 166 8 ~66,8 1.66.8 10006 ~3 69 23 69 ~4 20,:96 20. 62 9~i,~6 20 95 164.,9 164,.9 ~,64 9 164'9 164.9 9 10005 23,69 23 ~0 2~ ~ ~3 20,27 ~0 .79 20 41 ~0. 72 170,8 170,8 1.70 8 ~70.,8 !70.8 ~ 59 20 ~.0004 169 8 ~69. 8 ,65 2O 0122O 1:620 ~1 0 tO ~0 0,3 20 54 20 69 20 41 ~74, 22 ~73, 31 17g, 38 211 17 173 4. 179 174 ],73 ,4 ~ 79 ,§ 21.1 1000.3 23,59 23 91 23 10002 2~,25 2~ 87 lnOO1 23,38 23,62 23 35 2... 48 23 1.0000 23,31 2.4'22 23 30 ~4 !2 24 9999 24 ggg8 25 0997 27 99~A 29 0995 26 ~994 29 ~9o3 32 ggq2 ~4 ~9ql 35 g~ 35 9990 3~:03 36 6 25.2~ 24, ~5 25:,63 25 73 27,5! ~ :1,1 29;15 ~, 73 27 19 27 34 27 05 2,7 ia 32 ~8 30 ~4 34, lO 34 '3 2,., 25.10 25 06 ~6 27.36 28 ~5 27.37 26 26 30.90 33 80 34.8834 25 35.2! 3~ ~6 35.933. 73 2~ 4.5 21 24 2~ ~ ~ , 9]: 22 6i 2~ 42 22 ~ ~ 10 23 ~ 24 47 24 42 ~ . 34 26 26O 6~ ~5,91 ,57 36 2~ 226 8 270 8 270 0 285 0 285 ~77 4,2 252 260 2~6 202 3 277 9 242 3 252 O 260 3 226 4 202 ,6 1.74.6 ] 72 20 · 6 1't3,6 ~ 45 20 41.79,415020 5 211.5 ~ i5 20 8 270.8 22 3 277.3 78 9 242.9 270 285 243 243. 02. 202, 51 24 94 25 14 23 57 24 66 29 79 33 MpwH PASS1 PASS~ P~SS3 P5S$4 PASS5 PASS]. P~S$2 PASS3 PASS4 P~SS5 PASS1 PASS2 PASS3 PASS4 PASS5 AVE. AVE, NEAR MEA~ NFA~ NFAP NEAP FAW PAR ~'AP FAR PAP 5'EAR ~'AR FT CU CI~ CU CU Ct] Ct! CU CU CU CU GAP! GAPI ~API GAPI ~API CU CU 998§ 36.d7 ]5.86 36,37 36.21 35,57 37.09 36.94 3 55 37,87 37,5] 2o5.6 Z.b.m Z b.b 7..b,m z ~.~ ~.,~z ~, 53 O~7 35.i4 ]~,17 35.51 ]6.~8 3~,14 37,78 37.58 3~ 44 37.07 37.63 207.3 ~07.3 207.3 ~07.3 207.3 36.01. 37 68 O9~6 3~,ql ~6,48 39,~1 3&,~5 36.35 36.13 37,72 37 44 37,25 37.46 ~08.3 208,3 208.3 ~0~,3 908.3 36.45 37 36 O9~5 36.91 ~5,8q 36.1~ ~6.~ 37.{4 37.31 37,81 37 48 36.54 38,08 205.3 205.3 205.3 ~05.3 205.3 36.51 37 48 9~84 36,Og 39,88 35,87 36.34 37,20 37.78 37,16 36.7~ 37.25 36.98 204.4 204.4 904.4 204,4 20~.4 ~8~ 36.69 39.90 36,07 ]6.~6 ~7.00 37.56 37.90 37,06 37,~0 37.24 ]08.] 208.3 ~08.~ 208.3 908.3 36.54 37.~ ~9~ 37.O9 3&.~6 ]7,10 ]6.~6 36,49 ]7.09 36,57 ]7.~2 36,39 ]7,99 ~01.5 201.5 ~01.5 ~01.5 20~.5 36.78 36 9q§~ 36.50 36,34 3A.69 ~5,78 §5.49 ]6.91 36~25 37,25 36.38 37.53 194.0 194.0 194,0 194.0 194.0 36,14 36 O&~O ]~.~6 35,7~ 35,ql 36.~6 3~,53 37,09 35,56 36.7~ 36,0! 36.76 lO0.g 100.9 ~.qO.9 !90,9 190.9 35,94 36 ~79 36.~§ 3~.59 §~,56 36.m] ~5.~6 37.66 35,34 36,88 35,R4 35.85 195.8 195.8 195.8 195.8 195.8 35.86 36 ~78 ]6.{] 39,97 35,50 ]6.00 3~'44 37,75 37.20 3~,9.6 36,59 36,12 190.0 190.0 190.0 190.0 100.0 35,75 37 4%77 ~.~ ]~.63 ~.~9 ~5.50 35,31 36,U{. ]6,71 36.72 36.66 36.08 199.1 192.1 !99.1 192,~ 192,1 35,41 ~76 ]~54 35,61 3~,~7 ]g.9~ ]~,3~ ]6,~ 36,9{ 35.84 35,50 ~5,95 ~87..1 1~7.1 187.1 ].~7.,1 1~7,1 35~54 35 9975 ~.~4 ]~,59 3~.34 ~.4~ 3~.79 37,00 36,19 36,47 36,50 36.58 190.1 ~90.1 190.1 190.1 190.1 35,51 36 ~67~ ]~ 94 ~5 2~ 35 94 3~-~1 3~-71 ~6-33 36 9~ 36 50 36,47 36,23 {O9.5 199.5 10~,5 1~9,5 1~9.5 35.67 9973,35.78 35,34 35,56 35,19 34,86 36,1,3 ~6,25 36.97 35i06 35.97 ~91,9 191.9 191.9 191.9 1gl.., 35,]4 36 ~97~ 3R,4~ 35,75 35.44 35,~7 35.38 36.50 ]6,~5 35,7~ 36.00 36.18 ~96.8 196,8 196.8 196,8 196.8 35,44 36 ~9~ ]~,~ {5.~ 3~.~8 §~,~3 §~.98 ~7.I3 3S,91 ~5.44 ~6.~9 36,~$ 196.6 ~96...6196.6 1~6.6 196.6 4476 36,06 35,56 ]g,~4 3S,~4 35,4.7 37,~1 36,19 36..47 ~5,31 35,79 194..8 194.8 19~.8 194,8 {.94,8 35,84 36 6~69 ~9'94 ~,~6 36'~ 3~,~3 ~5,46 37,34 36,44 36,66 36,]] 35,96 192.8 192,8 192,8 ~92,8 199'8 35,75 36 ~6~ 3~,?~ ]~.v~ ]~.~, ]~.~ 3~.~0 36,]~ ~,0] 3~.~ 3~.~ ~.,~ 1~0,~ 1~0.8 lgo.~ l~o,~ !~0..~ 35,81 36 9067 ]~,5~ 35,63 ]~,~ 3~,60 36.04 35;~1 35,19 36,~9 35'70 36~;95 190.0 190,0 190,0 Jgo,o 190,0 35.82 35 ~966 34'~ ]~,03 3~]9 3~,91 ]~,65 3~,~8 36,]4 36,03 34,63 36,47 194.8 194,8 194,8 ~94,8 J94.~ 35,30 36 ~5 3~,59 ~,~.3 ~6.,6~ ~4!,~4 3~,19~ ~6']4 36,00 36,94 34.,'56 36,81 189,0 189,0 ~89.0 189,0 189'0 35,96 36 966~ ~,I~ 35~5~ '~6,16 ~5,~3 35,~7 36.,9~ 36,81 36.09 35,34 35,A0 ~.9~.,1 19~,1 192.1 192.1 192.1 35,64 36 496~ 3~,84 3~.78 36,95 35.3~ 35,.9 37,16 36, ~7 35,8 36.84 3,.~.40 19~. ~.,~, 1.~.U ~..1.,. ..1., 496'j ]~.44 39,03 ~5,4.~ 36.41 36,90 35,84 190.9 {90.9 190;9 190,9 190,9 35,51 36 9~60 3~,§§ ]5,~] 39,{'6 39,04 3~,25 36,91 371 ]~ 37,31 36,79 36,00 !98.9 198,9 198,9 198,9 198,9 35,88 36 0959 3~.,~ ]~'5936,60§6,65 ]~:,56 36,59 36.7~ :36'91 316,16: 37,00 201.4 201,4 201,4 ~01,4 ~01,4 36,~3 36 99~ 36,0636;!.9 35 4436,0.6.2. 3, .~ 1.. , 1 , .... :, , . ,.,. .,.t ~96 §~,?~ ~,)8 ]6;!3~ 36,03 36,53 36,59 36 34 35,53 36,83 35,94 194.0 194.0 104.0 1.94,0 104.0 36.08 36 ~ ]~,04 37.I3 35.;13 189.1 189,1 189,1 1~9.1 189.1 36'11 36 ~ ]~.i3 ]~,34 3~,$~ 3~.i5 3~,~8 36,91. 37 a~ 35,69 36,51 36,03 !90.,0 190,0 1.90.0 190,0 190.0 36,34 36 ~§ 36,17 35,.57 36,56 195~9 195.9 195.9 195,9 195,9 36'64 36 0~5 ]~ §4 ]5 97 36 ~3 ~6 95 ]6_47 36-75 36 ~6 36,s4 37 07 37,d7 191,8 101,8 lgi.~ lol,8 191,8 36,45 36 Og~l 36,81 36,00 36,05 36:.;6~ 35:i~8 37.,72:37 .)9 36.34 37.24 38,2. 189,9 189,... 1.~9,9 189:,9 1.8...9 36,30 ;.7 ~50 §$.00 36.1.3 ]6,57 ]~.o2 3~.i3 37,31 37 50 36.75 37 lB 38.59 1.94.0 1o4.0 194.0 194.0 194.0 36.35 37 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 13 - 05 FIELD NAME : Prudhoe Bay BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292062600 REFERENCE NO : 97569 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: **** REEL HEADER **** SERVICE NAFIE : EDIT DATE : 98/01/27 ORIGIN : FLIC REEL NAME : 97569 CONTINUATION # : PREVIOUS RRRr. : COMMENT : ARCO ALASKA, INC., D.S. 13-05, PRUDHOE BAY, API# 50-029-20626-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/01/27 ORIGIN : FLIC TAPE NAME : 97569 CONTINUATION # : 1 PREVIOUS TAPE : COF2~ENT : ARCO ALASKA, INC., D.S. 13-05, PRUDHOE BAY, API# 50-029-20626-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 13-05 API NUMBER: 500292062600 OPERATOR: ARCO ALASKA LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 27-JAN-98 JOB NUMBER: 97569 LOGGING ENGINEER: C. YON OPERATOR WITNESS: G. SARBER SURFACE LOCATION SECTION: 13 TOWNSHIP: ION RANGE: 14E FNL: FSL: 1761 FEL: FWL: 1372 ELEVATION (FT FROM MSL O) KELLY BUSHING: 78. O0 DERRICK FLOOR: GROUND LEVEL: 42.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 11055.0 29. O0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN b73MBER : PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 10209.0 10209.0 10180.5 10179.5 10179.5 10179.5 10153.5 10154.0 10153.0 10154.0 10124.0 10122.5 10112.5 10111.0 10111.0 10111.0 10098.5 10099.5 10095.0 10093.5 10088.5 10091.0 10086.5 10089.0 10078.5 10077.5 10075.5 10078.5 10071.5 10070.0 10058.0 10058.5 10053.0 10051,5 10049.5 10051.5 10021.0 10022.5 10020.5 10023.0 9997.0 9997.5 9994.0 9997.5 9968.5 9973.0 9961.5 9964.5 9943.5 9945.5 9937.0 9937.5 9936.5 9939.5 9902.0 9903.5 9898.0 9901.0 9879.0 9880.0 9876.0 9878.0 100.0 101.0 102,0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.0 88888.0 REMARKS: THIS TAPE CONTAINS THE LDWG EDIT FOR ARCO ALASKA WELL D.S. 13-05 RST(TDT). FOUR BASE PASSES AND AN AVERAGE PASS ARE PRESENTED. The depth adjustments shown above reflect cased hole GR to open hole BCS GR and cased hole SIGM to open hole GR. Ail other RST curves were carried with the SIGM shifts. BASELINE GR PROVIDED BY THE CLIENT $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10221.0 9832.0 RST 10240.0 9852.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH RST REMARKS: This file contains RST/TDT Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. $ LIS FORMAT DATA No ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 4 TYPE REPR CODE VALUE .............................. 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 EL~ CODE (HEX) DEPT FT 1022552 O0 000 O0 0 1 1 1 4 NBAC RST CPS 1022552 O0 000 O0 0 1 1 1 4 FBAC RST CPS 1022552 O0 000 O0 0 1 1 1 4 SBNA FIL CU 1022552 O0 000 O0 0 1 1 1 4 SFNA FIL CU 1022552 O0 000 O0 0 1 1 1 4 SBFA FIL CU 1022552 O0 000 O0 0 1 1 1 4 SFFA FIL CU 1022552 O0 000 O0 0 1 1 1 4 TRAT FIL 1022552 O0 000 O0 0 1 1 1 4 IRAT FIL 1022552 O0 000 O0 0 1 1 1 4 CIRNFIL 1022552 O0 000 O0 0 1 1 1 4 CIRF FIL 1022552 O0 000 O0 0 1 1 1 4 BSALRST PPK 1022552 O0 000 O0 0 1 1 1 4 $IBF RST CU 1022552 O0 000 O0 0 1 1 1 4 TPHI RST PU-$ 1022552 O0 000 O0 0 1 1 1 4 SFFC RST CU 1022552 O0 000 O0 0 1 1 1 4 SFNC RET CU 1022552 O0 000 O0 0 1 1 1 4 SIGM RET CU 1022552 O0 000 O0 0 1 1 1 4 D$IG RST CU 1022552 O0 000 O0 0 1 1 1 4 FBEF RST UA 1022552 O0 000 O0 0 1 1 1 4 CRRA RET 1022552 O0 000 O0 0 1 1 1 4 GRCH RST GAPI 1022552 O0 000 O0 0 1 1 1 4 TENS RST LB 1022552 O0 000 O0 0 1 1 1 4 CCL RST V 1022552 O0 000 O0 0 1 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. SFNA.FIL IRAT. FIL SIBF. RST SIGM. RST 10240.000 NBAC. RST 20.499 SBFA.FIL 0.529 CIRN. FIL 28.193 TPHI.RST 15.473 DSIG.RST 4871.114 FBAC. RST 10132.740 SBNA.FIL 41.518 SFFA.FIL 18.110 TRAT. FIL 1.120 CIRF. FIL 2.270 BSAL.RST 23.526 SFFC.RST 15.473 SFNC.RST 0.486 FBEF. RST 51.003 CRRA.RST 49.628 0.933 17.488 15.958 1.810 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: GRCH. RST -999.250 TENS.RST 1008.000 CCL.RST DEPT. 9833.000 NBAC. RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH. RST 32.999 TENS.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF. RST -999.250 CCL.RST -0. 002 -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC.RST -999.250 CRRA.RST -999.250 -999.250 -999.250 - 999. 250 - 999. 250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10230.0 9852.0 RST 10250.0 9872.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: BASELINE DEPTH .............. 88888.0 10227.5 10195.5 10191.5 10187.5 10183.5 10182.5 10179.5 10174.5 10171.5 10167.5 10154.5 10153.5 10151.5 10150.5 10147.5 10146.5 10143 5 10142 5 10139 5 10138 5 10135 5 10134 5 10131 5 10130 5 10115 5 10111 5 10107.5 10106.5 10103.5 10099.5 10098.5 10095.5 10092.5 10079.5 10078.5 10074.5 10067.5 10063.5 10059.5 10058.5 10055.5 10054.5 10051.5 10047.5 10043.5 10042.5 10038.5 10034.5 10031.5 10030.5 10027.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88889.0 88888.0 10227.5 10195.5 10192.0 10187.5 10183.0 10183.5 10175.5 10153.5 10150.0 10146.0 10141.5 10137.5 10134.0 10129.5 10105.5 10096.5 10076.5 10072.0 10056.0 10052.5 10040.5 10037.0 10034.0 10031.0 10179.5 10171.5 10168.0 10154.0 10152.0 10148.5 10143.5 10140.0 10136.0 10131.5 10115.5 10111.0 10107.0 10104.0 10100.0 10095.5 10094.0 10082.0 10069.0 10063.0 10059.5 10056.0 10052.5 10048.5 10045.0 10033.0 10030.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 10023.5 10026.0 10021.0 10023.0 10014.5 10015.0 10011.5 10013.5 10010.5 10010.5 10007.5 10010.5 10003.5 10006.0 9999.5 10002.0 9995.5 9998.5 9991.5 9991.5 9987.5 9990.5 9983.5 9987.0 9979.5 9982.5 9978.5 9980.0 9967.0 9969.0 9937.5 9939.5 9936.0 9937.0 9923.0 9926.0 9903.0 9903.5 9891.5 9894.0 9864.0 9864.5 100.0 100.5 102.5 $ REMARKS: This file contains RST/TDT Pass #2 (Base Pass #2). The depth shifts shown above relect GRCH Pass #2 to GRCH Pass #1 and SIGM Pass #2 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: TYPE REPR CODE VALUE .............................. 0 66 1 .............................. ** SET TYPE - CHAN ** ....................................................................................... ~ SERV ONIT SERVICE API API API API FILE NUMB ~ SIZE I~,PR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELI~4 CODE (HEX) DEPT FT 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1022552 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10250.000 NBAC. RST 5292.341 FBAC.RST 7733.454 SBNA.FIL SFNA.FIL 20.001 SBFA.FIL 37.475 SFFA.FIL 18.348 TRAT. FIL IRAT. FIL 0.565 CIRN. FIL 1.307 CIRF. FIL 2.547 BSAL.RST SIBF. RST 15.753 TPHI.RST 16.384 SFFC.RST 15.946 SFNC. RST SIGM. RST 15.948 DSIG.RST -0.600 FBEF. RST 44.170 CRRA.RST GRCH. RST -999.250 TENS. RST 766.000 CCL.RST 0.000 DEPT. 9852.500 NBAC. RST -999.250 FBAC. RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC. RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF.RST -999.250 CRRA.RST GRCH. RST 26.327 TENS.RST -999.250 CCL.RST -999.250 42.081 0.902 -19.032 15.337 1.733 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10180.0 9850.0 RST 10214.0 9870.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST 88888, 0 88887.5 88888.0 10201.5 10201 . 5 10189.5 10189.5 10185.5 10185.0 10181.5 10181,5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 10 10177.5 10173.5 10169.5 10165.5 10164.0 10154.5 10150.5 10149.5 10145.5 10142.5 10141.5 10138.5 10137.5 10134.5 10130.5 10125.5 10121.5 10119 0 10109 5 10105 5 10102 5 10098 5 10093 5 10087 5 10079 5 10078 5 10074 5 10062 5 10058 5 10057 5 10053 5 10047 0 10045 5 10041 5 10038 5 10037 5 10034.5 10033.5 10030.5 10029.5 10025.5 10022.0 10021.5 10017.5 10013.5 10009.5 10005.5 9995 0 9991 0 9981 5 9978 5 9977 5 9974 5 9973 5 9957 0 10163.5 10153.5 10150.0 10142.0 10137.5 10134.0 10129.5 10101.5 10097.0 10077.0 10072.5 10060.5 10057.0 10051.5 10045.5 10037.0 10034.5 10031.0 10022.5 9979.0 9976.5 10177.5 10173.0 10169.0 10166.5 10150.5 10147.0 10143.0 10138.0 10126.0 10121.5 10119.5 10109.5 10106.0 10095.0 10089.5 10082.0 10058.0 10054.5 10046.5 10043.0 10039.5 10035.5 10032.5 10028.0 10024.0 10019.5 10016.0 10012.0 1O0O8.5 9998.0 9994.5 9984.5 9981.0 9976.5 9959.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-I998 00:57 PAGE: I1 9935.0 9936.0 9933.0 9935.0 9903.0 9903.5 9897.5 9901.0 9894.5 9895.5 9889.5 9893.0 9885.5 9888.0 100.0 101.0 102.5 $ RE~AR~S: This file contains RST/TDT Pass #3 (Base Pass #3). The depth shifts shown above relect GRCH Pass #3 to GRCH Pass #1 and SIGM Pass #3 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 1022552 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1022552 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1022552 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1022552 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1022552 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1022552 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 12 NAFiE SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) SFFA FIL CU 1022552 O0 000 O0 0 3 1 1 4 TRAT FIL 1022552 O0 000 O0 0 3 1 1 4 IRAT FIL 1022552 O0 000 O0 0 3 1 1 4 CIRNFIL 1022552 00 000 O0 0 3 1 1 4 CIRF FIL 1022552 00 000 O0 0 3 1 1 4 BSALRST PPK 1022552 00 000 00 0 3 1 1 4 SIBF RST CU 1022552 O0 000 O0 0 3 1 1 4 TPHI RST PU-S 1022552 O0 000 O0 0 3 1 1 4 SFFC RST CU 1022552 O0 000 O0 0 3 1 1 4 SFNC RST CU 1022552 O0 000 O0 0 3 1 1 4 SIGM RST CU 1022552 O0 000 O0 0 3 1 1 4 DSIG RST CU 1022552 O0 000 O0 0 3 1 1 4 FBEF RST UA 1022552 O0 000 00 0 3 1 1 4 CRRARST 1022552 O0 000 O0 0 3 1 1 4 GRCH RST GAPI 1022552 O0 000 O0 0 3 1 1 4 TENS RST LB 1022552 O0 000 O0 0 3 1 1 4 CCL RST V 1022552 O0 000 O0 0 3 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 10214.000 NBAC. RST 3920.499 FBAC.RST SFNA.FIL 20.964 SBFA.FIL 39.839 SFFA.FIL IRAT. FIL 0.569 CIRN. FIL 1.339 CIRF. FIL SIBF. RST 16.265 TPHI.RST 19.357 SFFC. RST SIGM. RST 15.995 DSIG.RST 0.399 FBEF. RST GRCH. RST -999.250 TENS.RST 952.000 CCL.RST DEPT. SFNA.FIL IRAT. FIL SIBF. RST SIGM. RST GRCH. RST 9851.000 NBAC.RST -999.250 SBFA.FIL -999.250 CIRN. FIL -999.250 TPHI.RST -999.250 DSIG.RST 40.055 TENS.RST -999 250 FBAC.RST -999 250 SFFA.FIL -999 250 CIRF. FIL -999 250 SFFC. RST -999 250 FBEF. RST -999 250 CCL.RST 6085.887 SBNA.FIL 42.720 18.310 TRAT. FIL 0.941 2.508 BSAL.RST -17.493 16.015 SFNC.RST 17.152 45.963 CRRA.RST 1.714 0.000 -999.250 SBNA.FIL -999.250 -999.250 TRAT. FIL -999.250 -999.250 BSAL.RST -999.250 -999.250 SFNC. RST -999.250 -999.250 CRRA.RST -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 13 **** FILE HEADER **** FILE NAFIE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIM~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCR~ENT: 0.5000 FILE SUF~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10200.0 9850.0 RST 10218.0 9871.0 $ #. CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88887.0 88888.0 10205.5 10205.5 10201.5 10201.0 10197.5 10197.0 10193.5 10193.5 10189.5 10189.5 10185.5 10185.0 10174.5 10173.5 10169.5 10169.0 10165.5 10165.5 10164.0 10163.5 10161.5 10162.0 10155.5 10154.0 10153.5 10154.0 10149.5 10150.5 10145.5 10146.5 10142.5 10141.5 10141.5 10142.0 10138.5 10137.0 10134.5 10134.0 10133.5 10134.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 14 10130.5 10129.0 10129.5 10130.0 10124.0 10122.5 10109.5 10109.5 10105.5 10106.0 10092.0 10093.5 10091.5 10089.5 10080.0 10082.0 10078.5 10077.0 10076.0 10078.5 10074.5 10072.5 10067.0 10068.5 10061.5 10061.5 10058.5 10056.5 10058.5 10054.5 10053.0 10053.5 10051.5 10053.0 10054.5 10049.5 10050.5 10045.5 10047.0 10042.5 10041.0 10041.5 10043.5 10038.5 10037.5 10034.5 10034.5 10033.5 10035.5 10030.5 10031.0 10029.5 10032.5 10026.5 10027.5 10025.5 10027.5 10021.5 10022.5 10023.5 10018.5 10019.5 10017.5 10020.0 10014.5 10015.0 10013.5 10016.0 10009.5 10011,5 10005.5 10008.0 10001.5 10004.5 9991.0 9991.5 9978.5 9979.0 9965.5 9968.5 9957.5 9959.0 9939.5 9939.5 9930.0 9931.0 9922.5 9922.0 9902.5 9903.5 9879.0 9880.0 9878.5 9881.0 9863.5 9864.5 100.0 101.0 102.5 $ REFIARKS: This file contains RST/TDT Pass #4 (Base Pass #4). The depth shifts shown above relect GRCH Pass #4 to GRCH Pass #1 and SIGM Pass #4 to SIGM Pass #1. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 15 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL RST PPK 1022552 O0 · 000 O0 0 4 1 1 4 68 0000000000 SIBF RST CU 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RST PU-S 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RST CU 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RST CU 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RST CU 1022552 O0 000 O0 0 4 1 I 4 68 0000000000 DSIG RST CU 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RST UA 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARST 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 16 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) TENS RST LB 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RST V 1022552 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10214.000 NBAC.RST 2760.000 FBAC. RST 11484.533 SBNA.FIL SFNA.FIL 17.996 SBFA.FIL 37.254 SFFA.FIL 18.057 TRAT. FIL IRAT. FIL 0.576 CIRN. FIL 1.431 CIRF. FIL 2.468 BSAL.RST SIBF. RST 18.376 TPHI.RST 23.677 SFFC.RST 15.739 SFNC.RST SIGM. RST 15.754 DSIG.RST -0.948 FBEF. RST 45.255 CRRA.RST GRCH.RST -999.250 TENS.RST 962.000 CCL.RST 0.002 44.173 0.990 -11.174 14.080 1.706 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCR~ENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 17 RST 1, 2, 3, 4, $ REMARKS: The arithmetic average of passes 1, 2, 3 & 4 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 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 EL~ CODE (HEX) DEPT FT 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC RST CPS 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC RST CPS 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA RSAV CU 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA RSAV CU 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA RSAV CU 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA RSAV CU 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT RSAV 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT RSAV 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNRSAV 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF RSAV 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL RSAV PPK 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF RSAV CU 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI RSAV PU-S 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC RSAV CU 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NI]M~ NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP EL~4 CODE (HEX) SFNC RSAV CU 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM RSAV CU 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG RSAV CU 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 FBBF RSAV UA 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 CRRARSAV 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH RST GAPI 1022552 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10240.000 NBAC.RST 4871.114 FBAC.RST 10132.740 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT.RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV -999.250 SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV -999.250 GRCH. RST -999.250 DEPT. 9852.500 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV -999.250 SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG,RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV -999.250 GRCH.RST 26.327 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 19 FILE HEADER FILE NUFI~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMFIARY VENDOR TOOL CODE START DEPTH ........................... RST 10253.5 $ 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 .......... 9818.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE RST RESERVOIR SAT TOOL $ 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 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): O1 -DEC- 97 8C0-609 2100 O1 -DEC-97 10256.0 10240.0 9900.0 10240.0 1800.0 NO TOOL NUMBER ........... RSCH- A- 100 11055.0 PRODUCED FLUIDS THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 2O BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS THE RAW DATA FOR PASS #1. THIS LOG WAS DEPTH REFERENCED TO A SWS CNL LOG DATED 01 -NOV- 82 ALL INFORMATION WAS PROVIDED BY CO REP. ALL DEPTH CORRELATIONS WITNESSED BY CO REP LOGGED ON SANDSTONE MATRIX DEEPEST DEPTH REACHED ® 10240' DUE TO STICKY BOTTOM $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 364 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 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 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS1 F/HR 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 21 NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) NPHVPS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 AQTMPS1 S 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CPSV PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 C~I2V PS1 V 1022552 00 000 O0 0 6 1 1 4 68 0000000000 RCFR PS1 1022552 O0 000 00 0 6 1 1 4 68 0000000000 RCLC PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 RCAKPS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS1 S 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS1 PSIG 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 BMCU PS1 UA 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 GDCU PS1 MA 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS1 UA 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS1 UA 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS1 UA 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 XPSV PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 X~2V PS1 V 1022552 O0 000 O0 0 6 1 I 4 68 0000000000 RXFR PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 RXAK PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS1 MA 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PS1 PPK 1022552 O0 000 O0 0 6 ~1 1 4 68 0000000000 BSAL SIG PPK 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNPS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS1 CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS1 CPS 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PSi 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 22 NAME SERV UNIT SERVICE API API API API FILE ~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELE~ CODE (HEX) NBAC PS1 CPS 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS1 CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS1 CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS1 CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PS1 CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS1 CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PS1 CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS1 CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS1 CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS1 KHZ 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS1 KHZ 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS1 DEGC 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS1 DEGC 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS1 KV 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS1 AMP 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS1 AMP 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS1 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS1 PU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS1 V 1022552 O0 000 O0 0 6 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 10253.500 NPDE. PS1 1561.319 NSCE. PS1 AQTM. PS1 0.441 CHV. PS1 CM2V. PS1 -12.231 RCFR.PS1 RCAK. PS1 0.000 RTDF. PS1 FSCE. PS1 1.830 FSCR.PS1 HVPV. PS1 160.645 BMCU. PS1 NBEF. PS1 27.292 FBEF. PS1 BSTR.PS1 31.375 BSPR.PS1 CS. PS1 1688 555 TENS.PSI 2 202 0 0 0 33 51 1 561 000 NPHV. PS1 1569.825 500 CRRA.PS1 1 308 CP5V. PS1 5 000 RCLC. PS1 0 000 FPHV. PS1 1523 591 AQTF. PS1 0 105 GDCU. PS1 60 737 NPGF, PS1 1 017 MARC.PSI 0 896 NSCR.PS1 0.446 069 CP2V. PS1 12.202 000 RCRC. PS1 0.000 439 FPDE. PS1 1502. 610 441 SF6P. PS1 167. 472 012 EXCU. PSI 5.129 001 FPGF. PS1 0.998 000 XHV. PS1 201.096 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 23 XP5V. PS1 RXLC. PS1 BSAL. PS1 CIRN. FIL IRAT. PS1 SFFA. PS1 SFFA. SIG SFFA. FIL SFNC. PS1 SIGM. SIG GR. PS1 CTM. PS1 CACU. PS1 TPHI. PS1 5.050 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 115 265 99 6O9 2 539 -999 250 XP2V. PS1 RXRC. PS1 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC. PS1 TRAT. PS1 RDIX. PS1 XTM. PS1 BUST. PSI TPHI.SIG DEPT. 9818.500 CS.PS1 NPDE. PS1 1561.891 NSCE.PS1 AQTM. PS1 0.441 CHV. PS1 CM2V. PS1 -12.172 RCFR.PS1 RCAK. PS1 0.000 RTDF. PS1 FSCE. PS1 1.807 FSCR.PS1 HVPV. PS1 160.889 BMCU. PS1 NBEF. PS1 22.194 FBEF. PS1 BSTR.PS1 51.129 BSPR.PS1 XP5V. PS1 5.039 XP2V. PS1 RXLC. PS1 0.000 RXRC.PS1 BSAL.PS1 63.526 BSAL.SIG CIRN. FIL 0.549 CIRF. FIL IRAT. PS1 0.602 IRAT. FIL SFFA.PS1 36.395 SBNA.PS1 SFFA.SIG 0.840 SBNA.SIG SFFA.FIL 37.562 SBNA.FIL SFNC. PS1 30.703 SFFC. PS1 SIGM. SIG 0.797 TRAT. PS1 GR.PS1 23.205 RDIX. PS1 CTM. PS1 99.609 XTM. PS1 CACU. PS1 2.557 BUST. PSI TPHI.PS1 48.756 TPHI.SIG 12.012 XFI2V. PS1 0.000 RXAK. PS1 -999.250 CIRN. PS1 -999.250 DSIG.PS1 -999.250 NBAC. PS1 -999.250 SBFA.PS1 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. PS1 -999.250 TRAT. SIG 188565.000 CRNI.PS1 98.145 TAV. PS1 3.000 BUSP. PS1 -999.250 CCLC. PS1 1835 108 2 441 203 277 0 000 0 000 0 137 28 460 37 806 1 088 12.025 0.000 2. 740 O. 690 O. 603 65. 291 3. 078 62. 736 34.067 1.324 200632.000 98.703 3.000 1.442 TENS. PS1 CRRA. PS1 CP5V. PS1 RCLC. PS1 FPHV. PS1 AQTF. PS1 GDCU. PS1 NPGF. PS1 MARC. PS1 X~2 V. PS1 RXAK. PS1 CIRN. PS1 DSIG. PS1 NBAC. PS1 SBFA. PS1 SBFA. SIG SBFA. FIL SIGM. PS1 TRAT. SIG CRNI. PS1 TA V. PS1 BUSP. PS1 CCLC. PS1 -12 231 0 000 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 450.310 94.888 3.000 -0.038 957.000 1.703 5.021 0.000 1520.997 0.441 59.871 0.999 0.000 -12.231 0.000 0.563 -2.803 2299.252 57.835 3.305 54.671 34.065 0.032 448.288 94.960 3.OOO -999.250 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS.PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC.PS1 FPDE.PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC.PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT.FIL CRFI.PS1 FICU. PS1 RSXS.PS1 O. 000 38. 698 -999.250 - 999. 250 - 999. 250 -999.250 - 999. 250 -999.250 -999.250 -999. 250 237.542 2.275 8878. 000 1579. 591 O. 181 12.217 O. 000 1504. 632 1 68. 714 7. 045 1. O04 201. 096 O. 000 42. 787 O. 682 3167.101 33. 991 O. 724 33. 645 44. 721 1. 011 1. 328 263.163 2.240 8878. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 24 **** FILE HEADER **** FILE NAFIE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NI]MBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~WIARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10268.5 9842.0 RST $ 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 RST RESERVOIR SAT TOOL $ 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 TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : O1 -DEC-97 8C0-609 2100 O1 -DEC-97 10256.0 10240.0 9900.0 10240.0 1800.0 NO TOOL NUMBER ........... RSCH-A- 100 11055.0 PRODUCED FLUIDS LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 25 WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS THE RAW DATA FOR PASS #2. THIS LOG WAS DEPTH REFERENCED TO A SWS CNL LOG DATED O1 -NOV- 82 ALL INFORMATION WAS PROVIDED BY CO REP. ALL DEPTH CORRELATIONS WITNESSED BY CO REP LOGGED ON SANDSTONE MATRIX DEEPEST DEPTH REACHED @ 10240' DUE TO STICKY BOTTOM $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 364 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 26 TYPE REPR CODE VALUE .............................. 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS2 F/HR 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 NPHVPS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS2 S 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CPSV PS2 V 1022552 O0 000 O0 0 7 i 1 4 68 0000000000 CP2V PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CM2V PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RCAK PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 FPHVPS2 V 1022552 O0 000 O0 0 7 I 1 4 68 0000000000 FPDE PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS2 S 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS2 PSIG 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS2 UA 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS2 MA 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS2 UA 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS2 UA 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS2 UA 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 X~2V PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computin9 Center 27-JAN-1998 00:57 PAGE: 27 NAME SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) SHCUPS2 MA 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS2 PPK 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CIRFPS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1022552 O0 000 O0 0 7 I 1 4 68 0000000000 CIRF FIL 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS2 CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS2 CPS 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS2 CPS 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS2 CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS2 CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS2 CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS2 CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS2 CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS2 CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS2 CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS2 CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS2 KHZ 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS2 KHZ 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS2 DEGC 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS2 DEGC 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS2 KV 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS2 AMP 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS2 . AMP 1022552 O0 000 O0 0 7 1 1 4 68 . 0000000000 BUST PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS2 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS2 PU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS2 V 1022552 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 28 ** DATA ** DEPT. NPDE. PS2 AQTM. PS2 CM2V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR.PS2 XPSV. PS2 RXLC.PS2 BSAL.PS2 CIRN. FIL IRAT. PS2 SFFA.PS2 SFFA.SIG SFFA.FIL SFNC.PS2 SIGM. SIG GR.PS2 CTM. PS2 CACU. PS2 TPHI.PS2 10268.500 1556.932 0.661 -12.211 0.000 1. 903 160. 645 25. 713 35.306 5.040 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 13 561 99 121 2 554 -999.250 CS.PS2 NSCE. PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR.PS2 BMCU. PS2 FBEF. PS2 BSPR.PS2 XP2V. PS2 RXRC. PS2 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS2 SBNA.SIG SBNA.FIL SFFC.PS2 TRAT. PS2 RDIX. PS2 XTM. PS2 BUST. PS2 TPHI.SIG 1642.336 2.462 201.581 0.000 0.000 0.243 30.469 44.156 1.072 12.041 0.000 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 139790 000 98.145 3.000 -999.250 DEPT. 9842.000 CS.PS2 1865.852 NPDE. PS2 1560.060 NSCE. PS2 2.431 AQTM. PS2 1.322 CHV. PS2 201.944 CM2V. PS2 -12.172 RCFR.PS2 0.000 RCAK. PS2 1.000 RTDF. PS2 1.000 FSCE. PS2 1.892 FSCR.PS2 -0.282 HVPV. PS2 160.905 BMCU. PS2 30.840 NBEF. PS2 23.834 FBEF. PS2 39.377 BSTR.PS2 57.352 BSPR.PS2 1.134 XP5V. PS2 5.047 XP2V. PS2 12.037 RXLC. PS2 0.000 RXRC. PS2 0.000 BSAL.PS2 27.060 BSAL.SIG 2.827 CIRN. FIL 0.625 CIRF. FIL 0.770 IRAT. PS2 0.652 IRAT. FIL 0.654 SFFA.PS2 38.288 SBNA.PS2 54.900 SFFA.SIG 1.136 SBNA.SIG 3.248 SFFA.FIL 37.522 SBNA.FIL 54.073 SFNC.PS2 31.436 SFFC. PS2 36.370 SIGM. SIG 0.711 TRAT. PS2 1.238 GR.PS2 , 28.656 RDIX. PS2 151475.000 CTM. PS2 99.609 XTM. PS2 98.731 CACU. PS2 2.559 BUST. PS2 3.000 TPHI.PS2 40.587 TPHI.SIG 1.333 TENS.PS2 CRRA.PS2 CPSV. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 X~2V. PS2 RXAK. PS2 CIRN. PS2 DSIG.PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI. PS2 TA V. PS2 BUSP. PS2 CCLC. PS2 TENS. PS2 CRRA.PS2 CPSV. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 X~2V. PS2 RXAK. PS2 CIRN. PS2 DSIG. PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI . PS2 TA V. PS2 BUSP. PS2 CCLC. PS2 828.000 1.717 5.050 0.000 1513.673 0.661 59.684 1.009 0.000 -12.211 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 446.232 95.175 3.000 0.019 1026.000 1.652 5.065 0.000 1516.114 1.322 60.209 1,001 0.000 -12.236 0.000 0.609 -2.581 2171.123 45.830 4.925 48.351 36.158 0.030 493.503 95.003 3.000 -999.250 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC.PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI~PS2 FICU. PS2 RSXS.PS2 1567.384 0.055 12.217 0.000 1499.139 153.400 5.918 1.009 201.581 0.000 38.048 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 259.850 2.314 8878.000 1567.384 0.100 12.195 1.000 1502.916 159.097 6.260 0.998 201.226 0.000 38.807 0.765 3119.827 33.000 0 715 32 764 31 554 0 999 1 236 298 706 2 248 8878 000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 29 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NA~E : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 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 SUBtLetY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 10230.0 9839.0 RST $ LOG HEADER DATA DATE LOGGED: O1-DEC-97 SOFTWARE VERSION: 8C0- 609 TIME LOGGER ON BOTTOM: 2100 O1-DEC-97 TD DRILLER (FT) : 10256.0 TD LOGGER (FT) : 10240.0 TOP LOG INTERVAL (FT) : 9900.0 BOTTOM LOG INTERVAL (FT) : 10240.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE RST RESERVOIR SAT TOOL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : TOOL NUMBER ........... RSCH-A- 100 11055.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 3O LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REF~RKS: THIS FILE CONTAINS THE RAW DATA FOR PASS #3. THIS LOG WAS DEPTH REFERENCED TO A SWS CNL LOG DATED O1 -NOV- 82 ALL INFORMATION WAS PROVIDED BY CO REP. ALL DEPTH CORRELATIONS WITNESSED BY CO REP LOGGED ON SANDSTONE MATRIX DEEPEST DEPTH REACHED ® 10240' DUE TO STICKY BOTTOM $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 364 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-jAN-1998 00:57 PAGE: 31 TYPE REPR CODE VALUE .............................. 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 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 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CS PS3 F/HR 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 NPHVPS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS3 V 1022552 O0 000 00 0 8 1 1 4 68 0000000000 NSCE PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CRRA PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS3 S 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CHV PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CPSV PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RCFR PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RCAKPS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 FPHVPS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 FPDE PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 FSCR PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS3 S 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS3 PSIG 1022552 - O0 000 O0 0 8 1 1 4 68 0000000000 HVPV PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 BMCU PS3 UA 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 GDCU PS3 MA 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 EXCU PS3 UA 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS3 UA 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS3 UA 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 NPGF PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 32 NA~IE SERV UNIT SERVICE API API API API FILE NUM~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELE~ CODE (HEX) BSPR PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 XHV PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 XP5V PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 XP2V PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 Xbf2V PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RXFR PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RXLC PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RXRC PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RXAK PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS3 MA 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS3 PPK 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL SIG PPK 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNPS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNFIL 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF FIL 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 DSIG PS3 CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS3 CPS 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT FIL 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 NBAC PS3 CPS 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA PS3 CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA PS3 CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA PS3 CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA PS3 CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA SIG CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA SIG CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA SIG CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA SIG CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA FIL CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA FIL CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA FIL CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA FIL CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF PS3 CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SFNC PS3 CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SFFC PS3 CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS3 CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF SIG CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM SIG CU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT SIG 1022552 00. 000 O0 0 8 1 1 4 68 0000000000 TRAT FIL 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RDIX PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CRNI PS3 KHZ 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CRFI PS3 KHZ 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CTM PS3 DEGC 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 XTM PS3 DEGC 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 TAV PS3 KV 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 FICU PS3 AMP 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 33 NA~E SERV UNIT SERVICE API API API API FILE NUM~ NU~IB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUb~ SAMP ELi~q CODE (HEX) CACU PS3 AMP 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 BUST PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 BUSP PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 RSXS PS3 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS3 PU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI SIG PU 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 CCLC PS3 V 1022552 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 10230.000 CS.PS3 1665.125 TENS.PS3 602. NPDE. PS3 1560.823 NSCE. PS3 2.409 CRRA.PS3 1. AQTM. PS3 0.661 CHV. PS3 202.308 CP5V. PS3 5 CM2V. PS3 -12.211 RCFR.PS3 0.000 RCLC. PS3 0 RCAK. PS3 1.000 RTDF. PS3 0.000 FPHV. PS3 1520 FSCE. PS3 1.833 FSCR.PS3 0.562 AQTF. PS3 0 HVPV. PS3 161.621 BMCU. PS3 31.347 GDCU. PS3 59 NBEF. PS3 26.556 FBEF. PS3 46.013 NPGF. PS3 1 BSTR.PS3 40.473 BSPR.PS3 1.071 MARC. PS3 0 XP5V. PS3 5.050 XP2V. PS3 12.056 X~2V. PS3 -12 RXLC. PS3 0.000 RXRC. PS3 0.000 RXAK. PS3 0 BSAL.PS3 -999.250 BSAL.SIG -999.250 CIRN. PS3 -999 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS3 -999 IRAT. PS3 -999.250 IRAT. FIL -999.250 NBAC. PS3 -999 SFFA.PS3 -999.250 SBNA.PS3 -999.250 SBFA.PS3 -999 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999 SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999 SFNC.PS3 -999.250 SFFC. PS3 -999.250 SIGM. PS3 -999 SIGM. SIG -999.250 TRAT. PS3 -999.250 TRAT. SIG -999 GR.PS3 237.311 RDIX. PS3 157268.000 CRNI.PS3 447 CTM. PS3 99.609 XTM. PS3 99.609 TAV. PS3 94 CACU. PS3 2.549 BUST. PS3 3.000 BUSP. PS3 3 TPHI.PS3 -999.250 TPHI.SIG -999.250 CCLC. PS3 0 DEPT. 9839.000 CS. PS3 1807.917 TENS.PS3 971 NPDE. PS3 1560.174 NSCE. PS3 2.408 CRRA.PS3 1 AQTM. PS3 1.322 CHV. PS3 201.702 CPSV. PS3 5 CM2V. PS3 -12.142 RCFR.PS3 0.000 RCLC. PS3 0 RCAK. PS3 0.000 RTDF. PS3 0.000 FPHV. PS3 1518 FSCE. PS3 1.866 FSCR.PS8 -0.197 AQTF. PS3 1 HVPV. PS3 160.872 BMCU. PS3 29.765 GDCU. PS3 60 NBEF. PS3 23.176 FBEF. PS3 39.216 NPGF. PS3 1 BSTR.PS3 57.085 BSPR.PS3 1.161 MARC. PS3 0 XPSV. PS3 5.042 XP2V. PS3 12.038 X~2V. PS3 -12 RXLC. PS3 0,000 RXRC. PS3 0.000 RXAK. PS3 O. BSAL~PS3 28.198 BSAL.SIG 2.765 CIRN. PS3 O. CIRN. FIL 0.687 CIRF. FIL 0.886 DSIG.PS3 -2. IRAT. PS3 0.655 IRAT. FIL 0.658 NBAC. PS3 2310. SFFA.PS3 35.310 SBNA.PS3 48.055 SBFA.PS3 45. 000 NPHV. PS3 733 NSCR.PS3 030 CP2V. PS3 000 RCRC. PS3 997 FPDE. PS3 661 SF6P. PS3 356 EXCU. PS3 002 FPGF. PS3 000 XHV. PS3 231 RXFR.PS3 000 SHCU. PS3 250 CIRF. PS3 250 FBAC. PS3 250 SFNA.PS3 250 SFNA.SIG 250 SFNA.FIL 250 SIBF. PS3 250 SIBF. SIG 250 TRAT. FIL 253 CRFI.PS3 888 FICU. PS3 000 RSXS. PS3 019 000 692 065 000 556 322 296 000 000 225 000 670 397 695 812 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P. PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG 1569. 825 0.231 12.217 0.000 1503. 717 161. 331 5. 918 1. 002 201 096 0 000 39 024 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 25O 258 128 2 256 8878 000 1571. 046 - O. 752 12. 224 O. 000 1504.594 163. 890 6. 602 O. 999 201. 484 0.000 40.194 O. 871 3140. 642 32. 000 1. 037 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 34 SFFA.SIG 0.715 SBNA.SIG 4.925 SBFA.SIG SFFA.FIL 34.112 SBNA.FIL 50.566 SBFA.FIL SFNC. PS3 29.692 SFFC. PS3 32.286 SIGM. PS3 SIGM. SIG 0.651 TRAT. PS3 1.202 TRAT. SIG GR.PS3 26.689 RDIX. PS3 168230.000 CRNI.PS3 CTM. PS3 99.854 XTM. PS3 98.828 TAV. PS3 CACU. PS3 2.553 BUST. PS3 3.000 BUSP. PS3 TPHI.PS3 39.033 TPHI.SIG 1.181 CCLC. PS3 3.329 SFNA.FIL 45.870 SIBF. PS3 32.451 SIBF. SIG 0.026 TRAT. FIL 503.093 CRFI.PS3 94.984 FICU. PS3 3.000 RSXS. PS3 -999.250 31.561 31.956 0.978 1.197 297.322 2.249 8878.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 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 SD?4FIARY VENDOR TOOL CODE START DEPTH RST 10232.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): STOP DEPTH 9842.5 O1 -DEC-97 8C0- 609 2100 O1 -DEC-97 10256.0 10240.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 35 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 9900.0 10240.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE RST RESERVOIR SAT TOOL $ TOOL NUMBER ........... RSCH-A-iO0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 11055.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS THE RAW DATA FOR PASS #4. THIS LOG WAS DEPTH REFERENCED TO A SWS CNL LOG DATED O1 -NOV- 82 ALL INFORMATION WAS PROVIDED BY CO REP. ALL DEPTH CORRELATIONS WITNESSED BY CO REP LOGGED ON SANDSTONE MATRIX DEEPEST DEPTH REACHED @ 10240' DUE TO STICKY BOTTOM $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 36 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 364 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 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 EL~ CODE (HEX) DEPT FT 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CS PS4 F/HR 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS4 LB 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 NPHV PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 NSCE PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CRRA PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 NSCR PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMPS4 S 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CHV PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CPSV PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V PS4 V 1022552 O0 000 O0 0 9 1 I 4 68 0000000000 CM2V PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 RCFR PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC PS4 1022552 O0 000 O0 ~ 9 1 1 4 68 0000000000 RCRC PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 RCAK PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 RTDF PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 FPHVPS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 FSCR PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF PS4 S 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SF6P PS4 PSIG 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 37 NAM~ SERV UNIT SERVICE API API API API FILE NUMIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... HVPV PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU PS4 UA 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 GDCU PS4 MA 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 EXCUPS4 UA 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF PS4 UA 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF PS4 UA 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 NPGF PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 BSPR PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 MARC PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 XHV PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 XPSV PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 X~2V PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 RXFR PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 RXLC PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 RXAKPS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SHCU PS4 MA 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL PS4 PPK 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL SIG PPK 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNPS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNFIL 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FIL 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG PS4 CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS4 CPS 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FIL 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC PS4 CPS 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA PS4 CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA PS4 CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA PS4 CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA PS4 CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA SIG CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA SIG CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA SIG CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA SIG CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FIL CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FIL CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FIL CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FIL CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF PS4 CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SFNC PS4 CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SFFC PS4 CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS4 CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF SIG CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM SIG CU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT SIG 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 38 NAM~ SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMIB SAMP ELE~ CODE (HEX) TRAT FIL 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 RDIX PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CRNI PS4 KHZ 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CRFI PS4 K~Z 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CTM PS4 DEGC 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 XTM PS4 DEGC 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 TAV PS4 KV 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 FICU PS4 AMP 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CACU PS4 AMP 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 BUST PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 BUSP PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 RSXS PS4 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS4 PU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI SIG PU 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 CCLC PS4 V 1022552 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 10232.000 CS. PS4 NPDE. PS4 1560.784 NSCE. PS4 AQTM. PS4 0.661 CHV. PS4 CM2V. PS4 -12.231 RCFR.PS4 RCAK. PS4 0.000 RTDF. PS4 FSCE. PS4 1.963 FSCR.PS4 HVPV. PS4 160.889 BMCU. PS4 NBEF. PS4 25.962 FBEF. PS4 BSTR.PS4 40.965 BSPR.PS4 XPSV. PS4 5.050 XP2V. PS4 RXLC. PS4 0.000 RXRC. PS4 BSAL.PS4 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS4 -999.250 IRAT. FIL SFFA.PS4 -999.250 SBNA.PS4 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC. PS4 -999.250 SFFC. PS4 SIGM. SIG -999.250 TRAT. PS4 GR.PS4 128.826 RDIX. PS4 CTM. PS4 99.121 XTM. PS4 CACU. PS4 2.544 BUST. PS4 TPHI.PS4 -999.250 TPHI.SIG 1762 978 2 476 202 550 0 000 0 000 0 100 30 761 45 023 1.088 12.027 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 173697,000 98.633 3.000 -999.250 DEPT. 9842.500 CS.PS4 1841.916 NPDE. PS4 1560.899 NSCE. PS4 2.441 AQTM. PS4 1.322 CHV. PS4 202.308 CM2V. PS4 -12.182 RCFR. PS4 0.000 RCAK. PS4 0.000 RTDF. PS4 0.000 FSCE. PS4 1.881 FSCR.PS4 0.170 TENS.PS4 CRRA.PS4 CPSV. PS4 RCLC. PS4 FPHV. PS4 AQTF. PS4 GDCU. PS4 NPGF. PS4 MARC. PS4 X~2V. PS4 RXAK. PS4 CIRN. PS4 DSIG.PS4 NBAC. PS4 SBFA.PS4 SBFA.SIG SBFA.FIL SIGM. PS4 TRAT. SIG CRNI.PS4 TAV. PS4 BUSP. PS4 CCLC. PS4 TENS.PS4 CRRA.PS4 CP5V. PS4 RCLC. PS4 FPHV. PS4 AQTF. PS4 784 000 1 734 5 060 0 000 1530 763 0 661 59 684 1 001 0 000 -12 191 0 000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 448.733 95.031 3.000 0.105 NPHV. PS4 NSCR.PS4 CP2V. PS4 RCRC. PS4 FPDE. PS4 SF6P.PS4 EXCU. PS4 FPGF. PS4 XHV. PS4 RXFR.PS4 SHCU. PS4 CIRF. PS4 FBAC. PS4 SFNA.PS4 SFNA.SIG SFNA.FIL SIBF. PS4 SIBF. SIG TRAT. FIL CRFI.PS4 FICU. PS4 RSXS.PS4 1011.000 NPHV. PS4 1.522 NSCR.PS4 5.055 CP2V. PS4 0.000 RCRC. PS4 1519.777 FPDE. PS4 1.322 SF6P. PS4 1567.384 0.050 12.187 0.000 1505.357 165.169 5.523 0.998 200.854 0.000 39.349 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 258.757 2.290 8878.000 1567.384 0.007 12.195 0.000 1505.891 166.755 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-JAN-1998 00:57 PAGE: 39 HVPV. PS4 161.019 BMCU. PS4 NBEF. PS4 26.155 FBEF. PS4 BSTR.PS4 59.750 BSPR.PS4 XP5V. PS4 5.043 XP2V. PS4 RXLC. PS4 0.000 RXRC. PS4 BSAL.PS4 33.551 BSAL.SIG CIRN. FIL 0.613 CIRF. FIL IRAT. PS4 0.648 IRAT. FIL SFFA.PS4 37.944 SBNA.PS4 SFFA.SIG 0.901 SBNA.SIG SFFA.FIL 37.288 SBNA.FIL SFNC. PS4 32.037 SFFC.PS4 SIGM. SIG 0.698 TRAT. PS4 GR.PS4 31.118 RDIX. PS4 CTM. PS4 99.365 XTM. PS4 CACU. PS4 2.559 BUST. PS4 TPHI.PS4 38.900 TPHI.SIG 31.992 GDCU. PS4 39.810 NPGF. PS4 1.155 MARC. PS4 12.031 X~2V. PS4 0.000 RXAK. PS4 2.810 CIRN. PS4 0.797 DSIG.PS4 0.652 NBAC. PS4 53.608 SBFA.PS4 4.180 SBFA.SIG 53.861 SBFA.FIL 35.691 SIGM. PS4 1.202 TRAT. SIG 184617. 000 CRNI. PS4 98. 926 TAV. PS4 3. 000 BUSP. PS4 1.266 CCLC. PS4 59.990 EXCU. PS4 0.996 FPGF. PS4 0.000 XHV. PS4 -12.231 RXFR.PS4 0.000 SHCU. PS4 0.582 CIRF. PS4 -2.105 FBAC. PS4 2439.673 SFNA.PS4 47.083 SFNA.SIG 3.776 SFNA.FIL 50.813 SIBF. PS4 35.433 SIBF. SIG 0.028 TRAT. FIL 452.273 CRFI.PS4 94.993 FICU. PS4 3.000 RSXS.PS4 -999.250 5.629 1.005 201.161 0.000 39.587 0.779 3149.483 33.562 0.937 33.864 33.856 1.000 1.199 297.139 2.257 8878. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/01/27 ORIGIN : FLIC TAPE NAME : 97569 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA, INC., D.S. 13-05, PRUDHOE BAY, API# 50-029-20626-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/01/27 ORIGIN : FLIC REEL NAME : 97569 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., D.S. 13-05, PRUDHOE BAY, API# 50-029-20626-00 ~m~mmm~mm~m~m~mmmmm~ L%S T~PE V~I~"IC~TIO~ R%GIN :0000 APE; NA~i~ :q151 O~T~N~AT~ON ~ :01 R~V TD!)S T~P~ O~IF. iNq'S :I:,I~R~RY TRPE ** RECOPD TYPE 137 ** ILE N ~,h~E :~DIT ,OO1 E~VICF ~A~E : ERSION ~ : ATE : AXI~UM LENGTH : 1024 RE'V I UIIS F' I I.,~E , 1NFOR~ATIDN RECORDS N : ARCO ALASKA INC N : 13-5 N : PRtIDHOE F~AY ANG: 1. 4F', ECT: 1 3 ,TAT: A I.,,~SK A UNIT TYPE CATE SIZE CODE 000 000 016 065 000 000 004 065 000 000 012 065 000 000 004 065 000 000 004 065 000 000 002 065 000 000 008 06,5 000 000 006 065 000 000 004 065 /P 010.H02 v~!,.:Pll~'ICAg~Inq L!STIN(; PAGE 2 ****************************************************************************** SCHbU~ERG?R * ***************************************************************************** 3~PANY -- ATLANTIC RICHFIELD CO~P~NY {T.,L = DS 1.3'5 IELD : PRLIDHOE BAY DIINTY = NORTH SLOPE thT~ = At, ASKA, DR NU~FR AT ACC: 69151 d~ ~2, DATE LOGGED: 21 APR DP: J. KOHRING ASI, NG : 9,625" SURFACE 'rD 4850' ASI~O(; = 7,000" 1.1,050' TD 9547' YDE F~,il].(D = CRUD~ OIL (WELL FLOWING) ******************************************************************************* NOTH; ~ DATA DEPTH ~HIFTED TO S~JNIC G,A;~A RAY AS PER CLIEh]T'S REQUEST * PASSi GA~A RAY FRO~ 10246' TO 10232' INVALID - SEE FIELD PRINT ****************************************************************************** SC~L~I{4~E~GE~ LnGS ~NCLi,{DwD '~,,VITH THIS ~CNETIC T~PE: PAY LOG (GR) ~ DAT~ F'U~T RECnRD ** ~TR¥ TYPE 4 1 66 1 8 4 73 60 9 4 65 .1 IN 0 1 66 0 ~TI,I,H SPEC!FICATIOM BL[~CKS NEN SERVICE SERVICE UNJiT API API API /%Pl FILE SIZE PROCESS SAg'PLE REPR ID (')P, OMR ~ L~G TYPE Cb.ASS ~OD NO. EPT FT 0 0 0 0 0 4 IGM PSi CU 0 40 I 0 0 4 SIG PSI CU 0 0 0 0 0 4 R~T PS~ 0 42 1 0 0 4 R PSi. GAPI 0 3] 32 0 0 4 AC~ PS 1 CPS 0 O 0 0 0 4 BAC PS 1 CPS 0 0 0 0 0 4 TDT PS ~ CPS 0 n 0 0 0 4 TDT PS~ CPS 0 0 0 0 0 4 IC~ PS~ CU 0 40 I 0 0 4 S l G P S 2 C U 0 0 o 0 0 4 RAT PS~ 0 4~ I 0 0 4 R PS~ gAPI 0 3t 32 0 0 4 AC5 PS2 CPS 0 0 0 0 0 4 BAC PS2 CPS 0 0 0 0 0 4 TDT PS~ cPS 0 0 0 0 O 4 bEVEL CODE 0 1 68 0 ! 6~ 0 1 68 0 ~ 68 0 1 68 0 1 6 R 0 1 68 0 ~ 68 0 1 68 0 1 6~ ~ 1, 68 0 I 6~ 0 1 6~ 0 I 6n 0 1 68 0 1 6~ FP r).l.O,H()~ VF. RIFIF, ATION i,!S~rl~!(; PAGE 4 [C,M PS ~ CU 0 40 1 0 0 ~T PS3 0 42 1 0 0 ~ PS3 GAPI 0 31 32 0 0 k C K ~ S 3 C P S o 0 0 0 0 3hC PS3 CPS 0 0 0 0 O PDT PS~ CPS 0 0 0 0 0 ~DT DS3 CPS 0 O 0 0 0 [Ct~ PS ,4 Cd 0 40 1 0 ~ ~IG PS4 CU 0 0 0 0 0 ~gT PS4 0 42 1 0 0 ~ PS4 CAOI 0 31 32 0 O ~Cg PS4 CPS 0 0 0 0 0 ~C ~Sa CPS 0 0 0 0 0 FDT PS4 CPS 0 0 0 0 0 [~Y PS~ CU 0 40 1 0 0 ~IG PS5 CB 0 0 0 0 0 ~AT PS5 0 42 I 0 0 R PS5 GAPI 0 31 32 0 0 ~CK PS5 CPS 0 0 0 0 0 3AC PS5 CPS 0 0 0 0 0 rOT PS5 CPS 0 0 0 0 0 I'DT PS5 CPS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 * D ~ T,A EPT R R TOT R TO 'r' R TOT R T D 'l" EPT R TOT R T D T R TOT TDT R TDT E P T 10581 nooo -o99,2500 -099.2500 -99q.2500 o99,7500 299~.~5oo -990.~5no -o90,2500 -g9q,250(.) -09q,2500 -090.25n0 10500.0000 1.3 4531. 148 2500 47 3770 176 ~969 60 3438 156 5000 6~ ¢2941 ~4~ ~37b 76.1709 1 0~0¢l, oOOO SI~ BACK BACK SIC~ BACK Sign BACK SlC~ BACK SIC~ BACK SIC~ RACK BACK SIaM BACK BACK -999,2500 FSTG -a99,2500 FBAC -~99,2500 P$1. G -999,~500 FBAC -09q.2500 FSIG -999.2500 FB~C - qc99, , ~500 FSI(; -999,2500 FB~.C -~9~,2500 FSI'G -999.2500 FBAC 1,7 , 53 1 3 FSI'G 61. 0938 FB~C 18,3036 FSIG 1.7 ,62508 FBAC .~, 7500 FSIG I. .8750 F~C 1,~.6367 PSTG 18,1141 F'SIG 210,3047 PBIC 30.1250 FSTG -999.2500 -999.2500 -999.2500 -999.2500 -099.2500 -999.2500 :999. soo 99,2500 -090.2500 -099.2500 1~.1484 2.,6563 ~5 2358 6218828 15,4063 75.81~5 14 9336 8211125 ~5,44q0 82,I875 36.4063 mRAT NTDT TRhT NTDT TRAT NTDT TRAT NTDT TRhT NTDT TROT NTDT TR.AT NTDT TR~,T NTDT TRAT NTDT TRAT MTDT TR.gT -099 2500 -999 2500 -099 2500 -999 2500 -999 2500 -999 2500 -q99 2500 -~99 2500 -999 ~500 -ggg ~500 2 ~434 159 000 2: ~7oo 195 172 2 4~60 176 6250 2 3588 169 67~9 2 4387 ~94 5781 3809 L"I~ i'I 111 iil ilq ii! [:-I I (' tP o1~,~.~02 vE,~IglCA~In~,~ LTSTING PA~E 5 5a,~313 BACK 143,0000 78.319.5 RACK !53,9750 84,0625 .hACK 160.1 250 S.I C~z 102,56~5 RACK 159 ~250 SIa~ ~.o~o9~ ~c{ !7n,~2~9 10300,0000 SiG;~ 14.6172 .!84,1250 SIGa 29.q531 BACK 195,~750 $ I C.~i 44,6465 RACK 52,8125 !90,7500 SIGN 64,~9~0 RACK 178,~031 O~OO, nooo 22. 7656 RACK ?65 oOOO 39!4336 RACK 960 2969 SIGN 5a,1328 ~ACK ~73. 6004 66.4307 RACK ~54.7198 77.9548 BACK 01 oo O0 66 z~3 199 75 85 ~2 ~27 50 ~1.01 O0 190 ~7 11~.25 2.10,~5 117,32 198.60 00 S I C N 75 RACK O0 50 ~ACK O0 RACK 50 SlCN O0 RACK O0 03 ~ACK o4 RACK r~ACK B.A CK S 84,8750 39 4063 175~750 41,3438 ~02,6250 39,6875 21.9,2500 42 4297 2i7~0000 17,96R7 109.~125 lR,2031 185.6250 17 1.333 200:8945 18 0625 ~1.0~1250 16 q473 1B.1562 1.36,3125 In 7026 !.8315859 1~.5,4~5 198,6250 1a,0339 ~01.3750 1~ ~242 221~ 557 21.,1719 1.44,,3750 22 ~875 190 000 22 0781 206 2500 22 3125 217 ~250 21.7148 22~.3750 -99~ 2500 -999 2500 23 ~375 ~0,4 25O -999 2500 -999 2500 -g99 2500 FSTG FBAC FBAC FBAC F$IG FBAC FSIG FBAC FBAC FSIG FSIG FBAC F'SIG FBAC FBAC FBAC FSIG FBAC FSI(; FRAe' FST(; FBAC FS~G FBAC FSIG FBAC FBAC FSTG ma.AC wSlG F'BaC FSIG 35,9375 38.0313 68,5625 37,9062 80,6250 36,5000 82.3125 38.2734 89,6484 15,0156 35,1875 15.1641 61,7500 1.5,5439 76,5625 1..4.9531 74.9375 14,8428 78,3164 15,8789 51,28!3 15,432'1 69,111.3 15.9121 83.8242 15,6084 81.6992 15,2627 86,0977 18,1'119 60~0625 1~,.4688 79,6875 ~0, 50~ '0625 18,5361 97,24~2 -999,250o -999,2500 1~,4688 g ,.3125 -~99,2500 -999 ~500 -999~ 500 NTDT TRA~ ,~. NTDT NTDT TRAT ~TOT TRAT NTDT TRAT NTDT TRAT NTDT TRAT NTDT mRAT t~TDT TRAT NTDT TRAT NTDT TRAT NTDT TRAT NTDT TROT NTDT TRAT NTDT TRAT NTDT TRAT NTDT TRAT NTDT TRAT NTDT mR~T NTDT TRAT NTDT TRAT NTDT TRAT NTDT TROT 232.0000 3,2051 237.750O 3.3301 249.5000 3,3691 237.7500 3 6733 265~06~5 2 3184 191!6250 2 32~3 221 5000 2}2010 196 8594 2 3184 210,2500 2.3230 1.98,3359 2,4561 274.2500 2,4515 305,6895 2,5712 311,2187 2,~652 272,.062 2,4393 308,21~7 2 7520 232 6250 2 7656 279 7500 2 9199 252 3750 2 7188 273 2500 2 95]0 254 000 -099 2500 -qgg 250O 2 ~723 325 500 -999 ~50o -999 500 -999 ~500 IP 010,t'!02 VF~r,'iFICATIf~i~! LISTIMG PAGE 6 -q99.2500 n~CK -999,2500 SICM -999,7500 BACK -99q.2500 -q99.2500 FS~G -990.2500 MBAC ** RECORD TYPE 137 ** -999.2500 ~TPT -999.2500 TRAT -999.~500 MTDT -999.2500 -999.2500 -q99.2500 * TAPR TRAILER ** ERVTC~i b~A~E :F~DTT ATE :94/05/ 8 RIGI~ :0000 APE ~E :91.51 OMTI~!!tATIO~ ~ KXT TAP~ ~!A~E : OM~F'NU'S :LIBRARY TAPE * REEL TNAILE~ ** F,,RV T CF, MA~E : F, DI' T ATE : :~4/05/ 8 EEL NA~ :2240~5 EXT RFEL Ma~E ; ** RECO~D TYPE 137 ** RECORD TYPE 137 ** EOF EOF ********** ~ .... $CHbU~BERGER .... * his TA E VERIFICATION LIMTING bVP OiOoHO1 YE~RIFICATIOa I.,ISTING p,L\G~: ** REEL ~EADER ~* SERVICE NA~K :SERVIC DATE :82/11/ 3 ORIGIN ~ REEL NA~E : ee ee CONTINUATION ~ :01 PREVIObS REEL : CON~ENTS :LIBRARY TAPE ** TAPE HEADER SERWICE NA~E :$ER~IC DATE :82/11/ ORIGIN TAPE ~A~f; : CONTINDATION # PREVIOUS TAPE : COMMENTS :LIBRARY TAPE EOF ** FILE HEADER ** FI.bE NA~E :$ERVIC,O01 SERVICE NAME : VERSION # DATE : MAXIMUM LENGTH : ~024 FILE TYPE ** INFORMATION R~,;CORD$ ** CONTENTS CN : ATLANTIC RiCH~IEb[,) CO~PAg~ wN : l)$ 13-5 FN RAN(; T 0 W N: ~ 0 N 8ECTI 13 COON: N{,R~,H Sb:O:~, "~ ~ ' $ "t A T . A .L, A S CTRY: U, , A MNE~ CONTENTS : PRES: CNLO0 1E ** COMMENTS ** U Iq I T T Y P C C A T E S I Z E C [) D K 000 000 026 065 000 000 008 065 000 00 0 012 065 000 o 00 00 3 0 ~ 5 000 ()00 003 0~.~5 000 00o 002 065 0 O0 000 01,2 ub5 0()0 0 (,)(,, C, 06 065 0 00 o 00 00 ~ 065 0 O 0 000 007 065 LYP OlO,HOl YEalFiCATI, i"!',~i t'.,I$'1'~{',~(1 i?AC~:, 2 SCHUUh~BERG~R ALASKA CO!',POTI!',,tG CENTER COMPANY : ATLAi~TIC RICHFI, ELI,~ WELL : L).S, 13'5 FIELD = P~UOHOE BAY COUNI'Y = NORTH SLOPE S~'ATE : AUASKA JOB NUMBER AT ACC: 66016 RUN ~3 DATE LOGGED: 1 NOV CASING CASING TUBING TIlL TYPE FLUID BIT SIZE = 9 5/~" 9~50 FT Tr3 .,.SURFACE = 7" 11050 FT TO 9547 = 5 1/2" -- 4 1/2" 9571 = C~,t)DE -- 8 1/2" 11055 FT TU 9850 FT MATRIX SANDSTONE bYk OlO.HO1 VERIFIC~,TIO~'.; LISTING PA(;F 3 * CU~PENSA'I'ED NLUTRON LOG - CASED HOb~] (CNL) ~ ** DATA F'OR~AT RECORD ENTRY BLOCKS TYPE SIZE gE'PR CODE 6]NI'R¥ 4 1 6~ 1 ~ 4 73 60 9 4 ~5 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API APi AP1 AP1 F'IbE $IZf] PROC~iS~S SAMPh~i Rb]PR ID ORDER # LOG TYPE CLASS ~OD NO. DEPT FT 0 0 0 0 0 4 NPHI PSI Pi) 0 68 2 0 0 4 NRAT PSI o ~2 1 0 0 ~ RNRA PS1 0 0 0 0 0 4 NCNb PS1 0 34 92 0 0 4 FCN[, PSI 0 ~4 q~ 0 0 4 GR PS 1 GAP I 0 31 32 0 0 ~ NRAT P82 0 ~ 42 I 0 0 4 R~A PS2 0 o 0 0 o 4 ~,CN 0 34 92 0 ~CNb~ P~2 0 4 P S 2 0 3 4 93 0 0 4 GR PS2 GAP I O 31. 3:2:0 0 4 DATA LVP 0.10,H01 YER]:FiCA?I[.)i'~ LISTING DEPT 1 ! 065. 5000 NPHI NCNb -999.2500 FCNL NRAT ,3,2815 Ri,iRA GR 64.b8'/5 DgPT 11'000.0000 NPHI NCNb 135~, 0000 FCNL NRAT ~ ~8594 RNRA 71,25U0 DEPT 10900,0000 NPHI NCNL 1875.0000 f'CNL NRAT 2.~789 RN~A GR 31.3438 DEPT 10800.0000 NPHI NChb 1776,0000 FCNb NRAT 2,9434 HN~A GR 19,~375 DEPT 10700,0000 NPHI NCNb 1700.0000 FCNL NRAT 2,~926 RNRA GR 17,3750 DEPT 10600,0000 NPHI NCNb 1510,0000 FCN'5 NRAT 3,0020 RaRA GR 19,1562 DEPT 10500,0000 NPHI NCNb 1779,0000 FCNL NRAT ~,6~84 RN~:A GR ~3.~516 I)EPT NCNb NRAT GR DEPT NCNb NRAT GR DE, P NCNb N'RAT NCNb NRAT GR -999,2500 mRAT -999.2500 ~;~ 3.4297 mCNL. 27 BB09 NRAT 425~7500 GR 2.8789 i~CNL 20.752U NRAT 681,0000 GR 3,1055 NCNb 27,8320 NRAT 5~7,U000 GR 2,9492 NCNL 32,8125 NRAT 504,2500 GR ~,lu02 NCNb 29.443g NRAT 45i, 7500 GR ,0781 NCNI.., 23,0459 NRAT b16.0OO0 GR 2 ,';'793 NCNb 10400,0000 NPHI 1270,OOOOFCN~ 3,~109 RNR 75, 500 33,3008 NRA'~ 3:6~,b000 G~ .2227 NCNL 1:0300,0000 NP:H1 oooo .3'125 ' 2, '7012 [,iC Nb -999,25U0 -999.2500 2.93!6 64;0000 1370,0{~00 2.5332 27'9~44 1927,0000 2,9.277 17,21.87 1683.0000 3,2031 1,4..,9922 161B,OO00 3.0176 17,3125 609 . 0000 2.6680 11. 5469 1888,000O 7:2305 3125 1308.0000 2 5234 15" ,9375 1661o0000 1B,2187 2940.0000 6 ,3750 327'0,0000 R ,~RA ,'~ P H I Ir' C l~ b R~,~RA a P Id I ~' C ~'~ L RNRA N PH 1 t;'C N L RNRA N P ~ I ~ N R A FCNL R N R A N PHI F C N L NRA p H I, FCNI., R N R A aPHI ~' CN b F C N L, R ,N R A N P H I F C N L, -99~,250U 34,2285 3.t738 2.7520 26.9043 b2U,5000 2~.0762 5'/0.5000 3.3711 2 't. 148 bl iL. 'lbOu 3.32U3 29,1504 522.5000 2,~867 22,7051 3.4648 405.7500 2.b035 19,0430 bgg,50UO 3,0977 2~,~11..3 2, "/2 1, 7" 72 121,2, bVP O!O,HO~ YERIFICA'I~10~ L;IiST]'i~,G PAGF OEPT 10000 0000 N'PHI NCNL 2924,0000 FCNL ~RAT 2,6113 DEPT 9900,0000 NPH[ NCNL 1725.0000 FCi~B NRAT 3 9746 RNRA GR 80~7500 DEPT 9589,0000 NPHI NCNL 1675,0000 ECNh NRAT -999.2500 RNRA. GR -999,2500 · 21,6797 !~RAT 1042,0000 GR 2,7383 NCNL .~2.0'158 r~RAT 473,2500 GR 4,1602 NCNb 47,7539 ~;RAT 385,5000 GR -999,2500 2.5~98 70.5625 2922.0000 3,7441 72.0625 1.743,0000 4.0195 77,7500 -999,2500 R ~'~ RA ~PHI R iv, R A {~ P H 1 F C I~ L, 2.~047 22.0215 46.u750 4.3320 -999,2500 ** FILE TRAILER ** FILE NAME :$ERVIC,001 SERVICE NAME : VERSION # : DATE ~ MAXI~ltN LENGTN : 1024 FILE TYPE : NEXT FILE NAME : ** TA.P~. TRAILER ** SERVICE: NAME :8ER'VIC DATE :82/11/ 3 ~fA. PE NAgE : CONTINUATION NEXT TAPE NA~E CO~ENTS ~LIMRARY TAP~ REEL TRAILER :MERVIC 3 CON!ZN . ]ON ! COMMENT8 :'~ I'1111 ii1 ilq i[,__ [:] ~ ~mmmmmmmmmmmmmmmmmmmm~ LiS TAPE V ER I ~'I CA~I:'I. ON LISTING tP 009~H03 VERIFiCATiON LISTING PAGE 1 REEL HEADER fRVICE NAME :S~RVIC %TE :81/U8t20 {IGIN : ']EL ~AME :REEL ID )NTiNUATIO~ ~ :01 ~EVIOUS REEL : ]M~ENTS :REEL CDM~ENT.S TAPE H~;AUER ~* ~RVICE NAME : SEP, gIC %TE :81/08/26 ~IGIN :1070 ~PE NAME :62123 3NTINUATION ~ :01 REVIOUS TAPE : ~MMENTS :TAPE CO~MENTS FILE HEADER ILE NAME :SERVIC.O01 ERVlCE NAM~ : ERSION ~ ~TE : AXIMUM LENGTH : ~024 ILE TYPE : REVIOU& FILE INFORMATION RECORDS CONTENTS N : ATLANTIC RICHFIELD CO. N : 13-5 N : PRUDHOE BAY ANG: ~4 E DW~: 10 N ECT: ~3 OUN: N. SLOPE TAT: ALASKA ~R¥~: U.S.A. CONTENTS RE~: NEDiT4F RECORD TYPE 047 RECORD TYPE 047 UNIT TYPE CATE SIZE CODE 000 000 022 065 000 000 004 065 000 000 012 065 000 000 004 065 000 000 004 065 000 000 002 065 000 000 008 065 000 000 006 065 000 000 006 065 UNIT T¥'PE CATE SIZE CODE 000 000 0O7 O65 ~P 009.H()3 YkRIBICATION LISTING PAGE 2 RECORD TYPE 047 ** ~ COMMENTS ~TE LOGGED : 09-AUG-81 , ~SING DRiL~EH : 9850 IT SIZE : 8.5 ~UiD T'~PE : L!G~OSU[.~ONATE ;iNS. : 9.9 [SC. : ~2 ~ : 10.8 bUID LOSS : ~ ~ MEAS. TEMP. ~F ~ ~AS. TE~iP. ~C $ ~EAS. TEMP. ~TRIX : SANDSTONE RUN NO. : ONE 1.96 [~ 72 F 1.80 ¢~ 68 F 2.60 ~: 68 F 0.778 ~ 192 F DATA FOR~iAT RECORD ~TR¥ BLOCKS TYPE SIZE REPR CODE ENTRY 4 1 ~6 ~ 4 73 60 9 4 65 .1I~ 0 1 66 0 ATOM SPECIFICATION BLOCKS NE~ SERVICE SERVICE UNIT AP1 AP1 AP1 AP1 FI~E SIZE PROCESS SAMPLE RgBR iD ORDER # LOG TYPE CLASS ~OD NO, LEVEL CODE EPT FLU 5M ISN w~' OH~t~ 0 0 0 0 0 4 0 1 LD P R, DIL GAPi 7 31 32 0 0 T ISN PHI ISN PO 0 68 2 0 0 4 0 1 HO~ R FDN ........ GAPI 42 31 32 0 0 4 0 1 ~I ISN 1~ 0 28 3 0 0 4 0 1 68 68 68 68 68 68 68 ~8 68 68 68 /F 2NL 009;H03 IbN VERIFiCATiON G/C3 ~ bA~A ~AT ::PT RAT EPT RAT EPT P RAT EPT P RAT EPT P HOS RAT EPT P RAT EPT P HOB RAT P 11060.500 SFLU -999.250 GR 2.629 GR 2,770 NCNb i1000,000 SFGU -4.3&3 GR 2,670 GR 2.57& NCNL 10900,000 SFLU -56,906 GR 2.352 G~ 2.330 NCNL 10800.000 SFLU -59.125 GR 2,293 G~ 2.506 NCNb 10700.000 SFLU -71,625 GR 2.248 GR 2,535 NCNL 10600.000 SFLU -64.875 GR 2.24~ G~ 2.443 NCN6 10500.000 SFLU -75,686 GR 2.320 GR 2.145 ,NCNb i0~00.000 SFbU -25.141 GR 2,u97 GR 2.734 NCNL 10300,000 SFLU -96.I88 GR 2.338 GR 2.578 NCN5 10200.000 SFbU -106.000 GR G~$TING 44 ~2 34 34 0 1 92 93 -999.250 -999.250 -999.250 2882,000 4.922 107.188 110.500 2796.000 11.273 36,844 42.250 3930,000 3.461 28.469 32.750 3646.000 3.381 21.54.7 22.141 3924.000 3.537 24.859 25.141 3688.000 5.887 20.172 20.266 430~.000 8.734 117.375 99.500 2736.000 13.930 24,344 29.~84 3978,000 27.219 25.766 ILM DT CALl FCNL DT CALI FCNL IbM D~' CALl DT CALl FCNL DT CALI FCNb DT CALl FCN5 IDM DT CALl FCNL IbM DT CALl FCNL OT CALl FCN~ DT -999.250 -999.250 5.258 970.500 5.113 74.563 9.016 1003.500 6,496 O0 1624.000 2.205 91.000 9,023 1388,000 1,869 90,750 8.805 1470.000 1,790 92.000 8,61,7 1423.000 2.971 82.375 8.578 1857.000 8.320 74.000 10,906 909.000 10.820 87,563 8,594 1361.000 2~.656 91,188 ILL NPHI ILD DRHO IhD NPHI DRHO ILD NPHI DRHO ILD NPSI DRHQ IGD NPHI DRHO ILD NPHI DRHO NPHI DRHO IhD NPHI DRHO ILD NPHI PAGE 1 68 1 68 1 ~8 I 68 -999.250 34.131 0.141 5.29'1 26.953 0.059 6.477 23.242 -0,015 2 152 0,003 1,810 26.514 0,018 1,765 25.391 0,016 2.848 20.947 -0.001 0.032 14,406 27,44~ 0.032 33 594 25:244 /P 009.H03 VF.R!FiCATION [,iSTI~G PAGE 4 ~0~ 2.240 GR kAT 2 . q36 NCNb 27.359 CALI 341q.000 FCNL ~PT 10100.000 &FLU ~ -42.65~ GR ~OB 2.563 GR ~AT 1.873 NCNL 295.250 Ib~ 101.,438 DT 114.6BB CALI 4484.000 FCNb SPT 10000.000 SFLO ? -61.09~ GR ~Ob 2.387 GR RAT 2.311 NCNb 15.672 IbM 114.~13 DT 69.375 CALl 3572.000 FCNL EPT 9900.000 &FLU P -13.383 GR HOB 2,~45 G~ RAT 3.377 NCNb 2.006 IbM 101.188 DY 115.125 CaLl 1952.000 FCNL EPT 9825.000 SFLU P -999.250 G~ HO~ 2,176 GR RAT 3.793 .NCNb -999.250 IhM -999.250 DT 56.625 CALI 1626.000 FCNL ~ FILE TRAILER ** ILE NASE :SERVIC.00~ ERVICE NAME : ERSION # : ATE : AXIMUM LENGTH : 1024 ILE TYPE : EXT FILE NAME : EOF * TAPE TRAILER ERVICE NA~E :SER~IC ATE :81/08/26 RIG!N :1070 APE NA~E :62123 ONTINUATION ~ :01 EXT TAPE NAME : OMMENT8 :TAPE COMMENTS * REML TRAILER ** ER~ICE NAME :SERVIC ATE :81108/26 RIGI ~ : EEL NANE :REEL iD ONTINUATION ~ :01 EXT REEL NAME : :OM~MENTS :R~,Eb CO~q~ENTS ~ · 8.648 1306.000 55.781 71.000 9.891 2314.000 11.039 80.563 8.789 1435.000 1.795 108.000 14.070 525.000 -999.250 -999.250 8.8~6 404.500 DRHO ILO NPHI DRHO ILD NPHI DRHO ILD NPHI DRhO NPHI DRHO 0,015 82.750 15.2~3 -O.OO1 11.320 23.193 0.070 1.759 36.426 0.053 -999.250 48.242 -0.630 JP'OO9.H03 VERIFICATION LISTING PAGE